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207-110
taste F'rc~j+~ct 1~(elt History FAIL Cc~v~r i~a~e 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. - ~ L Q Well History File Identifier Organizing (aone> ^ Two-sided III (I'II) II II I II III ^ Rescan Needed II I II'I II II II III III RESCAN DIGI AL DATA ~olor Items: Diskettes, No.1 Greyscale Items: ~ ~ ^ Other, No/Type: G~ ^ Poor Quality Originals: U ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ { ~ Qg !s/ Project Proofing BY: Date: ~ G' 1 ~ ~l O g /s/ Scanning Preparation BY: Maria _x30= Date: ' Production Scanning + ~_ =TOTAL PAGES~,~ (Count does not include cover sheet) S /s/ Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanni Pre aration: ~ES _ BY: _ Maria Date: I a, ~ S ® 8 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~ 1 NO °humiuiiiiuu Res~.~~ed iuumumiiiii BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III IIII III P 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMNIIION JAN 2 3 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Ld Squeeze Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. ShutdownE Stimulate - Other ❑ Re -enter Suspended WOO 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development la Exploratory ❑ i 207 -110 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 20582 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: r f ADL0028285 PBU G -09B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12445 feet Plugs measured None feet true vertical 9023 feet Junk measured See Attachment feet Effective Depth measured 12392 feet Packer measured 8896 feet true vertical 9024.26 feet true vertical 7895.82 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" x 30" 30 - 110 30 - 110 0 0 Surface 2643 13 -3/8" 72# L -80 29 - 2672 29 - 2671.83 4930 2670 Intermediate None None None None None None Production 9453 9 -5/8" 47# L -80 28 - 9481 28 - 8391.69 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10500 - 11050 feet 11540 - 12391 feet True Vertical depth 9028.31 - 9019.13 feet 9029.61 - 9024.26 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 9 -5/8" Baker ZXP Packer 8896 7895.82 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): scAtitiED APR DR i 9 20 Treatment descriptions including volumes used and final pressure: t � 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 686 54728 19 0 975 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorLj Development 0 " Service ❑ Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil is Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Summerhay Title Petrotechnical Data Technician .. i Signatur• Phone 564 -4035 Date 1/23/2013 RBDAAS JAN 2 82013 #4,,.f 1 - /' '51 • 4/14103 Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028285 GTIvITYDATE SUMMARY w . . cope; • wi •rgano queeze CRETE 10/4/2012 Rig up.. * *job continued on WSR 10- 05 -12 ** * *Job continued from WSR 10- 04 -12 ** CTU 8 w/ 1.75" CT. Scope; GSO with Organo SEAL & Squeeze CRETE MU and RIH w/ BHA; 1.9" ctc, 1.7" dfcv, 1.69" disco, 1.69" crossover, two 2" stingers, 2.1" crossover, 2.25" JSN (oal= 11.58'). tagged soft bottom @ 12158'. Pickup wt = 27k. pulled 7k over (34k) appeared to be dragging then pulled at 27k. Assuming IPC fill. POH. LD nozzle assy. MU 1- 11/16" motor and 2.30" mill assy. Clean out easily to hard tag at 12380' CTM. Chase any solids up hole w/ fresh PowerVis. POH. LD milling assy. MU same 2.25" JSN assy and RIH. * *Held ER Drill; packoff failure ** Load well and perform injectivity test NH4CL. Tag bottom at 12382'. Pump 48 bbls of 12% HCL and swap to mud acid while 10/5/2012 reciprocating 10500- 12380'. * *job continued on WSR 10- 06 -12 ** * *Continued from WSR 10- 05 -12 ** CTU 8 w/ 1.75" CT. Scope; GSO with Organo SEAL & Squeeze CRETE Continue pumping 9:1 mud acid while reciprocating from 10500 - 12380'. Follow w/ 50 bbls NH4CL down coil and 210 bbls down CTBS. Pooh. RIH w/ BHA; 1.9" ctc, 1.7" dfcv, 1.69" disco, 1.6" crossover, 2" crossover, 2.2" carrier w/ GR and CCL, 2" crossover, 2.1" crossover, 2.25" JSN (oal= 16.61') to tag of PBD at 12384' CTM. Log up hole to 9400' and paint flag at 11100'. POH. RIH w/ BTT 2 -7/8" composite plug and set at 11190' ELMD. POH. MU and RIH w/ BHA; 1.9" ctc, two 2" stingers, crossover, cmt nozzle. (oal= 8.25') top at 8600 and establish injectivity rate 2.5 bpm @ 1550 psi, 2 bpm @ 1500 psi, 1.5 bpm @ 1400 psi, 1 BPM @ 1340 psi .5 bpm © 700 psi . 10/6/2012 * *job continued on WSR 10- 07 -12 ** * *Continued from WSR 10- 06 -12 ** CTU 8 w/ 1.75" CT. Scope; GSO with Organo SEAL & Squeeze CRETE RIH w/ BHA; 1.9" ctc, two 2" stingers, crossover, cmt nozzle. (oal= 8.25') . Finish pumping NH4CL down CTBS and follow with 165 bbls diesel. Pressure up IA to 1500 psi. Start pumping 250 bbls organoseal while reciprocate over perf interval 10500 - 11050' at initial 0.6 bpm /1670 psi whp, 0.4 bpm /2160 psi after 100 bbls into formation. Pump a total of 256 bbls of OS at final 0.4 bpm /2360 psi + 6 bbls FW + 35.5 bbls of 14.1# Squeeze Crete. Layed in cement from bottom perf. Saw immediate pressure response and whp rose to -2850 psi before breaking back. Broke back numerous times at -2640 psi. Opened choke w/ 10 bbls left and maintained 2600 psi while PUH to safety. WOC for one hour and lost 90 psi, IA gained 26 psi. Dropped ball and circ'd biozan to nozzle. Contaminated liners to PBD 10/7/2012 * *job in progress ** . • Daily Report of Well Operations ADL0028285 * *job continued from WSR 10- 09 -12 ** CTU 8 w/ 1.75" CT. Scope; GSO with Organo SEAL & Squeeze CRETE RIH w/ BHA; 1.75" ctc, 1.7" dfcv, 1.69" jars, disco, circ sub, motor, 2.3" 5 blade junk mill (oal= 18.7'). sat down at 9008' pump 10 bbls power vis sweep while milling to 9021. Motor stalled.. Attempt to pickup.. BHA stuck. start working jars and shock pump for 1 hr. and freed BHA. cont circ power vis and pooh chasing returns @ 80 %. FP wellbore to 700' w/ McOH. RDMO to SWS yard for planned maintenance Job not complete -will return in -two days to finish cleanout and mill 10/8/2012 composite plug CTU #3 1.75" Coil Tubing - Job Scope: Mill out cement in tubing and liner. RU and MU BKR milling assembly. 10/11/2012 ** *Job continued on 10/12/12 WSR * ** Cont' from WSR 10/11/12 ... CTU #3 1.75" Coil Tubing - Job Scope: Mill out cement in tubing and liner. RU and MU BKR 2 -7/8" motor and 3.79" Turbo Mill. Tag cement stringer at 7838', PU and mill through stringers down to liner top at 8696'. Chase returns at 80% to surface. Unstab and MU 4.36" 5 bladed Metal Muncher. RIH and mill from 7838 - 8696'. POOH. Unstab and MU 2 -1/8" motor and 2.64" 3 bladed Metal Muncher junk mill. (see log for milling 10/12/2012 details). Job continued on 10/13/12 WSR ... Cont' from WSR 10/12/12 ... CTU #3 1.75" Coil Tubing - Job Scope: Mill out cement in tubing and liner. RIH w/ 2 -1/8" BKR Extreme "X" motor and 2.64" 3 bladed Metal Muncher junk mill. Mill from 3 -1/2" linertop at 8696' down to 2- 7/8 "x3- 3/16" X -0 at 10581' w/ 2.64" mill at -2fpm. (see log for milling details). After tagging down on the X -O at 10581' a 1/2" steel ball was pumped to shear the circ sub. Cuttings swept w/ a 16bbI pill of PowerVis and chased OOH at 10/13/2012 80 %. Job continued on 10/14/12 WSR ... Cont' rom WSR 10/13/12 ... CTU #3 1.75" Coil Tubing Job Scope: Mill out cement in tubing and liner. Sheared circ sub and chased cutting at 80% OOH. MU and RIH w/ 2- 1/8" Extreme "X" motor and 2.36" 3 Bladed Opti -Cut junk mill. Mill cement from 10581 - 11085'. Broke through cement at 11085', didn't see any more motor work down to 11150'. PUH and pop circ sub, pump PowerVis pill and chase cuttings back to surface. Unstab and change out circ sub. RIH w/ 2 -1/8" motor and 2.36" Opti -Cut junk mill. Job 10/14/2012 continued on 10/15/12 WSR ... • • Daily Report of Well Operations ADL0028285 Cont' from WSR 10/14/12 ... CTU #3 1.75" Coil Tubing - Job Scope: Mill out CBP in liner and push to bottom. RIH w/ 2 -1/8" motor and 2.36" Opti -Cut junk mill. Tagged down on CBP at 11172'. Began milling plug and pushed to 12361'. Attempted to push deeper multiple times with no success. Began POOH, at 10787' started pulling heavy. Reciprocate in and OOH several times making it up hole farther each time before getting stuck at 10658'. Attempted to work pipe free w/ no success. Slacked off and pumped PowerVis down coil in attempt to lock up perfs to regain circulation up backside, formation was taking all fluids. After getting jars to fire, decision was made to drop a ball and shear disconnect. Pulled free, POOH and FP tubing w/ 40bbls of 60/40 methanol. Unstab and begin chain and bearing inspection, change packoff and perform BOP test before continuing w/ fishing job. Job continued on 10/16/12 WSR ... NOTE: FISH IN HOLE: Disconnect 2.13 "x.85' (2 -1/2" fish neck, 1.81" profile), circ sub 2.13 "x1.02, Extreme X motor 2.13 "x8.17', 3 bladed Opticut Junk Mill 2.36 "x1.14' (Max OD = 2.36 ", OAL = 11.18') 10/15/2012 Cont' from WSR 10/15/12 ... CTU #3 1.75" Coil Tubing - Job Scope: Make clean out run to fish, fish BHA. Performed chain inspection and weekly BOP test. RIH with slim hole jet swirl nozzle BHA. Cleaned out to fish at 10556' CTMD. RIH to top of fish with 1- 11/16" fishing BHA. Swap well over to diesel. Job continued on 10/16/2012 WSR 10 -17 -12 ... Cont' from WSR 10 -16 -12 .... CTU #3 1.75" Coil Tubing - Job Scope: Fish Stuck BHA. RIH with Fishing BHA and swap well over to Diesel. After 50 jar licks, POOH with Fishing BHA #1, cut 150' of coil, pick up Fishing BHA #2. RIH and latch up to fish and began jarring. Tried applying whp and dumping choke while jarring, found 0.1 -0.2 bpm leak -off rate. After 50 licks pulled up and began inj. test to determine flow around tool. Noticed breakdown around 2100 psi WHP - 1.0 bpm @ 2040 psi, 0.5 bpm @ 1910. After breakdown was noticed continued pumping around motor until lube 776 spotted around it. Relatched to see if it could be pulled to no joy. Began POOH while swapping well to diesel with lube 776 in 10/17/2012 preparation for next run. Job continued on WSR 10 -18 -12 .... Cont' from WSR 10 -17 -12 CTU 3 - 1.75" Coil Tubing Job Scope: Fish Stuck BHA POOH with BHA #2 and pick up fishing BHA #3. RIH and begin spotting 9:1 mud acid across fish. Noticed pulling heavy when pumping acid and tried to get back up into the 5 1/2" tubing. Could pull up only by pumping down coil and opening choke. Coil detained at —9290'. Can still pump down coil but no returns and no jar action. 10/18/2012 ...Job continued on 10- 19 -12... • • Daily Report of Well Operations ADL0028285 ...Job continued from WSR 10- 18 -12... CTU 3 - 1.75" Coiled Tubing Job Scope: Fish Stuck BHA, Try to free downhole tools by pumping down backside with weight set down and then pulling up while dumping WHP. No communication across tools. Pumped N2 down coil to displace and give N2 time to cross bridge and flush. 10/19/2012 ...Job continued from WSR 10- 19 -12... CTU 3 - 1.75" Coiled Tubing Job Scope: Fish Stuck BHA Spot 10.5 ppg NaCL brine below detained BHA as kill fluid and then pump 5/8" disconnect ball down with diesel w/ DRA. Had trouble launching ball and pumped away 10.5 ppg brine under BHA. Ball over gooseneck but no indication of ball on seat/ disconnect function. Pump second 5/8" ball did not see it seat or shear. Could not get disconnected even after bypassing the Micromotion to better hydraulically assist getting unstuck. Pressured up annulus to 1500 psi while jarring done, no movement noted from any attempts to move the stuck BHA. Set down weight and pump WHP up to 3000 psi. 10/20/2012 ....Job continued on WSR 10- 21 -12... ...Job continued from WSR 10- 20 -12... CTU 3 - 1.75" Coiled Tubing Job Scope: Fish Stuck BHA Still detained in well. 3000 psi of WHP and weight set down. Dumped choke and cycled weight with no noticable change. Well support arrived and rigged up pressure tested Kill Port. Tried surging wellhead while cycling weight, pipe still detained. Prepare equipment for retrieval. 10/21/2012 ...Job Continued on WSR 10- 22 -12... ...Job continued from WSR 10- 21 -12... CTU 3 - 1.75" Coiled Tubing Job Scope: Coil Retrieval Go over preparation and procedure with crew. Use 60/40 meth down coil to kill well and monitor no flow condition. Pull 24k lbs. and close slip rams of BOP, test slips by snubbing extra 5k lbs. Closed pipe rams and manually locked down. PT above pipe rams to 500 psi. Break lubricator and strip up injector. Hot tap and cut coil. Install external slip connector on downhole coil stub and Full Open TIW valve installed and closed. Stacked down lubricator and prepared uphole end of coil with double cold roll connector before setting down injector. Folded up T -bar and prepared for E -line operations through coil stub. Performed PT of e -line lubricator to 500 psi and opened TIW so that the coil could be refilled with 60/40 meth and backside no flow performed. Radio silence enforced and chem cut tools armed and deployed. 10/22/2012 Continued on WSR 10 -23 -12 • • Daily Report of Well Operations ADL0028285 * ** JOB CONTINUED FROM 22 -OCT -2012 * ** RIH AND TAG AT 9255FT. INSTRUCTED TO CUT AT LEASTTWO FEET ABOVE TAG DEPTH. CUT COIL AT 9252.5FT. POOH. AND CONFIRMED CUTTER FIRED NORMALLY, STAND -BY AND CONFIRMED CUT BY PULLING FREE WITH COIL, RIG DOWN AND RELEASE ELINE. TURN OPERATION BACK OVER TO COIL. 10/23/2012 ** *JOB COMPLETE * ** ...Job continued from WSR 10- 22 -12... CTU 3 - 1.75" Coiled Tubing Job Scope: Coil Retrieval E -line fired chemical cutting tool 9252.5' ELMD, 2' above tag at connector. Pressure in Coil x Tubing annulus slowly increased to 40 psi after fired. E -line POOH and bump up at surface and ensure tool released from head catcher. Pumped 60/40 kill down coil via kill port while taking returns from Coil x Tubing annulus with 1:1 returns, get full circ to 60/40. Perform no -flow test - good. Pop off E/L lub. Close TIW. Rig down E/L equipment. Check coil for flow. Good. Cut off TIW valve. MU double cold roll. Reconfigure scaffolding. Strip injector over connector. PU to previous hanging weight of 24k #. Open pipes and slips. Pull free /no overpulls. Put 4 wraps on the reel. Close gooseneck rollers. POOH, pumping meth /wtr down backside to fill hole. Perform swab checks from 300'. Swab closed. Blow down reel with N2. Begin RDMO 10/23/2012 ...Job Continued on WSR 10- 24 -12... Continued from 10/23/12 WSR. CTU 3- 1.75" Coiled Tubing Job Scope: Coil Retrieval Complete Rigdown. Road to shop for maintenance and pipe swap. 10/24/2012 Job complete. FLUIDS PUMPED BBLS 7035 1% KCL 71 METH 439 POWER VIS 685 3% NH4CL 87 FRESH WATER 48 12% HCL ACID 54 50/50 METH 51 9:1 MUD ACID 256 ORGANO SEAL 65 BIOZAN 445 DIESEL 35 SQUEEZE CRETE CEMENT 642 60/40 METH 405 DIESEL WITH LUBE 776 • • Daily Report of Well Operations ADL0028285 308 DIESEL WITH DRA 10626 TOTAL • Casing / Tubing Attachment ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" x 30" 30 - 110 30 - 110 LINER 821 3 -1/2" 9.3# L -80 8696 - 9517 7723.74 - 8422.08 10160 10530 LINER 594 7" 29# L -80 8975 - 9569 7963.64 - 8466.16 8160 7020 LINER 1064 3- 3/16" 6.2# L -80 9517 - 10581 8422.08 - 9027.6 LINER 1846 2 -7/8" 6.4# L -80 10581 - 12427 9027.6 - 9023.94 10566 11165 PRODUCTION 9453 9 -5/8" 47# L -80 28 - 9481 28 - 8391.69 6870 4760 SURFACE 2643 13 -3/8" 72# L -80 29 - 2672 29 - 2671.83 4930 2670 • TUBING 8869 5 -1/2" 17# L -80 27 - 8896 27 - 7895.82 7740 6280 TUBING 127 4 -1/2" 12.6# L -80 8896 - 9023 7895.82 - 8004.8 8430 7500 • TREE= aw 'A6.LFEAD= McEVOY • SAL NOTES:*'' *W ELL ANGLE> 70° ta 10342' * ** ACTUATOR = OTl G -0 9 B KB. BP/ = 64.14' BF. B..EV = 35.54' I - KOP= 3000' - Max Angle = 97° r„ 10617 1 2097' N SSSV CA MCO LAM)I G NP D= 4.662" Datum MD= 10064' Datum TVD = 8800" 800' SS Z ( 2584' 1—I a.5-51:78. [TJ PKR 113- 3 /8" CSG, 72#, L-80, D = 12.347" H 2677 ■ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2986 2984 9 CA CMY Pot 0 09/17/12 , Minimum ID = 2.377" @ 10581' 11 5104 4834 34 CA DMY RK 0 09/17/12 3 -3/16" X 2-7/8" XO 10 6269 5787 41 CA DMY RK 0 08/04/93 9 6417 5896 43 CA DMY FE 0 08/04/93 BKR 45A2 RETRBVA D PKR, D = 2.690" 1-1 8696' a 7070 6388 39 CA oMY RK 0 08/04!93 . 7 7215 6501 39 CA DMY RK 0 08/04/93 BOT C-2 LNR FLUTED DEPLOY M03'IT — 1 8703' 11111W,„ 6 7661 6856 36 CA D RK 0 08/04/93 SLV, D = 4.00" MY 5 7802 6971 35 CA CMY RK 0 08/04/93 4 8217 7316 33 CA DMY RK 0 08/04/93 13.70" BOT DBRLOY MENT SLV, 13= 3.00" 1-J 8710' 3 8364 7440 32 CA DMY RK 0 08/04/93 13 1/2" HES X NP D = 2.813 H 8729' 1 2 8627 7665 30 CA CMY RK 0 08/04/93 I *'1 8767 7785 31 CA CMY RK 0 09/14/07 "ST. #1 BERN/ 9/2007 SIDETRACK LNR 1 I I 8834' I 5-112" CAMCO SLIDING SLV, D = 4.500• (BERN/ PIPE) 8896' 1— TBG SEAL ASSEM3LY (SBR) (BERN/ PIPE( 1 I5 -1/2" TBG, 17 #, L-80, .0232 bpf, D = 4.892" H 8896' 1 8896' I -I9 5J8" BKR PFCR D = 4.00" 1 8960' H4 -1/2" X OTIS NP, D= 3.813" (Belle PIPE) 1TOPOF7"LNR —1 8975' 1TOC --J 8976' I 1 III 8991' 4 -112" XN OTrs MP, 13= 3.725" � (BEi1ND LNR) MLLE) OUT 01!19/99 (41/2" 113G, 12.6#, L -80, .0152 bpf, D = 3.958" 1 9023' , •4 Ill ' • 9023 j-14-1/2" TBG TAI_ (BE BEHIND UM) . 3 41 • 1 9025' —IELMD TT LOGGED 02/13/91 1 9-5/8" CSG, 47#, N-80, D = 8.681" 9481' ' A 4 r4�4 ! _____. ELM j FISH - BHA STUCK IN HOLE (10/23/12) I 13-1/7 LP, 9.3#. L-80 STL, .0087 bpf, D = 2.997 9517' ,$i V ( 9517' H3 -1/2" X 3 -3/16" XO, ID= 2.786" 1 7 1 0 • fi4 V WHIPSTOCK H 9565' • • i�• 1 • .1 ♦, MLLOUT WWOW (G -09B) 9569' - 9577' • 1% 10681' — 13.3116 X2-7/8" )D, D = 2.377' I) 17" CSG, 29#, N-80, = 6.182 I 10364' - .4 iI PERFORATION SIX�MARY '':11; 10660' ELM/ FISH - BHA REF LOG: IVCNUGR/CCL on 09/10/07 ' r• , 10/15/12 ANGLE AT TOP PBZF: 88° @ 10500' 3 -3/16" LW, 6.2#, 10581' Note: Refer to Production DB for historical perf data L-80 ICI, .0076 bpf, SEE SPF INTERVAL Opn/Sqz DATE .4`•t 2" 6 10500 - 11050 0 09/12/07 ID= 2.80' I P87 -I 12392' ■ , 4 . O j ` 2" 6 11540 - 12391 0 09/12/07 2 -7/8" LNR, 6.4#, L-80 SIT_ -- 12427' .0058 bpf, D = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/01/81 ORIGINAL COMPLETION 10/30/12 MEF /.AAD FISH: 2 BHA'S(10/15- 23/12) WELL: G-0913 01/01!99 CTD SIDETRACK (0-09A) 11/10/12 PJC FISH CORRECTIONS PERMIT No: "2071100 09/13/07 NORDIC 1 CID SIDETRACK (G-09B) API No: 50-029-20582-02-00 09/15/07 /TLH CORRECTIONS SEC 12, T11N, R13E, 2616' FSL & 2367' FEL 01/11/10 SM /JMD DRLG DRAFT CORRECTIONS 09/20/12 WRR/JMD GLV C/O (09/17/12) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg . Alaska Oil and Gas Conservation Commission . LllAUG J Li i= 333 West 7th Avenue Anchorage, Alaska 99501 07 (, 1 0 Subject: Corrosion Inhibitor Treatments of GPB G -Pad -061 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G 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 numbers, to of he attached spreadsheet represents the well name, API and PTD p cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) G-Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 1 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 ,_7 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -258 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 DATE: 17- May -12 Stephanie Pacillo TRANS #: 5955 .Y Data Delivery Services Technician " i ` Makana K B ender Schlumberger Oilfield Services -.% Natural Resources Technician I1 a Data & Consulting Services R1ska 011 & Gas Conservation Commisst<; n! 2525 Gambell St, Ste. 400 , L, , ‘- Anchorage, AK 99503 `t: Office: (907) 273 -1770 WELL _ OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR ELECTRONIC NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS CD MPB -20 C4W7 -00008 X WATERFLOW RST LOG 30- Apr -12 1 1 G -09B BD88 -00204 X MEMORY PPROF W GHOST 20- Mar -12 1 1 • G -09B BD88 -00204 X MEMORY CNL BORAX IPROF 22- Mar -12 1 1 16 -22 BX69 -00028 X PPROF W GHOST DEFT 22- Feb -12 1 1 P2 -39 BYS4 -00024 X USIT 26- Mar -12 1 1 OWDW -C C2JC -00013 X USIT W CBL 23- Apr -12 1 1 J -26 C2JC -00015 X LEAK DETECT LOG 7- May -12 1 1 • X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd j� ®1 1Q12 Anchorage AK 99503 Anchorage AK 99508 t 1— j 0 0 12/30/10 Screrger NO. 5672 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambeil Street, Suite 400 1 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 _-. I Attn: Christine Shartzer ATTN: Beth �� 333 West 7th Ave, Suite 100 / i - 6 ccc..���,,, Anchorage, AK 99501 Y Job 8 Log Description Date BL Color CD E -05 8L65 -00011 MEM DDL 12118/10 1 1 - 3B AY1M -00056 PROD PROFILE '7( / 11/27/10 1 (, 6$ 1 11 -12 BCZ2 -00033 PROD PROFILE C — . 12106/10 1 '' M 1 01 -25 BG4H -00022 INJECTION PROFILE ajim- •I k r en�2. 1 04-24 AY1M -00058 PROD PROFILE ' , vat irmiggprEgiopmwmi. 1 P2 -16 B5JN -00077 EILEIMraiL r Iv 1 A-41 BCZ2.00030 it 11 /26/10 1 � 1 04 -08 BCRJ - 000566 �IrfEAND2L79:>`eT31X3Mr?��AI� 12/08/10 1 4 . vr. 1 1 01 -24A BBSK -00043 I6 Ili *iir.L 8 Y r• !! EK f_ � ' iSeN V"1� 1 04-10 AV1H -00051 INJECTION PROFILE O 7 -- • 12107/10 1 ,' j 1 15 -26B BD88 -00080 MEM PROD PROFILE ,-/ [S 12/12/10 1 2b6,-, , 1 2- 28B/0 -19 _ BCRJ -00055 PROD PROFILE rr 4 3 11/30/10 1 /x5' 1 07 -238 AY1M -00056 SCMT / — 11/28/10 a( 1 1 02.21A BBSK -00042 SCMT a.!'fd - oci • 11123/10 • 1 1 02 -228 BL65 -00006 SCMT O— y - 12111/10 • ' 1 1 18 -12B BBUO -00029 SCMT — 08/30/10 1 1 1 P2 -16 B5JN -00077 USIT L T , j a -- / a, - 11/28/10 1TT - 1 1 05 -278 BAUJ -00049 MCNL Q — 1 09/18/10 1 16 -06B BBSK -00037 RST • - 11/15/10 1 ± '?,t►* 1 G -098 BGZ7 -00005 RST _ 09/20/10 1 1 E -34L1 BD88 -00050 MCNL (} — / Jj 09/28110 1 1 W -219 BGZ7 -00012 CH EDIT PDC -GR USIT — • --- 11122/10 t'! • y,4 j 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotchnical 900 EeBenson Bata Center 1112-1 -1 4 ' 0 >! �, (� t 2525 Gambell Street, Suite 400 A NNE ) j, j A i' a I ,. Anchorage, AK 99503 -2838 • 1 : , 12/17/10 Sankrger NO. 5667 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 55503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD NK-65A BCRD-00064 RST ' a • .. 10/21/10 e, ....._ 1 G-09B 11649989 PEN2105111110701Eri 09/11/07 gyik•Rrei MI= 1 06-24A BCRD-00068 IMEMIP.,_. • - • , 11/12/10 111.61110WIX1I1 1 01-06A BCRD-00063 IMIIIIIIIIMMICrini, 10129/10 11111111EMILSW 023 1 G-29B AWJI-00113 MCNL - / . 10/06/10 'ill 1 W-37A BD88-00048 MCNL a ;' - ) / 09/12/10 ' 2141)8 I 05-07 BBKA-00077 LDL ,&. - A - 11124/10 6,1 1 12-29 B5J N -00067 I Ii2E • rklrerAl OFI_I I 10/13/10 ,i 1 1 K-12B BL65-00002 1!. 1 17-16 BBSK-00036 PROD PROFILE ... : - ''' e-i 1 11/12/10 Er OW , 1 K-128 BCUE-00094 MEM PROD PROFILE n ,.. —I c 11/22/10 1 4 C.d 1 • K-128 BCUE-00094 MEM PROD PROFILE • ''' -- L.... 11/23/10 1.. • . 1 12-04A B5JN-00069 ETIMIIIM7 M1111111111111=.1.1111.1.1.1111111. 1 09-25 AV1H-00048 INJECTION PRO ILE illiWillarrAfenteMMOIREMENIMMINVIIMIr 41, 1 06-02 BBKA-00075 ESIEWICaCZ:Mallr 11/19110 kilf,W, 111111111111111 1 18-138 BCZ2-00028 SCMT 04)1 -. _ 11/07/10 00 ( 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 11,4 MA - • - , , ED K ,,,,, 4 ?.. DI: ,.......,, • ,L' :.,i,,:„.,.. ' -.,, ' • . . I I 0, • t>,, \ ~ ~ ~- ~~ ~ ~ ,„ ~. e .= w_ +r 'q;~ x ~ ~ 4 ~. ~ 1 n V• r ~r '~ ~ _ ~ ~. ~~_ '' "~c~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc r/-® BAKER NV6F~E5 • Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKAI'lUN (ALASKA) 1NC CUUN 1'Y NUK'1'H SLUYE BUKUUGH WELL NAME G-09B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 2/6/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO # 1537273 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield Houston. Texas 77073 This Distribution List Completed By: ~~~ F~~ ~ ~ 20D ~. ~b`~- I ( ~ Page 1 of 1 • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7"' Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: G-09B Contains the following: 1 LDWG Compact Disc `_~ (Includes Graphic Image files) w 1 LDWG lister summary a 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) ~ ~ ~ ~a~~r . _ ., r _,~ .w ~' t=~a~.~ LAC Job#: 1537273 Sent by: Terri Tuminello Date: 0 ~ ~, ,~ Received by: n Date: j ~~ ,~ ~ ~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGl~ - ~ RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ MUQMES INTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~p~-lJd 1~.~ ~D DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071100 Well Name/No. PRUDHOE BAY UNIT G-096 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20582-02-00 MD 12445 TVD 9024 Completion Date 9/14/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, MCNL/GR/CCL Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name ~,EC _ _ - -- -- D C Las 15679 --- __ --- --- Induction/Resistivity '~ D Asc Directional Survey If.F~pt Directional Survey Neutron dfD C Li 15881 G R s amma ay Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y Chips Received? '-l'id' ~~ Analysis Y / N Received? {data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop ------ OH / CH Received Comments -----___-- 9439 12444 Open 11/9/2007 - --_-- _- ATR, GR, RPM, ROP w/PDS amd PDF graphics 9500 12445 Open 11/21/2007 I 9500 12445 Open 11/21/2007 5 Blu 1 8410 11210 Open 1/22/2008 MCNL, GR, CCL, CNL in ~~ Carrier 11-Sep-2007 i 8407 11221 Open 1/22/2008 LIS Veri, CR, CNT Sample Set Sent Received Number Comments Daily History Received? Formation Tops Comments: Samples No Compliance Reviewed By: Directional S -- _ Date: ~`-~ r ~- , J ~~ • C] "~' s NVGN~ INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Fax 907-267-6623 To Whom It May Concern: November 16, 2007 Please find enclosed directional survey data for the following wells: G-09B ~ OS-lOC OS-22~' K-08B X-30APB 1 X-30APB2 X-30A X-20A Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. . G' ~ ~~ RECEIVED BY. ~ ,State of Alaska AOGCC DATE: ~ 4 ~ ~ l5 Cc: State of Alaska, AOGCC Date 1 1-09-2007 Transmittal Number:92919 ~1-. BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) t- you have any questions, please contact llouglas llortcri at the Yll(..; at Jb4-4y ~ s delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: _ ~,_ _ C-046 ._~_4~--_O'.~___!_;.~.~:__._..__. P2-1.5A ~1~.:~_c1.t,?"~ -.0~~._ i5,~.~s:~ '~ ; Please ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~; ;i4 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 !/ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, October 31, 2007 1:39 PM To: Saltmarsh, Arthur C (DOA) Cc: Stewman, Sondra D Subject: 10-407 Corrections Hi Art, I received one of your notes to make some corrections to the 10-407 that was submitted for: G-09B PTD #207-110 50-029-20582-02-00 You have indicated that the Completion Date (Box #5) should be 09/14/07. I agree and have made the correction. You have also made a note indicating that the window is at 9583' MD (8482' TVD). I disagree with that notation. Daily Drilling Report dated 09/02107 shows that the whipstock was set at 9565' (Time: 16:30) and that the Pinch Point is at 9569' (Time: 23:30}. From there on in the Daily Reports the Top of Window is continually noted at 9569'. In fact on 09/06/07 atie-in log was ran (Time: 23:40) and "zero correction'° is noted. I have checked the documents that we received from the rig and they also list the window as 9569'. What do you have that indicates a different depth? Thanks! Terrie 11 /1 /2007 STATE OF ALASKA /OG~~ ~ ~EC~EIVE® ALASKK"OIL AND GAS CONSERVATION COMMISSION T 07 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 0 C 2 2 20 Alaska Oil & Gas Cons. Commission 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 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban ~i~ib~ ~ ~ b 12. Permit to Drill Number 207-110 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded / 09/05/2007 ~ 13. API Number 50-50-029-20582-02-00 4a. Location of Well (Governmental Section): Surface: 2664' FNL 2367' FEL SEC 12 T R E 7. Date T.D. Reached 9/9/2007 ~ 14. Well Name and Number: PBU G-096 " , , . , 11 N, 13 , UM Top of Productive Horizon: 1009' FNL, 4030' FEL, SEC. 13, T11 N, R13E, UM 8. KB (ft above MSL): 64.10' Ground (ft MSL): 35.4' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2456' FNL, 3139' FEL, SEC. 13, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 12392 9024 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 657861 y- 5968977 Zone- ASP4 10. Total Depth (MD+TVD) 12445 9024 16. Property Designation: ~ ADL 028285 TPI: x- 656276 y- 5965318 Zone- ASP4 Total Depth: x- 657198 y- 5963890 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No ubmit electronic and rint inf rmation r 20 AAC 25.050 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 printer ~nf~~r.,at~~n Apr ~ nnr ~~ rri~~• _ MWD, DIR, GR, RES, MCNUGR/CCL />f~J/6oi,/ G', ~t~ °M~ ~~~N~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2" x 3 urface 11 rf 11 C n r 13- / " 72# L-80 urfa 2 72' Surf 2672' 17-1/2" 344 cu Ar i et II - 47# L- rfa 4 1' rf 1 -1/4" 1 I 7" 29# L-80 8 75' 7 84 8-1 /2" I 'G' 3-1/2" x 3-3/1 9. / 6.2# L-80 696' 12427' 7224' 024' 4-1/ " 2 8 c la 'G' x - / " / .1 L-8 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 SPF 5-1/2", 17#, L-80 8896' 8896' MD TVD MD TVD 4-1/2", 12.6#, L-80 8896' -9024' 10500' - 11050' 9028' - 9019' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11540' - 12400' 9030' - 9024' DEPTH INTERVAL MD AMOUNT 8< KIND OF MATERIAL USEO 2400' Freeze Protected with 35 Bbls of McOH 26. PRODUCTION TEST Date First Production: October 6, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 10/14/2007 HOUrS Tested: 4 PRODUCTION FOR TEST PERIOD OIL-BBL: 845 GAS-MCF: 2501 WATER-BBL: 20 CHOKE SIZE: 94 GAS-OIL RATIO: 3238 Flow Tubing Press. 437 CaSing PreSS: 760 CALCULATED 24-HOUR fV\TE~ OIL-BBL: 5071 GAS-MCF: 15004 WATER-BBL: 119 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? Yes No Sidewal l Cores Ac wired? Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~~iJ~"_.~ji~J~V f None ~- 0 CT ~ f 20Q7 9' ~ r; Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ORI~~n~a~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, ff needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. None Shublik 9532' 8435' Sadlerochit 9647' 8530' Top CGL 9890' 8713' Base CGL 9991' 8803' 23S6 10020' 8828' 22TS 10082' 8877' 21TS 10160' 8929' Zone 1 B 10300' 9000' Formation at Total Depth (Name): Zone 1 B 10300' 9000' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby,certify that the foregoing is true and correct to the best of my knowledge. 0~~~~ / ~ Signed Sondra Stewman Title Drilling Technologist Date PBU G-09B 207-110 Prepared By IVame/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permi N./ A r v l No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). 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. IreM 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 ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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 Orrc3inal Only BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase ~, Description of Operations __ - ---_ 8/31/2007 100:00 - 01:30 1.50 MOB i P ~ j PRE Clean rig pits. Clean up location. Tubascope on location to UT I rig pits during rig move 01:30 - 01:45 0.25 MOB I P ~ ~, PRE PRE-RIG MOVE SAFETY MEETING. Review procedure, 01:45 - 12:00 10.25 MOB P 12:00 - 12:15 0.25 MOB P 12:15 - 15:30 3.25 MOB P 15:30 - 15:45 0.25 MOB i P 15:45 - 16:30 0.75 MOB P 16:30 - 17:15 i 0.75 RIGU P 17:15 - 17:30 0.25 RIGU P 17:30 - 18:15 0.75 RIGU P 18:15 - 22:45 4.50 BOPSU P 22:45 - 00:00 1.25 BOPSU P 9/1/2007 00:00 - 08:30 8.50 BOPSU P 08:30 - 12:00 3.50 RIGU P 12:00 - 14:00 i 2.00 RIGU P 14:00 - 14:15 0.25 PULL P 14:15 - 15:45 1.50 PULL P 15:45 - 19:00 3.25 PULL I P 19:00 - 21:00 2.00 PULL P hazards and mitigation for rig move to G-09B with Security, Nordic and SWS personnel. PRE Move rig 14 miles to G Pad. No incidents or delays. Position rig in front of well G-09. PRE SAFETY MEETING. Review procedure, hazards and mitigation for laying down rig wind walls. PRE Lay down wind walls. Re-install ladder and work platforms on well tree. They were pulled by mistake. PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. PRE Check WHP. WHP = 0 psi. Close all tree valves. Back rig over well. PRE ACCEPT RIG AT 1630 HRS, 8/31/2007. R/U Mini camp and cuttings tank. PRE SAFETY MEETING. Review procedure, hazards and mitigation for Picking E-Coil Reel off of Veco trailer. PRE Open bombay door. Pick E-Coil reel off of Veco trailer and set in reel stand support/drive pins. Close bombay door. PRE N/U BOP stack. M/U hardline inside reel, pressure bulkhead, and internal grapple. Rig up Tiger tank and hardline. Press test hardline. Respooled bridge crane in reelhouse. PRE Valve crew installed double valve on the IA to meet two barrier requirement due to leak in GLM #1. PRE Pressure and function test BOPE. Change out lubricator. Re-Grease tree to get good body pressure test. Test witnessed by AOGCC inspecter, Lou Grimaldi. Greased rig valves to get good tests. Could not get good test on Valve #3 on choke manifold. Rebuilt valve. PRE PJSM. Install internal grapple and pull coil to injecter head. M/U coil packoff to injecter. M/U BTT CTC and pull test. PRE Pump 4 bbl. Press test inner reel valve and hardline. Fill coil and press test hardline, reel and lubricator and packoff. Press test CTC. DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for making up BTT fishing BHA. DECOMP M/U BTT Fishing BHA #1 with GS spear, hyd disc, jars, XO, 15 jts 2-3/8" PH6, XO and CTC. OAL = 490.35'. DECOMP RIH with fishing BHA #1. Up wt at 8950' = 33K. Down wt = 16.5K. Circ well clean. Take returns to Tiger tank. Crude and diesel in returns. IA is in direct communication to tubing thru GLM #1 at 7931'. IAP = 475 psi. KICK WHILE TRIPPING DRILL, 18:30 DECOMP Shut down pumps and stab into top of liner w/ GS spear. Liner came free easily on first attempt. POOH w/ fish to surface. Up wt 39K. Printed: 10/3/2007 2:23:11 PM BP EXPLORATION Page 2 of 10 Operations. Summary Report Legal Well Name: G-09 Common W ell Name: G-09 Spud Date: 5/15/1981 Event Nam e: REENTE R+COM PLET E Start : 8/31/2007 End: Contractor Name: NORDIC CALIST A Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours II Task Code ~ NPT ~ Phase Description of Operations ' i _1 ---- - - - __ _~ 9/1/2007 ~ 21:00 - 21:15 0.25 PULL P ~ DECOMP Flow check at surface, stable. ~ 21:15 - 21:30 0.25 PULL P ~ DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for UO BTT fishing BHA and 2-7/8" Inr. 21:30 - 23:15 1.75 PULL P I, DECOMP Standback injector. UO BTT fishing BHA #1 and 15 jnts of ', 1 2-3/8" PH6 in pipeshed. 23:15 - 00:00 0.75 PULL P ~, DECOMP ; LD fish, recovered G seal, X-O, 19 jts of 2 7/8" FL4S liner and '~, ! 22' cut joint with centralizers. total length of fish is 610', note bottom few jts had some cmt bonded to pipe, but no signs of ~ I corrosion on any of the 2-7/8" Inr 9/2/2007 00:00 - 00:45 0.75 PULL P I i DECOMP ~ Finished LD 2-7l8" Inr in pipeshed. Jet cut had 100% I . penetration, good cut. 00:45 - 01:30 0.75 EVAL P ~ W EXIT Slickline on location. Position tools to bottom of beaver slide. Meanwhile change out radiator on engine #2 and have Tool Services inspect liner for Norm scale, none detected. 01:30 - 01:45 0.25 EVAL P ,WEXIT SAFETY MEETING. Review procedure, hazards and ', ~ mitigation for Slickline operations 01:45 - 04:00 2.25 EVAL P 'WEXIT ~ PU slick line tools to rig floor, Program caliper tool, PU to rig ~ ', ~ , floor, PJSM on handling and running procedures of PDS caliper '~ log, MU Caliper tool on slick line I ~ RU sheave, pack off, weight bar, spang jar, and PDS Caliper ~ ; tool 04:00 - 05:30 1.50 EVAL P ~I W EXIT ~ RIH with caliper to 9585' 05:30 - 06:00 0.50 EVAL P I W EXIT I Log up from 9585' to 8700' 06:00 - 07:30 1.50 EVAL P I li WEXIT ;, POH with PDS memory caliper logging tools. 07:30 - 08:30 1.00 EVAL P i ',WEXIT ~ Rig down SWS Slickline unit and download PDS memory I ~ caliper log. Good log, 7", 29# Liner is in good condition, log shows 7.19" ID across whipstock setting interval, so no scale, i cement or liner deformation in whipstock setting area. 08:30 - 10:30 2.00 STWHIP P ~j WEXIT NOTE: While SWS Slickline unit was pulling away from the rig at 0830 hrs, The 20' long lubricator mounted on the side of the unit, swung sideways and caught the rig stairs and pulled them off of the rig. Please see remarks. Equipment damage only. PJSM. Did E-line slack management. Reverse circ at max rate of 4.5 bpm at 3400 psi, 3 times to pump E-Line slack back into reel. Cut off 230' coil to expose E-Line. 10:30 - 12:00 1.50 STWHIP P WEXIT M/U SWS CTC and pull test with 35K. M/U BHI UOC and M/U ~ E-Line connection. Check E-Line, OK. Press test BHI UOC with 3600 psi. Good Test. 12:00 - 13:20 1.33 STWHIP P I WEXIT ~ M/U BTT 3.635" Generation II TT whipstock and Baker #10 setting tool. ~ M/U BHI Coiltrak and check offset to highside of whipstock, i ' 224.8 deg. j M/U Coiltrak to UOC. M/U injecter. BHA OAL = 81.34'. 13:20 - 15:45 2.42 STWHIP P ~ WEXIT RIH with BHA #2. BTT Gen II whipstock and Coiltrak BHA. 15:45 - 16:30 0.75 STWHIP P !WEXIT Log GR tie-in at 9500'. -12' CTD correction. ' RIH at tag PBTD at 9587. Up wt = 34.5K. 16:30 - 16:40 0.17 STWHIP P I WEXIT Position top of whipstock at 9565' with highside TF. Bottom of whipstock is 4.5' above PBTD of 9587'. ~ i~ Press up coil and set whipstock with 2850 psi when shear pins sheared. i I ' ~ I Stack 5K WOB at 9583' CTD, so whipstock is set OK. Printed: 10/3/2007 2:23:11 PM BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To Hours Task ', Code NPT I Phase Description of Operations 9/2/2007 ~ 16:40 - 18:30 , 1.83 STWHIP P WEXIT POH with Coiltrak and BTT setting tool. i Circ at 1 bpm at 210 psi. 18:30 - 19:30 , 1.00 STWHIP P WEXIT ; PJSM. S/B injector. UD & inspect whipstock setting BHA#2 OK. UO BOT & BHI whipstock running tools. 19:30 - 19:45 ~ 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for making up window milling BHA. ~ a ~ _ 19:45 - 20:30 0.75 STWHIP P WEXIT M/U window milling HA # ec con inui y, ~ _~ 1 1 LOC P&C EDC DPS 2 7/8" BOT X T 3 80" St ' M'll 20:30 - 23:30 3.00 STWHIP P 'WEXIT 23:30-00:00 ~ 0.50 STWHIP P WEXIT 9/3/2007 1 00:00 - 01:00 1.OOi STWHIP P WEXIT ( i 01:00-03:00 2.00 STWHIP P WEXIT 03:00 - 05:00 2.00 STWHIP P WEXIT 1 05:00 - 06:00 i i 1.00 STWHIP P ~ WEXIT 06:00-08:00 2.00 STWHIP P WEXIT I 08:00 - 10:00 ~ 2.00 STWHIP P WEXIT 10:00 - 11:30 1.501 STWHIP P WEXIT 11:30 - 13:40 2.17 STWHIP P WEXIT 13:40 - 15:45 2.08 STWHIP P WEXIT 15:45 - 16:00 0.25 STWHIP P WEXIT i 16:00 - 16:30 j 0.50 STWHIP P WEXIT 16:30 - 00:00 7.50 DRILL N RREP PROD1 9/4/2007 00:00 - 00:30 i 0.50 DRILL P PROD1 00:30 - 09:00 8.50 DRILL N RREP ~ PROD1 09:00 - 12:00 ~ 3.001 DRILL ~ N ~ RREP PROD1 - - reme, ring i , 3.80" HCC W indow MIII. Overall length = 45.74' RIH w/ window milling BHA #3 at min rate. Swap to 2% double slick KCL w/ 2# Biozan. RIH w/ pumps at min rate. Tag Pinch Point, 0.50/0.68 bpm, 278 psi, PU 4'. Increase pump rate, 2.6/2.6 bpm, 1575 psi. Pinch point called at 9569', 4' from TOWS. Mill 3.80" window at 2.6 bpm, 1760 psi, 1.1 K DHWOB Milling 3.80" window at 2.6 bpm, 1940 psi, 2.6k DWOB. Milled to 9570.7' Milling window at 2.6 bpm, 2430 psi, 3.5-4k DWOB. Milled to 9572' Milling window at 2,6 bpm, 2460 psi, 2-3k DWOB. Milled to 9573.5' Milling window at 2.6 bpm, 2470 psi, 3 K wob Milled to 9574'. Milled window at 2.6 bpm, 2650 psi, 3K wob, Milled to 9576'. 'Milled 3.80" window thru 7", 29#, N-80 liner at 9577'. Milled next 1.5 ft at 1 fph to ream window with reamer. Swap well to new FloPro. Mill 10' of formation. 2.7 bpm, 3000-3500 psi, 4-5K wob, Milled to 9587'. Ream window area up/down 2 times slowly. RIH with no pump. Clean window. POH. SAFETY MEETING. Review procedure, hazards and mitigation for laying out BHA. UO window milling BHA. Window mill and string mill gauged at 3.78 and 3.79" NoGo. Change out SW S power pack traction motor. Lock out /tag out all SCR's. SWS mechanics and electricians performing change out with help from crew. Raised pipe shed roof. Used Peak crane to replace traction motor. Changed out traction motor in 7.5 hrs. PJSM. M/U drilling build BHA #4. 1.5 deg motor, rebuild Smith Bicenter bit. no res. Overall BHA length = 66.11'. Stab injector. Surface testing MW D tools when new traction motor began smoking. Internal problem in electric motor end. Lock out /tag out all SCR's. SLB looking into options for traction motor ~ replacement. Locate re-built 550 traction motor in Nordic storage yard at Kuparuk, Y pad. Tool service picking up traction motor. I Motor on location at 1200 hrs. Correct traction motor. Printed: 70/3!2007 2:23:11 PM BP EXPLORATION Page 4 of 10 .Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ' Task Code NPT ' Phase Description of Operations 9/4/2007 12:00 - 14:45 ! 2.75 ~ DRILL N RREP PROD1 PJSM. Pull traction motor out of SWS power pack. 14:45 - 15:00 I 0.25 DRILL N RREP PROD1 SAFETY MEETING. Review procedure, hazards and ~ mitigation for raising pipeshed roof. 15:00 - 17:15 ! 2.25 ~ DRILL N RREP PROD1 Raise driller side pipeshed roof to allow access for the Peak craned to pick the traction motor. 17:15 - 17:30 i 0.25 i DRILL N RREP PROD1 SAFETY MEETING. Review procedure, hazards and ~I ~ mitigation for picking traction motor with Peak crane. 17:30 - 21:00 I, 3.50 DRILL N RREP PROD1 Pick failed traction motor with Peak crane.lnstall and alighn motor to pump. 21:00 - 21:10 I~ 0.17 i DRILL N RREP PROD1 PJSM for start up of Power Pack. Start up test sequence. ID 21:10 - 22:30 22:30 - 00:00 9/5/2007 00:00 - 01:40 01:40 - 03:00 03:00 - 03:10 03:10 - 03:40 03:40 - 06:00 06:00 - 07:00 07:00 - 09:30 1.33 1.50 1.67 1.33 0.17 0.50 2.33 1.00 2.50 09:30 - 11:00 ' 1.50 11:00 - 11:15 ! 0.25 11:15 - 17:00 I 5.75 17:00 - 18:00 ~ 1.00 18:00 - 19:30 I 1.50 19:30 - 23:20 3.83 DRILL N RREP PROD1 DRILL i N RREP PROD1 DRILL N RREP PROD1 DRILL N RREP PROD1 DRILL P PROD1 DRILL P PROD1 DRILL P PROD1 DRILL P I PROD1 i DRILL P i PROD1 DRILL I N I WAIT I PROD1 DRILL N RREP PROD1 DRILL N RREP PROD1 DRILL I N I RREP I PROD1 DRILL I N I RREP I PROD1 DRILL I P 23:20 - 23:40 ! 0.33: DRILL P 23:40 - 00:00 I 0.33 ~ DRILL P PROD1 PROD1 PROD1 leader. Identify steps in start up procudure. Lock out tage out of SCR's. Start up of Power pack. Rotation correct. Blower motor not functing. Trouble shoot blower motor issues. Wait on Nordic electrian. Rig 2 electrian timed out on rig mods. Await on rig#3 electrial from Kuparuk Wait on arrival of Nordic electrian. Nortic elecrticial reset breaker. Power pack successfully tested. PJSM for PU BHA MU BHA #4 with 1.5 degree motor bend. RIH Log initial tie-in with GR from 9450-9587'. -19' CTD correction. Tagged bottom on depth at 9587'. Drill build section in Shublik. 2.5 bpm, 3040 psi, 3-4K wob, 20 fph. Drilled to 9631'. Pull up into 7" liner to wait for N2 electrician. Check traction and blower motors to determine what was making high pitched noise. SAFETY MEETING. Reviewed plan forward for checking blower and traction motors with electricians and mechanics. Check motors with electicians. Determine this traction motor bearing on the drive coupler side has failed. Held meeting with electricians and SWS lead mechanic to determine plan forward. Send previous traction motor to SWS shop to pull bearing. Ordered new bearing. Will try to replace traction motor bearings in SWS shop and provide 1 good 550 traction motor. Check coupling and re-grease it. POH with BHA. POH up to 2600' with no traction motor noise or heat, maximum temp on bearings was 120 deg F. Traction motor is working fine now. Discuss way forward with lead SWS mechanic and electricians. Decide to drill ahead while watching traction motor closely and monitoring bearing temperatures closely. RIH while monitoring traction motor. Looks good. Will keep bearing temperature log to track bearing performance while drilling ahead. Drill build 2.56/2.59 bpm @ 3384 psi, 3200 psi FS,WOB 1.2K, ROP 22, BHP 5046 psi. DH AP 4145 psi, ECD 9.49 ppg. Drill to 9780. W iper to window. Drill build 2.46/2.49 bpm @ 3775 psi, 3200 psi FS,WOB 1.8K, Printed: 10/3/2007 2:23:11 PM • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~i Task Code i NPT ~ Phase I Description of Operations 9/5/2007 23;40 - 00:00 0.33 i DRILL P PROD1 ROP 80, BHP 5360 psi. DH AP 4242 psi, ECD 9.55 ppg. Drill to 9/6/2007 00:00 - 04:20 4.33 ~ DRILL P PROD1 Directionally drill 2.51/2.53 bpm @ 3347 psi, 3200 psi FS, WOB 2K,ROP minimal,DHP 5090 psi,DHann 4271 psi. ECD ~ 9.53 ppg. 04:20 - 05:00 0.67 DRILL P PROD1 Directionally drill 2.6/2.6 bpm @ 3138 psi, WOB 1 K,ROP minimal,DHP 4854 psi,DHann 4271 psi. ECD 9.53 ppg.50-60% chirt in cuttings Zone 4.Drilled to 9902'. Irradic pressures off bottom rubber on shaker . 05:00 - 07:30 2.50 DRILL P PROD1 POH to check bit and motor. Last 30 ft drilled was in Zone 3.. 07:30 - 08:30 1.00 DRILL ~ P PROD1 C/O bit and motor. Bit was fully rung out, graded at 8,2,1. C/O Motor. ~ M/U Smith BC Bit #3 with 1.5 deg Xtreme motor. OAL = ~ ~ 66.11'. 08:30 - 10:15 1.75 DRILL P i PROD1 RIH with build BHA #5 with Smith BC bit and 1.5 deg Xtreme motor. 10:15 - 10:55 ~ 0.67 ~ DRILL P PROD1 Log GR tie-in. -15' CTD. 10:55 - 11:10 0.25 i DRILL P PROD1 RIH to bottom. 11:10 - 14:00 2.831 DRILL P PROD1 Drill build section in Zone 3, 2.5 bpm, 3000-3500 psi, 1-2K ~ wob, 160L, 36 deg incl, 20 fph. 14:00 - 16:00 2.00 DRILL P ( PROD1 Drilled to 9960'. Drill build section in Zone 3, 2.5 bpm, 3000-3500 psi, 1-2K ~ ~ wob, 90L, 27 deg incl, 30 fph. i Drilled into Zone 2 at 10,000'. Drilled to 10,050'. 16:00 - 16:20 0.33 DRILL P ! PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 16:20 - 18:00 1.67 DRILL P ~ PROD1 Drill build section in Zone 2, 2.5 bpm, 3000-3600 psi, 1-2K wob, 30R, 45 deg incl, 90 fph. Drilled to 10,160'. 18:00 - 18:40 0.67 DRILL ; P PROD1 Drill build section in Zone 2, 2.5 bpm, 3000-3600 psi, 1-2K wob, 30R, 48 deg incl, 90 fph. DH CP 4980 psi, DHAP 4433 psi ,ECD 9.64. Drill to 10200'. 18:40 - 19:20 0.67 DRILL P PROD1 Wiper to window. 19:20 - 22:30 3.17 DRILL P PROD1 Drill build section in Zone 2, 2.5 bpm, 3000-3600 psi, 1-2K wob, 50R, 56 deg incl, 60 fph. DH CP 4980 psi, DHAP 4433 psi ,ECD 9.61. Drill to 10352'. 22:30 - 23:08 0.63 DRILL P PROD1 Wiper to 9480'. 23:08 - 23:40 0.53 DRILL P PROD1 Log tie-in. Zero correction. 23:40 - 00:00 0.33 DRILL P PROD1 RIH 9/7/2007 00:00 - 00:15 0.25 DRILL P PROD1 RIH 00:15 - 02:15 2.00 DRILL P PROD1 Drill build section, 2.5 bpm, 3000-3300 psi, 2-3K wob, 50R, ~ 62-90 deg incl, 50-100 fph. DH CP 5113 psi, DHAP 4467 psi , ECD 9.61. Drill to 10500'. 02:15 - 03:15 1.00 DRILL P PROD1 Wiper to window. 03:15 - 03:45 0.501 DRILL P PROD1 Drill build section, 2.5 bpm, 3800 psi, 3K wob, 75L, 88 deg incl, 100 fph. DH CP 5613 psi, DHAP 4525 psi ,ECD 9.71. Drill to 10561 EOB. 03:45 - 06:30 2.75 DRILL ~ P PROD1 POH 06:30 - 08:00 1.50 DRILL ; P PRODi C/O BHA. Bit #3, graded at 3,3,1. M/U HCC BC Bit #4 re-build, j Adjusted motor to 1.2 deg and M/U RES tool. BHA #6 OAL = ~ , 78.96'. 08:00 - 08:30 0.50 1 BOPSUF~ P PROD1 I Did weekly function test of BOPE. All rams functioned OK. 08:30 - 10:15 1.75 1 DRILL P ~ PROD1 ~ RIH with Lateral BHA #6 with HCC BC bit, 1.2 deg motor and ~ RES tool. Printed: 10/3/2007 2:23:7 7 PM BP EXPLORATION Page 6 of t0 Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 'From - To 'Hours Task 'Code', NPT 9/7/2007 10:15 - 11:00 0.75 DRILL P I 11:00 - 13:30 2.50 DRILL P j 13:30 - 15:00 I 1.501 DRILL I P 15:00 - 15:30 I 0.50) DRILL I P 15:30 - 16:45 1.25 DRILL P 16:45 - 18:15 1.50 DRILL P 18:15 - 19:25 1.171 DRILL P 19:25 - 20:45 I 1.331 DRILL P 20:45 - 21:40 0.92 DRILL P 21:40 - 22:00 0.33 DRILL P 22:00 - 22:40 0.67 DRILL P 22:40 - 23:50 1.17 DRILL P 23:50 - 00:00 0.171 DRILL P 9/8/2007 00:00 - 01:20 1.33 DRILL P 01:20 - 03:00 1.67 DRILL P 03:00 - 04:40 1.67 DRILL P 04:40 - 06:30 1.83 DRILL P 06:30 - 07:45 1.25 DRILL P 07:45 - 08:15 0.50 DRILL. P 08:15 - 08:45 0.50 DRILL P 08:45 - 09:30 0.75 DRILL P 09:30 - 10:45 i 1.25 DRILL P 10:45 - 12:15 I 1.50 DRILL P 12:15 - 12:50 I 0.581 DRILL I P 12:50 - 14:30 1.67 DRILL P 14:30 - 16:30 2.00 DRILL P 16:30 - 17:30 1.00 DRILL P 17:30 - 19:10 1.67 DRILL P Spud Date: 5/15/1981 Start: 8/31 /2007 End: Rig Release: 9/14/2007 Rig Number: N1 Phase Description of Operations PROD1 Log GR tie-in at 9500'. -20' CTD correction. PROD1 Log MAD pass with RES from window to Bottom, 500 fph, 0.5 bpm. ', PROD1 Drill Zone 1 B lateral section, 2.5 bpm, 3200-3800 psi, 20R, !~ 91 deg incl, 80 fph, ~~ Swapped to new FloPro at 10,655'. Drilled to 10,655'. PROD1 Drill Zone 1 B lateral section, 2.5 bpm, 2600-3400 psi, 90R, ~ 93 deg incl, 80 fph, Drilled to 10,700'. PROD1 I Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 ;Drill Zone 1 B lateral section, 2.5 bpm, 2600-3400 psi, 90R, ~ ~ 91 deg incl, 120 fph, I' i Drilled to 10,850'. II PROD1 ~ W iper trip to window. PROD1 Drill Zone 1 B lateral section, 2.5 bpm, 2900psi, 2600 psi = FS, 90R, 88 deg incl, 150 fph, Drilled to 11,020'. PROD1 Wiper to 9510'. PROD1 Log tie-in. correction -2'. PROD1 RIH to TD on wiper trip. Clean trip. ', PROD1 Drill Zone 1 B lateral section, 2.5 bpm, 2750psi, 2700 psi = FS, 90L, 90 deg incl, 150 fph, ~~, Drilled to 11065 possible fault over pulls. PT 314bb1 Continue to drill 2.5 bpm @ 3040 psi, 90L,89 degree Incl, 140 ROP, 5047 psi DH CP, 4364 psi DHAP, ECD 9.39. Drill to 11170. ~ PROD1 Wiper to window. PROD1 Wiper to window. Clean trip. I PROD1 Directionally drill 2.58 bpm @ 2900 psi, 90L,89 degree Incl, 140 ROP, 5008 psi DH CP, 4364 psi DHAP, ECD 9.37. Drill to 11320. PROD1 Wiper to window. PROD1 Directionally drill 2.58 bpm @ 2900 psi, 90L,89 degree Incl, ~ 140 ROP, 5008 psi DH CP, 4364 psi DHAP, ECD 9.37. Drill to 11,448'. PROD1 j W iper trip to window. Clean hole. PROD1 j Open EDC and cleanout 7" liner up to tailpipe and down. PROD1 Log GR tie-in. -6' CTD. PROD1 ~ RIH clean to 11,020'. PROD1 ~ MAD pass down from 11,020' to bottom. PROD1 Drill Zone 1 B lateral with RES tool. 2.6 bpm, 2700-3500 psi, 70L TF, 90 deg incl, 100 fph, Drilled to 11550'. PROD1 Drill Zone 1 B lateral with RES tool. 2.6 bpm, 2700-3500 psi, 30L TF, 90 deg incl, 80 fph, ~ Drilled to 11,590'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill Zone 1 B lateral with RES tool. 2.6 bpm, 2700-3500 psi, 30L TF, 90 deg incl, 150 fph, i Drilled to 11,750'. PROD1 ~ Wiper trip to window. Clean hole. RIH clean to bottom. ~ PROD1 i Drill Zone 1 B lateral with RES tool 2.6 bpm, 2700-3500 psi, i 30L TF, 90 deg incl, 150 fph, Printed: 10/3/2007 2:23:11 PM BP EXPLORATION Page 7 of 10 Operations. Summary Report Legal Well Common W Event Nam Contractor Rig Name: ...Date ~ Name: ell Name: e: Name: From - To G-09 G-09 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 1 Task i PLET A Code E NPT Spud Date: 5/15/1981 Start: 8/31/2007 End: Rig Release: 9/14/2007 Rig Number: N1 Phase ' Description of Operations r 9/8/2007 17:30 - 19:10 1.67 DRILL P --- __ __ PROD1 I Drilled to 11,909'. 19:10 - 21:00 1.83 DRILL P PROD1 ',Wiper to tail pipe. RIH to 9510. 21:00 - 21:15 0.25 DRILL P PROD1 I~ Log tie-in. correction -T. 21;15 - 22:15 1.00 DRILL P PROD1 RIH. Seen double the anount of cutting as bottom up from 7" casing flush. 22:15 - 23:35 1.33 DRILL P PROD1 I Drill zone 2A 2.55 bpm @ 3100 psi, FS 2850 psi, 75L, 89 deg ~~ inc1,170-225 ROP, 2K WOB, DHCP 5108, DHAP 4502 psi, ~I ECD 9.68 ppg. Drill to 12050'. 23:35 - 00:00 0.42 DRILL P PROD1 I Wiper to window. 9/9/2007 00:00 - 01:50 1.83 DRILL P PROD1 ~ W iper to window .Clean trip. 01:50 - 03:15 1.42 DRILL P ~ PROD1 I Drill zone 2A 2.55 bpm @ 3200 psi, FS 2850 psi, 90L, 95 deg ~ ( inc1,100 ROP, 2K WOB, DHCP 5152, DHAP 4559 psi, ECD I ~ 9.78 ppg. Drill to 12200'. ~~ 03:15 - 07:00 3.75 DRILL P ~ PROD1 Wiper to 10300. RIH. Swap to new FloPro. Wiper to tailpipe. ! , !RIH to bottom. 07:00 - 08:45 , 1.75 DRILL P PROD1 'Drill Zone 2A, 2.6 bpm, 2.6 bpm, 2700 - 3100 psi, 100L, 90 'fph, 91 deg incl, 'Drilled to 12350'. 08:45 - 10:15 1.50 DRILL P PROD1 'Wiper trip to window. Clean hole. Pull up to 4-1/2" tailpipe and cleanout 7" liner. RIH to window. 10:15 - 10:45 0.50 DRILL P PROD1 ~ Log GR tie-in, -12' CTD correction. 10:45 - 11:45 1.00 DRILL P PROD1 !~ RIH clean to bottom. i All liner is tallied and drifted. 11:45 - 14:10 2.42 DRILL P PROD1 Drill Zone 2A, 2.6 bpm, 2.6 bpm, 2700 - 3100 psi, 70L, 70 fph, 90 deg incl, ' Slower drilling with 30K overpull. Called TD. Drilled to 12,449 . 14:10 - 15:45 1.58 DRILL P PROD1 ~ Wiper trip up to tailpipe at 9025'. Cleanou 7" liner. RIH to window. 15:45 - 16:10 0.42 DRILL P PROD1 Log GR tie-in. -5' CTD correction. 16:10 - 17:10 1.00 DRILL P PROD1 ,Wiper trip back to TD. Clean hole. Tagged final TD at 12,445'. ~ 17:10 - 21:10 4.00 DRILL P PROD1 Mad pass to 10200'. 21:10 - 23:10 2.00 DRILL P PROD1 ~ POH. to 9480 open EDC. POH 23:10 - 23:20 0.17 DRILL P PROD1 PJSM for LD BHA. 23:20 - 00:00 0.67 DRILL P PROD1 LD BHA 9/10!2007 ; 00:00 - 00:15 0.25 CASE P RUNPRD !PJSM to picket job. 00:15 - 02:00 1.75 CASE P RUNPRD ~ Pump 57 bbl H2O, 13 bbl bleach,l9 bbl inhibitor, & 8 bbl ! MEOH. 02:00 - 02:10 0.17 CASE P RUNPRD ~ PJS for N2 blowdown. 02:10 - 03:00 0.83 CASE P RUNPRD N2 unit PT to 4000 psi. Bleed back to 1000 psi. open up to rig. ~ Pump 1500 SCFM for 15 min. 03:00 - 04:30 1.50 CASE P RUNPRD ~ POP off well. Cut off CTC. Install grapple. Pull test. Pull CT 'back to reel. Secure CT to reel. remove hard line from reel. 04:30 - 06:00 1.50 CASE P RUNPRD ;Lower reel to trailer and stage on pad. Spot cementing reel 1 'and PU cementing reel. 06:00 - 06:15 0.25 ~ CASE P RUNPRD ~I SAFETY MEETING. Review procedure, hazards and I ~i mitigation for pulling coil to injector. 06:15 - 09:30 3.25 CASE P RUNPRD !Pull test grapple, pull coil to injecter, stab coil. M!U BTT CTC and pull test. 09:30 - 09:45 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running liner with BTT tools. ~ 09:45 - 10:30 0.75 CASE P RUNPRD ,Prep rig floor and pipe shed to run liner, Pick up BTT tools. 10:30 - 13:30 3.00 CASE P RUNPRD j Run 57 jts, 2-7/8", STL Liner with BTT float equipment. Stop ~ ''and fill liner. ~. Printed: 10/3/2007 2:23:11 PM BP EXPLORATION Page 8 of 10 Operations Summary Report. Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task I Code NPT ', Phase Description of Operations 9/10/2007 13:30 - 16:45 ii 3.251 CASE I P I RUNPRD Run 38 jts, 3-3/16", TCII Liner, XO, 25 jts, 3-1/2", STL Liner, 16:45 - 17:45 17:45 - 18:00 18:00 - 20:30 1.001 CASE I P 0.25 CASE P 2.50 CASE P 20:30 - 22:50 I 2.331 CASE I P 22:50 - 00:00 ! 1.171 CASE I P 9/11/2007 1 00:00 - 03:30 ! 3.50 CASE P 03:30 - 03:45 i, 0.25 CASE P 03:45 - 06:15 1 i I 2.50 i I i CEMT P I 06:15 - 08:00 I i i I I 1.75 i EMT P 08:00 - 08:30 0.501 CEMT P 08:30 - 10:30 2.00 CEMT N 10:30 - 11:00 ~ 0.50 ~ EVAL P , it I 11:00 - 15:00 ! 4.00 EVAL P 15:00 - 16:15 1.251 EVAL P 16:15 - 18:30 I 2.25 i EVAL P "X" Nipple, two 3-1/2" STL pup Jts, BTT 3" seal bore deployment sleeve and BTT C-2 Liner Deployment sleeve. RUNPRD Press test inner reel valve and hardline. Pump dart. Dart landed at 58.8 bbls. Press test CTC. RUNPRD M/U CTC to BTT CTLRT. Liner BHA total length = 3,728.76'. RUNPRD RIH with liner on coil to TD no problems. Tag at 12458'.( RIH ~ wt+15K) PU 51 K set down and reconfim TD OK. RUNPRD i Stack 10K on liner. Launch ball 5/8 steel. Circulate to seat. Release liner with 4150 psi. PU 27K. Confirm release. RUNPRD i Suck down pits in preparation to swapping well to 2% KCL double slick. RUNPRD Swap well to 2% KCL double slick. RUNPRD PJSM for cement job. RUNPRD Batch up 46 bbls, G Cement. Flood cementing line and PT line to 4000 psi. Pump cement. @ 5 bbl 1.9 bpm 1070 psi @ 10 bbl 1.9 / 1.8 bpm ,1300 psi @ 15 bbl 1.9 / 1.8 bpm, 1570 psi @ 25 bbl 1.7/ 1.58 bpm ,1700 psi DS having problem with rate. Used choke to hold back cement from running away. Choke 80% closed @ 37 bbl .78 / 1.57 bpm, @40bb1 1.15 /1.24 bpm, 800 psi @46 1.09/1.18 bpm, 524 psi Lauch dart with 600 psi Zero In MM Displace with 30 bbl Bio and 2% KCL Caught fluid 30 bbl @ 38.2 BBL Zero out MM 2.5bpm @400 psi. @ 50 bbl pressure increasing @ 59.4 PU LW P, sheared at 3000 psi. Bump plug at 85 bbls right on count. Out total 42.1 bbls, Lost 3.9 bbl to formation. Held pressure 5 min. Bleed off, floats held. Sting out and circ 3 bbls Biozan at top of liner, Contaminate next 200' of tubing. RUNPRD POH with CTLRT BHA. Circ. with 0.2 bpm returns, 190 psi pump press. RUNPRD Lay out BTT CTLRT. Recover 100%. WAIT RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for raising rig wind walls. Raise rig wind walls and secure them. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS Memory CNL/GR logging tools and running CSH workstring. LOW ER1 M/U BHA #8 with 2.30" diamond parabolic mill, motor, 2 jts CSH, SW S logging carrier, circ sub, hyd discon, 60 stds of (CSH and SWS MHA. OAL = 3,819.76'. LOW ER1 RIH with BHA #8 with mill, motor, MCNL/GR and CSH !workstring. RIH to 8500'. LOW ER1 % Log down at 30 fpm. Tag at 12427, cement contaminated Printed: 10!3/2007 2:23:11 PM • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Spud Date: 5/15/1981 Event Name: REENTER+COMPLETE Start: 8/31/2007 End: Contractor Name: NORDIC CALIS TA Rig Release: 9/14/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~, From - To Hours Task ', Code NPT Phase Description of Operations 9/11/2007 16:15 - 18:30 2.25! EVAL I P LOWERI ------ returns 18:30 - 19:45 1.25 ~ EVAL P LOW ER1 Log up at 54 fpm to 8500' 19:45 - 21:00 1.25 ~ EVAL P LOW ER1 RIH started pumping pert pill, tagged btm at 10427', flagged EOP at 8607 21:00 - 00:00 3.00 I EVAL P LOWERI POH to BHA, dropped 5/8" steel ball, POH, displaced with 9/12/2007 100:00 - 03:00 I 3.00 03:00 - 04:00 04:00 - 05:30 9/13/2007 05:30 - 12:00 12:00 - 13:50 13:50 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 17:45 17:45 - 18:15 18:15 - 18:30 18:30 - 19:00 19:00 - 21:30 21:30 - 21:45 21:45 - 00:00 00:00 - 03:55 03:55 - 06:00 06:00 - 07:00 07:00 - 09:30 09:30 - 12:00 12:00 - 13:30 13:30 - 15:10 15:10 - 15:15 15:15 - 16:15 1.00 1.50 6.50 1.83 1.17 1.50 0.50 0.75 0.50 0.25 0.50 2.50 0.25 2.25 3.92 2.08 1.00 2.50 2.50 1.50 1.67 EVAL IP EVAL ~P I EVAL .P PERFOB~P PERFOf3~ P PERFOBIP PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFO P PERFOBIP PERFO P CASE P CASE P CASE P 0.08 CASE P 1.001 CASE P 30bb1 Biozan pill while spotting pert pill across 2 7/8" liner, opened circ sub, POH, pump 2.79bpm, 3069psi LOW ER1 Monitor well, PJSM on POH, STD back CSH, std back injector, POH with cleanout, logging assy, Std back total of 61 stds of 1 1/4" CSH LOWERI PJSM on LD logging assembly. Remove source then LD logging tools. LOW ERi PJSM for Liner Lap test. Pumped up CT to 2000 psi twice and pressure did not hold. Shut swab to troubleshoot surface equipment and pressure held. Opened swab, pressured up tubing to 2000 psi and IA at 2500 psi and pressure held. After 15 minutes, CT at 1850 psi and IA at 2440 psi. After 30 minutes, CT at 1820 psi and IA at 2418 psi. Bled pressure off CT to 0 psi and IA fell to 538 psi. Good Test. LOWERI PU tools and RU handling tools. Pu 90 guns and 61 joints 1-1/4" CSH. LOW ER1 PU injector. Make up to BHA. Tag TD correct to 12392'. LOW ER1 Drop 5/8" steel ball and launch with 1200 psi. disptace with 20 bbl Bio. circulate to fireing head. Ball on seat @ 56.3 bbp Versis 58.8 theoritical. Sheared at 3090 psi. Bottom shot 12391 ' LOW ER1 POH to 8686. top of liner LOWERI Flow check welt. O. K. LOWERI POH to CSH. LOWERI Flow check well O. K. LOWERI PJSM on RU handling tools and LD 1 1/4" CSH LOW ER1 RU handling tools, floor valve, bowl and slips LOWERI POH, LD 61 jts of 1 1/4" CSH, offload pipeshed LOW ER1 PJSM on handling and LD fired guns LOW ER1 RU handling tools, LD 31 guns with all shots fired LOWERI Continued LD 59 additional guns with all shots fired LOW ER1 PJSM to remove guns from pipe shed. Removed guns and stacked outside. Clean rig floor and pipeshed LOWERI PJSM to handling 1 1/4" CSH. RIH with 1 1/4" CSH from derrick LOWERI POH 1 1/4 inch CSH and L/D each joint in pipe shed. RUNPRD Load Packer and sealing assembly. PJSM. P/U packer and sealing assembly. MU injector. RUNPRD RIH packer and sealing assembly to 8625'. Zero correction to flag. Park at 8633'. Circualte at Min rate..16 bpm. RUNPRD PJSM to freeze protect IA with Little Red 1 bpm @ 1600 psi. Initial Pit Total initial 260 bbls. Returns from IA freeze protection taking into pits. Total 100 bbls pumped. RUNPRD Flow check. RUNPRD RIH tag up. PU to ball drop position and launch ball with 1000 Printed: 10/3/2007 223:11 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: G-09 Common Well Name: G-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ', Hours Task `Code' NPT 9/13/2007 ~ 15:15 - 16:15 ~ 1.00 CASE P j 16:15 - 17:30 I 1.251 CASE ' P 17:30 - 18:30 1.00 CASE P 18:30 - 19:00 0.50 CASE P 19:00 - 21:00 2.00 CASE P 21:00 - 21:30 I i 0.50 CASE P 21:30-22:30 1.00 WHSUR P 22:30-23:15 0.75 WHSURj P I 23:15 - 00:00 0.75 WHSUR ~ I P ', 9/14/2007 i 00:00 - 00:30 0.50 WHSUR ~ P 00:30 - 01:10 0.67 WHSUR P 01:10 - 02:00 0.83 WHSUR N 02:00 - 02:30 0.50 WHSUR N 02:30 - 03:00 0.50 WHSUR P 03:00 - 03:15 0.25 WHSUR P 03:15 - 05:30 2.25 WHSUR P 05:30 - 06:00 0.50 WHSUR P 06:00 - 07:45 07:45 - 08:30 08:30 - 08:45 08:45 - 10:30 10:30 - 12:00 1.75 WHSUR P 0.75 WHSUR P 0.251 WHSUR P 1.75 j WHSUR ~ P 1.501 WHSUR I P 12:00 - 16:00 4.001 RIGD I P Start: 8/31 /2007 Rig Release: 9/14/2007 Rig Number: N1 Page 10 of 10 ~ Spud Date: 5/15/1981 End: Phase I, Description of Operations RUNPRD ~ psi. Circulate ball to seat 2.3 bpm at 880 psi Sting into tie back at 19 fpm 18K In Wt. Tag and stack 10K. PU to neutral. Ball on seat @ 47.2 bbls. Shear at 2800 psi. RUNPRD Pressure CT X tubing annulus 900 lbpm injection thru running tool to perf. Little Red conduct MIT IA to 2500psi. for 30 min. 5.5 bbl required to pressure up annulus. Lost 110 psi in 30 min. Good Test. RUNPRD Circulate Well. Crude and gas to tiger tank. Partial to no returns through out micro motion RUNPRD Shut in and monitor well, shut in pressure 75psi, Hold PJSM on load testing traction motor gathering voltage and sine wave data with electrician and crew and POH RUNPRD POH to Baker running tool while holding 100psi back pressure on choke, pumping .75bpm, 330psi, returns are sporatic, lost approx 100bb1s, secured well, std back inj I Gathered voltage readings of 402volts, sine wave was steady with no noise or spikes, SCR's are delivering clean power while POH carrying load on traction motor RUNPRD PJSM on handling BHA, POH LD Baker running tool, 100 percent recovery, offload from rig floor POST i PJSM on Freeze Protecting well with McOH, offloading KCL to pits, MU nozzle BHA #11 with xo's, check valves, AOL 3.73' POST RIH to 2400', pumped 35 bbls of neat McOH POST POH to BHA, laying in McOH to a 60/40 mix, Jet across wellhead and stack POST Hold PJSM for setting BPV with a t-bar, Monitor well, stable, LD BHA #11, Set back injector POST Three attempts to set BPV failed. POST MU swizzle stick, stab injector, RIH flush out tbg hgr profile several times at 4 bbl/min, POH, std back injector, waiting on BPV from DSM shop POST Fourth attempt setting BPV failed while waiting on BPV from DSM shop, POST Changed out BPV, Set BPV, RD t-bar POST PJSM for pickling CT and N2 blowdown jobs. Spotting Vac trucks. POST Circulate coil with 15 bbl bleach, 60 bbl fresh H2O, 15 bbl inhibitor, 5 bbls MEOH, followed by N2 blow down. POST PJSM on handling and securing CT, Brk out injector, cut off CTC, LD stuffing box, Installing grapple POST PJSM & Pull back CT to reel. POST Secure reel POST PJSM and load out of reel. POST Standback injector POST ND BOP. Install tree cap and test. Remove hose bundle from Injector and prep injector for removal. POST Clean pits. Release Rig at 1600 hrs. Printed: 10/3/2007 2:23'17 PM • • by BP Alaska ~~$ Baker Hughes INTEQ Survey Report INTE Q Company: BP Amoco Date: `9/11/2007 Time: 1fi:42:53 Page: t Field: Prtulhoe Bay Co-ordiuate(NE) Reference: ` Welk G-09, True North. Site: PB G Pad Vertlcnl (TVD) Reference: 13:09 5/15/1981 00:00 64.1 VYell: G-09 Sectioo(Y5)Referenct' Welt(O.OON,O.OOE,188.63Azi} Wellpath: G-096 Snrvey Caknlatioa Method: Minimum Curvatute Db: Orade 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 G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Gronnd Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-09 Slot Name: 09 G-09 Well Position: +N/-S 2111.35 ft Northiug: 5968977.00 ft Latitude: 70 19 18.975 N +E/-W 1604.03 ft Easting : 657861.00 ft Longitude: 148 43 12.200 W Position Uncertainty: 0.00 ft Wellpath: G-096 Drilled From: G-09 500292058202 Tie-on Depth: 9500.00 ft Current Datum: 13:09 5/t 5/1981 00:00 Height 64.10 ft Above System Datum: Mean Sea Level Magnetic Data: 9/15/2007 Declination: 23.59 deg Field Strength: 57656 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.76 0.00 0.00 188.63 Survey Program for Definitive Wellpath Date: 6/20/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 100.00 9500.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 9565.00 12445.00 MWD (9565.00-12445.00) MWD MWD -Standard Annotation MD TVD ft ft 9500.00 8407.72 TIP 9565.00 8462.77 KOP 12445.00 9023.77 TD Survey: MWD Start Date: 9/6/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD' Incl Azim TVD Sys TVD N/S E/W MapPI MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 9500.00 32.45 228.69 8407.72 8343.62 -3161.13 -1610.34 5965782.93 656317.61 3366.95 0.00 MWD 9565.00 31.79 227.85 8462.77 8398.67 -3184.13 -1636.13 5965759.39 656292,31 3393.56 1.23 MWD 9589.88 33.43 223.84 8483.73 8419.63 -3193.47 -1645.74 5965749.85 656282.91 3404.24 10.90 MWD 9621.84 35.98 219.30 8510.01 8445.91 -3207.09 -1657.79 5965735.98 656271,15 3419.51 11.36 MWD 9653.98 36.84 215.30 8535.87 8471.77 -3222.27 -1669.34 5965720.57 656259.92 3436.25 7.86 MWD 9685.20 42.34 211.87 8559.93 8495.83 -3238.85 -1680.31 5965703.76 656249.30 3454.29 18.95 MWD 9700.26 43.93 210.35 8570.92 8506.82 -3247.66 -1685.63 5965694.84 656244.17 3463.80 12.61 MWD 9731.07 47.68 210.89 8592.39 8528.29 -3266.67 -1696.88 5965675.60 656233.32 3484.28 12.24 MWD 9762.83 46.54 203.84 8614.02 8549.92 -3287.30 -1707.57 5965654.75 656223.06 3506.29 16.65 MWD 9791.81 42.42 200.88 8634.70 8570.60 -3306.07 -1715.31 5965635.83 656215.72 3526.00 15.91 MWD 9817.95 38.46 194.88 8654.59 8590.49 -3322.17 -1720.55 5965619.61 656210.83 3542.71 21.23 MWD • • by BP Alaska Baker Hughes INTEQ Survey Report 1NTE Q Companyr BP Amoco Date: 9/11/2007 Time: 16:42:53 Pagc: 2 Field: Prudhoe Bay Co-ordirate(NE) Reference: UdeIL' G-09, True North Site: PB G Pad Vertical (TVD) Reference: 13:09 5/15/1 981 00:00 64.1 Well: G-0ii Seetioe(VSjRetereace: Well (t).OONO .OOE,188. 63Azi) WellpatL: G-09B Survey Calcalatioq Metbod: Minimum Curvature Db: Orade Survey MD [ncl Azim TVD Sys TVD N/S . E/W MapN MapE VS DIS Tool 8 deg.. deg ft ft ft ft ft ft ft deg/100ft 9845.36 36.22 196.47 8676.39 8612.29 -3338.18 -1725.03 5965603.52 656206.68 3559.20 8.90 MWD 9876.37 33.82 196.52 8701.78 8637.68 -3355.24 -1730.08 5965586.36 656201.99 3576.83 7.74 MWD 9906.87 30.37 181.21 8727.66 8663.56 -3371.12 -1732.67 5965570.43 656199.74 3592.92 28.89 MWD 9937.23 27.21 171.99 8754.27 8690.17 -3385.67 -1731.86 5965555.89 656200.85 3607.19 17.92 MWD 9970.86 25.54 159.68 8784.43 8720.33 -3400.10 -1728.27 5965541.55 656204.75 3620.91 16.97 MWD 9999.78 27.34 151.81 8810.33 8746.23 -3411.80 -1722.96 5965529.96 656210.30 3631.69 13.61 MWD 10031.14 33.25 152.08 8837.39 8773.29 -3425.76 -1715.53 5965516.16 656218.02 3644.37 18.85 MWD 10068.35 40.49 151.03 8867.14 8803.04 -3445.37 -1704.89 5965496.78 656229.07 3662.16 19.53 MWD 10097.85 45.39 152.79 8888.73 8824.63 -3463.10 -1695.44 5965479.26 656238.89 3678.27 17.10 MWD 10127.66 48.89 156.93 8909.01 8844.91 -3482.88 -1686.18 5965459.68 656248.56 3696.44 15.54 MWD 10157.14 52.51 161.86 8927.69 8863.59 -3504.22 -1678.19 5965438.51 656257,01 3716.34 17.83 MWD 10186.70 55.96 169.80 8944.98 8880.88 -3527.45 -1672.36 5965415.41 656263.32 3738.43 24.71 MWD 10217.06 59.25 169.57 8961.24 8897.14 -3552.67 -1667.77 5965390.29 656268.44 3762.68 10.86 MWD 10246.70 61.57 171.35 8975.88 8911.78 -3578.09 -1663.50 5965364.98 656273.24 3787.16 9.41 MWD 10275.52 63.20 178.93 8989.25 8925.15 -3603.50 -1661.35 5965339.61 656275.92 3811.97 23.98 MWD 10309.36 67.92 180.04 9003.25 8939.15 -3634.30 -1661.08 5965308.83 656276.84 3842.38 14.26 MWD 10342.13 74.61 177.57 9013.77 8949.67 -3665:31 -1660.42 5965277.84 656278.16 3872.94 21.63 MWD 10372.95 80.87 175.29 9020.31 8956.21 -3695.35 -1658.54 5965247.85 656280.67 3902.36 21.56 MWD 10402.37 84.96 172.88 9023.94 8959.84 -3724.38 -1655.53 5965218.89 656284.29 3930.61 16.10 MWD 10434.32 89.88 167.77 9025.38 8961.28 -3755.82 -1650.17 5965187.57 656290.31 3960.89 22.19 MWD 10462.04 86.71 165.12 9026.20 8962.10 -3782.75 -1643.67 5965160.78 656297.37 3986.54 14.90 MWD 10490.40 86.62 160.43 9027.85 8963.75 -3809.79 -1635.29 5965133.93 656306.32 4012.01 16.51 MV1fD 10519.80 90.80 156.75 9028.52 8964.42 -3837.14 -1624.57 5965106.81 656317.61 4037.45 18.94 MWD 10550.49 89.97 152.66 9028.31 8964.21 -3864.88 -1611.46 5965079.36 656331.30 4062.91 13.60 MWD 10581.41 92.73 150.08 9027.58 8963.48 -3892.01 -1596.65 5965052.55 656346.68 4087.50 12.22 MWD 10612.16 96.68 150.67 9025.06 8960.96 -3918.64 -1581.50 5965026.24 656362.38 4111.57 12.99 MWD 10644.76 96.64 156.00 9021.28 8957.18 -3947.57 -1566.97 5964997.63 656377.51 4137.98 16.24 MWD 10676.81 96.05 159.91 9017.73 8953.63 -3977.09 -1555.02 5964968.37 656390.08 4165.38 12.26 MWD 10708.47 90.98 160.82 9015.79 8951.69 -4006.84 -1544.41 5964938.85 656401.32 4193.20 16.27 MWD 10740.50 91.14 165.52 9015.20 8951.10 -4037.49 -1535.14 5964908.41 656411.23 4222.11 14.68 MWD 10771.84 87.94 168.28 9015.45 8951.35 -4068.00 -1528.04 5964878.05 656418.97 4251.21 13.48 MWD 10813.64 88.78 175.17 9016.65 8952.55 -4109.33 -1522.03 5964836.87 656425.85 4291.17 16.60 MVO 10841.90 88.52 179.48 9017.32 8953.22 -4137.54 -1520.71 5964808.69 656427.76 4318.86 15.27 MWD 10872.12 88.55 184.83 9018.09 8953.99 -4167.72 -1521.84 5964778.50 656427.26 4348.87 17.70 MWD 10902.94 88.62 190.26 9018.85 8954.75 -4198.25 -1525.89 5964747.89 656423.86 4379.66 17.61 MWD 10932.04 89.72 195.04 9019.27 . 8955.17 -4226.63 -1532.26 5964719.38 656418.08 4408.68 16.85 MWD 10968.11 89.78 200.85 9019.43 8955.33 -4260.93 -1543.37 5964684.86 656407.70 4444.26 16.11 MWD 10997.86 89.51 205.95 9019.61 8955.51 -4288.23 -1555.18 5964657.32 656396.47 4473.01 17.17 MWD 11029.06 90.86 208.36 9019.51 8955.41 -4315.98 -1569.42 5964629.27 656382.82 4502.60 8.85 MWD 11059.24 91.41 202.95 9018.92 8954.82 -4343.17 -1582.48 5964601.82 656370.33 4531.44 18.01 MWD 11092.85 89.44 198.21 9018.67 8954.57 -4374.63 -1594.29 5964570.12 656359.19 4564.31 15.27 MWD 11122.89 89.35 195.63 9018.98 8954.88 -4403.36 -1603.03 5964541.21 656351.05 4594.03 8.59 MWD 11156.30 90.43 191.50 9019.05 8954.95 -4435.83 -1610.86 5964508.59 656343.91 4627.31 12.78 MWD 11193.93 89.57 187.64 9019.05 8954.95 -4472.93 -1617.12 5964471.37 656338.43 4664.92 10.51 MWD 11224.39 89.14 184.18 9019.39 8955.29 -4503.22 -1620.25 5964441.02 656335.93 4695.34 11.45 MWD 11254.92 86.78 182.24 9020.48 8956.38 -4533.68 -1621.96 5964410.53 656334.87 4725.71 10.00 MWD 11283.09 84.62 178.44 9022.59 8958.49 -4561.77 -1622.13 5964382.45 656335.29 4753.50 15.48 MWD 11312.60 84.93 174.35 9025.28 8961.18 -4591.09 -1620.28 5964353.18 656337.75 4782.22 13.84 MWD 11341.30 87.15 171.26 9027.26 8963.16 -4619.49 -1616.69 5964324.86 656341.94 4809.76 13.24 MWD 11380.05 89.91 166.22 9028.26 8964.16 -4657.46 -1609.13 5964287.06 656350.29 4846.17 14.82 MWD 11411.81 88.80 162.45 9028.61 8964.51 -4688.04 -1600.56 5964256.67 656359.51 4875.11 12.37 MWD 11442.58 88.71 160.98 9029.28 8965.18 -4717.25 -1590.91 5964227.68 656369.77 4902.54 4.79 MWD 11473.40 90.00 157.23 9029.63 8965.53 -4746.03 -1579.92 5964199.13 656381.36 4929.35 12.87 MWD i ~ by BP Alaska Br Baker Hughes INTEQ Survey Report 1NTE Q Compaoyt BP Amoco Date: 9/11/2007.. Time: 16:42:53 Page: 3 'Field: Prudhoe Bays .: Co-erdiaate(NE)Refenrece: Well: G-09, True North Site: PB G Pad . Vertical (TVD)Rekrence: 13:09 5/15/1981 00:00 64.1 Well: G-09 S ection (VS) Referemeo `Well (O.OON,OAOE,188 .63Azi) Wellpath: G-09B Sarvey Caku~ties Method: Minimum Curvature Db: Oracle Survey MD c tacl Azm TVD Sys TVD N/S E/W MapN MspE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11504.47 89.94 154.00 9029.64 8965.54 -4774.33 -1567.09 5964171.11 656394.78 4955.40 10.40 MWD 11537.13 90.12 149.81 9029.63 8965.53 -4803.13 -1551.72 5964142.64 656410.76 4981.57 12.84 MWD 11567.99 92.85 149.14 9028.83 8964.73 -4829.70 -1536.05 5964116.41 656426.98 5005.49 9.11 MWD 11599.18 94.88 145.60 9026.72 8962.62 -4855.91 -1519.27 5964090.56 656444.30 5028.88 13.06 MWD 11639.85 92.83 142.64 9023.99 8959.89 -4888.78 -1495.49 5964058.20 656468.77 5057.81 8.84 MWD 11671.04 89.26 141.10 9023.42 8959.32 -4913.30 -1476.24 5964034.09 656488.53 5079.17 12.46 MWD 11703.14 88.34 136.77 9024.09 8959.99 -4937.49 -1455.17 5964010.35 656510.11 5099.93 13.79 MWD 11734.29 88.16 133.69 9025.05 8960.95 -4959.60 -1433.24 5963988.71 656532.49 5118.49 9.90 MWD 11767.51 87.64 130.85 9026.26 8962.16 -4981.92 -1408.68 5963966.91 656557.52 5136.88 8.69 MWD 11799.38 88.96 127.92 9027.21 8963.11 -5002.13 -1384.06 5963947.22 656582.55 5153.17 10.08 MWD 11832.50 89.38 124.79 9027.69 8963.59 -5021.76 -1357.39 5963928.16 656609.62 5168.57 9.53 MWD 11861.83 89.91 120.27 9027.87 8963.77 -5037.53 -1332.67 5963912.92 656634.67 5180.45 15.52 MWD 11893.78 89.48 117.65 9028.04 8963.94 -5053.00 -1304.72 5963898.04 656662.94 5191.55 8.31 MWD 11927.65 88.90 114.05 9028.52 8964.42 -5067.76 -1274.25 5963883.92 656693.71 5201.58 10.76 MWD 11961.83 88.19 110.36 9029.39 8965.29 -5080.67 -1242.62 5963871.68 656725.61 5209.60 10.99 MWD 11997.41 88.54 106.56 9030.40 8966.30 -5091.93 -1208.89 5963861.13 656759.56 5215.67 10.72 MWD 12033.57 91.23 103.29 9030.48 8966.38 -5101.24 -1173.95 5963852.56 656794.68 5219.63 11.71 MWD 12059.47 91.07 101.25 9029.96 8965.86 -5106.75 -1148.65 5963847.59 656820.09 5221.28 7.90 MWD 12089.01 90.37 98.16 9029.58 8965.48 -5111.72 -1119.54 5963843.23 656849.30 5221.83 10.72 MWD 12142.05 92.88 94.25 9028.08 8963.98 -5117.46 -1066.85 5963838.61 656902.10 5219.59 8.76 MWD 12183.40 94.77 90.84 9025.32 8961.22 -5119.29 -1025.64 5963837.64 656943.33 5215.22 9.41 MWD 12220.73 92.69 86.03 9022.89 8958.79 -5118.27 -988.42 5963839.44 656980.52 5208.63 14.01 MWD 12262.65 89.97 83.34 9021.92 8957.82 -5114.39 -946.69 5963844.20 657022.15 5198.53 9.12 MWD 12301.93 90.77 82.05 9021.66 8957.56 -5109.39 -907.74 5963850.01 657060.99 5187.75 3.86 MWD 12329.95 87.38 77.95 9022.12 8958.02 -5104.53 -880.15 5963855.45 657088.46 5178.80 18.98 MWD 12367.61 87.60 74.31 9023.77 8959.67 -5095.51 -843.63 5963865.24 657124.78 5164.41 9.67 MWD 12396.63 90.55 72.34 9024.24 8960.14 -5087.19 -815.84 5963874.14 657152.39 5152.01 12.22 MWD 12445.00 90.55 72.34 9023.77 8959.67 -5072.51 -769.75 5963889.78 657198.16 5130.59 0.00 MWD TREE = Mc EV OY 6" WELLHEAD= McEVOY ACTUATOR = OTI KB. ELEV = 64.14' BF. ELEV = 35.54' KOP = 3000' Max Angle = 92 @ 10796' Datum MD = 10064' Datum ND = 8800' SS DRLG DRAFT G -Q 9 B Present CTD Sidetrack 2097' -~5-1/2" SSSV CAMCO LANDING NIP, ID = 4.662" 25$4' 9-5l8" DV PKR GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.44" @ 8976' 2-7/8" LNR Baker Retrieva D Packer - 8695' TOP OF 3-112" LNR. FLIffED C2 SET SLV 8703' GLM #1 LEAKING 8766' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ $$96' ST MD ND DEV NPE VLV LATCH PORT DATE 12 2986 2984 9 CA DOME RK 1 /4 09/27/07 11 5104 4834 34 CA SO RK 20 09/27/07 10 6269 5787 41 CA DMY RK 0 05/31/81 9 6417 5896 43 CA DMY RK 0 10/16/00 8 7070 6388 39 CA DMY RK 0 05/31 /81 7 7215 6501 39 CA DMY RK 0 05/31 /81 6 7661 6856 36 CA DMY RK 0 05/31/81 5 7802 6971 35 CA DMY RK 0 05/31 /81 4 8217 7316 33 CA DMY RK 0 05/31 /81 3 8364 7440 32 CA DMY RK 0 05131 /81 2 8627 7665 31 CA DMY RK 0 05/31 /81 "1 8767 7785 31 CA DMY RK 0 05/31!81 "ST. #1 E3ROKE9V LATCH - E3Eli1ND 9!2007 CTD LNR 8834' S-1/2" CAMCO SLD SLV, ID = 4.500" (BE3iIND PIPE 8866' TBG SEAL ASSEMBLY (SBR) (BE}IIND PIPE $904' 9-5/8" BAKER PKR, ID = 4.00" ~4-1/2" X OTIS NIP, ID = 3.813" (BE}iIND PIPE) ~ TOP OF 7" LNR I 8975' CALC TOC 8976' $991' 4-1/2" XN OTIS NIP, ID= 3.725" (BE}iIND LNR) MILLED OUT 01/19/99 12.6#, L-80, .0152 bpf, ID = 3.958" 9023' 9024' 4-112" TBG TAIL (BE}IIND LNR) 9025' ELMD TT LOGGED 02/13/91 9-518" CSG, 47#, N-80, ID = 8.681" 94$1' 9517' CTM 3-1/2" x 3-3116" xover 9565 a Im d 4 1 /2" x 7"whipstock 992$'-9935' MILLOUT WINDOW IN 7" TOC 2 7/8" LINER per SCMT 9580' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 88° @ 10500' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10500-11050 O 09/12/07 2" 6 11540-12400 O 09/12/07 7° CSG, zs#, N-8o, ID = s.18z 10354' 2-7/8" LNR, 6.16#, L-80, .0056bpf, ID=2.441" 11474' 10580' 3-3;16" x 2-7/8" xover 9935' RA TAG, ELMD 9575 cut 2 7/8" per SCMT ~ 9600 2 7/8" CIBP per SCMT 10095 16' OF 2-7/8" PERF GUN (8/8/06) PBTD 12392' 10190' CIBP(11/15/01) 3-3/16" x 2-7/8" LNF DATE REV BY COMMENTS DATE REV BY COMMENTS 06/01/81 ORIGINAL COMPLETION 01/24!07 MGS/TLH SL FISH PULLED 01/01/99 CTD SIDETRACK (G-09A) 09/13/07 NORDICI CTD SIDETRACK (G-098) 03/02!01 TMWKAK ADD PERFS 09/15/07 /TLH CORRECTIONS 01/16/02 AY/TLH ADD PERFS 09129/07 DAV/PJC GLV GO & CORRECTIONS 08/05/06 JCM/PJC PULL IBP @ 8934' 08!09/06 CJN/PJC 3 FISH PRUDHOE BAY UNIT WELL: G-09A PERMff No: 1982630 API No: 50-029-20582-01 SEC 12, T11 N, R13E, 2664' FNL & 2367' FEL BP Exploration (Alaska) • ~ ~ o o ~ ~ SARAH PALIN, GOVERNOR aaL[sa7~~ O~ oasD ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATI011T CO1rII~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-09B BP Exploration Alaska Inc. Permit No: 207-110 Surface Location: 2664' FNL, 2367' FEL, SEC. 12, T 11 N, R 13E, UM Bottomhole Location: 2500' FNL, 3127' FEL, SEC. 13, T11N, R13E, UM Dear Mr. McLaughlin: 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 (90759-3607 (pager). K. DATED this 'i~day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~_~ ~.-~~~-~~ Aug o 4f~ska t7i! ~GRcn _9 ?~0) 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propo r: QRltnj ^Coalbed Methane ^ Ga~es ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-09B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12390 TVD 8962ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2664' FNL 2367' FEL SEC T11N R13E UM 12 7. Property Designation: ADL 028285 Pool , , , , . , Top of Productive Horizon: 690' FNL, 4136' FEL, SEC. 13, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 14, 2007 Total Depth: 2500' FNL, 3127' FEL, SEC. 13, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 19,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-657861 y-5968977 Zone-ASP4 10. KB Elevation (Height above GL): 64.14 feet 15. Distance to Nearest Well Within Pool: 800' 16. Deviated Wells: Kickoff Depth: 9560 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3220 Surface: 2340 18. Casin Pr ram: S ecifi bons To - `ttin D th -Bo ttom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-1/2" x 9.3# / L-80 STL 3680' 8710' 7672' 12390' 8962' 250 cu ft Class'G' 3-3116" x 2-na" 6.2# / 6.16# TCI I /STL 19. PRESE NT-WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11476 Total Depth TVD (ft): 8002 Plugs (measured): 10190 Effective Depth MD (ft): 11407 Effective Depth TVD (ft): 8999 Junk (measured): 10095 Casing Length ize Cement Volume MD TVD Conductor /Structural 110' 20" x 0" 8 cu ds Concre 110' 110' Surface 2672' 13-3/8" 3440 cu ft Arcticset II 2672' 2672' Intermediate 9481' 9-5/8" 1300 cu ft Class 'G' 130 cu ft Arcticset I 9481' 8392' Production Liner 953' 7" 336 cu ft Class'G' 8975' - 9928' 7964' - 8776' Liner 2498' 2-7l8" 107 cu ft Class'G' 8976' - 11474' 7965' - 9002' Perforation Depth MD (ft): 10095' - 11405' Perforation Depth TVD (ft): 8900' - 8998' 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 Sean McLaughlin, 564-4387 Printed Name an McLaughlin Title CT Drilling Engineer 1 Prepared By Name/Number: Si nature ~b~ Phone 564-4387 Date ~ ~+ o Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: O~JJ D API Number: 50-029-20582-02-00 Permit A proval Date: 'Q See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed met1hane, gas hydrates, or gas contained shales: 1 Samples Req'd: ^ Yes LJ No Mud Log Req'd: Yes L~J No 3 ~~~ FS ` ~~~~'~'~~~~ ~`~~ HZS Measures: (Yes Tonal Survey Req'd: Yes ^ No Other. APPROVED BY THE COMMISSION Date ~ ZZ ' v ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ ~ ~ A ~ r t~ ~~ ~^~ Submit In Duplicate Iron • gp Prudhoe Bay G09B CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin August 20, 2007) 1. E Set 2-7/8" CIBP at 9600' 2. E Jet cut 2-7/8" liner at 9575'(this is 5' above the est. TOC) 3. C Pull test liner to verify section is free 4. O CMIT-TxIA (known leak across GLV # 1) 5. O MIT-OA done 5/15/07 6. O AC-LDS; AC-PPPOT-IC, T 7. O PT MV, SV, WV 8. O Bleed gas lift and production flowlines down to zero and blind flange 9. O Remove wellhouse, level pad Rig Work: (scheduled to begin on September 15, 2007) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 3<~~ " ~- 2. Pu11613' section of 2 7/8" liner 3. Run caliper log. 4. Cleanout/underream cement from 9450' down to 9575'. 5. Set 4-1/2 x 7" 4' with H rient tion. 6. Mi113.8" window at 9564' and 10' of rathole. Swap the well to Flo-Pro. 7. Drill Build: 4.125" OH, 886' (15 deg/100 planned) 8. Drill Lateral: 4.125" OH, 1940' (12 deg/100 planned) with resistivity 9. Run 3-1/2" x 3-3/16" x 2-7/8" solid liner leaving TOL at 8710' 10. Pump primary cement leaving TOC at 8976', 44.7 bbls of 15.8 ppg liner cmt planned 11. Cleanout liner and MCNL/GR/CCL log 12. Test liner lap to 2000 psi. ~~`'~ 13. Perforate liner per asset instructions (1000') 14. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. Test separator (1000' of prefs) Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. ~~~~ Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-1/2", L-80 9.3# STL 8710' md- 9500' and • 3-3/16", L-80 6.2# TCII 9500' and - 10600' and • 2-7/8", L-80 6.16# STL 10600'md - 12390'md A minimum of 44.7 bbls 15.8 ppg cement will be used for liner cementing. TOC planned at 8976' Well Control: • BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -19000 ft. (North) • Distance to nearest well within pool - 800 ft. (D-04) Anti-Collision • G-04A - 746' ctr-ctr distance; Well Status: P&A'd • G-27A - 550' ctr-ctr distance; Well Status: Producing well. Logging • MWD directional, Gamma Ray, will be run over all of the open hole section. Resistivity will be run over all the lateral section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on G Pad is 25 ppm.~ • Lost circulation risk is moderate potential for small losses. • Leak at GLV# 1 -monitor IA throughout j ob. Double valve the IA. • Zone 3 Conglomerate -plan for extra bit trips. Reservoir Pressure • The max res. press. is estimated to be 3220 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. • • b BP Alaska s P Baker Hughes INTEQ Planning Report INTEQ Company: BPAmOCO Date: 6/21/2007 Time: 11:10:26 Page: I Fiehl: Prudhoe Bay. Co-ordinate(NE) Reference: Well: G,-09, True North :Site: PB G Pad Vertical (1'Vt)) Reference: 13 :09 5!15/1981 00:00 64.1 Wells G-09 Section (V$jRefereoce: Well (O.OON,O.OOE,215.OOAzi) Wellpath: Plan 2, G-09B" Satvey Calcalation MetYod: Minimum Curvature Db: Orade 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: bggm2006 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-09 Slot Name: 09 G-09 Well Position: +N/-S 2111.35 ft Northing: 5968977 .00 ft Latitude: 70 19 18.975 N +E/-W 1604.03 ft Easting : 657861 .00 ft Longitude: 148 43 12.200 W Position uncertainty: 0.00 ft Wellpath: Plan 2, G-096 Drilled From: G-09 Tie-on Depth: 9500.00 ft Current Datum: 13:09 5/15/1981 00 :00 Height 64 .10 ft Above System Datum: Mean Sea Level Magnetic Data: 6/20/2007 Declination: 23.89 deg Field Strength: 57662 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.76 0.00 0.00 215.00 Plan: Plan #2 Date Composed: 6/20/2007 Copy Mary Endicott's plan 2 Version: 6 Principal: Yes Tied-to: From : Definitive Path Targets Map Map <--- Latitude ----5 ~-- Longitnde -> Name Description TVD +N/-S +E/-W Northing Easting Deb Min Sec I~g Min 'Sec Dip. I)ir. ft tt ft ft ft G-09B Polygon 64.10 -3390.83 -1481.75 5965556.00 656451.00 70 18 45.625 N 148 43 55.424 W -Polygon 1 64.10 -3390.83 -1481.75 5965556.00 656451.00 70 18 45.625 N 148 43 55.424 W -Polygon 2 64.10 -5024.33 -529.83 5963943.00 657437.00 70 18 29.561 N 148 43 27.652 W -Polygon 3 64.10 -5332.83 -510.31 5963635.00 657463.00 70 18 26.526 N 148 43 27.083 W -Poygon 4 64.10 -5314.75 -1750.29 5963627.00 656223.00 70 18 26.702 N 148 44 3.245 W -Polygon 5 64.10 -3547.41 -1884.16 5965391.00 656052.00 70 18 44.084 N 148 44 7.162 W G-09B Fault 1 64.10 -3199.25 -1791.81 5965741.00 656137.00 70 18 47.508 N 148 44 4.471 W -Polygon 1 64.10 -3199.25 -1791.81 5965741.00 656137.00 70 18 47.508 N 148 44 4.471 W -Potygon 2 64.10 -3107.39 -1308.74 5965843.00 656618.00 70 18 48.413 N 148 43 50.379 W G-096 Fault 3 64.10 -5623.60 -1761.79 5963318.00 656218.00 70 18 23.665 N 148 44 3.578 W -Polygon 1 64.10 -5623.60 -1761.79 5963318.00 656218.00 70 18 23.665 N 148 44 3.578 W -Polygon 2 64.10 -5628.16 -451.51 5963341.00 657528.00 70 18 23.622 N 148 43 25.367 W G-096 Fault 2 64.10 -4238.98 -1676.65 5964704.00 656274.00 70 18 37.283 N 148 44 1.104 W -Polygon 1 64.10 -4238.98 -1676.65 5964704.00 656274.00 70 18 37.283 N 148 44 1.104 W -Polygon 2 64.10 -4482.27 -1000.57 5964475.00 656955.00 70 18 34.891 N 148 43 41.383 W G-09B Target 1 8458.10 -3182.56 -1634.42 5965761.00 656294.00 70 18 47.673 N 148 43 59.879 W 6-098 Target 3 9025.10 -4243.74 -1545.71 5964702.00 656405.00 70 18 37.236 N 148 43 57.285 W G-09B Target 4 9027.10 -5115.56 -757.81 5963847.00 657211.00 70 18 28.663 N 148 43 34.301 W G-09B Target 2 9030.10 -3701.97 -1622.34 5965242.00 656317.00 70 18 42.564 N 148 43 59.523 W • • b BP Alaska s~ P Baker Hughes INTEQ Planning Report INTE Q Gompaoy: $P Amoco Date: 6/21/2007 Time: 11:10:26 Page: 2 Field: Prudhoe Bay Go=ordioate(NE) Retereuce: Well: G-09, True North Site:.. P B G Pad Vertical (TVD) Reference: 13 : 0 9 5/15/1981 00:00 64 .1 Wdl: G-09 Section (VS) Reference: WeN (O.OON,O. OOE,215.OOAzi) Wellpafb:" P lan 2, G-096 Survey Cakalatien Method: Minimum Curvature Db: OraGe AnnOtatlOn MD TVD ft_ ft 9500.00 8407.72 TIP 9560.00 8458.52 KOP 9580.00 8475.34 End of 9 Deg/100' DLS 9680.00 8551.40 4 9940.00 8771.43 5 10415.00 9030.31 6 10445.00 9029.11 End of 1 5 Deg/100' DLS 10470.00 9027.78 8 10520.00 9026.88 9 10620.00 9026.01 10 11020.00 9025.73 11 11320.00 9026.17 12 11720.00 9025.99 13 11840.00 9025.63 14 12140.00 9026.12 15 12190.00 9026.62 16 12390.00 9026.58 TD Plan Section Information MD Iaci Azim TVD +N!•S +E/-W DLS. Build Tara TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft '.deg 9500.00 32.45 228.69 8407.72 -3161.13 -1610.34 0.00 0.00 0.00 0.00 9560.00 31.84 227.92 8458.52 -3182.36 -1634.18 1.22 -1.02 -1.28 213.56 9580.00 33.64 227.92 8475.34 -3189.61 -1642.21 9.00 9.00 0.00 360.00 9680.00 47.16 217.75 8551.40 -3237.43 -1685.46 15.00 13.52 -10.17 330.00 9940.00 18.80 162.13 8771.43 -3357.33 -1732.81 15.00 -10.91 -21.39 205.00 10415.00 90.05 162.13 9030.31 -3701.81 -1621.78 15.00 15.00 0.00 0.00 10445.00 94.55 162.13 9029.11 -3730.33 -1612.58 15.00 15.00 0.00 0.00 10470.00 91.55 162.13 9027.78 -3754.09 -1604.93 12.00 -12.00 0.00 180.00 10520.00 90.50 168.04 9026.88 -3802.37 -1592.07 12.00 -2.10 11.82 100.00 10620.00 90.49 156.04 9026.01 -3897.32 -1561.30 12.00 -0.01 -12.00 270.00 11020.00 89.58 204.03 9025.73 -4285.73 -1561.56 12.00 -0.23 12.00 91.00 11320.00 90.25 168.04 9026.17 -4579.18 -1592.60 12.00 0.22 -12.00 271.00 11720.00 89.80 120.04 9025.99 -4893.57 -1364.53 12.00 -0.11 -12.00 269.50 11840.00 90.55 134.42 9025.63 -4965.99 -1269.24 12.00 0.63 11.98 87.00 12140.00 89.27 98.45 9026.12 -5097.36 -1005.00 12.00 -0.43 -11.99 268.00 12190.00 89.59 104.44 9026.62 -5107.27 -956.02 12.00 0.63 11.98 87.00 12390.00 90.44 80.45 9026.58 -5115.74 -757.66 12.00 0.42 -11.99 272.00 Survey MD Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Tool ft deg -deg ft ft ft ft ft deg/100ft ft deg 9500.00 32.45 228.69 8343.62 -3161.13 -1610.34 5965782.93 656317.62 0.00 3513.10 0.00 MWD 9525.00 32.20 228.37 8364.74 -3169.98 -1620.36 5965773.87 656307.79 1.22 3526.09 213.56 MWD 9550.00 31.94 228.05 8385.93 -3178.83 -1630.25 5965764.82 656298.08 1.22 3539.02 213.83 MWD 9559.50 31.85 227.93 8394.00 -3182.19 -1633.99 5965761.38 656294.42 1.22 3543.91 214.10 G-096 9560.00 31.84 227.92 8394.42 -3182.36 -1634.18 5965761.20 656294.23 1.22 3544.16 214.21 MWD 9575.00 33.19 227.92 8407.07 -3187.76 -1640.16 5965755.67 656288.36 9.00 3552.02 360.00 MWD 9580.00 33.64 227.92 8411.24 -3189.61 -1642.21 5965753.79 656286.36 9.00 3554.71 360.00 MWD 9600.00 36.27 225.38 8427.63 -3197.48 -1650.53 5965745.74 656278.20 15.00 3565.93 330.00 MWD 9625.00 39.61 222.63 8447.35 -3208.54 -1661.20 5965734.46 656267.77 15.00 3581.11 332.08 MWD 9650.00 43.02 220.24 8466.13 -3220.92 -1672.11 5965721.86 656257.12 15.00 3597.50 334.25 MWD 9675.00 46.46 218.15 8483.88 -3234.56 -1683.22 5965707.99 656246.31 15.00 3615.05 336.04 MWD 9680.00 47.16 217.75 8487.30 -3237.43 -1685.46 5965705.07 656244.12 15.00 3618.69 337.54 MWD 9700.00 44.45 215.94 8501.25 -3248.90 -1694.06 5965693.42 656235.77 15.00 3633.02 205.00 MWD 9725.00 41.12 213.42 8519.59 -3262.85 -1703.73 5965679.27 656226.39 15.00 3649.99 206.26 MWD 9750.00 37.84 210.54 8538.89 -3276.32 -1712.16 5965665.63 656218.25 15.00 3665.86 208.11 MWD 9775.00 34.65 207.21 8559.05 -3289.25 -1719.31 5965652.55 656211.38 15.00 3680.55 210.34 MWD 9800.00 31.56 203.31 8579.99 -3301.59 -1725.15 5965640.10 656205.80 15.00 3694.01 213.03 MIND i • b BP Alaska B p Baker Hughes INTEQ Planning Report INTEQ survey NID Iucl Aziro ft deg deg 9825.00 28.62 198.67 9850.00 25.86 193.10 9875.00 23.37 186.38 9900.00 21.22 178.26 9925.00 19.53 168.62 9940.00 18.80 162.13 9950.00 20.30 162.13 9975.00 24.05 162.13 10000.00 27.80 162.13 10025.00 31.55 162.13 10050.00 35.30 162.13 10075.00 39.05 162.13 10100.00 42.80 162.13 10125.00 46.55 162.13 10150.00 50.30 162.13 10175.00 54.05 162.13 10200.00 57.80 162.13 10225.00 61.55 162.13 10250.00 65.30 162.13 10275.00 69.05 162.13 10300.00 72.80 162.13 10325.00 76.55 162.13 10350.00 80.30 162.13 10375.00 84.05 162.13 10400.00 87.80 ~ 162.13 10415.00 90.05 162.13 10425.00 91.55 162.13 10445.00 94.55 162.13 10450.00 93.95 162.13 10470.00 91.55 162.13 10475.00 91.45 162.73 10500.00 90.92 165.68 10520.00 90.50 168.04 10525.00 90.50 167.44 10550.00 90.50 164.44 10575.00 90.50 161.44 10600.00 90.49 158.44 10620.00 90.49 156.04 10625.00 90.48 156.64 10650.00 90.43 159.64 10675.00 90.37 162.64 10700.00 90.32 165.64 10725.00 90.26 168.64 10750.00 90.20 171.64 10775.00 90.15 174.64 10800.00 90.09 177.64 10825.00 90.03 180.64 10850.00 89.97 183.64 10875.00 89.91 186.64 10900.00 89.86 189.64 10925.00 89.80 192.64 10950.00 89.74 195.64 10975.00 89.68 198.64 SS TVD N/S E/W ft ft ft 8601.62 -3313.27 -1729.65 8623.85 -3324.26 -1732.81 8646.58 -3334.50 -1734.60 8669.72 -3343.95 -1735.01 8693.16 -3352.57 -1734.05 8707.33 -3357.33 -1732.81 8716.75 -3360.52 -1731.78 8739.90 -3369.50 -1728.89 8762.38 -3379.90 -1725.54 8784.10 -3391.68 -1721.74 8804.96 -3404.78 -1717.52 8824.88 -3419.16 -1712.88 8843.76 -3434.74 -1707.86 8861.54 -3451.47 -1702.47 8878.12 -3469.26 -1696.73 8893.45 -3488.05 -1690.68 8907.46 -3507.76 -1684.32 8920.08 -3528.30 -1677.70 8931.26 -3549.57 -1670.85 8940.96 -3571.50 -1663.78 8949.13 -3593.98 -1656.53 8955.73 -3616.93 -1649.14 8960.75 -3640.23 -1641.62 8964.15 -3663.80 -1634.03 8965.93 -3687.53 -1626.38 8966.21 -3701.81 -1621.78 8966.07 -3711.32 -1618.71 8965.01 -3730.33 -1612.58 8964.63 -3735.07 -1611.05 8963.68 -3754.09 -1604.93 8963.54 -3758.85 -1603.42 8963.03 -3782.90 -1596.61 8962.78 -3802.37 -1592.07 8962.74 -3807.26 -1591.01 8962.52 -3831.51 -1584.94 8962.30 -3855.40 -1577.60 8962.08 -3878.88 -1569.03 8961.91 -3897.32 -1561.30 8961.87 -3901.90 -1559.29 8961.67 -3925.10 -1549.98 8961.50 -3948.76 -1541.90 8961.35 -3972.80 -1535.07 8961.22 -3997.17 -1529.51 8961.12 -4021.80 -1525.23 8961.04 -4046.62 -1522.24 8960.99 -4071.56 -1520.56 8960.97 -4096.55 -1520.19 8960.97 -4121.53 -1521.12 8960.99 -4146.43 -1523.36 8961.04 -4171.18 -1526.89 8961.12 -4195.70 -1531.72 8961.22 -4219.94 -1537.83 8961.34 -4243.83 -1545.19 MapN MapE DLS ft ft deg/10t 5965628.32 656201.54 15.00 5965617.27 656198.61 15.00 5965606.99 656197.04 15.00 5965597.54 656196.83 15.00 5965588.94 656197.97 15.00 5965584.21 656199.31 15.00 5965581.04 656200.40 15.00 5965572.13 656203.48 15.00 5965561.80 656207.05 15.00 5965550.11 656211.10 15.00 5965537.09 656215.60 15.00 5965522.82 656220.53 15.00 5965507.35 656225.88 15.00 5965490.74 656231.62 15.00 5965473.07 656237.73 15.00 5965454.41 656244.18 15.00 5965434.84 656250.95 15.00 5965414.45 656257.99 15.00 5965393.33 656265.30 15.00 5965371.55 656272.82 15.00 5965349.23 656280.54 15.00 5965326.45 656288.42 15.00 5965303.31 656296.42 15.00 5965279.90 656304.51 15.00 5965256.34 656312.65 15.00 5965242.17 656317.55 15.00 5965232.72 656320.82 15.00 5965213.85 656327.35 15.00 5965209.14 656328.97 12.00 5965190.26 656335.50 12.00 5965185.53 656337.11 12.00 5965161.63 656344.42 12.00 5965142.26 656349.37 12.00 5965137.39 656350.53 12.00 5965113.28 656357.11 12.00 5965089.55 656364.95 12.00 5965066.25 656374.01 12.00 5965047.98 656382.13 12.00 5965043.44 656384.23 12.00 5965020.45 656394.02 12.00 5964996.97 656402.60 12.00 5964973.07 656409.93 12.00 5964948.83 656416.01 12.00 5964924.30 656420.80 12.00 5964899.55 656424.31 12.00 5964874.65 656426.52 12.00 5964849.67 656427.42 12.00 5964824.68 656427.01 12.00 5964799.74 656425.30 12.00 5964774.93 656422.28 12.00 5964750.31 656417.97 12.00 5964725.95 656412.38 12.00 5964701.92 656405.52 12.00 VS TFO TOOT ft deg 3706.16 216.30 MWD 3716.97 220.31 MWD 3726.39 225.26 MWD 3734.37 231.38 MWD 3740.88 238.90 MWD 3744.07 247.94 MWD 3746.09 0.00 MWD 3751.78 0.00 MWD 3758.38 0.00 MWD 3765.85 0.00 MWD 3774.16 0.00 MWD 3783.28 0.00 MWD 3793.16 0.00 MWD 3803.77 0.00 MWD 3815.06 0.00 MWD 3826.98 0.00 MWD 3839.48 0.00 MWD 3852.50 0.00 MWD 3866.00 0.00. MWD 3879.91 0.00 MWD 3894.17 0.00 MWD 3908.72 0.00 MWD 3923.50 0.00 MWD 3938.45 0.00 MWD 3953.50 0.00 MWD 3962.55 0.00 MWD 3968.59 0.00 MWD 3980.65 0.00 MWD 3983.66 180.00 MWD 3995.72 180.00 MWD 3998.75 100.00 MWD 4014.55 100.02 MWD 4027.89 100.08 MWD 4031.29 270.00 MWD 4047.67 269.99 MWD 4063.04 269.97 MWD 4077.35 269.94 MWD 4088.02 269.92 MWD 4090.62 91.00 MWD 4104.29 91.01 MWD 4119.03 91.03 MWD 4134.81 91.05 MWD 4151.58 91.07 MWD 4169.30 91.08 MWD 4187.92 91.10 MWD 4207.38 91.10 MWD 4227.64 91.11 MWD 4248.64 91.11 MWD i 4270.32 91.11 MWD 4292.62 91.11 MWD 4315.48 91.10 MWD 4338.84 91.10 MWD 4362.63 91.08 MWD • • by BP Alaska B Baker Hughes INTEQ Planning Report INTE Q Coropaay; BP Amoco Date: 6/21/2007 Time: 11:10:26 Page: 4 Field: Prudhoe Bay Co-ordinnte(NE) Refereece: 'Web: G-09, True North Site: PB G Pad ' Vertical (TVD) Refereaee: 13:'09.5/15/1981 00:00 64 .1 Well: G-09 Section (VS) Retereace WeN (O.QON,O.OOE,215.OOAzi) Wellpalh: Plan 2,'G-09B Sorvey Cakalat~a Method: Minimum Curvature Db: Oracle Sarvey MD' Intl Aziro SS TVD N/S FJW MApN MapE DLS VS TFO Tuol ft deg deg ft ft ft ft ft deg/100ft ft deg 11000.00 89.63 201.64 8961.49 -4267.30 -1553.80 5964678.27 656397.41 12.00 4386.79 91.07 MWD 11020.00 89.58 204.03 8961.63 -4285.73 -1561.56 5964659.68 656390.04 12.00 4406.34 91.05 MWD 11025.00 89.60 203.43 8961.67 -4290.31 -1563.57 5964655.07 656388.12 12.00 4411.24 271.00 MWD 11050.00 89.65 200.44 8961.83 -4313.49 -1572.91 5964631.69 656379.27 12.00 4435.59 271.00 MWD 11075.00 89.70 197.44 8961.97 -4337.14 -1581.02 5964607.88 656371.66 12.00 4459.61 271.02 MWD 11100.00 89.76 194.44 8962.09 -4361.17 -1587.88 5964583.71 656365.31 12.00 4483.24 271.04 MWD 11125.00 89.81 191.44 8962.19 -4385.54 -1593.48 5964559.23 656360.22 12.00 4506.40 271.06 MWD 11150.00 89.87 188.44 8962.26 -4410.16 -1597.79 5964534.53 656356.43 12.00 4529.05 271.07 MWD 11175.00 89.93 185.44 8962.30 -4434.97 -1600.81 5964509.66 656353.93 12.00 4551.10 271.07 MWD 11200.00 89.98 182.44 8962.32 -4459.91 -1602.53 5964484.69 656352.74 12.00 4572.52 271.08 MWD 11225.00 90.04 179.44 8962.32 -4484.90 -1602.94 5964459.70 656352.86 12.00 4593.23 271.08 MWD 11250.00 90.10 176.44 8962.29 -4509.89 -1602.04 5964434.74 656354.28 12.00 4613.17 271.08 MWD 11275.00 90.15 173.44 8962.23 -4534.78 -1599.83 5964409.90 656357.01 12.00 4632.31 271.08 MWD 11300.00 90.21 170.44 8962.15 -4559.53 -1596.33 5964385.23 656361.03 12.00 4650.57 271.07 MWD 11320.00 90.25 168.04 8962.07 -4579.18 -1592.60 5964365.66 656365.18 12.00 4664.52 271.06 MWD 11325.00 90.25 167.44 8962.05 -4584.07 -1591.53 5964360.80 656366.34 12.00 4667.92 269.50 MWD 11350.00 90.22 164.44 8961.95 -4608.32 -1585.46 5964336.69 656372.92 12.00 4684.30 269.50 MWD 11375.00 90.19 161.44 8961.86 -4632.21 -1578.13 5964312.95 656380.76 12.00 4699.66 269.49 MWD 11400.00 90.17 158.44 8961.78 -4655.69 -1569.56 5964289.66 656389.82 12.00 4713.98 269.47 MWD 11425.00 90.14 155.44 8961.72 -4678.69 -1559.76 5964266.87 656400.10 12.00 4727.21 269.46 MWD 11450.00 90.11 152.44 8961.66 -4701.15 -1548.78 5964244.65 656411.55 12.00 4739.30 269.46 MWD 11475.00 90.08 149.44 8961.62 -4723.00 -1536.64 5964223.06 656424.14 12.00 4750.24 269.45 MWD 11500.00 90.05 146.44 8961.59 -4744.19 -1523.37 5964202.16 656437.85 12.00 4759.98 269.45 MWD 11525.00 90.02 143.44 8961.58 -4764.65 -1509.02 5964182.01 656452.64 12.00 4768.51 269.44 MWD 11550.00 89.99 140.44 8961.57 -4784.33 -1493.61 5964162.66 656468.46 12.00 4775.79 269.44 MWD 11575.00 89.96 137.44 8961.58 -4803.18 -1477.19 5964144.16 656485.27 12.00 4781.81 269.44 MWD 11600.00 89.93 134.44 8961.61 -4821.14 -1459.80 5964126.57 656503.02 12.00 4786.56 269.44 MWD 11625.00 89.90 131.44 8961.64 -4838.17 -1441.51 5964109.93 656521.67 12.00 4790.01 269.44 MWD 11650.00 89.88 128.44 8961.69 -4854.22 -1422.34 5964094.29 656541.17 12.00 4792.17 269.45 MWD 11675.00 89.85 125.44 8961.75 -4869.24 -1402.36 5964079.69 656561.46 12.00 4793.01 269.45 MWD 11700.00 89.82 122.44 8961.82 -4883.20 -1381.62 5964066.17 656582.48 12.00 4792.55 269.46 MWD 11720.00 89.80 120.04 8961.89 -4893.57 -1364.53 5964056.16 656599.80 12.00 4791.24 269.47 MWD 11725.00 89.83 120.64 8961.91 -4896.10 -1360.21 5964053.73 656604.16 12.00 4790.83 87.00 MWD 11750.00 89.99 123.64 8961.95 -4909.40 -1339.04 5964040.88 656625.60 12.00 4789.59 87.00 MWD 11775.00 90.14 126.63 8961.92 -4923.78 -1318.60 5964026.93 656646.34 12.00 4789.65 86.99 MWD 11800.00 90.30 129.63 8961.82 -4939.22 -1298.94 5964011.91 656666.32 12.00 4791.01 87.00 MWD 11825.00 90.46 132.63 8961.66 -4955.66 -1280.11 5963995.87 656685.49 12.00 4793.68 87.01 MWD 11840.00 90.55 134.42 8961.53 -4965.99 -1269.24 5963985.77 656696.58 12.00 4795.90 87.03 MWD 11850.00 90.51 133.22 8961.43 -4972.91 -1262.02 5963979.00 656703.94 12.00 4797.44 268.00 MWD 11875.00 90.40 130.23 8961.24 X989.55 -1243.37 5963962.76 656722.94 12.00 4800.36 267.99 MWD 11900.00 90.29 127.23 8961.08 -5005.19 -1223.86 5963947.54 656742.76 12.00 4801.99 267.97 MWD 11925.00 90.19 124.23 8960.98 -5019.78 -1203.57 5963933.37 656763.36 12.00 4802.31 267.95 MWD 11950.00 90.08 121.23 8960.92 -5033.30 -1182.54 5963920.30 656784.66 12.00 4801.32 267.93 MWD 11975.00 89.97 118.23 8960.91 -5045.70 -1160.84 5963908.37 656806.62 12.00 4799.02 267.93 MIND 12000.00 89.86 115.24 8960.95 -5056.94 -1138.51 5963897.59 656829.18 12.00 4795.43 267.93 MWD 12025.00 89.75 112.24 8961.03 -5067.00 -1115.63 5963888.02 656852.27 12.00 4790.55 267.93 MWD 12050.00 89.65 109.24 8961.16 -5075.86 -1092.25 5963879.66 656875.82 12.00 4784.39 267.94 MWD 12075.00 89.54 106.24 8961.34 -5083.47 -1068.44 5963872.55 656899.78 12.00 4776.97 267.96 MWD 12100.00 89.43 103.24 8961.57 -5089.83 -1044.27 5963866.70 656924.08 12.00 4768.32 267.98 MWD 12125.00 89.33 100.24 8961.84 -5094.92 -1019.80 5963862.12 656948.66 12.00 4758.45 268.00 MWD 12140.00 89.27 98.45 8962.02 -5097.36 -1005.00 5963860.00 656963.50 12.00 4751.95 268.04 MWD 12150.00 89.33 99.64 8962.14 -5098.93 -995.13 5963858.64 656973.41 12.00 4747.58 87.00 MWD • • by BP Alaska 8~~~ Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Date: 6/21/2007 Time: 11:10:26 Page: 5 Field: Prudhoe Bay Co-ordiante(NE) Reference: Well: G-09, True North Site: PB G Pad Vertical (1'VD) Reference: 13:09 5/15/198 1 00:00 64.1 Welk G-09 Section (VS) Reference: Well (O.OON,O.OOE,215.OOAzi) Wellpath; Plan 2, G-09B Sarvey Calculation Method: 'Minimum Curvature Db: Or ade Survey MD Incl Azim SS TVD N!S E/W MapN MapE DLS VS TFO Tool ft' deg deg ft ft ft ft ft' deg/100ft ft deg 12175.00 89.49 102.64 8962.40 -5103.76 -970.60 5963854.32 656998.03 12.00 4737.47 86.99 MWD 12190.00 89.59 104.44 8962.52 -5107.27 -956.02 5963851.12 657012.68 12.00 4731.98 86.95 MWD 12200.00 89.63 103.24 8962.59 -5109.66 -946.31 5963848.93 657022.44 12.00 4728.37 272.00 MWD 12225.00 89.73 100.24 8962.73 -5114.75 -921.83 5963844.37 657047.01 12.00 4718.50 272.01 MWD 12250.00 89.84 97.24 8962.82 -5118.54 -897.13 5963841.09 657071.79 12.00 4707.44 272.02 MWD 12275.00 89.95 94.24 8962.87 -5121.05 -872.26 5963839.11 657096.71 12.00 4695.22 272.04 MWD 12300.00 90.05 91.25 8962.87 -5122.24 -847.29 5963838.44 657121.69 12.00 4681.88 272.04 MWD 12325.00 90.16 88.25 8962.82 -5122.13 -822.29 5963839.08 657146.68 12.00 4667.45 272.04 MWD 12350.00 90.27 85.25 8962.73 -5120.71 -797.33 5963841.02 657171.60 12.00 4651.98 272.04 MWD 12375.00 90.37 82.25 8962.59 -5117.99 -772.49 5963844.26 657196.38 12.00 4635.49 272.02 MWD 12390.00 90.44 80.45 8962.48 -5115.74 -757.66 5963846.83 657211.16 12.00 4625.14 272.01 2.875" ~ • by BP Alaska Anticollision Report • ~.. s~icsi~~ 1NTEQ Companys BP Amoco Date: 6/21!2007 Time: 09:53:05 Page: t F'ceW: Prudhoe Bay ReterenceSite: PB G Pad Co-ordinate(NE) Reference: Well: G-09, True North Reference Well: G-09 Vertical (1'VD) Reference: 13:09 5/ 15/1981 00: 00 64.1 Reference Wellpath: Plan 2, G-098 Db: Grade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 1011/1000 of reference -There are'R~aells in this0idhtlipal Plan 8 PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9500.00 to 12390.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/20/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 100.00 9500.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOS S gyro multishot 9500.00 12390.00 Planned: Plan #2 V3 MWD MWD -Standard Casing Points MD TVD Diameter Hak Size Name ft ft in in 12390.00 9026.58 2.875 4.125 2.875" Summary Offset Wellpath -- ~ Reference Offset Ctr-Ctr ' No-Go Allowable Site Well Wellpath MD MD Distance Area - Deviation. Warning ft ft ft ft ft PB D Pad D-04 D-04 V2 12250.00 10961.33 737.71 297.35 440.35 Pass: Major Risk PB D Pad D-04 D-04A V1 12100.00 10792.10 1007.95 248.61 759.34 Pass: Major Risk PB D Pad D-04 D-04B V7 12064.77 10399.95 1111.13 213.67 897.46 Pass: Major Risk PB G Pad G-04 G-04A V1 10840.88 11972.53 746.29 1032.27 -285.98 FAIL: Major Risk PB G Pad G-04 G-046 V4 10475.00 10900.00 2101.54 932.47 1169.07 Pass: Major Risk PB G Pad G-09 G-09 V1 9983.13 10000.00 83.54 1024.00 -940.46 FAIL: Major Risk PB G Pad G-09 G-09A V1 9981.74 10000.00 82.05 1023.91 -941.85 FAIL: Major Risk PB G Pad G-18A G-18A V3 Out of range PB G Pad G-18AP61 G-18AP61 V2 Out of range PB G Pad G-18 G-18 V1 Out of range PB G Pad G-21 G-21 V1 9897.62 10400.00 1117.06 645.22 471.85 Pass: Major Risk PB G Pad G-21 PB1 G-21 PB1 V1 9897.62 10400.00 1117.06 645.22 471.85 Pass: Major Risk PB G Pad G-27 G-27 V1 9609.92 10905.80 1018.63 208.67 809.96 Pass: Major Risk PB G Pad G-27 G-27A V1 10011.05 12000.00 550.15 587.53 -37.38 FAIL: Major Risk Site: PB D Pad Well: D-04 Rule Assigned: Major Risk Wellpath: D-04 V2 Inter-Site Error: 0.00 ft Reference' Offset. Semi-Major.Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD - Ref Oftcet TFO+AZI TFO-HS Casieg/H5Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11950.00 9025.02 8700.00 7471.46 28.37 20.81 172.21 50.98 9.625 2467.78 131.97 2335.81 Pass 11959.38 9025.01 8800.00 7541.12 27.56 21.01 171.35 51.24 9.625 2370.25 130.78 2239.47 Pass 11963.30 9025.01 8900.00 7610.83 27.23 21.28 171.16 51.52 9.625 2272.79 133.70 2139.09 Pass 11975.00 9025.01 9000.00 7680.91 26.22 21.32 170.07 51.84 9.625 2175.65 132.47 2043.18 Pass 11975.00 9025.01 9100.00 7751.71 26.22 21.33 170.46 52.23 9.625 2078.82 133.19 1945.64 Pass 11975.00 9025.01 9200.00 7823.23 26.22 21.33 170.92 52.69 9.625 1982.59 134.12 1848.47 Pass 11982.33 9025.02 9300.00 7895.57 26.36 21.36 170.59 53.24 9.625 1887.20 135.61 1751.59 Pass 11988.36 9025.03 9400.00 7968.70 26.48 21.38 170.53 53.90 9.625 1792.77 137.19 1655.58 Pass 12000.00 9025.05 9500.00 8042.93 26.72 21.43 169.93 54.70 9.625 1699.44 139.50 1559.94 Pass 12000.00 9025.05 9600.00 8118.42 26.72 21.45 170.90 55.66 9.625 1607.40 141.15 1466.24 Pass 12009.57 9025.08 9700.00 8194.86 27.88 21.50 170.91 56.82 9.625 1516.98 146.24 1370.74 Pass 12018.11 9025.11 9800.00 8271.71 28.92 21.56 171.23 58.17 9.625 1428.53 151.31 1277.22 Pass 12025.00 9025.13 9900.00 8348.92 29.75 21.62 172.00 59.76 9.625 1342.86 156.30 1186.56 Pass 12039.00 9025.20 10000.00 8426.83 32.54 21.73 172.24 61.68 9.625 1261.22 167.26 1093.96 Pass 12050.00 9025.26 10100.00 8505.55 34.72 21.83 173.18 63.95 9.625 1183.32 177.22 1006.10 Pass 12063.82 9025.36 10200.00 8584.41 38.15 21.97 174.14 66.55 9.625 1108.26 191.41 916.85 Pass 12075.00 9025.44 10300.00 8661.97 40.92 22.10 175.71 69.47 9.625 1036.54 204.23 832.30 Pass 12093.46 9025.60 10400.00 8737.63 46.02 22.31 176.73 72.70 9.625 968.37 224.63 743.73 Pass 12110.11 9025.77 10500.00 8813.57 50.76 22.54 178.48 76.45 9.625 905.57 244.72 660.85 Pass TREE = McEV OY 6" WELLHEAD= McEVOY ACTUATOR = OT KB. ELEV = 64.14' BF. ELEV = 35.54' KOP = 3000' Max Angle = 92 ~ 10796' Datum MD = 10039' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" ~~ 2672' Minimum ID = 2.44" ~ 8976' 2-7/8" LNR 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 8896' (TOP OF 7" LNR ~--~ 8975• TOP OF 2-7/8" LNR, W!4" GS PROFLE, ID = 3.000" 8976' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 9023' 9-5/8" CSG, 47#, N-80, D = 8.681" 94$1' PERFORATION SUMMARY REF LOG: SPERRY NNVD GR ON 01/23/99 ANGLEATTOPPERF: 55 C~ 10095' Note: Refer to Productan DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 10095 - 10120 O 03/02/02 2 6 10105 - 10115 O 01/12/02 2 6 10115 - 10120 O 02/28/01 2 6 10119 - 10124 O 11!14/00 1.69 4 10480 - 10630 C 01 /25/99 1.69 4 10810 - 10950 C 01/25/99 1.69 4 11020 - 11220 C 01/25/99 1.69 4 11280 - 11405 C 01/25/99 ~ PBTD ~--~ 10317' csG, 29#, N-8o, D = s. t s2 10354' G -0 9 A S TES: STA #1 LATCH IS BROKEN (ND FPI). MODIR®PRONG IS BROKEN AND BENT OVER REMAINII~'a VALVE BODY. • 2096' 5-1/2" SSSV CAMCO LANDYVG N~, D = 4.662" ~ 2584' 9-5/8" DV PKR i GAS LET MANDRELS ST ND TVD DE1/ TYPE VLV LATCH PORT DATE 12 2985 2920 6 CA DMY RK 0 09/22/02 11 5103 4770 34 CA DNIY RK 0 09/22/02 10 6269 5796 41 CA DNIY RK 0 9 6416 5915 43 CA DMY RK 0 8 7070 6453 39 CA DMY RK 0 7 7215 6574 38 CA DMY RK 0 6 7660 6951 35 CA DNIY RK 0 5 7801 7072 35 CA DMY RK 0 4 8217 7440 33 CA DMY RK 0 3 8364 7572 33 CA DMY RK 0 2 8627 7807 30 CA DMY RK 0 1 8766 7931 31 CA DMY RK 0 8~34~~5-1/2" CAMCO SLDING SLV, D = 4.500" $$~' TBG SEAL ASSEMBLY (SBR) ® 9-5/8" BAKER PKR, D = 4.00" 8~' 8959' 4-1 /2" X OTIS NIP, ID = 3.813" 8991' 4-1 /2" XN OTIS NIP, D = 3.725" (BEHIND LNR) MILLED OUT 01/19/99 9023' 4-1/2" TBG TAIL (BEHIND LNR) 9025' ELND TT LOGGED 02/13/91 9925' TOP OF WHPSTOCK 9928'-9935' IWI-LOUT 1MNDOW IN 7" 9935' RA TAG, FIND 10095 16' OF 2-718" PERF GUN (8/8/06) \ 10190' C~P(11/15/01) ~ PBTD H 1140T r _ 2-7/8" LNR, 6.16#, L-80, 11474' .0056 bpf, ID = 2.441" DATE REV BY CONMBJTS DATE REV BY CONMENTS 06/01/81 ORIGINAL COMPLETION 10/10/06 RCTlfLH ~P PULLED CORRECTION 01/01/99 CTD SIDETRACK 12/12/06 CJNITLH FISH PULLED (FRAC SLV) 03/02/01 TMWKAK ADD PERFS 01/24/07 MGSlTLH SL FISH PULLED 01/16/02 AY/TLH ADD PERFS 08/05/06 JCMIPJC PULL ~P (tD 8934' 08/09/06 CJWPJC 3 FISH PRUDHOE BAY UNff" WELL: G-09A PERMff No: 1982630 API No: 50-029-20582-01 SEC 12, T11 N, R13E, 2664' FNL & 2367' FEL BP Exploration (Alaska) TREE= MCEVOY 6" WELLHEAD = McEVOY ACTUATOR = O KB. ELEV = 64.14' BF. ELEV = 35.54' KOP = 3000' Max Angie = 92 ~ 10796' Datum MD = 10039' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" ~~ 2672' G-09B Proposed CTD Sidetrack C Minimum ID = 2.44" @ 8976' 2-7/8" LNR v2 ~<'r. ~ 6n 8700' ~P0' 'LV 8710' GLM#1 LEAKING 8766' 5-1/2" SSSV CAMCO LANDI 9-5/8" DV PKR GAS LIFT MANDRELS = 4.662" I ST MD ND DEV NPE VLV LATCH PORT DATE 12 2985 2920 6 CA DMY RK 0 09/22/02 11 5103 4770 34 CA DMY RK 0 09/22/02 10 6269 5796 41 CA DMY RK 0 9 6416 5915 43 CA OMY RK 0 8 7070 6453 39 CA DMY RK 0 7 7215 6574 38 CA OM1' RK 0 6 7660 6951 35 CA DMY RK 0 5 7801 7072 35 CA DMY RK 0 4 8217 7440 33 CA DMY RK 0 3 8364 7572 33 CA DMY RK 0 2 8627 7807 30 CA DMY RK 0 .JMY j 8834' ~5-1/2" CAMCO SLING SLV, ID=4.500" 8866' TBG SEAL ASSETABLY (SBR~ $$~ 9-5/8" BAKER PKR, ID = 4.00" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 8896' a ~_ 8959' -j4-1/2" X OTIS NIP, ID = 3.813" I TOP OF 7" LNR 8975' CA L~ T~iC 8976' 8991' 4-1/2" XN OTIS NIP, ID = 3.725" (BB~BND LNR) MILLED OUT 01/19/99 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9023' 9023' 4-1/2" TBG TAIL (BEHIND LNR) 9025' ELMD TT LOGGm 02/13/91 9-5/8" CSG, 47#, N-80, ID = 8.681" 9481' 9500 a Im d ~ - . 9564 elmd ~ ' L'~ x „ ~.~ h~pstock 9928'-9935' MILLOUT WINDOW IN 7" TOC 2 7!8" LINER per SCMT 9580' PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: xx @ xxxx' Note: Refer to Production DB for historical perf data 7" CSG, 29#, N-80. ID = 6.182 ~~ 10354' ~ ~7/S' L1V~ fi'16~# L~ .OD~F, ~44'P' 11474 1 x DATE REV BY COMMENTS DATE REV BY COMMENTS 06101181 ORIGINAL COMPLETION 10/10/06 RCTlTLH IBP PULLED CORRECTION 01101199 CTD SIDETRACK 12/12/06 CJN/TLH FISH PULLED (FRAC SLV) 03/02/01 TMWKAK ADD PERFS 01/24/07 MGS/TLH SL FISH PULLED 01/16/02 AY/TLH ADD PERFS 08/05/06 JCM/PJC PULL IBP @ 8934' 08!09/06 CJWPJC 3 FISH PRUDHOE BAY UNR WELL: G-09A PERMIT No: 1982630 API No: 50-029-20582-01 SEC 12, T11 N, R13E, 2664' FNL & 2367' FEL BP Exploration (Alaska) ~~ x 2-718" xover 9935' RA TAG, ELMD 9575 cut z 7/s° per scMT 9600 2 7/8" CIBP per SCMT 10095 16' OF 2-7/8" PERF GUN • • rements are from i ~_ Blind/Shears TOTs 2 3/8" combi ram/slips ~ ~ Mud Cross I I Mud Cross of flow cross of blind/shears variable bore pipe 3 1/2"-2 7/8" TOTs le of pipe/slips 2 3/8" combi ram/slips + e~~~l Flow Tee EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 ~ 6000000 5950000 ~ 5900000 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 of 2 _, ~,., ~ =:+,_, ~ ~:xder's Search State Cabins ~ii~tlu~~'D4~1'~ES ~~ Alaska DIVR Case summary File Type: A~~ File Number: 28285 ~ Printable C..ase File Summary See Township, Range, Section and Acreage? C'- Yes ~" No New Search i_AS 1~11enE~ I Case Abstract I Case Detail I Land Abstract M l~il~r: ADL 282tiS '`'!~'~` Search far Status Plat. Updates 1~ cif Ug'1 ~i2007 Cuszo~ncr: 000107377 BP E?:PLOR.~1'ION (ALASK:~) INC. PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 995196612 Case Type: ~'~~ OIL & GAS LEASE COMP File Location: DOG DIV OIL AND GAS Case ,S'tatus': 35 ISS/APPRV/ACTV AUTH Total Acres: 2560.000 Office of Printcrrp Respof~sibility: DOG I Last Transactior2 Date: 12/04/2006 DNR Unit: 780 OIL AND GAS StatllS Date. Og/19/1g6~ Date Initiated: 05/28/1965 >IV OIL AND GAS Case Subtype: ~5 NORTH SLOPE 1 u.el Transactiofz: AA-NRB ASSIGNMENT APPROVED 1 c>ridian: U ToK~ns{zip. 0 I l N R~tn,~re: O l ~ [ Sec~uo~r: 1 ~ S'c~c/inn ~4eres: 640 Search. Plats a1E~ridi~rn: U To~~~r.S~Lij~.~ O 1 1 N Ran,~~e: 0 I i E S'ectir~n: I =I Section . I cress 6-~0 1lt°ricliu~t: U 7 oii~nshii~: 01 I N Ran,~rc.~ O1 i l ~. Sectiu~t.~ ? > .S'e criun Acr'c~~~: 6-~0 1lc~r'idian: U 1~nti~m•hij~: Ol IN Kru~~ye: Ol ~1~: Section: `_'~ .S'ectiof~.~lcre~s.~ (~lU Leal Description (15-28-1965 * ~ *SALE NOTICE LEGAL DESCRIPTION* C14-96 TI l N-R13E- UM 13,14, 23, 2~ 2, 560.00 LISBURNE PARTICIPATING AREA DESCRIPTION T. 11., R. 13 E., U. M. SECTION 13: ALL 640 ACRES COArTaINING 640 ACRES, MORE OR LESS. http://wvwv.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28285 &... 8/ 13/2007 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~/~.l/ ~'~9~U PTD# ~O~ »OD Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are 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 Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 a • o~ , ,, „ „ „ ,, , , o ~a „ , , C' ~ a` ~~ ~ N v ~; ; , O ti' ~ ca , a w N ~ o, E O 4 ° a ~, , p. d ; ~ °' W ~ ao, ~~ ~ ~ rn ~~ , 3 ~ , ~ c , , 'o ~; ~ c ~ Q ° c. m o N , , m d . rn a ~ w' a' O ~ ~ ~ O' m O ~ ~ ~ ~ ~ ~ ~ ~ 00 ~ ~ ~ ~, ~ ~ O, O, C. N~ ~ ~ L, ~ p,, ~' ~, ~ ~ c' N, ~ ~~ a m o; Z w ~, o, C a Q w, c. •3, y, ar 'y, ~, ~, a d' ,v_, ~ , c ~ ~ ~ , ~ ~ ~ ~ c O W. ~~ ~ >1 =, Q ~ ~ ~, , t, ~ ° i o' ~ ~ a °, Y, as ° oa d' °, > a m N d V ~ ~ d m• ~~ M ~ ~~ ~ ~ _~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ f , , a ¢' z~ W, N, N~ N~ ~ m ~ a~ ~, >', }~ >'~ N, a~ >', N~ N~ ~ ~ }~ ~~ N~ tp, H~ ~ ~ ~ }~ >-' ~' N~ a~, >- N ~ ~ I f d a' o' Z' ~' z' Z' ~ ~ ~ ~ a; a; a; Z N~ ~, N~ N~ a~ a~ ' ' N, fq. N~ a~ a~ a~ ' ~' ` ' N, N~ tlD a~ a~ a~ ' ' N~ N~ a~ a~ a' ~ o ~ a', ~ ~ y, a~ ~ ~ ~ ~ ~ , o ~ Z Z Z ~ ~ ~ >- >- >- Y >- >- >- Y~ z z Z ~ m fd ~ ~ ~ \ \ ~ O' l vV /1 •c ~ 3, , - E. °, , , ~, ~, , ~ a O n~~; o v C , W O O O ~ f0 ~ ~ ~ ~ ~ j N, N N, Q' N ~ OyyI U ~ ~ `~ ~ ~ ~ ~, ~ U' . ~ N ~ Q'. N Q ~ C• ~ O ~ ~ ~ ~ . O. O , ~ T v O ~~ ~ ~ N. a ~ cv N. ~ ~ ~. ~ C, ~ -O. y' . ~ W' N ~ 9, ~ ~ ~, O. L, ~ d Q• N• ~ O. C. ~ ~ N W d ~ 7, N. , ~~ •~ .N. C, a, p Vy O. 7, p. ~~ ~ C• dD ~ (6 C >~ N, ~ } p~ >i, ." ~ d O, ~ d N, ~ M a ~, ~~ W. O N. N c ~ O, - ~ py ~ 3 a'~ 'OO, N, N~ m Z ~ ~ C, t~ ~ ~ ~ ~, Z' ~ i A m ~ 7, ~ 3~ ~ a O s ~'~ C ~~ ~ .O M ~ ,r ~ Q O~ N y N' w - ~, o o a o, d rn •~ a O o, a~, o< c m ~ o. `, . o , m. , ~ o. o. ~ ~ ~ , ~, d' , , L, c. ~' °' °, ° c. ~, o ` O Q ~, ~, _ a> a, `~-, m C C ~ E ui ~ c,,a, >, •~, M ~ N, O c, o C fn, > ~ , a 4 m C ~ ~ ~, ~, ~, ~ c N y OI Q d d N .c O_ ~ rn a C c Y D c4 ~ ': ' " ~' ° m. o N ° o Q ~ ~ r. Cj ' ~' . g :?, ~ o ~ ~ `o i , ~ ~ Z o c ~ Q, ~, o u~ i, a o, a~ o, y i .vi a d Q ~ ~ 4 ~ c n m. ~ ~~ ° . t, a ~ ~~ ~, w ~ 5, ; o* ~ • ~ rn ~. N a 3 `-° o g ' Z , N. C, ~, N . ~~ f6, O~ . c Q~ ~, 3 3 -O , f0~ m, a, €~ ~ ~ a N~ N~ ~~ ~~ '~ C o ~~ ~~ ~, m. a~ M, O, q)~ V~ o N, ~ N~ ' , a O~ ~q' '~' o d 3 N' , (6' N O' ~ ~ w d ° O n ~°, c. v, ' v >~ •° a~ •o, ~ , .., o d . m. ~, o, a f .. ° . . o c °, n o v~ o, ' a a Q , ~ m , m o L Z, •~ n U ~ a, ° m m ~ m a ~ ~ o c ~' o o o Y ~ o ~ w ~ ° ~ t o ~ s r y, ~ ~ _, a °, ~, o. a ~ ~ ~ `o. w r'rn a i ~ t ~, a n a w u3 , ~ rn ~; ~; y `° ~' m c°> '3 ~ ~, o N s ~ m, o, o, m ~ ~ rn ~ , ~ ui ~ of co cu is , o ~ ' •f ' w' N ~ , , . o -° O ~ J :°., ~ ~, ~, o. o. ~, N °, ° x ~ °, m Q 3 c; ~ m c ~ 6 a a~ c '~; m; ~ ~~ ° a N L , 6, o ~ ~, O ° a ~, N >. " ~ ii a f6' °, L~ -, a~ a ~, ~, a>, a>, a. °?~ V. •-~ °, -a~ _~ ~, L~ o, r. c. Q, c, a• ~, O, fir, ° ~ ~ N~ 'y~ N. N. m. ~° a ' ' >~ ° ' .~ ~~ „~ t. ~ 3' ~ ~~ N, w o, ° ~ U• o, °~ Fu L, c, O a~, f6, C' ~, c, d, m, 1^~ W ' ? ' (0, • c N. U U E W ~~ j (6 O U tO V ~ 4?; _, 0 ~ ~ ~ a Q ~~ = O U ~ O U C w ~ ~ c U UU ° ° U ° O ~ ' ' , U• o ° ~' ~' ° ' ° ' ~3' ~' y ~ ~ „ ~ ~~ ' ' 3' y' ~' V' , ' U ~ m a m ~ ~, - - ~ - ~, > m; m; , a - a~, a 3 c > > m a i ~ ~, w, w ~ ' ' a ~ °- m. ~ m ai ~ .~ ~ y ~ ' ' ~ ~ ~ o: o: ~ ' ~, ~ ~ , ~ o, ' ' o' ~' ~' ~' ' ~; m a ~ a; 'v' = ' O; O L ~ o' ' ' ' ' a o' . c. . v v v' ~ c a, ; ~, ~ , ~ , ~; cn, ~; O O; a a U , ¢; o.; z ~ U vi U U U U, ¢, w -, ¢, o m m U, ~ ~ , ~' i i ~~ m a _ ~ V d ~ N M I tf) CO f~ 0p O O N ~ M ~_ I tfj f0 I~ _ ~ ~ _ O O O ~ N N N N M V N N .O O~ W N N N N _ O O N M M N M st M M M .O M CO M I~ O O M_M M U ~ O O O 0 C ° w ~ N ~ 'a' ~ N +O'' N ~ U C ~ L1J a, ~ ~+ '. r ~ °° ~ N ~ r °° O H ~ ~~ (~ ~. v' N H d T ~ ..J O 1 U W~ ~ Q Q ~ Q W ~ Q Q a Q w (9 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pen~itting 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. tapescan.txt **** REEL HEADER **** MWD 09/02/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/09/09 1537273 O1 3" CTK *** LIS COMMENT RECORD *** `v h, <., fS ~'~ !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~vers~on Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9439.5000: Starting De th STOP.FT 12447.5000: Ending Depth sTEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: G-09B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 18.975"N 148 deg 43' 12.200"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 09 Sep 2007 API API NUMBER: 500292058202 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 . TOWN.N T11N . RANG. R13E . PDAT. MSL . EPD .F 0 LMF KB . FAPD.F 64.14 . DMF KB . EKB .F 0 EDF .F 64.14 . EGL .F 0 . Page 1 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~b~-/!O 1~~~ • tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. . (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 11 sep 2007 per BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from G-09 through a milled window in a 7 inch liner. Top of window 9565 ft.MD (8402 ft.TVDSS) Bottom of window 9577 ft.MD (8409 ft.TVDSS) (9) Tied to G-09 at 9565 feet MD (8399 feet TVDSS). (10) The resistivity interval from 9577 feet to 10560 feet MD (8409 feet to 8964 feet TVDSS) was re-logged on run 5 98.2 hours after being drilled. TVDSS) (11) The interval from 12415 feet to 12445 feet MD (8959 feet to 8959 feet was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLx -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9440.08, 9440.43, ! 0.353516 9445.9, 9446.25, ! 0.353516 9450.32, 9449.61, ! -0.706055 9473.03, 9471.44, ! -1.58887 9484.86, 9482.74, ! -2.11816 9488.03, 9487.15, ! -0.882812 9489.98, 9488.92, ! -1.05957 9503.67, 9501.73, ! -1.94238 9512.32, 9510.73, ! -1.58887 9522.91, 9523.44, ! 0.530273 9530.68, 9529.09, ! -1.58887 9535.27, 9533.68, ! -1.58887 9537.92, 9536.86, ! -1.05859 9551.34, 9551.87, ! 0.529297 9553.99, 9553.99, ! 0 9556.03, 9555.85, ! -0.175781 9562.56, 9560.27, ! -2.2959 9567.5, 9566.62, ! -0.882812 9570.33, 9570.33, ! 0 9574.39, 9574.04, ! -0.353516 9580.04, 9579.33, ! -0.706055 9584.28, 9584.1, ! -0.176758 9587.81, 9587.63, ! -0.176758 Page 2 i tapescan.txt 9589.22, 9589.04, ! -0.176758 9590.28, 9590.28, ! 0 9592.22, 9592.05, ! -0.175781 9594.16, 9594.16, ! 0 9596.27, 9595.92, ! -0.352539 9604.57, 9607.04, ! 2.47266 9606.86, 9608.45, ! 1.58887 9608.98, 9610.39, ! 1.41309 9613.09, 9614.33, ! 1.23633 9614.68, 9617.33, ! 2.64844 9617.5, 9619.62, ! 2.11816 9618.56, 9620.51, ! 1.94141 9621.04, 9622.8, ! 1.76562 9625.45, 9627.39, ! 1.94238 9628.8, 9630.92, ! 2.11914 9631.1, 9633.04, ! 1.94141 9636.56, 9638.68, ! 2.11816 9639.21, 9640.97, ! 1.76562 9641.33, 9643.09, ! 1.76562 9642.38, 9644.5, ! 2.11816 9643.97, 9645.92, ! 1.94238 9646.27, 9648.74, ! 2.47168 9648.56, 9651.04, ! 2.47168 9653.68, 9656.33, ! 2.64746 9657.57, 9659.69, ! 2.11816 9659.86, 9661.63, ! 1.76562 9661.28, 9663.04, ! 1.76562 9663.04, 9665.16, ! 2.11914 9686.51, 9688.63, ! 2.11914 9693.57, 9694.63, ! 1.05957 9697.1, 9698.69, ! 1.58887 9698.34, 9700.46, ! 2.11914 9703.1, 9705.05, ! 1.94238 9707.34, 9709.28, ! 1.94238 9711.93, 9713.7, ! 1.76562 9721.2, 9723.32, ! 2.11914 9722.96, 9724.91, ! 1.94238 9724.91, 9727.02, ! 2.11816 9729.67, 9731.97, ! 2.29492 9736.21, 9737.97, ! 1.76562 9744.68, 9746.45, ! 1.76562 9747.68, 9749.8, ! 2.11816 9750.33, 9752.62, ! 2.2959 9758.45, 9760.39, ! 1.94238 9761.1, 9763.22, ! 2.11816 9773.03, 9776.21, ! 3.17773 9776.21, 9778.5, ! 2.2959 9794.74, 9797.04, ! 2.2959 9799.16, 9801.63, ! 2.47168 9800.39, 9803.22, ! 2.82422 9804.1, 9806.75, ! 2.64844 9806.57, 9808.87, ! 2.29492 9808.16, 9810.46, ! 2.2959 9810.28, 9812.75, ! 2.47168 9822.67, 9825.32, ! 2.64844 9829.38, 9833.8, ! 4.41406 9834.15, 9836.45, ! 2.29492 9837.15, 9840.86, ! 3.70801 9842.98, 9844.92, ! 1.94238 9844.57, 9846.69, ! 2.11914 9846.33, 9848.63, ! 2.2959 9848.1, 9849.86, ! 1.76562 9849.16, 9851.45, ! 2.29492 Page 3 • 9855.69, 9858.87, 9861.16, 9863.46, 9870.91, 9872.67, 9876.56, 9877.79, 9881.68, 9882.91, 9890.68, 9891.21, 9902.79, 9903.67, 9935.63, 9936.69, 9963.56, 9965.5, 9971.68, 9972.56, 10002.9, 10005.2, 10006.4, 10007.8, 10008.7, 10010.6, 10019.4, 10020.3, 10024.7, 10025.4, 10030, 10030.9, 10040.1, 10041, 10044.7, 10045.5, 10047.3, 10048.4, 10051.9, 10052.6, 10055.3, 10055.3, 10073.3, 10075.3, 10081.8, 10083, 10096.4, 10097.2, 10098.9, 10100.5, 10110.6, 10111.3, 10112.5, 10112.9, 10121.9, 10120.6, 10148.3, 10149.7, 10150.4, 10151.9, 10157.3, 10158.7, 10159.3, 10160.5, 10167.7, 10168.8, 10176.2, 10177.6, 10197.1, 10197.1, 10201.1, 10201, 10213.3, 10211.6, 10229, 10229.6, 10232.9, 10233.8, 10234.3, 10235.6, 10244.4, 10244.8, 10254, 10255, 10264.9, 10266, 10273, 10274.5, 10275.7, 10276.7, 10276.9, 10278.5, 10279.8, 10280.8, 10292.7, 10293.9, 10297.1, 10298.3, 10304.7, 10305.4, 10307.2, 10308.4, 10310.3, 10311.4, 10313.3, 10314.6, 10329.5, 10327.7, 10332.5, 10333, 10346.8, 10345.7, 10351.6, 10350.7, 10375, 10374.7, 10381.9, 10381.6, 10394.1, 10393, 10401.5, 10400.5, 10406.1, 10404.7, 10411, 10410.5, tapescan.txt 3.17773 2.29492 1.76465 1.23535 1.23535 0.529297 0.882812 1.05957 1.94238 0.882812 2.29492 1.41211 1.94238 0.881836 0.706055 0.882812 0.882812 0.882812 1.05859 0.706055 0 1.94141 1.23535 0.706055 1.58887 0.706055 0.353516 -1.23633 1.41211 1.41309 1.41211 1.23535 1.05859 1.41211 0 ! -0.175781 ! -1.76562 ! 0.530273 ! 0.882812 ! 1.23535 ! 0.353516 1.05957 ! 1.05957 ! 1.41309 ! 1.05957 ! 1.58887 ! 1.05957 ! 1.23633 ! 1.23633 ! 0.706055 ! 1.23633 ! 1.05957 ! 1.23535 ! -1.76562 ! 0.529297 ! -1.05957 ! -0.882812 ! -0.353516 ! -0.353516 ! -1.05957 ! -1.05859 ! -1.41211 ! -0.529297 Page 4 • 10415.3, 10414.1, 10444.3, 10444.6, 10493.4, 10493.1, 10512, 10510.7, 10515.5, 10514.1, 10559, 10557.6, 10561.1, 10559.7, 10568.7, 10568.5, 10577, 10577.2, 10597.3, 10598.7, 10606.6, 10606.1, 10614.7, 10615.6, 10616.8, 10617.4, 10622.5, 10623.6, 10627.8, 10629.2, 10637, 10639.6, 10641, 10644.2, 10645.1, 10648.5, 10651.8, 10655.9, 10663.4, 10666, 10686.9, 10689, 10696, 10697.3, 10701.3, 10704.1, 10714.4, 10723.2, 10718.6, 10726.9, 10746, 10758.7, 10757.9, 10772.2, 10767.7, 10779.6, 10772.2, 10783.3, 10782.9, 10794.2, 10906.3, 10904.2, 10932.4, 10930.3, 10943.9, 10940.9, 10967.5, 10969.5, 10979.7, 10981.1, 10992.1, 10994.7, 10995.4, 10998.8, 11017, 11020.3, 11045.6, 11050.4, 11057.1, 11062.4, 11059.2, 11064.2, 11065.6, 11069.8, 11070, 11075.3, 11089, 11091.5, 11095.2, 11097.7, 11106.4, 11108.9, 11127.9, 11129.2, 11138.7, 11140.5, 11145.9, 11147.3, 11153.5, 11153.9, 11158.3, 11159.7, 11177.2, 11179.2, 11192.2, 11194.5, 11195.2, 11197.9, 11199.6, 11201.4, 11208.6, 11210.9, tapescan ! -1.23633 ! 0.353516 ! -0.353516 ! -1.23633 ! -1.41211 ! -1.41211 ! -1.41309 ! -0.175781 ! 0.176758 ! 1.41309 ! -0.529297 ! 0.882812 ! 0.530273 ! 1.05859 ! 1.41309 ! 2.64844 ! 3.17773 ! 3.35449 ! 4.06055 ! 2.64746 ! 2.11816 ! 1.23535 ! 2.8252 ! 8.82812 ! 8.29785 ! 12.7119 ! 14.3008 ! 11.8291 ! 11.123 ! 11.2998 ! -2.11816 ! -2.11914 ! -3.00098 ! 1.94238 ! 1.41211 ! 2.64844 ! 3.35449 ! 3.35449 ! 4.76758 ! 5.2959 ! 4.94336 ! 4.2373 ! 5.29688 2.47168 ! 2.47168 ! 2.47168 ! 1.23633 ! 1.76562 ! 1.41211 ! 0.353516 ! 1.41309 ! 1.94238 ! 2.2959 ! 2.64844 ! 1.76562 ! 2.29492 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 283 records... txt Minimum record length: 10 bytes Page 5 Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 132 bytes CJ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from schlumberger GR CNL dated 11 sep 2007 per BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Log~iny direction is down (value= 255) optical Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 168 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De pth = 9439.500000 Tape File End Dept h = 12447.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Page 6 Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 181 records... 54 bytes 4124 bytes • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from MwD G-096 dated 09 Sep 2007 per BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Opticall Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth Io: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 124 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De th = 10186.000000 Tape File End Depth = 12401.000000 Page 7 r~ U Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** Tape Subfile: 3 137 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .001 1024 tapescan.txt 0.500000 feet records... bytes bytes ~~ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MADPass data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 20 bytes Logging direction is down (value= 255) optical Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 50 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool code samples units 1 RAD MWD 68 1 OHMM 2 RAS MWD 68 1 OHMM 3 RPD MWD 68 1 OHMM 4 RPS MWD 68 1 OHMM Total Data Records: 178 1 size Length 4 4 4 4 4 4 4 4 16 Tape File Start De pth = 10186.250000 Tape File End Dept h = 12401.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 8 tapescan.txt **** FILE TRAILER **** Tape subfile: 4 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 189 records... 54 bytes 4124 bytes • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) opticall Lod Depth scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 335 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De pth = 9438.750000 Tape File End Dept h = 12445.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 9 tapescan.txt **** FILE TRAILER **** Tape subfile: 5 348 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/09/09 1537273 O1 **** REEL TRAILER **** MWD 09/02/04 BHI O1 Tape subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LI5 DEPTH GR ROP RAD RAS RPD RPS 9439.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9440.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 67.7751 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 293.1151 47.2213 2000.0000 42.9342 16.3192 12.1161 9700.0000 112.3476 63.8546 2000.0000 2000.0000 78.3769 63.8146 9800.0000 45.2666 76.6974 2000.0000 70.3926 Page 10 tapescan.txt 38.2840 33.1222 9900.0000 25.0969 11.7599 2000.0000 643.2150 70.5340 70.7505 10000.0000 20.8411 50.7823 2000.0000 28.3830 15.4333 13.2763 10100.0000 36.0691 84.5784 31.3545 22.0177 18.7507 19.2361 10200.0000 34.8259 54.0925 12.7668 9.5686 8.1301 7.3951 10300.0000 23.2322 69.2815 17.6515 15.3024 14.4425 15.8760 10400.0000 70.8142 86.6026 13.5835 13.7080 11.5980 11.7930 10500.0000 50.6468 119.9256 16.1163 13.6740 11.6491 11.1500 10600.0000 51.2889 79.3870 12.5897 9.9047 9.1191 8.6863 10700.0000 38.7373 144.0700 18.5021 18.7859 14.7570 14.0832 10800.0000 34.1613 143.3387 18.2214 17.4705 15.9390 16.4206 10900.0000 34.3361 143.1917 20.3225 17.7926 15.6410 15.8830 11000.0000 26.1911 154.1609 18.0007 16.2204 14.4791 15.0591 11100.0000 32.2000 173.9000 18.0310 14.8290 13.4660 13.2620 11200.0000 35.7393 152.2397 13.1257 12.2222 10.8945 10.9821 11300.0000 100.3375 83.3641 23.2500 15.7540 13.6490 12.5700 11400.0000 64.7156 122.4437 17.4343 13.9562 12.1440 11.6595 11500.0000 73.6976 103.5226 15.3163 12.5351 10.9443 10.1988 11600.0000 42.3766 137.3031 13.2799 12.0524 11.0604 10.8420 11700.0000 26.9766 199.2898 13.9970 10.7509 8.4426 7.0713 11800.0000 76.4984 133.2547 17.7480 14.8775 11.5695 10.3482 11900.0000 22.8000 171.3062 11.0099 10.6504 Page 11 • • tapescan.txt 10.0254 10.3383 12000.0000 42.9555 245.9750 15.1604 13.6909 11.5010 10.8850 12100.0000 27.6445 158.6414 8.7347 7.3101 6.7214 6.3223 12200.0000 31.3383 627.4554 8.1200 8.2135 7.6924 7.7020 12300.0000 21.9188 115.7609 9.9276 10.4440 10.1447 11.2420 12400.0000 23.0164 81.1828 9.4748 9.7657 8.9230 9.1311 12447.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start De th = 9439.500000 Tape File End Dept h = 12447.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10186.0000 21.7000 61.2000 -999.2500 -999.2500 -999.2500 -999.2500 10186.5000 22.5000 69.7000 13.2680 10.7620 8.3650 8.3650 10200.0000 35.3000 51.9000 11.8100 9.1180 7.7390 7.7390 10300.0000 23.7000 69.5000 16.6120 15.0350 13.2100 13.2100 10400.0000 66.8000 80.3000 12.9380 13.4320 10.7360 10.7360 10500.0000 51.7000 144.0000 15.4750 13.5180 10.7170 10.7170 10600.0000 48.0000 80.3000 12.5310 9.8880 8.6840 8.6840 10700.0000 41.6000 114.8000 17.7770 17.7580 12.8820 12.8820 10800.0000 33.2000 145.7000 18.8440 17.5110 14.4200 14.4200 10900.0000 32.2000 144.0000 20.2510 17.9570 14.8210 14.8210 11000.0000 31.2000 153.0000 18.2930 16.4160 13.2100 13.2100 Page 12 • tapescan.txt 11100.0000 29.1000 305.9000 17.1880 13.7200 10.5820 10.5820 11200.0000 26.9000 150.4000 14.2740 13.2140 11.7510 11.7510 11300.0000 92.0000 86.2000 25.0400 17.4800 15.0570 15.0570 11400.0000 80.9000 68.7000 17.2120 13.0910 11.3060 11.3060 11500.0000 71.5000 105.8000 16.7580 13.9630 11.6040 11.6040 11600.0000 50.1000 141.0000 12.4690 12.0270 10.5450 10.5450 11700.0000 27.0000 209.8000 14.5480 11.4490 8.4980 8.4980 11800.0000 61.8000 93.6000 16.5090 13.6490 11.0340 11.0340 11900.0000 21.9000 173.4000 10.5470 9.9260 9.1840 9.1840 12000.0000 43.0000 184.7000 14.7830 13.4050 11.3980 11.3980 12100.0000 27.1000 161.4000 8.7170 6.8310 6.2690 6.2690 12200.0000 34.8000 118.3000 -999.2500 -999.2500 -999.2500 -999.2500 12300.0000 22.2000 114.5000 -999.2500 -999.2500 -999.2500 -999.2500 12400.0000 23.8000 79.1000 -999.2500 -999.2500 -999.2500 -999.2500 12401.0000 22.0000 85.9000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start De th = 10186.000000 Tape File End Dept h = 12401.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS DEPTH RAD RAS RPD RPS 10186.2500 -999.2500 -999.2500 -999.2500 -999.2500 10186.5000 13.2680 10.7620 8.3650 7.0630 10200.0000 11.8100 9.1180 7.7390 6.8810 10300.0000 16.6120 15.0350 13.2100 12.5700 10400.0000 12.9380 13.4320 10.7360 10.4000 10500.0000 15.4750 13.5180 10.7170 9.6550 10600.0000 12.5310 9.8880 8.6840 8.0760 Page 13 10700.0000 17.7770 10800.0000 18.8440 10900.0000 20.2510 11000.0000 18.2930 11100.0000 17.1880 11200.0000 14.2740 11300.0000 25.0400 11400.0000 17.2120 11500.0000 16.7580 11600.0000 12.4690 11700.0000 14.5480 11800.0000 16.5090 11900.0000 10.5470 12000.0000 14.7830 12100.0000 8.7170 12200.0000 -999.2500 12300.0000 -999.2500 12400.0000 -999.2500 12401.0000 -999.2500 tapescan.txt 17.7580 17.5110 17.9570 16.4160 13.7200 13.2140 17.4800 13.0910 13.9630 12.0270 11.4490 13.6490 9.9260 13.4050 6.8310 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start De th = 10186.250000 Tape File End Dept h = 12401.000000 Tape File revel Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 5 is type: LIS DEPTH GR ROP RPD RPS 9438.7500 -999.2500 -999.2500 -999.2500 -999.2500 9439.0000 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 62.3000 -999.2500 -999.2500 -999.2500 9600.0000 293.8000 51.2000 16.8260 11.4360 9700.0000 35.9000 45.3000 56.9850 45.1600 9800.0000 51.5000 67.7000 30.1000 27.4360 9900.0000 25.9000 7.8000 64.5900 67.4820 10000.0000 21.1000 50.9000 18.6620 13.1810 10100.0000 29.3000 83.7000 16.6520 16.1660 10200.0000 35.3000 51.9000 8.1350 7.4000 10300.0000 23.7000 69.5000 13.8480 14.8630 • 12.8820 14.4200 14.8210 13.2100 10.5820 11.7510 15.0570 11.3060 11.6040 10.5450 8.4980 11.0340 9.1840 11.3980 6.2690 -999.2500 -999.2500 -999.2500 -999.2500 RAD -999.2500 -999.2500 -999.2500 2179.3999 2179.3999 2179.3999 2179.3999 2179.3999 30.9310 12.7480 17.7870 11.4890 13.7030 14.3680 12.5700 8.8050 12.1700 13.9930 10.2680 10.5650 9.9900 7.1240 9.7540 9.1480 11.0130 5.7260 -999.2500 -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 51.5780 255.4800 59.1400 119.3140 27.8390 21.1850 9.5770 15.0840 Page 14 • ! tapescan.txt 10400.0000 66.8000 80.3000 13.2840 13.7240 11.4650 11.5210 10500.0000 51.7000 144.0000 16.0480 13.4680 11.5490 10.9920 10600.0000 48.0000 80.3000 12.7320 10.0530 9.2080 8.7770 10700.0000 41.6000 114.8000 18.0220 19.0310 14.5530 13.6860 10800.0000 33.2000 145.7000 18.7030 17.9360 15.9700 16.4570 10900.0000 32.2000 144.0000 20.7530 17.9410 15.7120 15.8830 11000.0000 31.2000 153.0000 18.2390 16.1500 14.6560 15.1620 11100.0000 29.1000 305.9000 17.4130 14.1630 12.7860 12.3790 11200.0000 26.9000 150.4000 13.7800 12.7600 11.4760 11.6580 11300.0000 92.0000 86.2000 24.1900 16.3180 14.2780 13.2620 11400.0000 80.9000 68.7000 17.3690 13.9260 12.2560 12.0530 11500.0000 71.5000 105.8000 15.6640 12.9580 11.1980 10.3590 11600.0000 50.1000 141.0000 12.8790 11.8160 10.6250 10.1590 11700.0000 27.0000 209.8000 14.0260 10.9120 8.5660 7.1850 11800.0000 61.8000 93.6000 17.4490 14.6320 11.7100 10.7360 11900.0000 21.9000 173.4000 10.7630 10.4070 10.0080 10.2590 12000.0000 43.0000 184.7000 15.2320 13.5550 11.3980 10.7770 12100.0000 27.1000 161.4000 8.8030 7.4800 6.8630 6.5470 12200.0000 34.8000 118.3000 8.1860 8.0290 7.3940 7.1850 12300.0000 22.2000 114.5000 9.6810 10.2270 10.1790 11.3320 12400.0000 23.8000 79.1000 10.0660 9.9420 9.1350 9.2340 Page 15 tapescan.txt 12445.0000 -999.2500 -999.2500 -999.2500 -999.2500 r 1 LJ -999.2500 -999.2500 Tape File Tape File Tape File Tape File 0 Tape subfile 6 start Depth = 9438.750000 End Depth = 12445.000000 revel Spacing = 0.250000 Depth units = feet is type: LIS Page 16
