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Home My WebLink About208-205Ima a Pro~ct Well History File Cove~age g J 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. Q Sa - ~i~ Jt-~ Well History File Identifier %n done Two-sided II I II II II II II I II III ^ Rescan Needed II I II ~I II II I I II I III Organ~z g ( ~ RE CAN DIGITAL DATA OVERSIZED (Scannable) C or Items: ^ Di kettes, No. ,~l ^ Maps: Greyscale Items:' Pa,O~~ Other, No/Type: G~ 1 to ` ^ Other Items Scannable by u a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: 3 3O © /s/ IIIIIIIIIIIIII IIIII Project Proofing gY; Maria Date: 3 3 O /s/ Scannin Preparation _~... x 30 = ~ + ~~ =TOTAL PAGES~~. g (Count does not include cover sheet) BY: Mar' Date: 3 V D `O /s/ IIIIIIIIIIIIII IIIII Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov eet) Page Count Matches Number in Scann'ng Pr paration: YES NO BY: Maria Date: 3 3 ~ r O /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO gY: Maria Date: /s/ IIIIIII his Dint unless rescanning is regwred_ II I II ~) II I II Scanning is complete at t p Scanned III IIIIII IIIII II III Re gY: Maria Date: /s/ Quality Checked IIIIIIIIIIIIIIIIIII Comments about this flle: 10/6/2005 WeII History File Cover Page.doc Page 1 of 1 • Schwartz, Guy L (DOA) From: Ciolkosz, Ryan R [Ryan.Ciolkosz @bp.com] Sent: Tuesday, June 28, 2011 9:44 AM To: Schwartz, Guy L (DOA) Subject: RE: B -10A RWO ( PTD 208 -205) Guy, the decision was made to run the second packer above the 7" liner top for a couple of reasons 1. We know that the well failed a pressure test before we moved on the well 2. The leak detect log indicated that the leak was at or below the liner top packer 3. Even though it passed a positive pressure test, if the leak path had been plugged off with gunk from the well or seal tight, then that leak path could be reopened when the IA pressure is decreased during production. 4. We do not expect a large temperature change between the produced fluids and the temperature of the brine that the tubing was landed at. So we do not expect induced hydraulics to be an issue. Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, June 27, 2011 2:21 PM To: Ciolkosz, Ryan R Subject: B -10A RWO ( PTD 208 -205) Ryan, During the rig work -over to replace tubing and fix a possible casing /liner leak nothing was found in the 9 5/8" or 7" liner lap. Understandably the scab liner was cancelled and instead a packer was set 5493' (above the 7" liner top). If there isn't a leak is there danger of temperature induced hydraulics in this area of trapped fluid ? ?? Could you update me on the decision process ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 6/28/2011 STATE OF ALASKA ALASK AND GAS CONSERVATION COMMIS REPOR SUNDRY WELL OPERA NS 1IN ` 3 11 1. Operations Performed: A{a8o wti & #�ap3 Criftg> L, i1i1111$I ion l ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended .V.VV1f},, t., f.16 ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver 0 Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory -. 208 - 205 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 .. 50 - 029 - 20321 - 01 - 00 7. Property Designation: 8. Well Name and Number: ADL 028310 & 028313 • PBU B - 10A 9. Field / Pool(s): _ Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 11190' feet Plugs (measured) 10436' feet true vertical 9162' feet Junk (measured) None feet Effective depth: measured 11104' feet Packer: (measured) 5493', 10214', 10371' feet true vertical 9081' feet Packer: (true vertical) 5157', 8234', 8383' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" x 20" 110' 110' Surface 2675' 13 - 3/8" 2675' 2675' 4930 2670 Intermediate 10011' 9 -5/8" 5737' 5343' 6870 4760 Production Liner 5067' 7" 5578' - 10645' 5222' - 8645' 7240 5410 Liner 708' 4-1/2" 10482' - 11190' 8489' - 9162' 8430 7500 Perforation Depth: Measured Depth: 10850' - 10868' True Vertical Depth: 8840' - 8857' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr85 / 13Cr80 10490' 8497' Packers and SSSV (type, measured and true vertical depth): 9 -5/8" x 4-1/2" HES 'TNT' packer; 5493' 5157' 7" x 4-1/2" HES 'TNT packer; 10214' 8234' 7" x 4-1/2" Baker S -3 Packer 10371' 8383' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 10320'. Planned to run scab liner, but unable to definitively locate the PC leak (- 5578'), therefore this well was recompleted with a straddle packer completion. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 595 14,401 1,438 Not Available Not Available Subsequent to operation: 903 6,366 2,793 860 300 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory 1 =' Development ❑ Service ❑ Stratigraphic 0 Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ - = . 011 ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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: Contact Ryan Ciolkosz, 564 -5977 311 - 050 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name /Number: Signature � � �� i Phone 564 -4628 Date °(9 / 63 /1( Terre Hubble, 564 -4628 Form 10-404 Revised 10/2010 ` BDMS JUN 21 2O11.4' '} G 7 7. �j Submit Original Only (-l- 01, 11.11 ( a • B -1 OA, Well History (Pre Rig Workover) Date Summary 5/5/2011 T /I /O =SSV /400/0, Temp =Sl. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (2500 psi), bled to 0 psi. Functioned LDS, (1) LDS left in the out position, getting very tight while running in. All the rest moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (200 psi), bled to 0 psi. Functioned LDS, (1) LDS is frozen to the GN (3:00 position). The assembly turns freely together, unable to R &R due to WHP's. All of the rest of the LDS moved freely (2.5 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 5/11/2011 WELL S/I ON ARRIVAL. Fn & PULLED 4 1/2" XXN FROM 10475' SLM, X 10478' MD. CURRENTLY RUNNING 2.50" CENT, 2.50" SAMPLE BAILER FOR SBHPS. 5/12/2011 RAN 2.50" CENT, 2.50" SAMPLE BAILER __TD Cc_ 10852_ SLM, 10855' MD 13' OF FILL. RAN SLB SBHPS AS PER PROGRAM (good data). SFT 4 1/2" HES COMP LUG (ca 10436' MD. WELL LEFT S/I ON DEPARTURE. PAD -OP NOTIFIED OF STATUS. 5/15/2011 T /I /0= 100/480/40 MIT -T Passed to 3500 psi./ MIT -IA Failed to 3500 psi.- established LLR of .34 bpm @ 3500 psi./ MIT -OA Passed to 2000 psi. (Pre Rig) Pumped 3.8 bbls crude into OA pressured up to 2000 psi lost 30 psi first 15 mins lost 10 psi second 15 mins. For a total of 40 psi in 30 minutes. MIT T pressured up to 3520 psi with 10.8 bbls crude. T lost 100 psi in first 15 minutes and 20 psi in second 15 minutes. For a total of 120 psi in 30 minutes. Bled back — 4 bbls. MIT IA pressured up to 3500 psi with 7 bbls crude. IA lost 175 psi in first 15 minuts and 150 psi in second 15 minutes. For a total of 325 psi in 30 minutes. Established LLR of .34 bpm @ 3500 psi. for 10 minutes. Bled pressure down. 5/19/2011 WELL SHUT IN UPON ARRIVAL. INITAIL T /I /O = 0/50/0 CUT 4.5" TUBING AT 10320' WITH SLB 3.65" POWER CUTTER. DIFFICULTIES FALLING DUE TO DEVIATION FROM 7000' DOWN TO 8600'. AFTER CUT TUBING PRESSURE CAME UP 75 PSI AND IA LOST 20 PSI. FINAL T /I /O = 75/380/0 PSI. JOB COMPLETE, WELL TURNED OVER TO DSO. 5/19/2011 T /I /0= 100/420/40 Pumped 20 bbls neat meth down TBG followed by 1% KCL to circ well . 5/20/2011 T /I /0= 0/0/0; Conduct PJSM; Verify Barriers; Test lubricator against SV to 3500 psi for 5 min. (passed); Set 4- 1/16" CIW "H" BPV #105 thru tree for 7ES pre -rig; 1 -1' ext. used, tagged @ 114 "; LRS tested BPV from below to 500 psi for 5 min. (passed & charted); RDMO and test tree cap to 500 psi for 5 min. (passed) No problems 5/20/2011 T /I /0= 100/420/40 ( Circ -Out / Pre -Rig ) WSR continued from 05- 19 -11. Continue pump 810 bbls 1% KCL down TBG taking returns up IA to B -35 FL. Shut Down / Freeze protect surface lines with 4 bbls diesel. U- AA m /�,,� Tube TBG x IA for 1 hr. Standby for hardline crew to rig down hardline. Standby for two way check valve I to be set. Test BPV to 500 psi for 5 min ** *PASSED * ** Bled back pressures to 0 psi BPV crew on well upon departure, Pad Op notified FWHP 0/0/0 5/20/2011 T /I /0= SSV /1200/0= Temp =SI PPPOT-T (PASS) PPPPOT -IC (PASS) (W /H Repair) PPPOT -T : RU 1 HP BT onto THA test void 0 psi, monitored void for 10 min. Removed LDS "Standard" © 3:00 position was in the out position, attempted to redress threads, unsuccessful. Installed blanking plug, Service tech can tap threads when tubing hanger and spool are removed. Tested to 5000 psi for 30 min (PASS). PPPOT -IC : RU 1 HP BT onto IC test void 300 psi bled to 0 psi, monitored for 10 minutes. Removed LDS "Standard" @ 3:00 position, redressed threads and installed new equipment. Tested to 3500 psi for 30 min (PASS). Page 1 of 1 • North America - ALASKA - BP Page 1 of 14 Operation Summary Report Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 ! End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:OOAM I Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date i From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 5/22/2011 00:00 - 02:00 2.00 RIGD P PRE RIG DOWN. LAY OVER DERRICK. - MOVE PITS AND STAGE ON PAD. - MOVE CUTTINGS BOX. 02:00 - 05:30 3.50 RIGD P PRE MOVE SUB OFF OF WELL. - MOVE MATS AROUND TO OTHER SIDE OF SUB. - STAGE MATS OVER SOFT SPOTS. I - INSTALL JEEP ON PITS, MOVE SUB TO !ACCESS ROAD. 05:30 - 08:30 3.00 MOB P PRE I PJSM W/ SECURITY. MOVE SUB BASE FROM F PAD TO B PAD. STAGE OUT OF THE WAY. 1 08:30 - 12:00 3.50 MOB P i PRE LAY MATS ON PAD AND AROUND WELL. - PREP FOR MOVING ACROSS SOFT PAD. 1- SPOT IN SUB AND PITS OVER WELL. I -LOAD SHOP AND PUSHER CAMP ON TRUCKS. 1- MOVE PITS, SHOP AND PUSHER CAMP FROM F PAD TO B PAD. 12:00 - 13:30 1.50 MOB P PRE !CONTINUE TO MOVE PITS, CAMP AND SHOP. 13:30 - 17:00 3.50 I MOB P PRE I PJSM. SPOT CAMP, SHOP AND GENERATOR SKID. 17:00 - 18:00 1.00 RIGU P PRE i PJSM. RAISE AND PIN DERRICK. 18:00 - 21:00 3.00 RIGU P PRE PJSM. SPOT SUB OVER WELL, DOUBLE MAT. 21:00 - 22:00 1.00 RIGU P j PRE PJSM. SPOT PITS, DOUBLE MAT. 22:00 - 00:00 2.00 RIGU P ! PRE I CONTINUE TO RIG UP FLOOR & CATTLE I CHUTE. - PIN BLOCKS TO TOP DRIVE. HANG & TIE BACK BRIDAL LINES. - M/U INTERCONNECT LINES. SET CUTTINGS BOX. - M/U STAND PIPE & CEMENT LINES. HANG ROTARY TONGS. 5/23/2011 00:00 - 02:00 2.00 RIGU P PRE ' CONTINUE TO FINISH RIGGING UP. - SPOT TIGER TANK, CALIBRATE AND TEST I ALARMS. - RIG ACCEPTED 02:00 HRS, 05/23/2011. 02:00 - 03:00 1.00 WHSUR P DECOMP 1 NIPPLE UP SECONDARY VALVE ON VA. - RIG UP HARD LINE TO TIGER TANK. 03:00 - 04:00 1.00 WHSUR P DECOMP CONDUCT RIG EVACUATION, (H2S) DRILL. - ALL HANDS EVACUATED TO SHOP, NO WIND. - ROLE CALL HELD. ALL HANDS INCLUDING TRUCK DRIVERS ACCOUNTED FOR. - DISCUSSED ROLES DURING REAL EVENT. - AGREED ALL HANDS IN VEHICLES TO SHUT DOWN VEHICLE AND GO TO SAFE AREA. - SIMULATED NOTIFYING PAD OPERATOR AND WELLS SUPERINTENDANT. - WELL SECURED. - AFTER DRILL, CONDUCTED PRE SPUD, OVERVIEW OF WELL PLAN. - EMPHASIS ON WELL CONTROL AND 1 CONSTANT MONITORING OF WELL. - -- - - - - - -- Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Ank Page 2 of 14 Aeration Summary Report Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 End Date: 5/31/2011 !X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:OOAM I Rig Release: 5/31 /2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth Phase I Description of Operations (hr) _ (ft) 04:00 05:30 1.50 WHSUR P DECOMP !CONTINUE TO TAKE ON SEAWATER.- WORK ON EPOCH SYSTEM. - PREP CELLAR FOR CIRCULATING OUT FREEZE PROTECT. 05:30 - 07:00 1.50 WHSUR P DECOMP PJSM. P/U DSM LUBRICATOR. ,- PRESSURE TEST LUBRICATOR 250 / 3500 PSI, 5 MIN EACH, GOOD TEST. 07:00 - 10:00 3.00 WHSUR P DECOMP ;TAKE ON SEAWATER. PREP LINES TO CIRCULATE THRU CHOKE MANIFOLD. - LOAD AND STRAP 4" DP. ! - CONTINUE TO TROUBLE SHOOT EPOCH 'SYSTEM. - RIG UP LINES TO CIRCULATE THRU SUPER CHOKE. 10:00 - 11:00 1.00 WHSUR P DECOMP PJSM. PULL BPV, UD LUBRICATOR. 11:00 - 12:00 1.00 KILLW P DECOMP FISNISH RIGGING UP LINES AND LINING UP !VALVES FOR WELL KILL. !- PRESSURE. TEST LINES & STAND PIPE @ 2000 PSI, OK. - SITP 360 PSI, SICP 360 PSI. O/A 40 PSI. 12:00 - 13:00 1.00 KILLW P DECOMP PJSM. REVERSE CIRCULATE DIESEL OUT OF TBG. - PUMPING SEAWATER @ 2 BPM / 480 PSI / ICP. - PUMPING THRU CHOKE TO TIGER TANK. - HOLDING 400PSI BACK PRESSURE. ' GETTING 1 : 1 RETURNS. - RECOVERED APPROXIMATELY 45 BBLS DIESEL. ! - SHUT DOWN, MONITOR F/ 10 MIN. - LINE UP LINES IN CELLAR TO PUMP DOWN TUBING. 13:00 - 16:00 3.00 KILLW i P DECOMP PUMP SEAWATER DOWN TUBING @ 3 BPM / 580 PSI / ICP. - TAKING RETURNS THRU SUPER CHOKE TO TIGER TANK. - HOLDING 300 - 400 PSI BACK PRESSURE. - GETTING 1 : 1 RETURNS. PUMP 260 BBLS. - SHUT DOWN PUMP, SHUT IN WELL AND MONITOR. 1 - 60 PSI ON TUBING, 120 PSI ON VA. ORDER 9.8 PPG KILL WT FLUID. 16:00 - 22:30 1 6.50 KILLW P DECOMP REMOVE 8.5 PPG SEAWATER FROM PITS. - LOAD 9.8 PPG BRINE IN TO PITS AS IT ARRIVES. 1 - CONTINUE TO LOAD / STRAP 4" DP. 22:30 - 23:30 1.00 KILLW P DECOMP 1 PERFORM RIG EVACUATION DRILL. - ALL HANDS EVACUATE TO SHOP, ROLE CALL HELD. - NO HANDS ABSENT, INCLUDING TRUCK DRIVERS, WELLHEAD GUYS AND MUD MAN. - PAD OPERATOR NOTIFIED OF DRILL. - WELL SHUT IN VIA MASTER AND ANNULUS 1 VALVES. - DISCUSSED IMPORTANCE OF WELL CONTROL AND REVIEWED WELL PROGRAM. 23:30 - 00 :00 0.50 1 KILLW 1 P DECOMP CONTINUE TO MONITOR WELL AND TAKE ON 19.8 PPG BRINE. 5/24/2011 00:00 - 01:30 1.50 KILLW � P DECOMP 1 CONTINUE TO TAKE ON 9.8 PPG BRINE. SITP 60 PSI, SICP = 120 PSI. Printed 6/6/2011 1:31:32PM arth America - ALASKA - BP Page 3 of 14 . Aeration Summary Report Common Well Name: B -10 I AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay I Site: PB B Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/20/1978 12:00:OOAM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs I Task ! Code NPT ! NPT Depth Phase I Description of Operations (hr) , 1 (ft) l 01:30 - 04:00 2.50 KILLW I P i ! DECOMP I PJSM. COMMENCE WELL KILLING OP. I - BRING ON PUMP, PUMPING DOWN TBG. HOLDING 250 PSI BACK PRESSURE ON SUPER CHOKE. PUMPING 5 BPM / 760 PSI ICP. - ADD SOAP, PUMP 50 BBLS SOAP PILL & CHASE W/ 600 BBLS 9.8 PPG BRINE. I - 9.8 PPG BACK IN TIGER TANK. SHUT DOWN. - CALCULATED 220 PSI OVER BALANCE. - 11 BBLS LOST W/ KILLING WELL. 04:00 - 05:00 1.00 KILLW 1 P DECOMP - MONITOR WELL, SLIGHT TRICKLE. - CONTINUE TO MONITOR, NO FLOW j i WHATSOEVER FROM TBG OR VA. , _ 1- MONITOR FOR 30 MINUTES. 05:00 - 08:00 3.00 WHSUR P DECOMP I PJSM. MAKE UP LUBRICATOR. - TEST LUBRICATOR @ 250 / 3500 PSI, 5 MIN EACH. I - SET TWO WAY CHECK VALVE. - PRESSURE TWC FROM ABOVE 20 / 3500 1 , PSI, 5 MIN EA / GOOD. I - PERFORM ROLLING TEST FROM BELOW / 1500 PSI / 10 MIN, GOOD. i - R/D LUBRICATOR, BREAK DOWN AND R/D ! LINES FROM VA. 08:00 - 09:30 1.50 WHSUR P DECOMP I PJSM. N/D TREE & ADAPTER FLANGE. 1 - INSPECT THREADS ON HANGER. - MADE UP TCII X/O, (6) TURNS TO THE RIGHT, OK. 09:30 - 12:00 I 2.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" X 5M BOPE. , - RAM CONFIGURATION FROM BOTTOM UP. 1- TEST SPOOL 1- 2 7/8" X 5" VBRS , ' - MUD CROSS I - BLIND SHEAR RAMS - 3 1/2" X 6" VBRS , - ANNULAR PREVENTOR. J I 12:00 - 13:00 i 1.00 BOPSUR P j DECOMP CUT RISER AND INSTALL. I 13:00 - 14:00 1.00 BOPSUR r P 1 DECOMP PJSM. P/U TEST TOOLS. - M/U 4 1/2" TEST JT. FILL STACK & CHOKE W/ 1 — i FRESH WATER. Printed 6/6/2011 1:31:32PM rth America - ALASKA - BP Page 4 of 14 Aeration Summary Report Common Well Name: B -10 1 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 9/20/1978 12:00:00AM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date 1 From - To Hrs Task Code ! NPT : NPT Depth Phase I Description of Operations I (hr) _ i __ (ft) 114:00 - 18:30 4.50 BOPSUR P DECOMP I PJSM. TEST BOPE TEST W/ 4 1/2" TEST JT. - TEST CHOKE VALVES, #1 THRU # 16. TEST ' MANUAL CHOKE & KILL VALVES. - TEST HCR VALVES ON CHOKE AND KILL SIDE. - TEST 4" TIW AND DART VALVES. TEST 4 1/2" ∎TIW VALVE. I TEST UPPER AND LOWER IBOP ON TOP �Q DRIVE. 1��y✓e I - TEST 2 7/8" X 5" & 3 1/2" X 6" VBRS & BLIND i SHEAR RAMS. 1- TEST W/ 2 7/8" TEST JT, ANNULAR /(117 I PREVENTER AND 2 7/8" X 5" VBRS. I - ALL TESTS, 250 PSI LOW AND 3500 PSI HIGH 5 MIN EACH. - CLOSE IN TIMES: USING 4 1/2" TEST JT. 3 11/2" X 6" VBRS, 7 SEC. (- 2 7/8" X 5" VBRS, 6 SEC, BLIND SHEAR RAMS 10 SECONDS. - - USING 4 1/2 ", ANNULAR PREVENTOR CLOSE IN TIME, 25 SEC. I I- KILL AND CHOKE HCR VALVES, CLOSE IN TIMES 1 SEC EACH. PERFORM DRAWDOWN TEST ON 'ACCUMULATOR. 1 - PRESSURE AFTER CLOSURE, 1550 PSI. 200 PSI ATTAINED IN 16 SEC. - FULL PRESSURE, (3000 PSI) ATTAINED IN 93 I - SEC. — 18:30 - 19:30 1.00 BOPSUR P r DECOMP IUD TEST TOOL UD TEST JT, BLOW DOWN _ SURFACE EQUIPMENT. 19:30 - 20:00 0.50 BOPSUR P � I DECOMP I PJSM. P/U DUTCH RISER AND EXTENSION. RILDS. 120:00 - 22:30 2.50 WHSUR P DECOMP I PJSM. P/U DSM LUBRICATOR. 1 - TEST LUBRICATOR 250 / 3500 PSI, 5 MIN EACH. - PULL TWC, MONITOR, NO PRESSURE ON TBG OR VA. UD LUBRICATOR, DUTCH RISER & TOOLS. ' 22:30 - 23:30 1.00 PULL 7 P DECOMP PJSM. M/U LANDING JT TO TBG HANC1FR BOLDS. - PULL HANGER TO FLOOR, 142K TO UNSEAT, , 1 138K UP WT. I - CHECK WELL WHEN HANGER TO FLOOR, WELL STABLE 23:30 - 00:00 0.50 PULL P DECOMP rPJSM. CIRCULATE BTMS UP, PUMPING 9.8 PPG BRINE. I - PUMP DOWN TBG, UP VA THRU CHOKE & GAS BUSTER TO PITS. 5/25/2011 00:00 - 02:00 2.00 PULL P DECOMP 1 PTM. CONTINUE TO CIRCULATE BOTTOMS UP, 9.8 PPG BRINE. 1- 3 BPM / 130 PSI THRU CHOKE & GAS 1 BUSTER TO PITS. 1 1- 411 BBLS TOTAL PUMPED, NO LOSSES. MONITOR WELL, WELL STABLE. OBTAIN SLOW PUMP RATES. 10,320' MD, 8350' TVD. 1 1- 9.8 PPG BRINE, PUMPS 1 & 2: 2 BPM / 50 PSI, ' 3 BPM / 130 PSI. Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page 5 of 14 Aeration Summary Report Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2011 ' End Date: 5/31 /2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay I Site: PB B Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/20/1978 12:00:00AM I Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date ■ From - To Hrs Task Code NPT NPT Depth ' Phase I Description of Operations (hr) ' -- — (ft) 102:00 - 10:00 8.00 I PULL P ; I DECOMP PJSM. POOH & L/D 4 1/2" 13CR -80 VAM TOP I I ■ ;TIIBINQ AND ACCOMPANYING COMPLETION I EQUIPMENT. - INITIAL PU WEIGHT = 135 KLBS. SO WEIGHT = 115 KLBS. - W/ 30 JTS OUT, STOP AND PULL STRIPPING ' I RUBBERS. - OBSERVE WELL W/ PUMPS OFF, NO FLOW I 1 & FLUID LEVEL IN WELLBORE SLOWLY DROPPING. - CONTINUE TO POOH. - CONDUCT KICK WHILE TRIPPING DRILL & AAR. I 1- RESUME POOH, TO SURFACE, LAYING DOWN - CLEAN TUBING CUT. FROM 10,320', 4 -7/8" ' a FLARE OD. CUTOFF JT LENGTH = 9' NO SCALE OR OTHER OBSTRUCTIONS/ABNORMALITIES NOTICED WITH TUBING. OVERALL TBG QUALITY = HIGH 1- TOOL SERVICES SCAN FOUND TUBING NORM CONTAMINATED. TBG REMOVED FROM LOCATION AND SENT TO GC-1 YARD FOR FURTHER INSPECTION. 10:00 - 10:30 0.50 PULL I P DECOMP ' RIG DOWN TONGS AND CLEAR RIG FLOOR AFTER PULLING COMPLETION ASSY. 10:30 - 11:00 0.50 WHSUR P l DECOMP [ INSTALL WEAR BUSHING (ID = 8 -5/8 ") 11:00 - 11:30 0.50 CLEAN I P ' DECOMP i PICKUP AND RACK BACK TWO STANDS OF 4" _ ! 1 DRILLPIPE. 11:30 - 12:00 0.50 CLEAN P DECOMP SERVICE TOP DRIVE AND ADJUST DRUM L _ _ ' BRAKE ON DRAWWORKS. 112:00 - 14:00 2.00 CLEAN P ' DECOMP MAKEUP 4 -1/2" TUBING STUB DRESSOFF /FISHING BHA AND RIH. - T s ' BHA MIN ID = 1 -1/4" I 1- UP AND DOWN WT = 45K. II- 4 -1/2" DRESSOFF MILL HAS 13.74' SWALLOW 14:00 - 20:00 6.00 CLEAN P � DECOMP IRIH W/ DRESSOFF BHA ON 4" DP. - PICKING UP DRILLPIPE FROM SHED, 1 X 1. 1 - @ 5519' BREAK CIRCULATION, VERIFIED 1 THAT CIRCULATION PATH THROUGH 1 DRILLSTRING WAS CLEAR. 1 TAGGED TOP OF 7" LNR @ 5592' MD (14' 1 , DEEPER THAN SCHEMATIC) I , - PUMP DP VOLUME, 57 BBLS, 5.3 BPM / 500 PSI. 20:00 23:00 3.00 CLEAN P 1 -E DECOMP I CONTINUE TO PICKUP 4" DRILLPIPE 1X1 AND RIH F/ 5613' T/ 10219' 1 23:00 - 00:00 1 1 1.00 CLEAN P DECOMP ! PICKUP FINAL STAND OF 4" DRILLPIPE AND I RIH TO TAG 4 -1/2" CUT TBG STUB @ 10320' I MD. - SLIDE OVER TUBING STUB WITH DRESSOFF I I 1 ASSY TO 10333' MD. 1 - MILLED ON TBG STUMP F/ 10320' T/ 10321' PUMPING 3 BPM @ 350 PSI, 4-6 KFT -LBS TD 1 TORQUE - PUMPED HI-VIS SWEEP 1 1- UP WT = 170KLBS, DN WT = 140KLBS, ROT WT = 155 KLBS 1- TOTAL DRILLPIPE PICKED UP = 108 STANDS Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page & of 14 Ask Aeration- Summary Report Common Well Name: B -10 1 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 1 End Date: 5/31/2011 X4 -0OTLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:00AM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB@69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs Task Code , NPT NPT Depth Phase Description of Operations (hr) _ (ft) 5/26/2011 00:00 - 02:00 2.00 CLEAN P DECOMP 1 CONTINUE TO CIRCULATE AND CONDITION HOLE ABOVE TUBING STUB AT 10321'. '- PUMPED SECOND HI-VIS SWEEP WITH NO SIGNIFICANT RETURNS ACROSS SHAKERS. - CIRCULATED SECOND SWEEP AROUND AT 7 BPM, 1320 PSI, 30 TDS RPM, 4 KFT -LBS TDS TORQUE. - FINAL PU = 170 KLBS, FINAL SO = 140 KLBS, FINAL ROT = 155 KLBS 02:00 - 06:30 4.50 CLEAN P I DECOMP ;TRIP OUT OF HOLE, RACKING BACK 4" DP IN I DERRICK F/ 10321' T/ 348' (BHA). - PERFORMED 10 MIN FLOWCHECK ON BOTTOM. NO FLOW. NO LOSSES. WELL STATIC. - OBTAINED SLOW PUMP RATES FOR MP #1 AND MP #2 WITH 9.8 PPG BRINE IN SYSTEM. - WORKED CASING SCRAPER ACROSS 7" it CASING (PROPOSED COMPLETION PKR SETTING DEPTH). I i - PERFORMED 10 MIN FLOW CHECK AT 6000' (-400' BELOW PC LEAK © 5594' MD). NO I FLOW. WELL STATIC. 06:30 - 08:00 1.50 CLEAN P j DECOMP ! HELD PJSM WITH RIG CREWS AND BAKER FISHING REP. RACKED BACK 3 STANDS OF 4 -3/4" DC. LAID DOWN 4 -1/2" DRESSOFF TOOLS. DRESSOFF MILLS HAD POSITIVE INDICATIONS OF SETTING DOWN ON TUBING STUB. - CLEANED MAGNETS AND BOOT BASKETS. 1 TOTAL RETURNED METAL = 11 LBS 08:00 - 09:00 1.00 CLEAN J P DECOMP PICKUP NEW 7" LINER TIE -BACK POLISHING BriA ANL RIH Tr345'. - FUTHL LtNu I r1 = - 344.99' - POLISHING MILL HAS 9.81' SWALLOW AND ,OD =7.72" - PU & SO WEIGHT = 45 KLBS BHA MIN ID = 1 -1/2" 09:00 - 11:00 r 2.00 : CLEAN P DECOMP CONTINUE IN HOLE F/ 345' T/ 5516'. PICKUP FINAL STAND AND WASH IN HOLE T/ 7" LINER TOP © 5592' MD. 7" LINER TIE -BACK POLISHING MILL PASSED EASILY BY THE LINER TOP WITHOUT SETTING DOWN. - UP WEIGHT = 115 KLBS, DOWN WT = 110 1 KLBS - 10' POLISHING MILL EXTENDED AND POLISHED TO DEPTH OF 5601' MD INSIDE OF 7" LINER. 11:00 - 12:00 1.00 CLEAN P DECOMP POLISH 7" LINER TIE -BACK RECEPTACLE AS DIRECTED BY BAKER REP. - CIRCULATE AT 3 BPM, 100 PSI, 60 TDS RPM, 1 -2.5 KFT -LBS TORQUE - NEVER EXCEEDED 5 KLBS WOB WHEN SETTING DOWN. 12:00 15:00 3.00 CLEAN P DECOMP 1TRIP OUT OF HOLE, RACKING BACK 4" DRILLPIPE IN DERRICK F/ 5592' T/ 345' (BHA). - OBTAINED SLOW PUMP RATES ON MP #1 & MP #2 AT 5592', 9.8 PPG BRINE - PERFORMED 15 MIN FLOWCHECK ON BOTTOM PRIOR TO POOH. NO FLOW. Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page 7 of 14 Aeration Summary Report Common Well Name: 8-10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:00AM ! Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date I From - To Hrs I Task I Code NPT NPT Depth Phase Description of Operations (hr) ' ; (ft) 15:00 - 18:00 3.00 I CLEAN , P , DECOMP ! LAYDOWN 7" LINER TIE -BACK POLISHING BHA. ' - CLEAN MAGNETS AND EMPTY JUNK SUBS. I - APPROXIMATELY 2 -1/2 LBS OF METAL 1 SHAVINGS ON MAGNETS. - JUNK SUBS WERE EMPTY. 18:00 - 18:30 0.50 CLEAN P ! DECOMP SERVICE RIG. ! - SERVICE TOP DRIVE, CHECK CROWN 0 MATIC, DRAWWORKS. '- PERFORMED MAN RIDER DRILL AND HELD I MR 18:30 - 22:00 3.50 EVAL P DECOMP ! PJSM. PICK UP POLISHED BORE RECE K " L NER. - HALLIBURTON 9 -5/8" 47# RTTS. I - (9) 6 -1/4" DCS & (9) 4 3/4" DCS FOR I ;SUFFICIENT WEIGHT. 1 1- BAKER. SLEEVE SEAL ASSY HAS 9.64' I SWALLOW INTO 7" LINER. SEAL LENGTH = 1' ON ASSY. _ - TOTAL BHA LENGTH = 594.78' 22:00 - 00:00 2.00 EVAL P DECOMP , W/ ABOVE MENTIONED BHA ON 4" 17# DP T/ 4966' © MIDNIGHT. I 47 STDS IN HOLE, 115K UP AND DOWN WTS. 5/27/2011 I 00:00 00:30 0.50 EVAL P DECOMP I CONTINUE TIH WITH HES 9-5/8" RTTS AND BAKER 7" LINER SLEEVE SEAL ASSY F/ 4966' T/ 5578' ON 4" DRILLPIPE STANDS. PICKUP i DRILLPIPE SINGLE AND RIH T/ 5592'. I- TAG 7" LINER TOP TIE -BACK (Q7 5592' AND TAB IN WITH SEAL ASSY. I - RIH 9.5' (BAKER SLEEVE ASSY ' SWALLOW INSIDE 7" LINER) TO SET DOWN WITH NO-GO ON TOL - SET DOWN ALL WEIGHT OF DRILLSTRING ,AND BHA (85 KLBS) - FINAL UP WEIGHT = 126 KLBS, DOWN I WEIGHT = 118 KLBS 00:30 - 02:30 2.00 EVAL P DECOMP I PRESSURE TEST DOWN DRILLSTRING BELOW BAKER SEAL ASSY INSIDE 7" LINER TO 250 PSI LOW FOR 55 MI NAND 3500 PSI I HIGH_FOR 30 MIN (PASS, CHART ATTACHED). - PRESSURE TESTING 7" LINER, 7" X 4 -1/2" PKR AND 4 -1/2 TBG TO CBP © 10436' - 1ST 15 MIN = 85 PSI LOSS, SECOND 15 MIN = 40 PSI LOSS FOR TOTAL OF 125 PSI LOSS - PRESSURE BUILD UP TOOK 54 STROKES, ! 3.1 BBLS (EXPECTED = 54 STROKES, 3.1 I BBLS) PRESSURE TEST DOWN BACKSIDE OF DRII-L-S-TRUNIAL ASSY INSIDE 2" L N.ER TO 250 PSI LOW FOR 5 MIN . ; AND 3500 PSI HIGH FOR 30 MIN (PASS, �/ I CHART ATTACHED). - PRESSURE TESTING 9 -5/8" CASING & 7" LINER TOP TIE -BACK I I- 1ST 15 MIN = 50 PSI LOSS, SECOND 15 MIN = 4 15 PSI LOSS FOR TOTAL OF 65 PSI LOSS - PRESSURE BUILD UP TOOK 63 STROKES, C 3.6 BBLS (EXPECTED = 70 STROKES, 4.0 I — 1 BBLS) l Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page 8 of 14 Aeration Summary Report Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2011 End Date: 5/31/2011 1X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:00AM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date 1 From - To 1 Hrs Task I Code NPT NPT Depth ! Phase I Description of Operations (hr) (ft) I 02:30 - 03:00 0.50 EVAL ! N WAIT 10,321.00 DECOMP ! WAIT ON ORDERS - DISCUSS PRESSURE I TESTING RESULTS AND PLANS. ' 03:00 - 04:00 1.00 EVAL P DECOMP PICK UP 50', UNSTABBING BAKER LINER I SLEEVE SEAL ASSY, SET RTTS AND PRESSURE TEST. - DRILLSTRING TAIL @ 5552', RTTS COE @ 5533' (RTTS COE 20' ABOVE TAIL) - PRESSURE TEST DOWN DRILLSTRING, I '; BELOW RTTS INSIDE 9 -5/8" CSG TO 250 PSI 1 LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN (PASS, CHART ATTACHED). 1 l- PRESSURE TESTING 59' OF 9 -5/8" CSG, 7" LINER TOP TIE -BACK, 7" LINER, 7" X 4 -1/2" PKR AND 4-1/2 TBG TO CBP @ 10436' - 1ST 15 MIN = 25 PSI LOSS, SECOND 15 MIN = 10 PSI LOSS FOR TOTAL OF 35 PSI LOST / - PRESSURE BUILD UP TOOK 55 STROKES, % 3.2 BBLS (EXPECTED = 55 STROKES, 3.2 BBLS) - USED UPPER 3 -1/2" X 6" VBR PIPE RAMS I _ I FOR TEST. 04:00 - 05:00 1.00 EVAL N WAIT ' 10,321.00 DECOMP ' WAIT ON ORDERS - DISCUSS PRESSURE _ TESTING RESULTS AND PLANS. 05:00 - 05:30 0.50 EVAL P ' DECOMP I RELEASE HES 9-5/8" RTTS AND PRESSURE 1 ; TEST ENTIRE WELLBORE SYSTEM TO 250 LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 ( MIN (PASS, CHART ATTACHED) I- 1ST 15 MIN = 30 PSI LOSS, SECOND 15 MIN = 10 PSI LOSS FOR TOTAL OF 40 PSI LOST i - PRESSURE BUILD UP TOOK 109 STROKES, 6,p& I I ; 6.3 BBLS (EXPECTED = 115 STROKES, 6.6 I __ BBLS) ! 05:30 - 07:30 2.00 EVAL P 1 i DECOMP ! POOH F/ 5992' T/ 595' (BHA), RACKING BACK _ 14" DRILLPIPE IN DERRICK. 107:30 - 10:00 2.50 I EVAL P I I DECOMP ' BREAKDOWN PRESSURE TESTING BHA. RACK BACK 3 STANDS OF 6 -1/4" DC AND 3 1 STANDS OF 4 -3/4" DC IN DERRICK. h. MONITORED WELL FOR FLOW PRIOR TO PULLING BHA THROUGH STACK. NO FLOW. - INSPECTED SEALS ON BAKER 7" SLEEVE I I SEAL ASSY. FOUND METAL SHAVINGS I ENGRAINED IN RUBBER SEALS. REDRESSED TOOL FOR RE- RUNNING. PREPARED TO RIH 1 1 1 WITH SAME BHA. BHA WEIGHT WITH TDS AND BLOCKS = 63 KLBS. 10:00 15:30 5.50 EVAL P DECOMP TIH W/ 9 -5/8" RTTS AND BAKER 7" SLEEVE ' SEAL ASSY T/ 5295'. CHECK DEPTHS AND (TALLY. - PU WEIGHT = 123 KLBS, SO WEIGHT = 115 KLBS. - OBTAINED SLOW PUMP RATES WITH MP #1 I AND MP #2 1- SET RTTS AND PRESSURED UP ON IA TO 375 PSI TO CONFIRM CIRC VALVE CLOSED. RELEASED RTTS. 15:30 - 00:00 8.50 EVAL P DECOMP I DEVELOPED AND REVIEWED PLANS FOR NEGATIVE PRESSURE TESTING PLAN. - FINAL OPS NOTE #1 REVIEWED AND APPROVED BY OPS SUPERINTENDENT AND WELLS TEAM LEADER Printed 6/6/2011 1:31:32PM ortpt America - ALASKA - BP Page 9 of 14 p eratan Summary Report . Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) i Start Date: 5/22/2011 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay I Site: PB B Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/20/1978 12:00:00AM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date i From - To 1 Hrs Task Code NPT i NPT Depth I Phase I Description of Operations (hr) I (ft) 5/28/2011 00:00 - 01:00 1.00 EVAL P DECOMP I HELD PJSM WITH RIG CREWS PLUS HES/BAKER REPS. PUMPED 56 BBLS 8.5 PPG SEAWATER DOWN TUBING TO DISPLACE 9.8 PPG BRINE. FULL COLUMN OF 9.8 PPG BRINE MAINTAINED ON BACKSIDE. - PRESSURE TESTING 59' OF 9 -5/8" CSG, 7" I i LINER TOP TIE -BACK, 7" LINER, 7" X 4 -1/2" 1 I PKR AND 4 -1/2 TBG TO CBP @ 10436' ! - PUMPING 8.5 PPG SEAWATER: ICP = 130 PSI, FCP = 408. AFTER SHUTTING DOWN ' PUMPS, DRILLPIPE PRESSURE STABILIZED _ @ 310 PSI. 01:00 - 03:00 I 2.00 EVAL P 1 I DECOMP SET HES RTTS W/ COE @ 5522' (70' ABOVE 7" ; i LNR TOP), TOOLSTRING TAIL @ 5541'. MONITOR DRILLPIPE PRESSURE DURING NEGATIVE PRESSURE TEST ACROSS 7" LNR TOP. '- CALCULATED UNDERBLANCE BETWEEN 8.5 PPG SEAWATER AND 9.0 PPG EMW FORMATION = 130 PSI. - DRILLPIPE PRESSURE BLED DOWN FROM FCP OF 408 PSI T/ 200 PSI. MONITORED WELL. FLOWBACK VOLUME TO TRIP TANK IS !CORRECT. 1 1- BLED DRILLPIPE PRESSURE DOWN FROM 200 PSI T/ 0 PSI. MONITORED WELL. FLOWBACK VOLUME TO TRIP TANK IS CORRECT. TOTAL FLUID BLED BACK, !INCLUDING LINE DRAIN, = 1.1 BBLS. 1- 1ST 30 MINUTES OF MONITORING WELL IN UNDERBALANCED STATE: PRESSURE BUILT TO 12 PSI. I '- 2ND HOUR OF MONITORING WELL IN UNDERBALANCED STATE: PRESSURE BUILT TO 2 PSI. - NO PRESSURE BUILD UP INDICATED NO f LEAK PATH FROM FORMATION INTO !PRODUCTION CASING @ 7" LNR TOP 03:00 - 04:00 ! 1.00 EVAL I P DECOMP LINE UP TO REVERSE CIRCULATE OUT I SEAWATER. RIG UP JUMPER LINE FROM ' MUD MANIFOLD TO CHOKE MANIFOLD. 04:00 - 05:00 1.00 t EVAL I P 1 DECOMP r RELEASED RTTS AND REVERSE I CIRCULATED SEAWATER OUT OF DRILLSTRING THROUGH TDS AND HYDRAULIC CHOKE BACK TO PITS. 1' - SIMULATED SECOND HALF OF W &W I METHOD FOR CREW WELL KILL DRILL (D5) ' DURING CIRCULATION. 1 - CIRCULATED UNTIL MW IN AND MW OUT = _ _ 9.8 PPG BRINE. 05:00 - 06:00 I 1.00 j EVAL P , DECOMP ' MIRU LRS PUMP UNIT. RIG UP TO HOSE RUN UP TO RIG FLOOR. I 06:00 07:00 1.00 EVAL P DECOMP I HELD UNANNOUNCED KICK WHILE TRIPPING I DRILL (D1) AND AAR TO DISCUSS ' I 1 LEARNINGS. 07:00 - 08:00 ' 1.00 EVAL P DECOMP LRS PUMP TRUCK PUMPED 38 BBLS DIESEL I INTO DRILLSTRING. FULL COLUMN OF 9.8 PPG BRINE MAINTAINED ON BACKSIDE. I - INITIAL CIRC PRESSURE = 50 PSI, FINAL , I CIRCULATING PSI = 570 PSI - OBTAINED SLOW PUMP RATES FOR MP #1 I — L I I AND MP # WITH 9.8 PPG BRINE, 5191' ND Printed 6/6/2011 1:31:32PM P arth America - ALASKA - BP Page 4a of 14 eration Summary Report Common Well Name: B -10 ' AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2011 I End Date: 5/31/2011 : X4- 00TLW -E: (2,700,000.00 ) ! I Project: Prudhoe Bay , Site: PB B Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/20/1978 12:00:00AM 1 Rig Release: 5/31 /2011 • Rig Contractor: NABORS ALASKA DRILLING INC. : UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase I Description of Operations (hr) (ft) 08:00 - 10:30 2.50 EVAL P DECOMP • SET HES RTTS W/ COE @ 5522' (70' ABOVE 7" LNR TOP), TOOLSTRING TAIL @ 5541'. MONITOR DRILLPIPE PRESSURE DURING 1 NEGATIVE PRESSURE TEST ACROSS 7" LNR TOP. j - CALCULATED UNDERBLANCE BETWEEN 38 I : BBLS OF 6.8 PPG DIESEL ( +18 BBLS 9.8 PPG BRINE IN DRILLSTRING) AND 9.0 PP G EMW • j FORMATION = 350 PSW S j DRILLPIPE PRESSURE BLED DOWN FROM • I I FCP OF 600 PSI T/ 400 PSI. MONITORED WELL. FLOWBACK VOLUME TO LRS PUMP ` TRUCK IS CORRECT (0.2 BBLS). - BLED DRILLPIPE PRESSURE DOWN FROM 400 PSI T/ 250 PSI. MONITORED WELL. I FLOWBACK VOLUME TO LRS PUMP TRUCK IS I CORRECT (0.09 BBLS) I '- BLED DRILLPIPE PRESSURE DOWN FROM 250 PSI T/ 130 PSI. MONITORED WELL. FLOWBACK VOLUME TO LRS PUMP TRUCK IS I CORRECT (0.1 BBLS) I [ - BLED DRILLPIPE PRESSURE DOWN FROM ;130 PSI T/ 30 PSI. MONITORED WELL. 1.5 HRS OF MONITORING WELL IN UNDERBALANCED STATE: PRESSURE HELD CONSTANT @ 30 PSI. NO PRESSURE BUILD UP INDICATED NO 'LEAK PATH FROM FORMATION INTO ROB RUCTION CASING @ 7" LNR TOP. 10:30 - 11:30 1.00 EVAL I P T DECOMP OPENED WELLBORE BACK UP TO LRS PUMP 1 TRUCK AND MAINTAINED OPEN BLEED FOR • 30 MIN. NO FLUID RETURNED. SHUT WELL I IN AND MONITOR FOR PRESSURE. NO ' PRESSURE BUILDUP. 1 11:30 - 12:30 1.00 EVAL N WAIT 10,321.00 DECOMP I DISCUSS RESULTS OF TESTING WITH ENGINEER AND OPS SUPERINTENDENT. DEVELOP FORWARD PLAN. 12:30 - 15:00 2.50 EVAL P DECOMP HELD PJSM W/ RIG CREW AND DISCUSSED REVERSE CIRC OUT OF DIESEL IN • ' DRILLSTRING. PRESSURED UP TO 570 PSI I TO EQUALIZE AROUND RTTS. CLOSED ANNULAR PREVENTER AS PRECAUTION. RELEASED RTTS AND REVERSE CIRCULATED DIESEL OUT OF DRILLSTRING 1 THROUGH TDS AND HYDRAULIC CHOKE BACK TO FLOWBACK TANK. • I - SIMULATED SECOND HALF OF W &W 1 METHOD FOR CREW WELL KILL DRILL (D5) • I DURING CIRCULATION. - CIRCULATED @ 3 BPM 15:00 - 16:30 1.50 EVAL P DECOMP CIRCULATED 370 BBLS 9.8 PPG BRINE THROUGHOUT WELLBORE UNTIL MW IN = MW OUT = 9.8 PPG. CHECKED FOR FLOW. • NO FLOW. • I • • 1- CIRCULATED @ 240 GPM, 420 PSI. 1 ! I I - OBTAINED SLOW PUMP RATES WITH MP #1 I AND MP #2 W/ 9.8 PPG BRINE @ 5191' ND 1 16:30 - 17:30 1.00 • EVAL P I DECOMP I PULL UP HOLE WITH TOOL STRING TO 4261', ' RTTS COE @ 4242' MD. PU = 113 KLBS, SO = _ I 110 KLBS. Printed 6/6/2011 1:31:32PM � 0th America - ALASKA - BP Page 11 of 14 • Operation Summary Report Common Well Name: B -10 1 AFE No Event Type: WORKOVER (WO) 1 Start Date: 5/22/2011 1 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:00AM 1Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT 1 NPT Depth Phase Description of Operations 17:30 - 19:00 1 1 1.50 ' EVAL P O DECOMP LRS PUMP TRUCK FILLED DRILLSTRING WITH 1 L 42 BBLS 6.8 PPG 50 DEG F DIESEL, 2 BPM, 630 PSI FCP. , - BRINE WEIGHT IN PITS = 9.6 PPG. 19:00 - 21:30 2.50 EVAL P 1 DECOMP , HES RTTS W/ COE an. 4242' (1350' . EXPOSED 9 -5/8" CSG ABOVE 7" LNR TOP), 1 1 TOOLSTRING TAIL @ 4261'. MONITOR DRILLPIPE PRESSURE DURING NEGATIVE 1 PRESSURE TEST ACROSS 9 -5/8" CSG AND 7" LNR TOP. - CALCULATED UNDERBLANCE BETWEEN 1 FULL. 42 BBL DRILLSTRING OF 6.8 PPG 1 DIESEL ( +9.8 PPG BRINE IN 9 -5/8" CSG) AND 9.0 PPG EMW FORMATION = 400 PSI. - MONITORED DP PRESSURE AFTER , !SHUTTING DOWN PUMPS FOR 15 MIN. 1 PRESSURE INCREASED FROM 630 FPSI FCP I, T/ 675 PSI - DRILLPIPE PRESSURE BLED DOWN FROM FCP OF 675 PSI T/ 45 PSI. MONITORED WELL FOR 1 HR. FLOWBACK VOLUME TO LRS PUMP TRUCK IS CORRECT (0.7 BBLS). PRESSURE BUILT F/ 45 PSI T/ 85 PSI (THERMAL EXPANSION) - DRILLPIPE PRESSURE BLED DOWN FROM 1 FCP OF 85 PSI T/ 12 PSI. MONITORED WELL FOR 1 HR. FLOWBACK VOLUME TO LRS PUMP TRUCK IS CORRECT (0.1 BBLS). PRESSURE BUILT T/ 13 PSI. / - NO PRESSURE BUILD UP INDICATED NO // LEAK PATH FROM FORMATION INTO 9 -5/8" CSG OR PRODUCTION CASING © 7" LNR — -- — I I TOP. — 21:30 - 00:00 2.50 EVAL P ! DECOMP 1 LRS PUMP TRUCK PRESSURED UP DRILLSTRING TO 600 PSI. CLOSED ANNULAR PREVENTER & RELEASED RTTS. ISOLATE AND RDMO LRS. REVERSE CIRCULATED DIESEL OUT OF DRILLSTRING TO FLOWBACK TANK @ 3 BPM THROUGH CHOKE PRACTICING WELL KILL TECHNIQUE. OPENED ANNULAR PREVENTER AND CIRCULATED 9.8 PPG BRINE THROUGHOUT WELLBORE. NO FLUID LOSSES OBSERVED. 1 - FORWARD PLAN TO PROCEED WITH STRADDLE PACKER COMPLETION (ASSEMBLY RECEIVED FROM WELLS TEAM LLEADER. 5/29/2011 00:00 - 00:30 0.50 1 EVAL P DECOMP 1 CONTINUE TO CIRCULATE 9.8 PPG BRINE 1 ,THROUGHOUT WELLBORE. SHUTDOWN ' PUMPS AND MONITOR WELL FOR 15 MIN. NO _ _ FLOW. 00:30 - 04:00 3.50 EVAL P DECOMP POOH W/ HES 9 -5/8" RTTS AND BAKER 7" LNR SLEEVE SEAL ASSY F/ 4261' T/ BHA @ 595'. LAYING DOWN 39 STANDS OF DRILLPIPE ON TRIP OUT. 1- PICKED 12 STANDS OF DRILLPIPE AND RIH. '- CONTINUE OUT OF HOLE, LAYING DOWN L - [ DRILLPIPE T/ BHA @ 595 Printed 6/6/2011 1:31:32PM orth A merica - ALASKA - BP Page 12 of 14 ID perat Summary Report Common Well Name: B -10 I AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2011 End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 9/20/1978 12:00:00AM � Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 @69.03ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth ' Phase Description of Operations (hr) (ft) 04:00 - 06:30 2.50 EVAL P DECOMP HELD PJSM FOR LAYING DOWN BHA. CHECK FOR FLOW PRIOR TO PULLING BHA [THROUGH STACK. NO FLOW. - RACK BACK 4 -3/4" DC, LAYDOWN 6-1/4" DC i - LAYDOWN HES AND BAKER PRESSURE TESTING TOOLS. ' 06:30 - 08:00 1.50 CLEAN P DECOMP ! P/U 95/8" SCRAPER BHA. _ - TOTAL BHA LENGTH = 312' 08:00 - 10:00 1 2.00 CLEAN P DECOMP ; RIH W/ CASING SCRAPER BHA ON 4" DP , - ROTATE SCRAPER THRU FOC @ 2096' @ 25 RPM. I- Rill TO 5577' & WORK SCRAPER F/ 5462' - 5566'. - 110K UP WT, 107K DOWN WT W/ PUMPING 7 BPM @ 568 PSI. 10:00 - 11:30 1.50 I CLEAN P DECOMP PJSM. CIRCULATE 20 BBLS HI VIS SWEEP AROUND, 10 BPM / 920 PSI. OBTAIN SLOW PUMP RATES, #1 & #2 PUMPS I I BOTH @ 2 BPM / 30 PSI & 3 BPM / 90 PSI. - 5577' MD / 5216' TVD WHILE GETTING SLOW PUMP RATES. - SHUT DOWN AFTER GETTING SWEEP L _ , BACK, MONITOR WELL, WELL STABLE. 1 11:30 - 12:30 7 1.00 CLEAN P DECOMP ' PJSM. SLIP AND CUT 129' OF DRILLING LINE. I SERVICE TOP DRIVE AND CROWN 0 MATIC. 12:30 - 17:30 5.00 CLEAN P DECOMP I PJSM. POOH & UD 4" DP. ROTATE SCRAPER i I THRU FOC @ 2096'. 25 RPM. 1 17:30 - 19:30 2.00 , CLEAN P DECOMP PJSM. MONITOR WELL, UD BHA. + j — r - CLEAR / CLEAN RIG FLOOR. 119:30 20:00 0.50 I CLEAN P I DECOMP PJSM. PERFORM TEST ON CASING TO ' VERIFY FOC. ' _ - 250 5 MIN / 1000 PSI 10 MIN, GOOD TEST. 120:00 21:00 1.00 WHSUR P T DECOMP ' PJSM. PULL WEAR BUSHING. 21:00 - 22:00 1.00 WHSUR P DECOMP PJSM. MAKE DUMMY RUN W/ TUBING _ HANGER, OK. 22:00 - 00:00 2.00 I RUNCOM P RUNCMP TRIG UP FLOOR TO RUN COMPELTION. - CONFIRM ALL COMPLETION EQUIPMENT AND RUNNING ORDER. - HANG TONGS AND COMPENSATOR. 5/30/2011 ' 00:00 00:30 0.50 RUNCOM P RUNCMP I PJSM ON RUNNING COMPLETION W/ ALL PARTICIPANTS. - EMPHASIS ON HAND / BODY PLACEMENT, GOOD COMMUNICATION. I - COMPENSATOR AND TORQUE TRUN ' EQUIPMENT RIGGED UP. 1 00:30 - 04:00 3.50 RUNCOM P 1 RUNCMP ',.MAKF LIP AND RIH W/ 4 -1/2 ", 12.6 #, 13CR -85 I I VAMTOP TUBING F/ SURFACE T/ 3342' MD. I EVERYTHING BELOW 7" PACKER , I LOCKED. I 1 - USING JET LUBE SEAL GUARD (FRICTION FACTOR = 1.0) AND TORQUE TURNING ALL CONNECTIONS TO 4440 FT -LBS. 04:00 - 05:00 ! 1.00 RUNCOM P RUNCMP HELD UNANNOUNCED KICK WHILE TRIPPING (D1) DRILL AND AAR WITH RIG CREW TO I DISCUSS RESULTS I - SIMULATED CLOSING OF ANNULAR PREVENTER AND OPENING OF HCR Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page of 14 eration Summary Re P rIt ort P Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) ! Start Date: 5/22/2011 1 End Date: 5/31/2011 ;X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay ' Site: PB B Pad Rig Name /No.: NABORS 7ES i Spud Date/Time: 9/20/1978 12:00:00AM ; Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB @69.03 022009 ©69.03ft (above Mean Sea Level) Date I From - To ! Hrs ' Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) [ 05:00 - 14:00 9.00 RUNCOM P RUNCMP CONTINUED TO RIH W/ 4 -1/2 ", 12.6#, 13CR -85 COMPLETION TUBING ASSY F/ 3342' T/ 10325' MD. - FINAL PU WEIGHT = 135 KLBS, SO WEIGHT = 115KLBS - TOTAL JTS = 240. AVERAGE RUNNING TIME SINCE 05:00 = —20 JTS/HR ;- TAGGED TOP OF 4 -1/2" TBG STUB 18' INTO _ JT #242 @ 10325' MD. 14:00 - 16:00 2.00 RUNCOM P RUNCMP 'SPACE OUT AND LANDED 4-1/2", 12.6#, 13CR -85 COMPLETION TBG @ 10,334' MD, 8438' ND. - CLEAR INDICATIONS OF SHEAR PINS AND OVERSHOT NO-GO ON DEPTHS. SHEARED ' 1ST SET OF OVERSHOT PINS W/ 30 KLBS, SHEARED 2ND SET OF OVERSHOT PINS W/ 13 KLBS. - 1 -1/2" MMG SLB GLM #1 W/ DGLV @ 5428' I MD, 5107' ND I- 1 -1/2" MMG SLB GLM #2 W/ DCR SHEAR VLV @ 3610 MD, 3599' TVD 16:00 - 16:30 0.50 RUNCOM P RUNCMP RIG DOWN EQUIPMENT AFTER RUNNING ; TUBING. CLEAR RIG FLOOR. 16:30 - 00:00 7.50 �! RUNCOM ' P RUNCMP j LINE UP AND REVERSE CIRCULATE 160 BBLS 120 DEG F 9.8 PPG CLEAN BRINE. FOLLOW WITH 386 BBLS 9.8 PPG CLEAN BRINE W/ 1/2% KI -3908 CORROSION INHIBITOR. CIRCULATED @ 1 -1.5 BPM, 1 300 1500 PSI ! PUMP PRESSURE. (DCR SHEAR VLV IN GLM _ #2 SHEARS 2600 DIFF PS - - - - - -- -- - - - - � P RUNCMP 5/31/2011 00:00 01:00 1.00 RUNCOM j !PICK UP LANDING JT AND SCREW INTO TBG ! HNGR. DROP 1 -7/8" BALL AND ROD ASSY (2" SB/RB PULLING TOOL REQUIRED) AND LET ' FALL TO RHC-M PLUG (4 -1/2" GS/GR PULLING TOOL REQUIRED) IN X NIPPLE @ 10249' MD. PULL LANDING JT AND LAYDOWN. LINE UP TO PUMP DOWN KILL LINE BELOW CLOSED BLIND RAMS. PRESSURE UP 4 -1/2" COMPLETION TBG TO SFT PKRS AND, I PERFORM TBG MIT -� PERFORM 250 PSI LOW TEST FOR 5 MIN AND 3500 PSI HIGH TEST FOR 30 MIN (PASS, 25 PSI DROP IN 1ST 15 MIN, 10 PSI DROP IN 2ND 15 MIN, SEE ATTACHED CHART). ' 1 I - DURING PRESSURE UP, NOTICED INITIALIZATION OF PKR SET AROUND 2100 I PSI. - P RESSURE TEST WITNESSED BY WSL 01:00 02:00 • 1.00 RUNCOM ' RUNCMP P BLEED TBG PRESSURE DOWN TO 1500 PSI AND HELD FOR IA TEST. LINE UP SECONDARY KILL LINE TO PUMP DOWN IA FOR MIT TEST. 1- PERFORM 250 PSI LOW TEST FOR 5 MIN AND 3500 PSI HIGH TEST FOR 30 MIN (PASS, 70 PSI DROP IN 1ST 15 MIN, 30 PSI DROP IN 2ND 15 MIN, SEE ATTACHED CHART). • - TUBING PRESSURE BUILT TO 2100 PSI DURING PRESSURE UP AND MAINTAINED 2100 PSI DURING TEST. ' - OBTAIN APPROVAL TO PROCEED WITH WELLPLAN FROM WELLS TEAM LEADER. ! - PRESSURE TEST WITNESSED BY WSL Printed 6/6/2011 1:31:32PM orth America - ALASKA - BP Page 14 of 14 Operation Summary Report Common Well Name: B -10 AFE No Event Type: WORKOVER (WO) ! Start Date: 5/22/2011 I End Date: 5/31/2011 X4- 00TLW -E: (2,700,000.00 ) Project: Prudhoe Bay 1 Site: PB B Pad Rig Name /No.: NABORS 7ES � Spud Date/Time: 9/20/1978 12:00:00AM Rig Release: 5/31/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292032100 Active Datum: Revised RKB@69.03 022009 @69.03ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth ! Phase I Description of Operations (hr) (ft) 1 02:00 - 02:30 0.50 RUNCOM P ' RUNCMP BLEED OFF IA F/ 3500 PSI T/ 1500 PSI. BLEED TBG AND IA PRESSURES TO ZERO EVENLY. PRESSURE BACK UP ON IA TO SHEAR DCR VLV IN GLM #2. VLV SHEARED AT 2600 PSI (SEE ATTACHED CHART). 02:30 - 04:30 2.00 BOPSUR P RUNCMP DRAIN BOP STACK AND INSTALL CAMERON j TYPE H 4 -1/2" TWC IN TUBING. PRESSURE TEST TWC FROM BELOW THROUGH SHEAR VLV TO 250 PSI LOW FOR 10 MIN AND 1000 PSI HIGH FOR 10 MIN (PASS). PRESSURE 1 TEST TWC FROM ABOVE BLIND RAMS TO 250 I PSI LOW FOR 10 MIN AND 3500 PSI HIGH FOR ;10 MIN (PASS). DRAIN BOP STACK. 04:30 - 05:30 1.00 BOPSUR –!--- P T RUNCMP i NIPPLE DOWN BOP STACK. LIFT STACK AND SET ON STUMP OFF TO SIDE OF WELLHEAD 05 :30 06:00 0.50 WHSUR P RUNCMP NIPPLE U LLR - !NIPPLE UP 13 -5/8" X 4- 1/16" 5000 PSI I ADAPTER FLANGE. 06:00 - 08:00 2.00 WHSUR P I RUNCMP I PRESSURE TEST ADAPTER FLANGE, TBG HANGER VOID AND SEALS TO 250 PSI LOW FOR 5 MIN AND 5000 PSI HIGH FOR 30 MIN (PASS) i — _! I - TEST WITNESSED BY WSL 08:00 09:00 1.00 BOPSUR P RUNCMP SET 4- 1/16" CAMERON TREE O N R ADAPT E ' FLANGE. NIPPLE UP SAME. 09:00 - 10:30 1.50 : BOPSUR P RUNCMP PRESSURE TEST ENTIRE TREE TO 250 PSI LOW FOR 5 MIN AND 5000 PSI HIGH FOR 30 I MIN. 10:30 - 12:00 1.50 1 BOPSUR P i RUNCMP PICK UP LUBRICATOR AND TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. PULL THE TWC AND RIG DOWN THE LUBRICATOR. 12:00 - 14:00 2.00 WHSUR P RUNCMP I RIG UP LRS AND PRESSURE TEST ALL LINE TO 300 PSI LOW AND 3500 PSI HIGH FOR 5 MIN. REVERSE IN 150 BBLS OF 60 DEG F 1DIESEL AT 2 BPM AND 650 PSI. ;14:00 15:00 1.00 WHSUR P ' RUNCMP I ALLOW DIESEL TO U -TUBE. RIG DOWN LRS LAND BLOW DOWN ALL LINES. ,15:00 - 16:00 l i 1.00 WHSUR 1 P ! RUNCMP I PICK UP LUBRICATOR AND TEST TO 250 PSI I LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. INSTALL THE BPV AND RIG DOWN THE ' LUBRICATOR. 16:00 - 17:00 1.00 WHSUR P I ! RUNCMP UTILIZING LRS, PRESSURE TEST THE BPV !FROM BELOW WITH DIESEL TO 1000 PSI FOR 10 MIN. BLOW DOWN ALL LINES AND RIG , DOWN LRS. 17:00 - 18:00 1.00 WHSUR P RUNCMP I REMOVE THE SECOND ANNULUS VALVE AND INSTALL THE FLANGES AND GAUGES ON 1 THE TREE. SECURE THE TREE FOR RDMO AND CLEAN UP THE CELLAR. ** *RELEASE THE RIG AT 18:00 * ** Printed 6/6/2011 1:31:31 PM TREE= 4- 1/16" CIW SAFETY AC UA OR= BAKER C • B-1 OA WEL BL ORE BELOW WHIPSTOCK _ ** ORIG KB. ELEV = 64.29' BF. ELEV = 37.24' PJC DRAFT ' ' KOP = 2800' — 2096' H 9-5/8" FOCI Max Angle = 61° @'6183' 2215' H4 -1/2" HES X NIP, ID = 3.813" I Datum MD = -- 10880' Datum TVDss= 8800. SS — 2306' I-19 -5/8" DV PKR I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2675' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3610 3600 16 MMG DOME RK 16 06/13/11 Minimum ID = 3.725" @ 10478' 1 5428 5107 40 MMG SO RK 20 06/13/11 4-1/2" HES XN NIPPLE 5464' —I4- 112 " HES X NIP, ID = 3.813" I 5493' 9 -5/8" X 4 -1/2" HES TNT PKR, ID = 3.903" 5527' 1-14-1/2" HES X NIP, ID = 3.813" I 9 -5/8" X 7" BKR HRD ZXPN LTP, ID = 6.28" I 5578' I9 -5/8" X 7" BKR FLEX -LOCK HGR, ID = 6.31" I. 5594' is ' ti 9 -5/8" WHIPSTOCK H 5750' I— '' 2' ►� • MILLOUT WINDOW (B -10A) 5737' - 5753' 9 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" H —5753 �� • I 10185' H4-1/2" HES X NIP, ID = 3.813" I x- _ 10214' 1-17" X 4-1/2" HES TNT PKR, ID = 3.856" I I 10249' H4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13CR -85 VAM TOP, 10319' .0152 bpf, ID = 3.958" 4-1/2" TUBING STUB (05/19/11) I 10320' II 1_ I 10334' 1-17" X 4 -1/2" UNIQUE OVERSHOT I ♦ ♦ 10371' —17" X 4-1/2" BKR S -3 PKR, ID = 3.870" I L 10405' H4-1/2" HES X NIP, ID = 3.813" I 4 -1/2" CIBP(05/11/11) I-I 10436' 1 10478' H4 -1/2" HES XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, —I 10490' .0152 bpf, ID = 3.958" 10482' I— 7" X 5" BKR C-2 ZXP LTP w /TIEBACK SLV i 1 .. & FLEXLOCK LNR HGR, ID = 4.400" 7" LNR, 26 #, L -80 BTC -M, .0383 bpf, ID = 6.276" I--j 10645' \ 10490' I- I4 -1/2" WLEG, ID = 3.958" I 10511' 1-1 5" X 4-1/2" XO, ID = 3.958" I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 19° @ 10850' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE _ 3-3/8 6 10850 - 10858 C 03/10/09 r 3 -3/8 6 10850 - 10868 C 04/15/09 PBTD H 11104' 4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, H 11190' -♦ • ♦ ♦ .0152 bpf, ID = 3.958" ••♦•♦• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10(24/78 ? ORIGINAL COMPLETION 06/15/11 ALH/ PJC GLV C/O (6/13/11) WELL: B -10A 07/11/90 NIES RWO CORRECTION (11/16/06) PERMIT No. r 2082050 04/10/08 014 RWO SUSPENDED API No: 50- 029 - 20321 -01 -00 03/02/09 N2ES SIDETRACK (B -10A) ' SEC 31, T11 N, R14E, 2070' FNL & 1611' FEL 05/31/11 N7ES RWO 06/02/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 26, 2011 4:31 PM To: 'Ciolkosz, Ryan R' Subject: RE: B -10A RWO (PTD 208 -205) (Sundry 311 -050) Ryan, Not a problem. Go ahead with the smaller 2 7/8" X 5" VBR as you stated below. Thanks for the notice. Good luck... Guy Schwartz Senior Petroleum Engineer cam, APR 2 y()1! AOGCC "" `` s " � 9 793 -1226 (office) 444 -3433 (cell) From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz @bp.com] Sent: Tuesday, April 26, 2011 1:27 PM To: Schwartz, Guy L (DOA) Subject: RE: B -10A RWO (PTD 208 -205) (Sundry 311 -050) Guy, I would like to request that we use 2 -7/8" x 5" VBR instead of the 3 -1/2" x 6" VBR's originally written in the Sundry request. Due to complications we have had in the past with pulling XXN plugs post rig workovers, we would prefer to pull the XXN plug currently in the well and set a 4.5" composite bridge plug in the tubing tail and drill out the composite plug before running the new completion. To drill out the plug, we will be using -900 ft of 2 -7/8" PAC HT drill pipe and therefore would like to switch to 2 -7/8" x 5" VBR. 2 -7/8" x 5" will be able to accommodate the 2 -7/8 ", 4" and 4.5" tubing sizes being run in this well. The following will be the BOPE configuration from the bottom to top: 2 -7/8" x 5" VBR, mud cross, blind /shear rams, 7" fixed rams and 13-%" annular preventer. Would this be acceptable? Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, February 28, 2011 2:05 PM To: Ciolkosz, Ryan R Subject: RE: B -10A RWO ( PTD 208 -205) Ryan, That is fine. Thanks, 4/28/2011 • Page 2 of 3 • Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz @bp.com] Sent: Monday, February 28, 2011 2:01 PM To: Schwartz, Guy L (DOA) Subject: RE: B -10A RWO ( PTD 208 -205) I that case, I propose that we go with a 4 preventer stack as follows from bottom to top: 3 -1/2" x 6" VBR, mud cross, blind /shear rams, 7" fixed rams, annular preventer. Would this be acceptable? Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, February 28, 2011 1:33 PM To: Ciolkosz, Ryan R Subject: RE: B -10A RWO ( PTD 208 -205) Ryan, I try to be consistent with the BOP requirements.... in this case the 7" RBP can't be tested with the upper leak in the liner top or 9 5/8" so you are left with just the tubing plug and KWF. I realize that extra time is required to change out the Rams but in this case it should be done. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ciolkosz, Ryan R [mailto: Ryan.Ciolkosz @ bp.com] Sent: Monday, February 28, 2011 1:09 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C Subject: RE: B -10A RWO ( PTD 208 -205) Guy, it will be a 3 preventer stack configuration as follows from the bottom up: 3 -1/2" x 6" VBR, mud cross, blind /shear rams, and Annular preventer. Will this configuration require us to change to 7" rams to run scab liner? Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska 4/28/2011 • Page 3 of 3 Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, February 28, 2011 11:43 AM To: Ciolkosz, Ryan R Subject: B -10A RWO ( PTD 208 -205) Ryan, In reviewing the RWO procedure can you clarify the BOP setup? Are there 2 ram bodies only plus annular ? ?? If so, at step 5 you will be required to change the rams to 7" to run the scab liner as there is only one tested mechanical barrier in place. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 4/28/2011 III . Alkiki / race - t.a -C.... . �.s:� a.., 33P .L- lo 1 Y 34 cis P‹ 1 1�, , � bp .Z Gj 1/ff B -10A Scab Liner zoo Z DS Well Type: Oil Producer Current Status: This well is completed with 4.5" production tubing tied into a 4.5" production liner. 7" liner from top of 4.5" liner to 5578' MD and 9-%" casing from top of 7" liner to surface. Inner annulus failed a MIT -IA on 8/19/10. Suspect possible leak in 7" liner top packer elements or 9 -5/8" casing. LDL indicates leak at or near the 7" Liner top. Well is secured from Ivishak with TTP in XN at 10478' MD. Scope of Work: Cut and pull 4 -1/2" tubing. RIH with LTP test assembly to confirm leak location. RIH and set 7" Scab liner from current 7" liner Tie back receptacle to - 4482' MD and cement in place. Run 4- 1/2" 12.6# Cr tubing and 7" x 4 -1/2" packer. Tie tubing into existing tubing stub with Unique Machine overshot MASP: 2,385 psi Estimated Start Date: June 15, 2011 9 . j X71 i AP R x - M Pre Riq Operations / S 1 Pull XXN plug at 10478' MD, Obtain SBHP, Set 4.5" Composite bridge plug in full joint of tubing between X nipple and XN nipple at -10,436' MD F 2 MIT -OA to 2,000psi (may have an open shoe), MIT -T to 3,500psi. MIT -IA to 3,500psi record LLR's if necessary. E 3 PowerJet cut 4 -W 13CR -80 tubing at -10,320' MD, -10' down from the top of the 1st full joint above the packer (Reference tubing tally 2- 27 -09). F 4 Circulate well with seawater and diesel cap. Record well head pressures W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. W 6 Set a BPV in the tubing hanger. F 7 Test BPV from below with 500psi rolling test for 10 min O 8 Remove the well house & flow line. Level the pad as needed for the rig. Riq Operations 1. MIRU Doyon 16. ND tree. NU three preventer BOP stack with 2 -7/8" x 5" VBR pipe rams, blind rams, 7" Casing rams and annular preventer. Pressure test to 3500psi. Circulate out freeze protection fluid and circulate well to clean KWF through the cut. 2. Pull and LD 4 1/2" tbg to cut 3. PU polished bore receptacle pack off and RTTS test packer. RIH and test 7" liner and 9-%" casing to confirm integrity. PU and set RTTS at -4682' MD and pressure test above and below to confirm leak is below liner top packer. 4. PU and set 7" RBP at - 5600' MD and dump -50 ft of sand on top 5. The 2 -7/8" x 5" VBR will NOT be changed to 7" as the barrier to the reservoir will be a tested 4-1/2" •' at -10,436' MD and kill weight fluid. PU -1400' of 7" 26# L -80 scab liner and Coy.? Y •z.l. of • r ported seal stem assembly and 7" x 9-%" Liner top packer. Fully cement 7' scab liner with 15.8 ppg Class G cement (1.17 cuft/sk). 6. Pressure test 7" scab liner to 3500 psi 7. PU clean out 6 -1/8" Clean out BHA and drill out cement plugs and clean out to top of 7" RBP. 8. Pull RBP. RIH with casing scraper and dress off shoe and dress off tubing stub. 9. PU Junk mill and 2 -7/8" PAC HT pipe and mill out composite bridle plug at -10,436' 10. Run 4 -1/2" Vamtop 13CR -85 completion with Halliburton TNT packer (Production packer setting depth - 10200' MD) 11 Displace IA to packer fluid and set packer 12. Test tubing and IA to 3500 psi. Freeze protect to 2000' TVD 13. Set BPV. ND BC PE. NU and test tree. RDMO. Drilling Engineer: Ryan Ciolkosz (907)564 -5977 Production Engineer: Laurie Derrick (907)564 -5952 • • r+ 1 SEAN PARNELL, GOVERNOR �( a ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader O 8 o BP Exploration (Alaska), Inc. a f P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B -10A Sundry Number: 311 -050 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. eamount, Jr. Chair r S DATED this/ day of March, 2011. Encl. Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 28, 2011 2:05 PM To: 'Ciolkosz, Ryan R' Subject: RE: B -10A RWO ( PTD 208 -205) Ryan, That is fine. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz @bp.com] Sent: Monday, February 28, 2011 2:01 PM To: Schwartz, Guy L (DOA) Subject: RE: B -10A RWO ( PTD 208 -205) 1 that case, I propose that we go with a 4 preventer stack as follows from bottom to top: 3 -1/2" x 6" VBR, mud cross, blind /shear rams, 7" fixed rams, annular preventer. Would this be acceptable? Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz @alaska.gov] Sent: Monday, February 28, 2011 1:33 PM To: Ciolkosz, Ryan R Subject: RE: B -10A RWO ( PTD 208 -205) Ryan, I try to be consistent with the BOP requirements.... in this case the 7" RBP can't be tested with the upper leak in the liner top or 9 5/8" so you are left with just the tubing plug and KWF. I realize that extra time is required to change out the Rams but in this case it should be done. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 2/23/2011 Page 2 of 2 • • From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz @bp.com] Sent: Monday, February 28, 2011 1:09 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C Subject: RE: B -10A RWO ( PTD 208 -205) Guy, it will be a 3 preventer stack configuration as follows from the bottom up: 3-1/2" x 6" VBR, mud cross, blind /shear rams, and Annular preventer. Will this configuration require us to change to 7" rams to run scab liner? Thank you, Ryan Ciolkosz GPB Workover Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 From: Schwartz, Guy L ( DOA) [ mailto:guy.schwartz @alaska.gov) Sent: Monday, February 28, 2011 11:43 AM To: Ciolkosz, Ryan R Subject: B -10A RWO ( PTD 208 -205) Ryan, In reviewing the RWO procedure can you clarify the BOP setup? Are there 2 ram bodies only plus annular ? ?? If so, at step 5 you will be required to change the rams to 7" to run the scab liner as there is only one tested mechanical barrier in place. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 2/28/2011 ' STATE OF ALASKA , ,,� ALASKA. AND GAS CONSERVATION COMMIS 3 ( � APPLICATION FOR SUNDRY APPROVAL , k1 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Cement 7" scab liner 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 208 - 205 ' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20321 - 01 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: se PBU B -10A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): _ ADL 028310 & 028313 ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11190' 9162' • 11104' 9081' 10478' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" x 20" 110' 110' Surface 2675' 13 -3/8" 2675' 2675' 4930 2670 Intermediate 10011' 9-5/8" 10011' 8042' 6870 4760 Production Liner 5067' 7" 5578' - 10645' 5222' - 8645' 7240 5410 Liner 708' 4-1/2" 10482' - 11190' 8489' - 9162' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10850' - 10858'- 8840' - 8848' - 4 -1/2 ", 12.6# 13Cr80 10490' Packers and SSSV Type: 7" x 4-1/2" Baker S -3 Packer Packers and SSSV 10371' / 8383' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: IN Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 15, 2011 ∎- Oil - ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ryan Ciolkosz, 564 -5977 Printed Name avid Reem Title Engineering Team Leader Signature Prepared By Name/Number. abeth Barker, 564-5674 E liz Phone 564 -5743 Date z _ 2 2._ 20 i'1 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6(1....-6- ❑ 1 Plug Integrity ,(BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 1 A 3500 se: j x ( sf FIECEIVOV Other: ZSOD Si 4"'"I 144, r / t 1. "''I -IN) /° FEB 2 3 2,011 teaska OP & Ges Cons. Coa asio Subsequent Form Required: 6 e) ° yo y Anctiotago OA APPROVED BY / Approved By: COMMISSIONER THE COMMISSION Date / l ` I Form 10-403 Revised 1 / 3 l f ieDM . MAR 02 0 ORIGINAL Z Z�' •/� Submit In Duplicate • • bP B -10A Scab Liner Well Type: Oil Producer Current Status: This well is completed with 4.5" production tubing tied into a 4.5" production liner. 7" liner from top of 4.5" liner to 5578' MD and 9-%" casing from top of 7" liner to surface. Inner annulus failed a MIT -IA on 8/19/10. Suspect possible leak in 7" liner top packer elements or 9 -5/8" casing. LDL indicates leak at or near the 7" Liner top. Well is secured from Ivishak with TTP in XN at 10478' MD.v Scope of Work: Cut and pull 4 -1/2" tubing. RIH with LTP test assembly to confirm leak location. RIH and set 7" Scab liner from current 7" liner Tie back receptacle to - 4482' MD and cement in place. Run 4- 1/2" 12.6# Cr tubing and 7" x 4 -1/2" packer. Tie tubing into existing tubing stub with Unique Machine overshot MASP: 2,385 psi / Estimated Start Date: June 15, 2011 Pre Rig Operations S 1 Drift tubing to 10478' (XXN plug set in XN nipple at 10478' MD) S 2 Dump -10' of sluggits on plug and set junk catcher on top of sluggits F 3 MIT -T to 3500 psi E 4 Jet cut tubing at -10332' MD F 5 Circulate through cut to confirm tubing is cut F 6 CMIT -T x IA to 3000 psi and confirm leak off rate Freeze Protect as necessary. F 7 MIT -OA to 2000psi. F 8 Bleed casing and annulus pressures to zero. W 9 Function tubing and casing LDS. Repair /replace as required. Perform PPPOT -IC to 3500psi and PPPOT -T to 5000psi. W 10 Set a BPV. Remove well house and flow line. Level pad as necessary. Rig Operations / 1. MIRU Doyon 16. ND tree. NU tl . preventer BOP stack with 3 -1/2" x 6" VBR pipe rams, blind 4- 7 rams and annular preventer. Pressure test to 3500psi. Circulate out freeze protection fluid and circulate well to clean KWF through the cut. 2. Pull and LD 4 1/2" tbg to cut 3. PU polished bore receptacle pack off and RTTS test packer. RIH and test 7" liner and 9-%" casing to confirm integrity. PU and set RTTS at -4682' MD and pressure test above and below to confirm leak is below packer. 4. PU and set 7" RBP at - 5600' MD and dump -50 ft of sand on top .� 5. • - - " • - - • • • - . • - • • - - • . - • the reservoir will be a tested 4 -' " wee . PU -1400' of 7" 26# L -81 sc. • • - - d ported -M' 7" RBP C Noy' TEs e..o) • seal stem assembly and 7" x 9-%" Liner top packer. Fully cement 7' scab liner with 15.8 ppg Class G cement (1.17 cuft/sk). 6. Pressure test 7" scab liner to 3500 psi 7. PU clean out 6 -1/8" Clean out BHA and drill out cement plugs and clean out to top of 7" RBP. 8. Pull RBP. RIH with casing scraper and dress off shoe and dress off tubing stub. 9. Run 4 -1/2" Vamtop 13CR -85 completion with Halliburton TNT packer (Production packer setting depth - 10200' MD) 10. Displace IA to packer fluid and set packer •/ 11. Test tubing and IA to 3500 psi. Freeze protect to 2000' TVD 12. Set BPV. ND BOPE. NU and test tree. RDMO. Drilling Engineer: Ryan Ciolkosz (907)564 -5977 Production Engineer: Laurie Derrick (907)564 -5952 • TREE_ • CIW SAFETY NO S: * * *4 -1/2" CHROME TBG, LNR & WELLHEAD= MCEVOY ig 1OA NIPPLES ** WBS NOT SHOWN BELOW ACTUATOR= BAKER WHIPSTOC KB. ELEV = 64.29' BF. ELEV = 37.24' KOP = 2800' — — I 2096' 1 FOC Max Angle = 61° @ 7000' 2219' H4 -1/2" HES X NIP, ID = 3.813" I Datum MD = ? DatumTVDss= ? 2306' 1 - 5/8" DV PKRI GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I-) 2675' ■ ST MD ND DEV TYPE VLV LATCH PORT DATE ILI 4 3452 3445 12 KGB2 DMY BK 0 08/17/10 3 6318 5699 61 KGB2 DMY BK 0 08/17/10 Minimum ID = 3.725" @ 10478' 2 9150 7239 30 KGB2 DMY BK 0 02/26/09 4-1/2" HES XN NIPPLE 1 10220 8240 18 KGB2 DMY BK 0 02/26/09 5578' 1 X 7" BKR HRD ZXPN LTP, ID = 6.28" I IP 5594' J - 19 - 5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.31" I 9 -5/8" WHIPSTOCK H 5750' 0 , 1 1 • � �1 ∎ 1 s1� MILLOUT WINDOW (B -10A) 5737' - 5753' I 19 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" I—) 10011' 10299' I- -I4 - 1/2" HES X NIP, ID = 3.813" I ii eI✓ 4 � 10371' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.870" I % ', PERFORATION SUMMARY Ii REF LOG: 10405' I— I4 -1/2" HES X NIP, ID = 3.813" I ANGLE AT TOP PERF: 19° @ 10850' 10478' H 4 -1 /2" HES XN NIP, ID = 3.725" I / Note: Refer to Production DB for historical perf data 10478' H4-1/2" XXN PLUG (08/22/10) (,/' SIZE SPF INTERVAL Opn /Sqz DATE 111 r 3 -3/8 6 10850 - 10858 0 03/10/09 10482' — 7" X 5" BKR C-2 ZXP LTP 3 -3/8 6 10850 - 10868 0 04/15/09 w /TIEBACK SLV & FLEXLOCK LNR HGR, ID = 4.400" I 10490' 1 - 112" WLEG, ID = 3.958" I 1 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, — 10490' 10511' I X 4 -1/2" XO, ID = 3.958" I .0152 bpf, ID = 3.958" 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 10645' li I PBTD H 11104' 1 04 1 4 I4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I — I 11190' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/24/78 ? ORIGINAL COMPLETION 06/02/09 CJN/TLH GLV C/O WELL: B -10A 07/11/90 NI ES RWO CORRECTION (11/16/06) 04/13/10 JR/JMD DRLG DRAFT CORRECTIONS PERMIT No: 8 2082050 04/10/08 D14 RWO SUSPENDED 09/05/10 SV GLV C/O (08/17/10) API No: 50- 029 - 20321 -01 -00 03/02/09 N2ES SIDETRACK (B -10A) 09/05/10 SV SET XXN PLUG (08/22/10) SEC 31, T11 N, R14E, 2070' FNL & 1611' FEL 03/18/09 RRK/SV PERF (03/10/09) 05/29/09 MV/TLH PERFS (04/18/09) BP Exploration (Alaska) TREE= CM/ SAFETY ***4-1/2" CHROME TBG, LNR & WELLHEAD = MCEVOY RI = B-1 OA IOPOSED NIPPLES * * *O G WBS NOT SHOWN BELOW ACTUATOR= BAKER C WHIPSTOCK * ** KB. ELEV = 64.29' BF. ELEV = 37.24' I KOP = 2800' 2096' H9-5/8" FOCI Max Angle = 61° @ 7000' ' 114 -1/2" HES X NIP, ID = 3.813" I Datum MD = ? Datum TVDss= ? — 2306' I -19 -5/8" DV PKR GAS LIFT . tNDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.347"11 2675' I-4 ST MD TVD DEV TYPE VLV LATCH PORT r 4 3611 3600 12 KGB2 DMY BK 0 9 -5/8" X 7" BKR HRD ZXPN LTP H 4280 3 6423 5750 61 KGB2 DMY BK 0 2 8984 7100 30 KGB2 DMY BK 0 9 -5/8" X 7" BKR HMC LNR HGR H 4296' k4. � � 1 10100 8126 18 KGB2 DMY BK 0 ,I l ►i • 5578' H 9 -5/8" X 7" BKR HRD ZXPN LTP, ID = 6.28" I IIII II X 41 ; II/ l 5594' IH 9 -5/8" X 7" BKR FLIXLOCK LNR HGR, ID = 6.31" I 9 -5/8" WHIPSTOCK I 5750' I* � • ti, •' MILLOUT WINDOW (B -10A) 5737' - 5753' Minimum ID = 3.725" @ 10478' 4. *�� -10262 H4 -1/2" HES X NIP, ID= 3.813" I 4 -1/2" HES XN NIPPLE * -10287 . 11 7" x 4 -1 /2" HES TNT PKR 19 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" I-1 10011' -10312 J-14-1/2" HES X NIP, ID = 3.813" I -10330 H7" X 4.5" Unqiue Overshot I PERFORATION SUMMARY 44 1 ►i� 10371' I�7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" REF LOG: , 10405' H 4 -1/2" HES X NIP, ID = 3.813" I ANGLE AT TOP PERF: 19° @ 10850' 10478' 114 -1/2" HES XN NIP, ID = 3.725" I Note: Refer to Production DB for historical perf data 10478' I-I4 -1/2" XXN PLUG (08/22/10) I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8 6 10850 - 10858 0 03/10/09 j 10482' I- 7" X 5" BKR C-2 ZXP LTP 3 -3/8 6 10850 - 10868 0 04/15/09 w /TIEBACK SLV & FLIXLOCK LNR HGR, ID = 4.400" I 10490' H4-1/2" W LEG, ID = 3.958" I 4 -1 /2" TBG, 12.6 #, 13CR -80 VAM TOP, H 10490' • 11 L 10511' I -15" X 4 -1/2" XO, ID = 3.958" I .0152 bpf, ID = 3.958" 17" LNR, 26 #, L -80 BTC -M, .0383 bpf, ID = 6.276" H 10645' . ` PBTD H 11104' I , g 1 ��j� 4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H 11190' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/24/78 ? ORIGINAL COMPLETION 06/02/09 CJN /TLH GLV C/O WELL: B -10A 07/11/90 NI ES RWO CORRECTION (11/16/06) 04/13/10 JR/JMD DRLG DRAFT CORRECTIONS PERMIT No: 2082050 04/10/08 D14 RWO SUSPENDED 09/05/10 SV GLV C/O (08/17/10) API No: 50- 029 - 20321 -01 -00 03/02/09 N2ES SIDETRACK (B -10A) 09/05/10 SV SET XXN PLUG (08/22/10) SEC 31, T11 N, R14E, 2070' FNL & 1611' FEL 03/18/09 RRK/SV PERF (03/10/09) 05/29/09 MV/TLH PERFS (04/18/09) BP Exploration (Alaska) C~ T~~Q~1//~fl°~a4L ,,. PaoAcrive Di,agNOSric SeavicES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration [Alaska), tnc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 • ~0/L (' 1 J Leak Detection - WLD 02Sep-10 B-10A 2j Signed : ~ . Print Name: 1_a 9 ,;; :, _ _~, Date ` ~; =' ~~~ `~ ? ~ ~'i' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8959 FAX: (907)245-88952 E-MAIL : ~~saa~~~€ar~aet~l~aea~®rvl®c~.e®rrs WEBSITE : unnrnr.as,elaaorslsac ,. ~ _ ~ ~ ~~~#a ~ 4.. _ -._.. .... ~-- ~~~~ BL/ EDE 50-029-20321-01 C:\Documents and Settings\Diane WilliamslDesktop\Tiansmit_BP.docx DATA SUBMITTAL COMPLIANCE REPORT 3r22r2o~ o Permit to Drill 2082050 Well Name/No. PRUDHOE BAY UNIT B-10A Operator BP EXPLORATION {ALASF(/~ INC API No. 50-029-20321-01-00 MD 11190 TVD 9162 Completion Date 3/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION __ Mud Log No Samples No Directional Survey Ye v DATA INFORMATIDN Types Electric or Other Logs Run: DIR, GR, RES PWD, NEU, DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ryp mearrrmi wumuer Name xa~e ~newa no atan: atop ~.n rcecervea ~.ommenr i' pt LIS Verification 5515 11185 Open 4/23/2009 LIS Veri, GR, RPX, RPS, RPM, RPD, ROP, FET, PEF, NPHI, RHOB, FCNT, - NCNT,DRHO ~ d ~ D C Lis 17915 uction/Resistivity 5515 11185 Open 4/23/2009 LIS Veri, GR, RPX, RPS, RPM, RPD, ROP, FET, PEF, NPHI, RHOB, FCNT, NCNT,DRHO ED C 17916~~duction/Resistivity 5737 11190 Open 4/23/2009 EWR Logs in PDS, EMF and CGM graphics og Induction/Resistivity 25 Col 5737 11190 Open 4/23/2009 MD ROP, EWR, DGR, ALD, CTN 25-Feb-2009 Log Induction/Resistivity 25 Col 5342 9162 Open 4/23/2009 TVD EWR, DGR, ALD, CTN 25-Feb-2009 ED C Asc /~ Directional Survey 31 11190 Open 3/13/2009 Rpt Directional Survey 31 11190 Open 3/13/2009 Vell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments s ~ DATA SUBMITTAL COMPLIANCE REPORT 3122/2010 Permit to Drill 2082050 Well Name/No. PRUDHOE BAY UNIT B-10A Operator BP EXPLORATION (ALASI(Ey INC API No. 50-029-20321-01-00 MD 11190 TVD 9162 Completion Date 3/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~/ N Chips Received? Y /la"~ Formation Tops ~! N ~_ Analysis Y ! N Received? Comments: Compliance Reviewed By: Date: s • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, f-__.~ by ,~~. w ~. 5 ~~$ r~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) o~e~ lv~~ros Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-Ot 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-058 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to Iasi NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 . 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 8-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA OPERABLE: B-l0A (PTD #2080) Tubing Integrity Restored ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, May 16, 2009 10:41 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: B-10A (PTD #2082050) Tubing Integrity Restored All, Well B-10A (PTD #2082050) has passed an MITIA on 05/16/09 after setting dummy gas lift valves proving tubing integrity has been restored. The well has been reclassified as Operable and may be brought on-line when convenient for Operations. Please be prepared for the IA pressure to increase due to thermal expansion as the IA v is liquid packed. Thank you, Anna Dude, ~P.~. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Roschinger, Torin T. Sent: Thursday, May 14, 2009 11:33 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB Subject: UNDER EVALUTION: B-l0A (PTD #2082050) TxIA Communication AI I, Well B-10 (PTD #2082050) has been found to have sustained casing pressure on the IA. The TIOs were 250/2060/0 psi on 04/20/09. However, a TIFL was not performed until today due to gas lift and tank issues. The TIFL did fail when the IAP increased 210 psi on an overnight monitor. The well has been reclassified as Under Evaluation and has been placed on a 28-day clock with a start date of 04/20/09. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: Set DGLVs .~ 3. F: MIT-IA to 3000 psi, LLR if fails A wellbore schematic and TIO plot have been included for reference. « File: B-10A.pdf» « File: B-10 TIO Plot.doc» 8/7/2009 OPERABLE: B-l0A (PTD #200) Tubing Integrity Restored ~ Page 2 of 2 Please call with any questions or concerns. Thank you, TOrin Ro5Chinger (filling in for Anna Dube) Well Integrity Engineer Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. x1154 8/7/2009 PBU B-l0A PTD 208-205 5/14/2009 TIO Pressures ~,GGG ~3,GGIa ~,GGG 1.GGG G:il141G9 G3?27iG9 G;~12Gr'G9 G~1G4IG9 G4r~71r'G9 G~~18IG9 G~r2brG9 G51G21G9 G51G9109 -~ Tbg -~ IA ~ OA Q 0,4 -~- aoo~ -~ Q n TREE = 4-1116" GIW 'WELLHEAD= MGEVOY~ 'ACTUATOR= BAKER. C KB. ELEV = 64.3' BF. ELEV = 37.24' KOP = 2800' Max Angle = 61° cr 7000" 'Datum MD = 11190 Datum TVOss= 9162' 4-1/2" CHROMETBG &LNR 2096° 9-518" FOC -~ 2219` 4-1/2" HES X NIP, ID = 3.813" -2306° 9-518" DV COLLAR r;A S I IFT MA Nt~RFI S B-10A e ~-, ;4 1T~T 13-318" GSG, 72#~--~ 2675' L-80 BTRS, ID = 12.347" Expected TOC behind 9-518" casin 541$' 4'~/G1t I~L`. x'b 1~.iti8 1'~i~€~E'~F.. 9-5/8" WHIPSTOCK ~-~ 5750° ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3452 3445 12 KBG2 DOME BK 16 03)07!09 3 6318 5699 61 KBG2 SO BK 20 03107109 2 9150 7239 30 KBG2 DMY BK 0 02126/09 1 10220 8240 18 KBG2 DMY BK 0 02126109 5579` --~ 9-5/8" X 7" BKR HRD ZXP LTP, ID = 6.28" 5594" 9-5/8" X 7" BKR FLEX LOCK HGR, ID = 6.31" 9200' TOP OF CEMENT MILLOUT WINDOW {B-10A) 5737' - 5753' 9-5/8" EZSV 5765' 9-518" Fzsv 9300' 4-112" TUBING S~LIH (XXIXXIXX} 9354' 10299' I- -~ 4-1 /2" HES X NIP, ID = 3.813" ~ 10371° 7" X 4-112" BKR S-3 PKR, ID = 3.870 1t}d{}~` ~ 4-112" HES X NIP. ID = 3.813" 10478' ~-{4-1I2" HES XN NIP, ID = 3.725" 9-518" GSG, 47#, L-80 BTRS, ID = 8.681 " ~ 1 {IQ1 "~ PEKFORATION SUMMARY REF LOG: ANGLE ATTOP PERF; 19° ~ 10850' NMe: Rehr to Production Database for historfcal pert data 3S'1"LE SPF INTERVAL Opn/5qz DATE '8" 6 1 ^0 - ] OE,58 O 03! 10!~ 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" ~ 10490° 7" LNR, 29#, L-80 BTGM, .0383 bpf , ID = 6.276" 10645° 4-1/2" CSC, 12.6#, 13GR-80 VAM TOP, .0152 bpf, ID = 3.958" ~-~ 11190' 104$2' '-{ 7" X 5" BKR G2 LNR TOP PKR, ( ~ w /FLEX LOCK LNR HGR, ID = 4.400" 10490` 4-1/2" WLEG, ID = 3.958" 10501 ° 7' X 5" BKR FLEX-LOCK LNR HGR, ID = 6.31" 10511 ` 5" X 4-1/2" XO, ID = 3.958" 10561' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 10124178 ? ORSGINAL COMPLETIQN 03/18/09 RRK/SV PERF (03/10109) 07111/90 N1ES RWO CORRECTION (11116106} 04110108 D14 RWt7 SUSPENDED 03102/09 N2ES SIDETRACK {B-10A} 03105r'09 PJC DRLG CORRECTIONS 03/07/09 DAV/PJC GLV C/O PRUDHOE BAY UNIT WELL: B-10A PERMIT No: "2082050 API No: 50-029-20321-01 SEC 31, T11N, R14E, 2069' FNL & 1611' FEL BP Exploration (Alaska) STATE OF ALASKA ~~IV~D- ALAS LAND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT Alv~'do~6 2,009 ~~~~~~ 09 ~c..,.l, t'1;~ G°, fvac l''nnc_ i:t~mnll$StUft 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 ~~~~ P ~ p ry o ment ^ Ex lorato ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/10/2009 12. Permit to Drill Number 208-205 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/17/2009 ' 13. API Number 50-029-20321-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/25/2009 ~ 14. Well Name and Number: PBU B-10A ° FNL, 1611 FEL, SEC. 31, T11N, R14E, UM 2070 Top of Productive Horizon: 598' FNL, 1006' FWL, SEC. 05, T10N, R14E, UM 8. KB (ft above MSL): 69.03. Ground (ft MSL): 37.24 15. Field /Pool(s): - Prudhoe Bay Field / Prudhoe Bay Total Depth: 716', FNL, 1081' FWL, SEC. 05, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 10561' 8564' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664056 y- 5948581 Zone- ASP4 10. Total Depth (MD+TVD) 11190' 9162' 16. Property Designation: ADL 028310 & 028313 TPI: x- 666770 y- 5944831 Zone- ASP4 - 5944715 Zone- ASP4 Total De th: x- 666848 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No ubmit ele r ni n rint inf rm i n er 20 AAC 25.0 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 inf rmation per 20 AA 25.071): DIR, GR, RES PWD, NEU, DEN y/fvDo~ ~'~S ~~`MQ S3~a?-~ `T/D 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVO HOLE AMOUNT ' WT. PER FT. GRADE ' TOP BOTTOM TOP BOTTOM SIZE ' CEMENTING RECORD PULLED " x 2 Insulated Condu r Surface 11 rface 11 36" 27 cu ft Ar i et 1 -/" 7 ~ ~ _/~~ P 9- /8" 47# L-80 rfa 57 7' Surf 34 ' 12-1/4" 17 7 cu ft Cla 'G' Perm frost C 7" 26# L- 0 557 ' 1 645' 5222' 45' 8-1/2" 724 u LiteCret 197 u ' -/" 12. r 1 4 4 6-1 124 I 23. Open to production or inject ion? ®Yes ^ No 24. Tuslrrc RecoRD If Yes, IISt each i MD+TVD of To & Bottom Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD ; ( p 6 SPF 3-3/8" Gun Diameter 4-1/2", 12.6#, 13Cr80 10490' 10371' , MD TVD MD TVD 1085U' - 10858' 8840' - 8848' 25. ACID, FRACTURE; CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 150 Bbls Diesel 26. PRODUCTION TEST Date First Production: March 31,2009 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 4/5/2009 HOUrS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 46 GAS-MCF: 2586 WATER-BBL: 1.74 CHOKE SIZE: 95 GAS-OIL RATIO: 55866 Flow Tubing Press. 300 Casing Press: 1660 CALCULATED 24-HouR RATE• OIL-BBL: 185 GAS-MCF: 10343 WATER-BBL: 7 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^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. None J' ~d~. n„W„~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ „ . ~ APR ~ ~ 1009 a~i ~~r oy ~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED: 29. FORMATION TESTS NAME MD TVD Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. WS2 6151' 5618' WS1 6713' 5891' None CM3 7142' 6099' CM2 8204' 6625' CM1 9270' 7345' Top Horizon 9621' 7671' Bottom Horizon 9797' 7939' J KU 9830' 7870' TJE 9853' 7892' TJC 10303' 8319' TJ B 10452' 8460' Top Sag River 10644' 8644' Top Shublik 10672' 8671' Top Sadlerochit 10758' 8754' 45S6 10797' 8790' 42S6 /Top Zone 4A 10867' 8856' TCGL /Top Zone 3 10981' 8964' BCGL /Top Zone 2C 11027' 9008' 23SB /Top Zone 26 11060' 9039' Formation at Total Depth (Name): 23SB /Top Zone 2B 11060' 9039' 30. List of Attachments: Summary of Daily Drilling Reports, Post Well Summary, Well Schematic Diagram, Surveys and aLeak-Off Test. Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra wma Title Drilling Technologist Date PBU B-10A 208-205 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number rmit . / A r v I No. Drilling Engineer: Jovy Roach, 564-4352 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. (real 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 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 TREEi- 4-1/16"CMl DRLG DRAFT B-10A SAF OTES: 4-1/2" CHROMETBG &LNR WELLHEAD= MCEVOY ACTUATOR= KB. ELEV - BAKER C 64.3' BF. ELEV - KOP - 37.24' 2800' Max Angle = 61 ° @ 7000' Datum MD = Datum TVDss= 11190 9162' 13-3/8" CSG, 72#, ~ 2675' L-80 BTRS, ID = 12.347" Expected TOC behind 9-5/8" casin 5414' Minimum ID = 3.725" @ 10478' 4-1I2" HES XN NIPPLE 9-5/8" WHIPSTOCK ~~ 5750' 9-5/8" ¢SV --~ 5765, 9-5/s° ¢sv 9300' 1/2" TUBING STUB (XX/XX/XX) 9354' 2096' 9-5/8" FOC 2219' --~ /2" HES X NIP, ID = 3.813" 2306' 9-518" DV COLLAR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3452 3445 12 KBG2 DOME BK 16 03/07109 3 6318 5699 61 KBG2 SO BK 20 03/07/09 2 9150 7239 30 KBG2 DMY BK 0 02/26/09 1 10220 8240 18 KBG2 DMY BK 0 02/26/09 5578' -j 9-518" X 7" BKR HRD ZXP LTP, ID = 6.28" 5594' 9-5/8" X 7" BKR FLEX LOCK HGR, ID = 6.31" 9200' TOP OF CEMENT \ MILLOUT WINDOW (B-10A) 5737' - 5753' 10299' I--~ 4-1 /2" HES X NIP, ID = 3.813" ~ 10371' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.870 10405' 1 4-1/2" HES X NIP, ID = 3.813" 1047$' ~~ 4-1 /2" HES XN NIP, ID = 3.725" 9-5/8" CSG, 47#, L-80 BTRS, m = 8.681" H 10011' PERFORATION SUMMARY REF LOG: ANGLE ATTOP PERF: 19° ~ 10650' Note: Refer to Production Database Tor historical rt data SI2E SPF INTERVAL OpnlSgz DAZE ~~ra^ ~ ~nR,n_~cw~s n rr~~cvaa 4-1 /2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" ~ 10490' 7" LNR, 29#, L-80 BTGM, .0383 bpf , ID = 6.276" 1064$' 4-1/2" CSG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" ~~ 11190' 10482' ~ 7" X 5" BKR G2 LNR TOP PKR, w 1 FLEX LOCK LNR HGR, ID = 4.400" 10490' ~4-1/2" WLEG, ID=3.958" 10501' 7" X 5" BKR FLEX-LOCK LNR HGR, ID = 6.31" 10511' 5" X 4-112" XO, ID = 3.958" 10561' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 10/24/78 ? ORIGINAL COMPLETION 03/18/09 RRK/SV PERF (03/10/09) 07/11/90 N1 ES RWO CORRECTION (11/16/06) 04/10/08 D14 RWO SUSPENDED 03/02109 N2ES SIDETRACK (B-10A) 03/05/09 PJC DRLG CORRECTIONS 03/07/09 DAV/PJC GLV CIO PRUDHOE BAY UNIT WELL: B-10A PERMIT No: `2082050 API No: 50-029-20321-01 SEC 31, T11N, R14E, 2069' FNL 8~ 1611' FEL BP Exploration (Alaska) BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT , Phase Description of Operations X2/7/2009 19:00 - 00:00 5.00 MOB P PRE Prepare and begin to move rig from 07-08B. Rig was released ~ 19:00. 2/8/2009 00:00 - 01:30 1.50 MOB PRE Move the rig off of the well and onto the other side of the pad and prepare for move to B-Pad. Transported the shop, camp, and pits to B-Pad. 01:30 - 06:00 4.50 MOB PRE Transport the rig from DS 7 to B-Pad. 06:00 - 12:00 6.00 MOB PRE Spot rig over Well B-10A and lay out herculite. Level the sub and place mats in front of the sub. Also place a berm around cellar area. Welder replaced a hinge on the derrick house that was broken. 12:00 - 15:00 3.00 MOB PRE Spot the pit module and hook up the interconnect steam and water lines. 15:00 - 18:00 3.00 MOB PRE Raise the derrick and pin up the cattle chute. Spot the cuttings box, shop, and outside buildings. Complete the pre-spud checklist. -Rig accepted ~ 1800 hrs. 18:00 - 19:00 1.00 MOB PRE Install the 2nd annulus valve. 19:00 - 21:30 2.50 MOB PRE Bridle down while taking on seawater to the pits. 21:30 - 23:00 1.50 WHSUR DECOMP Rig up and perform MIT on the OA to 2000 psi for 30 minutes and chart. Good test. 23:00 - 23:30 0.50 WHSUR DECOMP Rig up on the cellar and prepare to reverse circulate. 23:30 - 00:00 0.50 WHSUR N SFAL DECOMP Respond to 2 bbl leak into secondary containment outside the pits, located the leak in the outside wall of the pill pit. 2/9/2009 00:00 - 01:00 1.00 WHSUR N SFAL DECOMP Wait on SRT to come and investigate our 2bbl seawater spill. After looking at the spill location and talking about our plan on how to dispose of the frozen seawater. We were given the go ahead to continue. 01:00 - 06:00 5.00 WHSUR P DECOMP Rig up DSM lubricator and test to 500 psi. Had issues due to the cold, but after steaming the tree, the BPV pulled free with no issue. Close the master valve, bleed off the tree, and rig down DSM. 06:00 - 07:00 1.00 WHSUR P DECOMP Pre-Job safety meeting and Pre-Spud meeting. 07:00 - 08:30 1.50 WHSUR P DECOMP Rig up to kill the well. 08:30 - 11:30 3.00 WHSUR P DECOMP Reverse circulate 38bbls of diesel out of the tubing at 169 gpmC~ 600 psi. Shut down and switch lines to pump down tubing 310bb1s @ 242gpm and 600psi. All returns out to the cuttings tank. 11:30 - 12:00 0.50 WHSUR P DECOMP Install the TWC 12:00 - 14:00 2.00 WHSUR P DECOMP Test TWC x IA from below to 3500 psi for 30 minutes. Good Test. Test from above to 1000 psi for 10 minutes. Good test. 14:00 - 17:00 3.00 WHSUR P DECOMP Nipple down the tree and remove it from the cellar. Function all lock down screws. 17:00 - 20:00 3.00 WHSUR P DECOMP Nipple up the BOP stack, install the turnbuckles, riser, and mousehole. Air up the boots and fill stack with water to check for leaks. 20:00 - 21:30 1.50 WHSUR P DECOMP Pick up 4" test joint and make up crossover to hanger, TIW, and dart valve. 21:30 - 22:30 1.00 WHSUR P DECOMP Conduct a body test on the BOP stack to 250 psi/3500 psi high. Good test 22:30 - 00:00 1.50 WHSUR N WAIT DECOMP Wait on AOGCC Rep. Jeff Jones to arrive to begin the BOPE test. 2/10/2009 00:00 - 03:30 3.50 BOPSU P DECOMP Test BOPE to 250 PSI low, 3500 PSI high and Hydril to 250 PSI low, 2500 PSI high as per AOGCC. Test witnessed by Jeff rnnieu. oicoicvva ~ ~. w.yo rim i i~ BP EXPLORATION Page 2 of 13 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: B ell Name: B e: Name: From - To -10 -10 REENTE NABOBS NABOBS Hours ' R+COM ALASK 2ES Task PLET A DRI Code ~~ E LLING NPT Start I Rig Rig N Phase Spud Date: 9/20/1978 : 2/8/2009 End: Release: 3/2/2009 umber: Description of Operations 2/10/2009 00:00 - 03:30 3.50 BOPSU P DECOMP Jones with AOGCC. Test witnessed by WSL Chris Kobuck and Tourpusher Ken Helf. Tested the choke manifold, manual and hydraulic choke, HCR, Kill, and dart valve. All tests were good. At approx. 03:30 while tightening the unibolt on the kill line, the driller attempted to pump through the choke line and it was found that the choke line and the kill line were froze up. 03:30 - 08:45 5.25 BOPSU N SFAL DECOMP Thaw kill & choke lines. Blow kill and mud lines. Place another tioga heater in the cellar. 08:45 - 09:45 1.00 BOPSU N WAIT DECOMP Wait for arrival of AOGCC Rep to continue testing. 09:45 - 13:30 3.75 BOPSU P DECOMP Continue testing BOPE with 4" test joint & LD. PU 4-1/2" test joint, test top rams -fail. Witnessed by Jeff Jones AOGCC. 13:30 - 15:30 2.00 BOPSU P DECOMP C/O top rams with spare 3-1/2" x 6" variables. 15:30 - 18:00 2.50 BOPSU P DECOMP Contacted AOGCC Rep John Crisp. Fill stack & lines & start low pressure test while waiting on AOGCC Rep to arrive on location. Finish testing BOPE except for lower VBR's. Witnessed by John Crisp, AOGCC Rep. UD testing tools. 18:00 - 20:30 2.50 BOPSU P DECOMP RU DSM. Remove TWC. RD DSM. 20:30 - 21:30 1.00 BOPSU P DECOMP PJSM with all personnel plus Dan Hebert and Clyde Treybig. 21:30 - 22:30 1.00 PULL P DECOMP MU landing joint and RIH to tubing hanger. BOLDS. Pull hanger to floor. PU - 90k. 22:30 - 00:00 1.50 PULL P DECOMP CBU - 443 gpm ~ 364 psi. LD hanger and landing joint. 2/11/2009 00:00 - 07:00 7.00 PULL P DECOMP Pull 4-1/2" killstring from 5880' and LD. 07:00 - 08:30 1.50 PULL P DECOMP RD tubing handling equipment. Clean and clear rig floor. 08:30 - 09:30 1.00 BOPSU P DECOMP RU and test lower set of rams to 250/3500 psi. Good test. RD testing equipment. 09:30 - 10:00 0.50 DHB P DECOMP Install wear ring. ID - 8.75". 10:00 - 16:00 6.00 DHB P DECOMP PU and RIH with RBP retrieval tool. Single in with DP to 5963'. PU - 115k; SO - 110k. Establish circulation ~ 477 gpm; 1252 psi. 16:00 - 17:00 1.00 DHB P DECOMP Circulate and condition hole. 17:00 - 17:30 0.50 DHB P DECOMP Unlatch RBP at 5963'. PU to 130k, plug free. Immediately get a kick with 75% return flow. Open choke, close preventer, SI well. 11 bbl gain in pits. 17:30 - 00:00 6.50 DHB P DECOMP Monitor casing and drillpipe pressures. SICP - 220 psi; SIDPP - 80 psi. Establish circulation ~ 3 bpm, 200 psi. Circulate surface to surface sweep through the Gas Buster. SI well. SICP - 280 psi; SIDPP - 30 psi. Monitor for 25 minutes. SICP. - 390 psi; SIDPP - 100 psi. Begin second circulation through the gas buster. Establish circulation ~ 3 bpm, 250 psi. SICP and SIDPP still do not match. 120 bbls lost during circulation. Notify Chuck Scheve at AOGCC of event. Close choke and bullhead ~ 98 gpm, 591 psi to displace remaining 147 bbls of well displacement below RBP. 2/12/2009 00:00 - 08:00 8.00 DHB P DECOMP Continue bullhead C~ 98 gpm. At 350 bbls bullheaded, pump pressure C~ 850 psi. SI well. SICP - 860 psi, SIDPP - 740 psi. Monitor for 12 minutes. SICP - 660 psi, SIDPP - 490 psi. Open choke and pump 6 bbls. SICP - 120 psi, SIDPP - 20 psi. CBU C~ 120 gpm with SICP - 220 psi, SIDPP - 150 psi. Lose 45 bbls. Max SICP - 550 psi before dropping to 270 psi then re-climbing to 350 psi. Shut down. SICP - 350 psi, SIDPP - 70 Printed: 3/23/2009 11:14:46 AM # ~ BP EXPLORATION Operations Summary Report Legal Well Name: B-10 Page 3 of 13 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: I Date From - To Hours ', Task Code NPT Phase Description of Operations 2/12/2009 00:00 - 08:00 8.00 DHB P DECOMP psi. Monitor for 10 minutes. SICP - 430 psi, SIDPP - 110 psi. 08:00 - 10:00 2.00 DHB N WAIT DECOMP 10:00 - 12:00 2.00 DHB P DECOMP 12:00 - 16:30 4.50 DHB P DECOMP 16:30 - 18:00 1.50 DHB P DECOMP 18:00 - 21:30 3.50 DHB P DECOMP 21:30 - 22:00 0.50 DHB P DECOMP 22:00 - 00:00 2.00 DHB P DECOMP 2/13/2009 00:00 - 01:30 1.50 DHB P DECOMP 01:30 - 03:00 1.50 DHB P DECOMP 03:00 - 06:00 3.00 DHB P DECOMP 06:00 - 09:00 3.00 DHB P DECOMP Reset RBP at 5962' MD and release. Test to 2000 psi from above for 10 min -good test. CBU ~ 126 gpm. Monitor well - no flow. Wait on orders from town. Circulate to prevent freeze up of lines ~ 122 gpm, 220 psi. Pump dry job and POH from 5962' to 2808'. Found two bad joints and replaced -galled threads. RIH from 2808' to 5959' picking up DP singles. Install TIW valve. PU - 110k, SO - 110k. Swap well above RBP to 9.0 ppg brine. Circulate ~ 580 gpm, 1725 psi. Build 700 bbls and receive additional 580 bbls of 9.0 ppg brine for bullhead operation. PJSM. Unlatch RBP, close preventer, and PU 3' to open RBP bypass valve. No pressure on surface, open preventer. PU 10' past set depth and close preventer. Bullhead 402 bbls, pumping 2 bpm ~ 1160 psi through the drillpipe and 7 bpm C~ 1520 psi through the IA. Monitor well. Pressures bleeding down with SICP matching SIDPP. Bleed down pressures and open preventer. Establish circulation ~ 304 gpm, 630 psi and CBU. At 250 bbls of 350 bbls displacement, gain 12 bbls with gas at surface. SI well and circulate through the gas buster for the remainder of the BU. SICP - 310 psi. SIDPP - 195 psi. Continue circulating. At BU, SICP - 340 psi, SIDPP - 195 psi. At BU + 38 bbls, SICP - 355 psi, SIDPP - 185 psi. At BU + 53 bbls, SICP - 355 psi, SIDPP - 185 psi. SI and monitor well for 10 minutes. SIDPP bled from 80 psi to 50 psi. SICP bled from 350 psi to 340 psi. PJSM. RU to strip in hole. Resume circulation to prevent freezing of lines, taking returns through gas buster while rigging up. At 2:00, SIDPP - 160 psi, SICP - 100 psi. SI well and monitor for 15 minutes. SIDPP - 0 psi, SICP - 0 psi. Open preventer. Fluid level not visible. Turn on hole fill pump and fill hole with 25 bbls. Monitor fluid level, no gas returns. Proceed to RIH, ready to strip in if necessary. RIH from 5959' to 9049'. Fill pipe with another 25 bbls. CBU plus 1000 stks. Circulate at 196 gpm, 360 psi until gas returns show. Take returns thru gas buster at 3 bpm, 290 psi. Set RBP and bullhead 100 bbls at 9 bpm with 2bpm, 960 psi thru the drillpipe and 7 bpm, 1310 psi down the annulus to clear any gas below the RBP back in to the perfs. Bleed down all pressures to zero. rnmea: srzsieuva I I: 14:40 HM BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~ Task Code NPT " Phase ', Description of Operations 2/13/2009 09:00 - 10:00 1.00 DHB P DECOMP Release RBP and RIH to 9300' to verify we can get down to depth for setting the EZSV for squeezing the perfs. 10:00 - 16:30 6.50 DHB P DECOMP POH from 9300' to surface. Found washout in DP in pipe body of one joint and a second washout -washed tooljoint seal face when POH. LD bad joints. Lay down RBP and retrieving tools. Clean and clear rig floor. 16:30 - 19:30 3.00 DHB N RREP DECOMP Repair hydraulic leak on top drive. 19:30 - 22:00 2.50 BOPSU P DECOMP RU test joint and test the following BOPE: 4" dart valve, Choke manifold valve #7, Top Rams, 4" TIW, HCR choke, annular preventer. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP WSL Travis Peltier and NAD Driller Matt Turcotte. RD test equipment. 22:00 - 00:00 2.00 DHB P DECOMP MU EZSV & running tool and RIH to 1030'. 2/14/2009 00:00 - 05:00 5.00 DHB P DECOMP RIH with EZSV from 1030 to 9300'. Set EZSV. 05:00 - 05:45 0.75 REMCM P DECOMP Rig up to establish injection pressures for cement squeeze. Monitor for signs of flow up the annulus -None. 05:45 - 06:00 0.25 REMCM P DECOMP PJSM with crew and service companies for cement squeeze. 06:00 - 07:15 1.25 REMCM P DECOMP Displace DP to fresh water. Establish infectivity at 3 bpm - 1000 psi. Remain stung in to retainer for cement squeeze. 07:15 - 07:45 0.50 REMCM P DECOMP Line up to cementers. Pump 10 bbls fresh water. Test lines to 4000 psi. 07:45 - 08:10 0.42 REMCM P DECOMP Mix & pump 40.5 bbls (195 sx) Class G slurry at 15.8 ppg. 3 bpm at 730 psi at start. 3 bpm at 200 psi at end. Follow with 10 bbls fresh water to clear lines. 08:10 - 08:40 0.50 REMCM P DECOMP Switch to rig pump. Displace & squeeze cement to perfs. 3 bpm at 75 psi at start. 3 bpm at 65 psi at 500 stks. 3 bpm at 55 psi at 1000 stks. Cement hit perfs at 1010 stks. 3 bpm at 500 psi - 1100 stks. 3 bpm at 600 psi - 1150 stks. 2 bpm at 680 psi - 1200 stks. 2 bpm at 750 psi - 1250 stks. 2 bpm at 790 psi - 1260 stks. 2 bpm at 820 psi - 1270 stks. 2 bpm at 840 psi - 1285 stks and SD squeeze. 08:40 - 09:00 0.33 REMCM P DECOMP Pull up and unsting from retainer. Mousehole top single and RD cement line and head pin. Pull 3 stands slowly and allow remaining 8 bbls of cement to fall on top of retainer - approx 100' in 9 5/8" casing. 09:00 - 10:30 1.50 REMCM P DECOMP POH to 9028'. Pump 20 bbl nutplug sweep and circulate ~ 530 gpm, 2450 psi to clean out drillpipe and excess cement. 10:30 - 12:30 2.00 REMCM P DECOMP POH from 9028' to 4566'. Brine flowing up drillpipe -well out of balance. 12:30 - 13:00 0.50 REMCM P DECOMP CBU at 400 gpm, 800 psi. At 12:30, roustabout (spill champion) was on his walk around the rig and saw brine leaking out of pits on back side of complex. Shut down pump, and brine still leaking. Lowered fluid level in trip tank and leak stopped. x5700 called and Spill Response Team responded. 1 bbl spill on pad covering 100 sq. ft. Printetl: 3/23/2009 71:14:4ti Ann W BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABORS 2ES Rig Number: i Date ~~ From - To !Hours Task ', Code ~ NPT ~ Phase Description of Operations 2/14/2009 12:30 - 13:00 0.50 REMCM P DECOMP Continue to CBU. 13:00 - 16:00 3.00 REMCM P DECOMP POH from 4566'. LD EZSV running tool. Clean and clear rig floor. 16:00 - 21:00 5.00 CLEAN P DECOMP MU 9-5/8" cleanout BHA and RIH to 6505'. 21:00 - 21:30 0.50 CLEAN P DECOMP Circulate SS polymer sweep at 500 gpm, 1750 psi. PU - 150k, SO - 125k. 21:30 - 00:00 2.50 CLEAN N RREP DECOMP POH from 6505' to 3621' laying down drillpipe. 2/15/2009 00:00 - 02:30 2.50 CLEAN N RREP DECOMP POH from 3621' to 740' laying down drillpipe. 02:30 - 03:30 1.00 CLEAN N RREP DECOMP RIH with drillpipe in derrick from 740' to 4272'. 03:30 - 05:30 2.00 CLEAN P DECOMP Cut and slip 80' of drilling line. Service top drive. 05:30 - 08:00 2.50 CLEAN N RREP DECOMP POH from 4272' to 740' laying down drillpipe. 08:00 - 09:30 1.50 CLEAN P DECOMP Laydown cleanout BHA. 09:30 - 14:00 4.50 DHB P DECOMP RU E-line. RIH with GR/CCL and EZSV bridge plug. Log hole from 6000' to 5500'. Set EZSV with top at 5759' - 4.5' above a coupling. ,.Test EZSV for 5 mins to 3500 psi ; OK. RD SWS. 14:00 - 15:00 1.00 DHB P DECOMP Test EZSV for 30 mins at 3500 psi -good test. 15:00 - 19:00 4.00 DHB N RREP DECOMP Remove all fluids from pits. Jack pits up and pull herculite under pits. Build berm around entire pit module with 8x8 timbers. 19:00 - 21:30 2.50 DHB N RREP DECOMP Load shed with 4" 14# HT-40 S-135 drillpipe and tally pipe. Refilling pits while loading and tallying drillpipe in shed. 21:30 - 00:00 2.50 STWHIP P WEXIT MU whipstock BHA and RIH to 124'. 2/16/2009 00:00 - 02:30 2.50 STWHIP P WEXIT Continue to MU whipstock BHA and RIH to 859'. 02:30 - 08:30 6.00 STWHIP N RREP WEXIT RIH picking up 4" 14# HT-40 drillpipe 1x1 to 5746'. Fill pipe and circulate 2 drillpipe volumes every 30 jts. PU - 135k, SO - 120k. 08:30 - 09:30 1.00 STWHIP P WEXIT Orient whipstock 56 degrees left. SO i8k and shear to set anchor at 5760'. Overpull 10k to verify set -good set. SO 35k to shear off milling assembly. PU - 135k, SO - 120k. 09:30 - 10:30 1.00 STWHIP P WEXIT Displace well to 9.0 ppg LSND. Circulate ~ 450 m. 10:30 - 0 _ ill window. TOW = 5737. BOW = 5753'. Drill new hole rom 5753' to 5777'. PU - 135k, SO - 120k, RT - 125k. Circulate at 500 gpm, 1410 psi. RPM - 100, TO - 5k. Some cement seen during milling operations. Work mills through window with no pump or rotation. No PU or SO changes, window looks good. Recovered 325 Ibs of metal. POH to 5723'. 18:00 - 19:00 1.00 STWHIP P WEXIT Circulate super sweep around at 500 gpm, 1390 psi. 19:00 - 20:00 1.00 STWHIP P WEXIT Attempt FIT two times to 11.5 ppg EMW, LOT performed. On first attempt, well pressured up slowly to 200 psi after 40 strokes. Bleed off and attempt FIT again. On second attempt, well broke downat 450 psi on the Martin-Decker, EMW - 10.6. Mud weight in & out - 9.0 ppg. , 20:00 - 21:30 1.50 STWHIP P WEXIT Pump dry job and POH from 5723' to 4882'. Well swabbing on way out. Suspect balled up mill and BHA. 21:30 - 22:00 0.50 STWHIP P WEXIT Circulate at 500 gpm, 1390 psi attempting to remove balling material. 22:00 - 23:30 1.50 STWHIP P WEXIT POH from 4882' to 3850'. Well still swabbing. 23:30 - 00:00 0.50 STWHIP P WEXIT Circulate 40 bbl SAP and nutplug sweep at 500 gpm, 1140 psi, attempting to un-ball mills. Printetl: 3/23/2005 11:14:4ti AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABORS 2ES Rig Number: ~ Date I From - To ~ 'Hours Task Code'.. NPT i Phase Description of Operations 2/17/2009 00:00 - 00:30 0.50 STWHIP P WEXIT Continue to circulate SAP and nutplug sweep at 500 gpm, 1120 psi. 00:30 - 02:30 2.00 STWHIP P WEXIT POH from 3850' to 833', to top of whipstock BHA. Swabbing no longer an issue. 02:30 - 06:30 4.00 STWHIP P WEXIT POH from 833' and LD whi stock BHA. Clear & clean rig floor. 06:30 - 07:30 1.00 BOPSU P WEXIT Johnny Wack BOPE. Bleed down choke and kill lines. 07:30 - 11:30 4.00 STWHIP P WEXIT MU drillin BHA to 731'. Upload MWD and pulse test -good test. 11:30 - 17:00 5.50 STWHIP N RREP WEXIT MU two stand and rack back in derrick. RIH from 731' to 5721' picking up drillpipe 1x1. Fill every 20 stands. 17:00 - 18:00 1.00 STWHIP P WEXIT Obtain benchmark ECD clean hole - 9.35 ppg. Slow pump rate 1.8:00 - 00:00 6.00 DRILL P 2/18/2009 00:00 - 12:00 12.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 12/19/2009 100:00 - 12:00 12.001 DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P test on pumps 1 & 2 - 30/45 strokes C~ 280/330 psi. Orient 50 degrees left, slide through window. 1st slide - no problems. 2nd slide - 10k SO, no go. PU and reorient. 3rd slide - no problems. INT1 Drill from 5777' to 6073'. PU - 130k, SO - 115k, ROT - 120k. RPM - 60, TO - 5k / 6k while off / on btm. Pumping at 450 gpm, 1475 / 1600 psi while off / on bottom. Rotating time - .33 hrs, Sliding time - 2.65 hrs. MW in /out - 9.0 ppg. ECD calculated - 9.40 ppg. ECD actual - 9.56 PPg• INT1 Drill from 6073' to 7136'. i PU - 130k, SO - 110k, ROT - 120k. RPM - 100, TO - 5k / 7k while off / on btm. Pumping at 540 gpm, 2300 / 2500 psi while off / on bottom. Rotating time - 1.54 hrs, Sliding time - 4.44 hrs. MW in /out - 9.0+ ppg. ECD calculated - 9.54 ppg. ECD actual - 9.85 ppg. INT1 Drill from 7136' to 8232'. PU - 140k, SO - 130k, ROT - 125k. RPM - 80 to 100, TO - 5.5k / 7k while off / on btm. Pumping at 500 gpm, 2150 / 2500 psi while off / on bottom. Rotating time - 5.55 hrs, Sliding time - 2.25 hrs. MW in /out - 9.1 ppg. ECD calculated - 9.59 ppg. ECD actual - 10.01 ppg. INT1 Drill from 8232' to 8802'. PU - 150k, SO - 117k, ROT - 145k. RPM - 80, TO - 7k / 8k while off / on btm. Pumping at 530 gpm, 2200 / 2500 psi while off / on bottom. Rotating time - 3.87 hrs, Sliding time - 2.74 hrs. MW in /out - 9.1+ppg. ECD calculated - 9.7 ppg. ECD actual - 9.8 PPg• INT1 Drill from 8802' to 9362'. Nflflt8tl: :i/l'3/'LUU`J 11:14:4b HM ! ~ BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2009 12:00 - 00:00 12.00 DRILL P INTi PU - 170k, SO - 125k, ROT - 145k. RPM - 100, TO - 7.5k / 9k while off / on btm. Pumping at 540 gpm, 2750 / 3200 psi while off / on bottom. Rotating time - 2.92 hrs, Sliding time - 5.90 hrs. 12/20/2009 100:00 - 06:00 6.00 DRILL P INT1 06:00 - 07:00 1.00 DRILL N RREP INT1 07:00 - 08:30 1.50 DRILL P INTi 08:30 - 12:00 3.50 DRILL N RREP INT1 12:00 - 15:30 3.50 DRILL P INT1 15:30 - 17:00 1.50 DRILL P INTi 17:00 - 18:30 1.50 DRILL P INT1 18:30 - 22:00 3.50 DRILL N RREP INT1 22:00 - 00:00 2.00 DRILL P 12/21/2009 100:00 - 12:00 12.001 DR`LL P INTi INT1 Spike MW up at 9240'. MW in /out - 10.1 ppg. ECD calculated - 10.49 ppg. ECD actual - 10.85 ppg. Drill from 9362' to 9595'. PU - 170k, SO - 130k, ROT - 150k. RPM - 90, TO - 7k / 8k while off / on btm. Pumping at 531 gpm, 2975 / 3500 psi while off / on bottom. MW in /out - 10.1 ppg / 10.2 ppg. ECD calculated - 10.75 ppg. ECD actual - 11.02 ppg. C/O gauge assembly on Mud Pump #1 pulsation dampner bladder. Drill from 9595' to 9616'. PU - 170k, SO - 130k, ROT - 150k. RPM - 90, TO - 7k / 8k while off / on btm. Pumping at 531 gpm, 2975 / 3500 psi while off / on bottom. Rotating time - 1.83 hrs, Sliding time - 2.17 hrs since 00:00. MW in /out - 10.1 ppg / 10.2 ppg. ECD calculated - 10.75 ppg. CD actual - 10.88 ppg. Trip to shoe to fix pulsation dampner. POH from 9616' to 7042'. PU - 190k, SO - 130k. MW in /out - 10.1 ppg / 10.2 ppg. Ream out of hole from 7042' to 5780' ~ 80 RPM. TO - 8k to 14k. POH while MAD Passing C~3 300 fph from 5780' to 5566', pumping at 500 gpm C~ 2000 psi. No rotation or pumping while going across the window. Cut and slip drilling line. Service top drive. Adjust brakes on drawworks. RIH from 5566' to 9488'. From 8970' to 9018', took 10 - 15k weight down. Wiped section and RIH with no problems. Wash down from 9488' to 9616' circulating at 450 gpm ~ 2900 psi. PU - 175k, SO - 120k. Drill from 9616' to 9674'. PU - 170k, SO - 130k, ROT - 150k. RPM - 80, TO - 7k / 9k while off / on btm. Pumping at 500 gpm, 3200 / 3500 psi. while off / on bottom. Rotating time - 0.85 hrs, Sliding time - 0.43 hrs. MW in /out - 10.1 ppg. ECD calculated - 10.75 ppg. ECD actual - 10.87 ppg. Drill from 9674' to 10,219'. Printed: 3/23/2009 11:14:46 AM ~ ~ BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 2/21/2009 00:00 - 12:00 12.00 DRILL P INTi 12:00 - 21:30 I 9.501 DRILL I P 21:30 - 22:30 ~ 1.00 ~ DRILL ~ P PU - 190k, SO - 135k, ROT - 160k. RPM - 80, TO - 8.5k / 9.5k while off / on btm. Pumping at 485 gpm, 2732 / 3000 psi while off / on bottom. Rotating time - 3.39 hrs, Sliding time - 4.69 hrs. MW in /out - 10.1 ppg / 10.2 ppg. ECD calculated - 10.57 ppg. ECD actual - 10.62 ppg. INTi Drill from 10,219' to TD at 10,645'. Drilling brake at 10,639', reverse drillin brake at 10 642'. PU - 200k, SO - 135k, ROT - 155k. RPM - 80, TO - 9k / 10k while off / on btm. Pumping at 480 gpm, 3200 / 3370 psi while off / on bottom. Rotating time - 3.33 hrs, Sliding time - 2.44 hrs. MW in /out - 10.1 ppg. ECD calculated - 10.61 ppg. ECD actual - 10.68 ppg. INTi CBU and take sam les to verify casing point. Glauconite found in samoles. Circulate at 500 gpm, 3200 psi. 22:30 - 00:00 1.50 DRILL P INT1 Perform slow pump rate test. Pump 12.1 ppg weighted sweep at 500 gpm, 3200 psi. Sweep back to surface at 23:45. MW after sweep - 10.1+ ppg in, 10.2 ppg out. 2/22/2009 00:00 - 01:30 1.50 DRILL P INT1 Wiper trip. Pulled smooth from TD to 9392'. Slight overpull (5k - 10k) from 9860' to 9840'. Wiped section 1x and pulled smooth. PU - 215k, SO - 130k. 01:30 - 02:30 1.00 DRILL P INT1 RIH from 9390' to 10,550', smooth run. Wash down last stand to 10,645'. Circulate 480 gpm at 3200 psi, RPM - 80. 02:30 - 05:00 2.50 DRILL P INTi Pump 12.1 ppg weighted sweep. Circulate 1 more bottoms up. Shut down and monitor well. ECD calculated - 10.61 ppg. ECD actual - 10.68 ppg. MW in / out - 10.1+ ppg 05:00 - 11:00 6.00 DRILL P INT1 Pump dry job. POH from 10,645' to 5627' Drop ball and open circ sub. Continue to POH to 731' Drop ball and close circ - sub, flush BHA with fresh water. 11:00 - 14`.30 3.50 DRILL P INT1 Lay down BHA. Clean and clear rig floor. 14:30 - 18:30 4.00 CASE P LNR1 C/O 3-1/2" x 6" variable rams to 7" rams. RU testing equipment and test BOPE to 250/3500 psi -good test. RD testing equipment. 18:30 - 19:30 1.00 CASE P LNR1 RU to run 7" liner. 19:30 - 00:00 4.50 CASE P LNR1 MU 7" shoe track. ill and check floats -good check. RIH with 7" liner to 2805'. Average MU TO - 6500 ft-Ibs. 2/23/2009 00:00 - 03:00 3.00 CASE P ~ LNR1 Continue to RIH with 7" liner to 5036'. 126 liner joints total. 03:00 - 04:00 1.00 CASE P LNR1 RIH with Baker liner hanger and packer assembly. Add PAL-MIX protective polymer to hanger and let set for 30 minutes. 04:00 - 04:30 0.50 CASE P LNR1 RU to run liner in on drillpipe. 04:30 - 05:00 0.50 CASE P LNR1 RIH from 5036' to 5629', 108' above TOW. 05:00 - 06:00 1.00 CASE P LNR1 Stage pumps up to 5 bbls over 20 minutes and circulate 220 rnrnea: siesieuua ii:i4:aot+m • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 2/23/2009 05:00 - 06:00 1.00 CASE P LNR1 bbls. 06:00 - 10:00 4.00 CASE P LNR1 RIH from 5629' to 10621'. Fill every 20 stands. PU - 200k, SO 10:00 - 11:00 1.00 CASE P 11:00 - 12:00 1.00 CEMT P 12:00 - 13:30 1.501 CEMT P 13:30 - 14:00 I 0.501 CEMT I P 14:00 - 15:00 I 1.001 CEMT I P 15:00 - 16:00 1.00 CEMT P 16:00 - 18:30 2.50 CEMT P 18:30 - 19:30 1.00 CEMT P 19:30 - 21:00 1.50 BOPSU P 21:00 - 00:00 3.00 BOPSU P 2/24/2009 100:00 - 04:30 I 4.501 BOPSUR P 04:30 - 05:00 0.50 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 11:00 5.00 DRILL P 11:00 - 15:30 I 4.501 DRILL I P - 110k. Circulate C~3 6,568', 7,883'., 9,021' & 9,581'. PJSM with SLB cementers. LNR1 P/U & R/U Top Drive cementing head onto DP single. RIH to bottom at 10,645'. PU to verify 2 times. LNR1 Establish circulation staging up to 5 bpm, 1155 psi, and reciprocate pipe to remove stretch only Pressure test cement lines to 4500 psi -good test. 30 bbls 10.1 ppg LSND lost during RIH and circulations. LNR1 Cement as per plan. -Pump 30 bbls of mudpush C~ 900 psi -Pump 129 bbls of 11.0 LiteCrete @ 950 psi dropping to 400 psi -Pump 35 bbls of 15.8 Class G C~ 300 psi. -Drop dart and cleanout cement lines with 5 bbls water. Turn back over to rig & displace as per plan. Returns seen _ throw hout 'ob with 127 bbls mud lost Burin 'ob. -Dart latches with wiper at 936 strokes, 1150 psi. -Bump plug at 4260 strokes. CIP C~ 13:30 hours. -Pressure up to 3000 psi & SO 40k to set hanger. -Pressure up to 4200 psi to release running tool. -Bleed off and check floats -good check. LNR1 PU 9' to expose dogs, PU - 105k. Slack off 55k, good shear indication. Repeat SO - 55k two more times. Rotate at 15 RPM, and repeat three more times with rotation. Packer set. LNR1 CBU 1.5x ~ 500 gpm, 2300 psi, until returns are c ea-T' n. T~7o`- cement returns to surface. LNR1 RD cementing a uipment. LNR1 POH from 5555' tb;lop of running fool. LNR1 LD 2 singles drillpipe joints and liner running tool. LNR1 Chan a rams from 7" to 3-1/2" x 6" variables. LNR1 Be in BOP testin .Test BOPE to 250 / 3500 psi low -witness waived by AOGCC representative Bob Noble. Test witnessed by BP WSL Travis Peltier and NAD Tourpusher Ken Helf. LNR1 Continue BOP testing. Test ROPE to 250 / 3500 psi low - Good tests. Test Rams with 4" & 4 1/2" test joints. Annular with 4". Witness waived by AOGCC representative Bob Noble. Test witnessed by BP WSL Travis Peltier and NAD Tourpusher Ken Helf. LNR1 Remove Test Plug and clean and clear floor. LNR1 Pressure test casin to 3500 si. for 30 minutes. Good T t. PROD1 Make up the production interval BHA with a 6.125" bit. -6.125" bit -5" motor w/ 1.22 degree bend -MWD -Shallow tested MWD C~ 240 gpm. Good Test - Continue making up the BHA to 394' PROD1 RIH from 394' to 10372'. Filling the pipe every 3000'. Printed: 3/23/2009 11:14:46 AM ! • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABORS ALASKA DR ILLING I Rig Release: 3/2/2009 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task. .Code NPT ~ Phase Description of Operations 2/24/2009 15:30 - 17:00 1.50 DRILL P PROD1 Wash down from 10372' to landin collar ~ 10561'. Attem t to rotate on landin collar, but was unable to. 17:00 - 18:00 1.00 DRILL P PROD1 Dis lace the mud from 10.4 LSND to 8.4 Flo-Pro. 18:00 - 19:00 1.00 DRILL P PROD1 Drill up the landing collar, float collar, and cement to 10645'. Circulate C~ 300 gpm, 2300 psi. -TO on 5k/Off 4k/RPM 60 19:00 - 19:30 0.50 DRILL P PROD1 Drill new formation from 10645' to 10665'. -WOB 5-10k /RPM 60 -TO on 5-6k / TO off 4-5k -300 gpm ~ 2300 psi off/ 2600 psi on 19:30 - 21:00 1.50 DRILL P PROD1 Circulate btms up C~ 300 gpm, 2300 psi 21:00 - 21:30 0.50 DRILL P PROD1 Perform a FIT test to a 10.29 EMW. Good Test 21:30 - 00:00 2.50 DRILL P PROD1 Drill ahead from 10665' to 10722'. -WOB 5-10k /RPM 70 -TO on 5-6k / TO off 4-5k -300 gpm ~ 2300 psi off/ 2550 psi on -ADT 1.02 /ART .67 / AST 1.02 2/25/2009 00:00 - 05:00 5.00 DRILL P PROD1 Drill ahead from 10722' to 11140'. -WOB 5-10k /RPM 100 -TO on 5-6k / TO off 4-5k -300 gpm C~ 2300 psi off/ 2550 psi on 05:00 - 06:00 1.00 DRILL P PROD1 Circulating for samples as per geologist. 06:00 - 08:00 2.00 DRILL P PROD1 Drill ahead from 11140' to 11190' as per geology looking for the. -WOB 5-10k /RPM 80 -TO on 5-6k / TO off 4-5k -300 gpm C~? 2300 psi off/ 2550 psi on -Mud Wt. in and out 8.4ppg 08:00 - 09:00 1.00 DRILL P PROD1 Pull out of the hole dry from 11190' to 10593'. -Up Wt. 185k /Down Wt. 140k -Establish circulation and run back to 11190'. -Mud Wt. in and out 8.4 ppg 09:00 - 11:00 2.00 DRILL P PROD1 Pump a hi-vis sweep Q 300 gpm and 2488 psi. -Back reamed C~ 301 gpm / 2340 psi / 80 rpm from 11190' to 10840'. 11:00 - 12:00 1.00 DRILL P PROD1 MAD pass from 10840' to 10625'. -320fph C~3 300 gpm / 2298 psi / 80 rpm 12:00 - 12:30 0.50 DRILL P PROD1 Pull out of the hole from 10625' to 10559'. 12:30 - 14:00 1.50 DRILL P PROD1 Circulate ~ 300 gpm / 2250 psi at 10559'. -Drop ball to open the circ. sub C~ 500 gpm / 1650 psi -Rotate and reciprocate to clean the casing -Pump a dry job 14:00 - 16:00 2.00 DRILL P PROD1 Pull out of the hole from 10559' to 5667. ~ ' 16:00 - 16:30 0.50 DRILL P PROD1 Circulate (~ 500 gpm / 1250 psi at 5667. -Rotate and reciprocate to clean the casing -Pull out of the hole from 5667' to 5573' -Pump a dry job 16:30 - 18:00 1.50 DRILL P PROD1 Pull out of the hole from. 5573' to 488'. j 18:00 - 18:30 0.50 DRILL P PROD1 Drop ball to close the cit~'"sub ~ 1250 psi. -Flush the BHA with 15bb1 of water. 18:30 - 22:00 3.50 DRILL P PROD1 PJSM. Lay down the BHA, remove the radioactive sources, download the MWD, and clean and clear the floor. 22:00 - 00:00 2.00 CASE P RUNPRD Rig up to run 4.5" 12.6# Vam Top production liner. Change out Printed: 3/23/2009 11:14:46 AM 1 • BP EXPLORATION Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Page 11 of 13 ~ Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task ;Code NPT ', Phase Description of Operations 2/25/2009 22:00 - 00:00 2.00 CASE P RUNPRD the bales, and pick up the handing equipment. 2/26/2009 00:00 - 02:30 2.50 CASE P RUNPRD Make up 4.5" Vam Top 13CR80 Production Liner and liner 02:30 - 03:30 1.00 CASE P RUNPRD 03:30 - 04:30 1.00 CASE P RUNPRD 04:30 - 10:00 5.50 CASE P RUNPRD 10:00 - 11:00 1.00 CASE P RUNPRD 11:00 - 12:00 1.00 CASE P RUNPRD 12:00 - 14:00 2.00 CEMT P RUNPRD hanger to 715'. - aker~ lock the shoe track, check floats, held -Continue to make up a total of 16 jts. -Average make up TO 4,400 Wlb Rig down 4.5" casing equipment and rig up to run in on drillpipe. Make up stand to TD and circulate 24 bbls (~ 5bpm / 100 psi - Up Wt. 37k /Down Wt. 40k Run in the hole with the 4.5" Vam Too 13CR80 Production liner on drillpipe from 820' to 10609'. -Break circulate every 20 stands C~ 5bpm Establish circulation C~ 3bpm and work up to 5bpm. Run in hole from 10609' to 11190'. Make up cement head and establish circulation ~ 5bpm. -Up Wt. 180k /Down Wt. 136k Production liner cement job - Pump 5 bbls 10.5 ppg MudPush II -Pressure tested lines to 4500 PSI; tested good - Pumped 22 bbls/106 sks 15.8ppg GASBLOK tail at 5 BPM - Kick out DP wiper dart w/20 bbl pert pill - Displaced w/rig pumps - Dart latched at 1780 strokes - Bumped plug at 1940 strokes - Pressured up to 4000 PSI to verify hanger is set - Slacked off 80K - Bled pressure to 0 PSI to check floats; floats held - Pressured up to 700 PSI and. slacked off 65K to set packer - Pulled up above liner top packer and circulated out excess cement - Received 6 bbls of cement to surface - Cement in place at 1322 14:00 - 15:00 1.00 CEMT P RUNPRD Laydown the cement head and circ. the lines clear of cement. Blowdown and circulate retarded water through mud manifold and surface equipment. 15:00 - 16:30 1.50 CEMT P RUNPRD Displace well to 8.5ppg seawater. -500 gpm C~ 1960 psi 16:30 - 21:00 4.50 CEMT P RUNPRD Pull out of the hole laying down drillpipe from 10430' to 5303'. 21:00 - 22:30 1.50 CEMT P RUNPRD Slip and cut 129' of drilling line. 22:30 - 00:00 1.50 CEMT P RUNPRD Continue to pull out of the hole laying down drillpipe from 5303' to 2996'. 2/27/2009 00:00 - 04:00 4.00 CEMT P RUNPRD Continue out of the hole laying down drillpipe from 2996'. 04:00 - 05:00 1.00 BOPSU P RUNCMP Pull the wear bushing and pressure test the casing to 3500 psi for 30 minutes. Good Test. 05:00 - 07:30 2.50 BUNCO P RUNCMP Begin to rig up for 4.5" completion. -Change out the bails, rig up the double stack tongs, and compensator. 07:30 - 09:00 1.50 BUNCO P RUNCMP Make up tail pipe, X Nipple, and Packer. -Baker Lock all connections 09:00 - 11:30 2.50 BUNCO P RUNCMP Run in hole with 4.5" 13Cr80 Vam Top completion from 138' to 1323'. Average o 4,4 s 11:30 - 12:30 1.00 BUNCO RREP RUNCMP Stabbing board motor was leaking hydraulic oil. Printetl: 3/23/2009 11:14:46 AM ~ ~ BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~' Task Code NPT Phase Description of Operations 2/27/2009 12:30 - 00:00 11.50 BUNCO P RUNCMP Continue in the hole with 4.5" 13CR80 Vam Top completion from 1323' to 10490'. Average TO of 4,400 ft/Ibs. -Up Wt. 135k /Down Wt. 112k -Tagged 22.50' in on Jt. 245. Picked up and rotated 1/4 turn 4 times to verify no-go depth. Completion Consisted of: -WLEG -XN Nipple -X Nipple -Baker S-3 Packer -X Nipple -4 GLM's -X Nipple -243 Jts of 4.5" 13Cr80 Vam Top - 9.73', 9.67', and 3.85' Pup Jts 2/28/2009 00:00 - 03:00 3.00 BUNCO P RUNCMP ace out com letion with 9.73',9.67', and 3.85' pups. Make up tubing head, land, and run in lockdown screws. -Up Wt. 135k /Down Wt. 110k 03:00 - 07:00 4.00 BUNCO P RUNCMP Reverse circulate in 110 bbls of seawater, 203 bbls of corrosion inhibited seawater, and 185 bbls of seawater. -3 bpm @ 230 psi 07:00 - 08:30 ~ 1.50 RUNCMP set the test 08:30 - 10:00 1.50 BUNCO DFAL RUNCMP Waiting on Schlumberger slickline 10:00 - 18:00 8.00 BUNCO DFAL RUNCMP Rig up Schlumberger and RIH with the catcher sub. Run in hole with retrieval tool for the dummy shear, unable to get in pocket. POH and change out the tool and pull dummy with DCR and verified it had sheared. RIH with dummy. 1.8:00 - 19:00 1.00 BUNCO P RUNCMP Pressure test the annulus to 3500_ psi for 30 minutes to verify 19:00 - 23:00 4.00 BUNCO DFAL RUNCMP Run in hole with Schlumberger retrieval tool and pull the dummy valve. Then RIH and pull out catcher sub. Rig down Schlumberger. 23:00 - 23:30 0.50 BUNCO P RUNCMP Pump down the annulus at 3 bpm C~? 160 psi and pump down the tubing 3 bpm ~ 300 psi. Confirm we can pump both ways. 23:30 - 00:00 0.50 BUNCO P 3/1/2009 00:00 - 02:00 2.00 BOPSU P 02:00 - 06:00 I 4.001 WHSUR I P 06:00 - 07:30 1.50 WHSUR P 07:30 - 09:00 1.50 WHSUR P 09:00 - 22:00 I 13.001 WHSUR I N RUNCMP I Install the TWC and test from below and above to 1000 psi for 10 minutes. Good Test RUNCMP Ni le down the BOPE and chain it back to prepare it for the rig move. RUNCMP Nipple up the tree and adaptor flange. Test adaptor flange to 5000 psi for 30 minutes. Good Test. Test the tree to 5000 psi for 10 minutes. Good Test. RUNCMP Install and pressure test the lubricator to 500 psi. Good Test. RUNCMP Displace to completion fluid and rig up to freeze protect. Little Red having issues getting in postion due to the weather. WAIT RUNCMP Due to 50+ mph winds, Phase 3 was called and all rig Printed: 3/23/2009 11:14:46 AM • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: B-10 Common Well Name: B-10 Spud Date: 9/20/1978 Event Name: REENTER+COMPLETE Start: 2/8/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/2/2009 Rig Name: NABORS 2ES Rig Number: .Date From - To Hours ' Task Code 'NPT Phase Description of Operations 3/1/2009 09:00 - 22:00 13.00 WHSUR N WAIT RUNCMP operations were shut down until further notice. 22:00 - 00:00 2.00 WHSUR N WAIT RUNCMP Cleaning the rig of all snow and clearing the pad to be able to spot LRS for freeze protecting the well. 3/2/2009 00:00 - 01:00 1.00 WHSUR N WAIT RUNCMP Continue clearing the pad of snow, so that LRS could spot their trucks to freeze protect. 01:00 - 05:00 4.00 WHSUR N WAIT RUNCMP LRS was attempting to get their trucks started in order to start heating the diesel. Worked on the trucks until 330 when the decision was made to get out a new transport and pump truck in order to freeze protect. 05:00 - 10:00 5.00 WHSUR P RUNCMP Spot and rig up LRS to pump freeze protect. Pump 150bb1 of 110 degree diesel ~ 84 bpm and 500 psi. Let well U-tube for 2.5 hrs. Rig down LRS 10:00 - 11:00 1.00 WHSUR P RUNCMP Install the BPV and test to 1000 psi for 10 minutes. Good Test. 11:00 - 12:00 1.00 WHSUR P RUNCMP Prepare cellar and wellhead. Remove 2nd annulus valve and secure the cellar. Riq released @ 12:00. rnniea: oicaiwvy i i. iv.vo r.m ~ ~ B-10A Well History Date Summary 02/28/09 SET SLIP STOP CATCHER SUB AT 3589' SLM. PULLED STA# 4 DCR SHEAR VLV AT 3472' SLM / 3451' MD. SET DGLV IN STA# 4 AT 3472' SLM / 3451' MD RIG PRESSURE TESTED IA. PULLED STA#4 DGLV AT 3472' SLM 3451' MD. PULLED CATCHER SUB. STA #4 POCKET LEFT OPEN. 03/01/09 T/I/O=Vac/0/0; Pulled 4-1/16" CIW "H" TWC #257 thru tree for 2ES post tree test (Completion). 1-2' ext. used, tagged C~ 108" 03/05/09 T/I/0= Vac/0/0; Pulled 4-1/16" CIW "H" BPV #253 thru tree post 2ES; 1-2' ext. used, tagged C~ 102"; 03/07/09 PULL BALL & ROD FROM 10,472' SLM. PULL ST#3 BK-DGLV AT 6314'SLM (6318'MD). SET BK-LGLV IN ST#4 (3444'SLM/3452'MD) & BK-OGLV IN ST#3 (6314'SLM/6318'MD). 03/08/09 PULLED EMPTY RHC-M PLUG BODY FROM XN NIP @ 10,475'SLM / 10,477' MD. TAG HARD BTM AT 11,097'SLM W/ 3-3/8" DUMMY GUN, S.BLR. NO SAMPLE. 03/09/09 WELL SHUT IN, IA/OA OPEN TO GAUGES ON LOCATION STAND BY FOR WEATHER, RIG UP E- LINE FOR 10' 3.375" POWERJET PERFORATION 03/10/09 8' x 3.375" POWERJET PERFORATION SHOOTING INTERVAL 10850-10858 SWAB SHUT, IA/OA OPEN TO GAUGES 04/03/09 T/I/0=200/1400/40. Temp=50". IA FL (GLE). ALP=1500 psi. IA FL C~3 6318' (sta# 3, S/O). GLR=2.4 mmsfpd. SV=Closed. WV, SSV, MV, ALV=Open IA&OA=OTG. NOVP. 04/05/09 T/I/0=1450/1420/0 Hot to POP. Pumped 5 bbls of neat meth and 135 bbls of crude down TBG. TBG pressured up to 2950 psi. DSO P.O.Ped well. TBG pressure fell to 200 psi. FWHP's 200/ 1500/100 Page 1 of 1 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: B-10 Common Name: B-10 _ _ _ Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW j Surface Pressure Leak Off Pressure (BHP) EMW 2/16/2009 FIT 5,777.0 (ft) 5,373.4 (ft) 9.00 (ppg) 450 (psi) 2,962 (psi) 10.61 (ppg) 2/24/2009 FIT 10,665.0 (ft) 8,651.0 (ft) 8.40 (ppg) 850 (psi) 4,625 (psi) 10.29 (ppg) Printed: 3/23/2009 11:14:39 AM • North America -ALASKA - BP Prudhoe Bay PB B Pad B-10 -Slot 10 B-10A Design: B-10A Survey Report -Geographic 09 March, 2009 • Company: North America -ALASKA - BP Project:. Prudhoe Bay Site: PB B Pad Well: B-10 Wellbore: B-10A Design: 6-10A Survey Report -Geographic Local Co-ordinate Reference: Well B-10 -Slot 10 TVD Reference: Revised RKEi@69.03 022009@ 69.03ft (31.79KE MD Reference: Revised-RKB@69.03 022009 @ 69.03ft (31c79KE North Reference: True Survey Calculation Method: Mihimum Curvature Database: EDM .16 - AncProd - WH24P Project Prudhoe. Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Site PB B Pad, TR-11-14 i Site Position: Northing: 5,946,440.22ft Latitude: 70° 15' 36.475 N From: Map Easting: 662,094.05ft Longitude: 148° 41' 22.843 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 1.23 ° _. Well B-10 -Slot 10, B-10 Well Position +N/-S O.OOft Northing: 5,948,581.OOft Latitude: 70° 15' 57.108 N +E/-W 0.00 ft Easting: 664,056.00 ft Longitude: 148° 40' 24.409 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 37.24ft - _ ;Wellbore -- -- - B-10A Magnetics Model Name Sample Date Decl ination Dip Angle Field Strength BGGM2008 2/17/2009 22.83 80.89 57,697 ~ Design B-10A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5,731.73 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) lft) lft) (°) 31.03 0.00 0.00 147.96 Survey Program Date 3/6/2009 From To ~ (ft) (ft) Survey (Wellbore) Tool Name Description ' 32.93 5,737.00 5,731.73 1 : Schlumberger GCT multishot (B-10) 11,151.84 B-10A MWD+SAG+I IFR+MS (B-10A) GCT-MS MWD+IFR+MS Schlumberger GCT multishot MWD +IFR + Multi Station 3/9/2009 2:42:14PM Page 2 COMPASS 2003.16 Build 70 C~ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB B Pad Well: B-10 Wellbore: B-10A Design: B-10A Survey Measured Vertical Depth Inclination Azimuth Depth (ft) (°) (°) (ft) Survey Report -Geographic Local Co-ordinate Reference: Well B-10 -Slot 10 TVD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE MD Reference: Revised RKB@69.03 022009 @-69.03ft (31.79KE North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Map Map +N/-S +E/-W Northing Easting (ft) (ft) (ft) (ft) Latitude Longitude 31.03 0.00 0.00 31.03 0.00 0.00 5,948,581.00 664,056.00 70° 15' 57.108 N 148° 40' 24.409 W'. 32.93 0.43 328.71 32.93 0.01 0.00 5,948,581.01 664,056.00 70° 15' 57.108 N 148° 40' 24.409 W 39.13 0.33 318.23 39.13 0.04 -0.03 5,948,581.04 664,055.97 70° 15' 57.109 N 148° 40' 24.410 W 46.73 0.18 301.93 46.73 0.06 -0.05 5,948,581.06 664,055.95 70° 15' 57.109 N 148° 40' 24.411 W 54.23 0.15 294.27 54.23 0.07 -0.07 5,948,581.07 664,055.93 70° 15' 57.109 N 148° 40' 24.411 W 62.33 0.18 295.91 62.33 0.08 -0.09 5,948,581.08 664,055.90 70° 15' 57.109 N 148° 40' 24.412 W 76.23 0.22 290.33 76.23 0.10 -0.14 5,948,581.10 664,055.86 70° 15' 57.109 N 148° 40' 24.413 W 92.93 0.22 282.17 92.93 0.12 -0.20 5,948,581.12 664,055.80 70° 15' 57.109 N 148° 40' 24.415 W 109.53 0.20 277.67 109.53 0.13 -0.26 5,948,581.12 664,055.74 70° 15' 57.109 N 148° 40' 24.417 W '', 126.13 0.22 277.18 126.13 0.14 -0.32 5,948,581.13 664,055.68 70° 15' 57.109 N 148° 40' 24.418 W I 142.83 0.27 279.30 142.83 0.15 -0.39 5,948,581.14 664,055.61 70° 15' 57.110 N 148° 40' 24.420 W 159.43 0.28 278.67 159.43 0.16 -0.47 5,948,581.15 664,055.53 70° 15' 57.110 N 148° 40' 24.423 W' 176.03 0.27 276.65 176.03 0.17 -0.55 5,948,581.16 664,055.45 70° 15' 57.110 N 148° 40' 24.425 W ~ 192.63 0.25 277.83 192.63 0.18 -0.62 5,948,581.17 664,055.37 70° 15' 57.110 N 148° 40' 24.427 W 209.33 0.23 283.76 209.33 0.19 -0.69 5,948,581.18 664,055.30 70° 15' 57.110 N 148° 40' 24.429 W 225.93 0.27 294.17 225.93 0.22 -0.76 5,948,581.20 664,055.24 70° 15' 57.110 N 148° 40' 24.431 W 242.53 0.35 300.38 242.53 0.26 -0.84 5,948,581.24 664,055.16 70° 15' 57.111 N 148° 40' 24.433 W 259.13 0.40 297.03 259.13 0.31 -0.93 5,948,581.29 664,055.06 70° 15' 57.111 N 148° 40' 24.436 W 275.83 0.45 293.27 275.83 0.36 -1.05 5,948,581.34 664,054.95 70° 15' 57.112 N 148° 40' 24.439 W 292.43 0.53 289.94 292.43 0.42 -1.18 5,948,581.39 664,054.81 70° 15' 57.112 N 148° 40' 24.443 W 309.13 0.62 284.18 309.13 0.46 -1.34 5,948,581.43 664,054.65 70° 15' 57.113 N 148° 40' 24.448 W 325.83 0.65 277.82 325.82 0.50 -1.52 5,948,581.47 664,054.47 70° 15' 57.113 N 148° 40' 24.453 W ~ 342.53 0.65 271.59 342.52 0.51 -1.71 5,948,581.48 664,054.28 70° 15' 57.113 N 148° 40' 24.459 W'. 359.33 0.63 268.09 359.32 0.51 -1.90 5,948,581.47 664,054.09 70° 15' 57.113 N 148° 40' 24.464 W 376.03 0.58 268.12 376.02 0.51 -2.07 5,948,581.46 664,053.92 70° 15' 57.113 N 148° 40' 24.469 W ~~. 392.73 0.53 271.15 392.72 0.51 -2.23 5,948,581.46 664,053.76 70° 15' 57.113 N 148° 40' 24.474 W 409.43 0.53 281.48 409.42 0.52 -2.39 5,948,581.47 664,053.60 70° 15' 57.113 N 148° 40' 24.478 W ~! 426.13 0.65 291.86 426.12 0.57 -2.55 5,948,581.52 664,053.44 70° 15' 57.114 N 148° 40' 24.483 W ! 442.93 0.82 292.32 442.92 0.66 -2.75 5,948,581.60 664,053.24 70° 15' 57.115 N 148° 40' 24.489 W j 459.73 0.88 288.22 459.72 0.74 -2.98 5,948,581.68 664,053.00 70° 15' 57.115 N 148° 40' 24.496 W 476.33 0.85 276.93 476.31 0.80 -3.23 5,948,581.73 664,052.76 70° 15' 57.116 N 148° 40' 24.503 W 492.83 0.73 266.66 492.81 0.80 -3.45 5,948,581.73 664,052.53 70° 15' 57.116 N 148° 40' 24.510 W 509.33 0.65 265.79 509.31 0.79 -3.65 5,948,581.71 664,052.33 70° 15' 57.116 N 148° 40' 24.515 W' 525.83 0.60 271.07 525.81 0.79 -3.83 5,948,581.70 664,052.15 70° 15' 57.116 N 148° 40' 24.521 W', 542.33 0.67 282.68 542.31 0.81 -4.01 5,948,581.72 664,051.97 70° 15' 57.116 N 148° 40' 24.526 W 558.83 0.83 288.18 558.81 0.87 -4.22 5,948,581.78 664,051.76 70° 15' 57.117 N 148° 40' 24.532 W 575.33 0.90 284.22 575.31 0.94 -4.46 5,948,581.84 664,051.52 70° 15' 57.117 N 148° 40' 24.539 W 591.83 0.87 273.14 591.80 0.98 -4.71 5,948,581.87 664,051.27 70° 15' 57.118 N 148° 40' 24.546 W' 608.23 0.73 264.03 608.20 0.97 -4.94 5,948,581.86 664,051.04 70° 15' 57.118 N 148° 40' 24.553 W 'i 624.83 0.65 263.58 624.80 0.95 -5.14 5,948,581.84 664,050.84 70° 15' 57.117 N 148° 40' 24.558 W 641.23 0.58 269.01 641.20 0.94 -5.31 5,948,581.82 664,050.67 70° 15' 57.117 N 148° 40' 24.564 W 657.73 0.68 280.52 657.70 0.95 -5.49 5,948,581.84 664,050.49 70° 15' 57.118 N 148° 40' 24.569 W 674.23 0.83 285.08 674.20 1.00 -5.70 5,948,581.88 664,050.28 70° 15' 57.118 N 148° 40' 24.575 W 690.73 0.72 279.90 690.70 1.05 -5.92 5,948,581.92 664,050.06 70° 15' 57.118 N 148° 40' 24.581 W 707.23 0.60 276.00 707.20 1.08 -6.11 5,948,581.95 664,049.87 70° 15' 57.119 N 148° 40' 24.587 W it 723.73 0.60 272.82 723.69 1.09 -6.28 5,948,581.96 664,049.70 70° 15' 57.119 N 148° 40' 24.592 W i, 740.13 0.58 266.17 740.09 1.09 -6.45 5,948,581.95 664,049.53 70° 15' 57.119 N 148° 40' 24.597 W', 756.63 0.47 260.34 756.59 1.07 -6.60 5,948,581.93 664,049.38 70° 15' 57.119 N 148° 40' 24.601 W 773.03 0.32 270.12 772.99 1.06 -6.71 5,948,581.92 664,049.27 70° 15' 57.119 N 148° 40' 24.604 W 789.53 0.28 273.87 789.49 1.07 -6.80 5,948,581.92 664,049.18 70° 15' 57.119 N 148° 40' 24.607 W 806.03 0.30 261.70 805.99 1.06 -6.88 5,948,581.91 664,049.10 70° 15' 57.119 N 148° 40' 24.609 W 822.53 0.25 246.63 822.49 1.04 -6.96 5,948,581.89 664,049.02 70° 15' 57.118 N 148° 40' 24.611 W ~, 839.03 0.10 249.82 838.99 1.02 -7.00 5,948,581.87 664,048.98 70° 15' 57.118 N 148° 40' 24.613 W I~ 855.53 0.05 294.15 855.49 1.02 -7.02 5,948,581.87 664,048.96 70° 15' 57.118 N 148° 40' 24.613 W I, 871.93 0.12 303.86 871.89 1.03 -7.04 5,948,581.88 664,048.94 70° 15' 57.118 N 148° 40' 24.614 W j 3/9/2009 2.•42:14PM Page 3 COMPASS 2003.16 Build 70 • Survey Report -Geographic • Company: North America -ALASKA - BP Local Co-ordinate Reference: Well B-10 -Slot 10 Project: Prudhoe Bay TVD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE Site: PB B Pad MD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE Well: B-10 North Reference: True Wellbore: B-1 OA Survey Calculation Method: Minimum Curvature Design: B-10A Database: EDM .16 - Anc Prod - WH24P ,Survey Measured Vertical Map Map i Depth I nclination Azimuth Depth +N/-S +E/-W Northing Fasting t (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude ~ 888.43 0.15 258.72 888.39 1.04 -7.08 5,948,581.88 664,048.90 70° 15' 57.118 N 148° 40' 24.615 W ~ 905.03 0.15 210.59 904.99 1.02 -7.11 5,948,581.86 664,048.87 70° 15' 57.118 N 148° 40' 24.616 W' 921.43 0.10 153.21 921.39 0.98 -7.12 5,948,581.83 664,048.86 70° 15' 57.118 N 148° 40' 24.616 W !, 938.03 0.08 62.23 937.99 0.98 -7.10 5,948,581.82 664,048.88 70° 15' 57.118 N 148° 40' 24.616 W'. 954.43 0.12 319.88 954.39 1.00 -7.10 5,948,581.84 664,048.88 70° 15' 57.118 N 148° 40' 24.616 W ~i j 970.93 0.13 250.82 970.89 1.00 -7.13 5,948,581.85 664,048.85 70° 15' 57.118 N 148° 40' 24.617 W I 987.53 0.10 198.59 987.49 0.98 -7.15 5,948,581.83 664,048.83 70° 15' 57.118 N 148° 40' 24.617 W ~ 1,004.03 0.08 111.20 1,003.99 0.96 -7.15 5,948,581.81 664,048.84 70° 15' 57.118 N 148° 40' 24.617 W I ~ 1,020.63 0.10 27.72 1,020.59 0.97 -7.13 5,948,581.82 664,048.85 70° 15' 57.118 N 148° 40' 24.616 W 1,037.13 0.13 339.71 1,037.09 1.00 -7.13 5,948,581.85 664,048.85 70° 15' 57.118 N 148° 40' 24.616 W 1,053.63 0.12 298.76 1,053.59 1.03 -7.15 5,948,581.87 664,048.83 70° 15' 57.118 N 148° 40' 24.617 W ~ 1,070.23 0.05 0.82 1,070.19 1.04 -7.16. 5,948,581.89 664,048.81 70° 15' 57.118 N 148° 40' 24.618 W 1,086.73 0.08 66.52 1,086.69 1.06 -7.15 5,948,581.90 664,048.82 70° 15' 57.119 N 148° 40' 24.617 W' 1,103.23 0.15 41.93 1,103.19 1.08 -7.13 5,948,581.92 664,048.85 70° 15' 57.119 N 148° 40' 24.616 W' ' 1,119.83 0.17 11.73 1,119.79 1.12 -7.11 5,948,581.96 664,048.87 70° 15' 57.119 N 148° 40' 24.616 W'' 1,136.33 0.13 336.04 1,136.29 1.16 -7.11 5,948,582.00 664,048.86 70° 15' 57.120 N 148° 40' 24.616 W 1,152.93 0.08 332.35 1,152.89 1.19 -7.12 5,948,582.03 664,048.85 70° 15' 57.120 N 148° 40' 24.616 W 1,169.43 0.07 357.27 1,169.39 1.21 -7.13 5,948,582.05 664,048.84 70° 15' 57.120 N 148° 40' 24.617 W I, 1,186.03 0.17 5.58 1,185.99 1.24 -7.13 5,948,582.09 664,048.85 70° 15' 57.120 N 148° 40' 24.616 W !~ 1,202.63 0.27 356.28 1,202.59 1.30 -7.13 5,948,582.15 664,048.84 70° 15' 57.121 N 148° 40' 24.617 W it 1,219.13 0.32 342.69 1,219.09 1.39 -7.14 5,948,582.23 664,048.83 70° 15' 57.122 N 148° 40' 24.617 W I 1,235.63 0.42 328.78 1,235.59 1.48 -7.19 5,948,582.33 664,048.78 70° 15' 57.123 N 148° 40' 24.618 W 1,252.33 0.48 320.42 1,252.29 1.59 -7.27 5,948,582.43 664,048.70 70° 15' 57.124 N 148° 40' 24.621 W' 1,268.83 0.47 320.41 1,268.79 1.69 -7.35 5,948,582.53 664,048.61 70° 15' 57.125 N 148° 40' 24.623 W I. 1,285.43 0.47 327.79 1,285.39 1.80 -7.43 5,948,582.64 664,048.53 70° 15' 57.126 N 148° 40' 24.625 W', 1,301.83 0.57 332.06 1,301.79 1.93 -7.51 5,948,582.77 664,048.45 70° 15' 57.127 N 148° 40' 24.628 W ~i 1,318.13 0.73 330.83 1,318.09 2.10 -7.60 5,948,582.93 664,048.36 70° 15' 57.129 N 148° 40' 24.630 W', 1,334.43 0.80 326.54 1,334.39 2.28 -7.71 5,948,583.11 664,048.24 70° 15' 57.131 N 148° 40' 24.633 W ~'I 1,350.73 0.77 322.21 1,350.68 2.46 -7.84 5,948,583.29 664,048.11 70° 15' 57.132 N 148° 40' 24.637 W I 1,367.03 0.70 323.16 1,366.98 2.63 -7.97 5,948,583.46 664,047.98 70° 15' 57.134 N 148° 40' 24.641 W I 1,383.43 0.70 327.90 1,383.38 2.79 -8.08 5,948,583.62 664,047.86 70° 15' 57.136 N 148° 40' 24.644 W 1,399.73 0.77 330.61 1,399.68 2.97 -8.19 5,948,583.80 664,047.75 70° 15' 57.137 N 148° 40' 24.647 W', 1,416.13 0.83 329.72 1,416.08 3.17 -8.30 5,948,583.99 664,047.63 70° 15' 57.139 N 148° 40' 24.651 W 1,432.43 0.83 326.70 1,432.38 3.37 -8.42 5,948,584.19 664,047.50 70° 15' 57.141 N 148° 40' 24.654 W 'i 1,448.73 0.78 323.20 1,448.68 3.56 -8.56 5,948,584.37 664,047.37 70° 15' 57.143 N 148° 40' 24.658 W !. ' I 1,465.03 0.73 322.42 1,464.97 3.73 -8.69 5,948,584.54 664,047.24 70° 15' 57.145 N ~ 148° 40' 24.662 W 1,481.33 0.72 325.99 1,481.27 3.90 -8.81 5,948,584.71 664,047.11 70° 15' 57.146 N 148° 40' 24.665 W 1,497.73 0.77 330.18 1,497.67 4.08 -8.92 5,948,584.89 664,046.99 70° 15' 57.148 N 148° 40' 24.669 W 1,514.03 0.83 330.44 1,513.97 4.28 -9.03 5,948,585.08 664,046.88 70° 15' 57.150 N 148° 40' 24.672 W !, ' ' 1 530.33 0.83 327.31 1,530.27 4.48 -9.15 5,948,585.28 664,046.75 70° 15' 57.152 N ', 148° 40' 24.675 W , 1,546.63 0.75 321.74 1,546.57 4.66 -9.28 5,948,585.46 664,046.62 70° 15' 57.154 N 148° 40' 24.679 W ~~ ~ 1,562.83 0.63 316.28 1,562.77 4.81 -9.41 5,948,585.60 664,046.49 70° 15' 57.155 N I 148° 40' 24.683 W 1,579.13 0.58 316.17 1,579.06 4.94 -9.53 5,948,585.73 664,046.37 70° 15' 57.157 N 148° 40' 24.686 W I ' 1,595.43 0.60 319.91 1,595.36 5.06 -9.64 5,948,585.85 664,046.25 70° 15' 57.158 N 148° 40' 24.690 W !, 1,611.73 0.63 319.50 1,611.66 5.19 -9.75 5,948,585.98 664,046.13 70° 15' 57.159 N 148° 40' 24.693 W I 1,628.03 0.63 311.21 1,627.96 5.32 -9.88 5,948,586.10 664,046.01 70° 15' 57.160 N 148° 40' 24.697 W !~ 1,644.33 0.58 298.59 1,644.26 5.42 -10.02 5,948,586.20 664,045.86 70° 15' 57.161 N 148° 40' 24.701 W' I 1,660.63 0.52 290.04 1,660.56 5.48 -10.16 5,948,586.26 664,045.72 70° 15' 57.162 N 148° 40' 24.705 W ''~. it 1,676.93 0.47 295.06 1,676.86 5.54 -10.29 5,948,586.31 664,045.59 70° 15' 57.163 N 148° 40' 24.709 W 1,693.13 0.48 302.30 1,693.06 5.60 -10.41 5,948,586.37 664,045.47 70° 15' 57.163 N 148° 40' 24.712 W 1,709.43 0.52 299.02 1,709.36 5.67 -10.53 5,948,586.44 664,045.35 70° 15' 57.164 N 148° 40' 24.716 W 1,725.73 0.53 292.40 1,725.66 5.74 -10.67 5,948,586.51 664,045.21 70° 15' 57.165 N 148° 40' 24.719 W 1,742.03 0.53 285.64 1,741.96 5.79 -10.81 5,948,586.55 664,045.07 70° 15' 57.165 N 148° 40' 24.724 W i 1,758.23 0.48 278.67 1,758.16 5.82 -10.95 5,948,586.58 664,044.93 70° 15' 57.165 N 148° 40' 24.728 W 1,774.53 0.43 278.06 1,774.46 5.84 -11.08 5,948,586.59 664,044.80 70° 15' 57.166 N 148° 40' 24.731 W ~ 3/9/2009 2:42:14PM Page 4 COMPASS 2003.16 Build 70 • • Survey Report -Geographic Company: North America -ALASKA - BP Local Co-ordinate Reference: Well B-10 -Slot 10 Project: Prudhoe Bay TVD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE Site: PB B Pad MD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE Well: B-10 North Reference: True Wellbore: B-10A Survey Calculation Method: Minimum Curvature Design: B-10A Database: EDM .16 - Anc Prod - WH24P i~ Survey Measured Vertical Map Map i ~ Depth I nclination Azimuth Depth +N/S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1,790.73 0.43 287.35 1,790.66 5.86 -11.19 5,948,586.62 664,044.68 70° 15' 57.166 N 148° 40' 24.735 W'. 1,807.03 0.52 292.91 1,806.95 5.91 -11.32 5,948,586.66 664,044.55 70° 15' 57.166 N 148° 40' 24.738 W I 1,823.23 0.55 291.31 1,823.15 5.97 -11.46 5,948,586.72 664,044.41 70° 15' 57.167 N 148° 40' 24.743 W'I 1,839.53 0.55 287.91 1,839.45 6.02 -11.61 5,948,586.77 664,044.26 70° 15' 57.167 N 148° 40' 24.747 W ~' 1,855.73 0.48 280.91 1,855.65 6.06 -11.75 5,948,586.80 664,044.12 70° 15' 57.168 N 148° 40' 24.751 W 1,872.03 0.37 274.65 1,871.95 6.07 -11.87 5,948,586.81 664,044.00 70° 15' 57.168 N 148° 40' 24.754 W I, 1,888.23 0.33 282.41 1,888.15 6.09 -11.97 5,948,586.83 664,043.90 70° 15' 57.168 N 148° 40' 24.757 W', 1,904.53 0.38 292.01 1,904.45 6.12 -12.06 5,948,586.85 664,043.81 70° 15' 57.168 N 148° 40' 24.760 W I ~ 1,920.73 0.42 289.95 1,920.65 6.16 -12.17 5,948,586.89 664,043.70 70° 15' 57.169 N j 148° 40' 24.763 W 1,937.03 0.40 285.89 1,936.95 6.20 -12.28 5,948,586.93 664,043.59 70° 15' 57.169 N 148° 40' 24.766 W ' 1,953.23 0.32 271.22 1,953.15 6.21 -12.38 5,948,586.94 664,043.49 70° 15' 57.169 N i 148° 40' 24.769 W 1 969.43 0.22 260.73 1,969.35 6.21 -12.45 5,948,586.94 664,043.41 70° 15' 57.169 N 148° 40' 24.771 W , 1,985.63 0.18 277.60 1,985.55 6.21 -12.51 5,948,586.93 664,043.36 70° 15' 57.169 N 148° 40' 24.773 W ~i, i 2,001.93 0.25 290.65 2,001.85 6.22 -12.57 5,948,586.95 664,043.30 70° 15' 57.169 N 148° 40' 24.775 W 'I 2,018.13 0.30 283.84 2,018.05 6.24 -12.64 5,948,586.97 664,043.22 70° 15' 57.170 N 148° 40' 24.777 W ', 2,034.23 0.28 271.31 2,034.15 6.26 -12.72 5,948,586.98 664,043.14 70° 15' 57.170 N 148° 40' 24.779 W'. 2,049.83 0.27 262.73 2,049.75 6.25 -12.80 5,948,586.97 664,043.07 70° 15' 57.170 N 148° 40' 24.781 W 2,062.93 0.23 250.32 2,062.85 6.24 -12.85 5,948,586.96 664,043.01 70° 15' 57.170 N 148° 40' 24.783 W', 2,073.93 0.22 222.40 2,073.85 6.22 -12.89 5,948,586.93 664,042.98 70° 15' 57.169 N 148° 40' 24.784 W 2,084.13 0.20 195.20 2,084.05 6.18 -12.91 5,948,586.90 664,042.96 70° 15' 57.169 N 148° 40' 24.785 W 2,094.03 0.22 185.92 2,093.95 6.15 -12.91 5,948,586.87 664,042.96 70° 15' 57.169 N 148° 40' 24.785 W'i 2,103.93 0.32 184.46 2,103.85 6.10 -12.92 5,948,586.82 664,042.95 70° 15' 57.168 N 148° 40' 24.785 W 2,113.83 0.42 180.85 2,113.75 6.04 -12.92 5,948,586.76 664,042.95 70° 15' 57.168 N 148° 40' 24.785 W'! 2,123.73 0.50 177.94 2,123.65 5.96 -12.92 5,948,586.68 664,042.96 70° 15' 57.167 N 148° 40' 24.785 W I 2,133.73 0.65 173.83 2,133.65 5.86 -12.91 5,948,586.58 664,042.97 70° 15' 57.166 N 148° 40' 24.785 W 2,144.13 0.78 167.36 2,144.05 5.73 -12.89 5,948,586.45 664,042.99 70° 15' 57.165 N 148° 40' 24.784 W 2,156.43 0.82 159.96 2,156.35 5.57 -12.84 5,948,586.29 664,043.04 70° 15' 57.163 N 148° 40' 24.783 W 2,171.23 0.85 156.93 2,171.14 5.37 -12.76 5,948,586.09 664,043.13 70° 15' 57.161 N 148° 40' 24.780 W I 2,187.73 0.93 157.23 2,187.64 5.13 -12.66 5,948,585.85 664,043.23 70° 15' 57.159 N 148° 40' 24.778 W ! 2,204.33 1.00 157.36 2,204.24 4.87 -12.55 5,948,585.60 664,043.34 70° 15' 57.156 N 148° 40' 24.774 W I ' 2,220.93 1.10 156.77 2,220.84 4.59 -12.43 5,948,585.32 664,043.47 70° 15' 57.153 N 148° 40' 24.771 W I 2,237.53 1.15 153.50 2,237.43 4.30 -12.30 5,948,585.03 664,043.61 70° 15' 57.150 N 148° 40' 24.767 W I 2,254.03 1.12 150.70 2,253.93 4.01 -12.14 5,948,584.74 664,043.77 70° 15' 57.148 N 148° 40' 24.762 W 2,270.53 1.10 150.08 2,270.43 3.73 -11.99 5,948,584.47 664,043.94 70° 15' 57.145 N 148° 40' 24.758 W i 2,287.13 1.12 150.72 2,287.02 3.45 -11.83 5,948,584.19 664,044.10 70° 15' 57.142 N 148° 40' 24.753 W'~ I 2,303.73 1.17 151.59 2,303.62 3.16 -11.67 5,948,583.91 664,044.27 70° 15' 57.139 N 148° 40' 24.749 W 2,320.23 1.25 151.31 2,320.12 2.85 -11.50 5,948,583.60 664,044.44 70° 15' 57.136 N 148° 40' 24.744 W I 2,336.83 1.38 151.07 2,336.71 2.52 -11.32 5,948,583.27 664,044.63 70° 15' 57.133 N 148° 40' 24.738 W 2,353.33 1.52 150.71 2,353.21 2.16 -11.11 5,948,582.91 664,044.84 70° 15' 57.129 N 148° 40' 24.733 W it 2,369.93 1.55 148.49 2,369.80 1.77 -10.89 5,948,582.53 664,045.07 70° 15' 57.126 N 148° 40' 24.726 W ~ 2,386.43 1.50 146.96 2,386.30 1.40 -10.65 5,948,582.17 664,045.32 70° 15' 57.122 N 148° 40' 24.719 W 2,403.03 1.50 148.32 2,402.89 1.03 -10.42 5,948,581.81 664,045.56 70° 15' 57.118 N 148° 40' 24.712 W 2,419.53 1.52 151.04 2,419.38 0.66 -10.20 5,948,581.44 664,045.79 70° 15' 57.115 N 148° 40' 24.706 W ~, 2,436.13 1.53 152.48 2,435.98 0.27 -9.99 5,948,581.05 664,046.00 70° 15' 57.111 N 148° 40' 24.700 W' 2,452.73 1.55 152.81 2,452.57 -0.13 -9.79 5,948,580.66 664,046.22 70° 15' 57.107 N 148° 40' 24.694 W I 2,469.23 1.57 153.56 2,469.07 -0.53 -9.59 5,948,580.26 664,046.43 70° 15' 57.103 N ° ' 148° 40' 24.688 W I ° ' 2,485.83 1.62 154.70 2,485.66 -0.94 -9.38 5,948,579.85 664,046.64 57.099 N 70 15 24.682 W 40 148 2,502.43 1.65 154.07 2,502.25 -1.37 -9.18 5,948,579.43 664,046.85 70° 15' 57.095 N 148° 40' 24.676 W', 2,518.93 1.63 153.72 2,518.75 -1.79 -8.97 5,948,579.01 664,047.07 70° 15' 57.090 N 148° 40' 24.670 W' 2,535.53 1.62 155.59 2,535.34 -2.22 -8.77 5,948,578.59 664,047.28 70° 15' 57.086 N 148° 40' 24.664 W i, 2,552.13 1.62 157.32 2,551.93 -2.65 -8.58 5,948,578.16 664,047.48 70° 15' 57.082 N 148° 40' 24.659 W 2,568.73 1.63 158.66 2,568.53 -3.09 -8.41 5,948,577.73 664,047.66 70° 15' 57.078 N 148° 40' 24.654 W '~~ 2,585.33 1.68 158.40 2,585.12 -3.53 -8.23 5,948,577.29 664,047.85 70° 15' 57.073 N 148° 40' 24.649 W 2,601.93 1.67 157.54 2,601.71 -3.98 -8.05 5,948,576.84 664,048.04 70° 15' 57.069 N 148° 40' 24.643 W 2,618.43 1.58 158.47 2,618.21 -4.42 -7.87 5,948,576.41 664,048.22_ 70° 15' 57.065 N_ 148° 40' 24.638 W 3/9/2009 2:42:14PM Page 5 COMPASS 2003.16 Build 70 • • Survey Report -Geographic Company: North America -ALAS KA - BP Local Co-ordinate Reference: Well B-10 -Slot 10 Project: Prudhoe Bay TVD Reference: Revised R KB@69.03 022009 @ 69.03ft (31.79KE Site: PB B Pad MD Refere nce: Revised R KB@69.03 022009 @ 69.03ft (31.79KE Well: B-10 North Reference: True Wellbore: B-10A Survey Calculation Method: Minimum Curvature Design: B-10A Database: EDM .16 - Anc Prod - WH24P ~i Survey I __~ I Measured Vertical Map Map ~ I it Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2,635.03 1.53 160.04 2,634.80 -4.84 -7.71 5,948,576.00 664,048.39 70° 15' 57.061 N 148° 40' 24.634 W I 2,651.63 1.48 161.90 2,651.39 -5.25 -7.57 5,948,575.59 664,048.54 70° 15' 57.057 N 148° 40' 24.629 W ~ 2,668.23 1.47 163.33 2,667.99 -5.66 -7.44 5,948,575.18 664,048.68 70° 15' 57.053 N 148° 40' 24.626 W 2,684.83 1.47 163.34 2,684.58 -6.07 -7.32 5,948,574.78 664,048.81 70° 15' 57.048 N 148° 40' 24.622 W 2,701.43 1.52 163.56 2,701.18 -6.48 -7.20 5,948,574.37 664,048.94 70° 15' 57.044 N 148° 40' 24.619 W 2,718.03 1.58 161.51 2,717.77 -6.91 -7.06 5,948,573.94 664,049.09 70° 15' 57.040 N 148° 40' 24.615 W 2,734.63 1.60 157.46 2,734.37 -7.34 -6.90 5,948,573.51 664,049.26 70° 15' 57.036 N 148° 40' 24.610 W 2,751.33 1.83 150.14 2,751.06 -7.79 -6.68 5,948,573.07 664,049.49 70° 15' 57.032 N 148° 40' 24.603 W i~ 2,767.93 2.35 140.61 2,767.65 -8.28 -6.33 5,948,572.59 664,049.85 70° 15' 57.027 N 148° 40' 24.593 W 2,784.53 2.85 135.43 2,784.23 -8.84 -5.83 5,948,572.04 664,050.37 70° 15' 57.021 N 148° 40' 24.579 W 2,801.13 3.32 132.76 2,800.81 -9.46 -5.18 5,948,571.43 664,051.02 70° 15' 57.015 N 148° 40' 24.560 W it 2,817.73 3.65 131.02 2,817.37 -10.13 -4.43 5,948,570.78 664,051.79 70° 15' 57.009 N 148° 40' 24.538 W 2,834.33 3.92 129.81 2,833.94 -10.84 -3.60 5,948,570.09 664,052.64 70° 15' 57.002 N 148° 40' 24.514 W 2,850.93 4.18 128.61 2,850.50 -11.58 -2.69 5,948,569.36 664,053.56 70° 15' 56.994 N 148° 40' 24.487 W I 2,867.53 4.42 127.98 2,867.05 -12.35 -1.71 5,948,568.62 664,054.56 70° 15' 56.987 N 148° 40' 24.459 W !i 2,884.23 4.72 127.55 2,883.70 -13.17 -0.66 5,948,567.82 664,055.63 70° 15' 56.979 N 148° 40' 24.428 W' 2,900.63 4.95 127.36 2,900.04 -14.01 0.44 5,948,567.01 664,056.74 70° 15' 56.970 N 148° 40' 24.396 W 'i 2,916.93 5.18 127.56 2,916.28 -14.88 1.58 5,948,566.16 664,057.90 70° 15' 56.962 N 148° 40' 24.363 W', I 2,933.33 5.43 128.02 2,932.60 -15.81 2.78 5,948,565.25 664,059.12 70° 15' 56.953 N 148° 40' 24.328 W , 2,949.63 5.65 128.57 2,948.83 -16.79 4.01 5,948,564.31 664,060.38 70° 15' 56.943 N 148° 40' 24.292 W '; 2,966.03 5.87 129.09 2,965.15 -17.82 5.29 5,948,563.30 664,061.68 70° 15' 56.933 N 148° 40' 24.255 W'~ 2,982.33 6.03 129.41 2,981.36 -18.89 6.60 5,948,562.26 664,063.01 70° 15' 56.922 N 148° 40' 24.217 W 2,998.73 6.18 129.88 2,997.67 -20.00 7.95 5,948,561.18 664,064.38 70° 15' 56.911 N 148° 40' 24.178 W 3,015.03 6.32 130.31 3,013.87 -21.14 9.30 5,948,560.07 664,065.76 70° 15' 56.900 N 148° 40' 24.138 W' 3,031.33 I 6.42 130.33 3,030.07 -22.31 10.68 5,948,558.93 664,067.16 70° 15' 56.889 N 148° 40' 24.098 W li ; 3,047.63 6.57 130.65 3,046.26 -23.51 12.08 5,948,557.76 664,068.59 70° 15' 56.877 N 148° 40' 24.057 W I 3,064.03 6.72 131.24 3,062.55 -24.76 13.52 5,948,556.55 664,070.05 70° 15' 56.865 N 148° 40' 24.016 W 3,080.33 6.82 131.60 3,078.74 -26.03 14.96 5,948,555.31 664,071.52 70° 15' 56.852 N 148° 40' 23.974 W ~ 3,096.63 6.93 132.00 3,094.92 -27.33 16.41 5,948,554.04 664,073.00 70° 15' 56.839 N 148° 40' 23.931 W', ~ 3,112.93 7.08 132.45 3,111.10 -28.66 17.88 . 5,948,552.74 664,074.50 70° 15' 56.826 N 148° 40' 23.889 W i 3,129.23 7.22 132.80 3,127.27 -30.04 19.38 5,948,551.40 664,076.02 70° 15' 56.813 N 148° 40' 23.845 W' ~ 3,144.33 7.42 133.33 3,142.25 -31.35 20.78 5,948,550.11 664,077.46 70° 15' 56.800 N ', 148° 40' 23.804 W 3,162.43 7.67 133.61 3,160.19 -32.99 22.51 5,948,548.52 664,079.22 70° 15' 56.784 N 148° 40' 23.754 W 3,185.33 7.83 133.71 3,182.88 -35.12 24.74 5,948,546.43 664,081.50 70° 15' 56.763 N 148° 40' 23.689 W 3,217.23 8.13 134.40 3,214.48 -38.20 27.92 5,948,543.42 664,084.75 70° 15' 56.732 N 148° 40' 23.596 W ', 3,249.63 8.57 134.58 3,246.53 -41.50 31.28 5,948,540.20 664,088.17 70° 15' 56.700 N 148° 40' 23.499 W'; 3,282.03 9.00 134.77 3,278.55 -44.97 34.80 5,948,536.80 664,091.77 70° 15' 56.666 N 148° 40' 23.396 W 3,314.43 9.43 135.40 3,310.53 -48.65 38.46 5,948,533.20 664,095.51 70° 15' 56.630 N 148° 40' 23.290 W '', II 3,346.93 9.97 136.16 3,342.57 -52.57 42.28 5,948,529.36 664,099.41 70° 15' 56.591 N 148° 40' 23.178 W' 3,379.43 10.55 137.00 3,374.55 -56.78 46.26 5,948,525.25 664,103.48 70° 15' 56.550 N 148° 40' 23.063 W 3,412.03 11.17 137.96 3,406.57 -61.31 50.41 5,948,520.81 664,107.73 70° 15' 56.505 N 148° 40' 22.942 W 3,444.63 11.88 138.85 3,438.51 -66.18 54.73 5,948,516.03 664,112.15 70° 15' 56.457 N 148° 40' 22.816 W 3,477.13 12.63 139.74 3,470.27 -71.41 59.23 5,948,510.90 664,116.76 70° 15' 56.406 N 148° 40' 22.685 W' 3,509.63 13.38 140.64 3,501.93 -77.03 63.91 5,948,505.39 664,121.57 70° 15' 56.351 N 148° 40' 22.549 W 3,542.23 14.10 141.51 3,533.60 -83.05 68.77 5,948,499.47 664,126.56 70° 15' 56.291 N 148° 40' 22.407 W 3,574.83 14.83 142.54 3,565.17 -89.47 73.78 5,948,493.16 664,131.71 70° 15' 56.228 N 148° 40' 22.262 W', 3,607.53 15.65 143.65 3,596.72 -96.35 78.94 5,948,486.40 664,137.02 70° 15' 56.161 N 148° 40' 22.112 W', 3,640.13 16.45 144.56 3,628.05 -103.65 84.22 5,948,479.22 664,142.46 70° 15' 56.089 N 148° 40' 21.958 W ; 3 672.63 17.20 145.21 659.15 3 -111.34 89.63 5,948,471.64 664,148.03 70° 15' 56.013 N 148° 40' 21.800 W I , 3,704.83 17.93 145.83 , 3,689.85 -119.36 95.13 5,948,463.75 664,153.71 70° 15' 55.934 N I 148° 40' 21.640 W ~ 3,736.93 18.67 146.61 3,720.33 -127.73 100.74 5,948,455.50 664,159.49 70° 15' 55.852 N 148° 40' 21.477 W I 3,769.13 19.30 147.41 3,750.78 -136.52 106.44 5,948,446.84 664,165.38 70° 15' 55.765 N 148° 40' 21.311 W' 3,801.33 19.90 148.06 3,781.11 -145.65 112.21 5,948,437.84 664,171.34 70° 15' 55.676 N 148° 40' 21.143 W 0 7 3,865.83 ~ 21 .53 148.94 3,841.46 -165.07 124.09 5,948,418.68 664,183.65 70° 15' 55.485 N 97 W j ,148 40' 20. _ __._ 3/9/2009 2:42:14PM Page 6 COMPASS 2003.16 Build 70 • Survey Report -Geographic • Company: North America -ALASKA - BP Local Co-ordinate Reference: WeII B-10 -Slot 10 Project: Prudhoe Bay TVD Reference: Revised RKB@69.03 022009 @ 69.03ft {31.79KE Site: PB B Pad MD Refere nce: Revised RKB@69.03 022009 @ 69.03ft (31.79KE Well: B-10 North Reference: True Wellbore: B-10A Survey Calculation Method: Minimum Curvature Design: B-10A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3,898.03 22.52 149.34 3,871.31 -175.44 130.29 5,948,408.45 664,190.07 70° 15' 55.383 N 148° 40' 20.617 W ~i 3,930.33 23.47 149.79 3,901.04 -186.32 136.68 5,948,397.72 664,196.69 70° 15' 55.276 N 148° 40' 20.431 W'~ 3,962.63 24.30 150.18 3,930.57 -197.64 143.22 5,948,386.54 664,203.48 70° 15' 55.164 N 148° 40' 20.241 W ''. 3,995.03 25.10 150.49 3,960.01 -209.41 149.92 5,948,374.92 664,210.43 70° 15' 55.049 N 148° 40' 20.046 W '' 4,027.33 25.93 150.80 3,989.16 -221.54 156.74 5,948,362.95 664,217.52 70° 15' 54.929 N 148° 40' 19.847 W I 4,059.73 26.87 151.11 4,018.18 -234.13 163.73 5,948,350.51 664,224.78 70° 15' 54.805 N 148° 40' 19.644 W ~i 4,092.03 27.90 151.40 4,046.86 -247.16 170.88 5,948,337.64 664,232.21 70° 15' 54.677 N 148° 40' 19.436 W I 4,124.43 28.83 151.67 4,075.37 -260.69 178.21 5,948,324.28 664,239.84 70° 15' 54.544 N 148° 40' 19.222 W 4,156.83 29.72 151.83 4,103.63 -274.64 185.71 5,948,310.49 664,247.64 70° 15' 54.407 N 148° 40' 19.004 W 4,189.13 30.53 152.04 4,131.57 -288.95 193.34 5,948,296.35 664,255.57 70° 15' 54.266 N 148° 40' 18.782 W; 4,221.53 31.28 152.40 4,159.37 -303.67 201.09 5,948,281.80 664,263.65 70° 15' 54.122 N I 148° 40' 18.557 W i 4,253.93 32.13 152.98 4,186.93 -318.80 208.90 5,948,266.85 664,271.79 70° 15' 53.973 N 148° 40' 18.329 W I 4,286.33 33.15 153.63 4,214.21 -334.42 216.75 5,948,251.41 664,279.97 70° 15' 53.819 N 148° 40' 18.101 W '~; 4,318.73 34.07 154.01 4,241.20 -350.51 224.66 5,948,235.49 664,288.23 70° 15' 53.661 N 148° 40' 17.871 W j 4,351.03 34.87 154.32 4,267.83 -366.96 232.63 5,948,219.22 664,296.55 70° 15' 53.499 N 148° 40' 17.639 W I 4,383.53 35.57 154.82 4,294.38 -383.89 240.68 5,948,202.47 664,304.97 70° 15' 53.333 N 148° 40' 17.405 W'. 4,416.03 36.30 155.36 4,320.69 -401.19 248.71 5,948,185.35 664,313.38 70° 15' 53.162 N 148° 40' 17.171 W' 4,448.33 37.12 155.74 4,346.59 -418.77 256.70 5,948,167.96 664,321.75 70° 15' 52.990 N 148° 40' 16.938 W'.. 4,480.43 37.95 155.85 4,372.04 -436.60 264.72 5,948,150.30 664,330.15 70° 15' 52.814 N 148° 40' 16.705 W', 4,512.43 38.55 154.93 4,397.17 -454.61 272.97 5,948,132.47 664,338.79 70° 15' 52.637 N 148° 40' 16.465 W'i 4,544.33 38.82 152.71 4,422.07 -472.50 281.77 5,948,114.78 664,347.98 70° 15' 52.461 N 148° 40' 16.209 W i~ 4,576.23 39.33 150.78 4,446.84 -490.21 291.29 5,948,097.28 664,357.88 70° 15' 52.287 N 148° 40' 15.932 W 4,608.13 40.28 149.85 4,471.34 -507.95 301.40 5,948,079.77 664,368.38 70° 15' 52.112 N 148° 40' 15.637 W I 4,640.13 40.87 148.85 4,495.65 -525.86 312.01 5,948,062.10 664,379.37 70° 15' 51.936 N 148° 40' 15.329 W 4,672.03 40.30 147.43 4,519.88 -543.49 322.97 5,948,044.72 664,390.71 70° 15' 51.763 N 148° 40' 15.010 W 4,704.13 39.38 146.45 4,544.52 -560.72 334.18 5,948,027.73 664,402.30 70° 15' 51.593 N 148° 40' 14.684 W 4,736.23 39.05 146.18 4,569.39 -577.61 345.44 5,948,011.10 664,413.92 70° 15' 51.427 N 148° 40' 14.356 W 4,768.43 39.08 146.10 4,594.40 -594.46 356.74 5,947,994.50 664,425.59 70° 15' 51.262 N 148° 40' 14.027 W 4,800.53 39.20 145.96 4,619.29 -611.26 368.07 5,947,977.95 664,437.27 70° 15' 51.096 N 148° 40' 13.697 W 4,832.73 39.10 145.69 4,644.26 -628.08 379.48 5,947,961.38 664,449.05 70° 15' 50.931 N 148° 40' 13.365 W ~ 4,864.83 39.08 145.53 4,669.18 -644.78 390.92 5,947,944.93 664,460.85 70° 15' 50.767 N ! 148° 40' 13.033 W 4,897.03 39.05 145.57 4,694.18 -661.52 402.40 5,947,928.45 664,472.69 70° 15' 50.602 N 148° 40' 12.698 W' 4,929.23 38.92 145.73 4,719.21 -678.24 413.83 5,947,911.98 664,484.48 70° 15'50.438 N 148° 40' 12.366 W 4,961.43 39.00 145.88 4,744.25 -694.99 425.21 5,947,895.49 664,496.22 70° 15' 50.273 N 148° 40' 12.035 W '~ 4 993.63 39.03 146.02 4 769.27 -711.79 436.56 5,947,878.95 664,507.93 70° 15' 50.108 N 148° 40' 11.704 W ~ , 5,025.83 38.93 146.17 , 4,794.30 -728.60 447.85 5,947,862.39 664,519.59 70° 15' 49.942 N 148° 40' 11.376 W 5,058.13 38.87 146.23 4,819.43 -745.45 459.14 5,947,845.78 664,531.24 70° 15' 49.777 N 148° 40' 11.047 W ~' 5,090.43 38.70 146.29 4,844.61 -762.28 470.38 5,947,829.21 664,542.84 70° 15' 49.611 N 148° 40' 10.720 W' 5,122.83 38.42 146.40 4,869.95 -779.09 481.57 5,947,812.65 664,554.40 70° 15' 49.446 N 148° 40' 10.395 W 5,155.23 38.42 146.54 4,895.33 -795.87 492.69 5,947,796.11 664,565.88 70° 15' 49.281 N 148° 40' 10.071 W 5,187.73 38.50 146.70 4,920.78 -812.75 503.81 5,947,779.48 664,577.37 70° 15' 49.115 N 148° 40' 9.747 W , ~ 5,219.73 38.50 146.83 4,945.82 -829.41 514.73 5,947,763.06 664,588.64 70° 15' 48.951 N ' 148° 40' 9.430 W 5,251.73 38.70 146.99 4,970.83 -846.14 525.63 5,947,746.58 664,599.90 70° 15' 48.786 N 148° 40' 9.113 W I 5,283.63 38.93 147.14 4,995.69 -862.92 536.50 5,947,730.04 664,611.14 70° 15' 48.621 N 148° 40' 8.796 W 5,315.53 39.12 147.27 5,020.47 -879.80 547.38 5,947,713.39 664,622.38 70° 15' 48.455 N 148° 40' 8.480 W I 5,347.33 39.38 147.34 5,045.10 -896.74 558.25 5,947,696.70 664,633.61 70° 15' 48.289 N 148° 40' 8.163 W', ~' 5,379.23 39.78 147.29 5,069.68 -913.84 569.22 5,947,679.84 664,644.96 70° 15' 48.120 N 148° 40' 7.844 W' 5,411.13 40.12 147.24 5,094.14 -931.07 580.30 5,947,662.86 664,656.41 70° 15' 47.951 N 148° 40' 7.522 W ', 443.13 ~ 5 40.25 147.24 5,118.58 -948.44 591.47 5,947,645.74 664,667.96 70° 15' 47.780 N 148° 40' 7.197 W , 5,475.03 40.33 147.32 5,142.92 -965.79 602.62 5,947,628.64 664,679.48 70° 15' 47.609 N 148° 40' 6.872 W II 5,506.93 40.32 147.40 5,167.24 -983.18 613.76 5,947,611.50 664,690.99 70° 15' 47.438 N 148° 40' 6.548 W I, 5,538.93 40.17 147.45 5,191.66 -1,000.60 624.89 5,947,594.33 664,702.50 70° 15' 47.267 N 148° 40' 6.224 W' 5,571.03 40.03 147.44 5,216.22 -1,018.03 636.01 5,947,577.15 664,714.00 70° 15' 47.096 N 148° 40' 5.901 W 5,603.13 39.95 147.44 5,240.81 -1,035.41 647.12 5,947,560.01 664,725.48 70° 15' 46.925 N 148° 40' 5.578 W 5,635.23 40.17 147.51 5,265.38 -1,052.83 658.22 5,947,542.84 664,736.96 70° 15' 46.753 N 148° 40' 5.254 W 3/9/2009 2:42:14PM Page 7 COMPASS 2003.16 Build 70 i Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB B Pad Well: B-10 Wellbore: B-1 OA Design: B-10A ,Survey Survey Report -Geographic r~ Local Co-ordinate Reference: Well B-10 -Slot 10 TVD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE MD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 5,667.33 40.47 147.53 5,289.85 -1,070.35 669.38 5,947,525.56 664,748.50 70° 15' 46.581 N 148° 40' 4.930 W 5,699.53 40.43 147.54 5,314.36 -1,087.98 680.59 5,947,508.19 664,760.09 70° 15' 46.408 N 148° 40' 4.604 W 5,731.73 40.35 147.56 5,338.88 -1,105.59 691.79 5,947,490.83 664,771.67 70° 15' 46.234 N 148° 40' 4.278 W ~i 5,737.00 40.36 147.56 5,342.90 -1,108.47 693.62 5,947,487.99 664,773.56 70° 15' 46.206 N 148° 40' 4.225 W 5,773.30 40.47 147.76 5,370.54 -1,128.35 706.21 5,947,468.39 664,786.58 70° 15' 46.011 N 148° 40' 3.858 W 5,807.54 41.29 147.95 5,396.42 -1,147.32 718.13 5,947,449.68 664,798.91 70° 15' 45.824 N 148° 40' 3.511 W 5,838.89 42.87 148.11 5,419.69 -1,165.15 729.25 5,947,432.10 664,810.42 70° 15' 45.649 N 148° 40' 3.188 W 5,867.69 43.30 148.26 5,440.72 -1,181.86 739.62 5,947,415.62 664,821.15 70° 15' 45.484 N 148° 40' 2.886 W ~ 5,900.94 44.84 148.42 5,464.61 -1,201.55 751.76 5,947,396.20 664,833.71 70° 15' 45.291 N 148° 40' 2.533 W' 5,932.12 46.34 148.28 5,486.43 -1,220.51 763.45 5,947,377.50 664,845.81 70° 15' 45.104 N 148° 40' 2.193 W 5,962.55 48.06 146.50 5,507.11 -1,239.31 775.48 5,947,358.97 664,858.25 70° 15' 44.919 N 148° 40' 1.843 W' 5,994.79 50.27 144.09 5,528.19 -1,259.36 789.38 5,947,339.23 664,872.58 70° 15' 44.722 N 148° 40' 1.438 W' 6,027.87 52.75 145.99 5,548.78 -1,280.58 804.20 5,947,318.34 664,887.86 70° 15' 44.513 N 148° 40' 1.007 W 6,056.33 54.50 147.09 5,565.66 -1,299.69 816.84 5,947,299.51 664,900.91 70° 15' 44.325 N 148° 40' 0.639 W', 6,086.87 56.02 147.07 5,583.06 -1,320.76 830.47 5,947,278.74 664,915.00 70° 15' 44.118 N 148° 40' 0.243 W 6,122.28 57.40 146.62 5,602.49 -1,345.54 846.66 5,947,254.32 664,931.72 70° 15' 43.874 N 148° 39' 59.772 W :. 6,150.70 59.24 146.85 5,617.42 -1,365.76 859.93 5,947,234.40 664,945.42 70° 15' 43.675 N 148° 39' 59.386 W I 6,183.35 60.64 145.88 5,633.77 -1,389.29 875.58 5,947,211.22 664,961.58 70° 15' 43.444 N 148° 39' 58.930 W' 6,245.19 61.24 145.40 5,663.81 -1,433.91 906.09 5,947,167.28 664,993.06 70° 15' 43.005 N 148° 39' 58.043 W I, 6,339.44 60.92 145.99 5,709.39 -1,502.05 952.58 5,947,100.17 665,041.02 70° 15' 42.335 N 148° 39' 56.690 W' 6,434.02 61.25 145.43 5,755.12 -1,570.45 999.23 5,947,032.80 665,089.14 70° 15' 41.662 N 148° 39' 55.333 W 6,528.09 60.78 145.40 5,800.70 -1,638.20 1,045.94 5,946,966.10 665,137.31 70° 15' 40.996 N 148° 39' 53.974 W I, 6,622.89 61.02 144.63 5,846.81 -1,706.06 1,093.43 5,946,899.29 665,186.27 70° 15' 40.328 N 148° 39' 52.592 W 6,717.61 60.15 144.14 5,893.33 -1,773.14 1,141.48 5,946,833.28 665,235.76 70° 15' 39.669 N 148° 39' 51.195 W 6,811.42 61.19 144.54 5,939.28 -1,839.59 1,189.15 5,946,767.89 665,284.87 70° 15' 39.015 N 148° 39' 49.808 W', 6,905.90 61.22 144.80 5,984.79 -1,907.14 1,237.03 5,946,701.40 665,334.21 70° 15' 38.351 N 148° 39' 48.415 W',. 7 000.28 61.29 145.31 030.18 6 974.97 -1 1,284.43 5,946,634.63 665,383.07 70° 15' 37.683 N 148° 39' 47.036 W I , 7,094.73 60.77 144.57 , 6,075.93 , -2,042.60 1,331.89 5,946,568.05 665,431.99 70° 15' 37.018 N 148° 39' 45.655 W ICI 7,187.22 60.54 145.10 6,121.25 -2,108.51 1,378.33 5,946,503.17 665,479.85 70° 15' 36.370 N 148° 39' 44.305 W 7,281.84 59.88 144.96 6,168.26 -2,175.80 1,425.39 5,946,436.93 665,528.37 70° 15' 35.708 N 148° 39' 42.936 W 7,375.07 59.64 144.98 6,215.21 -2,241.76 1,471.62 5,946,372.00 665,576.02 70° 15' 35.059 N 148° 39' 41.591 W 7,469.30 60.31 145.39 6,262.36 -2,308.74 1,518.20 5,946,306.05 665,624.04 70° 15' 34.400 N 148° 39' 40.236 W 7,564.00 59.76 145.45 6,309.66 -2,376.28 1,564.77 5,946,239.54 665,672.06 70° 15' 33.736 N 148° 39' 38.881 W 7,656.85 60.42 144.80 6,355.96 -2,442.31 1,610.79 5,946,174.54 665,719.51 70° 15' 33.086 N 148° 39' 37.543 W i 7,752.72 60.20 144.34 6,403.45 -2,510.17 1,659.07 5,946,107.75 665,769.25 70° 15' 32.419 N 148° 39' 36.139 W' 7,846.83 60.60 144.81 6,449.93 -2,576.85 1,706.49 5,946,042.12 665,818.12 70° 15' 31.763 N 148° 39' 34.759 W 7,941.33 60.84 144.88 6,496.15 -2,644.24 1,753.96 5,945,975.79 665,867.04 70° 15' 31.100 N 148° 39' 33.379 W 8,035.75 60.83 146.84 6,542.17 -2,712.48 1,800.22 5,945,908.58 665,914.78 70° 15' 30.429 N 148° 39' 32.033 W i, 8,130.01 60.19 146.39 6,588.57 -2,780.99 1,845.37 5,945,841.08 665,961.40 70° 15' 29.755 N 148° 39' 30.720 W' 8,224.31 60.21 146.03 6,635.43 -2,849.00 1,890.88 5,945,774.08 666,008.38 70° 15' 29.086 N 148° 39' 29.396 W" 8,318.38 60.60 146.06 6,681.89 -2,916.85 1,936.57 5,945,707.25 666,055.53 70° 15' 28.419 N 148° 39' 28.068 W' 8,413.54 59.60 145.88 6,729.33 -2,985.21 1,982.73 5,945,639.91 666,103.17 70° 15' 27.746 N 148° 39' 26.725 W' 8,507.89 56.84 146.05 6,779.01 -3,051.67 2,027.62 5,945,574.45 666,149.49 70° 15' 27.092 N 148° 39' 25.420 W 8,602.08 53.78 146.32 6,832.61 -3,116.01 2,070.72 5,945,511.07 666,193.98 70° 15' 26.460 N 148° 39' 24.166 W 8,696.11 50.04 145.57 6,890.61 -3,177.31 2,112.14 5,945,450.69 666,236.73 70° 15' 25.856 N 148° 39' 22.962 W 8,726.48 47.87 145.01 6,910.55 -3,196.14 2,125.18 5,945,432.15 666,250.17 70° 15' 25.671 N 148° 39' 22.583 W ~, 8,757.25 46.96 144.44 6,931.37 -3,214.64 2,138.26 5,945,413.94 666,263.66 70° 15' 25.489 N 148° 39' 22.202 W I 8,787.93 45.37 144.86 6,952.62 -3,232.69 2,151.07 5,945,396.18 666,276.85 70° 15' 25.312 N 148° 39' 21.830 W I 8,882.82 41.51 144.07 7,021.51 -3,285.78 2,188.97 5,945,343.93 666,315.90 70° 15' 24.789 N 148° 39' 20.728 W 8,975.86 36.98 143.71 7,093.54 -3,333.33 2,223.64 5,945,297.15 666,351.59 70° 15' 24.322 N 148° 39' 19.719 W 9,070.34 33.08 142.96 7,170.89 -3,376.83 2,256.00 5,945,254.37 666,384.89 70° 15' 23.894 N 148° 39' 18.778 W 9,164.60 29.70 143.03 7,251.35 -3,416.03 2,285.55 5,945,215.82 666,415.29 70° 15' 23.508 N 148° 39' 17.919 W . 9,256.36 26.40 143.34 7,332.32 -3,450.57 2,311.41 5,945,181.86 666,441.89 70° 15' 23.168 N 148° 39' 17.167 W' 9,350.57 24.23 142.49 7,417.48 -3,482.71 2,335.69 5,945,150.26 666,466.86 70° 15' 22.852 N 148° 39' 16.461 W' 9,445.06 21.42 140.93 7,504.56 -3,511.49 2,358.38 5,945,121.98 666,490.17 70° 15' 22.569 N 148° 39' 15.801 W 3/9/2009 2:42:14PM Page 8 COMPASS 2003.16 Build 70 Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB B Pad Well: B-10 Wellbore: B-10A Design: B-10A 'Survey Local Co-ordinate Reference: Well Er10 -Slot 10 TVD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE MD Reference: Revised RKB@69.03 022009 @ 69.03ft (31.79KE North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Measured Vertical Map Map ', Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) lft) 9,538.39 18.57 141.49 7,592.25 -3,536.35 2,378.37 5,945,097.56 666,510.70 9,568.58 17.90 141.57 7,620.93 -3,543.75 2,384.25 5,945,090.29 666,516.74 9,632.37 17.28 141.38 7,681.73 -3,558.83 2,396.26 5,945,075.48 666,529.07 9,727.01 17.30 138.95 7,772.10 -3,580.43 2,414.27 5,945,054.28 666,547.55 ~~ 9,821.15 17.76 138.10 7,861.87 -3,601.67 2,433.05 5,945,033.45 666,566.79 9,914.28 19.56 136.83 7,950.10 -3,623.61 2,453.21 5,945,011.96 666,587.41 10,008.24 18.36 137.08 8,038.96 -3,645.92 2,474.05 5,944,990.11 666,608.73 10,102.09 18.42 136.85 8,128.02 -3,667.56 2,494.25 5,944,968.91 666,629.40 iI 10,194.48 18.25 136.52 8,215.72 -3,688.71 2,514.19 5,944,948.21 666,649.79 10,288.71 18.79 134.80 8,305.07 -3,710.11 2,535.11 5,944,927.27 666,671.18 10,381.19 17.74 134.49 8,392.89 -3,730.48 2,555.73 5,944,907.36 666,692.23 10,474.31 17.79 134.36 8,481.57 -3,750.37 2,576.02 5,944,887.92 666,712.95 10,537.12 16.64 133.70 8,541.56 -3,763.29 2,589.38 5,944,875.29 666,726.59 10,602.62 15.38 133.24 8,604.52 -3,775.72 2,602.49 5,944,863.15 666,739.97 10,613.54 15.31 134.13 8,615.05 -3,777.71 2,604.58 5,944,861.20 666,742.10 i 10,704.87 16.66 141.32 8,702.85 -3,796.33 2,621.42 5,944,842.96 666,759.34 I 10,801.10 19.65 148.14 8,794.29 -3,820.85 2,638.59 5,944,818.82 666,777.03 j 10,893.44 19.34 147.07 8,881.34 -3,846.87 2,655.09 5,944,793.17 666,794.10 ~~ 10,987.45 18.93 146.57 8,970.16 -3,872.66 2,671.96 5,944,767.75 666,811.52 I 11,080.33 18.35 145.91 9,058.16 -3,897.35 2,688.45 5,944,743.43 666,828.55 11,151.84 11 190.00 18.32 18.32 146.33 146.33 9,126.04 162.27 9 -3,916.02 -3,926.00 2,700.99 2,707.64 5,944,725.04 5,944,715.20 666,841.49 666,848.36 , , Casing Points Measured Depth (ft) 2,679.73 Checked By: Latitude 70° 15' 22.325 N 1 70° 15' 22.252 N 1 70° 15' 22.103 N 1 70° 15' 21.891 N 1 70° 15' 21.682 N 1 70° 15' 21.466 N 1 70° 15' 21.247 N 1 70° 15' 21.034 N 1 70° 15' 20.826 N 1 70° 15' 20.615 N 1 70° 15' 20.415 N 1 70° 15' 20.219 N 70° 15' 20.092 N 70° 15' 19.970 N 70° 15' 19.950 N 70° 15' 19.767 N 70° 15' 19.526 N 70° 15' 19.270 N 70°15'19.016N 70° 15' 18.773 N 70° 15' 18.589 N 70° 15' 18.491 N Longitude 48° 39' 15.220 W I 48° 39' 15.049 W ~' 48° 39' 14.700 W 48° 39' 14.176 W' 48° 39' 13.630 W i 48° 39' 13.044 W ! 48° 39' 12.438 W 48° 39' 11.850 W 48° 39' 11.270 W 48° 39' 10.662 W i 48° 39' 10.062 W ' 148° 39' 9.472 W' 148° 39' 9.084 W ', 148° 39' 8.702 W' 148° 39' 8.642 W'i. 148° 39' 8.152 W 148° 39' 7.653 W 148° 39' 7.173 W 'i 148° 39' 6.683 W 148° 39' 6.203 W 148° 39' 5.839 W 148° 39' 5.645 W i Vertical Casing Hole Depth Diameter Diameter 2,679.48 13-3/8 17-1 /2 13 3/8" Survey Report -Geographic Approved By: Name Date: 3/9/2009 2:42:14PM Page 9 COMPASS 2003.16 Build 70 • Rev. 2.3 Alaska Onshore Rig Elevation Record To be completed by MWD Engineer for each job as soon as data is obtainable. Job: Sidetrack or other later work ~ ., cinaen ,oroparry ~ ,... ~ •. - - ~,~, . 2 ways to use form: Reference pad level & enter newly measured flange or lock dn. screw height Preferred => Reference the previously recorded feature height as the "Fixed Ref. Pt." 1) Measure rig elevation above fixed reference point (flange). 2) Get pad level from recorded fixed pad height reference. 3) Complete form including pad as-built survey document number. 4) Print to a PDF file you'll save with other MWD files for the well. Name as "wellbore-name RigElev mo-day-yr. pdf". 5) Use "Rig Reference Point Elevation" as the InSite "KB elev" or "DF elev" & the "Fixed Ref. Pt." as the "GL elev". 6) E-mail pdf (or the xls file) to RTO (akiifr@halliburton.com). Optionally, post copy where convenient for rig personnel. Well Name: B-10A Field: Prudhoe Pad/Drillsite: B Pad Slot: 10 Nabors zes ~ Drilling Super. D. Maskell Date: 09-Feb-09 As-built doc.#: (or survey co. & date): SOHIO Oct. 2, 1978 Rotary Table /Drill Floor ~ Rig Ref. Pt. Rig Ref. Pt. to Surface Casing Flange 31.79 ft Surface Casing Flange ~ Surface Casing Flange ~ Fixed Ref. Pt. Surface Casing Flange above MSL 37.24 ft ! Sea Level Rig Reference Point Elevation 69.03 ft above MSL Contact Jim Durand (273-3537) with questions. January 2008 3/6/2009 11:55 AM B-10A RigElevForm.xls ~ ~ WELL LDG T ~1SiVII'I"TAL, To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: B-l0A April 14, 2009 AK-MW-6247174 B-10A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-20321-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-20321-01 Digital Log Images: 50-029-20321-01 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 B cyan. Burindahal~iburton. com Date: Signed /~~ ~ ~._~~~ ~ ~ W~I.I, L®G 'I'12A1~Sl~~TTAI. 'I'®: State of Alaska April 14, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: B-l0A AK-MW-6247174 B-10A: 1 LDWG formatted CD rom with verification listing. API#: 50-029-20321-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 9~>7-73-33-5 Bryan.l3urindaChallibtzrtan. com BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 o~~ /~ ":: Date: Signed: ~~ ~~~~ v • HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well B-10A Dear Christine Mahnken 09-Mar-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 5,731.73' MD Window /Kickoff Survey 5,737.00' MD (if applicable) Projected Survey: 11,190.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 Date ! ~ f~~ ~~~ Signed v (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) Nabors 2ES Well B-l0a Well Control Incident ~ Page 1 of Z Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 17, 2009 9:22 AM To: 'Hobbs, Greg S (ANC)'; (NSUADWDrIgRig2es@bp.com) Cc: DOA AOGCC Prudhoe Bay Subject: RE: Nabors 2ES Well B-10 (178-054) Well Control Incident Dick and Greg, Thanks for the info regarding the incident at 2ES. Look a# the record, it probably would have been appropriate to set the retainer and cement in April 2008. One other item, since the original well had not been plugged, the incident and work up to milling the window are considered to be accomplished in B-10 rather than B-10A (208- 205). ~oocT~uck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Tuesday, February 17, 2009 8:44 AM To: Maunder, Thomas E (DOA) Subject: FW: Nabors 2ES Well B-l0a Well Control Incident Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Drlg Rig 2es [mailto:NSUADWDrIgRig2es@bp.com] Sent: Saturday, February 14, 2009 2:54 PM To: DOA AOGCC Prudhoe Bay Cc: Hobbs, Greg S (ANC) Subject: Nabors 2ES Well B-10a Well Control Incident Gentlemen, Well B-10A had been suspended by Doyon 14 in April 2008, with a Halliburton retrievable bridge plug in the 9 5/8" casing at 5963'. On February11 th, 2009, at approx 17:00 hours, Nabors 2ES unseated this RBP prior to setting a cement retainer to squeeze off perfs in the old wellbore in preparation for a sidetrack. As soon as the RBP was unseated, significant flow from the wellbore was seen at surface. The well was immediately shut in using the annular preventer. At this point, SIDPP = 80 psi. SICP = 220 psi. In subsequent operations to circulate out the influx, the choke line HCR valve was operated as was the hydraulic choke and the valve downstream of the choke (valve #7 on the manifold). As part of the well control operation, a contingency was put in place to strip in the hole with drillpipe. A floor safety valve and a dart sub were run in the string as part of this plan, but stripping operations were ultimately unnecessary, and we were able to RIH to the previously cut tubing stub at 9354', to circulate out gas and bullhead additional fluid to the pen`s. 2/17/2009 Nabors 2ES Well B-l0a Welltrol Incident ~ Page 2 of 2 At the end of the well control operation, the annular preventer was tested to 250/2500 psi. In addition, the choke line HCR, valve #7 on the choke manifold, the floor safety valve and the dart valve were each tested to 250/3500 psi. All tests passed. If any further information is needed, please let me know. Dick Maskell BPX Company Rep Nabors 2ES maskelcrC~bp.com Tel: 659-4103 Fax: 659-4177 2/17/2009 B-l0A FIT/LOT ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 02, 2009 9:46 AM To: 'Roach, Jovy' Subject: RE: B-10A (208-205) FIT/LOT Jody, Either test is acceptable provided satisfactory formation strength is demonstrated outside the window to conduct the planned drilling program. Call or message with any questions. Please include the permit number in the email title. Tom Maunder, PE AOGCC From: Roach, Jovy [mailto:Jovy.Roach@bp.com] Sent: Monday, February 02, 2009 9:33 AM To: Maunder, Thomas E (DOA) Subject: B-10A FIT/LOT Tom, While milling the window for this well, we would like to do a FIT, rather than a LOT as stated in the ops summary of the permit application. The same kick tolerance of 11.0 ppg minimum with a 10.7 mud weight applies. Please let me know if this is ok. Thanks, Jovy 2/2/2009 Page 1 of 1 Fleckenstein, Robert J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, January 07, 2009 10:24 AM To: Fleckenstein, Robert J (DOA) Subject: PTD # Zt3&205, B-10A Permit Hi Bob, You are correct... the surface location of this Permit to Drill does need to be corrected to: 2070' FNL, 1611' FEL The TPI and TD locations are correct. Thanks! Terrie 1 /7/2009 a ,~ ~ ~ ma ~~-~ ,_ ~y I 33 j ~ (T p r '', ! ~~, 8 III ~ ~ ~ ~ ~ 5 _ f ~ f ~'- { ~i ~ 5 y I9 } V ~ ~ ~ .._ ~ ;.: ~ ~ ~ ~~~ . !»t 5, i ?_ ~? C.. ~.. k' w . i_ ...;.i i.J ~, ,d , ~ , .: t i_! _. s ALASSA OIL AHD GAS CO1~T5ERQA7'IO1~T COMItII55IO1~T Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519 r'1 SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B- l0A BP Exploration Alaska Inc. Permit No: 208-205 Surface Location: 2070' FNL, 1611' FWL, SEC. 31, T11 N, R 14E, UM Bottomhole Location: 769' FNL, 1110' FWL, SEC. 05, T10N, R14E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ' cerely Daniel T. Seamount, Jr. //, /~ Chair DATED this f? ~d"~ajy of January, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA /~3 ~ ALAS~IL AND GAS CONSERVATION COMMIS~N/ ~D-J~' DEC 2 9 2008 ~. ( ~ PERMIT TO DRILL ~~IS Alaska Oil & Gas Co 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Welt Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is p pp~F ' ^ Coalbed Methane ^ Gas'fi~ydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU B-10A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10973' TVD 9121' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028310 & 028313 Pool F ,SEC. 31, T11N, R14E, UM 2070 FNL, 1611 Top of Productive Horizon: R14E UM 373' FWL SEC. 32 T11 N 4514' FNL 8. Land Use Permit: 13. Approximate Spud Date: February 6, 2009 , , , , , Total Depth: 769', FNL, 1110' FWL, SEC. 05, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,360' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664056 y- 5948581 Zone-ASP4 10. KB Elevation Plan (Height above GL): 5.7 feet 15. Distance to Nearest Well Within Pool: 229' 16. Deviated Wells: Kickoff Depth: 7350 feet Maximum Hole An le: 46 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3786 Surface: 2930 18. Casin Pr r m: S cificatio ns T - Settin h -Bo ttom nti of m nt c.f. racks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BT -M 4 1 5 5' 1 269' 56 u Li rete 1 7 ft' ' 6-1/8" 41/2" 12. 13 r80 V m T 54' 1 119' 85 8' 10973' 121' 14 ft CI s'G' 19. PRESENT 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): 11100' Q5' Yes, See Diagram 10604' 9049' --9350' Casing `' Length Size Cement Volume MD TVD Conductor /Structural 7 r i 11 11 ' Surface 2 7 ' 13-3/ " 5 c P rmafro II 267 ' 2675' Intermediate 10011' 5/ " 179 I 'G' P rm fro 10011' 617' Pr i n Liner 1507' 7" 15 I 'G' 94 ' - 111 ' - 94 ' Perforation Depth MD (ft): 10310' - 10398' Perforation Depth TVD (ft): 8837' - 8901' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jovy Roach, 564-4352 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature ~ Phone 564-4166 Dat 3 ~~ Terrie Hubble, 564-4628 Commission Use Ont Permit To Drill Number: O S API Number: -010-00 50-029-20321 Permit Approval See cover letter for r it ment D e: ~ her ^ ~ ; Conditions of Approval: ~4~4y C~ ~~s~~'~5~~ ~~ ~QC+.~Q~`O\r~ s)v~~~ ~S: ~ 5~h~~\ 1 If box is checketl, well may not be used to explore for, test, or produce coal~fed methane, gas hydrates, or gas contained shales: ~~ eS~ '~~~_~ ~ Samples Req'd: ^ Yes I~No Mud Log Req'd: ^ Yes Q~No ~a ®® ~S ~,,~~ ~c~~,~-+~ c~.ti~J~,cxc ~L°S~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other. APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-40'I~Revised X2/2005 ~~ Submit In Duplicate ~ ~ ~ To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: December 23, 2008 Re: B-10A Sidetrack Permit to Drill The B-10A well is scheduled to be drilled by Nabors Rig 2ES which is currently scheduled to move onto the location ~ February 6, 2009. The plan is to P&A the well with cement to 9200' MD and run an RTTS to locate the production casing leak. A window will be milled in the parent B-10 wellbore from the 9-5/8" casing at ~ 7350' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where 7" casing will be run and fully cemented, high enough to cover the PC leak. A 6-1/8" hole will then be drilled to TD in the Ivishak Zone 2. A solid 4-1/2" production liner will be run and cemented in place, and a 4- 1/2" completion will be run. Well history/current status: B-10 was shut-in for TxIA communication in July 2006. Subsequent diagnostics confirmed that a RWO was the only option for returning this well to service. A RWO to replace corroded tubing was started on parent well B-10 in April 2008. During the decompletion phase of the RWO, a length of corroded tubing was left in the well, and fishing operations commended to recover the corroded tubing debris. Probability of completing the workover was considered very low, and the RWO was aborted. NOTE: It was not possible to test the 9-5/8" production casing pre RWO due to an obstruction at +/- 8454'MD. The Rig tested PC during RWO ops and determined there is a PC leak above 8343' dd and below 5971' dd. Please note the following Well Summary as detailed on the next few pages. B-10A Permit to Drill Application Page i Planned Well Summ~y Well B-10A Well Slant T e Sidetrack API Number: 50-029-20321-xx L ~ Target Zone 4 Ob'ective Current Status B-10 Shut-in with a kill string and RBP as downhole barrier Estimated Start Date: 6-Feb-2009 Time to Com lete: 18 Da s Surface Northin Eastin Offsets TRS Location 5,948,581 664,056 2069' FNL / 3391' FWL 11 N, 14E, 31 Northin Eastin TVDss Offsets TRS Target 5,946,180 666,120 -7406 4514' FNL / 373' FWL 11 N, 14E, 32 Locations 5,945,120 666,657 -8566 307' FNL / 901' FWL 10N, 14E, 5 5,944,760 666,830 -8950 671' FNL / 1064' FWL 10N, 14E, 5 Bottom Northin Eastin TVDss Offsets TRS Location 5,944,663 666,878 -9054 769' FNL / 1110' FWL 10N, 14E, 5 Planned KOP: 7350'MD / 6503'TVDss Planned TD: 10973'MD / 9054' TVDss Ri Nabors 2ES RT-GL: 28.5' BFE: 37.24' Directional -Sperry (Wp 1.0) KOP: 7350' MD Maximum Hole Angle: 46.1 ° in the 8-1 /2" intermediate section 46.1° in the 6-1/8" roduction section Close A roach Wells: All wells pass major risk criteria for close approach. Surve Pro ram: MWD Standard + IFR / MS Nearest Pro a Line: 20,360' (North) to the PBU property line Nearest Well within Pool: X-27 is the closest well at 229' ctr-ctr with 38' of allowable deviation at tanned de th of 8752' MD. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Cole Abel 564-4476 AI Schmoyer 564-5865 E-mail iow. roach ~ bosom cole.abel~bp.com al.schmoyer~ bp.com B-10A Permit to Drill Application Page 2 Formation Markers N-18A ~sed on SOR) Estimated Formation To s Formation TVDss Planned MD UG1 -4940 WS2 -5549 WS1 -5819 CM3 -6020 KOP @ -6503 SSTVD 7350 MD CM2 -6540 7397 CM1 -7260 8398 TH RZ -7600 8876 BHRZ -7730 9063 LCU -7765 9114 TJC (approx. at Fault 1 intersection -8231 9786 TJB -8388 10012 TSG R -8566 10269 TSHA -8592 10306 TSAD -8667 10414 45SB -8710 10476 42SB -8771 10564 TCG L -8860 10693 BCGL -8925 10787 To HO/T -8958 10834 23SB -8985 10873 OOWC -9005 10902 Casina/Tubina Program Hole Size Csg / Tb O.D. Wt/Ft Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-'/z" 7" 26# L-80 BTC-M 7,240 5,410 4319' 5950' / 5505' 10269' / 8633' 6-1/8" 4'/z" 12.6# 13Cr-80 Vam To 10,160 10,530 854' 10119'/8528' 10973' / 9121' Tubin 4'/z" 12.6# 13Cr-80 Vam To 10,160 10,530 10099' Surface 10099' / 8515' B-10A Permit to Drill Application Page 3 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densit PV YP API FL HTHP FL MBT PH 9.0 16-30 30-35 <6.0 N/C N/C 9.0-10 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 7350' - 8689' 9.0 - 9.5 10-18 20-30 <6.0 N/C <12 9.0-10 8689'- 10263' HRZ to Sa 10.7 + 12-22 20-25 4.0-6.0 <10.0 <15 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 10263' - 10973' 8.4 - 8.5 8-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Logging Program 8-1/2" Intermediate: Sample Catchers - as required by Geology Drillin Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drillin Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Program Casin Size: 7" 26#, L-80 Intermediate Liner Lead: 2919' of 7" x 8-1/2" open hole + 40% excess 1400' of liner lap Basis: based on LTP at 5950' MD + 200' DP excess Tail: 1000' of 7" x 8-1/2" open hole with 40% excess, plus 80' shoe track Tail TOC: 9263' MD Total Cement Spacer 30 bbls of Viscosified Spacer (Mud Push II) Volume: Lead 100 bbls, 560 cu ft, 163 sks, 11.2 Lite Crete, Yield = 3.43 cuft/sk Tail 35 bbls, 197 cu ft, 166 sks 15.8 Class G, Yield = 1.19 cuft/sk Tem BHST = 211 ° F at TOC, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, 13-Cr-80 Production Liner Basis: Lead: None Tail: 704' of open hole with 40% excess, 80' shoe track, 150' 4-'/z" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 8899' MD (TOL) Total Cement Volume• Spacer 30 bbls of Viscosified Spacer (Mud Push 11) Lead None Tail 25 bbls, 140 cuft, 120 sks 15.8 Ib/ al Class G, Yield = 1.17 cuft/sk Tem BHST = 216° F, BHCT TBD b Schlumber er B-10A Permit to Drill Application Page 4 Surface and Anti-Collis~n Issues Surface Shut-in Wells: n There are no wells requiring surface shut-in in order to move onto the well. At surface B-11 to the north and B-31 to the south are nearest at 110' and 36' centers, respectively. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide B-Pad IS designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Readin #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 B-35 10 m 10/1/2005 B-31, B-32 NA PW In'ectors B-09 and B-11 NA LTSLwells X-17 76 m 7/25/2008 B-26B 25 m 1/2/2003 B-34 400 m 06/07/95 The max recorded H2S for B-10 is 45 ppm on 7/17/96 Faults The drilling target polygon minimizes exposure to faulting in the production hole and optimizes standoff from offset wells. B-10 did not experience losses when it crossed Fault 1 in the Kingak, and the B-10A will cross in a similar position. A number of offset wells have experienced significant lost circulation problems when they intersected faults or fractures in the Shublik or Ivishak. B-26 had insignificant losses when it crossed Fault 1 in the Ivishak, but the B-26A CST suffered major losses (3300 bbls) when it was drilled parallel to (and likely intersected) the fault plane. It also crossed a fault intersection according to 13 TSHU seismic continuity data. B-26B was sidetracked further away from the fault plane and suffered no losses. B-09 lost 4470 bbls in the Shublik and Zone 2 when it crossed Fault 1, according to the WURD Lost Circulation database. X-17 and B-31 had no losses, while X-27 on the north side of the graben lost 450 bbls in the Colville and another 300 bbls at the top of the Sag River during intermediate casing operations. B-34 lost 825 bbls in the Shublik. B-10A Permit to Drill Application Page 5 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipm will be tested to 3,500 psi. BOP regular test frequency forwill be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3786 si C~ 8566' TVDss 8.5 EMW Maximum surface ressure 2930 si .10 si/ft as radient to surface Kick tolerance 154 bbl over 11.0 FIT assumin 8.5 ore ressure and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-1/2" hole FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3300 si C~ 8800' TVDss 7.2 EMW Maximum surface ressure 2420 si .10 si/ft as radient to surface Kick tolerance Infinite with a 9.0 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte ri Test - 6-1/8" hole FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Other Requests: ~~L ~~ ~~ ~ Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the ROPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Disyosal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject (GNI) at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: All Class II liquid waste (including drilling muds and/or brines that have been downhole) are to be hauled to GNI at DS-04 for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors (659-5893) for the appropriate disposal method at Pad 3 or GNI. NOTE: Generally, Class I solids will be directed to the GNI on DS-04 and Class liquids will be directed to Pad 3. B-10A Permit to Drill Application Page 6 Drillin Hazards a~d Contin encies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW, based on offset well pressures. All casing strings will be tested to 3500 psi, in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation /Faults The drilling target polygon minimizes exposure to faulting in the production hole and optimizes standoff from offset wells. B-10 did not experience losses when it crossed Fault 1 in the Kingak, and the B-10A will cross in a similar position. A number of offset wells have experienced significant lost circulation problems when they intersected faults or fractures in the Shublik or Ivishak. B-26 had insignificant losses when it crossed Fault 1 in the Ivishak, but the B-26A CST suffered major losses (3300 bbls) when it was drilled parallel to (and likely intersected) the fault plane. It also crossed a fault intersection according to 13 TSHU seismic continuity data. B-26B was sidetracked further away from the fault. plane and suffered no losses. B-09 lost 4470 bbls in the Shublik and Zone 2 when it crossed Fault 1, according to the WURD Lost Circulation database. X-17 and B-31 had no losses, while X-27 on the north side of the graben lost 450 bbls in the Colville and another 300 bbls at the top of the Sag River during intermediate casing operations. B-34 lost 825 bbls in the Shublik. III. Kick Tolerance /Integrity Testing A. The Kick Tolerance for the intermediate section is 154 bbl and that for the production section is infinite with planned mud weights. The FITs will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test De th Test a EMW Ib! al 9 5/8" window 20-ft minimum from the 9-5/8" window FIT 11.0 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 9.0 minimum IV. Stuck Pipe A. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. B-PAD IS designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad. The maximum recorded level on this pad is 400 ppm on B-34 in 1995. VII. Anti-Collision Issues A. All wells pass major risk criteria for close approach. X-27 is the closest well at 229' ctr-ctr with 38' of allowable deviation at planned depth of 8752' MD. CONSULT THE B-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION B-10A Permit to Drill Application Page 7 Operations Summary Current Condition and history: / Well currently shut in with a 4-1/2"kill string at 5881' MD and a RBP set at 5971 ' MD. / MITOA passed to 2000 psi on 03/07/08. / Confirmed IA leak between 5971' and 8400' MD. o The 9-5/8"tested to 3500 psi for 30 minutes from a RBP at 5971' on 4/8/08. / Top of 4-1/2"stub at 9354' MD with debris just inside stub. Last tag 04/07/08. / Well is loaded with seawater and diesel freeze protect. Scope Notify the field AOGCC representative with intent to plug and abandon. Pre-rig prep work: O 5 Bleed OA and IA to zero psi. PPPOT - IC (9-5/8") 3500 psi, PPPOT-T (4-1/2") 5,000 psi. Function all lock-down screws. O 6 Pressure test the OA (13-3/8" casing) to 2000 psi for 30 minutes. CMIT T x IA to 3,500 psi for 30 minutes. O 7 Bleed all casin and annulus ressures to zero. Ensure BPV in tubin han er. Secure well. O 8 Remove the well house. Level the pad. Provide total well preparation cost on the handover form. Ria Operations: 1. MI / RU. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Install TWC and test. 3. MIT-OA to 2000 psi for 30 min charted. 4. Nipple down tree and adapter. Nipple up and test BOPE to 3,500psi. Pull TWC. 5. R/U. Pull 4'/z" tubing (kill string) from 5881'. 6. With RBP as barrier, ND BOPs and change-out 9-5/8" pack-offs. Test packoff. NU and test BOPs. 7. RIH and pull RBP from 5971'. 8. MU 8-1/2" clean-out assembly and clean-out the 9-5/8" casing down to the top of tubing stub at 9354' MD. 9. RIH with cement retainer to 9300 MD. Perform injectivity test on TxIA and record LLR. 10. If injectivity is confirmed, squeeze cement through retainer to P&A wellbore. Pull up above retainer and lay cement to leave 100' of cement above retainer. If no injectivity established, set cement above retainer only. 11. RIH with RTTS to 7350' and pressure test 9-5/8" casing above RTTS to confirm IA leak is below whipstock setting depth. If test fails, move up in 500' increments until pressure test passes. Note: If leak is found above KOP, plan to run 7"liner to 150' above leak depth. From 04/08 RWO, leak depth ~~.~' should be below 5971' MD. ~~ 12. RU E-line and RIH with 9-5/8" GR/JB & GR/CCL below whipstock setting depth ~ 7350' MD in '~`~ preparation to set EZSV for whipstock. 13. With E-line, set 9-5/8" CIBP at ~ 7360' to allow fora 7350' MD whip-stock KOP (max hole angle 41.05 degrees at 6685' MD). Pressure test casing. 14. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set on 15. Displace the well to LSND milling fluid. Mill the window and 20' new formation. Perform LOT. 16. RIH w/ 8'/z" DIR/GR/Res drilling assembly and drill to top Sag River. POH. 17. Run and cement 7" L-80 BTC-M drilling liner. 18. RIH with 6 1 /8" bit /motor assembly with GR/Res/Den/Neu to landing collar. 19. Test casing to 3500 psi. Drill shoe tract. '°~-- 20. Displace the well to 8.4 ppg Flo-Pro drilling fluid. Drill 20' formation; perform FIT. ~ ~~ LXc ~~~,'~- 21. Drill ± 700' to TD at 10973 MD in Zone 2. ` _ 22. Circulate, short trip, spot liner running pill, POOH. 23. Run and cement a 4 ~h", 12.6#, 13-Cr-80 Vam Top solid production liner. POOH. B-10A Permit to Drill Application Page 8 24. R/U and run 4 1/2", 12.6#,~Cr-80 VamTop completion tubing. Land tubing, RILDS. 25. Reverse circulate inhibited seawater to the packer depth. 26. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500 psi 30 minutes. Record each test. 27. Shear the DCK valve and pump each way to confirm shear. 28. Set a TWC and test to 1000 psi. 29. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. Pull TWC w/lubricator. 30. Freeze protect the well to 2,200' 31. Install BPV and secure the well. 32. Rig down and move off. Post Rig Operations: W 1 Pull BPV. S 2 Pull ball & rod. S 3 Install GL valves. E 4 Perforate on a-line. O 5 Install wellhouse, instrumentation and flow-line. Estimated Pre-rig Start Date: 1/6/2009 Estimated Spud Date: 2/6/2009 B-10A Permit to Drill Application Page 9 TREE= ~ WELLHEAD= 7-1/16"CM/ MCEVOY ACTUATOR= oils D I~ L G D R T KB. ELEV = 64.29' BF. ELEV = 37.24' KOP = 2800' Max Angle = 45 @ 11000' Datum MD = 10348' Datum TVDss= 8800' 13-3l8" CSG, 72#, L-80, ID = 12.347" 2675' B-~ O SU~ENDED 04/10/08 19-{4-1/2" HES X NIP, ID = 3.813" 230 9-5/8" DV PKR~ 5869' -~4-1/2" HES X NIP, ID = 3.725" 4-112" KILL STRING TBG, 12.6#, L-80, ID = 3.958" 5881' 5880' 4-1/2" WLEG, ID = 4.00" 5971' 9-5/8" HES RPB (04/08/08) 9354' TBG STUB (LA ST TAG ON 04/07/08) GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT D~ 9373 8053 43 OTC DMY RM 0 07/ IGINAL TBG STRING 402' 4-1/2" PKR SWS NIP, ~ = 3.813" 406' H4-1/2" BKR PBR SEAL ASSY, ID = 4.0" ~7" TBG STUB, 26#, L-80, .0383 bpf, ID = 6.276" H 9478' TOP OF 7" LNR 94JS' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10011' PERFORATION SUMMARY REF LOG: BRCS, 10/15!78 A NGLE AT TOP PERF: 43 @ 10354 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10296 - 10320 S 2-7/8" 6 10310 - 10330 C 03/18/01 5" 4 10320 - 10330 C 5" 4 10354 - 10370 C 05/22/00 2-1/2" 4 10370 - 10398 C 05/02/96 4" 4 10416 - 10426 S 4" 4 10442 - 10450 S 4" 4 10465 - 10480 S 04/01 /96 ~ 4-1 /2" LNR 12.6#, L-80, .0152 bpf, ID = 3.958" H 10344' ~ PBTD H 10604' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11100' 428' I-19-5l8" x 4-1l2" BKR HB-RET PKR, ID = 4.0" 10276' ~--~4-1/2" OTIS XA SLID~a SLV, ID = 3.813" 1283'-10289' H M~-A TBG PATCH, ID = 3.25" 1291'-10335' 4-1/2" 7DS, BLAST JOINT, ID = 3.959" 10306' 7" MARKER JOINT 10336' 7"x4-1/2" BAKER SAB PERM PKR W/ANCHOR, ID = 4.0" 10343' 4-1 /2" OTIS 'XN' NIP, ID = 3.725" 10344' 4-1l2" WLEG, ID = 3.958" 10347' ELMD -LOGGED 10409' FISH - 79' TBG-CONVEYED 5" PERF GUN ? H 7" PERMANENT BR®GE PLUG ? 7" PERMANENT BRIDGE PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 10/24/78 ORIGINAL COMPLETION 04/10/08 GBNYSL IaLL STRING RWO ATTEM PT) 07/11/90 HS/PAG RWO CORRECTION (11/16/06) 04/20/08 JDMITLH DRAWING CORRECTIONS 03/26/01 RN/TP CORRECTIONS 11/01/01 WB/TP SURF LOC CORRECTION 07/18/06 CJN/PJC GLV GO 10/20/06 HS/PAG PERF CORRECTION (10/18/06) PRUDHOE BAY UNfT WELL: B-10 PERMIT No: 178-0540 API No: 50-029-20321-00 SEC 31, T11 N, R14E BP 6cploration (Alaska) TREE= ~ 4-1/16"CAM WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 64.29' BF. ELEV = 37.24' KOP = 7350' Max Angle = 47.7 @ 9348' Datum pnn = 10550' Datum TV Dss= 8800' GA S LIFT MANDRELS • ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 's 2 1 ~9-5/8" EZSV I TOC above cement retainer 9-5/8" EZSV 4112" TuhinQ Stub from Jet Cut I 7360' I 141/2" HES X NP, ID = 3.813" 1 X 41/2" HES X NP, ID = 3.813" ~ 4112" HES XN NP, D = 3.725" ID = as8r 1--I 1 PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: ~ Note: S¢E SPF MERVAL Opn/Sgz DATE 7" LNR, 29#, L-80, .0371 bpf, 1D = 6.184" 11100' B _ ~ O ~ SA F OTES Drig DRAFT 2100' 4-1/2" X-NIP, ID = 3.813" 2306' 9-5/8" DV PKR 2675' t 3-3/8" CSG, 72#, L-80, iD = 12.347" Minimum ID = 3.725" ~ 10069' XN Nipple - 5950 7 x 9-518" Liner hanger !packer _ 7350' KOP a :; ~' :- i:..':: ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 10/24/78 ORIGINAL COMPLETION 07/11190 HS/PAG RWO CORRECTION (11/16/06) 03/09/08 LH/PJC JET CUT 09/24/08 JER Drilling Draft CSG, 26# 141 /2" LNR, 12.611, 13-Cr-801 PRUDHOE BAY UNIT WELL: B-10A PERMff No: 178-0540 API No: 50-029-20321-01 SEC 31, T11 N, R14E BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM - BP Amoco Co-ordinate (N/E) Reference. Well Centre: B-IQ True North Depth Fm Depth To Survey/Plan Tool Plan: B-IOA Wp 1.0 (B-10/B-IOA Plan) I!1-' Vertical (TVD) Reference- 38GL+28.5 66.50 Iculation Method: Minimum Curvature Section (VS) Reference: Slol - 10 (O.OON,O.OOE) 7350.00 10263.00 Planned: B-IOA Wp L0 V7 MWD+IFR+MS Crea[ed By: Spetry Dulling Date: 12/17/2008 Error System. ISCWSA Measured Depth Reference: 38GL+28.5 66.50 10263.00 10972.56 Planned: B-IOA Wp L0 V7 MW D+IFR+MS Scan Method: Trav Cylinder North Calculation Method: Minimum Curvature -""'~' Error Surface- Elliptical+Casing ~~~~~- _ WELL DETAILS CASING DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot No. TVD MD Name Size B-10 2098.20 2007.72 5948581.00 664056.00 70°IS'S7.IOSN 148°40'24.409W 10 ~~~~~~~~~~~~~ SE TION DETAIL ~ --~~.__-~~~~ I 8632.50 10268.77 7" 7.000 2 9120.51 10972.56 41/2" 4.500 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target HALLIBURTON I 7350.00 38.82 144.43 6569.91 -1976.50 1280.36 0.00 0.00 2354.07 2 7370.00 39.09 140.64 6585.47 -1986.48 1288.00 12.00 -85.00 2366.62 3 7874.56 46.13 112.46 6959.98 -2180.98 1559.78 4.00 -80.62 2680.88 S err Orilli~ Service~~' S art Dir 12?/100' : 7350' M , 6569.91'TVD : 85? L 4 8114.80 46.13 112.46 7126.48 -2247.16 1719.84 0.00 0.00 2826.10 - p,-___y ___ g - 5 8872.56 46.10 155.00 7664.37 -2607.39 2096.45 4.00 105.15 3336.32 6 10822.56 46.10 155.00 9016.50 -3880.82 2690.26 0.00 0.00 4722.07 7 10972.56 46.10 155.00 9120.51 -3978.77 2735.94 0.00 0.00 4828.67 CM2 ' p~ _ End Dir 874.56' MD, 6959.98' TV 700 Sta Dir 4?/100' :8114.8' MD 7126. 48'TVD c 0 0 n. Q FORMATION TOP DE-FAILS No. TVDPath MDPath Fomtation I 6606.50 7397.14 CM2 2 7326.50 8397.69 CMI 3 7666.50 8875.64 THRZ 4 7796.50 9063.12 BHRZ 5 7831.50 9113.59 LCU 6 8297.50 9785.64 TJC 7 8454.50 10012.06 TJB 8 8632.50 10268.77 '1 SGR 9 8658.50 1030627 TSHA 10 8733.50 10414.43 TSAD II 8776.50 10476.44 45SB 12 8837.50 10564.41 42SB 13 8926.50 10692J7 TCGL 14 899L50 10786.51 BCGL l5 9024.50 10834.10 Top HO/T 16 905L50 10873.04 23S6 17 9071.50 10901.88 OOWC TARGET DETAILS Natne TVD +N/-S +E/-W Northing Easting Shape B-IOA TI SOR 7472.50 -2445.19 1993.33 5946180.00 666102.00 Point B-l0A T2 SOR 8632.50 -3517.11 2525.14 5945120.00 666657.00 Point B-IOA Geopoly 8632.50 -3880.82 2690.26 5944760.00 666830.00 Polygon B-!OA T3 SOR 9016.50 -3880.82 2690.26 5944760.00 666830.00 Point B-IOA T4 SOR 9120.50 -3978.85 2736.14 5944663.00 666878.00 Point B-10,4 Fault I 9866.50 -3231.20 2258.28 5945400.00 666384.00 Polygon B- I OA T 1 SOR Er Dir :8872.56' MD, 7664 3T TVD RZ {RZ 9000 L TJC 1B B-10A G~ B-10 T2 SOR TSHA _ TSGR 7" TSAD 45SB 42SB B-IOA T3 T p H(5/T ~ ;_ ~ To al Depth :10972.56' MD, 120.51' TVD 2386 ~`!~ 7'4 SOR B-10 (B-10) ' OOWC " D ~ BBIb~ fan 4 1/2^ B-l0A Wp LO Vertical Sec[ion a[ 145.49° [SOOf[/in] 5000 COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scatt Method: Trav Cylinder North Error Surface: Elliptical +Casing Warning Method: Rules Based HALLIBURTGlN Sperry Drilling Berviceef REFERENCE INFORMATION SURVEY PROGRAM E) Reference Well Centre: B-IQ, True Nonh Depth Fm Depth To Survey/Plan U) Reference: 38GL+28.5 66.50 'S) Reference: Slot - 10 (O.OON,O.OOE) 7350.00 10263.00 Planned: B-l0A Wp 1.0 V7 4h Reference 38GL+28.5 66.50 10263.00 10972.56 Planned: B-IOA W L0 V7 ano"nI Method. Minimum Curvature tart L.........'...~_W...W.W...'`( Di ~ I_?/100' : 7350' MD, 6~69.91'TVD : 85? L End Dir :787 .56' MD, 6959.98' TVD S[art Dir 4?/100' : SI14.8' MD, i 7000 B-l0A TI SOR End Dir :8872.56' MD, 7664.37 Tool Plan: B-IOA Wp L0 (B-10/B-IOA Plan) Created By: Sperry Drilling Date: 12/17/2008 MWD IFR+MS WELL DETA ILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot B-10 2098.20 2007.72 5948581.00 664056.00 70°IS'S7.lO8N 148°40'24.409W 10 TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape B-l0A TI SOR 7472.50 -2445.19 1993.33 5946180.00 666102.00 Point B-l0A T2 SOR 8632.50 -3517.1 I 2525.14 5945120.00 666657.00 Point B-IOA Geopoly 8632.50 -3880.82 2690.26 5944760.00 666830.00 Polygon B-IOA T3 SOR 9016.50 -3880.82 2690.26 5944760.00 666830.00 Point B-l0A T4 SOR 9120.50 -3978.85 2736.14 5944663.00 666878.00 Poin[ B-IOA Faul[ I 9866.50 -3231.20 2258.28 5945400.00 666384.00 Polygon w + -3271 x 0 L N -373 IOA B-IOA T2 8 -\ 7" __ 1 I\ \ B-Iq ('8-10) \t1~ I/ ,1 FORMATION TOP DETAILS No. TVDPath MDPath Fmmation 1 6606.50 7397.14 CM2 2 7326.50 8397.69 CMI 3 7666.50 8875.64 THRZ 4 7796.50 9063.12 BHRZ 5 7831.50 9113.59 LCU 6 8297.50 9785.64 TJC 7 8454.50 10012.06 TJB 8 8632.50 10268.77 TSGR 9 8658.50 10306.27 l'SHA 10 8733.50 10414.43 TSAD II 8776.50 10476.44 45SB 12 8837.50 10564.41 42S6 13 8926.50 10692.77 TCGL 14 8991.50 10786.51 BCGL IS 9024.50 10834.10 Top HO/T I6 9051.50 10873.04 2388 17 9071.50 1090L88 OOWC i 1402 1869 2336 West(-)/East( [al e th : 10972.56' M , 9120.5 ]'TVD IOA 4~SOR 1(lA-Plan OA Wp I.0 .t •i CASING DETAILS No. TVD MD Name Size I 8632.50 10268.77 7" 7.000 2 9120.51 10972.56 41/2" 4.500 SECTION DETAILS Sec MD Inc Aa TVD +N/-S +E/-W DLeg TFace VSec Target I 7350.00 38.82 144.43 6569.91 -1976.50 1280.36 0.00 0.00 2354.07 2 7370.00 39.09 140.64 6585.47 -1986.48 1288.00 12.00 -85.00 2366.62 3 7874.56 46.13 112.46 6959.98 -2180.98 1559.78 4.00 -80.62 2680.88 4 8114.80 46.13 112.46 7126.48 -2247.16 1719.84 0.00 0.00 2826.10 5 8872.56 46.10 155.00 7664.37 -2607.39 2096.45 4.00 105.15 3336.32 6 10822.56 46.10 155.00 9016.50 -3880.82 2690.26 0.00 0.00 4722.07 7 10972.56 46.10 155.00 9120.51 -3978.77 2735.94 0.00 0.00 4828.67 Sperry-Sun BP Planning Report Company:' BP Amoco Date: 12/17/2008 Time: 13:25:50 Page: 1 :Field: Prudhoe Bay' Co-ordinate(NE) Reference: WeIL' 6-10, True North Site: PB B Pad Vertical (TVD) Reference: 38GL+28.5.66.5 Well: B-10 Section (VS) Reference: Well (O.OON,O.OOE,145.49Azi) Wellnath: 8-10A Plan Survey Calculation Method: Minimum Curvature Dh:` OraGe Plan: B-10A Wp 1.0 Date Composed: 8/28/2008 Version: 7 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB B Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5946440.22 ft Latitude: 70 15 36.475 N From: Map Easting: 662094.05 ft Longitude: 148 41 22.843 W Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.23 deg Well: B-10 Slot Name: 10 B-10 Well Position: +N/-S 2098.20 ft Northing: 5948581.00 ft Latitude: 70 15 57.108 N +E/-W 2007.72 ft Easting : 664056.00 ft Longitude: 148 40 24.409 W Position Uncertainty: 0.00 ft Casing Points MD TVD ; Diameter Hole Size Name ft ft m in 10268.77 8632.50 7.000 8.500 7" 10972.56 9120.51 4.500 6.125 4 1 /2" Formations MD ft TVD ft Formations Lithology Dip Angle' deg Dip Direction deg 0.00 UG1 0.00 0.00 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 7397.14 6606.50 CM2 0.00- 0.00 8397.69 7326.50 CM1 0.00 0.00 8875.64 7666.50 THRZ 0.00 0.00 9063.12 7796.50 BHRZ 0.00 0.00 9113.59 7831.50 LCU 0.00 0.00 9785.64 8297.50 TJC 0.00 0.00 10012.06 8454.50 TJB 0.00 0.00 10268.77 8632.50 TSGR 0.00 0.00 10306.27 8658.50 TSHA 0.00 0.00 10414.43 8733.50 TSAD 0.00 0.00 10476.44 8776.50 45SB 0.00 0.00 10564.41 8837.50 42SB 0.00 0.00 10692.77 8926.50 TCGL 0.00 0.00 10786.51 8991.50 BCGL 0.00 0.00 10834.10 9024.50 Top HO/T 0.00 0.00 10873.04 9051.50 23S6 0.00 0.00 10901.88 9071.50 OOWC 0.00 0.00 Targets Map Map <---.Latitude.---> <- Longitnde'---> 'Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Seca.. Deg Min: `Sec bip. Dir. ft ft ft ft ft B-10A T1 SOR 7472.50 -2445.19 1993.33 5946180.00 666102.00 70 15 33.057 N 148 39 26.413 W -Plan hit target B-10A T2 SOR 8632.50 -3517.11 2525.14 5945120.00 666657.00 70 15 22.513 N 148 39 10.950 W -Plan out by 4.07 at 8632.50 -3519.17 2521.62 5945117.86 666653.53 70 15 22.493 N 148 39 11.052 W B-10A Geopoly 8632.50 -3880.82 2690.26 5944760.00 666830.00 70 15 18.936 N 148 39 6.150 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 12/17/2008 Time: 13:25:50 Page: : 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: B-10, True North Site: PB B Pad Vertical (TVD) Reference: 38GL+28.5 66:5 We1L B-t0 Section (VS) Reference: Well (O.OON,O.OOE,145.49Azi) Wellpath: ' B-10A Plan S urvey Calculation Method: Mi nimum Curvature D6 t?racle Targets Map Map` <-- Latitude ---> <--- Longitude --> Name Description ,TVD +N/-S +E/-W Northing " Fasting Deg Min :Sec -Deg Min See Dip. Dir. ft ft ft ft ft -Polygon 1 8632. 50 -3488. 39 2400. 72 5945146.00 666532.00 70 15 22.796 N 148 39 14.569 W -Polygon 2 8632. 50 -4122. 62 2585. 96 5944516.00 666731.00 70 15 16.558 N 148 39 9.187 W -Polygon 3 8632. 50 -4019. 66 3002. 33 5944628.00 667145.00 70 15 17.569 N 148 38 57.074 W -Polygon 4 8632. 50 -3487. 54 2728. 84 5945154.00 666860.00 70 15 22.803 N 148 39 5.024 W -Polygon 5 8632. 50 -3488. 39 2400. 72 5945146.00 666532.00 70 15 22.796 N 148 39 14.569 W -Plan out by 399.04 at 8632. 50 -3519. 17 2521. 62 5945117.86 666653.53 70 15 22.493 N 148 39 11.052 W B-10A T3 SOR 9016 .50 -3880. 82 2690. 26 5944760.00 666830.00 70 15 18.936 N 148 39 6.150 W -Plan hit target B-10A T4 SOR 9120 .50 -3978. 85 2736 .14 5944663.00 666878.00 70 15 17.971 N 148 39 4.817 W -Plan hit target B-10A Fault1 9866 .50 -3231. 20 2258 .28 5945400.00 666384.00 70 15 25.326 N 148 39 18.711 W -Polygon 1 9866 .50 -3231. 20 2258 .28 5945400.00 666384.00 70 15 25.326 N 148 39 18.711 W -Polygon 2 9866 .50 -3250. 40 2680 .00 5945390.00 666806.00 70 15 25.136 N 148 39 6.442 W Plan Section Information MD Incl Azim TVD +N/S +E/-W DLS Build Turn TFO Targe t ft deg deg ft' ft ft deg/100ft'deg/100ft deg/100ft deg 7350.00 38.82 144.43 6569.91 -1976.50 1280.36 0.00 0.00 0.00 0.00 7370.00 39.09 140.64 6585.47 -1986.48 1288.00 12.00 1.35 -18.97 -85.00 7874.56 46.13 112.46 6959.98 -2180.98 1559.78 4.00 1.39 -5.58 -80.62 8114.80 46.13 112.46 7126.48 -2247.16 1719.84 0.00 0.00 0.00 0.00 8872.56 46.10 155.00 7664.37 -2607.39 2096.45 4.00 0.00 5.61 105.15 10822.56 46.10 155.00 9016.50 -3880.82 2690.26 0.00 0.00 0.00 0.00 10972.56 46.10 155.00 9120.51 -3978.77 2735.94 0.00 0.00 0.00 0.00 Survey MD Incl ` Azim TVD Sys TVD VS N/S E/W DLS 1VIapN MapE TooVGo ft deg: deg ft ft ft ft ft- deg/100ft ft ft 7350.00 38.82 144.43 6569.91 6503.41 2354.07 -1976.50 1280.36 0.00 5946633.01 665379.03 Start Dir 1 ? 7370.00 39.09 140.64 6585.47 6518.97 2366.62 -1986.48 1288.00 12.00 5946623.20 665386.89 Start Dir 4. ~ 7397.14 39.28 138.95 6606.50 6540.00 2383.68 -1999.57 1299.07 4.00 5946610.35 665398.24 CM2 7400.00 39.30 138.77 6608.72 6542.22 2385.49 -2000.93 1300.27 4.00 5946609.01 665399.47 MWD+IFR 7500.00 40.22 132.68 6685.62 6619.12 2448.45 -2046.66 1344.89 4.00 5946564.28 665445.08 MWD+IFR 7600.00 41.43 126.85 6761.32 6694.82 2511.30 -2088.40 1395.12 4.00 5946523.64 665496.20 MWD+IFR 7700.00 42.93 121.32 6835.44 6768.94 2573.75 -2125.96 1450.72 4.00 5946487.30 665552.60 MWD+IFR 7800.00 44.68 116.12 6907.63 6841.13 2635.49 -2159.16 1511.40 4.00 5946455.43 665613.98 MWD+IFR 7874.56 46.13 112.46 6959.98 6893.48 2680.88 -2180.98 1559.78 4.00 5946434.68 665662.83 End Dir 7900.00 46.13 112.46 6977.61 6911.11 2696.26 -2187.99 1576.73 0.00 5946428.04 665679.92 MWD+IFR 8000.00 46.13 112.46 7046.92 6980.42 2756.71 -2215.53 1643.35 0.00 5946401.96 665747.13 MWD+IFR 8100.00 46.13 112.46 7116.22 7049.72 2817.15 -2243.08 1709.98 0.00 5946375.87 665814.33 MWD+IFR 8114.80 46.13 112.46 7126.48 7059.98 2826.10 -2247.16 1719.84 0.00 5946372.01 665824.27 Start Dir 4. 8200.00 45.33 117.09 7185.96 7119.46 2878.52 -2272.70 1775.20 4.00 5946347.69 665880.18 MWD+IFR 8300.00 44.64 122.67 7256.72 7190.22 2942.21 -2307.87 1836.46 4.00 5946313.86 665942.19 MWD+IFR 8397.69 44.23 128.22 7326.50 7260.00 3006.40 -2347.49 1892.15 4.00 5946275.47 665998.72 CM1 8400.00 44.23 128.35 7328.15 7261.65 3007.94 -2348.48 1893.41 4.00 5946274.50 666000.00 MWD+IFR 8500.00 44.10 134.09 7399.92 7333.42 3075.40 -2394.35 1945.77 4.00 5946229.79 666053.35 MWD+IFR 8600.00 44.25 139.83 7471.67 7405.17 3144.26 -2445.24 1993.29 4.00 5946179.95 666101.96, MWD+IFR 8601.15 44.26 139.89 7472.50 7406.00 3145.06 -2445.85 1993.81 4.00 5946179.35 666102.49 B-10A T1 8700.00 44.70 145.50 7543.06 7476.56 3214.17 -2500.90 2035.73 4.00 5946125.23 666145.60 MWD+IFR 8800.00 45.41 151.06 7613.73 7547.23 3284.81 -2561.07 2072.90 4.00 5946065.88 666184.07 MWD+IFR 8872.56 46.10 155.00 7664.37 7597.87 3336.32 -2607.39 2096.45 4.00 5946020.10 666208.62 End Dir: 8875.64 46.10 155.00 7666.50 7600.00 3338.51 -2609.40 2097.39 0.00 5946018.11 666209.60 THRZ 8900.00 46.10 155.00 7683.39 7616.89 3355.82 -2625.31 2104.81 0.00 5946002.36 666217.37 MWD+IFR 9000.00 46.10 155.00 7752.73 7686.23 3426.88 -2690.61 2135.26 0.00 5945937.74 666249.23 MWD+IFR 9063.12 46.10 155.00 7796.50 7730.00 3471.74 -2731.83 2154.48 0.00 5945896.96 666269.35 BHRZ lent IS IS IS ,~ Sperry-Sun BP Planning Report Company:. BP Amoco Field: Prudhoe Bay Date: 12/17!2008 Time: 13:25:50 Page: Co-ordinate(NE) References We1L 6-.10, True North 3 Site: PB B Pad Vertical (TVD) Reference: 38GL+28:5 66.5 Well: 6-1 0 Section (VS) Reference: Well (O.OON,O.OOE,145.49Azi) Wellpath: B-1 0A Plan Survey Calculation Method: Minimum Curvature Dh: Oracle. Survey MD Inc! Azim TVD Sys TVD VS N/S E/W DIS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/1OOft ft ft 9100.00 46.10 155.00 7822.07 7755.57 3497.95 -2755.92 2165.71 0.00 5945873.12 666281.10 MWD+IFR 9113.59 46.10 155.00 7831.50 7765.00 3507.61 -2764.79 2169.85 0.00 5945864.34 666285.43 LCU 9200.00 46.10 155.00 7891.41 7824.91 3569.01 -2821.22 2196.16 0.00 5945808.50 666312.96 MWD+IFR 9300.00 46.10 155.00 7960.75 7894.25 3640.08 -2886.52 2226.61 0.00 5945743.88 666344.83 MWD+IFR 9400.00 46.10 155.00 8030.09 7963.59 3711.14 -2951.83 2257.07 0.00 5945679.26 666376.69 MWD+IFR 9500.00 46.10 155.00 8099.43 8032.93 3782.20 -3017.13 2287.52 0.00 5945614.64 666408.56 MWD+IFR 9600.00 46.10 155.00 8168.77 8102.27 3853.27 -3082.44 2317.97 0.00 5945550.02 666440.43 MWD+IFR 9700.00 46.10 155.00 8238.11 8171.61 3924.33 -3147.74 2348.42 0.00 5945485.40 666472.29 MWD+IFR 9785.64 46.10 155.00 8297.50 8231.00 3985.19 -3203.67 2374.50 0.00 5945430.06 666499.58 TJC 9800.00 46.10 155.00 8307.45 8240.95 3995.40 -3213.04 2378.87 0.00 5945420.78 666504.16 MWD+IFR 9900.00 46.10 155.00 8376.79 8310.29 4066.46 -3278.35 2409.33 0.00 5945356.16 666536.02 MWD+IFR 10000.00 46.10 155.00 8446.14 8379.64 4137.52 -3343.65 2439.78 0.00 5945291.54 666567.89 MWD+IFR 10012.06 46.10 155.00 8454.50 8388.00 4146.10 -3351.53 2443.45 0.00 5945283.74 666571.73 TJB 10100.00 46.10 155.00 8515.48 8448.98 4208.59 -3408.96 2470.23 0.00 5945226.92 666599.75 MWD+IFR 10200.00 46.10 155.00 8584.82 8518.32 4279.65 -3474.26 2500.68 0.00 5945162.30 666631.62 MWD+IFR 10268.77 46.10 155.00 8632.50 8566.00 4328.52 -3519.17 2521.62 0.00 5945117.86 666653.53 B-10A T2 10300.00 46.10 155.00 8654.16 8587.66 4350.72 -3539.56 2531.13 0.00 5945097.68 666663.48 MWD+IFR 10306.27 46.10 155.00 8658.50 8592.00 4355.17 -3543.66 2533.04 0.00 5945093.63 666665.48 TSHA 10400.00 46.10 155.00 8723.50 8657.00 4421.78 -3604.87 2561.58 0.00 5945033.06 666695.35 MWD+IFR 10414.43 46.10 155.00 8733.50 8667.00 4432.03 -3614.29 2565.98 0.00 5945023.73 666699.95 TSAD 10476.44 46.10 155.00 8776.50 8710.00 4476.10 -3654.79 2584.86 0.00 5944983.66 666719.71 45SB 10500.00 46.10 155.00 8792.84 8726.34 4492.84 -3670.17 2592.04 0.00 5944968.44 666727.22 MWD+IFR 10564.41 46.10 155.00 8837.50 8771.00 4538.62 -3712.24 2611.65 0.00 5944926.81 666747.74 42S6 10600.00 46.10 155.00 8862.18 8795.68 4563.91 -3735.48 2622.49 0.00 5944903.82 666759.08 MWD+IFR 10692.77 46.10 155.00 8926.50 8860.00 4629.83 -3796.06 2650.74 0.00 5944843.87 666788.64 TCGL 10700.00 46.10 155.00 8931.52 8865.02 4634.97 -3800.78 2652.94 0.00 5944839.20 666790.95 MWD+IFR 10786.51 46.10 155.00 8991.50 8925.00 4696.45 -3857.27 2679.28 0.00 5944783.29 666818.51 BCGL 10800.00 46.10 155.00 9000.86 8934.36 4706.04 -3866.08 2683.39 0.00 5944774.57 666822.81 MWD+IFR 10822.56 46.10 155.00 9016.50 8950.00 4722.07 -3880.82 2690.26 0.00 5944760.00 666830.00 B-10A T3 10834.10 46.10 155.00 9024.50 8958.00 4730.27 -3888.35 2693.78 0.00 5944752.54 666833.68 Top HO/T 10873.04 46.10 155.00 9051.50 8985.00 4757.94 -3913.78 2705.63 0.00 5944727.38 666846.08 23S6 10900.00 46.10 155.00 9070.20 9003.70 4777.10 -3931.39 2713.84 0.00 5944709.95 666854.68 MWD+IFR 10901.88 46.10 155.00 9071.50 9005.00 4778.44 -3932.62 2714.42 0.00 5944708.74 666855.28 OOWC 10972.55 46.10 155.00 9120.50 9054.00 4828.65 -3978.76 2735.93 0.00 5944663.07 666877.79 B-10A T4 10972.56 46.10 155.00 9120.51 9054.01 4828.66 -3978.77 2735.94 0.00 5944663.07 666877.80 41/2" 10972.55 46.10 155.00 9120.50 9054.00 4828.66 -3978.77 2735.94 0.00 5944663.07 666877.80 Total Dept 10972.56 46.10 155.00 9120.51 9054.01 4828.67 -3978.77 2735.94 0.00 5944663.07 666877.80 MWD+IFR lent WLLL DIIAII,S ANTI-COLLISION SETTINGS COMPANY I)Iil All.S SURVEY PI2IX)RAM - Nauto +N/ 5 +I / W NoNwt@ 1~ ,turd Lulrtuclc I ongilwlu Slot olation Method MD Inter Interval 25 00 RI A u Ihplh lin Ihplh to Surve~/I'Iwt Tool I11RN lab°4u24AU1W IU 72 i'14R>SI IIU 6r.41n(, Ix) 711°IJ'i7 III 211'/8211 21X17 I5 . p Deplh Range Front. 73$0.00 . TO: . 10972.56 lI I'1 MUI rE Mu- Ctwalwe 7i OIHI 1112631N1 Plwurul: l3-IUA Wp I(1 V6 MWI?~II'It+MS R+Ms W ' . . - Maximum Range' 1294.41 Reference: Plan: B-IOA Wp L0 ¢ rsv 1 Iuwsn Sow M<IIwO. 'frav CrIvul~r NuNr U+IF IwvuN: I~lon wp Inv(, M wzr,31x1 Inn2.,6 1 L.nor Sur~uce Elliplii'ul+CuYmg Wunww Muhn~. Itulc~ 11aa:0 160 150 125 100 75 50 25 0 2 100 125 150 160 u °~ Travelling Cylinder Azin olour To MD ILUInI°Iwr - 250 Purenl Wc11Wth: n-IU 73S() lq '~a on bllJ' - 500 . 750 lie(: lxrtwu: 386E+28 i 66 >I111 - ~ooo . V.Scc14n1 Qbur Quin . Swttur~ - 250 AiEle +N/-5 +U-W Fnnn'I VI) - 1 500 Ni J9° 0.1111 QUIZ 2RSn - »so - 2000 - 22so - 2500 LEGE:NI) - 2750 ~ n-IOlI3-I (I).NOI~:I2RUILS I1 2G (I3-26). M~ryr Ituk - 3000 - 13.z6 ui 26nx Nwp>r Rim ---- 3250 13-2G (11261i}M>,R'r liuA ~ 13.34 (I3J4), Majnr RisA 3500 X-17 (.X-17). M Jur 12isA M 12i A 7 - 3750 ~ X-27 (X-2 ujur s A - '~'°^'''~' 4000 - 13-lun wv I n - 4250 • - 4500 4750 5000 - 5250 - 5500 Removed. pan for Plans le @ No Errors SEC PION DETAILS It¢ Ni "fW +N/-S +E/-W DI ~ "fEucc VSkc 7':ugY ] 38.%2 144.41 Gi699I -1 Y76.>U 1281136 0110 V011 21i4.U7 1 3')UY 140.64 6>RS47 -IY8d48 138%I1U 12 UU -8>nll ?16662 r 46-13 112.46 69iJ Y8 -2180.98 lii9.78 4.nn -80.62 2681LRR 46-13 112A6 7126 J8 -2247.16 171984 (111(1 (1110 28'_6.111 d6-IU Iii fXl 766J 37 -2611731 2U9G.4i 4110 IUS.Ii 1116.32 5 46.10 liiW YUI6.i11 -38811.82 2(90.2( !IW OIHI 4T2117 5 46.1(1 li>lx) YI2(1.51 -311877 273i'H II UII 11.011 4828.67 Guth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] Sperry-Sun Anticollision Report Company: BP Amoco Date: 12/17/2008 Time:. 13:20:55 Page: 1 : Field: Prudhoe Bay Reference. Site: PB B Pad Co-ordinate(NE) Reference: Well: B-10, True North Reference We1L• B-10 Vertical (TVD) Reference: 38GL+28: 5 66.5 Reference Wellpath::B-10A Plan Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tge/~Te~ls in this fRtdlcipal Plan & PLANNED PROGRAM Interpolation Method: MD Depth Range: 6600.00 to Interval: 25.00 ft 11070.99 ft Error Model: Scan Method: ISCWSA Ellipse Trav Cylinder North Maximum Radius: 1294.41 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/28/2008 Validated: No Version: 1 Planned From To Survey Toolcode Tool N ame ft ft 30.40 7350.00 1 : Schlumberger GCT multishot (30.40-1069~~~OS Schlumberger GCT multishot 7350.00 10263.00 Planned : B-10A Wp 1.0 V7 MWD+IFR+MS MWD +IFR + Multi Station 10263.00 10972.56 Planned : B-10A Wp 1.0 V7 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter = Hole Size Name ft ft in in 10268.77 8632.50 7.000 8.500 7" 10972.56 9120.51 4.500 6.125 41/2" Summary <~----------------; Offset Wellpath Site:. Well -------------> Wellpath Reference Offset MD MD Ctr-Gtr No-Go Distance Area Allowable Deviation ` H'arning ft ft ft ft ft PB B Pad B-10 B-10 V1 7327.20 7325.00 0.00 0.65 -0.65 FAIL: NOERRORS PB B Pad B-26 B-26 V3 8524.04 9050.00 605.01 171.20 433.80 Pass: Major Risk PB B Pad B-26 B-26A V4 8524.04 9050.00 605.01 171.20 433.80 Pass: Major Risk PB B Pad B-26 B-26B V3 8524.04 9050.00 605.01 171.20 433.80 Pass: Major Risk PB B Pad B-34 B-34 V1 6621.69 6975.00 734.57 168.96 565.61 Pass: Major Risk PB X Pad X-17 X-17 V1 Out of range PB X Pad X-27 X-27 V5 8752.11 10025.00 229.21 191.52 37.68 Pass: Major Risk Site: PB B Pad Well: B-10 Rule Assigned: NOERRORS Wellpath: B-10 V1 Inter-Si te Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Cir No-Go Allowable NIU TVD MD TVD' Ref Offset - TFO+AZI TFO-HS Casing/HSDistance Area Deviation }Yarning ft ft ft ft ft ft deg deg in ft ft ft 6602.20 5998.75 6600.00 5996.55 16.28 16.28 145.58 0.00 0.00 0.65 -0.65 FAIL 6627.20 6017.63 6625.00 6015.43 16.43 16.43 145.57 0.00 0.00 0.65 -0.65 FAIL 6652.20 6036.49 6650.00 6034.29 16.56 16.56 145.61 0.00 0.00 0.65 -0.65 FAIL 6677.20 6055.36 6675.00 6053.16 16.69 16.69 145.60 0.00 0.00 0.65 -0.65 FAIL 6702.20 6074.22 6700.00 6072.02 16.79 16.79 145.56 0.00 0.00 0.65 -0.65 FAIL 6727.20 6093.11 6725.00 6090.91 16.87 16.87 145.52 0.00 0.00 0.65 -0.65 FAIL 6752.20 6112.02 6750.00 6109.82 16.92 16.92 145.51 0.00 0.00 0.65 -0.65 FAIL 6777.20 6130.93 6775.00 6128.73 17.02 17.02 145.52 0.00 0.00 0.65 -0.65 FAIL 6802.20 6149.83 6800.00 6147.63 17.12 17.12 145.52 0.00 0.00 0.65 -0.65 FAIL 6827.20 6168.76 6825.00 6166.56 17.18 17.18 145.52 0.00 0.00 0.65 -0.65 FAIL 6852.20 6187.71 6850.00 6185.51 17.22 17.22 145.53 0.00 0.00 0.65 -0.65 FAIL 6877.20 6206.68 6875.00 6204.48 17.26 17.26 145.54 0.00 0.00 0.65 -0.65 FAIL 6902.20 6225.67 6900.00 6223.47 17.30 17.30 145.57 0.00 0.00 0.65 -0.65 FAIL 6927.20 6244.70 6925.00 6242.50 17.34 17.34 145.55 0.00 0.00 0.65 -0.65 FAIL 6952.20 6263.75 6950.00 6261.55 17.38 17.38 145.55 0.00 0.00 0.65 -0.65 FAIL 6977.20 6282.83 6975.00 6280.63 17.43 17.43 145.59 0.00 0.00 0.65 -0.65 FAIL 7002.10 6301.85 6999.90 6299.65 17.50 17.50 145.65 0.00 0.00 0.65 -0.65 FAIL 7027.20 6321.02 7025.00 6318.82 17.57 17.57 145.63 0.00 0.00 0.65 -0.65 FAIL 7052.20 6340.13 7050.00 6337.93 17.63 17.63 145.53 0.00 0.00 0.65 -0.65 FAIL 7077.20 6359.26 7075.00 6357.06 17.69 17.69 145.41 0.00 0.00 0.65 -0.65 FAIL 7102.20 6378.42 7100.00 6376.22 17.75 17.75 145.31 0.00 0.00 0.65 -0.65 FAIL 7127.20 6397.60 7125.00 6395.40 17.81 17.81 145.27 0.00 0.00 0.65 -0.65 FAIL 7152.20 6416.81 7150.00 6414.61 17.86 17.86 145.17 0.00 0.00 0.65 -0.65 FAIL Alaska Department of Natural Resources Land Administration System Page 1 of~ C ~: -. a ~~ ~ f~~~~~;~~~.,. ~r.--_~ ,.~ ~ -a~2u~ Plan ReCare'er's SeaCCh State Cabins ~F!'tti!'~~ SUPS ~~ Alaska DNR Case Summary File Type: ADL File Number: 28310 ~ ~ Pr.n..table.Case File_Summary See Township, Range, Section and Acreage? New Search C Yes No -~- - --- LAS Menu ~ Case Abstract i Case Detail ~ Land Abstract ,, File: =~llL 28310 ~'`~~'k' Search far Status Plat Updates ,-1~ of I ~'0/008 Customer: 000107377 BP EXPLORATION (ALASKA}INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG D1V OIL AND GAS Case Statics: 35 ISSUED Stata~s Date: 08!19/1965 Totul Acres: 2491.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case SuUtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Lleridiar~: l! 7r~tirjt~i~ip: O1lN K~nr,,~c~. O11[_ ~ti~~~c~tion: 29 Sc~~tfon_-Icrrs: 640 Search Puts Llr~i~li~u~: l ` 7uli ~zt~i~ip: O1 I N Rcrrrge: 01 ~L 1'~rcl%on: 30 .ti'~~c~iun _~l c~r~<~.~: 60--1 Vrric(i~m.~ l_ 7uirnsi2ip: O11N Ra~tge: 014E .5'cclir~i~.~ ~I ,1'c~~tiun.~lcrc.~: 60% ~1/~>i~r~/ruj~.~ U Township: Ol1N R~ui,~c~.~ 01.4E S~~cti~~r~: ~? .5'~tcliutt,lcrc~s: 640 Legal Description 0~-2~-196 * ~` *SALE NOTICE LEUAL DESCKIPlION* Cl~-]31 II1V 14E U~~129,30,31,32 2491.OQ U- 3- 7 ~n~ Cif ~~ t~mta11° Last updated on 12/30/2008. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=283... 12/30/2008 Alaska Department of Natural Resources Land Administration System ~ Page 1 of E 4 s. _ '_:~r ci ~-;r-a, ~r ,~_~ r i-~i~= Rec~~der's Search State Gabins ~la'~t~~ F~uC[~S ~C~SkC~ ~ R ~c"~St~' ~ aC File Type: ADL File Number: 28313 ~ ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~' Yes ~' NO ~ New Search IWAS Menu I Case Abstract I Case Detail I Land Abstract ,, FiIP: AUL 28313 ~''~~"~ Search for Status Plat Updates ~~ t~f 121 i0i'~'OOS Customer: OOOI 07377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tvpe: 784 OIL c4c GAS LEASE COMP DNR Unit. 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Statics: 35 ISSUED Status Date: 09/]4/1965 Totul Acres: 2501.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: 1315 NORTH SLOPE Last Trcnnsacti on: AA-NRB ASS IGNMENT AP PROVED Meridian: U Township: U I ON R~ulge: 014E Secti~~r~ ~ 05 Sctc:tic»r Acrr.l: 6~0 Search Plats Meridicrfl: U Tu~r~l.t~hi~~: Q 1(IN R~ar~<<e.~ U I ~tE .ti'<~c~ru~t.~ Uti ~S'e~ctiuji Acres: 609 Meridian, U 7u~i~n~~hr~>: 01 UN Ran,,r~~.~ U I ~I~; Section: U S'~~~rruri :Acres: 612 Meridian: U l i~~rnshr~>: O10N Range: 014E' Section: i)~ ~'ec~riu~r :1rr~~s~.~ 640 Legal Description OS-28-196 * *" SALE NOTICE LEGAL DESCRIPTIOl'V ~'~` "` C14-13~t 1'1 ON. R14E, UM 5, 6, 7, 8 2501.00 Last updated on 12130/2008. http://dnr. aaska. gov/proj ects/las/Case_Summary.cfm?Fi leType=ADL&FileNumber=283... 12/3 0/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~,~'~/ ~'_/py PTD# o?O ~~OS Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: __ P~C/D*~OE A y POOL: - ~.~1/.D~O~ ~y OrG Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in API number ~.e wel I , Permit No. ,API No. 50- - _ between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect 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 C i i SAMPLE omm ss on must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw h tar et zones. Non-Conventional Well Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _{Comaany Name) must contact the Commission to obtain advance a roval f h pp o suc water well testing ro ram. Rev: 1 / 11 /2008 WELL PERM]T CNECKL]ST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT B-10A Program DEV Well bore seg ^ PTD#:2082050 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11650 OnlOff Shore 4n Annular Disposal ^ Administration 1 Pe[mitfQe attached - - ~! - - - - - 2 Lease number zppropriate - Yes - 3 Unique well_name and number - - - - - Yes - - - - 4 Well located in_adefnedpool__----__ - Yes-- ---------------------------------- -- 5 Well located p[operdiskancefromdrillingunitboundery------ ------ -----------Yes-- ---.--------.------.-------------------------------- --- ------ - 6 Well located p[operdistancefrorrlotherwells----------------- ---------- Yes-- ------ ----------------------- -------------------- --- 7 Suffiraentacreageayaileblein_drillingunit----__--- ------- -----------Yes-. --- -2560aCrQS.------------------------------------.--- ---- ------------- 8 If-deviated, is welibore platinduded - - - Yes 9 Ope[ator only attested DadY - - - Yes - 10 Ope[ator has_appropriate-bond in force -- - - - - - - - - - - - - Yes - - - - - _ Blanket Bond # 6154193. _ _ _ _ - - . _ _ _ 11 Pe[mitcanbeissuedwithoutccnseryationorder---- ------------ -----------Yes-- -------.------------.------------- ------------------- Appr Date 12 Pe[mitcanbeissuedwithoutadministrafive-approval-------------- -----------Yes-. --- ---.-------------------------------- ------------------ 13 Can permit be approved before f 5-day wait - Yes - - - - ACS 12/3112008 X 14 Well located within area and strata authorized bylnieGtionOrde[#(put1O#in-eomments)_(For- NA--- -------------------------------------------_--.---- ---------- --- j 15 All wells_wfthin 1!4-mile area of [eview identified (For senriee well only) _ _ _ _ - - - _ _ _ _ _ _ NA- - _ _ _ _ 16 Pre-produced injector, duration_of pre production Less than 3 months_ (For service well only) - .NA - - - - - - 17 Konconven,gasconformsloAS31.05,03Q(j•1-A),(j.2.A-D)----.----- ---------- I~`-.- -- ----------------- -------- -- - --------------------------------- 18 Conductorstring.provided - - - - - - - - - - - - - - - _ - - NA_ _ - - Conductor setm - - - ' - •, Engineerin9 19 Surface casing protects all known USRWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -NA_ _ _ _ _ - - AU aquifers exempted, AE0 t. _ _ _ . _ _ _ _ _ . - - - 20 CMTvoladequate-toei[culate_onconducto[&surf_csg__ --____ _--__- __-.NA-_ _---_Surfacecasing set in B-10._--____.____..____-.-_----_.---------.- 21 CMT vol adequate_ to tie-in long string to surf ce9- - - - - - NA_ - _ - Production casing set in-B-10. .. - - - - - - - 22 CMT will cover_allknown-productive horizons- - _ _ _ _ _ _ Yes - . _ _ _ _ _ _ _ . - 23 CasingdesynsadequatefotC,-T,68_permafcost---- Yes-- ------- ---------------------------------- -------- ------ 24 Adequate tankage-or reserve pit . - - - - Yes Rig equipped with steel pits, No reserve pit planned.- All waste-to approved disposal well(s)_ _ _ _ _ _ _ _ _ _ _ __ _ ', 25 Ifa-re-dill,has-a10.403for abandonment beenapprov_ed __ - Yes-- -.___308,456_-------------------------------------- ------- -------------- 1 26 Adequate wehbore separation-proposed_ Yes - Proximity analysis perfo[med, Close approaches identifed._ Traveling cylinde[ path. calculated.. - - . - - - 27 Ifdiveder-required, doesitmeetregulations_ _-- __---- - NA--_ -._-_BOPstackwillal[eady-be inpiace------------- ------------- ------- -------- --- 28 Dnllingfluid program schematic & equip list adequate- Yes Maximim-expected formationpressure $.5 EMN1 in 8,5"hole $ 7,2 EMW in zone..MWs up So 10.7 RP9 & $•5 DP9• Appr Date - TEM 11512009 29 BOPEs,-dolheymeetregulation - - - Yes - - - ' /~ ~ ' X30 BOPE_press rating appropriate; lest to_(put psig in.comments) - Yes - - . - - - MASP calculated at 2930 psi, 3500-psi BOP testproposed._ / ,~~V 31 Choke manifold COmplieswlAPIRP-53 (MaY $4)- - - - - - - - - - - - - - - - - - - - - - - - - Yes _ ~Ql~ 132 Work will occu[ withoutoperationshutdown_ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - . - - - 33 Is presence of H2S gas probable - - - Yes H2S is reported_at B pad. _ Mud_ should preclude H2S on rig._ Rig has sensors and-alarms- - - - - - - - - - - -- - 34 MechanicaLconditionofwellswithinAORverifed(F9rservicewellpnly)--- ________.- NA--- ---- ----------------------------------------------- ----------- --- - 35 Pe[mit can be issued w/o hydrogen sulfide measures No- - Max level t12S on pad for weU 6-34 is 400ppm (6/7/95)_. - . - - - Geology 36 f)aka-presented on potential overpressure zones_ - ~- - Appr Date 37 Seismic analysis of shallow gas_zones- - -~` - ACS 12!3112008 38 Seabed-conditionsurvey.(if oft-shore)---------------------- -------- --1'!p`-- ---------------...-----.----------------------------------------------- '39 Contactnamelphoneforweekly-progressrepods[exploratoryonly]------ ----_----- No_ -_.__....-_____. --___--___--_--_ ---------------------- Geologic Engineering Public Date Date: ' Date Commissioner: Comm ~ fission r. ~~ '~ ~~°~ Cl~ - -6 _ a / ~ .. • Welt tiistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. '~ B10AO02252009SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LiSLib $Revision: 4 $ Fri Apr 10 14:17:59 2009 Reel Header Service name .............LISTPE Date . ...................09/04/10 Ori in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ............. ......09/04/10 Origin ............. ......STs Tape Name. .... .. ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: B-lOA API NUMBER: 500292032101 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 10-APR-09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw0006247174 Mw0006247174 Mw0006247174 LOGGING ENGINEER: T. ONYEKWELU T. ONYEKWELU J. PEREZ OPERATOR WITNESS: D. MASKELL B. DECKER B. DECKER MAD RUN 3 JOB NUMBER: MW0006247174 LOGGING ENGINEER: J. PEREZ OPERATOR WITNESS: 6. DECKER SURFACE LOCATION SECTION: 31 TOWNSHIP: 11N RANGE: 14E FNL: 2070 FSL: FEL: FWL: 1611 Page 1 B10AO0225200955N.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 69.03 GROUND LEVEL: 37.24 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.875 5737.0 2ND STRING 6.125 7.000 10643.0 3RD STRING PRODUCTION STRING REMARKS: 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. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 5737'MD/5343'TVD,IN THE B-10 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. ONLY SROP AND SGRC DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4), AND DRILL STRING DYNAMICS SENSOR (DDSr). MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 3 ALSO INCLUDED AZIMU- THAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD DATA OVER THE INTERVAL 10840'MD-10625'MD ACQUIRED WHILE POOH ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO AN OPEN-HOLE SCHLUMBERGER GAMMA RAY LOG RUN IN B-10 ON 15 OCTOBER 1978. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 3 APRIL 2009, AS AUTHOR- IZED BY COLE ABEL (BP). ALL LOG HEADER AND ANNOTATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THIS SHIFTED MWD DATA SET IS THE PDC FOR B-lOA. 6. MWD RUNS 1-3 REPRESENT WELL B-lOA WITH API# 50-029-20321-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11190'MD/9162'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). Page 2 ~ ~ B10AO0225200955N.txt 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT FIXED MUD WEIGHT: 8.4 - 8.45 PPG MUD SALINITY: 6500 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD 1 clipped curves; all bit runs merged. .5000 START DEPTH 5515.5 5725.0 5725.0 5725.0 5725.0 STOP DEPTH 11129.0 11136.0 11136.0 11136.0 11136.0 Page 3 B10AO0225200955N.txt ROP 5732.5 11185.0 FET 5732.5 11136.0 PEF 10635.0 11116.0 NPHI 10635.0 11100.5 RHOB 10635.0 11116.0 FCNT 10635.0 11100.5 NCNT 10635.0 11100.5 DRHO 10635.0 11116.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 5522.0 5522.5 5530.0 5531.0 5556.0 5556.0 5589.0 5589.0 5592.0 5593.5 5595.0 5597.0 5600.0 5601.0 5605.0 5604.5 5607.5 5608.0 5617.0 5617.5 5627.0 5628.5 5641.0 5642.5 5664.0 5665.5 5667.0 5668.0 5670.0 5670.0 5692.5 5693.5 5709.5 5711.0 5717.5 5717.5 5736.5 5737.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 5520.5 5777.0 5777.0 10645.0 10645.0 11190.0 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 Page 4 B10AO0225200955N.txt 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-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5515.5 11185 8350.25 11340 5515.5 11185 FCNT MWD CP30 131.83 4094.49 914.787 932 10635 11100.5 NCNT MWD CP30 14717 55219.1 31043.5 932 10635 11100.5 RHOB MwD G/cc 0.392 3.398 2.32792 963 10635 11116 DRHO MWD G/CC -3.635 0.921 -0.0153655 963 10635 11116 RPD MWD OHMM 0.1 2000 12.1268 10740 5725 11136 RPM MWD OHMM 0.11 2000 7.93633 10740 5725 11136 RPS MWD OHMM 0.13 1810.19 4.48956 10740 5725 11136 RPX MWD OHMM 0.18 1810.12 4.80214 10740 5725 11136 FET MWD HR 0.12 73.27 1.48451 10725 5732.5 11136 GR MwD API 11.59 492.26 106.057 11228 5515.5 11129 PEF MWD B/E 1.1 14.21 2.67577 963 10635 11116 ROP MWD FPH 0.08 520.45 146.431 10906 5732.5 11185 NPHI MWD PU-5 4.45 51.31 19.757 932 10635 11100.5 First Reading For Entire File..........5515.5 Last Reading For Entire File...........11185 File Trailer Service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 Page 5 B10AO0225200955N.txt FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PEF 10537.5 10766.5 RHOB 10537.5 10766.5 DRHO 10537.5 10766.5 GR 10550.5 10781.0 RAT 10613.5 10833.5 NPHI 10633.5 10751.5 FONT 10633.5 10751.5 NCNT 10633.5 10751.5 RPM 10635.0 10787.5 RPx 10635.0 10787.5 RPD 10635.0 10787.5 FET 10635.0 10787.5 RPS 10635.0 10787.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 3 1 10542.5 11190.0 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT 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-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10537.5 10833.5 10685.5 593 10537.5 10833.5 FCNT MAD CP30 129.26 4103.54 1244.92 237 10633.5 10751.5 NCNT MAD CP30 15229.2 54460.4 33662.8 237 10633.5 10751.5 RHOB MAD G/CC 0.815 2.971 2.43613 268 10537.5 10766.5 DRHO MAD G/CC -2.424 0.256 -0.0693657 268 10537.5 10766.5 RPD MAD OHMM 0.29 2000 109.204 306 10635 10787.5 Page 6 B10AO02252009SSN.txt RPM MAD OHMM 0.34 2000 106.473 306 10635 10787.5 RPS MAD OHMM 0.3 402.41 37.2477 306 10635 10787.5 RPX MAD OHMM 0.29 1444.2 67.9242 306 10635 10787.5 FET MAD HR 9.4 86.29 14.3708 306 10635 10787.5 GR MAD API 18.48 499.58 102.986 445 10550.5 10781 PEF MAD B/E 1.15 13.49 4.30097 268 10537.5 10766.5 RAT MAD FPH 1 1073 222.884 441 10613.5 10833.5 NPHI MAD PU-5 4.23 54.52 19.3978 237 10633.5 10751.5 First Reading For Entire File..........10537.5 Last Reading For Entire File...........10833.5 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 5520.5 5710.5 SROP 5737.5 5777.0 LOG HEADER DATA DATE LOGGED: 16-FEB-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5777.0 TOP LOG INTERVAL (FT): 5737.0 BOTTOM LOG INTERVAL (FT): 5777.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.4 MAXIMUM ANGLE: 40.5 Page 7 B10AO0225200955N.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 5737.0 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: Fresh water Gel 9.00 60.0 8.9 3300 8.6 .000 .0 .000 155.0 .000 .0 .000 .0 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 MWDO10 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5520.5 5777 5648.75 514 5520.5 5777 GR MWDO10 API 25.39 93.72 47.0186 381 5520.5 5710.5 ROP MWDO10 FPH 0.08 74.73 21.1977 80 5737.5 5777 First Reading For Entire File..........5520.5 Last Reading For Entire File...........5777 Page 8 • B10A002252009SSN.txt File Trailer service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC 5711.0 SESP 5730.0 SEXP 5730.0 SEMP 5730.0 SEDP 5730.0 SFXE 5737.5 SROP 5777.5 STOP DEPTH 10599.0 10591.0 10591.0 10591.0 10591.0 10591.0 10645.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 21-FEB-09 Insite 74.11 Memory 10645.0 5777.0 10645.0 17.3 61.3 TOOL NUMBER 203301 216787 Page 9 • B10AO02252009SSN.txt 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 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 8.500 5737.0 Fresh water Gel 10.20 47.0 9.7 2500 8.5 1.000 68.0 .510 140.0 2.400 68.0 .850 68.0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 5711 10645 8178 9869 5711 10645 RPD MWD020 OHMM 0.57 2000 5.36009 9723 5730 10591 RPM MWD020 OHMM 0.57 1810.24 2.81815 9723 5730 10591 RPS MWD020 OHMM 0.56 1810.19 2.78314 9723 5730 10591 RPX MWD020 OHMM 0.34 1810.12 2.76212 9723 5730 10591 FET MWD020 HR 0.12 33.4 1.3485 9708 5737.5 10591 GR MWD020 API 21.26 416.38 114.326 9777 5711 10599 ROP MWD020 FPH 0.92 520.45 149.219 9736 5777.5 10645 Page 10 B10AO02252009SSN.txt First Reading For Entire File..........5711 Last Reading For Entire File...........10645 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level~Name... version Number. ........1.0.0 Date of Generation.......09/04/10 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 10591.5 11141.0 SEDP 10591.5 11141.0 SEXP 10591.5 11141.0 SESP 10591.5 11141.0 SEMP 10591.5 11141.0 SGRC 10599.5 11134.0 SBD2 10640.0 11121.0 CTFA 10640.0 11105.5 SCO2 10640.0 11121.0 SNP2 10640.0 11121.0 CTNA 10640.0 11105.5 TNPS 10640.0 11105.5 SROP 10645.5 11190.0 LOG HEADER DATA DATE LOGGED: 25-FEB-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11190.0 TOP LOG INTERVAL (FT): 10645.0 BOTTOM LOG INTERVAL (FT): 11190.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 11 • i B10AO0225200955N.txt MINIMUM ANGLE: 15.3 MAXIMUM ANGLE: 19.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 948045 CTN COMP THERMAL NEUTRON 116332 EWR4 Electromag Resis. 4 148579 ALD Azimuthal Litho-Dens 10508969 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10643.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 57.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 6500 FLUID Loss (C3): 9.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .560 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .280 129.0 MUD FILTRATE AT MT: .500 60.0 MUD CAKE AT MT: .750 60.0 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 MwD030 cP30 4 1 68 4 2 NCNT MwD030 CP30 4 1 68 8 3 RHOB MWD030 G/CC 4 1 68 12 4 DRHO MWD030 G/CC 4 1 68 16 5 RPD MwD030 OHMM 4 1 68 20 6 RPM MwD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MwD030 API 4 1 68 40 11 Page 12 • B10AO02252009SSN.txt PEF MWD030 B/E 4 1 68 44 12 ROP MwD030 FPH 4 1 68 48 13 NPHI MwD030 PU-5 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10591.5 11190 10890.8 1198 10591.5 11190 FCNT MWD030 CP30 131.83 4094.49 914.787 932 10640 11105.5 NCNT MWD030 CP30 14717 55219.1 31043.5 932 10640 11105.5 RHOB MwD030 G/cc 0.392 3.398 2.32792 963 10640 11121 DRHO MWD030 G/CC -3.635 0.921 -0.0153655 963 10640 11121 RPD MwD030 OHMM 0.1 2000 76.8201 1017 10591.5 11141 RPM MwD030 OHMM 0.11 2000 56.8686 1017 10591.5 11141 RPS MWD030 OHMM 0.13 288.04 20.8037 1017 10591.5 11141 RPX MWD030 OHMM 0.18 649.97 24.3057 1017 10591.5 11141 FET MWD030 HR 0.19 73.27 2.78282 1017 10591.5 11141 GR MWD030 API 11.59 492.26 51.5193 1070 10599.5 11134 PEF MWD030 B/E 1.1 14.21 2.67577 963 10640 11121 ROP MWD030 FPH 3.06 406.07 130.719 1090 10645.5 11190 NPHI MwD030 PU-S 4.45 51.31 19.757 932 10640 11105.5 First Reading For Entire File..........10591.5 Last Reading For Entire File...........11190 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......sTSL26.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 3 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH SNP2 10542.5 10771.5 SBD2 10542.5 10771.5 Page 13 • B10AO02252009SSN.txt 5CO2 10542.5 10771.5 SGRC 10555.5 10786.0 SRAT 10618.5 10838.5 TNPS 10638.5 10756.5 CTFA 10638.5 10756.5 CTNA 10638.5 10756.5 5E5P 10640.0 10792.5 SEDP 10640.0 10792.5 SEMP 10640.0 10792.5 SFXE 10640.0 10792.5 SEXP 10640.0 10792.5 LOG HEADER DATA DATE LOGGED: 25-FEB-09 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10840.0 TOP LOG INTERVAL (FT): 10625.0 BOTTOM LOG INTERVAL (FT): 10840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.3 MAXIMUM ANGLE: 19.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 948045 CTN COMP THERMAL NEUTRON 116332 EWR4 Electromag Resis. 4 148579 ALD Azimuthal Litho-Dens 10508969 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10643.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 57.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 6500 FLUID LOSS (C3): 9.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .560 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .280 129.0 MUD FILTRATE AT MT: .500 60.0 MUD CAKE AT MT: .750 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 14 • • B10A0022520095SN.txt 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 MAD031 CP30 4 1 68 4 2 NCNT MAD031 CP30 4 1 68 8 3 RHOB MAD031 G/CC 4 1 68 12 4 DRHO MAD031 G/CC 4 1 68 16 5 RPD MAD031 OHMM 4 1 68 20 6 RPM MAD031 OHMM 4 1 68 24 7 RPS MAD031 OHMM 4 1 68 28 8 RPX MAD031 OHMM 4 1 68 32 9 FET MAD031 HR 4 1 68 36 10 GR MAD031 API 4 1 68 40 11 PEF MAD031 B/E 4 1 68 44 12 RAT MAD031 FPH 4 1 68 48 13 NPHI MAD031 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10542.5 10838.5 10690.5 593 10542.5 10838.5 FCNT MAD031 CP30 129.26 4103.54 1244.92 237 10638.5 10756.5 NCNT MAD031 CP30 15229.2 54460.4 33662.8 237 10638.5 10756.5 RHOB MAD031 G/CC 0.815 2.971 2.43613 268 10542.5 10771.5 DRHO MAD031 G/CC -2.424 0.256 -0.0693657 268 10542.5 10771.5 RPD MAD031 OHMM 0.29 2000 109.204 306 10640 10792.5 RPM MAD031 OHMM 0.34 2000 106.473 306 10640 10792.5 RPS MAD031 OHMM 0.3 402.41 37.2477 306 10640 10792.5 RPX MAD031 OHMM 0.29 1444.2 67.9242 306 10640 10792.5 FET MAD031 HR 9.4 86.29 14.3708 306 10640 10792.5 GR MAD031 API 18.48 499.58 102.986 445 10555.5 10786 PEF MAD031 B/E 1.15 13.49 4.30097 268 10542.5 10771.5 RAT MAD031 FPH 1 1073 222.884 441 10618.5 10838.5 NPHI MAD031 Pu-S 4.23 54.52 19.3978 237 10638.5 10756.5 First Reading For Entire File..........10542.5 Last Reading For Entire File...........10838.5 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/10 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.007 Page 15 Physical EOF B10AO02252009SSN.txt Tape Trailer Service name .............LISTPE Date . ...................09/04/10 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 Date . ...................09/04/10 Ori in ...................STS Ree~ 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 16