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Home My WebLink About207-1627. 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 02-40 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-162 50-029-23377-00-00 12800 Conductor Surface Intermediate Production Liner 8995 108 3454 10296 3524 10450 20" 9-5/8" 7" 4-1/2" 8561 29 - 108 29 - 3483 26 - 10322 9276 - 12800 29 - 108 29 - 3415 26 - 8464 7695 - 8995 none 3090 5410 7500 10450 , 10770 , 10800 , 11181 5750 7240 8430 10336 - 12700 4-1/2" 12.6# 13CR 24 - 9285 8474 - 9000 Structural 4-1/2" BKR S-3 , 9167 , 7615 9167 7615 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028311 24 - 7702 526 607 66547 60330 23 17 0 0 1152 1105 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV 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 3:52 pm, May 16, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.05.16 10:29:43 - 08'00' Bo York (1248) RBDMS JSB 052224 DSR-5/20/24WCB 7-16-2024 ACTIVITYDATE SUMMARY 4/19/2024 T/I/O=1700/442/0 Temp= S/I Assist E-line. Bullhead 192 bbls of crude down tubing. Shutdown and standby for E-line to set CIBP. Fill void and pressure up to 1500 psi with 3 bbls of crude. Lost 70 psi in 10 mins, plug appears to be holding. Bleld back1.2 bbls of crude. Final WHPS=279/458/0 E-Line in control of well upon departure. 4/19/2024 *** WELL SHUT IN ON ARRIVAL*** PT PCE 250LP 3000HP LOAD WELL WITH CRUDE CCL CORRELATED TO SLB JEWELRY LOG 09-Apr-2010 SET 3.50" NS CIBP @ (10,450 MD) (CCL STOP DEPTH= 10,438.9) (CCL- ME=11.1') TEST PLUG 1500 PSI FOR 10 MINS PERFORATE (10,336-10,366). ( CCL STOP DEPTH= 10,327.4) (CCL-TS=8.6') BLEED OFF LUB RD NOTIFY PAD OP OF WELL STATUS **JOB COMPLETE** Daily Report of Well Operations PBU 02-40 CIBP and adperfs are correctly shown on the new WBS, below. -WCB PERFORATE (10,336-10,366). SET 3.50" NS CIBP @ (10,450 MD) 7. 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 02-40 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-162 50-029-23377-00-00 12800 Conductor Surface Intermediate Production Liner 8995 108 3454 10296 3524 10770 20" 9-5/8" 7" 4-1/2" 8805 29 - 108 29 - 3483 26 - 10322 9276 - 12800 29 - 108 29 - 3415 26 - 8464 7695 - 8995 none 3090 5410 7500 10770 , 10800 , 11181 5750 7240 8430 10578 - 12700 4-1/2" 12.6# 13 CR 24 - 9285 8660 - 9000 Structural 4-1/2" BKR S-3 , 9167 , 7615 9167 7615 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028311 24 - 7702 644 526 62315 66547 23 23 0 0 1141 1152 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV 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 Samantha Coldiron at 9:09 am, Mar 08, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.07 10:15:05 - 09'00' Bo York (1248) WCB 2024-06-25 RBDMS JSB 031424 ACTIVITYDATE SUMMARY 2/9/2024 ***WELL FLOWING ON ARRIVAL*** (SET PLUG IN PROGRESS) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH THUNDER BIRD LOAD THE WELL WITH 180 BBLS OF CRUDE, RUN #1 W/CH/ X2 WB 1 11/16''/2.75'' GUN GR-CCL/BAKER#1/ 3.5'' OD CIBP TO SET PLUG AT=10800' CCL TO MID ELEMENT=12.5' CCL STOP DEPTH=10787.5 GAMMA RAY-CCL LOG CORRELATE TO SLB JEWELRY LOG DATED 09-APRIL- 2010 PLUG DIDN'T PASS THE PRESSURE TEST,TOWN MAKE DECISION TO SET AN OTHER PLUG IN THE MORNING LAY DOWN FOR THE NIGHT ***CONTINUE JOB ON 2/10/24*** 2/9/2024 T/I/O= 2470/500/0 TFS Unit 4 Assist E-Line (Load and Test) Pumped 3 BBLS of 60/40 and 180 BBLS of Crude to Load. Pumped 190 BBLS of Crude to Pressure test the plug. pumped total of 370 BBLS Crude down TBG, FWHP=145/500/0 Eline in control of well upon departure 2/10/2024 T/I/O= 364/500/0 TFS Unit 4 Assist E-Line Pump as directed and assist E-Line with Pressure Tests and Bleed downs. E-Line in control of Well upon departure. FWHP= 475/500/0 2/10/2024 *** JOB CONTINUE FROM 2/9/2024*** OBJECTIVE: SET SECOND 3.5'' CIBP PERFORATE TWO INTERVAL W/2.75'' GEO RAZOR GUN 6 spf 60 DEG PHASE PT PCE 300 PSI LOW./3000 PSI HIGH LOSS OF PRESSURE CONTROL DRILL RUN #1 CH/X 2 WB/2.75'' GUN GAMMA/BAKER #10/ 3.5'' OD CIBP TO SET PLUG AT 10770' CCL TO MID ELEMENT=12.5' CCL STOP DEPTH=10757' RUN #2 W/CH/2.75'' GUN GAMMA/20' OF 2.75'' GEO RAZOR GUN 6spf 60 DEG PHASE TO PERFRATE INTERVAL 10578'-10598' CCL TO TOP SHOT=7.8 CCL STOP DEPTH=10570.2' GAMMA RAY CCL CORRELATE TO SLB JEWELRY LOG DATED 9-APRIL-2010 JOB COMPLETE *** WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 02-40 SET PLUG AT=10800' CCL TO MID ELEMENT=12.5' CCL STOP DEPTH=10787.5 GAMMA RAY-CCL LOG CORRELATE TO SLB JEWELRY LOG DATED 09-APRIL- 2010 PLUG DIDN'T PASS THE PRESSURE TEST,TOWN MAKE DECISION TO SET AN OTHER PLUG IN THE MORNING PERFRATE INTERVAL 10578'-10598' CIBPs and adperfs are shown correctly on the new WBS, below. -WCB CIBP TO SET PLUG AT 10770' 7. 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): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well 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 02-40 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-162 50-029-23377-00-00 12800 Conductor Surface Intermediate Production Liner 8995 108 3454 10296 3524 11181 20" 9-5/8" 7" 4-1/2" 9039 29 - 108 29 - 3483 26 - 10322 9276 - 12800 29 - 108 29 - 3415 26 - 8464 7695 - 8995 none 3090 5410 7500 11181 5750 7240 8430 11040 - 12700 4-1/2" 12.6# 13 CR 24 - 9285 8984 - 9000 Structural 4-1/2" BKR S-3 9167 9167 7615 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 13.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 0028311 24 - 7702 414 642 44089 43013 212 31 0 0 1711 900 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 7615 No SSSV By Samantha Carlisle at 12:14 pm, Nov 15, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.11.15 08:53:13 -09'00' Bo York ACTIVITYDATE SUMMARY 10/5/2021 ***WELL SI ON ARRIVAL*** DRIFT WITH 3.70" X 9' DUMMY SUMP PACKER TO 11,240' SLM ***WELL LEFT SHUT IN*** 10/19/2021 ***WELL S/I ON ARRIVAL*** (SUBSIDENCE DRIFT) RAN 20' x 3.70" DMY WHIPSTOCK TO 2,500' SLM, NO ISSUES. WEATHER STANDBY FOR HIGH WINDS. ***WELL S/I ON DEPARTURE, INCOMPLETE, WILL RETURN TO FINISH JOB*** 10/21/2021 **WELL S/I ON DEPARTURE** DRIFTED w/ 3.78" GAUGE RING TO TAG @ 9245'SLM(9273'MD) *28' C/F* SET NORTHERN SOLUTIONS 3.70" SUMP PACKER w/ 2.31" PXN INSTALLED @ 11153'SLM(11181'MD) SET P-PRONG IN PXN @ 11154'SLM **TURNED WELL OVER TO OPERATIONS, S/I ON DEPARTURE** Daily Report of Well Operations PBU 02-40 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 direct inspection of the file. ~~ ~ - ~ ~~ Well History File Identifier Organizing (aone> RE CAN Color Items: ~Greyscale Items: ~~ ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing II I II it II I I III I I III BY: Maria Date: U ~ lsl Scanning Preparation ~ x 30 = ~_ + =TOTAL PAGES Count does not include cover sheet) , BY: Mana Date: /s/ ___ it ~~~ _____ -~ ' J / III IIIIN IIIII II III Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: l/ YES NO BY: Maria Date: ~ ~ D~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I IIlI II I (I II I I III Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked I+) IIIIII III IIII III ~.wo.a.a iiumiiiuiuim DIGITAL DATA Ae.~~~eee~ iuuiumiuuu OVERSIZED (Scannable) ^ D' kettes, No. ^ Maps: Other, No/Type: ~~ I~~D :~ ^ Other Items Scannable by a Large Scanner 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 sr 2 August 22, 2011 ik* Mr. Tom Maunder . �� 42 0/ 4 0 Alaska Oil and Gas Conservation Commission 4rc 333 West 7th Avenue Ait's . Anchorage, Alaska 99501 r S itio4 Subject: Corrosion Inhibitor Treatments of GPB DS -02 a07-/ 6g, Dear Mr. Maunder, O 3 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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 -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -326 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 (-) ,,~~.. r~ ~. ~~~~ ~ ~ ,~ .:, _ ~..~ W ~ ~~ ~~ ~~ Ij ° 4~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ALASKA AND GAS CONSE VAT ON COMMISS~ ~~~~~~~~ REPORT OF SUNDRY WELL OPERATIONS APR } 6 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time ~~.Ci0171(1 Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ~~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development Q Exploratory ^ 207-1620 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6 12 50-029-23377-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028311 ~ PBU 02-40 10. Field/Pool(s): PRUDHOE BAY FIELD ! PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12800 feet Plugs (measured) None feet true vertical 8995.05 feet Junk (measured) None feet Effective Depth measured 12714 feet Packer (measured) 9167 true vertical 8999.22 feet (true vertical) 7615 Casing Length Size MD TVD Burst Collapse Structural Conductor 108 20" 215.5# A-53 SURFACE - 108 SURFACE - 108 Surface 3454 9-5/8"40# L-80 29 - 3483 29 - 3415 5750 3090 Intermediate Production 10296 7" 26# L-80 26 - 10322 26 -8464 7240 5410 Liner 3524 4-1 /2" 12.6# L-80 9276 - 12800 7695 - 8995 8430 7500 Liner Perforation depth: Measured depth: O 11475 - 11950 O 12600 - 12700 O 11040 - 11060 ~ True Vertical depth: 9048.62 - 9043.35 9006.14 - 8999.9 8984 - 8994 Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# 13CR SURFACE - 9285 SURFACE - 7702 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 9167 7615 12. Stimulation or cement squeeze summary: ~y 1~ Intervals treated (measured): y„ &~,~~~='~~ ~~~ ~ ~ F~~~J 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: 1031 37052 258 1709 Subsequent to operation: 1133 36960 280 1668 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 1~ Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 4/13/2010 r Ullll IU-YUY RCVI}SCU //LVVy { {y{,~{r{V 111 ~~ i ~ LV ~V ~`J'/iJ .~ vuu~i~ia v~~cy~~ia~ v~~~y • • 02-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 4/9/2010***WELL FLOWING ON ARRIVAL*** (ELINE - ADPERF) ~SSV = 0, INITIAL T/I/O = 2000/700/50 PSI °TD NOT TAGGED, STOPPED DUE TO DEVIATION AT 11130' PERFORATE FROM 11040'-11060' WITH 3-3/8" PJ, HMX GUN. jGUN API DATA: PENETRATION = 36.5", ENTRANCE HOLE = 0.37" DEPTH REFERENCED TO SPERRY-SUN MWD DATED 18-AUG-2008 l I***JOB CONTINUED ON 10-APRIL-2010*** 4/9/2010***WELL FLOWING ON ARRIVAL***(btm shot @ 11060 md) 3DRIFT W/3-3/8" DMY GUN TO 11,168' SLM (73 degrees), NO RESTRICTIONS. !T/IA/OA= 2400/700/0 "**WELL LEFT S/I, DSO NOTIFIED OF WELL STATUS""*. 4/10/201 U T/I/0=1740/770/150. Temp=106 deg. Bleed IAP -300 psi (eval PC leak). IA FL @ 6278' Sta # 3 sogly. OA FL @ Surface. Bleed IA to 270 psi, 50 min, OAP increased 90 psi to 240 psi. IA FL unchanged @ 6278' sogly. Monitor 1 hr. No change in IAP, OAP decreased 160 psi to 80 psi. Final WHPs=1740/270/80. SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP. 4/10/2010. *'`'"JOB CONTINUED FROM 9APRIL-2010*** POOH WITH SHOT GUN, CONFIRM SHOTS FIRED AT SURFACE, RD ELINE FINAL T/I/0 = 2400/700/0 ***JOB COMPLETE*"" FLUIDS PUMPED BBLS 1 diesel 2 meth 3 Total :EE = CNV WELLHEAD = FMC ACTUATOR = BAKER C KB.ELEV = 58.7 BF. ELEV = 32.8 KOP = 2500 Max Angle = 98° @ 12488' Datum MD = 10841' Datum TV D = 8800' SS (20" CONDUCTOR, 21.5#, A-53, ID = ? ~ 10$' 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 34$3' Minimum ID = 3.725" @ 9273' 4-1 i2" HES XN NIPPLE 7" GSG, 26#, L-80 TCII XO TO L-80 BTGM 4923' 02-40 SAFETY ES:***CHROME TBG & NIPPLES*** WELLANGLE> 70° @ 11163' 1027' -j 9-518" TAM PORT COLLAR, ID = 8.679" 2173' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3478 3411 37 KBG2-1 R DOME BK 16 08/23/08 3 6278 5502 43 KBG2-1 R SO BK 20 08/23/08 2 8130 6857 44 KBG2-1 R DMY BK 0 08120/08 1 9099 7565 42 KBG2-1 R DMY BK 0 08/20108 9136 1-j 4-1/2" HES X NIP, ID = 3.813" I 9167' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 92~ 4-112" HES X NIP, ID = 3.813" 9j 273' I 9276' 4-112" TBG, 12.6#, 13CR VAM TOP, ( 92$5' .0152 bpf, ID = 3.958" 7" CSG, 26#, L-80 BTGM, ID = 6.276" ~-~ 10322' PERFORATION SUMMARY REF LOG: SLB MWD 11107/08 ANGLE AT TOP PERF: 94° @ 11475' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 11475 - 11950 O 08/21 /08 2-718" 6 12600 - 12700 O 08/21/08 PBTD 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 1 12713' 1 9i?$5=1 9294' 9~ 3fl5' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/22/08 N2ES ORIGINAL COMPLETION 09!01/08 JLJ/PJC GLV C!O (08/23!08) 08/17(09 FR1JM0 DRLG DRAFT CORRECTIONS 4-1/2" HES XN NIP, ID = 3.725" ( 7" X 5" G2 BKR ZXP LTP w (fIEBACK~ ID = 4.420" 4-1/2" WLEG, ID = 3.958" 7" X 5" FLEXLOCK LNR HGR, ID = 4.460" 5" X 4-1i2" XO, ID = 3.910" PRUDHOE BAY UNff WELL: DS 12-37 PERMIT No: 2071620 API No: 50-029-23377-0000 SEC 36, T11 N, R14E, 857' FNL & 1734' FWL BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071620 Well Name/No. PRUDHOE BAY 02-40 MD 12800 TVD 8995 Completion Date 8/21/2008 REQUIRED INFORMATION Mud Log No Operator 8P EXPLORATION (ALASKA) INC API No. 50-029-23377-00-00 Completion Status 1-OIL Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name C Lis 169641/Induction/Resistivity LIS Verification ~D C Lis 1696 Induction/Resistivity I' D C 16966 Se N t e o es !~g Induction/Resistivity /tog Induction/Resistivity '~og Induction/Resistivity ~ og Induction/Resistivity // (iED C Exc Directional Survey ~~t I Directional Survey !,iED C Exc Directional Survey pt Directional Survey pt LIS Verification Log Log Run Scale Media No Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 146 12800 Open 9/30/2008 LIS Veri, GR, ROP, RPD, NPHI, RPM, NCNT, FET, DRHO, RPS, RHOB, PEF, RPX, NCNT 146 12800 Open 9/30/2008 LIS Veri, GR, ROP, RPD, NPHI, RPM, NCNT, FET, DRHO, RPS, RHOB, PEF, RPX, NCNT 146 10449 Open 9/30/2008 P61 LIS Veri, GR, ROP, FET, RPD, RPX, RPS, RPM 146 10449 Open 9/30/2008 P61 LIS Veri, GR, ROP, FET, RPD, RPX, RPS, RPM 0 0 9/30/2008 TVD and MD EWR logs with P61 in EMF, CGM and PDF graphics 25 Col 212 12800 Open 9/30/2008 MD ROP, DGR, CTN, SLD, EWR 25 Col 212 8995 Open 9/30/2008 MD ROP, DGR, CTN, SLD, EWR 25 Col 212 j.0449 Open 9!30/2008 P61 MD ROP, DGR, EWR 25 Col 212 8545 Open 9/30/2008 P61 TVD DGR, EWR 0 12800 Open 10/8/2008 0 12800 Open 10/8/2008 0 10449 Open 10/8/2008 PB 1 0 10449 Open 10/8/2008 PB 1 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071620 Weil Name/No. PRUDHOE BAY 02-40 Operator BP EXPLORATION (ALASKA) INC MD 12800 TVD 8995 Completion Date 8/21/2008 Completion Status 1-OIL Gurrent Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received ? % N Chips Received? Y7"I~' Formation Tops Analysis Received? Comments: Compliance Reviewed By: API No. 50-029-23377-00-00 UIC N Date: ~~ 7 ~l'~~ ----- Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.comj Sent: Thursday, October 02, 2008 11:15 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 02-40 / PTD # 207-162 H i Art, Please reference the following well: Well Name: PBU 02-40 Permit #: 207-162 API #: 50-029-23377-00-00 Top Perf MD: 11475' Bottom Perf MD: 12700' This well began Production on September 12, 2008 Method of Operations is: Flowing Date of Test: All Test Data was Reported on the 10-407, Dated 09/19/08 ~` Apparently the well was put on Production on 09/12/08, but it didn't show up in the database correctly. 10/2/2008 • WELL LOG TRANSMITTAL To: State of Alaska September 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 02-40 AK-MW-5892494 02-40: 1 LDWG formatted CD rom with verification listing. API#: 50-029-23377-00 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: ~~~-r~~ ~~~~~" i i WELL LOG TRANSMITTAL To: State of Alaska September 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 02-40 PBl AK-MW-5892494 02-40 PB1: 1 LDWG formatted CD rom with verification listing. API#: 5 0- 029-23 3 77-70 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 Si ed: lm WELL LOG TRANSMITTAL To: State of Alaska September 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 02-40 + PBl AK-MW-5892494 02-40 + PB1: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23377-00,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23377-00,70 Digital Log Images: 1 CD Rom 50-029-23377-00,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 995'18 Anchorage, Alaska 99508 Date:.. Signed: 11-Sep-08 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well DS 02-40 Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and one disk. DS 02-40 Tie-on Survey: 3482.63' MD Window Survey: 3517.00' MD Projected Survey: 12,800.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~'~ ~~'^ d Signed ~~ ~ ~1~r'`.r-e)~. Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~~. ~ ~ ~~~ ~ ~ ~~ ~ _~ b 11-Sep-08 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well DS 02-40PB1 Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and one disk. DS 02-40PB1 Tie-on Survey: 3482.63' MD Window Survey: 3517.00' MD Projected Survey: 12,800.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~' ~~ Signed ~~- ~ hN~c9. Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) y~ ~ I ^~ ~LC.{eNl. ~ 1Mae l~~ /SOS` ~~07- ~ ~ ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZe.,os zoAACZe.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Ex location (Alaska) Inc. 5. Date Comp., Susp., or Aba 8/21/2008 12. Permit to Drill Number 207-162 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/11/2008 ~ 13. API Number 50-029-23377-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/17/2008 " 14. Well Name and Number: PBU 02-40 4423 FSL, 3546 FEL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 862' FSL, 2429' FEL, SEC. 35, T11 N, R14E, UM 8. KB (ft above MSL): 58.9' Ground (ft MSL): 30.4' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 170' FNL, 3765' FEL, SEC. 02, T110, R14E, UM 9. Plug Back Depth (MD+TVD) 12714' 8999' P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 688482 y- 5950366 Zone- ASP4 10. Total Depth (MD+TVD) 12800' 8995' 16. Property Designation: ADL 028311 TPI: x- 684412 y- 5946703 Zone- ASP4 Total Depth: x- 683102 y- 5945639 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No m' 'n ' n 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETT,NG DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED , 7" -1/ " 4- /2" 1 7 ' / " 7 I 23. Open to production or inject ion? ®Yes ^ No 24. T UaING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, 13Cr80 9285' 9167' , MD TVD MD TVD 11475' -11950' 9049' - 9043' 12600' -12700' 9006' - 9000' 25. ACID, FRACTURE, CEMENT SQUEEZE, erc. DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED Freeze Protected w/ 95 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: 9/12/2008 Hours Tested: 12 PRODUCTION FQR TEST PERIOD OIL-BBL: g25 GAS-MCF: 15,154 WATER-BBL: 287 CHOKE SIZE: 55 GAS-OIL RATIO: Flow Tubing Press. 1,691 Casing Press: 1,600 CALCULATED 24-HouR RaTE..' OIL-BBL: 1,649 GAS-MCF: 30,308 WATER-BBL: 574 OIL GRAVITY-API (CORK): 27. CARE DATA Conventional Core(s) Acquired? ^Yes ® No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. UUMPLETIUN None, ~~ rOrm 10-4q/ KeVl3ed U'1/ZUUI GQNTINUED UN KEVER$E 51DE ~, ,~ r ~ S ~~, ~~P ~ ~ 2D06 `~~3~ 2ti. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MAR ENCOUNTERED): 29. TrON TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 1853' 1852' results. Attach separate sheets to this form, ff needed, and submit detailed test information per 20 AAC 25.071. Sag River 10324' 8465' None Shublik A 10370' 8500' Shublik B 10402' 8524' Shublik C 10422' 8540' Sadlerochit 10464' 8572' Top CGL /Zone 3 10714' 8763' Base CGL /Zone 2C 10822' 8845' 23S6 /Zone 26 10904' 8904' 25N 10924' 8917' 22TS 10998' 8962' 22N 11071' 8999' 21TS /Zone 2A 11101' 9012' HOT 11220' 9049' HOT (Invert) 11474' 9049' 21TS/ Zone 2A (Invert) 12430' 9025' 22N (Invert) 12589' 9007' Formation at Total Depth (Name): 21TS /Zone 2A 11101' 9012' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the for 'ng is true and correct to the best of my knowledge. l C~ 0 ~ / (( l Signed Terrie Hubble Title Drilling Technologist Date PBU 020 207-162 P~epamd ey NameAVu~er. Tenie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Frank Roach, 564-4373 INSTRUCTlON3 GENEw-r.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well cempletion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defir~d as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cered and the correspondirxxl formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATfON Page 1 of 1 Leak-Off Test Summary Legal Name: 02-40 Common Name: 02-40 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 7/15/2008 LOT 3,510.0 (ft) 3,430.0 (ft) 8.80 (ppg) 650 (psi) 2,218 (psi) 12.45 (ppg) 7/30/2008 FIT 3,483.0 (ft) 3,414.0 (ft) 9.20 (ppg) 532 (psi) 2,164 (psi) 12.20 (ppg) 8/7/2008 FIT 10,322.0 (ft) 8,464.0 (ft) 8.50 (ppg) 950 (psi) 4,687 (psi) 10.66 (ppg) n ~J Printed: 9/8/2008 11:15:18 AM BP EXPLORATION Page 1 of 23 Operations Summary.... Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date i From - To ~ Hours TasK i Code NPT Phase ~ Description of Operations -- 7/9/2008 12:00 - 18:00 6.00 RIGD P PRE PJSM. Rig down primary unit. Rig down disconnect. Move pits off sub. Pull matting from sub. Make final preperstions for move. 18:00 - 00:00 6.00 MOB P PRE Move rig from 02-04 to 02-40. 7/10/2008 00:00 - 01:00 1.00 MOB P PRE PJSM. Move rig from 02-04 to 02-40. Rig accept at 00:00 hours. 01:00 - 07:00 6.00 MOB P PRE Line up sub. Spot herculite. Back rig to well. Remove flanges from BOP stack. Move rig over well. Remove mats from 02-04. 07:00 - 17:00 10.00 RIGU P PRE Nipple up Hydril and diverter system. Take on spud mud. Load pipe into pipe shed. Prep for spud. 17:00 - 18:00 1.00 DRILL P SURF Hold pre-spud meeting with onsite personnel. 18:00 - 18:30 0.50 BOPSU P SURF PJSM. Function test diverter and hold diverter drill - OK. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL's Bill Decker and Mitch Skinner and Toolpusher's Cleve Coyne and John Castle. 18:30 - 23:30 5.00 BOPSU P SURF PJSM. PU and MU 30 stands 5" DP and 6 stands HWDP. 23:30 - 00:00 0.50 DRILL P SURF PJSM. Rig up GYRO wireline unit. 7/11/2008 00:00 - 01:00 1.00 DRILL P SURF PJSM. Service rig. Hold pre spud with rig personnel. 01:00 - 03:00 2.00 DRILL P SURF PJSM. Pick up motor, bit, float sub and 1 stand heavy weight. Pump to fill pipe and stack with mud. Check for leaks. 03:00 - 03:30 0.50 DRILL P SURF Kick in pumps to 400 gpm with 600 psi. Still no leaks. Bring pumps up to 522 gpm with 710 psi. Rotate at 50 rpm with 1 k torque. Begin spud in. Up, down and RT weights 40k. WOB 5k. Drill ahead to nstall 4" bull plug in diverter line. 03:30 - 05:30 2.00 DRILL N SFAL SURF Drag chain failed and packed off. Chain jumped off sprocket. Shut down to clean out and repair. Remove 2 links and re-assemble. 05:30 - 08:30 3.00 DRILL P SURF Drill ahead to 219'. Pump at 500 gpm with 685 psi. Rotate at 80 rpms with 1k toruge. WOB 1-3k. 08:30 - 11:00 2.50 DRILL P SURF PJSM. Stand back HWDP. MU MWD tools, scribe and upload. PU flex drill collars to 174'. MU stand of HWDP and RIH to 203'. 11:00 - 12:00 1.00 DRILL P SURF Run sin le shot surve s with GYRO 12:00 - 14:30 2.50 DRILL N SFAL SURF PJSM. Add 8 paddles to drag chain. Re-assemble and adjust. 14:30 - 19:30 5.00 DRILL P SURF Directional drill ahead to 429'. Pump at 529 gpm with 1700 psi. Up, down ,and RT weights 65k. Run Gyro every stand, 19:30 - 20:30 1.00 DRILL N DPRB SURF Water comin u in cellar and around conductor on well # well #29. Shut down to evaluate. Clean up fluid. Line up Vac trucks to handle fluid coming to surface. Continue with rig operations. 20:30 - 21:00 0.50 DRILL N RREP SURF Repair topdrive rotary brake. 21:00 - 00:00 3.00 DRILL P SURF Drill ahead to 626'. Pumping at 529 gpm with 1700 psi. Sliding and rotating. Torque 1-2k at 80 rpm. WOB 1-5k. AST-1.26, ART-1.32, ADT-2.58. Mud weight in and out 8.8 ppg with 300+ vis. 7/12/2008 00:00 - 16:00 16.00 DRILL P SURF PJSM. Hold pre spud meeting with new crew during pre tour meeting. Directional drill ahead to 1050' MD. Pumping at 510 gpm with 1315 psi. WOB 10-15k. Torque 1-2k at 80 rpm. Continue to drill ahead to 2319'. Pump at 610 gpm with 1838 psi off bottom, 2015 psi on bottom.Torque 2-3k off bottom, 3-4k on bottom at 100 rpm. WOB 5-20k. 16:00 - 17:00 1.00 DRILL P SURF Circulate 3 bottoms up at 610 gpm with 1850 psi. Rotate and Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 2 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date ~; From - To Hours Task ~ Code NPT Phase Description of Operations 7/12/2008 16:00 - 17:00 1.00 DRILL P SURF reciprocate. Mud weight in and out 9.0 ppg. 17:00 - 19:00 2.00 DRILL P SURF PJSM. POOH to 806'. 19:00 - 19:30 0.50 DRILL P SURF PJSM. Rack back HWDP and collars. Break bit. 19:30 - 21:00 1.50 DRILL P SURF Pick up new bit. Set motor to 1.5 degree bend. Download/upload MWD. Run in to 806'. 21:00 - 23:30 2.50 DRILL P SURF RIH to 2319'. Take 15-25k down weight, hook up topdrive and wash through spots at 1208', 1410', 1720', 2124' and 2138'. Wash and ream last stand down. 23:30 - 00:00 0.50 DRILL P SURF Directional drill ahead to 2413' MD. Pump at 600 gpm with 1800 psi off bottom, 2010 psi on bottom. Rotate at 80 rpm with 2-3k torque off bottom, 4-5k torque on bottom. WOB 10-20k. ART-5.36, AST-4.71, ATD-10.07. 7/13/2008 00:00 - 08:30 8.50 DRILL P SURF PJSM. Directional drill ahead to 3125' MD. Pump at 640 gpm with 2140 psi off bottom, 2295 psi on bottom. Rotate at 80 rpm with 3-4k torque off bottom, 5-6k torque on bottom. WOB 5-25k. Mud weight in 9.2 ppg, out 9.3 ppg. Continue to drill ahead to Surface TD of 3490' MD. 3418' TVD. Pump at 650 gpm with 2230 psi off, 2330 psi on bottom. Rotate at 80 rpm with 3-4k torque off, 4-5k on bottom. WOB 15-20k. Up weight 125k, down 110k, RT 115k. 08:30 - 11:00 2.50 DRILL P SURF Circulate and condition with 3 bottoms up. Pump at 720 gpm with 2630 psi. Rotate at 85 rpm with 3-4k torque, Reciprocate. Unable to et back down ast 3430'. 11:00 - 11:30 0.50 DRILL P SURF Reamed back down to 3490', sliding with tool face up. Pump at 650 gpm wtih 2200 psi. WOB 25-30k. 11:30 - 12:30 1.00 DRILL P SURF Circulate at 650 gpm with 2200 psi until clean at bottoms up. Mud weight out 9.2 ppg, mud weight in 9.1 ppg. 12:30 - 13:30 1.00 DRILL P SURF PJSM. Perform wiper to 2225'. Hole appears to be in good shape. Tag bottom with 5k down. Establish circulation. 13:30 - 14:30 1.00 DRILL P SURF Circulate and condition until clean, pumping at 560 gpm with 1770 psi. Rotate at 50 rpm with 4k torque. Reciprocate with no problems. 14:30 - 16:00 1.50 DRILL P SURF PJSM. POOH to 806' with no problems. 16:00 - 19:30 3.50 DRILL P SURF PJSM. Rack back HWDP. Lay down collars. Break out bit. Download MWD. Lay down remaining BHA. Clear and clean floor. 19:30 - 00:00 4.50 CASE P SURF PJSM. Ri u to run 9 5/8" 40# L-8 Change out bales. PU 350 ton spiders. Make up Franks tool. Make dummy run and mark landing joint. Install XO to cement head. Rig up power tongs, back ups and stabbing board. 7/14/2008 00:00 - 01:00 1.00 CASE P SURF PJSM. Finish rigging up for casing run. 01:00 - 08:00 7.00 CASE P SURF Run 9-5/8", 40#, L-80, BTC casing to 3483' MD. Use Frank's tool to fill on the fly. Run Tam Port Collar. Average make up torque 8600 fUlbs. Rig up trucks and cementers. Load out cement head. Make up landing joint and run to bottom. Make up cement head. 08:00 - 10:00 2.00 CEMT P SURF Circulate and condition mud to 55 viscosity. Weight to 9.1 ppg. Stage pumps up to 286 gpm with 490 psi. Only able to reciprocate the pipe 2'. Up weight 170k, down 120k. Hold PJSM with rig and cement crews. 10:00 - 14:00 4.00 CEMT P SURF Begin cement job by pumping 5 bbls water and testing lines to 3500 psi, Pump 70 bbls of 10.2 ppg Mud Push II at 6 bpm. Printed: 9/8/2008 11:15:24 AM ~ ~ BP EXPLORATION Page 3 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To I, Hours Task Code NPT ~ Phase Description of Operations 7/14/2008 10:00 - 14:00 4.00 CEMT P SURF Drop bottom plug and follow with 710 bbls of 10.7 ppg lead cement at 6 bpm. Lose returns at end of lead slurry for 10 minutes then gain back. Water coming up in cellars on wells 29 and 3. Water sto ed when re ained returns. Pressure 440 psi at 7 bpm. Park on bottom at 3483' as lead rounds the corner. Pump 50 bbls of 15.8 ppg tail at 6 bpm. Shut down and drop top plug. Pump 10 bbls water to clear lines. Switch to rig pumps and chase cement with 9.1 ppg mud. Pump at 7 bpm with 1250 psi. Slow pumps to 2 bpm at 5 bbls before bumping calculated plug. Bump plug with 248 bbls of mud -right on calculated. Bump with 2050 psi. Got back approximately 300 bbls cement back to surface. Bleed off. Check floats, no flow back. Cement in place at 13:30 hours. 14:00 - 17:30 3.50 CEMT P SURF PJSM. Flush stack, flow line and troughs with retarder pill. Clean under shakers. Rig down cement head. Lay down casing equipment. Backout landing joint. Change out bales. Clear and clean floor. Flush out Hydril. 17:30 - 21:00 3.50 BOPSU P SURF PJSM. Nipple down diverter system. 21:00 - 22:00 1.00 WHSUR P SURF PJSM. Install new FMC 11"Gen 5 wellhead. Install new tubing spool. Test wellhead to 1000 psi - OK. 22:00 - 00:00 2.00 BOPSU P SURF Set BOP stack onto tubing spool. Change out bell nipple. NU BOPE. 7/15/2008 00:00 - 03:00 3.00 BOPSU P SURF PJSM. NU BOPE. Torque up flanges, install riser, install secondary annulus valves. Cement in 20" x 9-5/8" annulus do n ' 03:00 - 04:00 1.00 BOPSU P SURF Install test plug. Fill BOPE with water. Bell nipple leaking. 04:00 - 06:00 2.00 BOPSU P SURF Remove riser and bell nipple. Clean flanges and re-install. Fill ROPE with water. No leaks. 06:00 - 11:00 5.00 BOPSU P SURF Pressure test BOPE from 250 si low to 3500 si high with a 4" and 5" test joint. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP WSL Bill Decker and Nabors Tool Pusher Cleve Coyne. 11:00 - 11:30 0.50 BOPSU P SURF Rig down testing equipment and blow down choke and kill lines. 11:30 - 13:00 1.50 BOPSU P SURF Install wear ring and RILDS. Service the top drive. 13:00 - 15:30 2.50 CASE P SURF Make up an 8.5" bit and RIH on 5" drill pipe to 3276'. 15:30 - 16:00 0.50 CASE P SURF Make up to top drive and break circulation. circulate one one drill pipe volume at 648 GPM, 1700 psi. 16:00 - 16:30 0.50 CASE P SURF Pressure test 9-5/8" 40# surface casin to 3500 si. Hold test for 30 minutes and chart. Bled off 50 psi in first 15 min, 0 psi in second 15 min. 16:30 - 18:00 1.50 CASE P SURF Ta to of cement at 3373' Drill float equipment and shoe. Printed: 9/8/2008 11:15:24 AM BP EXPLORATION .Operations Summary Report Page 4 of 23 Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To Hours .Task ~, Code NPT Phase Description of Operations 7/15/2008 16:30 - 18:00 8:00 - 18:30 1.50 .50 CASE ASE P P SURF URF Begin displacing with 8.8 ppg LSND while drilling shoe. Drill 20' of new formation to 351 ' 610 GPM, 1390 psi, 84 RPM, 4K TO off, 5-6K TO on, 10K WOB, PU 125K, SO 110K, ROT 115K. Circulate bottoms up with 8.8 ppg LSND at 706 GPM, 1000 psi. Perform T t 12.5 EMW with 65 i rf r r . 18:30 - 21:30 3.00 CASE P SURF POOH laying down 5" drill pipe to 185'. 21:30 - 00:00 2.50 CASE P SURF Pick up 81 joints of 4" drill pipe. 7/16/2008 00:00 - 10:30 10.50 DRILL P INT1 Pick up 4" drill pipe singles and RIH to 3457" MD. Circulate at max rates to remove scale and POOH racking back stands in the derrick. Repeat process 2x until) enough 4" drill pipe is racked back to TD 8.5" intermediate hole section. Lay down drill collars, bit sub and 8.5" bit used to drill out 9-5/8" shoe. 10:30 - 13:00 2.50 DRILL P INT1 Change out the saver sub valve from 4-1/2" IF to HT-40. Change out the gripper ends and stabbing guide. Test the valve to 250 psi low and 3500 psi high. 13:00 - 14:30 1.50 DRILL P INT1 Make up the 8.5" intermediate drilling BHA with 8.5" Hycalog PDC bit, 1.22 degree bent housing motor, float, stabilizer, DIR/GR/PWD, 3 drill collars, circ sub, jars, and heavy weight. 14:30 - 15:30 1.00 DRILL P INTi RIH with 8.5" drilling BHA to 823'. 15:30 - 16:00 0.50 DRILL P INTi Shallow hole test the MWD tools at 500 GPM, 333 psi. 16:00 - 18:00 2.00 DRILL P INT1 Continue to RIH to 3433' MD. Place a ghost reamer in the drill string 1563' behind the bit. 18;00 - 19:30 1.50 DRILL P INT1 Slip and cut 99' of drilling line. 19:30 - 20:00 0.50 DRILL P INT1 Pick up another stand of drill pipe and estabilsh circulation at 500 GPM, 1183 psi. Obtain baseline ECD's at 500 GPM, 100 RPM = 8.86 ppg EMW and at 575 GPM, 100 RPM = 8.79 ppg EMW. PU 105K, SO 95K, ROT 103K. 20:00 - 00:00 4.00 DRILL P INT1 Drill 8.5" intermediate hole section from 3510' to 4013' MD. 1560 psi off, 1689 psi on, 100 RPM, 560 GPM, 3K TO off, 5K TO on, 5-10K WOB. 9.28 ECD Actual Drilling Time = 2.28 hrs, Slide Time = 0.49 hrs. Mud weight in and out = 8.9 ppg. 0 bbls lost to formation. 7/17/2008 00:00 - 12:00 12.00 DRILL P INTi Drill 8.5" intermediate hole from 4013' MD to 5334' MD. PU 140K, SO 100K, ROT 115K, 5-10K WOB, 100 RPM, 6-7K TO, 588 GPM, 2100 psi off, 2210 psi on. Actual Rotating Time = 6.67 hrs, Actual Slide Time = 0.72 hrs. Mud weight in = 9.1 ppg, mud weight out = 9.2 ppg 12:00 - 00:00 12.00 DRILL P INT1 Drill 8.5" intermediate hole from 5334' MD to 7048' MD. PU 170K, SO 110K, ROT 132K, 10K WOB, 120 RPM, 10-11K TO on, 7-8K TO off, 588 GPM, 2695 psi off, 2902 psi on. Actual Rotating Time = 6.52 hrs, Actual Slide Time = 1.02 hrs. Mud weight in = 9.2 ppg, mud weight out = 9.2 ppg. Adding 35 bbls/hr of water to mud system. Actual ECD's = 9.91 ppg. 7/18/2008 00:00 - 05:30 5.50 DRILL P INT1 Drill from 7048' MD to 7638' MD. Pu 185K SO 110K, ROT 140K, WOB 10-12K, 120 RPM, 8-9K TO on, 9-11 K TO off, 590 GPM, 2810 psi off, 3020 psi on. Printed: 9/8/2008 11:15:24 AM • • BP EXPLORATION Page 5 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours -Task i Code NPT Ph ase Description of Operations 7/18/2008 00:00 - 05:30 5.50 DRILL P INT1 Total slide time = 0.9 hrs. Mud weight in 9.4 ppg, Mud weight out 9.5 ppg. 05:30 - 06:30 1.00 DRILL P INT1 Circulate a nut plug/Sapp sweep at 590 GPM, 2920 psi. 06:30 - 08:00 1.50 DRILL P INTi Short trip from 7638' MD to 5052' MD, placing ghost reamer inside 9-5/8" casing shoe. 08:00 - 09:00 1.00 DRILL P INT1 Trip in hole from 5052' MD to 7546' MD. 19/2008 09:00 - 00:00 0:00 - 12:00 15.00 2.00 DRILL RILL P P INT1 NTi Hole in good condition, did not take any weight. Break circulation at 540 GPM, 2910 psi. Drill 8.5" intermediate hole from 7638' MD to 8787' MD. PU 185K, SO 130K, ROT 150K, 8-14K WOB, 120 RPM, 6-9K TQ, 590 GPM, 3200 psi off, 3420 psi on. Total Slide time = 1.69 hrs. Mud weight in 9.2, mud weight out = 9.3 ppg. Drill 8.5" intermediate hole from 8787' MD to 9508' MD. PU 185K, SO 134K, ROT 153K, 530 GPM, 3850 psi off, 4050 psi on, 7-8K TQ off, 8-9K TO on, 5-15K WOB, 120 RPM. Actual Slide Time = 1.51 hrs, Total Drill Time = 8.14 hrs. Began adding 16 ppg LSND spike fluid at 9133' MD to 932i' MD. Mud weight in and out 10.6 ppg. Calculated ECD = 11.15 ppg EMW, Actual ECD = 11.21 ppg EMW. 12:00 - 00:00 12.00 DRILL P INT1 Drill 8.5" intermediate hole from 9508' MD to 10,254' MD. Pu 205K, SO 135K, ROT 165K, 12K WOB, 120 RPM, 9-10K TO on, 9K TQ off, 500 GPM, 3830 psi off, 3950 psi on. Actual Slide Time = 2.52 hrs, Actual Drill Time = 9.27 hrs. Mud Weight in and out 10.6 ppg. 7/20/2008 00:00 - 01:30 1.50 DRILL P INT1 Drill 8.5" intermediate hole from 10,254' MD to 10,348' MD. PU 205K, SO 135K, ROT 165K, 9K TO off, 9-10K TQ on, 12K WOB, 120 RPM, 500 GPM, 3750 psi off, 4050 psi on. Total Drill Time = 1.08 hrs, no slides. Mud weight 10.6 ppg in and out. TD called b eolo ist at 10 34 ' MD 01:30 - 03:00 1.50 DRILL P INT1 Circulate bottoms up to confirm TD in the transition zone between Kingak and Sag River. Continue to circulate a second bottoms up. 500 GPM, 3830 psi, 120 RPM. 03:00 - 04:00 1.00 DRILL P INTi Short trip from TD to 8945' MD. Bring ghost reamer 3 stands above previous short trip depth. Hole in good condition, less than 15K overpulls. 04:00 - 04:30 0.50 DRILL P INTi RIH to TD at 10,348' with no problems. 04:30 - 07:00 2.50 DRILL P INT1 Circulate the hole clean with 2 bottoms up at 515 GPM, 4000 psi. 07:00 - 12:00 5.00 DRILL P INTi POOH from 10,348' MD to 823' MD. PU 230K, SO 135K. LD ghost reamer at 1563'. No overpulls on trip out. 12:00 - 15:00 3.00 DRILL P INT1 Lay down the 8.5" drilling BHA including 8.5" PDC bit, 1.22 degree bent housing motor, float, stabilizer, DIR/GR/PWD, Drill collars, circ sub, HWDP, and jars. 8.5" Hycalog DTX619M-D6 PDC bit graded Printed: 9/8/2008 11:15:24 AM • BP EXPLORATION Page 6 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours i Task Code NPT Phase Description of Operations 7/20/2008 12:00 - 15:00 3.00 DRILL P INTi 2-2-CT-G-0-1-WT-TD. Drilled 6838' avera in 161 Whr BOP. 15:00 - 18:00 3.00 BOPSU P INTi Chan a out the 3-1/2"x6" variable rams to 7". Remove the wear bushing. Pick up a 7" test joint and test top rams to 250 psi low, 3500 psi high. Test witnessed by BP WSL Bill Decker and Nabors Tool Pusher Charlie Henley. Rig down test equipment. 18:00 - 20:30 2.50 CASE P INTi Rig up to run casing. Bring the casing tools and long bails to rig floor. Change out bails. Make up the Franks tool. 20:30 - 00:00 3.50 CASE P INTi PJSM to run casing. Run in hole with 7", 26# L-80 BTC-M casin to 1872' MD. Bakerlok all joints in shoe track. Check floats: holding. Make up BTC-M connection to mark. Average MU torque 7500 ft-Ibs. 7/21/2008 00:00 - 18:00 18.00 CASE P INT1 Continue to RIH with 7", 26#, L-80, BTC-M casing. Circulate 1.5x the annular volume, 147 bbls at the 9-5/8" shoe. 5 bpm, 390 psi. Continue into open hole breaking circulation as needed based on displacements (approx. every 15 joints). Maintain running speeds under 1.5 minutes/joint. Cross over to TCII at 5405' MD. Torque turn the TCII connection to 10,100 ft-Ibs. Used Jet Lube Seal guard on all TCII connections. Circulated down 5 joints above the top of the HRZ. Continued in hole to 10,345' MD. 18:00 - 19:00 1.00 CASE P INT1 Circulated landing joint down. Land hanger in head. Lay down the Franks Tool. Make up the Cement Head. 19:00 - 20:00 1.00 CEMT P INT1 Break circulation at 1/2 bpm and stage pumps up to 2 bpm. Circulate at 2 bpm, 767 psi for 15 minutes. Continue to stage pumps up slowly to 4 bpm, 1065 psi and 5 bpm, 1246 psi. Noi 20:00 - 21:15 1.25 CEMT P INT1 PJSM with SLB cement hands and rig crew. Pressure test Schlumberger's cement lines to 4000 psi.. Pumped 30 bbls of Mud PUSH staging up to 5 bpm, 1107 psi. Dropped bottom plug and pumped 148 bbls of 11.5 ppg LiteCrete followed by 41 bbls of 15.8 ppg Class G cement at 5-6 bpm, 1390 psi. Dropped top plug and kicked out with -1.5 bbls of cement and 5 bbls of fresh water. 21:15 - 22:00 0.75 CEMT P INT1 Switch to rig pumps for displacement. (calculated displacement = 386 bbls, 6700 strokes) Pumped first 190 bbls (3300 strokes) at 830 psi with no pressure spikes. At 202 bbls 3500 strokes) began seeing steady increase in pressure as cement began to turn corner at shoe. Pressure spiked after 230 bbls (4000 stroked displaced to Printed: 9/8/2008 11:15:24 AM • BP EXPLORATION Page 7 of 23 Operations Summary Report Legal Well Name: 02-40 Common Weil Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code N'PT Phase Description of Operations 7/21/2008 21:15 - 22:00 0.75 CEMT P INTi 2090 psi. Shut down pumps. 22:00 - 00:00 2.00 CEMT N CEMT INT1 Loss of all returns with ressure holdin solid. Attem ted to work i e and um s. Work pipe up to 475K bringing pump pressure to 3900 psi. Repeated a number of times. Casing broke free coming upon three occasions. Momentary circulation then packed o again. 7/22/2008 00:00 - 01:00 1.00 CEMT N CEMT INTi Unable to move pipe up or down with up to 475K PU weight. Pressure up to 3900 psi held solid. Total cement around corner 26 bbls (calculated)_, Total cement inside 7" casing 164 bbls (calculated) =1151' o cement calcu ated in 7"x8.5' annulus au ed hole =4286' of cement inside 7" casin . Bottom of 7" casin is 28.5' above on final set de th. Original depth = 10,345' MD. Current depth = 10,316.5' MD. 01:00 - 09:00 8.00 CEMT N CEMT INTi Rig down SLB cement unit. Break out and lay down cement head. Rig down spider (elevators). Rig up 7" side door elevators. Drain the stack and suck out 7" casing with Super Sucker. Split stack and set 7" emergency slips. Cut 7" casing with WACHS cutter. LD cut joint (26.87'). Install 7" packoff and test to 4300 psi for 30 min. 09:00 - 11:00 2.00 BOPSU N CEMT INT1 Change out top rams from 7" to 3.5" x 6" VBRs. Set test plug and MU 4" test joint. Test 3.5" x 6" VBRs with 4" test joint to 250 psi low/3500 psi high. Test witnessed by WSL Bill Decker and Toolpusher Charile Henley. 11:00 - 15:00 4.00 CASE N CEMT INT1 Change out saver sub. Remove keeper pins from clamp on saver sub. Off critical ath: RU and um down 9-5/8" x 7" annulus to ensure ability to inject. Broke down at 620 psi; injected 2 bbls ~ 121 m and 830 si. Pum ed total of 8 bbls. 15:00 - 16:30 1.50 BOPSU N CEMT INT1 Test lower IBOP valve to 250 psi low/3500 psi high. Off critical path: Inject down 9-5/8" x 7" annulus. Broke down at 620 psi. Injected 4 bbls ~ 32 gpm and 650 psi. 16:30 - 17:30 1.00 CASE N CEMT INTi PU and RIH with 6-1/8" rock bit cleanout BHA to 373'. 17:30 - 21:00 3.50 CASE N CEMT INT1 RIH from 373' to 6404'. Tag hard cement at 6404'. Off critical path: Inject down 9-5/8" x 7" annulus. Broke down at 620 psi. Injected 4 bbls ~ 32 gpm and 710 psi. 21:00 - 22:00 1.00 CASE N CEMT INT1 Displace 10.7 LSND mud to seawater at 500 gpm and 2620 psi. 22:00 - 23:00 1.00 CASE P INT1 Slip and cut drilling line. 23:00 - 23:30 0.50 CASE P INT1 Service rig and top drive. 23:30 - 00:00 0.50 CASE N CEMT INT1 Drill cement from 6404' to 6443'. Up/down/rotating weig s= 90K/110K. WOB=10K. 100 RPM, 5-6K ft-Ibs torque. Pumping at 250 gpm/1400 psi. 7/23/2008 00:00 - 12:00 12.00 CASE N CEMT INT1 Drill cement inside 7" casing with 6-1/8" rock bit from 6443' to 8310'. Pick up/slack off/rotating weights= 165K/95K/125K. On/Off bottom torque=7800/8500 ft-Ibs. RPM=100. WOB=5-20K. Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 8 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date j From - To Hours Task Code ~ NPT Phase Description of Operations 7/23/2008 ~ 00:00 - 12:00 ~ 12.00 ~ CASE ~ N ~ CEMT ~ INTi ~ 450 gpm ~ 2700 psi. 12:00 - 00:00 12.001 CASE I N CEMT INT1 7/24/2008 100:00 - 05:00 I 5.001 CASE I N I CEMT I INT1 05:00 - 05:30 0.50 CASE N CEMT INT1 05:30 - 06:30 1.00 CASE P INTi 06:30 - 07:00 0.50 CASE P INT1 07:00 - 09:30 2.50 CASE N CEMT INT1 09:30 - 12:00 I 2.501 CASE I N I CEMT I INTi Continue drilling cement inside 7" casing from 8310' to 9698'. Pick up/slack off/rotating weights= 205K/105K/145K. On-bottom torque=10,500 ft-Ibs. RPM=90. WOB=20K. 430 gpm ~ 2940 psi. Pump High Vis sweeps as needed to clean hole. Add Glass Beads and Safe Lube as needed for lubricity. Continue drilling cement inside 7" casing from 9698' MD to 10,230' MD. PU 210K, SO 105K, ROT 140K, On-bottom torque=10.5-11.5K ft-Ibs. RPM=90. WOB=20K. 430 gpm ~ 3040 psi. Pump High Vis sweeps as needed to clean hole. Add Glass Beads and Safe Lube as needed for lubricity. Circulate high vis sweep to clean the hole at 430 GPM, 3000 psi, 90 RPM, ROT 140K. Pressure test 7" casing to 3500 psi for 30 minutes and chart.. Bled off 100 psi first 15 minutes, 100 psi second 15 minutes. Drill cement and landing collar rom 10,230' MD to 10,305' MD. 450 gpm, 3200 psi, 70 RPM, 15K WOB, 11.2K TO. Pump a 50 bbls high vis sweep with EP Steel Lube. Torque decreased from 11,500 ft-Ibs to 5,000 ft-Ibs while sweep was in the hole. Once sweep was dumped, torque returned to 11,500 ft-Ibs. Displace well to 8.8 ppg Flo-Pro mud at 500 GPM, 2300 psi, 60 RPM, 5K TO, 142K ROT wt. Drill out float shoe, and rat hole to 10,348' MD. PU 185K, SO 130K, ROT 150K, 275 GPM, 1260 psi, 60 RPM, 12K TO, 13K WOB. 12:00 - 13:00 I 1.001 DRILL I P I I PROD1 13:00 - 14:00 1.00 DRILL N CEMT PRODi 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 16:30 1.50 DRILL N CEMT PROD1 16:30 - 20:30 4.00 DRILL N CEMT PROD1 Drill 20' of new formation from 10,348' MD to 10,368' MD Packed off at 10,351' MD. Pulled up to shoe and circulate bottoms up. Sample contained 50% cement, 30% sand, and 20% shale (no splintery shale). Pick up into shoe from 10,368' MD. Hole attempted to pack off multiple times. Pulled into shoe and circulated hole clean. Sample contained 50% cement, 30% sand, and 20% shale (no splintery shale). 306 GPM, 1420 psi. Perform FIT to 11.4 ooa with 1142 psi surface pressure and chart. Bled off 50 psi in 10 minutes. Slide from inside 7" shoe to 10,368' MD circulating at 1 bbl/min. Tagged 2' of fill on bottom. Washed to bottom at full rate. Back Reamed into 7" casing with no problems. Circulate bottoms up at 320 GPM, 1490 psi. Sample contained 40% cement, 30% sand, and 30% shale (no splintery shale). Mud weight in = 8.8 ppg, mud weight out = 8.8 ppg. Monitor well, pump dry job. POOH with 6-1/8" dumb iron BHA racking back 4" drill pipe to 373' MD. Printed: 9/8/2008 11:15:24 AM PROD1 BP EXPLORATION Page 9 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours, Task Code ~ NPT Phase Description of Operations 7/24/2008 120:30 - 22:00 1.501 DRILL N CEMT PRODi Stand back HWDP and Flex drill collars. 22:00 - 00:00 I 2.001 DRILL I P 7/25/2008 100:00 - 06:00 6.001 DRILL P PRODi 06:00 - 06:30 0.501 DRILL N CEMT PROD1 06:30 - 09:00 I 2.501 DRILL I N I CEMT I PROD1 09:00 - 09:30 0.501 DRILL ~ N CEMT PROD1 09:30 - 14:30 5.00 I DRILL N I DPRB PROD1 14:30 - 22:00 I 7.501 DRILL I N I DPRB I PROD1 22:00 - 00:00 I 2.001 DRILL I N I DPRB I PROD1 7/26/2008 00:00 - 03:00 3.00 DRILL N DPRB PROD1 03:00 - 05:00 2.00 DRILL N DPRB PROD1 05:00 - 06:00 1.00 06:00 - 11:30 5.50 11:30 - 12:00 I 0.50 DPRB I PROD1 Lay down steel drill collars and 6-1/8" mill tooth bit. Clear and clean the rig floor. Make up 6-1/8" drilling BHA with insert bit, 1,5 degree bent housing motor, float, stabilizer, DIR/GR/RES/ABI, flex drill collars, circ sub, 9 joints of 4" drill pipe, Heavy weight and jars. RIH with 6-1/8" drilling BHA picking up enough singles to reach TD. Good shallow hole test on MWD tools at 250 gpm, 900 psi. RIH to 7" shoe at 10,314' MD. Attemot to Slide into 8-1/2" rat hole pumping at 1 bpm. Tagged up at 10,328', pull into shoe. Attempt to slide into 8-1/2" rat hole pumping at 1 bpm. Tagged uo at 10.337', packed off while pulling into 7" shoe. Rotate pipe at 60 RPM and wash down to 10,362' at 250 gpm, 1850 psi. Backream into shoe. Weight up from 8.8 ppg to 9.7 ppg with 14 ppg spike fluid. Bottoms up sample contained 50% coffee ground-size shale, 30% sand, and 20% cement. RIH and tag fill at 10,357'. Wash and ream to bottom at 270 gpm, 2330 psi. Drill from 10,368' to 10,449'. Weight up from 9.7 ppg to 10.7 ppg with 16 ppg spike fluid while drilling ahead. Up/down/rotating weights=205W125K/150K, 70 RPM. On/off bottom torques=8,000 ft-Ibs/7,000 ft-Ibs. 225 gpm, on/off bottom pressures=2100 psi/1900 psi. ART=2.55, AST=O. SPRs for pumps 1 & 2: 30 SPM C~ 710 psi, 45 SPM ~ 880 psi. MW in=MW out=10.7 ppg. Monitor well. Switch to seawater. Mix 80 bbl LCM pill. Circulate at 2 bpm to keep hole full. Regained returns at 21:00 hrs (3 bpm loss rate). Did not pump LCM pill (to ensure ability to squeeze cement below EZSV). Well u-tubing up drill pipe with pumps off. MW in=9.4 ppg, MW out 10.8 ppg. CBU with seawater/mud mix until mud weight in 9.4 ppg, mud weight out 9.5 ppg. POH from 10,260' to 9,147'. Up weight=195K, down weight=130K. Total losses since 12:00 = 970 bbls. POH with 6.125" drilling BHA to 650' racking back 4" drill pipe. Lay down 6.125" drilling BHA including: 6.125" insert bit, 1.5 degree bent housing motor, float, stabilizer, DIR/GR/RES, flex collars, 4" drill pipe, HWDP, and jars. Clear the rig floor. DPRB PROD1 MU EZSV, running tool, and crossover and RIH to 10,250' at 100 Wmin max, filling hole continuously. Loss rate 10-12 BPH. Up weight=195K, down weight=122K. DPRB PROD1 Circulate across EZSV setting depth at 2 BPM, 210 psi. Up weight=200K, down weight=125K. Rotate 37 turns to the right to set EZSV at 10,244. Pull up and shear at 40K over. Pick up to 10,220' and rotate 25 turns to the right. RIH and tag top of_ plug at 10,244' to confirm set; set down 15K. Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 10 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code ~ NPT ~~ Phase Description of Operations 7/26/2008 12:00 - 13:00 1.00 REMCM N DPRB PROD1 Stin back into EZSV and ressure test to 3500 si for 15 minutes. Good test; lost 20 psi in first 15 minutes, 5 psi in second 15 minutes. 13:00 - 15:00 2.00 REMCM N DPRB PROD1 PJSM. RU SLB cementers. Pressure test cement lines to 4000 psi. Pump 20 bbls fresh water, 30 bbls 15.8 'G' cement, 20 bbls fresh water. Switch to rig pumps and displace with 61 bbls seawater to squeeze 10 bbls cement below EZSV. Unstin an sot 20 bbls on to of EZSV at 3 b m 318 si. 15:00 - 16:00 1.00 REMCM N DPRB PROD1 POH from 10,244' to 9700'. Drop foam ball and CBU with 9.5 ppg mud, pumping at 500 gpm, 2500 psi. Bottoms up sample contained a trace of cement. Displace well to seawater. Seawater weight in=weight out=8.5 ppg. 16:00 - 20:30 4.50 REMCM N DPRB PROD1 POH from 9700' to EZSV setting tool. LD tool. Clean and clear rig floor. 20:30 - 22:30 2.00 STCTPL N DPRB PROD1 MU and RIH with Baker multi-string cutter to 3745'. U weight=85K, down weight=80K. 22:30 - 23:30 1.00 STCTPL N DPRB PROD1 Slip and cut drilling line. 23:30 - 00:00 0.50 STCTPL N DPRB PROD1 Service top drive. 7/27/2008 00:00 - 01:00 1.00 STCTPL N DPRB PROD1 Pressure test abandonment lu at 7" shoe to 2200 si for 30 minutes (0.25 psi/ft per AOGCC regs). Good test; lost 100 psi in first 15 minutes and 25 si in second 15 minutes. 01:00 - 02:00 1.00 STCTPL N DPRB PROD1 Extend knives on Baker multi-string cutter and locate casing collar at 3671'. RIH to 3683' and cut 7" casing. Continue to rotate for 15 additional minutes after indication of good cut. 250 GPM, 1255 psi, Max Torque 3000 ft-Ibs, 60 RPM. 02:00 - 04:00 2.00 STCTPL N DPRB PROD1 RU line from 7" x 9-5/8" annulus to cuttings box. Close rams and circulate out dead crude freeze protect throw h 7" casin cut. Pump 35 bbl Safe Surf-O pill followed by 110 degree seawater. Open rams and close the 7" x 9-5/8" annulus. Circulate bottoms up. 04:00 - 05:00 1.00 STCTPL N DPRB PRODi Pull out of hole with Baker multi-strin cutter from 3683' to 2722' MD. -3 bbl displacements on first 5 stands (correct). +3 bbl gain on second five stands. 05:00 - 10:00 5.00 STCTPL N DPRB PROD1 Monitor well: flowing. 7" x 9-5/8" annulus not u-tubin . Shut in well Shut in Casing Pressure: 20 psi increasing to 40 psi in 15 minutes, 50 psi in 60 minutes. Shut in drill pipe pressure 10 psi increasing to 40 psi in 15 minutes. No pressure on 9-5/8"x7" annulus. Bled off 10 bbls to check for charged formation (breathing). BBLS Seconds/bbl I Time to build pressure 1 - I SICP SIDPP Minutes 2 53 I 20 20 - 3 51 I 30 30 2 4 60 I 30 30 4 5 85 I 30 40 6 6 107 I 30 40 8 Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 11 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 7/27/2008 105:00 - 10:00 I 5.001 STCTPL I N I DPRB I PROD1 17 106 I 30 40 10 10:00 - 11:30 1.50 STCTPL N DPRB PROD1 11:30 - 13:00 1.50 STCTPL N DPRB PRODi 13:00 - 14:00 1.00 STCTPL N DPRB PRODi 14:00 - 15:00 I 1.00 STCTPL N DPRB PROD1 15:00 - 17:00 2.00 STCTPL N DPRB PRODi 17:00 - 18:00 1.00 BOPSU N DPRB PRODi 18:00 - 20:30 2.50 BOPSU N DPRB PROD1 20:30 - 00:00 I 3.50 I STCTPL I N I DPRB I PROD1 7/28/2008 (00:00 - 06:30 I 6.501 STCTPL I N I DPRB I PROD1 06:30 - 07:30 1.00 BOPSU~N DPRB PROD1 07:30 - 11:00 3.50 BOPSU N DPRB PROD1 8 75 I 40 40 12 9 102 I 10 118 I Well kill drill while waiting on 9.8 ppg brine with well shut in (40 psi SICP, 40 psi SIDPP). Displace both the drill pipe x 7" and the 7" x 9-5/8" annulus to 9.8 ppg brine at 4 bpm, 180 psi. Zero pressure on drill pipe and casing. Open rams and monitor well. Fluid falling. RIH from 2722' MD to 4865' MD. PU 100K, SO 85K Displace the well to 9.8 ppp brine from 4865' MD to surface. Spot a 30 bbl high vis pill at 4865' MD to help prevent 9.8 ppg brine from swapping with 8.5 ppg seawater below. 250 gpm, 1600 psi. Mud weight in and out 9.8 ppg brine Monitor well: 12 bbl/hr loss POH with Baker multi-string cutter and lay down. Pull wear bushing and install a test plug. Ria uD a second circulatino line to fill 7"x9-5/8" annulus during Change top rams to 7", Test BOP's from 250 psi low to 3500 psi high. Test lower rams with 4" test joint. Test upper rams with 7" test joint. Test witnessed by BP WSL Kris Honas /Adrienne McVey and Nabors Tool Pusher Ken Helf. Fill 7" x 9-5/8" annulus every 1/2 hour with 9.8 ppg brine. J into 7" casing pack-off. Pull free with no overpull and lay down. Make up a 7" spear and engage 7" casing. PU to 175K and hold. No movement. PU to 200K and hold. Casing free after holding a few seconds Pull to floor and remove 7" slips. Circulate bottoms up at 200 gpm, 200 psi. Break out spear and lay down cut off joint. Pull 7". 26#, L-80. TCII casino from cut at 3683' MD. Lay down in order for re-run. Average torque to break connections: 10,000 ft-Ibs. 88 full joints recovered, 2 pup joints, 13.79' cut joint from surface and a 13.32' cut joint from 3683' MD. Rig down casing equipment. Change 7" rams back to variable. Test BOP's with 4" test joint. Test not holding. Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 12 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 7/28/2008 07:30 - 11:00 3.50 BOPSU N DPRB PROD1 Close Manual vales to double block stack valves. Test still not holding. Change out top rams to 4" solid (non-variable) 11:00 - 13:00 2.00 BOPSU N DPRB PROD1 Test 4" solid BOP's with 4" test joint from 250 psi low to 3500 psi high; good test. Test witnessed by BP WSL Joey LeBlanc and Nabors Tool Pusher Charlie Henley. 13:00 - 13:30 0.50 BOPSU N DPRB PROD1 Lay Down 4" test joint and test plug. Install long wear ring. 13:30 - 14:30 1.00 REMCM N DPRB INT1 RU to run 3.5", 9.2#, L-80, NSCT cement stinger. 14:30 - 16:30 2.00 REMCM N DPRB INT1 Pick up 3.5", mule shoe with closed bottom and 3/4" holes along side, followed by 1005' of 3.5", 9.2#, NSCT work string. 16:30 - 18:30 2.00 REMCM N DPRB INTi Continue to RIH on 4" drill pipe to 6600' MD. 18:30 - 21:30 3.00 REMCM N DPRB INT1 Circulate bottoms up at 250 gpm, 500 psi. Spot a 40 bbl high vis pill at 250 gpm, 700 psi, P t Circulate the well from surface to surface to ensure balance on drill pipe and casing side prior to setting balanced cement plug. 250 gpm, 580 psi. 21:30 - 22:30 1.00 REMCM N DPRB INT1 PJSM with SLB cementers and rig crew. Test cement lines to 4000 psi. Pump 13 bbls of fresh water, 23 bbls of 15.8 ppg Class G cement followed by 4.5 bbls of fresh water at 3 bpm with SLB cementing unit. Switch to rig pumps and displace the cement with 40.7 bbls (698 strokes). Under displace from balanced by 3 bbls. Displace at 5 bpm to catch cement, slowing to 3 bbl after 400 strokes. Close in cement line and crack open valve to allow cement to u-tube to balanced state. 22:30 - 23:00 0.50 REMCM N DPRB INTi POH to 4800' MD slowly (2 - 2.5" min/stand). PU 90K, SO 80K. 23:00 - 00:00 1.00 REMCM N DPRB INT1 Circulate from surface to surface dropping a 6" ball to wipe pipe. 500 GPM, 1250 psi. 7/29/2008 00:00 - 02:00 2.00 REMCM N DPRB INT1 Continue to circulate at 4800' MD while waiting for 15.8 ppg cement plug to reach thickness of 100 bc. 02:00 - 03:00 1.00 REMCM N DPRB INT1 Sofa 40 bbl 18 hi h vis ill from 4800' to 3850'. 230 gpm, 160 psi. Treat pill as a balanced plug and under displace by 3 bbls. Total displacement volume 29.7 bbls (509 strokes). 03:00 - 03:30 0.50 REMCM N DPRB INTi POH to 3883' MD slowly (2 min/std) to allow pill to fall. 03:30 - 04:00 0.50 REMCM N DPRB INT1 irculate surface to surface at 500 gpm with 9.8 ppg brine. Hold a PJSM with SLB cementers and rig crew while circulating. 04:00 - 05:30 1.50 REMCM N DPRB INTi Make up cementing head with valve to isolate cement line and valve to open up to surface. Pump 190 bbls of 8.5 ppg seawater at 400 gpm with the rig pumps. Swap to SLB cementing unit and pump 28 bbls of fresh water, 55 bbls of 17 ppg Class G cement, followed by 4.7 bbls of fresh water. Switch back to rig pumps and displace with 20 bbls (343 strokes) of seawater at 5 bbls/min. 105 psi after 100 strokes, 148 psi after 250 strokes. Printed: 9/8/2008 11:15:24 AM CJ BP EXPLORATION Page 13 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date I From - To Hours Task Code' NPT Phase Description of Operations 7/29/2008 04:00 - 05:30 1.50 REMCM N DPRB INTi Under displaced by 3 bbls. Returns through out job. Isolate cement valve and open surface valve to allow cement plug to balance. Rig down cementing head. 05:30 - 06:00 0.50 REMCM N DPRB INT1 POH to 3100' MD slowl 2 min/std to allow cement to dro . 06:00 - 07:00 1.00 REMCM N DPRB INT1 Drop Nerf Ball to clean drill pipe and circulate surface to surface volume. 10 BPM ~ 670 psi. On bottoms up 14 bbls of seawater was contaminated with cement. Lost 8 bbls to the formation while circulating bottoms up. MW in and out 8.5 ppg seawater Monitor well, losing 0.5 bbl/hr 07:00 - 07:30 0.50 REMCM DPRB INT1 Pull 4" drill pipe out of hole racking back in derrick from 3,100' to 1,083' 07:30 - 08:30 1.00 REMCM N DPRB INT1 Rig up to lay down 3.5" 9.2# L-80 NSCT and 3.5" Mull Shoe. Monitor well loss 1 bbl/hr while ri in u . 08:30 - 10:00 1.50 REMCM N DPRB INT1 Pull out of hole laying down 32 joints of 3.5" NSCT and 3.5" Mule shoe. 10:00 - 10:30 0.50 REMCM N DPRB INTi Rig down 3.5" handling equipment and clean rig floor. Monitor well, well static. 10:30 - 12:30 2.00 STKOH N DPRB INTi Change upper rams from 4" to 3.5" X 6" variables and prepare for BOP test. 12:30 - 18:30 6.00 STKOH N DPRB INT1 PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi minimum high as per AOGCC. Test witnessed by Bob Noble with AOGCC, WSL Joey LeBlanc, and Toolpusher Charlie Henley. Test with 4" test joint. IBOP not functioning, change out - OK. 18:30 - 19:30 1.00 STKOH N DPRB INT1 Pull test plug. Break and lay down surface test equipment. Install 10" ID wear ring. 19:30 - 23:00 3.50 STKOH N DPRB INT1 PJSM. PU bit and BHA to 1544'. Shallow test MWD - OK. 23:00 - 00:00 1.00 STKOH N DPRB INT1 RIH to 2862'. Up weight 100k, down 95k. 7/30/2008 00:00 - 00:30 0.50 STKOH N DPRB INT1 PJSM. Wash down to 3135'. Tag up on green cement. Wash to 3144' and to hard cement. 00:30 - 04:00 3.50 STKOH N DPRB INTi Drill cement to shoe at 3483', Good cement back to u Also a large amount of metal cuttings back to surface, robabl rom 7 casm cut. 04:00 - 05:00 1.00 STKOH N DPRB INT1 PJSM. Pump hi-vis spacer and displace seawater with 9.2 ppg LSND mud. Up weight 105k, down 95k, RT 102k. Pump at 580 gpm with 1950 psi. Free torque 3k at 80 rpm. ECD baseline 9.64 ppg. 05:00 - 07:00 2.00 STKOH N DPRB INT1 Kick off at 3515' MD. Drill new formation to 3535'. 07:00 - 08:00 1.00 STKOH N DPRB INT1 Circulate BU. Perform FIT to 12.2 ppg EMW with 532 psi surface pressure. 08:00 - 00:00 16.00 STKOH N DPRB INT1 Directional drill ahead to 4794' MD, 4436' TVD. Pump at 575 gpm with 2250 psi off bottom, 2400 psi on bottom. Rotate at 80 to 100 rpm with 5k torque off bottom, 5 to 6k torque on bottom. WOB 5-15k. Up weight 130k, down 95k, RT 110k. Mud weight 9.2 ppg in, 9.2 +ppg out. ECD 9.88 ppg. ART - 6.85, AST - 4.76. 7/31/2008 00:00 - 00:00 24.00 STKOH N DPRB INTi PJSM. Directional drill ahead to 5915' MD, 4794' TVD. Pump at 575 gpm with 2480 psi off bottom, 2630 psi on bottom. Rotate at 100 rpm with 6-6.5k torque. Up weight 140k, down 98k, RT 112k. WOB 10-15k. ECD 9.98. Mud weight out 9.2+ ppg, in 9.2 Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To i Hours Task Code NPT Phase Description of Operations 7/31/2008 00:00 - 00:00 24.00 STKOH N DPRB INT1 ppg. Continue drilling ahead to 6971' MD, 6001' TVD. Pumping at 575 gpm with 3000 psi off bottom, 3250 psi on bottom. Rotate at 80-100 rpm with 9-10k torque off bottom, 10-11 k torque on bottom. WOB 5-15k. Up weight 175k, down 112k, RT 130k. Mud weight in and out 9.2+ ppg. ECD 9.78. AST - 1.56. ART - 13.55. 8/1/2008 00:00 - 00:00 24.00 STKOH N DPRB INT1 PJSM. Directional drill ahead to 7993' MD, 6971' TVD. Pump at 575 gpm with 3300 psi off bottom, 3600 psi on bottom. Rotate at 100 rpm with 10-12k torque on and off bottom. Up weight 190k, down 115k, RT 140k. WOB 5-15k. ECD 9.88. Mud weight in and out 9.2+ppg. Continue to drill ahead to 8705' MD, 7274' TVD. Pump at 525 gpm with 3140 psi off bottom, 3300 psi on bottom. Rotate at 100 rpm with 10-12k torque on and off bottom. WOB 5-15k. Up weight 203k, down 120k, RT 152k. Mud weight in 9.3 ppg, out 9.3+ppg. ECD .AST - 2.91. ART - 12.59. 8/2/2008 00:00 - 11:00 11.00 STKOH N DPRB INT1 PJSM. Directional drill ahead to 9397' MD, 7785' TVD. Pump at 525 gpm with 3225 psi off bottom, 3500 psi on bottom. Rotate at 100 rpm with 10-14k torque on and 10-11 off bottom. Up weight 210k, down 120k, RT 135k. WOB 5-15k. ECD 10.2, calculated 10.0. Mud weight in 9.3 ppg and 9.3+ ppg out. 11:00 - 12:00 1.00 STKOH N DPRB INT1 Circulate sweep around at 525 gpm with 3515 psi. Rotate and reciprocate. Sweep back on strokes. Mud weight in and out 9.3 PP9• 12:00 - 15:30 3.50 STKOH N DPRB INT1 PJSM. Wiper trip to 3423'. Up weight 225k, down 125k. Max pull during wiper 235k. No problems encountered. 15:30 - 17:30 2.00 STKOH N DPRB INT1 PJSM. Cut and slip 89' of drilling line. Inspect brakes and chains. tube Elmago Splines. Service rig, top drive and crown. 17:30 - 19:30 2.00 STKOH N DPRB INT1 PJSM. RIH to 9117'. No problems. 19:30 - 20:00 0.50 STKOH N DPRB INTi Wash to 9397' at 360 gpm with 2250 psi. Torque at 8-9k with 60 rpm. 20:00 - 21:00 1.00 STKOH N DPRB INT1 Circulate bottoms up at 525 gpm with 3400 psi. Reciprocate and orient pipe for slide to 45 right. 21:00 - 00:00 3.00 STKOH N DPRB INT1 Directional drill ahead to 9500' MD, 7861' TVD. Pump at 495 gpm with 3795 psi off bottom, 3925 psi on bottom, Rotate at 100 rpm with 11-13k torque on bottom, 12k off bottom. WOB 5-15k. Spike mud weight to 10.6 ppg on the fly. Up weight 215k, down 120k, RT 156k. AST - 1.91. ART - 8.00. ECD 11.07. Calculated ECD 11.07. 8/3/2008 00:00 - 15:30 15.50 STKOH N DPRB INT1 Directional drill ahead to 10329' MD, 8469' TVD. Pump at 475 gpm with 3800 psi off bottom, 4050 psi on bottom. Rotate at 100 rpm with 10-13k torque on bottom, 12 k off bottom. WOB 10-15k. Up weight 220k, down 125k, RT 165k. Mud weight 10.6 ppg in and out. ECD 10.98. 15:30 - 16:30 1.00 STKOH N DPRB INT1 Circulate bottoms up for samples at 480 gpm with 4060 psi. Shut down monitor well. Mud weight in and out 10.6 ppg. TD called at 10329' MD, 8469' TVD. 16:30 - 18:30 2.00 STKOH N DPRB INT1 PJSM. Make wiper trip to 8554' MD. Up weight 250k, down 115k, max up 265k, max down 105k. No problems encountered. Printed: 9/8/2008 11:15:24 AM ,~ BP EXPLORATION Page 15 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task I Code NPT Phase I Description of Operations 8/3/2008 18:30 - 20:30 2.00 STKOH N DPRB INT1 Circulate 40 bbl marker swee surface to surface at 465 m with 3950 psi. Rotate and reciprocate. Sweep back 1.6% over calculated au a hole. Final ECD at second bottoms up 11.22, calculate clean hole ECD 11.12. Mud weight in and out 10.7 ppg. 20:30 - 00:00 3.50 STKOH N DPRB INTi POOH for casing run. Pull above HRZ to 9397' MD and pump dry job. Continue to POOH to 4914'. Overpull of 45k at 9120' MD, wipe clean no problems. Up weight 250k, max up 265k. 8/4/2008 00:00 - 01:30 1.50 STKOH N DPRB INT1 PJSM. POOH to ghost reamer. Reamer in gauge. Continue to POOH to BHA at 805'. Change out handling equipment. 01:30 - 03:30 2.00 STKOH N DPRB INT1 PJSM. Lay down BHA to last flex collar. Flush MWD. 03:30 - 04:00 0.50 STKOH N DPRB INT1 Download MWD. 04:00 - 06:00 2.00 STKOH N DPRB INTi Continue to lay down BHA and tools. Clear and clean floor. 06:00 - 07:00 1.00 STKOH N DPRB INTi Flush out stack with flushing tool. Function rams. LD tool. 07:00 - 08:30 1.50 STKOH N DPRB INTi PJSM. Change out top rams to 7". Pick up 7" test joint. 08:30 - 10:30 2.00 STKOH N DPRB INT1 PJSM. Test upper rams with 7" test joint to 250 psi low, 3500 phi high ac oer AOCGG. Test witnessed by WSL's Joey LeBlanc and Dick Maskell and Toolpusher Charlie Henley. 10:30 - 13:00 2.50 STKOH N DPRB INT1 PJSM. Rip up to run 7", 26#, L-80, TCII/BTC-M casing to 10325' MD. Make dummy run with landing joint and mark. 13:00 - 19:30 6.50 STKOH N DPRB INT1 Run casing at 150 fpm to above 9-5/8" shoe at 3458'. Fill every joint. Circulate down every 15th joint at 3 minutes per joint at 4 bpm. Obtain up and down weight every 10 joints. 19:30 - 20:00 0.50 STKOH N DPRB INT1 Circulate bottoms up staging pumps up to 5 bpm with 554 psi. 20:00 - 23:30 3.50 STKOH N DPRB INT1 Run casing at 75 fpm filling every 10 at 4 bpm. Hole taking fluid. Slow down to 60 fpm filling every 10 at 3 bpm. Run to 5420'. Up weight 155k, down 115k. MU torque on BTC 7200 Wlbs. 23:30 - 00:00 0.50 STKOH N DPRB INT1 Run BTC-M to TCII XO. Rig up to run TCII. Circulate BU at 3 bpm with 800 psi to start and ending with 565 psi. 8/5/2008 00:00 - 01:00 1.00 STKOH N DPRB INT1 PJSM. Continue running 7", 26#, L-80, TCII/BTC-M. 01:00 - 02:00 1.00 STKOH N DPRB INT1 High level H2S alarm required evacuation of rig. Resolved issue as a false alarm. Returned to work. 02:00 - 14:00 12.00 STKOH N DPRB INT1 Continue to run in hole with 7" casing at 60 fpm filling every joint and circulating every 10 joints at 3 bpm over 4 minutes. Bad collar on joint 151. Replace joints 151 and 152. Wash down joints 233 through 239 at 3 bpm for 28 bbls each. Continue through HRZ and Kingak without circulation. Wash down last joint at 147 gpm with 1100 psi and 18% returns. Break out Frank's tool. Make up landing joint and land in profile. Up weight 170k, down 125k while pumping, 325k up, 155k down without um s. 14:00 - 16:00 2.00 STKOH N DPRB INTi Break circulation at 1 bpm and 730 psi. Stage pumps up to 2 bpm with 870 psi. At 4 bpm, 1150 psi. Calculated 1 spaceout pup of 19.82' was not run in hole. 16:00 - 17:30 1.50 STKOH N DPRB INT1 Attempt to pull hanger to floor pumping at 4 bpm with 1100 psi. Started to ackoff and ull ti ht. Work pipe to 425k up, 40k down. Work hanger back to profile with no circulation. 17:30 - 18:30 1.00 STKOH N DPRB INTi PJSM. lay down cement head. Make up circulating head to top drive. 18:30 - 00:00 5.50 STKOH N DPRB INT1 Work pipe and stage pump in an attempt to pull casing hanger to floor. Max pull 450k. Max pump pressure 1600 psi. Pull hanger to rig floor. Break out and lay down landing joint and Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 16 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ~ Hours Task Code NPT I Phase Description of Operations 8/5/2008 18:30 - 00:00 5.50 STKOH N DPRB INTi hanger. Pick up full joint with top drive and work down. 8/6/2008 00:00 - 01:30 1.50 STKOH N DPRB INT1 PJSM. Finish working 1 full joint to bottom. PU u 'oint of 19.82'. Wor to 10327' MD. ti no returns. 01:30 - 06:30 5.00 STKOH N DPRB INT1 Continue to work pipe and alternate pump rates in an attempt to re-establish circulation. No success. 06:30 - 10:00 3.50 STKOH N DPRB INT1 PJSM. Drain stack. ND BOP stack. Set emergency slips with 175k tension. Break out and lay down pup joint. Suck out 7". Rig up WACH's cutter and cut casing. Pull and lay down. 10:00 - 13:00 3.00 STKOH N DPRB INT1 Install 7" packoff. NU BOP stack. Test packoff to 4300 psi for 30 minutes - OK. Also change out handling equipment and lay down. Change out top rams to 3-1/2" x 6" variablesi 13:00 - 14:00 1.00 STKOH N DPRB INT1 PJSM. Install 4" test joint and test rams to 250 psi low, 3500 psi high as per AOGCC. Funtion test BOPE. Test witnessed by WSL Bill Decker and Toolpusher Cleve Coyne. 14:00 - 15:00 1.00 STKOH N DPRB INT1 PJSM. Attempt to test casino. Formation taking fluid at 3100 15:00 - 16:30 1.50 STKOH N DPRB INT1 PJSM. Line up of OA. Pump and establish an injection rate of 1/2 bpm at 650 psi. 16:30 - 19:30 3.00 STKOH N DPRB INT1 PU and RIH with an RTTS. SIMOPS with LRS to in'ect 65 bbls dead crude down 7" x 9-5/8" annulus at 5 bpm with 1000 psi. 19:30 - 20:30 1.00 STKOH N SFAL INTi Remove and replace sheared bolts on iron roughneck head. 20:30 - 23:30 3.00 STKOH N DPRB INT1 Continue to RIH with RTTS and to u on float collar at 10237'. Set RTTS with element at 10228'. 23:30 - 00:00 0.50 STKOH N DPRB INTi PJSM. Test casing to 3500 si for 30 minutes. Pressure bled off 75 si in first 15 minutes and 10 si in second 15 minutes - PASS. 8/7/2008 00:00 - 00:30 0.50 STKOH N DPRB INT1 PJSM. Finish casing pressure test to 3500 psi for 30 minutes. Bled off 75 psi in first 15 minutes and 10 psi in the second 15 minutes -PASS. 00:30 - 03:00 2.50 STKOH N DPRB INT1 PJSM. POOH with RTTS to 3708'. 03:00 - 04:30 1.50 STKOH N DPRB INT1 PJSM. Cut and slip drilling line. 04:30 - 05:00 0.50 STKOH N DPRB INT1 Service top drive and rig. 05:00 - 06:00 1.00 STKOH N DPRB INTi Continue to POOH with RTTS and lay down. 06:00 - 10:30 4.50 STKOH N DPRB PROD1 PJSM. Pick 3rd party tools up beaverslide. PU motor and MU bit. Set bend to 1.76 degrees. MU DM and scribe. Plug in and upload MWD. Surface test MWD at 250 gpm with 1550 psi - OK. Hold PJSM. Load sources. PU rest of BHA to 403'. Change out handling equipment. 10:30 - 14:00 3.50 STKOH N DPRB PROD1 RIH fillin and testin MWD eve 30 stands. Ta LC at 10236'. Up weight 200k down 110k. 14:00 - 16:30 2.50 STKOH N DPRB PROD1 PJSM. Pump 50 bbls fresh water spacer followed by a 45 bbl hi-vis sweep and displace 10.7 ppg LSND to 8.5 ppg FloPro at 275 gpm with 2100 psi. Up weight 175k, down 135k. 16:30 - 17:30 1.00 STKOH N DPRB PROD1 Drill ahead to 10350' MD at 275 gpm with 2250 psi. Torque 4k off bottom, 5k on bottom at 60 rpm. WOB 15k. 17:30 - 18:00 0.50 STKOH N DPRB PROD1 Circulate BU until mud 8.5 ppg in and out. 18:00 - 18:30 0.50 STKOH N DPRB PROD1 Perform an FIT to 10.66 ppg EMW with 950 si surface ressure. 18:30 - 22:00 3.50 STKOH N DPRB PROD1 Directional drill ahead to 10449' MD. Reached last wellbore TD. 22:00 - 00:00 2.00 DRILL P PROD1 Directional drill ahead to 10489' MD 8590' TVD. Pump at 275 gpm with 1950 psi off bottom, 2150 psi on bottom. Rotate at 60 rpm with 4k torque off bottom, 5k torque on bottom. WOB 15k. Up weight 175k, down 135k, RT 155k. ART - 3.76. Weight in Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 17 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To ~ Hours Task Code NPT I Phase Description of Operations 8/7/2008 22:00 - 00:00 2.00 DRILL P PROD1 and out 8.5 ppg. 8/8/2008 00:00 - 12:00 12.00 DRILL P PROD1 PJSM. Directional drill ahead to 10910' MD 8 65' V .Pump at 275 gpm with 2250 psi off bottom, 2400 psi on bottom. Rotate at 60 rpm with 5-8k torque off bottom, 5-6k torque on bottom. WOB 15-30k. Up weight 185k, down 130k, RT 158k. Mud weight out 8.5+ppg, in 8.5 ppg. 12:00 - 13:00 1.00 DRILL P PROD1 Take Directional Surveys to verify build section. -Due to low build rate, decision was made to trip out of the hole to change out the bit and angle of the motor. 13:00 - 14:00 1.00 DRILL P PROD1 Circulate and conditon hole, then pump dry job. -Monitor Hole -Static -Mud Wt. In and Out 8.5 ppg 14:00 - 19:00 5.00 DRILL P PROD1 Trip out of the hole from 10910' to 402'. -Up Wt. 200k / Down Wt. 145k -Change out handling equipment for BHA 19:00 - 20:00 1.00 DRILL P PROD1 Lay down the BHA and remove radioactive sources. - Break out the bit -good shape ,some wear on teeth -Download MWD 20:00 - 21:00 1.00 DRILL P PROD1 Make up new bit and change degree of motor to 2.0 -Load radioactive sources 21:00 - 22:00 1.00 DRILL P PROD1 Continue to pick up BHA to 402' and shallow test MWD -good test i -Change out handling equipment to handle 4" drill pipe 22:00 - 00:00 2.00 DRILL P PROD1 Run in hole from 402' to 9275' -Fill every 30 joints and test MWD 8/9/2008 00:00 - 01:00 1.00 DRILL P PROD1 Service Top Drive, Install blower hose, and service the draw works. 01:00 - 05:30 4.50 DRILL P PROD1 PJSM. Directional drill ahead from 1091 ' t 1 '. Pump at 250 - 300 gpm with 2250 psi off bottom, 2400 psi on bottom. Torque off bottom 5-8k, 5-6k torque on bottom. WOB 15-35k. Up weight 185k, down 130k. Mud weight out 8.5+ppg, in 8.5 PPg• -Varied WOB and gpm due to issues with building angle. 05:30 - 06:00 0.50 DRILL P PROD1 Trip out of hole from 10988' to 10303'. Low level H2S alarm went off at 14pom. 06:00 - 10:00 4.00 DRILL P PROD1 Evacuated the rig to the safe area, then notified the toolpusher and BP WSL's. WSL Bill Decker notified BP safety, BP Field Superintendent, ERT, BP Office, and Engineer. NAD Toolpusher notified Nabors Superintendent, Forklift Operator blocked off the pad. After having a meeting with the on-site personnel, 2 NAD hands went in with air packs and safed out the rig, the rig was cleared with handheld H2S monitors. Circulated through the choke and gas buster at 105 gpm and 900 psi for 5800 strokes to clear out the H2S. 10:00 - 11:30 1.50 DRILL P PROD1 Circulated a EP Mud Lube pill to reduce metal to metal drag. -Circulated at 270 gpm and 1920 psi. -Dumped pill at surface. 11:30 - 12:00 0.50 DRILL P PRODi Tripped in the hole from 10303' to 10988'. 12:00 - 17:30 5.50 DRILL P PROD1 Directionally drilled ahead from 10988' to 11095' at 277 gpm with 2295 psi off bottom and 2410 psi on bottom. Mud Wt. in and out 8.5 ppg. Build rate could not be established while sliding, so decision was ma a to tnp out o the hole and - Printetl: 9/8/2008 11:1524 AM BP EXPLORATION Page 18 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2008 12:00 - 17:30 5.50 DRILL P PROD1 chan a the bend on the motor and la down the stabilizer. 17:30 - 23:00 5.50 DRILL P PROD1 Circulated a bottoms up and monitored hole, static. Then pumped out of the hole at 267 gpm and 2000 psi from 11095' to 10209'. Up wt of 190k and down wt. of 135k. Pumped a slug and began to trip out of the hole from 10209' to 402'. 23:00 - 00:00 1.00 DRILL P PROD1 Begin to lay down the BHA and Rack back the HWDP and Circ. Sub. 8/10/2008 00:00 - 02:30 2.50 DRILL P PROD1 Finish Laying down the BHA, Down Load MWD, and remove radioactive sources. Also laydown the TM collar and stabilizer. 02:30 - 04:30 2.00 DRILL P PROD1 Pick u and Make u new BHA. Adjusted the motor from a 2.0. de ree bend to a 2.23 de ree bend Laid down the stabilizer and picked up a new TM. Shallow tested the new MWD; good test, then loaded radioactive sources. We then made up the HWDP and collars and ran in to 399'. 04:30 - 09:00 4.50 DRILL P PROD1 Run in hole from 399' to 11095', we filled the pipe every 30 stands. 09:00 - 23:00 14.00 DRILL P PROD1 Directionally drill ahead from 11095' to 11375' with an Up Wt. of 195k and a Down Wt. of 130k. We had 20-30k WOB while pumping at 270 gpm with 2310 psi. Mud Wt. In and Out of 8.5 ppg. Angle at TD of section was 95 degrees at the bit. 23:00 - 00:00 1.00 DRILL P PROD1 Monitored the hole; static, then we began to pump out of the hole from 11375' to 10951' at 260 gpm and 2058 psi. The Up Wt. was 190k and the Down Wt. was 130k with a Mud Wt. In and Out of 8.5 ppg. 8/11/2008 00:00 - 03:00 3.00 DRILL P PROD1 Pumped out of the hole from 10951' to 10266'. Dropped the ball to open the Circ. sub and circulated out until shakers cleaned up. Circ. sub sheared open at 2140 psi. Pumped a dry job and then monitored well, static. Mud Wt. In and Out 8.5 PPg• 03:00 - 06:00 3.00 DRILL P PROD1 Pulled out of hole from 10266' to 398'. Dropped ball to close the circ. sub at 1053'. 06:00 - 10:00 4.00 DRILL PROD1 Racked back HWDP and jars, then laid down the remaining BHA. Adjusted the motor from a 2.23 degree bend to a 1.5 degree bend. Clean and cleared floor; then prepared for BOPE test by sucking out the stack and removing the wear ring. 10:00 - 15:00 5.00 BOPSU P PROD1 Test BOPE. -Test all BOP related equipment to 250 psi low / 3500 psi high. -Test lower 2-7/8" x 5" Vari Rams, upper 3-1/2" x 6" Vari Rams, and Annular with 4" and 4 1 /2" test joint to 250 psi low / 3500 psi high. -Test Blind Shear Rams to 250 psi low / 3500 psi high. -Test IBOP and Choke Manifold to 250 psi low / 3500 psi high. -All test Good -Test Waived by AOGCC rep. Chuck Scheve on 8-10-08 ~ 17:30 hrs. -Test witnessed by BP WSL Bill Decker and NAD Toolpusher Cleve Coyne. 15:00 - 15:30 0.50 DRILL P PROD1 Laydown test joints and rig down testing equipment. Prepare to make up the BHA. 15:30 - 18:00 2.50 DRILL P PROD1 Installed the wear bushing and then made up bit, motor, uploaded MWD, installed radioactive sources and picked up the rest of the BHA to 398'. Shallow tested the MWD; good test. Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Operations Summary Report Page 19 of 23 ~ Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABORS 2ES Rig Number: 2ES i Date From - To Hours Task Code NPT Phase !. Description of Operations 8/11/2008 18:00 - 21:00 3.00 DRILL P PROD1 Tripped in the hole from 398' to 10298' filling ever 30 stands. 21:00 - 23:00 2.00 DRILL P PROD1 Cut and slip 98' of drilling line, serviced the draw works, and adjusted the brakes. 23:00 - 00:00 1.00 DRILL P PROD1 Tripped in the hole from 10298' to 11326' and established circulation at 245 gpm and 1673 psi. Up Wt 195k and Down Wt. 135k. Prepared for MAD Pass. 8/12/2008 00:00 - 01:30 1.50 DRILL C PROD1 Perform MAD pass from 11310' to 11218' at 150 fph. Pump at 255 gpm and rotate at 35 rpm. Lost 400 psi pump pressure. Shut down to troubleshoot. 01:30 - 02:45 1.25 DRILL X DPRB PROD1 Check all surface equipment. Trouble shooting pressure loss. 02:45 - 04:00 1.25 DRILL X DPRB PRODi POOH to shoe to drop ball and cycle CCV. 04:00 - 05:00 1.00 DRILL X DPRB PROD1 Drop operating ball to cycle CCV. Valve cycled at 2050 psi. Pressure at 83 gpm with 620 psi before and after cycle. Pressure at 300 gpm with 1240 psi before and after cycle. Drop second operating ball and cycle CCV at 2000 psi. No changes in pumping pressures. 05:00 - 11:30 6.50 DRILL X DPRB PROD1 Trip out of the hole from 10484' to 398'. - Mud weight in and out 8.5 ppg. 11:30 - 13:30 2.00 DRILL X DPRB PROD1 Stand back HWDP, Jars, and Circ. Sub. BHA was broken off 1.07' below box Circ sub. Left 203' of BHA including, bit, motor, MWD, radioactive sources, flex collars all in the hole. 13:30 - 15:00 1.50 DRILL X DPRB PROD1 Make up Fishing BHA containing overshot, grapple, pump out sub, HWDP, and drilling jars to 375'. 15:00 - 19:00 4.00 DRILL X DPRB PROD1 Trip in the hole from 375' to 10276'. Establish circulation at 301 gpm and 1312 psi with Up Wt. 185k and Down Wt. 130k. Chase the fish to 11138' and engage grapple and circulate at 160 gpm and 1100psi with an Up Wt. 205k and Down Wt. 150k. 19:00 - 20:00 1.00 DRILL X DPRB PROD1 Trip out of the hole with fish from 11138' to 9995' with Up Wt. 190k and Down Wt. 150k. Circulating at 250 gpm and 1600 psi, MWD showed pulses, verified fish was on. 20:00 - 20:30 0.50 DRILL X DPRB PROD1 Dropped the dart and opened circ. sub at 2200 psi. 20:30 - 00:00 3.50 DRILL X DPRB PROD1 Tripped out of the hole from 9995' to surface. Recovered remainder of ball catcher, flex collars, MWD, radioactive sources, motor, and bit. Also recovered the 4 steel balls that were dropped to function circ. sub. Entire fish recovered. 8/13/2008 00:00 - 03:30 3.50 DRILL X DPRB PROD1 Finish laying down the Fish (BHA #11) and fishing BHA. Then we clean and cleared floor and prepared for BHA #12. 03:30 - 08:00 4.50 DRILL X DPRB PROD1 Make up BHA # 12 and while loading radioactive sources the plug broke off. So we laid down the BHA and changed radioactive tool and then continued to pick up BHA # 12 and ran in hole to 385'. 08:00 - 11:30 3.50 DRILL X DPRB PROD1 Ran in the hole from 385' to 10285' filling every 30 stands. 11:30 - 12:00 0.50 DRILL X DPRB PROD1 Service top drive and draw works. 12:00 - 13:00 1.00 DRILL X DPRB PROD1 Oriented tool face from 10285' to 11221' with an Up Wt. 195k and Down Wt. of 135k. 13:00 - 18:00 5.00 DRILL P PROD1 Set depths and established parameters at 20 rpm's, torque at 6-7k, MAD Pass from 11220' to 10865' at 272 gpm and 2048 psi at 150 FPH max. 18:00 - 18:30 0.50 DRILL P PROD1 Run in hole from 10865' to 11374' and orient bit to 70 degree left of high side. 18:30 - 00:00 5.50 DRILL P PROD1 Drill ahead from 11374' to 11458' at 267 gpm and 2045 psi off bottom and 2310 psi on bottom. WOB of 5-10k with an Up Wt. Printed: 9/8/2008 11:15:24 AM ~ ~ BP EXPLORATION Page 20 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES i Date From - To ;Hours Task Code NPT Phase Description of Operations 8/13/2008 18:30 - 00:00 5.50 DR1LL P PROD1 of 195k and a Down Wt. of 135k. Mud Wt. In and Out of 8.5+. 8/14/2008 00:00 - 10:30 10.50 DRILL P PROD1 Drill ahead from 11458' to 11816' (9041' TVD) at 280 gpm and 2250 psi off bottom and 2470 psi on bottom. WOB of 5-15k with an Up Wt. of 180k, Down Wt. of 130k and Rot Wt. of 160k. Off bottom torque of 6-8k ft-Ibs, on bottom torque of 8-10k ft-Ibs. Mud Wt. In and Out of 8.6 ppg. Sperry determined that , the wrong radioactive source had been installed in the density 10:30 - 11:30 1.001 DRILL N i HMAN i PRODi 11:30 - 16:00 4.50 DRILL N HMAN PRODi 16:00 - 18:00 2.00 DRILL N HMAN PROD1 18:00 - 19:30 1.50 DRILL N HMAN PROD1 19:30 - 22:00 2.50 DRILL N HMAN PROD1 22:00 - 00:00 2.00 DRILL P PROD1 8/15/2008 00:00 - 11:30 11.50 DRILL N HMAN PRODi 11:30 - 12:00 0.50 DRILL I N HMAN PROD1 12:00 - 19:30 7.50 DRILL P PRODi 19:30 - 20:30 1.00 DRILL P 20:30 - 00:00 3.50 DRILL P .8/16/2008 00:00 - 03:00 3.00 DRILL P 03:00 - 04:30 1.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 07:00 0.50 DRILL P 07:00 - 10:30 3.50 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 12:00 1.00 DRILL P 12:00 - 00:00 I 12.001 DRILL I P 18/17/2008 ~ 00:00 - 13:30 ~ 13.50 ~ DRILL ~ P PROD1 PROD1 PROD1 PROD1 CBU at 280 gpm, 2240 psi. Monitor well; static. POH to change out source. MW In and Out=8.6 ppg. POH from 11816' to BHA at 386'. Rack back drill collars and HWDP. PJSM. Unload and change out radioactive source. Download MWD. Inspect bit; good shape. Upload MWD. Run back in with BHA to 386'. RIH, PU 15 joints of DP. RIH to 10,286', Cut and slip drilling line. Service top drive. MAD pass from 11,816' to 10860' at 280 gpm at 2320 psi and 30 rpm. MAD pass rates: 350 fph from 11816' to 11300'; 150 fph from 11300' to 11050'; and 350 fph from 11050' to 10860'. Re-MAD pass from 11,640'to 11,600' at 150 fph. RIH to bottom at 11,816'. Drill from 11,816'to 11,999' (9045' TVD). 280 gpm, On Btm Pressure 2690 psi, Off Btm Pressure 2420 psi. Up Wt. 185K, Down Wt. 125K, Rot. Wt. 155K. WOB 5-10K. 80 RPM. Off Btm Torque 6-8K ft-Ibs, On Btm Torque 8-9K ft-Ibs. MW In and Out 8.6 ppg. Unable to build angle; estimated inclination on bottom was 87.5 decrees and dropping at a rate of 4 W100. Estimated- 5' above HOT. Upon consulting with Town, decide to POH to change out bit to a roller cone insert and dial up motor. CBU at 280 gpm and 2380 psi. Monitor well; static. MW In and Out 8.6 ppg. POH from 11,999'to 3752'. POH from 3752' to BHA. Remove radioactive sources, lay down the remainder of the BHA. PROD1 Pick u new BHA with a new bit and chan a the bend of th motor to 1.76 de ree. Pick up new TM collar, and shallow test the MWD, good test. PROD1 Service top drive and clean and clear rig floor. PROD1 Finish picking up BHA with new jars from 292' to 389'. PROD1 Run in hole from 389' to 10289'. Up Wt of 165k and a Down Wt. of 135k. PROD1 Run into open hole from 10289' to 11879' with no problems. Up Wt. of 205k and a Down Wt. of 130k. PROD1 Wash down from 11879' to 11999' at 290 gpm and 2440 psi. Up Wt. of 185k and a Down Wt. of 130k. PROD1 Drill ahead from 11999' to 12454', 9025' TVD. Up Wt. of 180k, own t. 0 5 ,and Rot Wt. of 155k with a WOB of 10-15k at 300 gpm and 2720 psi off and 2790 psi on. Torque of 6-7 k and RPM of 50k. Mud Wt In and Out 8.5 ppg. Started having losses at 12035' with a total of 300 bbl loss for entire tour. PROD1 I Drill ahead from 12454' to 12800' with an Up Wt. of 185k, Printed: 9/8/2008 11:15:24 AM BP EXPLORATION Page 21 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To Hours ~ Task Code NPT ~, Phase Description of Operations 8/17/2008 00:00 - 13:30 13.50 DRILL P PROD1 Down Wt. of 125k, and Rot Wt. of 150k with a WOB of 15-25k at 300 gpm and 2600 psi off and 2700 psi on. Torque of 7-9 k and RPM of 50-60. Mud Wt In and Out 8.5 ppg. Losses slowed down to 20-25 bbl er hour. 13:30 - 14:30 1.00 DRILL P PROD1 Circulate bottoms up at 300 gpm and 2600 psi. Monitor Well for 10 minutes, static. Mud Wt In and Out 8.5 ppg 14:30 - 15:00 0.50 DRILL P PROD1 Back ream out of the hole from 12800' to 12630' at 300 gpm and 2400 psi. 15:00 - 16:00 1.00 DRILL N DFAL PROD1 Attempt to MAD Pass from 12630' to 12600' but no signal from MWD. Switched modes and attempted again with no success. 16:00 - 19:00 3.00 DRILL P PRODi Continue to back ream out of the hole from 12630' to 11321'. No Rotation from 11500' to 11300' due to dogleg. 19:00 - 20:00 1.00 DRILL P PROD1 Monitor the well for 10 minutes, static. Dropped the ball and rod to open the circ. sub, Opened the circ. sub at 2400 psi. Circulated a bottoms up at 500 gpm and 2650 psi. Pumped a dry job. Mud Wt In and Out 8.5 ppg. 20:00 - 00:00 4.00 DRILL P PROD1 Trip out of the hole from 10288' to 388'. 8/18/2008 00:00 - 03:00 3.00 DRILL P PRODi Laydown the BHA - Download the MWD, Remove the radioactive sources, laydown all third party tools. 03:00 - 04:45 1.75 CASE P PRODi Clean and clear floor, Rig up to run 4.5" production liner, Hold PJSM with all NAD hands, Casing Hand, Baker Hand, NAD Toolpusher Jon Castle, and SP WSL Chris Kobuck and Adrienne McVey 04:45 - 10:30 5.75 CASE P PROD1 Bun in hole with 86 joints of 4.5" 12.6# L-80 IBT-M production liner, filling liner on the fly. Joints #1-60: 2 centralizers/joint with stop ring in middle of joint. Joints #61-86: 1 centralizer/joint, free floating. k r h n er liner t acker and 1 joint of drill pipe. 16 bbl loss while runnin liner. Up Wt. 70K, Down Wt. 65K. 10:30 - 11:00 0.50 CASE P PROD1 Circulate 1.5x liner volume at 3533'. 11:00 - 15:30 4.50 CASE P PRODi Run liner in hole with 4" drill pipe from 3533' to 10260' filling every 10 stands. 15:30 - 16:30 1.00 CASE P PROD1 Circulate 1.5x pipe volume and stage pumps to 5 bpm at 850 psi. 16:30 - 18:00 1.50 CASE P PROD1 Run liner in the hole from 10260' to 12800' with no issues. Up Wt of 185k and Down Wt. of 130k. Make up the cement head. 18:00 - 20:00 2.00 CASE P PROD1 Circulate and stage pumps up to 210 gpm and 1100 psi. 20:00 - 23:00 3.00 CEMT P PROD1 Pressure tested outside lines to 4000 psi, good test. Pressure tested the inside lines, cement hose and head with mud to 4000 psi, good test. -Pumped away 20.2 bbls of mud push at 12 ppg -10 bbls of 15.8 ppg Class G neat cement -51 bbls of 15.8 ppg Class G neat cement with 1 Ib/bbl cemnet. -16 bbls of 15.8 ppg Class G neat cement - Bled down the lines and switched to rig pumps and chased the cement with 52 bbls of 8.5 ppg pert pill. -Chased with 93 bbls of 8.5 ppg mud. -Stopped reciprocating pipe 400 strokes prior to plug bumping because surface pressure was approaching 1500 psi. -Bu wed the plug with 2560 strokes and pressured up to 3500 Printed: 9/8/2008 11:15:24 AM • BP EXPLORATION Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To 8/18/2008 20:00 - 23:00 ~ 3.001 CEMT P 23:00 - 00:00 1.00 CEMT P ' 8/19/2008 00:00 - 00:30 0.50 CEMT P 00:30 - 01:00 0.50 CEMT P ~I 01:00 - 04:30 3.50 CEMT P 04:30 - 05:00 0.50 PERFOB P 05:00 - 06:00 1.00 PERFO P 06:00 - 12:00 6.001 PERFOB P 12:00 - 16:30 4.50 PERFO P 16:30 - 17:30 1.00 PERFO P 17:30 - 18:00 0.50 PERFO P 18:00 - 19:30 1.50 PERFO P ~ 19:30 - 00:00 4.50 PERFO P 8/20/2008 00:00 - 02:00 2.00 PERFO P 02:00 - 03:30 1.50 PERFO~ P 03:30 - 07:30 4.00 PERFO P 07:30 - 10:30 3.00 PERFO P 10:30 - 14:30 4.001 PERFOB P 14:30 - 15:30 1.00 PERFO P 15:30 - 18:30 3.00 BUNCO 18:30 - 00:00 5.50 BUNCO 18/21/2008 100:00 - 07:00 I 7.00 PROD1 psi and set down 50k, then checked floats, held. -Released from the liner, pressured up to 1000 psi and pulled out of the hanger. -Pumped 30 bbls, rotated at 20 rpm, set down 50k twice. Picked up and circulated out cement from the top of the liner. -Returned 10 bbls of cement -Cement in place at 21:43. -SEE REMARKS FOR PROCEDURE PROD1 Lay down cement head and displace to 8.5 ppg 1% KCI brine. PROD1 Clean out under shakers prior to POH. PROD1 Service top drive. PROD1 POH from 9293' to liner running tool. Up weight 175K, Down weight 125K. Clean and clear rig floor. OTHCMP PJSM. PU Schlumberger perforating BHA. OTHCMP P 1SM. Rig up and test liner lap and liner to 3500 psi for 30 minutes. Good test; lost 5 psi in first 15 minutes and 0 psi in second 15 minutes. Test recorded on chart. OTHCMP MU and RIH with 2.875" PJ Omega pert assembly to 3558'. -29 guns (26 loaded, 3 partial) -Guns spaced out with 2-7/8" PAC pipe -2 eFire firing heads -Total assembly length 1258' -2300' of 2-7/8" PAC pipe above guns Up weight 58K, Down weight 55K. OTHCMP RIH with pert assembly on 4" DP from 3558' to 12,711'. Tag plugs on top of landing collar at 12,711'. Up weight 180K, Down weight 130K. OTHCMP PJSM. Space out perforating assembly. Close annular preventer and fire guns per Schlumberger's procedure. Good indication of uns firin . 5 bbl loss after uns fired. -Pert intervals: 11,475'-11,950' and 12,600'-12,700'. OTHCMP POH from 12,700' to 11,402', racking back stands. Brine weight in/out=8.5 ppg. Up weight 205K. OTHCMP Slip and cut drilling line. Service crown, drawworks, and blocks. Monitor well; static. OTHCMP POH laying down drill pipe to pipeshed from 11,402'to 5,990'. OTHCMP POH laying down drill pipe from 5990' to 3600'. OTHCMP RIH with stands remaining in derrick from 3600' to 8635'. OTHCMP POH laying down drill pipe from 8635' to 3557'. OTHCMP Change out handling equipment for laying down 2-7/8" PAC pipe. LD PAC pipe from 3557' to top of pert assembly at 1257'. OTHCMP PJSM. LD Schlumberger perf guns and PAC pipe. -All shots fired__, OTHCMP Clean and clear rig floor. RUNCMP Pull wear ring. Rig up to run 4.5" VAM Top completion. RUNCMP PJSM. MU and RIH with VAM Top tubing tail (muleshoe, XN-nipple with RHC plug, X-nipple, Baker S-3 packer). Bakerlok all connections below packer. Run 4.5" 12.6# 13Cr-80 VAM Top completion to 3760'. Makeup torque 4440 ft-Ibs. RUNCMP Continue running 4.5" 13 Cr com letion from 3760' to 9285'. Pipe displacement correct throughout tubing run -hole is not taking any fluid. Up weight 130K, Down weight 100K. Operations Summary Report Page 22 of 23 'I Spud Date: 7/11 /2008 Start: 7/4/2008 End: Rig Release: 8/21 /2008 Rig Number: 2ES Phase Description of Operations 02-40 02-40 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 2ES Hours Task ~ Code NPT Printed: 9/8/2008 11:15:24 AM ~ • BP EXPLORATION Page 23 of 23 Operations Summary Report Legal Well Name: 02-40 Common Well Name: 02-40 Spud Date: 7/11/2008 Event Name: DRILL+COMPLETE Start: 7/4/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 2ES Rig Number: 2ES ..Date From - To Hours Task ~ Code NPT Phase Description of Operations 8/21/2008 07:00 - 08:30 1.50 BUNCO RUNCMP Space out tubing with 3.82' pup joint; WLEG is at 9285' a roximatel 6.5' inside TBR above liner to acker). Land tubing hanger, RILDS, LD landing joint. 08:30 - 10:30 2.00 BUNCO RUNCMP Reverse circulate well to 1 % KCL with corrosion inhibitor. Pump at 3 bpm, 210 psi. -142 bbl w/o inhibitor -54 bbl with inhibitor -117 bbl w/o inhibitor 10:30 - 12:00 1.50 BUNCO RUNCMP PU landing joint and drop ball and rod to set packer. Pressure u to 3500 si and hold for 30 minutes to test tubin ood test lost 10 si in first 15 minutes and 0 si in second 15 minutes Test IA to 3500 si for for 30 minutes• ood test lost 10 i i first 15 minutes and 0 si in second 15 minutes . 12:00 - 13:00 1.00 BUNCO RUNCMP Pump down IA to shear DCK valve. Pressure up to 2900 psi; no shear. Bleed off and pressure back up to 3000 psi, partially sheared. Circulate down IA at 3 BPM, 1300 psi, then tubing at 3 BPM, 1770 psi; attempting to fully open DCK valve. Increase pump rate down IA to 4.5 BPM, 3000 psi 2 times; valve would not open fully. Opt to freeze protect post-rig. 13:00 - 16:00 3.00 BOPSU RUNCMP Install and test TWC. ND BOPE. 16:00 - 19:00 3.00 WHSUR RUNCMP NU adapter flange and tree. Test flange to 5000 psi for 30 minutes and tree to 5000 psi for 10 minutes; good tests. 19:00 - 21:00 2.00 WHSUR RUNCMP RU DSM lubricator. Pull TWC. Install and test BPV to 1000 psi for 10 minutes; good test. 21:00 - 22:00 1.00 WHSUR RUNCMP Secure tree, clean up cellar, suck all fluid out of pits. 22:00 - 00:00 2.00 WHSUR RUNCMP Blow down lines, disconnect pits, bridle up, lay derrick over. Rig released from operations at 00:00 hrs. Printed: 9/8/2008 11:15:24 AM perry Drilling Services Survey Report Company: BP Amoco Datc: 8/26/2008 Time: 13:20:54 Page: 1 Field: Prudhoe Bay Co-ordinatclNE) Refcrcnce: Well: 02-40, True North Site: PB DS 02 Vertical (TVD) Refcrcnce: CBE30.4+RKB28.5@58.9 58.9 Wcll: 02-40 Section DVS) Reference: Well (O.OON,O.OOE,230.11Azi) Wellpath: 02-40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey - - __- - MD Intl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft degdr deg. ft; ft ft ft ft ft 28.50 0.00 0.00 28.50 -30.40 0.00 0.00 5950365.75 688482.31 TIE LINE 112.00 0.43 140.90 112.00 53.10 -0.24 0.20 5950365.51 688482.51 CB-GYRO-SS 170.00 0.40 103.94 170.00 111.10 -0.46 0.53 5950365.30 688482.85 CB-GYRO-SS 265.00 0.31 138.47 265.00 206.10 -0.73 1.02 5950365.04 688483.35 CB-GYRO-SS 350.00 0.71 196.55 349.99 291.09 -1.41 1.03 5950364.37 688483.37 CB-GYRO-SS 439.00 1.51 211.09 438.98 380.08 -2.94 0.26 5950362.81 688482.65 CB-GYRO-SS 547.00 2.49 211.80 546.91 488.01 -6.16 -1.71 5950359.55 688480.76 CB-GYRO-SS 634.00 4.11 214.68 633.76 574.86 -10.33 -4.48 5950355.32 688478.09 CB-GYRO-SS 712.00 4.75 218.74 711.53 652.63 -15.14 -8.09 5950350.41 688474.60 CB-GYRO-SS 808.00 3.41 219.94 807.28 748.38 -20.43 -12.41 5950345.01 688470.42 CB-GYRO-SS 850.49 3.04 211.86 849.71 790.81 -22.36 -13.82 5950343.05 688469.06 MWD+IFR+MS 944.85 2.19 224.98 943.97 885.07 -25.76 -16.41 5950339.59 688466.55 MWD+IFR+MS 1037.19 1.58 229.80 1036.26 977.36 -27.83 -18.63 5950337.46 688464.38 MWD+IFR+MS 1133.27 0.33 232.95 1132.32 1073.42 -28.85 -19.86 5950336.41 688463.18 MWD+IFR+MS 1229.07 0.24 279.71 1228.12 1169.22 -28.98 -20.28 5950336.27 688462.76 MWD+IFR+MS 1322.21 0.17 354.71 1321.26 1262.36 -28.81 -20.49 5950336.44 688462.55 MWD+IFR+MS 1415.85 0.06 191.27 1414.90 1356.00 -28.72 -20.51 5950336.52 688462.53 MWD+IFR+MS 1511.11 0.23 90.19 1510.16 1451.26 -28.77 -20.33 5950336.48 688462.71 MWD+IFR+MS 1606.46 0.14 350.21 1605.51 1546.61 -28.66 -20.16 5950336.60 688462.88 MWD+IFR+MS 1700.41 0.34 54.38 1699.46 1640.56 -28.38 -19.95 5950336.88 688463.08 MWD+IFR+MS 1795.47 0.22 79.37 1794.52 1735.62 -28.18 -19.54 5950337.09 688463.48 MWD+IFR+MS 1889.17 0.31 91.92 1888.22 1829.32 -28.16 -19.11 5950337.12 688463.91 MWD+IFR+MS 1985.31 0.57 33.24 1984.35 1925.45 -27.77 -18.59 5950337.53 688464.42 MWD+IFR+MS 2080.20 0.31 41.02 2079.24 2020.34 -27.18 -18.16 5950338.13 688464.84 MWD+IFR+MS 2173.65 0.43 350.22 2172.69 2113.79 -26.64 -18.05 5950338.66 688464.93 MWD+IFR+MS 2268.01 0.76 17.51 2267.04 2208.14 -25.70 -17.93 5950339.61 688465.03 MWD+IFR+MS 2361.02 0.92 185.66 2360.05 2301.15 -25.85 -17.81 5950339.46 688465.15 MWD+IFR+MS 2455.32 1.62 194.02 2454.33 2395.43 -27.90 -18.21 5950337.41 688464.80 MWD+IFR+MS 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 : bggm2007 Well: 02-40 Slot Name: Well Position: +N/-S 1543.95 ft Northing: 5950365.75 ft Latitude: 70 16 9.032 N +E/-W 882.68 ft Easting : 688482.31 ft Longitude: 148 28 32.366 W Position Uncertainty: 0.00 ft Wellpath: 02-40 Drilled From: 02-40PB1 500292337700 Tie-on Depth: 3482.63 ft Current Datum: CBE30.4+RKB28.5@58.9 Height 58.90 ft Above System Datum: Mean Sea Level Magnetic Data: 7/15/2008 Declination: 23.23 deg Field Strength: 57683 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 230.11 Survey Program for Definitive Wellpath Date: 8/26/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 112.00 808.00 02-40PB1 CB-GYRO-SS Sperry (11 CB-GYRO-SS Camera based gyro single shots 850.49 3482.63 02-40PB1 MWD+SAG+CA+IIFR+MS (8 MWD+IFR+MS MWD +IFR + Multi Station 3482.63 12758.42 02-40 MWD+SAG+CA+IIFR+MS Sperr MWD+IFR+MS MWD +IFR + Multi Station perry Drilling Services' Survey Report Companv: BP -- Amoco - - Uate: $/26/2008 Time: 13 :20:54 Nage: 2 Field: Pru dhoe Bay Cu-ordinate(NP,) Reference: Well: 02-40, True North Site: PB DS 02 Vcrtica l'(TVD) Reference: CBE3 0.4+RKB28. 5[7a 58.9 58.9 ~ Well: 02- 40 Section (VS) Reference: Well ( O.OON,O.OOE,230.11 Azi) Wellpath: 02- 40 Survey Calculation Method: Minim um Curvatu re Dh: Oracle Survey MU Incl Azim __ _ TVD Sys TVD ~ N/S __ _. E/~i' MapN MapE Tool ft deg. deg ft ft ft ft ft ft 2550.47 2.76 212 .80 2549. 41 2490.51 -31.13 -19.78 5950334.14 688463.32 MWD+IFR+MS 2642.20 5.07 224 .06 2640. 92 2582.02 -35.90 -23.79 5950329.27 688459.42 MWD+IFR+MS 2740.22 7.85 224 .50 2738. 31 2679.41 -43.79 -31.50 5950321.19 688451.92 MWD+IFR+MS 2835.75 11.36 225 .33 2832. 48 2773.58 -55.06 -42.77 5950309.64 688440.94 MWD+IFR+MS 2930.63 15.73 226 .00 2924. 70 2865.80 -70.57 -58.67 5950293.74 688425.43 MWD+IFR+MS 3025.02 18.53 226 .66 3014. 90 2956.00 -89.76 -78.79 5950274.05 688405.80 MWD+IFR+MS 3118.80 21.86 226 .25 3102. 90 3044.00 -112.06 -102.24 5950251.17 688382.91 MWD+IFR+MS 3213.30 26.73 224 .97 3189. 00 3130.10 -139.28 -129.99 5950223.27 688355.86 MWD+IFR+MS 3308.91 31.56 224 .87 3272. 48 3213.58 -172.24 -162.86 5950189.49 688323.83 MWD+IFR+MS 3403.20 35.67 228 .09 3351. 00 3292.10 -208.11 -200.74 5950152.69 688286.85 MWD+IFR+MS 3439.63 37.32 229 .13 3380. 28 3321.38 -222.44 -217.00 5950137.96 688270.96 MWD+IFR+MS 3482.63 37.46 229 .22 3414. 45 3355.55 -239.51 -236.76 5950120.41 688251.64 MWD+IFR+MS 3517.00 37.59 229 .30 3441. 70 3382.80 -253.17 -252.62 5950106.35 688236.12 MWD+IFR+MS 3537.30 37.01 227 .22 3457. 85 3398.95 -261.36 -261.80 5950097.94 688227.15 MWD+IFR+MS 3567.93 36.55 225 .85 3482. 39 3423.49 -273.97 -275.11 5950084.99 688214.16 MWD+IFR+MS 3662.48 35.83 226 .41 3558. 69 3499.79 -312.66 -315.35 5950045.31 688174.90 MWD+IFR+MS 3756.78 34.90 222 .33 3635. 60 3576.70 -351.64 -353.52 5950005.39 688137.73 MWD+IFR+MS 3845.83 35.06 220 .91 3708. 57 3649.67 -389.81 -387.42 5949966.39 688104.79 MWD+IFR+MS 3943.16 33.83 220 .28 3788. 83 3729.93 -431.60 -423.25 5949923.71 688070.03 MWD+IFR+MS 4036.84 34.10 219 .22 3866. 53 3807.63 -471.84 -456.71 5949882.65 688037.58 MWD+IFR+MS 4129.16 35.63 221 .05 3942. 28 3883.38 -512.17 -490.74 5949841.48 688004.58 MWD+IFR+MS 4221.67 37.66 223 .88 4016. 50 3957.60 -552.87 -528.03 5949799.86 687968.32 MWD+IFR+MS 4312.90 39.19 224 .81 4087. 97 4029.07 -593.41 -567.66 5949758.35 687929.72 MWD+IFR+MS 4405.88 43.50 228 .33 4157. 77 4098.87 -635.55 -612.30 5949715.10 687886.15 MWD+IFR+MS 4435.84 43.71 228 .60 4179. 47 4120.57 -649.26 -627.77 5949701.02 687871.04 MWD+IFR+MS 4500.38 44.90 230 .44 4225. 65 4166.75 -678.51 -662.06 5949670.91 687837.49 MWD+IFR+MS 4592.64 45.25 231 .91 4290. 81 4231.91 -719.46 -712.95 5949628.71 687787.65 MWD+IFR+MS 4685.83 45.67 233 .60 4356. 17 4297.27 -759.66 -765.82 5949587.20 687735.80 MWD+IFR+MS 4777.16 45.48 233 .97 4420. 10 4361.20 -798.19 -818.44 5949547.36 687684.16 MWD+IFR+MS 4871.66 45.10 233 .65 4486. 59 4427.69 -837.85 -872.65 5949506.37 687630.97 MWD+IFR+MS 4965.53 44.88 232 .94 4552. 97 4494.07 -877.51 -925.85 5949465.38 687578.78 MWD+IFR+MS 5057.96 44.39 233 .05 4618. 75 4559.85 -916.60 -977.71 5949425.01 687527.92 MWD+IFR+MS 5150.14 45.18 234 .39 4684. 17 4625.27 -955.02 -1030.06 5949385.30 687476.55 MWD+IFR+MS 5245.07 44.90 234 .17 4751. 25 4692.35 -994.23 -1084.59 5949344.73 687423.02 MWD+IFR+MS 5338.03 44.65 233 .85 4817. 24 4758.34 -1032.71 -1137.57 5949304.94 687371.02 MWD+IFR+MS 5431.08 44.43 231 .74 4883. 57 4824.67 -1072.17 -1189.55 5949264.20 687320.05 MWD+IFR+MS 5522.59 43.80 230 .46 4949. 27 4890.37 -1112.16 -1239.12 5949222.98 687271.50 MWD+IFR+MS 5617.16 43.60 230 .64 5017. 64 4958.74 -1153.68 -1289.57 5949180.21 687222.10 MWD+IFR+MS 5710.27 43.14 231 .23 5085. 32 5026.42 -1193.97 -1339.22 5949138.69 687173.49 MWD+IFR+MS 5803.66 42.82 231 .21 5153. 65 5094.75 -1233.85 -1388.85 5949097.58 687124.87 MWD+IFR+MS 5897.61 43.08 228 .38 5222. 42 5163.52 -1275.17 -1437.73 5949055.06 687077.05 MWD+IFR+MS 5990.88 42.42 228 .23 5290. 91 5232.01 -1317.28 -1485.00 5949011.78 687030.85 MWD+IFR+MS 6084.28 41.93 228 .35 5360. 13 5301.23 -1359.00 -1531.82 5948968.90 686985.10 MWD+IFR+MS 6177.80 43.33 228 .66 5428. 93 5370.03 -1400.96 -1579.26 5948925.76 686938.72 MWD+IFR+MS 6271.52 42.94 228 .97 5497. 32 5438.42 -1443.16 -1627.48 5948882.38 686891.57 MWD+IFR+MS 6365.28 42.86 229 .03 5566. 01 5507.11 -1485.03 -1675.65 5948839.31 686844.47 MWD+IFR+MS 6458.57 43.81 229 .94 5633. 86 5574.96 -1526.62 -1724.32 5948796.52 686796.86 MWD+IFR+MS 6552.81 44.13 230 .08 5701. 69 5642.79 -1568.67 -1774.45 5948753.24 686747.80 MWD+IFR+MS 6646.03 44.22 229 .83 5768. 55 5709.65 -1610.46 -1824.18 5948710.21 686699.14 MWD+IFR+MS 6739.45 43.84 230 .16 5835. 71 5776.81 -1652.20 -1873.92 5948667.24 686650.46 MWD+IFR+MS 6833.71 44.16 229 .62 5903. 52 5844.62 -1694.39 -1923.99 5948623.82 686601.46 MWD+IFR+MS 6927.16 41.82 230 .75 5971. 87 5912.97 -1735.19 -1972.92 5948581.80 686553.57 MWD+IFR+MS perry Drilling Services' Survey Report ---- Company: BP Amoco - _ Date: -_ 8/26/2008 Time: 13 :20:54 Page: 3 Field: Pru dhoe Bay Co-ord inate(NE) R eference: Well: 02-40, True North Site: PB DS 02 Vertica l (TVI)) Reference: CBE30.4+RKB28 .5@58.9 58.9 Well: 02- 40 Section (VS) Reference: Well (O.OON,O.OOE,230.11Azi) Wellpath: 02- 40 Survey Calculation Method: Minimum Curvatu re Db: Oracle Sure cv MD Incl Azim TVD Sys TVD N/S E/~V MapN Ma~E Tool ft deg deg ft ft ft ft ft ft 7021.37 41.88 230.37 6042.05 5983.15 -1775.12 -2021.47 5948540.67 686506.05 MWD+IFR+MS 7114.59 41.61 230.39 6111.60 6052.70 -1814.70 -2069.28 5948499.91 686459.25 MWD+IFR+MS 7207.67 41.16 229.81 6181.44 6122.54 -1854.18 -2116.49 5948459.27 686413.04 MWD+IFR+MS 7302.62 42.78 229.00 6252.03 6193.13 -1895.50 -2164.69 5948416.76 686365.89 MWD+IFR+MS 7394.24 43.36 230.13 6318.96 6260.06 -1936.07 -2212.32 5948375.00 686319.30 MWD+IFR+MS 7486.50 43.17 229.17 6386.14 6327.24 -1977.01 -2260.50 5948332.87 686272.15 MWD+IFR+MS 7579.50 42.63 228.39 6454.27 6395.37 -2018.73 -2308.12 5948289.98 686225.60 MWD+IFR+MS 7671.35 42.05 228.40 6522.16 6463.26 -2059.80 -2354.38 5948247.76 686180.38 MWD+IFR+MS 7764.16 43.30 229.05 6590.40 6531.50 -2101.30 -2401.66 5948205.10 686134.16 MWD+IFR+MS 7857.27 42.65 229.54 6658.52 6599.62 -2142.69 -2449.78 5948162.52 686087.10 MWD+fFR+MS 7950.57 43.62 228.64 6726.60 6667.70 -2184.47 -2497.98 5948119.55 686039.96 MWD+IFR+MS 8043.50 43.13 228.47 6794.15 6735.25 -2226.71 -2545.82 5948076.12 685993.19 MWD+IFR+MS 8137.14 43.92 228.36 6862.05 6803.15 -2269.51 -2594.06 5948032.13 685946.05 MWD+IFR+MS 8229.86 42.86 227.80 6929.43 6870.53 -2312.07 -2641.45 5947988.41 685899.74 MWD+IFR+MS 8322.96 43.44 229.15 6997.35 6938.45 -2354.27 -2689.12 5947945.02 685853.14 MWD+IFR+MS 8416.76 42.69 229.21 7065.88 7006.98 -2396.14 -2737.59 5947901.96 685805.74 MWD+IFR+MS 8511.44 42.91 229.92 7135.35 7076.45 -2437.86 -2786.55 5947859.02 685757.84 MWD+IFR+MS 8605.00 43.93 232.11 7203.31 7144.41 -2478.30 -2836.54 5947817.34 685708.88 MWD+IFR+MS 8699.08 44.00 233.11 7271.02 7212.12 -2517.96 -2888.43 5947776.40 685658.00 MWD+IFR+MS 8791.93 43.35 232.94 7338.18 7279.28 -2556.53 -2939.66 5947736.57 685607.76 MWD+IFR+MS 8887.14 42.70 232.35 7407.78 7348.88 -2595.94 -2991.30 5947695.88 685557.13 MWD+IFR+MS 8982.07 41.81 232.47 7478.05 7419.15 -2634.88 -3041.88 5947655.68 685507.54 MWD+IFR+MS 9074.85 42.34 230.56 7546.92 7488.02 -2673.57 -3090.54 5947615.79 685459.87 MWD+IFR+MS 9169.17 42.12 229.79 7616.76 7557.86 -2714.17 -3139.22 5947573.99 685412.22 MWD+IFR+MS 9263.02 43.04 229.29 7685.86 7626.96 -2755.38 -3187.53 5947531.59 685364.96 MWD+IFR+MS 9352.02 41.99 227.86 7751.46 7692.56 -2795.16 -3232.63 5947490.69 685320.87 MWD+IFR+MS 9447.46 42.14 229.15 7822.32 7763.42 -2837.53 -3280.53 5947447.14 685274.06 MWD+IFR+MS 9541.33 42.80 230.51 7891.56 7832.66 -2878.40 -3328.96 5947405.06 685226.67 MWD+IFR+MS 9635.12 42.50 228.53 7960.55 7901.65 -2919.65 -3377.29 5947362.62 685179.39 MWD+IFR+MS 9728.86 42.90 229.32 8029.44 7970.54 -2961.42 -3425.21 5947319.67 685132.53 MWD+IFR+MS 9823.34 43.44 230.22 8098.34 8039.44 -3003.16 -3474.56 5947276.71 685084.24 MWD+IFR+MS 9915.37 44.31 230.41 8164.68 8105.78 -3043.89 -3523.65 5947234.76 685036.19 MWD+IFR+MS 10009.00 43.67 230.49 8232.05 8173.15 -3085.30 -3573.79 5947192.12 684987.11 MWD+IFR+MS 10101.42 42.88 230.11 8299.33 8240.43 -3125.77 -3622.54 5947150.44 684939.39 MWD+IFR+MS 10196.05 41.88 230.37 8369.24 8310.34 -3166.56 -3671.57 5947108.43 684891.40 MWD+IFR+MS 10284.86 40.97 230.52 8435.83 8376.93 -3203.98 -3716.87 5947069.89 684847.05 MWD+IFR+MS 10352.16 41.02 229.61 8486.62 8427.72 -3232.32 -3750.72 5947040.72 684813.92 MWD+IFR+MS 10441.37 39.44 229.44 8554.73 8495.83 -3269.72 -3794.55 5947002.24 684771.05 MWD+IFR+MS 10534.53 39.38 231.00 8626.71 8567.81 -3307.56 -3840.00 5946963.27 684726.56 MWD+IFR+MS 10628.04 41.14 230.50 8698.07 8639.17 -3345.80 -3886.79 5946923.88 684680.75 MWD+IFR+MS 10721.77 40.96 231.07 8768.75 8709.85 -3384.71 -3934.48 5946883.78 684634.05 MWD+IFR+MS 10815.39 40.31 229.56 8839.80 8780.90 -3423.64 -3981.40 5946843.70 684588.12 MWD+IFR+MS 10848.89 42.66 227.67 8864.89 8805.99 -3438.31 -3998.04 5946828.61 684571.85 MWD+IFR+MS 10863.48 43.71 228.50 8875.53 8816.63 -3444.98 -4005.47 5946821.76 684564.59 MWD+IFR+MS 10879.72 45.29 229.59 8887.11 8828.21 -3452.44 -4014.07 5946814.08 684556.19 MWD+IFR+MS 10908.91 47.67 231.32 8907.21 8848.31 -3465.91 -4030.39 5946800.21 684540.21 MWD+IFR+MS 10941.51 50.50 232.26 8928.56 8869.66 -3481.14 -4049.75 5946784.50 684521.24 MWD+IFR+MS 10971.29 53.89 233.40 8946.82 8887.92 -3495.35 -4068.50 5946769.83 684502.85 MWD+IFR+MS 11003.75 57.04 233.88 8965.21 8906.31 -3511.20 -4090.03 5946753.44 684481.72 MWD+IFR+MS 11038.69 60.04 234.59 8983.45 8924.55 -3528.62 -4114.22 5946735.43 684457.99 MWD+IFR+MS 11068.79 63.04 234.17 8997.79 8938.89 -3544.03 -4135.72 5946719.49 684436.87 MWD+IFR+MS 11097.23 65.77 234.82 9010.08 8951.18 -3558.92 -4156.60 5946704.08 684416.37 MWD+IFR+MS 11128.90 68.79 235.37 9022.31 8963.41 -3575.64 -4180.56 5946686.77 684392.85 MWD+IFR+MS perry Drilling Services Survey Report Company: BP Amoco ~ llatc: 8/26/2008 Timc: 13:20:54 Pagc: 4 Field: Prudhoe Bay Co-ordiuate(NE) Kcference: Well: 02-40, True North Site: PB DS 02 Vertical (TVll) Kcference: CBE30.4+RKB28.5@58.9 58.9 Well: 02-40 Section (VS) Kcference: Well (O.OON,OAOE,230.11Azi) Wellpath: 02-40 Survey Calculation Method: Minimum Curvature I)b: ~ Oracle i Survey MD ft Incl deg Azim deg TVll ft Sys TVD ft 11162.97 71.66 236.56 9033.83 8974.93 11191.03 74.93 237.13 9041.90 8983.00 11219.54 77.79 237.91 9048.62 8989.72 11255.71 81.48 237.51 9055.13 8996.23 11283.50 85.08 238.09 9058.38 8999.48 11318.73 88.34 239.48 9060.40 9001.50 11334.51 90.46 238.07 9060.56 9001.66 11364.45 94.76 239.67 9059.20 9000.30 11391.11 96.68 237.46 9056.54 8997.64 11427.09 95.75 233.95 9052.65 8993.75 11457.49 94.51 232.09 9049.93 8991.03 11552.96 92.16 235.02 9044.37 8985.47 11646.36 92.16 234.06 9040.85 8981.95 11739.95 89 .38 231.02 9039.60 8980.70 11833.93 89 .32 233.56 9040.66 8981.76 11926.68 88 .27 232.16 9042.61 8983.71 11956.20 88 .03 230.62 9043.57 8984.67 12022.33 91 .05 229.78 9044.10 8985.20 12115.54 92 .53 230.92 9041.19 8982.29 12210.08 90 .99 230.11 9038.28 8979.38 12302.47 92 .59 229.12 9035.40 8976.50 12399.36 95 .57 229.98 9028.50 8969.60 12487.99 97 .61 229.66 9018.33 8959.43 12582.41 95 .32 229.74 9007.70 8948.80 12677.13 92 .78 229.89 9001.01 8942.11 12758.42 92 .78 229.73 8997.07 8938.17 12800.00 92 .78 229.73 8995.05 8936.15 N/S F/VV D1apN ft ft ft -3593.57 -4207.12 5946668.17 -3608.27 -4229.62 5946652.92 -3623.15 -4252.99 5946637.46 -3642.15 -4283.06 5946617.71 -3656.85 -4306.42 5946602.43 -3675.08 -4336.49 5946583.46 -3683.26 -4349.98 5946574.94 -3698.72 -4375.58 5946558.85 -3712.55 -4398.21 5946544.46 -3732.70 -4427.75 5946523.57 -3750.91 -4451.94 5946504.76 -3807.52 -4528.60 5946446.26 -3861.66 -4604.62 5946390.23 -3918.57 -4678.88 5946331.48 -3976.05 -4753.22 5946272.17 -4032.03 -4827.14 5946214.35 -4050.44 -4850.19 5946195.37 -4092.76 -4900.99 5946151.79 -4152.21 -4972.72 5946090.57 -4212.30 -5045.65 5946028.68 -4272.12 -5115.99 5945967.12 -4334.82 -5189.52 5945902.60 -4391.62 -5256.79 5945844.14 -4452.30 -5328.33 5945781.69 -4513.26 -5400.51 5945718.95 -4565.66 -5462.54 5945665.02 -4592.50 -5494.22 5945637.39 MapF. Tool ft 684366.74 MWD+IFR+MS 684344.62 MWD+IFR+MS 684321.63 MWD+IFR+MS 684292.04 MWD+IFR+MS 684269.07 MWD+IFR+MS 684239.46 MWD+IFR+MS 684226.18 MWD+IFR+MS 684200.98 MWD+IFR+MS 684178.70 MWD+IFR+MS 684149.67 MWD+IFR+MS 684125.95 MWD+IFR+MS 684050.74 MWD+IFR+MS 683976.11 MWD+IFR+MS 683903.29 MWD+IFR+MS 683830.42 MWD+IFR+MS 683757.93 MWD+IFR+MS 683735.35 MWD+IFR+MS 683685.63 MWD+IFR+MS 683615.41 MWD+IFR+MS 683544.02 MWD+IFR+MS 683475.21 MWD+IFR+MS 683403.27 MWD+IFR+MS 683337.45 MWD+IFR+MS 683267.45 MWD+IFR+MS 683196.83 MWD+IFR+MS 683136.14 MWD+IFR+MS 683105.13 4 1 /2" perry Drilling Services Survey Report Company: BP Amoco Date: 8/26/2008 Timc: 13:21:57 Yage: I Field: Prudhoe Bay Co-ordinate(NE) Keference: Well: 02-40, True North Site: PB DS 02 Vertical (TVll) Keference: CBE30.4+RK628.5@58.9 58.9 Well: 02-40 Section (VS) Keference: Well (O.OON,O.OOE,230.50Azi) Wellpath: 02-40PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey - - _ - - -- i i14D Incl Azim '' TVD Sys TVD N/S E/y1 14IapN 1~IapE Tool ~~ ft deg deg ft ft ft ft ft ft - _ ___ --- 28.50 0.00 0.00 28.50 -30.40 0.00 0.00 5950365.75 688482.31 TIE LINE 112.00 0.43 140.90 112.00 53.10 -0.24 0.20 5950365.51 688482.51 CB-GYRO-SS 170.00 0.40 103.94 170.00 111.10 -0.46 0.53 5950365.30 688482.85 CB-GYRO-SS 265.00 0.31 138.47 265.00 206.10 -0.73 1.02 5950365.04 688483.35 CB-GYRO-SS 350.00 0.71 196.55 349.99 291.09 -1.41 1.03 5950364.37 688483.37 CB-GYRO-SS 439.00 1.51 211.09 438.98 380.08 -2.94 0.26 5950362.81 688482.65 CB-GYRO-SS 547.00 2.49 211.80 546.91 488.01 -6.16 -1.71 5950359.55 688480.76 CB-GYRO-SS 634.00 4.11 214.68 633.76 574.86 -10.33 -4.48 5950355.32 688478.09 CB-GYRO-SS 712.00 4.75 218.74 711.53 652.63 -15.14 -8.09 5950350.41 688474.60 CB-GYRO-SS 808.00 3.41 219.94 807.28 748.38 -20.43 -12.41 5950345.01 688470.42 CB-GYRO-SS 850.49 3.04 211.86 849.71 790.81 -22.36 -13.82 5950343.05 688469.06 MWD+IFR+MS 944.85 2.19 224.98 943.97 885.07 -25.76 -16.41 5950339.59 688466.55 MWD+IFR+MS 1037.19 1.58 229.80 1036.26 977.36 -27.83 -18.63 5950337.46 688464.38 MWD+IFR+MS 1133.27 0.33 232.95 1132.32 1073.42 -28.85 -19.86 5950336.41 688463.18 MWD+IFR+MS 1229.07 0.24 279.71 1228.12 1169.22 -28.98 -20.28 5950336.27 688462.76 MWD+IFR+MS 1322.21 0.17 354.71 1321.26 1262.36 -28.81 -20.49 5950336.44 688462.55 MWD+IFR+MS 1415.85 0.06 191.27 1414.90 1356.00 -28.72 -20.51 5950336.52 688462.53 MWD+IFR+MS 1511.11 0.23 90.19 1510.16 1451.26 -28.77 -20.33 5950336.48 688462.71 MWD+IFR+MS 1606.46 0.14 350.21 1605.51 1546.61 -28.66 -20.16 5950336.60 688462.88 MWD+IFR+MS 1700.41 0.34 54.38 1699.46 1640.56 -28.38 -19.95 5950336.88 688463.08 MWD+IFR+MS 1795.47 0.22 79.37 1794.52 1735.62 -28.18 -19.54 5950337.09 688463.48 MWD+IFR+MS 1889.17 0.31 91.92 1888.22 1829.32 -28.16 -19.11 5950337.12 688463.91 MWD+IFR+MS 1985.31 0.57 33.24 1984.35 1925.45 -27.77 -18.59 5950337.53 688464.42 MWD+IFR+MS 2080.20 0.31 41.02 2079.24 2020.34 -27.18 -18.16 5950338.13 688464.84 MWD+IFR+MS 2173.65 0.43 350.22 2172.69 2113.79 -26.64 -18.05 5950338.66 688464.93 MWD+IFR+MS 2268.01 0.76 17.51 2267.04 2208.14 -25.70 -17.93 5950339.61 688465.03 MWD+IFR+MS 2361.02 0.92 185.66 2360.05 2301.15 -25.85 -17.81 5950339.46 688465.15 MWD+IFR+MS 2455.32 1.62 194.02 2454.33 2395.43 -27.90 -18.21 5950337.41 688464.80 MWD+IFR+MS 2550.47 2.76 212.80 2549.41 2490.51 -31.13 -19.78 5950334.14 688463.32 MWD+IFR+MS 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: bggm2007 Well: 02-40 Slot Name: Well Position: +N/-S 1543.95 ft Northing: 5950365.75 ft Latitude: 70 16 9.032 N +E/-W 882.68 ft Easting : 688482.31 ft Longitude: 1 48 28 32.366 W Position Uncertainty: 0.00 ft Wellpath: 02-40P61 Drilled From: Well Ref. Point 500292337770 Tie-on Depth: 28.50 ft Current Datum: CBE30.4+RKB28.5[7a 58.9 Height 58.90 ft Above System Datum: Mean Sea Level Magnetic Data: 7/15/2008 Declination: 23.23 deg Field Strength: 57683 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 230.50 Survey Program for Definitive Wellpath Date: 7/25/2008 Validated: Yes Version: 11 Actual From To Survey Toolcode Tool Name n n 112.00 808.00 02-40P61 CB-GYRO-SS Sperry (11 CB-GYRO-SS Camera based gyro single shots 850.49 10354.81 02-40P61 MWD+SAG+CA+IIFR+MS (8 MWD+IFR+MS MWD +IFR + Multi Station perry Drilling Services Survey Report Company: BP Amoco Date: 8/26/2008 Time: 13 :21:57 Page: 2 ! Field: Pru dhoe Bay Co-ordinatc~NE) Refercncc: Well: 02-40, True North ~ Site: PB DS 02 Vertical (TVD) Refe rcncc: CBE3 0.4+RK628 .5@58.9 58.9 6VeH: 02- 40 Scetion (VS) Kefcrcnce: Well ( O.OON,O.OOE,230.50Azi) ~~Wellpath: 02- 40P61 Survey Calculation Method: Minim um Curvatu re Db: Oracle Survey _ MD InCI --- -- Azim TVD - Sys TVD N/S F,/V1' MapN MapE Tool ~ ft deg deg ft'- ft ft ft ft ft - -- 2642.20 5.07 - 224.06 2640.92 - 2582.02 _ -35.90 -23.79 5950329.27 688459.42 _ MWD+IFR+MS 2740.22 7.85 224.50 2738.31 2679.41 -43.79 -31.50 5950321.19 688451.92 MWD+IFR+MS 2835.75 11.36 225.33 2832.48 2773.58 -55.06 -42.77 5950309.64 688440.94 MWD+IFR+MS 2930.63 15.73 226.00 2924.70 2865.80 -70.57 -58.67 5950293.74 688425.43 MWD+IFR+MS 3025.02 18.53 226.66 3014.90 2956.00 -89.76 -78.79 5950274.05 688405.80 MWD+IFR+MS 3118.80 21.86 226.25 3102.90 3044.00 -112.06 -102.24 5950251.17 688382.91 MWD+IFR+MS 3213.30 26.73 224.97 3189.00 3130.10 -139.28 -129.99 5950223.27 688355.86 MWD+IFR+MS 3308.91 31.56 224.87 3272.48 3213.58 -172.24 -162.86 5950189.49 688323.83 MWD+IFR+MS 3345.00 33.12 226.19 3302.97 3244.07 -185.77 -176.64 5950175.63 688310.39 9 5/8" 3403.20 35.67 228.09 3351.00 3292.10 -208.11 -200.74 5950152.69 688286.85 MWD+IFR+MS 3439.63 37.32 229.13 3380.28 3321.38 -222.44 -217.00 5950137.96 688270.96 MWD+IFR+MS 3482.63 37.46 229.22 3414.45 3355.55 -239.51 -236.76 5950120.41 688251.64 MWD+IFR+MS 3575.63 37.81 229.43 3488.09 3429.19 -276.52 -279.83 5950082.33 688209.51 MWD+IFR+MS 3671.45 37.62 228.93 3563.89 3504.99 -314.83 -324.19 5950042.92 688166.13 MWD+IFR+MS 3765.14 38.74 229.36 3637.54 3578.64 -352.71 -367.99 5950003.95 688123.29 MWD+IFR+MS 3857.80 40.56 229.88 3708.88 3649.98 -391.01 -413.03 5949964.54 688079.22 MWD+IFR+MS 3951.25 43.10 230.84 3778.51 3719.61 -430.76 -461.03 5949923.61 688032.24 MWD+IFR+MS 4044.67 43.80 232.07 3846.33 3787.43 -470.79 -511.28 5949882.33 687983.01 MWD+IFR+MS 4135.92 43.74 231.93 3912.22 3853.32 -509.65 -561.02 5949842.24 687934.26 MWD+IFR+MS 4231.58 43.15 231.07 3981.68 3922.78 -550.60 -612.50 5949800.02 687883.82 MWD+IFR+MS 4324.26 41.84 229.86 4050.01 3991.11 -590.44 -660.79 5949758.98 687836.55 MWD+IFR+MS 4419.52 42.23 229.69 4120.76 4061.86 -631.63 -709.49 5949716.59 687788.90 MWD+IFR+MS 4516.13 41.68 230.32 4192.61 4133.71 -673.15 -758.97 5949673.85 687740.48 MWD+IFR+MS 4608.50 42.49 230.46 4261.16 4202.26 -712.62 -806.66 5949633.20 687693.79 MWD+IFR+MS 4701.06 43.54 231.23 4328.84 4269.94 -752.48 -855.63 5949592.12 687645.84 MWD+IFR+MS 4796.40 43.28 230.93 4398.10 4339.20 -793.64 -906.60 5949549.70 687595.92 MWD+IFR+MS 4890.89 44.20 232.85 4466.37 4407.47 -833.95 -958.01 5949508.12 687545.54 MWD+IFR+MS 4983.93 43.44 233.14 4533.50 4474.60 -872.73 -1009.45 5949468.07 687495.09 MWD+IFR+MS 5075.19 42.89 232.43 4600.06 4541.16 -910.48 -1059.17 5949429.09 687446.33 MWD+IFR+MS 5168.21 42.08 232.45 4668.66 4609.76 -948.78 -1108.97 5949389.56 687397.51 MWD+IFR+MS 5261.51 41.63 232.12 4738.15 4679.25 -986.86 -1158.22 5949350.25 687349.23 MWD+IFR+MS 5354.56 43.10 232.88 4806.90 4748.00 -1025.03 -1207.97 5949310.86 687300.46 MWD+IFR+MS 5446.61 42.38 232.55 4874.51 4815.61 -1062.87 -1257.67 5949271.79 687251.72 MWD+IFR+MS 5539.99 41.86 232.92 4943.77 4884.87 -1100.79 -1307.51 5949232.63 687202.85 MWD+IFR+MS 5632.60 41.03 232.70 5013.19 4954.29 -1137.84 -1356.34 5949194.37 687154.96 MWD+IFR+MS 5724.72 41.80 234.09 5082.28 5023.38 -1174.17 -1405.26 5949156.83 687106.97 MWD+IFR+MS 5817.52 42.53 234.06 5151.06 5092.16 -1210.72 -1455.71 5949119.03 687057.46 MWD+IFR+MS 5911.70 43.84 232.38 5219.73 5160.83 -1249.32 -1507.32 5949079.15 687006.84 MWD+IFR+MS 6004.77 43.62 232.56 5286.99 5228.09 -1288.51 -1558.34 5949038.70 686956.82 MWD+IFR+MS 6098.94 43.80 231.97 5355.06 5296.16 -1328.34 -1609.80 5948997.60 686906.37 MWD+IFR+MS 6192.57 43.37 232.07 5422.88 5363.98 -1368.06 -1660.68 5948956.62 686856.50 MWD+IFR+MS 6286.27 42.76 232.68 5491.33 5432.43 -1407.12 -1711.35 5948916.30 686806.83 MWD+IFR+MS 6379.95 42.94 231.63 5560.01 5501.11 -1446.21 -1761.66 5948875.97 686757.52 MWD+IFR+MS 6473.42 44.13 230.33 5627.78 5568.88 -1486.75 -1811.67 5948834.19 686708.54 MWD+IFR+MS 6567.74 44.24 230.11 5695.41 5636.51 -1528.81 -1862.19 5948790.88 686659.09 MWD+IFR+MS 6663.23 44.30 228.11 5763.79 5704.89 -1572.44 -1912.58 5948746.01 686609.82 MWD+IFR+MS 6756.18 44.19 228.30 5830.38 5771.48 -1615.66 -1960.93 5948701.59 686562.57 MWD+IFR+MS 6849.63 44.37 228.10 5897.28 5838.38 -1659.15 -2009.57 5948656.90 686515.04 MWD+IFR+MS 6943.31 43.93 227.82 5964.50 5905.60 -1702.84 -2058.03 5948612.01 686467.69 MWD+IFR+MS 7034.86 43.56 227.66 6030.64 5971.74 -1745.41 -2104.88 5948568.28 686421.92 MWD+IFR+MS 7129.32 43.23 227.14 6099.28 6040.38 -1789.34 -2152.65 5948523.18 686375.27 MWD+IFR+MS 7222.57 42.85 227.48 6167.43 6108.53 -1832.49 -2199.43 5948478.87 686329.59 MWD+IFR+MS perry Drilling Services` Survey Report Company: BP Amoco Date: 8/26/2008 Time: 13 :21:57 Page: 3 Field: Pru dhoe Bay Cu-ord inatc(NE) Ref erencc: Well: 02-40, True North Site: PB DS 02 Vertical (TVDj Referencc: CBE3 0.4+RK628 .5@58.9 58.9 Well: 02- 40 Section DVS) Referen ce: Well ( O.OON,O.OO E,230.50Azi) Wcllpath: 02- 40PB1 Survey Calculation Method: Minim um Curvatu re Db: Oracle Sur~e~~ MD Licl Azim TVD Svs TVD N/S ~/W MapN MapE Tool ft deg deg ft ft ft,, ft ft ft _- -- 7316.54 42.56 227.82 6236.48 6177.58 -1875.43 -2246.53 5948434.77 686283.58 MWD+IFR+MS 7410.51 41.99 228.64 6306.01 6247.11 -1917.54 -2293.67 5948391.50 686237.51 MWD+IFR+MS 7504.45 40.98 228.11 6376.39 6317.49 -1958.87 -2340.19 5948349.02 686192.04 MWD+IFR+MS 7596.02 40.41 227.51 6445.81 6386.91 -1998.96 -2384.43 5948307.83 686148.83 MWD+IFR+MS 7688.59 39.93 227.43 6516.55 6457.65 -2039.33 -2428.43 5948266.37 686105.85 MWD+IFR+MS 7781.32 40.36 228.48 6587.44 6528.54 -2079.36 -2472.83 5948225.24 686062.47 MWD+IFR+MS 7875.98 42.05 230.41 6658.65 6599.75 -2119.89 -2520.21 5948183.55 686016.12 MWD+IFR+MS 7969.77 41.21 229.81 6728.76 6669.86 -2159.84 -2568.02 5948142.41 685969.33 MWD+IFR+MS 8062.05 41.55 231.03 6798.00 6739.10 -2198.71 -2615.03 5948102.38 685923.31 MWD+IFR+MS 8157.14 42.61 232.06 6868.58 6809.68 -2238.33 -2664.94 5948061.52 685874.41 MWD+IFR+MS 8250.96 41.75 232.23 6938.10 6879.20 -2276.99 -2714.68 5948021.63 685825.66 MWD+IFR+MS 8344.20 42.43 232.86 7007.29 6948.39 -2315.00 -2764.29 5947982.40 685777.02 MWD+IFR+MS 8437.43 42.80 233.33 7075.90 7017.00 -2352.90 -2814.77 5947943.24 685727.51 MWD+IFR+MS 8529.76 42.14 233.27 7144.01 7085.11 -2390.16 -2864.75 5947904.75 685678.48 MWD+IFR+MS 8623.35 44.38 234.36 7212.16 7153.26 -2428.01 -2916.52 5947865.62 685627.67 MWD+IFR+MS 8715.75 43.57 234.46 7278.66 7219.76 -2465.35 -2968.69 5947826.98 685576.46 MWD+IFR+MS 8810.40 42.36 234.01 7347.92 7289.02 -2503.05 -3021.04 5947787.99 685525.08 MWD+IFR+MS 8903.73 43.52 233.43 7416.24 7357.34 -2540.67 -3072.29 5947749.10 685474.79 MWD+IFR+MS 8996.71 44.51 232.90 7483.11 7424.21 -2579.41 -3123.99 5947709.08 685424.07 MWD+IFR+MS 9092.40 43.40 232.01 7551.99 7493.09 -2619.88 -3176.66 5947667.31 685372.44 MWD+IFR+MS 9185.96 43.41 231.37 7619.96 7561.06 -2659.73 -3227.10 5947626.21 685323.01 MWD+IFR+MS 9279.03 42.70 230.82 7687.97 7629.07 -2699.63 -3276.55 5947585.08 685274.58 MWD+IFR+MS 9371.70 41.78 230.16 7756.58 7697.68 -2739.26 -3324.61 5947544.26 685227.53 MWD+IFR+MS 9466.30 41.90 230.10 7827.06 7768.16 -2779.71 -3373.04 5947502.61 685180.13 MWD+IFR+MS 9559.91 41.69 230.71 7896.84 7837.94 -2819.48 -3421.12 5947461.66 685133.07 MWD+IFR+MS 9652.18 42.78 230.92 7965.16 7906.26 -2858.66 -3469.19 5947421.29 685086.00 MWD+IFR+MS 9746.16 45.16 232.53 8032.79 7973.89 -2899.06 -3520.42 5947379.62 685035.80 MWD+IFR+MS 9839.84 43.79 232.68 8099.64 8040.74 -2938.92 -3572.56 5947338.47 684984.67 MWD+IFR+MS 9933.36 42.68 232.70 8167.77 8108.87 -2977.75 -3623.51 5947298.38 684934.71 MWD+IFR+MS 10027.19 41.89 231.33 8237.19 8178.29 -3016.59 -3673.27 5947258.30 684885.95 MWD+IFR+MS 10117.76 42.83 228.79 8304.12 8245.22 -3055.77 -3720.04 5947217.97 684840.17 MWD+IFR+MS 10212.29 43.96 228.10 8372.81 8313.91 -3098.86 -3768.64 5947173.69 684792.68 MWD+IFR+MS 10304.91 42.87 228.03 8440.08 8381.18 -3141.39 -3815.99 5947129.98 684746.41 MWD+IFR+MS 10338.82 43.05 228.32 8464.90 8406.00 -3156.81 -3833.21 5947114.14 684729.58 7" 10354.81 43.14 228.46 8476.58 8417.68 -3164.06 -3841.38 5947106.68 684721.59 MWD+IFR+MS 10449.00 43.14 228.46 8545.30 8486.40 -3206.77 -3889.59 5947062.78 684674.47 BLIND ~ r~rL - w- u i o i,rv v EA = FMC GEN NELLH . 5 _ aCr`UATOR = O ~ ~ O ~ <B.ELEV = 58.7 3F. ELEV = <OP - 32.8 2500' ~- I vlax Angle - 98° @ 12488' datum MD = 10841' I~, 3atum TVD - 8800 SS 20" CONDUCTOR, 21.5", A-53, ID = i 9-5/8", 40 #/ft, L-80, BTC, ID = 8.835" SA~ NOTES: ***4-1 /2" CHROME TBG' 173' 1~4-1/2" HES X NIP, ID = 3.813" I 3483' I Minimum ID = 3.725" @ 9,273' 4-112" HES XN NIPPLE 7" CSG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" ~-) 4923' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV TC PORT DATE 4 3478 3412 37 KBG2-1R DOME BK 16 08/23/08 3 6278 5498 43 KBG2-1R SO BK 20 08/23/08 2 8130 6860 44 KBG2-1R DMY BK 0 08/20/08 1 9099 7547 42 KBG2-1R DMY BK 0 08/20/08 9,136' I-~ HES 4-1 /2" X NIP, ID = 3.813" I 9,167' 7" x 4-1 /2" BAKER S-3 PKR, ID = 3.87" 9,200' 4-1/2" HES X NIP, ID = 3.813" 9,273' 4-1/2" HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, 13CR, VAM TOP, .0152 bpf, ID = 3.958" " CSG, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 9285' 10322' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 94° @ 11475' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11475 - 11950 O 08/21/08 2-7/8" 6 12600 - 12700 O 08/21/08 276' 7" x 4-1/2" BAKER FLEX LOC LNR HGR, ID = 2.992" w / ZXP LT PKR w / 11.4' TBS, ID = 5.25" PBTD 12713' -1I2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 12800' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 08/22/08 N2ES ORIGINAL COMPLETION WELL: DS 02-40 09/01/08 JLJ/JPJC GLV C/O (08/23/08) PERMfr No: 2071620 API No: 50-029-23377-00-00 SEC 36, T11 N, R14E, 857' FNL & 1734' FWL BP Exploration (Alaska) Change in TD on 02-40 (PTD -162) Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 13, 2008 7:18 PM To: Roach, Frank Cc: Schultz, Mikel; Hobbs, Greg S (ANC) Subject: RE: Change in TD on 02-40 (PTD 207-162) Page 1 of 2 Frank, et al, Thanks for the call and update. I have spoken with Commissioner Foerster and she has given her oral approval for you to proceed with the new plan. Please have the Sundry submitted as soon as practical. Call or message with any questions. Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Wed 8/13/2008 7:01 PM To: Maunder, Thomas E (DOA) Cc: Schultr, Mikel; Hobbs, Greg S (ANC) Subject: Change in TD on 02-40 (PTD 207-162) Mr. Maunder, Per our phone conversation earlier this evening, new information gathered during our 6-118" production hole build and subsequent MAD pass through the build section has led us to changes in the original approved wellplan. Formation conditions prevented us from achieving planned build rates through Ivishak Zones 3 and 2B. As such, we crossed the HOT at a steeper angle than planned and would lose 300' of Zone 2A horizontal pay with our original TD (ASP coordinates x=683,546.15 ; y=5,945,785.79). The gas-oil contact identified in our MAD pass showed that in order to get enough standoff from the gas, the planned horizontal would be in lesser quality pay and the 300' lost would need to be recovered. The new plan is to drill our original planned horizontal length. This would extend our TD 300' laterally from the TD in the approved 10-401 Permit to Driii application (new ASP coordinates x=683,359.93 ; y=5,945,551.56). The directional plan has been run through our well survey database and there no anti-collision issues with the new plan. Referencing 20 AAC 25.015 subsection b, paragraph (2): To change a program approved in a Permit to Drill after drilling operations start and the proposed bottom-hole location is changed by less than 500 feet laterally or vertically, the operator shall: "submit and obtain the commission's approval of an Application for Sundry Approvals (Form 10-403) if the change is not covered by (1) of this subsection; the Application for Sundry Approvals must set out the approved program, the current condition of the well, and the proposed changes; in cases where prompt approval is needed, oral approval may be requested from the commission; if oral approval is obtained, the name of the representative of the commission who provided oral approval and the date of the approval must be included on the Application for Sundry Approvals, which must be submitted within three days for final approval by the commission." 8/14/2008 Change in TD on 02-40 (PTD 207-162) Page 2 of 2 i ~ We request oral approval from the commission to proceed with the new bottom-hole location. Application for Sundry Approvals (1003) will be submitted as soon as possible. Any questions or concerns, please let me know. Regards, -Frank Roach Office: 564-4373 Cell: 244-1674 8/14/2008 02-40 (PTD 207-162) Plan fo~ d ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 07, 2008 1:54 PM To: 'Roach, Frank' Cc: Hobbs, Greg S (ANC); Schultz, Mikel Subject: RE: 02-40 (PTD 207-162) Plan forward Gentlemen, This well has certainly been challenging!! It is likely that isolation will be realized due to collapse of the shales around the 7" casing as noted. From the discussion about the Put wells, with the producer (take) point closer to 02-40 than the injector, "higher" pressure should not initial be present due to the production. I don't require anything further. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Thursday, August 07, 2008 1:36 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Schultz, Mikel Subject: 02-40 (PTD 207-162) Plan forward Mr. Maunder, Per our phone conversation, 02-40 (PTD 207-162) has had another change from the original plan: Casing was run and landed on mandrel hanger without any hole stability issues. During the circulation in preparation for the cement job, it was discovered that a 20' pup joint was missing from the casing string. The plan was to pull the hanger and casing string to the floor, remove the mandrel hanger, add the 20' pup, reattach the mandrel hanger and re-land the casing. As we brought the hanger to the rig floor in order to add the 20' pup joint, the hole packed aff. We were able to establish movement in the casing string (though not free movement) and run the hanger back to the casing head, but no circulation. At this point, it was decided attempt to bring the casing string back up to the rig floor in order to remove the mandrel hanger, add the 20' pup joint plus an additional full joint of 7" casing, attempt to run the casing to TD, and set on emergency slips. While we were able to run 7" casing to TD at 10,327' MD, we were unable to reestablish circulation. The casing was landed on emergency slips and the 7" x 9-5/8" annulus was successfully freeze protected. Plan forward is to drill the 6-1/8" production hole as planned. Changes will be made to the production liner and the top of the liner will be moved to 500' TVD above the top of the Sag River formation (7406' TVD from current LWD/MWD measurements). Per our later phone conversation, the Put River formation was initially an area of concern for us since it lies above the Kingak and is a producing formation on DS-02 (one producer supported by one injector). Upon further review, the Put River formation lies above the Kingak, but below the HRZ and Seabee shales (See below lithology log for Drillsite 02). Discussions with the geologist give us confidence that these shales will provide effective isolation from shallower formations. Any questionslconcerns, please let me know. 8/7/2008 02-40 (PTD 207-162) Plan fo~ d • Thank you. Regards, -Frank Roach ... :171w - .._..:. ... .. - :V1fe~t,:... .. .. ... ... ..... ... ... ... ... West.,'~,~tC. Sand-group.. N6od:towell..•.--,:•..-....,. 6,000 : S~k : cer~ent~d, ire~~y fins to fire ~raiin "silty • 6920' :Seed: • ~saritd.ailtstor~e, and minor shales. ....:. 6357' :...... ._ K..f~ ......:........:.............:......... ....... ....... ....... ....... ... fU~a~in~ .. lJp~gF . : , - .:. .: , .:. , :. .:. , :. .:. , :Shale: - ~ ~ : .._..:. .6950' :.....~.....:... ..fanl~ilie:~.~~i~~td~).Marine.st~alesr._..~.....:.....~..... .. .... . mare sil~ceot~s t~elow ~(-5 rnarlceF. . ... . . . . . . . . . - . - - ; 7,000' .._... ; : ................ _ ; : : : ~ : .,~Q-Ma~k®r;,--~-r~n~ent~~-sr~rks................ ..: Seabee . tlniconfo~mrity..:....:. _ :. .:. .._..:. ~~.F~ds... ..:..........:..........:.....~.....:..... ...:... ...:... ...:.._ ...:... ... .. • • T400' .: .. . ,K-~ Marker:. Rrvcnir~e~tt ~R ~tker. ~ .:. . kl.~.~~tra;fa~nnity_<.. dap; af.:s.il~.~ ~s~~.. t~ul':fa~~......... .. - • Loiwer Seabee. -~O~g~ sh~lex interval. ~ ~ ~ ~ ~ ~ • . . ...._:..:..~..:..~-.: . K-~, top pf highly radioactive Corte (liFtZ)' . ' ~ 7898' TopH1;Z K-2 ext~rids :±t 1-fll~' atio?ve:ttie tS~l~ibi#c. : .. ~8,000' BD(to~. - ..FlF~~.. :. .:. .:. .:. .:. -:. .:. .:. _ -• soar • fCaf~ubik Pu1iF~i:~;, '. - -'. .~. .:. .~. _:. ._. .~. - slao' ....... :.....:.....:. ~ _:1..._.I"~~...Lower~C~etaceioois•U+~~vrtformiEy: 8168' _ - : - ~.[y. QK .Kir~g,ais-s~hale:_'Marine-shale-:with..-this siltstc~ne interbe~ls .....~. ~a .:... ~ .Sag.R:~..Glau~.oniti~.axgi~a~.*.quart~oese,....... : ~ : : r~tarine s~ands#one, thin siltsto~e bed at .. - ~~Y@f . - . - - , . . . ton, Fast; t1r]Q break ma~/~ ericaunter ti ht : $and hole prro6lems. : . : : : .. 8344' : .... ..... ..... ..... .... ... ... ... : : . : : : : : ..... .. ~tl~kxltk • ~ .. .......... ......... .......... ........., .......... ,.... ,., .. .. ......... .......... Sh~bl~k: Carbonates (limestonie, ilolvniite and si~detite), phosphates, shades, S~~tStR$, $- o~cce.s.. satndtstonQS.: See note 4el~w; Page 2 of 2 8/7/2008 02-40 Change in plan ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Grimaldi, Louis R (DOA) Sent: Monday, July 28, 2008 6:57 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Crisp, John H (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA); Scheve, Charles M (DOA) Subject: FW: 02-40 (207-162) Change in plan These guys took a little bump when they cut their casing. Did not have to weight up, kind of sounded like they charged the formation behind the casing. Spoke to Joey LeBlanc this morning and they are back on track with the program. Lou From: NSU, ADW Drlg Rig 2es [mailto:NSUADWDrIgRig2es@bp.com] Sent: Saturday, July 26, 2008 6:53 AM To: Grimaldi, Louis R (DOA) Subject: FW: 02-40 (207-162) Change in plan From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, July 25, 2008 4:28 PM To: Roach, Frank Cc: NSU, ADW Drlg Rig 2es; Hobbs, Greg S (ANC); Schultz, Mikel; Dean, lames A Subject: RE: 02-40 (207-162) Change in plan Frank, et al, Your plan is appropriate. Nothing further is needed. 1 will place a copy of this message in the well file. Good luck with the operations. Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Friday, July 25, 2008 4:25 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 2es; Hobbs, Greg S (ANC); Schultz, Mikel; Dean, James A Subject: 02-40 Change in plan Mr. Maunder, To follow up on our phone conversation, we have been experiencing well stability issues on 02-40, after setting 7" intermediate casing higher than planned. We have lost complete returns while drilling through the Shublik. Rather than attempt to fight the lost circulation to TD, the plan is to abandon the current hole section, cut and pull 7" casing below 9-5/8" surface casing shoe, redrill 8-1/2" intermediate hole section, run and cement new 7" casing, and drill 6-1/8" production hole to the original planned target. The current hole will be abandoned by setting a retainer ~50' above the 7" casing shoe. Pump 10 bbls 15.8 ppg neat "G" below retainer (two open hole volumes) and 20 bbls above the retainer as a cap. Two balanced plugs 8/7/2008 02-40 Change in plan • ~ Page 2 of 2 will be set high after the 7" has been cut and pulled from 200' below 9-5/8" casing shoe. The first upper plug will be set across the Cretaceous interval. The second balanced plug will be a 600' plug from 200' inside the 7" to 200' inside the 9-5/8" casing, covering the 200' open hole section. Please let me know if you require more information or if there are any questions/concerns. Thank you. Regards, -Frank Roach 8!7/2008 ~ ~ f; ~ ~~ s SARAH PAUN, GOVERNOR aaKa-7I~[~ OIL taisil GA5 333 W. 7th AVENUE, SUITE 100 CO1~T5IfRQA'1'IOIQ COAiMI55I011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-40 BP Exploration Alaska Inc. Permit No: 207-162 Surface Location: 4422' FSL, 3547' FEL, SEC. 36, T11N, R14E, UM Bottomhole Location: 32' FNL, 3288' FEL, SEC. 02, T110, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill 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 in ;er). DATED this day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA / ,O-O~ ~~V~~U~Q ' ~ ALAS~IL AND GAS CONSERVATION COMMI N PERMIT TO DRILL a~a~ NOV 19 2pp7 20 AAC 25.005 A~eSkz OII & Gas Cnns_ CAmm1AtlAfl 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is~~for: ^Coalbed Methane as Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 02-40 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12358 TVD 8995 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 44?~' FSL 354 / EL SE T11N R14E UM (As Planned) C 36 7. Property Designation: ADL 028311 Pool , , , . , ~,. ,~, ~ ~ To~of Prodr]'i;tive I-~orizori~~b-0~ 950' FSL, 2437' FEL, SEC. 35, T11 N, R14E, UM 7 8. Land Use Permit: 13. Approximate Spud Date: February 25, 2008 Total Depth: p/(,a ~'~-~f~-'J'~O-0 32' FNL, 3288' FEL, SEC. 02, ~j~(l, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x- y-,:~drao Zone-ASP4 10. KB Elevation Plan (Height above GL): 59 feet 15. Distance to Nearest Well Within Pool: 1,000' 16. Deviated Wells: ickoff Depth: 750 feet Maximum Hole An le: 105 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3715 Surface: 2874 18. C in Pr ram: S ificatk m To - Setti th -Bo ttom uanti of C ment c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 108' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3345' Surface Surface 3345' 3305' 532 sx Dee Crete 216 sx Class'G' 8-1/2" 7" 26# L-80 TCII 4595' Surface Surface 45 4244' See Below 8-1/2" 7" 26# L-80 BTCM 5660' 4595' 4244' 10255' 8395' 565 sx LiteCrete sx Class 'G 6-1/8" 4-1/2" 12.6# L-80 IBTM 2253' 10105' 8280' 12358' 8995' 269 sx Class 'G' 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Pr duc i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 foregoi true and correct. Contact John Rose, 564-5271 Printed Name Greg Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date It ! Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number~d~/~ j~ API Number: 50-Oo? aj°~ Op~O Permit Approval See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~~th//ane, gas ra s, or gas contained shales: Samples Req'd: ^ Yes lM No Mud Log Req'd: ^ Yes ~No HZS Measures: ~ Dir oval Survey Req'd: Yes ^ No Other: ~~ ~J (~ S~ ~~~ ~L S~ C oo~~ A ROVED BY THE COMMISSION Date ~/~ ,3~ v ,COMMISSIONER 'hc Form 10-401 Revised 12/2005 ~ //-~ ~7 V Submit In Duplicate ~~ X ~ ~8~~3 y. ~~~~ p 1 A L To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose -ODE Date: November 15, 2007 h Re: PBU DS 02-40 Permit to Drill ~,J Approval is requested for the drilling of the DS 02-40 grassroots Zone 2 Ivishak producer. For the planned drilling of this well, 20" conductor casing will be run and cemented at ~80' at the surface location as detailed in this request. From there, the basic drilling plan will include a 12-'/" surface hole to 3345' MD (SV3) where 9-5/8" surface casing will be run and fully cemented to surface. An 8-112" intermediate hole will then be drilled from the 9-5/8" casing shoe to the top of the Sag River formation 10,255' MD where a 7", 26.0# intermediate casing string will run and cemented with the proposed cement top to be 1000' below the surface casing shoe. A 6-''/s" production interval will then be drilled ~~ t ,1 n to the Zone 2 target (1200' of horizontal hole) with the final well TD at ~~~35T'MD where a 4-'/z", 1'a~ ~LTL~ 12.6#, carbon solid liner will be run and fully cemented. The planned completion for this well will ~ include a 4-'/2", 12.6#, 13 chrome tubing, 4 gas-lift mandrels, 4 tubing profiles (X & XN nipples) and an t ~~" \ S-3 permanent packer with the production packer being set above the Put River allowing future production possibilities. The 02-40 well is currently scheduled for Nabors 2ES beginning ~02/O1/08. Please refer to the additional data within this request for specific well details and do not hesitate to call if additional information is required. John Rose -ODE Office - 564-5271 Cell - 748-522 DS 02-40 Grass-roots Ivishak Well Page 1 Well Name: 02-40 Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Z2 Producer Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface As-built 688,481 5,950,365 11 N 14E 36 4422 3547 Target Start ASP 11 N 14E 32 950 2437 Coordinates: 684,401 5,946,791 -8768 Intermediate ASP 684163 5946562 11 N 14E 32 727 2681 Coordinates: -9039 BI3I.ASP 683576 5945789 10N 14E 2 5248 3288 Coordinates: -8995 AFE Number: PBD 4Pxxxx API Number: Estimated Start Date: 02/25/2008 Operatin da s: 24 Ri Nabors 2ES TMD 12,358' TVD rkb: 8995' RKB/GL 28.5/30.5 RTE 59 Well Desi n: Ivishak Z2 Producer w/4-1/2" Chrome Completion Current Status: New drill General Well Information: Estimated BHP: 3200 psi at 8800' TVDss Estimated BHT: 220 deg F at 8800' TVDss Formation Markers: DS 02-40 Grass-roots Ivishak Well Page 2 Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Farmat[on (TVDss) (feet) (Yes/No) (Psi) (ppg EMY~ NOTE All formation toffs are required from 1000' above proposed KOP to TD for sidetracks ~_...._. ~.._._. ~. ._ _ ~. ___,.. _, _._..._.. _ ........ . ......._ NOTE All formation to are re fired from surface to TD for all new wells ~... _.... ... _..._a.. _ . ~._..,. .. _,~.... G1 -421 20' no Permafrost -1950 20' na IJOCU -2149 20' no SV5 -2769 20' no S V4 -2908 20' no SVI -4063 20' no UC4 -4624 20' no UG3 -4792 20' no 8.5 ppg UGl -5313 20 no (normal pressure is expected, no pressure WS2 -5903 20' no data is available far these intervals) WS1 -6118 20' no CM3 -6334 20' no CM2 -6810 20' no CMl -7574 20' no THRZ -7892 20' no BHRZ -8075 20' no TPTR Put Riper -8201 20' yes 3684 psi 8.6 ppg TJB -8241 20' no TJA -8338 20' no TSGR -8406 20' yes TS HA -8435 20' no TSAD -8509 20' yes 42SB -8625 20' yes 3250 psi 7.2 ppg TCGL -8691 20' no BCGL -8765 20' no 23SB -8839 20' yes 22TS -8922 20' yes 21T5 -8945 20' yes 3250 psi 7.0 ppg HOT -8986 20' no Casing/Tubing Program: Hole Size Csg/ Tbg O.D. WtIFt Grade Connection Length (ft) Top MDITVD RTE ft Btm MD/TVD RTE ft 42" 20" insulated 215.5 A-53 WLD 108 GL 108/108 12-'/" 9-5/8" 40 L-80 BTC 3345 GL 3345/3305 8-1/2" 7" 26 L-80 TC-II 4595 GL 4595/4244 8-1/2" 7" 26 L-80 BTC-M 5660 4595 10,255/8395 6-%8' 4-%" 12.6 L-80 IBT-M 2253 10105/8280 12,358/8995 Tubin 4-%2" 12.6 13-Cr VT 10105 GL 10,105/8280 Directional: Directional Plan: S er Feasibili Stud P6 Ref Elev: xxxx' MD KOP: 750' MD, begin 2/100 build Close Approach Wells: All wells pass Major Risk scan. Surve Pro ram: CB-MAG-SS 800' , MWD + IFR + MS 12,538' Maximum Hole Angle: 105 degrees at TD Distance to Nearest Property Line: 24,300' Distance to Nearest Well in Pool: 1000' to 6-02 DS 02-40 Grass-roots Ivishak Well Page 3 Mud Program: 12 '/e" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-1950' ~BPRF 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1950'-3345' SV3 9.2-9.5 30-55 45 - 60 9.0 - 9.5 225-300 < 8.0 8-1/2" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3345'-9645' THRZ 8.8-9.4 12-18 18-24 9-10 <6 < 15 9645'-10,255' TSAG 10.6 12-22 18-28 9-10 HTHP < 10 < 20 6'/8" Production Hole Mud Pro erties FloPro-SF Interval Densit PV YP PH API Filtrate MBT 10,255'-12,358' Final Well TD 8.4-8.6 6-12 22-28 9.0-9.5 6-8 <4 Survpv and Laeaina Pmeram~ 12-'/." Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-112" Hole Section: MWD /LWD: DIR/GR/RES/PWD real time O en Hole: None Cased Hole: None required 6-'/8" Hole Section: Sample as required by well site Geologist MWD /LWD: DIR/GR/RES/NUE/DEN (from top Sag to TD) O en Hole: None Cased Hole: None Cement Calculations: CONFIRM ALL VOLUMES ASSOCIATED W/ALL CEMENT JOBS Casin Size Surface Casing - 9 g/8° 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface. Tail: O en hole volume + 40% excess + 80' shoe track. TOC -500' TVD above shoe Casin shoe. Fluid Sequence and Tam Port collar located at 1,000' as a contingency for cement to surface Volume: Wash None S acer 100 bbls of MudPush II wei hted to 10.0 Lead 343 bbls 531 sks 10.7 Ib/ al Dee CRETE - 3.62 cuft/sk Tail 45 bbls (217 sksl 15.8 Ib/gal Class G - 1.17 cuft/sk Temp I BHST - 80° F. BHCT ~70° F DS 02-40 Grass-roots Ivishak Well Page 4 Casing Size Intermediate Casir Basis Lead: Open hole volume + Tail: O en hole volume + ~ Fluid Sequence and None Volume: - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage )% excess from top of tail to 750' below surface shoe. /o excess + 80' shoe track. TOC 1000' above 7" shoe. Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 10.5-Ib/ al Lead 162 bbl 562 sks 12.0 LiteCRETE -1.61 cuft/sk Tail 34 bbl (166 sks) 15.8 ooa Class Gcement - 1.17 cuft/sk Casin Size Production Liner - 4-'/2", 12.6 Ib/ft, 13 Chrome, VamTop -Single Stage Basis Lead: None Tail: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner top (10,105' MD) Fluid Sequence and Wash None Volume: 20 bbls of Mudoush II Weiahted to 11 Tail 56 bbls (272 sks) 15.8 Ib/gal Class G Cement + Latex -1.17 cuft/sk Temp BHST ~ 221 ° F from SOR, BHCT 160° F estimated by Dowell Surface and Anti-Collision Issues: • With the 02-29 8~ 02-02 wells being ~35' on each side of this location, no surface shut-in's will be required to move onto this well. • Close Approach Shut-in Wells: All wells have passed the major risk scan and no wells will require sub-surface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. DS 02-40 Grass-roots Ivishak Well Page 5 ~ Well Control Surface hole will be drilled with a diverter. The intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Notes: 1. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 2. Full ram tests are required when rams are changed. Surface Section • ROPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1224 psi - SV5 (8.5 ppg EMW @ 2769' TVDss) 947 psi -Based on a full column of gas @ 0.10 psi/ft Function Test 3500 psi surface pressure test NA Intermediate Section Kick Tolerance and Intearity Testin • BOPS: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3715 psi -Top Sag River (8.5 ppg EMW @ 8406' TVDss) • Maximum surface pressure: 2874 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 3500 psi/250 psi Rams and 2500 psi/250 psi Annular • 7" Casing Test: 3500 psi surface pressure test • Integrity Test - 8-1/2" hole: LOT 20' - 50' from 9 g/8' shoe • Kick Tolerance: 74.8 bbl KT with a 10.6 ppg mud with a minimum 11.2 ppg FIT Production Section Kick Tolerance and Intearity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3097 psi - TSAD (7.0 ppg @ 8509' TVDss) • Maximum surface pressure: 2246 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 3500 psi/250 psi Rams and 2500 psi/250 psi Annular • 4'/z" Casing Test: 3500 psi surface pressure test • Integrity Test - 6-'/s" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with an 8.5 ppg mud with 8.8 ppg FIT/LOT • Planned completion fluid: Estimated 8.5 ppg Seawater / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. DS 02-40 Grass-roots Ivishak Well Page 6 DS 02-40 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: Normal pore pressures (8.5 ppg) are expected throughout surface hole drilling operations. Normal pore pressures (8.5 ppg) are also expected throughout the intermediate hole drilling operations, however, Cretaceous injection pressures up to 9.4 ppg may be encountered from the top of the UG1 to the base of the West Sak formation. For the production interval of the well, the Ivishak reservoir is expected to be pressured to 7.0 ppg EMW. II. Hydrates and Shallow gas: No gas hydrates or shallow gas is anticipated, however, follow good drilling practices in the regards at all times. III. Lost Circulation /Breathing: Lost circulation on the surface hole cement jobs has been a problem on this pad. Well breathing problems are a possibility in the intermediate hole after weighting-up the mud to 10.6 ppg for the HRZ. Lost circulation in the reservoir section is considered low. Follow the RP guidelines for dealing with Lost Circulation problems when/if they occur. IV. Kick Tolerance /Integrity Testing: Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test - 8-1/2" hole: LOT 20' - 50' from 9 b/a" shoe • Kick Tolerance: 74.8 bbl KT with a 10.6 ppg mud with a minimum 11.2 ppg FIT (NOTE: Will run a full LOT at this time. Need a 12.2 ppg FIT to satisfy ECD management requirements.) Production Section Kick Tolerance and Integrity Testing • Integrity Test - 6-%8" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with an 8.5 ppg mud with 8.8 ppg FIT/LOT (NOTE: Need a 10.8 ppg FIT/LOT to satisfy ECD management requirements.) V. Stuck Pipe There will be some differential sticking tendencies across upper sands in the intermediate hole with the planned 10.6 ppg mud weight in the hole. Keep the pipe moving and follow good "practices" while drilling and running the 7" casing in this interval of the well. VI. Hydrogen Sulfide As well -2-29A did record an H2S reading of 100 ppm on 10/23/92 (see below), DS2 is considered an H2S pad, therefore, the Standard Operating Procedures for H2S precautions should be followed at all times. Please review this document to confirm compliance. #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.) 02-02A 7 m 05/07/99 02-29C 3 m 11/12/94 02-06B 8 m 01/09/96 02-24A 5 m 11/21/92 02-29A 100 m 10/23/92 VII. Faults The directional plan for this well does not intersect any mapped faults. CONSULT THE DS-02 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION DS 02-40 Grass-roots Ivishak Well Page 7 DS 02-40 Drill and Complete Procedure Summary Pre-Rig Operations: 1. Install 20" conductor casing. 2. Weld an FMC landing ring on the conductor. 3. If necessary, level the pad and prepare location for rig move. Ria Operations: 1. MI/RU. 2. Nipple up the diverter spool and riser. P/U sufficient length of 4" drill pipe and stand back in the derrick. 3. M/U a 12-'/" drilling assembly with Dir/GR. Spud and directionally drill surface hole to the base of the permafrost. Gyro data will be required until clean surveys can be taken. Circulate and condition hole. Short trip to the top of the heavy weight drillpipe and/or pull out of hole for a new bit if necessary. 4. RIH and drill the remainder of the surface hole to the planned surface hole TD in a shale member of the SV3 sand at 3305' MD. POOH and L/D BHA. 5. Run, and cement the 9 5/e", 40# casing back to surface. A TAM port collar may be run as a contingency if hole conditions indicate a problematic primary cement job. With plug on cement job bumped, test the 9-8/e" casing to 3500 psi for 30 minutes and record the test. (NOTE: Efforts to ensure the final TOC is within 3' of surface will be required.) 6. N/D the riser spool and N/U the FMC casing head and tubing spool. 7. N/U the BOPE and test to 3,500 psi. 8. MU 6 3/" MWD/LWD drilling assembly and RIH picking-up 4" drill pipe as required to drill the 8-1/2" hole. 9. Drill out cement, float equipment, and the shoe. Displace the well as required with new ~8.8 ppg LSND drilling fluid. Drill approximately 20' new formation and perform the planed LOT. 10. Drill ahead, according to directional proposal, to -100' above the HRZ. 11. Increase mud weight to 10.6 ppg per the Kingak polar plot. 12. Drill according to directional plan to intermediate hole TD at 10,255' MD, approximately 5' and below the top of the Sag. Circulate bottoms up as necessary for sample collection to properly identify shale/siltstone cap. 13. Condition hole as necessary to run the 7" casing and POOH. 14. R/U, run, and cement the 7", 26#, L-80 intermediate casing (TC-II & BTC-M connections). Aftrer bumping the plug on the cement job, pressure test the 7" casing to 3,500 psi for 30 minutes. Record the test. (NOTE: To eliminate space-out problems and to insure the casing shoe is into the top of the Sag, the casing will be hung on emergency slips. Also, the planned TOC will be -750' below the surface casing shoe.) 15. After allowing tail slurry to develop ~50 psi compressive strength split the stack and install the casing slips and pack-off and cut of the excess casing per FMC representative. 16. NU the BOP stack and test the "breaks" to 3500 psi. 17. Freeze-protect the 9 5/e" x 7" annulus, once the tail cement has reached 500 psi compressive strength. Confirm that the OA is open. Ensure that the mud/diesel/brine in the OA is overbalanced to formation at the 9-%e" shoe (-8.5 ppg). 18. M/U a 6-%e" MWD/LWD drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and re-test the casing to 3500 psi f/10 minutes. 19. Displace the well to 8.5 ppg Flo-Pro SF fluid. 20. Drill out shoe and 20' of new formation and perform the planned FIT. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 12,358' MD. 21. Condition the hole as required in preparation of running and cementing the 4-'/2" production liner. If necessary, spot liner running pill on bottom. POOH, L/D excess 4" drill pipe, and L/D BHA. 22. R/U and run the 4 %2", 12.6#, L-80, IBT-M liner. CBU at 7" shoe and TD as necessary. Cement the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to surface. 23. Displace the well to seawater above the liner top. POOH and inspect and LID liner running tools. 24. After cement reaches a minimum 1000 psi compressive strength, R/U and pressure test the casing x liner string to 3,500psi for 30 minutes and record the test. 25. R/U and perforate well on drillpipe. 26. R/U and run a 4-%2", 12.6#, 13Cr-80, Vam Top completion w/ GLM's. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. DS 02-40 Grass-roots Ivishak Well Page 8 • 27. Reverse circulate filtered seawater and corrosion inhibitor into the tubing x casing annulus. 28. Drop ball/rod and set liner top hanger/packer. 29. Individually test the tubing and annulus to 3,500 psi for 30 minutes and record each test. 30. Shear DCR valve. 31. Install TWC and test. 32. N/D the BOPE. 33. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi with diesel. 34. RU DSM. Pull TWC. 35. R/U circulating lines and test. Freeze-protect the tubing and annulus to --2,000' TVD and allow the diesel to U-tube to equilibrium. 36. Install a BPV and VR plugs in the annulus valves. 37. Secure, 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. Install gas lift valves. 3. Install the well house, instrumentation, and flow line. DS 02-40 Grass-roots Ivishak Well Page 9 K& ELEV = 59 BF. ELEV = 30.5 KOP = 750' Max Angle = 105 DEG (d3 TD' Datum MD = Datum ND = 8800 Proposed Completion PtC oeedlDC ~ HANGER & '-80' 20", 215.5, A-53, Insulated Conductor ^2200' WES 4-112 `X' Landing I~i~~;ie: !?s = 5.813" 3,345' 9-5l8", 40 #lft, L-80, BTC, ID = 8.835" GAS LIFT MANDRELS (4-1/2" x 1" KBMG) Minimum ID = 3.725" @ 10,080' 4-112" HES XN NIPPLE 4-1/2", 12.6#/ft, 13 Chrome, 10,10; VamTop, ID = 3.958" P~iFORATIONSLMIA4RY loo) R~ LOG: CAMCO GR/SSL ON 07/12/91 ANGLEATTOP PERF: 45 @ 11250' Note: Refer to ProduStion DB for historiSal pert dali ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DCK-2 S/0 3 DMY OMY 2 DMY DMY 1 DMY DMY ,540' HES 4-1/2" X NIPPLE; I.D. 3.813" ,550' BAKER PKR 7" X 4-1/2" S-3, ID = 3.88", 12' TBS 1,060' HES 4-1/2" X NIPPLE; ID = 3.813" 1,080' HES 4-1/2" XN NIPPLE; ID = 3.725" 1,105' ~ x 4-1 /2" Baker Flex-Loc Liner Hanger (ID =2.992") w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 7", 26 #/ft, L-80, BTGM (f/10,255' to 4595' MD) & TG ),255' II (f/4595' to Surf), ID = 6.276" NOTE: Casing will be set on Slips. 1,278' 4-1/2" PBTD 1,358' 4-1/2", 12.6#, L-80, IBT-M, 10 = 3.958", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMEMS PRUDHOE BAY UNIT 11/13/07 JGR INITIAL WELL: DS 02-40 PERMfT No: API No: BP Exploration (Alaska) DS 02-40 w • 0 O N _~ ': ~ ~ ~ - ~ p ~ Y c F ~i O ~ 4 i j. ~ ; ~ i I ~ I~ ~~ ~ O s Q y 3 ~ b ~ ~ f I ! l l i I N a ti oonrn v,har°vrn c~ oorn-- i, i i I , r~ 1 I I ~ i Q '; __ 7 OOP ~Pr ONV~VM _ . r ' _ s . ~ ~ I . q c 0ooooorn o.ooo o00ooooonoo , ~ ~ . c ooom~o~o~_oa t- I ; a 3 ~ z N- N ~~ I q ~ ~ o o '~ Q r u 00000000000 00000000000 I i` 7 ~ _ o O ~ J ~ q O ~ T M i p G R _ n OO ~ ~ - ~ 1 11 ~ I 1 I _ m ~ - I-- ~"' ~ 3 OM.O .OKP P h 8onccPOh nPN I ~ 1 ~ Y ~ ~ I i q q ~ _ .S s Q YJ OOMnhPPO~~R _ ~ ' '. , ~ _ q°~, ~ - _ v V a ~ ~ ~ 0 ~Req° i I I ~ _ ~ o I n ~ _ ~ _ _ i m O ~ T N J ~ - N OOVPPNh QM m.O OONRQMmOh.nR Z oc oe ._ I I. _ ~ ~ ° O d OR ,p 00 3 ~S oonNrM, o 4 ~NNNmmPM~ I r y O u V O 3 O y~ .Z - v. ~ .o N I - I - I i I ~ i mo h M C . 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O L Cp~ oOm MMt t~pONrn70Mrn Op~vi t~r`viMT~01~ r p ONn MP ONrO?rn-V ~~ O-rnn Jrnp~ P mp - T ~ O O y U ~ ~ (- q pp p ~ ~NNNN~rn vRi ~D~rr m0~~000000000~ 'i o~ ~ y ~ MO L ~ O I k.FVFF 3 _O .J ¢ ~ 88888$8$888888888888885888 i- ~ <R°,R, °R, °q - NO q Orn ~ L q OQmrOn NM~00mrO M_?~[~Q~7 rnN~t~r1mV1-1~ m ONrONmn n O~ OTrMn PM--O~OMm~ Q ~ NmOr-~O MP~ mrn NMYV1 ~Oh nm0.0 ~ '~ ? O NNNNN z 00000 M ~ L v.1' nh mmmmmmm mmm O I>" NNNN7T?rn rn rO 6{ ° Q ~ O-N MYV1 r01~m Oro-NMYN~D r Z ~ T Z. -NM?h~OnmP----------N NNNNNN COMPANY DETAL-S REFERENCE INFORMATION SURVEY PROGRAM BP Amoco -ordinate (N; E) Reference: Well Centre: Plan 112-411, True North Depth Fm Depth To Survty/Plan Tool Plm: 02-40 Wp 6.0 (Pl m 02-00/Plan U2-011) Vertical (TVDI Reference: GL 30.5 KB 59.1X1 Calculation Method: Minimum Curvature Section (VSI Refereoce: Slot - (I1.11lIN,I1.IgE) 28.511 NlN1.IN1 Plamred: U2-40 Wp 6.U V 17 CB-MAG-SS Creased By: Sperry Drilling Date: Ill/25/2W7 Error Systao: ISCWSA eazured Depth Reference: GL 311.5 KB 59.1X1 NW.UU 12357.50 Planed: U2-411 W 6.0 V 17 MWDtIFR+MS Scao Method: Tmv Cylinder North Calculation Method: Minimum Curvature Error Surface: EIIipOCal +Cazing W ELL DETAILS Warning Method: Rules Based Name +N/-S +FJ-W Northing Eazling Latitude Longitude Slot H A L L I B U A T O N Plan 112-40 1543.24 %%1.35 5950365.00 6riR481.1q 70"l6'09.IRSN 148"2%'32.4115W N/A start Dir z~~loo' : 500' MD, 50 0'TVD Sperry Drilling Services End D ir :1000' MD, 999 T TVD --- FORMATION TOP DETAILS - -- - - - ~ ~ - ~ ~ ~ Sta rt Dir 3'!/ ' :25 00' MD, 2499.3TT D ..( 33/8" ~ 00 No. TVDPath MDPath Formation i ~ ~i S[art Du 4'! /100' : 26 .6T M D, 2665. B2TVD ----, ~- I I 1 480.00 480.00 GI -- '~ ~ __- _._~__ ... ~ 3500 ~~ 7 2208A0 2208.63 EOCU - 3 4683.00 5197.89 UG4 - ~ 4 4876.00 5460.85 UG3 - .. .. End Dv :3630.7 MD, 35 ' 3_ 75' T VD - ---. __- _ . 5 5360.00 6120.29 UGI ~ ~ ~ ~ ~ - ~ 4000 - ~ - - ~ ~ - 6 7 3978.00 6962.31 WS2 6186.00 7245.70 WSI - ~ ~ ~ ~ - - 8 6413.00 7554.99 CM3 ~ ~ ~ ~ ~ ~ - - - ~ - - - - - 9 6894.00 8210.34 CM2 - - - 4500 - - ----- 10 7513.00 9053.72 CMI _ -~. ~ - ~ r - ~- 7947.00 9645 04 THRZ ~ I ~ ~ 12 8139.00 9906.63 BHRZ - 4 - ~ ~ .± ~ ~ _ - _ - - _ _ ~~-- ~ - 13 6274.00 10090 57 TJA , ' - ~ _ . T . 500 0 . ~ 14 8395.00 10255.43 TSGR ~ - ~ _ - ~ - _ _ ~ - - - --_ _T._ .-. ~ IS 8432.00 10305.84 TSHA . - - - - - - - - - - -- .__ -_ . 16 8514.00 10417.57 TSAD _ - - --. _ .__. _. 17 8617.00 10557.90 4256 - 0 IS 8703.00 10675.06 TCGL - .. -. -. - . 55 0 - - _ - _. _.. . 19 8768.00 10763.64 BCGL - - - - - ~ ~ ~ ~ - - - -~ - ~ - - - - - - - ~ --~ ~ - - ~-- 20 6835.00 10854.92 23S6 - - - 21 8961.00 11096.42 22TS - ~ ~ 22 9017.00 11197.94 21TS . _ - i --~-~-r--- .. 6000 _ __---~- -_ _T __ _ ~_. '~ -T-t-__ . ~ -- 6500 ---- --. -- - - _2268 o' VI .-- -- - - -------._.. -_ __.- __-_-. 7000 __._, __ .. .--. _ .. - ----_ _. _. .. __-. ~__ -. ~.. 7$ 00 - _---1-- -~----- ~ - _-- ~- ~- ~ - CASING DETAILS - -:~ 02-40 Fault 1 No. TVD MD Name Size -3025 - ~ ~ - - ~ ~ - 7» ~" _ - ~ - ~ ---- - - ~ - - I 330511 3345.00 13 316" 13.375 2 6395.00 10255.43 7" 7.000 _. _ ~-_ 3 6995.00 12357.50 4lit" 4.500 __.. i - .. ~T - ____ --- ---- _`::. 850 - ~ ~ '- Start D~ 10'?1100': 10876.73'M D, 851.01'TVD TA RGET DETAILS , End Dir : 1136 09' MD 9039' TVD Name TVD +N;=S +Ei-W Northing Easting Shape p 0 , 02-40 Fault I 8809.00 -2939.69 -4441.27 5947315.00 684115.00 Pulygon - - - ~ - 2 10 TI rev I -9 02-40 T3 8995 00 -4454.46 -5046.27 5945765.79 663546.15 Point TD TEST . 8995 00 9009 76 00 5959541 77 6804 int 695056 86 P -3781 - - - - - ~ 02-40 Geo-Poly . 9034.00 . -4314.15 . . -4930.87 5945929.00 . o 663660.00 Polygon ' ~ _ - 02-40 T2 9034.00 -4230.58 -4860.95 5946014.26 683727.60 Point ~-- 95 % conL 02-40 T1 rev 1 9039.00 -3693.73 -4411.75 594656_ IS 664163.39 Point -~ ': S[art Di 5'?i 100' :12062.09' MD 34.6TTV D --~-. ~ SECTION DETAILS .' 02-40 , Sec MD Inc Azi TVD +N/-S +F/-W DLcg TFace VSa Target . 4 /2» -- 0 - D tal 2-40 Ge D th: Poly 2357 5' MD 8995' TVD - ~ 1 2%.50 U.(Nl O.UO 28.50 0.00 0.00 0.00 0.00 0.00 -_ - o ~: 02-40 - ep T3 . , 2 SUlLl10 O.Iq O.W SW.00 O.W 0.00 O.W 0.(NI O.W PI - x 02-40 '-- -~ - ~ ~ ~ ~ ~ 3 7511.011 S.Iq 2W.UU 749.68 -10.24 -3.73 2.1111 21111.00 9.57 -4537 - - - - - - - - 4 IlNlll.lq U.Iq U.W 999.37 -20.49 -7.46 2.IX1 1%O.W 19.15 ' 5 25110. W LL W O. W 2499.37 -20.49 -7.46 0.00 O. W 19.15 02-40 p 6.0 fi 2fifi(ufi7 5.IX1 2W.W 2665.82 -27.32 -9.94 3.00 2W.110 25.53 7 3fi311.7U 42.7ri 2311.93 3572.75 -282.ri7 -2%9.09 4.W 3405 403.92 % 10X76.73 42.7N 230.93 %%SL01 -33%S.IW -4109.79 0.110 O.Iq 5321.29 -52 93 -45 37 -3781 -3025 -22 68 9 11762.09 90.75 219.92 Y039.1q -3693.73 -0411.75 111.00 -14.76 5751.95 IIL40 T1 rev I 111 121162.119 90.75 219.92 91134.67 -4230.5% -4860.95 0.(10 ILW 6443.9(r 11 12757.50 IU5.12 219.92 ri995.W -0454.46 -504%.27 S.W 0.00 67]2.55 West(-)i Eas t( J YcJ • Sperry-Sun BP Planning Report Company: BP Amoco Date: 10/30/2007 Time: 16:42:51 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan 02-40, True North Site: PB DS 02 Vertical (TVD) Reference: GL 30.5 KB 59.0 We{l: Plan 020 Section (VS) Reference: Well (O.OON,O:OOE,228.58Azi) Wellpath: Plan 02-40 Survey Calculation Method: Minimum Curvature Db: Orade Plan: 02-40 Wp 6.0 Date Composed: 10/9/2007 Version: 18 Principal: Yes Tied-to: From Well Ref. Point 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: bggm2007 Site: PB DS 02 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: Plan 02-40 Slot Name: Well Position: +N/-S 1543.24 ft Northing: 5950365.00 ft Latitude: 70 16 9.025 N +E/-W 881.35 ft Easting : 688481.00 ft Longitude: 148 28 32.405 W Position Uncertainty: 0.00 ft Casing Points MD_ TVD Diameter Hole Size Name ft ft in in 3345.00 3305.21 13.375 17.500 13 3/8" 10255.43 8395.00 7.000 8.500 7" 12357.50 8995.00 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Aagte Dip Directlou ft ft deg deg 480.00 480.00 G1 0.00 0.00 2009.63 2009.00 BPRF 0.00 0.00 2208.63 2208.00 EOCU 0.00 0.00 2828.46 2826.00 SV5 0.00 0.00 2973.72 2967.00 SV4 0.00 0.00 4433.54 4122.00 SV1 0.00 0.00 5197.89 4683.00 UG4 0.00 0.00 5460.85 4876.00 UG3 0.00 0.00 6120.29 5360.00 UG1 0.00 0.00 6962.31 5978.00 WS2 0.00 0.00 7245.70 6186.00 WS1 0.00 0.00 7554.99 6413.00 CM3 0.00 0.00 8210.34 6894.00 CM2 0.00 0.00 9053.72 7513.00 CM1 0.00 0.00 9645.04 7947.00 THRZ 0.00 0.00 9906.63 8139.00 BHRZ 0.00 0.00 10090.57 8274.00 TJA 0.00 0.00 10255.43 8395.00 TSGR 0.00 0.00 10305.84 8432.00 TSHA 0.00 0.00 10417.57 8514.00 TSAD 0.00 0.00 10557.90 8617.00 42Sb 0.00 0.00 10675.08 8703.00 TCGL 0.00 0.00 10763.64 8768.00 BCGL 0.00 0.00 10854.92 8835.00 23SB 0.00 0.00 11096.42 8981.00 22TS 0.00 0.00 11197.94 9017.00 21 TS 0.00 0.00 0.00 HOT 0.00 0.00 Sperry-Sun BP Planning Report Companyc BP AMOCO Date: 10/30/2007 "time: 16:42:51 Page : 2 Field: Prudhoe Bay Co-ardinate(NE) Reference: W ell: Plan 02-40, True North Site: PBDS 02 Vertical (TVD) Reference: GL 30.5 KB 59.0 Well: Plan 02-40 Section (S'S) Reference: W ell (O.OON,O.OOE,228.58Azi) Wellpath: Plan Q2-40 Survey Calculation Method: Mi nimum Curvature Db: OraGe Targets Map. Map <-- Latitude --> <- Longitude ---> Name Description TVD +N!-5 +E/-W Northing Fasting Dcg Min Sec Deg 11i n Sec Dip.. Dir. ft ft ft ft ft 02-40 Fault 1 8809.00 -2939.89 -4441.27 5947315.00 684115.00 70 15 40.098 N 148 30 41.636 W -Polygon 1 8809.00 -2939.89 -4441.27 5947315.00 684115.00 70 15 40.098 N 148 30 41.636 W -Polygon 2 8809.00 -3363.17 -4316.82 5946895.00 684250.00 70 15 35.936 N 148 30 38.008 W -Polygon 3 8809.00 -2962.26 -4546.87 5947290.00 684010.00 70 15 39.877 N 148 30 44.709 W -Polygon 4 8809.00 -3385.53 -4422.42 5946870.00 684145.00 70 15 35.715 N 148 30 41.080 W -Polygon 5 8809.00 -2962.26 -4546.87 5947290.00 684010.00 70 15 39.877 N 148 30 44.709 W -Polygon 6 8809.00 -3363.17 -4316.82 5946895.00 684250.00 70 15 35.936 N 148 30 38.008 W -Polygon 7 8809.00 -2939.89 -4441.27 5947315.00 684115.00 70 15 40.098 N 148 30 41.636 W 02-40 T3 8995.00 -4454.46 -5048.27 5945785.79 683546.15 70 15 25.198 N 148 30 59.269 W 02-40 Geo-Poly 9034.00 -4314.15 -4930.87 5945929.00 683660.00 70 15 26.579 N 148 30 55.856 W -Polygon 1 9034.00 -3868.67 -4104.40 5946395.00 684475.00 70 15 30.965 N 148 30 31.819 W -Polygon 2 9034.00 -4677.31 X769.90 5945570.00 683830.00 70 15 23.008 N 148 30 51.167 W -Polygon 3 9034.00 -4331.62 -5391.48 5945900.00 683200.00 70 15 26.404 N 148 31 9.256 W -Polygon 4 9034.00 -3429.76 -4653.62 5946820.00 683915.00 70 15 35.279 N 148 30 47.806 W 02-40 T2 9034.00 -4230.58 -4860.95 5946014.28 683727.80 70 15 27.401 N 148 30 53.824 W 02-40 T1 rev 1 9039.00 -3693.73 -4411.75 5946562.18 684163.39 70 15 32.684 N 148 30 40.765 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target. ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft -deg 28.50 0.00 0.00 28.50 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 750.00 5.00 200.00 749.68 -10.24 -3.73 2.00 2.00 0.00 200.00 1000.00 0.00 0.00 999.37 -20.49 -7.46 2.00 -2.00 64.00 180.00 2500.00 0.00 0.00 2499.37 -20.49 -7.46 0.00 0.00 0.00 0.00 2666.67 5.00 200.00 2665.82 -27.32 -9.94 3.00 3.00 0.00 200.00 3630.70 42.78 230.93 3532.75 -282.87 -289.09 4.00 3.92 3.21 34.05 10876.73 42.78 230.93 8851.01 -3385.04 -4109.79 0.00 0.00 0.00 0.00 11362.09 90.35 219.92 9039.00 -3693.73 -4411.75 10.00 9.80 -2.27 -14.76 02-40 T1 rev 1 12062.09 90.35 219.92 9034.67 -4230.58 -4860.95 0.00 0.00 0.00 0.00 12357.50 105.12 219.92 8995.00 -4454.46 - 5048.27 5.00 5.00 0.00 0.00 Survey MD Incl Azim TVD Sys 1'VD VS N/S E/W DLS MapN MapE ToollCo ft deg deg ft ft ft ft ft deg/100ft ft ft 28.50 0.00 0.00 28.50 -30.50 0.00 0.00 0.00 0.00 5950365.00 688481.00 CB-MAG- 100.00 0.00 0.00 100.00 41.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 CB-MAG- 200.00 0.00 0.00 200.00 141.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 CB-MAG- 300.00 0.00 0.00 300.00 241.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 CB-MAG- 400.00 0.00 0.00 400.00 341.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 CB-MAG- 480.00 0.00 0.00 480.00 421.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 G1 500.00 0.00 0.00 500.00 441.00 0.00 0.00 0.00 0.00 5950365.00 688481.00 Start Dir 2 . 600.00 2.00 200.00 599.98 540.98 1.53 -1.64 -0.60 2.00 5950363.35 688480.44 CB-MAG- 700.00 4.00 200.00 699.84 640.84 6.13 -6.56 -2.39 2.00 5950358.39 688478.78 CB-MAG- 750.00 5.00 200.00 749.68 690.68 9.57 -10.24 -3.73 2.00 5950354.67 688477.53 CB-MAG- 800.00 4.00 200.00 799.53 740.53 13.02 -13.93 -5.07 2.00 5950350.95 688476.28 MWD+IFR 900.00 2.00 200.00 899.39 840.39 17.61 -18.85 -6.86 2.00 5950345.99 688474.61 MWD+IFR 1000.00 0.00 0.00 999.37 940.37 19.15 -20.49 -7.46 2.00 5950344.33 688474.06 End Dir : 1 1100.00 0.00 0.00 1099.37 1040.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1200.00 0.00 0.00 1199.37 1140.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1300.00 0.00 0.00 1299.37 1240.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1400.00 0.00 0.00 1399.37 1340.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1500.00 0.00 0.00 1499.37 1440.37 19.15 -20.49. -7.46 0.00 5950344.33 688474.06 MWD+IFR Went Sperry-Sun BP Planning Report Company: BP AMOCO Date: 10/30 /2007 Time: 16:42:51 Pagc: 3 'Field; Pru dhoe Bay Co-ordinate(N E) Referenc e: We ll: Plan 02~Q Tru e North Site: PB DS 02 Vertical (TVI)) Reference: GL 30.5 KB 59.0 Well:..- Plan 020 Section (VS)'Reference: Well (O.OON,O.OOE,228.58Azi) Wellpath: Plan 02-40 Survey Calculation Method: Minimum Curvature DV: Oracle Survey MI) Inc! Azm "IVD SysTVI? VS N/S E/W DLS MapN MxpE TooUCo ft deg. deg ft ft ft ft ft deg/100ft ft ft 1600.00 0.00 0.00 1599.37 1540.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1700.00 0.00 0.00 1699.37 1640.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1800.00 0.00 0.00 1799.37 1740.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 1900.00 0.00 0.00 1899.37 1840.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2000.00 0.00 0.00 1999.37 1940.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2009.63 0.00 0.00 2009.00 1950.00 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 BPRF 2100.00 0.00 0.00 2099.37 2040.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2200.00 0.00 0.00 2199.37 2140.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2208.63 0.00 0.00 2208.00 2149.00 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 EOCU 2300.00 0.00 0.00 2299.37 2240.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2400.00 0.00 0.00 2399.37 2340.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 MWD+IFR 2500.00 0.00 0.00 2499.37 2440.37 19.15 -20.49 -7.46 0.00 5950344.33 688474.06 Start Dir 3. 2600.00 3.00 200.00 2599.32 2540.32 21.45 -22.95 -8.35 3.00 5950341.85 688473.23 MWD+IFR 2666.67 5.00 200.00 2665.82 2606.82 25.53 -27.32 -9.94 3.00 5950337.44 688471.75 Start Dir 4. 2700.00 6.15 206.99 2699.00 2640.00 28.47 -30.27 -11.25 4.00 5950334.46 688470.51 MWD+IFR 2800.00 9.88 217.66 2798.01 2739.01 41.88 -41.84 -18.92 4.00 5950322.70 688463.13 MWD+IFR 2828.46 10.98 219.36 2826.00 2767.00 46.95 -45.87 -22.14 4.00 5950318.59 688460.02 SV5 2900.00 13.76 222.44 2895.87 2836.87 62.13 -57.42 -32.20 4.00 5950306.80 688450.25 MWD+IFR 2973.72 16.66 224.55 2967.00 2908.00 81.40 -71.42 -45.53 4.00 5950292.47 688437.27 SV4 3000.00 17.69 225.14 2992.11 2933.11 89.14 -76.92 -51.01 4.00 5950286.83 688431.94 MWD+IFR 3100.00 21.65 226.88 3086.25 3027.25 122.76 -100.26 -75.25 4.00 5950262.89 688408.28 MWD+IFR 3200.00 25.62 228.10 3177.85 3118.85 162.84 -127.32 -104.83 4.00 5950235.10 688379.40 MWD+IFR 3300.00 29.60 229.02 3266.44 3207.44 209.18 -157.97 -139.58 4.00 5950203.60 688345.43 MWD+IFR 3345.00 31.39 229.36 3305.21 3246.21 232.01 -172.89 -156.86 4.00 5950188.25 688328.52 13 3/8" 3400.00 33.58 229.73 3351.60 3292.60 261.55 -192.05 -179.34 4.00 5950168.53 688306.53 MWD+IFR 3500.00 37.57 230.31 3432.92 3373.92 319.69 -229.41 -223.92 4.00 5950130.06 688262.90 MWD+IFR 3600.00 41.56 230.79 3510.00 3451.00 383.33 -269.87 -273.10 4.00 5950088.40 688214.76 MWD+IFR 3630.70 42.78 230.93 3532.75 3473.75 403.92 -282.87 -289.09 4.00 5950074.99 688199.10 End Dir 3700.00 42.78 230.93 3583.62 3524.62 450.95 -312.54 -325.63 0.00 5950044.42 688163.32 MWD+IFR 3800.00 42.78 230.93 3657.01 3598.01 518.82 -355.36 -378.36 0.00 5950000.30 688111.68 MWD+IFR 3900.00 42.78 230.93 3730.41 3671.41 586.68 -398.17 -431.08 0.00 5949956.19 688060.05 MWD+IFR 4000.00 42.78 230.93 3803.80 3744.80 654.54 -440.98 -483.81 0.00 5949912.07 688008.41 MWD+IFR 4100.00 42.78 230.93 3877.20 3818.20 722.40 -483.79 -536.54 0.00 5949867.95 687956.77 MWD+IFR 4200.00 42.78 230.93 3950.59 3891.59 790.27 -526.60 -589.27 0.00 5949823.84 687905.14 MWD+IFR 4300.00 42.78 230.93 4023.99 3964.99 858.13 -569.41 -642.00 0.00 5949779.72 687853.50 MWD+IFR 4400.00 42.78 230.93 4097.39 4038.39 925.99 -612.23 -694.72 0.00 5949735.61 687801.86 MWD+IFR 4433.54 42.78 230.93 4122.00 4063.00 948.75 -626.58 -712.41 0.00 5949720.81 687784.55 SV1 4500.00 42.78 230.93 4170.78 4111.78 993.86 -655.04 -747.45 0.00 5949691.49 687750.23 MWD+IFR 4600.00 42.78 230.93 4244.18 4185.18 1061.72 -697.85 -800.18 0.00 5949647.37 687698.59 MWD+IFR 4700.00 42.78 230.93 4317.57 4258.57 1129.58 -740.66 -852.91 0.00 5949603.26 687646.95 MWD+IFR 4800.00 42.78 230.93 4390.97 4331.97 1197.44 -783.47 -905.64 0.00 5949559.14 687595.32 MWD+IFR 4900.00 42.78 230.93 4464.36 4405.36 1265.31 -826.29 -958.37 0.00 5949515.03 687543.68 MWD+IFR 5000.00 42.78 230.93 4537.76 4478.76 1333.17 -869.10 -1011.09 0.00 5949470.91 687492.05 MWD+IFR 5100.00 42.78 230.93 4611.15 4552.15 1401.03 -911.91 -1063.82 0.00 5949426.79 687440.41 MWD+IFR 5197.89 42.78 230.93 4683.00 4624.00 1467.46 -953.82 -1115.44 0.00 5949383.61 687389.86 UG4 5200.00 42.78 230.93 4684.55 4625.55 1468.90 -954.72 -1116.55 0.00 5949382.68 687388.77 MWD+IFR 5300.00 42.78 230.93 4757.94 4698.94 1536.76 -997.53 -1169.28 0.00 5949338.56 687337.14 MWD+IFR 5400.00 42.78 230.93 4831.34 4772.34 1604.62 -1040.35 -1222.01 0.00 5949294.44 687285.50 MWD+IFR 5460.85 42.78 230.93 4876.00 4817.00 1645.92 -1066.40 -1254.09 0.00 5949267.60 687254.08 UG3 5500.00 42.78 230.93 4904.73 4845.73 1672.48 -1083.16 -1274.73 0.00 5949250.33 687233.86 MWD+IFR 5600.00 42.78 230.93 4978.13 4919.13 1740.35 -1125.97 -1327.46 0.00 5949206.21 687182.23 MWD+IFR 5700.00 42.78 230.93 5051.53 4992.53 1808.21 -1168.78 -1380.19 0.00 5949162.10 687130.59 MWD+IFR Went 7S 1S 0 7S 7S 1S 1S 1S 7S i0 7S 7S 1S 7S 7S 7S 7S 7S 7S 7S 1S 7S 7S 7S 7S AS 1S 4S 7S 4S AS Sperry-Sun BP Planning Report Company: BP AmOCO Date: 10/30/2007 Time: 16:42:51 Page: 4 Fieldd Prudhoe Bay Co-ordinate(NE) Referenc e: Well: Plan 02-40, True North Site: PB DS 02 Vertical (TVD) Reference: GL 30.5 KB 59.0 Well: Plan 02-40 Section (VS) Reference: Well (O.OON,O.OOE,228.58Azi) Wellpath; Plan 02-40 S urvey Calculation Method: Min imum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS' ~iapN MapE TooUCo ft deg deg ft ft ft ft ft deg/1QOft ft ft 5800.00 42.78 230.93 5124.92 5065.92 1876.07 -1211.59 -1432.92 0.00 5949117.98 687078.95 MWD+IFR 5900.00 42.78 230.93 5198.32 5139.32 1943.94 -1254.40 -1485.65 0.00 5949073.86 687027.32 MWD+IFR 6000.00 42.78 230.93 5271.71 5212.71 2011.80 -1297.22 -1538.38 0.00 5949029.75 686975.68 MWD+IFR 6100.00 42.78 230.93 5345.11 5286.11 2079.66 -1340.03 -1591.10 0.00 5948985.63 686924.04 MWD+IFR 6120.29 42.78 230.93 5360.00 5301.00 2093.43 -1348.72 -1601.80 0.00 5948976.68 686913.57 UG1 6200.00 42.78 230.93 5418.50 5359.50 2147.52 -1382.84 -1643.83 0.00 5948941.51 686872.41 MWD+IFR 6300.00 42.78 230.93 5491.90 5432.90 2215.39 -1425.65 -1696.56 0.00 5948897.40 686820.77 MWD+IFR 6400.00 42.78 230.93 5565.29 5506.29 2283.25 -1468.46 -1749.29 0.00 5948853.28 686769.13 MWD+IFR 6500.00 42.78 230.93 5638.69 5579.69 2351.11 -1511.28 -1802.02 0.00 5948809.17 686717.50 MWD+IFR 6600.00 42.78 230.93 5712.08 5653.08 2418.98 -1554.09 -1854.74 0.00 5948765.05 686665.86 MWD+IFR 6700.00 42.78 230.93 5785.48 5726.48 2486.84 -1596.90 -1907.47 0.00 5948720.93 686614.22 MWD+IFR 6800.00 42.78 230.93 5858.87 5799.87 2554.70 -1639.71 -1960.20 0.00 5948676.82 686562.59 MWD+IFR 6900.00 42.78 230.93 5932.27 5873.27 2622.56 -1682.52 -2012.93 0.00 5948632.70 686510.95 MWD+IFR 6962.31 42.78 230.93 5978.00 5919.00 2664.85 -1709.20 -2045.78 0.00 5948605.21 686478.78 WS2 7000.00 42.78 230.93 6005.67 5946.67 2690.43 -1725.34 -2065.66 0.00 5948588.58 686459.32 MWD+IFR 7100.00 42.78 230.93 6079.06 6020.06 2758.29 -1768.15 -2118.39 0.00 5948544.47 686407.68 MWD+IFR 7200.00 42.78 230.93 6152.46 6093.46 2826.15 -1810.96 -2171.11 0.00 5948500.35 686356.04 MWD+IFR 7245.70 42.78 230.93 6186.00 6127.00 2857.17 -1830.53 -2195.21 0.00 5948480.19 686332.44 WS1 7300.00 42.78 230.93 6225.85 6166.85 2894.02 -1853.77 -2223.84 0.00 5948456.24 686304.41 MWD+IFR 7400.00 42.78 230.93 6299.25 6240.25 2961.88 -1896.58 -2276.57 0.00 5948412.12 686252.77 MWD+IFR 7500.00 42.78 230.93 6372.64 6313.64 3029.74 -1939.40 -2329.30 0.00 5948368.00 686201.13 MWD+IFR 7554.99 42.78 230.93 6413.00 6354.00 3067.06 -1962.94 -2358.29 0.00 5948343.75 686172.74 CM3 7600.00 42.78 230.93 6446.04 6387.04 3097.60 -1982.21 -2382.03 0.00 5948323.89 686149.50 MWD+IFR 7700.00 42.78 230.93 6519.43 6460.43 3165.47 -2025.02 -2434.75 0.00 5948279.77 686097.86 MWD+IFR 7800.00 42.78 230.93 6592.83 6533.83 3233.33 -2067.83 -2487.48 0.00 5948235.66 686046.22 MWD+IFR 7900.00 42.78 230.93 6666.22 6607.22 3301.19 -2110.64 -2540.21 0.00 5948191.54 685994.59 MWD+IFR 8000.00 42.78 230.93 6739.62 6680.62 3369.06 -2153.45 -2592.94 0.00 5948147.42 685942.95 MWD+IFR 8100.00 42.78 230.93 6813.01 6754.01 3436.92 -2196.27 -2645.67 0.00 5948103.31 685891.31 MWD+IFR 8200.00 42.78 230.93 6886.41 6827.41 3504.78 -2239.08 -2698.40 0.00 5948059.19 685839.68 MWD+IFR 8210.34 42.78 230.93 6894.00 6835.00 3511.80 -2243.51 -2703.85 0.00 5948054.63 685834.34 CM2 8300.00 42.78 230.93 6959.80 6900.80 3572.64 -2281.89 -2751.12 0.00 5948015.07 685788.04 MWD+IFR 8400.00 42.78 230.93 7033.20 6974.20 3640.51 -2324.70 -2803.85 0.00 5947970.96 685736.40 MWD+IFR 8500.00 42.78 230.93 7106.60 7047.60 3708.37 -2367.51 -2856.58 0.00 5947926.84 685684.77 MWD+IFR 8600.00 42.78 230.93 7179.99 7120.99 3776.23 -2410.33 -2909.31 0.00 5947882.73 685633.13 MWD+IFR 8700.00 42.78 230.93 7253.39 7194.39 3844.09 -2453.14 -2962.04 0.00 5947838.61 685581.49 MWD+IFR 8800.00 42.78 230.93 7326.78 7267.78 3911.96 -2495.95 -3014.76 0.00 5947794.49 685529.86 MWD+IFR 8900.00 42.78 230.93 7400.18 7341.18 3979.82 -2538.76 -3067.49 0.00 5947750.38 685478.22 MWD+IFR 9000.00 42.78 230.93 7473.57 7414.57 4047.68 -2581.57 -3120.22 0.00 5947706.26 685426.58 MWD+IFR 9053.72 42.78 230.93 7513.00 7454.00 4084.14 -2604.57 -3148.55 0.00 5947682.56 685398.85 CM1 9100.00 42.78 230.93 7546.97 7487.97 4115.55 -2624.39 -3172.95 0.00 5947662.14 685374.95 MWD+IFR 9200.00 42.78 230.93 7620.36 7561.36 4183.41 -2667.20 -3225.68 0.00 5947618.03 685323.31 MWD+IFR 9300.00 42.78 230.93 7693.76 7634.76 4251.27 -2710.01 -3278.41 0.00 5947573.91 685271.68 MWD+IFR 9400.00 42.78 230.93 7767.15 7708.15 4319.13 -2752.82 -3331.13 0.00 5947529.80 685220.04 MWD+IFR 9500.00 42.78 230.93 7840.55 7781.55 4387.00 -2795.63 -3383.86 0.00 5947485.68 685168.40 MWD+IFR 9600.00 42.78 230.93 7913.94 7854.94 4454.86 -2838.44 -3436.59 0.00 5947441.56 685116.77 MWD+IFR 9645.04 42.78 230.93 7947.00 7888.00 4485.42 -2857.73 -3460.34 0.00 5947421.69 685093.51 THRZ 9700.00 42.78 230.93 7987.34 7928.34 4522.72 -2881.26 -3489.32 0.00 5947397.45 685065.13 MWD+IFR 9800.00 42.78 230.93 8060.74 8001.74 4590.59 -2924.07 -3542.05 0.00 5947353.33 685013.49 MWD+IFR 9900.00 42.78 230.93 8134.13 8075.13 4658.45 -2966.88 -3594.77 0.00 5947309.21 684961.86 MWD+IFR 9906.63 42.78 230.93 8139.00 8080.00 4662.95 -2969.72 -3598.27 0.00 5947306.29 684958.43 BHRZ 10000.00 42.78 230.93 8207.53 8148.53 4726.31 -3009.69 -3647.50 0.00 5947265.10 684910.22 MWD+IFR 10090.57 42.78 230.93 8274.00 8215.00 4787.77 -3048.47 -3695.26 0.00 5947225.14 684863.45 TJA 10100.00 42.78 230.93 8280.92 8221.92 4794.17 -3052.50 -3700.23 0.00 5947220.98 684858.58 MWD+IFR ent S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S S Sperry-Sun BP Planning Report Companyt BP Amoco Date: 10!30/2007 Time: 16:42:51 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan 02-40, True North Site: PB DS 02 Vertical ('CVD) Reference: GL 30.5 KB 59.0 Well: PIa nA21t0 Section(VS)Reference: Well (O.OON,O.OOE,228.58Azi) Wettpat4: Plan 02-40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD VS N!S E!W DLS- MapN MapE TooVCo ft -de<J ; :deg ft ft ft ft ft deg/100ft ft ft 10200.00 42.78 230.93 8354.32 8295.32 4862.04 -3095.32 -3752.96 0.00 5947176.87 684806.95 MWD+IFR 10255.43 42.78 230.93 8395.00 8336.00 4899.65 -3119.05 -3782.19 0.00 5947152.41 684778.32 7" 10300.00 42.78 230.93 8427.71 8368.71 4929.90 -3138.13 -3805.69 0.00 5947132.75 684755.31 MWD+IFR 10305.84 42.78 230.93 8432.00 8373.00 4933.86 -3140.63 -3808.77 0.00 5947130.17 684752.29 TSHA 10400.00 42.78 230.93 8501.11 8442.11 4997.76 -3180.94 -3858.42 0.00 5947088.63 684703.67 MWD+IFR 10417.57 42.78 230.93 8514.00 8455.00 5009.68 -3188.46 -3867.68 0.00 5947080.88 684694.60 TSAD 10500.00 42.78 230.93 8574.50 8515.50 5065.63 -3223.75 -3911.14 0.00 5947044.52 684652.04 MWD+IFR 10557.90 42.78 230.93 8617.00 8558.00 5104.92 -3248.54 -3941.67 0.00 5947018.97 684622.14 42Sb 10600.00 42.78 230.93 8647.90 8588.90 5133.49 -3266.56 -3963.87 0.00 5947000.40 684600.40 MWD+IFR 10675.08 42.78 230.93 8703.00 8644.00 5184.44 -3298.70 -4003.46 0.00 5946967.28 684561.63 TCGL 10700.00 42.78 230.93 8721.29 8662.29 5201.35 -3309.38 -4016.60 0.00 5946956.29 684548.76 MWD+IFR 10763.64 42.78 230.93 8768.00 8709.00 5244.54 -3336.62 -4050.15 0.00 5946928.21 684515.90 BCGL 10800.00 42.78 230.93 8794.69 8735.69 5269.21 -3352.19 -4069.33 0.00 5946912.17 684497.13 MWD+IFR 10819.50 42.78 230.93 8809.00 8750.00 5282.45 -3360.54 -4079.61 0.00 5946903.57. 684487.06 02-40 Faul 10854.92 42.78 230.93 8835.00 8776.00 5306.49 -3375.70 -4098.29 0.00 5946887.94 684468.77 23SB 10876.73 42.78 230.93 8851.01 8792.01 5321.29 -3385.04 -4109.79 0.00 5946878.32 684457.51 Start Dir 1 10900.00 45.03 230.09 8867.77 8808.77 5337.41 -3395.30 -4122.24 10.00 5946867.75 684445.32 MWD+IFR 11000.00 54.77 227.11 8932.11 8873.11 5413.80 -3445.93 -4179.44 10.00 5946815.71 684389.40 MWD+IFR 11096.42 64.22 224.85 8981.00 8922.00 5496.68 -3503.64 -4239.05 10.00 5946756.52 684331.26 22TS 11100.00 64.57 224.77 8982.55 8923.55 5499.91 -3505.93 -4241.33 10.00 5946754.17 684329.04 MWD+IFR 11130.71 67.58 224.14 8995.00 8936.00 5527.90 -3525.97 -4260.98 10.00 5946733.65 684309.90 02-40 T3 11197.94 74.19 222.83 9017.00 8958.00 5591.14 -3572.04 -4304.66 10.00 5946686.51 684267.39 21 TS 11200.00 74.40 222.79 9017.56 8958.56 5593.11 -3573.50 -4306.01 10.00 5946685.02 684266.08 MWD+IFR 11300.00 84.24 221.00 9036.07 8977.07 5690.58 -3646.57 -4371.53 10.00 5946610.33 684202.41 MWD+IFR 11362.09 90.35 219.92 9039.00 8980.00 5751.95 -3693.73 -4411.75 10.00 5946562.18 684163.39 02-40 T1 r v 11400.00 90.35 219.92 9038.77 8979.77 5789.43 -3722.81 -4436.08 0.00 5946532.50 684139.79 MWD+IFR 11500.00 90.35 219.92 9038.15 8979.15 5888.29 -3799.50 -4500.25 0.00 5946454.23 684077.57 MWD+IFR 11600.00 90.35 219.92 9037.53 8978.53 5987.15 -3876.19 -4564.42 0.00 5946375.96 684015.34 MWD+IFR 11700.00 90.35 219.92 9036.91 8977.91 6086.01 -3952.89 -4628.59 0.00 5946297.69 683953.11 MWD+IFR 11800.00 90.35 219.92 9036.29 8977.29 6184.87 -4029.58 1t692.76 0.00 5946219.42 683890.89 MWD+IFR 11900.00 90.35 219.92 9035.68 8976.68 6283.73 -4106.27 -4756.93 0.00 5946141.15 683828.66 MWD+IFR 12000.00 90.35 219.92 9035.06 8976.06 6382.59 -4182.96 -4821.10 .0.00 5946062.88 683766.44 MWD+IFR 12062.09 90.35 219.92 9034.67 8975.67 6443.96 -4230.58 -4860.95 0.00 5946014.28 683727.80 Start Dir 5 . 12100.00 92.25 219.92 9033.81 8974.81 6481.43 -4259.65 -4885.27 5.00 5945984.62 683704.22 MWD+IFR 12200.00 97.25 219.92 9025.53 8966.53 6579.92 -4336.05 X949.20 5.00 5945906.64 683642.22 MWD+IFR 12300.00 102.25 219.92 9008.60 8949.60 6677.33 -4411.62 -5012.42 5.00 5945829.52 683580.91 MWD+IFR 12357.45 105.12 219.92 8995.01 8936.01 6732.50 -4454.42 -5048.24 5.00 5945785.83 683546.18 Total Dep 12357.50 105.12 219.92 8995.00 8936.00 6732.55 -4454.46 -5048.27 5.00 5945785.79 683546.15 4 1 /2" gent ~ . r • ~? „ ~a ~ ~ ~~ ~ ' a~ ~ a2 3`3 '~~ y~ ~_ <~ _~__o=< _ --«<s~~v __ ___ _________ 6 Y __-___"_ - ~. -X3338838_38 _ > __ ______ _ _ __ __ __~~T _.~T -_________ '.^, sus :; s..^___ ~ 3 83~~23d~~=' _ ..............~__._..._.__.~__..oooo_o_ooo_oo__oe~_o_o=_=._.... 00o r m _..; <$-~3 ~~ 111111 IIIIIIII^II I llllll^III^I ~ I Illillllllll li I II ^~ i 1111= ~~'~~" _ ~ v 3s^aaz ~:~~ ~ ~_ ~ o000000000o y ~ W ~ "~^~ay5x oooo~nov~o~nov,o~no ~,= ov,ovJONV,roN~nroNV, O Q. O FNV1r.-.~_.~NNI~INr+t r+t ~+'1 ~ z < o=~aZ_:(~'_^':a O I I I ~ ~ ~ ~ a3?~~i SS^~. ~.__ Eaooooo00000000 _ ~ ~ °s ~?~~'"'~^=?~ oN~nov,o~nov,ov,ov,o~n ~,: --. a U a ~~~~~~~<~~, ._ ~ N~nro~~roNV~roN -_-- ~ ~.~ Ci. ~ N N N N r~1 N'1 ~ _ ~3~~n \C~ I ~ a ~ i~~r y ~ fn-_~ ~\ a + • p 3 ~~~ `~~~' - '~ --'_~ .. ~^ i~,.~° 0 o - ~~ ° a ,,Ccr ~ 3` K ', ~ ,~ ~ ` / ~ , _ ~ " ~ ~ :, y -n ~ 11 .1J ~ ~ ~s ~ w II ~ B Nee 3~4i 1'~i' '~ . * i/~ ^ ~ ~~_-, p y ;~° o ~~ _< ~ x. ~ 3 ~~ `'' N U 00 - ~ a~ i L F :~ o °~ M N 3 O 3 ~ ~ N b~ N O ~ ~ N ~ N ~ C\ O N ~~ Halliburton Company Anticollision Report Company: BP Amoco Date: 10/30!2007 Time: 15:46:26 Page: 1 Field; Prudhoe Bay Reference Site: PB DS`02 Co-ordiaate(NE) Reference:. Well: Pla n 02-4Q Tru e North Reference WeQ;- Plan 02-40 Vertical ('fVD) References GL 30.5 KB 59.0 Reference Wellpath: Plan 02-40 Db: Oracle Summary < - -Offset Welipath --> Reference Offset Ctr-Ctr No-Go Albwable ; Site Well WeUpath MD MD Distance Area Deviation Warning .. ft ft ft ft ft PB DS 02 02-01 02-01 V2 2588.59 2600.00 167.35 51:60 115.76 Pass: Major Risk PB DS 02 02-01A 02-01A V1 493.98 500.00 210.57 17:78 192.79 Pass: Major Risk PB DS 02 02-01 B 02-016 V1 1994.56 2000.00 229.74 48.14 181.60 Pass: Major Risk PB DS 02 02-02 02-02 V2 494.98 500.00 30.49 13.48 17.01 Pass: Major Risk PB DS 02 02-02 02-02A V1 494.98 500.00 30.49 13.48 17.01 Pass: Major Risk PB DS 02 02-02 02-02APB1 V1 494.98 500.00 30.49 13.48 17.01 Pass: Major Risk PB DS 02 02-02 Plan 02-026 V4 Plan: 0 494.98 500.00 30.49 13.18 17.32 Pass: Major Risk PB DS 02 02-03 02-03 V2 2799.61 2800.00 66.31 45.28 21.03 Pass: Major Risk PB DS 02 02-03 02-03A V1 2799.61 2800.00 66.31 45.28 21.03 Pass: Major Risk PB DS 02 02-03 02-036 V8 2799.61 2800.00 66.31 45.28 21.03 Pass: Major Risk PB DS 02 02-04 02-04 V2 3012.06 3000.00 169.72 53.50 116.23 Pass: Major Risk PB DS 02 02-04A 02-04A V1 3012.06 3000.00 169.72 38.46 131.26 Pass: Major Risk PB DS 02 02-05 02-05 V4 3573.00 3600.00 254.48 48.70 205.78 Pass: Major Risk PB DS 02 02-05 OZ-05A V3 3573.00 3600.00 254.48 48.70 205.78 Pass: Major Risk PB DS 02 02-05 02-05APB1 V1 3573.00 3600.00 254.48 48.59 205.89 Pass: Major Risk PB DS 02 02-06 02-06 V3 7240.62 7300.00 217.07 133.24 83.83 Pass: Major Risk PB DS 02 02-06 02-O6A V4 7240.62 7300.00 217.07 133.24 83.83 Pass: Major Risk PB DS 02 02-06 02-O6B V2 7240.62 7300.00 217.07 133.24 83.83 Pass: Major Risk PB DS 02 02-07 02-07 V5 4695.18 4200.00 379.01 58.39 320.62 Pass: Major Risk PB DS 02 02-07 02-07A V2 4689.79 4200.00 379.01 58.22 320.79 Pass: Major Risk PB DS 02 02-07 02-07APB1 V2 4689.79 4200.00 379.01 58.22 320.79 Pass: Major Risk PB DS 02 02-07 02-07APB2 V2 4689.79 4200.00 379.01 58.22 320.79 Pass: Major Risk PB DS 02 02-08 02-08 V3 4232.94 3900.00 325.20 70.94 254.26 Pass: Major Risk PB DS 02 02-08 02-08A V2 4235.79 3900.00 325.54 70.87 254.66 Pass: Major Risk PB DS 02 02-08 02-08APB1 V1 4235.79 3900.00 325.54 70.87 254.66 Pass: Major Risk PB DS 02 02-08 02-086 V2 4232.94 3899.96 325.20 70.83 254.37 Pass: Major Risk PB DS 02 02-09 02-09 V2 3951.50 3800.00 263.42 70.57 .192.85 Pass: Major Risk PB DS 02 02-09 02-09A V4 3951.50 3800.00 263.42 70.58 192.84 Pass: Major Risk PB DS 02 02-09 02-09AP61 V5 3951.50 3800.00 263.42 70.57 192.85 Pass: Major Risk PB DS 02 02-09 02-09AP82 V5 3951.50 3800.00 263.42 70.57 192.85 Pass: Major Risk PB DS 02 02-09 02-09B V4 3951.50 3800.00 263.42 70.57 192.85 Pass: Major Risk PB DS 02 02-09 02-096P61 V3 3951.50 3800.00 263.42 70.57 192.85 Pass: Major Risk PB DS 02 02-09 Plan 02-09C V2 Plan: 0 3950.50 3800.00 263.07 70.45 192.61 Pass: Major Risk PB DS 02 02-09 Rig Surveys 02-09C VO 3950.50 3800.00 263.07 70.39 192.67 Pass: Major Risk PB DS 02 02-10 02-10 V3 4113.09 3900.00 387.07 78.09 308.97 Pass: Major Risk PB DS 02 02-10 02-10A V3 4113.09 3900.00 387.07 78.09 308.97 Pass: Major Risk PB DS 02 02-10 02-10AP81 V3 4113.09 3900.00 387.07 78.09 308.97 Pass: Major Risk PB DS 02 02-10 02-106 V2 4114.31 3900.00 387.13 78.11 309.02 Pass: Major Risk PB DS 02 02-11 02-11 V2 3968.13 3800.00 233.29 59.01 174.29 Pass: Major Risk PB DS 02 02-11A 02-11A V1 3968.13 3800.00 233.29 91.28 142.01 Pass: Major Risk PB DS 02 02-12 02-12 V2 4027.09 4000.00 287.04 100.57 186.47 Pass: Major Risk PB DS 02 02-12 02-12A V1 4027.09 4000.00 287.04 100.57 186.47 Pass: Major Risk GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Ti:feT~Tioeells in thisiit+ilbi9pal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 12357.50 ft Scan Method: Trav Cylinder North LMaximum Radius: 1432.90 ft _ Error Surface: Ellipse + Casing _ _~ Survey Program for Definitive Wellpath Date: 10/1/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name. ft ft 28.50 800.00 Planned: 02-40 Wp 6.0 V18 CB-MAG-SS Camera based mag single shot 800.00 12357.50 Planned: 02-40 Wp 6.0 V18 MWD+IFR+MS MWD +IFR + Multi Station Casing Points - --_- MD TVD Diameter HokSize Name ~ ft ff in in _ 3345.00 3305.21 13.375 17.500 13 3/8" 10255.43 8395.00 7.000 8.500 7" 12357.50 8995.00 4.500 6.125 41/2" Halliburton Company Anticollision Report Companyq BP Amoco Date: 10!30/2007 Time: 15:46:26 Page: 2 Fields Prudhoe Bay' Reference Site: PB OS 02 Co-ordinate(NE) Refe rence: Well: Pla n 02-40, Tru e North Reference Well; Plan'02-40 Vertical (TVD) Reference: GL 30.5 KB 59.0 Reference WeUpath: Plan 02-40 Db: Oracle Summary <---------- --- Offset Wellpath -----~-> Reference Offset Ctr-Ctr _- No-Go _ - Allowable -- Site Well' Well path MD MD Distance' Area Deviation Warning ft ft ft ft ft ~ PB DS 02 - 02-12 02-12ABP1 V1 4027.09 4000.00 287.04 100.57 186.47 Pass: Major Risk PB DS 02 02-12 02-12B V3 4027.09 4000.00 287.04 100.41 186.63 Pass: Major Risk PB DS 02 02-21 02-21 V4 5176.02 4400.00 924.69 110.29 814.40 Pass: Major Risk PB DS 02 02-21 02-21A V3 5176.02 4400.00 924.69. 1111.29 814.40 Pass: Major Risk ') PB DS 02 02-22 02-22 V1 5226.52 4800.00 227.00 124.43 102.56. Pass: Major Risk ~ PB DS 02 02-22 02-22A V4 5226.52 4800.00 227.00 124.43 102.56 Pass: Major Risk ~ PB DS 02 02-23 02-23 V3 5992.56 5300.00 242.52 86.12 156.41 Pass: Major Risk PB DS 02 02-23 02-23A V4 5992.56 5300.00 242.52 86.12 156.41 Pass: Major Risk PB DS 02 02-23 02-23P61 V1 5992.56 5300.00 242.52 86.12 156.41 Pass: Major Risk PB DS 02 02-24 02-24 V1 11515.50 10400.00 1030.36 744.41 285.96 Pass: MajotRisk ~i PB DS 02 02-24 02-24A V2 11461.86 10200.00 1154.32 684.00 470.32 Pass: Major Risk PB DS 02 02-25 02-25 V1 8776.41 7800.00 885.39 365.59 519.80 Pass: Major Risk ~ PB DS 02 02-29 02-29 V1 2136.63 2139.00 130.81 No Offset Errors PB DS 02 02-29A 02-29A V3 696.17 700.00 29.86 18.37 11.49 Pass: Major Risk PB DS 02 02-29A 02-296 V6 696.17 700.00 29.86 18.37 11.49 Pass: Major Risk PB DS 02 02-29A 02-29C V3 696.17 700.00 29.86 18.37 11.49 Pass: Major Risk I PB DS 02 02-29A 02-29CP61 V1 696.17 700.00 ..29.86 18.37 11.49 Pass: Major Risk PB DS 02 02-31 02-31 V9 2290.75 2300.00 243.92 39.18 204.74 Pass: Major Risk PB DS 02 02-31A 02-31A V1 2290.75 2300.00 243:92 39.18 204.74 Pass: Major Risk PB DS 02 02-31AP61 02-31APB1 V1 2290.75 2300.00 243.92 39.18 204.74 Pass: Major Risk ', PB DS 02 02-34 02-34 V3 3011.13 3000.00 261.38 40.08 221.30 Pass: Major Risk PB DS 02 02-34A 02-34A V1 3011.13 3000.00 261.38 40.08 221.30 Pass: Major Risk PB DS 02 02-34AP61 02-34AP61 V1 3011.13 3000.00 261.38 40.08 221.30 Pass: Major Risk PB DS 02 02-34AP62 02-34APB2 V1 3011.13 3000.00 261.38 40.08 221.30 Pass: Major Risk '; PB DS 02 02-35 02-35 V3 3988.81 3800.00 537.52 50.12 487.40 Pass: Major Risk ~ PB DS 02 02-35 02-35A V1 3997.27 3800.00 537.44 50.22 487.22 Pass: Major Risk PB DS 02 02-35 02-35B V5 3997.27 3800.00 537.44 50.07 487.36 Pass: Major Risk ~' PB DS 02 02-36 02-36 V4 498.58 500.00 240.99 13.82 227.16 Pass: Major Risk PB DS 02 02-36P61 02-36P61 V3 498.58 500.00 240.99 13.98 227.01 Pass: Major Risk PB DS 02 02-37 02-37 V3 497.87 500.00 180.36 13.06 167.31 Pass: Major Risk PB DS 02 02-37 02-37L1 V3 497.87 500.00 180.36 13.06 167.30 Pass: Major Risk PB DS 02 02-38 02-38 V1 497.98 500.00 122.01 13.48 108.53 Pass: Major Risk ~ PB DS 02 02-38L1 02-38Lf V1 497.98 500.00 122.03 13.48 108.55 Pass: Major Risk PB DS 02 02-39 02-39 V1 498.68 500.00 91.68 13.95 77.73 Pass: Major Risk i, PB DS 02 02-39L1 02-39L1 V1 498.68 500.00 91.68 13.95 77.73 Pass: Major Risk PB DS 02 02-39L1 P81 02-39L1 P81 V1 498.68 500.00 91.68 13.95 77.73 Pass: Major Risk j PB DS 02 02-39L1P62 02-39L1P82 V1 498.68 500.00 91.68 13.95 77.73 Pass: Major Risk PB DS 06 06-02 06-02 V1 Out of range i PB DS 06 06-16 Plan 06-16A Contingenc Out of range Site: PB DS 02 Well:. 02-01 Rule Assigned: Major Risk Wellpath: 02-01 V2 Inter-Site Error: 0.00 ft Reference Offs et Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSi)istance Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft 29.00 29.00 34.00 34.00 0.00 0.00 349 349 150.24 1.30 148.94 Pass 94.99 94:99 100.00 99.99 0.22 0.22 349 349 149.99 3.29 146.70 Pass 194.98 194.98 200.00 .199.98 0.80 0.36 349 349 149.82 6.44 143.38 Pass 294.97 294.97 300.00 299.97 1.34 0.57 349 349 150.03 9.66 140.38 Pass 394.97 394.97 400.00 399.97 1.85 0.83 349 349 150.17 13.01 137.15 Pass 494.97 494.97 500.00 499.97 2.37 1.11 349 349 150.16 16.40 133.76 Pass 590.85 590.84 600.00 599.97 2.41 1.33 350 150 151.07 18.13 132.93 Pass 686.35 686.22 700.00 699.97 2.10 1.47 350 150 154.77 18.54 136.23 Pass 784.74 784.31 800.00 799.97 1.78 1.66 352 152 161.17 19.08 142.09 Pass 889.91 889.30 900.00 899.97 1.65 1.68 353 153 166.01 19.78 146.23 Pass 995.36 994.72 1000.00 999.96 1.64 1.56 353 153 167.78 20.50 147.28 Pass 1.095.60 1094.96 1100.00 1099.96 1.64 1.72 353 353 167.69 21.93 145.76 Pass 1195.60 1194.96 1200.00 1199.96 1.65 1.71 352 352 167.89 22.92 144.97 Pass 1295.60 1294.96 1300.00 1299.96 1.67 1.46 352 352 168.29 23.21 145.07 Pass Alaska Department of Natural Resources Land Administration System Page 1 of ~ ~ i " - ~- ~ -~.,~ ' ~ ~ ~ t'.~~~ , .___~:~~er`s SearchState Cabins latur~l ~ ~!1'~S Alaska DNR Cass Summary File Type: Aug File Number 28311 ~ ~ Printable Case i=le._Summary See Township, Range, Section and Acreage? ; New Search ~'", Yes ~ No ~_.~.._.__ ~~ LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract I~'i/e: allL 28311 ``'''' Se<3rch for Status Plat Up~~~tes C7rstorner: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Cuse Tvpe: ~~~~ OTL & GAS LEASE COMP DNR Unit: 780 OIL ANDGAS File Location: DOG DIV OIL AND GAS Case SILXtLIS: 35 ISSUED States Date: 08/19/1965 Total Acres: 2560.000 Dute Initiated: 05/28/ 1965 Office of Prinza~}~ Responsibility: DOG D[V OIL AND GAS Lust Transaction Date: 12/04/2006 Case Subtype: S NORTN SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridiar~a: U Tox~nship: OION Range: 014E Section: Ol S~f~ctrnii J~~res: 640 search Plats 19rr-i~/uu~: l_ Tuuvr~Iri/~~ UION l~uir~~c~: 0111. Section: 02 SE~~~lrc~~t.Ec~r~c's.~ 640 ,ll~°ri~/iurt.~ l~ Townslrii?.~ 0I ON Rang=~~.~ 0I ~I~; S'c~~~lion: ll Sa~c~ir~~r :Iri~r~.~ 640 IIc°~~irli~m: [- TotivttshrE,.~ (110\ 1«m,;~cr.~ UI-11 S'e~~~r~~rl: I? Sectir~n:lc~r~~s.~ (~1O Legal llescription 0~-2~4-196 * ~ ~S:9LE NOTICE LEGAL DESCRIPTION*~ C'1=1-132 ION1~{EUM1, 2,11,12?~60.DOU-3-? ~~~'~ Last updated on 11/20/2007. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28311... 11 /20/2007 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~.~u ~~~~~ PTD# aO~f~v~O / Development Service Egptoratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PII,OT 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 upon issuance of a conservation order approving a spacing exception. , assumes the 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 ftom 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 weld until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro am. ~v: ~nsnoo~ • • ^^ o d G C > L i 3' ' ° ~ ._: c O ~ ~ N ~ ,~: m, O. ui: a N, o. ~, W fn ~ ~ 'O T O, 'S a' G ro O O ~ . , ~, ~ ~ ~ : O; ~ W. -°~ ~ ~ ~ N~ a` ~, ~ a' 3, ' y : ~ Q. U ro, ~ N ' ; : ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ U: to ro C' 01 i ~ ~ ~' m ~ ~ ~ N c, ro; .N ~ °. o >, w o a, O. L w O ~ ~ .Q ~ ~: a •~ v. ° o ~ o ~ rn, ~ a aoi; o; ~, n ~. ~ ~ ~ ~, ~ ~ ~ ~ ~ O' ~ ~ ~ a ~ •N: ~: ~ ~. i ~~ I z~ ~ ~ ~~ Q ~ ~ u Q; ; n ~ n: ~ x ~ , ~ ~. ' E ro O m. w .a ~, i ~ a o v' ai N. 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'o , ro: : o $• N a ~ ° L' . ro m, O. ~ o: rn ~ a' L, , ~, N' °~' ~ a .. _ Q ~, ~ a, c, c E' ~ m, ~, o M c' c. y ~' c ° ~ ~ w ~, c ~_' a~ rn °` N' t a c c D I Y U ) ~ °. ° N '~ -° ° C a~ $ m~ ~ N c ~ O~ O' Q' : o: ° rn ~ ' V' ... 'o. a, °r a~ . ~ o, a, .~, O : ~ 3. ~ °~ N N' ~k ro >; °- N N ~ QQ ~ 7 ~ ~ ~ ~~ L O. N ~~ , ~ C~ N. ~ C, >T O 7 7 O 'a ro ~~ 0~ 1 C O C ~ Y fp ~' O O' ~~ f6~ N~ C N O~ ~~ f6~ Q~ fd~ ~~ ~p~ ro M~ L~ 'O T O~ . Oi O~ Y N' f /1 C . . d Q ~' • L• ~ t6' C~ ro ' ``~ ~' ' ~: 3~ ~ E ' C ~ ro ro m i i f0. 4 ~ .3, 0~ N m ' a ro' ro, a~ ~, N. ~: N' m' - c , ~ ' N M. ' M. '°' t N O` N O ~' ~' Q `~' O C ' T m' ' ° Z o Q n; n; v. c. ' ' ~ m. , v. ~ 3 , m > ~ a>, .. a o .~ ~ '~, ~. 3 ro °: ~ o ~. ro ~ u~ ~ 'Q ~, w i ro, o. , 3; m ~ a~ L Z o , w V o O a ~ v, ro o. a v. v. c, .z ro m ; -°' °~' °~~ > a ro ~, ~ ~ v. o, ~' °' ~ m °' o ° ro c' o~ c' ~' o, ' ~' ~ o, o °' n °' ' c, Y. v a~, - o', o ~ ~; N' a~' - a~ o. E' a~ E' L ro: rn a m c, ~ o ~ ~. ai ~ °~ ' N •~ u'i a ro o ro d ~ o o E a~ v1 m' a~ ~ - v ° ~ ' a~ ai ai a ro ro - m o o rn ro' ~ o' ~; os 3: ' ~ c o, N' o ~: -a O o, m , ~ , , . m c ' o o m ; 4 !~: m' ro !~ ro ~ 3 c. N, : ro c c °y ° ° ,N m N Y ~, ~ o ~ ~ v, ~ S, c ~ N -°, •N, ._ fl. °~ -~ it d m. n. _ c: . . -: ~ v. v. ~, o. `~, ~ ro, '~ n. c' ro' m. .o. m ~ , -° : : ~; °' ~ ' L c' a~i a~i N' 'N' - >~ c. .fit . c t~ ;a' ~ o` °: ~' N ~ v' v' - - o. °~ ° n, °~~ c' >" a ro' c' ro' E' X a~' E o o a~~ m, v' o, s. c c ~>, _ ~ c 3' °' ro' o v o, m ro' ro` ~, N ro, - ~ ~ ~ . " ° o N c o, ' m' ' °' m. o c. a~, c. o, ro ~'"' w ~ ~ °~ c 3. U c`°i c`°i' a~' ° «~' m. ro: ro o ° u' ro o' E ~ ~ ~ -o. > o. o 3' ~, ~ ~ = a: , ro - ~ -`a. a;; ~ : ~, ? ~ ° _ ,~ a ~, _: ui 3 o a' .~ ro o' N ro, m ~ v, c ~ ~ ~ a ° a ro; ro o 0 3 0 , ~ , ~ . rn ar ro' o: ~, m ro .c ~' ~' ~' _' v a ~, ~, ~ ~, 3, ~ o o, ~ ~ ~, ~ ~ ~ ~, ~ v ~ ~, ~ ~ o, n ~ ~ ;°, N ~, c Y = ~ a i, a ~ ~; ~; ~' ~ ~; a O p; a; n ; v ~; z' d a' ~ ~ ' ' ' o' ~ ~' '~ m, ro, . a~, m o, p U , ' ' - : . . ; ~: v v v; ¢ -: a: - , m; m; ~; ; ; a, o <n, cn' v W a - ' O ~ N M V' ~O f0 I~ M O O ~ N M a ~O (D I~ O m 0 M M M M ~ - N M V ~ O ~ O - O ~ ~ .-- .- r ~ ~ ~ -- ~ ~ ~ N N N N N N N N N N M M M M M M U U ~ ti ° i ~ ° _ ti ° ` ~` C d +' o N I I o d ++ N y o +. N a > U C CNO ~-a ~ N I I ~ O N I ~ ON 00 f NA ~ Y r O •V ~ r ~ r _ ,J N H ', N ', ~ ~ E ~ a s ¢ ¢ ~w a~ ,Icy as Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitiing Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of il~e file under APPENDIX. No special effort has been made to chronologically organize this category of information. 02-40.tapx Sperry-Sun Driliin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 18 14:58:15 2008 Reel Header Service name .............LISTPE Date . ...................08/09/18 Ori gin ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing • Library. scientific Technical services Tape Header Service ndme .............LISTPE Date . ...................08/09/18 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 Mw-000589249 G. SAMONS B. DECKER MWD RUN 5 Mw-000589249 T. RITCHEY J. LABLANC scientific Technical services 02-40 500292337700 BP Exploration Alaska, Inc. Sperry Sun 17-SEP-08 MWD RUN 2 MWD RUN 3 Mw-000589249 Mw-000589249 G. SAMONS G. SAMONS B. DECKER B. DECKER MWD RUN 6 Mw-000589249 T. RITCHEY B. DECKER MWD RUN 8 MWD RUN 10 JOB NUMBER: MW-000589249 Mw-000589249 LOGGING ENGINEER: T. RITCHEY G. SAMONS OPERATOR WITNESS: B. DECKER B. DECKER MAD RUN 11 ~~~--«a MWD RUN 12 Page 1 MWD RUN 7 Mw-000589249 T. RITCHEY B. DECKER MWD RUN 11 Mw-000589249 G. SAMONS B. NEUFELD ~ I ~ q~~ 02-40.tapx JOB NUMBER: MW-000589249 MW-000589249 LOGGING ENGINEER: G. SAMONS G. SAMONS OPERATOR WITNESS: B. NEUFELD B. NEUFELD SURFACE LOCATION SECTION: 36 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 4423 FEL: FWL: 3546 ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 58.90 GROUND LEVEL: 30.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 20.000 108.0 2ND STRING 8.500 9.625 3484.0 3RD STRING 6.125 7.000 10355.0 PRODUCTION STRING REMARKS: C~ 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 EXITED 02-40PB1 OFF OF A CEMENT PLUG, THE KICKOFF POINT WAS AT 3517'MD, 3442' TVD. 4. MWD RUNS 1-3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND DRILLSTRING DYNAMICS (DDSr). RUN 2-3,5 ALSO INCLUDED PRESURRE WHILE DRILLING (PWD). 5. MWD RUNS 6-8,10-12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC RESISTIVITY-PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND AT-BIT INCLINATION (ABI). RUNS 6-9 ALSO INCLUDED DRILLSTRING DYNAMICS (DDS). NO DENSITY DATA PRESENTED FROM MWD RUN 10, DENSITY DATA FROM 11302 FT MD TO 11742 FT MD WAS ACQUIRED DURING A MAD PASS ON MWD RUN 11 AND MERGED WITH RUN 11 MWD DATA. NO DATA ACQUIRED ON MWD RUN 9. 6. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP) DATED 11 SEP 2008, AS AUTHORIZED BY PRIYA MARAJ (BP). Page 2 OZ-40.tapx THIS MWD LOG IS THE PDCL FOR 02-40. 7. MWD RUNS 1-3,5-8,10-12 REPRESENT WELL 02-40 WITH API# 50-029-23377-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12800 FT MD, 8995 FT 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 SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). 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 DENSITY SENSOR DEPTHS. SRAT = SMOOTHED RATE OF DATA ACQUISTION DURING MAD PASS. AN "M" PRECEDING THE MNEMONIC INDICATES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: FIXED 6.125" AVERAGE OFFSET: FIXED 0.4" MUD TYPE: WATER BASED MUD WEIGHT: 8.55 - 8.6 PPG MUD SALINITY: 3000 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLI6.000 Page 3 02-40.tapx Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 146.0 12739.5 RoP 212.5 12800.0 RPD 10300.0 12746.5 NPHI 10300.0 12711.5 RPM 10300.0 12746.5 NCNT 10300.0 12711.5 FET 10300.0 12746.5 DRHO 10300.0 12726.5 RPS 10300.0 12746.5 RHOB 10300.0 12726.5 PEF 10300.0 12726.5 RPx 10300.0 12746.5 NCNT 10300.0 12711.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 146.0 2319.0 2 2319.0 3490.0 3 3490.0 3517.0 5 3517.0 10329.0 6 10329.0 10910.0 7 10910.0 11098.0 8 11098.0 11375.0 10 11375.0 11816.5 11 11816.5 11999.0 12 11999.0 12800.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging 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 CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 Page 4 • i 02-40.tapx RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 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 HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MwD PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 146 12800 6473 25309 146 12800 FCNT MWD CP30 102.52 2139.31 614.782 4824 10300 12711.5 NCNT MWD CP30 13744.2 44005.7 27180.6 4824 10300 12711.5 RHOB MwD G/CC 1.012 3.039 2.34006 4854 10300 12726.5 DRHO MWD G/CC -1.941 0.809 0.0776908 4854 10300 12726.5 RPD MWD OHMM 0.32 2000 38.1695 4894 10300 12746.5 RPM MWD OHMM 0.5 1915.8 32.5366 4894 10300 12746.5 RPS MWD OHMM 0.58 1255.96 23.2864 4894 10300 12746.5 RPX MWD OHMM 0.69 920.45 18.5639 4894 10300 12746.5 FET MWD HR 0.4 100.74 6.58732 4894 10300 12746.5 GR MWD API 7.16 538.87 78.0276 25175 146 12739.5 PEF MwD B/E 0.79 13.76 2.2378 4854 10300 12726.5 ROP MWD FPH 0.15 1155.63 154.019 25176 212.5 12800 NPHI MWD PU 8.22 62.61 23.8545 4824 10300 12711.5 First Reading For Entire File..........146 Last Reading For Entire File...........12800 File Trailer Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 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; all MAD runs merged using earliest passes. Page 5 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NCNT RHOB DRHO GR PEF FCNT NPHI RPD RPM RPX FET RAT RPS MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: 02-40.tapx .5000 START DEPTH 10853.0 10853.0 10853.0 10853.0 10853.0 10853.0 10853.0 10855.5 10855.5 10855.5 10855.5 10855.5 10855.5 STOP DEPTH 11726.5 11742.0 11742.0 11754.5 11742.0 11726.5 11726.5 11761.5 11761.5 11761.5 11761.5 11809.5 11761.5 MAD RUN NO. MAD PASS NO. 11 1 MERGED MAD PASS. 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 MERGE TOP MERGE BASE 10853.0 11999.0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 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 HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10853 11809.5 11331.3 1914 10853 11809.5 FCNT MAD CP30 149.635 1436.7 561.211 1748 10853 11726.5 NCNT MAD CP30 15764.3 40719 27163.1 1748 10853 11726.5 RHOB MAD G/CC 1.758 3.114 2.31953 1779 10853 11742 Page 6 02-40.tapx DRHO MAD G/CC -0.068 0.677 0.0702687 1779 10853 11742 RPD MAD OHMM 3.45 105.354 13.0833 1813 10855.5 11761.5 RPM MAD OHMM 3.544 89.343 11.3998 1813 10855.5 11761.5 RPS MAD OHMM 3.764 118.658 11.6101 1813 10855.5 11761.5 RPX MAD OHMM 4.099 82.517 11.3828 1813 10855.5 11761.5 FET MAD HR 15.8359 168.649 83.454 1813 10855.5 11761.5 GR MAD API 11.544 152.798 35.7099 1804 10853 11754.5 PEF MAD B/E 1.001 5.576 1.95636 1779 10853 11742 RAT MAD FPH 0.78 2716.26 259.452 1909 10855.5 11809.5 NPHI MAD PU 13.79 49.41 25.3289 1748 10853 11726.5 First Reading For Entire File..........10853 Last Reading For Entire File...........11809 File Trailer Service name... .......STSLIB.002 service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSL2B.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 146.0 2260.0 ROP 212.5 2319.0 LOG HEADER DATA DATE LOGGED: 12-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2319.0 TOP LOG INTERVAL (FT): 212.0 BOTTOM LOG INTERVAL (FT): 2319.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 7 02-40.tapx MINIMUM ANGLE: .3 MAXIMUM ANGLE: 4.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 108.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 55.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 77.0 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 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MwD010 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 146 2319 1232.5 4347 146 2319 GR MWDO10 API 14.06 96.8 43.296 4229 146 2260 ROP MWDO10 FPH 0.85 1155.63 232.129 4214 212.5 2319 First Reading For Entire File..........146 Page 8 02-40.tapx Last Reading For Entire File...........2319 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER w 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 GR 2260.5 3430.5 $OP 2319.5 3490.0 LOG HEADER DATA DATE LOGGED: 13-7UL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3490.0 TOP LOG INTERVAL (FT): 2319.0 BOTTOM LOG INTERVAL (FT): 3490.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .9 MAXIMUM ANGLE: 35.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 108.0 BOREHOLE CONDITIONS Page 9 02-40.tapx 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 Loging 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 • Native/spud Mud 9.35 55.0 8.0 2000 11.0 99.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2260.5 3490 2875.25 2460 2260.5 3490 GR MwD020 API 20.95 115.57 69.1182 2341 2260.5 3430.5 ROP MWD020 FPH 21.01 523.55 262.429 2342 2319.5 3490 First Reading For Entire File..........2260.5 Last Reading For Entire File...........3490 File Trailer Service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Ty e ................LO Next Fl~e Name...........STSLIB.005 Page 10 • 02-40.tapx Physical EOF File Header service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 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 GR 3431.0 3517.0 ROP 3490.5 3517.0 LOG HEADER DATA DATE LOGGED: 20-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3517.0 TOP LOG INTERVAL (FT): 2490.0 BOTTOM LOG INTERVAL (FT): 3517.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 37.6 MAXIMUM ANGLE: 44.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718517 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 52.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 155.0 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL Page 11 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): • 02-40.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 GR MWD030 API 4 1 68 4 2 ROP MWD030 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3431 3517 3474 173 3431 3517 GR MWD030 API 42.06 114.84 73.2972 173 3431 3517 ROP MWD030 FPH 23.84 1144.38 481.181 54 3490.5 3517 First Reading For Entire File..........3431 Last Reading For Entire File...........3517 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 comment Record Page 12 i 1! 02-40.tapx FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3517.5 10278.0 ROP 3517.5 10329.0 LOG HEADER DATA DATE LOGGED: 03-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10329.0 TOP LOG INTERVAL (FT): 3517.0 BOTTOM LOG INTERVAL (FT): 10329.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 33.8 MAXIMUM ANGLE: 45.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 250050 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.25 MUD VISCOSITY (S): 50.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 2800 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 152.0 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Page 13 ~ r 02-40.tapx 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 MWD050 API 4 1 68 4 2 ROP MWD050 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3517.5 10329 6923.25 13624 3517.5 10329 GR MWD050 API 7.16 429.74 103.712 13509 3517.5 10278 ROP MWD050 FPH 1.35 333 137.922 13624 3517.5 10329 First Reading For Entire File..........3517.5 Last Reading For Entire File...........10329 File Trailer Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................L0 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.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10278.5 10845.0 PEF 10300.0 10832.0 FONT 10300.0 10817.0 FET 10300.0 10852.0 Page 14 ~ r 02-40.tapx NPHI 10300.0 10817.0 NCNT 10300.0 10817.0 RPM 10300.0 10852.0 RPS 10300.0 10852.0 RPX 10300.0 10852.0 RPD 10300.0 10852.0 DRHO 10300.0 10832.0 RHOB 10300.0 10832.0 RoP 10329.5 10910.0 LOG HEADER DATA DATE LOGGED: 08-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10910.0 TOP LOG INTERVAL (FT): 10329.0 BOTTOM LOG INTERVAL (FT): 10910.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.4 MAXIMUM ANGLE: 43.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10657857 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 223565 ALD Azimuthal Litho Dens 11077936 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10325.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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 F1oPro 8.45 55.0 8.8 3000 7.0 .920 86.0 .490 169.0 .800 86.0 .900 86.0 Page 15 ~ ~ 02-40.tapx 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 FONT MwD060 CP30 4 1 68 4 2 NCNT MWD060 CP30 4 1 68 8 3 RHOB MWD060 G/CC 4 1 68 12 4 DRHO MwD060 G/CC 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 oHMM 4 1 68 32 9 FET MWD060 HR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 B/E 4 1 68 44 12 RoP MWD060 FPH 4 1 68 48 13 NPHI MwD060 Pu 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10278.5 10910 10594.3 1264 10278.5 10910 FONT MWD060 CP30 102.52 2139.31 797.025 1035 10300 10817 NCNT MWD060 CP30 13744.2 44005.7 28459.9 1035 10300 10817 RHOB MWD060 G/CC 1.012 3.039 2.33007 1065 10300 10832 DRHO MWD060 G/CC -1.941 0.426 0.0289146 1065 10300 10832 RPD MwD060 OHMM 0.32 2000 112.606 1105 10300 10852 RPM MWD060 OHMM 0.5 1915.8 94.4197 1105 10300 10852 RPS MWD060 OHMM 0.58 1255.96 58.5409 1105 10300 10852 RPX MWD060 OHMM 0.69 920.45 42.1567 1105 10300 10852 FET MwD060 HR 0.78 100.74 7.22206 1105 10300 10852 GR MWD060 API 15.03 538.87 60.1471 1134 10278.5 10845 PEF MWD060 B/E 1.15 13.76 2.73406 1065 10300 10832 ROP MWD060 FPH 0.44 178.64 64.5659 1162 10329.5 10910 NPHI MWD060 Pu 8.22 62.61 20.5904 1035 10300 10817 First Reading For Entire File..........10278.5 Last Reading For Entire File...........10910 File Trailer Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Ty e ................LO Next File Name...........STSLIB.008 Physical EOF Page 16 02-40.tapx File Header Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ..........,.LO Previous File Name.......sTSLI6.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 10817.5 11005.0 FONT 10817.5 11005.0 NPHI 10817.5 11005.0 RHOB 10832.5 11020.0 PEF 10832.5 11020.0 DRHO 10832.5 11020.0 GR 10845.5 11033.0 RPX 10852.5 11040.0 FET 10852.5 11040.0 RPS 10852.5 11040.0 RPD 10852.5 11040.0 RPM 10852.5 11040.0 ROP 10910.5 11098.0 LOG HEADER DATA DATE LOGGED: 09-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11098.0 TOP LOG INTERVAL (FT): 10910.0 BOTTOM LOG INTERVAL (FT): 11098.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.3 MAXIMUM ANGLE: 60.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10657857 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 223565 ALD Azimuthal Litho Dens 11077936 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10325.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G): 8.45 Page 17 ~ r 02-40.tapx MUD VISCOSITY (S): 52.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 5200 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .600 86.0 MUD AT MAX CIRCULATING TERMPERATURE: .340 155.0 MUD FILTRATE AT MT: .480 86.0 MUD CAKE AT MT: .600 86.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta 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 FONT MWD070 CP30 4 1 68 4 2 NCNT MWD070 CP30 4 1 68 8 3 RHOS MWD070 G/CC 4 1 68 12 4 DRHO MWD070 G/CC 4 1 68 16 5 RPD MWD070 OHMM 4 1 68 20 6 RPM MWD070 OHMM 4 1 68 24 7 RPS MwD070 OHMM 4 1 68 28 8 RPX MWD070 OHMM 4 1 68 32 9 FET MWD070 HR 4 1 68 36 10 GR MWD070 API 4 1 68 40 11 PEF MWD070 B/E 4 1 68 44 12 ROP MWD070 FPH 4 1 68 48 13 NPHI MWD070 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10817.5 11098 10957.8 562 10817.5 11098 FCNT MWD070 CP30 313.36 959.75 614.831 376 10817.5 11005 NCNT MWD070 CP30 22789.9 34627.5 26684.4 376 10817.5 11005 RHOB MWD070 G/CC 2.179 2.834 2.30161 376 10832.5 11020 DRHO MWD070 G/CC -0.02 0.325 0.126973 376 10832.5 11020 RPD MWD070 OHMM 7.96 98.37 29.5002 376 10852.5 11040 RPM MWD070 OHMM 6.63 92.22 23.9255 376 10852.5 11040 RPS MWD070 OHMM 5.84 74.25 18.2971 376 10852.5 11040 RPX MWD070 OHMM 5.65 44.68 14.6658 376 10852.5 11040 FET MWD070 HR 2.06 16.2 8.86582 376 10852.5 11040 Page 18 ~ ~ 02-40.tapx GR MWD070 API 13.18 79.66 24.4768 376 10845.5 11033 PEF MWD070 B/E 1.32 4.17 1.85713 376 10832.5 11020 ROP MWD070 FPH 1.01 373.28 64.0935 376 10910.5 11098 NPHI MWD070 PU 16.34 35.32 22.3674 376 10817.5 11005 First Reading For Entire File..........10817.5 Last Reading For Entire File...........11098 File Trailer service name... .......STSLI6.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 11005.5 11287.0 FONT 11005.5 11287.0 NCNT 11005.5 11287.0 PEF 11020.5 11302.0 RHOB 11020.5 11302.0 DRHO 11020.5 11302.0 GR 11033.5 11315.0 RPS 11040.5 11322.0 RPD 11040.5 11322.0 RPx 11040.5 11322.0 RPM 11040.5 11322.0 FET 11040.5 11322.0 ROP 11098.5 11375.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Page 19 10-AUG-08 Insite 74.11 Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD 02-40.tapx 11375.0 11098.0 11375.0 63.0 90.5 BOTTOM) TOOL TYPE Dual Gamma Ray Comp Thermal Neutron EWR Phase-4 Azimuthal Litho Dens 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 Loging 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 TOOL NUMBER 10657857 231708 223565 11077936 6.125 10325.0 F1oPro 8.55 46.0 9.4 5200 6.0 .850 80.0 .420 170.0 .770 80.0 .700 80.0 Name service order units size Nsam Rep code offset DEPT FT 4 1 68 0 FCNT MWD080 CP30 4 1 68 4 NCNT MWD080 CP30 4 1 68 8 RHOB MWD080 G/CC 4 1 68 12 DRHO MWD080 G/CC 4 1 68 16 RPD MWD080 OHMM 4 1 68 20 Page 20 Channel 2 4 5 6 ~ r 02-40.tapx RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MwD080 OHMM 4 1 68 32 9 FET MWD080 HR 4 1 68 36 10 GR MwD080 API 4 1 68 40 11 PEF MWD080 B/E 4 1 68 44 12 RoP MwD080 FPH 4 1 68 48 13 NPHI MWD080 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11005.5 11375 11190.3 740 11005.5 11375 FONT MWD080 CP30 261.86 1333.37 519.065 564 11005.5 11287 NCNT MWD080 CP30 19719.5 37863.6 25764.2 564 11005.5 11287 RHOB MWD080 G/cc 1.794 3.038 2.37741 564 11020.5 11302 DRHO MWD080 G/CC -0.109 0.809 0.163887 564 11020.5 11302 RPD MWD080 OHMM 3.91 34.07 13.7632 564 11040.5 11322 RPM MWD080 OHMM 3.38 30.75 12.6437 564 11040.5 11322 RPS MWD080 OHMM 3.01 31.17 11.6268 564 11040.5 11322 RPX MWD080 OHMM 2.84 32.99 10.8563 564 11040.5 11322 FET MWD080 HR 1.05 19.92 6.0755 564 11040.5 11322 GR MWD080 API 14.27 150.31 42.0004 564 11033.5 11315 PEF MwD080 B/E 1.08 5.4 2.10245 564 11020.5 11302 ROP MWD080 FPH 0.73 391.83 92.0081 554 11098.5 11375 NPHI MWDO80 PU 13.57 37.19 25.8537 564 11005.5 11287 First Reading For Entire File..........11005 Last Reading For Entire File...........11375 File Trailer Service name... .......STSLI6.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File TyE~e ................LO Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.009 comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 Page 21 • 02-40.tapx FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPT H NCNT 11287.5 11727.5 NPHI 11287.5 11727.5 NCNT 11287.5 11727.5 GR 11315.5 11755.5 RPM 11322.5 11762.5 RPD 11322.5 11762.5 RPS 11322.5 11762.5 RPX 11322.5 11762.5 FET 11322.5 11762.5 ROP 11375.5 11816.5 LOG HEADER DATA DATE LOGGED: 12-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11816.0 TOP LOG INTERVAL (FT): 11375.0 BOTTOM LOG INTERVAL (FT): 11816.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.4 MAXIMUM ANGLE: 96.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10657857 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10325.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 49.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 4800 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .790 84.0 MUD AT MAX CIRCULATING TERMPERATURE: .390 175.0 MUD FILTRATE AT MT: .850 80.0 MUD CAKE AT MT: .800 84.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 22 • 02-40.tapx 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 MWD100 CP30 4 1 68 4 2 NCNT MWD100 CP30 4 1 68 8 3 RPD MWD100 OHMM 4 1 68 12 4 RPM MWD100 OHMM 4 1 68 16 5 RPS MWD100 OHMM 4 1 68 20 6 RPX MWD100 OHMM 4 1 68 24 7 FET MWD100 HR 4 1 68 28 8 GR MWD100 API 4 1 68 32 9 ROP MWD100 FPH 4 1 68 36 10 NPHI MWD100 Pu 4 1 68 40 11 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11287.5 11816.5 11552 1059 11287.5 11816.5 FCNT MWD100 CP30 173.18 849.23 536.31 881 11287.5 11727.5 NCNT MWD100 CP30 15207.3 34086.6 26553.4 881 11287.5 11727.5 RPD MWD100 OHMM 3.46 15.72 7.91742 881 11322.5 11762.5 RPM MWD100 OHMM 3.49 15.06 7.37936 881 11322.5 11762.5 RPS MWD100 OHMM 3.42 17.66 7.31032 881 11322.5 11762.5 RPX MWD100 OHMM 3.44 19.92 7.2307 881 11322.5 11762.5 FET MWD100 HR 0.61 71.25 10.4509 881 11322.5 11762.5 GR MWD100 API 13.35 109.81 30.2219 881 11315.5 11755.5 ROP MWD100 FPH 0.15 287.57 90.1765 883 11375.5 11816.5 NPHI MWD100 Pu 19.7 43.38 25.675 881 11287.5 11727.5 First Reading For Entire File..........11287.5 Last Reading For Entire File...........11816.5 File Trailer Service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.011 Physical EOF File Header Service name... .......STSLIB.O11 service sub Level Name... version Number...........1.0.0 Page 23 ! ~! 02-40.tapx Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO PreviOUS File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DRHO 11302.5 11926.0 RHOB 11302.5 11926.0 PEF 11302.5 11926.0 NPHI 11728.0 11911.0 NCNT 11728.0 11911.0 FONT 11728.0 11911.0 GR 11756.0 11939.0 RPD 11763.0 11946.0 RPM 11763.0 11946.0 RPS 11763.0 11946.0 RPx 11763.0 11946.0 FET 11763.0 11946.0 ROP 11817.0 11999.0 LOG HEADER DATA DATE LOGGED: 14-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11816.0 TOP LOG INTERVAL (FT): 11375.0 BOTTOM LOG INTERVAL (FT): 11816.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 151107 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 148579 ALD Azimuthal Litho Dens 11077936 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10325.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 48.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4200 FLUID LOSS (C3): 6.0 Page 24 • 02-40.tapx RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .750 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .340 183.0 MUD FILTRATE AT MT: .500 80.0 MUD CAKE AT MT: .850 80.0 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 MWD110 CP30 4 1 68 4 2 NCNT MWD110 cP30 4 1 68 8 3 RHOB MWD110 G/CC 4 1 68 12 4 DRHO MWD110 G/CC 4 1 68 16 5 RPD MwD110 OHMM 4 1 68 20 6 RPM MWD110 OHMM 4 1 68 24 7 RPS MWD110 oHMM 4 1 68 28 8 RPX MWD110 OHMM 4 1 68 32 9 FET MWD110 HR 4 1 68 36 10 GR MWD110 API 4 1 68 40 11 PEF MWD110 B/E 4 1 68 44 12 ROP MWD110 FPH 4 1 68 48 13 NPHI MwD110 Pu 4 1 68 52 14 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 11302.5 11999 11650.8 1394 11302.5 11999 FCNT MWD110 CP30 446.04 760.44 590.127 367 11728 11911 NCNT MWD110 CP30 23977.1 30521.4 27749.1 367 11728 11911 RHOS MWD110 G/CC 1.758 2.632 2.30258 1248 11302.5 11926 DRHO MwD110 G/CC -0.072 0.477 0.0709455 1248 11302.5 11926 RPD MwD110 OHMM 10.4 23.92 16.1866 367 11763 11946 RPM MWD110 OHMM 9.53 24.24 15.816 367 11763 11946 RPS MWD110 OHMM 9.23 25.41 15.0982 367 11763 11946 RPX MWD110 OHMM 8.15 21.99 13.3671 367 11763 11946 FET MWD110 HR 0.4 27.22 9.2043 367 11763 11946 GR MWD110 API 14.47 56.78 31.9064 367 11756 11939 PEF MWD110 B/E 0.79 4.399 1.94717 1248 11302.5 11926 ROP MWD110 FPH 0.99 203.03 106.875 365 11817 11999 NPHI MWD110 Pu 20.08 28.74 24.219 367 11728 11911 Page 25 • 02-40.tapx First Reading For Entire File..........11302 Last Reading For Entire File...........11999 File Trailer service name... .......STSLIB.O11 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.012 Physical EOF File Header Service name... .......STSLI6.012 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSL26.011 comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 11911.5 12711.5 FONT 11911.5 12711.5 NPHI 11911.5 12711.5 DRHO 11926.5 12726.5 RHOB 11926.5 12726.5 PEF 11926.5 12726.5 GR 11939.5 12739.5 RPD 11946.5 12746.5 RPM 11946.5 12746.5 RPS 11946.5 12746.5 RPx 11946.5 12746.5 FET 11946.5 12746.5 ROP 11999.5 12800.0 LOG HEADER DATA DATE LOGGED: 17-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12800.0 TOP LOG INTERVAL (FT): 11999.0 BOTTOM LOG INTERVAL (FT): 12800.0 BIT ROTATING SPEED (RPM): Page 26 • 02-40.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 91.0 MAXIMUM ANGLE: 97.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 151107 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 148579 ALD Azimuthal Litho Dens 11077936 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10325.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 49.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.200 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .560 180.0 MUD FILTRATE AT MT: 1.300 80.0 MUD CAKE AT MT: 1.300 80.0 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 FONT MWD120 CP30 4 1 68 4 2 NCNT MWD120 CP30 4 1 68 8 3 RHOB MWD120 G/CC 4 1 68 12 4 DRHO MWD120 G/CC 4 1 68 16 5 RPD MWD120 OHMM 4 1 68 20 6 RPM MWD120 OHMM 4 1 68 24 7 RPS MWD120 OHMM 4 1 68 28 8 RPX MWD120 OHMM 4 1 68 32 9 FET MWD120 HR 4 1 68 36 10 Page 27 -40.tapx GR MWD120 API 4 1 68 40 11 PEF MWD120 B/E 4 1 68 44 12 ROP MWD120 FPH 4 1 68 48 13 NPHI MWD120 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11911.5 12800 12355.8 1778 11911.5 12800 FCNT MWD120 CP30 343.54 1563.07 579.507 1601 11911.5 12711.5 NCNT MWD120 CP30 21794.8 41949.9 27184 1601 11911.5 12711.5 RHOB MWD120 G/cc 2.031 3.006 2.37178 1601 11926.5 12726.5 DRHO MWD120 G/CC -0.095 0.459 0.073456 1601 11926.5 12726.5 RPD MWD120 OHMM 3.11 61.5 19.1138 1601 11946.5 12746.5 RPM MWD120 OHMM 2.42 62.91 16.5321 1601 11946.5 12746.5 RPS MWD120 OHMM 2.2 46.1 14.9014 1601 11946.5 12746.5 RPX MWD120 OHMM 2.19 35.18 13.3388 1601 11946.5 12746.5 FET MWD120 HR 0.44 21.86 3.0685 1601 11946.5 12746.5 GR MWD120 API 8.48 164.46 41.4033 1601 11939.5 12739.5 PEF MWD120 B/E 0.94 7.09 2.27132 1601 11926.5 12726.5 ROP MWD120 FPH 0.93 264.89 69.2904 1602 11999.5 12800 NPHI MWD120 PU 12.9 33.91 24.5242 1601 11911.5 12711.5 First Reading For Entire File..........11911 Last Reading For Entire File...........12800 File Trailer Service name... .......STSLIB.012 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.013 Physical EOF File Header Service name... .......STSLI6.013 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......5T5L2B.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 11 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 10853.0 11726.5 Page 28 • 02-40.tapx RHOB 10853.0 11742.0 DRHO 10853.0 11742.0 PEF 10853.0 11742.0 FCNT 10853.0 11726.5 GR 10853.0 11754.5 NPHI 10853.0 11726.5 RAT 10855.5 11809.5 RPD 10855.5 11761.5 FET 10855.5 11761.5 RPM 10855.5 11761.5 RPS 10855.5 11761.5 PX 10855.5 11761.5 $ LOG HEADER DATA DATE LOGGED: 14-AUG-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11999.0 TOP LOG INTERVAL (FT): 10855.0 BOTTOM LOG INTERVAL (FT): 11810.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 151107 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 148579 ALD Azimuthal Litho Dens 11077936 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10325.0 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: Page 29 F1oPro 8.55 48.0 9.1 4200 6.0 .750 80.0 .340 183.0 .500 80.0 .850 80.0 • • 02-40.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin 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 FONT MAD111 CP30 4 1 68 4 2 NCNT MAD111 CP30 4 1 68 8 3 RHOB MAD111 G/CC 4 1 68 12 4 DRHO MAD111 G/CC 4 1 68 16 5 RPD MAD111 oHMM 4 1 68 20 6 RPM MAD111 OHMM 4 1 68 24 7 RPS MAD111 OHMM 4 1 68 28 8 RPX MAD111 OHMM 4 1 68 32 9 FET MAD111 HR 4 1 68 36 10 GR MAD111 API 4 1 68 40 11 PEF MAD111 B/E 4 1 68 44 12 RAT MAD111 FPH 4 1 68 48 13 NPHI MAD111 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10853 11809.5 11331.3 1914 10853 11809.5 FCNT MAD111 CP30 149.635 1436.7 561.211 1748 10853 11726.5 NCNT MAD111 CP30 15764.3 40719 27163.1 1748 10853 11726.5 RHOB MAD111 G/CC 1.758 3.114 2.31953 1779 10853 11742 DRHO MAD111 G/CC -0.068 0.677 0.0702687 1779 10853 11742 RPD MAD111 OHMM 3.45 105.354 13.0833 1813 10855.5 11761.5 RPM MAD111 OHMM 3.544 89.343 11.3998 1813 10855.5 11761.5 RPS MAD111 OHMM 3.764 118.658 11.6101 1813 10855.5 11761.5 RPX MAD111 OHMM 4.099 82.517 11.3828 1813 10855.5 11761.5 FET MAD111 HR 15.8359 168.649 83.454 1813 10855.5 11761.5 GR MAD111 API 11.544 152.798 35.7099 1804 10853 11754.5 PEF MAD111 B/E 1.001 5.576 1.95636 1779 10853 11742 RAT MAD111 FPH 0.78 2716.26 259.452 1909 10855.5 11809.5 NPHI MAD111 Pu 13.79 49.41 25.3289 1748 10853 11726.5 First Reading For Entire File..........10853 Last Reading For Entire File...........11809.5 File Trailer Service name... .......STSLIB.013 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.014 Page 30 02-40.tapx Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/09/18 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/09/18 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. Library. CJ scientific Technical services scientific Technical services Page 31 r ~ ~ • 02-40 PBl.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 18 12:00:12 2008 Reel Header Service name .............LISTPE Date . ...................08/09/18 0ri9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments.. .............STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/09/18 0rigin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF scientific Technical services Library. scientific Technical Services Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 02-40 PBl API NUMBER: 500292337770 OPERATOR: BP Exploration Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 12-SEP-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000589249 MW-000589249 MW-000589249 LOGGING ENGINEER: G. SAMONS G. SAMONS G. SAMONS OPERATOR WITNESS: B. DECKER B. DECKER B. DECKER MWD RUN 4 JOB NUMBER: Mw-000589249 LOGGING ENGINEER: G. SAMONS OPERATOR WITNESS: J. LABLANC SURFACE LOCATION SECTION: 36 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 4423 FEL: FWL: 3546 Page 1 ~o~---/~ ~9Cos ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 02-40 PBl.tapx .00 58.90 30.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 108.0 8.500 9.625 3484.0 6.125 7.000 10311.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND DRILLSTRING DYNAMICS (DDSr). RUN 2-3 ALSO INCLUDED PRESURRE WHILE DRILLING (PWD). 4. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC RESISTIVITY - PHASE 4 (EWR4), PRESSURE WHILE DRILLING (PWD), AT-BIT INCLINATION (ABI), AND DRILLSTRING DYNAMICS (DDS). ROP DATA FROM 10348 FT TO 10449 FT ACQUIRED WHILE DRILLING OUT OF 7~~ CASING WITHOUT MWD WERE MERGED WITH RUN 3 MWD DATA. 5. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP) DATED 11 SEP 2008, AS AUTHORIZED BY PRIYA MARAJ (BP). THIS MWD LOG IS THE PDCL FOR 02-40P61. 6. MWD RUNS 1-4 REPRESENT WELL 02-40PB1 WITH API# 50-029-23377-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10449 FT MD, 8545 FT 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 SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 ` . • 02-40 PBl.tapx ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. File Header service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPX RPS RPM 1 clipped curves; all bit runs merged. .5000 START DEPTH 146.0 212.5 10310.0 10310.0 10310.0 10310.0 10310.0 STOP DEPTH 10383.5 10449.0 10390.5 10390.5 10390.5 10390.5 10390.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 146.0 2 2319.0 3 3490.0 4 10368.0 REMARKS: MERGED MAIN PASS. MERGE BASE 2319.0 3490.0 10368.0 10449.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging 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 Page 3 • • 02-40 PBl.tapx RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 146 10449 5297.5 20607 146 10449 RPD MWD OHMM 1.62 1880.59 42.8227 162 10310 10390.5 RPM MWD OHMM 0.31 1969.78 36.2223 162 10310 10390.5 RPS MWD OHMM 1.47 1234.54 24.6296 162 10310 10390.5 RPX MWD OHMM 0.4 26.93 9.97932 162 10310 10390.5 FET MWD HR 3.55 129.51 70.7665 162 10310 10390.5 GR MWD API 5.43 407.1 87.664 20476 146 10383.5 ROP MWD FPH 0.85 1155.63 208.206 20474 212.5 10449 First Reading For Entire File..........146 Last Reading For Entire File...........10449 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ...........,LO Previous File Name......,STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 146.0 2260.0 ROP 212.5 2319.0 LOG HEADER DATA Page 4 • 02-40 PBl.tapx DATE LOGGED: 12-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2319.0 TOP LOG INTERVAL (FT): 212.0 BOTTOM LOG INTERVAL (FT): 2319.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 4.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 108.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 55.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 77.0 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 Loging 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 MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 Page 5 02-40 PBl.tapx • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 146 2319 1232.5 4347 146 2319 GR MWDO10 API 14.06 96.8 43.296 4229 146 2260 ROP MWDO10 FPH 0.85 1155.63 232.129 4214 212.5 2319 First Reading For Entire File..........146 Last Reading For Entire File...........2319 File Trailer Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 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 GR 2260.5 3430.5 ROP 2319.5 3490.0 LOG HEADER DATA DATE LOGGED: 13-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3490.0 TOP LOG INTERVAL (FT): 2319.0 BOTTOM LOG INTERVAL (FT): 3490.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .9 MAXIMUM ANGLE: 35.6 Page 6 • 02-40 PBl.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 108.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.35 MUD VISCOSITY (S): 55.0 MUD PH: $,0 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3): 11.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 99.0 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 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2260.5 3490 2875.25 2460 2260.5 3490 GR MWD020 API 20.95 115.57 69.1182 2341 2260.5 3430.5 ROP MWD020 FPH 21.01 523.55 262.429 2342 2319.5 3490 First Reading For Entire File..........2260.5 Last Reading For Entire File...........3490 Page 7 • 02-40 PBl.tapx File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3431.0 10298.5 oP 3490.5 10368.0 $ LOG HEADER DATA DATE LOGGED: 20-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10348.0 TOP LOG INTERVAL (FT): 3490.0 BOTTOM LOG INTERVAL (FT): 10348.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 37.6 MAXIMUM ANGLE: 44.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718517 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER's CASING DEPTH (FT): 3484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 52.0 Page 8 • i 02-40 PBl.tapx MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 155.0 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 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3431 10368 6899.5 13875 3431 10368 GR MWD030 API 5.43 407.1 104.318 13736 3431 10298.5 ROP MWD030 FPH 2,69 1144.38 193.828 13756 3490.5 10368 First Reading For Entire File..........3431 Last Reading For Entire File...........10368 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Page 9 • • 02-40 PBl.tapx File Header service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10299.0 10383.5 FET 10310.0 10390.5 RPD 10310.0 10390.5 RPM 10310.0 10390.5 RPS 10310.0 10390.5 RPx 10310.0 10390.5 ROP 10368.5 10449.0 LOG HEADER DATA DATE LOGGED: 25-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10449.0 TOP LOG INTERVAL (FT): 10368.0 BOTTOM LOG INTERVAL (FT): 10449.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.1 MAXIMUM ANGLE: 43.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10311.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G): 10.70 MUD VISCOSITY (S): 48.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .930 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .480 163.0 MUD FILTRATE AT MT: .570 80.0 Page 10 C~ MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 02-40 PBl.tapx 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 1.120 80.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10299 10449 10374 301 10299 10449 RPD MWD040 OHMM 1.62 1880.59 42.8227 162 10310 10390.5 RPM MWD040 OHMM 0.31 1969.78 36.2223 162 10310 10390.5 RPS MWD040 OHMM 1.47 1234.54 24.6296 162 10310 10390.5 RPX MWD040 OHMM 0.4 26.93 9.97932 162 10310 10390.5 FET MWD040 HR 3.55 129.51 70.7665 162 10310 10390.5 GR MWD040 API 54.59 294.33 101.11 170 10299 10383.5 ROP MWD040 FPH 1.15 49.51 22.8558 162 10368.5 10449 First Reading For Entire File..........10299 Last Reading For Entire File...........10449 File Trailer service name... .......STSLI6.005 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/09/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 page 11 • 02-40 PBl.tapx Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/09/18 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing • Library. scientific Technical Services Reel Trailer Service name .............LISTPE gate . ...................08/09/18 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical Services Page 12