The URL can be used to link to this page

Home My WebLink About201-074 STATE OF ALASKA • RECEIVED AliKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP 1 0 701L. ` ^ Coils. j{r��t� tn�',S1Ot 1. Operations Abandon Li Repair Well 11 Plug Perforations U Perforate U AI ' a ©t Performed: r ` ,,^N {1 C Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension, .t. Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other Q AC,w Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 11 Exploratory ❑ - 201 -074 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22399 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: r- ADL0047472 ' PBU X -22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 14018 feet Plugs measured None feet true vertical 9025.47 feet Junk measured None feet Effective Depth measured 13985 feet Packer measured See Attachment feet true vertical 9022.85 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 30 - 110 30 - 110 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10894 7 -5/8" 29.7# NT -95HS 28 - 10922 28 - 8867.93 8180 5120 Liner 531 4 -1/2" 12.6# 13Cr80 10744 - 11275 8776.27 - 8970.28 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 10635 - 10731 47.145.4, ,$Z.. Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: {� Intervals treated (measured): SCANNED MAR 0 4 201+� 3 Treatment descriptions including volumes used and final pressure: f � 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 82 1081 838 0 249 Subsequent to operation: 359 730 2732 0 259 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerhays Title petrotechnical Data Technician Si m /r��.y�Jire Phone 564 -4035 Date 9/7/2012 FISUMS SEP 11 2012 f i �� r IGINAL r igm Form 10-404 Revised 10/201 a 6 2 ` � � S ubmit al Only • • Perforation Attachment ADL0047472 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base X -22A 3/22/09 SPS 10678 10702 8739.94 8753.32 X -22A 7/7/11 SPR 10678 10702 8670.79 8684.17 X -22A 10/27/93 SL 11275 12686 8901.13 8965.48 X -22A 6/4/01 SL 12025 13984 8947.86 8953.62 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0047472 SW Name Type MD TVD Depscription X -22A PACKER 10527 8583.31 4 -1/2" HES TNT Perm Packer X -22A PACKER 10672 8667.41 4 -1/2" TIW HBBP Packer II Casing / Tubing Attachment ADL0047472 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" Conductor 30 - 110 30 - 110 LINER 531 4 -1/2" 12.6# 13Cr80 10744 - 11275 8776.27 - 8970.28 8430 7500 PRODUCTION 10894 7 -5/8" 29.7# NT -95HS 28 - 10922 28 - 8867.93 8180 5120 SLOTTED LINE 1413 4 -1/2" 12.6# 13Cr80 11275 - 12688 8970.28 - 9034.66 8430 7500 SLOTTED LINE 2063 2 -7/8" 6.16# L -80 11955 - 14018 9014.15 - 9025.47 13450 13890 i SURFACE 3171 10-3/4" 45.5# L -80 29 3200 29 3199.23 5210 2480 SURFACE 3171 10 -3/4" 45.5# L -80 29 - 3200 29 - 3199.23 5210 2480 • TUBING 96 4 -1/2" 12.6# 13Cr80 10635 - 10731 8715.53 - 8769.23 8430 7500 • • • Daily Report of Well Operations ADL0047472 ACTIVITYDATE 1 SUMMARY •11. emp= 1 1 • II Y "re . -= 1psi,• •nine. • FL @ 6049' (Sta #3, S /O). Stacked out TP to 1530 psi in 1 hour. Bleed IAP from 1530 psi to 310 psi in 1 hour and 15 minutes, to production. During bleed TP decreased 190 psi to 1340 psi. and IA FL raised 454' to 5595'. During 1 hour monitor TP decreased by 60 psi, IAP increased 100 psi and IA FL dropped 454' to 6049' (Sta #3, S /O). Final WHP's = 1280/410 6/1/2012 SV, WV = C. SSV, MV = 0. IA = OTG. NOVP. 23:55 hrs. T/I = 1050/1000. Temp = SI. WHPs, T & IA FLs ( Post TIFL ). AL SI © casing valve, ALP = 1880. TBG FL @ 2506' sta #4 (66 bbls ). IA FL @ 4842' between sta # 3,4. ( 126 bbls) TP decreased 230 psi, IAP increased 590 psi since 06/01/12. 6/3/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 0130. 171 = 350/1400. I emp = 110'. TII-L INCONCLUSIVE (I xIA Re-111-L). AL online @ 1400 psi. Initial IA FL @ 6049' (Sta# 3, S /O). SI AL @ casing valve and SI WV. Stacked out well using AL to 1800/1800. Bled IA to production from 1800 psi to 510 psi in 1 hr. During bleed IA FL inflowed 116' to 5934'. Opened SSV to check TP, WV was partially open and TP dropped to 1380 psi. Monitored for 1 hr. TP decreased 150 psi, IAP increased 210 psi, IA FL inflowed 75' to 5858'. Well back online. Job complete. Final WHPs = 1230/720. 6/4/2012 SV = C. WV, SSV, MV = 0. IA = OTG. NOVP. 17:00 hrs. T /110 = 220/1440. Temp = 110 °. TIFL INCONCLUSIVE (TxIA re -1 II-L). AL online. IA FL @ 6049' (sta# 3 SO). Stacked TP using ALP to 1870 in 1 hr 30 min. IA FL unchanged. Bled IAP to 270 psi in 1 hr 30 min. During bleed TP decreased 70 psi, IA FL unchanged. Monitored for 1 hr. TP decreased 50 psi, IAP increased 110 psi, IA FL unchanged. Job complete. Final WHPs = 380/1750. 6/5/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 1400. T /I /0 = 250/1440. Temp = 110 °. TIFL INCONCLUSIVE (TxIA Re- TIFL). AL online. IA FL @ 6049' (sta# 3 SO,). Stacked TP using ALP to in hr min. IA FL unchanged. Stack out tubing with AL gas well to 1730/1280 in 45 min. SI AL lateral valve & bled AL line with IAP to production from 1280 psi to 310 psi in 1 hr 15 min. During bleed TP decreased 350 psi. Monitored for 1 hr, TP decreased 70 psi, IAP increased 110 psi & IA FL unchanged. Job complete. Final WHPs = 1310/420. 6/7/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 15:00. T/I = 2200/1831 Temp = SI (Pre acid injectivity test) Pumed 100 bbls of crude at 5 BPM down the tubing. Pressure decreased through out. See pump log. Final WHP = 1100/1850 psi. SV,WV - 7/14/2012 closed SSV,MV,AL - open 7/14/2012 ASRC Test Unit #4 X -22 Fullbore Acid Flowback & Well Test. RU. Inlet X -22, Outlet X -05 ASRC Test Unit #4 " *Cont from 7- 14- 12WSR** X -22 Fullbore Acid Flowback & Well Test. RU, 7/15/2012 Inlet X -22, Outlet X -05 * *Cont. on 7/16/ WSR ** ASRC Test Unit #4 * *Cont from 7- 14- 12WSR ** X -22 Fullbore Acid Flowback & Well Test. RU, 7/15/2012 Inlet X -22, Outlet X -05 * *Cont. on 7/16/ WSR ** ASRC Test Unit #4 * *Cont from 7- 15- 12WSR ** X -22 Fullbore Acid Flowback & Well Test. S/B for 7/16/2012 gas lift to come back on. Inlet X -22, Outlet X -05 * *Cont. on 7/17/ WSR ** ** job in progress ** * ** Mud Acid treatment * ** Scope: Mud Acid Stimulation. SIM OPS. (ASRC Testing on location) Bled down IA from 1700 to 1000 psig prior to pumping TBG pickle. SLB MIRU and PT to 4000 psig. Just prior to acid being pumped (pickle) GC3 Upset. Shut down pumps and standing by Job in 7/16/2012 progress ASRC Test Unit #4 * *Cont from 7 -16 -12 WSR ** X -22 Fullbore Acid Flowback & Well Test. S/B for gas lift to come back on.POP well to separator. S/B for SLB pump crew. Inlet X -22, Outlet X -05 7/17/2012 * *Cont. on 7/18/ WSR ** ** job in progress ** * ** SLB Fullbore Mud Acid Treatment * ** Held Pre -Job - SIM ops meeting. JOB SCOPE: Mud Acid Treatment. Pumped recommended schedule for treatment, going slightly over volume to empty transports (see log). Never encountered formation facture pressures for duration of pump job, non 7/17/2012 issue for this job. ** *Job Continued on 7/18/2012 * ** • • T /I= 900/1140 LOAD IA (acid) Pump 3 bbls neat meth followed by 273 bbls crude and 3 bbls neat meth down IA to load. ASRC in control of well notified pad op upon departure. FWHP = 1430/560 S /SSV/W /M = ASRC 7/17/2012 IA = C 7/17/2012 LRS T -98 fluid support * ** Job continued from WSR 7/16/12* ** Scope: Mud Acid treatment. Received clearance to continue job by DSO after GC3 upset and standing by. (Now have a flowpath for pickle returns) Resume Acid Pickle and flowback. SIM OPS w/ SLB and ASRC Testing on location. Pickle pump 7/17/2012 complete, will complete mud acid stim within next 24 hours. T7I /O= vac /200 Temp= SI Displace tbg with crude ( Acid STim /Eval failed TIFL) Pumped 302 bbls crude down tbg for displacemnt of acid. FWHP's= 997/200 DSO notified upon departure ASRC still 7/18/2012 in control of all VLV's * ** Job continued from 7/17/2012 * ** SLB l-ullbore Mud Acid Treatment * ** Continued pumping recommended schedule for treatment, going slightly over volume to empty transports (see log). Never encountered formation facture pressures for duration of pump job, non issue for this job. SLB RDMO. LRS Displaced tubing with 302 bbls Dead Crude. Turned well over to ASRC Testers 7/18/2012 to flow back. Final T/I = 160/156 * ** Job Complete * ** FLUIDS PUMPED BBLS 8 METH 678 CRUDE 258 2% KCL 205 12% HCL 1033 NH4CL + F103 195 9:1 MUD ACID 48 OIL SEEK 2425 TOTAL TREE= 4 -1/16" CIIN X 22A 1 IV 1 rraL I�Iwxc- /v c�ti 1 ww ti- WELLHEAD = C2Vit 1/2" CFROME TBG & LNR ""' 7 -5/8" TNV PKR MAY FAL ACLU TO R= BAKB2C AT linn pc] ncc c PYCAMM r-m KB. B_EV = _ BF ELEN = 39.0' • *t KOP= 3763' I20• CONDUCTOR —{ . • • • 4. ( 2103' H4-1/2" I� X NP, N3= 3.813" Max Angle )a @ 13542 ;', 1 . • Datum MD = 10926' . • • *4 Datum 1VD = 8800 SS ∎i • • � 3058' — I7 -5/8" HES ES C23'1THR I 17 -5/8" CSG, 29.7 #, L -80 VAM TOP HC, D = 6.875 H 3101' = 3081' H7-5/8" BKR ECF', 13= 6.875" 17 -5/8 BKR BOWBV CSG PATCH, D = 6.75" H 3104' 10 -3/4" CSG, 45.5#, -I 3200' GAS LIFT MANDRELS _ ST MD 1VD DEV TYPE VLV _LATCH SIZE DATE L -80 LHE BUTT, ID = 9.953" ri 4 2506 2505 1 KBMG DOME BK 16 06/20/12 3 6049 5611 49 KBMG DOME BK 16 06/20/12 2 8399 7102 48 KBMG DOME BK 16 06/20/12 Minimum ID = 2.37" @1•961' 1 10420 8588 52 KBMG SO BK 24 06/20/12_ 2 -7I8" FL4S LNR X 2 -7/8" STL LNR XO 1 ---- 10497' — I4 -1/2" HES X NP, D= 3.813" Z -L 10527' — 7 -5/8" x 4-1/2" HES TNT FKR, D = 3.856" 4-1/2" TBG, 12.6#, 13CR 85 VAM TOP, —I 10630' 0152 bpf, D = 3.958" , � — $ 10560' H 4-1/2" I X NP, 0= 3.813" 4-1/2" TUBNG STL18 (06!10111} —I 10635' ( 1 �rI 10645' I — 7 -5/8" X 4-1/2" MOLE OVERSHOT Z x- 1 10672' —17-5/8' x 4-1/2" WI HBBP PKR, D = 4.00' I 10702' H 4-1/2" PKR SWS NP, D = 3.813" 1 ' I 10719' H 41/2" FICR SWN NP, MUD TO 3.80" (05/??/01) 1 4-1/2" TBG, 12.6#,13CR NSCT, — 10731' / \ 10731' H4 -1/2" WLEG, 1) = 3.958" 0152 bpf, D = 3.958• I H ELMD - NOT LOGGED I I TOP OF 4-1/2" LNR —I 10757' 10744' — I TIW SC OOROV ERSHOT ASSY 1075T H7-5/8" TM/ LNR TOP HCR, D = 4.00' I 1 7 -5 /8" CSG, 293# , NT95HS NSCC, D = 6.875' 1 10922' I- PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ` � Note: Refer to Production DB for historical pert data 11955' -- I 3.70" BKR DEPLOY SLV, D = 3.00" I SUM SPF NYTERVAL Opn/Sqz DATE ` . ` .. 4-1/2' SLTD 11275 -12663 SLOT 12/28/93 . ` - 11961' H3-1/2" X 2 -7/8" XO, 13= 2.37" \ \ PRE - DRLLED 3/8' HOLES .. . . 2 -7/8" 4 ( 12025 -13985 1 0 06/03/01 . ` �. \ N. � N. ■ . N `.- \ N. \ .. \ ` I PBTD 13985' 1 4 -1/2" LNR, 12.6#, 13CR -80 NSCT, .0152 bpf, D = 3.953 " —I 12688' 1 ---- V - ■ ` ` I2 -7/8" LNR, 6.16#, L -80 STL, .0057 bpf, 13= 2.44 " —I 14018' DATE REV BY COMMENTS _ i DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/27/93 N22E ORIG COMPLETION 06/22/12 DAS/ PJC GLV C/O (06/20/12) _ WELL X 22A 06/04/01 NORDIC 1 CTD SIDETRACK (X -22A) _ _ PERMIT No: 2010740 06/25/11 N7ES RWO API No: 50-029- 22399-01 06/29/11 SMM/ PJC FINAL DRLG CORRECTIONS SEC 8, T1ON, R14E, 307' FNL & 25' FWL 07/30/11 BSE/ PJC PULL PX/ SLUGGITS (7/8/11) _ 07/30/11 JLJ/ PJC GLV C!O (7/6/11) BP Exploration (Alaska) STATE OF ALASKA R . ALASK�L AND GAS CONSERVATION COMMIS !\ , i .. c' , D REPORT OF SUNDRY WELL OPERATIONS tai 3 ni= 1. Operations Performed: g ri a Gil & &vt, telisr. Nita ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re-enter uspen ed Well ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other A'6et ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory 201 - 074 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 •- 50 - 029 - 22399 - 01 - 00 7. Property Designation: 8. Well Name and Number: ADL 028313 & 047472 PBU X - 22A 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 14018' feet Plugs (measured) None feet true vertical 9025' feet Junk (measured) None feet Effective depth: measured 14018' feet Packer: (measured) 10527' & 10672' feet true vertical 9025' feet Packer: (true vertical) 8652' & 8737' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3169' 10 -3/4" 3200' 3199' 5210 2480 Intermediate 10894' 7 -5/8" 10636' - 10921' 8716' - 8867' 8180 5120 Production Liner 1931' 4 -1/2" 10757' - 12688' 8783' - 9035' 8430 7500 Liner 2063' 2 -7/8" 11955' - 14018' 9014' - 9025' 13450 13890 Tieback 3071' 7 -5/8" 33' - 3104' 33' - 3103' 6890 4790 Perforation Depth: Measured Depth: Slotted: 11275' - 13985' True Vertical Depth: 8970' - 9023' Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# 13Cr85 / 13Cr 10731' 8769' Packers and SSSV (type, measured and true vertical depth): 7 - 5/8" x 4 - 1/2" HES 'TNT packer 10527' 8652' 7 - 5/8" x 4 - 1/2" TIW 'HBBP' packer 10672' 8737' 11. Stimulation or cement squeeze summary: 6 Intervals treated (measured): r ' ^ ,1't ,N A.0 b K i- b u r, Treatment description including volumes used and final pressure: Cut, pull and dress tubing to 10636'. Cut and pull 7 -5/8" casing from 3101', run new 7 -5/8" tieback (29.7 #, L -80). Cement w/ 145 Bbls of Class 'G' (Yield 1.17). Run new completion to 10645'. 12. Representative Daily Average Production or Injection Data 1 Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 168 1,259 1,252 Not Available Not Available Subsequent to operation: 406 1,065 1,416 1,100 311 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic 0 Daily Report of Well Operations 0 Well Schematic Diagram 15. Well Status after work: ❑ GINJ -- 0 011 ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 311 - 168 Printed Name Terrie Hubble Title Drilling Technologist � 0y / { *Z t �� Prepared By Name/Number: Signature PC'° "`'t/ Phone 56 628 Date 1 / Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 BDMS JUL 13 2011 �� Submit Original Only • • X -22A, Well History (Workover) Date Summary 6/6/2011 T /I /O= SSV/220/140, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS), pre RWO. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Pumped through void, clean returns. Functioned LDS (ET style, 1"), all moved freely. Pressured void to 5000 psi, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test void (100 psi), bled to 0 psi. Pumped through void, clean returns. Functioned LDS (ET style 1 "), all were tight but fully functioned. 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. 6/6/2011 T/I/O= 0/300/120 Temp= S/I MIT -T to 1000 psi (RWO Prep) Pumped a total of 2.3 bbls of 60° meth down TBG to attempt 3 MIT -T's. 3rd test, 1st 15 min. lost 20 psi, 2nd 15 min. lost 15 psi. for a total of 35 psi in 30 min., SB for plan forward. 6/7/2011 CMIT TxIA 1000 psi * *Pass ** Pumped 1.5 bbls crude down TBG in unsuccessful attempt to stabilize pressure for MIT -T. TP did not stabilize, kept falling off. Pumped 1 bbls neat and 13 bbls crude down IA for CMIT TxIA to 1000 psi. 1st 15 min T /IA lost 20/15, 2nd 15 lost 0/5 for a total loss of 20/20 in 30 min. Bled TxIA pressure. Tags hung on WV and IA. FWHP's 0/180/100 6/7/2011 TAGGED 4 -1/2" JUNK CATCHER @ 10654' SLM WITH 3.75" CENT, 3.50" LIB(impression of ":G" fn). WELL LEFT S /I, PAD OP NOTIFIED. 6/9/2011 WELL SHUT IN ON ARRIVAL. INITIAL T /I /O = 0/175/100 PSI. BEGIN RIH WITH TOOLSTRING WHEN LEAK DETECTED AT THE LUBRICATOR. BEGIN POOH. 6/10/2011 O -RINGS CHANGED AT THE LUBRICATOR. SPILL RESPONSE CONTACTED AND INFORMED THAT 1/4 OF A CUP OF DIESEL LEAKED FROM LUBRICATOR. RIH WITH 3.65" POWER CUTTER. TIE IN TO TUBING TALLY DATED 28 -OCT -1993. PULL INTO CUTTING POSITION AFTER CONFIRMING INFORMATION WITH CLIENT CCL TO MIDDLE OF CUTTER = 11.6', TUBING CUT DEPTH = 10635', CCL STOP DEPTH = 10623.4'. GOOD INDICATION OF CUT. FINAL T /I /O = 0/175/100 PSI. JOB COMPLETED. WELL SHUT IN ON DEPARTURE. 6/11/2011 CMIT -TxIA 1000 psi * *PASSED ** Pumped 6 bbls neat spear and 670 bbls 110° 1% KCL down TBG, up IA to X -05 FL while maintaining an open bleed on OA. 3 bbls meth spacer followed by 103 bbls of 40° diesel down TBG. U- tubefd for 55 min to FP TxIA. Pumped 2 bbls diesel down hardline jumper to X -05 FL to flush /FP. CMIT -TxIA: pumped 1.3 bbls diesel down TBG to pressure up TxIA. 1st 15 min T /IA lost 50/20 2nd 15 min lost 0/0 psi for a total loss of 50/20 psi in 30 min. Bled back —3 bbls. Final Whp's= 0/0/0+ 6/11/2011 T /I /O= Vac/0 /0 Upon arrival, conducted PJSM, pressure tested barriers (swab) and removed tree cap. Attached lubricator and pressure tested low /300, High /3500 Pass. Set 4 1/16" CIW "H" BPV #254 thru tree using 1 -1' ext. Tagged @ 112" Pre 7 E.S. No problems. 6/16/2011 T /I /O= vac/0 /0; Conduct PJSM; MV & SSV S/I and tree cap removed on arrival; Install lubricator w/ pulling tool and test against SSV to 250 & 3500 psi for 5 min. (passed); Pulled 4/1/16" CIW "H" BPV #254 thru tree for 7ES Decompletion; 1 -2' ext. used, tagged @ 102 "; Lubricator left on rig floor for TWC set; NO PROBLEMS 6/16/2011 T /I /O = 0/0/0 Conduct PJSM. Rig up lubricator and test to 500 psi low and 3500 psi high. Set 4" CIW H TWC for rig to N/D tree. Rig tested TWC (passed) See Nabors 7ES Rig Work Summary (Attached), Below is the Post Rig Work Summary 06/26/11 T /I /O= 0/0/0 Conducted PJSM; P.T. (charted) lubricator w /each break to 250 psi -low /3500 psi -high; Pulled 4" CIW TWC #260 @ 99" w/1 -2' ext.; (Hot Oil freeze protect/U- tube); Set 4" CIW BPV #149 @ 99" w/1 -2' ext Page 1 of 2 • • X -22A, Well History (Workover) Date Summary 07/02/11 T /I /0= 0/0/0 Conducted PJSM w /crew; Verified Barrier (S.V.); P.T. (charted) lubricator to 300 psi- low/3500 psi -high (passed); Cycled Master valve open; Pulled 4" CIW "H" BPV #149 @ 108" w/1 -1' ext 06/06/11 WELL S/I ON ARRIVAL. PULLED BALL & ROD FROM 4 -1/2" RHC PLUG BODY @ 10,560' MD. PULLED BK -DGLV FROM ST #3 (6,049' MD) & BEK -DCK SHEAR VLV FROM ST #4 (2,506' MD). SET BK -LGLV AT ST #4 (2,506' MD) & BK -OGLV AT ST #3 (6,049' MD). PULLED 4 -1/2" RHC PLUG BODY FROM 10,544' SLM / 10,560' MD. CURRENTLY RIH W/ 3.00" x 10' PUMP BAILER, MULE SHOE FLAPPER. 07/07/11 BAILED -3 GALS OF SLUGGITS W/ 3.00" x 10' P -BLR OFF 4 -1/2" PX PLUG @ 10,702' MD. MADE 3 ATTEMPTS TO PULL P -PRONG FROM 4 -1/2" PX PLUG BODY @ 10,702' SLM. FLOWED WELL FOR 2.5 HOURS TO REDUCE HYDROSTATIC HEAD. BAILED AN ADDITIONAL 1/2 GALLON OF SLUGGITS OFF OF P -PRONG @ 10,702' MD. PULLED P -PRONG FROM 4 -1/2" PX PLUG BODY @ 10,702' MD. CURRENTLY IN HOLE @ 10,676' SLM W/ 3.00" x 10' PUMP BAILER. 07/08/11 BAILED -2 GALS OF SLUGGITS W/ 3.00" P -BLR OFF 4 -1/2" PX PLUG @ 10,702' MD. RECOVERED 4- 1/2" PX PLUG BODY FROM 10,702' MD. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS. Page2of2 • 0 North Arrterjc ° - ALASKA -BP . Page of 23 Operation Summary Replor Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) I Start Date: 6/8/2011 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:OOAM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date I From - To I Hrs Task Code . NPT I NPT Depth Phase Description of Operations 00:00 24.00 MOB N WAIT (ft) 6/9/2011 00:00 - PRE ', WAIT FOR PRE -RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X -22A BEFORE RDMO OF B-21A. I I - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE , WAITING. - INSPECT DRAW WORKS BRAKE BANDS AND LINKAGES. - DISASSEMBLE SLIPS, ELEVATORS, AND HANDLING EQUIPMENT FOR INSPECTION. - CHANGE OUT PIPING IN PUMP ROOM. 6/10/2011 00:00 MOB N WAIT 06:00 ', 6.00 PRE 'WAIT FOR PRE -RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X -22A BEFORE RDMO OF B-21A. I ! PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE WAITING. I - REPLACE PADDLES AND PERFORM MAINTENANCE ON DRAG CHAIN. ' - PM ON MUD PUMPS. 06:00 - 18:00 12.00 I MOB N WAIT PRE CONTINUE TO WAIT ON WELL PRE -WORK I:AND PAD PREP -- X -22A HAD PIPE SUCCESSFULLY JET CUT TODAY AND IS BEING CIRCULATED OUT NOW - HOPE TO HAVE BPV SET AND WELL HOUSE REMOVED BY TOMORROW PM - - -- RIG ACTIVITY: REASSEMBLE DRAWWORKS - REPLACE ' I HYDRAULIC RAM ON IRON ROUGHNECK - CHANGE OUT LOW PRESSURE PIPING ON MUD AND CENTRIFUGAL PUMPS - PREP FOR MPI OF TUBULAR HANDLING TOOLS 1 I 18:00 - 00:00 6.00 MOB I N WAIT ' PRE CONTINUE TO WAIT FOR PRE -RIG WORK 1 AND PAD PREPARATION TO BE COMPLETED ON X -22A BEFORE RDMO OF B-21A. - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE WAITING. - CONTINUE WORKING ON LOW PRESSURE PIPING IN PUMP ROOM. ' - CHANGE OIL IN BRIDGE CRANES AND AGITATORS. - REPAINT BAILS AFTER MPI. - CONTINUE WITH ANNUAL INSPECTION OF IRON ROUGHNECK. - BRIDAL UP AND UNPIN BLOCKS AND TOP DRIVE FOR RIG MOVE. I Printed 7/11/2011 10:32:48AM orth America - ALASKA - BP Page 2 of 23 perationl Summary Report Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 1 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay 1 Site: PB X Pad 1 Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:OOAM 1 Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs 1 Task j Code 1 NPT 1 NPT Depth Phase Description of Operations 1 (ft> (hr) 6/11/2011 00:00 - 08:00 8.00 1 MOB N I WAIT PRE CONTINUE TO WAIT FOR PRE -RIG WORK I 1 AND PAD PREPARATION TO BE COMPLETED 10N X -22A BEFORE RDMO OF B-21A. - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE WAITING. - CONTINUE WORKING ON LOW PRESSURE PIPING IN PUMP ROOM. - WORK ON AGITATORS IN PITS. - WORK ON PIPING FOR CENTRIFUGE. - TAKING PHOTOS FOR D.O.M.S. - CLEAN UP AND INSPECT TOP DRIVE. CONTINUE TO PREP RIG FLOOR FOR RIG 1 MOVE. I- MOVE CUTTINGS BOX FOR RIG MOVE. 08:00 - 08:30 1 0.50 MOB N WAIT PRE 1 PJSM WITH PEAK TRUCKING AND RIG CREW ' 1 FOR PULLING OFF OF B-21 08:30 10:00 1.50 MOB N i WAIT PRE 1MOVE RIG AND PITS OFF OF WELL - SPOT RIG MODULES - IN WIDE SPOT OF B PAD 10:00 12:00 2.00 MOB N WAIT PRE RE- CONNECT STEAM AND ELECTRICAL LINES BETWEEN MODULE AND CLEAN UP AROUND B-21 WELLHEAD - GENERAL . I HOUSEKEEPING AND PM'S 12:00 20:00 8.00 MOB 1 N 1 WAIT 1 PRE CONTINUE TO WAIT FOR PRE -RIG WORK ' AND PAD PREPARATION TO BE COMPLETED 10N X -22A BEFORE RDMO OF B-21A. - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE WAITING. ' - WELD FLANGES IN PUMP ROOM - INSTALL CHARGE PUMP MANIFOLD - PM'S ON DRAW WORKS AND AIR , 1COMPRESSORS - FIND AND FIX HYDRAULIC LEAK IN PIPE SHED - SHAKER PM AND TEST W/ MI -SWACO REP 20:00 00:00 4.00 RIGD ' N WAIT - PRE :CONTINUE TO WAIT FOR PRE -RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X -22A BEFORE RDMO OF B-21A. - UNPIN AND LOWER DERRICK. - PJSM WITH RIG CREW AND TOOLPUSHER. - LOAD TRUCKS AND TRANSPORT EQUIPMENT AND SUPPLIES TO X PAD. 6/12/2011 00:00 06:00 6.00 RIGD N WAIT - PRE CONTINUE TO WAIT FOR PRE -RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X -22A BEFORE RDMO OF B-21A. - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE WAITING. - WORK ON PIPING IN MUD PITS. - CONTINUE TO LOAD TRUCKS AND 1 EQUIPMENT AND HAUL TO X PAD. - MAKE UP LINK TILT CLAMPS TO BAILS, Printed 7/11/2011 10:32:48AM l iorth America - ALASKA - BP Ak Page 3 of 23 MI Pr peraton Summary Report Common Well Name: X-22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 , End Date: 6/25/2011 X4-00TMG-E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name/No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:OOAM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 --- 7 Active Datum: 32 : 22 9/21/1993 00:00 ©69.15ft (above Mean Sea Level) Date ' From - To Hrs I Task ' Code , NPT NPT Depth I Phase 1 Description of Operations (hr) I , (ft) I 1 1_ 06:00 - 18:00 I 12.00 ' RIGD N WAIT PRE CONTINUE TO WAIT FOR PRE-RIG WORK AND PAD PREPARATION TO BE COMPLETED 1 , 1 , , ON X-22A BEFORE RDMO OF B-21A. I , - PERFORM PREVENTATIVE MAINTENANCE •, I AND GENERAL HOUSEKEEPING WHILE WAITING. 1 - ADJUST AND INSPECT CLUTCHES. 1 1 I • REMOVE SCREENS FROM SHAKERS. REASSEMBLE HANDLING EQUIPMENT 1 I , AFTER MPI. • - CONTINUE TO WORK ON DERRICK ZONAL INSPECTION. 18:00 - 00:00 6.00 RIGD N WAIT PRE ' CONTINUE TO WAIT FOR PRE-RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X-22A BEFORE RDMO OF B-21A. 1 1 1 - PERFORM PREVENTATIVE MAINTENANCE I I , 1 ' AND GENERAL HOUSEKEEPING WHILE WAITING. 1 I , 1 , , - CONTINUE TO REASSEMBLE HANDLING I I EQUIPMENT AFTER MPI. - CHANGE GEAR OIL IN PLANETARY GEAR , I , 1 DRIVES FOR MOVING SYSTEM. , 1 - GAUGE AND INSPECT DERRICK SHEAVES. 1 1 - CONTINUE TO WORK ON DERRICK ZONAL INSPECTION. 1 , 6/13/2011 ' 00:00 - 06:00 6.00 , RIGD N WAIT r I PRE CONTINUE TO WAIT FOR PRE-RIG WORK AND PAD PREPARATION TO BE COMPLETED ON X-22A BEFORE RDMO OF B-21A. 1 1 - PERFORM PREVENTATIVE MAINTENANCE AND GENERAL HOUSEKEEPING WHILE , 1 WAITING. , 1 I , - CLEAN AND REPLACE SCREENS ON 1 , I SHAKERS. 1 , , - CONTINUE ZONAL DERRICK INSPECTION. - CONTINUE TO REASSEMBLE HANDLING , 1 , EQUIPMENT AFTER MPI. - CLEAN WIND WALLS. 06:00 - 18:00 12.00 RIGD N WAIT PRE CONTINUE TO WAIT ON PAD PREP TO BE COMPLETED ON X-22A - WORK ON ESD'S FOR BOILERS AND I/ TIOGA HEATERS - CALIBRATE THE FOLLOWING GUAGES: CONSOLE, MUD PUMP, CHOKE, STAND PIPE, TORQUE, AND WEIGHT INDICATOR W/ QUADCO - FINISH REASSEMBLY AND PAINTING OF TUBULAR HANDLING TOOLS - GENERAL HOUSEKEEPING , "** CURRENT STATUS OF X-22A IS: THAWING ICE IN THE BOTTOM OF CELLAR TO GAIN ACCESS TO THE CUT OFF CONDUCTOR PIPE SO CELLAR CAN BE LINED TO ACCOMODATE FLOW BACK - 12 HRS OF ROAD MATTING WILL BE REQUIRED AFTER THE LINING OF CELLAR IS COMPLETED Printed 7/11/2011 10:32:48AM 1 1 North America - ALASKA - BP Page 4, of 23 Summary Report : Common Well Name: X -22 - - -- AFE No Event Type: WORKOVER (WO) ' Start Date: 6/8/2011 I End Date: 6/25/2011 'X4- OOTMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date /Time: 5/30/2001 12:00:OOAM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations -- - - - - -- ', - -- (hr) I' , I — (ft) t- 18 :00 - 00:00 6.00 RIGD N WAIT PRE CONTINUE TO WAIT ON PAD PREP TO BE I ! COMPLETED ON X -22A. - FINISH CALIBRATING GAUGES WITH QUADCO REPRESENTATIVE. - PAINT ALL DOOR THRESHOLDS. - GENERAL HOUSE KEEPING. * ** CURRENT STATUS OF X -22A IS: ICE WAS THAWED OUT AND THE CELLAR ALREADY HAD A LINER. THE LINER IN PLACE WAS NOT COMPETENT AND HAD GROUNDWATER ' , COMING UP THROUGH IT. DISCUSSED WITH FIELD ENGINEER AND RWO ETL AND DECISION WAS MADE TO USE CONCRETE TO CREATE A COMPETENT CELLAR FLOOR ! THAT WOULD HOLD BACK THE GROUNDWATER. — 6/14/2011 00:00 - 06:00 6.00 RIGD N WAIT PRE CONTINUE TO WAIT ON PAD PREP TO MOVE TO X -22A. - DRESS OFF AND PAINT HAMMER UNIONS. ! - CLEAN WIND WALLS. - WORK ON RIG PROCEDURES. 06:00 - 12:00 6.00 I RIGD N WAIT PRE CONTINUE TO WAIT ON PAD PREP / CELLAR REPAIR - CHANGE OUT DERRICK LIGHTS - WORK ON DRUM CLUTCH, GENERAL HOUSEKEEPING. 12:00 - 00:00 12.00 RIGD N WAIT PRE ' CONTINUE TO WAIT ON PAD PREP, CELLAR I PREP AND RIG MATTAGE. - REMOVE STEAM TRAPS, BLOW DOWN AND VACUUM OUT PITS. DISCONNECT LINES AND CABLES F/ INTERCONNECT. - PAINT VARIOUS PIECES OF EQUIPMENT. - INSTALL NEW DIAPHRAGM AND FINISH PM I ON DRUM CLUTCH. - SECURE SHOP AND CAMP FOR MOVE TO X I PAD. - PULL PITS FROM SUB BASE AND INSTALL JEEP. 6/15/2011 00:00 - 02:00 2.00 RIGD N WAIT PRE CONTINUE TO WAIT ON RIG MATING FOR RIG MOVE - RIG CREW PERFORMING GENERAL MAINTENANCE AND SECURING MODULES . FOR RIG MOVE. 02:00 - 18:00 16.00 MOB P PRE MOVE NABORS 7ES RIG SUBSTRUCTURE , FROM B PAD TO X -22 - HOLD PJSM WITH SECURITY ESCORTS - RIG MATS AND PLYWOOD IN PLACE FOR ALL OF X PAD ACCESS ROAD AND ALL PIPELINE CROSSINGS ALONG ROUTE. HAD TO LEAP FROG RIG MATS DUE TO MAT SHORTAGE. 18:00 - 19:00 1.00 MOB P PRE SPOT RIG OVER X -22. MOVE PIT MODULE, MECHANIC SHOP AND RIG CAMP FROM B PAD TO X PAD. 19:00 20:30 1.50 MOB P i PRE PLACE PIT COMPLEX NEXT TO SUB AND RIG UP. 20:30 - 21:30 1.00 I MOB P PRE RAISE AND PIN DERRICK. Printed 7/11/2011 10:32:48AM orth America - ALASKA - BP Page 5 of 23 Aeration Summary Report Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 I End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay j Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:OOAM I Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs Task I Code 1 NPT NPT Depth Phase , Description of Operations (hr) (ft) - 21:30 00:00 2.5.5 0 MOB P . PRE ; GENERAL RIGUP OPERATIONS RIGUP FLOOR, RAISE CATTLE CHUTE, PIN BLOCKS TO TOP DRIVE, HANG BRIDAL LINES, I I MAKEUP STANDPIPE AND CEMENT LINE, I HANG ROTARY TONGS. SET CUTTINGS TANK AND OTHER AUXILLIARY I ' 1 ,I EQUIPMENT /MODULES AROUND RIGSITE. r 6/16/2011 00:00 - 04:00 4.00 MOB P PRE [ACCEPT RIG AND BEGIN RIG OPERATIONS AND TAKE ON SEAWATER AT 00:00 ON 6/16/2011. CONTINUE GENERAL RIG UP 1 OPERATIONS. - CH2M HILL WELLS SUPPORT CREW RIG UP OA AND TUBING/IA TO 500 BBL DOUBLE HULL 1 FLOWBACK TANK WITH 2" HARDLINE AND ' MANIFOLD SKID. IA/TBG RETURN LINE FOR CIRC OUT RIGGED UP TO CHOKE MANIFOLD ON RIG FLOOR. ' - INITIAL PRESSURES: TBG = 0 PSI, IA = 0 'PSI, OA = 100 PSI. HELD RIG EVACUATION DRILL AND AAR ' ' WITH RIG CREW AND ALL ON LOCATION. 04:00 - 05:30 1.50 WHSUR P DECOMP 1 MIRU WELLS SUPPORT VALVE SHOP CREW. ; RIG UP LUBRICATOR AND PRESSURE TEST !AGAINST SWAB VALVE TO 250 PSI LOW FOR 1 5 MIN AND 3500 PSI HIGH FOR 5 MIN. PRESSURE TESTS CHARTED AND ' WITNESSED BY WSL. PULL CIW 4 -1/2" TYPE ' H BPV. RD LUBRICATOR AND MOVE OUT - y, - VALVE SHOP CREW. 05:30 - 09:00 3.50 WHSUR P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT AND CIRCULATE WELL CLEAN THROUGH 1 t 1 TBG JET CUT @ 10635' MD. - FIRST LINED UP TO PUMP DOWN IA TO CIRCULATE OUR DIESEL IN TBG. PRESSURE TEST LINES TO 3500 PSI - REVERSE OUT 38 BBLS 120 DEG F 8.5 PPG SEAWATER. CLEAN . WATER TO SURFACE ' - SECONDLY LINED UP TO PUMP DOWN ' TUBING AND CIRCULATED SOAP PILL AND TOTAL OF 550 BBLS 120 DEG F 8.5 PPG SEAWATER. PUMP PRESSURE = 1400 PSI @ 5 BPM. SHUT DOWN AND MONITOR WELL AFTER STABLE FOR 10 MINUTES - WELL IS DEAD _ 09:00 11:30 2.50 WHSUR P DECOMP PJSM FOR TWC INSTALLATION. RIG UP DSM LUBRICATOR AND PSI TEST 250/5 MIN, 3500/5 MIN. INSTALL TWC AND PSI TEST F /BELOW 250/5 MIN 300/10 MIN PSI ZEST F /ABOVE 250/ 5MIN, 3500/ 10MIN. RD /LAY OUT LUBRICATOR 11:30 - 12:00 I 0.50 WHSUR P DECOMP PJSM FOR ND TREE AND ADAPTOR. CREW CHANGEOUT. 12:00 14:00 2.00 WHSUR P DECOMP BLEED OFF PACK -OFF VOID AND CONTROL LINES AS PER FMC REPS. REMOVE BOLTS ON ADAPTER AND TREE W/ SWEENEY WRENCH. LAY DOWN TREE AND ADAPTER. TERMINATE CONTROL LINES. CHECK TUBING ' I HANGER THREADS-. GOOD. 8 1/2 TURNS TO 1 ENGAGE X/O TO HANGER Printed 7/11/2011 10:32:48AM 01 th AmeriC - ALASKA BI? Page 6 of 23 peratian Summary Report - Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 j End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 5/30/2001 12:00:OOAM ' Rig Release: 6/25/2011 Rig Contractor NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth', Phase Description of Operations (hr) ' ( 14:00 - 16:00 2.00 BOPSUR P DECO SLOWLY LOWER BOPS ONTO WELLHEAD - NO MOVEMENT - NIPPLE UP BOPS. -- LEFT MESSAGE W/ AOGCC AT 15:15 TO INFORM OF BOP TEST AT 17:30 -- TORQUE BOLTS W/ SWEENEY WRENCH. INSTALL TURNBUCKLES AND RISER - STACK COMPONENTS ARE 13 -5/8" ANNULAR . PREVENTER, 3 -1/2" X 6" VB PIPE RAMS, BLIND /SHEAR RAMS, MUD CROSS, 2 -7/8" X 5" VB PIPE RAMS. 16:00 - 17:00 I 1.00 BOPSUR P 1 DECOMP ! PERFORM RIG EVAC DRILL AND HOLD AAR WITH ALL ON LOCATION. 17:00 18:00 - 1.00 BOPSUR ' P DECOMP VISUALLY INSPECT (BORESCOPE) BOP STACK. 18:00 19:00 1 1.00 BOPSUR P DECOMP RIGUP FOR BOPE TESTING MAKEUP TOP DRIVE TO 4" TEST JOINT AND . RIH. FILL STACK AND TEST JOINT WITH FRESH WATER. JOINTLY RIGUP TIW AND FLOOR DART VALVE. 19:00 - 20:00 I 1.00 I BOPSUR 1 P I DECOMP ''' BEGIN PRESSURE TESTING BOPE „JESTS WITNESSED BY AOGCC REP BOB NOBLE). - CLOSE UPPER PIPE PIPE RAMS ON 4" TEST i JOINT AND TEST RAMS WITH KILL LINE, !CHOKE MANIFOLD, UPPER IBOP, AND FLOOR DART VALVE. - 5 MIN 250 PSI LOW TEST PASSED. 5 MIN 1 3500 PSI HIGH TEST FAILED. - INSPECT SYSTEM FOR LEAKS. 20:00 - 21:00 1.00 BOPSUR ' P I DECOMP GREASE CHOKE MANIFOLD VALVES 21:00 22:00 1.00 1 BOPSUR ! P DECOMP REPEAT SAME FIRST ROPE TEST. 5 MIN 3500 PSI HIGH TEST FAILED FOR SECOND TIME. - LEAK FROM TOP PIPE RAM DOORS _ I IDENTIFIED. 22:00 - 23:30 1.50 BOPSUR T P DECOMP DRAIN STACK AND CHANGE OUT DOOR SEALS ON TOP PIPE RAMS. 23:30 00:00 0.50 BOPSUR 1 P DECOMP RESUME BOPE TESTING WITH SAME INITIAL FIRST TEST ON TOP PIPE RAMS. - 5 MIN 250 PSI LOW TEST PASSED. 5 MIN 3500 PSI HIGH TEST PASSED. Printed 7/11/2011 10:32:48AM . - North America - ALASKA - BP Page 7 of 23 perati"on Summary Report Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 . End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay j Site: PB X Pad Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 5/30/2001 12:00:OOAM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs Task Code NPT . NPT Depth Phase I Description of Operations (hr) (ft) 6/17/2011 00:00 - 04:00 4.00 BOPSUR P DECOMP (CONTINUE BOPE PRESSURE/FUNCTION TESTING PER AOGCC REGULATIONS AND BP ADWOP FROM 6/16/2011 (STARTED AT 19:00). TESTS WITNESSED BY AOGCC REP BOB NOBLE. ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER (SEE ATTACHED SIGNED PRESSURE CHARTS). - PRESSURE TESTED TO 250 PSI LOW AND ' 3500 PSI HIGH FOR 5 CHARTED MINUTES. D . - TESTED ALL CHOKE MANIFOLD VALVES _ / '1 � (16 TOTAL) +CHOKE/KILL LINES �'1 ¢/ I - MANUAL CHOKE AND MANUAL KILL VALVES. HCR CHOKE AND HCR KILL VALVES (CLOSING TIME BOTH VALVES = 1 SEC) ' - 4" FULL OPENING SAFETY VALVES. - 4" DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS (CLOSING TIME = 12 SEC) ' - UPPER VBRS WITH 4" AND 4 -1/2" TEST JOINTS (CLOSING TIME ON 4 -1/2" TEST JOINT = 7 SEC) 1 , - LOWER VBRS WITH 4" & 4 -1/2" TEST JOINTS (CLOSING TIME ON 4" TEST JOINT = 5 SEC) - TESTED THE ANNULAR PREVENTER WITH 14" TEST JOINT. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. N TIME N4 "T CLOSING I E O EST JOINT = 21 SEC - TESTED THE SUPER CHOKE AND MANUAL BEAN CHOKE. - 2500 PSI HIGH FOR 5 CHARTED MINUTES. - PERFORMED AN ACCUMULATOR DRAWDOWN TEST. - 18 SEC TO 200 PSI, 92 SEC TO FULL 3000 PSI PRESSURE. - 5 BOTTLES WITH 1900 PSI. TESTED THE SIERRA GAS MONITORING SYSTEM. 04:00 - 04:30 0.50 BOPSUR P DECOMP RIGDOWN, BLOWDOWN AND CLEAN FLOOR AFTER BOPE TESTING. 04:30 - 06:00 1.50 I BOPSUR P DECOMP MIRU WELLS SUPPORT VALVE SHOP CREW AND HYDRAULIC LUBRICATOR WITH QUICK TEST SUB AS EXTENSION AND DUTCH RISER. PRESSURE TEST LUBRICATOR, ANNULAR PREVENTER AND TWC TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH. PULL TWC. RDMO VALVE SHOP CREW AND LUBRICATOR. 06:00 07:00 1.00 BOPSUR P DECOMP ' PICKUP LANDING JT. MAKEUP TO CROSSOVER FOR TBG HANGER. RIH AND SCREW INTO TBG HGR (8 TURNS TO MU). - FMC REP ON LOCATION TO BACKOUT , LOCKDOWN SCREWS. ALL BACKED OUT SMOOTHLY. Printed 7/11/2011 10:32:48AM orth America - ALASKA - BP .. Page-8,of 23 peration Summary Report, - . Common Well Name: X-22 _ — — -- l AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 1 End Date: 6/25/2011 X4- OOTMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date /Time: 5/30/2001 12:00:OOAM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To 1 Hrs 1 Task Code ! NPT NPT Depth Phase Description of Operations I 107:00 - 07:30 1 0.50 I PULL P � DECOMP PULL 4 -1/2" TBG HANGER TO RIG FLOOR. I I - INITIAL PICKUP W G HGR LOOSE = 120 KLBS. NO OVERPULL I MAX PU WEIGHT THROUGH STACK = 135 , I l KLBS. I - RUBBER ELEMENTS ON HANGER ALL APPEAR TO BE IN GOOD CONDITION. ;07:30 - 10:00 2.50 PULL P 1 DECOMP I OSE .ANNULAR PREVENTER. CIRCULATE BOTTOMS UP. PUMP 280 BBLS THROUGH I 1 CHOKE @ 3 BPM, 90 PSI. CLEAN RETURNS. - RIG UP SLB SPOOLING UNIT ON RIG FLOOR TO HANDLE CONTROL AND BALANCE LINES 1 ; WHILE POOH. - FLOW CHECK WELL AFTER SHUTTING 1 :DOWN PUMPS. WELL STABLE. ,- LAYDOWN LANDING JOINT, XO AND TUBING .JOINT. 10:00 - 22:00 • 12.00 PULL P i DECOMP POOH WLTH 4 -1/2" TBG F/ JET CUT Coil 10635', MD, NUMBERING AND LAYING DOWN ALL JOINTS. - SLB SPOOLING UNIT RIGGED DOWN AFTER SSSV NIPPLE. HELD KICK WHILE TRIPPING DRILL - RECOVERED THE FOLLOWING FROM THE WELL: ' - 6 SS BANDS (PNEUMATIC CHISEL USED TO REMOVE) ' - 27 CLAMPS AND PINS - 263 JOINTS OF 4 -1/2 ", 12.6 #, 13CR, NSCT 1 TUBING I - (1) SSSV NIPPLE - (1) SWS NIPPLE ! - (6) GAS LIFT MANDRELS ' 1 - CUT JOINT OF 4 -1/2" TUBING - LENGTH = 9.82', OD OF FLARE = 4 -7/8 ", CONDITION = EXCELLENT CUT 22:00 - 23:00 1.00 PULL P DECOMP CLEAR RIG FLOOR AFTER POOH. RIG DOWN TUBING HANDLING EQUIPMENT 23:00 00:00 1.00 PULL P DECOMP ' PREPARE TO RIH W/ 4 -1/2" TBG STUB fRFSSOFF BHA. LIFT UP BHA COMPONENTS TO RIG FLOOR. CHANGEOUT ELEVATORS. RIG UP AIR SLIPS FOR TRIPPING DRILLPIPE. 6/18/2011 00:00 - 02:00 2.00 FISH P DECOMP MAKEUP 4 -1/2" TBG STUB DRESSOFF & 7 -5/8" CSG SCRAPER BHA AND RIH - BHA COMPONENTS BELOW 4" DRILLPIPE, LISTED IN ENTIRETY IN WORKSTRINGS, INCLUDE: - 6 -3/4" X 4 -1/2" DRESSOFF SHOE W/ WASHPIPE EXT. - (1) 4 -3/4" BOOT BASKET ' - (1) 7 -5/8" CSG SCRAPER - (1) 4 -3/4" MAGNET I - 4- 11/16" OIL JARS ' - (6) 4 -3/4" SPIRAL DRILL COLLARS - TOTAL BHA LENGTH = 240.64', TOTAL BHA WEIGHT = 10 KLBS 02:00 09:00 7.00 FISH P DECOMP TRIP IN HOLE WITH 4" DRILLPIPE, PICKING IT ' UP 1X1 FROM PIPE SHED F/ 241' T/ 9450'. 09:00 10:00 1.00 FISH P DECOMP SLIP AND CUT 95' (14 WRAPS) DRILL LINE 10:00 - 10:30 0.50 FISH P DECOMP SERVICE TOP DRIVE, CROWN CLUSTER AND DRAWWORKS. Printed 7/11/2011 10:32:48AM North America - ALASKA - BP Page of 23 ration S umrrta Repoli *oration P • . Common Well Name: X -22 1AFE No Event Type: WORKOVER (WO) 1 Start Date: 6/8/2011 I End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) I 1 Project: Prudhoe Bay I Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:OOAM 1Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To 1 Hrs Task I Code NPT 1 NPT Depth 1 Phase Description of Operations — — - (hr) (ft) 10:30 11:30 1.00 FISH P DECOMP CONTINUE TIH F/ 9450' T/ 10585'. - 116 STANDS PICKED UP IN TOTAL RECIPRICATE 7 -5/8" CSG SCRAPER ACROSS PROPOSED NEW TBG PKR SETTING 'DEPTH 10500' - 10590' MD. , ;_ AVERAGED APPROX. 48 JOINTS PER HOUR. 11:30 12:00 0.50 FISH P DECOMP PICKUP FINAL STAND DRILLPIPE AND TAG TOP OF 4 -1/2" TBG STUB @10636 SLOW PUMP RATES FROM BOTH PUMPS: .90 PSI @2 BPM, 210 PSI @3 BPM, 8.4 PPG SEA WATER, 8731' TVD, 10636' MD • - MILLING PARAMETERS = 135K DWT, 170K UWT, 150 RWT, 60 RPM, 3.5K TQ, 550 PSI, 5 BPM 12:00 - 12:30 0.50 FISH P 1 DECOMP 1DRESS OFF OD OF 4 1/2" TBG STUB @ 10636' • W/ ABOVE NOTED PARAMETERS - SWALLOW • STUB 16! TO MILL AND DRESS +/- 6" - VERIFY I SHOE OVER STUMP W/ NO PUMPS OR ' I ROTATIOh13X ' 12:30 - 13:30 ' 1.00 FISH P DECOMP PUMP 40 BBL HI-VIS SWEEP SURFACE TO '� (SURFACE @ 10BPM/ 1980PSI WHILE RECIP , 1PIPE 13:30 - 17:30 4.00 FISH P - DECOMP -', FLOW CHECK WELL - STATIC - POOH W/ MILLING BHA FROM 10635 - 240' 17:30 18:30 1.00 FISH 1 P DECOMP 1PULL ROTARY BUSHING AND STRIPPING I i RUBBERS. FLOW CHECK WELL. WELL i STATIC. LAY DOWN MILLING BHA - - 1 LB METAL SHAVINGS ON MAGNETS_ 18:30 - 19:30 1.00 I FISH P , DECOMP 1CLEAN AND CLEAR RIG FLOOR FOLLOWING , TRIP. CREW. MIRU SLB E -LINE UNIT #2320. 19 20:30 1.00 EVAL P DECOMP HELD SAFETY MEETING WITH SLB AND RIG 20:30 23:30 3.00 EVAL P , DECOMP ' - RUN GR/ CCUUSIT LOG IN 7 -5/8" CSG F/ 3650' 1MD T/ SURFACE IN 8.5 PPG SEAWATER. - STRONG TOC PICKED @ 3170' (30' ABOVE ' 10 -3/4" SURF CSG SHOE. � - LOG RESULTS DISCUSSED WITH WILMER 2? HOFFMAN, ODE, TO DETERMINE 7 -5/8" CSG CUT DEPTH. - NO CMT STRINGERS APPARENT IN OA FROM 3170' T/ SURFACE. PC 23:30 - 00:00 0.50 EVAL P DECOMP RDMO SLB E- LINE. 6/19/2011 00:00 02:00 2.00 PULL P DECOMP BRING HES 7 -5/8" RBP TO RIG FLOOI5 AND MAKEUP BHA TO RIH. - WSLS EVALUATE USIT LOG W/ SLB E -LINE & WILMER HOFFMAN, ODE - RBP RUN BELOW (6) 4 -3/4" DRILL COLLARS AND 4" DRILLPIPE. Printed 7/11/2011 10:32:48AM . ' Orth America - ALASKA - BP . Page 10 of 23 Aeration Summary Report Common Well Name: X -22 __u AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad -I Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM 1Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) — - (ft) 02:00 - 04:00 2.00 PULL P I DECOMP I RIH W/ HES 7 -5/8" RETRIEVABLE BRIDGE PLUG T/ 3206' CENTER OF ELEMENT, 3202' TOP OF TOOL. HES REP ONSITE. - 106' BELOW PROPOSED 7 -5/8" CSG CUT DEPTH. I RUNNING SPEED IN HOLE = 1 STAND PER I MIN BROKE CIRCULATION AT SET DEPTH AND ' TOOK SPR WITH PUMP #1. - PU WEIGHT @ SET DEPTH = 75 KLBS. 'SLACK OFF 20 KLBS & PICKUP 10 KLBS OVER STRING WEIGHT ON PLUG DURING SETTING I PROCESS. 04:00 - 04:15 0.25 PULL P — DECOMP i CLOSE TOP PIPE RAMS AND TEST RBP TO II 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 10 MIN. TEST CHARTED (SEE ATTACHED) AND 'WITNESSED BY WSL & TOOLPUSHER. PUMPED DOWN BACKSIDE THROUGH KILL 1 . LINE AND THROUGH DRILLSTRING. - 2.1 BBLS EXPECTED TO PRESSURE UP, 2.5 BBLS ACTUAL PUMPED. 04:15 - 07:00 2.75 PULL P DECOMP ', RELEASE FROM RBP AND RACK BACK ONE • STAND OF DRILLPIPE IN DERRICK. RIG UP MIXING TABLE ON TOP OF 4" DRILLPIPE FOR DUMPING SAND. DUMP 27 SACKS (1350 #), 50' 1 DOWN DRILLPIPE ON TOP OF RBP. - ATTEMPT SETTING SEQUENCE FOR RBP AFTER RELEASING FROM PLUG. NO , SUCCESS IN SEQUENCE = GOOD INDICATION ;OF PLUG SET. 07:00 - 08:00 1.00 PULL P DECOMP ,I PUMPED 1 DRILLSTRING VOLUME, 32 BBLS, AT 1/2 BPM, 30 PSI ABOVE SAND TO ENSURE DRILLPIPE CLEAR. 08:00 - 09:00 1.00 PULL , P DECOMP RIH T/ 3181' AND TAG TOP OF SAND (21' 1 1 , ABOVE TOP OF RBP). WELL UNSTABLE, LIGHTWEIGHT FLUID ON INSIDE OF DRILLPIPE. - PUMPED 5 BBLS 9.8 PPG BRINE AS DRY JOB FOR TOH. 09:00 - 10:00 1.00 PULL P DECOMP POOH F/ 3181' T/ 100'. CHECK FOR FLOW 1 PRIOR TO RBP RUNNING TOOL ENTERING STACK. WELL STABLE. 10:00 - 10:30 , 0.50 PULL P DECOMP LAYDOWN HES RBP RUNNING TOOL. PICKUP BAKER MULTI - STRING CUTTER (WITH BLADES SIZED FOR 7 -5/8" CSG), 6 -3/4" OD STABILIZER, (6) 4 -3/4" DC AND RIH. 10:30 - 12:00 1.50 PULL P DECOMP TRIP IN HOLE WITH BAKER MULTISTRING CUTTER ASSY T/ 3050' 12:00 - 13:00 1.00 PULL P DECOMP BREAK CIRCULATION AND DISPLACE HOLE VOLUME FROM 8.5 PPG SEAWATER TO 9.8 PPG BRINE (MW IN = MW OUT). - PITS FULL OF 9.8 PPG BRINE. ALL 8.5 PPG I BRINE HAULED OFF. - CIRCULATED @ 2 -4 BPM, 600 -700 PSI. - BLADES OPEN ON CUTTER. RIH SLOWLY F/ 3050' T/ 3125', ATTEMPT TO LOCATE 7 -5/8" CASING COLLARS. UNABLE TO SEE STRING WEIGHT CHANGE. Printed 7/11/2011 10:32:48AM North America ALASKA - BP Page 11 of 23 M eration Summary Report Common Well Name: X -22 LL AFE No �____ Event Type: WORKOVER (WO) I Start Date: 6/8/2011 1 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES , Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations 1 13:00 - 13:30 I 0.50 PULL P I DECOMP PU (1) STAND DP, RIH T/ 3154'. TAG TOP OF 1 SAND (48' ABOVE TOP OF RBP TOOL). RACK BACK (1) STAND DRILLPIPE. 13:30 16:00 2.50 PULL P DECOMP i RIG UP TO CUT 7 -5/8" CASING AND • • CIRCULATE OUT OA FLUIDS. HELD PJSM WITH LRS, CH2M HILL, RIG 1 ' CREW, MI SWACO AND BAKER FISHING , III - RIG UP OA LINE TO CHOKE MANIFOLD ON ; I 1 RIG FLOOR AND OUT TO TIGER TANK. - PREPARE VAC TRUCK TO TAKE RETURNS FROM CELLAR, SECOND VAC TRUCK RIGGED 1 UP TO TIGER TANK. ,- LRS PUMP TRUCK PRE -HEAT DIESEL TO 90 DEG F. RIG UP L R S TO MUD MANIFOLD ON RIG FLOOR (TO PUMP DIESEL). LRS 1 PRESSURE TEST LINES TO 250 PSI LOW AND 2500 PSI HIGH FOR 5 MIN EACH. `k 16:00 - 17:00 1.00 PULL P DECOMP 11 RIH W/ MULTI - STRING CUTTER T/ 3102' (4/4.4)- ) i � (CUTTER BLADES @ 3100', 70' ABOVE TOC) f. AND CU f 7 -5/8" CASING. ROTATE PIPE 60 RPM, STAGED UP PUMP RATE AS FOLLOWS: - 2 BPM, 775 FT -LBS, 165 PSI - 4 BPM, 1130 FT -LBS, 690 PSI • - 6 BPM, 1150 FT -LBS & INCREASING, 1100 ' PSI - OA CLOSED, RETURNS TAKEN TO PITS . 1 1 DURING CUTTING. - TORQUE SPIKE TO 1500 FT -LBS AT 1 MOMENT OF CUT. 7 -5/8" CSG APPEARED TO COLLAPSE ON ITSELF, PINCHING CUTTER I I BLADES. CONTINUE ROTATING AND I i CIRCULATING FOR A FEW MINUTES TO , I CONFIRM CUT. - NO FLOW TO CELLAR OBSERVED. OA , PRESSURE INCREASED TO 400 PSI AFTER CUT DUE TO 9.8 PPG VS CRUDE IN OA 1 U -TUBE EFFECT. 1 17:00 - 17:30 0.50 PULL P DECOMP CIRCULATE OUT OA FLUIDS: - WITH OA CLOSED AND RETURNS DIRECTED ' TO PITS, LRS PUMP 31 BBLS 90 DEG F DIESEL DOWN DRILLSTRING TO CUTTER, DISPLACING 9.8 PPG BRINE; 2 BPM, 500 -900 PSI. - ANNULAR PREVENTER CLOSED ON 4" . DRILLPIPE AND OA OPENED TO DIRECT RETURNS TO TIGER TANK. RIG PUMPED 1 DRUM SAFE - SURF -O MIXED INTO 40 BBLS FRESH WATER DOWN DRILLSTRING; 2 BPM, ' 150 PSI. DEAD CRUDE RETURNED TO TIGER ' TANK. 17:30 - 18:30 1.00 PULL P DECOMP WAIT ON SOAK TIME WITH 31 BBLS DIESEL + 10 BBLS SAFE - SURF -O /FRESH WATER IN ' OUTER ANNULUS. - RDMO LRS PUMP TRUCK. 18:30 - 20:30 2.00 PULL P DECOMP RESUME CIRCULATING OA FLUIDS OUT OF WELLBORE INTO TIGER TANK. - PUMP 290 BBLS 9.8 PPG BRINE; 6 BPM, 2000 PSI - SHUT DOWN PUMPS AND CHECK WELL FOR FLOW FOR 10 MIN. WELL STABLE - BLOW DOWN CHOKE MANIFOLD & SURFACE EQUIPMENT. Printed 7/11/2011 10:32:48AM orth America - ALASKA - BP Page 12 of 23 peration Summary Report Common Well Name: X -22 `__. _ ____ __- __._ -_____ AFE No ___.___ ____ __ Event Type: WORKOVER (WO) Start Date: 6/8/2011 1 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay I Site: PBX Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To I Hrs Task I Code NPT NPT Depth I Phase ' Description of Operations (hr) (ft) { POOH W/ BAKER MULTI STRING CUTTER F/ 20:30 21:30 1.00 PULL P DECOMP 3102', RACKING BACK DRILLPIPE AND 4 -3/4" DC IN DERRICK. MULTI- STRING CUTTER CONDITION = ' GOOD, WORN, NOT DAMAGED 21:30 - 22:00 0.50 PULL P DECOMP MONITOR WELL / 10 MIN. RACK BACK COLLARS. I r - UD CUTTER AND STABILIZER. — — 22:00 - 22:30 0.50 P PULL DECOMP :CLEAR / CLEAN RIG FLOOR. 22:30 - 00:00 I 1.50 PULL 1 P DECOMP ' PICK UP/ MAKE UP SPEAR,RIH & LATCH UP 75/8" CASING. - BOLDS & RIG UP DOUBLE DECKER CASING TONGS. 6/20/2011 100:00 00:30 1 0.50 PULL I P DECOMP 1CONTINUE TO BOLDS & RIG UP DOUBLE I, DECKER CASING TONGS 00:30 01:30 I 1.00 PULL P DECOMP PJSM. PULL 7-5/8" CASING, 80K TO PULL I 1 FREE AND 105K UP WT. - UD SPEAR ASSEMBLY, HANGER MANDREL I & PACK OFF. M/U CROSSOVERS & (1) JT 4 " DP. M/U TO , TOP DRIVE. 01:30 - 02:30 I 1.00 I PULL T P ' DECOMP CIRCULATE WELL BORE SURFACE TO ' ! SURFACE 9.8 PPG BRINE. - 8 BPM / 100 PSI WHILE RECIROCATING CASING, 100 K UP WT. ' 1 - DUMP 1ST 15 BBLS, (DIESEL . CONTAMINATED) - GET SLOW PUMP RATES BOTH PUMPS - 2 BPM / 30 PSI & 3 BPM / 75 PSI @ 3100' MD. ' 1 I - MONITOR WELL F/ 30 MINUTES / STATIC. 02:30 - 05:00 I 2.50 PULL I P I- 1 DECOMP I POOH W/ 7 5/8 ", 29.7 #, NSCC, NT95HS I ASING. - RECOVERED 77 FULL JTS & 18.46' OF CUTOFF JT. (2) CENTRALIZERS, (SELF LOCKING). ' ! - OD OF FLARE ON CUT = 8 -3/8 ". - AVERAGE BREAKOUT TORQUE FOR 7 -5/8" CSG = 13750 FT -LBS. - CASING CAME OUT CLEAN AND IN GOOD CONDITION. 05:00 - 05:30 0.50 PULL P DECOMP CLEAR CLEAN RIG FLOOR, RIG DOWN CASING TONGS. - MONITOR WELL, WELL STATIC. 05:30 - 06:00 0.50 PULL I P DECOMP SERVICE RIG AND WASHPIPE. 06:00 - 08:00 2.00 FISH P DECOMP PICKUP TOOLS FOR BHA #4 - 7 -5/8" STUB DRFSSOFF AND 10 -3/4" CSC; SCRAPER BHA - BHA OAL = 220.62, WEIGHT = 15 KLBS PORTED FLOAT IN STRING. 08:00 - 09:00 1 1.00 FISH 1 P I I DECOMP I TRIP IN HOLE F/ SURFACE T/ 3100' (TAGGED ' ON 4" DRILLPIPE. 09:00 10:00 1.00 FISH P DECOMP ' BREAK CIRCULATION AND FILL PIPE. - PU WEIGHT = 75 KLBS, SO WEIGHT = 72 ' KLBS ' 10:00 - 11:00 1.00 FISH P DECOMP PJSM. PUMP AND CIRCULATE OUT SAFE SURF 0 SWEEP. 7 BPM / 350 PSI WHILE RECIPROCATING STRING. 75K UP WT, 72K DOWN. 11:00 - 11:30 0.50 FISH P I I DECOMP I MONIOR WELL, 10 MINUTES, WELL STATIC. I I - POOH, RACK BACK (2) STANDS. Printed 7/11/2011 10:32:48AM North America ALASKA BP Page 13 of 23 eration Summary Report Common Well Name: X -22 u I AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 End Date: 6/25/2011 I X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay I Site: PB X Pad Rig Name /No.: NABORS 7ES I Spud Date/Time: 5/30/2001 12:00:00AM I Rig Release: 6/25/2011 Rig Contractor NABORS ALASKA DRILLING INC. , UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To Hrs I Task I Code I NPT NPT Depth !, Phase Description of Operations (hr) (ft) ,11:30 - 12:00 0.50 I FISH P DECOMP I PJSM, PICK HP HALT RI IRTON 1 0 -3/4" RTTS AND ONE STAND DRILLPIPE. 1- 12:00 - 13:30 1.50 I FISH !, P ! DECOMP I PRESSURE TEST 10 -3/4" CASING SHOE TO 1500 PSI. TOTAL STRING WEIGHT BELOW RTTS = 47 I ; KLBS (OK PER HALLIBURTON REP) - SET 10 -3/4" RTTS 47' BELOW WELLHEAD. PRESSURE UP DOWN DRILLPIPE BELOW RTTS TO 1500 PSI, 5 MIN TEST. TEST FAILED. RE- RIGGED DIRECTLY TO DRILL PIPE, BYPASSING MANIFOLD. , - 2ND TEST ALSO FAILED. MONITOR WELL, WELL STATIC. - CONSULTED WITH ENGINEER AND AGREED 4 I TO CONTINUE ON WITH PROGRAM. 13:30 14:00 0.50 FISH P DECOMP I BLEED OFF DRILLPIPE. CLOSE ANNULAR PREVENTER. RELEASE RTTS AND CHECK 1 FOR PRESSURE ON BACKSIDE OF DRILLPIPE DUE TO FLOAT IN DRILLSTRING. RACKBACK ONE STAND DRILLPIPE AND & UD RTTS. 14:00 - 15:00 1.00 FISH P DECOMP POOH W / DRESSOFF ASSEMBLY, RACKING BACK 4" DRILLPIPE AND (6) 4 -3/4" DC IN ', DERRICK. 15:00 16:00 1.00 FISH P DECOMP LAYDOWN DRESSOFF AND SCRAPER BHA. 16:00 - 18:30 1 2.50 BOPSUR . P DECOMP I NIPPLE DOWN BOP STACK AND STAND , BACK. BREAK BOLTS FROM TUBING SPOOL AND CASING HEAD. REMOVE SPOOL AND 1 STARTER HEAD PER FMC DIRECTION. 18:30 - 20:00 1.50 WHSUR P DECOMP ' RIGUP WACHS CUTTER WITH CAMERON AND CUT 10-3/4" CSG 15" ABOVE 20" CONDUCTOR IN CELLAR. RDMO CAMERON WACHS I ! CUTTER. MONITOR WELL. WELL STABLE. 20:00 22:30 2.50 CASING P I INTERV RIG UP TO RUN CASING. CHANGEOUT BAILS ' TO FROM SHORT TO LONG. RU I I COMPENSATOR AND DOUBLE STACK TONGS. NABORS CASING REP ON LOCATION FOR TORQUE TURN. 22:30 - 00:00 1.50 CASING P INTERV RIH W/ 7 -5/8 ", 29.7 #, L -80, VAMTOP HC CASING F/ SURFACE T/ 422' AT MIDNIGHT. - BOWEN CASING PATCH OVERSHOT HAS 3' SWALLOW. ' - CASING PATCH, BAKER EXTERNAL CASING , PACKER, HES ES CEMENTER, AND ASSOCIATED PUPS ALL BAKER - LOCK'D ' PRESSURE TO INFLATE BAKER ECP = 1600 PSI, PRESSURE TO OPEN HES ES 1 CEMENTER = 3300 PSI 1- MAKEUP TORQUE = 14,450 FT -LBS, JET LUBE SEAL GUARD USED. 1 FREE FLOATING CENTRALIZER RUN PER JOINT. Printed 7/11/2011 10:32:48AM . . - . . . . . .. . ■ ' . ' . North America - ALASKA - BP - . r' : ' . ' .: . , - ' ' . r Page 14 of 23 • - : - . . - . . . . . . . . . . . .. . . . :. . . . . . .. . • . : . : '. -.. , eration- Summary Report . . . . . . . . . . .. : . . Common Well Name: X-22 . AFE No Event Type: WORKOVER (WO) I Start Date: 6/8/2011 End Date: 6/25/2011 X4-00TMG-E (3,103,000.00 ) Project: Prudhoe Bay I Site: PB X Pad Rig Name/No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date ' From - To Hrs I Task Code : NPT : NPT Depth Phase Description of Operations (hr) I (ft) 6/21/2011 i 00:00 - 06:30 6.50 I CASING P I : INTERV , CONTINUE T/ RIH W/ 7-5/8", 29.7#, L-80, , 1 , I ' . 1 , I , VAMTOP HC CASING F/ 422' AT MIDNIGHT T/ I . LANDING DEPTH OF 3104' MD. I , : 1 , - SPACEOUT W/ PUPS T/ ENSURE FULL JOINT , , I , , . 1 ACROSS WELLHEAD CUT DEPTH. . 1 ; - CASING PATCH, BAKER EXTERNAL CASING . , : 1 i PACKER, HES ES CEMENTER, AND . . , : I , . , ASSOCIATED PUPS ALL BAKER-LOCK'D . . - TORQUE TURN CONNECTIONS TO OPTIMUM . ' 14,450 FT-LBS, JET LUBE SEAL GUARD USED. • I , I . ' , . - 1 FREE FLOATING CENTRALIZER RUN PER JOINT. , . , I . TAG 7-5/8" CSG STUB @ 3101' AND SLIDE ' 1 , OVER STUB WITH NO ROTATION AND NO . , . I ' . i PUMPING. SWALLOW STUB 3' INTO BOWEN CASING PATCH T/ 3104'. . . 1 , - CONFIRM PATCH GRAPPLE ENGAGED BY , , I PU/SO 25 KLBS, PU/SO 40 KLBS, AND PICKUP , . . . . T/ 150 KLBS. , . - SLACKOFF TO NEUTRAL STRING AND . : . 1BLOCK WEIGHT (105 KLBS) FOR ECP . . - I . : INFLATION AND CEMENT JOB. I 1 . ' . ' 06:30 - 08:00 . 1.50 CEMT P t r . INTERV RjG UP HALLIBURTON CEMENTING , . . , . . . • EQUIPMENT ON RIG FLOOR. "DOUBLE PLUG" 'CEMENTING HEAD INSTALLED ON VAMTOP ., . 1 ; ; . HC BY BTC X0 ON TOP OF 7-5/8" CASING THROUGH RIG FLOOR. . : . , - CENTRALIZE 7-5/8" CSG IN 10-3/4" CASING . : I WITH WEDGES PRIOR TO CEMENTING. . . . : . , : . . - SPOT IN SLB CEMENTERS AND CH2M HILL - . ; . SUPPORT FLUID TRUCKS. . , - WSL WITNESSED LOADING OF PLUG IN . . HEAD. - RU SCAFFOLDING PLATFORM ON RIG , . . : . FLOOR TO ACCESS CEMENTING HEAD . ' - PRESSURE TEST LINES ON RIG FROM , I . PUMPS TO HES CEMENTING HEAD T/ 4000 , . I .• . ! . . , PSI . . . : - SLB PUMP TRUCK RIG UP TO RIG CEMENT . . . . . . LINE THROUGH MUD MANIFOLD. 08:00 - 09:00 ' 1.00 CASING : P ' INTERV PRESSURE TEST BOWEN CASING PATCH TO . . 1000 PSI FOR 10 MIN (PASS). INFLATE BAKER EXTERNAL CASING PACKER (ECP). - INFLATION PRESSURE STAGED UP FROM I , , ; . . 1000 PSI TO 1200 PSI AND THEN TO 1510 PSI (SHEAR AND BEGIN INFLATION). PRESSURE , . . . , BLEED OFF TO 1000 PSI AND THEN EQUAL VOLUME PUMPED BACK INTO PACKER BAG TO CONFIRM INFLATION. PRESSURE TESTED ECP TO 2000 PSI FOR 10 MINUTES , . (PASS). PRESSURE BLEED OFF TO ZERO. . . . . . - PRESSURE UP TO 3500 PSI (EXPECTED SHEAR PRESSURE FOR 6 PINS = 3300 PSI) . : TO OPEN HES ES CEMENTER. VISUAL . . . , PRESSURE RELEASE OBSERVED ON . , BACKSIDE OF PIPE WHEN ES TOOL OPENED. , . - TESTS CHARTED, WITNESSED BY WSL AND . , . ' NABORS TOOLPUSHER (SEE ATTACHED). . . Printed 7/11/2011 10:32:48AM ,,,, North America - ALASKA - BP Page 15 of 23 eration Summary Report P rY rt P _ _ Common Well Name: X -22 _.- �.._._ AFE No —._ -- Event Type: WORKOVER (WO) Start Date: 6/8/2011 End Date: 6/25/2011 ,X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad I Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations - -.__- ( hr) - -- - ---- " - " - L— - 1 ' (ft) '---- - - - - -- 09:00 - 10:00 1.00 CEMT P , � INTERV CIRCULATE AND CONDITION HOLE FOR CEMENTING. PUMP HOLE VOLUME (265 BBLS) OF 90 DEG F 9.8 PPG BRINE @ 6 BPM, 300 PSI. FLUID TEMP IN AND OUT = 80 DEG i F. 10:00 - 12:00 • 2.00 CEMT P INTERV CEMENT 7 -5/8 ", 29.7 #, L -80 CASING TIE- BACK/PATCH WITH RETURNS TO CELLAR 1AS FOLLOWS: - HOLD PRE -JOB SAFETY MEETING WITH ALL INVOLVED ON LOCATION. - SLB PUMP 5 BBLS FRESH WATER AHEAD AND PRESSURE TEST LINES T/ 4000 PSI. SLB CHECK PUMP TRIPS @ 1500 PSI. PUMP I 1 I TRUCK POP OFFS SET @ 4800 PSI. - SLB PUMP 145 BBLS 15.6 PPG, CLASS G, 1.17 CUFT /SK, CEMENT @ 5 BPM. Cl" SHUTDOWN PUMP U - DROP PLUG FROM CEMENTING HEAD (WITNESSED BY WSL). SLB PUMP 5 BBLS FRESH WATER @ 5 BPM BEHIND PLUG TO CLEANUP LINES. SLB SHUTDOWN. LINE UP RIG PUMPS. RIG DISPLACES CEMENT WITH 135 BBLS 9.8 BRINE @ 5 BPM. 1 ;TOTAL DISPLACEMENT = 140 BBLS ' (CALCULATED = 140.5 BBLS). BUMP PLUG AT 1075 PSI FCP. INCREASED PRESSURE TO 2450 PSI TO CLOSE ES CEMENTER. HELD • !PRESSURE FOR 3 MIN AND BLEED OFF. - MONITOR CEMENTING HEAD FOR FLOWBACK FOR 10 MINUTES. FLOATS HOLDING. i 1 - 30 BBLS GOOD CEMENT RETURNS TO CELLAR (SUPERSUCKER ON LOCATION TO VAC OUT CMT RETURNS) 12:00 - 15:30 3.50 CEMT P INTERV ,RIG DOWN AFTER CEMENTING OPERATIONS. - RDMO SLB CEMENTING UNITS. - RD HALLIBURTON CEMENTING HEAD AND BREAKOUT CEMENTING HEAD XO. - VAC OUT LANDING JOINT DOWN TO 7 -5/8" ' CSG CUT DEPTH FOR SLIP LOCK WH. 15:30 - 17:00 1.50 WHSUR P INTERV CAMERON CUT IN 7 -5/8" CASING WITH WACHS CUTTER. - 7 -5/8" CASING RE- CENTRALIZED IN 10 -3/4" CSG WITH WEDGES PRIOR TO CUT. - 7 -5/8" CSG STRING WEIGHT HELD BY BLOCKS DURING CEMENT JOB. WHEN WEIGHT SLACKED OFF, 7 -5/8" CSG ' LOWERED 8 ". 17:00 - 20:00 3.00 WHSUR P INTERV CAMERON REPRESENTATIVES ONSITE TO INSTALL SLIP LOCK WH ON 7 -5/8" CASING.- - TIGHTEN FLANGE TO ENERGIZE SEALS. - TEST SEALS, 500 PSI LOW FOR 5 MIN, 5000 PSI HIGH FOR 30 MIN - CAMERON CHARTED PRESSURE TEST (SEE ' ATTACHED) Printed 7/11/2011 10:32:48AM North America ALASKA BP Page 16 of 23 . eration Summary Report Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) ! Start Date: 6/8/2011 1 End Date: 6/25/2011 ` X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date • From - To Hrs I Task Code • NPT NPT Depth , Phase Description of Operations 20:00 - 23:00 3.00 BOPSUR P - -_- (ft) INTERV PJSM. N/U 13-5/8" X 5M BOPE. I - INSTALL SECONDARY ANNULUS VALVE ON INNER ANNULUS. - SET DOUBLE STUD ADAPTER AND BOP ON WELLHEAD. I - TORQUE W/ SWEENEY WRENCH - INSTALL TURNBUCKLES AND RISER. 23:00 - 00:00 1.00 BOPSUR I P INTERV PJSM. RIG UP TEST TOOLS. - MU 4" TEST JT TO TEST PLUG, RIH & SET. FILL BOP STACK AND CHOKE W/ FRESH 'WATER. 6/22/2011 00:00 - 05:00 5.00 BOPSUR ' P T , INTERV CONDUCT WEEKLY TEST ON BOPE. AOGCC REP BOB NOBLE NOTIFIED, WAIVED WITNESSING. TESTS WITNESSED BY WSL & TOOLPUSHER. Q I PRESSURE TESTED TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH (SEE ATTACHED) • f - TESTED ALL CHOKE MANIFOLD VALVES (16 TOTAL) + CHOKE/KILL LINES - MANUAL CHOKE AND MANUAL KILL [VALVES. - HCR CHOKE AND HCR KILL VALVES (CLOSING TIME BOTH VALVES = 3 SEC) - 3 -1/2" & 4" FULL OPENING SAFETY VALVES. - 4" DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. I , , , , - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS (CLOSING TIME = 12 I SEC) I I - UPPER VBRS, (3 -1/2" X 6 "), WITH 4" AND 4 -1/2" TEST JOINTS (CLOSING TIME ON 4 -1/2" • , TEST JOINT = 6 SEC) - LOWER VBRS, (2 -7/8" X 5 "), WITH 4" & ' ' 4 -1/2" TEST JOINTS (CLOSING TIME ON 4" TEST JOINT = 6 SEC) - TESTED THE ANNULAR PREVENTER WITH 4" TEST JOINT. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. `■ - CLOSING TIME ON 4" TEST JOINT = 25 SEC - TESTED THE SUPER CHOKE AND MANUAL BEAN CHOKE. - 2500 PSI HIGH FOR 5 CHARTED MINUTES. PERFORMED AN ACCUMULATOR DRAWDOWN TEST. - 1560 PSI AFTER CLOSURE SEQUENCE ' ' ' COMPLETED. - 21 SEC TO 200 PSI, 98 SEC TO FULL 3000 PSI PRESSURE. - 5 BOTTLES WITH 1900 PSI. - TESTED THE SIERRA GAS MONITORING SYSTEM. 05:00 - 05:30 0.50 BOPSUR P INTERV RIG DOWN TEST EQUIPMENT. BLOW DOWN CHOKE MANIFOLD & TEST LINES. INSTALL WEAR BUSHING, 9" ID, 10 -7/8" OD. Printed 7/11/2011 10:32:48AM Page 17 of 23 North America - ALASKA - BP • . _ . 0 ' eration Summary Report Common Well Name: X-22 IAFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 I End Date: 6/25/2011 X4-00TMG-E (3,103,000.00 ) , 1 I Project: Prudhoe Bay Site: PB X Pad Rig Name/No.: NABORS 7ES ' Spud Date/Time: 5/30/2001 12:00:00AM I Rig Release: 6/25/2011 I Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date I From - To I Hrs I Task Code 1 NPT NPT Depth , Phase , Description of Operations I , 1 I (hr) ' (ft) I I 05:30 - 06:00 I 0.50 WHSUR P , I INTERV I PERFORM TOP OFF CEMENT JOB IN CELLAR , I TO FILL 7' VOID AFTER TOP OF CEMENT , . I , , I FELL. , , I - MIX & DUMP CEMENT BETWEEN 10-3/4" & 1 , [7-5/8" CASING IN CELLAR, 13 GAL. 06:00 - 06:30 0.50 CLEAN P , , INTERV BRING BAKER TOOLS TO RIG FLOOR. I 06:30 - 07:30 1.00 , CLEAN P I INTERV PICK UP / MAKE UP SHOE TRACK MILLING ' BHA. 1- 07:30 - 08:30 1.00 CLEAN 1 P , . INTERV PJSM. RIH W/ SHOE TRACK MILLING BHA. 1 ' - TAG TOP OF CEMENT @ 2988' MD (73', 3.3 BBLS ABOVE ES CEMENTER PORTS @ 3061') STRING WEIGHTS = 72 KLBS PU WT, 72 KLBS SO. 08:30 - 09:00 0.50 I CLEAN P I , , INTERV I DISPLACE WELL FROM 9.8 PPG BRINE TO 8.5 I ' I PPG SEAWATER. I . . , - PUMP DOWN DP @ 8 BPM. 820 PSI, 1 I COMPLETE HOLE VOLUME I , - OBTAIN SLOW PUMP RATES, BOTH PUMPS 09:00 - 13:00 4.00 CLEAN 1 P , 1 INTERV PJSM. DRILL OUT SHOE TRACK / CEMENT. I 1 I - ESTABLISH PARAMETERS, 72K LBS UP WT, I , , I 72K LBS DOWN, 72K LBS ROT WT. -8 BPM, 660 PSI, 60 RPM, 1K FT-LBS TORQUE , [ OFF BOTTOM. . - DRILL PLUG W/ 5K WOB. 13:00 - 13:30 ' 0.50 CLEAN . P ' INTERV , PJSM. PUMP 20 BBLS HI VIS SWEEP & . . , CHASE WITH SEAWATER. - CIRCULATE SURFACE TO SURFACE, 8 BPM, 650 PSI. I I , , 1 I - ROTATE & RECIPROCATE, 70 RPM, 700 F 1 FT-LBS TORQUE. 13:30 - 14:00 0.50 CLEAN , P 1 ' INTERV ' PJSM. QONTINUE TO RIH TO TOP OF SAND I 1 1 0 3154' (52' ABOVE TOP OF RBP 3206' 1 , , - DRY DRILL ON PLUG, 60 RPM, 1100 FT-LBS I Of TORQUE : I - 3K LBS WOB, DRILL ON PLUG, 72K LBS UP/DOWN/ROT WT. 14:00 - 14:30 0.50 CLEAN P INTERV PJSM. PUMP 20 BBLS HI VIS SWEEP, 8 BPM, 680 PSI. - ROTATE @ 20 RPM , 600 FT-LBS TORQUE, RECIPROCATE PIPE. 14:30 - 15:30 1.00 CLEAN P ' INTERV PJSM. POOH W/ SHOE DRILLING BHA. 15:30 - 16:00 0.50 CLEAN P INTERV RACK BACK 4-3/4" DRILL COLLARS, UD BIT, EMPTY JUNK SUBS. 16:00 - 17:00 1.00 CLEAN P INTERV PJSM. M/U REVERSE CIRCULATING JUNK BASKET BHA. 17:00 - 18:00 1.00 CLEAN P INTERV '* REVERSE CIRCULATING JUNK BASKET RUN #1 " PJSM. RIH W/ RCJB ASSEMBLY TO 3154', 31 STANDS. 75K LBS UP AND DOWN. 18:00 - 19:00 1.00 CLEAN , P INTERV PJSM. DROP 7/8" STEEL BALL. CIRC ON [ SEAT @ 3.5 BPM / 230 PSI. - ESTABLISH PARAMETERS. 70 RPM, 700 FT-LBS TORQUE OFF BOTTOM. - 75K LBS UP, DOWN AND ROTATING WTS. - PUMP 1.5 BPM, 70 PSI & SLACK OFF 5- 10 KLBS, ROTATING 60 RPM, 2000 - 3000 FT-LBS TORQUE, MILL 2'. - PICK UP AND BRING PUMPS TO 8 BPM, 1550 1 , PSI & SLACK OFF TO 3165'. Printed 7/11/2011 10:32:48AM North America - ALASKA - BP Page 18 of 23 .0 . . , Peration Summary Report : - . , - . ' Common Well Name: X -22 �� AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 1 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM 1Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. i UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To 1 Hrs 1 Task Code 1, NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 CLEAN 1 P INTERV PJSM. POOH W/ RCJB ASSEMBLY. 20:00 - 21:00 1.00 1 CLEAN P 1 1 INTERV 1 PJSM. RACK BACK 4 -3/4" DRILL COLLARS, I I I EMPTY JUNK SUBS. 1 1- L/D 7 -5/8" CASING SCRAPER. EMPTY RCJB, RECOVERED PARTIAL RING AND BRASS PIN. ' - REMAINDER OF PLUG/JUNK IN HOLE, _ 1 4 ;DECISION MADE TO MAKE ADDITIONAL RUN. 21:00 - 21:30 0.50 CLEAN r P INTERV PJSM. PICKUP SAME BHA MINUS CASING SCRAPER. 21:30 - 23:00 1.50 CLEAN P T INTERV '" REVERSE CIRCULATING JUNK BASKET RUN #2" PJSM. RIH W/ 2ND RCJB ASSEMBLY ON 4" DP. 123:00 - 00:00 1.00 CLEAN 1 P 1 INTERV 1 PJSM. ESTABLISH PARAMETERS. 75 KLBS I UP, DOWN AND ROT WTS. - RIH TO 3165'. PUMP 1 BPM / 55 PSI & SET DOWN 5 - 10K, ROTATING @ 50 - 60 RPM. GRIND ON JUNK ON TOP OF SAND FOR 2', ON BTM TORQUE 2000 - 3000 FT -LBS. ' r PICK UP AND BRING ON PUMPS TO 8 BPM, 1700 PSI & TAKE A BITE. I I 1- VACUUM DOWN TO 3175' AT MIDNIGHT , ,(CONTINUE ON NEXT REPORT). 6/23/2011 00:00 01:00 1.00 CLEAN 1 P 1 INTERV I CONTINUE TO WASH & CLEANOUT SAND /JUNK W/ RCJB F/ 3075' T/ 3182' (24' ABOVE RBP @ 3206') 1 - OPERATING PARAMETERS: 8 BPM, 23 -50 TDS RPM, 800 FT -LBS TORQUE, 5 -8 KLBS 1 WOB, 75 KLBS ROTATING WEIGHT, 1650 PSI - PUMP HI-VIS SWEEP SURFACE TO ! ' SURFACE. SAND OBSERVED IN RETURNS AT SHAKERS. 01:00 - 02:00 1.00 CLEAN 1 P INTERV POOH W/ RCJB F/ 3182' TO 235' (BHA), RACKING BACK 4" DRILLPIPE. - CHECK FOR FLOW ON BOTTOM AND PRIOR TO BHA ENTERING STACK. WELL STABLE. - BLOWDOWN TDS PRIOR TO TRIP OUT. 02:00 - 03:00 1.00 CLEAN P INTERV CLEANOUT REVERSE CIRCULATING JUNK BASKET AND PREPARE TO RUN BACK IN HOLE WITH SAME. - MORE CEMENT RETURNS AND TWO MORE BRASS PINS RETURNED IN RCJB. 03:00 - 03:30 0.50 CLEAN P INTERV UNANNOUNCED BOP DRILL WHILE MAKING UP DRILL COLLARS FOR NEXT RCJB RUN. - FLOW PADDLE MANIPULATED TO SIMULATE FLOW INCREASE - SIMULATED CLOSING OF ANNULAR PREVENTER & OPENING OF HCR. FOSV STABBED & CLOSED. - AAR HELD TO REVIEW CREW POSITIONS AND OVERALL RESPONSE. ! 03:30 - 05:00 ` 1.50 CLEAN P INTERV * REVERSE CIRCULATING JUNK BASKET RUN #3 " TIH W/ RCJB (BHA #8) ON 4" DRILLPIPE F/ 235' ! T/ 3182'. Printed 7/11/2011 10:32:48AM Page 19 of 23 North 'America'- ALASKA - BP r on Summary Report Ate ration Common Well Name: X-22 , AFE No Event Type: WORKOVER (WO) I Start Date: 6/8/2011 ' End Date: 6/25/2011 X4-00TMG-E (3,103,000.00 ) 1 1 Project: Prudhoe Bay ! Site: PBX Pad Rig Name/No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. i UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date ' From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 05:00 - 06:00 1.00 CLEAN P , INTERV TAG JUNK/SAND @ 3182' AND RESUME CLEANING OUT JUNK SAND T/ 3192'. , I - OPERATING PARAMETERS: 8 BPM, 0 KLBS I , 1 1 I WOB, 1600 PSI, 50 RPM, 1000 FT-LBS , 1 TORQUE I I 1 1- WASH AND ROTATE DOWN 10' W/ NO WOB , I , - PUMP 20 BBL HI-VIS SWEEP SURFACE TO , 1 ' 1 . SURFACE AND OBSERVE SAND IN RETURNS AT SHAKERS. , 06:00 - 07:00 1.00 CLEAN „ P INTERV !POOH W/ RCJB F/ 3192' TO 235' (BHA), RACKING BACK 4" DRILLPIPE. - CHECK FOR FLOW ON BOTTOM AND PRIOR ! I , TO BHA ENTERING STACK. WELL STABLE. I , - BLOWDOWN TDS PRIOR TO TRIP OUT. 07:00 - 08:00 1 1.00 CLEAN I P ' ' INTERV HELD PJSM. LAYDOWN RCJB BHA. 1 1 1 1 - ONLY MINOR VOLUME OF SAND FOUND IN I 1 I 1 1 I JUNK BASKETS. NO MAJOR JUNK I , 1 1 I RETRIEVED ON THIRD RUN. 1- CLEAR RIG FLOOR OF RCJB BHA 08:00 - 09:00 1 1.00 CASING P . INTERV I PRESSURETEST 7-5/8" CASING FROM ,... 1 I , SURFACE TO RBP 0 3206' MD 1 , - CLOSE BLIND RAMS AND PUMP DOWN KILL LINE. ,- CHART 250 PSI LOW TEST FOR 5 MIN AND . , 3500 PSI HIGH TEST FOR 30 MIN (SEE , 1 ATTACHED). , I , 1 , - TESTS WITNESSED BY WSL AND APPROVAL TO PROCEED GAINED FROM , , • VVTL. , 09:00 - 10:00 1.00 CLEAN P • INTERV TIH WITH HES RBP RETRIEVING TOOL F/ SURFACE T/ 3192' MD. 10:00 - 11:30 1.50 CLEAN ' P 1 INTERV I WASH DOWN TO TOP OF RBP @ 3206'. . , I CIRCULATE OUT SAND WITH 20 BBL HI-VIS SWEEP. RIH T/ 3206' AND LATCH INTO RBP. . 1 , I PU AND RELEASE RBP. CHECK FOR FLOW. WELL STABLE. , , I - RIH TO 5' PAST SET DEPTH TO CONFIRM PLUG UNSET PRIOR TO POOH. - OBTAIN SLOW PUMP RATES FOR PUMP #1 & #2 11:30 - 14:00 2.50 CLEAN P INTERV , TOH W/ HES RBP RETRIEVING TOOL & RBP F/ 3206' MD T/ SURFACE. LAYDOWN RBP AND TOOL. - CHECK FOR FLOW PRIOR TO BHA ENTERING STACK. WELL STABLE. BLOWDOWN TDS AT START OF TRIP. 14:00 - 15:00 1.00 CLEAN P INTERV RIG UP EQUIPMENT ON RIG FLOOR TO RUN 2-7/8" PAC PIPE ON JUNK CATCHER FISHING RUN. 15:00 - 16:00 1.00 CLEAN P INTERV HELD PJSM. PU & MU BAKER TOOLS FOR ' JUNK CATCHER FISHING ASSY - OAL 348.56' TOOLSTRING INCLUDES: -4 JTS 2-7/8" PAC PIPE MADE UP TO 4.6 1 , KFT-LBS I ' 1 - 5-3/4" X 2-3/8" SHEAR PIN GUIDE - 4-3/4" BUMPER & OIL JARS ' - (6) 4-3/4" SPIRAL STEEL DRILL COLLARS - 2-13/16" ITCO SPEAR (COVERED BY TSS EXTENSION) Printed 7/11/2011 10:32:48AM North America - ALAS - BP Page 20 of 23 ra ion Summary Report p e t� mm rY p Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 I End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date ( ) From Co Depth Phase Description of Operations 16:00 21:30 5.50 . CLEAN NPT NPT N P (ft) !I INTERV ' TRIP IN HOLE W/ JUNK CATCHER FISHING ! ASSY F/ 348' T/ 10,635' MD. I - OBSERVE SHEAR PIN GUIDE ASSEMBLY 1 SHEAR @ 10,635, TOP OF 4 -1/2" TBG. ! - RIH TO 10,689' & TAG. ATTEMPT TO CIRCULATE AT VARIOUS RATES TO GET DEEPER. 1 - UNABLE TO GET DEEPER, CONSULT WITH WTL WILMER HOFFMAN AND ENGINEER SEAN MCLOUGHLIN. - DECISION MADE TO POOH & L/D DP. 21:30 00:00 2.50 CLEAN P I INTERV ; POOH F/ 10689' MDT/ 7550' AT MIDNIGHT, LAYING DOWN 4" DRILLPIPE. , 1 - PJSM. MONITOR WELL FOR 15 MIN ON •BOTTOM. WELL STATIC. 6/24/2011 00:00 - 06:00 6.00 CLEAN P , INTERV CONTINUE TO TOR Fl 7550' MD @ MIDNIGHT T/ 350' (BHA), LAYING DOWN 4" DRILLPIPE. T06:00 - 08:30 2.50 CLEAN P INTERV ! PJSM. MONITOR WELL PRIOR TO PULLING BHA THRU STACK, WELL STATIC. - RECOVERED JUNK CATCHER FROM TOP OF ' PX Pt tK; IN TBG 0 10702' MR. UD 4 -3/4" DC, RU POWER TONGS & UD 2 -7/8" PAC PIPE - UD SPEAR BHA, CLEAR / CLEAN RIG FLOOR. 08:30 - 10:30 2.00 RUNCOM ! P 1 RUNCMP PJSM. RIG UP TO RUN 4 -1/2" VAM TOP COMPLETION. - R/U LONG BALES, SINGLE JOINT ELEVATORS, COMPENSATOR & STABBING BOARD. - RIG UP DOUBLE STACK TONGS, REMOVE WEAR BUSHING. - MAKE DUMMY RUN W / TUBING HANGER, MARK LANDING JOINT AT RIG FLOOR. 10:30 23:30 13.00 RUNCOM P ' RUNCMP PJSM. PICK UP & RIH UNIQUE MACHINE OVERSHOT WITH DUAL SETS OF SHEAR ' PINS. - PICK UP / MAKE UP ALL COMPONENTS OF COMPLETION AS PER WELL PROGRAM AND PIPE TALLY. ' - ALL CONNECTIONS BELOW PACKER ARE BAKER LOCKED. RIH WITH 4 -1/2 ", 12.6 #, 13CR -85 TUBING USING SINGLE JOINT COMPENSATOR. - USING JET LUBE SEAL GUARD PIPE DOPE AND RUNNING RABBIT THROUGH ALL JOINTS PRIOR TO GOING DOWNHOLE. - NABORS CASING REP ONSITE WITH TORQUE TURN MAKING UP ALL VAMTOP CONNECTIONS TO OPTIMUM 4440 FT /LBS. 23:30 - 00:00 0.50 RUNCOM P RUNCMP SPACE OUT COMPLETION - TAG TOP OF TBG STUB a 10635' MD. CONTINUE IN HOLE AND TAG FIRST PINS © ,10639'. SHEAR PINS WITH 6 KLBS DOWN WEIGHT. CONTINUE IN HOLE AND TAG SECOND SHEAR PINS @ 10647'. SHEAR PINS W/ 6 KLBS DOWN WEIGHT. CONTINUE IN I HOLE T/ OVERSHOT NO-GO @ 10650'. PICKUP OFF STUB, LAYDOWN FULL JOINTS ! AND PICKUP PUP JOINTS AS NECESSARY FOR SPACE OUT. Printed 7/11/2011 10:32:48AM North America - ALASKA - BP Page:21 of 23 t e ration Summary Report - , Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) I Start Date: 6/8/2011 I End Date: 6/25/2011 I X4- OOTMG -E (3,103,000.00 ) Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date /Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) ! , 6/25/2011 00:00 - 00:30 ! 0.50 RUNCOM P RUNCMP CONTINUE TO SPACE OUT COMPLETION. FINAL LANDING DEPTH = 10645' MD, 8722' TVD (10' SWALLOW W/ OVERSHOT) ' - RUN PUP JOINTS IN BELOW ONE FULL JOINT. PICKUP LANDING JOINT MADEUP TO CAMERON 11" X 4 -1/2" TYPE H TCII TUBING HANGER. RIH W/ SAME. LANDING WEIGHT = 143 KLBS UP, 120 KLBS DOWN. - 7 -5/8" X 4 -1/2" HES TNT PKR TOP SET @ 10526' MD, COE © 10524' MD, 8651' TVD FINAL DEPTHS OF GLMS: KBMG GLM #1 @ 10420' MD, 8588' ND - 1" I I , [ i DMY GLV W/ BK LATCH KBMG GLM #2 © 8399' MD, 7202' TVD - 1" DMY GLV W!' BK LATCH KBMG GLM #3 @ 6049' MD, 5611' TVD - 1" DMY GLV W/ BK LATCH KBMG GLM #4 @ 2505' MD, 2504' ND - 1" DCK SHEAR VLV W/ BEK LATCH 100:30 - 01:00 1 0.50 RUNCOM P j R PULL LANDING JOINT AND LAYDOWN. RIG I DOWN DOUBLE STACK TONGS, COMPENSATOR AND OTHER COMPLETION I RUNNING EQUIPMENT. CAMERON REP ONSITE TO RUN IN LOCKDOWN SCREWS ON TUBING HANGER. 01:00 - 04:00 3.00 RUNCOM 1 P RUNCMP REVERSE CIRCULATE FOLLOWING FLUIDS. LINE UP SECONDARY KILL LINE TO PUMP DOWN IA, TAKING RETURNS DOWN FLOWLINE. - 160 BBLS 8.5 PPG 120 DEG F SEAWATER. - 3 BPM, INITIAL CIRCULATING PRESSURE = 1100 PSI, FINAL CIRC PRESSURE = 800 PSI � - 290 BBLS 8.5 PPG 120 DEG F SEAWATER W/ KI -3908 CORROSION INHIBITOR (1 DRUM PER 2k0 BBLS, MIXED AT MI FACILITY) - 3 BPM, ICP = 700 PSI, FCP = 800 PSI - 10 BBLS 8.5 PPG SEAWATER TO FLUSH LINES BEHIND INHIBITED FLUID. ! Printed 7/11/2011 10:32:48AM North America - ALASKA - BP Page 22 of 23 er tian Summa Report � rY � Common Well Name: X -22 1 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) ' Project: Prudhoe Bay Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date 1 From - To 1 Hrs 1 Task Code NPT NPT Depth' Phase I Description of Operations 104:00 - 07:00 ' 3.00 I RUNCOM r P (ft) — • RUNCMP j DROP 1 -7/8" BALL & ROD ON ROLLER STEM AND LET FALL T/ RHCM PLUG IN X NIPPLE @ 10559' MD. LAYDOWN LANDING JOINT AND CLOSE BLIND RAMS FOR INTEGRITY . TESTING. TESTS CHARTED AND WITNESSED ' BY WSL (SEE ATTACHED). 1- ROLLER STEM OD = 2 ", FISHING NECK = 1.375 ", B &R PULLING TOOL = 2" SB/RB, RHCM PLUG PULLING TOOL = 4.5" GS/GR i- 4 -1/2" COMPLETION INTEGRITY TESTING AS FOLLOWS: - PRESSURE UP ON TUBING T/ 2910 PSI TO SET HES TNT PKR. PKR OBSERVED TO , BEGIN SETTING AT 1800 PSI. CONTINUE TO PRESSURE UP TUBING. ' - NEW 4 -1/2" TBG PRESSURE TEST FROM ' SURFACE T/ B &R © 10559' MD: PERFORM 5 1 ' MIN 250 PSI LOW AND 30 MIN 3500 PSI HIGH , j PRESSURE TEST (PASS). BLEED OFF TUBING PRESSURE T/ 1500 PSI. IA PRESSURE TEST T/ 10526" PKR DEPTH: PERFORM 5 MIN 250 PSI LOW AND 30 MIN 3500 PSI HIGH PRESSURE TEST (PASS). BLEED OFF TUBING PRESSURE T/ ' 1500 PSI WITH 1500 PSI HELD ON TUBING. ' BLEED BOTH TUBING AND IA TO ZERO PSI. RESULTS OF PRESSURE TESTING REVIEWED WITH WTL DESIGNEE AND 1 , AUTHORIZATION TO PROCEED GAINED. - SHEAR 1" DCK VLV IN GLM #4 @ 2505': PRESSURE UP ON IA T/ 2500 PSI AND OBSERVE SHEARING OF VALVE. CIRCULATE 3 BBLS EACH WAY THROUGH GLM #4 T/ CONFIRM VALVE SHEARED. 07:00 - 08:30 ' 1.50 BOPSUR P RUNCMP CAMERON REP ONSITE TO INSTALL 1 CAMERON 4 -1/2" TYPE H TWC. ' , , 1 - PERFORM 10 MIN 250 PSI LOW AND 10 MIN ' 1000 PSI HIGH PRESSURE TEST BELOW TWC DOWN TO B &R, OBSERVED BY WSL & CHARTED. - PERFORM 10 MIN 250 PSI LOW AND 10 MIN 3500 PSI HIGH PRESSURE TEST ABOVE TWC, OBSERVED BY WSL & CHARTED. 08:30 - 10:30 2.00 BOPSUR P RUNCMP NIPPLF DOWN ROP STACK AND SECURE ON STUMP FOR RIG MOVE. 10:30 - 14:30 4.00 WHSUR P RUNCMP CAMERON REP ON LOCATION TO NIPPLE UP 11" X 4- 1/16" 5K ADAPTER FLANGE AND PRESSURE TEST TUBING HANGER VOID. - TEST VOID AND SEAL TO 250 PSI LOW FOR 5 MIN AND 5000 PSI HIGH FOR 30 MIN. TESTS 'BOTH PASS (CHART ATTACHED) 14:30 - 15:00 0.50 WHSUR P RUNCMP PJSM. N/U 4- 1/16" X 5M CAMERON TREE - CYCLE VALVES PRIOR TO TESTING TO FILL VOIDS WITH FLUID. 15:00 - 16:30 1.50 WHSUR P RUNCMP PRESSURE TEST TREE W/ DIESEL. - RECORD 250 PSI FOR 5 MIN & 3500 PSI FOR 30 MINUTES (PASS, SEE ATTACHED CHART) 16:30 - 18:00 I 1.50 WHSUR P RUNCMP PJSM. P/U LUBRICATOR & PULL CIW 4 -1/2" , TYPE H TWC. , - PRESSURE TEST LUBRICATOR TO 250 PSI LOW & 3500 PSI HIG FOR 5 MIN EACH. Printed 7/11/2011 10:32:48AM North America - ALASKA - BP Page 23 of 23 tration Summary _ rY Report' Common Well Name: X -22 AFE No Event Type: WORKOVER (WO) Start Date: 6/8/2011 End Date: 6/25/2011 X4- 00TMG -E (3,103,000.00 ) I Project: Prudhoe Bay I Site: PB X Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 5/30/2001 12:00:00AM Rig Release: 6/25/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292239900 Active Datum: 32 : 22 9/21/1993 00:00 @69.15ft (above Mean Sea Level) Date From - To 1 Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) hr _ (ft) 18:00 20:00 2.00 WHSUR ! P RUNCMP PJSM. MIRU LRS PUMP TRUCK. PRESSURE , ,TEST LINES TO 700 PSI LOW & 3300 PSI HIGH. - REVERSE CIRCULATE 100 BBLS DIESEL @ 2 I BPM, 1100 - 1300 PSI. , - RETURNS DIRECTED TO CUTTINGS BOX. 20:00 - 21:00 1.00 i WHSUR ! P RUNCMP ' WAIT FOR ONE HOUR TO ALLOW DIESEL FREEZE PROTECT FLUIDS TO U -TUBE BETWEEN TUBING & ANNULUS. 21:00 00:00 3.00 WHSUR RUNCMP PJSM. RIG UP VALVE SHOP LUBRICATOR, SET BPV & PRESSURE TEST FROM BELOW J WITH LRS PUMP TRUCK. ;✓/ - PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH. ' - TEST BPV FROM BELOW TO 250 PSI LOW 1 AND TO 1000 PSI HIGH FOR 5 MIN EACH. RIG DOWN LUBRICATOR, REMOVE SECONDARY ANNULUS VALVE. - RDMO LRS PUMP TRUCK. - SECURE CELLAR, CLOSEOUT WELLWORK TRANSFER PERMIT. - ALL VALVES ON TREE LEFT CLOSED. PRESSURE GAUGES INSTALLED ON SWAB CAP AND IA. - NABORS 7ES RIG RELEASED @ 23:59 ON — _ 6/25/2011 (END OF REPORTS FOR X -22A) ! Printed 7/11/2011 10:32:47AM TREE= 4 -1/16" CIW X-2 2A SAFETY 2' CHRO , BG & LNR 7-5/8" TIW PKR MAY FAIL GVELLHEAD= CM/ ACTUATOR = BAKER C AT 2100 PSI DIFF IF EXCEEDED CTD. KB. ELEV = 69.15' i :4 � BF. ELEV = 39.0' 3763' � .4 KOP = 20" CONDUCTOR I ? •■ *' * 4 �� 2103' I- 4-1/2" HES X NIP, ID = 3.813" I • Max Angle = 94 @ 13542' b. ∎i Datum MD = 10926' .� �� Datum TVD = 8800' SSI ∎i �i - 3058' �1 7 -5/8" HES ES CEMENTER ` 7 -5/8" CSG, 29.7 #, L -80 VAM TOP HC, ID = 6.875 H 3101' ■'! �Zf 3081' HI 7 -5/8" BKR ECP, ID = 6.875" 7 -5/8" BKR BOWEN CSG PATCH, ID = 6.75" H 3104' GAS LIFT MANDRELS 10 -314" CSG, 45.5 #, H 3200' ST MD TVD DEV TYPE VLV LATCH SIZE DATE L -80 LHE BUTT, ID = 9.953" I "f 4 2506 2505 1 KBMG DCK BEK 0 06/25/11 3 6049 5611 49 KBMG DMY BK 0 06/25/11 2 8399 7102 48 KBMG DMY BK 0 06/25/11 1 10420 8588 52 KBMG DMY BK 0 106/25/11 Minimum ID = 2.37" @11961' L - 2-7/8" FL4S LNR X 2 -7/8" STL LNR XO 1 10497' f - I4 -1/2" HES X NIP, ID = 3.813" �� 10527' F17-518"x4-112" HES TNT PKR. ID = 3.856" I 4 -1/2" TBG. 12.6 #. 13CR -85 VAM TOP, H 10630' .0152 bpf, ID = 3.958" 1 10560' H4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TUBING STUB (06110/11) 10635' r 10645' H7 -5/8" X 4 -1/2" UNIQUE OVERSHOT I �� 10-7::1 10672' }- 7 -5/8" x 4-1/2" TIW HBBP PKR, ID = 4.00" I /I . , _ _ 10719' I4 -1/2" PKR SWN NIP, MILLED TO 3.80" (05/ ? ?/01) I 4 -1/2" TBG, 12.6 #, 13CR NSCT, -I 10731"1 10731' I4 -1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" I I--I ELMD - NOT LOGGED I TOP OF 4-1/2" LNR 1—J 10757' (- , 10744' --I TIW SCOOP /OVERSHOT ASSY I 10757' H 7 -5/8" TIW LNR TOP PKR, ID = 4.00" I 7 -5/8" CSG, 29.7# , NT95HS NSCC, ID = 6.875" H I 10922' I--' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ``� ` `` ` 11955' —13.70" BKR DEPLOY SL' /, 1D = 3.00" I Note: Refer to Production DB for historical perf data . N. . ` SIZE SPF INTERVAL Opn /Sqz DATE '- `\ 4 -112" SLTD 11275 - 12663 SLOT 12/28/93 `. ` ` 11961' H3-1/2" X 2 -7/8" XO. CD = 2.37" .. ` PRE DRILLED 3/8" HOLES 2-7/8" 4 12025 - 13985 0 06/03/01 `\ `. ` `5 . . ` ` `. �� \' 4 -1/2" LNR, 12.6 #, 13CR -80 NSCT, .0152 bpf, ID = 3.953" I-{ 12688' I--NP 5 PBTD I 13985' \ 5 40 2 -7/8" LNR. 6.16 #, L -80 STL, .0057 bpf, ID = 2.44" I 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/27/93 N22E ORIG COMPLETION WELL: X -22A 1 06/04/01 NORDIC 1 CTD SIDETRACK (X -22A) PERMIT No: F 2010740 06/25/11 N7ES RWO API No: 50- 029 - 22399 -01 06/29/11 SMM/ PJC FINAL DRLG CORRECTIONS SEC 8, T10N, R14E, 307' FNL & 25' FWL BP Exploration (Alaska) 2.. 1, 13 -JUL -2011 2-21`7 Schhnrerger No. 5764 Alaska Data & Consulting Services SCANNED MAR 2 8 2013 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD W -223 BCRJ -00086 ISOLATION SCANNER 18- May -11 1 1 W -221 BJGT -00040 USIT 16-Jun-11 1 1 C -11A BLPO -00111 PPROF W GHOST 14-Jun-11 1 1 H -19B BLPO -00109 MEMORY PPROF W GHOST 12-Jun-11 1 1 r> V -227 BCRJ -00090 SCMT 19-Jun-11 1 1 X -22A AWJI -00143 USIT 18-Jun-11 1 1 MPI-09 14-36 BCRC -00067 MEMORY LEAK DETECTION LOG 18-Jun-11 1 1 BCRJ -00091 (PROF 21- Jun -11 1 1 J -27A BAUD -00090 PPROF W GHOST 20-Jun-11 1 1 D -06A BL65 -00041 PPROF W DEFT GHOST 24-Jun-11 1 1 • 16 -05A BSM4 -00008 LEAK DETECTION LOG 27-Jun-11 1 1 Z -27 BSM4 -00009 GAS LIFT SURVEY 2-Jul-11 1 1 09 -22 BJGT -00048 (PROF 4-Jul-11 1 1 W -08A BBSK -00076 SCMT 26-Jun-11 1 1 Y -04 AWJI -00147 PPROF W DEFT GHOST 22-Jun-11 1 1 R -28 BJGT -00047 SBHPS 3-Jul-11 1 1 U -11B BG4H -00058 PPROF 16-Jun-11 1 1 Z -31 BCRJ -00093 SCMT 10-Jul-11 1 1 F-48 BG4H -00062 PPROF W DEFT GHOST 9-Jul-11 1 1 06 -11 BSM4 -00012 PPROF W DEFT GHOST 4-Jul-11 1 1 C -32C BLPO -00117 PPROF W GHOST 5-Jul-11 1 1 01 -31 BP5G -00001 RST EDIT 17- Mar -11 1 1 N -17 BJOH -00007 PDC -GR EDIT 9- Feb -11 1 C -12B BAUJ -00064 MCNL EDIT 9- Mar -11 1 1 C -22A BL65 -00022 MCNL EDIT 7- Mar -11 1 1 14 -33A 8L65 -00023 MCNL EDIT 6- Apr -11 1 1 S -129 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB1 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB2 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services • Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 , M • • STIATE OEF AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. a01-0 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X -22A Sundry Number: 311 -168 Dear Mr. Reem: N ,, Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i i Daniel T. Seamount, Jr. Chair DATED this / 6 day of May, 2011. Encl. .c STATE OF ALASKA lt' , (RECEIVED • � \ t ALASK,L AND GAS CONSERVATION COMMISO c'n (ilA .�iI ..,Off 5 el APPLICATION FOR SUNDRY APPROVAL '/.0.? -// 20 AAC 25.280 1. Type of Request: AIit�Ka Oil & f Cnnb, Ctimmi44ioft ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ■1 Repair Well ❑ Change Approved Progi*i f" raUO ❑ Suspend ❑ Plug Perforations ❑ Perforate - ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate _® Alter Casing -0 Other surface casing leak 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 201 -074 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22399 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU X -22A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028313 & 047472' Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14018' - 9025' - 14018' 9025' 10702' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3169' 10 -3/4" 3200' 3199' 5210 2480 Intermediate 10894' 7 -5/8" 10921' 8867' 8180 5120 Production Liner 1931' 4-1/2" 10757' - 12688' 8783' - 9035' 6430 7500 Liner 2063' 2 -7/8" 11955' - 14018' 9014' - 9025' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted (41/2& & 2- 7/51 : 11275 -13985 8970' - 9023' 4 12.6# 13Cr 10731' Packers and SSSV Type: 7 - 5/8" x 4 TIW 'HBBP' packer Packers and SSSV 10672' / 8737' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Development - ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2011 0 Oil _ ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564 -5743 Date 67420 Elizabeth Barker, 564-5674 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 31 .— ' v , ^ Sundry Number: 1 � ❑ Plug Integrity %BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 3566 los` 40P �s f Other: l ZS-6 o p s AhK,4,c� s Cam.. Subsequent Form Required: /O _ (to / o APPROVED BY (Ig Approved By: COMMISSIONER THE COMMISSION Date 1 Form 10-403 Rev ed AY 1 8 zon �(° Submit In Duplicate L 1lf/I R \ G\N A L ,-05A 7 4 s47„ • • 0 b P aji 91 X -22A Rig Workover (Repair surface casing leak) Scope of Work: Pull 4.5" 13Cr -80 completion. Run USIT log to find 7.625" TOC, cut and pull 7.625" casing as deep as possible. Tie back 7.625" casing, and cement to surface over top of 10.75" casing and into 20" annulus. Replace 10 -3/4" starting head w/ 7 -5/8" sliplock starting head. Run 4.5" 13Cr -80 completion. Engineer: Sean McLaughlin MASP: 2340 psi ✓ Well Type: Producer Estimated Start Date: June 1st, 2011 F 1 MIT -T to 1000 psi to verify PX plug still holding. Surface casing leak, no need to MIT OA . S 2 Drift tubing for 4 -1/2" Jet Cutter and dump bail 10' of sluggits on top of PX plug. Set Itco -spear retrievable junk catcher on top of sluggits. E 3 Jet cut tubing @ 10,635' if plug holds. Reference tubing tally 10/28/93. Cut desired to be 1/4 way down first full joint above packer. * F 4 Circulate well through the cut with seawater and diesel freeze protect to 2000' MD. CMIT TxIA to 1000 psi to verify PX plug integrity for use as a barrier post -tbg cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. • V 6 Set BPV in the tubing hanger. O 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. O 8 Excavate the cellar as needed to get top of spray -in liner below the leak in the 10.75" casing. Line the cellar around the wellhead with impermeable, Rhino lined Herculite. I Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate seawater. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. RU wireline and run USIT from -3500' to surface. - 5. Run 7 - RBP and set -100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set.•• Dump -50 ft of sand on RBP. 6. Mechanically cut 7 - /8" casing in 1 full joint above top of cement. Pull casing thru stack. Dress -off 7 - stub in ✓ preparation of casing overshot. Note: VBR's will not be changed to 7- pipe rams as the well has 2 tested barriers (RBP & packer /PX plug) to the reservoir. ' 4 Kwr 7. ND BOP, ND Tubing spool, Cut off wellhead 8. RIH with 7- 29.7 #, L -80 casing. Cement new 7 - casing to surface and over top to 20" annulus. 9. Install 7 -5/8" slip -lock wellhead. PT wellhead. 10. Drill out 7.625" • 11. Cleanout above 7 -%" RBP. PT 7.625" to 3500 psi for 30 minutes. Pull 7 -%" RBP. 12. Run 4 -W 13Cr -85 VamTOP stacker packer completion 13. Displace the IA to packer fluid and set the packer. • 14. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 15. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. ■ = f' 4» 5Nl CR • SAFETY 1 B(31LW! 1- '.6/8' Tri71W PKR ACTUATOR* OTIS Xe *2 2A MAY FAH. T 2100 FISI OIFF IF MOOED CM. 2-7/6' KB. ®.E1/ = 88.69 LNR I4AB BIN W1318' HOLM • 4 HOLES INF. 18.8V = 0' PIMt FT. 4.1? SINN NP Q 10719' MUM OUT TO KOP = 3763' 3.80x' D BY CM. Mix Angle = )4 41 13547 • . I y (Mum ND = 10928' Clam TVD = 8800' SS 21 4.112' HXO $ V NM, D = 3.813' • [L 20" CSG, 91.5 #, H -40, ID = 19.124" @ 110' 1 10 -3/4" caeca, 4$.l6B, L- 80, D = s . Sad53" H ' 1 GAS UFT MANOFII.S ST N() TVD OWN TYFS VLV LATrrH Sge DATE 6 3564 3513 $ CiA KBP 3 001* BK 16 OW19F02 L 5 6017 5521 49 CA WAG 0066E IBC 16 09/19/02 4 6057 6906 49 CA KBMG DONE BK 16 09/19/02 3 9367 7918 43 CA 103193 OMY BK 0 06/14101 Minimum ID a 2.37" $11$$1' 2 10441 8532 53 CA KBM3 DMY BK 0 06114/01 2.7/8" FL4S LNR X 2.7/8" STL LNR XO 1 10596 8818 55 CA KB193 50 BK 22 09/19/02 19611' 4-1/3' WM NP, 10 = 3.813" g ( + H x 4 tivvresitkott. pa 4.0" 10702' 4.1/2" PARKER SW8 NP, D = 3.813" I / I 10702' 4-1/2" PI PLUG (08/13108) 1 1 1- 1011*" ' - 4-1/x' MOO* SWN NM (MLLd° BY CTD) D * FROM 3.725" TO 380" 4 T$G. 1 ` .68 13CA, 0.0152 bpf, D = 3.5158' 10x31' / \- 10131' 4 W .B3. ID" 3.958" 1 TOP OF 4.1 rr LNR H lour +--- - BLMD - NOT LOGGED I 1-5/6" CSC), 28.7'8, D = 6.815 H 101122' 1-A , 10144' H TNV SCOOINOvERSHOT ASSY 1 11!58' _I- ja.70" BKR DEPLOY SLV, D = 3.00" \d 11960" H3 -1/2' x 2.1'/8" X0.10 = 2.44" I t zi 4- LNR, 12.69, 13CR- 80.0.0152 bpf, 10 = 3.9517' 1127 ' \ \ 1 2- /8" ORI.LI'D LNR D = 2.37' \ • . ■ \ • . \ • \ . •` \ 4.1 ' L 1 - !., :.... 0.01 bpf, '' s134$01 \ . 3. -;` 1' \ ` 2- fir 8.1 . L-$0 ' , "." bpf, : = 2.3 140191' 1 i.rw wow �� " • :' i i "I� iu11� I i I i.7.,.,- + ;ri FIOAHO' BAY UNl" lEctitr;l ,A rw.Lawr , `t. v wi ��n L', .;.AIMIL ♦�� < .. 1 �W L X-22A ri✓T 1 f.'' l"r'f'1Y��"Ni n ii "•3[+ 0_17n,.1- a �r'.' •r,rri - rrlr r. r �;'� RaaT No:' 10740 an W 7 r `. w r,'N a den Tr' API Ns: 50-029.2239901 r s. a rrr La :4i ; U 4604' 15257' S } ee IL MK 8149E tilaskai L.L..;"Ta1111.11111111Ett. 111111111111111111111111111111111111111111111111111111111111M TREE= r 4" 5M, CR le X ..2 2A YVELLHEAO = 5M FMC SAFETY: CHROME TBG/LNR. 7 -5/8" TM/ PKR ACTUATOR= PROPOSED MAY FAI 2100 PSI RIFF IF EXCEEDED CTD. 2-7/8" KB ELEV = 688.64 64' LNR HAS BEEN PREDRILLED W/3/8" HOLES @ 4 HOLES BF. ELEV = 39.0' PER FT. 4-1/2" SWN NIP © 10719' MLLED OUT TO KOP = 3763' 3.80" ID BY CTD. Max Angle = 34 I2 13542' Datum MD = 109 Datum TV D = 8800' SS 2000' 4 -1/2" HES X NIP, ID = 3.813" 20" CSG, 91.5 #, H -40, ID = 19.124" @ 110' 1 10 -3/4" CSG, 45.51, L -80, ID = 9.953" H 3200' 1 GAS LIFT MANDRELS 7 -5/8" 29.7 #, L -80, VamTop HC from old TOC to surface ST MD 1VD DEV TYPE VLV LATCH SIZE DATE 4 10t L 3 8386 2 6032 1 2502 Minimum ID = 2.37" @11961' 2 -7/8" FL4S LNR X 2 -7/8" STL LNR XO I I 4 -1/2" HES X NIP, ID = 3.813" E Z 7 -5/8" x 4.5" HES "TNT" packer @ — 10570' I I -- 4-1/2" HES X NIP, ID = 3.813" 4 -1/2" 12.6 # /ft, 13Cr -85, VamTop tubing / \ Z g` I 10672' H7-5/8" x 4-1/2" TAN HBBP PKR, ID = 4.0" I 10702' — I4 -1/2" PARKER SWS NIP, ID = 3.813" I I I I 10719' — 4-1/2" PARKER SWN NIP (MILLED BY CTD) ID = FROM 3.725" TO 3.80" 4-1/2" TBG, 12.61, 13CR, 0.0152 bpf, ID = 3.958" 1--1 10731' / \ — 1 10731' — 14 - 1/2" WLEG, ID = 3.958" I TOP OF 4-1/2" LNR H 10757' \ I —I ELMD - NOT LOGGED I I 7 -5/8" CSG, 29.7/, ID = 6.875" 1 10922' 1' — N 10744' H TAN SCOOP/OVERSHOT ASSY 11955' —13.70" BKR DEPLOY SLV, ID = 3.00" I I 11960' H3-1/2" X 2 -7/8" XO, ID = 2.44" 1 1 4-1/2" LNR, 12.61, 13CR -80, 0.0152 bpf, ID = 3.953" I 11275' \` � x 12025' 1-12-7/8" PRE- DRILLED LNR, ID = 2.37" I TOP OF 4-1/2" SLOTTED LNR I--.I 11275' 1 � ` ` ` .` \ \\ ` V \ \ \ \ ` \ \ \ 1 4 -1/2" LNR, 13- CR -80, SLOTTED, 0.0152 bpf, ID = 3.953" H 12688' 1 ` \ . \ O p PBTD H 13184' 1 1 2 -7/8" LNR, 6.16#, L -80 STL, .0057 bpf, ID = 2.37" 1-1 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/27/93 FARGO ORIG HORIZ COMPLETION 06/25/01 CH/TP CORRECTIONS WELL: X -22A 02/24/01 SIS -0AA CONVERTED TO CANVAS 09/19/02 DTR/KK GLV CJO PERMT No: 2010740 03/02/01 SIS-IVO FINAL 08/17/08 JRA /SV SET PX PLUG (08/13/08) API No: 50- 029 - 22399 -01 05/18/01 RWKAK CORRECTIONS 4909' FSL & 5257' FEL Sec 8, T10N, R14E 06/04/01 CTD SIDETRACK BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS RECEIVED M AY ~ 0~ ~ 2010 1. Operations Abandon ^ Repair Well Q Plug Perforations ^ Stimulate^ O her ter E~~~10t1 ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ ~ ~ Time E~ Change Approved Program ^ Operat. Shutdown ^ ~~npp ~~,,r Perforate ^ Re-enter Suspended Well ~"`L`t'rSiT~S1 repair 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 'Permit to Drill Number: Name: Development Q Exploratory ^ 201-0740 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. PI Number: Anchorage, AK 99519-6612 50-029-22399-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ` ADLO-047472 X-22A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14018 feet Plugs (measured) 10702' 8/13/09 feet true vertical 9025.47 feet Junk (measured) None feet Effective Depth measured 14018 feet Packer (measured) 10672 true vertical 9025 feet (true vertical) 8737 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 3169 10-3/4" 45.5# L-80 SURFACE - 3200 SURFACE - 3199 5210 2480 Intermediate 10984 7-5/8" 29.7# L-80 SURFACE - 10894 SURFACE - 8867 8180 5120 Production Liner 1931 4-1 /2" 12.6# 13CR80 10757 - 12688 8783 - 9035 8430 7500 Liner 2063 2-7/8" 6.16# L-80 11955 - 14018 9014 - 9025 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 10731 SURFACE - 8769 Packers and SSSV (type, measured and true vertical depth) 7-5/8" X4-1 /2" TIW HBBP PKR 10672 8737 12. Stimulation or cement squeeze summary: Intervals treated (measured): sad ~ ~ r.7 ~ry 14s. { I ' ! ~ j f i ~~ Treatment descriptions including volumes used and final pressure: y~ ,~~,'s'~ !~ ! - ~ ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-028 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 5/20/2010 • ~ivu1V1~ MAl' 2 0 ~ .,~~~ ~~. 1010 sziw ~/~ X-22A 201-074 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base X-22A 10/27/93 SL 11,275. 12,686. 8,970.28 9,034.63 X-22A 6/4/01 SL 12,025. 13,984. 9,017.01 9,022.77 X-22A 3/22/09 SPS 10,678. 13,984. 8,739.94 9,022.77 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED S4Z SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • X-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/5/2010iT/I/O=SSV/230/0. Temp=S1. Removed grating and install spit containment (prep for Furmanite). AL SI & blinded @ casing valve. Fluid is trickling out of the hole in the OA @ the 0100 position. Vac truck removed 3 bbls of water/crude from cellar box, revealing 2' of ice in the bottom of cellar box. Water wash needed to install surface liner. SV, WV, SSV=Closed. MV=Open. IA, OA=OTG. 4/7/2010 4/8/2010 T/I/O=SSV/240/0. Temp=S1. Remove grating, hot wash cellar (prep for Furmanite). AL SI & blinded. Fluid is slowly streaming from hole in the OA casing @ the 1 O'clock position. IA FL level @ 360' (13 bbls). Bled IAP to slop tank from 240 psi to 0 psi in 45 mins (gas). Pumped 43 bbls of 120* water into cellar to melt ice bottom & clean out crude. Plugged hole in OA with foam & tape to divert fluid to an open bleed. Continued OA bleed for 4 hrs with no fluid or gas returns. Job in progress. Final WHPs=SSV/0/0. SV, WV, SSV=Closed. MV=Open. IA & OA=OTG. NOVP. T/I/O=MV/10/3. Temp=S1. Maintain an open OA bleed (pre-Furmanite wrap). **Job continued from previous days AWGRS. ALP=95 psi, SI & blinded @ casing valve. IA FL @ 280' (<10 bbls). Maintained an open OAP bleed with -1 pint per hr returns @ start of bleed. ""Note: IAP will bleed down to zero, 1 hr BUR=2 psi. OAP will not bleed below 0+ psi, generally maintaining 3 psi @ casing valve during bld (-7' of height @ bld trlr inlet). See log for details. Final T/I/O=MV/0+/3. **Job continued on next days AWGRS. SV, WV, MV=C. SSV=O. IA, OA=OTG. NOVP. .T/I/O=MV/0/1. Temp=S1. Hold open OAP bleed (pre-Furmanite). ALP=108 psi, SI & blinded @ casing valve. *"Job continued from previous days AWGRS. Maintained an open OA bleed. IAP bleeds from 1 psi to 0 psi in -4 mins (all gas). Bled 32.4 gal from OA in 21.5 hrs=1.5 gal/hr. **Note: MV was opened & demonstrated to be 5 psi. See log for details. Final T/I/O=MV/0/0. **Job continued on next days AWGRS. !SV.WV,MV=C. SSV=O. IA=OTG. OA=Open to 1/2 drum. NOVP. • 4/9/2010`T/I/O = 5/0+/0. Temp=S1. Hold open OAP bleed (pre Furmanite). AL is SI & blinded @ casing valve. ALP=97 psi. Held open bleed on OAP. OA bleeding into ~ 1/2 drum, vacuumed out drum and recorded volume of fluid (see log) for a total =volume of 46 gal in 23.5 hrs (2 gph). IAP bleeds from 1 psi to 0 psi in, all gas. Removed grating & ladder to swab platform from wellhouse. Final WHPs=5/0+/0. **Job continued on next days AWGRS** SSV, WV, MV=C. SSV=O. IA, OA=OTG. NOVP. 4/10/2010'T/I/O=MV/2/5. Temp=S1. Hold open bleed on OA (pre-Furmanite). ""Continued from previous days AWGRS. ALP=93 psi, blinded @ casing valve. Pulled temporary patch @ 0100 hrs & drained SC to depth of hole. Displaced void w/N2; Furmanite applied rubber plug covered by a 6" stainless steel band using Balzona 1111 to cement the patch to the circumference of the pipe. Begin prepping for media blasting. During prep for the media blasting, dicovered additional questionsable spots on surface casing that did not appear to be related to the current U/T map. Decided to not proceed with the blasting and SI OA to monitor build up rate. SIP @ 5 psi, BUR 10 psi after 30 minutes. No leak observed .stainless band. Continue holding open bleed. *"Note: See log for details. Final T/I/0= MV/0+/5 **Job Continued on next days AWGRS"" iSV, WV, MV=C_._SSV_=0. IA, OA=OTG. NOVP. _ _ _ _ _ _ 4/11/2010 T/I/O = MV/0+/5. Temp=S1. Hold open bleed on OA (Furmanite). **Job continued from previous days AWGRS*' ALP=4 psi, SI & blinded @ casing valve. Held open ;bleed on OA and bled IAP to 0 psi as needed, (see log for details). Final T/I/O=MV/1 /5. *"Job in progress*" SSV, WV, MV=C. SSV=O. IA, OA=OTG. NOVP. 4/12/2010 T/I/O=MV/1/5. Temp=S1. Assist with Furmanite. ""Job continued from previous days AWGRS"* ALP=4 psi, SI & blinded @ casing valve. Held open bleed on OA & bled IAP to 0 psi as needed, Installed nitrogen cap on OA to 20 psi and inspected for leaks. Found fluid level at 12' to 18' in OA at 20 psi. Performed build up test on OA, gaining 18 psi in 43 minutes. No leaks were seen on patches on surface casing. Prep for CCI to media blast surface casing. Put 20 psi N2 cap, and begin media blasting surface casing. During blasting, a 4"x3" piece of metal was knocked off the surface casing. The piece was one of the stainless steel patches installed 04/11/09 which had adhered itself to the metal of the surface casing. No fresh break marks were observed on the back of the the piece. Media blasting was halted and the well was bled off and returned to an open bleed. Pass down tonight shift. Final WHPs = MV/3/5. "''JOB IN PROGRESS*" • • 4/12/2010'T/I/O =SSV/3/5. Temp=S1. Hold open OAP bleed (Furmanite). AL is connected, SI & blinded @ casing valve. ALP=175 psi. Held open bleed on OA bleeding IAP periodically. Total fluids bled from OA in 24 hrs=43 gal. Job incomplete. Final WHPs=SSV/4/5. SV,WV,MV=Closed. SSV=Open. IA,OA=OTG. NOVP 4/13/2010 T/I/O = MV/4/5. Temp=S1. Hold open OA bleed (Furmanite). *"Continued from 'previous days AWGRS** ALP=175 psi, SI @ casing valve. Held open bleed on OA (see log for details). *"Note: Removed 22" containment from cellar. Water level in cellar continues to rise, even tho a heater trunk is installed. '**Continued on next days AWGRS*" 'SV, WV, MV=C. SSV=O. IA, OA=OTG. NOVP. ______ W____________~ _____ 4/14/2010 T/UO=MV/0/5. Temp=S1. Hold open OA bleed (Furmanite). "*Continued from previous days AWGRS** Held open bleed throughout the day, monitoring returns (See log for details). Turned over to day shift. 4/14/2010; T/I/O=MV/0/5. Temp=S1 previous days AWGRS** (See log for details). Hold open OA bleed (Furmanite). **Continued from Held open bleed throughout the day, monitoring returns 4/15/2010 T/I/O = MV/5/5~Temp = SI. Hold open OAP bleed (Furmanite). "'"Continued from previous days AWGRS"" ALP = 140 psi, SI @ lateral & casing valve. Held open bleed on OA (Total returns=21 gals), bleeding IAP as needed (see log for details). Final WHPs = MV/2/5. ""Continued on next days AWGRS** 4/16/2010 • T/I/O=MV/7/4. Temp=S1. Maintain open OAP bleed (for Furmanite). *"Continued !from Day shift*" ALP=136 psi, Blinded @ casing valve. Maintained an open OAP bleed throughout shift, bleeding IAP as needed (See log for details). **Note: 'Ordered Vac truck for following days work, eta @ 1000 hrs. Final T/I/O=MV/3/4. ""Continued on next days AWGRS"* 4/16/2010 T/I/O=MV/2/5. Temp=S1. Maintain open OAP bleed (for Furmanite). "*Continued `from previous days AWGRS"* Maintained an open OA bleed throughout the day; Bled IAP as needed (See log for details). **Job incomplete**. Night shift in charge of valve position. 4/17/2010 T/I/O=MV/3/4. Temp=S1. Hold open OAP bleed (for Furmanite). **Continued from previous days AWGRS"* ALP=136 psi, Blinded @ casing valve. OA FL @ 60'. Maintained open OAP bleed till CCI arrived on location. Installed 25 psi N2 cap, i monitor OAP during media blasting. CCI media blasted SH. Furmanite apllied e- glass. Bled IAP as needed (See log for details). Final T/I/0= ?. ***Job in progress*** Turned over to night shift. 4/18/2010~T/I/O=MV/5/4. Temp=S1. Hold open OA bleed (Furmanite). *"Continued from I previous days AWGRS** Assisted Furmanite, maintained open bleed on OA ;throughout day (see log for details). Furmanite techs applied 1st carbon layers. *Job in progress* Continued on next day WSR. 4/19/2010~T/I/O = MV/10/5. Temp = SI. Hold open OA bleed (Furmanite). '"''Continued** Maintained open bleed on OA throughout the day (see log for details). Furmanite ~Techs applied 2nd set of carbon layers. *Job in progress* n U 4/20/2010~T/I/O = MV/0+/5. Temp = SI. Assist Furmanite; hold open OA bleed (Furmanite). **Continued"" Furmanite completed final wrap @ 9:20 am. Maintained open bleed on OA throughout the day (see log for details). Job in Progress 4/21 /2010 4/22/2010 T/I/O=MV/6/5. Temp=S1. Hold open OA bleed (Furmanite). Continued from previous day. Furmanite pulled final layer of paper off of well. Bled IAP as needed (see log for details). T/I/O=MV/5/5. Temp=S1. Hold open OA bleed (Furmiate). Continue WSR from '4-21-10. Maintain open bleed on OA. Bled IAP as needed see log for details. Turned over to night crew. 4/23/2010 T/I/O=MV/4/3. Temp=S1. Hold open OAP bleed (Furmanite). Maintain open OA bleed. See log for details. "Job incomplete" Continued on next days AWGRS WSR. 4/24/2010 T/I/O=MV/4/3. Temp=S1. Hold open OAP bleed (Furmanite). Maintain open OA bleed. See log for details. '`Job incomplete* Continued on next days AWGRS WSR. y 4/24/2010iT/1/O=MV/4/3. Temp=S1. Hold open OAP bleed (Furmanite). Maintain open OA bleed. See log for details. *Job incomplete* Continued on next days AWGRS WSR. 4/25/2010 4/26/2010 ....4/27/201 i T/I/O=MV/2/4. Temp=S1. Hold open OA bleed (Furmanite). Continue to hold open OA bleed (see log for details). 'T/I/O=MV/7/5. Temp=S1. Hold open OAP bleed (Furmanite).Continue open OA bleed (see log for details). i T/I/O=MV/2/4. Temp=S1. Hold open OAP bleed (Furmanite). Continue from 4-26- 10. Maintain open bleed on OA till 9:20 am (see log). SI bleed @ 9:20 am. 'Monitored for 1 hr. IAP increased 1 psi. OAP increased 2 psi. Final WHPs= 'MV/1/2. Job complete ~ 'A'SV, WV= Unable to verify due to no swab scaffolding. MV= Closed. SSV= Open. IA, OA= OTG. NOVP. i 4/28/2010I,T/I/O=MV/9/33. Temp=S1. WHP's. (Eval OA BUR). IAP increased 8 psi & OAP increased 31 psi overnight. No scaffold lader on well. SV, WV & MV =CLOSED (CANT CONFIRM) SSV =OPEN. IA & OA = OTG. NOVP. i • 5/3/20 0 /I/0= MV/30/110. Temp= SI. WHPs (eval OA BUR). Monitored WHPs @ 14:30 pm. AL SI, ALP= 105 psi. IA increased 21 psi, OAP increased 77 psi sence 4-28- , 10. No scaffold to access SV platform. ~SV,WV,MV= C. (CAN'T CONFIRM) SSV= O. IA,OA= OTG. ~ 5/5/2010 T/I/O = MV/40/120. Temp = SI. WHPs (eval OA BUR) WHPs taken @ 1345. IAP increased 10 psi, OAP increased 10 psi overnight. , SV,WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 5/6/2010~T/I/O= MV/40/130. Temp= SI. WHP's (eval OA BUR). MV,WV,ALV locked out. WHP's taken @ 15:40. OAP increased 10 psi overnight. **Job complete** ~SV,WV,MV=C. SSV=O. IA,OA=OTG. NOVP. 5/7/2010 5/15/2010 T/I/O = MV/50/120. Temp = SI. WHPs (eval OA BUR). AL blinded, ALP = 70 psi. 'Monitored @ 15:36. IAP increased 10 psi overnight. SV, WV, MV =Closed. SSV =Open. IA, OA = OTG. NOVP. T/I/O = MV/70/130. Temp = SI. WHPs (eval Furmanite wrap). AL blinded, ALP = 45 psi. IAP increased 20 psi, OAP increased 10 psi since 5-7-10. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 5/16/2010`T/I/O=MV/80/130 Temp=S1. WHPs (eval Furmanite wrap). WHPs unchanged overnight. Furmanite wrap shows no signs of seepage or any discoloration due to hydrocarbon seepage, no audible or visible signs of leaks. jSV,WV,MV=C. SSV=O. IA,OA=OTG. NOVP. NO FLUIDS PUMPED ,TREE = 4" 5M, CR WELLHEAD= SMFMC ACTUATOR= OTIS KB. ELEV = 68.64' BF. ELEV = 39.0' KOP = 3763' Max Angle = 94 @ 13542' Datum MD = 10926' Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" SAFETY~ES: CHROMETBG/LNR. 7-5/8" TNU PKR MAY FAI 2100 PSI DIFF IF EXCEEDED CTD. 2-7/8" LNR HAS BEEN PREDRILL® W/3/8" HOLES @ 4 HOLES PER FT. ~ X-22A 4-1/2" OTIS HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 6 3584 3513 8 KBMG DOME BK 16 09/19!02 5 6017 5521 49 KBMG DOME BK 16 09!19!02 4 8057 6906 48 KBMG DOME BK 16 09119102 3 9387 7818 43 KBMG DMY BK 0 06/14/01 2 10441 8532 53 KBMG DMY BK 0 08/14!01 1 10586 8818 55 KBMG SO BK 22 09/19/02 Minimum ID = 2.37" @11961' 2-7/8" FL4S LNR X 2-7/8" STL LNR XO 10614' H4-112" PARKER SWS NIP, ID = 3.813" 14-1/2" JUNK CATCHER (03/23/09) I SLUGGfCS (03/23/09) 14-1i2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" I TOP OF 4-1 /2" LNR 17-518" CSG, 29.7# , NT95HS NSCC, ID = 6.875" I 10650' 7-5/8'" x 4-112" TIW HBBP PKR, ID = 4.0" 10660' 10702' 4-1/2" PARKER SWS NIP, ID = 3.813" 10702' 4-1/2" PX PLUG {08/13/08) 10719' 4-1/2" PARKER SWN NIP (M ILLED TO 3.$0") 10731' 10731' 4-1/2" WLEG, ID = 3.958" ` ~ ELMD -NOT LOGG®~ I 10922' I ITIW SCOOP/OVERSHOTASSY I 11955' I--I 3.70" BKR DEPLOY SLV, ID = 3.00" 3-112" X 2-7/8" XO, ID = 2.44" \~ ` ~~ 12025' 2-7/8" PRE-DRILLED LNR, ID = 2.37" 4-1/2" LNR, 12.6#, 13CR-80 NSCT, .0152 bpf, ID= 3.953" 11275' ~~ ~ ~ ~` 4-1/2" SLOTTED LNR, 13CR-80 NSCT, .0152 bpf, ID = 3.953" 12688' `~~ ~~` PBTD 13984' ~ `~ 2-7/8" LNR, 6.16#, L-80 STL, .0057 bpf, ID = 2.37" 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS 10127!93 FARGO ORIG HORIZ COMPLETION 02/24/01 SIS-OAA CONVERTED TO CANVAS 08!17/08 JRA/SV SET PX PLUG (08/13/08) 03/29/09 BSE/PJC SLUGGITS/ JNK CATCHER (3123/09) 05/03/10 JLW/PJC CSG CORRECTIONS PRUDHOE BAY UNIT WELL: X-22A PERMff No: 2010740 API No: 50-029-22399-01 4909' FSL & 5257' FEL Sec 8, T10N, R14E BP Exploration (Alaska} • • SEAN PARNELL, GOVERNOR ~T !~~ ®I~I tusis ~ 333 W. 7th AVENUE, SUITE 100 CO1sSEIIQA~IOis COMrIISSIOis ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Al Schmoyer Senior Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~''~'-~"~'~~~'' ~~~ 4` ~~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU X-22A ~~ ~ 1 ~~~` Sundry Numbcr: 310-02E Dear Mr. Schmoyer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 2010 Encl. Sincerely, STATE OF ALASKA C~ ~'~ ALAS~IL AND GAS CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIV~Q- ..? / /O JAN ~ $ X910 ~Ia~sks Oil ~ 6as Cor>wa. Commis~i~~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^ Changegram ^ Suspend ^ Plug Pertorations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ 0 Other: External surface casing reaair ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ , Exploratory ^ 201-0740- 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22399-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU X-22A 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADLO-047472 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14018 ~ 9025.47. 14018 9025 1 0702' NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" surface 110 surtace 110 1490 470 Surface 3169 10-3/4" 45.5# L-80 surface 3200 surface 3199 5210 2480 Intermediate 10984 7-5/8" 29.7# L-80 surface 10894 surtace 8867 8180 5120 Liner 1931 4-1/2" 12.6# 13cr80 10757 12688 8783 9035 8430 7500 Liner 2063 2-7/8" 6.16# L-80 11955 14018 9014 9025 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 4-1/2" 12.6# 13CR80 surtace 10731 Packers and SSSV Tvoe: 4-1/2" TIW HBBP PKR Packers and SSSV MD and TVD (ft): 10672 8737 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/3/2010 Oil ^~ ;, Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact AI Schmoyer Printed Name AI Schmo ~ Title Senior Pad Engineer Signature ? Phone Date 564-5865 1/26/2010 Prepared by Ga Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notif Commission so that a representative may witness Sundry Number: 3/0 ~ ©~~ y cation Clearance ^ Plug Integrity ^ Mechanical Integrity Test ^ Lo BOP Test ^ ®® // / Other: .Ifr ~{t GlLt ~t Pko1}'o G(OG~t -+. a,,,fs..'~~"'~ i'J ~ t.i.~ t r'G~ . G.~,l~. L _ / n '~ NO+- -F7 .L h $~c.e..~j' '~-.S n /~.a r 4[. /h6Y f/ • T~ ~ r~4.~.f Subsequent Form Required: l 0 •y O APPROVED BY ~+~-/~ D t Approved by: OMMISSIONER THE COMMISSION e: a ~10-~BRO ~e,4Ylp~ ~~ ~ ~ A L ~ ~ ~• ~O S Du~ate~ X-22A 201-074 DGDC ATTA~_1-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base X-22A 10/27/93 SL 11,275. 12,686. 8,970.28 9,034.63 X-22A 6/4/01 SL 12,025. 13,984. 9,017.01 9,022.77 X-22A 3/22109 SPS 10,678. 13,984. 8,739.94 9,022.77 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE TREE = 4" 5M, CR WELLHEAD = ACTUATOR = 5M FMC OTIS KB. ELEV = 68.64' BF. ELEV = 39.0' KOP = 3763' Max Angle = 94 @ 13542' Datum MD = 10926' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ( SAF S: CHROMETBG/LNR. 7-518" TMJ PKR X~~ ~~ MAY FAI AT 2100 PSI OIFF IF EXCEEDED CTD. 2-718" LNR HAS BEEN PREDRILLED W/3/8" HOLES @ 4 HOLES „~,~, PER FT. 4-1/2" SWN NIP @ 10719' MILLED OUT TO 3.80" ID BY CTD. 2101' H4-1/2" OTIS HXO SSSV NIP, ID = 3.813" I 3200' I Minimum ID = 2.37" @11961' 2-718" FL4S LNR X 2-7/8" STL LNR XO ~ 4-112" JUNK CATCHER {03123109) ~ SLUGGTTS (03!23!09) 14-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" I CAS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 6 3584 3513 8 CA KBMG DOME BK 16 09119!02 5 6017 5521 49 CA KBMG DOME BK 16 09/19/02 4 8057 6906 48 CA KBMG DOME BK 16 09/19/02 3 9387 7818 43 CA KBMG DMY BK 0 06/14/01 2 10441 8532 53 CA KBMG DMY BK 0 06/14101 1 10586 8618 55 CA KBMG SO BK 22 09/19!02 10650' 10614' 4-112" PARKER SWS NIP, ID = 3.813" " " " ` 10660` TIW HBBP PKR, ID = 4.0 x 4-1/2 7-518 10672 10702' 4-1/2" PARKER SWS NIP, ID = 3.813" 10702' 4-112" PX PLUG {08113(08) 10719' 4-112" PARKER SWN NIP (MIMED AA f~'9 BY CTD) ID =FROM 3.725" TO 3.80" TOP OF 4-112" LNR ~ 10757' 7-5/8" CSG, 29.7#, iD = 6.875" 10922' 10731` 4-1/2" WLEG, ID = 3.958" -~ ELMD -NOT LOGGED 10744' (-~ TIW SCOOP/OV ERSHOT ASSY 11955' I-I 3.70" BKR DEPLOY SLV, ID = 3.00" 11960' I-~ 3-1/2" X 2-718" XO, ID = 2.44" 4-1/2" LNR, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.953" 11275' ~ l ~~ 12025` 2-718" PRE-DRILLED INR, ID = 2.37" TOP OF 4-1/2" SLOTTED LNR 11275' ~- • ~ `~• ~• `` ~` `` r- .`'`` .`` 4-112" LNR, 13-CR-80, 5L0'TTED, 0.0152 bpf, ID = 3.953" 12688' `~` ~~ PBTD 13984' ~~ 2-7/8" LNR, 6.16#, L-80 STL, .0057 bpf, ID = 2.37" I-{ 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/27/93 FARGO ORIG HORIZ COMPLETION 06/25(01 CH/TP CORRECTIONS WELL: X-22A 02/24/01 SIS-QAA CONVERTED TO CANVAS 09/19/02 DTR/KK GLV C/O PERMIT No:'2010740 03/02/01 SIS-MD FINAL 08!17/08 JRA/SV SET PX PIUG (08!13(08) API No: 50-029-22399-01 05/18/01 RN/KAK GORRECTIONS 03/29/09 BSE/PJC SLUGGITS/ JNK CATCHER {3/23/ 09) 4909' FSL & 5257' FEL Sec 8, T10N, R14E 06!04101 CTD SIDETRACK BP Exploration (Alaska) ~ # ~~ ~~~s Subject: External Surface Casing Repair with Furmanite Composite Wrap Well: X-22A Program Objective Well X-22A developed a shallow surface casing leak at a depth of 14" below the top of the conductor. As part of the evaluation process, a portion of the conductor was removed and the surface casing was examined using ultra sonic inspection to assist in developing a repair procedure. The repair includes installing a Furmanite Composite Wrap across the surface casing leak area. A pressure test will be conducted prior to returning the well to service. Repair Procedure Major Steps 1. Clean and prepare the surface casing by media-blasting 2. Apply Furmanite Composite Wrap across the surface casing leak area 3. Allow Furmanite to cure while maintaining zero psi on outer annulus 4. Pressure test the repair with MIT-OA to 1200 psi. 5. Rebuild conductor pipe 6. Return well to Operable status • • ~~5~I /'v s,~~[ I~~r j~lIl /ii ~I i~', CO1~T5ER A~TIO CU1rII-~II55 pH David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAN PALlN, G~VERN~R 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 air-~ ~r Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-22A Sundry Number: 309-108 Dear Mr. Reem: :~~~';;~~~~ BAR :~ `~ ~ ~[;" Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~s day of March, 2009 Encl. STATE OF ALASKA ~~"~'%S~ . f0 `^ 2~.0 A~ OIL AND GAS CONSERVATION CO~~SION ~~~~ ~ ~ ~~a9 '~ 3 APPLICATION FOR SUNDRY APPI~OVAL~~'/~ `t ~'~ 20 AAC 25.280 ~iasaa @! a~ ~€an~. ~oafnmission 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensio~(iC~lOfa~B ®Alter Casing , ®Repair Well • ^ Plug Perforations. ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-074 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22399-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU X-22A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL 047472 - 69.15' _ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12: PRESENT WELL CONDITION SUM MARY. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14018' ~ 9025' ^ 14018' 9025' 10702' None Casin n h i M TV Bur II Stru ural 11 1 14 47 rf 3169' 10-3/4" 199' 21 2480 In rm is 10894' 7- / " 109 1' 7' 8180 12 Pr i n Liner 1931' 4-1/2" 107 T - 12 87 3' - 035' 84 750 Liner 2 3' 2-7/8" 11 ' - 14 1 14' - 9025' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): stoned ~a-ins a zaie">: »z~s' -13985' 8970' - 9023' 4-1 /2", 12.6# 13Cr 10731' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP' packer Packers and SSSV MD (ft): 10672' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 15, 2009 ®Oil ~ ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name avid Reem Title Engineering Team Leader Prepared By NameMumber: Signature Phone 564-5743 Date ,~~Zt3 b~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: . ~~ Conditions of approval: Notify Commission so that a representative may witness ~~G ~~~~~~~ ~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~5~~~ ~-M.~y'~' i ~~~ f~ S ~ ~~i v~Z~.uv~-~C~. ~a~t~til~c- ~"`~ Subsequent Form Required: ~^`~ ~` APPROVED BY ~~~ C / 9 A roved B COMMISSIONER THE COMMISSION Date cJ Form 10-403 F~' v~ec~~6~80~ Submit In Duplicate ~.. !~~K ~ ~ L~J~b • • by cr,~,~ X-22A Rig Workover (Repair surface casing leak) Scope of Work: Pull 4.5" 13Cr-80 completion. Run USIT log to find 7.625" TOC, cut and pull 7.625" casing as deep as possible. Tie back 7.625" casing, and cement to surface squeezing out 10.75" casing leak. Replace 7.625" packoff and hanger. Run 4.5" 13Cr-80 completion. Engineer: Hank Baca MASP: 2340 psi Well Type: Producer Estimated Start Date: April 15th, 2009 F 1 MIT-T to 1000 psi to verif PX lu still holdin .Surface casin leak, no need to MIT OA S 2 Drift tubing for 4-1/2" Jet Cutter and dump bail 10' of sluggits on top of PX plug. Set Itco-spear retrievable 'unk catcher on to of slu its. E 3 Jet cut tubing C~ 10,645' if plug holds. Reference tubing tally 10/28/93. Cut desired to be'h wa down first full 'oint above acker. F 4 Circulate well through the cut with seawater and diesel freeze protect to 2000' MD. CMIT TxIA to 1000 si to verif PX lu inte rit for use as a barrier ost-tb cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 6 Set BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . O 8 Excavate the cellar as needed to get top of spray-in liner below the leak in the 10.75" casing. Line the cellar around the wellhead with im ermeable, s ra -sealed Herculite. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate seawater. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. RU wireline and run USIT from 3500' to surface. 5. Run 7 5/8" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 6. Mechanically cut 7 5/8" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 7- 5/8" stub in preparation of casing overshot. Note: VBR's will not be changed to 7 5/8" pipe rams as the well has 2 tested barriers (RBP & packer/PX plug) to the reservoir. 7. RIH with 7 5/8", 29.7#, L-80 casing and land on new emergency slips with new primary pack-off. PT 7 5/8" pack-off to 3500 psi. 8. Cement new 7-5/8" casing to surface squeezing cement out 10.75" casing leak 9. Drill out 7.625" 10. Cleanout above 7-$/e" RBP. PT 7.625" to 3500 psi for 30 minut s. Pull 7-5/e" RBP. 11. Run 4-'h" 13Cr-80 TC-II stacked packer completion 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. • s 14. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = 4" 5M, CR WELLHEAD,= 5M FMC ACTUATOR = OTIS KBrELEV = 68.64' BF. ELEV = 39.0' KOP = 3763' Max Angle = 94 @ 13542' Datum MD = 10926' Datum TV D = 8800' SS ~-~ ~~ SAFETY NOTES: CHROME TBG/LNR 7-5/8" TNV PKR IL AT 2100 PSI DIFF IF IXCEEDED CTD. 2-7/8" LN S BEEN PR®RILLED W/3!8" HOLES @ 4 HOLES PER FT. 4-1/2" SWN NIP @ 10719' M~L® OUT TO 3.80" ID BY CTD. 20" CSG, 94#, H-40, ID = 19.124" @ 82` ~ 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~ Minimum ID = 2.37" @11961' 2-7/8" FL4S LNR X 2-7/8" STL LNR XO ~4-1/2" OTIS HXO SSSV NIP, ID = 3.813" ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCI-I SIZE DATE 6 3584 3513 8 CA KBMG DOME BK 16 09/19/02 5 6017 5521 49 CA KBMG DOME BK 16 09/19/02 4 8057 6906 48 CA KBMG DOME BK 16 09/19/02 3 9387 7818 43 CA KBMG DMY BK 0 06/14/01 2 10441 8532 53 CA KBMG DMY BK 0 06/14/01 1 10586 8618 55 CA KBMG SO BK 22 09/19/02 10614' H4-1/2" PARKER SWS NIP, ID = 3.813" 10672 H 7-5/8" x 4-1/2" TM/ HBBP PKR, ID = 4.0" 10702' H 4-1/2" PARKER SWS NIP, ID = 3.813" 10702' 4-1/2" PX PLUG (08/13/08) 10719' 4-1/2" PARKER SWN NIP (MILLED BY CTD) ID =FROM 3.725" TO 3.80" I 4-1/2" TBG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" I TOP OF 4-1 /2" LNR H 10757' 7-5/8" CSG, 29.7#, ID = 6.875" H 10922' 4-1/2" WLEG, ID = 3.958" ELMD -NOT LOGGED ~ TNV SCOOP/OV ERSHOT ASSY ~ 11955' H 3.70" BKR DEPLOY SLV, ID = 3.00" 3-1/2" X 2-7/8" XO, 1D = 2.44" 4-1 /2" LNR, 12.6#, 13CR 80, 0.0152 bpf, ID = 3.953" 11275' ~~ ~ ~ ~ 12025' 2-7/8" PRE-DRILLED LNR ID = 2.37" TOP OF 4-1/2" SLOTTED LNR 11275' • ~ ~~ ~~ ~ ~ • ~ ~ ~ ~ ~ ~ ~ ~~ ~• ~~ ~ ~ ~ ~ ~ ~ ~ ~` ~ ~ ~ 4-1/2" LNR, 13-CR-80, SLOTTED, 0.0152 bpf, ID = 3.953" 126$$' ~` ~~ PBTD 13984' ~~ 2-7/8" LNR, 6.16#, L-80 STL, .0057 bpf, ID = 2.37" 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/27/93 FARGO ORIG HORIZ COMPLETION 06/25/01 CH/TP CORRECTIONS 02/24/01 SIS-QAA CONVERTED TO CANVAS 09/19/02 DTR/KK GLV CJO 03/02/01 SIS-MD FINAL 08/17/08 JRA/SV SET PX PLUG (08!13!08) 05/18/01 RWKAK CORRECTIONS 06/04/01 CTD SIDETRACK PRUDHOE BAY UNIT WELL: X-22A PERMff No: n2010740 API No: 50-029-22399-01 4909' FSL & 5257' FEL Sec 8, T10N, R14E BP F~cploration (Alaska) TREE = 4" SM, CR WELLHEAD,= 5M FMC ACTUATOR = OTIS KB.'ELEV = 68.64' BF. E1EV = 39.0' KOP = 3763' Max Angle = 94 @ 13542' Datum MD = 10926' Datum TVD = 8800' SS 20" CSG, 94#, H-40, ID = 19.124" @ 82` 10-314" CSG, 45.5#, L-80, ID = 9.953" ~~ 3200' 7-5/8" 29.7#, L-80 from old TOC to surtace Minimum ID = 2.37" @11961' 2-7/8" FL4S LNR X 2-7/8" STL LNR XO 4-1 /2" 12.6#/ft, 13Cr-80 tubing -'2000'4-1/2"HESXNIP, ID=3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 4 10663 3 8386 2 6032 1 2502 4-1/2" HESXNIP, ID = 3.813" 7-5/8" x 4.5" Baker S-3 packer @ _10570' 10672' H 7-5/8" x 4-1 /2" TMJ HBBP PKR, ID = 4.0" 10702' 4-1/2" PARKER SWS NIP, ID = 3.813" 10719' 4-1/2"PARKER SWN NIP (MILLED BY CTDI ID =FROM 3.725" TO 3.80" I 4-1/2" TBG, 12.6#, 13CR 0.0152 bpf, ID = 3.958" I 10731' J ~ 10731' 4-1/2" WLEG, ID = 3.958" TOP OF 4-1 /2" LNR 10757' ~~ ELMD -NOT LOGGED 7-5/8" CSG, 29.7#, ID = 6.875" H 10922' TNV SCOOP/OV ERSHOT ASSY ~ 11955' -j3.70" BKR DEPLOY SLV, ID = 3.00" 1~9~ 3-1/2" X 2-7/8" XO,ID = 2.44" 4-112" LNR 12.6#, 13CR-80, 0.0152 bpf, ID = 3.953" 11275' \~ l ~~ 12025' 2-7/8" PRE-DRILLED LNR, ID = 2.37" TOP OF4-1/2"SLOTTED LNR 11275' ~ ~ ~• ~~ ~ ~ • ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~` ~ ~ 4-1/2" LNR, 13-CR-80, SLOTTm, 0.0152 bpf, ID = 3.953" 12688' ~\ ~~ PBTD 13984' ~~ 2-7/8" LNR, 6.16#, L-80 STL, .0057 bpf, ID = 2.37" 14018' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/27/93 FARGO ORIG HORIZ COMPLETION 06/25/01 CH/TP CORRECTIONS 02/24/01 SIS-QAA CONVERTED TO CANVAS 09/19/02 DTR/KK GLV CJO 03/02/01 SIS-MD FINAL 08/17/08 JRA/SV SET PX PLUG (08/13/08) 05/18/01 RWKAK CORRECTIONS 06/04/01 CTD SIDETRACK PRUDHOE BAY UNfT WELL: X-22A PERMIT No: 82010740 API No: 50-029-22399-01 4909' FSL & 5257' FEL Sec 8, T10N, 814E X-22A SAFETY NOTES: CHROMETBG/LNR. 7-518" TM/ PKR ~ PROPOSE ~ IL AT 2100 PSI DIFF IF EXCEEDED CID. 2-7/8" LN~S BEEN PRmRILLED W/3/8" HOLES @ 4 HOLES PER FT. 4-1/2" SWN NIP @ 10719' MILL®OUT TO 3.80" ID BY CID. e e ~~, it¡;:...,~. . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inserts\Microfihn _ Marker.doc Permit to Drill 2010740 MD 14018 -""~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. PRUDHOE BAY UNIT X-22A Operator BP EXPLORATION (ALASKA) INC 9025 'j Completion Dat 6/412001 ? Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22399-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample N._9o Directional Survey .._No'.,/ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type imedia Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments ~ Ver LIS Verification Rpt Ver LIS Verification ~~ Pdf Cn See Notes Directional Survey MWD Survey FINAL FINAL 1 12696 13972 1 12696 13972 1 9003 14018 CH 6/15/2001 OH 6/14/2001 Open 9/10/2002 c.l-f031 Open 9/10/2002 Case 12/3/2002 (_.1J-$65 Directional Survey, Paper Copy MWD Survey, Digital Data Digital Well Log Data Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y I[~i'~ Chips Received? Analysis Daily History Received? Formation Tops Comments: / ! Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 02, 2002 MWD Formation Evaluation Logs: X-22A, AK-MW-10178 X-22A: Digital Log Images 50-029-22399-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING, AND RETURNING. A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical iData Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED DEC 03 2002 Alaska 0t~ & C/as Cons. CommiBaion Anchorage WELL LOG TRANSMITYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs X-22A, AK-MW-10178 September 03, 2002 1 LDWG formatted Disc with verification listing. API#: 50-029-22399-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. AND RETURNING. A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED SEP 10 ~a~a 0i'~ & Gas Cons, CommiB~ioq STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG CTD Extension 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended I-I Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-074 , 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22399-01 4. Location of well at surface '. , ' ...... '~~ ' 9. Unit or Lease Name 370' SNL, 25' EWL, SEC. 08, T10N, R14E, UM .... ~_.'. I~'LOC--A~~E:~S!~~.~,,.~,,,., Prudhoe Bay Unit At top of productive interval .~ ~ [ :i . 2832' SNL, 44646752' WEL, SEC. 07, T10N, R14E, UM ..... At total depth,:'~ "~: '~ '" ;'~~f 10. Well Number X-22A 3547' SNL, 2121' WEL, SEC. 12, T10N, R13E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 69.15' ADL 047472 12. Date Spudded5,31,2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'6,2/2001 6,4,2001 [ 15. Water depth, if offshoreN/A MSL I16' N°' °f c°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 14018 9025 FTI 14018 9025 ETI [] Yes [] NoI (Nipple) 2101' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, ROP 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H'40 Weld 110' 30" 280 sx Arcticset (Approx,.,) ..... '1'0-3/4" '45.5# '" NT'80' ' 3i' ' 3200' 1~-1/2" 2407 cuft CS III, 431 cu ft Class '5' ' ........................ 7-5/8" 29.7# NT95HS 27' 10921' 9-7/8" 298 cuff Class 'G' 4-1/2" 12.6~ ' 13Cr80 10757" ~"~2'688" ...... 6-'§/4" Uncemented Slott~d'i'i'n~r ................................................. 2-7/8,, 6.16# I L-80 11955' 14018' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S,ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8" Slotted Liner 4-1/2", 12.6#, 13Cr 10731' 10672' MD TVD MD TVD 10760'- 11275' 8785'. 8970, 12025'- 13985' 9017' - 9023' 26.' ..... AC~D, FRACTURE, CEMENT SQUEEZE, ETCi .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 30 Bbls of 50/50 MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 20, 2001 Gas Lift i'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/2/2001 4 TEST PERIOD 2274 4656 1596 176I 2047 , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAwTY-API (CORR) Press. 24-HOUR RATE 23.8 .. .... 28. . C..0RE DATA . . 'Brief description' of lithol0gY, porosity, fraciures,' 'aPParent'dips and presence of'0il, 'gas or water.' 'submit core chips. RECEIVED JUL 2, Z001 Alaska 0il & Gas Cons. Commission Form 10-407 Rev. 07-01-80 O TiGiNAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sadlerochit / Zone 4B 11349' 8980' 31. List'of Attachme~tsl Summary of 'Da'ily Drilling Reports, Surveys ................... , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TorrieHul3ble.~~j~ ~ Title TechnicalAssistant Date - , X-22A 201-074 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: X-22 Common Well Name: X-22A Spud Date: 5/30/2001 Event Name: REENTER+COMPLETE Start: 5/30/2001 End: 6/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 6/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/29/2001 03:30 - 05:30 2.00 MOB P PRE Rig Released from G-25a @ 0330 hrs, 05/29/01. Prep rig for derrick down move. Move off well and spot on G Pad 05:30 - 10:00 4.50 MOB P PRE Rig on Standby @ 0530 hrs waiting on wind (15-23 mph, gusts to 30 mph) 10:00 - 14:30 4.50 MOB P PRE Restart rig move rate at 1000 hrs. Lay out wind walls. Scope down and lay down derrick in pipe shed. 14:30 - 00:00 9.50 MOB P PRE Move from G to X Pad. Raise derrick and wind walls. Rig up HB&R on X-22A. SIWHP = 1900 psi. Pump 300 bbls · 2% KCL water to kill well. Final WHP = 0 PSI. RID HB&R. Shut in well. 5/3,0/2001 00:00 - 03:00 3.00 MOB P PRE Move Nordic 1 Rig over well. 03:00 - 04:30 1.50 MOB P PRE Pick up injector head and goose neck. :04:30 - 06:00 1.50 BOPSUF P DECOMP ACCEPT RIG AT 0430 HRS, 05/30/01. N/U BOPE. ,06:00 - 08:00 2.00 BOPSUF P DECOMP Spot and berm green tank and flowback tank. Fill rig pits with 300 bbl, 2% KCL water. 08:00 - 13:30 5.50 BOPSUF P DECOMP Perform initial BOPE pressure /function test. Send test report to AOGCC. Order new FIoPro drilling fluid per An¢. Eng. 13:30 - 16:45 3.25 BOPSUF.P DECOMP Change out CT pack-off and M/U CT connector. Pull test w/ 35K, fill CT with KCL water and press test CT connnector. 16:45 - 17:30 0.75 STWHIP P WEXlT Held Well Planning meeting with all personnel. Reviewed well plan and potential hazards. Held PJSM for killing well and M/U milling BHA. 17:30 - 18:00 0.50 STWHIP P WEXlT Press test inner reel valve, 18:00 - 19:00 1.00 STWHIP N RREP WEXlT Repair Baker choke on rig floor. 19:00 - 19:45 0.75 STWHIP P WEXIT MU nozzle & test packoffs. Bullhead 50 bbls kcl down tbg. WHP dropped from 110 to 0 psi. Monitor well before MU BHA. 19:45 - 21:15 1.50 STWHIP P WEXlT MU HC mill on mtr w/DC & jars. 21:15-23:15 2.00 STWHIP P WEXlT Onwell. RIH. Prep to displace to flo pro. 23:15 - 23:30 0.25 STWHIP P WEXlT .,,Tag SWN nipple at 10726'. Correct depth to 10719' (ELM). 40k# up, 20 k# dn wt. Mill nipple in 10 minutes. Back ream ,,same. '23:30 - 00:00 0.50 STWHIP P WEXlT ~ Continue in hole. Work thru tight spot at 11482'. 5/31/2001 00:00 - 00:30 0.50 STWHIP N DPRB WEXlT Tag tight spot at 11854'. Motor work & stalling. No progress. POOH for round btm mill. Pull tight again at 11482'. 00:30- 03:00 2.50 STWHIP N DPRB WEXlT POOH for parabolic mill. 03:00- 04:15 1.25 STWHIP N DPRB WEXlT At surface. Set back injector. Change out mills (pu parabolic). Lost 175 bbls new flo pro during well kill. 04:15 - 06:15 2.00 STWHIP N DPRB WEXlT ,RIH. Take on additional mud (used) 06:15 - 09:00 2.75 STWHIP N DPRB WEXIT Ream undergauge liner from 11848 - 11853 ft. Losses decreased from 1.2 bpm to 0.3 bpm. 2.4 bpm / 1.8 bpm, 2500 psi. 09:00 - 09:10 0.17 STWHIP N DPRB WEXlT Ream thru restriction at 11853 ft., back ream. Ream down clean. 09:10 - 09:40 0.50 STWHIP N DPRB WEXIT RIH. Stall at 11895 ft. Ream thru at 11897 ft. RIH to 12060 ft. 09:40 - 12:50 3.17 STWHIP N DPRB WEXIT Ream at 12062 ft. RIH to 12072 ft. Ream. 12072-12074 ft. RIH. Ream 12084- 12091 ft. 12:50 - 13:50 1.00 STWHIP N DPRB WEXlT Ream 12091 - 12093 ft. Back ream. 13:50 - 14:30 0.67 STWHIP N DPRB WEXlT RIH with 3.80" mill to PBTD of'12,674 ft CTD. 14:30 - 14:45 0.25 STWHIP P WEXIT Mill 4 1/2" Pack-off Bushing. [Pack-off is AL and 4" long]. Mill out in 5 min. RIH to 12698 ft. 14:45-16:30 1.75 STWHIP P WEXIT Mill TIW Guide shoe, Mil12ft. to12700ft. Pick up 30 ft. No overpull. RIH. Drill formation to 12,706 ft. Short trip, clean. ~ Printed: 6/11/2001 2:50:23 PM BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: X-22 Common Well Name: X-22A Spud Date: 5/30/2001 Event Name: REENTER+COMPLETE Start: 5/30/2001 End: 6/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 6/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/31/2001 14:45 - 16:30 1.75 STWHIP P WEXlT Drill to 12,712 ft, short trip, clean. Drill formation to 12,717 ft. Short trip clean. Drill formation to 12,724 ft CTD. 16:30 - 18:00 1.50 STWHIP P WEXlT Back ream at 5 fpm to 12,670 ft. No motor work or overpull. POOH. ,Motor work at 12375 ft. Ream in hole and out. POOH. Motor work at 12120 ft. Ream in hole and out. POOH. 18:00 - 20:00 2.00 STWHIP P WEXlT POOH for MWD BHA. 20:00 - 22:00 2.00 STWHIP P WEXlT Test rupture disk sub on rig floor. 4500 disc sheared after surging coil several times to 5000 psi. 22:00 - 23:30 1.50 DRILL P PROD1 MU lateral assy #1 with resistivity. 23:30 - 23:59 0.48 DRILL P PROD1 RIH with drilling assy. SHT mwd. ~6/1/2001 00:00 - 02:00 2.00 DRILL P PROD1 RIH with drilling assy. 02:00 - 03:30 1.50 DRILL P PROD1 Log initial GR tie in from 12420'. Unable to match anything. RIH to verify TD. Tag at 12732' (6' deep from previous run) 03:30 - 04:30 1.00 DRILL P PROD1 .Make 2nd tie in pass from 11850'. GR counts reading way too high. Apparent tool failure. 04:30 - 06:00 1.50 DRILL N DPRB PROD1 POOH to check mwd tool. 06:00 - 07:30 1.50 DRILL N DPRB PROD1 Check GR tools at surface. All three sensors working properly. Changed out sensors and checked again, same correct readings. 07:30 - 10:00 2.50 DRILL N DPRB PROD1 RIH with MWD BHA, with 1 deg motor, DS49 bit #1. No problems RIH to 12350 ft. 10:00 - 11:00 1.00 DRILL N DPRB PROD1 Log Tie-in with GR. Add 9 ft CTD. [ Note: the Non productive time was not rig down time]. 11:00 - 11:30 0.50 DRILL P PROD1 Tag TD at 12740 ft. Orient TF. 11:30 - 12:30 1.00 DRILL P PROD1 Drilling, TF -- 20L, build incl to 94 deg. 2.5 / 2.3 bpm, 3100 psi. Drilled to 12800 ft. 12:30 - 12:45 0.25 DRILL P PROD1 Orient TF to 90L. 12:45-15:00 2.25 DRILL P PROD1 Drilling, TF=90L, 2.5/2.3bpm, 3100psi, ROP=80fpm. Drilled to 12,900'. 15:00 - 15:15 0.25 DRILL P PROD1 Wiper trip to shoe. Hole was clean. RIH. 15:15 - 15:30 0.25 DRILL P PROD1 Orient TF to right side. 15:30 - 17:15 1.75 DRILL P PROD1 Drilling, TF = 70R, 2.5 / 2.3 bpm, Drilled to 13,050 ft, 17:15 - 17:45 0.50 DRILL P PROD1 Wiper trip to shoe. Hole was clean. RIH. 17:45 - 18:15 0.50 DRILL P PROD1 Orient TF 18:15 - 20:15 2.00 DRILL P PROD1 Drilling, TF = 2.5 / 2.3 bpm, 3300 psi, Drilled to 13200'. 20:15-21:30 1.25 DRILL P PROD1 "long" Short trip to 10920'. 21:30 - 22:15 0.75 DRILL P PROD1 Log gr tie in from 10950' (near top of Sag). Add 12' correction. 22:15 - 22:45 0.50 DRILL P PROD1 RIH 22:45 -23:15 0.50 DRILL P PROD1 Log deeper gr tie in from 12465'. Add 8' correction. RIH. 23:15 - 00:00 0.75 DRILL P PROD1 Drill ahead. 2.5 bpm / 3200 psi/ TF: 85r. Drill to 13230'. Continue to climb TVD. 6/2/2001 00:00 - 01:30 1.50 DRILL P PROD1 Drill ahead. 2.5 bpm / 3300 psi / TF: 90R. Drill to 13350'. 35k# up, 15k# dn wt. 01:30-02:45 1.25 DRILL P PROD1 Short trip to linershoe. Pulled heavyat 12780'. Looked like pulling junk along BHA. Worked pipe. Popped through. Run back in hole. Saw weight bobbles same area, but through ok. 02:45 - 04:00 1.25 DRILL P PROD1 Drill ahead. 2.5 bpm / 3400 psi / TF:90L. ROP: 100fph. Drill to 13450'. 04:00 - 04:15 0.25 DRILL P PROD1 Orient to 90L. 04:15 - 04:45 0.50 DRILL P PROD1 Drill ahead. 2.5 bpm / 3400 psi/TF:90L. ROP: 100fph. Drill to 13482. Printed: 6/11/2001 2:50:23 PM BP EXPLORATION Page 3 of 4 Operations Summa Report Legal Well Name: X-22 Common Well Name: X-22A Spud Date: 5/30/2001 Event Name: REENTER+COMPLETE Start: 5/30/2001 End: 6/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 6/4/2001 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 6/2/2001 04:45 - 05:45 1.00 DRILL P PROD1 Short trip to shoe. Hole smooth. 05:45 - 06:00 0.25 DRILL P PROD1 Orient to 100L. 06:00-07:30 1.50 DRILL P PROD1 Drillahead. 2.6 / 2.5 bpm / 3500 psi, 100FPH, Drilledto 13,600 ft. 07:30 - 07:45 0.25 DRILL P PROD1 Orient TF to 80R. 07:45 - 08:45 1.00 DRILL P PROD1 Drilling, 2.6 / 2.5 bpm, 3500 psi, TF = 80R, ROP - 100 FPH, Drilled to 13,650 ft. 08:45 - 10:15 1.50 DRILL P PROD1 Wiper trip to 10,900 ft to clean horizontal section. Hole clean. RIH. 10:15 - 11:00 0.75 DRILL P PROD1 Log Tie-in with GR. add 16 ft to CTD. 11:00 - 11:30 0.50 DRILL P PROD1 RIH to TD clean. 11:30 - 13:30 2.00 DRILL P PROD1 Drilling, TF = 140R, need to drop incl. to get below pyrite at top of zone 4. presently seeing 20% pyrite in samples. 2.5 / 2.4 bpm, 3500 psi, Drilled to 13737 ft. 13:30 - 14:15 0.75 DRILL P PROD1 Drilling, TF = 70R. 2.5/2.4 bpm, 3500 psi. Drilled to 13,801 ft 14:15 - 15:00 0.75 DRILL P PROD1 Wiper trip to shoe. Hole was clean except for motor work / overpull at 13,310 ft. RIH. 15:00 - 17:00 2.00 DRILL P PROD1 Drilling, TF = 100R, 2.4 / 2.3 bpm, 3500 psi, ROP = 80 fph. Drilled to 13895 ft 17:00 - 17:40 0.67 DRILL P PROD1 Driling, TF = 100R, 2.4 / 2.3 bpm, 3500 psi, ROP -- 80 fph. Drilled to 13,950 ft. 17:40 - 19:00 1.33 DRILL P PROD1 Wiper trip to shoe. Clean hole, except for motor work / overpull at 13,310 ft. RIH. 19:00 - 19:15 0.25 DRILL P PROD1 Orient to 21R. 19:15 - 20:45 1.50 DRILL P PROD1 Drill ahead. 2.3 bpm, 3400 psi, 100 fph. TF:21R. Drill to 14010'. Resistivity shows water. Call town. Call TD. Corrected to 14018' after final tie-in. 20:45 - 00:00 3.25 DRILL P PROD1 Long short trip to 10700'. 6/3/2001 00:00 - 00:45 0.75 DRILL P PROD1 Log final tie in. Add 16' correction. 00:45-01:30 0.75 DRILL P PROD1 RIH. Tag & correct TD to14018'. 01:30 ~ 03:00 1.50 DRILL P PROD1 Final wiper to 12650'. Start new mud pill down coil. 03:00 - 05:30 2.50 DRILL P PROD1 POOH for liner. 05:30 - 07:15 1.75 DRILL P PROD1 At surface. Download mwd data. LD BHA. 07:15 - 07:30 0.25 CASE P COMP SAFETY MEETING. Review liner running procedure. 07:30 - 08:30 1.00 CASE P COMP Prepare to run liner. R/U Safety Joint with TIW valve and XO. 08:30 - 10:00 1.50 CASE P COMP Run 2 7~8" liner, TIW guide shoe, float jr, BKR O ring sub, 42 jts, pre-drilled 2 7~8", STL liner, 4 holes per ft. 3/8" holes., XO, BKR Deployment sleeve. 10:00 - 10:30 0.50 CASE P COMP Cut off DS CTC. M/U BKR CTC, Pull test and press test. 10:30 - 12:30 2.00 CASE P COMP RIH with perforated liner. Liner total length = 1410 ft. 12:30 - 13:20 0.83 CASE P COMP Stop at 12,600 ft. Up wt = 37.5 K, Dwn wt = 16K, RIH at 60 fpm. Setdown at 13,475 ft shoe depth several times. No progress. Restriction is the 6 ft X 3.70" OD deployment sleeve not drifting thru the milled scale in the 4.5" liner at 12,070 ft. A total of 4 hrs milling time with a 3.80" diamond mill was spent from 12062 - 12095 ft. 13:20- 14:45 1.42 CASE N DPRB COMP POOH with liner. 14:45 - 16:30 1.75 CASE N DPRB COMP L/O Baker CTLRT. M/U 20 more jts of 2 7/8", STL, pre-drilled liner. Total -- 63 Jts RIH. Total liner length -- 2,063.4 ft. Printed: 6/11/2001 2:50:23 PM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: X-22 Common Well Name: X-22A Spud Date: 5/30/2001 Event Name: REENTER+COMPLETE Start: 5/30/2001 End: 6/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 6/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/3/2001 14:45 - 16:30 1.75 CASE N DPRB COMP M/U Baker CTLRT. 16:30 - 18:25 1.92 CASE N 'DPRB COMP RIH with 2 7/8" pre-drilled liner on CT. Circ. at min. rate. 18:25-18:45 0.33 CASE N 'DPRB COMP Stop at12,600 ft. Upwt=39.5K. Dwnwt=16.5K. 18:45-19:30 0.75 CASE P COMP TagTDat 14005'. Correctto 14018'. 41.5k#up, 15k#dnwt. Drop 0.625" ball. Chase with flo pro at 2.3 bpm / 2650 psi. On seat at 52 bbls. (calc: 60 bbls). Pressure to 3500 psi 19:30 - 22:00 2.50 CASE P COMP POOH. Displace well to 1% k¢l. 22:00 - 22:30 0.50 CASE P COMP FP tubing from 2000' with 50/50 meth. 22:30 - 00:00 1.50 RIGD P COMP Shut master. Blow down lines. Off well. LD BHA. 6/4/2001 00:00 - 01:50 1.83 RIGD P COMP Clean pits. Pressure tested tree cap. RELEASED RIG AT 0130 HRS. 6/4/01. TOTAL TIME ON WELL WAS 4 DAYS, 21 HOURS. 01:50 - 0.00 RIGD P COMP Rig on Standby waiting for well prep on X-15A. Printed: 6/11/2001 2:50:23 PM 14-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well X-22A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,636.00' MD Window / Kickoff Survey: 12,688.00' MD Projected Survey: 14,018.84' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN 1 4 2.001 NaCa Oil & Gas Cons. C~mission DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA X Pad, Slot X-22 X-22A Job No. AKMWI0178, Surveyed: 2 June, 2001 SURVEY REPORT June, 200~ Your Ref: API-500292239901 Surface Coordinates: 5939759.43 N, 665918.41 E (70° 14' 29.9617" N, Kelly Bushing: 69.15ft above Mean Sea Level 148° 39'35.8655"W) DRILLING SERVICE=; Survey Ref: svy10842 A Halliburton Company Sperry. Sun Drilling Services Survey Report for X-22A Your Ref: AP1-500292239901 Job No. AKIViWI0178, Surveyed: 2 June, 2001 DEFINITIVE North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 12636.00 89 200 249.300 8964.79 9033.94 12688.00 89.200 249.300 8965.51 9034.66 12719.80 88.430 246.800 8966.17 9035.32 12753.00 89,340 244.610 8966.82 9035.97 12788.80 93.300 243.730 8965.99 9035.14 12819.20 93.830 241.270 8964.10 9033.25 12855.80 92.250 238.450 8962.16 9031.31 12893.00 93.300 232.460 8960.36 9029.51 12929.80 93.480 235.450 8958.18 9027.33 12970.80 93.480 243.030 8955.69 9024.84 13002.80 92.690 246.380 8953.97 9023.12 13038.80 91.890 252.370 8952.53 9021.68 13083.40 91.100 260.830 8951.36 9020.51 13112.80 91.100 264.880 8950.80 9019.95 13148.00 93.480 271.050 8949.39 9018.54 13176.20 93.830 273.690 8947.59 9016.74 13213.60 93.740 280.210 8945.12 9014.27 13243.00 93.040 284.790 8943.38 9012.53 13275.40 91 720 280.030 8942.03 9011.18 13328.00 91.010 275.980 8940.78 9009.93 13363.00 87.580 272.630 8941.21 9010.36 13397.00 87.670 266.290 8942.62 9011.77 13430.80 88.280 262.060 8943.81 9012.96 13459,80 91 100 258.710 8943.97 9013.12 13494.80 92.330 254.830 8942.92 9012.07 13542.00 94.180 250.250 8940.24 9009.39 13586.00 91.720 245.670 8937.98 9007.13 13614.60 91.190 243.380 8937.25 9006.40 13647.20 91.010 249.900 8936.62 9005.77 13670.20 89,960 252.190 8936.43 9005.58 Local Coordinates Global Coordinates Northings Easfings Northings Eastings (ft) (ft) (ft) (ft) 2947.35 S 5880.29W 5936683.37 N 660104.41 E 2965.73 S 5928.93W 5936663.92 N 660056.19 E 2977.61S 5958.41W 5936651.39 N 660026.98 E 2991.27 S 5988.67W 5936637.07 N 659997.03 E 3006.86 S 6020.87W 5936620.78 N 659965.17 E 3020.87 S 6047.79W 5936606.18 N 659938.58 E 3039.22 S 6079.39W 5936587.14 N 659907.39 E 3060.28 S 6109.98W 5936565.41N 659877.27 E 3081.89 S 6139.68W 5936543.15 N 659848.05 E 3102.81S 6174.82W 5936521.47 N 659813.38 E 3116.46 S 6203.71W 5936507.18 N 659784.80 E 3129.12 S 6237.36W 5936493.78 N 659751.44 E 3139.44 S 6280.69W 5936482.51 N 659708.34 E 3143.10 S 6309.85W 5936478.21N 659679.27 E 3144.35 S 6344.98W 5936476.19 N 659644.18 E 3143.19 S 6373.09W 5936476.73 N 659616.04 E 3138.67 S 6410.12W 5936480.43 N 659578.93 E 3132.32 $ 6438.76W 5936486.15 N 659550.15 E 3125.37 S 6470.37W 5936492.41 N 659518.40 E 3118.05 S 6522.43W 5936498.58 N 659466.19 E 3115.42 S 6557.32W 5936500.44 N 659431.25 E 3115.74 S 6591.27W 5936499.37 N 659397.31 E 3119.17 S 6624.87W 5936495.21N 659363.80 E 3124.01S 6653.45W 5936489.73 N 659335.33 E 3132.02 S 6687.50W 5936480.98 N 659301.46 E 3146.15 S 6732.44W 5936465.86 N 659256.85 E 3162.63 S 6773.16W 5936448.49 N 659216.50 E 3174.93 S 6798.96W 5936435.62 N 659190.97 E 3187.85 S 6828.87W 5936422.05 N 659161.36 E 3195.32 S 6850.62W 5936414.11 N 659139.78 E Dogleg Rate (°/100ft) 0.000 8.224 7.142 11.331 8.262 8.822 16.329 8.126 18.454 10.741 16.773 19.045 13.773 18.773 9.425 17.397 15.732 15.233 7.815 13.697 18.633 12.636 15.099 11.624 10.450 11.803 8.216 20.004 10.953 Alaska Drilling & Wells PBU WOA X Pad Vertical Section Comment 6302.76 6353.85 6384.95 6417.11 6451.54 6480.47 6514.78 6548.57 6581.57 6619.81 6650.62 6685.96 6730.43 6759.78 6794.59 6822.08 6857.76 6884.87 6914.78 6964.78 6998.68 7032.18 7O65.86 7O94.85 7129.77 7176.48 7219.44 7246.99 7278.69 7301.41 Tie on point MWD Magnetic Window point 14 Ju~m, 2001 - 9:30 Page 2 of 4 Dr#/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for X-22A Your Ref: API-500292239901 Job No. AKMWIOI78, Surveyed: 2 June, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13712.20 85.370 256.600 8938.14 9007.29 3206.60 S 6891.02W 5936401.93 N 659099.64 E 13754.20 85.110 261.710 8941.63 9010.78 3214.48 S 6932.11W 5936393.16 N 659058.73 E 13793.20 90.660 265.230 8943.07 9012.22 3218.90 S 6970.81W 5936387.88 N 659020.13 E 13824.00 90.220 272.100 8942.83 9011.98 3219.62 S 7001.58W 5936386.49 N 658989.39 E 13854.20 88.110 275.630 8943.27 9012.42 3217.59 S 7031.71W 5936387.86 N 658959.23 E 13889.80 86.610 280.210 8944.91 9014.06 3212.69 S 7066.92W 5936391.98 N 658923.91 E 13926.40 84.050 285.670 8947.89 9017.04 3204.53 S 7102.45W 5936399.36 N 658888.21 E 13959.80 83.960 289.370 8951.38 9020.53 3194.53 S 7134.12W 5936408.66 N 658856.32 E 13984.80 85.460 292.190 8953.69 9022.84 3185.70 S 7157.40W 5936416.97 N 658832.86 E 14018.00 85.460 292.190 8956.32 9025.47 3173.20 S 7188.04W 5936428.79 N 658801.95 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.641° (30-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 260.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14018.00ft., The Bottom Hole Displacement is 7857.30ft., in the Direction of 246.181 ° (True). Dogleg Rate (°l'~00ft) 15.147 12.140 16.846 22.350 13.616 13.524 16.430 11.021 12.734 0.000 Alaska Drilling & Wells PBU WOA X Pad Vertical Section Comment 7343.15 7384.99 7423.87 7454.29 7483.61 7517.43 7551.01 7580.47 7601.85 7629.86 Projected Survey 14 June, 2001 - 9:30 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for X-22A Your Ref: AP1-500292239901 Job No. AKMWlOI78, Surveyed: 2 June, 200f North Slope Alaska Alaska Drilling & Wells PBU WOA X Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 1263600 9033.94 2947.35 S 5880.29 W Tie on point 12688.00 9034.66 2965.73 S 5928.93 W Window point 14018.00 9025.47 3173.20 S 7188.04 W Projected Survey Survey tool program for X-22A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 1263600 9033.94 12636.00 9033.94 14018.00 9025.47 Survey Tool Description AK-3 BP_HM - BP High Accuracy Magnetic (X-22) MWD Magnetic (X-22A) 14 June, 2001 - 9:30 Page 4 of 4 DrillQuest 2.00.08.005 ALASKA OIL AND GAS CONSERVA~ION COMPtlSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-35.39 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit X-22A BP Exploration (Alaska) Inc. Permit No: 201-074 Sur Loc: 370' SNL, 25' EWL, SEC. 08, T10N, R14E, UM Btmhole Loc. 3580' SNL, 2267' WEL, SEC. 12 T10N, R13E, UM Dear Ms Endacott: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits' required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ,. Julie M. Heuss~r Co~issioner BY ORDER OF THE COMMISSION DATED this 2 7T3 day of April, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA d. AND GAS CONSERVATION COMMI,~ DN PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil [] Drill [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone la. Type of work [] Re-Entry [] Deepen [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 69.15' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047472 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.O25) 370' SNL, 25' EWL, SEC. 08, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval ,8. Well Number 2686' SNL, 4462' WEL, SEC. 07, T10N, R14E, UM X-22A Number 2S100302630-277 At total depth 9. Approximate spud date 3580' SNL, 2267' WEL, SEC. 12, T10N, R13E, UM 05/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 147476, 1699' MDI No Close Approach 2560 14200' MD / 8950' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12669' MD Maximum Hole Angle 98 ° Maximum surface 2308 psig, At total depth (TVD) 8800' / 3364 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.5# L-80 ST-L 1600' 12600' 8965' 14200' 8950' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Liner Perforation depth: measured Alas~a Oil & Gas Cons. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Numbec Terrie Hubble, 564-4628 21. I hereby certify that the~regoing is true and correct to the best of my knowledge Signed M.S. Endacott (~)~ ,. ~¢,,4~"t~- CT Drilling Engineer Date ~ / :!!i:;i:.!;i ;' .'. ..'..' """: .... : ':.". ;. '.'.' '.".( .'="':.:;.'.."? ... i;..'.-.. :..'.'".'.':'... '."Com.misSiOnUse, iOrqy;: ;".: '.:..'.. .?¥..'..' . ." ".::...;.. ';.":'. :'i::;'..':.'.. :'='.".. :..: '. ;.:.'. "...'=": .:".=..=':.' '"; '..? .=..'.. ' Permit Numbe'r I APl Number I Approv_alD8te, i See cover letter -~.c::::~/'- ,c::> ~ .~ 50- 029-22399-01 ~, ~."-~. ~.// for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Lbg Required [] Yes [] No Hydrogen Sulfide Measures ,j~ Yes [] No Directional Survey Required [] Yes [] No Required Working P~ssure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~.5K psi for CTU Other: ORiGiNAL 8~GNED BY .f. ~. ~,.e.~,~r. by order of Approved By 0~~~,,.~ ¥ Commissioner the commission Date ~/~.~. F~]/ Form 10-401 Rev. 12-01-85 O IGINAL Submit In Triplicate bp X-22a Sidetrack Summary of Operations: X-22 is currently completed in Zone 4B, offset wells were successfully drilled to within -500' or less of the edge of the field implying the X-22 could be extended at least 1000'. The well is currently producing 300BOPD, 65% WC. The extension, X-22a, will exit the 4 1/2" slotted liner shoe in the production interval and extend -1500' in Zone 4B. Existing pay, behind a slotted liner, will be controlled with mud weight during drilling. The extension will be completed with a pre-drilled 2 7/8" liner. '~Phase 1: Prepare well Planned for May 1, 2001. . · Drift tubing and liner ~'-~' ~ · Dummy off gas lift mandrels ~7'~~'"~ ~ ' ~'-~,i~ Verify tubing integrity Test master valve, wing valve and tree to 5000psi. Test wellhead seals for integrity Phase 2: Mill SWN, shoe, Drill and Complete extension: Planned for May 15, 2001. Coil tubing unit will be used to mill existing shoe track, drill and complete the directional hole as per attached plan. Mud Program: · FIo-Pro (8.6- 8.7 ppg) 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. Casing Program: · Top of 2 7/8" pre-drilled liner to be ±12,600' MD (±8965' TVDSS), Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. BHL (State Plane): 658,656; 5,936,393. Max. hole angle is 97deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity Log will be run in open hole. Hazards · The highest H2S recorded to date on X Pad is 11 ppm on X-21 on 1/29/01. X-22=30ppm+/-10% · No mapped faults. Reservoir Pressure Res. press, is estimated to be 3364 psi at 8800TVD, 7.35ppg EMW. Max. surface pressure with gas (0.12psi/ft) to surface is 2308 psi. TREE 5M,CR WELLHEAD= FMC ACTUATOR: OTIS 'R~':-~'~'"'~ 68.64' 'i~i~'i'-~"'~ ......................................... ~'i'i~~' "~ ~h'~j'i~'"~ ...... ~0'~"i"i"~'i~'6~ Datum MD = 10425 Datum TVDss= 8800' X-22A Proposed Extd,,sion 3200' GAS LIFT MANDRELS Minimum ID = 3.725" @10719' 4-1/2" PARKER SWN NIP. 10614' Id4-1/2" PARKER SWS NIP. ID=3.813"I 10672' l--17-5/8,, x 4-1/2" TIW HBBP PKR, ID:4.0"I 10702' 1-14-1/2" PARKER SWS NIP. ID=3.813"I ~07~' I-I"'~=""^"K~WN N,.. '~=~'~=~" I 4-1/2" TBG, 12.6#, 13CR, 0.0152 bpf, ID:3.958 I--~ I TIW 4-1/2" SS Horizontal PKRI 10731' 10757' I 10922' I { 10731' 1--14-1/2"WLEG, ID=3.958I I/1"-.._ ? Id ~M~ I 10744' I--IT~N SCOOP/OVERSHOT ASSY. I TIW 4-1/2" Slickstick Riser I Caution: Do Not Exceed 2100psi differential pressure across 7-5~8" TIW packer. 4-1/2" LNR, 12.6#, 13CR, 0.0152 bpf, id--3.9581 ITOP OF 4-1/2" SLO'FrED LNR. It ITop of 2-7/8" Pre-drilled Liner Id 11275' I 12600' I 4-1/2" LNR, 13-CR-80,SLO3-rED, 0.0152 bpf, ID:3.958 Id 12688' I 12686' I 3-3/4" Open Hole 2-7/8" Pre-drilled Liner DATE REV BY COMMENTS 10/27/93 FARGO ORIGINAL HORIZONTAL COMPLETION 02/24/01 SlS-OAA CONVERTED TO CANVAS 03/02/01 SIS-MD FINAL 03/26/01 pcr Sidetrack Proposed I-t 14200'I PRUDHOE BaY UNIT WELL: X-22A Proposed PERMIT No: 93-1300 APl No: 50-029-22399-00 Sec. 12, T1 ON, R13E BP Exploration (Alaska) Obp (' BP Amoco Baker Hughes INTEQ Planning Report I 111 INTEQ CompanY: BP Amoco Field: Prudhoe Bay Site: PBX Pad Well: X-99 Weilpath: Plan#4 X-22A Date: 4/912001 Time: 15:47:45 Page: 1 Co-ordinate(NE) Reference: Well: X-22, True North Vertical (TVD)Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,260.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PBX Pad TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5937417,97 ft Latitude: 70 14 7.207 N 664667.65 ft Longitude: 148 40 13.706 W North Reference: True Grid Convergence: 1.25 deg Well: X-22 Slot Name: 22 X-22 Well Position: +N/-S 2314.17 ft Northing: 5939759.84 ft Latitude: 70 14 29.966 N +E/-W 1301.26 ft Easting: 665917.98 ft Longitude: 148 39 35.878 W Position Uncertainty: 0.00 ft Wellpath: Plan#4 X-22A Drilled From: X-22 500292239901 Tie-on Depth: 12669.00 ft Current Datum: 32: 22 9/21/1993 00:00 Height 69.15 ft Above System Datum: Mean Sea Level Magnetic Data: 41912001 Declination: 26.68 deg Field Strength: 57475 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 260.00 Plan: Plan #4 Date Composed: 4/9/2001 Lamar's Plan #4 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets X-22A Polygon4.1 0.00 -3348.00 -6543.10 5936268.88 659450.60 70 13 57.010 N 148 42 46.004 W -Polygon 1 0.00 -3348.00 -6543.10 5936268.88 659450.60 70 13 57.010 N 148 42 46.004 W -Polygon 2 0.00 -3218.69 -7425.55 5936378.72 658565.58 70 13 58.274 N 148 43 11.649 W -Polygon 3 0.00 -2938.74 -7419.43 5936658.72 658565.54 70 14 1.027 N 148 43 11.479 W -Polygon 4 0.00 -3068.05 -6536.99 5936548.87 659450.55 70 13 59.764 N 148 42 45.833 W Annotation 12636.00 8964.79 TIP 12669.00 8965.25 KOP 12839.00 8955.07 1 12915.61 8949.97 2 13540.61 8949.97 3 14200.00 8949.97 TD Plan Section Information 12636.00 89.20 249.30 8964.79 -2947.40 -5880.32 0.00 0.00 0.00 0.00 12669.00 89.20 249.30 8965.25 -2959.06 -5911.18 0.00 0.00 0.00 0.00 12839.00 97.63 234.50 8955.07 -3038.61 -6060.37 10.00 4.96 -8.71 300.00 12915.61 90.00 233.83 8949.97 -3083.33 -6122.30 10.00 -9.96 -0.87 185.00 13540.61 90,00 296.33 8949.97 -3134.28 -6714.58 10.00 0.00 10.00 90.00 14200.00 90.00 230.39 8949.97 -3206.35 -7334.00 10,00 0.00 -10.00 270.00 Obp i" BP Amoco Baker Hughes INTEQ Planning Report COmpanY: BP Amoco Date: 419/2001 Time: 15:47:45 Page: 2 Field: PrUdhoe Bay CO-ordinate(NE) Reference: Well: X-22, True North Site: PBX Pad Vertical (TV]))Reference: System: Mean Sea Level Well: X-22 Section (VS) Reference: Well (0.00N,0.00E,260.00Azi) Wellpath: Plan~4 X-22A Survey Calculation Method: Minimum Curvature Db: oracle Survey MI) Inel Azim SSTVI) N/S E/W MapN MapE DLS VS TFO Tool ft deg deg fi: ff ft ff ft deg/100fi: fi: deg 12636.00 89.20 249.30 8964.79 -2947.40 -5880.32 5936683.94 660104.36 0.00 6302.80 0.00 TIP 12650.00 89.20 249.30 8964.99 -2952.35 -5893.41 5936678.70 660091.38 0.00 6316.55 0.00 MWD 12669.00 89.20 249.30 8965.25 -2959.06 -5911.18 5936671.60 660073.77 0.00 6335.21 0.00 KOP 12675.00 89.50 248.78 8965.32 -2961.21 -5916.78 5936669.33 660068.21 10.00 6341.10 300.00 MWD 12700.00 90.75 246.62 8965.26 -2970.69 -5939.91 5936659.34 660045.30 10.00 6365.53 300.01 MWD 12725.00 92.00 244.45 8964.66 -2981.04 -5962.66 5936648.49 660022.79 10.00 6389.72 300.00 MWD 12750.00 93.25 242.28 8963.52 -2992.24 -5984.98 5936636.81 660000.72 10.00 6413.65 299.95 MWD 12775.00 94.49 240.10 8961.83 -3004.26 -6006.83 5936624.31 659979.14 10.00 6437.26 299.85 MWD 12800.00 95.72 237.92 8959.61 -3017.07 -6028.18 5936611.03 659958.08 10.00 6460.51 299.70 MWD 12825.00 96.95 235.73 8956.85 -3030.67 -6048.98 5936596.98 659937.59 9.99 6483.35 299.48 MWD 12839.00 97.63 234.50 8955.07 -3038.61 -6060.37 5936588.79 659926.37 9.99 6495.95 299.24 1 12850.00 96.53 234.40 8953.71 -3044.96 -6069.25 5936582.25 659917.64 10.00 6505.80 185.00 MWD 12875.00 94.04 234.19 8951.41 -3059.48 -6089.46 5936567.29 659897.75 10.00 6528.23 184.99 MWD 12900.00 91.55 233.97 8950.19 -3074.13 -6109.68 5936552.20 659877.86 10.00 6550.68 184.97 MWD 12915.61 90.00 233.83 8949.97 -3083.33 -6122.30 5936542.72 659865.45 9.99 6564.70 185,12 2 12925,00 90.00 234.77 8949.97 -3088.81 -6129.93 5936537.08 659857.95 10.00 6573.16 90.00 MWD 12950.00 90.00 237.27 8949.97 -3102.78 -6150,65 5936522.65 659837.53 10.00 6596.00 90.00 MWD 12975.00 90.00 239.77 8949.97 -3115.84 -6171.97 5936509.14 659816.51 10.00 6619.27 90,00 MWD 13000,00 90.00 242.27 8949.97 -3127.95 -6193.84 5936496.55 659794.91 10.00 6642,90 90.00 MWD 13025.00 90.00 244.77 8949.97 -3139.09 -6216.22 5936484.91 659772.79 10.00 6666.88 90.00 MWD 13050.00 90.00 247.27 8949.97 -3149,25 -6239.06 5936474.25 659750.18 10.00 6691.13 90.00 MWD 13075.00 90.00 249.77 8949.97 -3158.41 -6262.32 5936464.59 659727.13 10.00 6715.63 90.00 MWD 13100.00 90.00 252.27 8949.97 -3166.54 -6285.96 5936455.94 659703.67 10.00 6740.32 90.00 MWD 13125.00 90.00 254,77 8949.97 -3173.63 -6309.93 5936448.32 659679.87 10.00 6765.16 90.00 MWD 13150.00 90.00 257.27 8949.97 -3179.67 -6334.18 5936441.75 659655.75 10.00 6790.10 90.00 MWD 13175.00 90.00 259.77 8949.97 -3184.65 -6358.68 5936436.24 659631.37 10.00 6815.09 90.00 MWD 13200.00 90.00 262.27 8949.97 -3188.55 -6383.37 5936431.79 659606.77 10.00 6840.08 90.00 MWD 13225,00 90.00 264.77 8949.97 -3191.37 -6408.21 5936428.42 659582.00 10.00 6865.03 90.00 MWD 13250.00 90.00 267.27 8949.97 -3193.11 -6433.15 5936426.14 659557.11 10.00 6889.89 90.00 MWD 13275.00 90.00 269.77 8949.97 -3193,75 -6458.14 5936424.95 659532.14 10.00 6914.62 90.00 MWD 13300.00 90.00 272.27 8949.97 -3193.31 -6483.13 5936424.84 659507.15 10.00 6939.15 90.00 MWD 13325.00 90.00 274.77 8949.97 -3191.77 -6508.08 5936425,82 659482.17 10.00 6963.46 90.00 MWD 13350.00 90.00 277.27 8949.97 -3189.15 -6532.95 5936427.90 659457.26 10.00 6987.49 90.00 MWD 13375.00 90.00 279.77 8949.97 -3185.45 -6557.67 5936431.06 659432.46 10.00 7011.19 90.00 MWD 13400.00 90.00 282.27 8949.97 -3180.67 -6582.20 5936435.29 659407.83 10.00 7034.52 90.00 MWD 13425.00 90.00 284.77 8949.97 -3174.83 -6606.51 5936440.60 659383.40 10.00 7057.45 90.00 MWD 13450.00 90.00 287.27 8949.97 -3167,93 -6630.54 5936446.97 659359.23 10.00 7079.91 90.00 MWD '13475.00 90.00 289.77 8949.97 -3159.99 -6654.24 5936454.38 659335.36 10.00 7101.87 90.00 MWD 13500.00 90.00 292.27 8949.97 -3151.02 -6677.58 5936462.83 659311.84 10.00 7123.30 90.00 MWD 13525.00 90.00 294.77 8949.97 -3141.05 -6700.50 5936472.30 659288.70 10.00 7144.14 90,00 MWD 13540.61 90.00 296.33 8949.97 -3134.28 -6714.58 5936478.75 659274.47 10.00 7156.83 90.00 3 13550.00 90.00 295.39 8949.97 -3130.18 -6723.03 5936482.66 659265.94 10.00 7164.44 270.00 MWD 13575.00 90.00 292.89 8949.97 -3119.96 -6745.84 5936492.38 659242.91 10.00 7185.13 270.00 MWD 13600.00 90.00 290.39 8949.97 -3110.74 -6769.08 5936501.09 659219.48 10.00 7206.41 270.00 MWD 13625.00 90.00 287.89 8949.97 -3102.54 -6792.69 5936508.76 659195.69 10.00 7228.25 270.00 MWD 13650.00 90.00 285.39 8949.97 -3095.39 -6816.64 5936515.39 659171,59 10.00 7250,59 270.00 MWD 13675.00 90.00 282.89 8949.97 -3089.28 -6840.88 5936520.96 659147.22 10.00 7273.40 270.00 MWD 13700.00 90.00 280.39 8949.97 -3084.23 -6865.37 5936525.47 659122.63 10.00 7296.64 270.00 MWD 13725.00 90.00 277.89 8949.97 -3080.26 -6890.05 5936528.89 659097.87 10.00 7320.26 270.00 MWD 13750.00 90.00 275.39 8949.97 -3077.37 -6914.88 5936531.24 659072.98 10.00 7344.21 270.00 MWD 13775.00 90.00 272.89 8949.97 -3075.57 -6939.81 5936532.49 659048.02 10.00 7368.45 270.00 MWD 13800.00 90.00 270.39 8949.97 -3074.85 -6964.80 5936532.66 659023.02 10.00 7392.93 270.00 MWD 13825.00 90.00 267.89 8949.97 -3075.23 -6989.80 5936531.73 658998.04 10.00 7417.61 270.00 MWD ObP BP Amoco ( Baker Hughes INTEQ Planning Report BAKER' INT~Q COmpany: BPAmoco Date: 4/9/2001 Time: 15:47:45 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: X-22, True North Site: PBX Pad ' Vertical (TVD)Reference: System: Mean Sea Level Well: X-22 Section (VS) Reference: Well (0.00N,0.00E,260.00Azi) Wellpa~: Planet X-22A Survey Calcalation Method: Minimum Curvature Db: oracle Survey MD lncl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ff deg deg ff ff ff ff ft deg/100ft fi deg 13850.00 90.00 265.39 8949.97 -3076.69 -7014.75 5936529.72 658973.13 10.00 7442.44 270.00 MWD 13875.00 90.00 262.89 8949.97 -3079.24 -7039.62 5936526.62 658948.33 10.00 7467.38 270.00 MWD 13900.00 90.00 260.39 8949.97 -3082.88 -7064.35 5936522.44 658923.68 10.00 7492.36 270.00 MWD 13925.00 90.00 257.89 8949.97 -3087.59 -7088.90 5936517.20 658899.24 10.00 7517.36 270.00 MWD 13950.00 90.00 255.39 8949.97 -3093.36 -7113.22 5936510.89 658875.05 10.00 7542.31 270.00 MWD 13975.00 90.00 252.89 8949.97 -3100.19 -7137.27 5936503.53 658851.17 10.00 7567.18 270.00 MWD 14000.00 90.00 250.39 8949.97 -3108.07 -7160.99 5936495.13 658827.62 10.00 7591.91 270.00 MWD 14025.00 90.00 247.89 8949.97 -3116.97 -7184.35 5936485.72 658804.46 10.00 7616.46 270.00 MWD 14050.00 90.00 245.39 8949.97 -3126.88 -7207.30 5936475.31 658781.74 10.00 7640.79 270.00 MWD 14075.00 90.00 242.89 8949.97 -3137.78 -7229.80 5936463.91 658759.49 10.00 7664.83 270.00 MWD 14100.00 90.00 240.39 8949.97 -3149.66 -7251.80 5936451.56 658737.76 10.00 7688.56 270.00 MWD 14125.00 90.00 237.89 8949.97 -3162.48 -7273.26 5936438.27 658716.59 10.00 7711.92 270.00 MWD 14150.00 90.00 235.39 8949.97 -3176.22 -7294.13 5936424.07 658696.02 10.00 7734.87 270.00 MWD 14175.00 90.00 232.89 8949.97 -3190.87 -7314.39 5936408.98 658676.09 10.00 7757.36 270.00 MWD 14200.00 90.00 230.39 8949.97 -3206.35 -7334.00 5936393.07 658656.83 10.00 7779.36 270.00 TD Amoco 7¢00-7~00 7700-7600-75,~0-7400-7;;00 ~00 7100 ~7000 ~5900.6800.67OO-3600 650O-64OO <3300-6200~100-6O00 5¢0-5800 5700 5600 5500-5400-5300 West(-}/East(+) [1 O(~ft/in] Vertical Section at 260.00° [lOOft/in] 4/9/2001 4:08 PM 2 3/8" CT ~1 I 10,000 psi Lubricator~[ Nordic 1 X- 22~ CT Drilling & Completion BOP 7 1/16" Annular 7 1/16' 5000 psi Blind/Shear 7 1/16" Pipe/Slip -' -'- 2 3/8" ~1~ ~ 2 7/8" Pipe/Slips 7 1116" Pipe/Slips 3/8" SWAB OR MASTER VALVE H 1_ 8 4 3 5t3 o=,/;,',zo, oo,,..3~, VENDOR ALASKAOILA O0 DATE INVOIOE / CREDIT MEMO DESCRIPTION GROS~ DI,~:~OUNT NET 012901 CKO12901G 100. O0 100. O0 PYMT (;OMMENTS: Pee:~it To Deill I-ee HANDL N~ INST: S/H- Teeei Hubb Le X4&~8 IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ii[t]ll'_,~ll m 1OO. OO 1 OO. OO PAY WELL PERMIT CHECKLIST COMPANY WELL NAME/~'--.2..~ PROGRAM: exp dev Z,//redrll 1// serv wellbore seg ann. disposal para req FIELD & POOL INIT CLASS ,/')e.~ ,/- ~,,,~/ -- ADMINISTRATION APPR DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~.,~',~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. APPR [~ 33. ~ 34. GEOL AREA <~ ~',,3 UNIT# //~, ,.f 4) ON/OFF SHORE Y N ~ N Permit can be issued w/o hydrogen sulfide measures ..... ~,~ /~" YY N./ ,~, Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. N N Contact name/phone for weekly progress reports [exploratory only] Y ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Apnular COMMISSION: TEM~~/ JMH - / Com m e ntsll nstructions: o Z o -I c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well 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 APPENDIXi . . No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 S LisLib SRevlsion: 4 $ Wed Aug 21 13:09:30 20C)2 Reel Header Service name ............. LISTPE Date ..................... 02/'08/2i Origin ................... STS Reel Name ................ Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/08/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services //OS / Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MW-10178 S. LATZ WHITLOW/GOOD X-22A 500292239901 BP Exploration (Alaska), Inc. Sperry Sun 21-AUG-02 8 i0N 14E 370 25 69.15 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 10.750 3200.0 2ND STRING 7.625 10922.0 3RD STRING 4.500 12688.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 NO FOOTAGE DRILLED AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGN ET I C WAVE RESISTIVITY PHASE 4 (EWR4). 4. NO TVD LOGS DLJE TO MINIMAL VERTICAL DEPTH CHANGE. 5. DEPTH SHIFTING / CORRECTION WAIVED BY J. BUZA OF BP E.',::PLOP~ATION (ALASKA) , I PER THE EMAIL FROM D. SCHNORR OF 02./08./02. MWD CONSIDERED PDC. THIS WELL DRILLS OUT OF X-22A AT THE 4.5" LINER GUIDE SHOE (NO WINDOW). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. MWD RUN 2 REPRESENTS WELL X-22A WITH AP1 50-029-22399-01. THIS WELL REACHED A TOTAL, DEPTH (DF 14018' MD, 8956' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 12696.5 RPX 12'707.5 RPS 12707.5 RPM 12707.5 RPD 12707.5 FET 1.2707.5 ROP 12741.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 12696.5 14018.0 STOP DEPTH 13972.0 13983 0 13983 0 13983 0 13983 0 13983 0 14018 0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lc, ggir:g Direction ................. Down OpEical leg doeth units ........... Feet Data Reference Point .............. Undefined Fz-ame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 i ROP MWD FT/H 4 1 68 4 2 GR MWD AP1 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 i 68 28 8 Name Service Unit Min Max DEPT FT 12696.5 14018 ROP MWD FT/H 2.94 430.74 GR M~D AP1 24.11 482.31 RPX MWD OHMM 0.36 2000 RPS MWD OHMM 0.3 2000 RPM MIND OHMM 0.28 2000 RPD MWD OHMM 0.5 2000 FET NF~D HR 0.21. 3.92 Mean 13357.3 102.763 49.3422 46. 8657 31.3888 23.5941 44.1089 0.891375 First Reading For Entire File .......... 12696.5 Last Reading For Entire File ........... 1.4018 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Nsam 2644 2555 2552 2552 2552 2552 2552 2552 First Reading 12696.5 12741 12696 5 12707 5 12707 5 12707 5 1.2'707 5 12'707 5 Last Reading 14018 14018 13972 13983 13983 13983 13983 13983 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12696.5 RPX 12707.5 RPX 12707.5 RPM 12707.5 RPD 12707.5 STOP DEPTH 13972.0 13983.0 13983.0 13983.0 13983.0 FET 127 07.5 ROP 12741.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTNARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE {MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT}: 8OTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: HAXIMUM ANGLE: 13983. 1'~01° TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth uni, ts ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 02-JUN-01 Insite 4.05.5 4.30 M e mo r y 14 Ii} 18. C, 84.0 94 .2 TOOL NUMBER PB01862RF3 3.750 Flo Pro 8.62 54.0 8.5 24000 6.2 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 RO? MWD020 FT/H 4 1 68 GR MWD020 AP1 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 .150 76.0 .062 194.3 .140 76.0 .160 76.0 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Hin Max DEPT FT 12696.5 14018 RO? MWD020 FT/H 2.94 430.74 GR MWD020 AP1 24.11 482.31 RPX I,'NqD020 OHMM 0.36 2000 RPS MWD020 OHMM 0.3 2000 RPM P~ND020 OH~I 0.28 2000 RPD MND020 OHMM 0.5 2000 FET HWD020 HR 0.21 3.92 Mean 13357.3 102.763 49.3422 46.8657 31.3888 23. 5941 44.1089 0.891375 First Reading For Entire File .......... 12696.5 Last Reading For Entire File ........... 14018 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date ef Generatien ....... 02/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Last Nsam Reading Reading 2644 12696.5 1401~ 2555 12741 14018 2552 12696.5 13922 2552 12707.5 13983 2552 12707.5 13983 2552 12707.5 13983 2552 12707.5 13983 2552 12707.5 13983 Physical EOF 'rape Trailer Service name ............. LISTPE Date ..................... 02/08/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Lib,rary. Reel Trailer Service name ............. LISTPE Date ..................... 02/08/2]. Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File