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208-124
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p~~~- ~~~ Well History File Identifier Organizing (done) ^ Two-sided III II'III II III II III ^ Rescan Needed RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: DIGITAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: p~, ~ © /s/ Project Proofing III II'I II II III I I III BY: Maria Date: /s/ Scanning Preparation _„~_ x 30 = + ~~ =TOTAL PAGES A / ~ (Count does not include cover sheet) BY: ~ Maria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Q3[ia. Dater rq ~' ~ /s/ V 1/I I ' r Stage 1 If NO in stage 1, page(s) discrepancies w e found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II I (III ReScanned ~" "~"""II ""' BY: Maria Date: /s/ Comments about this file: Quality Checked 53 10/6!2005 Well History File Cover Page.doc STATE OF ALASKA ALAS AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERAMONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory " 208 - 124 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 0 50 - 029 - 22703 - 61 - 00 7. Property Designation: li a 8. Well Name and Number: ADL 02829 & 034622 P1 24L1 - 01 9. Field / Pool(s): Z Prudhoe Bay Field / Point McIntyre Pool 10. Present well condition summary Total depth: measured 14017 feet Plugs (measured) None true vertical 9002 feet Junk (measured) —11510' Effective depth: measured 14017 feet Packer: measured 11229 & 11410 feet true vertical 9002 feet true vertical 8383 & 8502 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20' 110' 110' Surface 3352' 9 - 5/8" 3386' 3356' 5750 3090 Intermediate Production 12439' 7" 12044' 8917' 8160 7020 Liner 2584' 2 -7/8" 11433'- 14017' 8517'- 9002' 13450 13890 Perforation Depth: Measured Depth: Slotted Liner 11436'- 13976' QLANN N O V �` � 2010 True Vertical Depth: Slotted Liner 8519' - 9000' Tubing (size, grade, measured and true vertical depth): 4 -1/2" x 3 -1/2" x 4 -1/2 ", 9Cr / 13Cr80 / 11456' MD 8532' TVD 12.6# x 9.2# x 12.6# 13Cr Packers and SSSV (type, measured and true vertical depth): 7" x 3 -1/2" HES TNT Packer 11229' MD 8383' TVD 7" x 4 -1/2" Baker Packer 11410' MD 8502' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): A, EEI Treatment description including volumes used and final pressure: N 0 5 20 10 Cut and pull tubing from 11361'. Clean out and run new Chrome tubing. o?I Oil & Gas Cons. Cow' � Anchatap 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1800 1165 Subsequent to operation: 750 650 327 1415 651 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: • Daily Report of Well Operations ► ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic • Well Schematic Diagram 15. Well Status ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 5645683 1 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si�ature; - Phone 564-4750 Date j —Ci iD Sondra Stewman 564 -4750 Form 10-404 Revised NEW NOV 4 510 Submit Original Only /r TREL = CIW WELLHEAD = F MC SAFETY TES: ***4-1/2" & 3-1/2" CHROME ACTUATOR= BAKER C JMD DRA P1 -2 4 TUBINGWIPPLES'7" CHROME CSG`CTD KB. ELEV = 43.3' L 1 &L 1 -O 1 LATERALS ARE ELM Ds. BF. ELEV = KOP= 2797' 2223' 4 -1/2" CAMCO BAL -O SVLN, ID = 3.813" Max Angle 54° @ 6020' Datum MD = 11931' Datum TV ID = 8800' SS GAS LIFT MANDRELS 1 4-1/2" TBG, 12.6 #, 13 -CRVAM TOP, 2256' ST MD TVD DEV TYPE VLV LATCH PORT DATE . 0152 bpf, ID = 3.958" 1 3797 3699 38 MMG DOME RK 16 09/10/10 9 -5/8" CSG, 40 #, L -80 BUTT, ID = 8.835" 3386 2 6727 5504 52 MMG DOME RK 16 09/10/10 3 8267 6489 52 MMG DOME RK 16 09/10/10 4 9716 7406 50 MMG DOME RK 16 09/10/10 7" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 11108 1 S 111128 83181 49 MMG SO RK 22 09/10/10 11198 3 -1/2" HES X NIP, ID = 2.813" Minimum ID = 2.37" @ 11434' 11229 7" X 3 -1/2" 3- ES PKR, ID = 2.949" 3 -1 /2" X 2 -7/8" LINER XO 11265 3 -1/2" HES X NIP, ID = 2.813" 11327 3 -1/2" HES XN NIP, ID = 2.75" 3 -1/2" TBG, 9.2 #, 13CR -85 VAM TOP 11360' .0087 bpf, ID = 2.992" 11375 7" X 4 -1/2" UNIQUE OVERSHOT TBG STUB (08/30/10) 11361' 11410 7" X 4 -1/2" BKR PKR, ID = 3.875" 11433 4 -1/2" HES X NIP, ID = 3.813" 11433 3.770 BTT DEPLOYMENT SLV, ID = 3.00" 11444' 4 -1/2" HES XN NIP, ID = 3.80" 1 (MILLED 03/17/08) (BEHIND PIPE) 1 4 -1/2" TBG, 12.6 #, 13CR NSCT, 11456' 1 1 11434 3 -1/2" x 2 -7/8" XO, ID = 2.37" .0152 bpf, ID = 3.958" I I 11456 4 -1/2" WLEG, ID = 3.958" I I I I 11448 SQZ CMT DONUT F/ 11448 -11493 FISH: TOP OF WIRE ( 1 0 /01/10) 11510 MILLED TO 3.80 (07117/08) TOPOF WHIPSTOCK 12040' I I I I MILLOUT WINDOW (P1 -24L1) 12044'-12053' PERFORATION SUMMARY I I I I KOP(P1- 24L1 -01) 12356' REF LOG: GR/LDT /CNL ON 09/23/96 I ANGLE AT TOP PERF: 49' @ 12030' 1 Note: Refer to Production DB for historical perf data 1 1 12261 FISH: 29' SL TOOLS (10/01/10) SIZE SPF INTERVAL Opn /Sqz DATE I 2 -7/8" SLTD LNR, 6.16 #, L -80, STL, 14750' P1 -24L1 1 I\ 0058bpf, ID = 2.441" SLTD 12356 - 14719 C 08/09/08 ` 1111- 240.01 �` 12356 ALUMINUM BILLET SLTD 11433 - 13976 C 08/13/08 ' `�. P1 -24 `�� ---- - - - - -- :Fm__ ? 4 11465 - 11469 S 09/28/96 3 -3/8" 4 12030 - 12070 C 04/20/97 \ 14719 PBTD 2 -7/8" 6 12090 - 12200 C 04/17/98 2 -7/8" 6 12220 - 12270 C 04/17/98 ? 4 12264 - 12268 S 09/28/96 — — ? 4 12276 - 12280 S 09/28/96 PBTD 13976' PBTD 12390 2 -7/8" SLTD LNR, 6.16 #, L -80, STL 14017' = 7" CSG, 29 #, 13 -CR NSCC, .0371 bpf, ID = 6.184" 12470' .0058bpf, ID 2.441" P1-24L1-0 DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 10/03/96 D14 ORIGINAL COMPLETION 10/03/10 JCM/SV FISH (10/01/10) WELL: P1 -24 / L1 & L1 -01 08/14/08 NORDICI CTD MULTI -LAT (L1 &L1 -01) PERMIT No: 1961490 / 2081030 / 2081240 09/04/10 D16 RWO API No: 50-029-22703-00/60/61 09/07/10 SV DRLG HO CORRECTIONS SEC 16, T12N, R14E, 1364' FSL & 965' FEL 09/23/10 1 RCT /AG GLV GO (09/10/10) 09/27/10 IO ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 07/20/10 RAN 3.80" CENT, UNABLE TO PASS 1743' SLM. RAN 3.00" S.BAILER, BROKE THRU OBSTRUCTION Q 1743' SLM, UNABLE TO PASS 1929' SLM. RECOVERED2 CUP OF HYDRATES. PUMPED 12 BBLS METH DOWN TBG. WORKED FROM 1743' SLM TO 1943' SLM, UNABLE TO GET ANY DEEPER. LRS PUMPED 580 BBLS HOT CRUDE DOWN IA. DRIFTED TO K -VLV IN SVLN @ 2168' SLM W/ 3.805" G.RING, BRUSH, NO PROBLEMS. PULLED 4 -1/2" K -VLV (K314 -A) FROM SVLN @ 2168' SLM/2197' MD. 07/20/10 T /I /0= 2300/2500/40 Temp= SI Assist wireline pump as directed- Load IA 10 bbis 60/40 MW spear followed with 577 bbis 180* crude down the IA. RD IA & RU TBG, Started pumping 110` crude down TBG 07/21/10 LRS LOADED TBG W/ 220 BBLS OF CRUDE. BRUSHED FROM SURFACE TO X- NIPPLE Q 11 397' SLM/11425' ELMD. SET PX -PLUG IN X- NIPPLE @ 11397' SLM/11425' ELMD. LRS CMITAA 3500 PSI,PASSED. DUMPED 10' OF SLUGGITS Q 11397' SLM. SET 4 1/2" JUNK CATCHER Q 11 378' SLM. ** *WELL LEFT S/I OPER NOTIFIED * ** 07/27/10 ** *WELL S/I ON ARRIVAL ** *(pre rwo) PULLED 4 -1/2" JUNK CATCHER FROM 11,391' SLM. BAILED -4.5 GALS SLUGGITS FROM 11,401' TO 11,406' SLM W/ 3.00" x 10' P- BAILER. PULLED P -PRONG FROM 4 -1/2" PX PLUG BODY @ 11,433' MD. CURRENTLY IN HOLE Q 11,407' SLM W/ 3.00" x 10' PUMP BAILER. 07/28/10 BAILED -2.5 GALS OF SLUGGITS FROM 11,407' TO 11,412' SLM W/ 3" x 10' P-BAILER. RAN 2.25" x 5'P-BAILER W/ SNORKEL BTM TO 11,413' SLM (Metal marks from end cap of blr btm / 1/2 cup of sluggits). PULLED 4 -1/2" PX PLUG BODY. (intact). DRIFTED TUBING TO 12,255' SLM W/ 2.25" CENT S -BLR. (no sample recovered). RAN 2.25" CENT, PETRADAT GAUGES AS PER PROGRAM (see data tab). SET 4 -1/2" WRP AT 11,388'SLM/11,417'MD. 07/28/10 Assist S -Line MIT OA 1000 psi ( RWO prep) SB for SL to set WRP. 07/29/10 T /I /0= 220/350/20 Temp =Sl Assist SL as directed. MIT -OA 1000 psi FAIL, CMIT -TxIA 3500 psi PASS (3rd attempt) (RWO expense) CMIT -TxIA: pumped a total of 12.8 bbis 90* crude down IA to test. 3rd test, 1st 15 min T /IA lost 0/0, 2nd 15 min T /IA lost 0 /0, for a total T /IA loss of 0/0 in 30 min. Bled back --9 bbls. MIT - OA: pumped a total of .8 bbis crude down OA to test. 2nd test, 1 st 15 min lost 20 psi, 2nd 15 min lost 20 psi, 3rd 15 min lost 20 psi for a total of 60 psi in 45 min. Bled OAP. S -Line on well on dep. Wing shut swab shut ssv shut master open casing valves open to gauges Final W hps= 320/320/10 07/29/10 * * *CONT WSR FROM 7/28/10 * ** LRS CMIT -TxIA TO 3500 #.(passed after 3 attempts) LRS MIT -OA TO 1000# (failed after 3 attempts). DUMP BAIL 10' OF SLUGGITS ON TOP OF WRP TO 11,376' SLM SET 4.5 JUNK CATCHER AT 11,366' SLM. * * *RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED 30-Jul-2010 T /I /0= 600/300/100 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 2 HP BT onto THA 2000 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4900/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems, LDS from 7:00 - 9:00 blocked by hydraulic panel needs to be functioned after removal. Page 1 of 8 P1 -24 / P1 -24 L1 & P1- 241_1 -01 Well History Date Summary PPPOT -IC : RU 2 HP BT onto IC test void 100 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "ET style" all functioned with no problems. * ** NOT ALL LDS CYCLED ON TUBING SPOOL * ** 31 -Jul -2010 ** *WELL SHUT -IN ON ARRIVAL * * *(E -LINE JETCUT) INITIAL T /IA/OA = 1350/1450/200 RIH WITH 25.5'x 3.65" TOOLSTRING. CORRELATED TO DOYON 14 TUBING SUMMARY DATED 23- SEP -1996. CUT TUBING AT 11 370' WITH 3.65" POWERCUTTER: CCL TO CUTTER DEPTH = 8.5% CCL STOP DEPTH = 11361.5'. FINAL VALVE CONFIGURATION: SWAB CLOSED, WING CLOSED, MASTER OPEN, SSV OPEN. RDMO AND HAND OVER TO DSO FINAL TWO 1750/1750/0 ** *JOB COMPLETED * ** T /1 /0= 1650/1650/150 Temp =S1 CMIT TAA Passed to 2500 psi (RWO prep) CMIT T/I pressured up to 2500/2500 psi with 3 bbls diesel. T/I lost 100/60 psi in first 15 minutes and 0/20 psi in second 15 minutes. For a total of 100/80 psi in 30 minutes. Bled pressure down until getting gas gas. FW HP's= 1800/1800/300 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 1- Aug -2010 T /1 /0= 1800/1800/120 Temp= SI Circ -Out TAA (Pre RWO) Rigged up to well. While attempting to bleed AL line pressure down flowline of P1 -23 the choke washed out. Currently standing by for Hardline crew to rig jumper line to P1 -20. * ** Job continued on 8 -2 -10 WSR * ** 2- Aug -2010 * ** Job continued from 8 -1 -10 WSR * ** Circ -Out (Pre RWO) Pumped 2 bbls meth, 289 bbls 1% KCL and 297 bbls seawater down Tbg up IA taking returns to flowline of P1 -20. Freeze protect TxIA with 66 bbls diesel, U -Tubed for 1 hr. Job transfered to LRS# S -2. T /1 /0= 300/300/0. Circ -out. (RWO prep) MIT -OA * *FAILED ** to 1000 psi. Take over job for LRS Unit 62. (Mechanical issues) Freeze protect flowline on well P1 -20. Pumped 8 bbls of neat methanol to freeze protect P1 -20 flowline. Pumped .8 bbis dsl to pressure up OA. 2nd test 15 min OA lost 40 psi. 30 min OA lost 40 psi. 45 min OA lost 40 psi. Final WHP= 320/380/0 15- Aug -2010 T /1 /0= 60/50/30. Temp =Sl. Bleed WHP's to 0 psi. (pre -RWO). T, IA & OA FL's @ surface. No flowline or wellhead scaffolding on this well, drilling scaffold in place. Bled IAP from 50 psi to 0 psi in 1 hour, during IA bleed TP decreased to 0 psi. Bled OAP from 30 psi to 0 psi in 30 minutes, 6 gallons of fluids were returned during IA & OA bleeds. Monitor for 30 minutes during rig down. No change in TP, IAP increased to 0+ & OAP increased to 0+ during monitor. Final W HP's= 0/0 + /0 +. Job Complete. 18- Aug -2010 T /1/0= SSV /200/0 Temp =Sl Cycle LDS on tubing head Pre rig conducted on 07/30/10 Panel was restricting access on LDS 7:00 to 9:00, cycled and torqued LDS "ET style" all functioned with no problems. 23- Aug -2010 T /I /0= 20/20/100 Tested Swab (barrier) valve for 5 min. (1208 -1213) 500 psi low /pass -3500 psi for 5 min. (1214 -1219) high /pass; Tested Master (barrier) valve for 5 min. (1224 -1229) low /pass -3500 psi for 5 min. (1231 -1236) high /pass; Tested lubricator to 300 psi low /pass -3500 psi high /pass; Set 4" CIW BPV #105 @ 108" w /1 -1' ext.; Upon completion tested tree cap to 500 psi; Pre Doyon 16 Post -rig 26- Aug -2010 T /I /O = 0/0/0 Verified Barriers, Pressure tested Lubricator - Low: 300 PSI 05:13- 05:18 / Pass High: 3500 PSI 05:21- 05:24 / Pass. Pulled 4- 1/16" CIW "H" BPV # 105 thru tree, 1 -1' ext. used..... tag Q 111 "..... Doyon 16 moved over well .... no problems. 27- Aug -2010 T /1 /0= 0/0/0 Pressure tested lubricator for 5 min. @ 300 psi low /pass -3500 psi high /pass; Pulled 4" CIW TWC # 256 thru stack, 3 -5' ext. & 1 -5' centralizer used, RKB 27'; Post Doyon 16 BOPE test. 3- Sep -2010 * ** DOYON 16 RIG ASSIST. JOB WAS CANCELLED * ** Page 2 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Weil History Date Summary 5-Sep-201 T /I /O= Vac /Vac /0; Pulled 4- 1/16" CIW "H" TWC #286 thru tree for post Do on 16; 1 -1' ext. used, to i 99 ed p p Y @ 114 "; No Problems 7- Sep -2010 Charges for WRP redress - Pulled on 8/31/2010 by Doyon 16 8- Sep -2010 T /1 /0= 0/0/0. Temp =Sl. Rigged up 6000 psi chart recorder for MIT -IA to 2000 psi & MIT -TBG to 3500 psi, for slickline & LRS. Wound clock and installed new pens on recorder. slickline has control of valve positions. * ** WELL S/I ON ARRIVAL * ** (post rwo) PULL 4 1/2" DUMMY WRDP SSSV FROM 2201' SLM/2223' MD. SET 3 1/2" SLIP STOP CATCHER @ 3916' SLM. PULL RKP -DCR FROM STA #1(3781' SLM/3797' MD) SET RK -DGLV @ STA #1(3797' MD). PULL EMPTY 3 1/2" SLIP STOP CATCHER FROM 3916' SLM. FW HP= 150/150/0 * * * *CONT JOB ON 9- 9 -10 * ** LRS T -98 fluid support 9- Sep -2010 * * * *CONT JOB FROM 9- 8 -10 * ** *(post rwo) MIT -IA TO 2000 #.(PASS). MIT -T TO 3500 #(FAIL) SET 3 1/2" X SEL TEST TOOL Q 11238' SLM/11265' MD, MIT -T TO 3500 #(PASS) PULL RK -DGLV FROM STA #5,11107 SLM/1 1 128'MD. SET RKP -CIRC GLV IN STA #5,11107 SLM/11128' MD LRS PUMPED KCL PILL, PULL RKP -CIRC GLV FROM STA #5, 11107' SLM/11126' MD PULL RK -DGLV FROM STA #4, 9700' SLM/9716' MD & STA #3, 8250' SLM/8267' MD. T /1 /0= 20/20/0 * * * *CONT JOB FROM 9- 10- 10 * * ** T /I /0= x ( Assist S -Line / MITxT / MITx IA / Spot 9.8 ppg Brine) MITx IA Passed / Pumped 3.3 bbls diesel down IA to achieve test press of 2000 Psi. IA lost 0 Psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 20 Psi in 30 min test. MITx IA passed per S -Line PE. Rig to TBG. MITxT / Pump 2.1 bbls diesel to achieve a test press of 3500 Psi against TBG Test Plug. TBG lost 100 Psi in 1 st 15 Min and 20 Psi in 2nd 15 Min for a total Iss of 120 Psi in 30 Min test. Pumped 5 bbls neat meth, 23 bbls 9.8# inhibited brine, 213 bbls inhibited 1 % KCL and a 35 bbl DSL freeze protect down IA, up TBG, taking returns to an open top tank. * *IA & OA valves left open to gagues upon departure, tags hung. ** FWP's= 0/460/100 10- Sep -2010 * * * *CONT JOB FROM 9- 9 -10 * ** *(post rwo) PULL ST #2 RK -DGLV @ 6713'SLM/6727'MD, PULL ST #1 RK -DGLV Q 3781'SLM/3797'MD SET ST #1 RK -LGLV @ 3781'SLM/3797'MD, SET ST #2 RK -LGLV @ 6713'SLM/6727' MD, SET ST #3 RK -LGLV @ 8250'SLM/8267'MD, SET ST #4 RK -LGLV @ 9700'SLM/9716' MD). SET ST #5 RK -OGLV Q 11 107'SLM/1 1 128'MD, PULL 3 1/2" X SEL TEST TOOL FROM 11 238' SLM /11265' MD. PULL B &R FROM 11298' SLM. FW HP= 350/220/0 * * * *CONT JOB ON 9- 11- 10 * * ** 11- Sep -2010 * * * *CONT JOB FROM 9- 10 -10 * ** *(post rwo) PULL 3 1/2" RHC PLUG BODY FROM 11 300' SLM/11327' MD. DRIFT W/ 2'x 1.50" STEM, 2,25" CENT, 1 3/4" S- BAILER TO 12261' SLM/12288 MD. (LOST OSS & LSS. UNABLE TO GET FREE). DROP & RECOVERED KINLEY CUTTER BAR, CUT @ BKR DEPLOYMENT SLV Q 11,433' MD (- -826' of .125" carbon & 29.5' toolstring left in hole). CURRENTLY GETTING EVERYTHING SET UP TO FISH WIRE & TOOLSTRING ** *JOB IN PROGRESS, CONTINUED ON 9/12/10 WSR * ** T /I /0= 500/140/20 Temp =S /I Assist slickline pump as directed (Post -RWO) Pumped 286 bbls crude down the tubing. Final WHP's= 1500/220/20 "Slickline has control of well at departure" Page 3 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 09/12/10 ** *WELL S/I ON ARRIVAL ** *(Post RWO) RAN BAITED 3 -1/2" BLB, 2.32" BOWEN OVERSHOT BODY TO 11,424' SLM (No marks, unable to get any deeper). RAN BAITED 2 -7/8" BLB, 2.32" BOWEN OVERSHOT BODY TO 11,424' SLM, ABLE TO WORK TO 11,425' SLM. BOWEN OVERSHOT BODY HAD MULTIPLE SCRAPES ON THE SIDE, APPEARS TO BE FROM WIRE. CURRENTLY PUTTING TOGETHER WIRE GRAB, SCRATCHER, AND BRAIDED LINE BRUSH. 09/13/10 MULTIPLE RUNS TRYING TO FISH TOOLSTRING AND WIRE (see log for details). 09/15/10 ** *CONTINUED FROM 9/14/10 WSR * ** (post -rig) MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details) RECOVERED -6' OF .125" CARBON WIRE ( -820' remains w/ 29.5' slickline toolstring) TAGGED 2.377" X -OVER @ 11,425' SLM / 11,434' MD W/ 2.50" L.I.B. (Clean impression of liner w/ no wire) ** *JOB IN PROGRESS, CONTINUED ON 9/16/10 WSR * ** 09/15/10 MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). ON LAST RUN W/ WIRE FINDER IT APPEARS THAT WE HAVE MOVED FISH & WIRE UP HOLE TO XN NIPPLE @ 11,319' SLM (11,327' MD). CURRENTLY POOH W/ 2 -7/8" GR (Sheared). 09/16/10 MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). ON LAST RUN W/ WIRE FINDER IT APPEARS THAT WE HAVE MOVED FISH & WIRE UP HOLE TO XN NIPPLE @ 11,319' SLM (11,327' MD). CURRENTLY POOH W/ 2 -7/8" GR (Sheared). 09/17/10 FREED UP BAIT SUB ASSY FROM 11,326' SLM (Wire finder missing 6 fingers: 3/8" width, 6 -1/2" long each). TAGGED WIRE W/ 2.50" LIB @ 11,333' SLM (Impression of ball of wire). MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). RECOVERED APPROX. 22' OF .125" CARBON WIRE ( -798' remains w/ 29.5' toolstring). CURRENTLY IN HOLE W/ BAITED, BRUSH, SCRATCHER, AND WIRE GRAB @ 11,352' SLM. 09/18/10 MADE MULTIPLE RUNS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). RECOVERED --66' OF .125 CARBON WIRE (732' remaining w/ 29.5'- 1 -1/2" toolstring). CURRENTLY IN HOLE @ 11,401' SLM JARRING ON BAITED WIRE GRAB. 09/19/10 MADE MULTIPLE RUNS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). RECOVERED -12' OF .125 CARBON WIRE (720' remaining w/ 29.5'x 1 09/21/10 MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). CURRENTLY POOH W/ 2.50" MAGNET FROM 11,425' SLM. 09/22/10 MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). TAGGED WIRE W/ 2.25" LIB @ 11,427' SLM (Impression of wire). RAN 2.35" GAUGE RING TO TOP OF WIRE AT 11,427 CURRENTLY JARRING DOWN TO BALL UP WIRE FOR FISHING 09/23/10 MADE MULTIPLE ATTEMPTS TO FISH WIRE AND TOOLSTRING (see log for details) CURRENTLY POOH W/ BAITED 2.35" GAUGE RING. 09/25/10 MADE SEVERAL ATTEMPTS TO FISH WIRE AND TOOL STRING (recovered 7' of .125" wire for the day) CURRENTLY RIH W/ BAITED 2 PRONG WIRE GRAB. 09/26/10 MADE SEVERAL ATTEMPTS TO FISH WIRE & TOOLSTRING 09/27/10 MADE SEVERAL ATTEPMTS TO FISH WIRE AND TOOLSTRING CURRENTLY ATTEMPTING TO PULL BAITED SPEAR @ 11,510'SLM 09/28/10 MADE MULTIPLE ATTEMPTS TO PULL BAITED SPEAR @ 11,510'SLM. W/ .125 WIRE CURRENTLY RIGGING UP BRAIDED LINE Page 4 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 09/29/10 T /1 /0= 925/180/80 Assist S -Line (fish tool string) Pump 5 bbls 60/40 meth followed by 20 bbls KCL - Slick Pump 65 bbls dead crude. SD S -line lubricator leaking. Pump 180 bbls 9.9 lb brine to kill well. Freeze protect well with 35 bbls crude and 5 bbls 60/40 meth cap. Standby for fluid support. Pump 198 bbls 9.9 brine followed by 2 bbls dead crude down TBG. Standby for S -Line. WSR continued on 09 -30 -10 * * *CONT WSR FROM 9/28/10 ** *(post rwo) RIGGED UP B /L, LATCHED FISH AT 11,490'SLM, LRS PUMPED 20 BBLS OF KCUSLICKWATER AND 64 BBLS OF CRUDE. GREASE HEAD STARTED LEAKING WHILE PUMPING.( 1 QUART SPILL), SECURED WELL, LRS LOAD AND KILL WELL W/ 180 BBLS OF 9.9# BRINE. ATTEMPT TO BLEED TBG TO 0 #(ONLY ABLE TO BLEED DOWN TO 100 #) LRS LOAD TBG W/ 200 BBLS OF 9.9# BRINE. * * *CONT WSR ON 9/30/10 * ** 09/30/10 ( WSR continued from 09 -29 -10 ) T /I /0= 925/180/80 Assist s -Line ( Fishing Job ) Freeze protect tbg with 40 bbls crude. FWHP's= 1000/120/0 SV/WV /SSV =S /I MV =O IA, OA =OTG * * *CONT WSR FROM 9/29/10 * ** (post rwo) PULLED BAITED SPEAR FROM 11,510'SLM, RECOVERED 11' OF WIRE * ** (APPROX 696' OF WIRE LEFT IN HOLE W/ 29.5'x 1 -1/2" Slickline Toolstring * ** (fish diagram on file) RIG DOWN.TAG LEFT ON WING VALVE ** *WELL LEFT S /I * ** DSO INSPECTED WELL HEAD PRIOR TO DEPARTURE 10/03/10 ** *WELL S/I ON ARRIVAL ** *(post rwo) LRS DISPLACE I/A 20 BBLS 60/40,122 BBLS CRUDE. SET 4 -1/2" WRDP -2 SSSV @ 2201' SLM (2223' MD) (SER# HBS -603 - 2 SETS STANDARD PACKING - 0 -RINGS IN EACH STACK PERFORM SUCCESSFUL CLOSURE TEST. ** *RELEASE WELL TO PAD OP & DHD TO POP * ** T /1 /0= 75/400/80 Assist Slickline/ Circ IA to crude (post RWO). Pumped 10 bbls 60/40 meth, 122 bbls crude and a 10 bbl 60/40 cap down IA. * *Tags hung, IA & OA valves left open to gauges upon departure, SLB still on location ** FW P's= 600/540/520 10/04/10 TWO = 410/450/170 Temp = SI. Slip stream meth into IA (assist OPS with POP). LRS and SL on site upon arrival. Waited for SL to set and test SSSV (finished @ 1200). PO POP well @ 0145. Pumped initial 6 bbl volume of meoh, then began to slip stream methanol @ 1 bbl /hr on the hour. See log for details. Job in progress. 10/05/10 TWO = 700/1700/220. Temp = 67 °. Slip stream meth into IA (assist OPs with POP). Job continued from 10 -4 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. 10/06/10 T /I /O = 700/1700/180. Temp = 60 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -5 -10 AWGRS. Continue to monitor well while pumping as directed by operations. See log for details. Job in progress. 10/07/10 T /I /O = 700/1700/220. Temp = 70 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -6 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. 10/08/10 TWO = 540/1620/140. Temp = 64 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -7 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. Page 5 of 8 • i P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 10/09/10 T /I /O = 580/1340/20. Temp = 59 Slip stream meth into IA (assist OPs with POP). Job continued from 10- 8-10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job continuing on night shift. 10/10/10 T /I /O = 720/1480/90. Temp = 62 Slip stream meth into IA (assist OPs with POP). * *Job Continued from 10 -09 -10 WSR ** Pumped 0.5 bbls methanol into IA on the hour until 07:00, continued to monitor well until 16:00. See log for details. Job Complete. Final WHPs= 700/1470/100. SV =C. WV, SSV, MV =O. IA, OA =OTG. NOVP. 10/11/10 T/1/0=700/1450/1 10. Temp =62 *. Monitor IAP & slip stream meth into IA if needed. (assist OP's w /POP). Rig up Tri -plex pump & PT all surface lines to 2700 psi. Pumping .5 bbl meth for 12 hour well test. See Log for details. 10/12/10 T /1 /0= 700/1450/110. Temp =62 *. Monitor IAP, slip stream meth into IA. (assist OP's w /POP). ** Continued from previous days AWGRS. Continued pumping .5 bbls meth per hour, (See log for details). 10/13/10 T /I /O = 650/1540/130. Temp =64. Slip stream meth into IA (Assist OPs with POP) every hour as directed by operator. Continued from previous day's AWGRS. Pumped MEOH into IA @ .5 bbl /hr, (see log for details). T /I /O = 650/1540/130. Temp =64. Monitor IAP, slip stream meth into IA (assist OP's w/ POP). Continued from previous day's AWGRS. Continued pumping .5 bbl MEOH per hour into IA. 10/14/10 T /I /O = 650/1520/120. Temp =62 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed (see log for details). Job Continuing. SV = C. WV, MV & SSV = O. IA & OA = OTG. NOVP. 10/15/10 T /I /O = 710/1610/130. Temp =64 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed 10/16/10 T /I /O = 700/1580/130. Temp =66 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed (see log for details). Job shut down for fishing job. Job complete. Final WHPs = 700/1590/130. SV = C. WV, SSV, MV = O. IA & OA = OTG. NOVP. ** *WELL FLOWING ON ARRIVAL ** *(post rwo) LRS F/P FLOWLINE THEN PUMPED 120 BBLS 180* DIESEL FOR HOT TUBING FLUSH. RAN 3.65" BOWEN WIRE FINDER. TAG 4 -1/2" CA. WRDP -2 @ 2205' SLM (No wire encountered). PULLED 4 -1/2" CA. WRDP -2 (s /n = HBS -603, 2 - sets std o -ring pkg stks) FROM 2,223' MD. DRIFT TO 2.75" XN NIPPLE @ 10,327' MD W/ 2.725" BOWEN WIRE FINDER (Flared out to - 2.990 ", No wire encountered). TAG 3 -1/2" x 2.377" X - OVER @ 11,434' MD W/ 2.50" L.I.B. (Impression of clear liner top). ** *JOB IN PROGRESS, CONTINUED ON 10/17/10 WSR * ** T /1 /0= 1450/1420/120 Temp = SI , Assist Slickline ( Hot Tubing Flush ) Freeze Protected flowline with 7 bbls neat meth. Pumped 5 bbls of neat and 120 bbls of 180* F diesel down the tubing. Final WHP= 550/1480/480 . Slickline rigging up on well at departure. 10/17/10 ** *CONTINUED FROM 10/16/10 WSR ** *(post rwo) RAN 2.00" L.I.B. TO 11,436' SLM ( -10' into liner top, all clear, no impression). RAN 2.31" BOWEN WIRE FINDER TO 11,510' SLM (wire marks -4" up inside finder). RAN 2.00" L.I.B. TO 11,510' SLM (Impression of wire loop on face, wire gouge on side). LAY DOWN SURFACE EQUIPMENT & CRANE DUE TO HIGH WINDS. ** *WELL S/I & SECURED, SWCP 4517 ON WEATHER HOLD * ** * * ** -695' OF .125" CARBON WIRE & 29.5'x 1 -1/2" TOOLSTRING STILL IN HOLE * * ** Page 6 of 8 P1 -24 / P1 -24 L1 & P1- 241_1 -01 Well History Date Summary 10/19/10 ** *CONTINUED FROM 10/17/10 WSR ** *(post rwo) MADE SEVERAL ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING. TOP OF WIRE @ 11510' SLM (See log for details). ** *JOB IN PROGRESS, CONTINUED ON 10/20/10 WSR * ** * * ** -695' OF .125" CARBON WIRE & 29.5'x 1 -1/2" TOOLSTRING STILL IN HOLE * * ** 10/20/10 ** *CONTINUED FROM 10/19/10 WSR ** *(post rwo) MADE MULTIPLE ATTEPMTS TO FISH SLICKLINE WIRE AND TOOLSTRING. RECOVERED -3' OF WIRE, CURRENTLY RIH W/ BAITED SPEAR. 10/21/10 * * *CONT FROM 10/20/10 WSR ** *(post rwo) MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE AND TOOLSTRING RECOVERED APPROX. 29.5' OF WIRE. CURRENTLY POOH. 10/22/10 * * *CONT WSR FROM 10/21 /1 0***(post rwo) MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE AND TOOL STRING. RECOVERED - 10' OF WIRE. CURRENTLY JARRING ON BAITED 2.35" GAUGE RING. 10/23/10 * * *CONT WSR FROM 10/22/10 ** *(post rwo) JARRED ON BAITED 2.35" GAUGE RING AT 11,461'SLM ** *LAY DOWN FOR HIGH WINDS * ** 10/24/10 * * *CONT WSR FROM 10- 23 -10 * ** (post rwo) PULLED BAITED 2.35" GAUGE RING FROM 11,470'SLM(recovered 13' of wire). RAN BAITED 2.35" GAUGE RING TO 11,615'SLM.(worked from 11,604'slm to 11,615'slm). CURRENTLY RIH W/ BAITED SPEAR. * * *CONT WSR ON 10/25/10 * ** 10/25/10 * * *CONT WSR FROM 10/24/10 ** *(post rwo) MADE MULTIPLE ATTEMPTS TO FISH WIRE AND TOOLSTRING.(*** APPROX 640' OF WIRE AND 29.5" TOOL STRING. * * *) BRUSHED SSSVLN AT 2201'SLM/2223'MD W/ 4 -1/2" BLB,3.805" GAUGE RING. MADE ONE ATTEMPT TO SET 4 -1/2" WRDP- 2(ser# bws -152) SCSSSV AT 2201'SLM /2223'MD(unable to get c/I and b/I integrity). PUMPED 7 BBLS METH DOWN TBG. CURRENTLY IN HOLE W/ 3.84" NO -GO CENT,2'x1- 7/8 "STEM,4 -1/2" BLB,3.805" GAUGE RING WORKED FROM 740'SLM DOWN TO 1150'SLM * * *CONT WSR ON 10/26/10 * ** 10/26/10 * * *CONT WSR FROM 10/25/10 * ** (post rwo) RAN ASSORTMENT OF GAUGE RINGS FROM 3.84" TO 3.50" TO CLEAR UP HYDRATES / PUMPED 15 BBLS OF METH DRIFT W/ 3.84" NO -GO CENT TO SSSVLN AT 2,201'SLM/2,223'MD. MADE A COUPLE ATTEMPTS TO SET 4 1/2" WRDP -2 SSSV (SER # BWS -152) 2 SET STD PACKING W /0- RINGS. (unable to get c/I and b/I integrity) PARRAFIN ON FIRST VALVE SO PERFORMED BRUSH & FLUSH TO SSSV NIPPLE WITH 100 BBLS OF 190* CRUDE CURRENTLY PULLING OUT W/ SECOND VALVE * * *CONT WSR ON 10/27/10 * ** T /1 /0= 1400/1400/0 ( Assist s -line w /brush n flush /set sssv/ ) Pump 2 bbls neat meth spear followed by 100 bbls dead crude @ 190* down TBG to assist S -Line with Brush and Flush. FW HP= 900/1400/200 / S- Line on well @ departure. IA and OA open to gauges. Operator notified. Page 7 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 10/27/10 * * *CONT WSR FROM 10/26/10 * ** (post rwo) PULLED 4 -1/2" WRDP FROM 265'SLM (packing & O -rings intact / scarring on valve body from possible shear stock) BRUSHED SSSVLN Q 2201'SLM W/4 -1/2" BRUSH, 3.805" GAUGE RING RE -SET 4 -1/2" WRDP -2 SSSV (SER# BWS -153) @ 2201'SLM (unable to gain control line integrity), PULLED SSSV BACK OUT (all pkg & o -rings intact) (pkg stacks measure 36" center to center) PERFOMED B &F ON SSSV NIPPLE @ 2201'SLM WHILE LRS PUMPING 100 BBLS OF 180* DIESEL SET 4 1/2" WRDP -2 (SER # BWS 153) 2 SETS OF STD PACKING W/ O- RINGS. UNABLE TO GET LINE INTEGRITY, PULL VALVE SET 4 1/2" DSSSV (OVERSIZED SANDWICH BOTH STACKS). HELD 5500# AND BLED TO ZERO (pkg stacks measure 40" center to center) SET 4 1/2" DSSSV (STANDARD PACKING) HELD 5500# AND BLED TO ZERO (pkg stacks measure 40" center to center) SET 4 -1/2" WRDP -2 (SER# HKS -42) Q 2,201'SLM/2,223'MD (2 - SETS OF PACKING, UPPER SET STD W/ O -RING, BOTTOM SET 1 PIECE OVERSIZE PKG ON EACH SIDE OF ORING) PERFORM CLOSURE TEST (GOOD TEST) T /1 /0= 1000/1400/20 Assist S -Line Brush and Flush (Post RWO) Pump 100 bbls 180* diesel down tbg. FWHP's= 1400/1400/300 S -line in control of well at LRS departure. 10/31/10 T /1 /0= 1150/1450/160 Temp =Sl Hot to POP (Assist Ops with POP) Pumped 5 bbls neat methanol spear and 117 bbls 180* crude down IA. Turned well over to DHD and DSO to POP. FW HP's= 1320/1080/740 T /1 /0= 1380/1160/150. Temp =Sl. Slip stream Meth into IA (Assist OP's w /POP). ALP =S1 @ casing valve. Pump 5 bbls Meth down IA to start, follow up w/1 bbl /hr (see log for details). Pumped a total of 8 bbls of Meth. Continued on 11 -01 -10 WSR 11/01/10 Continued from 10 -31 -10 WSR TIO= 650/1900/0. Temp =60. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr (see log for details). 11/03/10 T /l /O = 640/1400/2. Temp = 60 AL online. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr TIO= 560/1420/0 +. Temp =58 *. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr 11/04/10 ** *Continued from 11 -03 -10 WSR * ** T /I /O = 690/1410/90. Temp = 68 AL online. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr (see log for details). Pumping operations suspended at 6:00 am due to weather. Well is to be SI by ops. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. Page 8 of 8 'North - ALASKA. - BP ` Rage 1 of 1' ©peratian Summary Rep ©rt . Common Well Name: P1 -24 AFE No Event Type: MOBILIZATION (MOB) Start Date: 8/20/2010 End Date: X4- OOPQB -E (500,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/25/2010 20:00 - 00:00 4.00 MOB P PRE HELD UNANNOUNCED H2S DRILL. -HELD AAR FOR DRILL. -MOB RIG OFF OF P1 -07A AND OVER P -24. -RIG UP MODULES 8/26/2010 00:00 02:00 2.00 MOB P PRE 0 PSI ON IA AND OA -MOB RIG OVER WELL, SPOT AND SHIM RIG. ACCEPT RIG AT 0200 HRS. 02:00 - 03:30 1.50 RIGU P PRE'' R/U 2" LINE FROM OA TO CUTTINGS TANK. -RIG UP DOUBLE ANNULAR VALVE. -RIG UP CIRCULATION LINES. -HAVE LADDER REMOVED OFF OF WELL HOUSE NEXT TO BEAVALATOR. -TEST MASTER AND SWAB VALVES TOO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -BRING ON 9.0 PPG NACL BRINE AND WEIGHT UP TO 9.1 PPG. 03:30 07:30 4.00 RIGU P PRE PJSM FOR PULLING BPV. -DSM IS TO WITNESS TESTING OF MASTER AND SWAB VALVES PRIOR TO TESTING THEIR LUBRICATOR. - RETEST MASTER AND SWAB VALVE WITH DSM WITNESS TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -R /U DSM LUBRICATOR TO TREE AND TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. - CONTINUE TO WEIGHT UP 9.0 PPG BRINE TO 9.1 PPG BRINE. Printed 10/14/2010 3:01:20PM North America = AL ASkCA - BP ; Pa'Qf 2 .. Qpera #i ©n'Summary "Report z Vk Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) Printed 10/14/2010 3:02:59PM orth America ALASKA - BP � ,�Page`� of 23;, Operation Summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORI KELL BUS @43 .30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/26/2010 07:30 - 10:00 2.50 KILLW P DECOMP HOLD PJSM WITH RIG CREW, CH2MHILL DRIVERS, MI MUD ENGINEER, AND WSL TO DISCUSS WELL KILL CIRCULATION. DISCUSS THE FACT THAT THIS WELL RECENTLY TESTED AT 60 -PPM H2S. WSL POINTED OUT THAT THE CELLAR WINDWALLS NEED TO BE IN THEIR DOWN POSITION TO PREVENT MOISTURE ACCUMULATION FROM THE FOG DAMAGING OR POISONING THE H2S SENSORS IN THE CELLAR- -ONE BEHIND THE BOP AND ONE NEAR THE PITCHER NIPPLE. 0730 TO 0745 -Hrs, REVERSE CIRCULATE 31 -Bbls, 4 -BPM AT 1030 -psi, TO GET THE DIESEL OUT OF THE TUBING, TAKING RETURNS TO THE CUTTINGS TANK. - 0745 -Hrs; REALIGN CIRCULATING MANIFOLD VALVES AND CIRCULATE THE LONG WAY, LEADING WITH A 20 -Bbl SAFE- SURF -O SWEEP 4.25 -BPM AT 1030 -psi. - 0820 -Hrs, 4 -BPM AT 1380 -psi TO 1600 -psi FOR 130 -Bbls. - 0850 -Hrs, 4.25 -BPM, 1110 -psi AT 240 -Bbls PUMPED. RETURNS ARE SMELLY, BUT NOT STRONG. - 0905 -Hrs, 4.25 -BPM, 1120 -psi AT 270 -Bbls PUMPED GET A STRONG ODOR OF H2S AT SHAKERS, BUT NO ALARM. THE SMELL DISSIPATES IN 2 -3- MINUTES. PITWATCHER HAD A HAND -HELD GAS DETECTOR WITH A 10 FOOT SAMPLE LINE THAT HE LEFT IN THE BOTTOM OF THE TROUGH GOING TO THE DRAG CHAIN. IT MEASURED 170 -TO- 200 -PPM H2S FOR A FEW SECONDS, THEN QUICKLY DROPPED TO 0 -PPM. PITWATCHER WAS OUTSIDE THE SHAKER ROOM. - 0910 -Hrs, SENT 165 -Bbls OF RETURNS TO HYDROCARBON RECYCLE CONTAINING ABOUT 40% DIESEL. - 0930 -Hrs, CONDUCTED UNANNOUNCED H2S DRILL AND EVERYONE MET AT THE UPWIND MUSTER POINT WITHIN 2- MINUTES. WSL OBSERVED THE DRILLER SAFE -OUT THE WELL AND DON AN SCBA. DRILLER ALSO GRABBED THE HAND -HELD GAS DETECTOR. HELD AN AAR IN THE CREW TRAILER WITH EVERYONE ACCOUNTED FOR: THE RIG CREW, TOOLPUSHER, 3 CH2MHILL DRIVERS, MI MUD ENGINEER, 2 ADP STUDENTS, DOYON CASING CREWMAN, AND WSL. FINDINGS: THE SIGN -IN SHEET WAS DOWNWIND IN THE SPOC SHACK - -WE WILL NOW REQUIRE THAT ANYONE THAT NEEDS TO WORK ON THE RIG FOR ANY PERIOD OF TIME MUST SIGN INTO THE SPOC SHACK AND IN THE DRIVER'S CAB SIGN-IN SHEET. PERSONNEL NEWLY ASSIGNED TO ANOTHER POSITION MUST REVIEW THEIR NEW DRILL REQUIREMENTS. - 0950 -Hrs, RESUME CIRCULATING TO GET TO 9.1 -ppg - 1000 -Hrs, RETURNS ARE CLEAN 9.1 -ppg NaCl BRINE AFTER CIRCULATING 458 -Bbls. Printed 10/14/2010 3:02:59PM 22 Orth America -ALASKA - BP Page of 23 Operation Summary Report, Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 1 0148'35'01.251"W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 13:30 3.50 KILLW P DECOMP MONITOR WELL AT GAS BUSTER OUTLET AND DRIPS STOP AT 1040 -Hrs. - 1040 -Hrs, R/U TO TEST THE SWAB AND MASTER VALVES TO 3500 -psi, RECORDED ON CHART. SWAB VALVE IS A SOLID TEST. - 1100 -Hrs, TEST MASTER VALVE, BUT IT WON'T HOLD DESPITE THE EARLIER SUCCESSFUL TESTS. - 1130 -Hrs, CALL GREASE CREW TO GREASE THE MASTER VALVE. -1'300 -Hrs, GREASE CREW ARRIVED. GREASE MASTER VALVE AND RESUME TESTING THE MASTER VALVE FOR GOOD, CHARTED TEST. 13:30 15:30 2.00 WHSUR P DECOMP FMC TECH INSTALL TWC. R/U TO TEST TWC AND RECORD ON CHART. TESTED TO 1000 -psi FROM BELOW FOR A SOLID TEST. RETESTED 5 -TIMES FROM THE TOP TO 3500 -psi DUE TO EXCESS GREASE INSIDE THE VALVE CAVITY AFTER THE GREASE CREW INJECTION. - 1600 -Hrs, FMC TECH BLEED GAS OFF THE 2 -ea 1/4" CONTROL LINES. 15:30 18:00 2.50 WHSUR P DECOMP PJSM TO N/D TREE WITH RIG CREW, TOOLPUSHER, WSL, RWO /CTD SUPERINTENDENT, AND RWO /CTD TEAM LEADER FROM ANCHORAGE. - 1600 -Hrs, BREAK BOLTS ON ADAPTOR FLANGE AND TREE. - 1630 -Hrs, HOOK UP CHOKE AND KILL LINES. - 1700 -Hrs, WD TREE AND ADAPTOR FLANGE. 18:00 19:00 1.00 WHSUR P DECOMP TERMINATE CONTROL LINES. -CLEAN UP WELL HEAD. - -TEST FIT HANGER THREADS WITH XO. GOOD TEST AT 6 -1/2 TURNS. 19:00 - 22:00 3.00 BOPSUR P DECOMP BREAK 13 -5/8" X 13 -5/8" SPACER SPOOL OF STACK. - INSTALL 13 -5/8" X 11" SPACER SPOOL ON WELL HEAD. -N /U 4 PREVENTER BOP STACK. 3 -1/2" X 6" VBRS, BLIND SHEAR, MUD CROSS, AND 2 -7/8" X 5" VBRS. -CLEAN AND SERVICE RIG FLOOR. -R /U LINES AND EQUIPMENT TO TEST BOPE. -FILL STACK WITH WATER FOR TESTING BOPE. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM FOR TESTING BOPE. -TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. - PERFORM ALL TEST TO BP AND AOGCC STANDARDS. -ALL TESTS PERFORMED FOR 5 CHARTED MINS. -TEST WITH 4 -1/2" AND 3 -1/2" TEST JOINTS. -TEST WITNESSED BY BP WSL JOHN WILLOUGHBY AND DOYON TOUR PUSHER JERRY HANSEN. Printed 10/14/2010 3:02:59PM orth America ALASKA SP Page of 23 Operation Summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/27/2010 00:00 - 02:30 2.50 BOPSUR P DECOMP CONTINUE TESTING BOPE. -TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. - PERFORM ALL TEST TO BP AND AOGCC STANDARDS. -ALL TESTS PERFORMED FOR 5 CHARTED MINS. -TEST WITH 4 -1/2" AND 3 -1/2" TEST JOINTS. -TEST WITNESSED BY BP WSL JOHN WILLOUGHBY AND DOYON TOUR PUSHER JERRY HANSEN. 02:30 - 03:00 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. RD TEST EQUIPMENT. -B /D CHOKE AND KILL LINE. 03:00 - 03:30 0.50 PULL P DECOMP P/U DUTCH RISER. - RILDS. 03:30 - 06:00 2.50 PULL P DECOMP PJSM FOR PULLING TWC. -R/U DSM LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. -TEST AT HI PRESSURE FAILED WITH A GLAND LEAK IN THE LUBRICATOR. -0440 Hrs - DSM TIGHTENED LEAKING GLAND. RETEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. -GOOD TEST. -PULL TWC. LID LUBRICATOR, UD DUTCH RISER. - 0530 -Hrs, P/U LANDING JOINT AND XO AND RIH TO ENGAGE HANGER. FMC TECH BACKOUT ALL LDSs. PULL HANGER FREE WITH 140K -Ibs, CONTINUE PULLING AND THE 4 -1/2" TUBING STRING PULLS FREE WITH 155K -Ibs. P/U ANOTHER 5' AND PREPARE TO CIRCULATE WELLBORE. 06:00 07:30 1.50 PULL P DECOMP CIRCULATE AT 7- 1 /2 -BPM, 800 -psi, TAKING ALL RETURNS ACROSS THE SHAKERS. RETURNS ARE CLEAN AND REMAIN AT 9.1 -ppg. DO NOT SEE ANY DEBRIS OR OIL ACROSS THE SHAKERS DURING THE ENTIRE CIRCULATION OF 375 -Bbis PLUS 50 -Bbls. - 0715 -Hrs, STOP PUMPING TO MONITOR WELL FOR 15- MINUTES. WELL IS DEAD. I Printed 10/14/2010 3:02:59PM I ,, orth America - ALASKA - BP ?ag of 23 = Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active D atum: ORIG KEL BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 22:00 14.50 PULL P DECOMP PJSM WITH RIG CREW, TOOLPUSHER, FMC TECH, SCHLUMBERGER SPOOLER TECH, AND WSL TO DISCUSS HOW WE WOULD REMOVE THE 2 -ea 1/4" CONTROL LINES. DON'T TRY TO GRAB A FALLING CONTROL LINE AT ANY TIME. DROPPED OBJECTS - INCLUDE SMALL PARTS FROM THE TOP DRIVE WHICH WAS INSPECTED DURING THE BOPE TEST. PINCH POINTS ARE EVERYWHERE, ESPECIALLY AROUND THE SPOOLING CONTROL LINES AND THE SWINGING TUBING BEING UD ON THE PIPE SKATE. ALSO DISCUSSED THE FACT THAT THIS IS THE CREW'S LONG DAY, AND REMINDED THE DRILLER TO MAKE SURE THAT THE CREW TAKES APPROPRIATE SAFETY BREAKS. -FLUID ON- BOARD: 355 -Bbls IN THE PITS, 40 -Bbls IN THE PILL PITS, AND 30 -Bbls IN THE TRIP TANK FOR 425 -Bbls OF 9.1 -ppg NaCl BRINE. 0745-Hrs, BREAK OFF AND UD HANGER USING LIFTING CAP WITH CROSSOVER. 0800-Hrs, PUMP DRY JOB. R/U SCHLUMBERGER SPOOLER IN FRONT OF IRON ROUGHNECK. - 0830 -Hrs, CUT CONTROL LINES AND R/U TO SPOOLER DRUM. - 0900 -Hrs, START POH AND UD THE 4 -1/2 ", 12.6 #, 13Cr, NSCT TUBING. - 0940 -Hrs, JT #15 OF 280 - JOINTS PLUS A CUTOFF, 4 -GLMS, A BAL -0 SVLN,2- CONTROL LINES, AND 62 -ea SS CLAMPS. - 1005 -Hrs, UD JT #24. CONTROL LINES APPEAR TO HAVE PARTED DEEP. SCHLUMBERGER SPOOLER TAKING UP SLACK, SPOOLER CONTINUED TO SPOOL UP WHAT APPEARED TO BE ALL OF THE CONTROL LINE. - 1025 -Hrs, JT #30 UD. -SAW PARAFFIN ON JOINTS 110 THRU 125. -ALL JOINTS AFTER 125 PULLED CLEAN. - 2000 -Hrs, JT 270 UD. -DRAIN STACK AND FISH BANDS OUT OF STACK WITH HOOK ASSY. ON A ROPE. - RECOVERED 9 FULL BANDS AND 2 PARTIAL BANDS (MISSING BAND BUCKLES) FROM STACK. -TOTAL TUBING RECOVERED 280 FULL JOINTS PLUS 1 CUT JOINT AT 10.37' FLARED TO 4 -5/8 ". -TOTAL JEWELRY RECOVERED 1 BAL -0 SVLN, 4 GLMS, 49 STAINLESS STEEL BANDS. - MISSING 13 BANDS AND 2 BAND BUCKLES. -R /D POWER TONGS. -CLEAR AND CLEAN RIG FLOOR. Printed 10/14/2010 3:02:59PM O arth America - ALASKA - BP Page f�of�23 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/412010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY B USHING @43.30ft (a Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:26 - 07:30 PULL P DECOMP - 0610 -Hrs, CIRCULATE AT 7- 1 /2 -BPM, 800 -psi. ALL RETURNS ARE BACK TO THE PITS ACROSS THE SHAKERS, THEY STAY CLEAN AND AT 9.1 -ppg. DO NOT SEE ANY DEBRIS OR OIL ACROSS THE SHAKERS FOR A FULL CIRCULATION OF 375 -Bbls PLUS 50 -Bbls. 0715-Hrs, STOP PUMPING AND MONITOR WELL FOR 15- MINUTES. WELL IS DEAD. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM FOR PULLING PACK OFF WITH WSL, TOUR PUSHER, CREW AND FMC REP. - DISCUSS SAFETY HAZARDS, DROPPED OBJECTS- SUCH AS DROPPING PACK OFF FROM J -HOOK, WELL CONTROL - MONITORING WELL ONCE PACK OFF IS FREE. ENSURE OA PRESSURE IS 0. -PICK UP PACK OFF RETRIEVING TOOL AND RIH 25', J- INTO PACK OFF. - BOLDS. -PULL PACK OFF. TAKING 15K TO PULL FREE. - MONITOR WELL - STATIC -UD OLD PACK OFF. -R /U AND RIH WITH NEW 7" STANDARDIZED PACK OFF. -SET PACK OFF 25' IN APPLYING 1 OK TO SEAT PACK OFF. 8/28/2010 00:00 - 01:00 1.00 WHSUR P DECOMP PRESSURE TEST PACK OFF TO 80% COLLAPSE PSI. 4200 PSI FOR 30 CHARTED MIN. GOOD TEST. -R /D TEST EQUIPMENT. 01:00 - 01:30 0.50 WHSUR P DECOMP INSTALL WEAR RING. 01:30 - 02:30 1.00 CLEAN P DECOMP PJSM FOR M/U BHA AS FOLLOWS: -6" OD X 4- 9/16" ID DRESS OFF SHOE, 4 -3/4" X 3 -7/8" INNER MILL 2.23, EXTENSIONS, BOOT BASKET, SUB, 7" CSG SCRAPER, BIT SUB, BUMPER SUB, PO SUB, MAGNETS, X0, AND 6 EA 4 -3/4" DC. 02:30 14:30 12.00 CLEAN P DECOMP RIH P/U DRILL PIPE FROM PIPE SHED. - 0600 -Hrs, P/U DRILLPIPE JOINT #107. - 0845 -Hrs, P/U JT #156 FOR 5203' OF DRILLPIPE RIH. - 0930 -Hrs, P/U JT #210 FOR 6877' OF DRILLPIPE RIH. - 1115 -Hrs, P/U JT #270, 8737' OF DP IN HOLE. - 1415 -Hrs, P/U JT #320, 10,287' OF DP IN HOLE. RECIPROCATE SCRAPER 4 -TIMES IN 7" CASING FROM 11,127' TO 11,287'. Printed 10/14/2010 3:02:59PM orth America - ALASKA- Page 7t 23 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/412010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @ (above Mean S ea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 16:00 1.50 FISH P DECOMP 1430 -Hrs, P/U JT #350 AND GET SLOW PUMP PARAMETERS: #1 - -32 -SPM AT 180 -psi, 39 -SPM AT 340 -psi; #2 - -30 -SPM AT 150 -psi, 40 -SPM AT 470 -psi. TEST LINES FROM PUMP #2 TO 3500 -psi. - 1445 -Hrs, GET PARAMETERS FOR DRESS -OFF RUN: 5 -BPM AT 720 -psi, 60 -RPM ROT WT OF 170K -Ibs AND FREE TORQUE OF 7K- FT -LBS. -1455 -Hrs, STOP ROTATING AND REDUCE PUMP TO 3 -BPM AT 240 -psi. SLOWLY RIH AND TAG STUB AT 9' IN ON #350, PLACING THE STUB AT 11,361'. P/U AND RIH TO VERIFY ONE MORE TIME. - 1500 -Hrs, P/U START ROTATING AND BRING UP TO 60 -RPM, 7K -ft -Ibs TORQUE, AND LEAVE PUMP ON AT 3 -BPM AT 240 -psi. SLOWLY LOWER OVER STUB AND TORQUE STOPS ROTATION. INCREASE PUMP RATE TO5 -BPM AND 710 - 720 -psi. KICK OUT 20 -Bbl FLOZAN SWEEP. REPEAT P/U AND RIH OVER THE STUB AND BRING TORQUE LIMIT UP TO START MILLING JUNK AROUND THE STUB. CAN SEE TORQUE VARIATIONS AS THE SHOE CONTINUES OVER THE STUB. PRESSURE INCREASES TO 740 -psi AT 5 -BPM. - 1525 -Hrs, CONTINUE MILLING AFTER INSIDE DRESS -OFF MILL CONTACTS THE STUB, BUT MILL OFF —4 -5 ", THEN STOP ROTATING AND P/U OFF STUB SLIGHTLY TO SEE THE PRESSURE DROP OFF TO 690 -psi. EASE DOWN OVER STUB TO STACK OUT ON IT AT 11,361' PLUS A FEW INCHES. - 1530 -Hrs, P/U ABOVE STUB TO VERIFY THAT WE CAN GET BACK OVER IT. SLOWLY RIH AND STACK OUT 1 -2K -Ibs. P/U AND START ROTATING 20 -RPM, PUMP 5 -BPM AT 660 -psi, RIH AND SEE THE STUB BUT SHOE SLIPS OVER. STOP ROTATING AND CONTINUE RIH. START ROTATING TO 60 -RPM WITH 5 -BPM AT 660 -psi AND CONTINUE IN TO PUT THE DRESS -OFF MILL BACK ON THE STUB TO POLISH IT FOR 1 -2 ". P/U AND STOP ROTATING. 16:00 17:00 1.00 FISH P DECOMP 1600 -Hrs, PUMP 20 -Bbl FLOZAN SWEEP, 8 -BPM AT 880 -psi. SEE ONLY PARAFFIN BALLS WITH METAL SHAVINGS ACROSS THE SCREENS WHEN THE SWEEP COMES ACROSS. MIX AND PUMP DRY JOB. FLUID ON HAND 425 -Bbls OF 9. 1 -ppg NaCl. 17:00 - 20:30 3.50 FISH P DECOMP POH AND S/B DP AND DCs IN DERRICK. -POH FROM 11,361' TO 4,248'. Printed 10/14/2010 3:02:59PM orth America - ALASKA - BR Page "3 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/412010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Se L evel) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 21:30 1.00 FISH P DECOMP HELD UNANNOUNCED H2S DRILL WITH TOUR PUSHER, WSL, RIG CREW, BAKER FISHING REP, AND CH2MHILL TRUCK DRIVER. -CREW RESPONDED IN 2 MIN. THE WELL WAS SECURED. -HELD AAR. THE RESPONSE TIME WAS — APPROPRIATE, AND ALL HANDS DID A REALLY GOOD JOB. -THE NEED FOR IMPROVEMENT WAS THE WSL FORGOT TO MENTION TO THE NIGHT TRUCK DRIVER TO SIGN INTO THE 1 A DOOR ON THE RIG AND HE SIGNED INTO THE SPOC SHACK. THIS WAS ADDRESSED AND WILL BE BROUGHT UP TO THE TRUCKING PJSM FOR THIS LOCATION AS SPOC SHACK IS ALWAYS DOWN WIND. ALSO ADDRESSED WAS THE NEED FOR A HARMONY IN THE CHANGE OUT OR SAFE AREA OF THE RIG AS THERE IS ONE IN THE SPOC SHACK ON THE OPPOSITE SIDE. THERE WHERE ALSO 2 SIGN IN SHEETS IN THE DOOR 1 A, CAUSING CONFUSION AND ONE WAS ELIMINATED. WE DISCUSSED THE DONNING OF THE SCOTT AIR PACKS, THE NEW HAND ON THE RIG WAS TAKEN IN TOW BY AN EXPERIENCED FLOOR HAND - GREAT JOB. WE ALSO DISCUSSED THE FACT OF WHAT IF WE HAD NON SHEARABLE TOOLS ACROSS THE STACK. 21:30 - 00:00 2.50 FISH- P DECOMP POH AND S/B DP AND DC IN DERRICK. -POH FROM 4,248' TO 235'. - MONITOR WELL - STATIC. 8/29/2010 00:00 - 01:00 1.00 FISH P DECOMP L/D 7" CSG SCRAPER DRESS OFF BHA. - MARKINGS ON THE MILL SHOWED GOOD INDICATIONS OF MILLING TUBING. - RECOVERED 3 FULL SS BANDS AND 2 BAND CLAMPS. - MAGNETS RECOVERED 1/2 GAL. OF METAL SHAVINGS. 01:00 - 03:00 2.00 FISH P DECOMP PJSM FOR WU JUNK CATCHER BHA: -BULL NOSE, ITCO SPEAR, SPEAR EXTENSION, STOP SUB, XO, SHEAR PIN GUIDE, FOX TUBING, XO, BUMPER SUB, PUMP OUT SUB, DC, XO. -RIH WITH BHA TO 277.01'. 03:00 - 06:30 3.50 FISH P DECOMP RIH W/ DP FROM DERRICK. -RIH FROM 227' TO 11,262' AND STOP TO SLIP AND CUT DRILLING LINE. 06:30 - 07:30 1.00 FISH P DECOMP SLIP AND CUT DRILLING LINE. Printed 10/14/2010 3:02:59PM Page! America - ALASKA - BP 9 of 23 0 eratim gmmary Report Common Well Name: P1 -24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:00 1.50 FISH P DECOMP RESUME RIH TO 11,358' AND GET PARAMETERS: P/U WT 205K -Ibs, S/0 WT 150K -Ibs; SLOW PUMP RATES FOR PUMP #1: 3 -BPM AT 590 -psi, 4.5 -BPM AT 1800 -psi. REDUCE RATE TO 3.5 -BPM @ 790 -psi. RIH AND SEE TAG AT 11,361', CONTINUE RIH AND SET 20K -Ibs DOWN TO SHEAR PINS IN SHEAR PIN GUIDE, BUT NO ACTION. P/U AND SLOWLY RIH FOR SAME TAG DEPTH. -P /U ABOVE STUB AND START ROTATING AT 15 -RPM AND RIH AND SLIP DOWN INSIDE THE STUB WITH THE JUNK CATCHER BHA BULLNOSE. STOP ROTATING AND CONTINUE RIH TO SHEAR THE PINS. - 0800 -Hrs, INCREASE PUMP RATE TO 5 -BPM AT 1820 -psi TO CLEAN OFF THE TOP OF THE JUNK CATCHER. STOP PUMPING. CONTINUE RIH AND GET INSIDE THE JUNK CATCHER AT 11,392'. SET DOWN 6K -Ibs WITH BOTTOM OF BULLNOSE AT 11,396'. - 0810 -Hrs, P/U TO 20K -Ibs OVER. SET DOWN TO NEUTRAL AND P/U TO 20K -Ibs OVER. SET DOWN TO NEUTRAL, START PUMP AND BRING UP TO 1.5 -BPM AT 310 -psi AND LOSE THE 20K -Ibs DRAG WHILE P /U. - 0815 -Hrs, BREAK -OFF TOPDRIVE AND S/B STAND IN DERRICK. PULL NEXT STAND WITH ELEVATORS AND SEE SAME 20K -Ibs OVERPULL. M/U TO TOPDRIVE AND BRING ON PUMP TO 1.8 -BPM AT 310 -psi AND OVERPULL DISAPPEARS. BREAK -OFF TOPDRIVE AND S/B STAND IN DERRICK. - 0820 -Hrs, DROP BALUROD TO OPEN THE PUMP -OUT SUB. - 0850 -Hrs, BALL ON SEAT AND PUMP -OUT SUB OPENS WITH 1500 -psi. 09:00 09:30 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP 8.5 -BPM AT i 1440 -psi. 09:30 - 14:00 4.50 FISH P DECOMP POH AND S/B DP AND DCs IN DERRICK. - 1330 -Hrs, S/B DCs IN DERRICK. 14:00 - 15:00 1.00 FISH P DECOMP - 1400 -Hrs, B/O AND UD PUMP -OUT SUB AND BUMPER SUB. B/O FIRST JOINT OF 2 -7/8" FOX TUBING. - 1420 -Hrs, B/O AND UD JUNK CATCHER. HAD THE REMAINS OF THE BOTTOM PLUG FROM THE JET CUTTER INSIDE AS WELL AS TWO PIECES OF SS- BANDS. B/O AND UD WASHPIPE EXTENSIONS AND FIND 8- PIECES OF SS BANDS WRAPPED INSIDE NEAR THE SHEAR PIN GUIDE. 15:00 - 16:30 1.50 FISH P DECOMP M/U WRP RETRIEVAL TOOL BHA: WRP RETRIEVAL TOOL, XO, SHEAR PIN GUIDE ASSY, 2 -7/8" FOX TUBING, XO, BUMPER SUB, PUMP OUT SUB, DC, AND XO. -RIH TO 304.09' Printed 10/14/2010 3:02 :59PM oith America - ALASKA - BP _ Page 10 23 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: _ 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 22:30 6.00 FISH P DECOMP RIH WITH DP FROM DERRICK. -RIH FROM 304' TO 11,385'. - OBTAIN PARAMETERS OF UP WT 204K, DOWN WT OF 152K -WITH PUMPS OFF. UP WT OF 200K, DOWN WT OF 152K WITH PUMPS ON AT 3.3 BPM AND 260 PSI. OBTAIN SLOW PUMP RATES OF: PUMP #1 - 30 SPM/ 160 PSI, 40 SPM/ 260 PSI, PUMP #2 - 30 SPM/ 230 PSI, 40 SPM/ 410 PSI RIH TO TOP OF STUB AT 11,361'. SHEAR THE SHEAR OUT SUB AT 1 OK. -R /U AND OBTAIN REVERSE CIRCULATING PARAMETERS OF 5 BPM AND 750 PSI. 22:30 - 00:00 1.50 FISH P DECOMP PJSM WITH RIG CREW, WSL, TOUR PUSHER, AND BAKER FISHING HAND. -RIH AND TAG TOP OF SAND AT 11390'. CLOSE BAG AND BEGIN WASHING DOWN TO 11,398'. CIRCULATE A B/U WITH DP VOLUME (150 BBLS): -RATE OF 5 BPM AND 770 PSI. - SHAKERS HAD GOOD SLUGGITS ON B /U. Printed 10/14/2010 3:02:59PM orth America -,-ALASKA - BP Page i 1 of 23 Operation Summary 'Repoft Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/30/2010 00:00 03:30 3.50 FISH P DECOMP R/U TO CIRCULATE THE LONG WAY. -BRING PUMPS UP TO 9 BPM AND 1980 PSI. -WASH DOWN TO 11404' AND TAKE 8K OF WEIGHT. - MONITOR WELL - WELL STATIC. -P /U AND SEEN NO WT INCREASE. P/U TO 11385' - ATTEMPT TO RIH PAST 11404' TO SEE IF WE HAD PLUG AND COULD NOT GET ANY DEEPER THEN 11,400' STACKING 5K WEIGHT. -P /U AND ATTEMPT AGAIN. AT 11,400' STACKED 1 OK WEIGHT. -NO LOSSES AND STATIC WELL. CLOSE RAMS AND ATTEMPT TO BULL HEAD TO ENSURE WE HAD THE PLUG. NOT SUCCESSFUL PRESSURED UP TO 580 PSI. SHUT PUMPS DOWN AND PRESSURE HELD. BLEED OFF PRESSURE. -BEGIN WASHING DOWN CIRCULATING AT 3.5 BPM AND 300 PSI. ROTATE PAST 11,400' AND DOWN TO 11,411'. STACK 5K WEIGHT ON PLUG. ANNULAR VOLUME DROPPED ABOUT 2 BBLS. -P /U TO NEXT TOOL JOINT AT 11,370'.CLOSE THE PIPE RAMS AND BULL HEAD 4 BBLS AWAY AT 80 PSI. WITH GOOD CONFIRMATION WE HAD THE PLUG. WE OPENED UP THE RAMS TO PULL ABOVE THE TUBING STUB AT 11,361'. WHEN WE PULLED AN EXTRA 25K OVERPULL. WORKED NUMEROUS TIMES UP TO 75K OVERPULL AND DOWN TO 10K OVER AND ATTEMPTED WITH PUMPS ON AT 1 BPM AT 590 PSI DOWN THE DP. THE ANNULAR WAS STATIC. CONFIRMED WITH WEATHERFORD THE MAX PULL ON THE PLUG WAS 85K SO WE WORKED PIPE DOWN (SLAPPING THE BUMPER SUB) TO 25K OVER 2 TIMES WHEN WE BECAME FREE. -A TOTAL OF 42 BBLS WAS BULLHEADED WHILE WORKING PIPE. PRESSURE INCREASED FROM 280 PSI TO 590 PSI AT 1 BPM. -P /U TO 11,320' ABOVE THE STUMP. - MONITOR WELL - WELL GAVE BACK 1 BBL OF FLUID. THEN WENT STATIC. -CLOSE RAMS AND BULL HEAD 5 BBLS AT 3 BPM AND 400 PSI AND WHEN PUMPS WHERE TURNED OFF THE PRESSURE BLEED DOWN TO 210 PSI PRIOR TO OPENING THE BLEEDER. A TOTAL OF 47 BBLS WAS BULL HEADED AWAY. - MONITOR WELL - STATIC. -DROP BALL TO OPEN PUMP OUT SUB. Printed 10/14/2010 3:02:59PM Orth Nmeric6 - ALASKA - BP Fage 12 of 23' Operation SurnmaryReport Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/2112010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °3601.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:30 1.00 FISH P DECOMP BREAK CIRCULATION TO CIRCULATE B /U. TAKING 3 BBLS TO FILL HOLE. - CIRCULATE AT 8 BPM WITH 1200 PSI. DYNAMIC LOSS RATE OF 30 BPH. -0345 Hrs - SAW FLOW INCREASE TO 53% WITH A GAINOF 17 BBLS WITHIN 2 MIN. SOME FLUID FROM BUBBLES BURSTING ON TOP OF THE FLUID SURFACE AT THE FLOWLINE SPILLOVER POINT WAS SPLASHED UP ONTO THE ROTARY TABLE, WETTING DOWN THE ROTARY BUSHINGS AND A SMALL AREA IN FRONT OF THE IRON ROUGHNECK. THERE WAS AN OILY SHEEN ON THE WET AREAS, CLOSED THE UPPER PIPE RAMS. -SHUT IN PRESSURE ON DP - 40 PSI, CSG - 120 PSI. NOTIFICATIONS MADE TO DRILLING SUPERINTENDENT AND TO DAY WSL. -0425 SHUT IN PRESSURES OF 40 PSI DP AND 260 PSI CSG. 04:30 - 06:30 2.00 FISH P DECOMP PJSM - LINE UP AND CIRCULATE THROUGH CHOKE. -BRING PUMPS ONLINE UP TO 4 BPM/ 380 PSI SLOWLY AND OPEN CHOKE SEEING FLUID RETURNS IN 5 BBLS AT 8.7 PPG. - RETURNS ARE WATER AND CRUDE, TURNING TO CRUDE, THEN WATER 55 BBLS INTO THE CIRCULATION. - 0530 -Hrs, CONTINUE CIRCULATING AND AT 210 -Bbls SEE CRUDE OIL COMING OVER THE SHAKERS WITH 50 -psi CASING PRESSURE AND 440 -psi DRILLPIPE PRESSURE. RETURNS CHANGE TO BRINE WITHIN 8- 10 -Bbls AND WEIGHT OF RETURNING BRINE IS 9.17 -ppg. - 0615 -Hrs, CALL RWO SUPT AND RWO ENGINEER TO KEEP THEM IN THE LOOP ON THE CIRCULATION. GET TO BOTTOMS -UP VOLUME OF 255 -Bbls AND ANOTHER SLUG OF CRUDE OIL COMES ACROSS THE SHAKERS. THE FLUID CLEANS UP TO BRINE IN 5- 6 -Bbls. PUMP A TOTAL OF 350 -Bbls. STOP PUMPING WITH 0 -psi CASING AND 40 -psi DRILLPIPE. BLEED OFF THE DRILLPIPE AND CHECK FOR FLOW AT THE GAS BUSTER OUTLET TO THE POSSUM BELLY. 0630 -Hrs, WELL IS DEAD. Printed 10/14/2010 3:02:59PM orth,America - ALASKA' BP Page 13 6f °23 Operation Summary Report Common Well Name: PI-24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/212008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: O RIG KELLY BUS HING @43.30 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 09:30 3.00 FISH P DECOMP CALL RWO LEAD ENGINEER TO DISCUSS PLAN FORWARD FOR THE WELL KILL. ADVISED TO GO AHEAD AND CIRCULATE THROUGH THE CHOKE AND WAIT ON ORDERS FROM TOWN. - 0645 -Hrs, START PUMPING AT 4 -BPM AND 400 -PSI. CHECK LOSS RATE AND CALCULATE 12 -BPH DURING FIRST 20 -Bbls. PUMPING UNDER CLOSED 3 -1/2" X 6" VBRs. - 0715 -Hrs, FLUID ON BOARD: 335 -Bbls OF 9.1 -ppg NaCl BRINE IN PITS AND A FULL VAC TRUCK OF 290 -Bbls 9.1 -ppg NaCl BRINE ONSITE, WITH ANOTHER FULL LOAD OF 9.2 -ppg (TO BE CUT BACK CONTINGENT ON SI WELL PRESSURES) ON THE WAY. -DO NOT SEE ANY OIL OR DEBRIS ACROSS THE SHAKERS FOR A CIRCULATION OF 293 -Bbls. CALCULATE A DYNAMIC LOSS OF 15.5 -BPH WHILE PUMPING AT 4 -BPM AND 400 -Psi. - 0830 -Hrs, STOP PUMPING WITH 0 -psi CASING AND DRILLPIPE PRESSURE BLEEDING OFF TO 40 -psi ALMOST INSTANTANEOUSLY, OPEN BLEEDER AND BLEED OFF DP TO 0 -psi AND MAKE A FLOW CHECK AT THE SHAKERS. OPEN 3 -1/2" X 6" VBRs. FLUID LEVEL IS BELOW THE OPENED VBRs. FILL THE STACK TO THE FLOWLINE SPILLOVER AND PREPARE TO MONITOR THE WELL. - 0850 -Hrs, MONITOR WELL FOR 30- MINUTES AND THE FLUID LEVEL SLOWLY DROPS. - 0920 -Hrs, FILL STACK FROM TRIP TANK AND IT TAKES 6.2 -Bbls FOR A CALCULATED STATIC LOSS RATE OF 12.4 -BPH. Printed 10/14/2010 3:02:59PM orth America - ALASKA - BP Page 14 of�23 0 eration Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/2112010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point Mc Intyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 812/2008 12:00:OOAM Rig Release: 914/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148'35'01.251"W Active Datum: ORIG KELLY BUSHING @43.3 (above Mean S ea Lev el) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 16:00 6.50 FISH P DECOMP PJSM TO DISCUSS POH AND UD DP, DCs, AND THE WRP RETRIEVAL BHA. ALSO HOLD AAR ON THE WELL KILL AND DISCUSS THE MINIMUM REQUIREMENTS FOR BULLHEADING AFTER REMOVING A BARRIER FROM ABOVE AN OPEN WELLBORE: 1.5 TIMES THE TAILPIPE VOLUME AT A RATE OF 1 -BPM PER INCH OF TAILPIPE DIAMETER. - 0935 -Hrs, CALLED RWO SUPT AND RWO ENGINEERING TEAM LEAD AND RECEIVE APPROVAL TO POH AND UD THE DP STRING. - 1130 -Hrs, CALL AOGCC TO NOTIFY THEM OF IMPENDING TEST FOR THE BOP COMPONENTS ACTUATED FOR THE WELL SHUT -IN. BOB NOBLE, AOGCC NORTH SLOPE INSPECTOR IMMEDIATELY RETURNED THE CALL AND WAIVED AOGCC'S RIGHT TO WITNESS THE TESTS. - 1345 -Hrs, UD DP JT # 75. CALCULATED LOSS RATE OF 9 -BPH. - 1420 -Hrs, UD JT #90; CALCULATED LOSS RATE IS 7.4 -BPH. STOP RIH TO MONITOR WELL FLUID LEVEL AND THE FLUID LEVEL IS SLOWLY DROPPING. 1425 -Hrs, CALL RWO ENGINEER TO INFORM HIM OF THE DECREASE IN THE CALCULATED LOSS RATE. PITWATCHER REPORTS THAT FLUID IN ALL PITS IS 9.1 -ppg HEAVY. - 1455 -Hrs, FILL THE STACK AFTER MONITORING FOR 30- MINUTES AND IT TAKES 3 -Bbls TO FILL FOR A 6 -BPH LOSS RATE. CALLED RWO ENGINEER AND AGREE TO WEIGHT ALL FLUID IN PITS TO 9.2 -ppg WHILE USING CONSTANT HOLE FILL BEFORE RESUMING POH WITH THE DP. 16:00 17:30 1.50 FISH P DECOMP WAIT ON ADDITIONAL SALT TO WEIGHT UP PITS TO 9.2-pp g. 17:30 18:30 1.00 FISH P DECOMP BUILD 9.2 -ppg NaCl BRINE IN ALL PITS FROM THE 9.1 -ppg IN THE PITS. 18:30 00:00 5.50 FISH P DECOMP CONTINUE TO POH UD DP. - MAINTAIN CONSTANT HOLE FILL WITH 9.2 PPG NACL BRINE. - MONITOR WELL EVERY 30 JTS OF DP UD. -21:00 Hrs - LOSS RATE OF 6.0 BPH. -21:30 Hrs - LOSS RATE DECREASED TO 5.4 BPH. STOP AND MONITOR WELL. ATTAIN ANOTHER LOSS RATE 5.6 BPH. - CONTINUE POH UD DP TO 5843'. - MAINTAIN CONTINOUS HOLE FILL AT 5.4 BPH LOSS RATE. 8/3112010 00:00 06:00 6.00 FISH P DECOMP POH UD DP FROM 5,843' TO 303'. - MAINTAIN CONTINOUS HOLE FILL. i - MONITOR WELL FOR 10 MINS EVERY 30 JTS OF PIPE PULLED. -0100 Hrs - 3.5 BPH LOSS RATE. -0230 Hrs - 6.4 BPH LOSS RATE. -0300 Hrs - 2.8 BPH LOSS RATE. -0330 Hrs - 9.3 BPH LOSS RATE. -0430 Hrs - UD JT 313 - 4.1 BPH LOSS RATE. 0500 Hrs -4.6 BPH LOSS RATE. Printed 10/14/2010 3:02:59PM crth America - ALASKA - BP Page 1 P 2 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BU SHIN G @43.3 (above Me Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 07:30 1.50 FISH P DECOMP B/O AND UD BHA. - 0630 -Hrs, UD FIRST JT OF 2 -7/8 ". B/O AND UD THE WRP. IT SHOWED NO SIGNS OF DAMAGE. - MIDNIGHT TO 0630 -Hrs TOTAL FLUID LOSS WAS 85.7 -Bbls FOR A 14 -BPH LOSS RATE. FLUID ONSITE: 278 -BBLS, VAC TRUCK WITH 160 -Bbls OF 9.2 -ppg NaCl BRINE, AND VAC TRUCK WITH 290 -Bbls OF 9. 1 -ppg NaCl BRINE. 07:30 - 12:00 4.50 BOPSUR P DECOMP R/U TO TEST THE BOP EQUIPMENT USED IN THE WELL S/I EVENT 8 -30 -2010. 0830Hrs, HOLD PJSM FOR NON - ROUTINE WORK SUCH AS TESTING THE BOP AGAINST A TEST PLUG FOR A PARTIAL TEST OF THE ENTIRE BOP SYSTEM. -TEST THE 3 -1/2" X 4 -1/2" VBRS USING THE 3 -1/2" AND 4-1/2" TEST JTS, BOTH CHOKE AND KILL HCRs AND THE HYDRIL PREVENTER'WITH 3 -1/2" TEST JT. (USED THE ANNULAR IT TO STRIP THROUGH WHILE CLEANING THE SLUGGITS OFF OF THE WRP) -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. -AOGCC REP BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS TEST ON 8 -3 -10 AT 1100 -H RS. - 1100 -Hrs, THE HYDRIL PREVENTER FAILED THE TEST. CALL RWO ENGINEER AND CONFIRM THAT WE CAN USE THE NEW HANGER WITH A TWC TO INSTALL IN THE TUBING HEAD AND SET IT UP AS A BARRIER FOR THE WD OF THE HYDRIL. A ROLLING TEST UNDER THE HANGER WILL HAVE TO BE PERFORMED TO 1000 -psi, AND A 3500 -psi TEST BETWEEN THE BLINDS AND THE HANGER WHILE PUMPING DOWN THE KILL LINE. 12:00 - 12:30 0.50 BOPSUR N DECOMP L/D TEST JOINT AND TEST PLUG. -FILL HOLE TAKING 13 BBLS. -LOSS RATE OF 14.0 BPH. - MAINTAIN CONSTANT HOLE FILL. 12:30 - 14:30 2.00 BOPSUR N DECOMP PJSM FOR SETTING HANGER WITH TWC. -P /U AND R/U HANGER WITH TWC INSTALLED. -SET HANGER AND RILDS. -13:42 Hrs - TEST TWC TO 3500 PSI FROM ABOVE. GOOD - 1000 PSI ROLLING TEST FROM BELOW AT 1.7 BPM TO MAINTAIN 1000 PSI. TOOK 10 BBLS TO FILL HOLE AND 40 BBLS TO SEAT TWC BALL. HOLD 1000 PSI FOR 10 MIN ONCE BALL WAS SET. 64 BBLS TOTAL VOLUME PUMPED AWAY FOR TEST. -14:00 Hrs - SEND OVERSHOT FOR COMPLETION TO BAKER MACHINE TO HAVE TURNED DOWN FROM 5.93" OD TO 5.80" OD. -SUCK DOWN STACK. - MAINTAIN CONSTANT HOLE FILL. Printed 10/14/2010 3:02:59PM o6 America - AL SKA - BP Page 1623 Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Acti Dat ORI KE LLY BU SHING @43.30ft (above Mea Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 21:30 7.00 BOPSUR N DECOMP PJSM FOR CHANGING OUT ANNULAR PREVENTER. - BARRIERS ARE 1)TESTED TWC AND TUBING HANGER AND 2) TESTED BLIND RAMS. - CHANGE OUT ANNULAR PREVENTER. - MAINTAIN CONSTANT HOLE FILL. 21:30 - 22:30 1.00 BOPSUR P DECOMP R/U AND TEST BAG WITH 3 -1/2" TEST JOINT. -TEST BAG TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. R/D TEST EQUIPMENT - MAINTAIN CONSTANT HOLE FILL AT 6.6 BPH LOSS RATE 19:45 Hrs'- AOGCC WAS NOTIFIED OF UPCOMING ANNULAR PREVENTER TEST. JOHN CRISP WAIVED WITNESS. 22:30 - 00:00 1.50 BOPSUR P DECOMP CHECK FOR PRESSURE UNDER THE HANGER NONE. -BOLDS AND PULL HANGER TO FLOOR, INSPECT HANGER - GOOD. - MAINTAIN CONTINOUS HOLE FILL AT 6.6 BPH LOSS RATE. 9/1/2010 00:00 - 02:00 2.00 RUNCOM P RUNCMP FINISH L/D HANGER. -PJSM R/U TO RUN 3 -1/2" 9.2# 13cR VAM TOP COMPLETION. -P /U AND R/U HANDLING EQUIPMENT. -MAKE UP FLOOR VALVE. - MAINTAIN CONTINUOUS HOLE FILL AT 7 BPH LOSS RATE. 02:00 16:00 14.00 RUNCOM P RUNCMP PJSM WITH WSL, TOUR PUSHER, HALIBURTON HANDS, DOYON CSG, AND RIG CREW ON RUNNING COMPLETION. DISCUSS DROPPED OBJECTS - CALIPER ELEVATORS, DISCUSSED PINCH POINTS, PIPE SHED SAFETY, DISCUSSED WELL CONTROL, ENSURE PIT WATCHER DOES NOTHING BUT FLUID MANAGEMENT, CHECK FOR FLOW EVERY 2000' RIH, MAINTAIN CONTINUOUS HOLE FILL. -P /U OVERSHOT ASSY AND RIH AT 0245 HRS. -RIH WITH XN ASSY, JOINT A, X -NIP ASSY, TNT PACKER ASSY, X -NIP ASSY, JOINT #1. -0315 HRS RIH WITH GLM #1. -0330 HRS MAINTAIN CONTINUOUS HOLE FILL AT 7 BPH LOSS RATE. -0400 HRS 15 JOINTS RIH. - 0950 -HRS - 150 -JTS RIH. PU WT = 80K -LBS, SO WT - 8OK -LBS. MONITOR WELL - FLUID LEVEL DROPPING SLOWLY. - CONTINUE RIH WITH 3 -1/2" 9.2# 13CR80 TUBING to 9117'. LOSS RATE = —5 -BPH. -PU WT = 104K -LBS, SO WT = 95K -LBS. 16:00 - 17:00 1.00 RUNCOM P RUNCMP MONITOR WELL- FLUID LEVEL DROPPING. - CHANGE OUT ELEVATORS TO HANDLE 4 -1/2" TUBING. -PU 4 -1/2" 12.6# 13CR80 VAM TOP X 3 -1/2" 9.2# 13CR80 VAM TOP XO ASSEMBLY AND MU. Printed 10/14/2010 3:02:59PM orth America - ALASKA - BP Page It ,f'23 Operation Summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 17:30 0.50 RUNCOM P RUNCMP HOLD PJSM ON RIGGING UP CONTROL LINE SPOOLING UNITS WITH HES AND RIG CREW. DISCUSS DROPPED OBJECT POTENTIALS, SPOOLER AND SHEAVE PLACEMENT AND POSITIONS OF PEOPLE. -RU HES CONTROL LINE SPOOLING UNITS. - MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF —5 -BPH. 117:30 - 22:30 5.00 RUNCOM P RUNCMP CIRCULATE A TUBING VOLUME AT 1.7 -BPM WITH 100 -PSI. LOSS RATE = 6.6 -BPH. - ATTEMPT TO RD CIRCULATING EQUIPMENT AND WELL IS OUT OF BALANCE. -RE- ESTABLISH CIRCULATION AT 2.4 -BPM WITH 150 -PSI AND PERFORM A FULL WELLBORE CIRCULATION PLUS LOSS RATE. LOSS RATE OF 6.5 BPH. - CIRCULATE A TOTAL OF 350 BBLS AND HAVE 9.2 PPG IN AND OUT. MONITOR WELL - ON A VAC. 22:30 - 00:00 1.50 RUNCOM P RUNCMP P/U SSSV. - DRIFTED SSSV WITH BALL AND ROD. GOOD. -M /U AND RIG UP TEST EQUIPMENT TO TEST SSSV. MAINTAIN CONTINUOUS HOLE FILL AT 6.2 BPH LOSS RATE. 9/2/2010 00:00 - 03:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH 4 -1/2" 12.6# 13Cr VAM TOP TUBING FROM 9,133'. - MAINTAIN CONTINUOUS HOLE FILL AT 6.4 BPH LOSS RATE. -0300 Hrs. RIH WITH JT # 54 P/U WEIGHT OF 125K, S/O WEIGHT OF 11 OK. -0300 Hrs LOSS RATE OF 7.1 BPH. 03:00 - 04:30 1.50 RUNCOM P RUNCMP SPACE OUT. -P /U JOINT # 55 RIH WITH NO WEIGHT DIFFERENCE. -P /U JOINT #56 RIH WITH NO WEIGHT DIFFERENCE. -THE FIRST INDICATION WAS ON JT 57 AT 2' IN SHOWING 4K. RIH 5' IN ON JOINT 57 AND STACK 25K. - ROTATE PIPE 1 TURN AND WORK TORQUE DOWN. RIH AND STACK 25K DOWN 5' IN ON JT 57. -WORK TORQUE DOWN AND ATTEMPT AGAIN WITH SAME RESULTS. -0400 Hrs - ROTATE PIPE 1 TURN AND WORK TORQUE DOWN. ATTEMPT TO SLIDE OVER STUMP AND STACK 15K DOWN. -0430 Hrs - ROTATE ANOTHER 1/4 TURN AND CONTINUE TO WORK TORQUE DOWN. NO SUCCESS. - DECIDED TO ATTEMPT TO WASH OVER STUMP. Printed 10/14/2010 3:02:59PM Page orth America - ALASKA - BP . s of 23 Operation. Summary Report Common Well Name: P1 -24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W A Datum: O RIG KE LLY BUSHIN @4 3.30ft (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 0430 - 06:00 1.50 RUNCOM P RUNCMP L/D JOINT #57 AND REMOVE COMPENSATOR. -R /U TO CIRCULATE DOWN TBG. -P /U AND WU JT #57. BRING PUMPS ONLINE AT 2 BPM WITH 80 PSI. -WASH DOWN AND SEE 4K WEIGHT AT 5' IN ON JOINT 57, - CONTINUE DOWN AND SHEAR SCREWS WITH 14K AT TIN AND SECOND SHEAR AT 16IN.NOGOAT17'IN. GOOD CONFIRMATION SEEING BOTH SHEARS ON CALCULATION. - PERFORM SPACE OUT CALCULATION AND WILL USE 2)'10' PUPS AND 1) 6' PUP. 06:00 - 06:30 0.50 RUNCOM P RUNCMP LD 4 -1/2" TUBING JOINT #57 AND RD CIRCULATING EQUIPMENT. - ATTEMPT TO PULL JOINT #56 AND OVERPULL 25K -LBS AT 11362'. - DISCUSS OPTIONS WITH RWO ENGINEERING TEAM. 06:30 - 08:30 2.00 RUNCOM N RUNCMP RU CIRCULATING EQUIPMENT TO REVERSE CIRCULATE. ATTEMPT TO REVERSE CIRCULATE WELL. -PUMP 7- STROKES AND PRESSURE UP TO 410 -PSI. PRESSURE DOES NOT BLEED OFF WITH PUMPS OFF. -BLEED OFF PRESSURE. CHECK ALL CIRCULATING EQUIPMENT AND ENSURE PROPER LINE UP. BLOW AIR THROUGH CIRCULATING LINES ON RIG FLOOR. NO PROBLEM WITH CIRCULATING EQUIPMENT. - ATTEMPT TO REVERSE AGAIN WITH IDENTICAL RESULTS. -RD CIRCULATING EQUIPMENT. -FILL TUBING TO MAINTAIN CONTINUOUS HOLE FILL. - DISCUSS SITUATION WITH RWO ENGINEERING TEAM AND DECIDE TO WORK OVERSHOT OVER 4 -1/2" TUBING STUB. i Printed 10/14/2010 3:02:59PM of th America - ALASKA - RP: Page 19 _f 23 Qperation Summary',Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY B USHIN G @43.30ft (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 10:30 2.00 RUNCOM N RUNCMP MU 4 -1/2" TUBING JT #57 TO STRING AND TO TOP DRIVE. -RIH TO 11367' (1' OF SWALLOW OVER 4 -1/2" STUMP) - DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CONTINUE TO SLACK OFF AS FAR AS POSSIBLE AND THEN WORK 8' INTERVAL TO MAINTAIN OVERSHOT OVER STUMP AT ALL TIMES. CONTINUE TO RIH AND SET DOWN 10K -LBS AT 11372'. - DISCUSS SITUATION WITH RWO ENGINEER. DECIDE TO ATTEMPT TO REVERSE CIRCULATE WELL CLEAR. PU TO 11368' AND RU TO REVERSE CIRCULATE. CLOSE ANNULAR AND ATTEMPT TO REVERSE. -PUMP 7 -STKS AND WELL PRESSURES UP TO 410 -PSI AND HOLDS. BLEED OFF, CHECK EQUIPMENT AND REPEAT WITH IDENTICAL RESULTS. - DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CONTINUE TO ATTEMPT TO PASS 11372'. -RIH AND SET DOWN 25K -LBS AT 11,372' THREE TIMES WITHOUT SUCCESS. -ON FINAL ATTEMPT, PU TO SEE WEIGHT BREAKOVER AND SEE 10K -LB OVERPULL. SLACKOFF TO PU WT AT 11368'. LOSS RATE USING HOLE FILL = 0 -BPH. - DISCUSS SITUATION WITH RWO ENGINEER. 10:30 - 11:00 0.50 RUNCOM N— RUNCMP PUMP DOWN TUBING TO FILL HOLE AT 1.5 -BPM WITH 180 -PSI. - ESTABLISH RETURNS AT 5 -BBLS PUMPED AND PRESSURE DROPS OFF TO 120 -PSI. -LOSS RATE = 20 -13PH. 11:00 14:00 3.00 RUNCOM N RUNCMP CONTINUE CIRCULATING AT 1.5 -BPM WHILE DISCUSSING SITUATION WITH RWO ENGINEER. - DECIDE TO CIRCULATE A BOTTOMS UP, WORK PIPE WITH PUMPS ON AND THEN PUMP A 40 -BBL HI VIS SWEEP AROUND TO CLEAN WELL. -STAGE PUMPS UP TO 2 -BPM WITH 230 -PSI. - NOTHING SEEN ACROSS SHAKERS DURING CIRCULATION. VERY SMALL AMOUNT OF GAS AT BOTTOMS UP. -LOSS RATE WHILE CIRCULATING REDUCES FROM 16 TO 13 -BPH. 14:00 14:30 0.50 RUNCOM N RUNCMP RIH TO 11379' WITH PUMPS ON AT 2 -BPM AND WITHOUT ISSUE. - RECIPROCATE SLOWLY FROM 11379' TO 11371' FIVE TIMES. -ALL MOVEMENT MADE WITHOUT ISSUES. Printed 10/14/2010 3:02:59PM W orth America - ALASKA = BP ' `Page ;2o of�z3. Operation Summary Common Well Name: P1 -24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Da ORI KELLY BUSHING @43.30ft (above Mea Sea Lev el) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 18:00 3.50 RUNCOM N RUNCMP PUMP 40 -BBL HI VIS SWEEP AT 2 -BPM WITH 190 -PSI. LOSS RATE= 16 -13PH. -WITH 85 -BBLS PUMPED, SLOW PUMPS TO 1 -BPM AND 50 -PSI. LOSS RATE = 4 -BPH. -AS SWEEP TURNS THE CORNER, WORK PIPE SLOWLY BETWEEN 11 379' AND 11371'. NO ISSUES PIPE MOVEMENT. -ONCE ALL SWEEP IS IN THE ANNULUS, STAGE PUMPS UP TO 2.8 -BPM WITH 240 -PSI. LOSS RATE = 18 -BPH. - PRESSURE CLIMBS SLOWLY AND WHEN IT REACHES 300 -PSI, WORK PIPE SLOWLY AGAIN. PRESSURE DROPS OFF. -FINAL RATE = 2.8 -BPM, FINAL PRESSURE _ 360 -PSI. LOSS RATE= 14 -13PH. -VERY SMALL AMOUNT OF SLUGGITS SEE AT SHAKERS THROUGH CIRCULATION. -RED PAINT AND FINE FLAKES OF PARAFIN SEEN WITH SWEEP. 18:00 18:30 0.50 RUNCOM N RUNCMP MONITOR WELL. FLUID LEVEL DROPPING VERY SLOWLY. -DRAIN POSSUM BELLY AND CLEAN UNDER SHAKERS. MINIMAL AMOUNT OF SLUGGITS RECOVERED. 18:30 - 20:30 2.00 RUNCOM N RUNCMP P/U AND DOWN WITH OUT PUMPS FROM 11 379' TO 11,370' DRY WITH UP WEIGHT AT 155K THEN DROPPING TO 130K. DOWN WEIGHT OF 95K THEN DROPPING BACK TO 11 OK THIS WAS THE SAME WITH 3 ATTEMPTS. -BRING PUMPS ONLINE WITH 2 BPM AND 60 PSI WORKING PIPE FROM 11,379' TO 11370' SEEING 130K UP WEIGHT AND 110K DOWN WEIGHT AND VERY LITTLE RATTINESS. -SPOKE WITH ADW TOWN ENGINEER AND DECIDED TO PUMP OFF OF STUMP AND THEN PULL THE NEXT 2 JOINTS WITHOUT PUMPS. P/U JT 57 WITH 2 BPM AND 60 PSI AND PULLED OFF OF STUMP WITH 130K UP AND 11 OK DOWN. -SHUT DOWN PUMPS AND UD JT 57, PULL AND UD JT 56 WITH 135K UP WEIGHT. 20:30 - 21:15 0.75 RUNCOM N RUNCMP R/U AND TO PULL JT 55 BUT FLUID WAS FLOWING OUT OF TOP OF PIPE SO WE MADE UP TO JT 55 AND PUMPED A TUBING VOLUME AT 2.5 BPM AND 180 PSI WITH 16 -19% FLOW RETURNS. DYNAMIC LOSS RATE OF 3.4 BPH. MUD WT IN 9.2 PPG MUD WT OUT 9.2 PPG PRIOR TO SHUTTING DOWN PUMPS. 21:15 21:30 0.25 RUNCOM N RUNCMP MONITOR WELL. FLUID LEVEL DROPPING SLOWLY. 21:30 - 23:00 1.50 RUNCOM P RUNCMP P/U AND UD JOINT #55. -MU SPACE OUT PUPS, 9.92', 9.89', 5.65'. -P /U JOINT 55 AND RIH WITH 110K DOWN. - MAINTAIN CONTINUOUS HOLE FILL AT 3 BPH LOSS RATE. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM FOR P/U M/U HANGER. -M /U HANGER. M/U LANDING JOINT. Printed 10/14/2010 3:02:59PM orth America - ALASKA - BP ,P e �of 2� Operation Summary Report _ Common Well Name: P1 -24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148'35'01.251"W Active Da O KELLY BUSHING @ (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/3/2010 00:00 02:30 2.50 RUNCOM P RUNCMP PJSM FOR SPLICING CONTROL LINE TO SSSV. - SPLICE 1 CONTROL LINE 6' UNDER HANGER AND TEST CONTROL LINES TO 5000 PSI. - GOOD TEST. -RUN CONTROL LINES THROUGH HANGER AND TEST PACK OFF TO 5000 PSI. GOOD TEST. -RUN CONTROL LINE TO RIG FLOOR AND RETEST TO 5000 PSI. GOOD TEST. LEAVE 3500 PSI ON CONTROL LINES WHILE LANDING. 02:30 03:30 1.00 RUNCOM P RUNCMP RIH TO LAND HANGER 23' IN ON LANDING JOINT. 21';.IN ON LANDING JOINT DOWN WT INCREASED 18K OVER. -P /U AND BREAK CIRCULATION AT 2 BPM AND 130 PSI. -WASH OVER TUBING STUB AT ABOVE RATES AND LAND HANGER 23' IN ON LANDING JOINT. -30 CANNON CONTROL LINE CLAMPS USED. BOTTOM OF OVERSHOT IS LOCATED AT 11,375'. NO GO AT 11,380', LEAVING 8' OF SWALLOW OVER 4-1/2" STUB. 03:30 - 04:00 0.50 RUNCOM P RUNCMP ATTEMPT TO REVERSE CIRCULATE -PUMP 9.2 PPG BRINE FROM PITS. - ANNULUS PRESURED UP TO 500 PSI IN 13 STROKES. SHUT DOWN PUMPS AND PRESSURE HELD FOR 2 MIN. -BLEED DOWN ANNULUS. -SPOKE WITH ADW TOWN ENGINEER AND AGREED TO DROP BALL AND ROD AND SET PACKER. HAVING THE PACKER FLUID PUT INTO PLACE POST RIG. 04:00 - 05:00 1.00 RUNCOM P RUNCMP LINED UP TO CIRCULATE DOWN TUBING TO WASH BALL SEAT CLEAR OF ANY DEBRIS OFF AT 2 BPM AND 230 PSI. - REMOVE BAILS TO TURN TOP DRIVE AND REMOVE XO FROM LANDING JOINT. -R /U AND DROP BALL AND ROD. 05:00 06:30 1.50 RUNCOM P RUNCMP PUMP DOWN TUBING AND PRESSURE UP ON BALL AND ROD ON SEAT. - PACKER BEGAN SETTING AT 1900 PSI THEN BROUGHT PRESSURE UP TO 3500 PSI. - ATTEMPT TO TEST TUBING FOR 30- CHARTED MIN. - TUBING PRESSURE DROPPING OFF. -CHECK SURFACE EQUIPMENT AND REPLACE ONE BLOCK VALVE. -STILL UNABLE TO GET A GOOD TEST. 06:30 - 07:30 1.00 RUNCOM P RUNCMP BLEED TUBING PRESSURE TO 2500 -PSI AND TEST IA TO 3500 -PSI FOR 30- CHARTED MINUTES. -GOOD TEST ON ANNULUS WITH TUBING PRESSURE STILL FALLING. -BLEED ANNULUS PRESSURE TO 0 -PSI AND BLEED TUBING PRESSURE TO 1000 -PSI. Printed 10/14/2010 3:02:59PM orth America - ALASKA - BP 4Fage pf 23 Oppratio _ ummary' mport Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 08:30 1.00 RUNCOM P RUNCMP DISCUSS SITUATION WITH RWO ENGINEERING TEAM AND CONTINUE TO MONITOR TUBING PRESSURE. - TUBING PRESSURE CONTINUES TO DROP AND THEN HOLDS STEADY AT 1000 -PSI. 08:30 10:30 2.00 RUNCOM P RUNCMP ATTEMPT TO TEST TUBING TO 3500 -PSI AGAIN. TEST FAILS. -TEST TUBING TO 1000 -PSI FOR 10- CHARTED MINUTES. GOOD, FLAT LINE TEST. ATTEMPT TO PRESSURE TEST TUBING TO 3500 -PSI AGAIN AND UNABLE TO GET GOOD TEST. -BLEED TUBING PRESSURE TO 0 -PSI. 10:30 - 11:00 0.50 RUNCOM P RUNCMP PRESSURE UP ON ANNULUS TO 2700 -PSI AND SEE DCR SHEAR. - REVERSE THROUGH VALVE AT 2 -BPM WITH 130 -PSI. CIRCULATE DOWN TUBING AT 2 -BPM WITH 140-PSI. -LD LANDING JT AND VAC OUT BOP STACK. 11:00 - 15:00 4.00 RUNCOM P RUNCMP FMC T -BAR IN TWC. ATTEMPT TO TEST BELOW TWC TO 1000 -PSI FOR 10- CHARTED MINUTES. VISUALLY CONFIRM TWC IS NOT LEAKING. NO FLUID SEEN WHEN LOOKING AT TOP OF TWC. HANGER IS NOT LEAKING. NO FLUID SEEN COMING FROM AROUND HANGER. -BUMP TEST PRESSURES UP TO KEEP FROM FALLING BELOW TEST PRESSURE. -HOLE IS STAYING FULL OF 9.2 -PPG KWF AS WE ARE ABLE TO CONSISTENTLY PRESSURE TEST. -BEST TEST LOSES 75 -PSI OVER 10- MINUTES. - ATTEMPT TO TEST BELOW TWC TO 700 -PSI. LOSE 70 -PSI OVER 10- MINUTE TEST INTERVAL. HOLE STAYS FULL OF 9.2 -PPG KWF AND NO LEAKS SEEN AROUND TWC OR HANGER. - ATTEMPT TO TEST BELOW TWC TO 500 -PSI FOR 10- MINUTES. LOSE 50 -PSI OVER 10- MINUTE TEST INTERVAL. HOLE STAYS FULL OF KWF AND NO LEAKS SEEN AROUND TWC OR HANGER. 15:00 - 17:00 2.00 RUNCOM P RUNCMP PU LANDING JT AND FILL. MU TEST EQUIPMENT. -TEST TWC FROM ABOVE TO 3500 -PSI FOR 10- CHARTED MINUTES. GOOD TEST. -XO FROM LANDING JT TO TIW VALVE. 17:00 - 17:30 0.50 RUNCOM P RUNCMP R/D TEST EQUIPMENT. - ESTABLISH CONTINUOUS HOLE FILL THROUGH IA. NO LOSSES. 17:30 - 20:00 2.50 BOPSUR P RUNCMP PJSM FOR RIGGING DOWN BOPE. -R /D HALIBURTON EQUIPMENT FROM RIG FLOOR. -N /D BOPE Printed 10/14/2010 3:02:59PM a th America - ALASKA - BP Page 23 of 2� Operation Summary R epo'rt Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 WHSUR P RUNCMP N/U ADAPTER FLANGE. - NOTICE BUBBLING AROUND PACK OFF ON CONTROL LINE. FLUID IS BEING PUMPED INTO THE IA TO KEEP HOLE FULL. - REPAIR LEAK IN CONTROL LINE PACK OFF, WITH A SWEDGE LOCK. TEST TO 5000 PSI. GOOD TEST. -N /U ADAPTER FLANGE. 9/4/2010 00:00 04:00 4.00 WHSUR P RUNCMP FINISH N/U ADAPTER FLANGE. -TEST CONTROL LINES TO 5000 PSI FOR 10 CHARTED MIN. EACH. GOOD TEST. -TEST ADAPTER SPOOL TO 5000 PSI FOR 10 CHARTED MIN. GOOD TEST. -N /U TREE. -TEST TREE TO 5,000 PSI FOR 10 MIN. -GOOD TEST. 04:00 - 06:00 2.00 WHSUR P RUNCMP SECURE TREE. -R /D SECONDARY ANNULAR VALVES AND SECURE THE TREE. -EMPTY AND CLEAN PITS. - RELEASE RIG AT 0600 Hrs. Printed 10/14/2010 3:02:59PM i • ~c~lerger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.5468 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 13-35 BBKA-00005 CROSS FLOW CHECK 02/07/10 1 1 A-02 M-08 V-123 4-38/K34 AWJI-00072 AYTO-00035 AWJN-00033 AWJI.00070 MEMORY PROD PROFILE - CROSS FLOW CHECK - SCMT -~ C MEMORY PROD PROFILE 01/31/10 02/07/10 01/15/10 02/02/10 1 1 1 i 1 1 1 1 Y-36 AYKP•00061 RST O1/14110 1 1 F-40 AZCM-00053 RST 12/29/09 1 1 01-14A P1.24L1-01 AWJI-00067 12034915 MCNL OH LDWG EDIT (FLEX 01/07/10 - 08/12/08 1 1 1 1 V-224 09AKA0147 OH MWD/LWD EDIT 12/08/09 2 1 BP Exploration (Alaska) Inc. ~V~ V V•~,'•••V ^„v ^~ ~ Vn"'"V v„c yvr r Gwyn ~ v. Petrotechnical Data Center LR2.1 900 E. Benson Blvd. ~~ Alaska Data & Consulting Services 2525 Gambell Street, Su9e 400 Anchorage, AK 99503-2838 ovt apt o DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2081240 Well Name/No. PRUDHOE BAY UN PTM P1-24L1-01 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-22703-61-00 MD 14017 TVD 9002 Completion Date 8/14/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~y mearrrmi rvurnaer Name acme wieaia no s[art stop ~.n r<ecervea ~.ommenrs D D Asc Directional Survey 0 14017 Open 9/17/2008 PBU P1-24L1 also on Disk pt Directional Survey 0 14017 Open 9/11/2008 ED C Las 17271 Induction/Resistivity 11682 14016 Open RPM, GR, RAD, RAM, ROP, RPD FIELD DATA pt LIS Verification 11681 14014 Open 11/2/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis ~~~ 18855"Induction/Resistivity 11681 14014 Open 11/2/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 12040 14017 Open 11/2/2009 MD MPR, GR tog Induction/Resistivity ~s'S~ Col 12040 14017 Open 11/2/2009 TVD MPR, GR og Gamma Ray 25 Col 12040 14017 Open 11/2/2009 MD GR og See Notes s2 ~~ Col 11680 14020 Open 11/2/2009 Depth Shift Monitor Plot Weil Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2081240 Well Name/No. PRUDHOE BAY UN PTM P1-24L1-01 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-22703-61-00 MD 14017 TVD 9002 Completion Date 8/14/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION (~, ~~ Well Cored? Y ~ Daily History Received? y~'~" Chips Received? Y~ Imo' Formation Tops Q/ N Analysis ~T I~ Received? Comments: Compliance Reviewed By: _.______ - Date: C 9 ~~-l.~ ( U i .~.. BAKER HV6HE5 Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y BY EXYLURA'1'lUN (ALASKA) 1NC WELL NAME PI-24L1-O1 CUUN'1 Y NUR'1H SLUYE BURUUGH STATE ALASKA FIELD POINT MCINTYRE DATE 10/28/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #:2120695 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 CORAZON MANAOIS Address LR2-1 Address SSO WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE AK 99508 ANCHORAGE, AK 99501 I Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. TTH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westtield Houston, Texas 77073 This Distribution List Completed Bv: ~ ~~ ,~ ~~ Page l of l INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P1-24L1-Ol Contains the following: ~~ 1 LDWG Compact Disc "~ (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2120695 Sent by: Catrina uidry Date: 10/28/09 Received by: ' 1 ~ ~ Date: ~, ; _ _ .- ®, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 :.~_ .= 4 i#lGI~IES l fr ! ~lz Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~}~-1~ ~~~ Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, October 23, 2008 2:21 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU P1-24L1-01 / PTD # 208-124 H i Art, Please reference the following well: Well Name: PBU P1-24L1-01 Permit #: 208-124 API #: 50-029-22703-61-00 Top Perf D: 11436' Bottom Perf MD: 13976' This well began Production on October 13, 2008 Method of Operations is: Gas Lift Date of Test: 10/14/08 Hours Tested: 8 24-Hour Rate /Oil-Bbl: 4,412 24-Hour Rate /Gas-Mcf: $,868 24-Hour Rate 1 Water-Bbl: 1,660 Test Rate 1 Oil-Bbl; 1,471 Test Rate 1 Gas-Mcf: 2,956 Test Rate /Water-Bbl: 553 Choke Size: 85 Gas-Oil Ration: 2,010 Flow Tubing Pressure: 1,200 Casing Pressure: 1,600 Oil Gravity-API: Unavailable Page 1 of 1 10/23/2008 i t ~~~ ~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: September 15, 2008 Please find enclosed directional survey data for the following wells: Pl-24L1 V-115L1 Pl-24L1-Ol ~. ~ ~ ^C a- `{ V-115L2PB1 p;so< <,ti ~.fl~-t~~ 02-25A V-115L2 E-29A Enclosed for each well is: 1 ea 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. RECEIVED BY: ti~,,~ lJ ~ State of Alaska AOGCC DATE: ~ Cc: State of Alaska., AOGCC u..~ ,~,~ I T~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: September 08, 2008 Please find enclosed directional survey data for the following wells: Pl-24L1 V-115L1 Pl-24L1-Ol a2.v g ' ~ Z`~ V-115L2PB1 02-25A V-115L2 E-29A Enclosed for each well is: tea copies of directional survey reports 1 ea 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. RECEIVED BY: ,State of Alaska AOGCC DATE: ~,c)-~ Cc: State of Alaska, AOGCC • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ `~ ~ 4~ L00~ 4° WELL COMPLETION OR RECOMPLETION REPORT AND LQG r~~ ~~~..~ ~~,rl ~,_.. ~~ 41~~ ix w+ _. ~f'4t rl r. :t'"? (3 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~oS zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 8/14/2008 12. Permit to Drill Number 208-124 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/10/2008 13. API Number 50-029-22703-61-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/12/2008 14. Well Name and Number: PBU P1-24L1-01 FEL, SEC. 16, T12N, R14E, UM 1364 FSL, 965 Top of Productive Horizon: 2851' FSL, 1416' FEL, SEC. 09, T12N, R14E, UM 8. KB (ft above MSL): 43.1' Ground (ft MSL): 9.5' 15. Field /Pool(s): Prudhoe Bay Field /Point Total Depth: 3547' FSL, 3030' FEL, SEC. 09, T12N, R14E, UM 9. Plug Back Depth (MD+ND) 14017' 9002' McIntyre Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 674093 y- 5994489 Zone- ASP4 10. Total Depth (MD+TVD) 14017' 9002' 16. Property Designation: ADL 028298 &ADL 034622 TPI: x- 673470 y- 6001244 Zone- ASP4 - 61902 Zone- ASP4 Total De th: x- 671838 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y 18. Directional Survey ®Yes ^ No mi I r ni nd ri inf rm i n r 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed inform n per 20 AAC 25.071): ~ MWD DIR, GR, RES d!/~rvDOW~ /i?,O~i~D 'ryD ~ ~ C~ ~~~L{,Cp l~~ 22. CASING, LINER AND CEMENTING RECORD ~ ~~~ CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2 -4 S rfa 110' 2 r i r x. " ~ ~ 1290 sx CS III 327 sx'G' 250 sx CS II 7" / 1' 17' - /2" 385 'G' -7/ " .1 14 T I 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+ND of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER .SET MD ; p 2-7/8" Slotted Section Note: 4-1/2", 12.6#, 13Cr 11447' 11403' MD ND MD ND 11436' - 13976' 8519' -9000' Only Well Branch P1-24L1-01 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Is Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Accessible 2200' Freeze Protect w/ Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: I m ? ~° ~ - PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: 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+ND 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. COMPLETdON None -p~~ ~~ SEA ~ ~ 2008 ~1RIGINAL Form 1'0-407 Revised 02/2007 ~ CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. (From Parent Well) None Kuparuk 11987' 8880' Formation at Total Depth (Name): Kuparuk 11987 8880' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoipg is true and correct to the best of my knowledge. ~~ ~ ~ 1 ~ Title Drilling Technologist Date Signed Terrie Hubble PBU P1-24L1-01 208-124 PreparedeyNameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only P1-24, V~ell History (Pre Rig Si8'etrack) Date Summary 6/2/2008 T = 1200 Change out swab valve, torque to 800 ft.lbs. test to 5000 psi. 6/6/2008 T/I/0= 1980/2140/150 Temp= S/I Assist Slickline (CTD screen). Pumped 1.4 bbls 90°F diesel down Tbg, Tbg pressured up. Pumped 236 bbls 190°F crude down IA in attempt to free Tbg of paraffin. 6/6/2008 WELL S/I ON ARRIVAL. DRIFT W/3:85" GAt1GE RING, TOOLS SET DOWN C~3 220' SLM (PARAFFIN ON TOOLS). LRS PUMPS 1.5 BBLS DOWN TUBING, PRESSURES UP TO 3000#. LRS CURRENTLY PUMPING HOT CRUDE DOWN THE IA TO ATTEMPT TO CLEAR PARAFFIN IN TUBING. 6/7/2008 LRS PUMPED 306 BBLS HOT CRUDE DOWN IA TO CLEAR PARAFFIN IN TBG. CONDUCTED BRUSH & FLUSH W/ 2.00" TO 3.85" G-RINGS & BRUSH TO K-VALVE C~ 2197' MD W/ LRS. PULLED 4 1/2 DB LOCK W/ K-VLV (ser # K11A) FROM FROM 2197' MD. RAN MUTIPLE GAUGE RINGS (2.75" TO 3.80") W/ 4-1/2" BRUSH FROM SURFACE TO 11436' MD WHILE LRS PUMPED HOT DIESEL. 6/7/2008 Assist Slickline with Brush-n-Flush (CTD screen). Pumped 66 bbls (306 total) 190°F crude down IA. Pumped 175 bbls 180°F diesel down Tbg while slickline RIH with brush. Final WHPs 1400/1900/120. 6/8/2008 RAN 3.70 DMY WHIPSTOCK, SAT DOWN AT SOZ CMT DONUTC~ 11439' SLM (NO PROBLEMS). RAN 2.25" CENT, S-BAILER TO TD ~ 12210' SLM, SOFT BTM (S-BAILER EMPTY). RAN PDS 40 ARM CALIPER FROM 12210' SLM TO SURFACE (GOOD DATA). SET WHIDDON C-SUB AT 11416' SLM. PULLED S/O GLV FROM STA#3 C~ 9744' MD & LGLV'S FROM STA#2 C~ 7397' MD, &STA#1 C~3 4310' MD. SET INT- DVLV'S IN STA# 1 & STA# 2 . CURRENTLY SETTING DGLV IN STA# 3. 6/9/2008 T/I/0= 1950/1950/140. Temp= SI. IA & OA FL (CTD screening). FMC hanger. A/L SI ~ casing valve. A/LP= 2150 psi. IA FL C~2 5570' (98 bbls). OA FL ~ surface. Bled IAP to production through P1- 18 from 1950 to 650 in 2 hours. IAP increased 200 psi in 1 hour monitor. Final WHPs= 1950/8501140. 6/9/2008 PULLED EMPTY WHIDDON C-SUB FROM 11416' SLM. LEFT WELL SI, NOTIFIED DSO OF WELL STATUS. 6/11/2008 RAN PETRODAT GAUGES MAKING STATIC STOPS AS PER PROGRAM. (USED 20' CORRECTION FROM LAST XN-NIPPLE TAG 06/09/08). PETRODAT DOWN LOADED GOOD DATA. LEFT WELL S/I NOTIFY DSO. 6/12/2008 T/I/0=1930/700/150 Temp=S/I -MIT IA FAILED to 3000 psi (CTD Screen) -Pumped 135 bbls 95° crude down IA. Did not reach test pressure. Established LLR of 2 bpm C~ 1560 psi for 30 bbls. Bled IA to starting pressure. Pumped 19 bbls 95° crude down OA. OAP drops off when reaches 1190 psi. 6/12/2008 T/I/0=1900/1150/150. Temp=Sl. Bleed IA <500 psi (pre FB). IA FL C~ 950'. Bled IAP from 1150 psi to 700 psi in 3hrs. IAP would not bleed below 700 psi. SI, TBGP decreased 70 psi. 6/13/2008 MIT OA FAILED to 2000 psi (CTD screen) Pumped 13 bbls 95° crude down OA (32 bbls total) OA did not reach test pressure. OA dropped from 1400 psi to 1100 psi while pumping at .50 bpm and then 1250 psi to 1190 psi while pumping at .40 bpm. OA mantained 1200 psi C~ .28 bpm. Established. LLR of .28 bpm C~3 1200 psi for 10 bbls. OAP dropped to 600 psi in 20 min when shut down pump. Bled OA to 250 psi. FWP's = 2090/760/300. Casing valves open to guages, tags hung, DSO notified of well status. 6/17/2008 RAN 1.25" LIB TO STA#'s 1, 2, 3, 4. LRS MIT IA (FAILED). 6/17/2008 T/I/O = 1980/760/215 Temp = S/I -Assist slickline, MIT IA FAILED to 3000 psi (CTD screen) -Pumped 20 bbls 95° crude down IA C~ 1 bpm and 30 bbls 95° crude at 2 bpm. TP and OAP increased while IAP increased. All pressures drop off when shut down pump. 6/18/2008 Assist slickline w/LDL (CTD screen) -Pumped 249 bbls 95° crude down IA to while slickline runs memory log. 6/18/2008 RECEIVED GOOD DATA ON SLB LEAK DETECT LOG (DATA SHOWS POSS. LEAK AROUND STA#'s 3 & 4). SET 4-1/2" WHIDDON C-SUB IN XN NIP. ~ 11,436' SLM. PULLED INT-DGLV FROM STA# 3 (9744' MD), VALVE MISSING NOSE, SHEAR RING & 1 COLLET. ATTEMPTED TO PULL STA #4 (11343' MD) MULTIPULE TIMES. Page 1 of 3 P1-24,11Vell History (Pre Rig Si~etrack) Date Summary 6/19/2008 ATTEMPTED TO PULL INT-GLV FROM STA #4 C~3 11343' MD. RAN LIB TO STA #4 ~ 11343' MD (PIC OF INT- GLV). PULLED INT-DUMMY GLV FROM STA #4 C~3 11343' SLM. RAN POCKET POKER TO STA #4 (CLEAR). 6/19/2008 Slickline pulling GLV's and setting DGLV's. Called off job. FWP's = 1850/660/300. Casing valves open to guages, tags hung, DSO notified of well status. 6/20/2008 T/I/0=1760/660/300 temp=s/i Assist Slickline (CTD Screen) Load tbg w/5 bbls neat meth & 143 bbls crude. Pump 10.6 bbls crude to pressure up. TP lost 80 psi 1st 15 min., & 40 psi 2nd 15 min, for total loss of 120 psi in 30 min. Pump 2 bbls meth & 1 bbls crude down IA to pressure up. IAP lost 80 psi 1st 15 min, 20 psi in 2nd 15 min, for a total loss of 100 psi in 30 min. WHP's=1350/660/300. Annulus valves open to gauges, tags hung, & pad op notified of valve positions C~ departure. 6/20/2008 RAN POCKET POKER TO STA #3 (CLEAR). SET INT-DGLV IN STA #3 (9744' MD) &STA #4 (11343' MD). PULLED 4-1/2" WHIDDON C-SUB FROM 11,436' MD. RECOVERED NOSE CONE & SHEAR RING FROM STA#3 GLV. SET 4-1/2" PXN PLUG BODY C~ 11,436' MD. SET "P" PRONG IN PLUG BODY ~ 11,436' MD. LRS MIT-T TO 3000 PSI (PASS). LRS MIT-IA TO 3000 PSI (PASS). PULLED P-PRONG FROM 11439' SLM. 6/21/2008 RAN 3.70" CENT, 3.25" LIB, SD C~ 8710' SLM WORK TO 8810' SLM. RAN 4 1/2 BLB, 3.805" GAUGE RING, SD ~ 8735' SLM. RAN 10' x 3" DRIVE DOWN BAILER TO 8761' SLM. RECOVERED PARAFIN. BROKE ~~ THROUGH OBSTRUCTION W/ 3.805 G-RING & TAGGED PLUG BODY ~ 11,443' SLM. ATTEMPT TO PULL PLUG BODY. CAN'T MAKE IT PAST OBSTRUCTION W/ PULLING TOOL. RAN 4 1/2 BLB, 3.805" GAUGE RING. 6/21/2008 T/I/0= 900/840/300 Temp=S/I Assist S/L w/B&F (CTD Screen) Pumped 62 bbls 190° crude down TBG while S/L RIH. Start pumping down TBG w/180° DSL. 6/22/2008 T/I/0=800/1100/300, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). CTD screen. PPPOT-T: Stung into test port (1000 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS).. Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 6/22/2008 Assist Slickline w/B&F (CTD Screen) Pumped 127 bbls 180° DSL & 11 bbls 190° crude down TBG while S/L RIH. Annulus casing valves left open to gauges, operator notified, SLB on well upon departure. FWHP's 800/1160/300 6/22/2008 RAN 3.80" GAUGE RING, 4 1/2 BLB, SD ~ 11440' SLM. PULLED 4-1/2" PXN PLUG BODY FROM 11,436' MD. LEFT WELL S/I, NOTIFY PAD-OP VALVE STATUS. 7/17/2008 Perform weekly BOP test. MU BOT 2 7/8" left motor/3.79" string reamer/3.80" DSM. Fluid pack/kill well. RIH & MITI XN nipple C~ 11430 and CMT Donut from 11433' to 11478'. RIH to 12150. POOH. MU 3.63" X 18.87' dummy W/S. Drift clear to 12150'. POOH. 7/18/2008 POOH from dummy W/S drift. FP wellbore to 2500 w/ water/meth. RDMO. Job complete. 7/19/2008 WELL SHUT IN ON ARRIVAL. T/I/0= 225/1020/300. JUNK BASKET WITH 3.7" GAUGE RING RUN ON 1ST DESCENT. CORRELATION WITH GR/CCL PERFORMED FROM 11330' - TD TAGGED AT 12,203'. SET TOP OF 4.5" x 7" WHIPSTOCK AT 12040' AND 0.7 DEG ROHS. RADIATION PIP TAGS AT 12050', BOTTOM OF WHIPSTOCK AT 12057.5'. FINAL T/I/O = 200/1000/300. WELL LEFT SHUT IN UPON COMPLETION, WING VALVE CLOSED SWAB VALVE CLOSED, MASTER CLOSED, CASING VALVES OPEN TO GAUGES.. DSO NOTIFIED. JOB COMPLETE. 7/20/2008 T/I/O = 240/920/170. Temp = SI. T & IA FL (pre CTD). No AL line. F/L removed. TBG FL ~ surface. IA FL Cud 30'. WV & SV closed. MV & SSV open. IA & OA valves OTG's. Page 2 of 3 P1-24, Welt History (Pre Rig Si~etrack) Date Summary 7/21/2008 T/I/O = 240/920/210. Temp = SI. Bleed IAP & OAP to 0 psi (pre CTD). No AL line. F/L removed.. IA FL ~ 30'. OA FL ~ surface. Bled OAP from 210 psi to 180 psi w/open bleed, SI & OAP increased to 200 psi. Bled IAP from 920 psi to 0 psi in 25 min into BT (gas/fluid). During IA bleed TBGP decreased to 110 psi, OAP increased to 290 psi. Monitored pressures for 30 min. IAP increased to 0+, TBGP & OAP unchanged. Final WHPs = 110/0+/290. MV, SV & WV closed. SSV open. IA & OA valves OTG's. 7/23/2008 Set 4-1/16" CIW BPV# END404 for pre nordic. Set ~ 96", T/I/0= 100/300/0. Pressure test tree to 5000 Ib. 7/24/2008 Temp=S/I Load OA (CTD prep) Rod to location. 7/25/2008 T/I/O=BPV/30/240. Temp=Sl. Bleed OA to 0 psi (pre-CTD prep). No A/L. F/L removed. While FB was rigging down OAP increased 190 psi. Bled OA from 220 psi to 0+ psi in 7.5 hr (37 bbl return, diesel). monitor 30 min, OAP increased 15 psi. During bleed IAP increased 5 psi. Final WHPs=BPV/35/15. WV, SV, MV=Closed, SSV=OPEN, IA&OA=OTG. 7/25/2008 T/I/O=BPV/60/400 Temp=S/I Load OA (CTD prep] Started pumping down OA with diesel spear. Pumped 1.4 bbls before shutting down pump before reaching 2000 psi. After 20 minutes OA pressure dropped to 1750 psi. OA pressure was then bled down to 250 psi getting back 1 bbl diesel. Came back on line with pump and pumped 1.75 bbls diesel into OA before reaching 2000 psi again. Pressure on OA fell to 520 psi after 1 hour. Switched over to 9.8# brine and pumped 0.25 bbls into OA before reaching 2000 psi. Pressure on OA fell to 1080 psi after 3 hours. Rigged down from OA and bled OA to bleed trailer unit) DHD arrived. Turned well over to DHD to continue bleed on OA. Final WHP's 0/100/0 Upon departure -Annulus casing valves open to gages. Swab, Wing closed , SSV ,Master , IA and OA left open. 7/25/2008 T/I/O=BPV/0+/100 Load OA w/ brine to secure. (CTD prep) Pumped 2.2 bbls 9.8# NaCI brine into OA. 7/26/2008 Load OA w/ 9.8 brine to secure. (CTD prep) Pumped 3.5 bbls of 9.8# brine into the OA. OA did not want to take fluid. Final WHP's = 0/120/1800. Valve positions at the time of departure: Swab closed /Wing closed /SSV open /Master closed / IA open to gauge / OA open to gauge. 7/27/2008 T/I/0= 0/60/760. Temp= SI. Monitor, WHPs (post-CTD). Wellhouse, Flowline & A/L removed. SV,WV=SHUT MV,IA,OA=OPEN 7/29/2008 T/I/O=BPV/30/760. SI. Bleed IA & OA to 0 psi (CTD prep). No AL line or flow line. IA FL near surface. OA FL CAB surface. Bled IAP from 30 psi to 0 psi in 1 minute. Bled OAP from 760 psi to 0 psi in 5 minutes. Monitored 30 minutes. OAP increased to 60 psi. Bled OAP back to 0 psi several times with the OA pressure increasing less each time. Final Bleed was from 5 psi to 0 psi in 2 seconds with no increase in 30 minutes. Total fluid back < 2 bbls. Final WHPs=BPV/0/0 SV, WV, SSV, MV=closed. IA & OA valves OTG. 7/29/2008 T/I/O=BPV/0+/0+. Temp=Sl. Bleed WHPs to 0 psi, monitor (CTD prep). No A/L or F/L. No changes in WHPs overnight. Page 3 of 3 BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 7/30/2008 07:00 - 21:40 14.67 MOB N WAIT PRE Rig has been released from 13-30C at 0700, but is still on that pad waiting for rig mats to move off the pad. 21:40 - 22:00 0.33 MOB P PRE SAFETY MEETING. Discuss crew assignments and hazards f or moving rig off well 22:00 - 00:00 2.00 MOB P PRE Move rig off of well and down pad 100m. Pick up spill containment dykes and rig mats. 7/31/2008 00:00- 04:00 4.00 MOB N WAIT PRE Continue waiting for rig mats to be laid on 13-30 to move the rig off the pad. Tool service starts laying them about 0200. 04:00 - 04:15 0.25 MOB P PRE SAFETY MEETING. PJSM for moving rig.. 04:15 - 06:00 1.75 MOB P PRE Move rig to front side of pad 13-30 and set down. Move rig mats from pad onto pad access road to guard shack. 06:00 - 12:00 6.00 MOB N WAIT PRE Wait for rig mats to get spotted to guard shack. 12:00 - 16:00 4.00 MOB P PRE Move off of DS 13 and start towards Oxbow. 16:00 - 00:00 8.00 MOB N WAIT PRE Park rig at DS 7, wait for rig mats that are being used by Doyon 16. 8/1/2008 00:00 - 04:00 4.00 MOB N WAIT PRE Continue waiting at DS7 for completion of Doyon 16 move. 04:00 - 04:20 0.33 MOB P PRE Safety meeting with Security, ready to move off DS7 towards West Dock Road. 04:20 - 11:00 6.67 MOB P PRE Move rig off DS7 and onto Oxbow towards West Dock Rd. 11:00 - 21:00 10.00 MOB N WAIT PRE Park at entrance to PM1 and lay out rig mats ahead. 21:00 - 21:20 0.33 MOB P PRE SAFETY MEETING. Discuss next stage of rig move. 21:20 - 23:30 2.17 MOB P PRE Move rig down PM1 access road to about 300m short of pad. 23:30 - 00:00 0.50 MOB N WAIT PRE Wait for more rig mats to complete the last 300m. 8/2(2008 00:00 - 02:30 2.50 MOB N WAIT PRE Continue waiting for rig mats to get positioned behind rig. 02:30 - 03:00 0.50 MOB N WAIT PRE Move rig backwards over tripled up mats. 03:00 - 04:30 1.50 MOB N WAIT PRE Spread out mats in single layer in front of rig. 04:30 - 05:00 0.50 MOB P PRE Move rig onto pad. 05:00 - 11:00 6.00 MOB N WAIT PRE Park off to side of pad and prep area around well, more gravel is needed to park the rig on. Survey and level pad. Position rig mats in front of well. 11:00 - 11:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing over well. 11:15 - 11:30 0.25 MOB P PRE Back over well and center rig over well. Set rig down. 11:30 - 16:00 4.50 BOPSU P PRE Nipple up BOP's. Position equipment. 16:00 - 20:40 4.67 BOPSU P PRE Pressure /Function test BOPE. AOGCC inspector, John Crisp witnessed test. Test Annular, Blind /Shears, 2-3/8" Pipe /Slips, 3-1/2" x 2-3/8" VBR, Lower 2-3/8" Pipe /Slips, 2-3/8" TIW valve, all kill and choke line valves to 350 / 3,500 psi. All valves pass. Loaded and prepared new 2-3/8" E-Coil while testing BOP's. Install 1502 pump line inside reel. 20:40 - 21:40 1.00 MOB P PRE Load BPV pulling equipment to rig floor and rig it up. RT flowback line to 4,000 psi, good. 21:40 - 22:20 0.67 MOB P PRE PT BPV lubricator to 1,000 psi, good. Pull BPV, 160 psi underneath. Bleed off pressure then shut in, climbs back to 80 psi rapidly. Close master and swab valve. 22:20 - 22:40 0.33 MOB P PRE Load out BPV lubricator and pulling tools. 22:40 - 00:00 1.33 MOB P PRE Prepare reel to pull cable across pipe shed roof. Install cable bulkhead and collector. Install inside grapple connector and pull test. 8/3/2008 00:00 - 00:40 0.67 MOB P PRE Continue prep reel for pulling CT across pipe shed. 00:40 - 00:55 0.25 MOB P PRE SAFETY MEETING. Discuss hazards and crew responsibilities Printed: 8/25/2008 2:12:33 PM . BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: I Date From - To Hours Task ~ Code NPT Phase Description of Operations 18/3/2008 00:40 - 00:55 0.25 MOB P PRE 00:55 - 02:15 1.33 MOB P PRE 02:15 - 03:45 ~ 1.50 ~ MOB ~ P ~ ~ PRE 03:45 - 04:10 I 0.421 MOB I P I I PRE 04:10 - 05:30 1.33 MOB P PRE 05:30 - 06:00 0.50 STWHIPI P WEXIT 06:00 - 08:15 2.25 STWHIP P WEXIT 08:15-09:15 ~ 1.OO~STWHIP~P (WEXIT 09:15-12:20 ~ 3.08~STWHIP~P ~ WEXIT 12:20-15:40 ~ 3.33~STWHIP~N AWAIT WEXIT 15:40-18:45 ~ 3.08~STWHIP~P ~ WEXIT 18:45-19:00 ~ 0.25~STWHIP~P ~ WEXIT 19:00-19:50 ~ 0.83~STWHIP~P ~ WEXIT 19:50 - 22:20 2.50 STWHIP P WEXIT 22:20 - 23:40 1.33 STWHIP P WEXIT 23:40 - 00:00 0.33 STWHIP P WEXIT for pulling CT. Use air tugger to pull CT into injector. Cut off grapple. Install cable boot for slack management. Install new stripper element. M/U CT riser to well. Line up valves to fill reel in reverse. Fill reel backwards to shift cable. Pressure test inner reef valve and reel 1502 line to 300 / 3,500 psi, good. Break off well. Cable is found at end of CT. Check cable for continuity and resistance. Install CT connector. Pull test to 35 Klbs, good. Install cable head. Pressure test to 3,500 psi, good. M/U BHA #1 -Nozzle + check valve to circulate out McOH. M/U CT riser to wellhead. Open swab and master valve. Initial WHP is 100 psi. RIH to 3000 ft and circ out MEOH to Tiger tank. 3.0 bpm, 3440 psi. Close choke and bullhead 2.0 bpm at 1600 psi. Pump 153 bbls. POH. Circ. 8.6 ppg in and 8.7 ppg out. Flow check at surface. Well flowing at 0.25 bpm, did not slow down. Shut in well. SIWHP built to 120 psi in 10 min. Ordered 290 bbls of 9.2 ppg Biozan to kill well. MI Plant mixing fluid for Nordic 2. We are second in line. RIH while holding 200-300 psi on choke. Circ 0.3 bpm, RIH to 12,000'. Open choke and circ bottoms up at 2.8 bpm. Circ 70 bbls with 8.7 ppg returns, at 70 bbls had 8.4-8.0 ppg returns, dump light returns. Had 7.9 ppg returns at 105 bbls pumped. Some crude with Biozan. 8.3 ppg at 115 bbls. 8.6 ppg at 125 bbls. 8.67 ppg in and out at 130 bbls. Stop pump and flow check. Well flowed at 0.25 bpm. Circ with nozzle at 12,000'. 8.65 ppg in/out. 1.7 bpm. Circ while waiting for Biozan. Flow check after Circ 300 bbls. Still had slight flow, 0.1 bpm. Wait for 9.2# Biozan. Circ. in 9.2 ppg Biozan to nozzle. 2.7 bpm in / 2.6 bpm out. Get 20 bbls out and POH while circ at 2.5 bpm. Well full of 9.2 PPG Biozan with BHA at surface. Flow Check at surface. Well is dead. SAFETY MEETING. Discuss contingencies and hazards for running BHA #2. UD BHA #1. P/U BHA #2 - 3.80 HCC Diamond window mill + 3.80 String Reamer + 2-7/8" BOT Xtreme motor + 2 jts 2-3/8 PH6 + 3" CoilTrack. RIH. Log GR down from 11,800 ft. Correct -38 ft. Continue RIH. Up wt is 43 Klbs at 12,000 ft. Tag whipstock dry at 12,043 ft. BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/3/2008 23:40 - 00:00 0.33 STWHIP P WEXIT Bring pump to 2.6 bpm, RIH slowly to start millin . - 8/4/2008 00:00 - 06:00 6.00 STWHIP P WEXIT tart milling. 12,043.6 ft 2.57 2.40 bpm ~ 3,360 psi. DWOB _ -0.02 Klbs. 01:00 - 12,044.4 ft 2.55 / 2.39 bpm ~ 3,240 psi. DWOB = -0.02 Klbs. ~ ( ~~ ~ ~ 1~~ 02:00 - 12,045.56 ft 2.54 / 2.39 bpm ~ 3,250 psi. DWOB = 0.18 Klbs. 03:00 - 12,046.50 ft 2.54 / 2.42 bpm ~ 3,400 psi. DWOB = 1.76 Klbs. 04:00 - 12,047.49 ft 2.55 / 2.43 bpm ~ 3,560 psi. DWOB = ,~~ ~j -\ A 1 ~ ~ G` (~ ~ ~ 3.64 Klbs. 05:00 - 12,048.30 ft 2.53 / 2.39 bpm ~ 3,410 psi. DWOB = 3.52 Klbs. 06:00 - 12,048.70 ft 2.53 / 2.41 bpm ~ 3,400 psi. DWOB = 3.49 Klbs. 06:00 - 07:30 1.50 STWHIP P WEXIT Mill 3.80" window thru 7", 29#, 13CR casing. 3200-3400 psi, 2.5 bpm, 2.4 bpm returns, 3.5K wob, 1 fph, Wipstock set at 1 Deg. ROHS. Milled to 12,050.3'. 07:30 - 10:30 3.00 STWHIP P WEXIT Mill 3.80" window, 3200-3500 psi, 2.5 bpm, 2.4 bpm returns, 3.5K wob, 1 fph, Milled to 12052.7. 10:30 - 12:15 1.75 STWHIP P WEXIT Mill 3.80" window, 3200-3500 psi, 2.5 bpm, 2.4 bpm returns, 3.5K wob, 1 fph, Exit 7" casing at 12,053'. Milled 1 ft formation at lfph to mill window with string mill. Milled to 12054'. Top of window at 12,044'. Bottom of window at 12,053'. 12:15 - 14:30 2.25 STWHIP P WEXIT Mill 10' of Kuparuk sandstone, 2.5 bpm, 3200-3500 psi, 4-5K wob, 5 fph. Swap to 9 PPG FloPro while milling formation. Milled to 12,063'. 14:30 - 16:15 1.75 STWHIP P WEXIT Ream window area. Ream up and down 2 times. Pull above window, stop pump and dry tag. Window area is clean. 16:15 - 18:30 2.25 STWHIP P WEXIT POH with milling BHA. Circ at 0.8 bpm, 1500 psi. 18:30 - 18:45 0.25 STWHIP P WEXIT Tag stripper, flow check well. SAFETY MEETING. Discuss hazards and mitigations for change out BHA. 18:45 - 19:25 0.67 STINHIP P WEXIT Lay down milling BHA. Mill comes out 3.78 no-go with a ring worn around the shoulder. String reamer comes out 3.79 no-go with normal wear. 19:25 - 20:30 1.08 DRILL P PROD1 Make up BHA #3 on catwalk. BHA #3 is 3-3/4" x 4-1/8" HCC bi-center bit, 2-7/8" BHI Xtreme motor with 1.9 deg AKO, 3.0" CoilTrack. Run BHA #3. 20:30 - 22:45 2.25 DRILL P PROD1 RIH. 22:45 - 23:10 0.42 DRILL P PROD1 Log GR down from 11,790 ft. Correct -32 ft. 23:10 - 23:30 0.33 DRILL P PROD1 Resume RIH. Pass through window at highside toolface, slight weight change at top of window. Tag bottom at 12,065 ft. Pick up and start pumps, slightly reduced drilling rate due to .,__._~. o,.~~,~,,,,o ,.,,.~~ o.. '~ BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 8/4/2008 23:10 - 23:30 0.33 DRILL P 23:30 - 00:00 0.50 DRILL P ~ 8/5/2008 ~ 00:00 - 04:00 ~ 4.00 ~ DRILL ~ P 04:00 - 04:15 I 0.25 DRILL P 04:15 - 05:30 1.25 DRILL P 05:30 - 05:45 0.25 DRILL P 05:45 - 06:45 1.00 DRILL P 06:45 - 08:00 1.251 DRILL ~ P 08:00 - 08:15 0.25 DRILL P 08:15 - 08:40 0.42 DRILL P 08:40 - 09:00 0.33 DRILL P 09:00 - 10:45 1.75 DRILL P 10:45 - 11:30 0.75 DRILL P 11:30 - 12:00 0.50 DRILL P 12:00 - 12:30 0.50 ~ DRILL ~ P 12:30 - 15:15 I 2.751 DRILL I P 15:15 - 15:40 0.42 DRILL P 15:40 - 17:45 ~ 2.08 ~ DRILL ~ P 17:45 - 20:10 2.42 DRILL P 20:10 - 20:40 0.50 DRILL P 20:40 - 21:55 1.25 DRILL P 21:55 - 23:30 1.58 DRILL P PROD1 long coil and used mud. PROD1 Drill from 12,063 ft at 2.23 / 2.07 bpm ~ 3600 - 3900 psi. Maintain HS toolface initially to build angle. Drill to 12,066 ft. PRODi Continue drilling from 12,066 ft at 2.33 / 2.24 bpm. ROP from 20 - 90 ft/hr. Drill to 12,200 ft. PROD1 Wiper trip from 12,200 ft to 12,070 ft. Up weight is 36 Klbs, clean pickup. PROD1 Drill from 12,200 ft at 2.34 / 2.22 bpm ~ 3600 - 4000 psi. ROP is 100 ft/hr. Drill to 12,350 ft. PROD1 Wiper trip from 12,350 ft to 12,070 ft. Up weight is 36 Klbs, clean pass up and down. PROD1 Drill from 12,350 ft at 2.35 / 2.26 bpm ~ 3600 - 3900 psi. ROP 60 - 160 ft/hr. Drilled to 12435'. PROD1 Drill left turn section, 2.35 bpm, 3600-4000 psi, 1.5K wob, 80L TF, 93 deg incl, 60 fph, 10.5 ecd, Drilled to 12500'. PROD1 Wiper trip to window. 2.3 bpm, 3400 psi. PROD1 Log GR tie-in at 11800'. Added 1 ft to CTD. PRODi RIH clean thru window and clean to bottom. PROD1 Drill left turn section, 2.3 bpm, 3500-4000 psi, 1 K wob, 80L TF, 92 deg incl, 100 fph, 10.5 ecd, Drilled to 11,650'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PRODi Drill left turn section, 2.3 bpm, 3500-4000 psi, 1-2K wob, 90L TF, 92 deg incl, 60 fph, 10.6 ecd, Drilled to 12,680'. PROD1 Drill left turn section, 2.3 bpm, 3500-4000 psi, 1-2K wob, 90L TF, 92 deg incl, 60 fph, 10.6 ecd, Drilled to PROD1 POH with build section BHA. Clean in open hole. Pump at full rate above 11400'. No problems. PROD1 PJSM with Baker, Schlumberger and Nordic rig teams. Discuss plan forward for BHA swap. Discuss hazards, including keeping the rig floor clear of unnecessary personnel. PROD1 Tag up at surface. Flow check well. No flow observed. Lay down BHA #3, build section BHA. Bit recovered and graded 2,1 with 1 chipped cutter and a very slight ring. Two jets were plugged with clay. Hook up rib steer BHA and check electrically. Pick up BHA #4 and stab. Running Hughes "Easy Drill" 3.75" bit, rib steer motor, RES tool and MWD. PROD1 RIH with BHA #4, Rib Steer BHA. PROD1 Log GR down from 11,795 ft. Correct -36 tt. PROD1 Pass through window, MAD pass with resistivity from 12,075 ft. PROD1 Tag bottom and drill from 12,701 ft. Start new mud down the CT. Initial ROPs 60 - 100 ft/hr with 60L toolface. New mud density is 9.05 ppg. Drill to 12,860 ft. - rnrnea: acwc~~o c. ~c.au r~~~ ~ ~ BP EXPLORATION Page 5 of 13 Operations Summary Report !Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT I Phase Description of Operations 8/5/2008 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip from 12,860 ft to 12,065 ft. Up weight is 36 Klbs, clean pass up and down. 8/6/2008 00:00 - 00:10 0.17 DRILL P PROD1 Continue wiper trip from 12,860 ft. 00:10 - 01:35 1.42 DRILL P PROD1 Drill from 12,860 ft ®2.3 / 2.2 bpm. ROP is 100 - 130 fUhr. Build angle to 93 deg as per Geo. Drill to 13,000 ft. 01:35 - 02:40 1.08 DRILL P PROD1 Wiper trip from 13,000 ft to 12,065 ft. Clean pass up and down. 02:40 - 04:00 1.33 DRILL P PROD1 Drill from 13,000 ft at 2.35 / 2.29 bpm ~ 3600 - 4000 psi. Push inclination to 95 deg to try and get into UC2-3 sands, no sign of this yet in GR. Rib steer is giving adequate build rates (>10 deg/100) when asked to. 04:00 - 05:10 1.17 DRILL P PROD1 Wiper trip from 13,150 ft to 11,500 ft, clean out 7" casing. 05:10 - 05:20 0.17 DRILL P PROD1 Log GR down from 11,805 ft to tie-in depth. No correction. 05:20 - 06:00 0.67 DRILL P PROD1 Continue wiper trip. 06:00 - 07:30 1.50 DRILL P PROD1 Tag bottom, resume drilling. ROP 120 fph, PVT=285 bbls. IAP=377 psi, OAP=298 psi. DHWOB=1500 lbs. Drilling at 2.33/2.2/3700 psi. Density 9.1 iNout. 07:30 - 08:30 1.00 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 35 klbs. Clean in open hole. 08:30 - 09:20 0.83 DRILL P PROD1 Tag bottom, resume drilling. ROP=95 fph. PVT=277 bbls. IAP=126, OAP=32 psi. (Both were bled down since morning crew change. DHWOB=2300 lbs. Drilling at 2.36/2.23/3800 psi. Density out =9.1. Free spin 3600 psi at 2.35 bpm. String weight while drilling = 2300 lbs. 09:20 - 10:15 0.92 DRILL P PROD1 Pump 20 bbl high viscosity sweep to see if it helps clean the hole. 10:15 - 11:30 1.25 DRILL P PROD1 Wiper trip to window. Minor 5k overpull off bottom. Clean at 35 klbs in open hole. Watch 25 bbl high vis sweep come back. Got about a 30% increase in cuttings when sweep came back. Not a huge benefit, but probably will pump additional sweeps going forward to assist hole cleaning. 11:30 - 13:00 1.50 DRILL P PRODi Resume drilling. PVT=243 bbls. IAP=211 psi, OAP=122 psi. DHWOB=1400 lbs. Drilling at 2.43/2.35/3800 psi. ROP 90 fph. Density 9.16 in/out. 100 bbls of new mud on location. Will add to the pits mid afternoon. Anew mud system with max tubes is ready at ML 13:00 - 14:00 1.00 DRILL P PROD1 Wiper trip to window. Slightly ratty off bottom for 200', clean above 13400'. Pump an additional 27 bbl high vis sweep to clean 7" as we get close. Drop pumps to minimum, pull thru the window. Pumps back to full rate. Pull up to 11800'. 14:00 - 14:40 0.67 DRILL P PROD1 Log tie in pass over GR charecter at 11800'. Make +2' correction. 14:40 - 15:20 0.67 DRILL P PROD1 Drop pumps thru the window. Continue wiper back in the hole. Pumping at full rate. Clean to bottom. Examine returns from 2nd sweep. About the same increase in solids returns from the second sweep. Some benefit, but not a tremendous amount more. 15:20 - 16:45 1.42 DRILL P PRODi Resume drilling. PVT=318 bbls. (Added 100 bbls to system). IAP=165 psi, OAP=95 psi. DHWOB=2800 lbs. RP=120 fph. Drilling at 2.49/2.4/3900 psi. BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/6/2008 16:45 - 18:30 1.75 DRILL P PROD1 Wiper trip to window. Clean off bottom at 36 klbs. Clean in open hole. 18:30 - 19:50 1.33 DRILL P PROD1 Drill from 13,750 ft at 2.50 / 2.42 bpm. Off bottom pressure 3,700 psi. PVT = 305 bbls, losing about 5 bbls/hr. Maintain 94 - 95 deg inc to get to 8,890 ft TVD. Call for new mud at 18:50, was informed 15 trucks are backed up at Pad 3 (G&I shut down). Drill to 13,864 ft. 19:50 - 20:20 0.50 DRILL P PRODi GR section from 13,680 ft to 13,864 appears to match UC2-3 sand that was seen in build. Short wiper trip while Geo team discusses plan forward. Possibly in the UC2-3 sand, decision made to turn down to 89 - 90 to match formation dip. 20:20 - 20:45 0.42 DRILL P PROD1 Drill from 13,864 ft to 13,900 ft. String wt is -7 Ktbs while drilling. Mud is 9.17 / 9.47 ppg. 20:45 - 22:35 1.83 DRILL P PROD1 Wiper trip to window. Up weight is 40 Klbs off bottom, dropping to 35 Klbs. Pump a hi-vis sweep around when back on bottom. 22:35 - 00:00 1.42 DRILL P PROD1 Drill from 13,900 ft. New geologic interpretation is that the bit is in UC2-3 sand, will reduce inclination to 84 deg to match formation dip. 23:00 -Start new mud downhole at 13,910 ft. Drill to 13,943 ft. 8/7/2008 00:00 - 01:20 1.33 DRILL P PROD1 Drill from 13,943 ft to 14,050 ft. Freespin is 200 psi higher after mud swap, very gradual increase. 01:20 - 03:10 1.83 DRILL P PROD1 Wiper trip 14,050 ft to window. Clean pickup 36 Klbs, no problems up or down. 03:10 - 05:05 1.92 DRILL P PROD1 Drill from 14,050 ft. Initial ROP is 100 - 120 ft/hr at 2.39 / 2.37 bpm, 3700 - 4000 psi. DWOB = 2.23 Klbs with -2 Klbs string weight. Mud density 9.05 / 9.17 ppg with ECD = 10.61 ppg. Push inclination down to 81 deg as per Geo. 05:05 - 06:25 1.33 DRILL P PROD1 Wiper trip from 14,200 ft to window. Up weight is 45 Ktbs off bottom. Drop pumps to minimum thru window. Pumps to full rate and wipe 7" up to 11550'. 06:25 - 06:40 0.25 DRILL P PROD1 Log tie in pass down over GR charecter from 11800'. Make +1' correction. 06:40 - 07:40 1.00 DRILL P PROD1 Continue back in the hole with the wiper trip. Pump at full rate in open hole. 07:40 - 08:55 1.25 DRILL P PROD1 Tag bottom, resume drilling. PVT=309 bbls. IAP=294 psi, OAP=180 psi. Free spin = 3550 psi at 2.4 bpm. Drilling at 2.36/2.26/3700 psi. DHWOB=2000 lbs. ROP=125 fph. String weight at surface = 2400 lbs. ROP=127 fph. 08:55 - 11:00 2.08 DRILL P PROD1 Wiper trip to window. Clean PU at 39 klbs. Clean to the window. Clean back in the hole. No bobbles. Pumped at full rate the entire way. 11:00 - 12:30 1.50 DRILL P PROD1 Resume drilling. PVT=302 bbls. IAP=391 psi, OAP=230 psi. Free spin=3500 psi at 2.37 psi. Drilling at 2.37/2.33/3700 psi. DHWOB=2800 lbs. String wt at surface = 1900 lbs. ROP=105 bpm. 12:30 - 14:50 2.33 DRILL P PROD1 Wiper trip to window. Clean PU. Clean in OH. Clean back to bottom. 14:50 - 16:10 1.33 DRILL P PROD1 Tag bottom, resume drilling. PVT=286 bbls. IAP=157 psi, OAP=229 psi. Free spin = 3770 psi at 2.5 bpm. Drilling at ~....~...I• RMGMl1(1R 9~17•~l~i Pful BP EXPLORATION Page 7 of 13 Operations Summary Report 'Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/7/2008 14:50 - 16:10 1.33 DRILL P 16:10 - 17:45 I 1.581 DRILL ~ P 17:45 - 19:30 I 1.75 DRILL P 19:30 - 20:50 1.33 DRILL P 20:50 - 00:00 ~ 3.17 ~ DRILL ~ P 8/8/2008 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ P 01:00 - 05:30 ~ 4.50 ~ DRILL ~ P 05:30 - 05:40 0.171 DRILL ~ P 05:40 - 06:40 1.00 DRILL P 06:40 - 06:50 0.17 EVAL P 06:50 - 07:45 0.92 EVAL P 07:45 - 08:15 0.50 EVAL P 08:15 - 10:30 ~ 2.25 ~ EVAL ~ P PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 10:30 - 13:00 ~ 2.50 ~ EVAL ~ N ~ HMAN ~ PROD1 13:00 - 13:50 0.83 EVAL P PROD1 13:50 - 15:30 1.67 EVAL P PROD1 2.5/2.44/3930 psi. DHWOB=2500 lbs. String wt at surface = 600 lbs. ROP=124 fph. Wiper trip to window. 5k overpufl off bottom. Clean in OH. Trip up in 7". Log Tie in pass down from 11800'. Make 0' correction. Finish wiper trip to bottom. Drill from 14,650 ft to 14,750 ft. Geo calls TD here based on reaching target TVD of 9,030 ft. Wiper trip and tie-in log back to 11,500 ft. Log GR down from 11,805 ft, no correction. Continue wiper trip. Continue wiper trip back to bottom. Tag at 14,750 ft. Pump 25 bbl viscous sweep on bottom, chase with 30 bbls old mud then lay in 100 bbls new mud while POOH. POOH, lay in new mud from TD. Pull through window, pump full rate out of hole. Open EDC at 11,500 ft. SWS arrives at 0400. Tag stripper and flow check well. SAFETY MEETING. Discuss hazards and crew responsibilities for change out BHA. UD BHA #4. Bit has 2 chipped cutters and some washing around the nose. Graded 2-1 Hold PJSM with rig hands only to discuss cleaning up and getting ready for Schlumberger logging operations. Pull off Baker UOC, spool off 20' of pipe and check for wear spots. Hold PJSM with all rig and logging hands on location. Discuss expectations for 3rd party hands on location. Assign points of contact and communications betwen rig and logging teams. Discuss proceedure for rigging up SLB equipment, and hazards associated. Discuss mitigations to hazards. Taking time to do the job correctly and having good communications was stressed. Rig up Schlumberger logging head and cables to collector and injector. Note -Schlumberger not using the logging head from Canada, they are using one put together locally. The Canadian head has not arrived in Deadhorse yet. Significant time spent getting the logging head built and set up properly. This time is due to non-standard equipment being used for the logging head, and 2 trips back to the SLB Deadhorse shop to get needed connectors, etc. Continue rigging up Slb logging head. Make up SLB logging tools. Note -The bottom nose on this logging tool string is a hard pointed bottom nose with a short 45 deg champher. The bottom nose has no hole finder ability. It may be difficult to get to TD if there are any washouts on this well. The toolstring is "centrallized" with 4, inline spring (weak) cementralizers. i.e., it won't probably be centralized very much in horizontal hole. Discussed with Schlumberger engineer before running in the hole. He says there are no alternatives. This is how the tool must be run. Continue rig up. • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Dater 8/2/2008 ..Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/8/2008 15:30 - 16:00 0.50 EVAL P PROD1 Check the tool electrically. Checks ok. Pick up logging tools. Install radioactive sources. Lower tools back down. Pull injector over. Run coif down and stab logging head onto tool string. RIH and perform shallow hole test. 16:00 - 18:00 2.00 EVAL N DFAL PROD1 Tools not working. Wait on schlumberger to troubleshoot 18:00 - 18:15 0.25 EVAL I P 18:15 - 19:00 0.75 EVAL P 19:00 - 21:40 2.67 EVAL P 21:40 - 23:25 1.75 EVAL P 23:25 - 00:00 0.58 EVAL P 8/9/2008 00:00 - 00:20 0.33 EVAL P 00:20 - 00:50 0.50 EVAL P 00:50 - 03:30 2.67 EVAL P 03:30 - 03:45 0.25 EVAL P 03:45 - 04:30 0.75 EVAL P 04:30 - 04:50 0.33 BOPSU P 04:50 - 05:20 0.50 DRILL P 05:20 - 06:00 0.67 DRILL P 06:00 - 06:15 0.25 CASE P 06:15 - 07:10 0.92 CASE P 07:10 - 08:30 1.33 CASE P 08:30 - 09:00 0.50 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 10:15 0.75 CASE P toolstring from logging unit. Can't sort out. Need to pull Toolstring out of hole and troubleshoot. Pull back to surface. Break apart toolstring and sort out. Found that sonic tool is not working and causing the problems. Only 1 sonic tool on location. No backups on the slope. Call town to discuss. Ok to log with out the sonic tool. Lay down the sonic and make up resistivity, density, neutron. Check at surface with jumpers. Checks ok. Install logging sources. PROD1 Safety meeting with night tour. Discuss plan forward and hazards for logging run. PROD1 Make up final connection on logging tool and test. Test is good. Make up CT riser. PROD1 Tag stripper, set depths and RIH. Pump 0.2 bpm while RIH. Tie-in depth from 11,700 ft to 12,040. Correct -30 ft. PROD1 Wt check is 46 Klbs. Pass through window and start logging down at 30 ft/min. PROD1 Stop at 14,740 ft and extend caliper arms. POOH logging at 50 fUmin. Increase pump to 0.52 bpm. PROD1 Continue logging up to 12,060 ft. PROD1 Stop at 12,060 ft and retract caliper arms. Log repeat section down to 12,500 ft. Data is good, pull through window and POOH. PROD1 POOH. PROD1 Tag stripper and flow check well. SAFETY MEETING. Discuss pinch points, overhead loads, and radioactive sources. PROD1 Lay down BHA #5, SLB open hole logging BHA. Load out logging tools and equipment. PROD1 Function test BOP rams from SLB panel. Good test. PROD1 Rig up hydraulic CT cutter. Cut 100 ft of pipe off. PROD1 Install CT connector. Pull test to 36 Klbs, good. RUNPRD Crew change, plan forward safety meeting. RUNPRD Make up safety joint, organize rig floor. Strap and drift pup joints, get ready to run liner. RUNPRD Install BHI UOC, test electrically and pressure test. All tested ok. RUNPRD PJSM re: running liner. RUNPRD Begin running 2-7l8" slotted liner. RUNPRD Hold kick drill for 2 new floor hands. Picked up and deployed safety joint. Closed bag and TIW valve. Hold debrief to discuss proceedure. Took 4 minutes to secure well and • BP EXPLORATION Operations Summary Report Page 9 of 13 Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2008 09:30 - 10:15 0.75 CASE P RUNPRD generally went as per proceedure. A couple minor glitchs that were reviewed with the hands. Check well for pressure, return t o normal liner running operations. Good drill. 10:15 - 15:00 4.75 CASE P RUNPRD Continue running liner as per proceedure. Running 2-7/8" slotted liner. 15:00 - 15:30 0.50 CASE P RUNPRD Make up BHI tools, stab injector. Shallow hole test BHI tools. All looking ok. Coil string weight at surface = 10600 lbs. DHW06=-14000 lbs. Attempt to open EDC. Got position missed errors. 15:30 - 17:15 1.75 CASE N DFAL RUNPRD BHI engineer indicates a lack of confidence in the EDC. Unstab the injector, lay down the EDC and PC. Change out the EDC. Pick up new EDC and PC, and make up BHA and stab on injector. Shallow hole test BHA. All working OK. This time, do not attempt to open the EDC. 17:15 = 20:25 3.17 CASE P RUNPRD RIH pumping at minimum rate thru the hydraulic GS. String weight at surface = 11,400 Ibs, DHWOB=-13680 lbs. Wt check at 12,000 ft is 48 Klbs. Pass thorugh window clean, run liner to 14500 ft and tag here. This depth places the billet about 54 ft outside the window (uncorrected), about 2 ft outside the window after correction. Tag in the same spot a second time, then work past. Work liner down slowly back and forth, with higher pump rates. Repeated pickups are clean, around 60 Klbs. Work down to 14,797 ft uncorrected, solid bottom here. Repeat and find bottom at same depth. 20:25 -20:40 0.25 CASE P RUNPRD Pick up prior to pumping off liner, CT wt is 57 Klbs, DWOB = 0.35 Klbs. Stack down to 0 CT wt and pump 2 bpm to release GS. After pumping off CT wt is 43 Klbs, DWOB = +10.3 Klbs. NOTE: DWOB was inadvertantly zeroed while RIH, so the absolute values are wrong, but the delta is correct. 20:40 - 21:10 0.50 EVAL P RUNPRD Log tie-in from 14,152 ft (11,752 ft GR depth). Correct -52 ft. This places top of Aluminum billet at 12,351 ft after correction. 21:10 - 23:30 2.33 CASE P RUNPRD POOH. 23:30 - 23:45 0.25 CASE P RUNPRD Tag stripper and flow check well. SAFETY MEETING. Discuss crew positions and hazards for changing out BHA. 23:45 - 00:00 0.25 CASE P RUNPRD Lay down liner running tools. Assemble HOT to CoilTrack, test on catwalk 8/10/2008 00:00 - 01:20 1.33 DRILL C PROD2 Continue to make up HOT and test. HOT fails test, make up new one and re-test, good. 01:20 - 01:50 0.50 DRILL C PROD2 M/U BHA #7 - 3.75" STR335 bit + 1.9 deg AKO X-treme + 3" CoilTrack. 01:50 - 04:10 2.33 DRILL C PROD2 RIH. 04:10 - 04:40 0.50 DRILL C PROD2 Log GR down from 11,820 ft. Correct -47 ft. 04:40 - 05:00 0.33 DRILL C PROD2 RIH and pass through window at HS toolface. Ta billet at 12 346 ft. 05:00 - 06:45 1.75 STWHIP C PROD2 Increase pump rate, start time drilling from 12,344.9 ft. Follow recommended time drill schedule. 2 stalls getting started. 06:45 - 10:00 3.25 STWHIP C PROD2 12345.7' Following Nordic 2 time milling schedule. Top of Printed: 8/25/2008 2:12:33 PM • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/10/2008 06:45 - 10:00 3.25 STWHIP C PROD2 whipstock last found at 12345'. Time milling at 1.2 fph. PVT=312 bbls. IAP=O psi, OAP=359 psi. DHWOB=500, String weight = 19,500#. Milling at 2.43/2.38/3680 psi. Drilled to 12378', did not see a departure off of the bottom of the tray, but expect that it should be about 5-6' long, which would put it at 12351'. Saw good indication on inclination that we are in a new hole. 10:00 - 12:00 2.00 STWHIP C PROD2 Ream the whipstock area with the as drilled tool face and at +/- 45 deg. Ream at 1 fpm. No bobbles or weight loss. 12:00 - 14:20 2.33 DRILL C PROD2 Begin drilling turn section of well. Drilling at 2.52/2.52/3860. Swapping to new mud. 14:20 - 14:55 0.58 DRILL C PROD2 Wiper trip to window. Stick pickup off bottom. Orient to 45 R, pull thru the whipstock with no problems. RBIH with no problems. 14:55 - 17:20 2.42 DRILL C PROD2 Resume drilling. PVT=295 bbls. IAP=O, OAP=390 psi. Free spin = 3615 psi at 2.43 bpm. Drilling at 70 fph, String wt=13 klbs. DHWOB=39001bs. 17:20 - 19:50 2.50 DRILL C PROD2 Turn section complete. POOH to pick up lateral section BHA. Clean in open hole and thru OH whipstock. Held tool face at "as drilled" when pulling thru whipstock. Pumps down when pulling thru the window. Pump at full rate while POH. 19:50 - 20:00 0.17 DRILL C PROD2 Tag stripper and flow check well. SAFETY MEETING. Discuss hazards and mitigations for change out BHA. 20:00 - 21:20 1.33 DRILL C PROD2 Lay down BHA #7. Bit comes out 1-1 with clay packed around the outside. Pick up BHA #8 - 3.75" Easy Drill + Rib Steer motor + Resistivity + 3" CoilTrack. 21:20 - 22:30 1.17 DRILL C PROD2 RIH. 22:30 - 22:50 0.33 DRILL X SFAL PROD2 Stop at 1600 ft. Problems with depth counter on injector. Anew one was put on during the BHA change but its not working. Swap back to the old one. 22:50 - 23:30 0.67 DRILL X SFAL PROD2 POOH from 1600 ft to tag stripper and reset depth. Counter was not working properly while RIH. Tag stripper at -360 ft and reset depth. 23:30 - 00:00 0.50 DRILL C PROD2 Reset depth and RIH. 8/11/2008 00:00 - 01:30 1.50 DRILL C PROD2 Continue RIH. 01:30 - 02:30 1.00 DRILL C PROD2 Log GR down from 11,805 ft. Missed the GR marker, pull up to 11,780 ft and log down. Correct -2 ft. 02:30 - 02:40 0.17 DRILL C PROD2 Continue RIH. Slight weight bobble passing through window. Shut off pump to pass billet, ensure arms are retracted. Pass billet with no weight fluctuations. 02:40 - 03:00 0.33 DRILL C PROD2 MAD pass from 12,361 ft to TD at 700 ft/hr. Motor work at 12,538 ft then fall through. 03:00 - 05:20 2.33 DRILL C PROD2 Tag at 12,593 ft. Up weight is 47 Klbs. Drill from 12,593 ft at 2.48 / 2.43 bpm ~ 3800 psi. CT weight is 8 - 12 Klbs with 3 - 6 Klbs DWOB. PVT = 299 bbls. Initial ROP is 90 ft/hr falling to 20 - 40 ft/hr. Drill to 12,750 ft. • BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/11/2008 05:20 - 06:00 0.67 DRILL C PROD2 Wiper trip from 12,750 ft to window. Clean pass up and down. Shut off pump going across billet, both ways. 06:00 - 06:15 0.25 DRILL C PROD2 Drill from 12,750 ft. 06:15 - 07:35 1.33 DRILL C PROD2 Drilling ahead from 12778'. PVT=295 bbls. IAP=O psi, OAP=350 psi. String wt = 3400 Ibs. DHWOB= 5600 lbs. ROP=80 fph. Free spin 3600 psi at 3600 psi. Drilling at 2.48/2.35/4050 psi. 07:35 - 08:30 0.92 DRILL C PROD2 Wiper trip. Clean PU. Clean in open hole. Clean thru billet, not even a bobble. Clean back in hole. 08:30 - 10:00 1.50 DRILL C PROD2 Drill ahead. PVT=290 bbls. IAP=O, OAP=421 psi. ROP = 108 fpm, String wt = 12300 Ibs, DHWOB=3000 lbs. Drilling at 2.46/2.42/3700 psi. Free spin = 3600 psi at 2.46 bpm. 10:00 - 11:00 1.00 DRILL C PROD2 Wiper trip. Clean PU. Clean in open hole. Clean thru the junction. Pull up thru the 7" to clean it. 11:00 - 11:25 0.42 DRILL C PROD2 Log tie in pass. Make +2' correction. 11:25 - 12:05 0.67 DRILL C PROD2 Wiper back to bottom. No problems. 12:05 - 13:30 1.42 DRILL C PROD2 Tag bottom, resume drilling. Free spin 3850 psi at 2.44 bpm. PVT=282 bbls. IAP=O psi, OAP=442 psi. Drilling at 2.46/2.40/3850 psi. ROP=112 fph. String wt=11000 Ibs. DHWOB=3600 Ibs. 13:30 - 14:35 1.08 DRILL C PROD2 Wiper trip. Clean pick up off bottom. Clean in open hole. 14:35 - 15:30 0.92 DRILL C PROD2 Tag bottom, resume drilling. Free spin 3580 psi at 2.5 bpm. PVT = 272 bbls. IAP=22 psi, OAP=485 psi. Drilling at 2.49/2.45/3750 psi. String weight = 12200 Ibs. DHWOB=2000 lbs. ROP=180 fph. ECD=10.5 ppg. ROP very high. Mix and pump a high vis sweep to assist in hole cleaning. 15:30 - 16:50 1.33 DRILL C PROD2 Wiper trip to window. Clean pickup off bottom. Clean up and back to bottom. Note -This lateral has a more challenging directional plan than the last lateral. It requires a continuous tum to the right, followed by a continuous turn to the left. The rib steer is delivering good directional control. No problems. 16:50 - 18:20 1.50 DRILL C PROD2 Last sweep OOH just as we got back to bottom. No significant difference in returned cuttings when sweep at surface. This is a good indication that present mud gives adiquate hole cleaning. Tag bottom, resume drilling. Free spin 3620 psi at 2.47 bpm. PVT=266 bbls. IAP=43 psi, OSP=492 psi. ECD=10.6 ppg. Drilling at 2.52/2.4/3860 psi. DHWOB=2500 lbs. String wt=11500 Ibs. Drill to 13,500 ft. 18:20 - 20:30 2.17 DRILL C PROD2 Wiper trip from 13,500 ft to window. Another 25 bbl sweep exits the bit just off bottom. Pull through window and clean 7" casing. Tie-in depth on the way back down. Correct +4 ft. 20:30 - 21:50 1.33 DRILL C PROD2 Drill from 13,500 ft. 2.49 / 2.43 bpm ~ 3900 FS. ROP is 100 - 150 ft/hr. Pump a viscous sweep around prior to wiper trip. 21:50 - 23:10 1.33 DRILL C PROD2 Wiper trip from 13,650 ft to window. Shut off pump passing billet. Clean pass up and down. 23:10 - 00:00 0.83 DRILL C PROD2 Drill from 13,650 ft at 2.48 / 2.45 bpm ~ 3900 psi free spin. o.~~fo.f• u~95/'1f1f1A 9.7T:i7 PM • • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/11/2008 23:10 - 00:00 0.83 DRILL C PROD2 Start swap to new mud. Drill to 13,755 ft. 8/12/2008 00:00 - 00:30 0.50 DRILL C PROD2 Continue drilling to 13,800 ft. 00:30 - 02:00 1.50 DRILL C PROD2 Wiper trip from 13,800 ft to window. Clean pass up and down. Shut down pump going past billet. 02:00 - 03:15 1.25 DRILL C PROD2 Drill from 13,800 ft at 2.44 / 2.38 bpm ~ 3650 FS. Mud swap is complete. Initial ROP is 100 ft/hr with 3-4 Klbs on DWOB. Drill to 13,952 ft. 03:15 - 05:00 1.75 DRILL C PROD2 Wiper trip from 13,952 ft to window. Clean pass up and down. New mud is 9.07 / 9.14 ppg. FS = 3500 psi ~ 2.45 / 2.42 bpm. Shut down pump going past billet. Clean 7" casing and log tie-in, correct +4.5 ft. 05:00 - 05:35 0.58 DRILL C PROD2 Drill from 13,952 ft at 2.52 / 2.39 bpm ~ 3700 psi FS. Steer downwards from here as per Geo. TD called at 14,017 ft by Geo due to drilling in wet zone. 05:35 - 06:50 1.25 DRILL C PROD2 Wiper trip to window. Clean PU off bottom. Clean in open hole. Clean thru billet. Wiper 7" up to bottom of cement donut. 06:50 - 07:05 0.25 DRILL C PROD2 Make Tie in pass down from 11800'. Make +2' correction. 07:05 - 08:15 1.17 DRILL C PROD2 Wiper trip back in the hole. Clean, no problems. 08:15 - 11:30 3.25 DRILL C PROD2 Tag bottom, begin pulling OOH. Making MAD pass, so pulling at 10 fpm, pumping at full rate. Should have a very clean hole. Clean hole, no problems while POH. 11:30 - 13:40 2.17 DRILL C PROD2 BHA up inside tubing. POH. 13:40 - 13:50 0.17 DRILL C PROD2 PJSM for LD Drilling BHA, Discuss. procedure, risks and mitigation 13:50 - 14:30 0.67 DRILL C PROD2 LD Drilling BHA 14:30 - 15:00 0.50 DRILL C PROD2 Cut 10' of coil for flat spot, install CC, PT 15:00 - 15:15 0.25 EVAL C PROD2 PJSM for RU SLB logging tools 15:15 - 20:45 5.50 EVAL C PROD2 MU SLB logging tools XO circ sub, OC eline socket 20:45 - 21:00 0.25 EVAL C PROD2 PJSM for handling and PU of sources for logging tools, discuss procedure and risks 21:00 - 22:00 1.00 EVAL C PROD2 PU SLB logging tools and install sources, change out BHI encoder for SLB encoder 22:00 - 00:00 2.00 EVAL C PROD2 RIH with logging too-s 8/13/2008 00:00 - 00:50 0.83 EVAL C PROD2 RIH to 12,000', and tie in (-1' correction) 00:50 - 03:45 2.92 EVAL C PROD2 Log at 30 fpm down to 10' above TD. Lay in liner running pill while logging up at 30 fpm up to 13,700', log back down to 10' above TD at 30 fpm, log up to the window at 60 fpm. 03:45 - 06:00 2.25 EVAL C PROD2 POOH 06:00 - 07:30 1.50 EVAL C PROD2 Crew change, PJSM to discuss procedure, risks and mitigation associated with source handling, and LD logging BHA 07:30 - 08:30 1.00 CASE C PROD2 RU floor for running liner 08:30 - 12:30 4.00 CASE C RUNPRD PU 83 joints of 2-7/8 L80 slotted liner. Wt 23K. 12:30 - 15:10 2.67 CASE C RUNPRD RIH to 12000. Wt Ck. 25.5K DN, 48K Up wt. Continue to RIH 14027'. PU wt 55K. 15:10 - 16:15 1.08 CASE C RUNPRD Circulate .8 ~ 1510 psi, 2.45 bpm ~ 4000. PU 38K. Open EDC.Circulate brine to liner running tool. 16:15 - 18:30 2.25 CASE C RUNPRD POH 90 fpm swapping well to 9 ppg brine.l.5bpm ~ 1330 psi. 18:30 - 18:45 0.25 CASE C RUNPRD Flow check well. Well is stable. 18:45 - 19:30 0.75 CASE C RUNPRD Standback injector, UD CoilTrak, PU nozzle, than stab injector. oamea• aMSMnna 9.19.3A PM ` • • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: P1-24 Common Well Name: P1-24 Spud Date: 8/2/2008 Event Name: REENTER+COMPLETE Start: 7/24/2008 End: 8/14/2008 Contractor Name: NORDIC CALISTA Rig Release: 8/14/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 8/13!2008 19:30 - 20:30 1.00 WHSUR P POST RIH w/ nozzle. RU Little Red. PT lines. 20:30 - 21:00 0.50 WHSUR P POST FP w/ diesel from 2200' to surface. 21:00 - 21:10 0.17 WHSUR P POST PJSM to P/U injector and B/O BHI tools. 21:10 - 21:30 0.33 WHSUR P POST B/O BHA tools and nozzle. 21:30 - 21:40 0.17 WHSUR P POST Flow check; well is dead. Install BPV w/ T-bar. 21:40 - 22:00 0.33 WHSUR P POST Stab injector onto well, pump corrosion inhibitor. 22:00 - 22:10 0.17 WHSUR P POST PJSM discussing hazards, mitigations, and safe work practices to blowdown the coil with N2. 22:10 - 00:00 1.83 WHSUR P POST PT N2 harlines, blow down coil w/ N2, bleed off coil pressure. 8/14/2008 00:00 - 03;00 3.00 WHSUR P POST Cut 3000' of coil and eline, rig down coil cutter 03:00 - 03:15 0.25 WHSUR P POST PJSM for securing reel and reel drop. Discuss procedures, risks, and mitigations 03:15 - 05:15 2.00 WHSUR P POST Secure coil and drop coil onto trailer for transport to drillsite 2 05:15 - 06:00 0.75 WHSUR P POST Standback injector. 06:00 - 07:30 1.50 WHSUR P POST ND BOP and secure. Install tree cap and test.to 3500 psi. Rig release 07:30 8-14-08. Printed: 8/25/2008 2:12:33 PM by BP Alaska Baker Hughes INTEQ Survey Report INTEQ Cotnpany: BP Amoco Date: 8/22/2008 Time: 15:21:29. Page: l Fielda Point McIntyre Co-ordinate(NE)Reference:. . Well: P1-24,.True North Site: Pt Mac 1 Vertical (TVD) Reference: 24,: Z4 8/28/199614;45 43.3 Well: P1-24 Section. (VS) Reference: Well (O.OON,O.OOE,344.40Azi) Wellpath: P1-24L1-01 Survey Calculation. Method: Minimum Curvature Db: Oracle - - ----- -- --- Field: Point McIntyre 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 ~ J ~ Site: Pt Mac 1 __ ___ TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5990567.02 ft Latitude: 70 22 48.179 N ~ From: Map Easting: 672146.94 ft Longitude: 148 36 0.861 W ~ Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.32 deg I J ---- _ Well: P1-24 P1-24 Slot Name: 24 Well Position: +N/-S 3876.66 ft Northing: 5994489.23 ft Latitude: 70 23 26.303 N +E/-W 2035.71 ft Easting : 674092.78 ft Longitude: 148 35 1.251 W Position Uncertainty: 0.00 ft L _ _ _ J' -- __- _ ___- - Wellpath: P1-24L1-01 Drilled From: P1-24L1 500292270361 Tie-on Depth: 12311.59 ft Current Datum: 24:24 8/28/1996 14:45 Height 43.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/8/2008 Declination: 23.18 deg ~I Field Strength: 57687 nT Mag Dip Angle: 80.99 deg Vertical Section: Depth From (TVD) +N/-S +E/- Direction ~, ft ft ft deg it 33 80 0.00 0.00 344.40 Survey Program for Definitive Wellpath 'i Date: 8/8/2008 Validated: Yes Version: 2 Actual From To Survey ft ft I Toolcode Tool Name __ - _ - __.. - -- ._ - - - 127.06 12011.63 2 : MWD -Standard (127.06-130 MWD MWD -Standard 12039.35 12311.59 MWD (12039.35-14750.00) (3) MWD MWD -Standard 12345.37 14017.00 MWD (12345.37-14017.00) MWD MWD -Standard Annotation MD TVD ~ ft ft 12311.59 9027.24 TIP 12345.37 9027.72 KOP 14017.00 9001.64 TD Survey: MWD Start Date: 8/18/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path by ~ BP Alaska ~ ~ Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 8/22!2008 Time: 15.21:29. Page: 2 Field: Point McIntyre Co-ordinate(NE) Reference: . Well: P1-24, True North Site: Pt Mac 1 Vertical (TVD} Reference: 24:24 8/28/199614:45 43.3 Well: P7-24 Section (VS}Reference: Well (0=00N,O.OOE,344:40Azi} Wellpathc P1-24L1-01 Survey Calculation Method: Minimum Curvature llb: Oracle Survey MD [ncl Azim TVD Sys TVD N/S E/W MapN MapE ft deg deg ft ft ft- ft ft tt 12311.59 86.28 331.29 12345.37 92.09 330.20 12371.93 95.41 329.35 12396.49 99.35 328.56 12424.09 97.72 327.66 12455.53 94.86 319.54 12487.19 93.59 313.61 12516.21 92.18 305.19 12547.23 91.44 292.49 12563.49 92.73 286.01 12578.03 93.40 280.76 12591.65 92.76 277.74 12607.25 91.47 276.71 12624.27 90.21 275.73 12641.63 89.05 275.34 12654.63 87.98 275.65 12670.97 88.31 274.81 12692.21 88.16 274.42 12703.57 88.10 274.57 12718.83 88.41 274.63 12735.09 88.31 274.90 12757.79 88.50 274.56 12770.85 89.14 273.87 12787.33 89.79 272.92 12800.83 90.25 272.39 12820.15 91.32 270.95 12834.63 91.26 270.96 12850.35 91.26 271.01 12866.93 91.47 269.04 12883.23 91.10 268.33 12903.87 91.26 267.83 12919.15 91.16 266.77 12933.99 91.13 266.59 12949.41 91.13 266.43 12965.47 91.17 266.45 12979.73 91.44 266.85 12995.57 91.38 266.11 13014.27 .91.69 266.54 13031.57 91.72 265.99 13047.09 91.81 265.45 13063.53 91.59 265.94 13080.85 91.59 266.24 13107.27 91.66 266.32 13121.99 91.75 265.67 13141.51 91.69 266.73 13156.05 91:50 266.67 13178.67 91.04 267.25 13197.79 90.15 267.49 13211.87 90.18 267.15 13226.23 89.60 267.72 13245.73 90.25 267.56 13259.25 90.15 268.71 13275.83 89.97 269.73 9027.24 9027.72 9025.98 9022.83 9018.73 9015.28 9012.95 9011.48 9010.50 9009.91 9009.13 9008.40 9007.82 9007.57 9007.68 9008.02 9008.55 9009.20 9009.58 9010.04 9010.51 9011.14 9011.41 9011.56 9011.56 9011.29 9010.96 9010.62 9010.22 9009.86 9009.43 9009.11 9008.81 9008.51 9008.19 9007.86 9007.47 9006.97 9006.46 9005.98 9005.49 9005.01 9004.26 9003.82 9003.24 9002.83 9002.33 9002.13 9002.09 9002.12 9002.15 9002.10 9002.08 8983.94 7037.89 8984.42 7067.35 8982.68 7090.24 8979.53 7111.11 8975.43 7134.28 8971.98 7159.41 8969.65 7182.33 8968.18 7200.71 8967.20 7215.63 8966.61 7220.98 8965.83 7224.34 8965.10 7226.53 8964.52 7228.49 8964.27 7230.33 8964.38 7232.01 8964.72 7233.25 8965.25 7234.74 8965.90 7236.45 8966.28 7237.34 8966.74 7238.56 8967.21 7239.91 8967.84 7241.78 8968.11 7242.74 8968.26 7243.72 8968.26 7244.35 8967.99 7244.91 8967.66 7245.15 8967.32 7245.42 8966.92 7245.43 8966.56 7245.05 8966.13 7244.36 8965.81 7243.64 8965.51 7242.78 8965.21 7241.84 8964.89 7240.85 8964.56 7240.01 8964.17 7239.04 8963.67 7237.84 8963.16 7236.72 8962.68 7235.56 8962.19 7234.33 8961.71 7233.15 8960.96 7231.43 8960.52 7230.40 8959.94 7229.11 8959.53 7228.27 8959.03 7227.08 8958.83 7226.20 8958.79 7225.54 8958.82 7224.90 8958.85 7224.09 8958.80 7223.65 8958.78 7223.43 -526.16 -542.66 -556.00 -568.56 -582.98 -601.51 -623.20 -645.58 -672.68 -688.01 -702.13 -715.56 -731.02 -747.94 -765.22 -778.15 -794.42 -815.58 -826.90 -842.10 -858.30 -880.91 -893.93 -910.38 -923.87 -943.18 -957.65 -973.37 -989.94 -1006.23 -1026.86 -1042.11 -1056.93 -1072.32 -1088.34 -1102.57 -1118.38 -1137.03 -1154.29 -1169.76 -1186.14 -1203.42 -1229.77 -1244.45 -1263.92 -1278.43 -1301.01 -1320.11 -1334.17 -1348.52 -1368.00 -1381.51 -1398.09 6001512.51 673402.93 6001541.57 673385.75 6001564.15 673371.88 6001584.71 673358.84 6001607.54 673343.89 6001632.23 673324.78 6001654.63 673302.56 6001672.48 673279.76 6001686.77 673252.32 6001691.77 673236.87 6001694.80 673222.67 6001696.67 673209.21 6001698.27 673193.70 6001699.72 673176.75 6001700.99 673159.43 6001701.93 673146.47 6001703.04 673130.18 6001704.26 673108.99 6001704.88 673097.65 6001705.75 673082.42 6001706.73 673066.20 6001708.07 673043.55 6001708.73 673030.51 6001709.32 673014.04 6001709.63 673000.55 6001709.74 672981.23 6001709.65 672966.76 6001709.55 672951.04 6001709.17 672934.47 6001708.42 672918.20 6001707.25 672897.60 6001706.17 672882.36 6001704.97 672867.57 6001703.67 672852.21 6001702.30 672836.21 6001701.14 672822.01 6001699.80 672806.23 6001698.17 672787.61 6001696.64 672770.38 6001695.12 672754.95 6001693.51 672738.59 6001691.93 672721.36 6001689.60 672695.05 6001688.23 672680.40 6001686.48 672660.97 6001685.31 672646.48 6001683.58 672623.94 6001682.26 672604.87 6001681.28 672590.82 6001680.30 672576.50 6001679.04 672557.04 6001678.29 672543.54 6001677.68 672526.97 VS' DLS .Tool ft deg/100ft 6920.19 0.00 MWD 6953.00 17.50 MWD 6978.64 12.90 MWD 7002.11 16.36 MWD 7028.31 6.73 MWD 7057.49 27.23 MWD 7085.40 19.10 MWD 7109.12 29.38 MWD 7130.78 40.99 MWD 7140.06 40.61 MWD 7147.09 36.35 MWD 7152.81 22.63 MWD 7158.85 10.58 MWD 7165.18 9.38 MWD 7171.44 7.05 MWD i 7176.11 8.57 MWD 7181.92 5.52 MWD 7189.25 1.97 MWD 7193.16 1.42 MWD 7198.42 2.07 MWD 7204.08 1.77 MWD 7211.96 1.72 MWD 7216.38 7.21 MWD 7221.75 6.98 MWD 7225.98 5.20 MWD 7231.71 9.29 MWD 7235.83 0.42 MWD 7240.32 0.32 MWD 7244.78 11.95 MWD 7248.80 4.91 MWD 7253.68 2.54 MWD ~ 7257.09 6.97 MWD 7260.25 1.23 MWD 7263.48 1.04 MWD 7266.83 0.28 MWD 7269.85 3.38 MWD ~~ 7273.17 4.69 MWD 7277.03 2.83 MWD 7280.58 3.18 MWD 7283.63 3.53 MWD 7286.85 3.27 MWD 7290.35 1.73 MWD 7295.79 0.40 MWD 7298.75 4.46 MWD 7302.73 5.44 MWD 7305.83 1.37 MWD 7310.75 3.27 MWD 7315.04 4.82 MWD 7318.18 2.42 MWD 7321.42 5.66 MWD 7325.89 3.43 MWD 7329.10 8.54 MWD 7333.34 6.25 MWD by BP Alaska Baker Hughes INTEQ Survey Report INTEQ ~ - -- Company: Field: BP Amoco Point McIntyre Date:. 8/22/2008 Time: 15 2129 Go-ordinate(NE) Reference: Well. P1 24, True North Page: 3 $ite: Pt Mac 1 Vertical (TVD) Reference: 24:24 8!28/1 996 14: 45 43.3 WeN: P1 -24 Section (VS) Reference: Well (O.OON,O .OOE,344.40Azi) Wellpatlr: P1 -24L1-01 Survey Calculation Method:- Minimum Curvature Db: Oracle: Survey MD Inct Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 13291. 53 89.97 270.37 9002. 09 8958. 79 7223. 44 -1413.79 6001677.33 672511.28 7337. 57 4.08 MWD 13307. 85 90.31 271.78 9002. 05 8958. 75 7223. 75 -1430.11 6001677.25 672494.96 7342. 25 8.89 MWD ~ 13322. 31 89.97 272.25 9002. 01 8958. 71 7224. 26 -1444.56 6001677.42 672480.50 7346. 63 4.01 MWD 13338. 03 90.09 272.49 9002. 01 8958. 71 7224. 91 -1460.27 6001677.71 672464.78 7351. 48 1.71 MWD 13352. 05 90.40 273.79 9001. 95 8958. 65 7225. 67 -1474.26 6001678.15 672450.77 7355. 98 9.53 MWD 13371. 23 90.95 273.76 9001. 72 8958. 42 7226. 94 -1493.40 6001678.97 672431.61 7362. 34 2.87 MWD 13387. 97 90.95 274.80 9001. 44 8958. 14 7228. 19 -1510.09 6001679.83 672414.90 7368. 03 6.21 MWD I 13405. 57 92.27 276.35 9000. 95 8957. 65 7229. 90 -1527.60 6001681.13 672397.36 7374. 39 11.56 MWD 13421. 93 92.21 277.51 9000. 31 8957. 01 7231. 87 -1543.83 6001682.72 672381.09 7380. 65 7.09 MWD 13439. 55 91.93 277.98 8999. 67 8956. 37 7234 .24 -1561.28 6001684.69 672363.59 7387. 63 3.10 MWD 13454. 45 91.94 279.22 8999. 17 8955. 87 7236 .47 -1576.00 6001686.57 672348.82 7393. 73 8.32 MWD 13473. 64 92.39 281.93 8998. 44 8955. 14 7239 .99 -1594.85 6001689.65 672329.90 7402. 19 14.31 MWD 13490. 02 92.18 282.57 8997. 79 8954. 49 7243 .46 -1610.84 6001692.75 672313.83 7409. 83 4.11 MWD 13503. 92 92.46 282.59 8997. 23 8953. 93 7246 .48 -1624.40 6001695.46 672300.20 7416. 39 2.02 MWD 13518. 06 92.40 283.39 8996. 63 8953. 33 7249 .66 -1638.16 6001698.31 672286.37 7423. 15 5.67 MWD 13533. 82 92.24 283.65 8995. 99 8952. 69 7253 .34 -1653.47 6001701.64 672270.98 7430. 81 1.94 MWD 13548. 50 92.43 283.87 8995. 39 8952. 09 7256 .83 -1667.72 6001704.79 672256.66 7438. 01 1.98 MWD 13565. 38 92.86 285.14 8994. 61 8951. 31 7261 .05 -1684.05 6001708.63 672240.24 7446. 46 7.94 MWD 13580. 18 92.27 285.32 8993. 95 8950. 65 7264 .94 -1698.31 6001712.18 672225.89 7454. 04 4.17 MWD 13595. 24 92.76 286.48 8993. 29 8949 .99 7269 .06 -1712.78 6001715.97 672211.33 7461. 90 8.35 MWD 13610 .10 92.77 287.26 8992. 57 8949 .27 7273 .37 -1726.99 6001719.94 672197.03 7469. 87 5.24 MWD 13626 .48 92.28 288.43 8991. 85 8948 .55 7278 .38 -1742.56 6001724.59 672181.34 7478. 89 7.74 MWD 13642 .26 92.55 289.66 8991. 19 8947 .89 7283 .53 -1757.46 6001729.39 672166.32 7487. 85 7.97 MWD i 13657 .76 92.06 290.73 8990. 56 8947 .26 7288 .87 -1772.00 6001734.39 672151.67 7496. 91 7.59 MWD 13676 .60 91.38 291.75 8990. 00 8946 .70 7295 .69 -1789.55 6001740.81 672133.96 7508. 20 6.50 MWD 13696 .08 90.03 291.93 8989. 76 8946 .46 7302 .94 -1807.63 6001747.63 672115.72 7520. 04 6.99 MWD 13711 .54 89.29 292.18 8989. 85 8946 .55 7308 .75 -1821.96 6001753.10 672101.26 7529. 48 5.05 MWD ~~ 13724 .98 88.49 293.31 8990. 11 8946 .81 7313 .94 -1834.35 6001758.00 672088.75 7537. 82 10.30 MWD 13740 :64 87.60 293.84 8990. 64 8947 .34 7320 .20 -1848.70 6001763.93 672074.27 7547. 70 6.61 MWD 13754 .06 86.68 294.74 8991. 31 8948 .01 7325 .71 -1860.91 6001769.15 672061.93 7556. 30 9.58 MWD 13767 .92 85.91 296.21 8992 .21 8948 .91 7331 .66 -1873.40 6001774.81 672049.31 7565 .38 11.95 MWD 13782 .48 85.91 296.41 8993 .25 8949 .95 7338 .10 -1886.42 6001780.94 672036.14 7575 .08 1.37 MWD i 13795 .40 86.22 296.77 8994 .14 8950 .84 7343 .87 -1897.94 6001786.44 672024.48 7583 .74 3.67 MWD 13812 .02 86.03 297.91 8995 .26 8951 .96 7351 .48 -1912.67 6001793.71 672009.58 7595 .04 6.94 MWD 13825 .58 86.31 299.44 8996 .16 8952 .86 7357 .98 -1924.54 6001799.92 671997.57 7604 .48 11.45 MWD 13839 .69 86.03 299.74 8997 .11 8953 .81 7364 .93 -1936.79 6001806.59 671985.17 7614 .47 2.90 MWD 13854 .92 87.05 300.66 8998 .03 8954 .73 7372 .57 -1949.92 6001813.93 671971.85 7625 .37 9.01 MWD 13870 .20 88.31 301.30 8998 .64 8955 .34 7380 .43 -1963.01 6001821.48 671958.59 7636 .45 9.25 MWD 13884 .78 89.26 302.25 8998 .95 8955 .65 7388 .11 -1975.40 6001828.86 671946.02 7647 .18 9.21 MWD 13898 .80 89.54 303.14 8999 .10 8955 .80 7395 .68 -1987.20 6001836.16 671934.05 7657 .64 6.65 MWD 13913 .26 89.23 304.00 8999 .26 8955 .96 7403 .68 -1999.25 6001843.87 671921.82 7668 .58 6.32 MWD 13930 .30 89.11 304.33 8999 .50 8956 .20 7413 .24 -2013.35 6001853.11 671907.50 7681 .59 2.06 MWD 13946 .42 89.38 305.98 8999 .71 8956 .41 7422 .53 -2026.53 6001862.08 671894.11 7694 .07 10.37 MWD 13963 .02 88.31 305.98 9000 .05 8956 .75 7432 .28 -2039.96 6001871.51 671880.46 7707 .08 6.45 MWD 14017 .00 88.31 305.98 9001 .64 8958 .34 7463 .98 -2083.62 6001902.18 671836.08 7749 .35 0.00 MWD ~ /VtLLFitJ-1U = 4CTUATOR = <B. ELEV = 3F. ELEV = <OP = Vlax Angle = datum MD = datum TV D = ~~ ~ f'' ~~ -L 4 I SAFEr~TES: ***4-112" CHROME TBG*** BAKER C 43.3' P1-24L1 & P1-24L1-01 2797' DRLG DRAFT _ 54 @ 6020' 2197' 4-1/2" CAMCO BAL-O SVLN, ID - 3.812" 11931' ® - W/O WR SSSV 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" I~ 3386' 7" CSG, 26#, L-80, ID = 6.276" 11108' TOP OF 7^ CSG 11108' GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DA TI 1 4310 4041 53 KBG-2-LS DOME INT 16 08/18/ 2 7397 5934 49 KBG-2-LS SO INT 20 08/18/i 3 9744 7424 50 KBG-2-LS DMY INT 0 06/20/i 4 11343 8458 49 KBG-2-LS DMY INT 0 06/20h 11403' I~ 7" BAKER S-3 PERT PKR, ID = 3.875" Minimum ID = 1.00" @ 13976' 2-7/8" BAKER TT O-RING SUB TOP OF 2-7/8" SLOTTED LINER I~ 11 1 /2" TBG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" I-i 1 7" BAKER GEN2 FLOW BY WHIPSTOCK I~ 1 PERFORATION SUMMARY REF LOG: GRILDT/CNL ON 09/23/96 ANGLE AT TOP PERF: 49° @ 12030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" SLTD 11433 - 13976 O 08/13/08 2-718" SLTD 12356 - 14719 O 08/09/08 ? 4 11465 - 11469 S 09/28/96 3-3/8" 4 12030 - 12070 O 04/20/97 2-7/8" 6 12090 - 12200 C 04/17/98 2-7/8" 6 12220 - 12270 C 04/17/98 ? 4 12264 - 12268 S 09!28!96 ? 4 12276 - 12280 S 09/28/96 PBTD I~ 12390' 11425' I--14-1 /2" HES X NIP, ID = 3.813" 1 I I I I I I 11436' 4-1/2" HES XN NIP, ID MILLED TO 3.80" I I I I I I I I 11447' 4-1/2" TBG TAIL WNVLEG, ID = 3.958" I I I I 11447' ELMD TT LOGGED 12/16/96 1 I I I I I I I I I 11448' SOZ CMT DONUT F/ 11448-11493 I I ID MILLED TO 3.80" I I I I FLOW THRU WHIPSTOCK 12,356' P1-24L' I I I I 2-7/8" SLOTTED LNR, 6.16#, 1-80, ID = 2.441" 14750' I I I I 1 - - ~ • ~ ~ - - -' I,'~'l~~ ` ~~----------------------i ~ ~~~_ I 2-7/8" SLOTTED LNR, 6.16#, I-80, ID = 2.441" ~ 14017' P 1-24L 1-01 I 7" CSG, 29#, 13CR, ID = 6.184" ~ 12470' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNfI- 10/03/96 D14 ORIGINAL COMPLETION WELL: P1-24 / L1 / L1-01 08114/08 NORDICI CTD M ULTILATERAL PERMfT No: 1961490 / 2081030 1 208???? 08/20/08 KDC/SV GLV C/O (08/18/08) API No: 50-029-22703-00 / -60 / -61 SEC 16, T12N, R14E, 1394.69' FEL 8 1598.35' FNL BP Exploration (Alaska) • SARAH PAL/N GOVERNOR oi4ca-7~A O~ ~ t7rt~7 333 W. 7th AVENUE, SUITE 100 CO1~T5T'iRQA7'IO1~T COl-IIrII5SI0I~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, PT. McIntyre Oil Pool, PBU P 1-24L 1-01 BP Exploration Alaska, Inc. Permit No: 208-124 Surface Location: 1364' FSL, 965' FEL, SEC. 16, T12N, R14E, UM Bottomhole Location: 4130' FSL, 4361' FEL, SEC. 09, T12N, R14E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well P 1-24, Permit No 196- 149, API 50-029-22703-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely Danie . Seamount, Jr. Chair DATED this C 3 day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. _ -. • ~ ~ ,~ ._ Sj STATE OF ALASKA ~ ~~~ ' ~ ALAS4c~IL AND GAS CONSERVATION COMMI~N ~~~ ' PERMIT TO DRILL ~,,I, 20 AAC 25.005 ;, 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 i"s'propo~e~~For: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU P1-24L1-01 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15537' TVD 8981'ss 12. Field /Pool(s): Prudhoe Bay Field /Point 4a. Location of Well (Governmental Section): Surface: 1364' FSL 965' FEL SEC 16 T12N R14E UM 7. Property Designation: ADL 02829& ADL 034622 McIntyre Pool , , . , , , Top of Productive Horizon: 2851' FSL, 1416' FEL, SEC. 09, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 9, 2008 Total Depth: 4130' FSL, 4361' FEL, SEC. 09, T12N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 910' 4b. Location of Well (State Base Plane Coordinates): Surface: x-674093 y- 5994489 Zone-ASP4 10. KB Elevation (Height above GL): 43.1' feet 15. Distance to Nearest Well Within Pool: 1,650' 16. Deviated Wells: Kickoff Depth: 12345 feet Maximum Hole An le: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3926 Surface: 3036 18. Casin Pro ram: S ecificatio n To - Settin De th -Bottom Quant' of Cement c.f. or sa ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3-3/4" 2-7/8" 6.16# 13Cr STL 4107' 11430' 8472'ss 15537' 8981'ss Uncemented Slotted Liner fig. PRESE NT WELL CONDITION SUMMARY (To he completed for Redrill and Re-entry Operations) Total Depth MD (ft): 13080' Total Depth TVD (ft): 9593' Plugs (measured): None Effective Depth MD (ft): 12390' Effective Depth TVD (ft): 9140' Junk (measured): None Casing Length: ize Cement Volume MD TVD Conductor /Structural 110' 20" 260 sx Arcticset A rox. 110' 110' Surface 3352' 9-5/8" 1290 sx CS III 327 sx'G' 250 sx CS II 3386' 3356' Intermediate Pr uc ion 12439' 7" 385 sx Class 'G' 1247 ' 9191' Liner P1-24L1 2405' 2-7/8" Uncemented Slotted Liner 12345' - 14750' Perforation Depth MD (ft): 12030' - 12270' Perforation Depth TVD (ft): 8908' - 9063' 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 certi that the foregoing is true and correct. Contact Greg Sarber, 564-4330 Printed Na a Greg artier Title CT Drilling Engineer Prepared By Name/Number: Si nature h FnR G• Sarbu- Phone 564-4330 Date '®5-08-~a Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number:o?~~ d API Number: 50-029-22703-61-00 Permit A Date: pr al 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 me_th/ane, gas hydrates, or gas contained shales: Samples Req'd: ^)tes L1Q No Mud Log Req'd: ^ Yes [a Na H2S Measures: Yes ^ No Directional Survey Req'd: ®'Yes ^ No Other: 3 ~~ Q 5 ~~'~ ~~. - APPROVED BY THE COMMISSION ~" Date ,COMMISSIONER Form 10-401 Revised 12/2`C105 ( ) ~,f ~ ~ I ~~ [~ ~ Submit In Duplicate ~f ' ` /'1 ~~~IS ~F~.. AUG 1 ~ 1D08 • by BPXA Pt. Mcintyre P1-24L1-01 CTD Sidetrack August 8, 2008 To: Tom Maunder Petroleum Engineer Alaska Oil ~ Gas Conservation Commission From: Greg Sarber CTD Engineer Date: August 8, 2008 Re: P1-24L1-01 Permit to Drill Permit to Drill approval is requested for a sidetrack lateral added to well P1-24L1. History - P1-24L1 is a well currently being drilled by Nordic 1, a coil tubing drilling rig. The lateral was drilled to test rock with poor reservoir quality in the western area of the Point Mcintyre field and to test a seismic anomaly that could have been related to better quality reservoir rock. The rig has just completed drilling on the P1-24L1 lateral. The rock quality and oil saturations on the P1-24L1 lateral came in favorably. The BP asset team feels that the results of the first lateral prove the concept of production from this part of the field and justify drilling a lateral to a secondary objective to the north of the existing lateral. The rig is currently running a full quad combo logging package. After the logging is completed, the plan is to run slotted liner from TD at 14,750' up to 12, 345'. An aluminum kickoff billet will be run on the top of the liner. This kickoff billet will be placed 300' outside the window. in the present well. The plan will be to kickoff of the sidetrack billet, then drill a lateral to the north of the existing lateral. The P1-24L1-01 lateral will be completed with slotted liner back into the parent well. The rig is currently on location and will need to begin operations on the new P1-24L1-01 lateral on Saturday August 9, 2008. A quick permit to drill approval would be appreciated. Reason for PTD Request -Your approval is requested give quick approval for a permit to drill a lateral from P1- 24L1. This lateral will target reserves north of the existing well. Rush attention is requested due to the presence of the rig on location, and the need to begin the sidetrack tomorrow, 8-9-2008. CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin on July 1, 2008) 1. S Pull K-valve; Run DGLVs; Drift & tag; SBHPS; Caliper liner & tubing from TD to surface. Drift w/DMY Whipstock 2. F MIT-IA, -OA 3. W PPPOT-T. Torque LDS. 4. E Set 4-1/2" x 7" WS at 12040' and 20 deg LOHS 5. W Set BPV 6. W PT MV, SV, WV 7. O Blind and bleed lines, remove well house, level pad Rig Work: (scheduled to begin on August 1, 2008) Covered by PTD 2081030 1. MIRU, Pull BPV, and test BOPE to 250 psi low and 3500 psi high. 2. Mill 3.80" window with KOP at 12040' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 310' (25 deg/100 planned) to a depth of 12350' MD. 4. Drill P1-24L1 Lateral: 4.125" OH, 2700' (12 deg/100 planned) to a depth of 15050' MD. 5. Run Schlumberger OH logs 6. Run 2-7/8" slotted liner leaving TOL at 12.345' 7. Work below covered by new permit to drill and will be lateral P1-24L1-01 8. Sidetrack off of aluminum billet at 12,345' with a 1.9 deg mud motor. Drill 30'. 9. Drill P1-24L1-01 lateral 3.75"~ize to a depth of 15,537'. 10. Run slotted 2-7/8" liner from TD to 11,430'. 11. Swap well to 2% KCL 12. Freeze protect well, install BPV, and RDMO Post-Rig Work: 1. Remove BPV. 2. Re-install wellhouse and FL's. 3. Test separator (5500' of slotted liner) Mud Program: • Well kill: 8.7 ppg brine • Milling/drilling: 8.7 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: 3.75" Casing Program: Slotted liner • 2-7/8", 13CR 6.16# STL Slotted Liner 11,430'md -15,537'md 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 95.48 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 910 ft. • Distance to nearest well within pool - 1650 ft. (P1-21 ). Anti-Collision • No Close approaches planned Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. • A Quad Combo (GR, Density, Neutron, and Sonic) OH log will be run on the P1-24L1 lateral only. Hazards • The maximum recorded H2S level on P1 Pad is 190 ppm. • The maximum recorded H2S level on P1-24 was 38 ppm on 4-7-2008. • Lost circulation risk is low. Reservoir Pressure • The max res. press. is estimated to be 3926 psi at 8900'ss (8.5 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 3036 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble NlELLHEAD = ClVV ACTUATOR = BAKER C KB ELEV = 43 3' BF ELE`J = KOP = 2797' Max Anyle = 54 C G020' Datum h1D = 11931' Dalurn ND = 8800' SS P 1-24 L 1& P 1-24 L 1-01 Proposed CTD Sidetrack 2197' ~4-172" CArv1C0 BAL-O SV W. D = 3.812' - Wi0 WR SSSV GAS L FT h14NDRELS ST h1) ND DEV TYPE VLV LATCH PORT DATE 1 4310 4041 53 KBG-2-LS DOME NT 16 12,'13?05 2 7397 5934 49 KBG-2-LS DOME NT 16 12;13.+05 3 9744 7424 50 KBG-2-LS SO NT 24 12.13;05 4 11343 6458 49 KBG-2-LS DtiN NT 0 12i13r05 Minimum ID = 3.725" @ 11436' 4-1I2" OTIS XN NIPPLE 4-1;2" TBG. 12.6#. 13CR. 0.0152 bpf. ID = 3.958" I~ 11447 PERFORATION SUMMARY REF LOG: GR'tDT;CNL ON 09!23;96 ANGLE AT TOP PERF: 49 (a 12030' Note: Refer to Roduclion DB for h'storical perf data SIZE SPF NTERVAL OpniSge DATE 3-36" d 12030 - 12070 O O~U20~97 2-re~ s 12090 - 1 zzoo O oa;1 r9s z-76• s 12220 -12270 O oaints8 ? 4 11465 - 11469 S 09128!96 ~ 4 12264 - 12268 S 09r28~96 ~ •1 12276 - 12260 S 09i28r96 w I 11108' I 1 1403' ~-{ 7" BAKER S-3 FEAT FKR. D = 3.875" 1 1425' ~4-1±2" HES X NIP. D = 3.813" I I I 11430' T`JPa! 4r~.er 2-7i8" slotted I I I I I 11436' 4-1;2" HES XN NP. ID rnik:d .a = 3.80" I I I I I I I I 11447' 4-tit"TBGTAL'J'~:+WLEG.~D=3.958" I I I I 1 1 qq7' ELhD TT LOGGED 12~ 16+96 I I I I I I I I SOZ Ch1T DONUT Fr 11448-11493. I I 11448' 1 I ID mllea to = ; 30. I I t I 1 I Flaw Thru Wipstock 12,345` I I j I I 1 I I TD=14,750' ~ ' P1-24L1 I ~ j, ` ~ I P1-24L1-01 TD=15,537' T CSG. 2911. 13CR. D = 6.184" DATE REV BY COhth£NTS DATE REV BY COA4hETJTS 10103/96 ORIGINAL COMPLETION 08,•1201 RN!TP CORRECTIONS 07+24+03 JBhhKK GLV G`O 12,'13+05 KDCiPJC GLV G'O 06±04+OS MSE PROPOSED CTD SIDETRACK PONT MCINTYRE UNIT WELL: Pt-24Lt FfR1v1R No: API No: 50-029-22703-06 SEC 16. T12N. R14E 1394.69' FEL & 1598 BP Exploration (Alaska) by + BP Alaska Baker Hughes INTEQ Planning Report /lit/ s Nu'c ins INTEQ Company: BP Amoco Date: '8/8/2008 Time: 11:27:30 Page: 1 Field: Point McIntyre Co-ordinate(NE) Reference: WeII; P1-24, True North Sites Pt Mac 1 Vertical (TVD) Reference: 24 s 24 8/28/1996 14:45. 43.3 Well: P1-24 Section(VS)Reference: Weff(O.OON,Ot00E,290.00Azi} Wellpath Plan 1, P1-24L1-01 Survey. Calculation Method: Minimum Curvature Db; Sybase Field: Point McIntyre 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: Pt Mac 1 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5990567.02 ft Latitude: 70 22 48.179 N From: Map Easting: 672146.94 ft Longitude: 148 36 0.861 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.32 deg Well: P1-24 Slot Name: 24 P 1-24 Well Position: +N/-S 3876.66 ft Northin g: 5994489.23 ft Latitude: 70 23 26.303 N +E/-W 2035.71 ft Easting : 674092.78 ft Longitude: 148 35 1.251 W Position Uncertainty: 0.00 ft Wellpath: Plan 1, P1-24L1-01 Drilled From: P1-24L1 Tie-on Depth: 12311.59 ft Current Datum: 24:24 8/28/1996 14:45 Height 43.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/8/2008 Declination: 23.18 deg Field Strength: 57687 nT Mag Dip Angle: 80.99 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.80 0.00 0.00 290.00 Plan: Plan 1 Date Composed: 8/8/2008 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min .Sec.. Deg Min Sec Dip. Dir. ft ft ft ft ft P1-24L1-01 Fault2 8973.30 7665.16 -2225.06 6002100.00 671690.00 70 24 41.685 N 148 36 6.473 W P1-24L1-01 Target3 8983.30 7492.63 -2119.04 6001930.00 671800.00 70 24 39.989 N 148 36 3.364 W P1-24L1-01 Target2 8998.30 7327.31 -1892.82 6001770.00 672030.00 70 24 38.363 N 148 35 56.731 W P1-24L1-01 Faultl 9013.30 7163.94 -1106.35 6001625.00 672820.00 70 24 36.758 N 148 35 33.678 W P1-24L1-01 Target4 9023.30 8072.56 -3395.97 6002480.00 670509.99 70 24 45.687 N 148 36 40.800 W P1-24L1-01 Targets 9027.30 7065.80 -543.45 6001540.01 673385.00 70 24 35.793 N 148 35 17.179 W Annotation MD TVD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100fT deg/100ft deg/1 OOft deg 12311.59 86.28 331.29 9027.24 7037.89 -526.16 0.00 0.00 0.00 0.00 12341.59 90.95 335.95 9027.96 7064.75 -539.48 22.00 15.58 15.54 45.00 12677.00 91.34 262.15 9020.13 7216.55 -812.75 22.00 0.12 - 22.00 271.12 13047.00 91.34 262.15 9011.47 7166.00 -1179.18 0.00 0.00 0.00 0.00 13547.00 90.88 289.65 9001.58 7216.88 -1671.68 5.50 -0.09 5.50 90.67 by ~ BP Alaska ~ Baker Hughes INTEQ Planning Report mar sus INTEQ Company: BP AmoCO Date: 8/8/2008 Time: 11:27;30 Page: 2 Fields Point McIntyre Co-ordinate(NE) Reference: WeIL Pi-24,;True North Sites Pt Mac 1 Vertical (TVD) Reference: 24:24 8/28/1996 14:45:43 .3 Well: P1-24 Section (VS) Reference: Well (O :OON,O.OOE,290.OOAzi) Wellpath: Pl an 1, P1-24L1-01 SurveyCalcWationMethodr Minimum Curvature Dh: `Sybase Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO `Target' ft deg deg ft ft ft deg/iOOft deg/100ft deg/100ft ` deg 13847.00 90.56 306.15 8997.78 7356.74 -1935.88 5.50 -0.11 5.50 91.00 14047.00 95.53 314.84 8987.13 7486.23 -2087.59 5.00 2.49 4.34 60.00 14097.00 95.44 317.35 8982.35 7522.09 -2122.11 5.00 -0.18 5.02 92.00 14297.00 90.28 311.23 8972.36 7661.43 -2265.00 4.00 -2.58 -3.06 230.00 14397.00 88.91 307.47 8973.06 7724.81 -2342.32 4.00 -1.37 -3.76 250.00 15197.00 86.69 275.52 9004.56 8014.03 -3076.41 4.00 -0.28 -3.99 265.50 15537.00 86.69 275.52 9024.17 8046.67 -3414.28 0.00 0.00 0.00 0.00 Survey MD Inch Azim SS TVD N/S E/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 12311.59 86.28 331.29 8983.94 7037.89 -526.16 6001512.51 673402.93 0.00 2901.53 0.00 MWD 12325.00 88.37 333.38 8984.56 7049.75 -532.38 6001524.22 673396.44 22.00 2911.43 45.00 MWD 12341.59 90.95 335.95 8984.66 7064.75 -539.48 6001539.04 673388.99 22.00 2923.23 44.90 MWD 12350.00 90.99 334.10 8984.52 7072.37 -543.03 6001546.58 673385.27 22.00 2929.17 271.12 MWD 12375.00 91.09 328.60 8984.07 7094.30 -555.01 6001568.22 673372.78 22.00 2947.93 271.09 MWD 12400.00 91.18 323.10 8983.57 7114.97 -569.03 6001588.56 673358.28 22.00 2968.18 270.99 MWD 12425.00 91.26 317.60 8983.04 7134.21 -584.97 6001607.42 673341.89 22.00 2989.74 270.88 MWD 12450.00 91.33 312.10 8982.47 7151.83 -602.69 6001624.63 673323.78 22.00 3012.41 270.76 MWD 12475.00 91.38 306.60 8981.88 7167.67 -622.00 6001640.01 673304.10 22.00 3035.98 270.64 MWD 12500.00 91.42 301.10 8981.27 7181.59 -642.75 6001653.44 673283.03 22.00 3060.24 270.51 MWD 12525.00 91.45 295.60 8980.64 7193.45 -664.74 6001664.78 673260.77 22.00 3084.96 270.37 MWD 12550.00 91.47 290.09 8980.01 7203.15 -687.76 6001673.94 673237.53 22.00 3109.91 270.24 MWD 12575.00 91.47 284.59 8979.36 7210.60 -711.61 6001680.83 673213.52 22.00 3134.86 270.10 MWD 12600.00 91.46 279.09 8978.73 7215.72 -736.06 6001685.39 673188.96 22.00 3159.59 269.95 MWD 12625.00 91.43 273.59 8978.09 7218.48 -760.89 6001687.57 673164.07 22.00 3183.87 269.81 MWD 12650.00 91.40 268.09 8977.48 7218.85 -785.87 6001687.35 673139.09 22.00 3207.47 269.67 MWD 12675.00 91.35 262.59 8976.88 7216.82 -810.77 6001684.74 673114.25 22.00 3230.17 269.54 MWD 12677.00 91.34 262.15 8976.83 7216.55 -812.75 6001684.43 673112.27 22.00 3231.94 269.41 MWD 12700.00 91.34 262.15 8976.29 7213.41 -835.53 6001680.76 673089.58 0.00 3252.27 0.00 MWD 12725.00 91.34 262.15 8975.71 7209.99 -860.29 6001676.77 673064.91 0.00 3274.37 0.00 MWD 12750.00 91.34 262.15 8975.12 7206.58 -885.05 6001672.78 673040.24 0.00 3296.47 0.00 MWD 12775.00 91.34 262.15 8974.53 7203.16 -909.81 6001668.79 673015.57 0.00 3318.56 0.00 MWD 12800.00 91.34 262.15 8973.95 7199.75 -934.56 6001664.80 672990.89 0.00 3340.66 0.00 MWD 12825.00 91.34 262.15 8973.36 7196.33 -959.32 6001660.81 672966.22 0.00 3362.76 0.00 MWD 12850.00 91.34 262.15 8972.78 7192.92 -984.08 6001656.82 672941.55 0.00 3384.86 0.00 MWD 12875.00 91.34 262.15 8972.19 7189.50 -1008.84 6001652.82 672916.88 0.00 3406.95 0.00 MWD 12900.00 91.34 262.15 8971.61 7186.08 -1033.60 6001648.83 672892.21 0.00 3429.05 0.00 MWD 12925.00 91.34 262.15 8971.02 7182.67 -1058.36 6001644.84 672867.54 0.00 3451.15 0.00 MWD 12950.00 91.34 262.15 8970.44 7179.25 -1083.12 6001640.85 672842.87 0.00 3473.25 0.00 MWD 12975.00 91.34 262.15 8969.85 7175.84 -1107.88 6001636.86 672818.20 0.00 3495.34 0.00 MWD 13000.00 91.34 262.15 8969.27 7172.42 -1132.63 6001632.87 672793.53 0.00 3517.44 0.00 MWD 13025.00 91.34 262.15 8968.68 7169.01 -1157.39 6001628.88 672768.86 0.00 3539.54 0.00 MWD 13047.00 91.34 262.15 8968.17 7166.00 -1179.18 6001625.37 672747.15 0.00 3558.98 0.00 MWD 13050.00 91.34 262.31 8968.10 7165.60 -1182.15 6001624.89 672744.19 5.50 3561.64 90.67 MWD 13075.00 91.32 263.69 8967.51 7162.55 -1206.96 6001621.27 672719.46 5.50 3583.91 90.67 MWD 13100.00 91.31 265.06 8966.94 7160.10 -1231.83 6001618.24 672694.65 5.50 3606.44 90.71 MWD 13125.00 91.29 266.44 8966.38 7158.25 -1256.76 6001615.81 672669.78 5.50 3629.23 90.74 MWD 13150.00 91.27 267.81 8965.82 7156.99 -1281.72 6001613.98 672644.85 5.50 3652.26 90.77 MWD 13175.00 91.25 269.19 8965.27 7156.34 -1306.70 6001612.74 672619.89 5.50 3675.51 90.80 MWD 13200.00 91.23 270.56 8964.73 7156.28 -1331.70 6001612.10 672594.91 5.50 3698.98 90.83 MWD 13225.00 91.21 271.94 8964.20 7156.83 -1356.68 6001612.07 672569.92 5.50 3722.64 90.86 MWD 13250.00 91.19 273.31 8963.67 7157.97 -1381.65 6001612.63 672544.93 5.50 3746.50 90.89 MWD 13275.00 91.16 274.69 8963.16 7159.72 -1406.58 6001613.79 672519.97 5.50 3770.52 90.92 MW D by ~ BP Alaska ~ ~.-r s ~$ Baker Hughes INTEQ Planning Report INTEQ Company:.: BP Amoco Date: 8/8/2008 Time: 1127:30 Page: 3 Field: Point McIntyre Co-ordinate(NE) Reference: WeIL' P 1-24, True North Site:. Pt Mac 1 Vertical (TVD) Reference: 24:24 8/28!1996 14:45:43.3 Well: Pi -24 Section (VS) Reference: Well (O. OON,O.OOE,290.OOAzi)' Wellpatb: Plan 1, P1-24L1-01 Survey Calculation Method: Minimu m Curvatu re Db: Sybase Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft degh OOft ft deg 13300.00 91.14 276.06 8962.66 7162.06 -1431.47 6001615.55 672495.04 5.50 3794.71 90.95 MWD 13325.00 91.12 277.44 8962.16 7165.00 -1456.29 6001617.91 672470.15 5.50 3819.04 90.97 MWD 13350.00 91.09 278.81 8961.68 7168.53 -1481.03 6001620.87 672445.34 5.50 3843.50 91.00 MW D 13375.00 91.07 280.19 8961.21 7172.65 -1505.69 6001624.42 672420.60 5.50 3868.07 91.03 MW D 13400.00 91.04 281.56 8960.75 7177.37 -1530.23 6001628.56 672395.95 5.50 3892.75 91.05 MW D 13425.00 91.02 282.94 8960.30 7182.67 -1554.66 6001633.29 672371.41 5.50 3917.52 91.08 MW D 13450.00 90.99 284.31 8959.86 7188.56 -1578.95 6001638.61 672346.99 5.50 3942.36 91.10 MW D 13475.00 90.96 285.69 8959.44 7195.03 -1603.09 6001644.52 672322.70 5.50 3967.26 91.13 MWD 13500.00 90.93 287.06 8959.02 7202.08 -1627.08 6001651.00 672298.56 5.50 3992.21 91.15 MWD 13525.00 90.91 288.44 8958.62 7209.70 -1650.88 6001658.07 672274.59 5.50 4017.18 91.17 MWD 13547.00 90.88 289.65 8958.28 7216.88 -1671.68 6001664.76 672253.63 5.50 4039.18 91.19 MW D 13550.00 90.88 289.81 8958.23 7217.89 -1674.50 6001665.70 672250.79 5.50 4042.18 91.00 MW D 13575.00 90.85 291.19 8957.85 7226.64 -1697.91 6001673.91 672227.18 5.50 4067.17 91.00 MWD 13600.00 90.83 292.56 8957.49 7235.96 -1721.11 6001682.68 672203.77 5.50 4092.16 91.02 MWD 13625.00 90.80 293.94 8957.13 7245.82 -1744.08 6001692.01 672180.58 5.50 4117.11 91.04 MWD 13650.00 90.78 295.31 8956.79 7256.24 -1766.80 6001701.89 672157.62 5.50 4142.03 91.06 MWD 13675.00 90.75 296.69 8956.45 7267.20 -1789.27 6001712.32 672134.91 5.50 4166.89 91.08 MW D 13700.00 90.72 298.06 8956.13 7278.69 -1811.47 6001723.30 672112.45 5.50 4191.68 91.10 MWD 13725.00 90.70 299.44 8955.82 7290.71 -1833.38 6001734.81 672090.26 5.50 4216.39 91.12 MW D 13750.00 90.67 300.81 8955.52 7303.26 -1855.00 6001746.84 672068.36 5.50 4240.99 91.14 MW D 13775.00 90.64 302.19 8955.24 7316.32 -1876.32 6001759.40 672046.74 5.50 4265.49 91.15 MW D 13800.00 90.61 303.56 8954.96 7329.89 -1897.31 6001772.48 672025.44 5.50 4289.86 91.17 MWD 13825.00 90.59 304.94 8954.70 7343.96 -1917.98 6001786.06 672004.46 5.50 4314.09 91.18 MWD 13847.00 90.56 306.15 8954.48 7356.74 -1935.88 6001798.43 671986.26 5.50 4335.28 91.20 MWD 13850.00 90.64 306.28 8954.45 7358.52 -1938.30 6001800.14 671983.80 5.00 4338.16 60.00 MWD 13875.00 91.26 307.36 8954.03 7373.49 -1958.31 6001814.65 671963.45 5.00 4362.09 60.00 MW D 13900.00 91.88 308.44 8953.35 7388.85 -1978.03 6001829.54 671943.38 5.00 4385.87 60.02 MW D 13925.00 92.51 309.53 8952.39 7404.56 -1997.45 6001844.80 671923.60 5.00 4409.49 60.05 MWD 13950.00 93.13 310.61 8951.16 7420.63 -2016.55 6001860.42 671904.13 5.00 4432.95 60.09 MWD 13975.00 93.75 311.70 8949.66 7437.06 -2035.34 6001876.40 671884.96 5.00 4456.22 60.14 MWD 14000.00 94.37 312.79 8947.89 7453.82 -2053.81 6001892.72 671866.12 5.00 4479.30 60.21 MWD 14025.00 94.99 313.87 8945.85 7470.92 -2071.93 6001909.39 671847.60 5.00 4502.18 60.29 MWD 14047.00 95.53 314.84 8943.83 7486.23 -2087.59 6001924.34 671831.58 5.00 4522.14 60.38 MWD 14050.00 95.53 314.99 8943.54 7488.34 -2089.71 6001926.40 671829.42 5.00 4524.85 92.00 MW D 14075.00 95.48 316.24 8941.14 7506.12 -2107.11 6001943.77 671811.61 5.00 4547.28 92.01 MW D 14097.00 95.44 317.35 8939.05 7522.09 -2122.11 6001959.38 671796.25 5.00 4566.83 92.13 MW D 14100.00 95.37 317.25 8938.76 7524.28 -2124.13 6001961.52 671794.17 4.00 4569.49 230.00 MWD 14125.00 94.72 316.48 8936.56 7542.45 -2141.16 6001979.30 671776.73 4.00 4591.70 229.99 MWD 14150.00 94.08 315.72 8934.65 7560.41 -2158.44 6001996.85 671759.03 4.00 4614.09 229.92 MWD 14175.00 93.43 314.95 8933.01 7578.16 -2175.98 6002014.18 671741.09 4.00 4636.63 229.86 MWD 14200.00 92.79 314.19 8931.65 7595.68 -2193.76 6002031.27 671722.90 4.00 4659.34 229.81 MW D 14225.00 92.14 313.42 8930.58 7612.96 -2211.79 6002048.14 671704.48 4.00 4682.19 229.77 MWD 14250.00 91.49 312.66 8929.79 7630.02 -2230.05 6002064.76 671685.83 4.00 4705.18 229.74 MWD 14275.00 90.85 311.90 8929.27 7646.83 -2248.54 6002081.14 671666.95 4.00 4728.31 229.72 MWD 14297.00 90.28 311.23 8929.06 7661.43 -2265.00 6002095.34 671650.15 4.00 4748.77 229.70 MWD 14300.00 90.24 311.11 8929.04 7663.40 -2267.26 6002097.27 671647.85 4.00 4751.57 250.00 MWD 14325.00 89.90 310.17 8929.02 7679.68 -2286.23 6002113.10 671628.51 4.00 4774.96 250.00 MW D 14350.00 89.55 309.23 8929.14 7695.65 -2305.47 6002128.62 671608.91 4.00 4798.50 250.00 MWD 14375.00 89.21 308.29 8929.40 7711.31 -2324.96 6002143.81 671589.06 4.00 4822.17 250.00 MWD 14397.00 88.91 307.47 8929.76 7724.81 -2342.32 6002156.91 671571.39 4.00 4843.10 250.01 MWD 14400.00 88.90 307.35 8929.82 7726.63 -2344.70 6002158.67 671568.96 4.00 4845.96 265.50 MW D 14425.00 88.82 306.35 8930.32 7741.62 -2364.70 6002173.19 671548.62 4.00 4869.89 265.50 MW D by ~ BP Alaska ~ Baker Hughes INTEQ Planning Report ~.r sAs INTEQ Company: BP AmoCO Date: 8/8/2008: Time: 11:27:30 Page: 4' Field: Point McIntyre Co-ordinate(NE)12eference: WeIL P 1-24, True North Site: Pt Mac 1 Vertical (TVD) Reference: : 24:24 8/28/1996 14:45 43.3 Well: P1 -24 Section {VS)Reference: Well'(O .OON,O.OOE,290f00Azi) Wellpath: Plan 1, P1-24L1-01 Survey Calculation Method: Minimu m Curvature Db: Sybase' Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 14450.00 88.75 305.35 8930.85 7756.26 -2384.96 6002187.35 671528.03 4.00 4893.93 265.52 MWD 14475.00 88.67 304.35 8931.41 7770.54 -2405.47 6002201.16 671507.19 4.00 4918.09 265.54 MWD 14500.00 88.59 303.36 8932.01 7784.47 -2426.23 6002214.59 671486.12 4.00 4942.35 265.57 MWD 14525.00 88.51 302.36 8932.64 7798.03 -2447.22 6002227.66 671464.82 4.00 4966.72 265.59 MWD 14550.00 88.44 301.36 8933.31 7811.22 -2468.45 6002240.35 671443.29 4.00 4991.18 265.61 MWD 14575.00 88.36 300.37 8934.00 7824.04 -2489.90 6002252.67 671421.55 4.00 5015.72 265.64 MWD 14600.00 88.29 299.37 8934.74 7836.48 -2511.57 6002264.60 671399.60 4.00 5040.34 265.67 MW D 14625.00 88.21 298.37 8935.50 7848.55 -2533.45 6002276.15 671377.44 4.00 5065.03 265.70 MWD 14650.00 88.14 297.37 8936.30 7860.23 -2555.54 6002287.32 671355.09 4.00 5089.78 265.73 MW D 14675.00 88.06 296.37 8937.12 7871.52 -2577.83 6002298.09 671332.54 4.00 5114.58 265.76 MW D 14700.00 87.99 295.38 8937.98 7882.43 -2600.31 6002308.46 671309.82 4.00 5139.44 265.79 MWD 14725.00 87.92 294.38 8938.88 7892.94 -2622.97 6002318.44 671286.92 4.00 5164.33 265.83 MWD 14750.00 87.85 293.38 8939.80 7903.05 -2645.82 6002328.02 671263.84 4.00 5189.26 265.86 MWD 14775.00 87.78 292.38 8940.75 7912.76 -2668.83 6002337.20 671240.61 4.00 5214.21 265.90 MWD 14800.00 87.71 291.38 8941.74 7922.07 -2692.01 6002345.96 671217.22 4.00 5239.17 265.94 MWD 14825.00 87.64 290.39 8942.76 7930.98 -2715.35 6002354.32 671193.68 4.00 5264.15 265.98 MW D 14850.00 87.57 289.39 8943.80 7939.48 -2738.84 6002362.27 671170.00 4.00 5289.13 266.02 MWD 14875.00 87.50 288.39 8944.88 7947.56 -2762.47 6002369.80 671146.19 4.00 5314.10 266.06 MW D 14900.00 87.43 287.39 8945.98 7955.23 -2786.24 6002376.92 671122.25 4.00 5339.06 266.10 MWD 14925.00 87.36 286.39 8947.12 7962.49 -2810.13 6002383.61 671098.20 4.00 5363.99 266.15 MWD 14950.00 87.30 285.39 8948.28 7969.33 -2834.15 6002389.89 671074.03 4.00 5388.90 266.19 MWD 14975.00 87.23 284.39 8949.48 7975.74 -2858.28 6002395.74 671049.75 4.00 5413.77 266.24 MWD 15000.00 87.17 283.39 8950.70 7981.74 -2882.52 6002401.17 671025.38 4.00 5438.60 266.29 MWD 15025.00 87.11 282.39 8951.95 7987.31 -2906.86 6002406.18 671000.92 4.00 5463.38 266.34 MWD 15050.00 87.04 281.40 8953.22 7992.46 -2931.29 6002410.75 670976.38 4.00 5488.10 266.39 MWD 15075.00 86.98 280.40 8954.53 7997.18 -2955.81 6002414.90 670951.76 4.00 5512.75 266.44 MWD 15100.00 86.92 279.40 8955.86 8001.47 -2980.40 6002418.61 670927.08 4.00 5537.32 266.49 MW D 15125.00 86.86 278.40 8957.21 8005.33 -3005.07 6002421.90 670902.33 4.00 5561.82 266.54 MW D 15150.00 86.80 277.40 8958.59 8008.76 -3029.79 6002424.75 670877.54 4.00 5586.23 266.60 MW D 15175.00 86.74 276.40 8960.00 8011.75 -3054.57 6002427.17 670852.70 4.00 5610.54 266.65 MWD 15197.00 86.69 275.52 8961.26 8014.03 -3076.41 6002428.94 670830.81 4.00 5631.84 266.71 MWD 15200.00 86.69 275.52 8961.43 8014.32 -3079.40 6002429.16 670827.82 0.00 5634.74 0.00 MWD 15225.00 86.69 275.52 8962.88 8016.72 -3104.24 6002430.98 670802.93 0.00 5658.91 0.00 MWD 15250.00 86.69 275.52 8964.32 8019.12 -3129.08 6002432.80 670778.04 0.00 5683.07 0.00 MWD 15275.00 86.69 275.52 8965.76 8021.52 -3153.92 6002434.62 670753.15 0.00 5707.24 0.00 MWD 15300.00 86.69 275.52 8967.20 8023.92 -3178.77 6002436.44 670728.26 0.00 5731.41 0.00 MW D 15325.00 86.69 275.52 8968.65 8026.32 -3203.61 6002438.26 670703.37 0.00 5755.57 0.00 MW D 15350.00 86.69 275.52 8970.09 8028.72 -3228.45 6002440.08 670678.48 0.00 5779.74 0.00 MWD 15375.00 86.69 275.52 8971.53 8031.12 -3253.29 6002441.90 670653.59 0.00 5803.90 0.00 MWD 15400.00 86.69 275.52 8972.97 8033.52 -3278.14 6002443.72 670628.70 0.00 5828.07 0.00 MWD 15425.00 86.69 275.52 8974.41 8035.92 -3302.98 6002445.54 670603.81 0.00 5852.23 0.00 MWD 15450.00 86.69 275.52 8975.86 8038.32 -3327.82 6002447.36 670578.92 0.00 5876.40 0.00 MWD 15475.00 86.69 275.52 8977.30 8040.72 -3352.67 6002449.18 670554.03 0.00 5900.56 0.00 MW D 15500.00 86.69 275.52 8978.74 8043.11 -3377.51 6002451.00 670529.14 0.00 5924.73 0.00 MWD 15525.00 86.69 275.52 8980.18 8045.51 -3402.35 6002452.82 670504.25 0.00 5948.89 0.00 MWD 15537.00 86.69 275.52 8980.87 8046.67 -3414.28 6002453.70 670492.30 0.00 5960.49 0.00 MWD s • Rig Floor to Top of Well Y-09AL1 2.25 9.23 5.00 ~- 12.65 r~~ 13.56 ~~- 2 L'16" 5000 psi . R-~= Mud Cross "- 14.89 HCR M ' ChoKe Line 16.10 f-~ 16.66 •- ~ 20.04 ~ Tree Size .~ 22.88 it Armular 7 l/16' Annular x 5000 psi 7 I ' I F,' 5000 psi. RX-46 tit~~,i:> TC?T -~'~ 7 1i 16" 5000 psi RX-46 Master Valve Lock Down Screws Ground Level Sidetrack of P 1-24L 1 U Page 1 of 2 ~~ Maunder, Thomas E (DOA) From: Sarber, Greg J [SarberJG@BP.comJ Sent: Friday, August 08, 2008 10:38 AM To: Maunder, Thomas E (DOA) Subject: RE: Sidetrack of P1-24L1 -- ~~ ~ ~ y ~*~ a~~-~a~~ Tom, Thank you very much. I appreciate the approval to continue operations without having to move the rig off of this well. I will get the required material for the PTD application to Terrie Hubble in the BP office this afternoon. She will have a courier bring the PTD application to the AOGCC by the end of day today. Thank you for your help. Cheers, Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 08, 2008 10:32 AM To: Maunder, Thomas E (DOA); Sarber, Greg J Cc: McMullen, John C; McLaughlin, Sean M; Miller, Kenneth C; Archey, Pat; Strait, David R; Saltmarsh, Arthur C (DOA) Subject: RE: Sidetrack of Pi-24L1 Greg, et al, I have spoken with Commissioner Foerster. She asked me to convey her oral approval for the continuation of operations including the spudding of P1-24L1-01. A permit to drill application should be submitted as soon as possible. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, August 08, 2008 8:02 AM To: 'Sarber, Greg J' Cc: McMullen, John C; McLaughlin, Sean M; Miller, Kenneth C; Archey, Pat; Strait, David R Subject: RE: Sidetrack of P1-24L1 Greg, et al, I will speak with the Commissioners and get back with you. You are correct regarding the well name as P1-24L1- 01. Tom Maunder, PE AOGCC From: Sarber, Greg J [mailto:SarberJG@BP.com] Sent: Thursday, August 07, 2008 4:29 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; McLaughlin, Sean M; Miller, Kenneth C; Archey, Pat; Strait, David R Subject: Sidetrack of Pl-24L1 Dear Tom, To confirm our telephone conversation earlier this afternoon. BP is currently drilling a horizontal sidetrack of well P1-24. The sidetrack is P1-24L1 (PTD# 2081030). This lateral has encountered a good oil column at the 8/8/2008 Sidetrack of P 1-24L 1 Page 2 of 2 perifery of the field to the southwest of the Point Mac #1 drillsite. The toe of the present lateral has encountered an apparent oil water contact, and the last 600' of the 2800' lateral is water. The BP asset team is enouraged by the oil column and believes there is a secondary target to the north of the present wellbore. BP plans to complete the present P1-24L1 lateral with slotted liner as covered in the origional permit to drill application. BP would like to get preliminary approval to perform a sidetrack of the P1-24L1 lateral about 400' outside the present window and drill a lateral to the north. This new lateral would be a sidetrack of the P1-24L1 lateral and should probably be named P1-24L1-01. The directional planning for the lateral is currently in progress. I will provide the AOGCC a full permit to drill application on Firday for the new sidetrack lateral with directional information and a well schematic. Thank you for your attention. Sincerely, Greg Sarber BPXA 8/8/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~~ !: :: ,_ :;~:± ;, . t ..r ~ :: = ~ ..^°•,rri~r's Search State Cabins ~~ura~ 'S+DUf'~S ~c"~S c"~ +ar File Type: ADL _ File Number: „28?98 ~ Printable Case Fle._Summary See Township, Range, Section and Acreage? New Search Yes ~> No ~~W .~ ~; SAC Men€~ i Case Abstract I Case Detail i Land Abstract File: AUL 28298 '~~~'~' Search far Status Plat Updates A~ of OS'1 li?OOS Custorner.~ 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 995196612 Case Type: ~<~. OI1, & GAS LEASE COMP DNR Unit 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 312.000 Date Initiated: 05/28/1965 Office of PriTnary Responsibility: DOG DIV OIL AND GAS Last Tf~ansaction Date: 12/04/2006 Case Subrype:~ I S NORTH SLOPE Last Ti°ansaction: AA-NRB ASSIGNMENT APPROVED llerrilicm: U Township: UI?N /i~u1~;~~. 014E Sc~c~trr~fl: 17 5eclir>n.-1ci~E~s: ~I~ Search Plats Legal llescription OS-28-196 ~ * *SALE NOTICE LEGAL DESCRIPTION* C1=t-119 012N-OI~F-UM 17,18,19,?01638.00 EXC. PLO 171 =1-11-9-? '~* PRUDHOE PAY UNIT EXPANDED; PT. MCINTYRE PARTICIPATING ARE11 FORMED. LEASE COMMITTED IN PART TO PPUAND PT. M_AC PA. LEASE SEGREGAT ED ~* UNIT LEGAL DESCRIPTION ** T. 12 N.. R. 1-1 E. , UILIIAT 1LIERIDIAN -- TRACT 11 ~ ~S'EC'TIO.'~' 1 %: 1V ~2, N,~2SE,~=I, r~'E%~SiY"%=l, E.I~'L UDL'~'(I L~' S. SUR 6'EY -10-1<t C'ONTAL'VING 312.00 ACKES N1URE OR LESS. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28298&... 8/T 1/2008 Alaska Department of Natural Resources Land Administration System Page 1 ofx ~ __ ,~~~ 3,._ =,;.i f' ;'.. ::'er's Search utate Cabins l~I~tu~ ~~oue~s ~ £ ['ii C ~~~ File Type: ,ADL File Number: 34622 -Printable Case File Summary See Township, Range, Section and Acreage? C Yes C No New Search !.A~°s F/ler,a ~ Case Abstract t Case Detail I Lane! Abstract ti File: ~`tDL 31622 '~'~ Search for Status Plat Upd~+tes .<1 oP OR!t 1-?008 cnstomer•.~ ouu l o~~ ~ ; BP ExPLORATION ~ALASxA> INc PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tape: 7~4 OIL & GAS LEASE COMP DNR Unit: 780 O[L AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 03/24/1967 Totul Acres: 2560.000 Date Initiated: 12/23/1966 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Szrbtype: ht,~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Mc;rirlian: [ i 7ox~rrcfrih: 0l ~N l~un~e: 014E Section: (.) Plats !lltri~[icur: 1_'- [urirr~IrrJ~: 012N Rurt~=e: OI~IE .~'ccliorr: 04 Mer~clrcrn: L ~cnrnshrt~: 01'^N Ir'ur7,~=c: 014-I~ S~c~iur~: 09 ~l'h'/'lCll(rn: li I olt7L~'{ZIf~: O I ~N I~c1!!<~N: ~) ~ -~~', ,~~Cc"I/U77: I O Legal Description 12-23-1966 * * * SALE NOTICE LEGAL DESCRIPTION C18-1 T. 12 N., R. 1 ~lE., U.M. SFC'TION 3: ALL 6-IO ACRES SECTION ;t: ALL 6=l0ACRES SECTION >: ALL 6~0 ACRES SECTION 10: ALL 610 ACRES ,Section ,~cr~~s: 600 Search ,ti'ecllun _-1cr~c~~: 6-10 .See(zorz Jc~~e~: 610 Section .lcres: 6=10 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=34622&... 8/11 /2008 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~,BL/ ~~ o?~L/-D/ PTD# 010'/o?~d Develo men~t S i p ~ er v ce Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.E'61D~D~' ,/~.ay POOL: ~T /~~///TY.e~- ~,i T Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well __ ~1 ° ~'--~ti, , ~~ (If last two digits in AP1 number ar Permit No. ~(z\'yti , AP[ No. 50- v~ - ~3~'1C1 ~_OC~ . e 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(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of weln until after (Coraoanv Narael has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _fCoraoanv Narae) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PT MCINTYRE OIL • 644180 Weil Name: PRUDtiOE BAY UN PTM P1-24L1-01 Program DEV Well bare seg ^ PTD#:2081240 Comparry BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 OnlOff Shore Qn Annular Disposal ^ Administration 1 Pe[mitfeeattached--------------------------------- ---------- NA--- ------------------------------- 2 Lease number appropdate- - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - 3 Uniquewellnameandnumbe[-- ---- ---- ---- ---- Yes-- - - -- -- -- --- ---- -- --- -- - --- 4 Well located in a_defined-pool---- - ---- - - ---- --- Yea ---- ---- -- - - - --- -- - - -- ---- 5 -WeIIIQCatetiproperdistanuefromdriilingunft_boundary-------------- ---------- Yes-- -------------------------------------------------------- --- 6 Well lQCaiad p[oper distance from other weps- - - - - - - - - - Y~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage available in_drilling unit- - - - - - - - - - - - - - - Yea - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Ifdeviated, is-welibore plat-included - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Ops[aiot9nlyaffectedpafi~ -- - ---- - -- -- ----- - Y~-- -- -- ---- - - - ---- ---- - - -- ----- 10 Operetothas-appropriate bond in force__-----------------._ ----_----- Yes-- -----BlanketBond#6194199•--------------------------------------------------- 11 Pemlkcanbeisg~redwiihoutconservationorder_-_-.------------ ---_----- Yes-- ------------------------------------------------------------ - - - - Appr Date 12 Pemlitcanbeisguedwiihoutadministtative.approval------------- ---------- Yes-- ----------------.------------,------------------------ ---- ----- - ACS 811112008 13 Can permit be apRrQved before 14-daY-wak- - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 14 WfllllocatedwithimaraaandslrataauthorizadbylnjectignOrder~(putJO#in_comments)-(FOr_ NA_-- -_--_--------------_---_-__---_--..---_-.-------__---------_----_-_ 15 Ahwegs_within114_roiieateaofreyie4videntified(Fo[setvicewelipniy)_____ __________ NA_-- ._--__------------_------.-.-----------------------------.---- ------ 16 Pre•producedinjector.durationofpreproductiontessthan3m4nths_(Forservicewailaniy)_- NA-- -----------_------_-___-_---_-_----.---------------- ------------ ~1 17 Norconven, gas-c9nf4rma tQ A831,05,030[11.A),i1.2.A-D) - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 ConductotstringRrQvided----------------------------- ---------- -NA--- -----CQnductOrsgtinP1-24 (19$-149).-------------_----.-------------.--------------- 19 Su[face~casingprQtectsall_knpwnU$DWs-------.-----_----- --.------ NA--- ---._NGaquifers,AIQ4B,Conclusion5.------------------------------------.--------- 20 CMTvoiadsquafet9arculate_onconductQrB,s~trfcsg-------------- --__-_-- NA._ _--__Surfas~ecasingsatinP1-24.-_____________-__-__-------__----_------_- -- 21 CMTvoladequaie_ictie•inlongstringtosurfcsg__--__-_--__--_ __----_- NA--- _-_-_Production-casing set in_P1-24,_-__---__-_-------_--_------------------------ 22 CMTwiilcoyerallknown_productivaberizons------------------_ -.__-._-- -No--_ .-._Slotsedliner completion p(anned,-____-_________----__--_---_-----_-.--_-__---_- 23 Caging desgns adequate fo[ G, T B &. permafrost- _ _ - - - - - - - - - - - - - - - - - - - _ NA_ _ _ - - _ original wall met design specifications. _ NA for slotted liner.. _ _ - - - - - - - _ - - . - - - - - - _ . - - _ - - - _ - 24 Adequate fankage_ or reserve pit - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - - - Yes - - - - - .Rig equipped with steel pits, Na reserve pit planned.- All waste to approved disposal well(s). _ _ - _ _ _ _ - _ - 25 Ifa_re-dtiil,has_a10.403forabandpnmentkeenapproved------------ ---------- ~A--- ------------------------------- --- -- -- --- - -- ----- 26 Adequate-wellbote separation proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - Proximity analysis performed, Nearest segment is 1.1 lateral and_paths diverge.- - - - - - - - . _ - - - _ - - _ - - 27 If divertarrequired,does~meetregulati9ms_____-_--_---_--_- --_------- NA-__ ____-BQPStackwiNalready_~inpiaee------------------------------------------------ Appr Date 28 Drilling fluid- program schematic_& equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected fo[mation pressure 8,5 EMW._ MW planned $.7 ppg. - - . - _ . _ _ _ _ - - _ . _ _ _ _ - - _ _ _ _ TEM 811112008 29 BOP)s,dotheymeetregulation------------------------- --------- Yes-- --------------------------------------------------- --- - - --- ([r<y, n 30 BOPE_p-ress rating appropriate; test to-(put prig in c9mments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ , - _ _ psi_BQP tesiplanned, - - . _ - MASP caiculaled of 3036 psi- 3500 ~~' 1v ~ 31 Choke_manifpid CompJias wIAPIRP•53 fMay $4)- - - - - - - - - - - - - - _ - - Yes - - _ _ _ _ = - - - - - . - - - - - - 32 Work willoccutwithoutoperatonshutdown-------------------- ----_ -_-- Yes-- --------------.------.----------------------------------------------- 33 is presence of H2S gas probabte - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ _ - - _ t12S is reporter at PM4._ Mud shook! preclude H2S_ on_ng, Rig_has sensors and alarms.- - - _ - - - - - - - _ - - _ 34 _Mechanical condition of walls Within AQR verified (F9r service wep only) _ . - _ _ - _ _ _ - _ NA- - --- - -- - -- - --- ----- ----- -- --- - --------------- Geology 35 PemlitcanbeissuedwlohYdtogen_sulfidem~asures_------------- --_---_-_ No___ _.--_MaxlevelH2$Ptpad190ppm,wellP1,24=38ppm._.__.---_---------- _-----------_---_- 36 Data_presentedonpoSentialDVerpressurezones-_------_------- ---------- Yes-- ----------------------------------------------------------- --- - Appr Date 37 Seismic analysis of shallow gas zones-----------------___-_ ---_-_--- NA-__ _-__---_ ----------------------------- ACS 811112008 38 Seabed conditionsunrey_(ifoff-shore)__________________----_ --.------- -NA--- ------------ 39 Contact.namelphoneforWaakly_progresstel~rts[exploiatory9nlyl------- ---------- Yes-- -----G[egSarber-5643$0,----------.----------------------------------------- Geologic CommLasioner: Engineering Pub!' Date: Date er: Com ro Co Date m ~./ 8/3 D~ //JG V ' l~ /////1/~'/~J[f} w-V Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. 7 ~ • tapescan.txt **** REEL HEADER **** MWD 09/10/08 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/08/12 2120695 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 11681.5000: Starting Depth STOP.FT 14014.0000: Ending Depth STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P1-24L1-O1 FLD FIELD: Point McIntyre LOC LOCATION: 70 deg 23' 26.303"N 148 deg 35' 1.251"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 12 Aug 2009 API API NUMBER: 500292270361 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 16 . TOWN.N T12N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 43.1 DMF DF EKB .F 0 . EDF .F 43.1 EGL .F 0 . CASE.F N/A OS1 DIRECTIONAL Remarks Description section Township Range Permanent Datum ElevdtlOn Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. <3) All True vertical Depths <TVD55) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 ~.~ _~~~ ~~ ~ ~ ~ ~ 5~ • tapescan.txt (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 well P1-24L1 above the Kick off Point of 12345 feet MD dated 08 Aug 2009 per Dave Boyer with BP Exploration (Alaska), Inc. The MwD data is now the Primary Depth Control (PDC) log for well Pl-24L1-O1. (8) The sidetrack was drilled from P1-24 througgh a milled window in a 7 inch liner. Top of window 12044 ft.MD (8873.4 ft.TVDSS) Bottom of window 12053 ft.MD (8879.1 ft.TVDSS) (9) Tied to P1-24L at 11782 feet MD (8703.0 feet TVDSS). (10) The interval from 13982 feet to 14017 feet MD (8958.3 feet to 8957.3 feet TVDSS) was not logged due to sensor to bit offset at well TD. (11) The P1-24L1-O1 sidetrack off of an aluminum billet was started at 12345 feet MD (8984.2 feet TVDSS). (12) Baker Hughes INTEQ runs 4 and 5 are not presented in the header due to being associated with the P1-24L1 wellbore. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate Of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> R25lstlVity (AT)(LS)2MHZ-Compensated Borehole Corrected (oHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole corrected (oHMM) RPCHX -> Re5i5tiVlty (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TVDSS -> True VertiCdl Depth (SUbSed) CURVE SHIFT DATA BASELINE, M EASURED, DISPLACEMENT 11683.1, 11682.4, ! -0.716797 11687.6, 11686.9, ! -0.717773 11691.7, 11690.8, ! -0.896484 11696.6, 11695.3, ! -1.25586 11701, 11 700.3, ! -0.716797 11703.4, 11702.8, ! -0.539062 11710, 11 708.8, ! -1.25586 11712.5, 11711.4, ! -1.07617 11715, 11713.8, ! -1.25586 1].721.3, 11720.6, ! -0.717773 11726, 11724.9, ! -1.07617 11731.7, 11730.1, ! -1.61523 11736, 11734.8, ! -1.25586 11744.5, 11744.3, ! -0.179688 11748, 11748.6, ! 0.538086 11753, 11751.6, ! -1.43457 11756.5, 11755.9, ! -0.538086 11761.3, 11761.3, ! 0 11764.5, 11763.8, ! -0.717773 11768.1, 11766.7, ! -1.43457 11778.7, 11777.5, ! -1.25586 11782.7, 11781.9, ! -0.717773 11786.4, 11785.2, ! -1.25586 11792.9, 11791.3, ! -1.61426 11795.2, 11794, ! -1.25586 11797.7, 11795.8, ! -1.97363 11802.8, 11800, ! -2.87012 11807.9, 11805.9, ! -1.97266 11810.4, 11808.9, ! -1.43457 11813.6, 11812, ! -1.61426 11816.5, 11814.9, ! -1.61523 11820.6, 11819, ! -1.61426 12040.1, 12036.6, ! -3.40918 12045.2, 12041.8, ! -3.40918 12047, 12043.6, ! -3.4082 12049, 12045.4, ! -3.58789 12049.6, 12046, ! -3.58789 12053.3, 12049.9, ! -3.40918 12055.7, 12052.1, ! -3.58789 Page 12058.2, 12054.6, 12060.3, 12056.7, 12063.5, 12060.1, 12066.8, 12063.4, 12070, 12066.6, 12072.9, 12069.6, 12075.6, 12072.2, 12079.3, 12075.9, 12083.5, 12079.9, 12086.5, 12083.1, 12091.2, 12087.8, 12097.1, 12093.3, 12099.6, 12096, 12104.8, 12101.2, 12110.9, 12107.3, 12114.7, 12111.1, 12123.1, 12119.5, 12128.6, 12125, 12136, 12132.4, 12146.9, 12143.3, 12150.5, 12147.1, 12158.6, 12155, 12164.5, 12160.9, 12172, 12168.4, 12180.7, 12177.3, 12184.8 , 12181.3, 12190.4, 12187, 12203.5,.12199.9, 12211.2, 12207.6, 12218.9, 12215.2, 12228.2, 12224.6, 12235.9, 12232.3, 12248.4, 12244.8, 12259.4, 12255.8, 12264.8, 12261.4, 12273.2, 12269.6, 12283.8, 12280.4, 12286.3, 12282.9, 12291.2, 12287.8, 12300.9, 12297.5, 12306.1, 12302.5, 12311.3, 12307.9, 12321.9, 12318.3, 12328.4, 12325.3, 12332.1, 12329.2, 12335.3, 12332.5, 12340.6, 12337.7, 12343.2, 12340.4, EOZ END ! BASE CURVE: GROH, Tape subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER ~*~* MWD .001 1024 n tapescan.txt -3.58789 -3.58887 -3.4082 -3.4082 -3.40918 -3.22949 -3.40918 -3.40918 -3.58789 -3.4082 -3.40918 -3.76758 -3.58789 -3.58789 -3.58789 -3.58789 -3.58887 -3.58789 -3.58789 -3.58789 -3.4082 -3.58789 -3.58789 -3.58887 -3.40918 -3.58789 -3.40918 -3.58789 -3.58789 -3.76758 -3.58789 -3.58789 -3.58789 -3.58789 -3.40918 -3.58789 -3.40918 -3.40918 -3.40918 -3.40918 -3.58789 -3.40918 -3.58789 -3.0498 -2.87109 -2.87109 -2.87012 -2.87109 OFFSET CURVE: GRAX 166 records... 10 bytes 132 bytes Page 3 tapescan.txt *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted well P1-24L1 above the Kick off Point of 12345 feet MD dated 08 Aug 2009 per Dave Boyer with BP Exploration (Alaska), Inc. The MwD data is now the Primary Depth Control (PDC) log for well P1-24L1-O1 *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging 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 code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 130 Tape File Start Depth = 11681.500000 Tape File End Depth = 14014.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 143 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 Page 4 t • tapescan.txt *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 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: 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 Code Samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 260 Tape File Start Depth = 11682.000000 Tape File End Depth = 14016.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet *~** FILE TRAILER **** Tape Subfile: 3 273 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/08/12 2120695 O1 Page 5 tapescan.txt **** REEL TRAILER **** MWD 09/10/08 BHI O1 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RPD RPS 11681.5000 -999.2500 -999.2500 -999.2500 -999.2500 11682.0000 -999.2500 -999.2500 -999.2500 -999.2500 14014.0000 -999.2500 46.1250 -999.2500 -999.2500 Tape File Start Depth = 11681.500000 Tape File End Depth = 14014.000000 Tape File Level spacing = 0.500000 Tape File Depth units = feet Tape subfile 3 is type: LIS DEPTH GR ROP RPD RPS 11682.0000 -999.2500 -999.2500 -999.2500 -999.2500 11682.2500 -999.2500 -999.2500 -999.2500 -999.2500 14016.7500 -999.2500 119.1000 -999.2500 -999.2500 Tape File Start Depth = 11682.000000 Tape File End Depth = 14016.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet D Tape Subfile 4 is type: LIS RAD -999.2500 -999.2500 -999.2500 RAD -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 Page 6
