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202-127
)) ~ ¡Ill age Project Well History File Cover Page XHVZE This page identifies ¡I,ose items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection (I f the file. J Qd... - 1 a 7 Well History File Identifier Organizing (done) ~wo-sided III" II1II111111111 ~scan Needed 1111111111111111111 RESCAN uz(6'olor Items: o Greyscale Items: DIGITAL DATA ~kettes, No. 3 o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: BY: ~ Date: o¡ '30/ 0 ~ OVERSIZED (Non-Scannable) ~s of various kinds: o Other:: :9 /s/ V11 1111111111111111111 Isl iYl!J o Other: NOTES: Project Proofing BY: C Maria) Production Scanning Stage 1 Page Count from Scanned File: ::t I L... (Count does include c~r sheet) Page .count Matches Number in Scan~ing PìParation: V YES BY ,~ Date:q 3D oS- Stage 1 If NO in stage 1, page(s) discrepancies were found: f Date: ~ 3D /0 S- 7 X 30 = 1;'0+ ~ = TOTAL PAGES ~ /.3 q ( () 0 ~ (Count does not include cover sheet) ý)J)-P Date: I 3 0 /s/, , ~ 11111-111 -1111111 Scanning Preparation BY: C Mari0 /s/ NO - V\1!) YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned IIIII r 1111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc Revisions: NS Acid Treatments - NS05,11,16, 19 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 7:11 PM To: Lau, John, Jack Cc: Younger, Robert O Subject: RE: Revisions: NS Acid Treatments - NS05,11,16, 19 Jack and Bob, No issues with the diverter. ~,~;;~'~,? ~ ~ ~ ~,~ ~~~ Tom Maunder, PE AOGCC From: Lau, John, Jack [mailto:Jack.Lau@bp.com] Sent: Mon 2/9/2009 4:56 PM To: Maunder, Thomas E (DOA) Cc: Younger, Robert O Subject: Revisions: NS Acid Treatments - NS05,11,16, 19 Tom, Boa - ~ a ~ As you are aware we are planning divererted acid treatments on NS05, NS11, NS16, and NS19 during ice road season. Originally we planned to use wax beads to divert between stages, however we have revised the programs to use benzoic acid flakes (BAF) in place of wax beads. We see no negative effects of using BAF, as BAF is extremely soluble in hydrocarbons and slightly soluble in water which should facilitate cleanup. Let me know if you have any questions, concerns, or requests. Thanks! ~I~e~ Isamu Fells 1?ngineet- BI? F;aploration (:Alaska) lnc. C)ffice: 907.56~.~i 10? Cell.: 907.227.?7E~0 2/10/2009 • Date 04-15-2008 Transmittal Number:92956 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions, please contact Joe Lastufka at (907)564-4091 Delivery Contents Well Name Date Contractor Lo Run Top De th Bottom De th Lo T e NS05 03-11-2008 SCH 1 13600 13850 PERFORATION RECORD NS16 03-06-2008 SCH 1 0 12200 FREE POINT INDICATION LOG C. ~ ~-- Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC ~ Murphy Exploration DNR MMS ~~~ ~P R ~, ~~ 200 ~~ X02 - ~~- # /~ ~ ~~~/ David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~p • Date 03-13-2008 Transmittal Number:92941 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC ,.~ can nnn~ Log Top Well Name Date Contractor Run De th Bottom De th Lo T e Depth Correlation Log PBMS-B NS16 02-07-2008 SCH 1 0 3576 GR/CCUPress/Tem _ ; Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center Attn: Christine Mahnken AOGCC Kristin Dirks DNR Doug Chromanski MMS Ignacio Herrera Murphy Exploration David Fair BPXA ~~-r~`~ ~~~039 ~~ C~~ - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ~~~ ALASK~IL AND GAS CONSERVATION COM~II~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAR 1 1 2008 ' a Uil ~ Gas Cogs. Cottwrr!issi011 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Cla~~hp1'~ ®Development Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 2/10/2008 ~~~ 12. Permit to Drill Number 202-127 ~ 306-334 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/29/2002 13. API Number , 50-029-23096-00-00 4a. Location of Well (Governmental Section): Surface: S ` ' ' 7. Date T.D. Reached 3/18/2003 14. Well Name and Number: NS16 J 1199 N L, 645 WEL, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 956' NSL, 520' WEL, SEC. 10, T13N, R13E, UM 8. KB (ft above MSL): 56.46' ~ Ground (ft MSL): 15. Field /Pool(s): Northstar Unit Total Depth: 956` NSL, 546' WEL, SEC. 10, T13N, R13E, UM 9. Plug Back Depth (MD+TVD) 3250 10850 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 659830 y- 6030971 Zone- ASP4 10. Total Depth (MD+TVD) 12424 ~ 11148 - 16. Property Designation: ADL 312799' TPI: x- 654682 y- 6030619 Zone- ASP4 Total Depth: x- 654656 y- 6030618 Zone- ASP4 11. SSSV Depth (MD+TVD) 972 968 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore 39' ft MSL 20. Thickness of Permafrost (TVD): 1545' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD ,GYRO , GR , CCL , RES , DIR , PWD ,DEN , NEU 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM ` TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 169# X-56 Surface 201' Surface 201' 20" Driven 13-3/8" 68# L-80 44' 3494' 44' 3200' 16" 618 sx PF'L' 470 sx Class'G' 9-5/8" 47# L-80 34 10435' 3193' 9288' 12-1 /4" 550 sx Econolite 621 sx Class 'G' 7" 26# L-80 10265' 12094' 9139' 10824' 8-1/2" 288 sx Class 'G' 4-112" 12.6# 13Cr80 11919' 12424' 10655' 11148' 6-1/8" 87 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No '24. TUBING RecoRD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, 13Cr80 11929' 11880' MD TVD MD TVD Tubin cut at 11874' t~~..,, ~'~j C~J'~ ~ MAY ~ ~ 200$ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 12120' P&A with 15 Bbls Class'G' 3670' Set 9-5/8" CIBP 3282' Set 13-3/8" CIBP -- 3250' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. 1 r None .?-~17- ..<;~..- Form 10-407 Revised 02/2007 CONTINUED ON ~~I~ ~/~~ ~; C ~! z8. GEOlYOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED: 29. FORMATION TESTS NAME TVD We11 Teste Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Kuparuk 9888' 8822' None Kuparuk'C' 10025' 8939' Top of Miluveach 10396' 9260' Top of Kingak 10975' 9778' Top of Sag River 12065' 10804' Top of Shublik 12162' 10898' Top of Ivishak 12258' 10992' Formation at Total Depth (Name): 30. List of Attachments: Well Work Summary and a Wellbore Schematic. 31. l hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Sondra St wman Title Drilling Technologist Date ©~ "` ~ '~ NS16 202-127 306-334 Prepared ByNameMumber: Sondra Stewman, 564-4750 Drilling Engineer: paul Hanson, 564-4195 Well Number Permit No. l A roval No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only E = ABB-VC3 5.1 rE" ~{SI LHEA~ = ABB-VGI 13.5lS" MJL118CU1~ g{g ''UATOR.- . BAKER .............. .. ....... . ... B_EY _ ... . ....... ................. .............. 56:4f$ ELEV = .......................... 40.56' (CB 15.9') ................................................................................... = .......................... 10f7 .................................................. ............:......... ......... Argle = .......................... . . 33° (~ 9614' ................................................................................... m ND = 11 S1'T " CSG, 68#, L-80 BTC, IR = 12.415' ~~ 3494 Minimum I[7 =-~.T25" f~'I'1995` +4=712" 7W NIPPLE SAFETYNOifS: °"+1=7 t!" L}iliOME T9G 8 LlIR+" I g~-113.3+'3" TAhA PORT CD 13-3/8" EZSV at 3282' 9-5/8" EZSV at 3670' 9.3 ppg Brine ~TOPOFT' LNR ~-1 7 9.5I8" CSG.47#.L-80 BTNFC.ID=8B81" ~I i TOP OF 41lL" LN R ~~ 7 4112" TBG, 12.6# 13C R VAhr1-ACE, --C .0152 bpf, ID = 3:958". LN R, 28#; L80 HYD R L 521, ID = 6.276" PERFORATION SUr~4iARY REF LOG; PDC GRICCL on 07!14103 ANGLE AT TOP PERF: 9 deg ~ 12304 INfTIAL PERF - CHFtRGE 2906 POWERJET, HSD, PBJETRLITION:,27",HOLE: 0,36". PHASE;f30 DEG: Note: Refer to Production DB fot historical perf data SQE SPF INTERVAL(MD) OpnlSgx DATE 2.7x8" 6 12:104- 12384 S ~115AD'T 12420' 1C2" LNR, 1218#, 13CR-80 VAM-ACS !~" &5r'8" X7"2XP LNR PKRw! &fLEX-LOCK HYDRFLULIC'H 77$$0' -jT'X41f2" PVCRi 77903 ~41~2" X NIP, ID = 3.813" 7 79 75'~ 4112" XN N P, D = 3.225 11~ 41!2"SELFALIGNINGUU ID = 3,85CI' 77~~6' ELnro LaG~ED 0a,~a,o~ TO P OF =f3. DATE REV BY COMMENTS DATE REU B`( COhAtdENTS NORTHSTAR 47M3J42 JAS INTC4N1PLE714M 081107 GLMIPJC P8d# UU~L: NS1$ .03!27143 FM FIMAL CGNf~LET14M 11127AD7 WRRIPJC WELLHDI LOCATION CORRECTI O PERMTNo: 2[121270 07118JQ0 ENF ADR PERFS 1?115'1d1 iiCTIPJC JET CUT(12106.07) APINo: 5Q•029.2309600 11/04+15 @JM NEW FORhA~T 12+15r1D7 RCTIPJC HOLD OPEN $LV (12A]7107) SBv 1T, T13N, R13~ 1199' FSL&646_` FEL 04r3QA77 WRRIPJC ELMDLOGGEDlUUELLHEAD 05N1AD7 WRRITLH GL DEPTH CORRECTION BP Exploration [Alaska)' l~1.1~(~I~~e Page 1 of 2 ~ ~ Well History Well Date Summary NS-16 8/14/2007 CTU #5. Rig-up. Assist with hardline rigup for NS-16. Standby on LRS to MIT-IA to 4200 psi before spotting unit. *** Job continued on WSR 08/15/2007 *** NS-16 8114/2007 Assist CTU#5 (Pre-RWO Cement Squeeze) -Heating seawater, rig up for MIT IA ***Continued to next Days WSR*** NS-16 8/15/2007 CTU #5. Cement P & A. *** Continue from WSR 08/14/2007 *** MIRU CTU. Perform 5000 psi BOP test, Kill Well with 380 BBLs of Seawater. RIH 12382' and PUH and flag at 12378' yellow***Job in Progress *** NS-16 8/15/2007 ***Continued from previous days WSR*** T/I/0=3600NacNac Temp=Sl MIT IA to 4200 osi PASSED !Pre-RWO/Cement Squeeze).; Pressured up IA to 4200 psi w/33 bbls 60*F diesel. IA lost 70 psi in 1st 15 min. IA lost 20 psi in 2nd 15 min. Passed, Bled IAP (~14 bbls fluid back) Tag well, normal casing valves & notify well tender/control room. Assist CTU as directed w/cement squeeze. Heat seawater, supply diesel as directed. ***Job In Progress*** NS-16 8/15/2007 CTU #5. Cement P & A. *** Continue from WSR 08/14/2007 *** MIRU CTU. Perform 5000 psi BOP test *** Job in progress *** NS-16 8/15/2007 ***Continued from previous days WSR*** T/I/0=3600NacNac Temp=Sl MIT IA to 4200 psi PASSED (Pre-RWO/Cement Squeeze) -Pressured up IA to 4200 psi w/33 bbls 60*F diesel. IA lost 70 psi in 1st 15 min. IA lost 20 psi in 2nd 15 min. Passed, Bled IAP (-14 bbls fluid back) Tag well, normal casing valves & notify well tenderlcontrol room. Assist CTU as directed for cement squeeze. Heat seawater, supply diesel Job in progress.. NS-16 8/15/2007 CTU #5. Cement P & A. *** Continue from WSR 08/14/2007 *** MIRU CTU. Perform 5000 psi BOP test. Kill Well with 380 BBLs of Seawater. RIH 12382' and PUH and flag at 12378' yellow. Lay in 15 bbls of , Class G 15.8 ppg LARC cement from flag. Squeeze 500 psi over static WHP for 1 hour. WHP gained 80 a wi s o pp iozan o c m. ash all bottom jewelry with 4 passes with XS seawater. POOH washing all jewelry with up/down/up pass. *** Job continued on WSR 08!1612007 *** NS-16 8/16/2007 CTU #5. Cement P & A. *** Continued from WSR 08/15/2007 *** Continue POOH washing tubing. Perform up/down/up passes on jewelry. Wash tree and BOP with XS seawater. RIH and lay in diesel from 3000'. Final PT at 1035 si lost 2 si over 10 minutes. Shut in and t ,Tag well as freez`e~protected. DMO CTU. Final T!I/O = 1034/1210. Notify well tender and control room of status. Demob equipment from island. ***Job Completed *** NS-16 8/16/2007 ***Continued from Previous Days WSR*** Assist CTU#5 (Pre-RWO/Cement Squeeze) -Assist coil as directed, de-mobe, travel to shore. ***Job Complete*** NS-16 9/11/2007 T/I/0=550/vac/vac Temp=Sl I~QIT T PASSED to 1000 psi (Post P&A Cement Squeeze -.Pressured up tbg from 550 psi to 1000 psi w/diese~TCgTos psi in st i~min. T6gTosf-~psi in n 15 min. Passed, bled TP from 990 psi to 300 psi. All fluid. Verified casing valves open to gauges, tag well & notify well tender. Final WHP's=300/vac/vac NS-16 9/11/2007 *** WELL S/I ON ARRIVAL*** SIDETRACK PREP ***DRIFT FOR JET CUT*** RAN 4 1/2" XN LOC, 3.7"CENT, LOC XN NIPPLE ~ 11885' SLM, +30' TO MD (11915'), TAG CMT ~ 12090' SLM, (12120') MR, WHILE PULLING OUT OF HOLE, CUT WIRE ON TRSSSV. TRSSSV HAD 3000 PSI ON CONTROL LINE. RAN 3.85" CENT TO SSSV NIPPLE ~ 939' SLM. CYCLE SSSV 3 TIMES. HOLD SSSV OPEN WITH 5000 PSI. RAN 3.85" CENT /FLAPPER CHECKER TO SAME, SSSV APPEARS TO BE FUNCTIONING^ ..r r„ rte,*,r..au n n» nr„ r" nnn n rr ,nn rl ~ nnc~~ cl AA ** T!1lll CTQIAI(_ RECOVERED ** *** CONTINUED PDS CALIPER ON 9/12/07 WSR *** NS-16 9/12/2007 *** CONTINUED FROM 9/11/07 WSR *** PRE SIDETRACK *** CALIPER TUBING FROM 12,094' SLM TO SURFACE ~ 50 FPM "GOOD DATA " *** WELL LEFT SHUT IN ON DEPARTURE *** NS-16 12/3/2007 PPOT NS-16 12/3/2007 71110=SSVNACNAC, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL). (pre sdtrk) Test tubing hanger void to 5000 psi. Good. Bleed to 0. Pressure pack-off to 5000 psi. Lost 200 psi in 2 min. Pressure back up to 5000 psi, lost all pressure. Re-energize and attempt to test again. Unsuccessful. Try tro pump JR-2 all the way around BT seal. No returns after 6 tubes. BT seal or o-ring bad. Program calls for cut & pull casing. Slips & pack-off available. NS-16 12/4/2007 ***TRAVEL TO NORTHSTAR/SPOT EQUIPMENT*** (pre sidetrack) http://digitalwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 3/6/2008 74~r5"I WP17J4/~D07 T/I/0=ssv/v c Temp=Sl MIT OA PASSED to 2000 si (Pre-SD Prep} -Loaded OA w/7.3 btllsage 2 Of 2 ' diesel. On empt re-pressured OA w/0.1 s iese . os i m st 15 mm. OA lost 10 psi in 2nd 15 min. al loss of 30 psi in 30 min. Passed, bled OAP to 0 p II fluid (-3 bbls). Verify casing valves open to gauges, tag well & notify well tender. Final WHP's=ssv/vac/60 NS-16 12/4/2007 Function test LDS & gland nuts. INCOMPLETE. {Permit cancelled due to extremely high wind gusts). Travel from Northstar to Prudhoe. NS-16 12/5/2007 T/U0=350/vac/100 Temp=Sl MIT T PASSED to 1000 si SDTRK Pre -Pressured up tbg from 350 psi to 1000 psi w/0.5 bbls diesel (against cement plug . g ost psi in st min. Tbg lost 10 psi in 2nd 15 min for a total of 20 psi in 30 mins. Bled TP (all fluid), verify casing valves open to gauges, tag well & notify operator. Final WHP's=20/vac/100 NS-16 12/5/2007 ***JOB PREP FOR JET CUT*** (pre sidetrack) NS-16 12/6/2007 De-Mobe Equipment, Travel to Prudhoe NS-16 12!612007 ***WELL SHUT IN ON ARRIVAL"'* {pre sidetrack) INITIAL WHP 40/0/100 CUT TUBING 11874' 15' BELOW NIPPLE. CUT WITH 3.65" JET POWERCUTTER, 2 GEMCOS RUN ABOVE C TTER. FINAL WHP 0/150/125 ***JOB COMPLETE*** NS-16 12/7/2007 '*`WELL S/I ON ARRIVAL*" (pre sidetrack) SFT HCII n C)PFN S FEV w/a ~/2" X LOCK IN TRSSSV ~ 940' SLM (AOL= 55" LOCK OPEN, MIN ID=2.50" }. RAN 4112" CHECK-SET TO CONFIRM. CHECK-SET CAME SACK SHEARED. ***WELL LEFT S/I CONTROL ROOM NOTIFIED*** NS-16 12/16/2007 *****Well Shut in on Arrival***** NS-16 Pre Sidetrack prep. Vetco-Gray checked and cycled all lock down screws. All lock down screws on tubing head adaptor cycled good. Well ready for Nabors 33-E NS-16 1/10/2008 T/I/0=0/150/85 Temp=Sl CMIT TxIA PASS D to 00o gsi (P1P RWO/Pest T n Cutl -Pressured up TxIA via tbg with a total of 6.7 bbls 10*F diesel, (caught fluid ~ 3.5 bbls away). T/IA lost 30/30 psi in 1st 15 min. T/IA lost 0/0 psi in 2nd 15 min. Passed, Bleed TxIAP all fluid -3.5 bbls. Tag well, verify casing valves open to gauges & notify operator/control room. Final WHP's=150/350/90 Print Date: 3!612008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 3/6/2008 ;! ; Operations Summary Report PRE BP EXPLORATION Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date i I From - To Hours I Task ~ Code ~ NPT ! Phase 1/18/2008 J 11:00 - 00:00 I 13.001 MOB P 1/i9l2008 100:00 - 09:00 I 9.001 MOB 1 P 09:00 - 00:00 I 15.00 I RIGU P 1/20/2008 100:00 - 12:00 12.001 RIGU P 12:00 - 00:00 I 12.001 RIGU I P 1/21!2008 100:00 - 02:00 I 2.OOi WHSUR I P PRE PRE PRE 1 /18/2008 33E Page 1 of 27 Spud Date: 6/29/2002 End: 3/18/2008 Description of Operations Pre-job safety meeting and Procedure review with all personnel involved with move. G & I ,ACS, AIC and Pad Operator involved in meeting Discuss responsibilities of all parties involved in the rig move Monitoring flowline, well house & pipe rack clearances Laying Herculite & spotting mats -Had to lay plywood on matting boards as need to keep rig level as we skid out of hole caused by subsidence. .Move ria from NS23 to NS16 Pre-job safety meeting and Procedure review with all personnel involved with move. G & I ,ACS, AIC and Pad Operator involved in meeting Discuss responsibilities of all parties involved in the rig move Monitoring flow line, well house & pipe rack clearances Laying Herculite & spotting mats Worked in conjunction with Pad Operator, shut-in and bleed wells and also putting wells back on line as we skid past All work done with appropriate permits Rig up Berm Rig, Close doors and weatherize rig, Slide walkways back into position, Rig Up and level stairs, Connect service lines to pipe rack, Secure cellar, Connect Comm lines, Prepare pit to take on seawater, Attach & Test line running to G & I, Complete move check list, Rig up on Well to displace diesel from well, G & I heating seawater for displacement Rig up on Well to displace diesel from well -Rig up on Annulus riser -R/U secondary annulus valve and lines into circ. manifold -R/U and open actuator valve on tree, -G & I take on seawater and heat, -test injection line, -test emergency shut down system, -test remote well emergency shut off, test gas alarms, hang heat blankets on standpipe PRE Rig Up to Displace Diesel freeze protect out of well -G & I take on seawater and heat, -Low PT on circulating lines to 120 psi, -Calibrate Epoch System, -Switch to high line power, -Rig Evacuation drill, -Adjust pump stroke counters PJSM with all personnel displacing diesel Tested lines to 1500 psi, O. K. Start to displace Diesel out of tubing, Flowline Actuator valve on tree leaking, Blind of flowline actuator line DECOMP Pre-Job safety meeting with all personnel involved with operation -Line up and start displacing freeze protect diesel from tubing at ICP =1.1 bpm /1720 psi Start: Rig Release: Rig Number: Printed: 2/27/2008 2:58:46 PM • BP EXPLORATION Operations Summary Report Page 2 of 27 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date From - To j Hours Task ~ Code NPT Phase j Description of Operations 1/21/2008 00:00 - 02:00 2.00 WHSUR P DECOMP 02:00 - 08:30 6.50 WHSUR P DECOMP 08:30 - 12:00 3.50 WHSUR P DECOMP 12:00 - 13:30 1.50 WHSUR P DECOMP 13:30 - 14:00 0.50 WHSUR P DECOMP 14:00 - 15:00 1.00 WHSUR P DECOMP 15:00 - 16:00 1.00 WHSUR P DECOMP 16:00 - 19:00 3.00 WHSUR P DECOMP 19:00 - 20:00 1.00 WHSUR P DECOMP 20:00 - 00:00 4.00 WHSUR P DECOMP 1/22/2008 00:00 - 12:00 12.00 WHSUR DECOMP 12:00 - 16:00 4.00 WHSUR DECOMP 16:00 - 17:00 1.00 WHSUR DECOMP 17:00 - 21:00 4.00 WHSUR DECOMP -Pressure increased as we loaded backside up with seawater, FCP = 1.1 bpm / 2010 psi -Pumped a total of 90 bbls from tubing to get good seawater returns G & I Injecting returns Line up to pump down tubing to displace diesel freeze protect from IA -pumping C~? 1.3 bpm / 60 psi -Pumped a total of 1737 bbls heated seawater around until clean at surface. G & I Injecting returns Continue to circulate 1 annulus volume at 6 BPM 700 psi to allow well to stabilize, taking returns down the drag chain to G &I. Pump 70 bbl High-Vis sweep around surface equipment and trip tank to clean same back to G & I. Blow down and RD all circulating lines and manifolds in cellar. Pumped a total of 1897 bbls to G & I. Secure tree stand in cellar and check well pressures. Well out of balance 400 psi on tubing, 100 psi on IA. RU lines and allow well to U-Tube to balance. T x IA 0 psi. RD and blow down lines. PJSM with VETCO service personnel RU T-bar and install BPV, test same from below to 1000 osi. Test held. RD T-bar. PJSM -Remove and secure control lines to tree /well head, ND tree and secure same on tree stand. Terminate control line and fiber optic cable at tubing hanger. Inspect tubing hanger, threads in good condition. Make dry run with 5.875" MCA x 4.5" IF running tool, 19 rounds to make up. Install blanking plug in tubing hanger. Obtain RKB measurements. 40.21' rotary table to tubing hanger. PJSM - NU drilling spacer spool, BOPE, Choke and Kill lines. Install turnbuckles PJSM - NU BOPE, Choke and Kill lines. Install turnbuckles, accumulator lines, replace air boots, remove iron rough neck track and master bushings, install drilling riser. Torque all flanges. Make up 5" test joint, Floor safety valve, pump in sub. Center up BOPE with turn buckles, well head leaning to east side of island. Continue to center BOP stack with rotary table. PJSM with all personnel. RU test equipment to test 250 psi low, 5000 psi high as per BP / AOGCC regulations. Witness of test by John Chrisp (AOGCC), Kelly Cozby & Roy Hunt (NAD Toolpushers), Chris Clemens (WSL) Repair leak on riser air boot. Pressure up against Blind shear rams, Kill line, Choke Manifold valves # 2, 5, & 3. Kill line Uni-Bolt connection failed. Replace ring gasket in same and retest. Blind Shear ram bonnet seal failed. PJSM -open blind shear ram and replace bonnet seal. Retest system, 13-5/8" API flange gasket leaking between bottom ram gate and drilling spool. PJSM - Re-torque flange bolts. Printed: 2/27/2008 2:58:46 PM • • BP EXPLORATION Page 3 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E i i ~ i i i ~ ' Code NPT Phase I Description of Operations Date From - To Hours Task 1!22!2008 21:00 - 00:00 3.00 WHSUR DECOMP Continue Test BOPE Test Blind Shear rams Choke Valves # 1-12 Kill line HCR & Manual: Kill Valves to 250 psi low / 5000 psi High, for 5 min. Test Manual and super choke to 250 psi low / 1500 psi high. 1/23/2008 00:00 - 01:30 1.50 WHSUR DECOMP Install 4-12" test joint, IBOP, Floor safety Valve. 01:30 - 02:30 1.00 WHSUR DECOMP Test: IBOP, Floor Safety Valve, Pass Attempt to test 3-1/2" x 6" VBR, Choke valve #13, Failed Whitey Valve failed on test manifold, bleed off and repair same. Re-pressure system. Whitey valve stem failed on pump in sub and 13-5/8" flange began leaking between bottom ram aate 02:30 - 03:30 1.00 WHSUR DECOMP PJSM - re-torque flange bolts on drilling spool. 03:30 - 05:30 2.00 WHSUR DECOMP Attempt to test BOP's, found leak between lower ram gate and drilling spool flange again. 05:30 - 08:30 3.00 WHSUR N WAIT DECOMP PJSM on ND BOP's, ND BOP's at drlg spool to change out ring gasket and inspected ring groove, stopped ND operations, Notify Control room of BOP pick in cellar and pick BOP to inspect flange connections on drilling spool and bottom ram gate. 08:30 - 23:30 15.00 WHSUR N WAIT DECOMP 4hiit rlnwn au riq~erations do to Phase 3 weather conditions winds gusting to 65 knots, PJSM with crew on phase 3 weather conditions, unable to move personnel to or from island 23:30 - 00:00 0.50 WHSUR P DECOMP Pre Spud meeting held for NS-16A, Katie Nitzberg, Paul Hanson with Randy Axness rig crew, Anadrill Directional Drillers, Anadrill MWD, MI Mud engineers, WSL & NAD Toolpusher. 1(24/2008 00:00 - 00:30 0.50 WHSUR P DECOMP Continue Pre Spud meeting held by Katie Nitzberg, Paul Hanson with Randy Axness rig crew, Anadrill Directional Drillers, Anadrill MWD, MI Mud engineers. 00:30 - 01:00 0.50 WHSUR P DECOMP PTSM & Helicopter Travel safety video reviewed. 01:00 - 07:00 6.00 WHSUR N SFAL DECOMP PJSM on ND BOP -Remove iron roughneck floor plate, Master bushings, Drilling riser. Inspect bridge crane lines and seat lifting ring. Notify Control room of BOP pick in cellar and pick BOP to inspect flange connections on drilling spool and bottom ram gate. Shorten studs above drilling spool blind flanges and inspect stud cavities on ram gate. Replace API ring gasket and set stack. 07:00 - 09:00 2.00 WHSUR N SFAL DECOMP NU BOPE -Check torque on all BOP flange bolts. Pull riser adapter and reseal same, reinstall drilling riser. Mobilize casing equipment to the rig floor while re-torque flange bolts. 09:00 - 12:00 3.00 WHSUR N SFAL DECOMP Helicopter Crew change, PJSM - & continue NU BOPE -Install and tighten drilling riser, turnbuckles, center stack, and MU 4.5" test joint. 12:00 - 17:00 5.00 WHSUR N SFAL DECOMP PJSM with all personnel. RU test equipment and test BOPE. Top 3.5" x 6" VBR's HCR & Manual Choke valves Choke Manifold valve #13 Bottoms 3.5" x 6" VBR's Printed: 2/27/2008 2:58:46 PM BP EXPLORATION Operations Summary Report Page 4 of 27 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code' NPT ' Phase Description of Operations 1/24!2008 12:00 - 17:00 5.00 WHSUR N SFAL DECOMP Top Drive Lower well control valve Top Drive Upper well control valve 250 psi low / 5000 psi High Annular preventer 250 psi low 3500 psi High Perform Koomey function test. 17:00 - 18:30 1.50 WHSUR N SFAL DECOMP LD 4.5" Test joint and MU 5" Test joint and install same and RU test equipment. 18:30 - 19:30 1.00 WHSUR N SFAL DECOMP Test Top set 3.5" x 6" VBR's to 250 psi low / 5000 psi High. Failed. Test Bottom 3.5' x 6" VBR's to 250 psi low / 5000 psi High. Passed. 19:30 - 23:00 3.50 WHSUR N 23:00 - 00:00 1.00 WHSUR N 1 /25/2008 00:00 - 04:30 4.50 WHSUR N 04:30 - 06:00 1.50 WHSUR N 06:00 - 09:00 3.00 WHSUR N 09:00 - 11:30 2.50 WHSUR N 11:30 - 18:00 6.50 WHSUR N 18:00 - 21:30 3.50 WHSUR N 21:30 - 23:00 1.50 WHSUR N 23:00 - 00:00 1.00 WHSUR N 1/26/2008 00:00 - 01:30 1.50 WHSUR N 01:30 - 02:30 1.00 WHSUR N 02:30 - 03:30 1.00 WHSUR N SFAL DECOMP PJSM on changing rams -Drain BOP stack open top ram gate bonnets. Inspect rams and replace 3.5" x 6" VBR packer ; SFAL ~ DECOMP ~ RU test equipment, fill stack and test Top set of rams with 5" test joint to 250 psi low / 5000 psi High. Test Failed. SFAL DECOMP PJSM on chan in rams -Drain BOP stack open top ram gate bonnets. Change out top rams to 4-1/2" x 7" VBR's. Close and tighten bonnets. Center BOP stack with rotary. SFAL DECOMP RU test equipment, fill stack and test Top set of rams with 5" test joint to 250 psi low / 5000 psi High. Failed, Could visually, see leak at to of ram block, ossibl wear late SFAL DECOMP PJSM -Pull test joint, drain stack, remove turnbuckles. Open top bonnets and remove and inspect seal plate and gaskets. One minor scratch found on face of seal plate. SFAL DECOMP Install New seal plate and gaskets. Change out rams for 3-1/2" x 6 VBR. Button up bonnets, install turnbuckles and center stack with rotary. SFAL DECOMP Install 5" test joint, RU test equipment and fill stack. Attempt to test top rams, 250 psi held, 5000 psi failed. Trouble shooting r f le k Service surface equipment un-successful in all attempts to obtain high pressure test. SFAL DECOMP PJSM -Pull test joint, drain stack, remove turnbuckles. Open top bonnets and remove and inspect seal plate and gaskets. No damage found on seal plate or gaskets. Change out 3-1/2" x 6" VBR's with New never used set of 3-1/2" x 6" VBR's mobilized from NOC. Close and tighten bonnets. Re-Torque Drilling spool BOP bolts top and bottom. SFAL DECOMP Center stack with rotary. Install 5" test joint, RU test equipment and fill stack. Attempt to test top rams, 250 psi held, 5000 psi. SFAL DECOMP PJSM -Drain stack and blow down test equipment and lines. Pull and LD test joint. SFAL DECOMP PJSM -Remove iron roughneck track, pull master bushings, ND and pull drilling riser to allow better visual inspection of upper ram /seal plate area. SFAL DECOMP PJSM -Install 5" test joint and RU testing equipment. SFAL DECOMP Fill stack and test top 3-1/2" x 6" VBR with 5" test joint to 250 psi low / 5000 psi High. Good test. Bleed off and repeat test. Held. Witness of test by Chris Clemens (WSL ), Brian Tiedemann (NAD Toolpusher ), Randy Axness (NAD Driller ). Printed: 2/27/2008 2:58:46 PM • • BP EXPLORATION Page 5 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date ~ From - To Hours Task Code ~ NPT ' Phase Description of Operations 1/26/2008 02:30 - 03:30 1.00 WHSUR N SFAL DECOMP 03:30 - 05:00 1.50 WHSUR N SFAL DECOMP 05:00 - 06:00 1.00 WHSUR N SFAL DECOMP 06:00 - 08:00 2.00 WHSUR N SFAL DECOMP 08:00 - 09:00 1.00 WHSUR N SFAL DECOMP 09:00 - 10:30 1.50 WHSUR P DECOMP 10:30 - 11:00 0.50 WHSUR P DECOMP 11:00 - 12:00 1.00 WHSUR P DECOMP 12:00 - 14:00 2.00 WHSUR P DECOMP 14:00 - 15:00 1.00 PULL P DECOMP 15:00 - 17:30 2.50 PULL P DECOMP 17:30 - 18:00 0.50 PULL P DECOMP 18:00 - 21:30 I 3.501 PULL I P 21:30 - 00:00 2.50 PULL P 1/27/2008 00:00 - 02:00 2.00 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 07:00 4.00 PULL P 07:00 - 12:00 I 5.001 PULL I P 12:00 - 20:30 I 8.501 PULL I P Witness of test waived by John Chrisp (AOGCC ) RD test equipment and LD 5" test joint. PU and MU 4-1/2" test joint and RU test equipment. Fill stack and ~ttemot to test upper 3-1/2" x 6" VBR's to 250 psi / 5nnn osi. Failed. Test surface equipment. Isolation valves failed on test equipment. Change out two whitey valves on manifold line and test joint line. Test top 3-1/2" x 6" VBR with 4.5" test joint to 250 psi low / 5000 psi High. Good test. Witness of test by Richard Bordes WSL ), Kelly Cozby (NAD Toolpusher ), Randy Axness (NAD Driller ). Witness of test waived by John Chrisp (AOGCC ) Blow down all lines and RD Test equipment. PJSM - NU Drilling riser, install master bushings, iron roughneck track. Wrap wellhead with and herculite and apply steam. PU Test joint with Vetco test dart running tool and recover same. LD test dart, running tool and test jiont. PJSM - MU 6" lubricator extension and install in BOP stack closed on top set of rams and annular preventer. RU DSM lubricator and running tools. PJSM -Test lubricator to 500 psi. Verify IA pressure 0 psi. Pull BPV _Well static. RD DSM lu ricator, an ow own i ine. Clear rig floor of vendors tools. Lower top drive to rig floor and service /warm same -35 Deg temperatures. PJSM - MU 5.875" MCA running tool to double 5" DP and engage tubing hanger with 19 rounds MU. MU top drive and back out lock down studs on tubing hanger. PJSM -Unseat tubino hanger. pulled free 155K PU 2' and DECOMP Displace well to 9.3 ppg brine. Pump 100 bbl 100 deg heated seawater followed by 30 bbl heated Safe-Surf W sweep followed by 941 bbls 9.3 ppg brine all returns sent to G & I for injection. Final circulating rate 7 BPM 500 psi. Shut down and monitor well. Static. DECOMP Drain BOP stack and work tubin han er to ri floor difficult workino hanoer throucth BOP stack due to subsidence wellhead DECOMP Work tubing hanger to rig floor, difficult working hanger through BOP stack due to subsidence wellhead /BOP angle. Re-center BOP stack. Up wt 175k Dn wt 160k DECOMP Terminate control line and fiber optic cable. RU casing tools and LD tubing hanger and DP landing joint. DECOMP PJSM -Work on centering BOP stack with rotary table by skidding rig floor 4" to the west to center rig over wellhead. Secure rig floor to substructure, realign BOP stack, PU all tools. Tubing string now hanging in center of rotary table. DECOMP POH La in down 4.5" Vam Ace 13Cr80 com letion from 11,835' to 10,205' spooling up 971' of TRSV Control line and Fiber Optic cable, Removing control line clamps every joint. DECOMP Continue POH Laying down 4.5" Vam Ace 13Cr80 completion from 10,205' to 5,500' spooling up Fiber Optic cable, Removing control line clamps every joint. Excessive crude /Paraffin build Printed: 2/27/2008 2:58:46 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date i From - To Hours I Task Code i NPT Page 6 of 27 Spud Date: 6/29/2002 Start: 1 /18/2008 End: 3/18/2008 Rig Release: Rig Number: 33E Phase Description of Operations 1/27/2008 12:00 - 20:30 8.50 PULL P DECOMP 20:30 - 21:30 1.00 PULL P DECOMP 21:30 - 00:00 2.50 PULL P DECOMP 1/28/2008 00:00 - 06:30 6.50 PULL P DECOMP 06:30 - 08:30 2.00 PULL P DECOMP 08:30 - 09:00 0.50 WHSUR P DECOMP 09:00 - 10:00 1.00 FISH P DECOMP 10:00 - 13:30 3.50 MOB N SFAL DECOMP 13:30 - 16:DO 2.50 EVAL P DECOMP 16:00 - 23:00 7.00 EVAL P DECOMP 23:00 - 00:00 1.00 DHB P DECOMP 1/29/2008 00:00 - 02:00 2.00 DHB P DECOMP 02:00 - 03:00 1.00 DHB P DECOMP 03:00 - 04:00 1.00 DHB P DECOMP 04:00 - 05:00 1.00 STCTPL P DECOMP 05:00 - 14:00 9.00 STCTPL P DECOMP up on pipe and clamps. Pump 30 bbl 100 deg Safe-Surf W sweep around rr~ 11 BPM, 325 psi to clean tubing string. Continue POH Laying down total of 196 Jts 4.5" Vam Ace 13Cr80 completion from 5,500' to 3,799' spooling up Fiber Optic cable, Removing control line clamps every joint. Pipe much cleaner. POH Laying down 4.5" Vam Ace 13Cr80 completion from 3,799' spooling up Fiber Optic cable, Removing control line clamps every joint. Recovered: 278 Jts 4.5" Vam Ace 13Cr80 Tubing 7 each 4.5" Vam Ace Pup Jts. 1 each cut pup Jt. 1 TRSV assembly 2 GLM assembly 1 HES X Nipple assembly 1 Cidra Gauge Carrier Mandrel 288 Cannon Control Line Clamps 1 Stainless Steel bands. RD casing equipment and clear rig floor of vendors tools. MU running tool on 5" drill pipe and install wear bushing in tubing head. Bushing ID = 8-13/16" PU Baker fishing tools and stage on rig floor.- Mobilize Schlumberger E-Line unit. Pintle hitch on island loader became damaged while moving pipe trailer out of E-line units way. Unable to spot E-line unit. Repair Pintle hitch and spot E-line unit. PJSM - RU Schlumberger E-Line, Load pipe shed with tools, MU 8.5" Gauge Ring /Junk Basket / CCL / GR and RIH to 4 010' & POH. Minimal debris in junk basket. LD gauge ring / junk basket. MU USIT to in tool string and RIH to 4,010' and Log up to surface. Repeat log from 3,700' up to 2,000 and LD USIT tool string. C_ ement stringers from -1,900' to 2,370' TOC -2,370' PJSM - MU HES 9.625" EZSV Bridae Pluo., Continue PJSM - MU HES 9.625" EZSV Bridge Plug &RIH to 3,800' and correlate log up to 3,450'. RIH and PU placing plug Mid Joint Ci? 3,670'. Set Plug @ 3,670', good indication plug set. SO setting tool to confirm set, Plug in place. POH with E-Line LD setting tool & RD Schlumberger, Clear rig floor of vendors tools PJSM - RU and Test 9.625" EZSV CIBP & casing to 2000 psi and record on chart for 30 min. oo est. & ow down test equipment. PJSM - PU and MU BHA #1 Baker 8-1/4" Multi String Cutter with 3-1t2" Knives 1 XO RIH Picking up 5" Drill Pipe 1 x 1, Tag EZSV @ 3,670' with 10k set down weight. Printed: 2/27/2008 2:58:46 PM • • BP EXPLORATION Operations Summary Report Page 7 of 27 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date From - To ; Hours Task ~ Code NPT Phase I Description of Operations 1129/2008 14:00 - 16:00 2.00 STCTPL P DECOMP Monitor hole, Static. POH racking back 39 stands 5" DP. 16:00 - 17:00 1.00 STCTPL P DECOMP MU running tool and pull wear bushing. LD running tool and single DP. 17:00 - 19:00 2.00 MOB P DECOMP Mobilize E-line tools for free point operations and load in pipe shed. 19:00 - 21:30 2.50 STCTPL P DECOMP PJSM - MU side door entry sub to Baker 9.625" spear assembly. Open blind shear rams and drain BOP stack. MU Top drive to spear assembly, RIK and engage A-5/8" r_.acina . 21:30 - 22:30 1.00 STCTPL P DECOMP PJSM - RU Schlumberger E-line unit, hang a-line sheave in derrick and MU free point tool. 22:30 - 23:30 1.00 STCTPL P DECOMP RIH with E-line tool and place on depth ~ 1,800' 23:30 - 00:00 0.50 STCTPL P DECOMP Monitor open OA to bleed trailer in preparation to back out lock down studs on 9-5/8" packoff while installing shock hose on mud line. 1/30/2008 00:00 - 03:00 3.00 STCTPL N RREP DECOMP Continue to Monitor open OA to bleed trailer in preparation to back out lock down studs on 9-5/8" packoff while installing shock hose on mud line. Shock hose split while installing. 03:00 - 04:30 1.50 STCTPL N RREP DECOMP Continue to Monitor open OA to bleed trailer, discuss options with rig team on free pointing while mobilizing back up hose. 04:30 - 08:00 3.50 STCTPL P DECOMP PJSM -with all personnel on free point operations. Back out 9-5/8" pack off lock down studs and unseat casing hanger with 300k ull unto 450k, approximately 2.5" pipe stretch. Repeat ;e point tools up to 1,0 e inconclusive results. 08:00 - 09:00 1.00 STCTPL P DECOMP Consult with Anchorage rig team on forward plan. Decision e to make first cut ~ -1,915' 09:00 - 11:00 2.00 STCTPL P DECOMP POH with a-line tool-string, LD tools, RD a-line. Release spear, LD side-door entry sub, double DP and spear. Clear rig floor of vendor's tools. 11:00 - 12:00 1.00 STCTPL P DECOMP MU BHA #3 Baker 9.625" Multi-String Cutter. 12:00 - 14:00 2.00 STCTPL P DECOMP RIH slow to 800', knifes catching on casing collars on trip in. 14:00 - 14:30 0.50 STCTPL P DECOMP Pressure test new mud line shock hose to 250 psi / 3500 psi. Good Test. 14:30 - 16:00 1.50 STCTPL P DECOMP Continue to RIH from 800' to 1,889' with multi-string cutter. Obtain SPR #1 MP = 1.5 BPM 113 PSI ! 2.5 BPM 155 PSl. 16:00 - 17:00 1.00 STCTPL P DECOMP PJSM on cutting casing. MU top drive, Obtain up and down weights, up / do / rt 82k, pump at 3.5 BPM to open cutters and SO, locate collar at 1,918'. pU 2' to place cutters at 1,916'. 1 Bring pump rate up to 5 BPM / 550 PSI, 70 RPM's , 2k TO. Good indication of cut by casin / ri 'um and pressure dro . 17:00 - 18:00 1.00 STCTPL P DECOMP ~ Shut down pumping and investigate leak in cellar. Notified on site ACS Environmental Tech, OIM and Town DE. 1/2 gallon of diesel released from needle valve on OA on to secondary containment. Clean up with absorb and placed into oily waste bags for disposal. 18:00 - 22:30 4.50 STCTPL P DECOMP PJSM on circ out diesel. RU cellar lines from OA to choke, Open up OA to closed choke 240 psi. Crack open choke and pump 100 bbl 100 deg 9.3 ppg brine down the DP and establish displacement rate of 1.5 bpm maintaining fluid level in Printed: 2/2712008 2:58:46 PM BP EXPLORATION Page 8 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date From - To Hours I Task ~ Code i NPT I Spud Date: 6/29/2002 Start: 1 /18/2008 End: 3/18/2008 Rig Release: Rig Number: 33E Phase Description of Operations 1/30/2008 18:00 - 22:30 4.50 STCTPL P DECOMP IA taking returns to the trip tank, shipping diesel to G & I for injection. ~ 94 bbls close annular preventer and pump 30 bbl viscous SafeSurf-O sweep followed by 160 bbls heated 9.3 ppg brine, at 130 bbls clean brine returns observed, switch to active system and increase pump rate to 5 bpm 500 psi DP / 50 psi Csg, overboard sweep down drag chain to G & I. Shut down open well and monitor. Well static. RD and blow down circulating equipment /clean diesel out of trip tank. 22:30 - 00:00 1.50 STCTPL P DECOMP POH with BHA #3 to pull casing. 1/31!2008 00:00 - 01:00 1.00 STCTPL P DECOMP LD BHA #3 01:00 - 02:00 1.00 STCTPL P DECOMP PJSM -Drain stack, MU running tool and pull wear bushing, LD running tool. 02:00 - 04:00 2.00 BOPSU P DECOMP PJSM - Chanae out top set of rams to 9-5/8" 04:00 - 06:00 2.00 BOPSU P DECOMP PJSM - MU 9-5/8" Test joint & RU Test equipment and test Rams to 250 psi low / 3500 psi high. RD blow down test equipment. Witness of test by R. Bordes / C. Clemens (WSL), B. Bixby / B. Tiedemann (NAD Toolpusher). 06:00 - 07:00 1.00 FISH P DECOMP PJSM - MU BHA #4 9-5/8" casing spear RIH and engage fish at wellhead 07:00 - 07:30 0.50 WHSUR P DECOMP Check OA pressure 0 psi. Back out lock down studs on 9-5/8" packoff. 07:30 - 08:00 0.50 FISH P DECOMP Unseat casing string /hanger with 140k and pull casing hanger to ri floor. Release spear and LD BHA #4. 08:00 - 12:00 4.00 FISH P DECOMP RU casing tools, LD casing hanger & pup jt. POH LD 9-5/8" Casing from cut @ 1,916' to 1,412'. 12:00 - 15:30 3.50 FISH P DECOMP Continue POH laying down 9-5/8" Casing. Recovered: Csg Hanger& Pup Jt. 44 Full Joints 1 Cut Jt. 40.25'. Total = 45 Joints 9-5/8" #47 L-80 BTC-M casing Slight traces of cement on joints # 43, 44, & 45 three feet off the pin end. 15:30 - 16:00 0.50 FISH P DECOMP RD casing tools, Clean and clear rig floor 16:00 - 16:30 0.50 FISH P DECOMP MU BHA #5, 9-5/8" ITCO casing spear / XO /Single 5" DP. 16:30 - 19:30 3.00 FISH P DECOMP RIH to 1,824' took 10k drag over normal down wt. Cad 1,814' Up Wt. 80k / Dn Wt. 85k. 19:30 - 20:00 0.50 FISH P DECOMP Break circulation and clear drill pipe prior to engaging fish. Blow down top drive and mud line. 20:00 - 21:00 1.00 STCTPL P DECOMP PJSM - MU sidedoor entry sub to drill string, SO and engage fish C~ 1,916'. Pull 200k to verify spear set and SO to neutral wt. 21:00 - 22:30 1.50 STCTPL P DECOMP PJSM - RU Schlumberger a-line and MU Free point tool and RIH to 1,990'. 22:30 - 00:00 1.50 STCTPL P DECOMP Calibrate FPIT and check Stations working pipe between 80k up to 230k 2/1/2008 00:00 - 04:30 4.50 STCTPL P DECOMP Pull up to 1,990' and recalibrate tool and Continue to free point stations as follows, working pipe between 60k up to 230k 1,990' Free 100% 2,030' Free 99% 2.598' Stuck 100% Printed: 2/27/2008 2:58:46 PM BP EXPLORATION Operations Summary Report Page 9 of 27 Legal Well Name: N516 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date j From - To Hours ~ Task Code NPT % Phase ~, Description of Operations 2/1/2008 00:00 - 04:30 04:30 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 10:15 10:15 - 11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 00:00 4.50 STCTPL P DECOMP 2,308' Free 82% 2,438' Free 31 2,352' Free 80% 2,397' Free 30% 1.50 STCTPL P DECOMP POH & LD free point tool string & RD E-Line, Release spear and LD side-door entry sub. 1.00 FISH P DECOMP POH - 10 stands to 975' 1.00 FISH P DECOMP Circulate -Run #1 & 2 mud pumps to check loping problem with #2 and check calibration of stroke counters, GPM, Flow show on EPOCH. 1.50 FISH P DECOMP Cont' POH to BHA. 0.75 FISH P DECOMP LD BHA #5 Spear assembly, Change out knifes on multi string cutter. 1.25 WHSUR P DECOMP MU running tool and install wear bushing, LD running tool. Wear bushing ID 12-5/16" 0.50 STCTPL P DECOMP PJSM - MU BHA #6 Baker 9.625" Multi-String Cutter. 1.50 STCTPL P DECOMP RIH to 2,361' -Obtain SPR's #2 MP - 2 bpm = 92 psi. 3bpm = 189 psi w/ 9.3 ppg brine. Establish parameters, Up Wt. 90k / Dn Wt. 93k, Pump 211 gpm, 235 psi, S/O and locate collar ~ 2,371' and set down w/ 10k to verify: PU 2' to place cutter (~ 2,369'. 0.501 STCTPL I P 1.001 STCTPL I P 1.001 STCTPL ~ P 0.5011 STCTPL P 3.50 FISH P 2.00 FISH P 0.50 FISH P 1.501 FISH I P 212!2008 100:00 - 00:30 I 0.501 FISH I P 00:30 - 03:00 2.50 FISH P 03:00 - 04:00 1.00 FISH P 04:00 - 05:30 1.50 FISH P 05:30 - 06:00 0.50 FISH P 06:00 - 08:00 2.00 FISH P DECOMP Start cutting operations, 211 gpm 1585 psi 170 rpm ! 2-3k Tq J pressure increased to 605 psi, observed pressure drop to 553 psi, and increase in torque. Stop rotary and PU 10k over-pull. DECOMP CBU 420 gpm / 2107 psi, Monitor well, Static. Fluid Wt in and out 9.3 ppg. DECOMP POH with BHA #6 DECOMP LD Cutting BHA #6, Clean and clear rig floor DECOMP MU Fishing BHA #7 - Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub /Bumper Sub !Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier DECOMP RIH from 322' to 1,857' DECOMP Establish parameters, Up Wt 97k / Dn Wt 100k, SO and engage fish l~ 1,916 and swallow spear up to stop sub / PU 3', Fish free ~ 118K Up Wt, establish circulation. DECOMP Ramp pumps up to 888 gpm, 1067 psi, &CBU fine sand cement after 1.5 bottoms up increasing to larger pebble sized up to 2.5" rock sized soft cement chunks, mix and pump 30 bbl Duovis sweep around and continue to circulate until well cleaned up. DECOMP Monitor well, Static. Rack back 1 stand DP and Blow down top drive and mud line. Fluid Wt in and out 9.3 ppg. DECOMP POH with 9-5/8" casing fish on 5" DP to BHA DECOMP LD Intensifier, Stand back 3 stands of DC's DECOMP Release spear from fish, LD remainder of fishing BHA #7 DECOMP PJSM - RU 9-5/8" Casing tools DECOMP POH LD 453' of 9-518" 47# L-80 BTC-M casing. No residual cement on casing joints. RD casing tools. Recovered: 2' Stub 10 Full Joints Printed: 2/27/2008 2:58:46 PM BP EXPLORATION Page 10 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date ~ From - To Hours Task I Code i NPT it Phase I! Description of Operations 2/2/2008 06:00 - 08:00 2.00 FISH P DECOM 1 Cut Joint = 39.91' 11 joints for this run. Total Recovered from well = 56 Jts. 08:00 - 09:00 1.00 FISH P DECOMP Service Top Drive, Blocks & Crown, Draw works. 09:00 - 10:00 1.00 STCTPL P DECOMP Clean & Clear rig floor, Change out knifes on multi-string cutter. 10:00 - 10:30 0.50 STCTPL P DECOMP PJSM - MU BHA #8 Baker 9-5/8"" Multi-String Cutter. 10:30 - 12:30 2.00 STCTPL P DECOMP RIH with MSC on 5" DP to 1,224' 12:30 - 14:00 1.50 STCTPL N RREP DECOMP Iron Roughneck hydraulic cylinder failure f RU floor tools to continue to RIH while trouble shooting Iron Roughneck. 14:00 - 15:00 1.00 STCTPL P DECOMP Cont' RIH from 1,224' to 2,440' 15:00 - 15:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 90k / Dn Wt. 92k, Pump 131 gpm, 220 psi, S/O and locate collar C~ 2,451' and set down w/ 10k to verify. PU 2' to place cutter C~ 2,449'. Start cutting operations, 210 gpm / 585 psi / 70 rpm / 2-3k Tq / observed pressure drop to 489 psi, and increase in torque. 15:30 - 16:00 0.50 STCTPL P DECOMP CBU - 398 gpm / 1,685 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Blow down top drive /mud line. 16:00 - 19:30 3.50 STCTPL P DECOMP POH from 2,449' to BHA using chain tongs. 19:30 - 20:00 0.50 STCTPL P DECOMP LD cutting BHA #8 & Clear rig floor 20:00 - 23:30 3.50 BOPSU P DECOMP PJSM - MU BOP flushing tool and wash out stack. Blow down top drive. Pull wear bushing. MU 5" test joint to test plug and install floor safety valve and IBOP. RU test equipment and fill BOP stack with water. 23:30 - 00:00 0.50 BOPSU P DECOMP Test BOPE as er BP / AOGCC Re ulations to 250 si low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of test waived by Chuck Sheeve (AOGCC State Inspector). Test witnessed by Chris Clemens (WSL), Brian Tiedemann (NAD Toolpusher), Randy Axness (NAD Driller). Test as follows with 5" Test Joint. #1) Annular 250 psi / 3500 psi. 2/3(2008 00:00 - 06:00 6.00 BOPSU P DECOMP Continue to Test BOPE as follows with 5" Test Joint: #2) Bottom 3.5" x 6" VBR 250 psi / 5000 psi. / IBOP #3) Floor Safety Valve #4) Lower Well Control Valve #5) Upper Well Control Valve Function Test Accumulator #6) Blind Shear Rams /Kill HCR /Choke Valve #8 - 9 - 11 #7) Choke Valve #9 -12 (Choke Valve # 12 Failed) 06:00 - 06:30 0.50 BOPSU P DECOMP Drain BOP stack, blow down all lines and test equipment to change out top set of rams to 3.5" x 6" VBR's while repairing #12 Choke manifold valve. 06:30 - 08:30 2.00 BOPSU P DECOMP Change Top set of rams to 3.5" x 6" VBR's, Rebuild #12 Choke manifold valve while changing out rams. 08:30 - 09:30 1.00 BOPSU P DECOMP Install 5" test joint and RU test equipment. 09:30 - 12:30 3.00 BOPSU N DECOMP Continue to Test BOPE as follows with 5" Test Joint: #8) Top Rams 3.5" x 6" VBR 250 psi / 5000 psi. / IBOP #9) Choke Valve # 9-12-13 #10) Choke Valve # 8-11 #11) Choke Valve # 4-7-10 Printed: 2/27/2008 2:58:46 PM BP EXPLORATION Page 11 of 27 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: I' From - To I NS16 NS16 REENTE NABOB NABOB Hours R+COM S ALASK S 33E ~ Task PLET A DRI Code ~ E LLING NPT Start I Rig Rig ~ Phase Spud Date: 6/29/2002 : 1/18/2008 End: 3/18/2008 Release: Number: 33E Description of Operations 2/3/2008 09:30 - 12:30 3.00 BOPSU N DECOMP #12) Manual Kill Valve /Choke Valve #3-5-6 #13) Choke Valve #1 #14) Choke Valve #2 #15) Choke HCR Valve #16) Manual Choke Valve Witness of test by Richard Bordes (WSL), Bill Bixby (NAD Toolpusher), Sean Holcomb (NAD Driller) 12:30 - 13:30 1.00 WHSUR P DECOMP RD Test equipment and blow down all lines, Install wear bushing. ID = 12-5116" 13:30 - 16:00 2.50 FISH P DECOMP MU Fishing BHA #9 - Bull Nose /Packoff / ITCO Spear w/ 8.861 grapple !Extension 1 Stop sub f Bumper Sub /Oil Jar XO / 9 x 6-1/4" DC's / XO /Intensifier &RIH to 405' 16:00 - 18:00 2.00 FISH P DECOMP Rig Morale f Team Building Meeting with Sean Holcomb's Crew / Day and Night WSL's, Toolpushers /Mud Engineers. 18:00 - 19:00 1.00 FISH P DECOMP RIH from 405' to 2302' 19:00 - 19:30 0.50 FISH P DECOMP Establish parameters, Up Wt 103k / Dn Wt 103k, SO and en a e fish ~ 2 369 and swallow spear up to stop sub / PU 3', Fish free ~ 110K Up Wt, establish circulation without problem. 19:30 - 21:00 1.50 FISH P DECOMP CBU with 35 bbl high vis sweep with 930 gpm / 1180 psi. while reciprocating pipe, Sweep brought up moderate amount of contaminated cement and continued to increase, pumped second 35bb1 high vis sweep around, hole unloaded large chunks of soft rock sized cement up to 3" in length and cleaned up after another bottoms up. Fluid Wt in and out 9.3 ppg. 21:00 - 22:00 1.00 FISH P DECOMP Monitor Well, Static. POH with fish from 2,449' to BHA 9# 22:00 - 00:00 2.00 FISH P DECOMP LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #9 2/4/2008 00:00 - 01:00 1.00 FISH P DECOMP PJSM - RU 9-518" Casing tools & POH LD 80' of 9-518" 47# L-80 BTC-M casing. Residual cement on Jt #57 and Jt #58 was clean.RD casing tools. Recovered: 1.3' Stub 1 Full Joints 1 Cut Joint = 40.40' 2 joints for this run. Total Recovered from well = 58 Jts. 01:00 - 01:30 0.50 STCTPL P DECOMP PJSM -Change Knifes & MU BHA # 0 Baker 9-5/8" Multi-String Cutter. 01:30 - 02:00 0.50 STCTPL P DECOMP RIH with MSC to 1,135' 02:00 - 03:00 1.00 STCTPL P DECOMP Service Top Drive, Blocks, Crown & Draw works. 03:00 - 05:00 2.00 STCTPL P DECOMP RIH with MSC from 1,135' to 2,610' 05:00 - 05:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 95k / Dn Wt. 95k, Pump 130 9Pm, 198 psi, S/O and locate collar @ 2,613' and set down w/ 10k to verify. ni ~ ro a-. -.~..,.,. -...u-.. ca n c~ ~~ Start cutting operations, 211 gpm / 600 psi / 70 rpm / 2-3k Tq / observed pressure drop to 483 psi, and increase in torque. 05:30 - 06:30 1.00 STCTPL P DECOMP CBU - 398 gpm / 1,685 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. 06:30 - 08:30 2.00 STCTPL P DECOMP POH with MSC BHA #10 Remove knife blades and LD same. 08:30 - 10:00 1.50 FISH P DECOMP PJSM -Redress 9-518° Spear and MU BHA #11 Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub / Printed: 2/27/2006 2:58:46 PM BP EXPLORATION Page 12 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTE R+COM PLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABOB S ALAS KA DRILLING I Rig Release: Rig Name: NABOB S 33E Rig Number: 33E Date From - To Hours Task ~ Code NPT Phase Description of Operations 2/4/2008 08:30 - 10:00 1.50 FISH P DECOMP Bumper Sub /Oil Jar! XO 19 x 6-1/4" DC's f XO f Intensifier. 322', Blow down kill line. 10:00 - 11:30 1.50 FISH P DECOMP RIH from 322' to 2,396' 11:30 - 12:00 0.50 FISH P DECOMP Establish parameters, Up Wt 105k / Dn Wt 105k, SO and en a e i 449 and swallow spear up to stop sub, Pull 200K and hit jar, PU to 250k Up Wt, establish circulation without problem 940 gpm / 1170 psi. Repeat several times and casing pulled free with 115k 12:00 - 13:00 1.00 FISH P DECOMP Pump two 40 bbl high vis sweeps back to back pumping 940 gpm / 950 psi while reciprocating pipe until hole cleaned up. Large amounts of cement chunks to surface. Monitor well, Static. Blow down top drive and mud line. Fluid Wt. in and out 9.3 pP9• 13:00 - 14;00 1.00 FISH P DECOMP POH with fish to BHA #11 14:00 - 15:30 1.50 FISH P DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #11 15:30 - 17:00 1.50 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 162' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jts #59 and Jt #62. RD casing tools. Recovered: 1.6' Stub 3 Full Joints 1 Cut Joint = 38.06' 4 joints for this run. Total Recovered from w I = 62 Jts. 17:00 - 17:30 0.50 STCTPL P DECOMP PJSM - MU BHA #12 Baker 9-5/8" Multi-String Cutter. 17:30 - 19:00 1.50 STCTPL P DECOMP RIH to 3,207' and MU TDS 19:00 - 20:00 1.00 STCTPL P DECOMP Obtain SPR's w/ #2 MP 2 bpm = 75 psi / 3 bpm = 170 psi. Establish parameters, Up Wt. 108k / Dn Wt. i04k, Rt Wt. 105k Pump 130 gpm, 190 psi, S/O and locate collar C~ 3,237' and set down w/ 10k to verify. Start cutting operations, 211 gpm / 558 psi / 70 rpm / 2-3k Tq / observed pressure drop to 493 psi, and increase in torque. 20:00 - 21:00 1.00 STCTPL P DECOMP CBU - 419 gpm / 1,885 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. 21:00 - 23:00 2.00 STCTPL P DECOMP POH with MSC BHA #12 and LD same. 23:00 - 00:00 1.00 FISH P DECOMP PJSM - PU 9-5/8" Spear and change out packoff. 00:00 - 01:30 1.50 FISH P DECOMP Change out packoff and RIH with remainder of BHA #13) 9 x 6-1/4" DC's / XO /Intensifier to 322'. 01:30 - 03:30 2.00 F1SH P DECOMP R1H from 322' to 2,585' 03:30 - 05:30 2.00 FISH P DECOMP Establish parameters, Up Wt 110k / Dn Wt 105k, SO and engage fish C~ 2,611' and swallow spear up to stop sub, Pull 250K and hit jar, PU to 250k Up Wt, break circulation 84 gpm / 400 psi. Start Jarring Up with 250k pulling up to 250k while staging pump rate up to 700 gpm 2000 psi, Increase Jar & pull to 270k. Increase Jar to 300k & pull up to 350k, pump 35 bbl high vis sweep and increase pump rate to 780 gpm 1900 psi. Increase pump rate to 914 gpm, jar with 300k and pull to 400k. Jarred free to 3,235'. 05:30 - 07:30 2.00 FISH P DECOMP Reciprocate pipe and wash back down to stub at 3,235'. Pump 2 x 35 bbl high vis sweep around at 926 gpm / 1250 psi. Printed: 2/27/2008 2:58:46 PM r~ u BP EXPLORATION Page 13 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E I i Date I From - To Hours i Task Code i NPT 2/5/2008 05:30 - 07:30 07:30 - 10:30 10:30 - 11:00 11:00 - 14:30 2.00 FISH ~ P 3.00 I FISH I P 0.50 I FISH I P 3.50 {FISH I P 14:30 - 16:30 2.00 STCTPL P 16:30 - 17:00 0.50 STCTPL P 17:00 - 18:00 1.00 STCTPL P 18:00 - 20:30 20:30 - 22:30 2/6/2008 22:30 - 00:00 00:00 - 02:00 2.50 STCTPL P 2.00 STCTPL P 1.50 STCTPL P 2.00 FISH P 02:00 - 04:00 I 2.001 FISH I P 04:00 - 05:00 1.00 FISH N 05:00 - 06:30 1.50 FISH P 06:30 - 09:00 2.50 FISH P 09:00 - 10:00 1.00 FISH SFAL Spud Date: 6/29/2002 Start: 1/18/2008 End: 3/1 812 0 0 8 Rig Release: Rig Number: 33E Phase I Description of Operations I DECOMP Followed by 1 x 80 bbl high vis sweep. Continue to circulate until hole cleaned up. Monitor well, Static, Fluid Wt in and out 9.3 Pp9• DECOMP Blow down TDS & Mud line, POH with fish from 3,235' to BHA #13 DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #13 DECOMP PJSM - RU 9-518" Casing tools & POH LD 162' of 9-518" 47# L-80 BTC-M casing. Residual cement on Jts #63 - Jt #77. RD casing tools. Clean and Clear Rig Floor. Recovered: 1.11' Stub 14 Full Joints 1 Cut Joint = 40.47' 15 joints for this run. Total Recovered from well = 77 Jts. DECOM PJSM - MU BHA #14 Baker 9-5/8" Multi-String Cutter &RIH to 3,450' DECOMP Establish parameters, Up Wt. 112k / Dn Wt. 105k, Pump 130 gpm, 200 psi, S/O and locate collar ~ 3,487' and set down w/ 10k to verify. PU 2' to place cutter C~3 3,485'. DECOMP POH with fish from 3,485' to BHA #15 DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release Start cutting operations, 211 gpm / 660 psi / 70 rpm / 2-3k Tq / observed pressure drop to 565 psi, and increase in torque. DECOMP CBU - 419 gpm / 1,866 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. DECOMP POH from 3,485' with MSC BHA #14 and LD same. DECOMP PJSM -Redress 9-5/8" Spear and MU BHA #15 Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub / Bumper Sub / PU New Oil Jar / XO / 9 x 6-1/4" DC's / XO / Intensifier. 322'. DECOMP RIH, to 3,184', PU 1 single DP & MU TDS DECOMP Establish parameters, Up Wt 125k / Dn Wt 112k, SO and en a e fish ~ 3 235' and swallow spear up to stop sub, Pull 150K and attempt to break circulation without success, Hold 1000 psi, PU 250K and hit jar, Pull to 300k Up Wt, Start Jarring Up with 250k pulling up to 300k while holding 1000 psi, Increase Jar to 300k & pull up to 400k holding 1500 psi. -30 deg ambient temp. Bleed off pressure and Circulate surface equipment every 45 min. Jarred Free. DECOMP Work fish up the hole to 3,395' trying to establish circulation. Break circulation and stage pump rate up to 905 gpm f 950 psi. Reciprocate pipe 30' & CBU x 2. Large amounts of contaminated cement back. DECOMP Circulate while trouble shooting electrical problem. DECOMP Wash back down to top of the stub C~ 3,485' &CBU with sweep until hole cleans up 914 gpm / 900 psi. Monitor well, Static. Fluid Wt in and aut 9.3 ppg. Blow down TDS and mud line. spear from fish, LD remainder of fishing BHA #15 Printed: 2/27/2008 2:58:46 PM • • BP EXPLORATION Page 14 of 27 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1h8I2008 End: 3/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 33E Rig Number: 33E Date II From - To i Hours ~ Task ~ Code ~ NPT II Phase Description of Operations 2/6/2008 10:00 - 12:00 2.00 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 250' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jts #78 - Jt #83. RD casing tools. Clean and Clear Rig Floor. Recovered: 1.23' Stub 5 Full Joints 1 Cut Joint = 40.70' 6 joints for this run. Total Recovered from well = 83 Jts. 12:00 - 12:30 0.50 FISH P DECOMP Clean and clear rig floor 12:30 - 13:00 0.50 STCTPL P DECOMP PJSM - MU BHA #16 Baker 9-5/8" Multi-String Cutter 13:00 - 15:00 2.00 STCTPL P DECOMP RIH to 3,586' 15:00 - 15:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 118k / Dn Wt. 105k, Pump 130 9Pm, 200 psi, S/O to locate collar ~ 3,609' took Wt @ 3,605'. PU to place Start cutting operations, 211 gpm / 675 psi / 70 rpm / 4.5k Tq / observed pressure drop to 550 psi, and increase in torque then drop to 2.8k. SO 10k to verify cut. SPR- #2 MP) 2 bpm = 100 psi / 3 bpm = 180 psi. 15:30 - 16:30 1.00 STCTPL P DECOMP CBU - 419 gpm / 1919 psi. Monitor well, Static. Blow down TDS and mud line. Fluid WT in and out 9.3 ppg. ~ 16:30 - 18:30 2.00 STCTPL P DECOMP POH with MSC BHA #16 18:30 - 19:00 0.50 STCTPL P DECOMP Make service breaks and LD BHA #16 19:00 - 20:30 1.50 FISH P DECOMP MU Fishing BHA #17 - Bull Nose I Packoff I ITCO Spear w/ 8.861 grapple /Extension /Stop sub /Bumper Sub /Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier 20:30 - 21:30 1.00 FISH P DECOMP RIH -from 322' to 3,433' 21:30 - 22:00 0.50 FISH P DECOMP MU TDS and CBU C~ 900 gpm / 985 psi ~ 3,487' 22:00 - 00:00 2.00 FISH P DECOMP Establish parameters, Up Wt 130k / Dn Wt 115k, SO and en a e fish C~? 3,485' and swallow spear up to stop sub, Pull 200K and attempt to break circulation without success, Hold 500 psi, PU 250K and hit jar, Pull to 300k Up Wt, Start Jarring Up with 250k pulling up to 300k while holding 500 psi, Increase Jar to 300k & pull up to 400k holding 600 - 700psi. -30 deg ambient temp. Break connection every 45 minutes and circulate surface equipment for 5 minutes. 2/7/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue -Jar to 300k & pull up to 415k holding 600 - 700psi. -30 deg ambient temp. Break connection every 45 minutes and circulate surface equipment for 5 minutes. In'ection rate established ~ 690 psi. 8 spm. Total of 16 bbls of fluid loss to formation w i e iarrmg. 02:30 - 03:30 1.00 FISH P DECOMP Release spear from fish. 03:30 - 04:00 0.50 FISH P DECOMP CBU with 918 gpm 945 psi. Monitor well. Static. Fluid Wt in and out 9.3 ppg. Blow down TDS & mud line. 04:00 - 06:30 2.50 FISH P DECOMP POH with BHA #17 for 13-3/8" clean out assembly 06:30 - 07:30 1.00 FISH P DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #17 07:30 - 08:00 0.50 STWHIP P DECOMP Clean and clear rig floor of vendors tools. 08:00 - 09:30 1.50 STWHIP P DECOMP MU Clean out BHA #18 - 12-1l4" Bit f 13-3/8" Scrapper! Sit Sub/XO/Bumper Sub/Jar/XO/9xDC's/XO/ 09:30 - 10:30 1.00 STWHIP P DECOMP RIH from 305'to 1,248' 10:30 - 11:30 1.00 STWHIP P DECOMP Service TDS, Blocks, Crown and Draw Works Printed: 2/27/2008 2:58:46 PM BP EXPLORATION Page 15 of 27 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: ~~ From - To I NS16 NS16 REENTE NABOB NABOB Hours R+COM S ALAS S 33E I Task PLET KA DRI ~I Code E LLING ~i NPT Start I Rig Rig I Phase Spud Date: 6/29/2002 : 1/18/2008 End: 3/18/2008 Release: Number: 33E Description of Operations 2/712008 11:30 - 13:00 1.50 STWHIP P DECOMP RIH from 1,248'to 3,416' MU TDS, Break circulation and wash down to casin stub C~3 3,485'. Up Wt 132k /Down Wt. 116k 13:00 - 14:00 1.00 STWHIP P DECOMP Pump 50 bbl High Vis Sweep around ~ 900 gpm / 1570 psi. Monitor well, Static. Blow down TDS and mud lines. Fluid Wt in and out 9.3 ppg. 14:00 - 16:00 2.00 STWHIP P DECOMP POH from 3,485' to BHA #18 C~? 305'. 16:00 - 18:30 2.50 STWHIP P DECOMP LD -BHA #18. 18:30 - 19:00 0.50 STWHIP P DECOMP Clean and clear rig floor of vendors tools. 19:00 - 20:00 1.00 EVAL P DECOMP PJSM - RU Schlumberger E-line and MU CCL 1 GR tools. 20:00 - 22:30 2.50 EVAL P DECOMP RIH with E-Line to 3,560' and Log up to surface. 22:30 - 23:30 1.00 EVAL P DECOMP RD SWS. 23:30 - 00:00 0.50 ZONISO P DECOMP PJSM - MU 13-3/8" EZSV CIBP Running tool and make dummy run through BOP and well head to 80'. 2/8/2008 00:00 - 03:30 3.50 ZONISO P DECOMP MU 13-3/8" EZSV CIBP To running tool &RIH on 5" DP. 03:30 - 04:00 0.50 ZONISO P DECOMP MU TDS Up Wt. 110k / Dn Wt. 100k circulate 80 bbls 70 deg fluid around EZSV to warm up prior to setting at 3 bpm / 55 psi. PU to place top of the 13-3/8" CIBP 5' above casing collar ~ 3,287' Rotate 36 turns, PU 20k and pause 2 min / PU 10k, pause 2 min / PU 10k, pause 2 min / PU 10k, pause 2 min / PU 10k and shear off plug with 170k. Rotate 20 turns to retract mandrel, SO & weight check plug with 25k. ~ TOP of the lu set C~ 3,282' 04:00 - 05:00 1.00 ZONISO P DECOMP RU and test EZSV to 1000 psi for 10 min. 29 strokes. Test d. RD & blow down test equipment. 05:00 - 09:00 4.00 STWHIP P DECOMP POH laying down 5" DP. 09:00 - 10:00 1.00 STWHIP P DECOMP LD EZSV running tool and clean /clear rig floor of vendors tools. 10:00 - 10:30 0.50 STWHIP P DECOMP RIH with remaining DP from derrick to 479' 10:30 - 11:30 1.00 STWHIP P DECOMP POH laying down DP 11:30 - 12:30 1.00 STWHIP P DECOMP Clear rig floor. Off load drill pipe out of pipe shed. 12:30 - 20:30 8.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, -3,025' 20:30 - 23:00 2.50 STWHIP P DECOMP PJSM -Slip and cut 132' of drilling line. Function test crown-o-matic. 23:00 - 00:00 1.00 STWHIP P DECOMP POH racking back 20 stands 5" DP 2/9!2008 00:00 - 01:00 i.00 STWHIP P DECOMP POH racking back 12 stands 5" DP 01:00 - 07:00 6.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, -3,025' 07:00 - 08:30 1.50 STWHIP P DECOMP POH racking back 32 stands 5" DP 08:30 - 14:00 5.50 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, -3,025' 14:00 - 15:30 1.50 STWHIP P DECOMP POH racking back 32 stands 5" DP 15:30 - 16:30 1.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 15 Jts, -472' 16:30 - 17:00 0.50 STWHIP P DECOMP POH racking back 5 stands 5" DP 17:00 - 17:30 0.50 STWHIP P DECOMP Clean & clear rig floor and ready tool for mill BHA #19 17:30 - 18:00 0.50 STWHIP DECOMP PJSM on picking up milling assembly / BHA #19 18:00 - 21:00 3.00 STWHIP P DECOMP PU & MU Whipstock Mill Assembly BHA #19 -Starter Mill /Bit Sub /Flex Jt. /Upper Mill / XO / 1 x HWDP / XO /Bumper Sub / Flt Sub /MWD / UBHO /Orient MWD & UBHO Sub to starter Printed: 2/2712008 2:58:46 PM r BP EXPLORATION Page 16 of 27 Operations Summary Report ~!z, Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/18/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date j From - To ~ Hours it Task ; Code i NPT j Phase ~ Description of Operations 2/9/2008 18:00 - 21:00 3.00 STWHIP P DECOMP mill. 21:00 - 00:00 3.00 STWHIP P DECOMP Cont' RIH PU - 6 x 8" DC's / XO / 21 x HWDP 2/10/2008 00:00 - 02:30 2.50 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 27 Jts, 1,786' 02:30 - 03:00 0.50 STWHIP P DECOMP D-1 Drill & secure well. Safety meeting discussing D-6 stripping drill and D-5 well kill drill. 03:00 - 05:00 2.00 STWHIP P DECOMP Install IBOP Pressure up to 200 psi & Perform D-6 stripping drill, Strip in the hole picking up singles from the pipe shed maintaining 200 psi on choke. Perform D-5 well kill drill, pumping ~ 3 bpm holding 240 psi. back pressure, allowing hands to become accustom to bringing up pumps to kill rate and choke operations. 05:00 - 05:30 0.50 STWHIP P DECOMP Bleed off pressure, POH to IBOP & floor safety valve, LD same. Blow down TDS and all surface equipment. 05:30 - 08:00 2.50 STWHIP P DECOMP Cont' RIH from 1,786' to 3,220' Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 08:00 - 09:00 1.00 STWHIP P DECOMP MU TDS, Wash down and tag EZSV CIBP W/ 15k ~ 3,282' & CBU Up Wt: 150k / Dn Wt: 130 / 620 gpm / 560 psi Monitor Well, Static. Fluid Wt in and out 9.3 ppg 09:00 - 11:00 2.00 STWHIP P DECOMP POH from 3,282' to BHA 11:00 - 12:00 1.00 STWHIP P DECOMP POH stand back HWDP & DC's 12:00 - 14:30 2.50 STWHIP P WEXIT PJSM - PU and MU BHA #20) 13-3/8" whipstock slide to starter mill assembly &RIH with DC's &HWDP to 954' 14:30 - 16:00 1.50 STWHIP P WEXIT RIH from 954'to 3,249' 16:00 - 16:30 0.50 STWHIP P WEXIT MU TDS and establish parameters / Up Wt 155k / Dn Wt 129k / 702 gpm / 765 psi. Orient whipstock 21 deg LHS. SO, tag CIBP & set bottom trip anchor with 26K, PU to 170k & verify anchor set. SO and shear off of whipstock with 60k. TOW = 3,250' BOW = 3,274' 16:30 - 18:00 1.50 STWHIP P WEXIT Displace well -Pump 50 bbl high vis sweep followed by 446 bbls 8.8 ppg LSND milling fluid Vis 77 / YP 33 C~ 939 gpm / 303 psi, rate adjusted as per G & I. Obtain SPR's #1 MP 2 bpm = 90 psi / 3 bpm = 100 psi .._. ~ ~ ~ ~ #2 MP 2 bpm = 80 psi / 3 bpm = 110 psi 250 TVD 2 993 MD 3 ~ - C , , ,~.. . - i ow rom o .- Up Wt 145k / Dn Wt 130k / Rt Wt 140k / 766 gpm / 840 psi / RPM80/TQ5koffbttm-7-12kon. 2/11/2008 00:00 - 03:00 3.00 STWHIP P WEXIT Cont' Mill Window from 3,268' to 3,274' & 20' of new hole to 3,294' Up Wt 145k / Dn Wt 130k / Rt Wt 140k 1766 gpm / 840 psi 1 RPM 80/TQ5koffbttm-7-12kon. Dress window, work mills through with and without pumps and rotation. 03:00 - 05:00 2.00 STWHIP P WEXIT Pump 30 bbl 11 ppg weighted super sweep followed by 30 bbl high vis super sweep around pumping 880 gpm 1030 psi, rotating 120 rpm's. Circulate 3 x surface to surface until well cleaned up. Mud Wt. in and out 8.9 ppg. 05:00 - 06:00 1.00 STWHIP P WEXIT RU & Perform LOT MD 3,250 /TVD 2,993, Mud Wt in and out Printed: 2!2712008 2:58:46 PM • Date 02-19-2008 Transmittal Number:92928 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 5Fi4-4n91 Log Top Well Name Date Contractor Run De th Bottom De th Lo T e Bridge Plug Setting Record 9- NS16 01-28-2008 SCH 1 3450 3800 5/8" EZSV/GR/CCL Ultrasonic Cement Evacuation NS16 01-28-2008 SCH 1 80 4010 Lo USITlGR/CCL Free Point Indicator Log NS16 02-01-2008 SCH 1 2030 2598 FPIT/CCL Perforation Record w/Gamma Ray 2.88" HSD 6SPF 60 DEG NS11 01-06-2006 SCH 1 14400 14580 Phased PF2906 ,;~ ~ /r ~~ ~ , Please Sign and Return one copy of this transmittal. ~E® ~F `~ ~ ~QO~ Thank You, Joe Lastufka Petrotechnical Data Center Attn: Christine Mahnken Kristin Dirks Doug Chromanski Ignacio Herrera David Fair J`? ~~ ~~~ `~ ~~~-r~~" AOGCC DNR MMS Murphy Exploration BPXA _ -; ... ._ r ~, ;, .~ '., ~~,,, ~~ _~ "~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Northstar - NS 16A ~ Maunder, Thomas E (DOA) Frorn: Kara, Danny T [Danny.Kara@bp.com] Sent: Thursday, February 07, 2048 8:51 AM To: Maunder, Thomas E (DOA} Suhjec#: RE: Northstar - NS16A (206-141), N516 (202-127) Thanks Tom. ~ Page 1 of 2 From: Maunder, Thomas E (DOAj [maiito;tom.maunder@alaska.gov~ Sent: Thursday, February 07, 2Q08 8:45 AM To: Kara, Danny T Subject: RE: Northstar - NS16A (206-14i), NS16 (202-127) Dan, It is acceptable to proceed with the installation of the big bridge plug. Tom Maunder, PE ~ AOGCC From: Kara, Danny T [mailto:Danny.Kara@bp.com] Sent: Thursday, February 07, 2008 8:42 AM t f•,~~~i~ To: Maunder, Thomas E(DOA) ~.~~~;~~~;;~ ~;~~. ~ L Subject: FW: Northstar - NS1bA (206-141), NS15 (202-127) Tom, We are unable to fish out the last 100' of 9-5/8" below the 13-318" shoe. The 13-3/8" shoe is at 3494' MD. We successfully removed 9-518" down to 3485' md, 9' inside the shoe. We made the next cut at 3600' MD, 106' below the 13-3/8" shoe. We attempted to jar/circulate and could not move pipe or establish circulation - we injected 16 bbls of 9.3 fluids away at 680 psi, thru the cut. As Paut describes below, there is a tested 9-5/8" bridge plug at 3670' MD. You state below that it would be satisfactory to install a 13-318" plug to abandon the NS16 wellbore. We wou-d like to exercise that option and uvhipstock out the 13-3/8". However, there is now a cut in the 9-5/8" (3600'} and that cut will be between the 9- 5!8" and 13-3/8" bridge plug. This is a bit different than PauPs scenario. Question - Is it still acceptable to install the 13-3l8" plug for proper abandonment? There appears to be reasonable cement outside the 9-5/8" - we could not establish circulation. PII call you to discus5. Thanks Qan From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 04, 2008 12:i1 PM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: Northstar - NS16A {206-141), NS16 {202-127) 2/7/2008 Northstar - NS 16A • ~ Page 2 of 2 Paul, Based on the information provided, if you are unable to recover the 9-5/8" casing to the below the 13-3/8" shoe setting the 13-38/" retainer and testing it as described in conjunction with the deeper plugs will satisfactorily abandon the NS16 wellbore. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Monday, February 04, 2008 10;47 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: Northstar - NS16A Tom, Pursuant to our conversafion on Friday, I will describe our current situation at Northstar on NS16A and ou~ thoughts as we move fon~vard. As you know, NS16A is a planneci cut-and-pult sidetrack which salvages the surfacs casing and the slot in order to complete a new wetl at a bottom-hole location with bet#er isolation from gas. Our plans are to cut the 9-5/8" casing approximately 1fl0' betow #he surface casing shoe at 3494' MD, leaving an EZSV below the stub and setting a cement kick-o#f plug. This plan requires us to cut 9-5I8" down to about 3600'. The EZSV has been set at 3670' and pressure tested to 20~0 psi and weight tested to 10K-Ibs. CuRently, we have cu# and pulled down ta 2449' and our tatest cut was made at 2611' IND. We expect to know whether this section "pults" tater today. A USIT log run conducted before starting the cut-&-putl indicates cement stringers as we get deeper, with signi€icant cement in the vicinity af the 13-3/8" shoe, so we sxpect the fishing to get more difif'icult ftom this point forward. Also, it was knawn before we moved on NS16 that we had no injectivity down the DA. Therefore, we are co~templating cutting down to approximately 3040' MD, setting an EZSV in the 13-3l8", pressufe and weight testing this, and then setting a whipstock and exiting the 13-3/8". There is a good sand zor~e aE this depth far kicking o#f. Our base ptan is still #o sidetrack off the cement plug, but, if this o~ration r+eaches a~int af diminishing retums we would like to know if AOGCC would regard the #ested cement piug across the perfs, ihe tes#ed bridge plug in the 9-5/8" and the tested 13-3/8" plug and na injectivity down the OA are adequa#e abandonment of the NS16 wellbore. Thank you #or your consideration. Best Regards, Pau1 Hanson zi7izoos BOPE Test Pressures - NS 16~ Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Monday, February 04, 2008 12:07 PM To: 'Hanson, Paul' Cc: Kara, Danny 7 Subject: RE: BOPS Test Pressures - NS16A {206-141) ~ S ~ b ~a_ `~~ Paul, Proceeding as described is appropriate. As we discussed, given that the well was/is plugged deep and pressure tested, testing to 3500 psi was not inappropriate. As further discussed, you are free to request a reduced BOP test pressure for similar situations where the deep well section has been plugged and successfully pressure tested. Call or message with any questions. Tom Maunder, PE AOGCC PS: Based on where the operations presently are, the wellbore reference used by the Commission would be NS 16 (202-127). By convention, the redrilt is not considered to "begin" until the window is milled. From: Hanson, Paul [mailto:PauLHansonl@bp.com] Seat: Thursday, January 3i, 2008 11:24 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: BOPS Test Pressures - N516A Tom, ~~° ~~ FEB ~ 200 I am writing in follow-up to our conversation this morning. Early this moming,-in preparation for pulling our 9-518" casing on NS16, our rig team swapped rams to 9-518" and #ested the rams against a test joint #0 3500 psi. Our sundry permit stipulates that ROPE be tested to 5000 psi. This came to {fight in our moming call, and i called you thereafter. We are currently pulling 9-5/8" down to our first cut a# 1916'. Our next BOP test is on February 2nd, so !propose that we continue operations until our next BOP test, and, on February 2nd, resume testing at the permitted pressure. As you are aware, the NS16 perforated interval has been abandoned with 184' of 15.8# Class G cement above the uppermost pert which has been pressure #ested. We also have an EZSV set, pressure tested and weight tes#ed with 10,000# at 3670'. The annulus was pressure tes#ed, and the entire wellbore has been swapped 9.3 ppg KWF. We are operating in a mechanically sound wellbore. Sincerely, Paul M. Hanson 2/4/2008 Northstar - NS 16A Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 04, 2008 12:11 PM To: 'Hanson, Paul' Page 1 of 1 Cc: Kara, Danny T Subject: RE: Northstar - NS16A (206-141), NS16 (202-127) Paul, Based on the information provided, if you are unable to recover the 9-5/8" casing to the below the 13-318" shoe setting the 13-38/" retainer and testing it as described in conjunction with the deeper plugs will satisfactorily abandon the NS16 wellbore. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sen#: Monday, February 04, 2008 10:47 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: Northstar - NS16A Tom, Pursuant to our conversation on Friday, I will describe our current situation at Northstar on NS18A and our thoughts as we move forward. As you know, NS16A is a planned cut-and-pull sidetrack which salvages the surface casing and the slot in order to complete a new well at a bottom-hole location with better isolation from gas. Our plans are to cut the 9-518" casing approximately 100' below the surface casing shoe at 3494' MD, leaving an EZSV below the stub and setting a cement kick-off plug. This plan requires us to cut 9-518" down to about 3600'. The EZSV has been set at 3670' and pressure tested to 2000 psi and weight tested to 10K-Ibs. Currently, we have cut and pulled down to 2449' and our latest cut was made at 2811' MD. We expect to know whether this section "pulls" later today. A USIT log run conducted before starting the cut-&-pull indicates cement stringers as we get deeper, with significant cement in the vicinity of the 13-3/8" shoe, so we expect the fishing to get more diff+cult from this point forward. Also, it was known before we moved on NS18 that we had no infectivity down the OA. Therefore, we are contemplating cutting down #o approximately 3040' MD, setting an EZSV in the 13-318", pressure and weight testing this, and then setting a whipstock and exiting the 13-3/8". There is a good sand zone at this depth for kicking off. Our base plan is still to sidetrack off the cement plug, but, if this operation reaches a point of diminishing returns we would like to know if AOGCC would regard the tested cement plug across the perfs, the tested bridge plug in the 9-5/8" and the tested 13-3/8" plug and no infectivity down the OA are adequate abandonment of the NS16 wettbore. Thank you for your consideration. Best Regards, Paul Hanson 214/2008 ............._.__~_..~ ~-------o - ---- Maunder, Thomas E (DOA) I ~ a~~ From: Maunder, Thomas E (DOA) Sent: Tuesday, January 15, 2008 8:06 AM To: Kara, Danny T Subject: RE: 2008 Northstar Drilling Plans ~ ~t -"" `~~ Hi Dan, Thanks for the update. It appears from your note on NS16 and 16a that the sundry for the activities prior to drilling is also in place. Good luck, Tom Maunder, PE AOGCC From: Kara, Danny T [mailto:Danny.Kara@bp.com] Sent: Monday, January 14, 2008 4:54 PM To: Maunder, Thomas E (DOA); Monkelien; Kyle (MMS) Cc: Crane, Lowell R Subject: 2008 Northstar Drilling Plans ~~ JUL 1 ~ 200$ Tom/Kyle, I thought I'd send you guys an update of the drilling plans for Northstar this year. The quick summary is sidetrack NS16a and finish NS34. NS33 will be deferred until the '09 ice road season. We're actively building ice to the island - we need sufficient ice road thickness to support Schlumberger's cementer, before we can start any openhole drilling. At this time we're estimating about Jan 26t" for heavy equipment travel on the ice road. We plan to MIRU on NS16 and begin the tubing & 9-5/8" casing cut and pull on about Jan 18t". That will allow us about a week of rigging up and dealing with the uncertainties associated with the decomplete -get that off the critical path. So our first BOP test will be sometime around Jan 22"d. In summary, we will cut/pull the 9-5/8" below the 13-3/8" surface casing shoe, pump cement, sidetrack from below the surface pipe w/ 12-1/4" to the Miluveach and cement 9-5/8" casing, drill the Miluveach/Kingak and line with 7" to the top of Sag, drill the Sag/Ivishak production hole and cement in a 4-1I2" liner, then complete with 4-1/2" 13Cr tubing. I've attached the approved NS16A PTD for your reference. NS16A sidetrack should take ~35 days. N~53~;.t refresh your memory, was attempted last year but we lost the hole and BHA in the Miluveach/Kingak section. The ~s suspended with 13-3/8" surface casing set in the SV sands, and 9-5/8" intermediate casing cemented into the top o ruk. We pumped cement into the openhole below the 9-5/8" shoe. An extensive review of the log data suggests ~ veach instability was probably driven by proximity to faulting and wellbore roof collapse associated with borehole inc r approaching that of bedding planes (Drilling is still o-- blame the Geologist for these, again). Our solution to move the well away from as far as possible (limited by exiting the 9-518" shoe) and reduce the inclination hole t a es. We will not underream the Miluveach/Kingak, from 8-1/2" to 9-1/2", as we've don ast - reamers make dealing with unstable hole conditions very difficult. Inst nrng the hole we'll reduce t size from 7" to 6-5/8", down to top of Sag. We'll fini uction hole a 5-7/8" bit and 4-1/2" cemented liner. ave plenty of contingency ca pin the event wellbore instability continues to be a problem. Dave Johns urrently w e TD application and you guys should see it sometime next week. NS34A should take about 5 to finish. I've attached a couple of slides which summarize NS34. ~ ~~~ ~~ 7/15/2008 ~ ~~p 2008 Northstar Drilling Pians • Page 1 of ~~ ~ ~ Maunder, Thomas E (DOA) From: Kara, Danny T [Danny.Kara@bp.com] Sent: Monday, January 14, 2008 4:54 PM To: Maunder, Thomas E{DOA); Monkelien, Kyle {MMS) Cc: Crane, LoweH R Subject: 2008 Northstat Drilling P1ans Attachments: NS96A Drilling Permit.pdf; Northstar NS34A .ppt TomJKyle, i thought I'd send you g~ys an update of the drilling plans for Northstar this year. ! y'~ \ ~ ----~ .~~ ~3 ~- ~ ~ "1, The quick summary is sidetrack NS16a and finish NS34. NS33 vvill be deferred until the '~9 ice road season. We're ac#ively building ice to the island -we need sufficient ice road thickness to support Schlumberger's cementer, before we can start any openhofe drilling. At this time we're es#imating abc~ut Jan 26t~' for heavy equipment travel on the ice road. We plan to MIRU on NS16 artd begin the tubirtg & 9-5l8° casing cut and putt on about Jan 18~'. That will a!{aw us about a week of rigging up and dealing witfi #he ancer#ainties associated with the decomplete - get that off the cri#ical path. So our first BOP test wi~l be some#ime around Jan 22"a In summary, we w~ll cufi/pull the 9-5/8" below the 13-3/8" surFace casing shoe, pump cemen#, s~fetrack from belaw the sur#ace pipe w/ 12-1/4" to the Miluveach and cement 9-5/8" casing, drill the Miluveachl~Cingak and Ime wit~ 7" to the top of Sag, drili the Sag/lvishak production hole and cement in a 4-1/2" liner, #hen complete with 4-1/2" 13Cr #ubing. I've attached the approved NS16R PTD for your r~ference. NS16A sidet~ac#c should #ake ~35 days. NS34, to refresh your memory, was attempted iast year bu# we lost the hole and BHA ~n the Mituv~achtKingak section. The well is suspended with 13-3l8a surface casing set in the SV sands, and ~5l8" intermediate casi~g cemented into the top o# Kuparuk. We pumped cement into the openhole below the 9-5/8" shoe. An e~ctensive review of the log dat~ suggests the Miluveach instability was probably driven by proximity to faulting and wellbare roof collapse associated with borehole inclination approaching tha# a# bedding pianes {Drilling is still trying to blame the Geologist for these, again}. Our sotu#ion wiN be to move the welt away €~om the fautt as far as passible (limited by exiting the 9-5/8" shoe) and reduce the inclination of the hole thru tt~e shales. We will not underream the MiluveachfKir~gak, from 8-1/2" ta 9-1/2", as we've dor~e in the past - und~reart~ers -nake dealing with unstable hale conditions very di#ficult. instead of o~ning the hole we'il reduce the hner size from 7M to 6-5/8°, down #o tap of Sag. We'li finish the producfion ho#e a 5-7/8" bi# and 4-1t2" cement~l ~ner. We have p{enty of contingency cases lined u~ in the event wellbore instability continues to be a problem. Dave Johnson is currently wor~cing the PTD application and you guys should see i# sometirne next week. NS34R should take about 5 weeks to finish. t've attached a coupte of s#ides which summarize NS34. With good planning and some luck we hope to comptete tt-e dr~lling season before May 9St. Ptease call with questions. Thanks Dan Kara Engineering Tean~ Lead Noi-~l~star/Mi2ne Point/Endicott Urilling k-. ~~~~~~.1 .'~.~~., i .$. ~~~J ~«. ! 2/7/2008 STATE OF ALASKA ~~~ ALASKIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOC3~pN 0 $ ~~Q~ Alaska Oil ~ Gas lan~ta-0 ~dttltwtitseid,~n 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended 20AAC 25.105 zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions 1b. Well pfeq@ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12!6/2007 12. Permit to Drill Number 202-127' 306-334 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/29/2002 13. API Number 50-029-23096-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/18/2003 14. Well Name and Number: NS16 WEL, SEC. 11, T13N, R13E, UM NSL, 645 1199 Top of Productive Horizon: 956' NSL, 520' WEL, SEC. 10, T13N, R13E, UM 8. KB (ft above MSL}: 56.46' Ground (ft MSL): 15. Field /Pool(s): Northstar Unit - Total Depth: 956' NSL, 546' WEL, SEC. 10, T13N, R13E, UM 9. Plug Back Depth (MD+TVD) 12120 10850 4b. Location of Well (State Base Plane Coordinates, NAD 27): y- 6030971 Zone- ASP4 Surface: x- 659830 10. Total Depth (MD+TVD) 12424 ~ 11148 - 16. Property Designation: ADL 312799 __ TPI: x- 654682 y- 6030619 Zone- ASP4 - 6030618 Zone- ASP4 th: x- 654656 Total De 11. SSSV Depth (MD+TVD) 972 968 17. Land Use Permit: y p 18. Directional Survey ^ Yes ®No Sub i le roni an rin infor a i n er 20 AA 25.050 19. Water depth, if offshore 39' ft MSL 20. Thickness of Permafrost (TVD): 1545' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD ,GYRO , GR , CCL , RES , DIR , PWD ,DEN , NEU 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wr. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 169# X-56 Surface 201' Surface 201' 20" Driven 13-3/8" 68# L-80 44' 3494' 44' 3200' 16" 618 sx PF'L' 470 sx Class 'G' 9-5/ " 47# L- 0 4 ' 10435' 4 ' 9288' 12-1/4" 550 sx Econolite 621 sx Class'G' 7" 26# L-80 10265' 12094' 9139' 10824' 8-1/2" 288 sx Class'G' 4-1/2" 12.6# 13Cr80 11919' 12424' 10655' 11148' 6-1/8" 87 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. TU91NG RECORD If Yes, list each i & Bottom; Pe (MD+TVD of To nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD p 4-1/2", 12.6#, 13Cr80 11929' 11880' MD TVD MD TVD Tubin cut at 11874' No n e 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ '+ ~p~ ~~~NE~ MAY ~ ~ 20Q$ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 26, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK}: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. S ~'~ JAN ~ ~ 2009 ~' . None ~~ t ~~~' Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMA TIONS AN' 4KERS ENC OUNTERED): 29. FORMATION TESTS NAME ~ TVD Well Tested ^ Yes ®No Permafrost Top tf yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Kuparuk 9888' 8822' None Kuparuk 'C' 10025' 8939' Top of Miluveach 1039ti' 9260' Top of Kingak 10975' 9778' Top of Sag River 12065' 10804' Top of Shublik 12162' 10898' Top of Ivishak 12258' 10992' Formation at Total Depth (Name): 30. List of Attachments: Well Work Summary and a Wellbore Schematic. 31. I hereby certify that the fore ~ ing is true and correct to the best of my knowledge. Signed Sondra Vim' 'tle Drilling Technologist Date (~ ~ ~ (~ ~ (~~j NS16 202-127 306-334 Prepared ByName/Num6er. Sondra Stewman, 564-4750 Well Number P rmit No. / A royal No. Drilling Engineer: paul Hanson, 564-4995 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 28. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Well History Well Date Summary NS-16 11/19/2006 **"WELL SHUT IN ON ARRIVAL*'* DRIFT & TAG W/3.50" CENTRILIZER , 2' x 1 7/8" STEM , 3.74" XN LOCATOR LOCATED XN @ 11,890' SLM + 25' = 11,915' MD. TAG TD an. 12,350' SLM + 25' = 12,375' MD. **"WELL SHUT IN ON DEPARTURE"*' NS-16 11!30/2006 T/V0=3610/vac/vac Terre=Sl MIT IA 4200 psi **"PASSED*`"` (Pre-RWO) -Pumped 18 bbls diesel to fluid pack IA. Pumped a total of 30.2 bbls diesel to pressure up IA to 4200 psi. IA lost 60 psi in 1st 15 min. IA lost 20 psi in 2nd 15 rr9n. Passed. Bleed IAP all fluid (approx 12 bbls). Final WHPs=3610/40/vac. Well to remain shut in. ****"Job Complete***** NS-16 2/7/2007 T/V0= 3540/Vac/Vac. Temp= SI. OA FL Carrpaign. OA FL near surface. NS-16 4/23/2007 Heat seawater & Load Upright for upcorrrng w ork NS-16 4/29/2007 ****"Travel to Northstar****" Spot and prep equipment for SCMT log. NS-16 4/29/2007 Travel to N*/start equipment/begin rig up NS-16 4/30/2007 ***""`Well shut in on arrival (high GOR)**"** LOGGED SCMT/GR/CCL BOND LOG FROM 12380'-11775' AFTER FLUID PACKING WELL WITH 80 DEGF FSW.UNDER BALANCED WELL WITH 58 BBL DIESEL AND 5 BBL METH CAP. FOUND GOOD BOND ABOVE PERF INTERVAL. LEFT WELL SHUT IN AND NOTIFIED PRODUCTION OF WELL STATUS. "***"JOB COMPLETE""*** NS-16 4/30/2007 T/V0=3600/15/Vac. Well shut in on arrival. Assist E-Line w/SCMT-Load & Kill well w/5 bbl methanol spear, 290 bbls 80*F filtered seawater, 5 bbl methanol spacer, 58 bbls 80*F diesel & 5 bbl methanol cap. Final WHPs=400/15/Vac **"Job Complete*** NS-16 7/3/2007 **"well shut in on arrival*** (sbhp) ran 3.725" xn nipple locator & dual petradat memory gauges located xn nipple @ 11,890' slm + 25' = 11,915' and lightly tagged td @ 12,350' slm+ 25' cor. = 12,375' and corrected performed sbhp survey as per program except for stop # 1 memory gauges taken to gpb to be checked for data **"turn w ell over to w ell tender*** NS-16 8/14/2007 CTU #5. Rig-up. Assist with hardline rigup for NS-16. Standby on LRS to MIT-IA to 4200 psi before spotting unit. *** Job continued on WSR 08/15/2007 *** NS-16 8/14/2007 Assist CTU#5 (Pre-RWO Cement Squeeze) -Heating seawater, rig up for MIT IA **"Continued to next Days WSR*** NS-16 8/15/2007 CTU #5. Cement P & A. *** Continue from WSR 08/14/2007 *** MIRU CTU. Perform 5000 psi BOP test. Kill Well w ith 380 BBLs of Seawater. RIH 12382' and PUH and flag at 12378' yellow *** Job in Progress *** NS-16 8/15/2007 CTU #5. Cement P & A. ""* Continue from WSR 08/14/2007 *** MIRU CTU. Perform 5000 psi BOP test *** Job in progress *** NS-16 8/15/2007 **"Continued from previous days WSR*** T/V0=3600/Vac/Vac Temp=Sl MIT IA to 4200 psi PASSED (Pre-RWO/Cement Squeeze) -Pressured up IA to 4200 psi w/33 bbls 60*F diesel. IA lost 70 psi in 1st 15 rrtin. IA lost 20 psi in 2nd 15 min. Passed, Bled VaP (--14 bbls fluid back) Tag w ell, normal casing valves & notify w ell tender/control room. Assist CTU as directed w/cement squeeze. Heat seawater, supply diesel as directed. **"Job In FYOgress*** NS-16 8/15/2007 **"Continued from previous days WSR*** T/V0=3600/Vac/Vac Temp=Sl MIT IA to 4200 psi PASSED (Pre-RWO/Cement Squeeze) -Pressured up IA to 4200 psi w/33 bbls 60*F diesel. IA lost 70 psi in 1st 15 rrtin. IA lost 20 psi in 2nd 15 min. Passed, Bled IAP (-14 bbls fluid back) Tag w ell, normal casing valves & notify w ell tender/control room. Assist CTU as directed for cement squeeze. Heat seaw ater, supply diesel Job in progress.. Print Date: 1/8/2008 Page 1 of3 `~' Well Date Summary NS-16 8/15/2007 CTU #5. Cement P & A. *"`* Continue from WSR 08/14/2007 **"' MIRU CTU. Perform 5000 psi BOP test. Kill Well w ith 380 BBLs of Seawater. RIH 12382' and PUH and flag at 12378' yellow . Lay in 15 bbls of Gass G 15.8 ppg LARC cement from flag. Squeeze 500 psi over stati~`"c 1T1HP for 1 hour. WHP gained 80 psi over hesitation period. Contaminate with 70 bbls of 1.5 ppb Biozan to 12,100' ctm. Wash all bottom few e ry w it 4 passes w i h XS seaw ater. POOH w ashing all jew elry w ith up/down/up pass. **" Job continued on WSR 08/16/2007 *** NS-16 8/16/2007 CTU #5. Cement P & A. *** Continued from WSR 08/15/2007 *** Continue R~OH w ashing tubing. Perform up/dow n/up passes on jew elry. Wash tree and BOP w ith XS seaw ater. RIH and lay in diesel from 3000'. Final PT at 1035 psi lost 2 psi over 10 mtinutes. Shut in and tag w ell freeze protected, Tag well as freeze protected. RDMO CTU. Final T/VO = 1034/12/0. Notify w ell tender and control room of status. Demob equipment from island. *** Job Completed *** NS-16 8!1612007 ***Continued from Previous Days WSR*** Assist CTU#5 (Pre-RWO/Cement Squeeze) -Assist coil as directed, de-mobe, travel to shore. ***Job Complete*** NS-16 9/11/2007 T/V0=550/vac/vac Temp=Sl MIT T PASSED to 1000 psi (Post P&A Cement Squeeze) -Pressured up t 10 si isi in 1st 15 min. Tb lost 0 si in 2nd 15 min. tbg from 550 psi to 1000 si w/diesel. Tb lolos ~ Passed, bled TP rom 990 psi to ~ O~psi:~lrfl-uid. 0-erii'iecrcasing va ves open to gauges, tag w ell & notify w ell tender. Final WHPs=300/vac/vac NS-16 9/11/2007 *** WELL S/I ON ARRIVAL*** SIDETRACK PREP ***DRIFT FOR JET CUT*** RAN 4 1!2" XN LOC, 3.7" CENT, LOC XN NIPPLE @ 11885' SLM, +30' TO MD (11915'), TAG CMT 12090' SLM, (12120') MD, WHILE PULLING OUT OF HOLE, CUT WIRE ON TRSSSV. TRSSSV HAD 3000 PSI ON CONTROL LINE. RAN 3.85" CENT TO SSSV NIPPLE @ 939' SLM. CYCLE SSSV 3 TIMES. HOLD SSSV OPEN WITH 5000 PSI. RAN 3.85" CENT /FLAPPER CHECKER TO SAME, SSSV APPEARS TO BE FUNCTIONING. FISHED TOOL STRING W/ 3.6" BELL GUIDE, 2.5" JDC @ 12067' SLM, ** TOOL STRING RECOVERED** *** CONTINUED PDS CALIPER ON 9/12/07 WSR *** NS-16 9/12/2007 *** CONTINUED FROM 9/11/07 WSR *** PRE SIDETRACK *** CALIPER TUBING FROM 12,094' SLM TO SURFACE @ 50 FPM " GOOD DATA " *** WELL LEFT SHUT IN ON DEPARTURE *** NS-16 12/3/2007 PPOT NS-16 12/3/2007 T/VO=SSV/VACNAC, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL). (pre sdtrk) Test tubing hanger void to 5000 psi. Good. Bleed to 0. Pressure pack-off to 5000 psi. Lost 200 psi in 2 min. Pressure back up to 5000 psi, lost all pressure. Re-energize and attempt to test again. Unsuccessful. Try tro pump JR-2 all the w ay around BT seal. No returns after 6 tubes. BT seal or o-ring bad. FYogram calls for cut & pull casing. Slips & pack-off available. NS-16 12/4/2007 ***TRAVEL TO NORTHSTAR/SPOT EQUIPMENT*** (pre sidetrack) NS-16 12/4/2007 T/VO=ssv/vac/vac Terrp=Sl MIT OA PASSED to 2000 psi (Pre-SDTRK Prep) -Loaded OA w/7.3 bbls diesel. On 2nd attempt re-pressured OA w/0.1 bbls diesel. OA lost 20 psi in 1st 15 rrtin. OA lost 10 psi in 2nd 15 min. Total loss of 30 psi in 30 min. Passed, bled OAPto 0 psi, all fluid (-3 bbls). Verify casing valves open to gauges, tag w ell & notify w ell tender. Final WHPs=ssv/vac/60 NS-16 12!4/2007 Function test LDS & gland nuts. INCOMPLETE. (Permit cancelled due to extremely high w ind gusts). Travel from Northstarto Prudhoe. NS-16 12/5/2007 T/V0=350/vac/100 Temp=Sl MIT T PASSED to 1000 psi (SDTRK Prep) -Pressured up tbg from 350 psi to 1000 psi w/0.5 bbls diesel (against cement plug). Tbg lost 10 psi in 1st 15 min. Tbg lost 10 psi in 2nd 15 min for a total of 20 psi in 30 mins. Bled TP (all fluid), verify casing valves open to gauges, tag well & notify operator. Fnal WHPs=20/vac/100 NS-16 12/5/2007 ***JOB PREP FOR JET CUT*** (pre sidetrack) NS-16 12/6/2007 De-Hobe Equipment, Travel to Prudhoe NS-16 12/6/2007 ***WELL SHUT IN ON ARRVAL*** (pre sidetrack) INITIAL WHP 40/0/100 CUT TUBING 11874', 15' BELOW NIPPLE CUT WITH 3.65" JET POWERCUTTER, 2 GEMCOS RUN ABOV E CUTTER. FINAL WHP 0/150/125 ***JOB COMPLETE"** Print Date: 1/8/2008 Page 2 of3 Well Date Summary NS-16 12/7/2007 ***WELL S/I ON ARRIVAL*** (pre sidetrack) SET HOLD OPEN SLEEVE W/4 1/2" X LOCK IN TRSSSV @ 940' SLM (AOL= 55" LOCK OPEN, MIN ID=2.50" ). RAN 4 1/2" CHECK-SET TO CONFIRM. CHECK-SET CAME BACK SHEARED. '"*WELL LEFT S/I CONTROL ROOM NOTIFIED*""` NS-16 12/16/2007 *"**"Well Shut in on Arrival'*"'* NS-16 Pre Sidetrack prep. Vetco-Gray checked and cycled all lock dow n screw s. All lock dow n screw s on tubing head adaptor cycled good. Well ready for Nabors 33-E Print Date: 1/8/2008 Page 3 of3 FREE _ WELLHEAD = AB ACTUATOR- BAKER KB. ELEV = 56.46' BF. ELEV = 40.56' (CB 15.9') KOP = ..., 100 Max Angle = .__.-.~.__ ~~_ Datum MD = 33 @ 9614' P. ~.m.~.-_.._...__._ . __._~. _R~_.,..~._.~, 11817' Datum TV D = 10500' SS ~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" SAS,' NOTES: ***4-1 i2" CHROME TBG &LNR*** W~ -__-._ J?2' 4-1/2" TRM-4E SSSV, ID = 3.813" 972' 4-1/2" HOLD OPEN SLV, ID = 2.50" (12107107) --~ 1587 13-3/8" TAM PORT COLLAR GAS LIFT MANDRELS Minimum ID = 3.725" @ 11915' 4-112" XN NIPPLE TOP OF 7" LNR 10265' 9-5/8" CSG, 47##, L-80 BTM-C, ID = 8.681 " ABB-VGI5-1 /8" 5K~ B-VGI 13-5/8" MULTIBOWL 5K JET CUT (12/06/07) ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 4981 7189 4483 6453 27 26 10265' ~ 9-5/8" X 7" ZXP LNR PKR w / TIEBK SLV & FLEX-LOCK HYDRAULIC HGR, ID = 6.19" 11833' -~ 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.945" 11836' ELM 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.945" 11859' 4-1/2" X NIP, ID = 3.813" 11880' --[7" X 4-1/2" PKR 11903' 4-1/2" X NIP, ID = 3.813" 11915' ~-~4-1/2" XN NIP, ID = 3.725" ITOP OF 4-112" LNR 4-1/2"TBG, 12.6##, 13CRVAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 HY DRIL 521, ID = 6.276" 1 PERFORATION SUMMARY REF LOG: PDC GR/CCL on 07/14/03 ANGLE AT TOP PERF: 9 deg @ 12304' INfI'IAL PERF-CHARGE: 2906 POWERJET, HSD, PENETRATION: 27", HOLE: 0.36", PHASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) OpnlSgz DATE 2-7/8" 6 12304 - 12384 S 08/15/07 PBTD 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE, .0152 bpf, ID = 3.958" 11926' 4-1/2" SELF ALIGNING WLEG ID = 3.850" 11926' ELMD LOGGED 04/30/07 (2100' -j.EST TOP OF CEMENT (08!15/07) ~:~ ~r~P ~-~ C'~vv,-~.n~F-~ ~l z -off, c~~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/02 JAS INIT COMPLETION 08/15/07 GLNU PJC P&A 03/21/03 FM FINAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIC 07/18/03 EMF ADD PERFS 12/15/07 RCT/PJC JET CUT (12/06/07) 11/04/05 BJM NEW FORNIAT 12/15/07 RCT/PJC HOLD OPEN SLV (12/07(07) 04/30/07 WRR/PJC ELMD LOGGED / WELLHEAD 05/01/07 WRR/TLH GL DEPTH CORRECTION NORTHSTA R WELL: NS16 PERMIT No: 2021270 API No: 50-029-23096-00 SEC 11, T13N, R13E, 1199' FSL & 645' FEL BP Exploration (Alaska) . . bp Date 10-23-2007 Transmittal Number:92913 '~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ -I~ Log Top SW Name Date Contractor Run Depth Bottom Depth Loa Tvpe MEMORY MULTI-FINGER ... ~ CALIPER LOG RESUL TS ~4 NS16 09-11-2007 PDS 1 0 12110 SUMMARY MULTI-FINGER CALIPER 3D NS16 09-11-2007 PDS 1 0 12110 DATA AND VIEWER ~é)(> '1- NS30 09-16-2007 SCH 1 15900 16170 PERFORATING RECORD - MEMORY STATIC PRESSURE - fol NS06 07 -29-2007 SCH 1 13096 13694 AND TEMERATURE SURVEY - MEMORY STATIC PRESSURE - L.(( NS18 07 -30-2007 SCH 1 16290 16845 AND TEMERATURE SURVEY - h~lq MEMORY STATIC PRESSURE NS09 07 -31-2007 SCH 1 12666 13341 AND TEMERATURE SURVEY Jofi ðtJd dOd :)0 é-JJ~ Please SIgn and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center ~~NED NOV C 1 Z007 Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP Exploration (Alaska), Inc. September 11, 2007 8626 1 4.5" 12.6 lb. 13CR Tubing & Uner Well: NS-16 Field: North Star State: Alaska API No.: 50-029--23096-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 12,110 Ft. (MO) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into the 4.5" tubing ELMD @ 11,926' (Drillers Depth). This log was run to assess the condition of the 4.5" tubing and liner interval with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing and liner interval logged are in good condition. No significant waD penetration (in excess of 20%). areas of significant cross sectional wall loss. or significant I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>11 %) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross sectional wall loss (>4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. ~Dd -/;;1- ¢ /5'S"« I Field Engineer: K. Miller Analyst: B. Qi Witness: B. Rochín ProActive Diagnostic Services, Inc. I P,O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I I I I I I I I I I I I I I I I I I I - Well: Field: NS-16 Prudhoe Bay BP Exploration USA Inc. Country: Nom.OD 4.5 ins Weight 12.6 f Grade &; Thread HCR Penetration and Metal loss (% metal loss body o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% Damage ( body ) 10 o isolated general line ring hole ¡ pass pitting corrosion corrosion corrosion role hote o o o PDS Repo Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Anal st: Nom.lD 3.958 ins Bottom of Analysis Overview page 2 1 t 2007 MFC 40 No. 99493 2.75 40 B. Nom. Upset 4.5 ins penetration body o o 94 GLM 1 GLM2 190 279 "" 284 Upper len. 6,0 ins Profie walO metal loss 50 Lower len. 6.0 ins 100 I I I I I I I I I I I I I I I I I I 111' 1171 1220 1?62 1304 1346 1388 14iO 1472 1514- 1556 1SQ9 1640 16Ri 1725 1767 1809 4.5 in 12.6 0.271 in 0.271 in 3.958 in DCR Joint jt. Depth Pen Pen. Pen i\;k~ Min. No. !.D. .1 18_(ln5.) ~~:; pun 1 73 ~ 1.1 6f. 'I 0.01 ~ Pun 1.2 72 I 0.01.2 1 .91 Pun 1.3 =t=i= 0.01 Iii 3.9? Pun 1 4 1 3.<i1···· p~ .2 101 ¿~91 3 143 I .90 L!. 1R5 .91 m22; 7 3.91 6 270 0.01 'q() 7i1 i 0.00 .Q1 3 0.01 j I (,:1 10 4, I .i I 11 480 17 522 13 <;14 14 6( 15 6 16 6< 17 73 18 775 19 817 /0 8S!} 21 901 21.1 943 21.2 953 213 958 22 968 21 1010 24 1052 25 26 27 28 ?9 10 31 32 31 34 35 36 37 38 ,9 40 41 42 3.92 3.Ql }()/ 391 1.97 3.92 3.9? 3.92 1.91 1.9? 3.91 ttrt 390 3.90 3.91 i 1.89 i 0.01.2 3.91 om 3 ~ i om 2 ~ ~ i1$t ~:~~ ( 3.90 }) om j ~ n ¡ 0.011.90 o I 0.00 3.91 ~i ~ 'I.QO ~-=~:fi ( i i ( ( 0.0 0.0 0.0 0.0 0.0 0.0 o.m 1 A .;\ '\ ) ¡ ? ¡ '; ¡ o ( We ¡: Field: Country: Survey Date: Pun SSSV pun LA TION NS-16 Pm dhoe Sf' USA Comments 11, 2007 Inc. , Profile o 50 100 ill I I I I I I I I I I I I I I ULATION 4.5 in 12.6 ppf 13CR 0.271 in 0.271 in 3.958 in Well: N5-16 Field: Pm dhœ BP !nc. USA Date: 11,2007 Joint Jt. Depth Per Pen. Pen, I !\1eí;¡ Min. ,,,¡',,,':"''''' No. \:;:~(;t (Ins.) !.D. Comments \7<> wan} (Ins.) 0 50 100 1851 n 0.01 3.89 44 3.90 45 3.91 46 1977 ! ~~ 47 ¡ 48 ¡ 0.00 49 3.91 50 2146 3.91 51 7188 n 3.90 52 2 30 n 0.01 .2 3.QO CI .0 I 1 I~I= (J ¡ .2 ~ 56 398 57 440 (J 58 2482 ( o 1 0.01 " ~ 0.00 I ~88 61 2609 0.00 it 62 2651 , 61 2691 h4 273'1 65 2777 3.89 66 2819 3.89 67 2862 ( T 3QO 68 2904 ( O. 3.88 69 2946 ( O. 389 tKf:2988 I O. 3.88 71 3027 .2 { ¡ 3.8<1 72 3069 .2 4œ 71 3111 {1 74 3153 0.01 75 '1195 0.02 3. 3.89 389 78 3321 0 fi 79 3363 00 3405 R1 3447 I 88 82 3489 3.88 .2 3.90 3574 1.88 16 ~ 3.90 58 3.89 87 1700 3.89 ~ 3.90 96 3826! ( rl,h ~90l 91 I 186R ¡ ( 92 ¡ 3910 I ( I I I I 2 I I I I I I I I I I I I I I I I I I I JOINT TABULATION SH Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in BCR Joint Jt. Depth I'en Pen. Pen i ¡Vlefal Min. No. 1.0. (Ins.) (Ins.) (Ins.) 93 3952 11 f! 00 94 3994 tl OlQ q5 403(; fl.OO ~ 96 4078 0.00 '{ RR ~~ :~¿g . i±di L2 o"fri ~ 104 ~ om i 3.90 105 ~ I (U)? 3.89 106 4497 (1'lõ1 ..J&L 111 4539 I 0.00 ...l.2Q.. 108 ~ 0.01 3.89 109 .dh13 Hì 38f! no .dh65 '.90 111 4707 3.90 112 4750 n 3.89 113 4791 n (, 3.90 11 '> 4876 H 000 3.88 116 4918 [) Iìíì 3.88 11h.1 4%1 0 ~ 116.2 4971 I 11 0 11 l::Y..!i... 116.1 4979 0 ~ 391 117 4989 n ~ 3.91 118 5030 ~01 m.9 119 5072 0.00 120 5114 0.01 121 5156 om 122 5198 3.92 123 5241 0 3.93 1 n ~1 125 I 5324 3.92 116 I 5366 3.92 127 om 3.92 118 om 3.90 129 5493 (0.01 3.91 Bi 5'B5 ¡ 001 3.91 13 5577 0.01 I' 3.92 13. 56 9 0.01 3.92 13 561ì1 om 3.92 134 571!3 0.01 3.92 135 57 5 0.01 3.91 136 5787 0.01 3.92 137 5829 0.D2 3.91 138 5871 Ófi1 X 3.Q2 139 5913 0.01\ 3.93 Well: Field: NS-16 Prudhoe Bay BP Exploration (Alaska), Inc. USA 11,2007 Comments PUIJ GlM 1 (latch @ijÐm PI'" 3 ~a Profile o 50 100 I I I I I I I I I I I I I I I I I I I 4.5 in 12.6 ppf 13CR 0.271 in 0.271 in 3.958 in Jt Depth Pen. Pen. l(:~::(;t (Ins.) o om o OJI1 o 0.01 Joint No. Pen. I ¡\'Ietal Min. ;s LD. (Ins.) ..L.l-J.,92 ~9 I 3.9 3.9: 3.91 3.92 3.91 2 3 3 140 5955 141 /';998 ti=t 6040 6082 6124 145 6166 0.01 146 6208 0.01 147 6250 ¡ 0.01 148 ~ 0,02 ¡ 149 ~ 0.01 ~ 6376 0,00 151 6418 ~ 1 5 6460 1 3 0 i92 154 i 6544 OÖ:01 :> 155 6587 U1OO.I 1 156 6628 ~ :> 1 "7 6671 0.01 ¡ " 159 6755 0.001 3.94 160 ó797 10m! 3.92 161 683q i ----' 3.91 162 6881 f--' 2 3.91 163 69231 ~ 164 6965 ~ 165 7007 1 3.92 166 7049 001 3.91 167 7092 0.00 1 3.91 168 7130 0 ~ 3.92 168.1 7174 0 ~ 3.92 168.2 7181 0 0 0 1i 168,3 7190 0 om += 169 7200 D 0.01 1 70 7242 0.01 171 7281 ~ ..92 172 7322'1 3.92 173 7365 ~! 3.92 174 7407 t 0.01 ~ 3.92 175 7448 í UUlL :> 3.92 176 7490 l.J2JlL 4) 3.92 177 7532 O:O~1 2) 3.92 178 7575 1 1 3.92 179 7617 0 ~ 180 7658 0 181 7700 182 7742 183 7784 3.92 184 7826 3.92 185 7869 3.92 186 7911 3.92 JOINT Weft: Field: '-ATION SH NS-16 Pru dhœ SP USA Comments PUD GLM 2 {latch @ 12:15ì Puo 4 (Alaska), Inc. 11,2007 -0 Profile 'nt on \ to """"i o 50 100 I LATION SH I 4.5 in 12.6 13CR Well: NS-16 0.271 ill Field: Prudhoe I 0.271 ill BP inc. 3.958 in USA SUlvey 11,2007 I Joint jt. Depth Pen. Pen. Pen. I,\-íetal Min. _" Profile No. 1.0. Comments "" . m \ 10 Will'! (Ins.) (Ins.) (Ins. ) 0 50 100 I 187 7953 B 0.ü1 7 2 3.92 188 7995 ~ 3 ~.92 189 8037 I 2 ~ 190 079 $$i 1 I 191 3.92 192 163 ¡f 0.ü1 ! 3.92 193 8205 3 3.92 194 8247 2 3.92 195 8289 ~mr92 I 196 8328 3.el? 197 8369 3:92 198 8413 1.92 199 8455 3 3.93 I 200 8497 4 3.92 201 1'1539 1 3513 202 85Hl 7 392 203 8623 I '1 ~.93 I 204 8665 ¡ 0.01 3.93 205 8706 0,01 3.92 205.1 874q n 0.01 3.93 Pun 205.2 8759 Ii i 393 Pun I 205.3 8761 n H 3.93 Pun 206 8767 0 3.91 207 BOOB 0 41 208 AA'i1 0 11 209 BB93 0 0.ü1 I 210 8935 Ii 001 2 =þ= 211 8977 0.ü11 3 212 9019 0.01 3 213 9061 m 3.93 I 214 91113 o 1H 215 9145 I 0.00 216 9187 ¡¡ 0.01 217 9229 n 0.ü1 3.93 I 218 9271 0.01 1 393 219 9314 om 3.92 :ì:?O ¡ 9356 0.01 1 3.93 221 9398 0.01 1 3.93 222 9440 000 II ~.91 I 223 9482 1 om 3.92 2/4 9524 11 =! 3.92 225~ 11 3.92 226 11 Ji I 227 9650 0 ]I 228 Qf,q:ì 0 3.92 22q 9734 11 3.92 230 9776 n 3.92 I 231 9819 () 3.92 232 9860 () 0.D1 3.92 233 9903 0 0.01 3.92 I 5 I I I I I I I I I I I I I I I I I I I I JOINT ULATION Pipe: Body Wall: UpsetWa": Nominal 1.0.: 4.5 in 12.6 ppf BCR 0.271 in 0.271 in 3.958 in WeD: Field: (Alaska), Inc. Country: Date: 11,2007 Joint Jt Depth 1'1' Pen. Perr I ¡!Aetal Min. Profile No. ~;~:;';t Body W. Comments '-wall) (Ins.) (Ins.) 0 50 100 234 9945 JJ 3.92 I 235 9987 3.92 236 10029 C .01 3.92 237 10071 0 0.ü1 ±1= Y* 238 1011±±:O 0.00 I 239 10155 0,00 240 10197 ~ 3.92 241 102 39 3.92 !III 242 102 81 0.ü1 ~ 243 10323 om 244 ¡ 10365 0 om 245 10406 0 0,02 ¡ ],92 246 I 10449 0 0.00 I 3.92 247 10491 0 om [I 248 1053 ] 0 0.01 2.49 ~ ;J I 250 10617 251 10659 Jl. 252 10698 0 1 3.92 253 10736 J Li ].91 254 10778 0,01 3 i 255 10820 gll j 256 10858 257 10900 258 10940 259 10982 3.92 260 11024 om 3.92 261 11066 o L 3.92 262 11108 o 0.ü1 3.92 263 11150 C 0.ü1 3.92 264 11191 0 0.01 3.91 265 11234 0.02 ( 3.91 266 11276 ( itl± , 3.91 267 11318 ( 3.91 268 11360 3.91 269 11402 0.00 3.91 2ZQ 11444 0.D1 3.91 271 11486 0.Q2 I 3.91 272 11528 0.01 3,91 273 11570 0 0,01 3 3.91 274 11612 0 0.01 3.90 275 11654 ( 0,01 3.91 276 11696 ( 0.01 3.91 277 11738 ( If I] 3.91 278 11780 J 3.91 278.1 11822 ( 3.91 PuP 278.2 11B.11 ( .3.90 PUP 278.3 11837 ( 3.89 PUD 278.4 11847 J 0.01 3.88 PUD 278.5 11857 J ° ( ( 3.81 X NiDDle Body Meia! loss Body 6 JOINT 4.5 in 12.6 ppf HCR 0.271 in 0,271 in 3,958 in Wall: UpsetWaU: NominaltD.: Field; Survey Date: Joint No. I I I I I I I I I I I I 7 I I ~ LA TION Ns..16 Pm dhoe BP USA Comments (Alaska), Inc. 11,2007 . Profile o 50 100 I "TREE = ABB- VGJ 5-1/8" W8..LHEAD = ABB- VGI13-5/8" MJL TIBOWL ACTUATOR = KB BF KO Ma Da Da N516 ~ NOTES: ***4-1/2" CHROME TBG & LNR*** I 113 . 8..EV = 56.46' . 8..EV = 40.56' (CB 15.9') P= 50' . I 972' 4-1/2"TRM-4ESSSV, 10=3.813" I x Angle = 33° @ 9614' : 1587' 1-113-3/8" TAM PORT COLLAR turn MD = 11817' turn TVD = 10500' SS -3/8" CSG. 68#, L-BO BTC, D = 12.415" I 3494' ~ ~ GAS LIFT MANDRELS ST I\ID NO DEV TYÆ VLV LATCH FDRT DAlE l 1 4981 4483 27 Minimum ID = 3.725" @ 11915' 2 7189 6453 26 4-1/2" XN NIPPLE I TOP OF 7" LNR I 10265' ~ 10265' 9-5/8" x 7" ZXP LNR PKR w 1 TIEBK SL V I & FLEX-LOCK HYDRAULIC HGR, 10= 6.19" /8" CSG, 47#, L-80 B1M-C, 10 = 8.681" I 10435' µ ~ 11833' '-14-1/2" FBER OPTIC TRANSDUCER, 10 = 3.945" I J 11836' ELM I 4-1/2" FIBER OPTIC TRANSDUCER, 10 = 3.945" I · 11859' H4-1/2"XNf', 10=3.813" t '" 2S 11880' H7" X 4-1/2" PKRI - I I 11903' 1-14-1/2" x Nf'. 10 = 3.813" I · I · 11915' 1-;4-1/2" XN Nf', 10=3.725" I I TOP OF 4-1/2" LNR I 11919' t- ~ 8 14-1/2" TBG, 12.6#, 13CR VAM·ACE, 11926' .... ¡.....I 11926' 4-1/2" S8..F ALIGNING WLEG I .0152 bpf, 10 = 3.958" 10 = 3.850" 17" LNR, 26#, L-80 HYDRIL 521, D = 6.276" 12094' ~ ~ I 11926' H 8..1\1D LOGGBJ 04/30/07 I PERFORA TION SUM\,1ARY REF LOG: PDC GRlCa... on 07/14/03 ANGLE AT TOP PERF: 9 deg @ 12304' I 12100' '-tEST TOP OF ŒNENT (08/15/07) I INrrlAL PERF - CHARGE 2906 POWERJET, HSD, PENETRATION: 27", HOLE: 0.36", PHASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL IMD) Opn/Sqz DATE I 2-7/8' 6 12304 - 12384 S 08/15/07 PBTDI 12420' I 4-112" LNR, 12.6#, 13CR-80 VAM·ACE, 12424' .0152 bpf, 10 = 3.958" I I I I I 19-5 I I I I I I DATE 07/15/02 03/21/03 07/18/03 11/04/05 04/30/07 05/01/07 REV BY COMrvENTS JAS INIT COM PLETION FM ANAL COMPLETION EMF ADD PERFS BJM NEVV FORMAT WRRfPJC 8..1\1D LOGGED 1 W8..LHEAD WRRlTLH GL DEPTH CORRECTION DA lE REV BY 08115/07 GLMI PJ P&A COM\>1B'JTS NORTHSTAR W8..L: NS16 PERMrr No: ~021270 AA No: 50-029-23096-00 SEe ii, T13N, R13E, 1199' NSL & 645' W8.. BP Exploration (Alaska) 2008 Northstar Drilling Plans • . Page 1 of ~~ -_. Maunder, Thomas E (DOA) From: Kara, Danny T[Danny.Kara@bp.com] e'1 r~a ^`a~ i7` `J Sent: Friday, September 07, 2007 11:18 AM Subject: 2008 Northstar Drilling Plans If you're interested in the general plans for the upcoming drilling season at Northstar, please read on. We plan to start well operations with Nabors 33E on January 15~', 2008. The first well will be a sidetracking operation in NS16; projected length of time on this well is estimated at 36 days. The second and final well will be the re-entry of NS34, the ILX well that was attempted last winter drilling season. We shauld start NS34 about February 20th, lasting approximately 38 days, to finish up by late March, giving us approximately 1 month contingency time before May 1St end of ice travel. Ice road construction will begin as soon as possible (Dec 1 St) with aggressive flooding, with the intent of creating ice thickness great enough to suppo~t heavy traffic (SLB cementer) no later than January 20~'. The island will not be re-supplied with drilling equipment this year - we will support drilling activities with #he ice road. There will be some limited barging to move equipment necessary for rig maintenance. Nabors crews (~20) will be on the island mid September to early October for -3 weeks to execute summer maintenance. When the major components of maintenance are complete, Nabors crews will leave the island unfil ~mid November. From mid November we will begin fully sta~ng the rig/G&I, to continue rig maintenance until rig acceptance on January 15~'. We are setting up the Chugach Camp at West Dock to hause a good portion of the drilling crew with the remainder of the crew staying on the island. I will be sending out information specific to the individuak wells, summarizing the results of the NS33 & NS34 review, probably to a smaller distribution. Please feel free to forward this e-mail to anyone else who needs to be aware of our plans. I.)an Kara Engineering Team Lead Narthstar/Milne Point/Endicott Drilling 564-5667 (offce} 240-8047 (cell) ~~'a~~~~ ~t~} = 20G~ 2/7l2008 NS-16 P&A at Northstar Island e Page 1 of 1 e Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 09, 20077:26 AM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: NS-16 P&A at Northstar Island à()(}- \ d" Paul and Dan, I agree that your plan is within the scope of the approval. One item to remember is that since there will be some length of time between the surgical plugging and the rig work is that the well will be considered suspended. When the work is accomplished, a 407 should be submitted documenting the work and the status change. When the remaining work on the sundry is resumed with the rig, some notice of that start up should be given. Likely, an email will suffice. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Wednesday, August 08,20074:26 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: NS-16 PM at Northstar Island SCANNED AUG 0 9 2007 Tom, Last year we (bp) received Sundry Approval # 306-334 (on 10-03-2006) to P&A the perforations on NS-16 in preparation for a sidetrack that we planned to drill during the 2006-2007 drilling season. Due to the events with NS-34 and NS-33, this did not happen during the 2006-2007 season. We now plan to drill the sidetrack during the 2007-2008 drilling season and desire to do some of the work before rig start-up. The sundry covers the P&A of the perforated interval, cutting the tubing, pulling the completion, setting a bridge plug in the 9-5/8", cutting and pulling the 9-5/8" above the bridge plug, and bringing TOC up into the 13-3/8" casing in preparation for the sidetrack. Our intent in the near future (the coming week) is only to abandon the perforations. The only thing that has changed about this operation is that we now plan to place the cement with coil, as this will be more "surgical" than the full-bore cement P&A down the tubing that was planned last year. The new TOC will be at 12180', which is 124' above the uppermost perforation. This will help us insure that our tubing cut, when it takes place, will be below the CiDRA mandrel, and all the fibre optic cable will come out with the tubing. Its just cleaner. I think this is within the scope of the existing Sundry, but I wanted to make sure that this is so. Best Regards. Paul Hanson ACT! Drilling Engineer 8/9/2007 bp . . Date 07-06-2007 Transmittal Number:92896 óbé)- I;;Y+ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type NS16 04-30-2007 SCH 1 11775 12380 CEMENT BOND LOG - FINAL ULTRASONIC CORROSION NS33PB1 04-29-2007 SCH 2 100 5500 USIT - FINAL TRUE VERTICAL SUB SEA VISION RESISTIVITY - FIELD NS33PB1 03-30-2007 SCH 1 200 23236 VERSION TRUE VERICAL VISION RESISTIVITY - FIELD NS33PB1 03-30-2007 SCH 1 200 23236 VERSION MEASURED DEPTH VISION RESISTIVITY - FIELD NS33PB 1 03-30-2007 SCH 1 200 23236 VERSION TRUE VERTICAL SUB SEA VISION RESISTIVITY - FIELD NS33PB2 04-09-2007 SCH 1 200 23460 VERSION TRUE VERTICAL VISION RESiSTiVITY - FIELD NS33PB2 04-09-2007 SCH 1 200 23460 VERSION MEASURED DEPTH VISION RESISTIVITY - FIELD NS33PB2 04-09-2007 SCH 1 200 23460 VERSION TIGHT HOLE RAW FIELD NS33PB1 03-30-2007 SCH 1 203 23236.5 DATA CD ROM TIGHT HOLE RAW FIELD NS33PB2 04-09-2007 SCH 1 203 23459.5 DATA CD ROM ~~ RECEIVED) Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data CenterS~ JUL 1 ,() 2007 o ~ Z007 iiJas1œ on & Gas Coos. COi'nrniS5ion Ar.d1orage Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC ..... .. .. DNR BPXA (no CD ROM) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . Date 05-24-2007 Transmittal Number:9289 I BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ô 'J--1 :J.. 7 NS- ,'(p I Log Top SW Name Date Contractor Run Depth Bottom Depth LoCI Type NS13 03-31-2007 SCH MEMORY COIL FLAG PERFORATION RECORD NS13 04-16-2007 SCH WITH GAMMA RAY JEWELRY LOG GAMMA RAY NS16 04-30-2007 SCH COLLARS PERFORATION RECORD NS12 04-17 -2007 SCH WITH GAMMA RAY NS19 04-24-2007 SCH PRODUCTION PROFILE I 0 l - O<¡çÇ;, \ ~-I¡¡)1- - 08-116 -' o d -,;)0'1- Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center RECEIVED MAY 2 9 Z007 Attn: Cheryl Ploegstra Doug Chromanski Ignacio Herrera Kristin Dirks Christine Mahnken pJaska Oil & Gas Cons. Commission Anchorage SCANNED MAY 3 1 2007 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . FRANK H. MURKOWSK1, GOVERNOR ALASIill OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS16 Sundry Number: 306-334 , --ç"A-ìt,H\ì'''n- i.~-)}\-. _~:¡~'1:..J=,;'! .."" _ - -. ,;..- 1_.,.- '\oI{,.;¡:~4::~. C t~' Dear Mr. Archey: Enclosed is the approved Application for Sundry Apprôvalrelating -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 23rcl clay falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~ day of October, 2006 Enel. ÐÖ8-ld7 .áJ c/J /°/'3/£ IIPe, j¡zI:J/Ob STATE 6F ALASKA _ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 R eøE It.tHI)DD tC SEP 2 9 2006 1. Type of Request: g Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well g Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2, Operator Name: 4, Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 202-127 / 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23096-00-00 ./ 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: NIA NS16 Spacing Exception Required? DYes 181 No ./ 9. Property Designation: 110. KB Elevation (ft): 11. Field 1 Pool(s): ADL 312799 KBE = 56.46' Northstar Unit 12> <i>} i.·.. .}} ... .......... .> i.· .vv¡;;;LL \"'.1.. ''\ILJI i<i .}. cr.····.·...i C}i}··...r}}, (........ }··0c"<}0 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12424 11148 12420 11144 None None Casino Lenoth Size MD TVD Burst Collaose Structural Conductor 201' 20" 201' 201' 4260 2590 Surface 3450' 13-3/8" 3494' 3200' 4930 2270 Intermp.diate Production 10392' 9-518" 10435' 9288' 6870 4760 Liner 1829' 7" 10265' - 12094' 9139' - 10824' 7240 5410 Liner 505' 4-1/2" 11919' - 12424' 10655' -11148' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 12304' - 12384' 11030' - 11109' 4-112",12.6# 13Cr80 11929' Packers and SSSV Type: 7" x 4-112", Baker S-3 Perm Packer I Packers and SSSV MD (ft): 11880' 4-1/2" TRM-4E SSSV 972' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch 181 Detailed Operations Program o Exploratory 181 Development o Service 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: December 1, 2006 OOil o Gas o Plugged ~ Abandoned 17. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Pat Archey Title Senior Drilling Engineer ßi Prepared By Name/Number: Signature cLcL'-? Phone 564-5803 Date 1-2 fP -db Sondra Stewman, 564-4750 / Commission Use On Iv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:::J{Y IJ _ d n JI - o Plug Integrity ~OP Test D Mechanical Integrity Test 0 Location Clearance Other: Te c., t- BOrE V, S"ooo f~' Subsequent Form Required: to - 4U?r RBDMS 8FL OCT () 4 2DDfi ( APPROVED BY /()"~'ob Approved Bv: /::OMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 ORI~NÃ( , Submit In Duplicate Alaska Oil & Gas Cons. Commission Anchorage . . bp ~.~ ,\~f.'~. --...~ ~...-- ~4:- ~4:-- ....~ ~.. .. ~\~~~\... "~ To: Winton Aubert - AOGCC BP Exploration Alaska Inc. Date: September 15, 2006 From: Paul Hanson Northstar Drilling Engineer Subj ect: NS16A Application for Sundry Permit - Plug and Abandonment of NS16, decompletion with preparation to sidetrack to a new bottom- hole location. API #50-029-23096-00 Reference: Sundry approval is requested to plug and abandon the original NS 16 production interval in preparation for a sidetrack from the existing 13-3/8" surface casing. To accomplish this objective, approximately 8 bbl* of 15.8 ppg Class G cement will be bullheaded down the existing tubing to a height of approximately 260 f1. above the existing perforations. The 4-1/2", 12.6# 13Cr-80 production tubing will be cut above the uppermost packer and pulled. A bridge plug will be set in the 9-5/8" casing ~ 100 feet below the surface casing depth. The 9-5/8" casing will be cut above the bridge plug and pulled. A cement plug will be set which covers the 9-5/8" stub and extends approximately 100 feet above the 13-3/8" shoe (~200' total length of cement plug). The plug will be dressed off in preparation for sidetracking to a new bottom-hole location. (See attached Wellbore Diagrams) *exact volume to be pumped will be determined after injectivity test. NS16 Brief Historv of Operations NS 16 was originally drilled and completed in June, 2003. Since perforating and testing in Q3 and Q4 of 2004 the well has been plagued with high GOR and low oil rate due to gas coning and/or channeling. I -Oil -Gas -\Nater NS16 Cum Oil (bbls): Cum Gas Cun~ W.rter 1,480,21"1 11,478,378 122,510 Spud First 6128¡D2 1 00000 1 0000 I !II 1 0000 .. ¡.:; ... ;:, :¡" 1 000 å. 1000 § å, 100 Ð ~ 10 "" 100 MMMMMMM~v~.v~~~v~vv~~~~~~~~~~~~~~W~øWW~W~ OOOOQOOOOOOoooooooooooooooooooooooooooooo 00000000000000000000000000000000000000000 ~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~.~~.~~~~~ ~~~~~~~~@~@@~~~~§~£~~~~~",~~~~~5~g~~~gg~~~~ ~~~~S~~-NM~~~~~~~~~ ~~ ~ ~ ~W~~~ ,~,,~~~~ ~ . . The purpose of the sidetrack is to re-complete NS 16 at a bottomhole location less prone to gas influx. Pre-Ri2 Work: 1. Test the 9-5/8" Pack-off to 5,000 psi. 2. MIT the inner annulus to 4,200 psi. 3. Full-bore cement squeeze with 15.8 ppg Premium Class G cement down the existing tubing leaving approximately 260' of cement above the uppennost perforation (estimated TOC at ~ 12,044' MD). Estimated volume is 8 bbl- assuming pushing at least 1 bbl into the perfs. / Hold pressure and WOC per SLB recommendations. Note: An Injectivity Test should be conducted prior to pumping cement. The cement should be preceded by 50 bbl of seawater. Ideally, we would like TOC to be below the CiDRA mandrel at 11,833' in order that the mandrel can be recovered when the tubing is pulled. If TOC is higher than the mandrel will not be recovered. 4. RU wireline. Drift tubing and tag TOC. Pressure test tubing to 2,000 psi to confinn plug. 5. RU e-line with CCL and Jet-cutter. IfTOC allows, cut the 4-112" tubing below the uppennost X-nipple at 11,859' and above the 7"x 4-112" packer at 11,880'. Circulate 9.3 ppg brine w/300' of diesel rreeze protection. IfTOC is high, cut as close to TOC as possible - not / at the location of a coupling. 6. Install BPV and test down IA with 500 psi. Remove wellhead housing, flow lines and sweeps. RiQ Operations: 1. 2. MIRU. Pull BPV. Circulate well to 9.3# KWF thrujet-cut, displacing diesel FP. se~~y. Test rrom above and below (if possible) to 1,000 psi. ND tree. NU test BOPE ~ to ~ psi. Pull TWC. Pu d LD the 4-112" tubing string to the cut. RU slickline and drift 9-5/8" casing using Gauge Ring/Junk Basket/CCL. PU drillpipe. RIH with pennanent bridge plug to approximately 3,600' (actual depth detennined by CCL) and set. Pressure test to 2,000 psi to demonstrate plug set. POOH. RIH with a hydraulic multi-string casing cutter. Cut the 95/8" casing approximately in the middle of the full joint above the bridge plug. POOH. PU and Spear the 9-5/8" casing and unseat/recover mandrel hanger. RU casing crew. Pull/ and lay down 9-5/8" casing. RIH w/open-ended drillpipe and lay in approximately 40 bbl of 15.8 ppg Class G cement. / The cement should cover the 9-5/8" stub with TOC approximately 100' up inside the 13- 3/8" casing (~200' plug). POOH. RIH and dress cement plug off in preparation for sidetrack. 3. 4. 5. 6. 7. 8. 9. TREE = ABB-VG/5-1/8" 5K W8..LHEAD = ABB-VGI13-5/8" MUL TlBOWL 5KS ACTUA TOR = ( A(. lS ., KB. 8..EV = 56.46' BF. 8..EV = 40.56' (CB 15.9') 1-f4-1/2" TRM-4ESSSV, 10 = 3.813" I KOP= . 972' Max Angle = 33° @ 9614' :~ i-----! 1587' H 13-3/8" TAM PORT COLLAR I Datum MD = Datum 1VD = 113-3/8" CSG, 68#, L-80 BTC, ID:: 12.415" I 3494' -µ .. GA S LIFT MA NDRB...5 ST MD 1VD DEV TYÆ VLV LATCH PORT DATE L 1 4981 4483 27 Minimum ID = 3.725" @ 11915' 2 6453 6453 26 4-1/2" XN NIPPLE I TOP OF 7" LNR I 10265' ~2S 8~ 19-5/8" CSG, 47#, L-80 BTM-C, ID:: 8.681" I 10435' I 11833' 1-14-1/2" FIBEROPTICTRANSDUCER,ID=3.945" I 111836' ELM H4-1/2" FIBER OPTIC TRANSDUCER, 10:: 3,945" I I I 11859' "'4-1/2" x NIP, 10::: 3.813" I I ~ I 11880' 1-17" X 4-1/2" PKR I ~ I r 11903' 1-14-1/2" x NIP, 10:: 3.813" I I ~I I 11915' 1-14-1/2" XN NIP, 10 = 3.725" I I TOP OF 4-1/2" LNR I 11919' ~ . ~ 14-1/2" TBG, 12.6#, 13CRVAM·ACE 11926' l- I 11926' 4-1/2" S8..F ALIGNING WLEG I .0152 bpf, 10 = 3.958" ID = 3.850" IT' LNR, 26#, L-80 HYDRIL 521, ID = 6.276" I 12094' -µ r.. I H 8..MD TT NOT LOGGED? I ÆRFORA TION SUMMARY REF LOG: PDC GRlCCL on 07/14/03 ANGLE A T TOP PERF: 9 deg @ 12304' INITIAL PERF - CHARGE: 2906 POWERJET, HSD, PENETRATION: 27", HOLE: 0.36", A-iASE: 60 DEG. Note: Refer to A'oductìon DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8 6 12304 - 12384 0 07/15/03 Iì ¡PaTD I 12420' 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE 12424 ' .0152 bpf, /0 = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07115102 JAS INlT COM PLETION W8..L: NS16 03/21103 FM ANAL COMPLETION PERMIT No: 2021270 07/18/03 EMF ADD PERFS API No: 50-029-23096-00 11/04/05 BJM NEW FORMAT BP Exploration (Alaska) NS16 S. NOTES: ***4·1/2" CHROME TBG & LNR*** TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 0- 133/8" TAM Port Collar at +/-1587'MD 13 3/8", 68#/ft, L-80, BTC @ 3494' 9-5/8" 47# L-80 BTM-C @ 10435' 4.5" X NIPPLE, @ 11903' 3.813" ID 4.5" XN NIPPLE, @ 11915' 3.725" ID 4.5" WLEG, @ 11926' 3.958" I 7", 26#/ft L-80, BTC-M @ 12094' PBTD @ 12420' MD TD @ 12424' MD DATE 9/23/06 .NS16-pandA REV. BY COMMENTS PMH NS16 Pro osed P and A ORIG.KB. ELEV = 55.9' KB-B = 40,2' CB, EL = 16.0' Toe PLUG @ -3394'MD 7" LINER TOP @ 10265' 7" PACKER,13 Cr @ 11880' MD 4.5" LINER TOP @ 11919' MD 4.5" PROPOSED TOP OF CEMENT @ 12044' MD Top of Squeezed Perfs @ 12304' MD 4.5", 12.6#,13CrVamAce Northstar WELL: NS16 API NO' 50-029-23096-00 BP Exploration (Alaska) 0.0.1 - 1\8-16 01 -- Wiler~e NCRTHSrAA QL 100 - m Om 01 Prod (M'vtJbI ) G3s/0I R:mo (Mcflbbl ) Wiler QJ! ( %) 01 10. Prod 5 0.5 0.1 0.05 AUG SEP OCT NO\! CEC JAN FEB ~R APR i\fII:\y JUN JUL AUG SEP œT NO\! DEe JAN FEB Ml\R APR NAY JUN 2004 2005 2005 Dal:e & ??oo Ô ~500 $ '" a:: ð 100 00 10 dX)4 05 œ A1æe cj ti te Et.JR Fcreœ¡t Eroeá B¡ . Ràe Fcreœ¡t Date tJ7 . . Date: 08-22-2006 Transmittal N umber:92819 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ð},'Jì SW Name Date Contractor Loq Run Top Depth Bottom Depth Loq Type NS08 03-28-2006 SCH PERF RECORD NS08 06-01-2006 SCH PERF RECORD NS14A 01-20-2006 SCH DEPTH CONTROL NS16 05-05-2006 SCH PRODUCTION PROFILE PERF RECORD WITH NS31 06-05-2005 SCH GAMMA RAY NS30 04-15-2006 SCH JEWELRY LOG NS30 04-02-2006 SCH JEWELRY LOG PERF RECORD WITH NS30 04-14-2006 SCH GAMMA RAY NS19 05-15-2006 SCH PERF RECORD oU Plea e ign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center ~ L~ Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Ignacio Herrera Doug Chromanski SCANNE[} AUG 3 1 2006 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc J /"\ ~- (~V'i tj-- DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2021270 Well Name/No. NORTHSTAR UNIT NS-16 Operator BP EXPLORATION (ALASKA) INC Sf~J.. ~crJw.. ~ ~ API No. 50-029-23096-00-00 MD 12424/" TVD 11156 __ Completion Date 7/14/2003 / Completion Status - - ------ ---~ --- -------~ REQUIRED INFORMATION Mud Log Yes Samples No - --------- - -----------------~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GYRO, GR, CCL, RES, DIR, PWD, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset ~edlFrm~Numbe~:g i~ See Notes I , L-Rpt ~D '~ ~ ¡.co-g Log Log Scale Media 2 BM Run No 1 Directional Survey Directional Survey ~L09 ,....MUd Log Gamma Ray 5 BM 2 BM 2 Blu I ~ See Notes Casing collar locator ~õ See Notes : } ~D C Lis 12026 LIS Verification ED C Pds 12026 I nd uction/Resistivity ~ C Pds 12026 I nd uction/Resistivity !ED C Pds 12026 Neutron I !. ED C Pds 12026 Neutron ~ ~c Lis 12056 LIS Verification ;ED C Pds 12056 Casing collar locator 5 Col 2 Blu 25 Final 25 Final 25 Final 25 Final 25 1-01L Current Status 1-01L UIC N Directional ~ (data taken from Logs Portion of Master Well Data Maint) Interval OH/ -" Start Stop CH Received Comments 201 12105 Open 12/5/2002 201 12105 Case 9/5/2002 end of well report 0 12105 Open 8/5/2002 0 12105 Open 8/5/2002 201 12105 Open 12/5/2002 201 12105 Open 12/5/2002 40 1 0985 Case 1/3/2003 201 12105 Case 9/5/2002 mud log data ASCII files 40 1 0985 Case 1/3/2003 201 12105 Case 9/5/2002 mudlog data ASCII files 200 12430 Open 8/22/2003 MWD/MAD 12070 12430 Open 8/22/2003 MWD/MAD - Resistivity, Borehole Corrected 12070 111 00 Open 8/22/2003 MWD/MAD - Resistivity, Borehole Corrected 12070 12430 Open 8/22/2003 MWD/MAD - Density Neutron 12070 11100 Open 8/22/2003 MWDIMAD - Density Neutron 40 10985 Case 7/29/2003 40 1 0985 Case 7/29/2003 Primary Depth Log, GR, CCL-MD DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2021270 Well Name/No. NORTHSTAR UNIT NS-16 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23096-00-00 MD 12424 TVD 11156 Completion Date 7/14/2003 Completion Status 1-01L Current Status 1-01L UIC N -- --- ---- . Log 12056 Casing collar locator 25 Blu 40 10985 Case 7/29/2003 Primary Depth Log, GR, ( CCL-MD ~ Directional Survey 0 12328 Open 4/15/2003 : Rpt Directional Survey 0 12424 Open 4/15/2003 Geodetic ¡~D Directional Survey 0 12424 Open 4/15/2003 Geodetic ~ Directional Survey 0 12328 Open 4/15/2003 Report: Final Well R 0 0 1 0/21/2003 þ-- See Notes Col 201 12424 Case 1 0/21/2003 Rig Monitoring - in Well --~ History File w/End of Well Report ----- --- - ----- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? yø Chips Received? Y / N Daily History Received? 0N ® Formation Tops Analysis Y / N Received? --- - ----------- -----.----- Comments: ~ ---------- Ik ( Date: :2L~ - --- - ---------~ Compliance Reviewed By: ) ) Date: 09-21-2005 Transmittal Number:92674 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data supersedes all previously delivered data. Please replace all previously delivered data listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS22 07/13/2005 SCH FINAL SURVEY REPORT NS25 07/13/2005 SCH FINAL SURVEY REPORT NS20 07/13/2005 SCH FINAL SURVEY REPORT NS08 07/13/2005 SCH FINAL SURVEY REPORT NS23 07/13/2005 SCH FINAL SURVEY REPORT NS24 07/13/2005 SCH FINAL SURVEY REPORT NS25PB1 07/13/2005 SCH FINAL SURVEY REPORT NS25PB2 07/13/2005 SCH FINAL SURVEY REPORT NS06 07/13/2005 SCH FINAL SURVEY REPORT NS20PB1 07/13/2005 SCH FINAL SURVEY REPORT NS19 07/13/2005 SCH FINAL SURVEY REPORT ~16 07/13/2005 SCH FINAL SURVEY REPORT NS18 07/13/2005 SCH FINAL SURVEY REPORT NS17 07/13/2005 SCH FINAL SURVEY REPORT NS21 07/13/2005 SCH FINAL SURVEY REPORT NS13 07/13/2005 SCH FINAL SURVEY REPORT NS15 07/13/2005 SCH FINAL SURVEY REPORT NS12 07/13/2005 SCH FINAL SURVEY REPORT NS09 07/13/2005 SCH FINAL SURVEY REPORT Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ;) OÌ-~ / ~) b"p ) BPXA WELL DATA TRANSMITTAL NS14 07/13/2005 SCH NS07 07/13/2005 SCH NS27 07/13/2005 SCH Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra ACT Data Manager Jim Seccombe BPXA Howard Okland AOGCC Jason Smith Murphy Exploration Tim Ryherd DNR Don Chromanski MMS Terrie Hubble SSD (1 Report) (1 Report) (2 Reports + disk) (1 Report + disk) (1 Report + disk) (1 Report + disk) (1 Report) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ') Date: 09-21-2005 Transmittal Number:92674 FINAL SURVEY REPORT FINAL SURVEY REPORT FINAL SURVEY REPORT ) \ l Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Tuesday,August09,2005 To Whom It May Concern: I n response to a request by BP, to look into improving TVD accuracy, it was determined that the wells on the Northstar pad could be further enhanced by applying a SAG correction. This is merely a further analysis of how the MWD tool was oriented in the BHA, and using this information to improve upon the survey. Due to BHA configuration, the MWD tool mä~t l's'"äg' between two stabilizers. This 'sagging' effect may cause the MWD tool to have an inclination difference in reading that was greater than ± 0.10 inclination, relative to the tool being parallel with the wellbore. Therefore, the survey is further improved on inclination accuracy by adding or subtracting this W offset to inclination readings on the original survey, and ultimately better TVD accuracy is achieved. ~ 3 C" CD '"'II cc CD '"'II We have examined the list of surveys, and corrected them. NS06 NS07 NS08 NS09 NS12 NS13 NS14 NS15 NS16..."" NS17 NS18 NS19 NS20PB1 and--NS20 NS22 NS23 NS24 NS25PB1, NS25PB2, and NS25 NS27 ." '"'II <' I» - CD NS21 All other surveys on the Northstar pad not listed here either did not require a SAG correction, had the correction applied while drilling, or have Gyro surveys as definitive. As the accuracy of the survey has improved, these surveys should be used to replace previously defined and distributed surveys, for the list above. For any questions or concerns, you can contact me about these surveys and the procedure to improve them. Regards, c. Scott Delapp DEC Manager / Survey Engineer Schlumberger - Alaska Phone: 907-273-1766 ~ D) -... I Á- 7 ~ôÀ-\~7 Generated 7/13/20053:00 PM Page 1 of 4 NS16\NS16\NS16\NS16 Sag Corr SurveyEditor Ver SP 1.0 Bld( doc40x_56) bp NS16 Survey Report Schlumberger Report Date: June 2, 2005 Survey / DlS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska , Vertical Section Azimuth: 267.800° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF / NS16 TVD Reference Datum: KB Well: NS16 TVD Reference Elevation: 56.46 ft relative to MSL Borehole: NS16 Sea Bed I Ground level Elevation: 15.57 ft relative to MSL UWUAPI#: 500292309600 Magnetic Declination: 26.179° Survey Name I Date: NS16 Sag Corr / January 28,2003 Total Field Strength: 57548.366 nT Tort I AHD I DDlI ERD ratio: 111.420° /5212.23 ft / 5.811/ 0.468 ·.Magnetic Dip: 80.964° --.. Grid Coordinate System: NAD27 Alaska State Planes, Zone 04. US Feet Declination Date: July 01, 2002 location lal/long: N 70 29 28.174, W 148 41 35.878 Magnetic Declination Model: BGGM 2004 location Grid N/E YIX: N 6030971.560 ftUS. E 659829.810 ftUS North Reference: True North Grid Convergence Angle: +1.23170678° Total Corr Mag North -> True North: +26.179° Grid Scale Factor: 0.99992902 local CoorqinatesReferenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DlS Northing Easting latitude longitude Depth Section Departure (fI) ( deg ) ( deg ) (fI) (fI) (fI) (fI) {fI } ( fI) (fI) ( deg/1 00 fI ) ( flUS) (flUS) RTE 0.00 0.00 0.00 -56.46 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6030971.56 659829.81 N 702928.174 W 1484135.878 First GYD GC SS 50.00 0.94 282.89 -6.46 50.00 0.40 0.41 0.41 0.Q9 -0.40 1.88 6030971.64 659829.41 N 702928.175 W 14841 35.890 100.00 1.39 278.89 43.53 99.99 1.39 1.43 1.43 0.28 -1.40 0.91 6030971.81 659828.41 N 702928.177 W 14841 35.919 150.00 2.24 275.10 93.50 149.96 2.95 3.01 3.01 0.46 -2.97 1.72 6030971.95 659826.83 N702928.179 W1484135.965 200.00 2.39 275.77 143.46 199.92 4.95 5.03 5.02 0.65 -4.98 0.30 6030972.10 659824.82 N 702928.181 W 14841 36.024 269.00 2.54 273.98 212.40 268.86 7.90 8.00 " 7.99 0.90 -7.94 0.24 6030972.29 659821.85 N 702928.183 W 14841 36.111 361.00 2.49 280.72 304.31 360.77 11.87 12.03 12.02 1.41 -11.94 0.33 6030972.72 659817.85 N 702928.188 W 14841 36.229 450.00 2.76 280.11 393.22 449.68 15.85 16.10 16.09 2.15 -15.94 0.30 6030973.37 659813.82 N 702928.195 W 14841 36.347 540.00 3.34 277.39 483.09 539.55 20.55 20.89 20.88 2.87 -20.68 0.66 6030973.98 659809.08 N 702928.202 W 14841 36.486 630.00 4.93 271.58 572.85 629.31 27.00 27.38 27.35 3.31 -27.14 1.82 6030974.29 659802.60 N 702928.207 W 14841 36.677 ---.. 720.00 5.79 272.70 662.46 718.92 35.38 35.78 35.73 3.63 -35.54 0.96 6030974.43 659794.20 N 702928.210 W 14841 36.924 810.00 7.38 276.28 751.86 808.32 45.62 46.10 46.04 4.48 -45.83 1.82 6030975.05 659783.90 N 702928.218 W 14841 37.226 Last GYD GC SS 843.00 7.95 279.91 784.57 841.03 49.95 50.50 50.44 5.10 -50.18 2.27 6030975.58 659779.54 N 702928.224 W 14841 37.354 First MWD+SAG 933.38 9.34 286.36 873.92 930.38 63.01 64.07 63.91 8.24 -63.38 1.87 6030978.44 659766.28 N 702928.255 W 14841 37.743 1028.89 11.60 282.98 967.83 1024.29 79.63 81.42 81.15 12.58 -80.17 2.45 6030982.42 659749.39 N 702928.298 W 14841 38.237 1123.71 13.90 274.23 1060.32 1116.78 100.15 102.31 102.02 15.57 -100.82 3.16 6030984.95 659728.68 N 702928.327 W 14841 38.845 1219.39 15.75 271.83 1152.81 1209.27 124.53 126.79 126.39 16.83 -125.27 2.04 6030985.69 659704.22 N 702928.340 W 14841 39.564 1314.14 16.66 273.18 1243.79 1300.25 150.88 153.23 152.74 17.99 -151.68 1.04 6030986.29 659677.79 N 702928.351 W 1484140.341 1409.45 18.76 274.53 1334.58 1391.04 179.70 182.22 181.70 19.96 -180.60 2.24 6030987.63 659648.83 N702928.371 W1484141.192 1503.93 20.84 272.53 1423.47 1479.93 211.55 214.22 213.67 21.90 -212.54 2.32 6030988.89 659616.86 N 702928.390 W 14841 42.132 1599.00 23.64 269.29 1511.47 1567.93 247.46 250.19 249.51 22.41 -248.51 3.21 6030988.63 659580.90 N 702928.395 W 1484143.191 1694.87 26.08 265.29 1598.45 1654.91 287.74 290.47 289.46 20.44 -288.74 3.09 6030985.79 659540.72 N 702928.375 W 1484144.374 1790.01 28.82 262.16 1682.88 1739.34 331.46 334.32 332.67 15.60 -332.31 3.25 6030980.01 659497.27 N 70 29 28.328 W 14841 45.657 Generated 7/13/2005 3:00 PM Page 2 of 4 NS16\NS16\NS16\NS16 Sag Corr SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) ( deg ) ( deg ) (ft ) (ft) (ft) (ft) (ft ) (ft) (ft) ( deg/100 fI ) ( flUS) (flUS) 1882.86 29.69 264.05 1763.88 1820.34 376.68 379.69 377 .49 10.16 -377 .35 1.37 6030973.61 659452.36 N 702928.274 W 1484146.982 1978.38 30.93 266.35 1846.35 1902.81 424.83 427.89 425.42 6.15 -425.38 1.78 6030968.56 659404.43 N 70 29 28.235 W 148 41 48.395 2072.62 31.50 268.16 1926.95 1983.41 473.66 476.73 474.17 3.81 -474.16 1.16 6030965.18 659355.71 N 702928.212 W 1484149.831 2168.92 30.96 269.24 2009.29 2065.75 523.58 526.66 524.08 2.68 -524.07 0.81 6030962.97 659305.84 N 70 29 28.200 W 14841 51.300 2265.53 30.80 270.92 2092.21 2148.67 573.12 576.24 573.66 2.74 -573.65 0.91 6030961.97 659256.27 N 702928.201 W 14841 52.759 2362.71 30.66 271.72 2175.74 2232.20 622.69 625.90 623.31 3.89 -623.30 0.44 6030962.05 659206.62 N 702928.212 W 14841 54.220 2458.01 31.65 268.49 2257.30 2313.76 671.94 675.19 672.60 3.96 -672.58 2.04 6030961.06 659157.35 N 702928.213 W 14841 55.670 2552.39 31.30 269.41 2337.80 2394.26 721.20 724.47 721.86 3.05 -721.85 0.63 6030959.10 659108.11 N702928.204 W1484157.120 2648.36 31.39 270.86 2419.76 2476.22 771.08 774.39 771.78 3.17 -771.77 0.79 6030958.14 659058.20 N 7029 28.205 W 14841 58.589 2743.14 31.60 267.08 2500.59 2557.05 820.56 823.89 821.26 2.28 -821.26 2.09 6030956.18 659008.75 N 702928.196 W 148420.045 /- 2838.55 31.72 266.63 2581.80 2638.26 870.64 873.97 871.26 -0.47 -871.26 0.28 6030952.36 658958.82 N 702928.169 W 148421.516 2933.88 29.79 267.61 2663.72 2720.18 919.38 922.71 919.95 -2.93 -919.94 2.09 6030948.86 658910.21 N 702928.145 W 148422.949 3029.84 29.89 267.67 2746.96 2803.42 967.12 970.46 967.66 -4.90 -967.65 0.11 6030945.87 658862.56 N 702928.125 W 148424.353 3124.90 30.51 268.03 2829.11 2885.57 1014.94 1018.28 1015.46 -6.69 -1015.43 0.68 6030943.05 658814.83 N 702928.108 W 148425.759 3221.44 31.26 267.72 2911.96 2968.42 1064.50 1067.83 1064.99 -8.53 -1064.95 0.79 6030940.14 658765.36 N 70 29 28.090 W 148427.216 3316.59 31.97 268.30 2992.99 3049.45 1114.37 1117.71 1114.85 -10.26 -1114.80 0.81 6030937.34 658715.57 N 70 29 28.073 W 148428.683 3409.86 31.70 268.34 3072.23 3128.69 1163.57 1166.91 1164.04 -11.70 -1163.98 0.29 6030934.84 658666.44 N 702928.058 W 1484210.130 3446.83 31.52 269.04 3103.72 3160.18 1182.94 1186.29 1183.41 -12.14 -1183.35 1.11 6030933.98 658647.08 N 702928.054 W 1484210.700 3602.01 31.19 267.68 3236.24 3292.70 1263.68 1267.03 1264.14 -14.45 -1264.06 0.50 6030929.94 658566.45 N 702928.031 W 1484213.075 3696.89 31.75 267.17 3317.16 3373.62 1313.21 1316.56 1313.65 -16.68 -1313.54 0.65 6030926.65 658517.03 N 702928.009 W 1484214.531 3793.31 31.93 266.19 3399.07 3455.53 1364.07 1367.43 1364 .46 -19.62 -1364.32 0.57 6030922.62 658466.33 N 702927.980 W 14842 16.026 3888.26 32.29 265.81 3479.50 3535.96 1414.51 1417.90 1414.86 ~23.15 -1414.67 0.43 6030918.01 658416.07 N 702927.945 W 1484217.507 3983.92 31.86 265.41 3560.55 3617.01 1465.27 1468.70 1465.56 -27.03 -1465.32 0.50 6030913.04 658365.52 N 702927.907 W 1484218.998 4079.27 31.59 264.37 3641.66 3698.12 1515.35 1518.83 1515.58 -31.50 -1515.25 0.64 6030907.50 658315.69 N 70 29 27.863 W 1484220.467 4173.31 31.01 263.69 3722.01 3778.47 1564.10 1567.69 1564.27 -36.58 -1563.84 0.72 6030901.38 658267.23 N702927.813 W1484221.897 4267.53 30.49 262.50 3802.98 3859.44 1612.10 1615.86 1_612.22 -42.36 -1611.67 0.85 6030894.57 658219.54 N 70 29 27.756 W 1484223.304 4363.74 30.33 261.74 3885.96 3942.42 1660.56 1664.56 1660.63 -49.04 -1659.91 0.43 6030886.86 658171.46 N 702927.690 W 1484224.724 ..- 4459.43 29.92 260.41 3968.73 4025.19 1708.26¡ 1712.58 1708.28 -56.49 -1707.35 0.82 6030878.39 658124.20 N 70 29 27.617 W 1484226.120 4555.46 29.59 260.40 4052.09 4108.55 1755.52 1760.24 175552 -64.43 -1754.34 0.34 6030869.44 658077.39 N 702927.539 W 1484227.502 4651.24 29.17 260.14 4135.56 4192.02 1802.10 1807.23 1802.11 -72.37 -1800.65 0.46 6030860.51 658031.26 N 702927.460 W 1484228.865 4746.57 28.52 259.67 4219.06 4275.52 1847.66 1853.22 1847.68 -80.43 -1845.93 0.72 6030851.48 657986.17 N 702927.381 W 1484230.198 4841.21 27.96 259.76 4302.43 4358.89 1891.99 1898.00 1892.06 -88.43 -1889.99 0.59 6030842.54 657942.29 N 70 29 27.302 W 1484231.494 4934.90 27.53 260.53 4385.35 4441.81 1935.22 1941.62 1935.34 -95.89 -1932.96 0.60 6030834.15 657899.49 N 702927.229 W 1484232.759 5027.97 26.94 260.58 4468.10 4524.56 1977.47 1984.21 1977 .66 -102.88 -1974.98 0.63 6030826.26 657857.64 N 70 29 27.160 W 1484233.995 5123.53 26.73 260.87 4553.37 4609.83 2020.28 2027.35 2020.54 -109.84 -2017.55 0.26 6030818.39 657815.23 N 702927.091 W 1484235.248 5217.67 26.77 262.36 4637.44 4693.90 2062.41 2069.72 2062.73 -116.01 -2059.47 0.71 6030811.32 657773.46 N 702927.030 W 1484236.481 5313.06 26.70 263.71 4722.63 4779.09 2105.17 2112.63 2105.55 -121.22 -2102.06 0.64 6030805.20 657730.99 N 702926.979 W 1484237.734 5406.09 26.70 264.73 4805.74 4862.20 2146.88 2154.43 2147.32 -125.43 -2143.65 0.49 6030800.10 657689.51 N 702926.938 W 1484238.958 5501.63 26.63 265.95 4891.12 4947.58 2189.72 2197.30 2190.18 -128.91 -2186.38 0.58 6030795.69 657646.86 N 70 29 26.903 W 1484240.215 5596.52 26.71 267.01 4975.92 5032.38 2232.30 2239.89 2232.77 -131.53 -2228.89 0.51 6030792.17 657604.42 N 70 29 26.877 W 1484241.466 5691.50 26.74 268.62 5060.75 5117.21 2275.01 2282.61 2275.47 -133.15 -2271.57 0.76 6030789.62 657561.79 N 702926.861 W 1484242.722 Generated 7/13/2005 3:00 PM Page 3 of 4 NS16\NS16\NS16\NS16Sag Corr SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical· Along Hole Closure Depth Section DePartUre NS 'EW DLS Northing Easting Latitude Longitude (ft) ( deg ) (deg) (ft) (ft) (ft) (ft ) (ft) . (ft) (ft) ( deg/100 ft ) (ftUS) (ftUS) 5786.77 26.70 269.16 5145.85 5202.31 2317.83 2325.44 2318.27 -133.98 -2314.40 0.26 6030787.87 657519.00 N 70 29 26.853 W 148 42 43.983 5881.06 26.44 269.60 5230.18 5286.64 2359.99 2367.62 2360.40 -134.44 -2356.57 0.35 6030786.51 657476.85 N 70 29 26.848 W 148 42 45.223 5976.44 26.34 270.58 5315.62 5372.08 2402.35 2410.01 2402.72 -134.37 -2398.96 0.47 6030785.66 657434.47 N 702926.849 W 1484246.471 6072.87 26.28 272.43 5402.06 5458.52 2445.00 2452.75 2445:32 -133.25 -2441.68 0.85 6030785.87 657391.73 N 70 29 26.860 W 1484247.728 6166.64 26.44 273.08 5486.08 5542.54 2486.48 2494.38 2486.74 -131.25 -2483.27 0.35 6030786.97 657350.12 N 702926.879 W 1484248.952 6261.78 26.23 272.74 5571.35 5627.81 2528.52 2536.59 2528.72 -129.11 -2525.42 0.27 6030788.21 657307.93 N 70 29 26.900 W 14842 50.192 6356.60 26.27 272.17 5656.39 5712.85 2570.31 2578.53 2570.47 -127.31 -2567.32 0.27 6030789.10 657266.01 N 702926.918 W 1484251.425 6453.98 26.22 272.09 5743.73 5800.19 2613.25 2621.59 2613.38 -125.71 -2610.35 0.06 6030789.78 657222.95 N 702926.933 W 1484252.692 6548.62 26.00 272.25 582K71 5885.17 2654.78 26q3.24 2654,88 -124.13 -2651.97 0.24 6030790.46 657181.31 N 702926.949 W 1484253.916 6643.75 26.50 272.22 5914.03 5970.49 2696.73 2705.31 2696.80 -122.49 -2694.02 0.53 6030791.20 657139.25 N 70 29 26.965 W 148 42 55.154 ,- 6738.20 27.02 271.76 5998.37 6054.83 2739.14 2747.84 2739.19 -121.02 -2736.52 0.59 6030791.76 657096.73 N 702926.979 W 1484256.404 6833.00 27.34 270.95 6082.70 6139.16 2782.36 2791.14 2782.40 -120.00 -2779.81 0.52 6030791.85 657053.43 N 702926.989 W 1484257.678 6928.58 27.60 270.40 6167.50 6223.96 2826.40 2835.23 2826.42 -119.48 -2823.89 0.38 6030791.42 657009.34 N 702926.994 W 1484258.975 7022.43 28.01 269.86 6250.52 6306.98 2870.14 2879.01 2870.15 -119.38 -2867.67 0.51 6030790.58 656965.58 N 70 29 26.995 W 148430.264 7119.26 28.66 268.82 6335.74 6392.20 2916.08 2924.97 2916.09 -119.91 -2913.62 0.84 6030789.06 656919.65 N 70 29 26.989 W 148431.616 7221.83 28.98 268.60 6425.61 6482.07 2965.52 2974.41 2965.53 -121.03 -2963.05 0.33 6030786.88 656870.26 N 70 29 26.978 W 148433.070 7315.05 28.73 268.62 6507.26 6563.72 3010.50 3019.40 3010.51 -122.12 -3008.03 0.27 6030784.82 656825.32 N 70 29 26.967 W 148434.394 7408.15 28.57 268.61 6588.96 6645.42 3055.13 3064.04 3055.14 -123.20 -3052.65 0.17 6030782.79 656780.73 N 70 29 26.956 W 148435.707 7503.39 28.33 268.63 6672.70 6729.16 3100.50 3109.41 3100.50 -124.29 -3098.01 0.25 6030780.72 656735.41 N 70 29 26.946 W 148437.042 7598.11 28.18 268.87 6756.13 6812.59 3145.33 3154.25 3145.34 -125.27 -3142.84 0.20 6030778.78 656690.62 N 70 29 26.936 W 148438.361 7694.13 28.05 268.57 6840.82 6897.28 3190.58 3199.50 3190.58 -126.28 -3188.08 0.20 6030776.79 656645.42 N 70 29 26.926 W 148439.692 7787.96 27.90 268.07 6923.69 6980.15 3234.59 3243.51 3234.59 -127.57 -3232.07 0.30 6030774.56 656601.46 N 702926.913 W 1484310.987 7889.62 27.54 267.73 7013.68 7070.14 3281.88 3290.80 3281.~8 -129.;30 -3279.33 0.39 6030771.81 656554.26 N 702926.895 W 1484312.377 7987.35 27.17 267.30 7100.48 7156.94 3326.78 3335.70 3p26.78 -131.25 -3324.19 0.43 6030768.90 656509.45 N 702926.876 W 1484313.697 8079.84 26.86 267.17 7182.88 7239.34 3368.79 3377.71 3368.79 -133.27 -3366.16 0.34 6030765.98 656467.54 N 70 29 26.856 W 1484314.932 8174.64 26.52 266.22 7267.58 7324.04 3411.36 3420.29 3411.37 -135.73 -3408.66 0.58 6030762.61 656425.10 N 70 29 26.832 W 1484316.183 8270.27 26.80 266.96 7353.04 7409.50 3454.26 3463.20 3454.26 -138.28 -3451.50 0.45 6030759.14 656382.34 N 70 29 26.806 W 1484317.443 - 8368.44 26.77 267.34 7440.68 7497.14 3498.50 3507.44 3498.50 -140.48 -3495.68 0.18 6030755.99 656338.21 N 70 29 26.785 W 1484318.744 8461.77 26.67 267.33 7524.04 7580.50 3540.46 3549.41 3540.47 -142.43 -3537.60 0.11 6030753.14 656296.35 N 70 29 26.765 W 1484319.977 8565.89 27.09 268.90 7616.91 7673.37 3587.53 3596.48 3587.54 -143.97 -3584.65 0.79 6030750.58 656249.35 N 702926.750 W 1484321.361 8661.33 27.68 269.48 7701.66 7758.12 3631.42 3640.38 3631.42 -144.59 -3628.54 0.68 6030749.02 656205.48 N 702926.744 W 1484322.653 8756.14 27.96 269.07 7785.51 7841.97 3675.65 3684.63 3675.65 -145.15 -3672.78 0.36 6030747.51 656161.26 N 702926.738 W 1484323,955 8851.96 28.40 268.93 7869.97 7926.43 3720.89 3729.88 3720.89 -145.94 -3718.03 0.46 6030745.75 656116.05 N 702926.730 W 1484325.286 8947.56 28.80 267.97 7953.91 8010.37 3766.65 3775.64 3766.65 -147.18 -3763.77 0.64 6030743.53 656070.35 N 702926.717 W 1484326.632 9041.91 29.11 267.66 8036.46 8092.92 3812.32 3821,31 3812.32 -148.92 -3809.41 0.37 6030740.80 656024.75 N 702926.700 W 1484327.976 9134.86 29.63 267.53 8117.47 8173.93 3857.91 3866.90 3857.91 -150.84 -3854.96 0.56 6030737.91 655979.26 N 702926.681 W 1484329.316 9238.51 30.77 268.10 8207.05 8263.51 3910.05 3919.04 3910.05 -152.82 -3907.06 1.13 6030734.81 655927.22 N 702926.661 W 1484330.849 9334.58 31.60 268.20 8289.23 8345.69 3959.79 3968.78 3959.79 -154.42 -3956.78 0.87 6030732.13 655877.55 N 702926.645 W 1484332.312 9423.65 31.95 268.22 8364.95 8421.41 4006.69 4015~69 4006.69 -155.89 -4003.66 0.39 6030729.66 655830.72 N 702926.630 W 1484333.691 9519.46 32.25 268.94 8446.12 8502.58 4057.60 4066.60 4051.60 -157.15 -4054.56 0.51 6030727.31 655779.86 N 702926.618 W 1484335.189 9613.99 32.85 270.03 8525.80 8582.26 4108.44 4117.46 4108.44 -157.60 -4105.41 0.89 6030725.76 655729.03 N 702926.613 W 1484336.686 Generated 7/13/2005 3:00 PM Page 4 of 4 NS16\NS16\NS16\NS16 Sag Corr SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) ( deg ) ( deg ) (ft ) (ft) (ft) (ft) (ft ) ( It ) (ft) ( deg/100 ft ) (ftUS) (ftUS) 9714.23 31.53 269.41 8610.63 8667.09 4161.81 4170.86 4161.81 -157.86 -4158.81 1.36 6030724.36 655675.66 N 702926.610 W 1484338.257 9808.76 30.37 268.77 8691.70 8748.16 4210.41 4219.47 4210.41 -158.63 -4207.42 1.28 6030722.55 655627.08 N 702926.602 W 1484339.687 9903.73 30.77 268.24 8773.4 7 8829.93 4258.70 4267.77 4258.71 -159.89 -4255.70 0.51 6030720.25 655578.84 N 702926.590 W 1484341.108 9997.85 31.15 267.36 8854.18 8910.64 4307.12 4316.19 4307.12 -161.75 -4304.08 0.63 6030717.35 655530.51 N 702926.571 W 1484342.532 10092.54 32.17 265.18 8934.78 8991.24 4356.80 4365.89 4356.80 -164.99 -4353.67 1.62 6030713.04 655481.01 N 702926.539 W 1484343.991 10187.02 31.10 264.74 9015.22 9071.68 4406.29 4415.44 4406.29 -169.35 -4403.03 1.16 6030707.63 655431.75 N 702926.496 W 1484345.443 10281.30 29.13 262.96 9096.77 9153.23 4453.48 4462.74 4453.48 -174.39 -4450.06 2.29 6030701.57 655384.85 N 702926.446 W 1484346.827 10374.64 28.19 261.59 9178.67 9235.13 4498.03 45Ò7.50 4498.Ò4 -180.40 -4494.42 1.23 6030694.61 655340.63 N 702926.387 W 1484348.132 10398.98 28.29 262.33 9200.12 9256.58 4509.49' 4519.02 4509.50 -182.01 -4505.82 1.50 6030692.76 655329.27 N 702926.371 W 1484348.468 10539.99 28.62 262.14 9324.09 9380.55 4576.36 4586.21. 4576.39 -191.09 -4572.39 0.24 6030682.25 655262.91 N 702926.281 W 1484350.427 r- 10634.53 27.07 262.66 9407.68 9464.14 4620.32 4630.36 4620.36 -196.93 -4616.16 1.66 6030675.47 655219.28 N 702926.223 W 1484351.714 10730.34 26.27 263.62 9493.30 9549.76 4663.18 4673.37 4663.24 -202.07 -4658.86 0.95 6030669.41 655176.71 N 70 29 26.173 W 14843 52.971 10824.24 25.44 263.44 9577.80 9634.26 4704.01 4714.32 4704.09 -206.69 -4699.54 0.89 6030663.92 655136.14 N 702926.127 W 1484354.168 10918.33 23.99 264.20 9663.27 9719.73 4743.26 4753.65- 4743.34 -210.93 -4738.65 1.58 6030658.84 655097.13 N 70 29 26.085 W 1484355.319 11013.11 23.15 263.91 9750.14 9806.60 4781.08 4791.55 4781.18 -214.85 -4776.35 0.89 6030654.11 655059.53 N 702926.046 W 1484356.428 11105.75 22.49 263.50 9835.53 9891.99 4816.91 4827.48 4817.03 -218.79 -4812.06 0.73 6030649.40 655023.92 N 702926.007 W 1484357.479 11201.31 22.65 263.94 9923.77 9980.23 4853.50 4864.16 4853.63 -222.80 -4848.52 0.24 6030644.61 654987.56 N 702925.967 W 1484358.551 11297.96 22.16 264.56 10013.12 10069.58 4890.26 4901.00 4890.42 -226.50 -4885.17 0.56 6030640.13 654950.99 N 702925.931 W 1484359.630 11389.45 22.79 265.29 10097.66 10154.12 4925.19 4935.97 4925.36 -229.59 -4920.01 0.75 6030636.29 654916.23 N 70 29 25.900 W 148440.655 11483.67 21.82 265.25 10184.83 10241.29 4960.92 4~71. 73 4961.10 -232.54 -4955.64 1.03 6030632.58 654880.67 N 70 29 25.871 W 148441.703 11579.48 20.18 265.94 10274.28 10330.74 4995.23 5006.06 4995.41 -235.18 -4989.88 1.73 6030629.20 654846.51 N 70 29 25.845 W 148442.711 11674.15 18.35 266.09 10363.64 10420.10 5026.44 5037.30 5026.64 -237.35 -5021.03 1.93 6030626.36 654815.40 N 70 29 25.823 W 148443.628 11767.85 17.15 266.77 10452.88 10509.34 5055.00 5065.86 5055.20 -239.14 -5049.54 1.30 6030623.96 654786.94 N 70 29 25.806 W 148444.466 11863.25 15.66 267.85 10544.39 10600.85 5081.94 5092.80 5082.14 -240.41 -5076.45 1.59 6030622.11 654 760.07 N 70 29 25.793 W 148445.258 11957.31 14.67 268.18 10635.18 10691.64 5106.55 5117.41 5106.75 -241.27 -5101.04 1.06 6030620.72 654735.50 N 702925.784 W 14844 5.982 12043.27 13.40 267.83 10718.57 10775.03 5127.39 5138.26 5127.59 -241.99 -5121.88 1.48 6030619.55 654714.69 N 70 29 25.777 W 148446.595 12154.57 13.03 268.05 10826.92 10883.38 5152.84 5163.70 5153.03 -242.91 -5147.31 0.34 6030618.09 654689.29 N 70 29 25.768 W 148447.343 -~ 12250.07 11.05 268.33 10920.32 10976.78 5172.76 5183.62 5172.95 -243.54 -5167.22 2.07 6030617.03 654669.40 N 70 29 25.761 W 14844 7.929 1WD+SAG 12328.65 9.01 272.11 10997.69 11054.15 5186.42 5197.30 5186.61 -243.53 -5180.89 2.73 6030616.74 654655.73 N 70 29 25.761 W 148448.331 1,-, \ Projected) 12424.00 9.01 272.11 11091.87 11148.33 5201.31 5212.23 5201.49 -242.98 -5195.82 0.00 6030616.97 654640.80 N 70 29 25.767 W 148448.771 Survey Type: Definitive Survey NOTES: GYD GC 55 - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + SAG - ( MWD + Sag correction -- MWD with a BHA deformation correction applied.'Covers all BHA corrections-from simple 2D to finite-element 3D models. ) Le : al Description: Northing (Y) [ftUS] Eas~ing (X) [ftUS] Surface: 1199 FSL 645 FEL S11 T13N R13E UM 6030971.56 659829.81 BHL: 954 FSL 561 FEL S10 T13N R13E UM 6030616.97 654640.80 .. " ) STATE OF ALASKA ) RECEIVi=[) ALASKA OIL AND GAS CONSERVATION COMMISSION [.~'" ~,.. REPORT OF SUNDRY WELL OPERATld~ 6 Z005 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD AI~~sIŒ Oil 8t Ga~~ C(\)m~. COInnnis::m]!1 Stimulate Œ] At. /I' ~~. ""!"I1 ')j OtherD )",\ I H.~11(lf'~i~t;; WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 202-1270 6. API Number 50-029-23096-00-00 Repair Well 0 PluQ PerforationsD Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate D P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.46 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Stratigraphic D Service D 9. Well Name and Number: NS16 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 12424 feet true vertical 11148.3 feet Effective Depth measured 12420 feet true vertical 11144.4 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse LINER 1829 7" 26# L-80 10265 - 12094 9139.0 - 10824.4 7240 5410 LINER 505 4-1/2" 12.6# 13Cr80 11919 - 12424 10654.6 - 11148.3 8430 7500 PRODUCTION 10392 9-5/8" 47# L-80 43 - 10435 43.0 - 9288.3 6870 4760 SURFACE 3450 13-3/8" 68# L-80 44 - 3494 44.0 - 3200.4 4930 2270 Perforation depth: Measured depth: 12304 - 12384 True vertical depth: 11029.83 - 11108.82 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 40 11929 Packers & SSSV (type & measured depth): 7" Top Packer 4-1/2" Top Packer 4-1/2" TRM-4E SSV 4-1/2" Baker S-3 Perm Packer @ 10265 @ 11919 @ 972 @ 11880 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12304' -12384' Treatment descriptions including volumes used and final pressure: 12Bbls 12% HCL, 37 Bbls 12% HCL with L66 @ 2100 psig 13 Prior to well operation: Subsequent to operation: Oil-Bbl 3052 4915 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 29.4 229 440 40.3 1006 440 Tubing Pressure 772 864 14. Attachments: ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒ] GasD Development ŒI Service D Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 305-037 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron q ,I C -r---" _. .^.J C~ CU'\.Ã.('J ~ Title Production Technical Assistant Signature Phone 564-4657 Date RODMS DFl,JUN 0 7 2005 6/3/05 Form 10-404 Revised 4/2004 · . ') ') NS16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/20/05 ACID / SIT TREATMENT, WELL FLOWING ON ARRIVAL, SHUT IN WELL, PUMP TUBING PICKLE, 4 BBLS METH, 12 BBLS 12% HCL, 102 BBLS SW, 67 BBLS DIESEL, FLOW BACK 181 BBLS PICKLE THROUGH TEST SEPARATOR, PUMP ACID / SCALE INHIBITOR TREATMENT. 37 BBLS 12% HCL W / L66, 104 BBLS 2% KCL W / L66, 15 BBLS DIESEL, 181 BBLS SW, 73 BBLS DIESEL, SHUT IN WELL FOR 4 HOURS, FLOWBACK TREATMENT. FINAL INJECTIVITY 6.5 BPM @ 2400 PSI. ***SHUT IN*** FLUIDS PUMPED BBLS 4 Methanal 155 Diesel 283 SeaWater 104 2% KCL w/L66 12 12% HCL 37 12% HCL w/L66 595 TOTAL Page 1 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ') NS16 13 3/8" TAM Port Collar at +/-1587'MD 1 3 3/8", 68#/ft, L-80, BTC @ 3494' MD ..4 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" .. CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-BO BTM-C @ 10435' MD H Jj- 4.5" X NIPPLE, @ 11859' MD 3.813" 10 4.5" X NIPPLE, @ 11903' MD 3.813" 10 4.5" XN NIPPLE, @ 11915' MD 3.725" 10 4.5" Self Aligning WLEG, @11926'MD 3.850" 10 - J , E- 7", 26#/ft L-80, Hydril 521 @ 12094' MD J, ¡::m:(FA TO'\! SLMv'ARY' ÆF L03: AX: GRm (7/14/03) AN2LEATTœ~: N:Xe: ~er to R"oducüon œ for historica perl data l!iüal Fèrf - O1a'ge: 2906 Fbwer Jet, f-S); f'€netraüon: 27'; l-tie: .36"; A1ase: 60 deq SIZE SFF NTm/ALMJ INTm/AL lVD Q:x1lSQz CÄTE 2.875 6 12304' - 12384' 11037 - 11116" cpn 7/15'2003 PBTD @ 12420' MD TO @ 12424' MD 1 DATE 6/17/02 6/5/03 7/18/03 REV. BY JAS FH EMF COMMENTS ~S16 Proposed NS16 Proposed Update Add Perfs )RIGINAL KB. ELEV = 56.46' KB-BF. ELEV = 40.56' CB. ELEV = 15.9' I 1/2" TRM- 4E SSSV @ 972' MD w/4 1/2 "x" PROFILE=3.813" 10 .. 41/2" GLM @ 4981' MD (4484'TVD) w/3.833" 10 4 1/2" GLM @ 7189' MD (6546' TVD) w/ 3.833" 10 ~ - 7" LINER TOP @ 10265' MD V I 4.5" Fiber Optic Transducer 3.945" 10 @ 11833' (11836' ELM, 10582' TVDrkb) M _ 7" PACKER, 13 Cr @ 11880' MD, ,~ '0625'TVD ~ 4.5" LINER TOP @ 11919' MD ~ ~ 4.5", 12.6#, 13Cr-80 Vam Ace Northstar WFI I : N5;16 API NO: 50-029-23096-00 BP Exploration (Alaska) :~r-~ l . \ I '. r ¡ " ¡ I \ I' I ' t [r ¡ , ì 'I I \0': ) ~/Iíì¡' ~ r,! ffi/¡1l\\" '~~ n~,'.7 i~.i'\ , ü ~ ¡: / fIj, . Ii" ¡ iJ :, , ~~f1i®U~W ) ;¿IJ). -/:27 A.~A~IiA OIL AlWD GAS CONSERVATION COMMISSION / I / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: N orthstar NS 16 Sundry Number: 305-037 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours 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 'day or weekend. A person may not appeal a Commission deC(¡iSion to g ·0 0 unless rehearing has been requested. lnc DATED thisß day of February, 2005 Encl. "' bp ) ) ,\~Atl. -..,~ ~~. ~~- ~~ *..~ F..... ·'i'·~I\" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519·6612 (907) 561·5111 February 16, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: R' "~ I. "~' "'\ FEB 1 8 2.005 Re: Sundry Notice for NS 16 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS16 well. This well has exhibited a high rate of decline and analysis of formation water indicates the /" formation of CaC03 scale is likely. Offset wells have responded very well to similar treatments in the past. The procedure includes the following major steps: · Bullhead HCI based acid treatment (which includes scale inhibitor) . Flowback /" Sincerely, ~tAtJf· ::k&</Y\ÙJ Michael J. -*isl, P.E. Senior Petr leum Engineer BPXA, ACT, Northstar '--..1 f ,...... ¡ N -.," i ,J~) í AL \t.l G A- zt¿L.I7ØfJS ) STATE OF ALASKA ) p"~/S Z/ffý ALASKA OIL AND GAS CONSERVATION COMMISSIONJ', [,,,,,,,j,,,!" APPLICATION FOR SUNDRY APPROVA1B 1 g 2005 20 AAC 25.280 1. Type of Request: ~.I~I Abandon D D D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ]] Perforate D 1~~J'W~~ii~&fJEJ StimulateŒ] Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1270/' Suspend D RepairWell D Pull Tubing 0 Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. /' Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD Service D 9. Well Name and Number: NS16 /' 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12420 11095.5 Size MD TVD 7. KB Elevation (ft): 56.46 KB 8. Property Designation: ADL-312799 11. Presen1 Total Depth MD (ft): 12424 Casing Total Depth TVD (ft): 11155.9 Length Other D 6. API Number /' 50-029-23096-00-00 Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom LINER 1829 7" 26# L-80 10265 12094 9144.9 10832.0 4930 2270 LINER 505 4-1/2" 12.6# 13Cr80 11919 12424 10662.1 11155.9 6870 4760 PRODUCTION 10392 9-5/8" 47# L-80 43 10435 43.0 9294.3 7240 5410 SURFACE 3450 13-3/8" 68# L-80 44 3494 44.0 3200.4 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12304 - 12384 11037 - 11116.4 4-1/2 " 12.6 # 13Cr80 40 11929 Packers and SSSV Type: 7" Top Packer 4-1/2" Top Packer 4-1/2" TRM-4E SSV 4-1/2" Baker S-3 Perm Packer 12. Attachments: Packers and SSSV MD (ft): 13. Well Class after proposed work: Description Summary of Proposal ŒJ Detailed Operations ProQram 0 BOP Sketch 0 14. Estimated Date for CommencinQ Operation: 10265 11919 972 11880 i¡J61\- Exploratory 0 Development ]( Servic~--- 15. Well Statu!#er proposed work: Oil L!I Gas D Plugged 0 Abandoned 0 W (.ilt- GINJD March 25, 2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WAGD Date: Contact Printed Name Signature Michael Francis "" ~~f~)?'r=. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-4240 2/8/05 BOP TestD Mechanciallntegrity Test D Location Clearance D ReDMS B~L r, . MAR 0 1 20D5 WI~ WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Number: ~S--03? BY ORDER OF ~~~~ THE COMMISSION Date: ~/-¿.pl '05 RBDMS 8Ft f'¡\Q ~1 i @ R 1 G \ r\~ A L Form 10-403 Revised 11/2004 SUBMIT IN DUPLICATE .. TREE: ABB-VGI 5 1/8" 5ksi ') WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS16 13 3/8" TAM Port Collar at +/-1587'MD 13 3/8", 68#/ft, L-80, BTC @ 3494' MD ~ 41/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" ~ CAPACITY: 0.01522 BBUFT 9-5/8" 47# L-80 BTM-C @ 10435' MD H ~- 4.5" X NIPPLE, @ 11859' MD 3.813" ID 4.5" X NIPPLE, @ 11903' MD 3.813" ID 4.5" XN NIPPLE, @ 11915' MD 3.725" 10 4.5" Self Aligning WLEG, @11926'MD 3.850" ID - B_ B 7", 26#/ft L-80, Hydril 521 @ 12094' MD iI Æ:JVœA 1Œ SlJvMI.\R( ÆF LOO AX: GR'0:l. (7/141æ) AI'G£ATlCPÆfF: I'tte: A3fer to Ftoduction œ for historica perf data ntial Fèrf - Ola'ge: 2906 Rm er Jet, I-tSQ Fènetration: Zl"; Hje: .36"; R1ase: 60 deç SIZE SR= N!tRJALlvO INJER./AL lVD QJrV&:¡z [)<\lE 2.875 6 12304' -12384' 11æ7' -11116' Cp1 7/1512003 PBTD @ 12420' MD TO @ 12424' MD i DATE 6/17/02 6/5/03 7/18/03 REV. BY JAS FH EMF COMMENTS ""NS16 proposed NS16 Proposed Update Add Perfs ~ ~ I )RIGINAL KB. ELEV = 56.46' KB-BF. ELEV = 40.56' CB. ELEV = 15.9' '1 1/2" TRM- 4E SSSV @ 968' TVD (972' MD) 3.813" 10 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4196' TVD (4654'MD) .. 4 1/2" GLM @ 4484' TVD (4981' MD) w/3.833" ID 41/2" GLM @ 6456' TVD (7189' MD) w/ 3.833" 10 ~ - 7" LINER TOP @ 10265' MD 4.5" Fiber Optic Transducer 3.945" ID @ 11833' (11836' ELM, 10582' TVDrkb) -;;- _ 7" PACKER, 13 Cr @ 11880' MD, 10625' TVD ': ... ~ 4.5" LINER TOP @ 11919' MD 4.5",12.6#, 13Cr-80 Vam Ace North~tar WF~ ~ : N~16 API NO: 50-029-23096-00 BP Exploration (Alaska) ) ) Date: 10-20-2003 i Transmi ttal N urnber:92626 i I BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type ¿rt;-JID NS12 06-07-2002 SPERRY 1 201 3647 MUD LOG; END OF WELL REPORT; T NS16 06-28-2002 SPERRY 1-4 201 12424 MUD LOG; END OF WELL REPORT; !Jet) -)d fiC&-ll9'1 NS17 08-24-2002 SPERRY 1-6 201 18396 MUD LOG; END OF WELL REPORT; SPERRY t}tl}àð T NS19 10-29-2002 1-4 201 14063 MUD LOG; END OF WELL REPORT; ~_)~ NS20 09-26-2002 SPERRY 1-5 201 18531 MUD LOG; END OF WELL REPORT; 6ò NS23 03-31-2003 SPERRY 1-5 201 13981 MUD LOG; END OF WELL REPORT; P)03-0· ._..;~~\~~~~~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIV'EI) 0,("" 2 i ('1"IO'r J j . ¡ ill (I !\Ì¡'~skn ();.; a Ga~ (;{im\ G\,)nun¡8~km ¡\ncl1Qrn~8 Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~~'\JN\~ ) ') II Date: 08-22-2003 Transmittal Number:92619 c:7 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or bye-mailing to johnsojh @ bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS16 03-19-2003 SCH 1-4 12070 12430 VISION RESISTIVITY BOREHOLE CORRECTED LOG; MEASURED DEPTH; COMPOSITE FINAL PRINT; NS16 03-19-2003 SCH 1-4 12070 12430 VISION RESISTIVITY BOREHOLE CORRECTED LOG; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; NS16 03-19-2003 SCH 1-4 12070 12430 VISION DENSITY NEUTRON; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; NS16 03-19-2003 SCH 1-4 12070 12430 VISION DENSITY NEUTRON; MEASURED DEPTH LOG; COMPOSITE FINAL PRINT; ~12 03-06-2003 SCH 1-6 13135 13584 VISION DENSITY NEUTRON; TRUE VERTICAL DEPTH LOG; ~2 03-06-2003 SCH 1-6 13135 13584 VISION DENSITY NEUTRON; rr MEASURED DEPTH LOG; J%f2 03-06-2003 SCH 1-6 13135 13584 VISION RESISTIVITY LOG; \\0 TRUE VERTICAL DEPTH LOG; )%12 03-06-2003 SCH 1-6 13135 13584 VISION RESISTIVITY LOG; MEASURED DEPTH LOG; ~ 03-06-2003 SCH 1-6 13135 13584 LDWG DATA; CD ROM 1EA; J90fJ!5 NS16 03-19-2003 SCH 1-4 12070 12430 LDWG DATA; CD ROM 1EA; /!)O[)W ~\~~~~h~C!Yr\ Please Sign and Return one copy of thi"s tra'hsmittal. Thank You, James H. Johnson Petrotechnical Data Center ¡t~ij:~(·\Ei\¡ED ~ ... li..,""," .J U ('\ 2 ") ,..003 1\ \J _ L L .A!aska 0;; K c;¿:~~ C{ìi IL. ~;úrlÌfíllgStOn Ù,lirJtOí ~0e Petrotechnical Data Center LR2- ] 900 E. Benson Blvd. PO Box 1966]2 Anchorage, AK 99519-6612 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,f' 1a. Well Status: IS! Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1199' NSL, 645' WEL, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 956' NSL, 520' WEL, SEC. 10, T13N, R13E, UM Total Depth: 956' NSL, 546' WEL, SEC. 10, T13N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 659830 y- 6030971 Zone- ASP4 TPI: x- 654682 y- 6030619 Zone- ASP4 Total Depth: x- 654656 y- 6030618 Zone- ASP4 18. Directional Survey IS! Yes 0 No 21. Logs Run: MWD , GYRO, GR , CCL , RES, DIR , PWD , DEN, NEU CASING, LINER AND CEMENTING RECORD , :" '".. . .... :.;','. ,'.. '.. .1:1<,11:11,' ,,'. I'; SE::rTING."DEP:rHil:"I,:iIBoLEI'.~" .....",',:'!;,,',!I:,' :,,":';. ';,1",'; ,:WT: P~RF;¡:., 1 , "ßAA'P.E!, I ,'.'ToPI': :I!.;;'., :BOrtOM:" ,"":\:'I:,~I~E '.:: : :"GEM'ENIIM3:,Rect)f~Q".::" Surface 201' 20" Driven 44' 3494' 16" 618 sx PF 'L', 470 sx Class 'G' 43' 10435' 12-1/4" 550 sx Econolite, 621 sx Class 'G' 10265' 12094' 8-1/2" 288 sx Class 'G' 11919' 12424' 6-1/8" 87 sx Class 'G' 22. , ,CASINC3, ISlzel:, 20" 13-3/8" 9-5/8" 7" 4-1/2" 169# 68# 47# 26# 12.6# X-56 L-80 L-80 L-80 13Cr80 Other 5. Date Comp., Susp., or Aband. 7/14/2003 6. Date Spudded 6/29/2002 7. Date TD. Reached 3/18/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 56.46' 9. Plug Back Depth (MD+ TVD) 12420 + 11152 Ft 10. Total Depth (MD+ TVD) 12424 + 11156 Ft 11. Depth where SSSV set 972~ MD 19. Water depth, if offshore 39' MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 202-127 13. API Number 50- 029-23096-00-00 14. Well Number NS16 15. Field and Pool Northstar Unit 16. Lease Designation and Serial No. ADL 312799 17. Land Use Permit: 20. Thickness of Permafrost 1545' (Approx.) ,....... .".'··.1.... I......,.··.·,.' ¡, 'AMO:Ut:-J~ PUÜ.F;D 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD 12304' -12384' 11037' - 11116' 26. Date First Production: SIZE 4-1/2", 12.6#, 13Cr80 DEPTH SET (MD) 11929' PACKER SET (MD) 11880' 25: i )\CID, F~CTù'RE,CEMENTS9~EEZE~ ETC.. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 320 Bbls of Diesel August 10,2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE GAs-McF W A TER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF W A TER-BsL OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit cor~.chips; if none, state "none". ¡' ; : .:~ '\ .~ None . ',I, (~: ; . ý~¿-- ¡ ~ VbOr! ¡r:,p:--¡ ~ ¿¡¿. _I .. ,e.!. " I :1 ¡--,-~- .; ~s 8Ft AUG 1 9i 7n03 ORIGINAL ~ý Form 10-407 Revised 2/2003 , ,- ..........,.......... _, oj¡.....,~""-...~~~.......,.; CONTINUED ON REVERSE SIDE 28. it GEOLOGIC MARKE ) 29. ) FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Top of Kuparuk Kuparuk 'C' 9888' 8822' None 10025' 8939' Top of Miluveach 10396' 9260' Top of Kingak 10975' 9778' Top of Sag River 12065' 10804' Top of Shublik 12162' 10898' Top of Ivishak 12258' 10992' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and a Leak-Off Test Summary. 31. I hereby certify that the f~lìng is tru_e and cor. rect to the best of my knowledge. Signed Sondra s'man ~~/"'- Title Technical Assistant Date D~ ~ I ~ ". 0) NS16 202-127 Prepared By NamelNumber: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Allen Sherritt, 564-5204 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 r ) ) BP EXPLORATION . Ope rationsSI..I mmaryReport Paget of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NSt6 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task· Code NPT Phase Descri ptionof Operations 6/28/2002 15:00 - 19:30 4.50 MOB P PRE Release rig from NS12 at 1500 hrs. Prepare to move rig. 19:30 - 20:00 0.50 MOB P PRE PJSM. Complete unit permit. 20:00 - 22:00 2.00 MOB P PRE Move rig to NS16. Move went well. Lock out wells under sub during move. 22:00 - 22:30 0.50 MOB P PRE Level rig. 22:30 - 00:00 1.50 MOB P PRE Make up connections between sub and service unit. Berm around rig and rig up disposal line. 6/29/2002 00:00 - 03:30 3.50 RIGU P PRE Complete rig up and sign off Nabors pre-spud check list. 03:30 - 04:00 0.50 RIGU P PRE PJSM. Accept rig at 0400 hrs. 6/29/2002. 04:00 - 06:30 2.50 RIGU P PRE Rig up drilling riser. 06:30 - 07:30 1.00 RIGU P PRE Fill riser with seawater and repair leak. 07:30 - 08:00 0.50 RIGU P PRE PJSM. 08:00 - 10:00 2.00 RIGU P PRE Pick up 1.83 deg bent housing with Gyro orientation collar. Make up bit #1, new Hughes MX-C1. 10:00 -11:00 1.00 RIGU P PRE Hold pre-spud safety meeting. 11 :00 - 12:00 1.00 RIGU P PRE Clean up spill in cellar. See remarks. 12:00 - 14:00 2.00 DRILL P SURF Spud well and clean out conductor. Drill 16" hole to 334' with Gyro survey's. Bottom of conductor at 2.39 deg at 275.77 azimuth. Spud well at 1200 hrs. 06/29/2002. 14:00 - 14:30 0.50 DRILL P SURF POOH with BHA #1 to pick up MWD. 14:30 -18:30 4.00 DRILL P SURF Pick up BHA #2 with MWD, and orientation collar. 18:30 - 19:00 0.50 DRILL P SURF Dir drill 16" hole from 334 to 389'. 19:00 - 19:30 0.50 DRILL P SURF Run gyro survey. 19:30 - 00:00 4.50 DRILL P SURF Dir drill 16" hole from 389 to 1007'. Pumps 660 gpm, rotary 35 rpm, WOB 15-25K, On btm 550 psi, Off btm 500 psi. Full MWD survey's, rig out Gyro. 6/30/2002 00:00 - 01 :00 1.00 DRILL P SURF Complete Gyro survey's and rig down sheaves. 01:00 -12:00 11.00 DRILL P SURF Dir drill 16" hole from 1004 to 2336'. Pumps 850 gpm, WOB 30K, Rotary 35 rpm. 12:00 - 22:00 10.00 DRILL P SURF Dir drill 16" hole from 2336 to 3514'. Casing Point. Pumps 850 gpm, WOB 25 to 35K, Rotary 35 rpm. SWU 175K, SWD 150K, SWR 160K. ONBP 2000 psi. OFFBP 1850 psi. Top of SV 3312' md. 22:00 - 23:30 1.50 DRILL P SURF Pump 75 bbl Hi-Vis sweep and circulate clean. Moderate amount of cuttings on bottoms up. Circulate 2 bottoms up. 23:30 - 00:00 0.50 DRILL P SURF POOH with BHA #2 to run surface casing. 7/1/2002 00:00 - 02:30 2.50 DRILL P SURF Flow check and pump dry job. Pooh with bha #2. Intermittent tight spots requiring overpull up to 25K. Work through and would not see on second pass up. Hole looks good to run casing and did not swab. 02:30 - 05:00 2.50 DRILL P SURF Lay down dir bha. Bit grade 1-1-WT-A-E-No-TD. Stabs and bit were balled up. 05:00 - 06:00 1.00 DRILL P SURF Clean up rig floor. 06:00 - 06:30 0.50 CASE P SURF PJSM prior to rig up casing equipment. 06:30 - 09:00 2.50 CASE P SURF Install long bails and rig up Franks tool to run casing. 09:00 - 21 :00 12.00 CASE P SURF Make up shoe track and thread lock. Check floats. Run total of 85 jts, 13-3/8", 68 Ib, BTC, L-80 casing and make up Vetco casing hanger. Land hanger without pumps, and did not see any fill. PUW prior to landing 325K, SOW 125K. Increased drag of approx 25 to 40K from 1696 to 1864' and 2836 to 3000'. 21 :00 - 22:00 1.00 CASE P SURF PJSM. Rig up cement head. Printed: 6/16/2003 2:07:50 PM t ) ) BP EXPLORATION Operations $UmrnaryReport Page 2 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From- To Hours Task Code NPT Phase Descri ption of· Operations 7/1/2002 22:00 - 00:00 2.00 CASE P SURF Break circulation and stage up rate to 10 bpm at 600 psi. Hole cleaned up clean good with no losses. 7/2/2002 00:00 - 00:30 0.50 CASE P SURF Circulate and pump 75 bbls mud spacer. PJSM prior to cementing. 00:30 - 03:00 2.50 CASE P SURF Cement with Halliburton. Pump 5 bbls water. Pressure test to 3500 psi. Held ok. Pump 75 bbls Alpha spacer at 10.3 ppg. Drop bottom plug and pump 453 bbls (618 sacks) lead at 10.7 ppg and tail with 97 bbls (470 sacks) tail at 15.8 ppg. Drop top plug and pump 25 bbls sea water. 03:00 - 04:00 1.00 CASE P SURF Switch to mud pump and displace with 496 bbls (4874 strokes) at 95% efficiency at 9 bpm. Slow rate to 3 bpm and bump plug 500 psi over for 2 min. Bleed off pressure. Floats held. Had 600 psi lift prior to bumping plug. No losses. 04:00 - 05:00 1.00 CASE P SURF Flush riser and lay down cement head. Clean up floor. 05:00 - 07:00 2.00 CASE P SURF Back off landing joint and lay down. 07:00 - 07:30 0.50 CASE P SURF PJSM. 07:30 - 09:00 1.50 CASE P SURF Nipple down riser. 09:00 - 16:00 7.00 CASE P SURF PJSM and nipple up BOP's. 16:00 - 16:30 0.50 CASE P SURF Pick up test joint and make up test plug. 16:30 - 21:00 4.50 CASE P SURF Pressure test annular to 250/3500 psi for 5 min. Test all rams, stack valves, choke manifold and safety valves to 250/4800 psi. Held ok. 21 :00 - 21 :30 0.50 CASE P SURF Pull test plug. Install wear bushing. Blow down choke manifold and lines. 21 :30 - 22:00 0.50 CASE P SURF Rig service, grease top drive, crown sheaves, draw works. 22:00 - 00:00 2.00 CASE P SURF PJSM. Pick up BHA #3 (rotary steerable). 7/3/2002 00:00 - 04:00 4.00 CASE P SURF Surface test bias sub for rotary steerable and mwd. RIH to 3381'. Wash to 3405'. Tagged cement at 3395'. 04:00 - 04:15 0.25 CASE P SURF PJSM - Casing and FIT test. 04:15 - 05:00 0.75 CASE P SURF Pressure test casing to 3500psi with 9.1 ppg mud for 30 minutes. Note: Review 01, 02, and 05 well control procedures. 05:00 - 07:30 2.50 CASE P SURF Drill out shoe track while displacing to new mud. 07:30 - 08:00 0.50 DRILL P INT1 Clean out rat hole and drill to 3534' -- 20' of new formation. 08:00 - 09:00 1.00 DRILL P INT1 FIT to 660 psi with 8.7ppg mud, EMW 12.67 ppg. Blowout kill line. 09:00 - 16:00 7.00 DRILL P INT1 Drill from 3534-4300' md with RSS tool. Notes: 1. RSS tool responding to down links. 2. Conducted 02 drill with crew. 16:00 - 18:00 2.00 DRILL N SFAL INT1 Flowline plugged with Clay and overflowedCirculated up mud ring and plugged flow line. Spilled 4 bbl of drilling fluid. 18:00 - 00:00 6.00 DRILL P INT1 Drill from 4300-4997' with RSS tool. Notes: 1. RSS tool responding to down links. 2. Intermittent episodes of bit balling. Pumped walnut hull sweeps as required to clean up, adding SAP at connections and sand sequences also assisting in cleaning bit. 7/4/2002 00:00 - 00:00 24.00 DRILL P INT1 Drill f/4997' - 7375' md with RSS Tool. Notes: 1. Tool responding to down links. 2. Drilled several hard streaks in Ugnu, most notable 6966'-6972' (2-4 fph) Printed: 6/16/2003 2:07:50 PM t ') ) BPEXPLORA TrON Operations Summary Report Page30f19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task Code NPT Phase Description· of Operations 7/4/2002 00:00 - 00:00 24.00 DRILL P INT1 3. Pumped walnut hull sweeps at 500' intervals. 4. Put non rotating stabilizer in string while drilling at 7295' to reduce stick slip and surface vibration. Stabilizer buried one stand (string depth 7180'). Noted immediate response -- reduction in both surface vibration and stick/slip. 5. Added 4 bbls of EP Lube at 7295' to reduce torque and stick slip. Torque dropped approx. 2000 ft.lb and stick slip dropped from approx. 150 to 70 rpm. Lubricant concentration in system approximately 1.5%. 7/5/2002 00:00 - 14:00 14.00 DRILL P INT1 Drill f/7380' - 8817' md with RSS Tool. Notes: 1. Tool responding to down links. 2. Adding non rotating stabilizers every 7 stands. 3. Maximum stick slip 70 rpm. 4. Pumping walnut sweeps every 500'. 14:00 - 14:30 0.50 DRILL P INT1 Service Top Drive and draw works. 14:30-21:30 7.00 DRILL P INT1 Drill f/ 8817' - 9523' md with RSS Tool. Notes: 1. Same as above notes 1 -- 4. 2. Weight up mud system for HRZ (9.8ppg) and Kuparuk (10.1 ppg). 21 :30 - 23:30 2.00 DRILL N DFAL INT1 Recovered blade from non rotating stabilizer at shakers. Blade had sheared off of sleeve. Pull 8 stands of pipe. Layout damaged stabilizer, remainder of sleeve still intact. Replace stabilizer and RIH. 23:30 - 00:00 0.50 DRILL P INT1 Drill f/9523' - 9535' md. Notes: 1. Tool responding to down links. 2. Changed spacing on last 2 non rotating stailizers to 1000'. 3. No walnut sweeps last 1000' due to weight up. 7/6/2002 00:00 - 12:30 12.50 DRILL P INT1 Drill f/9535' - 10,460' with RSS Tool-- TO of 12-1/4" hole section. Notes: 1. Tool responding to down links. 2. Stick slip mostly in 40 rpm range with exception of Kuparuk C where increased to 80 rpm with spikes to 120 rpm. 3. No lubricants added to mud system today. Final lubricant concentration approximately 1.5%. 4. Utilizing 4 non rotating stabilizers inside 13-3/8" casing to help reduce stick slip and surface vibration. No problems with surface vibration in this hole section. 12:30 -15:00 2.50 DRILL P INT1 Circulate and Condition for Wiper Trip to 13-3/8" shoe. Notes: 1. Pump Hi-Vis Weighted Sweep -- 50 bbls. 2. Circulate 882 gpm with 120 rpm while reciprocating 80' strokes. 3. Pump 2-1/2 bottoms up while observing shakers. 4. Sweep at shakers did not really show any significant cuttings or solids. 15:00 - 15:30 0.50 DRILL P INT1 Shut down pumps and monitor well -- Static. Stroke pipe and Printed: 6/16/2003 2:07:50 PM 1" ) ') BP EXPLORATION Operations Summary· Report Pa~e4 of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/6/2002 15:00 - 15:30 0.50 DRILL P INT1 verify well not swabbing. 15:30 - 17:30 2.00 DRILL P INT1 POOH wet 10 stands to place BHA above the HRZ -- hole in good shape, maximum overpull 50K. Pump dry job. Continue to POOH through Colville formation. Notes: 1. Hole in excellent shape to base of Shrader -- Max overpull 50K in Kuparuk, 20 K in Colville. 2. Observe over pull 40 - 70 klb at 7850' while swabbing -- unable to effectively work pipe upwards without swabbing. 17:30 - 00:00 6.50 DRILL P INT1 Pump out of hole from Base of Schrader Bluff formation to 4600' md. Notes: 1. Hole swabbing while attempting to pull BHA up into the base of the Schrader Bluff (7683' md/6891, tvdrkb). 2. Attempted to wipe ball off with no success -- commit to pumping out of hole based on experience from previous wells. 3. Pumping out with 840 gpm at 2-3 minutes / stand through Schrader and Ugnu. 4. Pump out rates through SV from 5000' - 4500' up to 8-10 minutes / stand. - Hole packing off readily. - Cuttings at shakers look like a herd of turtles -- rolled up clay balls. - Clay balls packed off grating over drag chain at back of shakers and inlet to G&I. - Depth at 00:00 hrs -- 4500', pack off conditions starting to improve. 7/7/2002 00:00 - 02:30 2.50 DRILL P INT1 Continue pumping out of hole f/ 4600' md to 13-3/8" csg shoe @3494' md. Notes: 1. Increased pump rate back to 840 gpm while pumping out of the hole to 13-3/8" casing shoe @ 3494' md. 2. Lost -200 bbls of mud and cuttings over the shakers. 3. Clay balls ranging in size of tennis balls across the shakers. 02:30 - 04:00 1.50 DRILL P INT1 Circulate hi-vis sweep and clean hole. Note: Clay balls the size of footballs unloading from the hole. 04:00 - 05:00 1.00 DRILL P INT1 Slip and Cut Drill Line. 05:00 - 06:00 1.00 DRILL P INT1 Service Top Drive and Lubricate Rig. 06:00 - 10:00 4.00 DRILL P INT1 RIH and wash last stand down -- 2-3' of fill. Notes: 1. Stacked up at 10030' in the Kuparuk with 1 OOK -- total string wt was 200k. Worked pipe thru with 3 attempts. 2. Stacked up at 10397' (to of Miluveach). 5 attempts to work pipe thru -- unsuccessful. MU Top Drive and circulate down with 100 spm - acted like tight hole, not necessary to rotate -- 2 to 3 feet of fill. 10:00 - 13:00 3.00 DRILL P INT1 Circ and Cond drilling fluid for running casing. Note: 1. Pumped hi-vis sweep - no noticeable increase in returns with sweep to surface. 2. Increase cuttings at 1.5x bu -- circ until shakers cleaned up at 2.5x bu. 13:00 - 13:30 0.50 DRILL P INT1 Monitor well -- static. Check for swab. Printed: 6/16/2003 2:07:50 PM .) ) BP·EXPLORATION OperationsS u rnmal"yRe port Page 5 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From -To Hours Task Code NPT Phase Description of Operations 7/7/2002 13:30 - 21 :30 8.00 DRILL P INT1 POOH to run 9-5/8" casing'. Notes: 1. LD 2 singles and stand back stand #1 (99) -- no problems. 2. Attempted to POOH with stand #2(98) -- 1 OOK overpull @ 10310' md with top stabilizer at base of Kuparuk sand package at -10135' md. Worked pipe to attempt to pull through with 125K overpull -- unsuccessful. Assume top stabilizer hanging up @ base of sand package noted above. Discussion with rig team -- MU top drive, engage pumps and rotate thru tight spot with 60 spm and 60 rpm. Hung up again at 10250' md which correlates with top stab at base of another Kuparuk Sand package @ -10100' md -- backream thru this with same parameters as above. Shut down pumps and rotary at top of stand, run stand back in hole with no problem with evidence of bobbles at 10250' and 10310' md. PU with no pump or rotary and evidence of 50K overpull at these respective depth which again correlate to top stabilizer going thru sand packages at 10135' and 10100' md respectively. 21 :30 - 00:00 2.50 DRILL P INT1 Lay Down BHA. Notes: 1. Scraped off 1/2 of 5 gal bucket of clay off the stabs -- pretty clean. 2. Bit was in pretty good shape 2-1-WT-N-X-I-BT-TD. However, there the nose cutters were worn 4 and signs of rung pattern developing which was suspected while drilling one or two of the stubborn hard streaks in the lower Ugnu. 3. RSS tool looked to be in good shape. 7/8/2002 00:00 - 01 :15 1.25 CASE P INT1 Pull Wear Ring and Run Test Plug. Note: Wear ring has groove worn in wear pad -- due to slanted conductor and rotating tool joints wearing in one spot. Not useable for another well. 01 :15 - 02:30 1.25 CASE P INT1 Change top set of pipe rams to 9-5/8". Note: Necessary to remove mousehole to reposition bridge crane. 02:30 - 03:00 0.50 CASE P INT1 Close annular and test ram doors to 3500 psig for 5 min -- chart. Bleed pressure, pull test plug and LD test joint. 03:00 - 03:30 0.50 CASE P INT1 Clean rig floor and pull iron rough neck tracks. 03:30 - 06:00 2.50 CASE P INT1 PJSM -- RU to run 251 joints of 9-5/8" 47# L80 Mod-Btrc Intermediate Casing. Notes: LD 5" elevators, bales, PU Franks Casing Tool and RU Casing Tools. 06:00 - 11 :30 5.50 CASE P INT1 Run 85 joints of 9-5/8" casing to 13-3/8" surface casing shoe. 11 :30 - 12:00 0.50 CASE P INT1 Circulate one casing volume -- rig crews perform tour change. 12:00 - 19:30 7.50 CASE P INT1 Finish RIH with 251 total joints of 251 joints of 9-5/8" 47# L80 Mod-Btrc Casing. Note: Entire casing run went well with no problems - hole was in excellent shape. 19:30 - 20:30 1.00 CASE P INT1 MU mandrel casing hanger, landing joint, pull spiders and master bushings and land mandrel casing hanger. Note: Pulled landing joint over toward NE with cat head chain and lowered landed mandrel hanger without a glitsch -- did not hang up on any ram cavities. Printed: 6/16/2003 2:07:50 PM ) ) BP EXPLORATION o pè rati "nsSu mrnaryRèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From -To Hours Task Code NPT Phase 7/8/2002 20:30 - 21 :15 21 :15 - 00:00 0.75 CASE P 2.75 CASE P INT1 INT1 7/9/2002 00:00 - 00:30 0.50 CASE P 00:30 - 02:30 2.00 CASE P 02:30 - 03:45 1.25 CASE P 03:45 - 05:30 1.75 CASE P 05:30 - 07:00 1.50 CASE P 07:00 - 09:00 2.00 CASE P INT1 INT1 INT1 INT1 INT1 INT1 09:00 - 12:00 3.00 CASE P INT1 12:00 - 13:30 13:30 - 19:30 1.50 CASE P 6.00 CASE P INT1 INT1 19:30 - 20:30 1.00 CASE P INT1 20:30 - 21 :00 0.50 CASE P INT1 21 :00 - 21 :30 0.50 CASE P INT1 21 :30 - 00:00 2.50 CASE P INT1 7/10/2002 00:00 - 04:30 4.50 CASE P INT1 04:30 - 05:00 0.50 CASE P INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 07:30 1.50 CASE P INT1 07:30 -10:15 2.75 CASE P INT1 Pagë6 of19· Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Description of Operations Lay down Franks Casing Tool. Rig up cement head. Break circulation and step rate up to 12 bpm. Circulate excess of one casing volume to allow for crew change. Maximum gas 2550 units at 4000 strokes. Complete circulating @ 12 BPM in preparation for cement job. PJSM for cementing. Test lines to 4000 psi. Pump 50 bbls of 11.0 ppg weighted spacer, 317 bbls of 11.2 ppg lead cement followed by 127 bbls 15.9 ppg tail cement. Displace cement wI rig pump & bump plug wI 7431 strokes 94.5 % pump efficiency with both rig pumps and Howco flow meter. LID cement head & x-over. Remove elevators & clean floor. LID landing jt. Flush stack, install pack-off & test to 5000 psi, RIU to pump down annulus. PJSM - Remove 9 5/8" ram blocks & install 4 1/2" X 7" variables. Start pumping down 13 3/8" x 9 5/8" annulus @ 1/2 BPM. Note: Broke down at 1000 psi - final pressure 800 psi. 230 bbls of mud pumped to chase annulus. LID casing running equipment & change bails. RU to test BOPE. Notes: 1. Finish mixing spike fluid for weight up. 2. Cleaning L pits. 3. Changing pump liners to 5-1/2". 4. Welding landing ring on NS18 conductor in sub. Finish R/U to test BOPs - PJSM Test BOPE to 250 psi/4800 psi -- 5 minutes per test. Blow down kill line. Notes: 1. Function tested panel in pipeshed. 2. Chuck Sheave with AOGCC waived witness of BOPE Test @ 1500 hrs on 7/8102. 3. Welder replaced Door in Derrick. 4. Finish welding landing ring on NS 18 conductor in sub. Pull test plug, install bowl protector, & UD test jt. Lubricate rig. PJSM on PIU BHA. PIU BHA # 4 - shallow test MWD. RIH wI BHA # 4 on 5" DP. Adjust Brakes on Drawworks. Wash down & tag cement @ 10330' MD. Drill to float collar @ 1 0350'. Perform Casing Test to 4050 psi with 10.2 ppg mud for 30 minutes -- chart. Notes: 1) Held safety meeting wI crews & reviewed the following: a. Well design regarding well control. b. 01,02, & 05 drills. c. Drilling hazards for the 8 1/2" hole section. Drill shoe track, rathole, & 20' of new formation while increasing Printed: 6/16/2003 2:07:50 PM ) ) .Bp·EXPLORATION Operati()nsSummaryR~port Page 7 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From.;; To Hours Task Code NPT Phase Description of Operations 7/1 0/2002 07:30 - 10:15 2.75 CASE P INT1 MW to 12.0 ppg wI spike fluid. Notes: 1) Good hard cement in shoe track. 2) Bit showed signs of balling while drilling 20' of new hole - need to consider pumping nut plug sweep around as bit engages new formation. 3) Non-process leak occurred in pit room when 1 gallon of drilling fluid spilled over pit 1 wall while introducing the spike fluid from the G & I and drilling the shoe track. 10:15 - 10:45 0.50 CASE P INT1 Perform FIT to 14.0 ppg EMW to 970 psi wI 12.0 ppg. Circulated until MW in = MW out. 10:45 - 11 :30 0.75 CASE P INT1 Pump Sweep and calibrate PWD while pumping 15 ppb medium nut plug to the bit. 11 :30 - 17:30 6.00 CASE P INT1 Drill ahead f/10480' -- 10802' md. Notes: 1) Discussion wI DO to change plan forward instructions - instead of back reaming 30' on connections as outlined, wipe 90'. This was successful on the last well and DO is concerned about exagerating the dropping tendency of the BHA. Apparently this technique was successfully employed on the last well to minimize the dropping tendency of the BHA without any detrimental affects on the liner run. 17:30 - 18:00 0.50 CASE N DPRB INT1 Pumped 25 bbls. 15 ppb medium nut plug sweep to unball the bit. Notes: 1) Bit balled up after drilling ahead with 25K WOB with no problems. 2) Event occurred approx. 10' after a connection during which top drive maintenance was performed. 3) While waiting for pits to mix sweep and while circulating sweep to bit, the pump rate was dropped from 18:00 - 22:30 4.50 CASE P INT1 Drill from 10802' MD to 11169' MD. 22:30 - 23: 15 0.75 CASE P INT1 Slide from 11169' to 11207' to build some angle and to keep angle from dropping too fast. Gained 1 deg. from 21.4 deg to 22.44 deg. 23: 15 - 00:00 0.75 CASE P INT1 Drill from 11207' to 11264' md. 7/11/2002 00:00 - 12:00 12.00 DRILL P INT2 Drill from 11267' -12010' md. Notes: 1. One slide from 11361' to 11395' md. 2. Pump sweeps approx. every 400'. 12:00 - 13:30 1.50 DRILL P INT2 Drill from 12010' - 12105' md. Note: Top of Sag @ 12064' md 110803' tvdrkb. 13:30 - 15:00 1.50 DRILL P INT2 Circulate high vis barofibre sweep wI minimal cuttings seen at shakers. 15:00 - 16:45 1.75 DRILL P INT2 Monitor well & wiper trip back to 9 5/8" shoe. Trip to shoe was good with maximum drag of 25K. 16:45 - 17:30 0.75 DRILL P INT2 Monitor well & service top drive. 17:30 - 18:30 1.00 DRILL P INT2 RIH from shoe back to bottom. Tag fill @ 12086 - (19' offill). 18:30 - 20:30 2.00 DRILL P INT2 Circulate B/U wI minimal cuttings seen @ shakers. Spot 100 bbl. baratrol pill in open hole in preparation for 7" liner. Monitor well. 20:30 - 22:30 2.00 DRILL P INT2 Drop ESS & POH to shoe. Notes: Printed: 6/16/2003 2:07:50 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/11/2002 7/12/2002 - ) ) BP EXPLORATION Operations Slirnma ryReport NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Page 8 of 19 Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: 20:30 - 22:30 From - To Hours Task Code NPT Phase INT2 1) First 10 stands off bottom with drags of 15K to 20K. 2) Dry wiped 3 tight spots one time only @ 11795', 11480' & 11077'. Went back through & pulled back up with no problems. 3) Last 8 stands to shoe were problem free with 1 OK or less of drag. PJSM - Cut & slip drilling line. Waiting on weather to clear to fly linerlhangerlpacker assy, insert landing collar and cement head from West Dock to Northstar Island. Notes: 1) Circulate 35 SPM with bit position 15' below 9 S/8" shoe to prevent any excessive wear on bit, motor or casing. 2) No losses while circulating 35 SPM @ shoe. 3) Performed rig maintenance. 4) Completed yearly boiler inspection -- fired up boilers. 5) First chopper arrived with cement head and insert landing collar -- hold PJSM for RIH while waiting for arrival of C2 Flex Lock liner/hanger/packer. Clean ice from derrick & top drive. Notes: 1. Considerable ice formed in derrick from ice fog. 2. All equipment for running C2 Flex Lock liner hanger assy on location. Perform another wiper trip into open hole section to verify stability of the Jurassic Shales (Miluveach and Kingak). Notes: 1. No problems tripping in hole -- hole in excellent shape. 2. Approximately 10' of fill -- this would have provided 31' of rathole in the Sag if this would have been a liner run. 3. Establish circulation and carefully ream to bottom to prevent packoff. 4. Witness increase in torque and stand pipe pressure while reaming to bottom. Difficult to determine if hole trying to packoff around bit and motor or if we are seeing differential from PDC bit and motor biting into the shale fill -- Conclude differential from motor since no reduction in flowrate and no evidence of ECD increase on PWD to increase fill trying to packoff around upper stabilizer. 5. Narrow VFR window in weather and the HRD liner hanger packer assembly arrived at island at about the time the bit tagged up on fill. Establish circulation, clean out fill, pump sweep, & circulate B/U. Spot Baratroll Baranex pill in open hole. Notes: 1. Questioned Sperry about possible damage to ESS if rotate 80 rpm and pump 12 bpm -- thought not to be a problem but not absolutely sure. 2. Returns at shakers were very much a repeat of the same bottoms up for the previous wiper trip. a) Small ground up cuttings at bottoms up. b) Followed by dark flakes of Kingak shale between bottoms up and the hi-vis weighted sweep. c) Sweep brought much of the same with more 22:30 - 00:00 00:00 - 10:30 10:30-11:00 11 :00 - 12:00 12:00 - 1S:00 2.00 DRILL P 1.50 DRILL P 10.50 DRILL N INT2 WAIT INT2 0.50 DRILL N WAIT INT2 1.00 DRILL N WAIT INT2 3.00 DRILL N WAIT INT2 Description of Operations Printed: 6/16/2003 2:07:50 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) Bp··EXPLORATION Operations.Surnrnary ·Report NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E 7/12/2002 12:00 - 15:00 15:00 - 17:00 17:00 - 17:30 17:30 - 22:00 22:00 - 23:30 7/13/2002 23:30 - 00:00 00:00 - 00:45 00:45 - 01 :45 01 :45 - 07:00 07:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 17:00 Task Code NPT Phase 3.00 DRILL N WAIT INT2 2.00 DRILL N WAIT INT2 0.50 DRILL P 4.50 DRILL P 1.50 DRILL P 0.50 DRILL P 0.75 DRILL P 1.00 CASE P 5.25 CASE P 7.00 CASE P 1.00 CASE P 1.00 CASE P 1.00 CASE P INT2 INT2 INT2 INT2 INT2 INT2 INT2 INT2 INT2 INT2 INT2 Page 9 of 19 Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Description of Operations concentration. d) Hole cleaned while circulating BaranexlBaratrol conditioned pill into open hole, again similar to previous circ POOH and running liner. e) Sperry and Baroid caught samples for borehole stability report. Monitor well - POH to 10' below shoe @ 10444'. Notes: 1) Trip back to shoe was about the same as the last trip wI 20 to 25K of drag. 2) Hole in good shape for running liner. Pump dry job & drop 2 1/2" rabbit. POH to BHA & stand back HWDP. LID BHA. Notes: 1) Did not get good information for from ESS to confirm MWD surveys for Jorps -- ESS was dropped on first attempt to POOH to run liner. a) Batteries damaged - possibly from pumping operations once we ran back to bottom & circulated. b) Battery damage most likely occurred after information was down loaded into tool, but could be a indicator of other reasons why tool failed. c) Suspect Information from ESS - Incl157 deg, Az 56 deg. Clear & clean rig floor. Finish LID stabs & clean up rig floor. PJSM - RIU to run liner. M/U & run 46 jts. of 7" 261b. 521 Hydril & ZXP packer. Filling every jt wI fill up line from trip tank. PIU 1 stand of DP & circulate one liner volume. Notes: 1. Record liner parameters -- PIU wt. 113K & SIO wt 105K- no rotation. 2. Install drill pipe wiper rubber. RIH with 7" Drilling Liner to 10400' md -- inside 9-5/8" casing shoe. Establish circulation and drill pipe and liner volume. Notes: 1. Fill Pipe Every Row -- hole displacement correct. 2. Running Speed 80 seconds per stand. 3. Record Liner parameters: PIU 285k & SIO 215k & 9500 ft. Ibs @ 15 rpm Establish circulation and pump drill pipe and liner volume @ 7 bpm -- shut down, hole static and no losses. Prepare cement head while in shoe. Notes: 1. Add 15' drill pipe pup on stand 90. 2. Break out single from top of stand 91. 3. Mousehole single, MU to cement head, set back and secure on drillers side pipe set back. Run into open hole with 7" liner to 12100' md. Notes: 1. Hole in great shape SIO ranged from 205k to 230k -- smooth. Printed: 6/16/2003 2:07:50 PM ') ) BP EXPLORA rlON Operations Summary Report Page 10of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From... To Hours Task Code NPT Phase Description. of Operations 7/13/2002 16:00 - 17:00 1.00 CASE P INT2 2. Top of Kingak @ 10976' md -- no change in S/O. 3. Top of Sag @ 12094' md -- no change in S/O. 17:00 - 17:30 0.50 CASE P INT2 MU Cement Head. 17:30 - 20:00 2.50 CASE P INT2 Establish Circulation @ 0.5 bpm @ 310 psi and increase based on pressure response to 5 bpm @ 550 bpm. Notes: 1. Reduce rate to 1 BPM & RiH and Tag Fill @ 12096' md -- 9' of fill. 2. PU 2' to 12094' for liner shoe depth -- 30' into Sag River formation. 3. Did not attempt to clean out fill to avoid pack of risk or circulating shale around liner running tool. 4. Did not rotate liner to avoid disturbing Kingak shale to prevent circulating shale cavings around the liner running tool. 20:00 - 20:30 0.50 CASE P INT2 Pressure test cement lines to 4500 psi. 20:30 - 21 :00 0.50 CASE P INT2 Mix and pump spacer and liner cement on the fly. Notes: 1. 35 bbls 13.0 ppg Alpha Spacer 2. 77 bbls (288 sxs) of 15.9 ppg Class G cement (see cement report). 21 :00 - 22:00 1.00 CASE P INT2 Displace with rig pumps and bump plug. Notes: 1. Rig pump bumped plug with 2833 stokes -- 100% efficiency. Never did catch the cement until the right @ the dart latch up with the plug. 2. Halliburton meter showed 2 bbls less than rig stroke counter. 22:00 - 22:30 0.50 CASE P INT2 Set packer, check floats and LD cement head. Notes: 1. Slack off 60k to verify hanger set. 2. Increased pump pressure to 4200 psi to hydraulically release from liner. 3. Bleed pressure to zero and check floats. 4. PU 8 feet to engage dogs and slack off with 65K to set packer. 5. Witnessed bobble to indicate packer set. 6. Slack Off to 175K and rotate 10 rpm for 1 min -- SO increased to 180K. 7. Slack lack off to 165k to add 15K to confirm packer set. 8. PU 5' with tool joint at rotary. 9. LD cement head with single while still stung into tie back with packoff. 10. Engage top drive, pressure up to 500 psi and unsting from packer engage pumps to circulate cement of top of liner. 22:30 - 23:30 1.00 CASE P INT2 Circulate excess cement out of well. Note: Evidence of cement and cement contaminated mud at bottoms up. 23:30 - 00:00 0.50 TA P SURE Begin displacement of 12.0 ppg drilling fluid with sea water. 7/14/2002 00:00 - 00:15 0.25 T A P SURE Continue displacement operations. 00:15 - 01 :00 0.75 TA N RREP SURE Shut Down for rig repairs - repair discharge valve on rig pump and dresser sleeve. 01 :00 - 03:00 2.00 TA P SURE Resume diplacement operations. Notes: Printed: 611612003 2:07:50 PM ) BP EXPLORATION Operations Summary. Report Page 11 of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task. Code NPT Phase Descri ption of Operations 7/14/2002 01 :00 - 03:00 2.00 TA P SURE 1. Utilized both pumps with one on G&I pit and one on sea water line. 2. Clean brine at surface to 84 NTU with 1.25x BU. 3. Reciprocated minimum 31' to overlap tool joints. 4. No rotation to prevent damage to liner running tool. 03:00 - 08:00 5.00 CASE P LNR1 POOH with liner running tool. Notes: 1. Tool looked especially clean when compared to recent wells. 2. All ports and junk slots and slots for dogs were all clean of shale and debris. On recent wells these areas were completely packed off with shale. 08:00 - 09:00 1.00 CASE P LNR1 Lay down liner running tool in pipe shed, bring cement TO head to rig floor and break off the 10 ' pup and clean rig floor. 09:00 - 10:00 1.00 CASE P LNR1 RU cement unit, shut blind rams and test 9-5/8" casing & 7" liner to 4800 psi for 30 minutes. Notes: 1. Well site leader gathered rig crew in dog house and held open forum discussion on personal experiences associated with each item listed on the "AT RISK BEHAVIOR" card. 2. Several individuals expressed that it has revived their awareness level of the risks associated with jobs they perform solo. 3. Some individuals expressed a renewed and strenghened commitment toward working safely. 4. Others simply stated that the card emphasizes positive safe behaviors which they are already committed to. 10:00 -12:00 2.00 TA P SURE PJSM -- RIH open ended with 5" drill pipe to 3000' & RU for freeze protecton of 9-5/8" casing to 1700' md. 12:00 - 12:30 0.50 TA P SURE RU TIW, king pin and swing on drill pipe and line up in cellar with kill line to reverse circulate. 12:30 - 14:30 2.00 TA N WAIT SURE Waiting on production operator to be able to supply diesel to the rig. 14:30 - 14:45 0.25 TA P SURE Hold PJSM for diesel tranfer from OPS to rig. Notes: 1. Production operator present for PJSM. 2. Reviewed powerpoint procedure for diesel transfer. 3. Executed NAD fluid transfer permit. 14:45 - 19:00 4.25 TA P SURE Freeze protect - Reverse circulate 125 bbls @ 1.5 BPM of diesel down 9 5/8" x DP annulus & U-tube. 19:00 - 19:30 0.50 TA P SURE Rig down head pin & monitor well. Well static. 19:30 - 20:45 1.25 TA P SURE POH Notes: 1) Changing out drilling sweeps for production sweeps on annulus valves. 2) RIU kill line on lower annulus valve wI valve & hose to enable blowing down to bleed trailer. 20:45 - 21 :00 0.25 TA P SURE Fill hole wI 21 bbls. of sea water wI hole fill pump via trip tank. 21 :00 - 21 :30 0.50 TA P SURE Pull bowl protector. Bowl protector in good shape. 21 :30 - 23:30 2.00 TA P SURE RIH wI tubing hangar on stand of 5" HWDP & land in hangar profile. Test seals to 5000 psi & hold for 15 min. 23:30 - 00:00 0.50 TA N WAIT SURE Lined up to freeze protect 13 3/8" X 9 5/8" annulus. Printed: 6/16/2003 2:07:50 PM 1- J ) Bp·EXPLORATION Operations Summary. R~port Page 12 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From-To Hours Task Code NPT Phase Descri ptibn · of Operations 7/14/2002 23:30 - 00:00 0.50 TA N WAIT SURE Troubleshooting electrical problems with Production's diesel transfer pump @ diesel fuel tank farm. (low pressure switch kicking out pump) 7/15/2002 00:00 - 00:30 0.50 TA P SURE Crew Change and RU lines to freeze protect. 00:30 - 02:30 2.00 TA P SURE Freeze protect 13 3/8" X 9 5/8" annulus wI 120 bbls of diesel @ 1.5 BPM. Notes: 1. Pressure broke over after pumping 13.5 bbls. @ 1730 psi. 2. Final pressure @ 120 bbls. pumped was 1540 psi. 02:30 - 03:00 0.50 TA P SURE RIU on upper annulus to test TWC & prod. sweeps via Halliburton. Test lines to 4200 psi. Test failed. Bled off & replaced valve on manifold in cellar. 03:00 - 04:30 1.50 TA P SURE Retest lines to 4200 psi - okay. Bled off pressure & opened upper annulus valve & tested to 4200 psi. Held for 35 min - final pressure @ 4115 psi. 04:30 - 05:00 0.50 TA P SURE Bleed off pressure to bleed trailer via manifold. 05:00 - 10:00 5.00 TA P SURE PJSM - NID riser & BOP's 10:00 - 12:00 2.00 TA N RREP SURE Troubleshoot & repair hydraulic problem wI cellar bridge crane. 12:00 - 13:00 1.00 T A P SURE Stand BOP's back in cradle & secure. 13:00 - 14:00 1 .00 T A P SURE Rack back BOP stack in stand. 14:00 - 16:00 2.00 TA P SURE NU and Test Tree to 5000 psi. 16:00 - 17:00 1.00 TA P SURE Finish Rigging Down off NS16. Notes: 1. Release rig from NS16 on 071502 @ 1700 hrs. 2. Next well NS18. 3/16/2003 07:00 - 12:00 5.00 MOB P SURE PJSM for Rig Move from NS12 to NS16. - Move rig from NS12 to NS16. - Operations SI and bringing on wells as the rig passes over them. 12:00 - 14:00 2.00 MOB P SURE Complete rig move- level up rig. - Prepare cellar for work. 14:00 -19:00 5.00 BOPSURP SURE *******ACCEPT RIG ONTO NS16 @ 1400 HRS 3/16/2003****** PJSM for NU BOP's. - Wells in cellar are: NS15, NS17, and NS18. Install gas detector in NS15 wellhouse. - NU Drilling Sweeps - NU BOP's. 19:00 - 20:00 1.00 BOPSUR P SURE PJSM. RU and pull hanger. Run test plug. 20:00 - 00:00 4.00 BOPSUR P SURE PJSM. Pressure test BOP's to 250/4800 psig. - AOGCC Rep. Chuck Scheve out to witness test. 3/17/2003 00:00 - 01 :00 1.00 BOPSURP SURE Continue BOP test to 250/4800 psig. - AOGCC Rep. Chuck Scheve out to witness. 01 :00 - 02:00 1.00 CASE P SURE Pull Test Plug. Set wear ring. 02:00 - 04:00 2.00 CASE P SURE PJSM for diesel displacement. - Test line to G & I to 100 psig wI Sea water. 04:00 - 05:00 1.00 CASE P SURE RIH wI 4" DP to 2000' md. 05:00 - 07:00 2.00 CASE P SURE Close bag and displace diesel through choke wI sea water from pipe rack. 07:00 - 08:00 1.00 CASE P SURE Clean up Trip tank and take on clean sea water for hole fill on TOH. Printed: 6/16/2003 2:07:50 PM ) ) BP EXPLORATION Operations Summary Report Page 13 of 19 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: DRILL +COMPLETE Start: 6/28/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2003 08:00 - 08:30 0.50 CASE P SURE BOP Drill (01) Kick while Tripping. 08:30 - 09:30 1.00 CASE P SURE Trip out of hole with 4" DP. 09:30 - 11 :30 2.00 CASE P SURE PJSM for casing/liner test wI HOWCO. - Pressure test lines to 5000 psig. - Close blind rams and test to 4800 psig fl 30 mins. - Blow down lines. Prespud Meeting held with crews and discussed Lost Circulation. 11:30-15:00 3.50 CASE P LNR1 PJSM wI both crews for MU of BHA#5. MU BHA #5: > Smith 6-1/8" XR30YD20DGPD (TFA=.518/3x15 Jets); 4-3/4" PDM; NM IB Stab; ADN4; ARC5; MWD, 2x NM DC's; and 4-3/4" PBL Sub (2-port). 15:00 - 16:00 1.00 CASE P LNR1 Shallow Test MWD and new PBL sub. - Retrieve balls from PBL sub. 16:00 - 18:00 2.00 CASE P LNR1 PU 6 Jts total of 4" HWDP from pipeshed. RIH wI BHA #5 wI 24 stds of 4" DP. 18:00 - 22:00 4.00 CASE P LNR1 Change over to 5" handling equipment and RIH to 10171' md, above 7" liner top @ 10265' md. 22:00 - 23:00 1.00 CASE P LNR1 Break circulation and pump 100 bbls viscosified sea water. - Blow down lines and TO. 23:00 - 00:00 1.00 CASE P LNR1 RIH wI BHA#5 into 7" liner. 3/18/2003 00:00 - 01 :30 1.50 CASE N WAIT LNR1 Waiting on production to swap fuel gas (power lost to the rig). 01 :30 - 02:30 1.00 CASE P LNR1 Trip in hole to 11967'MD. 02:30 - 03:00 0.50 CASE P LNR1 Wash and ream to 12,015' MD. Tagged landing collar. 03:00 - 05:00 2.00 CEMT P LNR1 Drill landing collar at 12,015' MD. Drilled through landing collar real quick. NOTE: Initial on bottom torque of 16k ftlb. Very close to the model. 05:00 - 07:00 2.00 CEMT P LNR1 Displace well with 9.1 ppg drill in fluid while drilling shoetrack to within 15 ft of shoe. 07:00 - 08:30 1.50 CEMT P LNR1 Drill remainder of shoe track. Shoe at 12,094' MD. 08:30 - 09:30 1.00 CEMT P LNR1 Drill 20 feet of new formation to 12,125'MD. 09:30 - 10:00 0.50 CEMT P LNR1 Condition mud and circulate for FIT. 10:00 - 10:30 0.50 CEMT P LNR1 RIU and Perform FIT to 11.5 ppg. NOTE: 1. 9.2 ppg mud in the hole. 2. Surface pressure at 1300 psi. 3.8 bbls pump/return 10:30 - 11 :00 0.50 DRILL P PROD1 Pre-reservoir drilling meeting on well control while monitoring pressure. 11 :00 - 21 :30 10.50 DRILL P PROD1 Drill from 12,125' MD to 12,424'MD. No Drag, No Losses. NOTE: 1. No losses were incurred. 2. Minimal shocks were observed. 3. 60 rpm I 90 spm I 320 gpm 4. 16k off bottom; 19k on bottom torques. 21 :30 - 00:00 2.50 DRILL P PROD1 Circulate 100 bbl (4 open hole volumes). Printed: 6/16/2003 2:07:50 PM ) Bp· EXPLORATION o þe rations·· Sum rnary . Report Pagé140f 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From -TbHours Task Code NPT Phase Description of Operations 3/18/2003 21 :30 - 00:00 2.50 DRILL P PROD1 MAD pass from 12,424'MD to 7" shoe at 12,095'MD Pumpingl Rotating OOH @ 180 ftlhr. 3/19/2003 00:00 - 00:30 0.50 DRILL P PROD1 Finish MAD pass from 12,424' MD to 12,094' MD (7" shoe). 00:30 - 03:30 3.00 DRILL P PROD1 Open PBL. Circulate sweep. Circulate the hole clean. Prior to pumping the dry job, attempted to lock the PBL open by dropping the locking ball. No clear indication was observed that the ball had seated. Decided to drop the closing balls (two steel balls) to close the PBL, taking the dry job out the BHA. The closing balls did pressure up in a way that indicated the locking ball did, in fact, seat. NOTE: 1. Circulated the opening ball down at 16 bpm, slowing to 3.5 bpm at 1700 strokes (2400 strokes surface to bit). 2. When ball seated, saw a 200 psi decrease. 3. At approximately 9000 strokes, saw good Ivishak cuttings returned (6500 strokes for bottoms up) 4. The locking ball was dropped - no indication it set. Pressures increased from 400 psi to 405 psi. 5. Dropped the closing balls. The first ball seated saw significant pressure increase, the second ball seated increased pressure as well, shearing out the initial opening ball. The final circulating pressure was 1650 psi. 6. Dry job successful. 03:30 - 04:00 0.50 DRILL P PROD1 Monitor well for 30 minutes. Drop the hollow rabbit (from joint 100). 04:00 - 05:30 1.50 DRILL P PROD1 Trip out of hole to the 7" liner top. Hole taking correct fill. 05:30 - 06:00 0.50 DRILL P PROD1 Monitor well for 30 minutes at 7" liner top. 06:00 - 09:30 3.50 DRILL P PROD1 Trip out of hole with 5" drillpipe. 09:30 - 10:00 0.50 DRILL P PROD1 Monitor well for 30 minutes at top of 4" drillpipe. 10:00 - 11 :00 1.00 DRILL P PROD1 Trip out of hole and stand back 4" drillpipe. 11 :00 - 14:30 3.50 DRILL P PROD1 PJSM -- Lay down HWDP and BHA #5. 14:30 - 15:00 0.50 DRILL P PROD1 PJSM -- Clear rig floor. 15:00 - 16:00 1.00 CASE P COMP PJSM -- Rig up to run 4 1/2" liner 16:00 - 17:30 1.50 CASE P COMP Run in hole with 41/2" 13Cr 12.6# liner. NOTES: 1. Checked floats. 2. Ran 11 joints and one 6" marker joint on top of joint #5. 17:30 - 20:30 3.00 CASE P COMP PJSM -- Rig up and run 2.7/8" inner string. Fill annulus with viscosified brine. NOTES: 1. Ran 14 joints of 2.7/8" Kawasaki Fox, 8.25' pup, and liner wiper plug assy. 2. Tagged landing collar with innerstring - total of 9' high given 4' above rotary table and 5' spaceout from the landing collar. Laid down 8.25' pup. Printed: 6/16/2003 2:07:50 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/19/2003 3/20/2003 ) BP EXPLORATION Operations Summary Report Page 150f19 . NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: From - To Hours Task Code NPT Phase Description of Operations 17:30 - 20:30 3.00 CASE P COMP 3. Filled the 4 1/2" x 27/8" annulus with 9.3 ppg viscosified brine. 20:30 - 21 :30 1.00 CASE P COMP Make up hangerlpacker assembly. 21 :30 - 22:00 0.50 CASE P COMP Rig down liner running tools. 22:00 - 22:30 0.50 CASE P COMP Make up a stand of 4" drillipipe. Circulate 10 bbls to verify returns. 22:30 - 00:00 1.50 CASE P COMP Run in hole with 4" drillpipe. Fill pipe every 10 stands. Good hole fill. 00:00 - 07:30 7.50 CASE P COMP Trip in hole with 4 1/2" liner and 2 7/8" innerstring. Fill pipe every 10 stands. 07:30 - 08:30 1.00 CASE P COMP At 12,094' MD (7" liner shoe), circulatae one string volume @ 5 BPMI 600 psi 08:30 - 09:00 0.50 CASE P COMP Continue to trip in the hole to TO at 12,424' MD. NOTES: 1. 305k PU I 230k SO 09:00 - 12:30 3.50 CEMT P COMP Pick up cement head. Break circulation and stage up pumps to 6.5 bpm (730 psi) for cement job. 12:30 - 14:00 1.50 CEMT P COMP PJSM -- Cement 4 1/2" liner. Set packer and release running tool. NOTES: 1. Test cement lines to 4700 psi. 2. Pump 25 bbls of weighted Alpha spacer. 3. Pump 23 bbls of 15.9 ppg Class G Premium cement at 3.5 bpm and 400 psi. Plug left tee. 4. Total of 18 bbls of cement downhole, 5 bbls flushed out of surface lines. 5. Pump 5 bbls of 10 ppg viscosified brine behind cement. 6. Displace cement with drilling mud at 6 bpm and 400 psi. 7. Bump the plug at 95% efficiency and pressure to 4200 psi. ( Correct on flowmeter- 190 bbls) 8. Slack off to set hanger. 9. Pick up 8' after stretch to expose dogs. set liner top packer. Verify. Rotate. 14:00 -15:00 1.00 CEMT P COMP Circulate out cement at 17 bpm. Cement back to surface = 8 bbls. NOTES: 1. Pressured up to 1000 psi. 2. Pick up approximately 15' keeping pressure @ 1000 psi. and circulate at 17 BPMI 3000 psi. 3. Total feet off bottom = 23 feet. No reciprocation. 15:00 - 16:00 1.00 CEMT P CaMP Test casing to 1500 psi for 30 minutes. PJSM -- Displace well to seawater. 16:00 - 16:30 0.50 CEMT P COMP Rig down cement head and lines. 16:30 - 19:00 2.50 CEMT P COMP Displace the well to seawater. Final NTU reading = 60 NTU at 14,000 strokes. 19:00 - 19:30 0.50 CEMT P COMP Negative pressure test on well for 30 minutes. PJSM - POOH with running tool and inner string. 19:30 - 00:00 4.50 CEMT P COMP POOH with liner running tool and innerstring. Printed: 6/16/2003 2:07:50 PM ) ) . BP EXPLORATIQN OperationsSÜmmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date Page ·16of19 Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: From - To Hours Task· Code NPT Phase Description of Operations 3/21/2003 00:00 - 02:30 2.50 CEMT P 02:30 - 03:30 1.00 CEMT P 03:30 - 07:30 4.00 CEMT P 07:30 - 08:00 0.50 CEMT P 08:00 - 12:00 4.00 CEMT P 12:00 - 12:30 0.50 CEMT P 12:30 - 14:00 1.50 WHSUR P 14:00 - 14:30 0.50 WHSUR P 14:30 - 16:15 1.75 WHSUR P 16:15-17:30 1.25 RIGD P 17:30 - 19:00 1.50 RIGD P 19:00 - 19:45 0.75 RIGD N 19:45 - 20:15 0.50 RIGD P 20:15 - 22:30 2.25 RIGD P 22:30 - 22:45 0.25 RIGD P 22:45 - 23: 15 0.50 RIGD P 23:15 - 00:00 0.75 RIGD P 6/9/2003 18:00 - 22:00 4.00 MOB P 22:00 - 23:00 1.00 RIGU P 23:00 - 00:00 1.00 RIGU P 6/10/2003 00:00 - 02:30 2.50 RIGU P 02:30 - 03:30 1.00 RIGU P 03:30 - 08:00 4.50 BOPSUR P 08:00 - 10:30 2.50 BOPSUR P 10:30 - 14:00 3.50 BOPSUR P 14:00 -15:00 1.00 BOPSUR P 15:00 - 16:00 1.00 RIGU P 16:00 - 19:00 3.00 RIGU P 19:00 - 20:30 1.50 RIGU P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP WAIT COMP COMP COMP COMP COMP COMP SURE SURE SURE SURE SURE SURE SURE SURE SURE SURE SURE SURE Trip out of hole to 2200' MD. Break down cement head. PJSM -- Rig up to displace well to freeze protect fluid. Reverse circulate in 120 bbls of heated (45 degree) diesel. U-tube same. Flow check well for 30 minutes. Trip out of hole with 4" drillipipe. Lay down liner running tool and 2.7/8" inner string. Pressure test casing to 4370 psi for 30 minutes. 12.9 bbls pump/returned. Pull wear bushing. Install tubing hanger and BPV. Test hanger to 5000 psi for 15 minutes. PJSM -- Rig up kill line to upper annulus. Test under BPV to 4200 psi for 15 minutes. Blow down mud and kill lines. PJSM -- Pull floor plate, mouse hole, bushings, and risers in preparation for rig move. Nipple down BOP's. Shut in NS-15 and NS-17. Notified Control Room at 18:00 of upcoming heavy lift at 19:00 hrs. Confirmed at 18:30. Wells still not shutin. Waiting on production. Set BOP on rack. PJSM -- Set and Nipple up dry hole tree. Test API area to 5000 psi for 15 minutes. Clear rig floor. PJSM -- Rig Move. Move off NS16. Release rig at 00:00 03/22/03. PJSM. Move Rig from NS23 to NS16. ACCEPT RIG @ 2200 Hrs on 6/9/2003. Shim and level rig. Lower stair landings and begin rigging up. Burm rig. Put steps and hand rails in place. Put derrick climber and geronimo line in place. Walk ways in place. Clean pad area around NS23. Nipple down dry hole tree. PJSM -- Nipple up the BOPE. Pull hanger. Set test plug. Fill stack. PJSM -- Pressure test BOPE to 250 psi low I 4800 psi high. Rig down test equipment. Blow down choke /lines. Set wear ring. PJSM -- RIH with 4" drillpipe. Rig up to displace diesel. PJSM -- Displace diesel with 150 bbls of seawater from the pipe rack at 1.5 bpm, followed by 150 bbls of filtered seawater from G&I at 6 bpm. Rig down pumping equipment and latch on to drillpipe to check hole center in relation to rotary bushing. Pull stack to the Southwest with turnbuckles and raise rig on the Southwest corner to center pipe. Note: This did not make a significant amount of difference. The direction of the well (270-290 deg AZ) is pulling the pipe to the West, thus causing the pipe to rub. The decision was made that whife running the completion, the cables will be Printed: 6/16/2003 2:07:50 PM ) ) BP EXPLORATION Opetati.ons SummaryRË:Jport Page 170f 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 6/10/2003 19:00 - 20:30 1.50 RIGU P SURE positioned to the Northwest to prevent damaging the cables while going through the dogleg. 20:30 - 21 :30 1.00 RIGU P SURE POOH, Laying down 66 joints of 4" drill pipe. 21 :30 - 22:00 0.50 RIGU P SURE Pull wear bushing. 22:00 - 23:45 1.75 RIGU P SURE PJSM -- Rig up and test casing to 4370 psi for 30 minutes. 23:45 - 00:00 0.25 RIGU P SURE Blow down all lines and choke. 6/11/2003 00:00 - 03:00 3.00 RUNCOrvP COMP Remove 4" drillpipe from pipe shed. Clear floor. Lay down short bales. Pick up long bales. Rig up compensator and 4.5" elevators. Rig up Gator Hawk and Weatherford equipment. 03:00 - 13:00 10.00 RUNCOrvP COMP Run in hole with 4.5" 13Cr-80 VAM ACE completion. Notes: 1. Vam inspecting every connection. 2. Gator Hawk testing each connection with water to 5000 psi for 15 seconds. 3. Torque turning each connection. 4. Weatherford monitoring cable integrity every hour. 13:00 - 15:00 2.00 RUNCOMN SFAL COMP Gator Hawk seal failure. Replace same. 15:00 - 00:00 9.00 RUNCOrvP COMP Run in hole with 4.5" 13Cr-80 VAM ACE completion. Notes: 1. Vam inspecting every connection. 2. Gator Hawk testing each connection with water to 5000 psi for 15 seconds. 3. Torque turning each connection. 4. Weatherford monitoring cable integrity every hour. 5. #152 joints in hole. 6/12/2003 00:00 - 12:00 12.00 RUNCOrvP COMP Run in hole with 4.5" 13Cr-80 VAM ACE completion. #254 joints in hole. Notes: 1. Vam inspecting every connection. 2. Gator Hawk testing each connection with water to 5000 psi for 15 seconds. 3. Torque turning each connection. 4. Weatherford monitoring cable while RIH. 12:00 - 12:30 0.50 RUNCOrvP COMP Check crown-o-matic and service power tongs. 12:30 - 13:00 0.50 RUNCOrvP COMP Run in hole with 4.5" 13Cr-80 VAM ACE completion. #257 joints in hole. Notes: 1. Vam inspecting every connection. 2. Gator Hawk testing each connection with water to 5000 psi for 15 seconds. 3. Torque turning each connection. 4. Weatherford monitoring cable integrity every hour. 13:00 - 13:30 0.50 RUNCOrvP COMP Pickup ball valve and hook up control line. Pressure up line to 6000 psi and hold for 15 minutes. 13:30 - 15:30 2.00 RUNCOrvP COMP Run in hole with 4.5" 13Cr-80 VAM ACE completion. #278 joints in hole. Notes: Printed: 6/16/2003 2:07:50 PM ) ) BP EXPLORATION OperationsSurhma ryRe port Page 18 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E Spud Date: 6/29/2002 End: Date From - To Hours Task Code NPT Phase Description of. Operations 6/12/2003 13:30 - 15:30 2.00 RUNCOrvP COMP 1. Vam inspecting every connection. None rejected. 2. Gator Hawk testing each connection with water to 5000 psi for 15 seconds. No failures. 3. Torque turning each connection. Backed out two connections. 4. Weatherford monitoring cable integrity while RIH. Slightly crimped cable twice, both times integrity in tact. 15:30 - 17:30 2.00 RUNCOrvP COMP RIH to #281. Tag and spaceout with 35.4' of pups (4 total). Pick up tubing hanger. 17:30 - 18:30 1.00 RUNCOrvP COMP Hook up control line to hanger. Splice Weatherford fiber optic cable. 18:30 - 19:00 0.50 RUNCOrvP COMP Land hanger. RILDS. Test seals to 5000 psi. 19:00 - 22:00 3.00 RUNCOrvP COMP Rig up lines for setting I testing packer and circulating freeze protection. Test lines to 4700 psi. 22:00 - 23:00 1.00 RUNCOrvP COMP Pressure up on tubing to set packer. Hold 4250 psi for 30 minutes. Bleed tubing to 2700 psi and shut in. 23:00 - 00:00 1.00 RUNCOrvP COMP Pressure up on annulus to 4200 psi and hold for 30 minutes. Bleed annulus to 0 psi. Bleed tubing to 0 psi. 6/13/2003 00:00 - 00:30 0.50 RUNCOrvP COMP Pressure up annulus to 2500 psi for RP shear. Circulate at 2 bpm for 5 minutes to ensure RP shear latches open. Close TRSV and pressure up annulus to 1000 psi to test TRSV from below for 30 minutes. 00:30 - 01 :00 0.50 RUNCOrvP COMP PJSM for pumping inhibited seawater and diesel for freeze protection. 01 :00 - 05:30 4.50 RUNCOrvP COMP Open TRSV and pump freeze protection. Notes: 1. Pump 25 bbls of corrosion inhibitor, followed by 30 bbls of seawater at 3 bpm. 2. Pump 320 bbls of diesel with 2 drums of corrosion inhibitor bled in at 1.5 bpm. 3. Follow all with 10 bbls of seawater flush. 05:30 - 10:00 4.50 RUNCOrvP COMP U-tube. Note: The u-tubing effect took a liitle while to get going; however, fiber optic tubing pressure indicated u-tubing was occuring. 10:00 - 11 :00 1.00 RUNCOrvP COMP Install TWC and test to 1000 psi from below for 30 minutes. 11 :00 - 14:00 3.00 RUNCOrvP COMP Clear floor. Notes: 1. Rig down Weatherford Equipment. 2. Rig down Gator Hawk Equipment. 3. Rig down Nabors Casing Equipment. 4. Flush mud manifold, cement line, kill line and stand pipe with fresh water. Blow down. 14:00 -15:00 1.00 WHSUR P COMP Pull bushings and clean under rotary table. 15:00 - 17:00 2.00 WHSUR P COMP Pull all ram blocks from BOP. 17:00 - 19:30 2.50 WHSUR P COMP Nipple down risers and shut in wells. 19:30 - 19:45 0.25 WHSUR P COMP Rack back BOP's on holder. 19:45 - 00:00 4.25 WHSUR P COMP Terminate TRSV line. Splice fiber optic control line. Install dry hole tree. Printed: 6/16/2003 2:07:50 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION Operations Summary Report . NS16 NS16 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 6/28/2002 Rig Release: Rig Number: 33E From - To Hours Task Code NPT Phase COMP 6/13/2003 19:45 - 00:00 4.25 WHSUR P Release rig at 00:00 hrs. 06/14/03 Page 19 of19 Spud Date: 6/29/2002 End: Descri ption· of Operations Printed: 6/16/2003 2:07:50 PM ') ') NS16 Northstar Unit 50-029-23096-00 202-127 Accept: Spud: Release: 06/29/03 06/29/03 07/15/03 Nabors 33E POST-RIG WORK 06/30/03 PJSM. MIRU. RIH WI 3.6011 BELL GUIDE & 211 JD PULLING TO 11882' MD. PULL BALL & ROD. RIH WI 4-1/211 OK-1 TO 800' AND SET DOWN. RIH WI BRAIDED LINE BRUSH AND BRUSH 800-1200' WLM. RIH WI 4-1/211 OK-1 KOT AND SET DOWN AT 8301 WORK TOOLSTRING DOWN TO 945' WLM WHERE TOOLS STARTED FALLING FREELY. WORK TOOLS FI 800-1200' WLM UNTIL FALLING FREELY. RIH TO 2200' WLM. POH TO REBUILD KOT. RIH AND PULL RP SHEAR AND SET 111 DGLV WI BK-LATCH. RIH AND PULL RHC PLUG BODY FROM 'XN' AT 11882' WLM. 07/01103 POH WI 4.511 IRHC' PLUG BODY RIH WI 12' X 2-7/811 DUMMY GUN & SAMPLE BAILER TO 123651 SLM. POH. 07/14/03 GAMMA RAY-CCL LOGGED FROM TD 12393' UP TO 10000'. LOG TIED INTO GR PDC LOG DATED 2-DEC-2002. PERFORATE WITH 2-7/811 HSD 2906 PJ HSD GUNS 6SPF - 60 DEG RANDOM FROM 12364'-12384' - DEPTHS REFERENCED TO TO DAYS GR LOG- DEPTH SHIFTED +6' FROM MWD LOG. GUN API DATA IN 4-1/211 CASING: PEN= 2711, EHD= 0.3611. 07/15/03 PERFORATE INTERVAL 12304'-12384' (BOTTOM 20' PERFED 7/14/03) WITH 2-71811 HSD 2906 PJ HSD GUNS 6SPF - 60 DEG RANDOM. DEPTHS REFERENCED TO GR LOG- LOGGED 12-JUL Y- 2003. GUN API DATA IN 4-1/211 CASING: PEN= 2711, EHD= 0.3611. AFTER FIRST RUN WHP UP TO 300 PSI- WHP REMAIN 300 PSI THROUGHOUT JOB. Legal Name: Common Name: Test Date 7/3/2002 7/10/2002 7/3/2002 3/18/2003 FIT FIT FIT FIT NS16 NS16 Test Type Test Depth (TMD) 3,494.0 (ft) 10,434.0 (ft) 3,494.0 (ft) 12,125.0 (ft) ~ BP.EXPLORATION Leak-Off..Test·Surnrnary Test DepthJTVD) 3,201.0 (ft) 9,293.0 (ft) 3,201.0 (ft) 10,862.0 (ft) AMW 8.70 (ppg) 12.00 (ppg) 8.70 (ppg) 9.20 (ppg) Sul'facePressure '-eaI<Offprès~ul"~(I3HP.) 2,107 (psi) 6,763 (psi) 2,107 (psi) 6,491 (psi) 660 (psi) 970 (psi) 660 (psi) 1,300 (psi) EMW 12.67 (ppg) 14.01 (ppg) 12.67 (ppg) 11.50 (ppg) _/ -.,../ Printed: 6/16/2003 2:07:43 PM hp U.J NS16 Schlumberger Survey Report - Geodeti : Report Date: 19-Mar-03 Survey I DLS Computajon Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical ~ect'on Azimuth: 267.320° Field: Northstar Vertica· Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS 16 TVD Reference Datum: K8 Well: NS16 TVD Refe~ence Elevation: 56.460 ft relative to MSL Borehole: NS16 Sea Bed I Ground bvel Elevation: 15.670 ft relative to MSL .. UWUAPI#: 500292309600 Magn~tic Declination: +26.294° ; Survey Name I Date: NS16/March 19,2002 TotE I Fi~ld Strength: 57541.798 nT -~ Tort I AHD I DDII ERD ratio: 110.317° /5197.41 ft /5.805/ 0.466 ~ - agnetic Dip: 80.943° t Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel ['ecl'nation Date: July 01, 2002 ~' Location LatILong: N 70.49115951, W 148.6932993E Magnetic D~clir ation Model: 8GGM 2002 Location Grid NIE Y/X: N 6030971.560 ftU8, E 659829.810 ftUS ~orh Reference: True North Grid Convergence Angle: +1.23170678° Total Corr Mag Nor.h -> True North: +26.294° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head I Grid Co~rdinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6030971.56 659829.81 N 70.49115951 W 148.69329938 50.00 0.94 282.89 50.00 0.40 0.09 -0.40 1.88 6030971.64 659829.41 N 70.49115976 W 148.69330264 100.00 1.39 278.89 99.99 1.38 0.28 -1 .40 0.91 6030971.81 659828.41 N 70.49116026 W 148.69331081 150.00 2.24 275.10 149.96 2.95 0.46 -2.97 1.72 6030971.95 659826.83 N 70.49116076 W 148.69332366 200.00 2.39 275.77 199.92 4.95 0.65 -4.98 0.30 6030972.10 659824.82 N 70.49116128 W 148.69334010 269.00 2.54 273.98 268.86 7.89 0.90 -7.94 0.24 6030972.29 659821.85 N 70.49116197 W 148.69336427 361.00 2.49 280.72 360.77 11.86 1.41 -11.94 0.33 6030972.72 659817.85 N 70.49116337 W 148.69339694 450.00 2.76 280.11 449.68 15.83 2.15 -15.94 0.30 6030973.37 659813.82 N 70.49116538 W 148.69342('- J 540.00 3.34 277.39 539.55 20.52 2.87 -20.68 0.66 6030973.98 659809.08 N 70.49116734 W 148.69346~ 630.00 4.93 271.58 629.31 26.96 3.31 -27.14 1.82 6030974.29 659802.60 N 70.49116855 W 148.69352126 720.00 5.79 272.70 718.92 35.34 3.63 -35.54 0.96 6030974.43 659794.20 N 70.49116943 W 148.69358993 if 810.00 7.38 276.28 808.32 45.57 4.48 -45.83 1.82 6030975.05 659783.90 N 70.49117174 W 148.69367396 ,. 843.00 7.95 279.91 841 .03 49.89 5.10 -50.18 2.27 E030975.58 659779.54 N 70.49117344 W 148.69370956 " 933.38 9.34 286.36 930.38 . 62.9_2 8.24 -63.38 1.87 f030978.44 659766.28 N 70.49118203 W 148.69381742 '. 1- 1028.89 11.60 282.98 1024.29 79.50 12.58 -80.17 2.45 E 030982.42 659749.39 N 70.49119388 W 148.6939547'. 1123.71 13.90 274.23 1116.78 99.99 15.57 -100.82 3.16 E030984.95 659728.68 N 70.49120203 W148.69412353 1219.39 15.75 271.83 1209.27 124.34 16.83 -125.27 2.04 E030985.69 659704.22 N 70.49120548 W 148.69432333 1314.14 16.66 273.18 1300.25 150.67 17.99 -151.68 1.04 E 030986.29 659677.79 N 70.49120866 W 148.6945392~ Schlumberger Private Page 1 of 5 3/28/2003-4:34 PM NS16 ASP Final Survey.xls ¡ Grid Co~rdinates Geographic Coordinates Station ID MD Incl Azim TVD VSéC N/·S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 1409.45 18.76 274.53 1391.04 179,47 19.96 -180.60 2.24 6030987.63 659648.83 N 70.49121403 W 148.69477567 1503.93 20.84 272.53 1479.93 211.29 21.90 -212.54 2.32 6030988.89 659616.86 N 70.49121934 W 148.6950367q 1599.00 23.64 269.29 1567.93 247.19 22.41 -248.51 3.21 8030988.63 659580.90 N 70.49122073 W 148.69533071 1694.87 26.08 265.29 1654.91 287.46 20.44 -288.74 3.09 6030985.79 659540.72 N 70.49121534 W 148.69565957: 1790.01 28.82 262.16 1739.34 331.21 15.60 -332.31 3.25 6030980.01 659497.27 N 70.49120210 W 148.69601572 1882.86 29.69 264.05 1820.34 376.46 10.16 -377.35 1.37 6030973.61 659452.36 N 70.49118724 W 148.69638391 1978.38 30.93 266.35 1902.81 424.63 6.15 -425,38 1.78 6030968.56 659404.43 N 70.49117626 W 148.6967765~ 2072.62 31.50 268.16 1983.41 473.46 3.81 -474.16 1.16 6030965.18 659355.71 N 70.49116988 W 148.69717524 2168.92 30.96 269.24 2065.75 523.37 2.68 -524.07 0.81 6030962.97 659305.84 N 70.49116677 W 148.697583?5 2265.53 30.80 270.92 2148.67 572.90 2.74 -573.65 0.91 6030961.97 659256.27 N 70.49116695 W 148,6979E 2362.71 30.66 271.72 2232.20 622.43 3.89 -623.30 0.44 6030962.05 659206.62 N 70.49117006 W 148.698394'!3 2458.01 31.65 268.49 2313.76 671.66 3.96 -672.58 2.04 6030961.06 659157.35 N 70.49117024 W 148.6987972- 2552.39 31.30 269.41 2394.26 720.92 3.05 -721.85 0.63 6030959.10 659108.11 N 70.49116775 W 148.6991999L 2648,36 31.39 270.86 2476.22 770.78 3.17 -771.77 0.79 6030958.14 659058.20 N 70.49116806 W 148.69960799 2743.14 31.60 267.08 2557.05 820.25 2.28 -821.26 2,09 6030956.18 659008.75 N 70.49116561 W 148.70001249 2838.55 31.72 266.63 2638.26 870.33 -0.47 -871.26 0.28 6030952.36 658958.82 N 70.49115808 W 148.70042122 2933.88 29.79 267.61 2720.18 919,07 -2.93 -919.94 2.09 6030948.86 658910.21 N 70.49115134 W 148.7008191fB io "":; 1 3029.84 29.89 267.67 2803.42 966,82 -4.90 -967.65 0.11 6030945.87 658862,56 N 70.49114596 W 148.70120913 3124.90 30.51 268.03 2885.57 1014.64 -6.69 -1015.43 0.68 6030943.05 658814.83 N 70.49114104 W 148.70159971 3221 .44 31.26 267.72 2968.42 1064.19 -8.53 -1064.95 0.79 6030940.14 658765.36 N 70.49113600 W 148.70200451 3316.59 31.97 268.30 3049.45 1114.06 -10.26 -1114.80 0.81 6030937.34 658715.57 N 70.49113125 W 148.70241197 3409.86 31.70 268.34 3128.69 1163.25 -11.70 -1163.98 0.29 6030934.84 658666.44 N 70.49112729 W 148.70281394- ì 3446.83 31.52 269.04 3160.18 1182.62 -12.14 -1183.35 1.11 8030933.98 658647.08 N 70.49112607 W 148.70297229 3602.01 31.10 267.68 3292.76 1263.25 -14.45 -1263.95 0.53 6030929.95 658566.55 N 70.49111975 W 148.70363116 3696.89 31.62 267.17 3373.78 1312.62 -16.67 -1313.28 0.62 6030926.67 658517.29 N 70.49111366 W 148.70403 3793.31 31.82 266.19 3455.80 1363.31 -19.60 -1363.89 0.57 6030922.65 658466.76 N 70.49110561 W 148.704440.,..( 3888.26 32.15 265,81 3536.33 1413.59 -23.11 -1414.06 0.41 6030918.06 658416.68 N 70.49109600 W 148.70485814 3983.92 31.75 265.41 3617.50 1464.19 -26.99 -1464.53 0.47 6030913.10 658366.30 N 70.49108539 W 148.70527071 4079.27 31.47 264.37 3698.70 1514.12 -31.44 -1514.31 0.64 6030907.59 658316.64 N 70.49107321 W 148.7056775f} 4173.31 30.90 263.69 3779.15 1562.74 -36.50 -1562.74 0.71 6030901.48 658268.33 N 70.49105935 W 148.70607344- 4267.53 30.39 262.50 3860.22 1610.63 -42.27 -1610.41 0.84 6030894.69 658220.79 N 70.49104356 W 148.70646313 4363.74 30.22 261.74 3943.28 1658,98 -48.92 -1658.50 0.44 6030887.00 658172.86 N 70.49102535 W 148.7068562- 4459.43 29.82 260.41 4026.13 1706.56 -56.35 -1705.79 0.81 E030878.57 658125.74 N 70.49100504 W 148.70724277 4555.46 29.48 260.40 4109.59 1753.72 -64.26 -1752.64 0.35 E030869.64 658079.09 N 70.49098338 W 148.7076256L 4651,24 29.06 260.14 4193.14 1800.20 -72.18 -1798,79 0.46 6030860.74 658033.12 N 70.49096173 W 148.7080029(' Schlumberger Private NS16 ASP Final Survey.xls Page 2 of 5 3/28/2003-4:34 PM Grid Co;rdinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/·S EJ·W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) e/100ft) (ftUS) (ftUS) 4746.57 28.42 259.67 4276.73 1845.65 -80.21 -1843.92 0.71 6030851.74 657988.17 N 70.49093976 W 148.708.37171' =, 4841.21 27.87 259.76 4360.18 1889.90 -88.18 -1887.84 0.58 6030842.83 657944.43 N 70.49091795 W 148.70à7308Ò 4934.90 27.43 260.53 4443.17 1933.04 -95.62 -1930.68 0.60 6030834.47 657901.77 N 70.49089759 W 148.7090809:p '1 5027.97 26.86 260.58 4525.99 1975.21 -102.59 -1972.57 0.61 6030826.6C 657860.05 N 70.49087852 W 148.7094233$ 5123.53 26.64 260.87 4611.32 2017.93 -109.53 -2015.02 0.27 6030818.76 657817.76 N 70.49085955 W 148.70977026; 5217.67 26.67 262.36 4695.45 2059.95 -115.68 -2056.79 0.71 6030811.7C 657776.13 N 70.49084270 W 148.7101117$ 5313.06 26.60 263.71 4780.72 2102.60 -120.87 -2099.24 0.64 6030805.61 657733.81 N 70.49082850 W 148.7104586~ 5406.09 26.60 264.73 4863.91 2144.19 -125.06 -2140.68 0.49 6030800.52 657692.47 N 70.49081701 W 148.7107974$ 5501.63 26.54 265.95 4949.36 2186.89 -128.54 -2183.27 0.57 6030796.13 657649.96 N 70.49080749 W 148.71114~t;6 5596.52 26.61 267.01 5034.22 2229.34 -131.14 -2225.64 0.51 6030792.62 657607.66 N 70.49080033 W 148.7114£ 5691.50 26.64 268.62 5119.13 2271.90 -132.76 -2268.17 0.76 6030790.08 657565.18 N 70.49079587 W 148.71183~ 5786.77 26.60 269.16 5204.30 2314.57 -133.59 -2310.85 0.26 6030788.34 657522.53 N 70.49079357 W 148.71218839 I 5881.06 26.35 269.60 5288.70 2356.58 -134.05 -2352.88 0.34 6030786.98 657480.52 N 70.49079229 W 148.71253196 5976.44 26.25 270.58 5374.21 2398.79 -133.98 -2395.14 0.47 6030786.14 657438.28 N 70.49079243 W 148.71287738 6072.87 26.19 272.43 5460.72 2441.27 -132.86 -2437.73 0.85 6030786.34 657395.68 N 70.49079545 W 148.71322548 6166.64 26.33 273.08 5544.81 2482.58 -130.87 -2479.17 0.34 6030787.44 657354.21 N 70.49080086 W 148.71356421 6261.78 26.14 272.74 5630.15 2524.43 -128.73 -2521 .17 0.25 6030788.68 657312.17 N 70.49080666 W 148.7139075$ 6356.60 26.17 272.17 5715.26 2566.06 -126.94 -2562.93 0.27 6030789.57 657270.39 N 70.49081151 W 148.71424884 6453.98 26.12 272.09 5802.68 2608.82 -125.35 -2605.81 0.06 6030790.24 657227.49 N 70.49081583 W 148.7145994X 6548.62 25.93 272.25 5887.72 2650.20 -123.78 -2647.30 0.21 6030790.92 657185.97 N 70.49082008 W 148.7149385; . 6643.75 26.40 272.22 5973.11 2691.99 -122.14 -2689.22 0.49 6030791.65 657144.03 N 70.49082451 W 148.71528122 6738.20 26.91 271.76 6057.52 2734.22 -120.67 -2731.57 0.58 6030792.21 657101.67 N 70.49082848 W 148.71562736 6833.00 27.24 270.95 6141.93 2777.26 -119.65 -2774.70 0.52 6030792.3C 657058.52 N 70.49083122 W 148.71597996 6928.58 27.50 270.40 6226.81 2821.13 -119.14 -2818.64 0.38 6030791.88 657014.59 N 70.49083259 W 148.71633911 7022.43 27.91 269.86 6309.90 2864.71 -119.04 -2862.27 0.51 6030791.04 656970.97 N 70.49083281 W 148.71669' 7119.26 28.54 268.82 6395.22 2910.47 -119.57 -2908.06 0.83 6030789.52 656925.20 N 70.49083131 W 148.71707b.f 7221.83 28.86 268.60 6485.19 2959.71 -120.68 -2957.30 0.33 6030787.35 656876.00 N 70.49082822 W 148.71747256 ! 7315.05 28.63 268.62 6566.92 3004.53 -121.77 -3002.12 0.25 6030785.30 656831.22 N 70.49082520 W 148.7178389~ 7408.15 28.47 268.61 6648.70 3049.02 -122.84 -3046.60 0.17 6030783.27 656786.77 N 70.49082222 W 148.71820249 7503.39 28.23 268.63 6732.51 3094.23 -123.93 -3091.82 0.25 6030781.21 656741.60 N 70.49081919 W 148.71857206 7598.11 28.08 268.87 6816.03 3138.91 -124.91 -3136.50 0.20 6030779.28 656696.95 N 70.49081647 W 148.71893730 7694.13 27.95 268.57 6900.79 3184.00 -125.91 -3181.59 0.20 6030777.30 656651.89 N 70.49081367 W 148.71930586 7787.96 27.79 268.07 6983.74 3227.85 -127.20 -3225.43 0.30 6030775.07 656608.09 N 70.49081011 W 148.71966424- 7889.62 27.44 267.73 7073.82 3274.97 -128.92 -3272.52 0.38 6030772.33 656561.05 N 70.49080534 W 148.72004915 7987.35 27.07 267.30 7160.70 3319.73 -130.86 -3317.24 0.43 6030769.43 656516.40 N 70.49079998 W 148.72041463 Schlumberger Private NS16 ASP Final Survey.xls Page 3 of 5 3/28/2003-4:34 PM Grid Cordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/·W DLS Northing Easting Latitude Longitude (ft) (0) (") eft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 8079.84 26.76 267.17 7243.17 3361.59 -132.88 -3359.05 0.34 5030766.5~ 656474.63 N 70.49079442 W 148.7207564$ 8174.64 26.44 266.22 7327.94 3404.04 -135.33 -3401 .43 0.56 5030763.1 E 656432.32 N 70.49078768 W 148.72110282 8270.27 26.69 266.96 7413.47 3446;.80 -137.87 -3444.12 0.43 3030759.7C 656389.70 N 70.49078068 W 148.7214517þ 8368.44 26.67 267.34 7501.19 3490.88 -140.06 -3488.14 0.17 ô030756.5ï 656345.74 N 70.49077464 W 148.72181162 8461.77 26.59 267.33 7584.62 3532.71 -142.01 -3529.93 0.09 3030753.7~ 656304.00 N 70.49076927 W 148.72215318 8565.89 27.00 268.90 7677.56 3579.64 -143.55 -3576.84 0.79 3030751.1 f 656257.14 N 70.49076501 W 148.7225366) 8661.33 27.57 269.48 7762.38 3623.37 -144.16 -3620.59 0.66 3030749.6~ 656213.42 N 70.49076326 W 148.72289419 8756.14 27.86 269.07 7846.31 3667.44 -144.72 -3664.68 0.37 '3030748.1" 656169.36 N 70.49076168 W 148.72ß2545B 8851.96 28.29 268.93 7930.86 3712.51 -145.51 -3709.77 0.45 '3030746.3E 656124.30 N 70.49075947 W 148.72362'J13 8947.56 28.69 267.97 8014.88 3758.10 -146.75 -3755.35 0.64 3030744.1 £ 656078.76 N 70.49075603 W 148.7239,~¿ 9041.91 29.01 267.66 8097.52 3803.63 -148.48 -3800.84 0.37 50307 41 .4~ 656033.32 N 70.49075122 W 148.7243675V 9134.86 29.54 267.53 8178.60 3849.08 -150.39 -3846.25 0.57 '3030738.5£ 655987.96 N 70.49074595 W 148.72473877- 9238.51 30.65 268.10 8268.28 3901.05 -152.37 -3898.19 1.11 '3030735.4E 655936.08 N 70.49074047 W 148.7251632Ø 9334.58 31.47 268.20 8350.57 3950.61 -153.97 -3947.73 0.86 3030732.n 655886.59 N 70.49073603 W 148.7255682~ 9423.65 31.83 268.22 8426.39 3997.34 -155.43 -3994.44 0.40 -3030730.3~ 655839.92 N 70.49073197 W 148.72595005 9519.46 32.14 268.94 8507.66 4048.08 -156.68 -4045.18 0.51 -3030727.9f 655789.23 N 70.49072847 W 148.7263647~ 9613.99 32.68 270.03 8587.47 4098.71 -157.13 -4095.84 0.84 -3030726.4'- 655738.59 N 70.49072716 W 148.72677885 ; 9714.23 31.42 269.41 8672.43 4151.85 -157.39 -4149.03 1.30 3030725.0'- 655685.42 N 70.49072638 W 148.72721364- 9808.76 30.31 268.77 8753.57 4200.32 -158.16 -4197.52 1.22 3030723.2~ 655636.97 N 70.49072421 W 148.72760997 9903.73 30.66 268.24 8835.41 4248.49 -159.41 -4245.68 0.46 3030720.9£ 655588.85 N 70.49072070 W 148.72800365 9997.85 31.05 267.36 8916.21 4296.76 -161.27 -4293.91 0.63 3030718.0E 655540.67 N 70.49071556 W 148.72839791 10092.54 31.99 265.18 8996.93 4346.25 -164.50 -4343.30 1.56 ò030713.7E 655491.36 N 70.49070665 W 148.7288016~ 10187.02 30.96 264.74 9077.51 4395.53 -168.83 -4392.44 1.12 6030708.3ï 655442.33 N 70.49069474 W 148.7292032~ 10281.30 29.06 262.96 9159.15 4442.60 -173.86 -4439.32 2.23 6030702.3~ 655395.58 N 70.49068092 W 148.7295864~ 10374.64 28.13 261.59 9241 .10 4487.09 -179.86 -4483.59 1.22 6030695.3S 655351 .45 N 70.49066447 W 148.7299/ 10398.98 28.18 262.33 9262.56 4498.53 -181.46 -4494.96 1.45 6030693.5'- 655340.12 N 70.49066006 W 148.73004'1-1-Ô 10539.99 28.44 262.14 9386.70 4565.14 -190.50 -4561.22 0.20 6030683.Of 655274.07 N 70.49063526 W 148.73058272 10634.53 26.94 262.66 9470.42 4608.91 -196.32 -4604.76 1.61 6030676.3~ 655230.67 N 70.49061931 W 148.73093861 10730.34 26.13 263.62 9556.13 4651.59 -201.43 -4647.26 0.96 6030670.3C 655188.30 N 70.49060525 W 148.73¡128593! i '} 10824.24 25.28 263.44 9640.74 4692.23 -206.02 -4687.72 0.91 6030664.8£ 655147.94 N 70.49059265 W 148.73ÚH67':>! i 10918.33 23.86 264.20 9726.31 4731.28 -210.24 -4726.62 1.55 6030659.7S 655109.15 N 70.49058106 W 148.73193459 I 11013.11 23.01 263.91 9813.27 4768.91 -214.14 -4764.11 0.91 6030655.0E 655071.75 N 70.49057033 W 148.73224102 I 11105.75 22.37 263.50 9898.74 4804.58 -218.06 -4799.63 0.71 6030650.4C 655036.33 N 70.49055957 W 148.7325313~ 11201.31 22.50 263.94 9987.07 4840.97 -222.05 -4835.88 0.22 6030645.6£ 655000.17 N 70.49054861 W 148.7328276? 11297.96 22.05 264.56 10076.50 4877.55 -225.72 -4872.33 0.53 6030641 .1 E 654963.81 N 70.49053851 W 148.7331255~ Schlumberger Private NS16 ASP Final Survey.xls Page 4 of 5 3/28/2003-4:34 PM Grid CO;Jrdinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S Ef·W DLS Northing Easting Latitude Longitude i (ft) (0) (0) (ft) (ft) (ft) (ft) (G/100ft) (ftUS) (ftUS) i 11389.45 22.62 265.29 10161.13 4912.29 -228.79 -4906.96 0.69 6030637.37 654929.26 N 70.49053005 W 148.73340861 11483.67 21.66 265.25 10248.40 4947.78 -231.72 -4942.35 1.02 6030633.6E 654893.94 N 70.49052199 W 148.73369784- ! 11579.48 20.02 265.94 10337.94 4981.85 -234.35 -4976.33 1.73 6030630.32 654860.03 N 70.49051476 W 148.7339756Ö 11674.15 18.21 266.09 10427.39 5012.84 -236.50 -5007.26 1.91 6030627.5C 654829.16 N 70.49050881 W 148.73422837 t 11767.85 16.99 266.77 10516.70 5041.16 -238.27 -5035.53 1.32 6030625.12.. 654800.93 N 70.49050392 W 148.7344594$ 11863.25 15.52 267.85 10608.28 5067.87 -239.54 -5062.20 1.57 6030623.2£ 654774.29 N 70.49050042 W 148.7346774$ 11957.31 14.51 268.18 10699.13 5092.23 -240.38 -5086.56 1.08 6030621.9:2 654749.97 N 70.49049806 W 148.73487654 12043.27 13.30 267.83 10782.57 5112.89 -241.10 -5107.20 1.41 6030620.7E 654729.34 N 70.49049607 W 148.7350452? 12154.57 13.03 268.05 10890.94 5138.24 -242.01 -5132.53 0.25 6030619.3C 654704.04 N 70.49049353 W 148.7352523~ 12250.07 11.05 268.33 10984.34 5158.15 -242.64 -5152.44 2.07 6030618.2L 654684.15 N 70.49049176 W 148.7354.1 12328.65 9.01 272.11 11061.72 5171.82 -242.64 -5166.12 2.73 6030617.9E 654670.47 N 70.49049175 W 148.73552mr9 I 12424.00 9.01 272.11 11155.89 5186.70 -242.09 -5181.04 0.00 6030618.1 E. 654655.55 N 70.49049323 W 148.73564881 ~ ~ ;j i .~ -' NS16 ASP Final SUNey.xls Schlumberger Private Page 5 of 5 3/28/2003-4:34 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS16 API number...............: 50-029-23096-00 Engineer.................: Leafstedt RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 33 E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. . . . . . . . . .: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent. . . . . . . : na DF above permanent.......: 56.46 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 267.80 degrees ** All MWD survey are "D-MAG" corrected ** [(c)2003 Anadrill IDEAL ID6_1C_I0J 19-Mar-2003 06:30:42 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 29-Jun-2002 19-Mar-03 135 0.00 ft 12424.00 ft -> ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date............: 15-Mar-2003 Magnetic field strength..: 1151.05 HCNT Magnetic dec (+E/W-).....: 26.03 degrees Magnetic dip.. .... .......: 80.95 degrees ----- MWD survey Reference Reference G... ...........: Reference H............ ..: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.69 mGal 1151.05 HCNT 80.95 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.03 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.03 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)..... ...: No degree: 0.00 -. ANADRILL SCHLUMBERGER Survey Report 19-Mar-2003 06:30:42 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 0.00 0.94 1.39 2.24 2.39 2.54 2.49 2.76 3.34 4.93 5.79 7.38 7.95 9.34 11.60 13.90 15.75 16.66 18.76 20.84 23.64 26.08 28.82 29.69 30.93 31.50 30.96 30.80 30.66 31.65 0.00 282.89 278.89 275.10 275.77 273.98 280.72 280.11 277.39 271.58 272.70 276.28 279.91 286.36 282.98 274.23 271.83 273.18 274.53 272.53 269.29 265.29 262.16 264.05 266.35 268.16 269.24 270.92 271.72 268.49 0.00 50.00 50.00 50.00 50.00 69.00 92.00 89.00 90.00 90.00 90.00 90.00 33.00 90.38 95.51 94.82 95.68 94.75 95.31 94.48 95.07 95.87 95.14 92.85 95.52 94.24 96.30 96.61 97.18 95.30 [(c)2003 Anadrill IDEAL ID6_1C_10J 269.00 361.00 450.00 540.00 630.00 720.00 810.00 843.00 933.38 1028.89 1123.71 1219.39 1314.14 1409.45 1503.93 1599.00 1694.87 1790.01 1882.86 1978.38 2072.62 2168.92 2265.53 2362.71 2458.01 0.00 50.00 99.99 149.96 199.92 268.86 360.77 449.68 539.55 629.31 718.92 808.32 841.03 930.38 1024.29 1116.78 1209.27 1300.25 1391.04 1479.93 1567.92 1654.91 1739.34 1820.34 1902.81 1983.41 2065.75 2148.67 2232.20 2313.76 0.00 0.40 1.39 2.95 4.95 7.90 11.87 15.85 20.55 27.00 35.38 45.62 49.95 63.01 79.63 100.15 124.53 150.88 179.70 211.55 247.46 287.74 331.46 376.68 424.83 473.66 523.58 573.12 622.69 671.94 0.00 0.09 0.28 0.46 0.65 0.90 1.41 2.15 2.87 3.31 3.63 4.48 5.10 8.24 12.58 15.57 16.83 17.99 19.96 21.90 22.41 20.44 15.60 10.16 6.15 3.81 2.68 2.74 3.89 3.96 0.00 -0.40 -1.40 -2.97 -4.98 -7.94 -11.94 -15.94 -20.68 -27.14 -35.54 -45.83 -50.18 -63.38 -80.17 -100.82 -125.27 -151.68 -180.60 -212.54 -248.51 -288.74 -332.31 -377.35 -425.38 -474.16 -524.07 -573.65 -623.30 -672.58 0.00 0.41 1.43 3.01 5.02 7.99 12.02 16.09 20.88 27.35 35.73 46.04 50.44 63.91 81.15 102.02 126.39 152.74 181.70 213.67 249.51 289.46 332.67 377.49 425.42 474.17 524.08 573.66 623.31 672.60 0.00 282.89 281.19 278.75 277.42 276.47 276.75 277.67 277.89 276.95 275.83 275.58 275.80 277.41 278.92 278.78 277.65 276.76 276.31 275.88 275.15 274.05 272.69 271.54 270.83 270.46 270.29 270.27 270.36 270.34 2 of 6 DLS (deg/ 100f) 0.00 1.88 0.91 1.72 0.30 0.24 0.33 0.30 0.66 1.82 0.96 1.82 2.27 1.87 2.45 3.16 2.04 1.04 2.24 2.32 3.21 3.09 3.25 1.37 1.78 1.16 0.81 0.91 0.44 2.04 ------ ------ Srvy tool type Tool qual type ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR - GYR GYR GYR D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG -~/ D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report 19-Mar-2003 06:30:42 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2552.39 2648.36 2743.14 2838.55 2933.88 3029.84 3124.90 3221.44 3316.59 3409.86 3446.83 3602.01 3696.89 3793.31 3888.26 3983.92 4079.27 4173.31 4267.53 4363.74 4459.43 4555.46 4651.24 4746.57 4841.21 4934.90 5027.97 5123.53 5217.67 5313.06 31.30 31.39 31.60 31.72 29.79 29.89 30.51 31.26 31.97 31.70 31.52 31.10 31.62 31.82 32.15 31.75 31.47 30.90 30.39 30.22 29.82 29.48 29.06 28.42 27.87 27.43 26.86 26.64 26.67 26.60 269.41 270.86 267.08 266.63 267.61 267.67 268.03 267.72 268.30 268.34 269.04 267.68 267.17 266.19 265.81 265.41 264.37 263.69 262.50 261.74 260.41 260.40 260.14 259.67 259.76 260.53 260.58 260.87 262.36 263.71 94.38 95.97 94.78 95.41 95.33 95.96 95.06 96.54 95.15 93.27 36.97 155.18 94.88 96.42 94.95 95.66 95.35 94.04 94.22 96.21 95.69 96.03 95.78 95.33 94.64 93.69 93.07 95.56 94.14 95.39 [(c)2003 Anadrill IDEAL ID6_1C_10J 2394.26 2476.22 2557.05 2638.26 2720.18 2803.42 2885.57 2968.42 3049.45 3128.69 3160.18 3292.76 3373.78 3455.80 3536.33 3617.50 3698.70 3779.15 3860.22 3943.28 4026.13 4109.59 4193.14 4276.73 4360.18 4443.17 4525.99 4611.32 4695.45 4780.72 721.20 771.08 820.56 870.64 919.38 967.12 1014.94 1064.50 1114.37 1163.57 1182.94 1263.58 1312.95 1363.64 1413.91 1464.49 1514.40 1562.99 1610.85 1659.16 1706.70 1753.81 1800.24 1845.64 1889.84 1932.93 1975.05 2017.74 2059.72 2102.33 3.05 3.17 2.28 --0.47 -2.93 -4.90 -6.69 -8.53 -10.26 -11.70 -12.14 -14.45 -16.67 -19.60 -23.11 -26.99 -31.44 -36.50 -42.27 -48.92 -56.35 -64.26 -72.18 -80.21 -88.18 -95.62 -102.59 -109.53 -115.68 -120.87 -721.85 -771.77 -821.26 -871.26 -919.94 -967.65 -1015.43 -1064.95 -1114.80 -1163.98 -1183.35 -1263.95 -1313.28 -1363.89 -1414.06 -1464.53 -1514.31 -1562.74 -1610.41 -1658.50 -1705.79 -1752.64 -1798.79 -1843.92 -1887.84 -1930.68 -1972.57 -2015.02 -2056.79 -2099.24 721.86 771.78 821.26 871.26 919.95 967.66 1015.46 1064.99 1114.85 1164.04 1183.41 1264.04 1313.39 1364.03 1414.25 1464.78 1514.64 1563.16 1610.97 1659.22 1706.72 1753.81 1800.24 1845.66 1889.90 1933.05 1975.23 2017.99 2060.04 2102.72 270.24 270.24 270.16 269.97 269.82 269.71 269.62 269.54 269.47 269.42 269.41 269.35 269.27 269.18 269.06 268.94 268.81 268.66 268.50 268.31 268.11 267.90 267.70 267.51 267.33 267.16 267.02 266.89 266.78 266.70 3 of 6 DLS (deg/ 100f) 0.63 0.79 2.09 0.28 2.09 0.11 0.68 0.79 0.81 0.29 1.11 0.53 0.62 0.57 0.41 0.47 0.64 0.71 0.84 0.44 0.81 0.35 0.46 0.71 0.58 0.60 0.61 0.27 0.71 0.64 ------ ------ Srvy tool type Tool qual type ------ ------ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) ------ ------ Incl angle (deg) ------- ------- Azimuth angle (deg) ------ ------ Course length (ft) -------- -------- TVD depth (ft) 19-Mar-2003 06:30:42 -------- -------- Vertical section (ft) ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5406.09 5501.63 5596.52 5691.50 5786.77 5881.06 5976.44 6072.87 6166.64 6261.78 6356.60 6453.98 6548.62 6643.75 6738.20 6833.00 6928.58 7022.43 7119.26 7221.83 7315.05 7408.15 7503.39 7598.11 7694.13 7787.96 7889.62 7987.35 8079.84 8174.64 26.60 26.54 26.61 26.64 26.60 26.35 26.25 26.19 26.33 26.14 26.17 26.12 25.93 26.40 26.91 27.24 27.50 27.91 28.54 28.86 28.63 28.47 28.23 28.08 27.95 27.79 27.44 27.07 26.76 26.44 264.73 265.95 267.01 268.62 269.16 269.60 270.58 272.43 273.08 272.74 272.17 272.09 272.25 272.22 271.76 270.95 270.40 269.86 268.82 268.60 268.62 268.61 268.63 268.87 268.57 268.07 267.73 267.30 267.17 266.22 93.03 95.54 94.89 94.98 95.27 94.29 95.38 96.43 93.77 95.14 94.82 97.38 94.64 95.13 94.45 94.80 95.58 93.85 96.83 102.57 93.22 93.10 95.24 94.72 96.02 93.83 101.66 97.73 92.49 94.80 [(c)2003 Anadrill IDEAL ID6_1C_10J 4863.91 4949.36 5034.22 5119.13 5204.30 5288.70 5374.21 5460.72 5544.81 5630.15 5715.26 5802.68 5887.72 5973.10 6057.52 6141.93 6226.81 6309.90 6395.22 6485.18 6566.92 6648.70 6732.51 6816.02 6900.79 6983.74 7073.82 7160.70 7243.17 7327.94 2143.90 2186.60 2229.04 2271.60 2314.28 2356.30 2398.52 2441.03 2482.36 2524.25 2565.91 2608.70 2650.10 2691.93 2734.18 2777.25 2821.13 2864.73 2910.51 2959.76 3004.58 3049.07 3094.29 3138.98 3184.08 3227.94 3275.06 3319.81 3361.68 3404.12 -125.06 -2140.68 -128.54 -2183.27 -131.14 -2225.64 -132.76 -2268.17 -133.59 -2310.85 -134.05 -2352.88 -133.98 -2395.14 -132.86 -2437.73 -130.87 -2479.17 -128.73 -2521.17 -126.94 -2562.93 -125.35 -2605.81 -123.78 -2647.30 -122.14 -2689.22 -120.67 -2731.56 -119.65 -2774.70 -119.14 -2818.64 -119.04 -2862.27 -119.57 -2908.06 -120.68 -2957.30 -121.77 -3002.12 -122.84 -3046.60 -123.93 -3091.82 -124.91 -3136.50 -125.91 -3181.59 -127.20 -3225.43 -128.92 -3272.52 -130.86 -3317.24 -132.88 -3359.05 -135.33 -3401.43 2144.33 2187.05 2229.50 2272.05 2314.71 2356.70 2398.89 2441.35 2482.62 2524.45 2566.07 2608.82 2650.19 2691.99 2734.23 2777.28 2821.16 2864.74 2910.52 2959.77 3004.59 3049.08 3094.30 3138.99 3184.08 3227.94 3275.06 3319.82 3361.68 3404.12 266.66 266.63 266.63 266.65 266.69 266.74 266.80 266.88 266.98 267.08 267.16 267.25 267.32 267.40 267.47 267.53 267.58 267.62 267.65 267.66 267.68 267.69 267.70 267.72 267.73 267.74 267.74 267.74 267.73 267.72 4 of 6 DLS (deg/ 100f) 0.49 0.57 0.51 0.76 0.26 0.34 0.47 0.85 0.34 0.25 0.27 0.06 0.21 0.49 0.58 0.52 0.38 0.51 0.83 0.33 0.25 0.17 0.25 0.20 0.20 0.30 0.38 0.43 0.34 0.56 ------ ------ Srvy tool type Tool qual type ------ ------ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ........../ D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report 111 112 113 114 115 116 117 118 119 120 19-Mar-2003 06:30:42 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 8270.27 8368.44 8461.77 8565.89 8661.33 26.69 26.67 26.59 27.00 27.57 27.86 28.29 28.69 29.01 29.54 30.65 31.47 31.83 32.14 32.68 31.42 30.31 30.66 31.05 31.99 30.96 29.06 28.13 28.18 28.44 26.94 26.13 25.28 23.86 23.01 266.96 267.34 267.33 268.90 269.48 269.07 268.93 267.97 267.66 267.53 268.10 268.20 268.22 268.94 270.03 269.41 268.77 268.24 267.36 265.18 264.74 262.96 261.59 262.33 262.14 262.66 263.62 263.44 264.20 263.91 95.63 98.17 93.33 104.12 95.44 94.81 95.82 95.60 94.35 92.95 103.65 96.07 89.07 95.81 94.53 100.24 94.53 94.97 94.12 94.69 94.48 94.28 93.34 24.34 141.01 94.54 95.81 93.90 94.09 94.78 [(c)2003 Anadrill IDEAL ID6_1C_I0J 96 97 98 99 100 8756.14 8851.96 8947.56 9041.91 9134.86 101 102 103 104 105 9238.51 9334.58 9423.65 9519.46 9613.99 106 107 108 109 110 9714.23 9808.76 9903.73 9997.85 10092.54 10187.02 10281.30 10374.64 10398.98 10539.99 10634.53 10730.34 10824.24 10918.33 11013.11 7413.47 7501.19 7584.62 7677.56 7762.38 7846.31 7930.86 8014.88 8097.52 8178.60 8268.28 8350.57 8426.39 8507.66 8587.46 8672.42 8753.57 8835.41 8916.21 8996.93 9077.50 9159.14 9241.10 9262.56 9386.70 9470.42 9556.13 9640.74 9726.31 9813.27 3446.87 3490.95 3532.78 3579.71 3623.45 3667.53 3712.62 3758.21 3803.74 3849.19 3901.16 3950.73 3997.46 4048.21 4098.85 4152.01 4200.49 4248.67 4296.94 4346.42 4395.69 4442.72 4487.19 4498.61 4565.17 4608.90 4651.56 4692.18 4731.20 4768.82 -137.87 -3444.12 -140.06 -3488.14 -142.01 -3529.93 -143.55 -3576.84 -144.16 -3620.59 -144.72 -3664.68 -145.51 -3709.76 -146.75 -3755.35 -148.48 -3800.84 -150.39 -3846.25 -152.37 -3898.19 -153.97 -3947.73 -155.43 -3994.44 -156.68 -4045.18 -157.13 -4095.84 -157.39 -4149.03 -158.15 -4197.52 -159.41 -4245.68 -161.27 -4293.91 -164.50 -4343.30 -168.83 -4392.44 -173.86 -4439.32 -179.86 -4483.59 -181.46 -4494.96 -190.50 -4561.22 -196.32 -4604.76 -201.43 -4647.26 -206.02 -4687.72 -210.24 -4726.62 -214.14 -4764.11 3446.88 3490.96 3532.79 3579.72 3623.46 3667.53 3712.62 3758.21 3803.74 3849.19 3901.16 3950.73 3997.47 4048.21 4098.85 4152.01 4200.50 4248.67 4296.94 4346.42 4395.69 4442.72 4487.19 4498.62 4565.20 4608.95 4651.62 4692.25 4731.29 4768.92 267.71 267.70 267.70 267.70 267.72 267.74 267.75 267.76 267.76 267.76 267.76 267.77 267.77 267.78 267.80 267.83 267.84 267.85 267.85 267.83 267.80 267.76 267.70 267.69 267.61 267.56 267.52 267.48 267.45 267.43 5 of 6 DLS (deg/ 100f) 0.43 0.17 0.09 0.79 0.66 0.37 0.45 0.64 0.37 0.57 1.11 0.86 0.40 0.51 0.84 1.30 1.22 0.46 0.63 1.56 1.12 2.23 1.22 1.45 0.20 1.61 0.96 0.91 1.55 0.91 ------ ------ Srvy tool type Tool qual type ------ ------ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ---~ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ~- D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report 19-Mar-2003 06:30:42 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 131 132 133 134 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 11105.75 11201.31 11297.96 11389.45 11483.67 11579.48 11674.15 11767.85 11863.25 11957.31 12043.27 12154.57 12250.07 12328.65 22.37 22.50 22.05 22.62 21.66 20.02 18.21 16.99 15.52 14.51 13.30 13.03 11.05 9.01 263.50 263.94 264.56 265.29 265.25 265.94 266.09 266.77 267.85 268.18 267.83 268.05 268.33 272.11 Projected to TD 135 12424.00 9.01 272.11 92.64 95.56 96.65 91.49 94.22 95.81 94.67 93.70 95.40 94.06 85.96 111.30 95.50 78.58 9898.74 9987.07 10076.50 10161.13 10248.40 10337.94 10427.39 10516.70 10608.28 10699.13 10782.57 10890.94 10984.34 11061.71 95.35 11155.89 [(c)2003 Anadrill IDEAL ID6_1C_10] 4804.46 4840.84 4877.40 4912.13 4947.60 4981.66 5012.64 5040.97 5067.67 5092.03 5112.69 5138.04 5157.96 5171.63 -218.06 -4799.63 -222.05 -4835.88 -225.72 -4872.33 -228.79 -4906.96 -231.72 -4942.35 -234.35 -4976.33 -236.50 -5007.25 -238.27 -5035.53 -239.54 -5062.20 -240.38 -5086.56 -241.10 -5107.20 -242.01 -5132.53 -242.64 -5152.44 -242.64 -5166.12 4804.58 4840.97 4877.55 4912.29 4947.78 4981.84 5012.84 5041.16 5067.87 5092.23 5112.89 5138.24 5158.15 5171.81 267.40 267.37 267.35 267.33 267.32 267.30 267.30 267.29 267.29 267.29 267.30 267.30 267.30 267.31 5186.52 -242.09 -5181.04 5186.70 267.32 6 of 6 DLS (degl 100f) 0.71 0.22 0.53 0.69 1.02 1.73 1.91 1.32 1.57 1.08 1.41 0.25 2.07 2.73 0.00 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG PROJ ------ ------ Tool qual type ------ ------ ..-, 7/25/2002-5:43 PM Page 1 of 10 NS16 ASP.xls Report Date: 25-Jul-2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 267.300° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS16 TVD Reference Datum: KB Well: NS16 p ß..' TVD Reference Elevation: 55.770 ft relative to MSL Borehole: NS16 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWUAPI#: 500292309600 Magnetic Declination: +26.294° Survey Name I Date: NS16 Current / July 1 2002 Total Field Strength: 57541.798 nT Tort I AHD I DDII ERD ratio: 105.919° /5137.73 ft/5.784/ 0.474 Magnetic Dip: 80.943° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: July 01, 2002 Location Lat/Long: N 70 29 28.174, W 14841 35.878 Magnetic Declination Model: BGGM 2002 Location Grid NIE YIX: N 6030971.560 ftUS, E 659829.810 ftUS North Reference: True North Grid Convergence Angle: +1.23170678° Total Corr Mag North -> True North: +26.294° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/-5 I EI·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 0.0 0.00 0.00 0.00 0.00 6030971.56 659829.81 N 702928.174 W 14841 35.878 50.00 0.94 282.9 50.00 0.40 0.09 -0.40 1.88 6030971.64 659829.41 N 702928.175 W 14841 35.890 100.00 1.39 278.9 99.99 1.38 0.28 -1.40 0.91 6030971.81 659828.41 N 702928.177 W 14841 35.919 150.00 2.24 275.1 149.96 2.95 0.46 -2.97 1.72 6030971.95 659826.83 N 702928.179 W 14841 35.965 200.00 2.39 275.8 199.92 4.95 0.65 -4.98 0.30 6030972.10 659824.82 N 70 29 28.181 W 148 41 36.024 269.00 2.54 274.0 268.86 7.89 0.90 -7,94 0.24 6030972.29 659821.85 N702928.183 W1484136.111 361.00 2.49 280.7 360.77 11.86 1.41 -11.94 0.33 6030972.72 659817.85 N 7029 28.188 W 14841 36.229 450.00 2.76 280.1 449.68 15.83 2.15 -15.94 0.30 6030973.37 659813.82 N 702928.195 W 14841 36.347 540.00 3.34 277.4 539.55 20.52 2.87 -20.68 0.66 6030973.98 659809.08 N 702928.202 W 14841 36.486 630.00 4.93 271.6 629.31 26.96 3.31 -27.14 1.82 6030974.29 659802.60 N 702928.207 W 14841 36.677 720.00 5.79 272.7 718.92 35.33 3.63 -35.54 0.96 6030974.43 659794.20 N 702928.210 W 14841 36.924 810.00 7.38 276.3 808.32 45.56 4.48 -45.83 1.82 6030975.05 659783.90 N 702928.218 W 14841 37.226 843.00 7.95 279.9 841.03 49.88 5.10 -50.18 2.27 6030975.58 659779.54 N 70 29 28.224 W 148 41 37.354 933.38 9.34 286.4 930.38 62.92 8.24 -63.38 1.87 6030978.44 659766.28 N 702928.255 W 14841 37.743 1028.89 11.60 283.0 1 024.29 79.49 12.58 -80.17 2.45 6030982.42 659749.39 N 70 29 28.298 W 148 41 38.237 1123.71 13.90 274.2 1116.78 99.98 15.57 -100.82 3.16 6030984.95 659728.68 N 702928.327 W 14841 38.845 1219.39 15.75 271.8 1209.27 124.33 16.83 -125.27 2.04 6030985.69 659704.22 N 702928.340 W 14841 39.564 Scblumberger Survey Report - Geodetic NS-16 ~..~ -- .-, -~. f' ~ I ~ CO 7/25/2002-5:43 PM Page 3 of 10 NS 16 ASP .xls Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 4651.24 29.06 260.1 4193.14 1800.19 -72.18 -1798.79 0.46 6030860.74 658033.12 N 702927.462 W 1484228.810 4746.57 28.42 259.7 4276.73 1845.65 -80.21 -1843.92 0.71 6030851.74 657988.17 N 702927.383 W 1484230.138 4841.21 27.87 259.8 4360.18 1889.90 -88.18 -1887.84 0.58 6030842.83 657944.43 N 702927.305 W 1484231.431 4934.90 27.43 260.5 4443.17 1933.04 -95.62 -1930.68 0.60 6030834.47 657901.77 N 702927.231 W 1484232.691 5027.97 26.86 260.6 4525.99 1975.21 -102.59 -1972.57 0.61 6030826.60 657860.05 N 702927.163 W 1484233.924 5123.53 26.64 260.9 4611.32 2017.94 -109.53 -2015.02 0.27 6030818.76 657817.76 N 702927.094 W 1484235.173 5217.67 26.67 262.4 4695.45 2059.96 -115.68 -2056.79 0.71 6030811.70 657776.13 N 702927.034 W 1484236.402 5313.06 26.60 263.7 4780.72 2102.60 -120.87 -2099.24 0.64 6030805.61 657733.81 N 702926.983 W 1484237.651 /o~ 5406.09 26.60 264.7 4863.91 2144.20 -125.06 -2140.68 0.49 6030800.52 657692.47 N 702926.941 W 1484238.871 5501.63 26.54 266.0 4949.36 2186.90 -128.54 -2183.27 0.57 6030796.13 657649.96 N 702926.907 W 1484240.124 5596.52 26.61 267.0 5034.22 2229.35 -131.14 -2225.64 0.51 6030792.62 657607.66 N 702926.881 W 1484241.371 5691.50 26.64 268.6 5119.13 2271.91 -132.76 -2268.17 0.76 6030790.08 657565.18 N 702926.865 W 1484242.622 5786.77 26.60 269.2 5204.30 2314.58 -133.59 -2310.85 0.26 6030788.34 657522.53 N 702926.857 W 1484243.878 5881.06 26.35 269.6 5288.70 2356.59 -134.05 -2352.88 0.34 6030786.98 657480.52 N 70 29 26.852 W 148 42 45.115 5976.44 26.25 270.6 5374.21 2398.80 -133.98 -2395.14 0.47 6030786.14 657438.28 N 702926.853 W 1484246.359 6072.87 26.19 272.4 5460.72 2441.28 -132.86 -2437.73 0.85 6030786.34 657395.68 N 702926.864 W 1484247.612 6166.64 26.33 273.1 5544.81 2482.58 -130.87 -2479.17 0.34 6030787.44 657354.21 N 702926.883 W 1484248.831 6261.78 26.14 272.7 5630.15 2524.44 -128.73 -2521.17 0.25 6030788.68 657312.17 N 702926.904 W 1484250.067 6356.60 26.17 272.2 5715.26 2566.06 -126.94 -2562.93 0.27 6030789.57 657270.39 N 702926.921 W 1484251.296 6453.98 26.12 272.1 5802.68 2608.82 -125.35 -2605.81 0.06 6030790.24 657227.49 N 702926.937 W 1484252.558 6548.62 25.93 272.3 5887.72 2650.19 -123.78 -2647.30 0.21 6030790.92 657185.97 N 702926.952 W 1484253.779 6643.75 26.40 272.2 5973.11 2691.99 -122.14 -2689.22 0.49 6030791.65 657144.03 N 702926.968 W 1484255.012 6738.20 26.91 271.8 6057.52 2734.22 -120.67 -2731.57 0.58 6030792.21 657101.67 N 702926.983 W 1484256.258 6833.00 27.24 271.0 6141.93 2777.26 -119.65 -2774.70 0.52 6030792.30 657058.52 N 702926.992 W 1484257.528 /~~ 6928.58 27.50 270.4 6226.81 2821.12 -119.14 -2818.64 0.38 6030791.88 657014.59 N 702926.997 W 1484258.821 7022.43 27.91 269.9 6309.90 2864.70 -119.04 -2862.27 0.51 6030791.04 656970.97 N 70 29 26.998 W 148430.105 7119.26 28.54 268.8 6395.22 2910.46 -119.57 -2908.06 0.83 6030789.52 656925.20 N 702926.993 W 14843 1.452 7221.83 28.86 268.6 6485.19 2959.71 -120.68 -2957.30 0.33 6030787.35 656876.00 N 70 29 26.982 W 148432.901 7315.05 28.63 268.6 6566.92 3004.52 -121.77 -3002.12 0.25 6030785.30 656831.22 N 702926.971 W 148 43 4.220 7408.15 28.47 268.6 6648.70 3049.01 -122.84 -3046.60 0.17 6030783.27 656786.77 N 702926.960 W 148 43 5.529 7503.39 28.23 268.6 6732.51 3094.22 -123.93 -3091.82 0.25 6030781.21 656741.60 N 702926.949 W 148 43 6.859 7598.11 28.08 268.9 6816.03 3138.90 -124.91 -3136.50 0.20 6030779.28 656696.95 N 70 29 26.939 W 148438.174 7694.13 27.95 268.6 6900.79 3183.99 -125.91 -3181.59 0.20 6030777.30 656651.89 N 702926.929 W 148439.501 7787.96 27.79 268.1 6983.74 3227.84 -127.20 -3225.43 0.30 6030775.07 656608.09 N 702926.916 W 1484310.791 7889.62 27.44 267.7 7073.82 3274.96 -128.92 -3272.52 0.38 6030772.33 656561.05 N 70 29 26.899 W 148 43 12.177 - _/-- 7/25/2002-5:43 PM Page 5 of 10 NS 16 ASP .xls - Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/oS EJ·W DLS Northing Easting Latitude I Longitude (ft) (O) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 11297.96 22.05 264.6 10076.50 4877.56 -225.72 -4872.33 0.53 6030641.18 654963.81 N 702925.939 W 1484359.252 11389.45 22.62 265.3 10161.13 4912.29 -228.79 -4906.96 0.69 6030637.37 654929.26 N 70 29 25.908 W 14844 0.271 11483.67 21.66 265.3 10248.40 4947.78 -231.72 -4942.35 1.02 6030633.68 654893.94 N 702925.879 W 148 44 1.312 11579.48 20.02 265.9 10337.94 4981.85 -234.35 -4976.33 1.73 6030630.32 654860.03 N 70 29 25.853 W 14844 2.312 11674.15 18.21 266.1 10427.39 5012.84 -236.50 -5007.26 1.91 6030627.50 654829.16 N 70 29 25.832 W 148 44 3.222 11767.85 16.99 266.8 10516.70 5041.17 -238.27 -5035.53 1.32 6030625.13 654800.93 N 702925.814 W 148444.054 11863.25 15.52 267.9 10608.28 5067.87 -239.54 -5062.20 1.57 6030623.29 654774.29 N 702925.802 W 148444.839 11957.31 14.51 268.2 10699.13 5092.23 -240.38 -5086.56 1.08 6030621.92 654749.97 N 702925.793 W 14844 5.556 .- 12043.27 13.30 267.8 10782.57 5112.89 -241.10 -5107.20 1.41 6030620.76 654729.34 N 70 29 25.786 W 14844 6.163 12105.00 13.30 267.8 10842.64 5127.09 -241.64 -5121.39 0.00 6030619.92 654715.17 N 702925.780 W 14844 6.581 Survey Error Model: (No Error Model Selected) ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Northstar Well.....................: NS16 fl61 API number... . . . . . . . . . . . .: 50-029-23096-&e7ù Engineer. . . . . . . . . . . . . . . . .: Rathert/Leafstedt RIG: . . . . . . . . . . . . . . . . . . . . .: Nabor 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. . . . .: Minimum curvature Method for DLS. . . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent.......: NA DF above permanent.......: 56.46 ft ----- vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 267.80 degrees 11-Jul-2002 15:30:58 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 29-Jun-02 11-Jul-02 132 0.00 ft 12105.00 ft ----- Geomagnetic data ---------------------- Magnetic model....... ....: BGGM version 2001 Magnetic date.......... ..: 05-Jul-2002 Magnetic field strength..: 1150.38 HCNT Magnetic dec (+E/W-).. ...: 26.41 degrees Magnetic dip......... ....: 80.94 degrees ----- MWD survey Reference Reference G..............: Reference H.......... ....: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.69 mGal 1150.84 HCNT 80.94 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.29 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 26.29 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ..... ...: No degree: 0.00 [(c)2002 Anadrill IDEAL ID6_1C_10J ** All surveys with tool type "D-MAG" are corrected for Drillstring Magnetism ** -.,./ ANADRILL SCHLUMBERGER Survey Report 11-Jul-2002 15:30:58 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 0.00 0.94 1.39 2.24 2.39 2.54 2.49 2.76 3.34 4.93 5.79 7.38 7.95 9.34 11.60 13.90 15.75 16.66 18.76 20.84 23.64 26.08 28.82 29.69 30.93 31.50 30.96 30.80 30.66 31.65 0.00 282.89 278.89 275.10 275.77 273.98 280.72 280.11 277.39 271.58 272.70 276.28 279.91 286.36 282.98 274.23 271.83 273.18 274.53 272.53 269.29 265.29 262.16 264.05 266.35 268.16 269.24 270.92 271.72 268.49 0.00 50.00 50.00 50.00 50.00 69.00 92.00 89.00 90.00 90.00 90.00 90.00 33.00 90.38 95.51 94.82 95.68 94.75 95.31 94.48 95.07 95.87 95.14 92.85 95.52 94.24 96.30 96.61 97.18 95.30 [(c)2002 Anadrill IDEAL ID6_1C_10J 269.00 361.00 450.00 540.00 630.00 720.00 810.00 843.00 933.38 1028.89 1123.71 1219.39 1314.14 1409.45 1503.93 1599.00 1694.87 1790.01 1882.86 1978.38 2072.62 2168.92 2265.53 2362.71 2458.01 0.00 50.00 99.99 149.96 199.92 268.86 360.77 449.68 539.55 629.31 718.92 808.32 841.03 930.38 1024.29 1116.78 1209.27 1300.25 1391.04 1479.93 1567.92 1654.91 1739.34 1820.34 1902.81 1983.41 2065.75 2148.67 2232.20 2313.76 0.00 0.40 1.39 2.95 4.95 7.90 11.87 15.85 20.55 27.00 35.38 45.62 49.95 63.01 79.63 100.15 124.53 150.88 179.70 211.55 247.46 287.74 331.46 376.68 424.83 473.66 523.58 573.12 622.69 671.94 0.00 0.09 0.28 0.46 0.65 0.90 1.41 2.15 2.87 3.31 3.63 4.48 5.10 8.24 12.58 15.57 16.83 17.99 19.96 21.90 22.41 20.44 15.60 10.16 6.15 3.81 2.68 2.74 3.89 3.96 0.00 -0.40 -1.40 -2.97 -4.98 -7.94 -11.94 -15.94 -20.68 -27.14 -35.54 -45.83 -50.18 -63.38 -80.17 -100.82 -125.27 -151.68 -180.60 -212.54 -248.51 -288.74 -332.31 -377.35 -425.38 -474.16 -524.07 -573.65 -623.30 -672.58 0.00 0.41 1.43 3.01 5.02 7.99 12.02 16.09 20.88 27.35 35.73 46.04 50.44 63.91 81.15 102.02 126.39 152.74 181.70 213.67 249.51 289.46 332.67 377.49 425.42 474.17 524.08 573.66 623.31 672.60 0.00 282.89 281.19 278.75 277.42 276.47 276.75 277.67 277.89 276.95 275.83 275.58 275.80 277.41 278.92 278.78 277.65 276.76 276.31 275.88 275.15 274.05 272.69 271.54 270.83 270.46 270.29 270.27 270.36 270.34 2 of 6 DLS (deg/ 100f) 0.00 1.88 0.91 1.72 0.30 0.24 0.33 0.30 0.66 1.82 0.96 1.82 2.27 1.87 2.45 3.16 2.04 1.04 2.24 2.32 3.21 3.09 3.25 1.37 1.78 1.16 0.81 0.91 0.44 2.04 Srvy tool type TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ '-" .'--" ANADRILL SCHLUMBERGER Survey Report ll-Jul-2002 15:30:58 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2552.39 2648.36 2743.14 2838.55 2933.88 3029.84 3124.90 3221.44 3316.59 3409.86 3446.83 3602.01 3696.89 3793.31 3888.26 3983.92 4079.27 4173.31 4267.53 4363.74 4459.43 4555.46 4651.24 4746.57 4841.21 4934.90 5027.97 5123.53 5217.67 5313.06 31.30 31.39 31.60 31.72 29.79 29.89 30.51 31.26 31.97 31.70 31.52 31.10 31.62 31.82 32.15 31.75 31.47 30.90 30.39 30.22 29.82 29.48 29.06 28.42 27.87 27.43 26.86 26.64 26.67 26.60 269.41 270.86 267.08 266.63 267.61 267.67 268.03 267.72 268.30 268.34 269.04 267.68 267.17 266.19 265.81 265.41 264.37 263.69 262.50 261.74 260.41 260.40 260.14 259.67 259.76 260.53 260.58 260.87 262.36 263.71 94.38 95.97 94.78 95.41 95.33 95.96 95.06 96.54 95.15 93.27 36.97 155.18 94.88 96.42 94.95 95.66 95.35 94.04 94.22 96.21 95.69 96.03 95.78 95.33 94.64 93.69 93.07 95.56 94.14 95.39 [(c)2002 Anadrill IDEAL ID6_1C_l0J 2394.26 2476.22 2557.05 2638.26 2720.18 2803.42 2885.57 2968.42 3049.45 3128.69 3160.18 3292.76 3373.78 3455.80 3536.33 3617.50 3698.70 3779.15 3860.22 3943.28 4026.13 4109.59 4193.14 4276.73 4360.18 4443.17 4525.99 4611.32 4695.45 4780.72 721.20 771.08 820.56 870.64 919.38 967.12 1014.94 1064.50 1114.37 1163.57 1182.94 1263.58 1312.95 1363.64 1413.91 1464.49 1514.40 1562.99 1610.85 1659.16 1706.70 1753.81 1800.24 1845.64 1889.84 1932.93 1975.05 2017.74 2059.72 2102.33 3.05 3.17 2.28 -0.47 -2.93 -721.85 -771.77 -821.26 -871.26 -919.94 -4.90 -6.69 -8.53 -10.26 -11.70 -967.65 -1015.43 -1064.95 -1114.80 -1163.98 -12.14 -1183.35 -14.45 -1263.95 -16.67 -1313.28 -19.60 -1363.89 -23.11 -1414.06 -26.99 -1464.53 -31.44 -1514.31 -36.50 -1562.74 -42.27 -1610.41 -48.92 -1658.50 -56.35 -1705.79 -64.26 -1752.64 -72.18 -1798.79 -80.21 -1843.92 -88.18 -1887.84 -95.62 -1930.68 -102.59 -1972.57 -109.53 -2015.02 -115.68 -2056.79 -120.87 -2099.24 721.86 771.78 821.26 871.26 919.95 967.66 1015.46 1064.99 1114.85 1164.04 1183.41 1264.04 1313.39 1364.03 1414.25 1464.78 1514.64 1563.16 1610.97 1659.22 1706.72 1753.81 1800.24 1845.66 1889.90 1933.05 1975.23 2017.99 2060.04 2102.72 270.24 270.24 270.16 269.97 269.82 269.71 269.62 269.54 269.47 269.42 269.41 269.35 269.27 269.18 269.06 268.94 268.81 268.66 268.50 268.31 268.11 267.90 267.70 267.51 267.33 267.16 267.02 266.89 266.78 266.70 3 of 6 DLS (deg/ 100f) 0.63 0.79 2.09 0.28 2.09 0.11 0.68 0.79 0.81 0.29 1.11 0.53 0.62 0.57 0.41 0.47 0.64 0.71 0.84 0.44 0.81 0.35 0.46 0.71 0.58 0.60 0.61 0.27 0.71 0.64 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ ~ .~ ANADRILL SCHLUMBERGER Survey Report 11-Jul-2002 15:30:58 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5406.09 5501.63 5596.52 5691.50 5786.77 5881.06 5976.44 6072.87 6166.64 6261.78 6356.60 6453.98 6548.62 6643.75 6738.20 6833.00 6928.58 7022.43 7119.26 7221.83 7315.05 7408.15 7503.39 7598.11 7694.13 7787.96 7889.62 7987.35 8079.84 8174.64 26.60 26.54 26.61 26.64 26.60 26.35 26.25 26.19 26.33 26.14 26.17 26.12 25.93 26.40 26.91 27.24 27.50 27.91 28.54 28.86 28.63 28.47 28.23 28.08 27.95 27.79 27.44 27.07 26.76 26.44 264.73 265.95 267.01 268.62 269.16 269.60 270.58 272.43 273.08 272.74 272.17 272.09 272.25 272.22 271.76 270.95 270.40 269.86 268.82 268.60 268.62 268.61 268.63 268.87 268.57 268.07 267.73 267.30 267.17 266.22 93.03 95.54 94.89 94.98 95.27 94.29 95.38 96.43 93.77 95.14 94.82 97.38 94.64 95.13 94.45 94.80 95.58 93.85 96.83 102.57 93.22 93.10 95.24 94.72 96.02 93.83 101.66 97.73 92.49 94.80 [(c)2002 Anadrill IDEAL ID6_1C_10J 4863.91 4949.36 5034.22 5119.13 5204.30 5288.70 5374.21 5460.72 5544.81 5630.15 5715.26 5802.68 5887.72 5973.10 6057.52 6141.93 6226.81 6309.90 6395.22 6485.18 6566.92 6648.70 6732.51 6816.02 6900.79 6983.74 7073.82 7160.70 7243.17 7327.94 2143.90 2186.60 2229.04 2271.60 2314.28 2356.30 2398.52 2441.03 2482.36 2524.25 2565.91 2608.70 2650.10 2691.93 2734.18 2777.25 2821.13 2864.73 2910.51 2959.76 3004.58 3049.07 3094.29 3138.98 3184.08 3227.94 3275.06 3319.81 3361.68 3404.12 -125.06 -2140.68 -128.54 -2183.27 -131.14 -2225.64 -132.76 -2268.17 -133.59 -2310.85 -134.05 -2352.88 -133.98 -2395.14 -132.86 -2437.73 -130.87 -2479.17 -128.73 -2521.17 -126.94 -2562.93 -125.35 -2605.81 -123.78 -2647.30 -122.14 -2689.22 -120.67 -2731.56 -119.65 -2774.70 -119.14 -2818.64 -119.04 -2862.27 -119.57 -2908.06 -120.68 -2957.30 -121.77 -3002.12 -122.84 -3046.60 -123.93 -3091.82 -124.91 -3136.50 -125.91 -3181.59 -127.20 -3225.43 -128.92 -3272.52 -130.86 -3317.24 -132.88 -3359.05 -135.33 -3401.43 2144.33 2187.05 2229.50 2272.05 2314.71 2356.70 2398.89 2441.35 2482.62 2524.45 2566.07 2608.82 2650.19 2691.99 2734.23 2777.28 2821.16 2864.74 2910.52 2959.77 3004.59 3049.08 3094.30 3138.99 3184.08 3227.94 3275.06 3319.82 3361.68 3404.12 266.66 266.63 266.63 266.65 266.69 266.74 266.80 266.88 266.98 267.08 267.16 267.25 267.32 267.40 267.47 267.53 267.58 267.62 267.65 267.66 267.68 267.69 267.70 267.72 267.73 267.74 267.74 267.74 267.73 267.72 4 of 6 DLS (deg/ 100f) 0.49 0.57 0.51 0.76 0.26 0.34 0.47 0.85 0.34 0.25 0.27 0.06 0.21 0.49 0.58 0.52 0.38 0.51 0.83 0.33 0.25 0.17 0.25 0.20 0.20 0.30 0.38 0.43 0.34 0.56 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ¿ ------ ------ Tool qual type ------ ------ -- ANADRILL SCHLUMBERGER Survey Report 11-Jul-2002 15:30:58 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 8270.27 8368.44 8461.77 8565.89 8661.33 96 97 98 99 100 8756.14 8851.96 8947.56 9041.91 9134.86 101 102 103 104 105 9238.51 9334.58 9423.65 9519.46 9613.99 106 107 108 109 110 9714.23 9808.76 9903.73 9997.85 10092.54 111 112 113 114 115 10187.02 10281.30 10374.64 10398.98 10539.99 116 117 118 119 120 10634.53 10730.34 10824.24 10918.33 11013.11 26.69 26.67 26.59 27.00 27.57 27.86 28.29 28.69 29.01 29.54 30.65 31.47 31.83 32.14 32.68 31.42 30.31 30.66 31.05 31.99 30.96 29.06 28.13 28.18 28.44 26.94 26.13 25.28 23.86 23.01 266.96 267.34 267.33 268.90 269.48 269.07 268.93 267.97 267.66 267.53 268.10 268.20 268.22 268.94 270.03 269.41 268.77 268.24 267.36 265.18 264.74 262.96 261.59 262.33 262.14 262.66 263.62 263.44 264.20 263.91 95.63 98.17 93.33 104.12 95.44 94.81 95.82 95.60 94.35 92.95 103.65 96.07 89.07 95.81 94.53 100.24 94.53 94.97 94.12 94.69 94.48 94.28 93.34 24.34 141.01 94.54 95.81 93.90 94.09 94.78 [(c)2002 Anadrill IDEAL ID6_1C_l0J 7413.47 7501.19 7584.62 7677.56 7762.38 7846.31 7930.86 8014.88 8097.52 8178.60 8268.28 8350.57 8426.39 8507.66 8587.46 8672.42 8753.57 8835.41 8916.21 8996.93 9077.50 9159.14 9241.10 9262.56 9386.70 9470.42 9556.13 9640.74 9726.31 9813.27 3446.87 3490.95 3532.78 3579.71 3623.45 3667.53 3712.62 3758.21 3803.74 3849.19 3901.16 3950.73 3997.46 4048.21 4098.85 4152.01 4200.49 4248.67 4296.94 4346.42 4395.69 4442.72 4487.19 4498.61 4565.17 4608.90 4651.56 4692.18 4731.20 4768.82 -137.87 -3444.12 -140.06 -3488.14 -142.01 -3529.93 -143.55 -3576.84 -144.16 -3620.59 -144.72 -3664.68 -145.51 -3709.76 -146.75 -3755.35 -148.48 -3800.84 -150.39 -3846.25 -152.37 -3898.19 -153.97 -3947.73 -155.43 -3994.44 -156.68 -4045.18 -157.13 -4095.84 -157.39 -4149.03 -158.15 -4197.52 -159.41 -4245.68 -161.27 -4293.91 -164.50 -4343.30 -168.83 -4392.44 -173.86 -4439.32 -179.86 -4483.59 -181.46 -4494.96 -190.50 -4561.22 -196.32 -4604.76 -201.43 -4647.26 -206.02 -4687.72 -210.24 -4726.62 -214.14 -4764.11 3446.88 3490.96 3532.79 3579.72 3623.46 3667.53 3712.62 3758.21 3803.74 3849.19 3901.16 3950.73 3997.47 4048.21 4098.85 4152.01 4200.50 4248.67 4296.94 4346.42 4395.69 4442.72 4487.19 4498.62 4565.20 4608.95 4651.62 4692.25 4731.29 4768.92 267.71 267.70 267.70 267.70 267.72 267.74 267.75 267.76 267.76 267.76 267.76 267.77 267.77 267.78 267.80 267.83 267.84 267.85 267.85 267.83 267.80 267.76 267.70 267.69 267.61 267.56 267.52 267.48 267.45 267.43 5 of 6 DLS (deg/ 100f) 0.43 0.17 0.09 0.79 0.66 0.37 0.45 0.64 0.37 0.57 1.11 0.86 0.40 0.51 0.84 1.30 1.22 0.46 0.63 1.56 1.12 2.23 1.22 1.45 0.20 1.61 0.96 0.91 1.55 0.91 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ '-' ~ ANADRILL SCHLUMBERGER Survey Report Il-Jul-2002 15:30:58 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 11105.75 11201.31 11297.96 11389.45 11483.67 11579.48 11674.15 11767.85 11863.25 11957.31 131 12043.27 22.37 22.50 22.05 22.62 21.66 20.02 18.21 16.99 15.52 14.51 263.50 263.94 264.56 265.29 265.25 265.94 266.09 266.77 267.85 268.18 13.30 267.83 Projected to TD 132 12105.00 13.30 267.83 92.64 95.56 96.65 91.49 94.22 95.81 94.67 93.70 95.40 94.06 9898.74 9987.07 10076.50 10161.13 10248.40 10337.94 10427.39 10516.70 10608.28 10699.13 85.96 10782.57 61.73 10842.64 [(c)2002 Anadrill IDEAL ID6_1C_10J 4804.46 4840.84 4877.40 4912.13 4947.60 4981.66 5012.64 5040.97 5067.67 5092.03 -218.06 -4799.63 -222.05 -4835.88 -225.72 -4872.33 -228.79 -4906.96 -231.72 -4942.35 -234.35 -4976.33 -236.50 -5007.25 -238.27 -5035.53 -239.54 -5062.20 -240.38 -5086.56 4804.58 4840.97 4877.55 4912.29 4947.78 4981.84 5012.84 5041.16 5067.87 5092.23 267.40 267.37 267.35 267.33 267.32 267.30 267.30 267.29 267.29 267.29 5112.69 -241.10 -5107.20 5112.89 267.30 5126.89 -241.64 -5121.39 5127.09 267.30 6 of 6 DLS (deg/ 100f) 0.71 0.22 0.53 0.69 1.02 1.73 1.91 1.32 1.57 1.08 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG 1.41 D-MAG 0.00 PROJ ------ ------ Tool qual type ------ ------ ~ -- bp ) ) Date: 07-29-2003 Transmittal Number:92658 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type ,NS17 08-25-2002 SCH 1-8 326 18360 VISION DENSITY NEUTRON - C TVD ícð' )l9 08-25-2002 SCH 1-8 326 18360 VISION DENSITY NEUTRON - MD 08-25-2002 SCH 1-8 326 18360 VISION RESISTIVITY - MD 08-25-2002 SCH 1-8 326 18360 VISION RESISTIVITY - TVD 10-29-2002 SCH 1-5 265 14032 VISION DENSITY NEUTRON - TVD NS19 10-29-2002 SCH 1-5 265 14032 VISION DENSITY NEUTRON - MD 1 0-29-2002 SCH 1-5 265 14032 VISION RESISTIVITY - MD 10-29-2002 SCH 1-5 265 14032 VISION RESISTIVITY - TVD NS12 05-17 -2003 SCH 1 11800 13539 CH EDIT OF RST-SIGMA ON 909-\ \L CD ROM; NS17 02-22-2003 SCH 1-8 395 18396 LDWG, LWD; CDR; DEN; NEU; CD ROM; NS19 03-25-2003 SCH 1 LDWG EDIT DATA; LWD DATA; ARC/NEU/DEN/CDR/RTG R; ON CD ROM; _NS16 12-02-2002 SCH 1 26 10985 LDWG CASED HOLE EDIT cil ~--- OF PRIMARY DEPTH ~ CONTROL LOG; ON CD ROM; NS12 05-17-2003 SCH 1 11800 13539 RESERVOIR SATURATION TOOL; ~S16 12-02-2002 SCH 1 40 10985 PRIMARY DEPTH LOG; dc1J) RECEIVED ~"- ....,j\,;:~, C....£\ '~C'-,~ JUL 2 9 2003 Petrotechnica1 Data Center LR2-1 Alaska Oi-l & Gas Cons. Gornmieeion 900 E. Benson Blvd. PO Box 196612 Ancmorage Anchorage, AK 99519-6612 bp ) J Date: 07-29-2003 Transmittal Number:92658 1Þl- IJ..} BPXA WELL DATA TRANSMITTAL Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Kristin Dirks MMS Attn: Doug Choromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ') ') ) Date: 04-15-2003 Transmittal Number:92639 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS16 03-19-2003 SURVEY REPORT - GEODETIC :tt )9~NS16 03-19-2003 FINAL SURVEY REPORT NS16 03-19-2003 FINAL SURVEY - DISKETTE :1- NS19 ~-9-7NS19 \NS19 03-25-2003 SURVEY REPORT - GEODETIC 03-25-2003 FINAL SURVEY REPORT 03-25-2003 FINAL SURVEY - DISKETTE ) ~~J...¥\.~,.c ~'-'>" d'--JV\ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Howard Okland (AOGCC) X 2 reports Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED APR 15 2003 ). .r A1~a Or; 5. G~~ O':a1¡.:. C{:;Thl1¡~!tQJ1 .A.nctrOf~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RE: Northstar Completion Delays ) ) Subject: RE: Northstar Completion Delays Date: Mon, 17 Mar 2003 12:50:49 -0600 From: "Hernandez, Floyd" <HernanF1@BP.com> To: "'Winton Aubert'" <Winton_Aubert@admin.state.ak.us> Winton, z,. O'l. .. (2..1 The wells that could potentially have deferred completions will be NS16, NS19, NS23, NS20, & NS21. Just to let you know, I'm planning on suspending these wells with seawater and a diesel cap (1700'). This puts us in an under balance situations, except that before the well is switch over to seawater, a positive pressure test to 4370 psi will be conducted. After the switching to seawater, a negative test or inflow test will be performed for 30 minutes. A tubing hanger and BPV will also be installed and tested to 4200 psi. Any issues with how we suspend these wells? They are basically the same as what we have been doing on the previous Top Sag suspensions. Thanks, Floyd Hernandez Senior Drilling Engineer Northstar Development (907) 564-5960 work (907) 240-8056 cell hernanf1@bp.com -----Original Message----- From: Winton Aubert [mailto:Winton Aubert@admin.state.ak.us] Sent: Friday, March 14, 2003 6:50 AM To: Hernandez, Floyd Subject: Re: Northstar Completion Delays Floyd, No Sundries are necessary. Let me know by E-mail which wells are involved so I can update our files. Thanks, Winton "Hernandez, Floyd" wrote: > Winton, > > To be able to drill and case off as many wells thru the reservoir section > prior to the beginning of the Seasonal Drilling Restriction which begin on > June 1st, we have decided to delay running the tubing completions on wells > until after June 1st. Do you need a Sundry Notice or can we still utilize > the Original Drilling Permit which discussed "Operation Shutdown" of the > wells after top setting the Sag River. > > Thanks, > Floyd Hernandez > Senior Drilling Engineer > Northstar Development > (907) 564-5960 work > (907) 240-8056 cell > hernanf1®bp.com Perforation intervals for Northstar weBs ) ) Subject: Perforation intervals for Northstar wells Date: Fri, 17 Jan 2003 11 :44:09 -0600 From: "Sherritt, Allen" <SherriJA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Francis, Michael J" <Michael.Francis@BP.com>, "Hernandez, Floyd" <HernanF 1 @BP.com> Winton, As per our conversation, the following Northstar wells do not have a reference to perforation intervals included in the drilling permits. NS18 NS22 NS06 NS20 NS16 'ÎOt. -,/'1. 1 NS21 NS19 They all will be perforated within the Ivishak interval: "Perforate -140' Ivishak formation between the Top Ivishak and owe." "Perforation interval will be based on PE recommendation after completion of well." The actual perforation depths will be provided in the final well completion reports. If you need any further information, give me a shout. Thanks, Allen Sherritt BP Northstar Operations Drilling Engineer * (907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrija@bp.com * (907) 564-5200 (Fax) * MB 3-6 / 383B ) ) Date: 01-02-2003 Transmittal Number:92451 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS-15 10-11-2002 SCH 2 14420 151 00 PERFORATING RECORD; .. ¿;;Q:) -()5 '-I NS-15 10-04-2002 SCH 1 15006 15093 PERFORATING RECORD; ac::a-05 t../ J NS-20 10-22-2002 SCH ¿;p;;.- ,/d '/ ,NS~Jb 1~~t'!J~-2~f) 5(;-1 /Ål5 -JA I:J-t'/-;).oof). S Cf-I '1 5 C 11 , /AI~-I 7 I~ _D/"'¿wI), ~ LJ)o¥~ ~ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center 1 100 15770 ULTRASONIC IMAGER; ~/a, pl('~A.AÆY DJ:P'Tf-1 La;.J· d.Od--1 g"~ fJl2l1?A1!Y D£~rH ¿~; aOd.-/LfI ¡'f'iJl'l"lI4I2V O/?/ìN L tq;,,J' óIDdt -ól 0 Î I ) 40 o It!'ý&S- ¡ç.-S8j- ¡ '3 1.( .t' t:7 'i1:' Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED JAN 0 3 2003 Alaska (J.¡ & GG$ W'ì¢. ~mmieeirm Anchorage ._~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date: 12-5-2002 Transmittal Number:92602 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, pl~ase contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS06 06-07 -2002 SPERRY 100,101 , '201 13396.9 MUD LOG - 5" - MD LOG -.... SUN 200,300, () .t/ v'" 400 -¡- NS06 06-07 -2002 SPERRY 100,101~ 201 13396~9 MUD LOG - 2" - TVD LOG ~ SUN 200,300, ~NS06 V' /' 400,401 06-03-2002 SPERRY 100,101, 201 13396.9 MUD LOG - 2" - MD LOG SUN 200,300, I 400,401 NS07 05-15-2002 SPERRY 100,200, 201 13529 . MUD LOG - 5"- MD LOG SUN 300,400, ç:: NS07 v 500 05-15-2002 SPERRY 100,200, 201 13529 MUD LOG - 2" - TVD LOG 0 SUN 300,400, ( ¡- 500 BNS07 05-15-2002 SPERRY 100,200, 0 13529 MUD LOG - 2" - MD LOG SUN 300,400, r1) v' 500 NS08 03-10-2002 SPERRY 1 ,2,3,4 201 12030 MUD LOG - 5" - MD LOG - SUN ~ NS08 03-10-2002 SPERRY 1,2,3,4 201 12030 MUD LOG - 2" - TVD LOG ~'NS08 SUN 03-1 0-2002 SPERRY 1 ,2,3,4 201 12030 MUD LOG - 2" - MD LOG SUN NS12 06-27 -2002 SPERRY 100,200, 201 13135 MUD LOG - 5" - MD LOG C v"" SUN 300 -NS12 06-27 -2002 SPERRY 100,200, 201 13135 MUD LOG - 2" - TVD LOG - , ./' SUN 300 ~NS12 / 06-27-2002 SPERRY 100,200, 201 13135 MUD LOG - 2" - MD LOG ~ SUN 300 NS14 ~ q~~Ðèi2:ôb2) šÞ€8RY 1 ,2,3,4 201 13020 MUD LOG - 5" - MD LOG ./ SUN ÒO NS14 02~09-2092 ,BP'ERRY 1 ,2,3,4 201 13020 MUD LOG - 2" - TVD LOG .¡ SUN \ . o NS14n~N::~ 02.;.09.;.200~USÞEHFty; 1 ,2,3,4 201 13020 MUD LOG - 2" - MD LOG ~ / ~.:·'-~:·tl··<\'·:t. ~/. SUN NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 5" - MD LOG -::::r SUN 300,400, ~ NS15 ~ 500 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - TVD LOG ~ / SUN 300,400, 0 <ã Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date: 12-5-2002 Transmittal Number:92602 BPXA WELL DATA TRANSMITTAL 500 NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - MD LOG / SUN . 300,400, 500 NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 5" - MD LOG " ./ SUN ~NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG-2"-TVD LOG ( ,/ SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - MD LOG f""\) I SUN NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 5" - MD LOG SUN 200,201, /' 300,301, 400,401 .::;: NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 2" - TVD LOG -... SUN 200,201 , . 300,301, rcr ,/ 400,401 ~NS18 08-06-2002 SPERRY 100,101 , 201 16550.4 MUD LOG - 2" - MD LOG SUN 200,201 , ~ / ,\ 300,301, 400,401 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 5" - MD LOG ~ v SUN 300 -.9 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - TVD LOG - ~ NS24 v SUN 300 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - MD LOG CO I SUN 300 Q~g~n one copy Df this transmittal. Thank You, RECEIVED James H. Johnson Petrotechnical Data Center DEe 05 2002 Ken Lemley MB3-6 AI8Ika Oit & Gaa ConI. CGnIniIIion Esther Fueg MB3-6 ÞJ.... Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Northstar - SSSV Setting Depths ) ) Subject: Northstar - SSSV Setting Depths Date: Fri, 22 Nov 2002 13:35:25 -0600 From: "Francis, Michael J" <Michael.Francis@BP .com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Holt, Barbara M" <HoltBM@BP.com>, "Sherritt, Allen" <SherriJA@BP.com>, "Hernandez, Floyd" <HernanF1@BP.com>, "Schultz, Mikel" <Mikel.Schultz@BP.com>, "Garing, John D" <GaringJD@BP.com> Winton, Pursuant to our conversation, this note is to inform you that BP will be changing the SSSV setting depths in the following already permitted producer wells: NS24 NS18 NS16 ~r,¡ ~, .. 1"2.. 7 NS20 NS19 As allowed by Conservation Order No. 458A, these setting depths will be changed to 10001 TVD. Please call if you have any questions or comments, Mike Michael J. Francis, P.E. BP Exploration Alaska, Inc. Senior Petroleum Engineer Phone: (907) 564 - 424 0 Cell: (907) 529-8678 Fax: (907) 564-5200 e-mail: Michael.Francis@bp.com P.O. Box 196612 Anchorage, AK 99519-6612 ) ) Date: 09-05-2002 Transmittal #92565 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Bottom SW Name Date Contractor Log Run Top Depth Depth Log Type NS18 07-17-2002 SPERRY END OF WELL REPORT; i~.. ~1':11 MUDLOG DATA ASCII FILES; ~Dd--} 0 I NS06 05-18-2002 SPERRY END OF WELL REPORT; MUDLOG DATA ASCII FILES; ~~- J~I NS16 06-07 -2002 SPERRY END OF WELL REPORT; MUDLOG DATA ASCII FILES; ~æ... }) 0 NS12 06-28-2002 SPERRY END OF WELL REPORT; MUDLOG DATA ASCII FILES; ~ú QQop- ) Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) Attn: Buford Bates (Murphy Exploration) RECEIVED SEP C 5 2002 Àlaska \Ji¡ &; GaB Cans. C¡;mffiÍ!3ioi¡ Anch~ae Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date.,Æ-05-2002 Transmittal #92556 aoa-Jd7 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Bottom SW Name Date Contractor Log Run Top Depth Depth NS16 07-11-2002 ANADRILL 1 0 12105 Log Type DIRECTIONAL SURVEY; HARDCOPY/DISKETTE; ~e copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) ) i ,) RECEIVED AUG 0 5 2002 Alaska Oil & Gas Cons. COrnmiasfon Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 ) ) ~ 1J!Æ9"f r?Œ ~~: rp ß·~ n ffi~ ~ œ· fÃ" !! fi. .! i ¡.' ~ ; I I ~ A \ ! I .ß ." ' I.ß \... . u! : U U '"\J ~ .n! c9 '\.~ Lr-~ AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 'JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 1, 2002 Floyd Hernandez BP Exploration (Alaska), Inc. Drilling Department PO Box 196612 Anchorage Alaska 99519 Re: Permit to Drill 202-127 Dear Mr. Hernandez: Last week the Commission approved the above-referenced application for permit to drill. The approval letter inadvertently included two sentences from a template generally used for exploratory wells. Please disregard the following requirement that was included in the approval letters: "A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a I generalized synopsis of the week's activities and is exclusively for the Commission's internal use." We apologize for any inconvenience this may have caused you. Sincerely, ~ - / c9<.eki." ~ Ca~~; ~~sli Taylor Chair 1 ) ~9~?~ , , I ¡ ! IJ· .A iI : ~. . ~.' u ~ fTIì r-i \U¡ r:) '\",-...1 ~.J ffill \ n..l·. ,Æ\ ~.' :.' ~~'..rl !f}\ ~,~ In'rÌJ) i, If~r""",\ '. .J L'::J! U U ~¡.J '- U TONY KNOWLES, GOVERNOR AlfASKA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TIt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Northstar Unit NS16 BP Exploration (Alaska), Inc. Permit No: 202-127 Surface Location: 1199' NSL, 645' WEL, Sec. 11, T13N, R13E, UM Bottomhole Location: 996' NSL, 593' WEL, Sec. 10, T13N, R13E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above development well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CaAv <Û~U· I~. jL< Cam~echsli Ta~;0 Chair BY ORDER OF THE COMMISSION DATED thi~~ day of June, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA STATE OF ALASKA, )L AND GAS CONSERVATION COMt\,...,hION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 56' Northstar Unit 6. Property Designation ADL 312799 7. Unit or Property Name Northstar Unit 8. Well Number ./ NS16 9. Approximate spud dqte 06/27/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12400' MD / 11136' TVD o 17. Anticipated pressyre {see 20 AAC 25.035 (e) (2)} 28.55 Maximum surface 4172 psig, At total depth (TVD) 11080' / 5280 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 201' 201' Driven Surface Surface 3508' 3230' 618 sx PF 'L', 466 sx Class 'G' Surface Surface 10425' 9306' 548 sx Econolite, 617 sx Class 'G' 10275' 9174' 12117' 10864' 518 sx Class IG' 11967' 107201 12400' 111361 78 sx Class 'G' vJ6A- !PI tð /0 Î- J ¿r- '=4 2-D \ 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1199' NSL, 6451 WEL, SEC. 11, T13N, R13E, UM At top of productive interval 10001 NSL, 503' WEL, SEC. 10, T13N, R13E, UM At total depth 996' NSL, 5931 WEL, SEC. 10, T13N, R13E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well / ADL 312808,2756 MD (approx) NS15 is 12.59' ft away at 550' 16. To be completed for deviated wells Kick Off Depth 3001 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 20" 169# X-56 WELD 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-Mod 7" 26# L-80 Hydril521 4-1/2" 12.6# 13Cr Vam Ace Hole 20" 16" 12-1/4" 8-1/2" 6-1/8" Lenath 2011 35081 10425' 1842' 433' Quantitv of Cement (include staae data) 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 Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED JUN 1 8 2002 Perforation depth: measured Alaska Oil & Gas Cons. lIUllliill.....;,n.' Anchoraoe true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hemandez ~ l~ .... Title Senior Drilling Engineer ¿;,/ Commi.ssionUseOnly Permit Number API Number Appr0J:I Dat1 See cover letter 2.(1 Z - /./ 7 50- 02.. '7 - 2- 3 ð 9 h lO 3\)¡ ().?- for other reauirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log Re ired 181 Yes 0 No Hydrogen Sulfide Measures 0 Yes LiI No Directional Survey Required S Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~t-- B'~£ ~ 'ff3..C?c7 pç,,' ~ . L r,,~~d. P-w 2t:/4à ( 2..S.o~S(~){"l)/ ~~ t't6~t'l"'-~\"~ \1J8toraer of Approved By Oogmal 3Ign(,\1 D)(~. <{'Y1\s~,ri\ I ¡^ t~e commission Form 10-401 Rev. 12-01-85 Cammy Oechsli Taylb.J ¡ \ I lJ i i ~ ~-\ L Date (./ I &/. ì... Date [0 I~\'/ó ~ 'Sutmlt TrI~riPlicate . . ') ) bp ,.'. ,,1'.'11. ......~ ~~. ~- ~~ ..~ ~..... · I'~~I\" ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: June 18, 2002 From: Allen Sherritt Northstar Operations Drilling Engineer Subject: NS16 Application for Drilling Permit Mr. ~~r, j NS16 is currently scheduled for Nabors 33E on June 26th, 2002. The rig will be finishing 8 Y2 interval on NS12 approximately June 25th. I A Diverter waiver is also requested on NS16. To date, BP has drilled twelve development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Eleven surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth,/ (-150' TVD below the top of the SV6), with one well extending into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ,/ NS16 will perform an "Operation Shutdown" durinJ the 2002 Seasonal Drilling Restriction period. A Sundry '* for the Operation Shutdown will ~ be submitted, as the operations are covered in the ADP procedure. Please find attached the NS16 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5204. Sincerely, Allen Sherritt BP Northstar Operations Drilling Engineer 564-5204 II , ) ) NS 16 SUMMARY DRilliNG OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ria Operations: ..¡ 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if rquired. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the top of the SV6 marker at approximately 3312' MD. Surface casing point has been picked at 3508' MD. POOH. / 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. A TAM port collar will be run at +/- 1600' MD. In the event the cement does not circulate to surface, this port collar will. btA- ~ utilized to ensure a successful cement job is performed. l/ 60þJl-(L ~ 5. ND diverter / riser system and NU casing / multi-bowl wellhead. NU BOPE and test to 250/~si. 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. , 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a 12.5 v" ppg EMW. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximately 10,425' MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.1 '/ppg at the top of Kuparuk. POOH. (No logs will be run, unless the Kuparuk is oil bearing.) ./ 9. Run 9-5/8", 47# intermediate casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with 1 annular ./ volume of mud upon installing and testing the packoff. Down-squeeze diesel to 2000' TVD for freeze ~ protection after WOC. / 10. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4100 psi with 10.1 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. ./ 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a 13.5 ppg EMW, (FIT/LOT procedure on file with AOGCC). 12. Weight up to 12.5 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 12,076' MD,/' Intermediate casing point has been picked at 12,118' MD. POOH. 13. Run and cement a 7" 26# drilling liner. Displace cement with 12.5 ppg mud. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 14. Pressure-test the liner tOR packer and casing to 1500 psi (11.8 ppg equivalent) v 15. Circulate to clean 8.65 ppg seawater (less than 80 NTU's) using spacers as per Baroid recommendation. 16. Shut down and monitor the well for a minimum of 30 minutes (nª' ;;est on liner top). ~ 17. POOH and lay down liner running tools. Test 9 5/8" x 7" liner to 800 psi for 30 mins, (MMS - 70% of burst), will need to wait 8 hrs for cement to build 500 psi compre siv strength. RIH to 100' below the base of permafrost and circulate 6.8 ppg diesel to freeze protect t e well to surface. POOH. 18. Prepare for "Operations Shutdown. (June 1st Seasonal Drilling Restriction)" 19. Install 4 Y2" tubing hanger and test to 4200 psi. 20. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 21. Install (dry rod in) BPV and test. Ensure all valves are closed. RD and move off well. / NS16 Permit to Drill ) I ) 22. Prepare to re-enter well post "Seasonal Drilling Restriction." ~ 23. MIRU Nabors 33E. t/ßtøo v.J6 24. Pull BPV. Install TWC. ND dry hole tree. NU BOPE and test to 250~ psi. ~ 25. RIH wI 6-1/8" directional assemblYSO' MD. Displace diesel with seawater, (see diesel handling . procedure). Test 9 5/8" x 7" liner to 4800 si for 30 mins. RIH to 7" liner top. Displace seawater to 9.3 ,/ ppg mud. Clean out 7' liner to the Ind' g collar. 26. Drill out remaining cement. Drill 20~f new formation below 7" shoe with 9.1 ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 27. Drill 6-1/8" production interval to the proposed TD at 12,400' MD. Increase mud weight to 9.3 ppg '(" prior to POOH. 28. RU Schlumberger E-line unit. Run open hole Dipole Sonic and RFT's (pressures only). POOH and RD Schlumberger. 29. Make a clean out run, if requjred, and condition the hole for a liner. POOH. 30. Run and cement the 4-1/2" 12.6# 13Cr liner with an inner string. Set the liner hanger and liner top packer. Circulate min. 1 bottoms up to remove excess cement 9.3 ppg viscosified brine. 31. Pressure-test the liner top packer and casing to 1500 psi (11.8 ppg equivalent) 32. Circulate to clean seawater (less than 80 NTU's) using spacers as per Baroid recommendation. 33. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 34. POOH. Close the blind rams and pressure-test the liner lap to 3400 psi ~ith 9.3-ppg fluid in the well for 30 minutes. prey,are to run the 4 Y2" completion. No slick line work will be done. 35. Run the 4 Y2", 13Cr Yam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 36. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +1- 2000' TVD (2108' MD) to surface. 37. Run space out pups and terminate the 2 - 0.25" control lines and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function test the fiber optic line. 38. Pump corrosion inhibitor and heated diesel down the 4 Y2" x 9 5/a" annulus equivalent to the annulus * capacity plus tubing capacity to a depth of 4061' TVD (4403' MD). RU the U-tubing manifold and allow the Freeze Protection fluid to u-tube through the GLM lower, -6500 MD. v 39. Drop ball and rod to Sr~-- cker. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with .65- pg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 40. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 41. Bleed down the annulus to 3500 psi. Bleed down the tubing to 0 psi. This will shear the RP valve in the lower most GLM. )t~·- 42. Bleed off annulus to 0 psi. Allow fluids to U-tube from the annulus into the tubing. 43. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 44. Install and test (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: Estimated Operations Shutdown Date: June 27th, 2002 July 16th, 2002 Allen Sherritt Operations Drilling Engineer 564-5204 2 NS16 Permit to Drill ) ) NS16 WELL PLAN SUMMARY I Type of Well (producer or injector): I 1 I TVDrkb: 111,136 1 1 RKB/Surface Elevation: (a.m.s.l.) 156.0' / 15.9' I I 1 Northstar Slot: Surface Location: Target (top of SAG): 400' Radius Bottom Hole Location: 1 AFE Number: 1 831312 1 Estimated Start Date: I MD: 112,400 1 I Producer NS16 1199' FSL, 645' FEL, Sec. 11, T13N, R13E, UM X = 659830 Y = 6030972 1000'FSL,503'FEL,Sec.10,T13N,R13E,UM X = 654697 Y = 6030664 10,824' TVDrkb 996' FSL, 593' FEL, Sec. 10, T13N, R13E, UM X = 654607 Y = 6030658 11,136' TVDrkb )/ /" I Rig: I Nabors 33E I 6/27/02 / I Operating days to complete: I 33.2 I Well Design (conventional, slimhole, etc.): I Modified Big Bore I Objective: 1 Ivishak Producer with fiber optic surveillance control line Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS16 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 of @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 2011 MDrkb of 20",169#, X-56 (pre-driven) 3 .; , NS16 Permit to Drill ) ). MUD PROGRAM: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3508' MD / 3230' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel API FL pH (ppg) (seconds) 10 sec Initial 8.8- 9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5, 100 - 200 30 - 45 >6 15 - 25 4-10 8.5 - 9.5 SV6 @ Interval TD *9.5 / 75 - 100 20 - 35 >6 10 - 25 4-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer 12-1/4" Hole Section From Surface Casing Shoe to 10,425' MD / 9306' TVD (-65 below top Miluveach). Interval Density (ppg) PV YP Tauo Initial 8.7 - 9.3 10 -16 20 - 30 4-7 TopHRZ 9.6 10-16 20-25 4-7 Top Kuparuk to Miluveach 10.1 / 10- 18 20 - 28 4 - 7 API/ HTTP FL 6-10 4-6/<12 4-6/<12 pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 12,117' MD /10,864' TVD (top of Sag) Interval Density (pp~ PV YP Miluveach & Kingak to top of Sag 12.5 10 - 25 20 - 25 Tauo 4-7 API FL 4-6/<10 pH 8.5 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 12,400' MD /11,136' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 7 8 - 12 20 - 25 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P11 ) Survey Program: /' ±300' MD Cay(tenary curve 1.0°/100' to 2.50°/100' build ±28° Surface- 10' well spacing to well NS-15 NS17 - planned well, not yet drilled. NS15 - closest point at 550' MD center-to-center distance is 12.59 ft. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1600'. Standard MWD surveys from +/-1600' to TD. KOP: Maximum Hole Angle: Close Approach Wells: SURFACE AND ANTI-COLLISION ISSUES: Well NS16 is 12.59 ft center to center from NS15 at 550' MD. All wells pass the major risk rule. Gyros will be run from surface to -1600' MD or until reliable MWD surveys can be taken. See Anti- collision Report in directional (P11) attachment for summary of allowable deviations. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 4 NS16 Permit to Drill ) LOGGING PROGRAM: ) 16" Section: Drilling: GR/Directional - Gyro as needed to -1600' MD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Resistivity (real-time), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples from 9750' MDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, Resistivity (real-time), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GR/Directional, Resistivity/Density/Neutron (recorded) Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: RFT's - 20 Pressures Cased Hole: None InteÇlritv Testinq: Test Point 12 %" Surface Shoe 9 5/8" Intermediate Shoe 7" Drilling Liner Shoe Depth Test Type 20' min from 12 1/4" shoe FIT 20' min from 95/8" shoe FIT 20' min from 7" shoe FIT CASINGfTUBING PROGRAM: Hole Size Casing/ Wt/Ft Grade Conn. Casing Tbg a.D. Length 20" 20" 169# X-56 WELD 201' 16" 13 3/8" 68# L-80 BTC 3508' 12 %" 9 5/8" 47# L-80 BTC-Mod 10425' 8 Y2" 7" 26# L-80 Hydril521 1842' 6-1/8" 4-1 /2" 12.6# 13Cr Vam Ace 433' Tubing 4-1 /2" 12.6# 13Cr Vam Ace 11967' 5 EMW 12.5 ppg EMW Target 13.5 ppg EMW Target 11.5 ppg EMW Target / Casing Top M DITVDrkb Surface Surface Surface 10275'/9174' 11967'/10720' Surface Hole 8tm M DITVDrkb 201 '/201' 3508'/3230' 10425'/9306' 12117'/10864' 12400'/11136' 11967'/10720' / NS16 Permit to Drill ) ') FORMATION MARKERS: TVDss MDrkb Pore Press. Comment Formation Top estimated (Psi) I (ppg EMW) Top Permafrost 1,149 1219 542 8.65 Base Permafrost 1,519 1624 708 8.65 Set surface casing -150' tvd 9, S SV6 - top confining zone 3,002 3312 1375 8.65 below top SV6 Surface casing point 3,174 3508 0 0.00 SV5 - base confining zone 3,266 3613 1494 8.65 SV4 3,557 3944 1625 8.65 SV2 - top upper injection zone 3,960 4403 1806 8.65 SV1 - top major shale barrier 4,361 4859 1987 8.65 - top lower injection zone - T o~ 4,704 5250 2141 8.65 1 - top Schrader Bluff - Base L 6,394 7174 2901 8.65 3ase lower injection zone (top ( 6,835 7676 3099 8.65 THRZ - Top HRZ 8,522 9597 3858 8.65 cr. I BHRZ - Base HRZ 8,620 9708 3902 8.65 Top Kuparuk 8,670 9765 4265 9.46 ,./" Kuparuk e 8,831 9948 4428 9.64 to Top Miluveach 9,199 10367 4333 9.06 Set intermedate casing into the Intermediate casing point 9,250 10425 0 0.00 top of the Miluveach Intermediate logging point 9,250 10425 0 0.00 Top Kingak 9,723 10955 4690 9.28 Expected in upper Kingak 12. Top Sag River 10,768 12076 5037 8.95 Geol target 10,768 12076 4992 8.92 Set drilling liner into top Sag River to cover Kingak. Intermediate casing point 10,808 12118 0 0.00 Hydrocarbon bearing. Top Shublik 10,858 12170 5079 8.95 r. ~ Top Ivishak 10,950 12266 5122 8.95 Total Depth 11 ,080 12400 5280 9.12 TD - - 20· above owe. Oil - Water contact 11 ,1 00 12420 5192 8.95 Top Kavik Top Lisbu me 6 NS16 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ) 3508' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 10425' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 147 - 9 5/8" x 12" 1842' 1 - 8 Y2" 1 -7" 1 -7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1-7" 433' 1 -4-1/2" 1 -4-1/2" 22 - 4-1/2" x 5-3/4" 11- 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 11967' 1 1 1 1 1 1 1 1 1 2 1 ) 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) TAM Port Collar SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 3,4" external ACME landing thread ABB-VGI Casing HeadfTbg head 95/8",47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7", 26# L-80 Hydril 521 BBL reamer shoe HES Super Seal II Float Shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2",12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Vam Ace 4 Y2" ABB-VGI tubing hanger 4 Y2" ABB- VG I adapter flange 4 Y2" ABB-VGI 5-1/8" 5K Swab Valve w/ tree cap CIDRA mandrel and 0.25" fiber optic cable (w/4 Y2" cable clamps). 4 Y2" SVLN and 2 - 0.25" control lines 4 Y2" X 1 Y2" GLM with dummy valve installed 4 Y2" x 1 Y2" GLM with RP Shear valve installed 7" x 4 Y2" Baker 13 Cr packer S-3. 4 Y2" WLEG (w/o holes) 4 Y2" 13 Cr X nipples 4 Y2" 13 Cr XN nipple 7 NS16 Permit to Drill ') ) PERMAFROST: The 13-3/8" surface casing will be run approximately 1600' TVD below the permafrost to -3508' MD / 3230' TVD. The casing will be cemented to surface with a Premium 'G' with 20/0 calcium chloride tail slurry and a Permafrost 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 1375' of Open Hole + 175% excess from the permafrost ~ surface + 50% excess to 750'MD above the shoe. Lead TOC: Surface Tail: Based on 750' of 16" open hole x 133/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2758' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 457 bbl 1618 sl<12565 ft of 10.7 ppg Permafrost 'L' Cement. 4.15""'d/sk, BHST 50° I BHCT 50°, TT = 6.0 hrs 96 b91 /466 sl<7'541 ft;; of 15.8 ppg Premium 'G' wi 2% CaCI2. 1.16 disk, BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 6022' of 12 1/4" open hJe x 9 5/8" csg with 30% excess Lead TOC: At -4403' MD (4016' TVD) Tail: Based on 1667' of 12 "IA" open hole x 9 5/8" csg with 300/0 excess + 80' shoe joint. Tail TOC: At -10121' MD (8200' TVD) IStage 1: Total Cement / Spacer Preflush 20 bbls sea water Spacer 50 bbl Alpha ,9Pacer wei~hted to 1.0 ppg over mud MW Lead 316 9Ø1 I 548 sk 11776 ft of 11.2 ppg Econolite. 3.24 disk, BHSJ-21 0° I BHCT 130°, TT = 4.0 hrs Tail 126b~ 617 SK 1710 fe of 15.9 ppg Premium 'G'. 1.15 disk, BHST 210° I BHCT 130°, TT = 4.0 hrs Casing 17" Drilling Liner Basis: Stage 1 : Slurry: Based on 1692' of 9 7/8" open hole x 7" csg with 50% excess + 150' 95/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -10275' MD (9174' TVD) Stage 1: Total Cement / Spacer Spacer 50 bbl Alpha Spaçer weighted to 1.0 ppg over mud MW Slurry 141 ~ /518 sk1777 ft;; of 15.9 ppg Premium 'G'. 1.50 disk, BHST 250° I BHCT 1500, TT = 4.0 hrs Casing 14-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 283' of 61/8" open hole x 41/2" csg with 50% excess + 150' 7" csg x 41/2" csg liner lap + 200' 7" csg x 4" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -11967' MD (10720' TVD) Stage 1: Total Cement / Spacer Spacer 35 bbl Alpha 9Pacer ~eighted to 1.0 ppg over mud MW Slurry 21 bb,YJ78 sk / 117 ft;; of 15.9 ppg Premium 'G'. 1.50 disk, BHST 2500 I BHCT 150°, TT = 4.0 hrs 8 NS16 Permit to Drill ) ì) WELL CONTROL: / ~ A Diverter waiver has been requested on well NS16. To date, BP has drilled twelve development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. All twelve surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams r ~ Annular preventer 4tJOO pç" ilJ61r- ~ Based upon the calculations below, BOP equipment will be tested to ~ psi. ../' Surface Section: · Maximum anticipated BHP: 1375 psi @ 3002' TVOss - SV6 · Maximum surface pressure: 1075 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/H) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 8831 TVDss - Kuparuk 'c' · Maximum surface pressure: 3545 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/H) Drilling Liner Section: · Maximum anticipated BHP: 5037 psi @ 10768' TVOss - Sag River · Maximum surface pressure: 3960 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/H) Production Section: · Maximum anticipated BHP: 5280 psi @ 11 080' T~s - Total Depth · Maximum surface pressure: 4172 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/H) · Planned BOP test pressure: 4500 psi (annular to 3500 psi) . Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ~ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ~ No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ~ No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. /~ Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. DISPOSAL: ' Annular Injection: There will be no annular injection in this well. / Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. 9 NS16 Permit to Drill ') ') SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre as required prior to penetrating sand intervals. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. · Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS06 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. INTERMEDIATE SECTION: . Mudloggers will be rigged up throughout the entire section. · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · The shallow intervals beneath Northstar are, by interpretation, not faulted. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. . Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. · The kick tolerance for the 12 1/4" open hole section would be 69 bbls assuming an influx from the Kuparuk interval at -8726' TVD. This is the worst-case scenario based on a 9.9 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.1 ppg mud in the hole. 10 '. NS16 Permit to Drill ) ) DRilLING LINER SECTION: · Mudloggers will be rigged up throughout the entire section. · The directional target has been designed not to penetrate any faults. However, be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control /tool to make sure the well does not become under-balanced. · Gas in the SAG is possible. Circulate as required. According to Geology, the top of the SAG is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.8 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 13.5 ppg at the 9-5/8" shoe, and 12.5 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. The drilling liner shoe will be drilled out with the 12.5 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Losses are not expected but calcium carbonate (CaC03) will be maintained in the system. Severe lost circulation was encountered on the NS29. The Ivishak is a conglomerate section. Directional control will be maintained with MWD surveys to minimize doglegs. The well is planned to stop short of the OWC. The Kavik willi not be penetrated. The project Geologist will be in charge of picking TD above the OWC and rathole sufficient to bury the open hole logs will be drilled. The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open / hole) assuming an influx from the proposed TD. This scenario is based on a 9.62 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. · · · · · · 11 .. NS16 Permit to Drill ) ) NS16 RiQ-site Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS16 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. ~ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. ~ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any previously drilled Northstar wells. Mudloggers will be used continuously on NS16 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. ~ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 Y2" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. ~ Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ~ Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ~ The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ~ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ~ Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 12 TREE: ABB-VGI 5 1/S" 5ksi WELLHEAD: ABB-VGI13-5/8" ) Multibowl5ksi ~ ORIGINAL KB. ELEV = 56' )B-BF. ELEV = 40.1' CB. ELEV = 15.9' 4 1/2" SSSV @ 2000' TVD wI HXO SVLN nipple - 4.562" ID 6.SPPG DIESEL FREEZE PROTECTION AT +1- 4061' TVD (4403'MD) NS16 - Proposed 13 3/S" TAM Port Collar at +1-1600'MD 13 3/S", 6S#/ft, L-SO, BTC @ 3508' MD ~ 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.95S" .. CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-80 BTM-C @ 10425' MD H ~- 4.5" X NIPPLE, @ 11917' MD 3.813" ID 4.5" X NIPPLE, @ 11937' MD 3.S13" ID 4.5" XN NIPPLE, @ 11947' MD 3.725" ID 4.5" WLEG, @ 11957' MD 3.95S" ID - B B 7", 26#/ft L-SO, Hydril 521 @ 12117' MD JI PBTD @ 12360' MD TD @ 12400' MD ~ DATE 6/17/02 REV. BY COMMENTS JAS ~S 16 t-'roposed ~ 4 1/2" GLM @ 4500' TVD (4953' MD) wI 4.62" ID 4 1/2" GLM @ Q, TVD (6500' MD) wI 4.62" ID ~ ~ - 7" LINER TOP @ 10275' MD It I 4.5" Fiber Optic Transducer 3.95S" 10 -;;- _ 7" PACKER, 13 Cr @ 11927' MD I I r~ ~ 4.5" LINER TOP @ 11967' MD .. ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WFJ . : NS16 API NO: BP Exploration (Alaska) I TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" TAM Port Collar at +1-1600'MD 133/8", 68#/ft, L-80, BTC @ 3508' MD 9-5/8" 47# L-80 BTM-C @ 10425' MD 7", 26#/ft L-80, Hydril 521 @ 12117' MD DATE 6/17/02 ') NS16 - Operation Shutdown ~ ~ ~ 6 ~ REV. BY COMMENTS JAS ~S16 Operation Shutdown .. ) ORIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.9' 6.8PPG DIESEL FREEZE PROTECTION AT +1- 1575' TVD (1623'MD) .. 8.65 ppg Seawater from 1623' MD I 1575' TVD to 10275' MD 19174' TVD ~ - 7" LINER TOP @ 10275' MD ~ .. 12.5 ppg drilling mud from 10275' MD 19174' TVD to 12117' MD /10864' TVD Northstar WFJ J : NS16 API NO: BP Exploration (Alaska) õ I KB KOP 1/100 Bid 2/100 Crv 2.5/100 Top Permafrost End Crv Base Permafrost Report Date: Client: Field: Structure / Slot: Well: Borehole: UWIIAPI#: Survey Name / Date: Tort / AHD / DDI/ ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: NS16 Proposed Well Profile - Geodetic Report June 10,2002 Survey / DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar stu dy Vertical Section Origin: Northstar PF I NS16 . b.II·I~ TVD Reference Datum: NS16 Fe851.~ TVD Reference Elevation: NS16 Sea Bed / Ground Level Elevation: 50-029- Magnetic Declination: NS16 (P11) S18 op41 June 10, 2002 Total Field Strength: 42.685° 15233.65 ft 15.3961 0.47C Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49115951, W 148.69329938 Magnetic Declination Model: N 6030971.560 ftUS, E 659829.810 ftUS North Reference: +1.23170678° Total Corr Mag North -> True North: 0.99992902 Local Coordinates Referenced To: Schlumberger Minimum Curvature 1 Lubinski 267.800° N 0.000 ft, E 0.000 ft KB 55.8 ft relative to MSL 15.670 ft relative to MSL 26.290° 57541.969 nT 80.944 ° July 05, 2002 BGGM 2002 True North +26.290° Well Head ~ Grid Coordinates Geographic Coordinates MD Incl I Azim I TVD VSec I N/-S I EI·W I DLS Northing Eastlng Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 280.00 0.00 0.00 0.00 0.00 0.00 6030971.56 659829.81 N 70.49115951 W 148.69329938 300.00 0.00 280.00 300.00 0.00 0.00 0.00 0.00 6030971.56 659829.81 N 70.49115951 W 148.69329938 400.00 1.00 280.00 399.99 0.85 0.15 -0.86 1.00 6030971.69 659828.95 N 70.49115992 W 148.69330641 500.00 3.00 280.00 499.93 4.26 0.76 -4.30 2.00 6030972.23 659825.49 N 70.49116158 W 148.69333452 600.00 5.00 280.00 599.68 11.08 1.97 -11.17 2.00 6030973.29 659818.60 N 70.49116489 W 148.69339068 700.00 7.00 280.00 699.13 21.30 3.78 -21.46 2.00 6030974.88 659808.28 N 70.49116983 W 148.69347479 800.00 9.00 280.00 798.15 34.90 6.20 -35.16 2.00 6030977.00 659794.53 N 70.49117645 W 148.69358678 900.00 11.00 280.00 896.62 51.87 9.22 -52.26 2.00 6030979.65 659777.37 N 70.49118470 W 148.69372656 1000.00 13.38 276.38 994.36 72.64 12.16 -73.16 /2.50 6030982.14 659756.41 N 70.49119273 W 148.69389740 1100.00 15.80 273.84 1091.13 97.63 14.35 -98.25 2.50 6030983.79 659731.28 N 70.49119871 W 148.69410249 .~ 1200.00 18.24 271.96 1186.75 126.77 15.80 -127.48 2.50 6030984.62 659702.03 N 70.49120267 W 148.69434142 1219.00 18.70 271.66 1204.77 132.78 15.99 -133.49 2.50 6030984.68 659696.02 N 70.49120319 W 148.69439055 1300.00 20.69 270.52 1281.03 160.03 16.50 -160.79 2.50 6030984.60 659668.71 N 70.49120458 W 148.69461371 1400.00 23.15 269.36 1373.79 197.34 16.44 -198.12 2.50 6030983.74 659631.40 N 70.49120441 W 148.69491885 1500.00 25.62 268.42 1464.86 238.62 15.62 -239.40 2.50 6030982.03 659590.15 N 70.49120217 W 148.69525628 1600.00 28.10 267.64 1554.06 283.80 14.06 -284.55 2.50 6030979.50 659545.04 N 70.49119790 W 148.69562535 1618.38 28.55 267.51 1570.24 292.52 13.69 -293.26 2.50 6030978.94 659536.34 N 70.49119689 W 148.69569654 1623.54 28.55 267.51 1574.77 294.98 13.58 -295.72 0.00 6030978.78 659533.89 N 70.49119659 W 148.69571665 Station ID NS16 (P11) report.xls Page 1 of 3 6/10/2002-9:55 AM Grid Coordinates Geographic Coordinates I Station 10 MO Incl I Azim TVO I VSec N/-S I EI·W OLS Northing Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) SV6 3311.89 28.55 267.51 3057.77 1101.98 -21.51 -1101.97 0.00 6030926.37 658728.64 N 70.49110052 W 148.70230706 16" Csg Pt 3507.71 28.55 267.51 3229.77 1195.58 -25.58 -1195.48 0.00 6030920.29 658635.24 N 70.49108936 W 148.70307143 SV5 3612.45 28.55 267.51 3321.77 1245.64 -27.75 -1245.49 0.00 6030917.05 658585.30 N 70.49108341 W 148.70348021 SV4 3943.75 28.55 267.51 3612.77 1403.99 -34.64 -1403.70 0.00 6030906.76 658427.28 N 70.49106451 W 148.70477344 SV2 4402.55 28.55 267.51 4015.77 1623.29 -44.17 -1622.79 0.00 6030892.52 658208.46 N 70.49103836 W 148.70656430 SV1 4859.08 28.55 267.51 4416.77 1841.50 -53.66 -1840.80 0.00 6030878.35 657990.72 N 70.49101229 W 148.70834632 TMBK 5249.58 28.55 267.51 4759.77 2028.15 -61.77 -2027.27 0.00 6030866.23 657804.48 N 70.49099001 W 148.70987054 WS1 7173.60 28.55 267.51 6449.77 2947.79 -101.76 -2946.05 0.00 6030806.51 656886.84 N 70.49087992 W 148.71738063 CM3 7675.66 28.55 267.51 6890.77 3187.77 -112.19 -3185.81 0.00 6030790.93 656647.38 N 70.49085116 W 148.71934041 Top HRZ 9596.27 28.55 267.51 8577.77 4105.77 -152.11 -4102.96 0.00 6030731.31 655731.37 N 70.49074087 W 148.72683709 '"-' Base HRZ 9707.84 28.55 267.51 8675.77 4159.10 -154.43 -4156.24 0.00 6030727.84 655678.15 N 70.49073445 W 148.72727259 Top Kuparuk 9764.76 28.55 267.51 8725.77 4186.31 -155.61 -4183.42 0.00 6030726.08 655651.01 N 70.49073119 W 148.72749475 KupC 9948.06 28.55 267.51 8886.77 4273.92 -159.42 -4270.95 0.00 6030720.39 655563.59 N 70.49072064 W 148.72821021 TMLV 10367.02 28.55 267.51 9254.77 4474.17 -168.12 -4471.01 0.00 6030707.39 655363.77 N 70.49069655 W 148.72984546 9-5/8" Csg pt 10425.08 28.55 267.51 9305.77 4501.92 -169.33 -4498.74 0.00 6030705.59 655336.08 N 70.49069320 W 148.73007212 Drp 0.7/100 10439.20 28.55 267.51 9318.17 4508.67 -169.62 -4505.48 0.00 6030705.15 655329.35 N 70.49069240 W 148.73012721 10500.00 28.13 267.51 9371.69 4537.54 -170.88 -4534.32 0.70 6030703.27 655300.54 N 70.49068891 W 148.73036295 10600.00 27.43 267.51 9460.16 4584.14 -172.91 -4580.88 0.70 6030700.24 655254.04 N 70.49068329 W 148.73074352 10700.00 26.73 267.51 9549.20 4629.66 -174.88 -4626.36 0.70 6030697.29 655208.62 N 70.49067783 W 148.73111526 10800.00 26.03 267.51 9638.79 4674.09 -176.82 -4670.74 0.70 6030694.40 655164.29 N 70.49067245 W 148.73147801 10900.00 25.33 267.51 9728.91 4717.42 -178.70 -4714.03 0.70 6030691.59 655121.05 N 70.49066724 W 148.73183186 Top Kingak 10955.08 24.94 267.51 9778.77 4740.81 -179.72 -4737.41 0.70 6030690.07 655097.70 N 70.49066441 W 148.73202296 11000.00 24.63 267.51 9819.56 4759.65 -180.54 -4756.22 0.70 6030688.84 655078.92 N 70.49066214 W 148.73217671 11100.00 23.93 267.51 9910.71 4800.76 -182.32 -4797.30 0.70 6030686.18 655037.89 N 70.49065721 W 148.73251249 11200.00 23.23 267.51 10002.36 4840.76 -184.06 -4837.26 0.70 6030683.58 654997.98 N 70.49065238 W 148.73283911 11300.00 22.53 267.51 10094.50 4879.64 -185.75 -4876.10 0.70 6030681.06 654959.18 N 70.49064770 W 148.73315658 11400.00 21.83 267.51 10187.10 4917.39 -187.39 -4913.81 0.70 6030678.61 654921.52 N 70.49064315 W 148.73346481 ~ 11500.00 21.13 267.51 10280.15 4954.00 -188.98 -4950.39 0.70 6030676.23 654884.99 N 70.49063874 W 148.73376381 11600.00 20.43 267.51 10373.65 4989.47 -190.53 -4985.84 0.70 6030673.92 654849.58 N 70.49063444 W 148.73405357 11700.00 19.73 267.51 10467.57 5023.80 -192.02 -5020.13 0.70 6030671.70 654815.33 N 70.49063031 W 148.73433385 11800.00 19.03 267.51 10561.90 5056.98 -193.46 -5053.28 0.70 6030669.54 654782.22 N 70.49062631 W 148.73460481 11900.00 18.33 267.51 10656.64 5089.01 -194.85 -5085.28 0.70 6030667.47 654750.26 N 70.49062245 W 148.73486637 12000.00 17.63 267.51 10751.75 5119.87 -196.19 -5116.11 0.70 6030665.46 654719.47 N 70.49061873 W 148.73511836 Top Sag River 12075.45 17.10 267.51 10823.76 5142.39 -197.17 -5138.61 0.70 6030664.00 654697.00 N 70.49061601 W 148.73530227 Target 12075.46 17.10 267.51 10823.77 5142.39 -197.17 -5138.61 0.70 6030664.00 654697.00 N 70.49061601 W 148.73530227 NS16 (P11) report. xIs Page 2 of 3 6/10/2002-3: 1 0 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD VSec N/·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 12100.00 16.93 267.51 10847.24 5149.57 -197.48 -5145.79 0.70 6030663.54 654689.83 N 70.49061515 W 148.73536096 7" Csg pt 12117.27 16.81 267.51 10863.77 5154.59 -197.70 -5150.79 0.70 6030663.21 654684.84 N 70.49061454 W 148.73540183 Top Shublik 12169.46 16.44 267.51 10913.77 5169.51 -198.35 -5165.71 0.70 6030662.24 654669.93 N 70.49061274 W 148.73552378 12200.00 16.23 267.51 10943.08 5178.11 -198.72 -5174.29 0.70 6030661.68 654661.36 N 70.49061171 W 148.73559391 Top Ivishak 12265.21 15.77 267.51 11005.77 5196.08 -199.50 -5192.25 0.70 6030660.52 654643.43 N 70.49060955 W 148.73574071 12300.00 15.53 267.51 11039.27 5205.46 -199.91 -5201.62 0.70 6030659.91 654634.07 N 70.49060841 W 148.73581730 TO 14-1/2" Csg pt 12399.99 14.83 267.51 11135.77 5231.64 -201.05 -5227.78 0.70 6030658.20 654607.94 N 70.49060525 W 148.73603112 LeQal Description: .~ Surface: 1199 FSL 645 FEL S11 T13N R13E UM Target: 1000 FSL 503 FEL S10 T13N R13E UM BHL: 996 FSL 593 FEL S10 T13N R13E UM Northinq (Y) fftUSl 6030971.56 6030664.00 6030658.21 EastinQ (X) fftUSl 659829.81 654697.00 654607.94 -; NS16 (P11) report.xls Page 3 of 3 6/10/2002-9:55 AM ) ) OÞP .. ....'.:.,..::,.,..,.,..........'.'.'::.'..,.'... ...,. ". " II."". ,:.' VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS16 (Pll) Field: Northstar Structure: Northstar PF Section At: 267.80 deg Date: June 10, 2002 Schlumberger 0-··· KOP 1/100 30) MD 300 TVD 0.00' 280.00' az 0 departure ~~=- _________ 11.0C' 280.00' az 52 daparture _______' End Cry 1618 MD 1570 TVD 28.55' 267.51' az 293 departure ....."... ..., "........",.'"."...,.....,.,."....~.".."."... ...' ....""."."..".._"."".,,,,,....,,.."'",,..,,.. 2000 _. Top PermBtroãï 1219 MD 1205 -vo - BesëPermafrOOt 1624 Mõ fS75lVD- ...-.. ...... 0) ...-.. Jl -J 4000 -.- en 0 ~ 0 0 (I) C\I > II 0 ..c .~ ro ¢:: ~I"- -I"- 6000 _. .l: . ......LC) Q.LC) 0)- CI m m ~ 0 ..¡,..: :.e (I) 0) a::: > > 0) (I) 8000 _.. :J ill '- .- 16" Ceg PI /3508 MD 3230TVD 28.55' 267.51' az 1196 daparture '\' ~- - -sl7S'3ffitom 31i58í\7b- ß - - - svr; 3m MD 3~ í\7b - -SV4 3044 MD 3ð'i31'iJD - - S\7f 4S5tJ tom 44'17 í\7b - -"""",-.",.,,.--..,,- -s~441r3Mlr4¡¡;61V¡¡'-· -T~K "525c51J1D 4r60ìVIJ Hold Angle 28.550 - WS1 7174MD 6450-TVD- - CM3 7676MD 6s91TvD- - !iii> HRZ !!5!I61ID B57a\1D:: - - - - - - - = Tõþ Küj5arilR" 9765 MIJ 8726 TVD =Efasë=FiRiRJ7ÐB Me: 86i'6 TVÐ - IWp é99oŒMIJ88l!7 T'J!:j - - - - - - - - 9-518" ::sg PI ........-.... "104ð'MO--g30151VO' ~28.55' 267.51' az 4502 departure -- ----- -------- -------- - ------ Dr > 0.7/100 1~39MD 9318TVD 28.55' 267510 az- 4509 departure - TMLv10367MD9255TVõ - ----- - TOP Kiñgak10955 MD 9779 TVD --------- 10000 -'''- - ---..--.. -,."--.--....--.--- ~I,~f~lri~ == Targ8i - - 12075 MD 10824 TVD 17.10' 267.51' az 5142 departure 12000 _..... . - ---_..- ---- -.--~..._- ---, -,-"- -... --------.~.,._"_._----_._-_.__._.- TD /4-1/2" Csg PI _ _ _.-.J.~_OQ.MP_11.t:¡§JYO. 14.83' 267.51' az 5232 depar:ure -2000 o 2000 4000 6000 Vertical Section Departure at 267.80 deg from (0.0, 0.0). (1 in = 2000 feet) - ""-' 1000 I o End CrY 1618 MD 1570 TVD 2R55· 267.51· az 14N 293W t -1000 -2000 EAST »> -3000 I -4000 «< WEST -5000 ~ -6000 -2000 -1000 o ~ . Cry 2.51100 900 MD 897 TVD 11.01>" 280.00· az , 9 N 52W 16" Csg pt 3508 MD 3230 TVD 28.55· 267.51' az 268 1m5W ~ ~ lIT'" ~ 9-518" Csg pt 10!125 MD 9306 TVD 2~,...55' 267.51' az 1~8 4499W DrpO.7/100 ¡ 10439 MD 9318 TVD 28.55· 267.51' az 170 8 4505 W -.- -2000 _ _n__ KOP 111 00 300 MD 300 TVD . 0.00' 280.00" az ON OE IV-I Hold Az~muth 267.51° Target 12075 MD 10824 TVD 17.10' 267.51' az 1978 5139W I : t- i 7" Csg pt ::> -1000 - ~- : 12117MD 10864TVD O : 16.81' 267.51' az 1 198 8 5151 W en I V V V 0- .---+--- Bid 2/100 400 MD 400 TVD 1.00' 280.00' az ON 1W 1000 2000 1000 I o I TD /4-112" Csg pt 12400 MD 11136 TVD 14.83' 267.51' az 201 S 5228 W ^ ^ ^ I t- n:: o z j~ I-~ 1000 -- True North Mag Dee ( E 26.29° -1000 I -2000 I -3000 I -4000 I 2000 ----- -5000 I -6000 I bp PLAN VIEW Client: BP Exploration Alaska 0 Well: NS16 (Pll) I Schlumberuer Field: Northstar Structure: Northstar PF Scale: 1 in = 1000 ft Date: 10-Jun-2002 ) Schlumberger Anticollision Report ') NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.20 to 12399.99 ft Maximum Radius: 2000.00 ft Reference: Error Model: Scan Method: Error Surface: , D~: Sybas~ Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 3/9/2002 Validated: No Planned From To Survey ft ft 40.20 1000.00 Planned: Plan #11 V1 1000.00 12399.99 Planned: Plan #11 V1 Version: 29 Tooicode Tool Name GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points iMI),' 'tVD ft ft 3507.71 3229.77 13.375 16.000 13 3/8" 10425.08 9305.77 9.625 12.250 95/8" 12117.27 10863.77 7.000 8.500 7" 12399.99 11135.77 4.500 6.125 41/2" Summary <."---"':' Offset W~llpath ' RHel'ence , . '~():(f~¢t "., . ' Çtr~cttl'No~Gø,' Allowa.ble":'.' ..",,', ......... Site Wen 'MD ' ;.MD,· Dista:nc~. A¡;ea ' Oev~atiol)' . WarDing ft·' ft', ' · '.ft ""ft I·' :':',:: :(ti I" ::, I, : ":':: II ,I : .::'.~, ':: ~ I' ,;'. ,-1 I,.: :",' ;:, " ',;' , ., Northstar PF NS05 Plan NS05 V7 Plan: Pia 498.68 500.00 110.86 9.16 101.70 Pass: Major Risk Northstar PF NS06 NS06 V28 399.48 400.00 101.24 7.26 93.98 Pass: Major Risk Northstar PF NS07 NS07 V33 149.64 150.00 91.31 3.12 88.19 Pass: Major Risk Northstar PF NS08 NS08 V18 299.76 300.00 79.88 5.50 74.38 Pass: Major Risk Northstar PF NS09 NS09 V14 548.11 550.00 75.13 8.76 66.41 Pass: Major Risk Northstar PF NS10 NS10 V17 598.18 600.00 52.17 9.02 43.28 Pass: Major Risk Northstar PF NS12 Plan NS12 V19 Plan: PI 499.22 500.00 40.48 8.99 31.52 Pass: Major Risk Northstar PF NS13 NS13 V12 449.61 450.00 33.62 7.73 25.89 Pass: Major Risk Northstar PF NS14 NS14 V11 400.00 400.00 17.76 7.26 10.50 Pass: Major Risk Northstar PF NS15 NS15 V19 549.67 550.00 12.59 9.42 3.17 Pass: Major Risk Northstar PF NS18 Plan NS 18 V3 Plan: Pia 549.96 550.00 19.79 9.99 9.80 Pass: Major Risk Northstar PF NS20 Plan NS20 V5 Plan: Pia 650.18 650.00 39.88 11.92 27.96 Pass: Major Risk Northstar PF NS21 Plan NS21 V37 Plan: PI 450.35 450.00 50.85 8.22 42.63 Pass: Major Risk Northstar PF NS25 Plan NS25 V2 Plan: Pia 450.63 450.00 91.02 8.36 82.66 Pass: Major Risk Northstar PF NS26 NS26 V22 750.28 750.00 98.50 11.89 86.62 Pass: Major Risk Northstar PF NS27 NS27 V29 699.88 700.00 109.90 12.72 97.19 Pass: Major Risk Northstar PF NS28 Plan NS28 VO Plan: Pia 800.00 800.00 117.90 14.56 103.34 Pass: Major Risk Northstar PF NS29 NS29 V22 400.48 400.00 130.55 7.09 123.46 Pass: Major Risk Northstar PF NS31 NS31 V14 750.11 750.00 148.48 12.92 135.56 Pass: Major Risk Northstar PF NS35 Plan NS35 VO Plan: Pia 900.00 900.00 186.59 16.46 170.13 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 946.14 950.00 353.00 18.11 334.89 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 997.18 1000.00 338.20 19.72 318.48 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 950.50 950.00 337.59 17.06 320.53 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 948.35 950.00 336.38 15.33 321.06 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 805.44 800.00 377.01 14.42 362.59 Pass: Major Risk --- "- Target: S 18 Op4 Site: Northstar PF ., Drilling Target Coni: 99~~ Description: sag tgt Map Northing: 6030665.00 ft Map Easting: 654697.00 ft Latitude: 70029'26.227N Shape: Circle ~ell: NSl6 Jased on: Planned Program Vertical Depth: 10768.00 ft below Mean Sea Level Local +N/-S: -196.17 ft Local +E/-W: -5138.58 ft Longitude: 148°44'07. 088W Radius: 300 ft .-.---- "-"---~"-'-- -- --"_..,-_.,, ~ -~,.-_._.,--_.,~ -~ --.~--,-------,.,_..,- ----.,------ ...y.----.-".,. _.- ---..----.----... _._-,--- - --_.~.~-.---'------.'- '.--,,_.,.__.-.~--_..."-,. ~~-_...._- --.---"---,-,...,-----.---.---..- "- _.__._-------"._.._--~-._--- .-,,,,-- _.__._'....-...._-.~..__. 300 200 + -500 100 o -100 -200 -300 -4-00 I , -500 -lOO ~ C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) 0 ~ ~ Ln .3- (Y) N 0 a- eD I LO / Ln Ln Ln Ln Ln Ln .3- .3- .3- .3- ~ ~ / I I I I I I I I I I ~ ~ I ~ I DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE CHECK NO. OS/28/02 H206923 ·t VENDOR DISCOUNT NET $100.00 H H 206923 OS/23/02 CK052302F ?ermit To Drill Fee ?ls call Terrie Hubble X4628 \1\5 \lp -- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. $ 100 . 00 TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAfflL,IATEOF- . NATIONAL: CITY BANK CLEVELAND, .OHIO NQ.H2.0-B923 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 '"41'2 ... 'Ie.. ** * *$400..0. Ö * * ***,!,..t;. .... - -- - -- - -- . -~ PAY 13 q t:f~T IdjJ Ø) d. ¡;;.. _ ~~ L. \ultt.m.J .'tun TO THE ORDER OF Alaska Oil &·Gas Conservation>Commission 3"33 W7th Av~, Ste 10.0·· Anchorage, AI< 99501 NOTVALlD ÁFTER 120 DAYS ...... III 2 0 b q 2 j III I: 0 ~ ~ 20 j a ., 5 I: 008 I. I. ~., ul ".-. --.- . (4~~,'cJ~~flJ RECMVED - JUHl82002 AlaSKö U .villl ""\¡¡\.oll""! cl·é· CHECK 1 ST ANDARD LETTER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\tcmplates ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME~4~,.. all /t/S-Jb CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-) SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY A P X WELL NAME ¡t}- 5" I h PROGRAM: Exp _ Dev -X. Redrll_ Serv _ Wellbore seg _ Ann. disposal para req FIELD & POOL _ \¡;Ó/ðÖ INITCLASS tJ<P. V /- all GEOLAREA ~7 é\ UNIT# //-5("')1"1 ON/OFF SHORE oIT ADMINISTRATION 1. Permittee attached. ..................... tV N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. " . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N A~P_ R º~ T~E ~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . Y N If¡r~ 6/11/02- 13. Can permit be approved before 15-day walt.. . . . . . . . . . .::v N ~ N~ uÎ" Jr;. ".~ I - WI;. ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . If' ¡o 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. . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . .. N ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Q N ¡Jilt, Ov~ 35 E. 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N-1Ii ~ 22. Adequate well bore- separation proposed.. . . . . . . . . .-. . @ N .... -:I" . 23. If diverter required, does it meet regulations . . . . . . . . .. *~y N D)" ~-y {,..Utk.-( \I £1.-y. 24. Drilling fluid program schematic & equip list adequate. . . . . . NN 25. BOPEs, do they meet regulation. . . . . .. . . . . . . . . . IA/>. d' -I- t J"/f APPR DATE 26. BOPE press rating appropriate; test to c¡. (3oD psig. ~. NN'v EA.f" (t;o:; ~ð..., '-t 00 P ~ ' WGj+- (p{loï02- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . I 28. Work will occur without operation shutdown. . . . . . . . . . . I ]i. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Ÿ(!V 30. Permit can be issued w/o hydrogen sulfide measures. . . . . m N 31. Data presented on potential overpressure zones . . . . . .. }rN " /J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /1./, /7.. I\rPR 2~"!'9 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N K J'r: q#ffOZ- 34. Contact name/phone for weekly progress reports [exploratory ° 1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for dispos I (D) will not damage producing formation or impair recovery fro a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP&'- JDH ~ COT WGA I¡JC¡/v DTS 06 { (0/0 ¿ GEOLOGY APPR DATE Q~ r;/¡t62- l l A/I/1; N N Com mentsllnstructions: G:\geology\permits\checklist.doc ') ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 infonllation, infomlation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I I I I ( I [ f)09-/ó'7- spe.....r-av-5un C RILL I N G 5 e R V I c: E 5 BP EXPLORATION ALASKA END OF WELL REPORT NORTHSTAR NS16 ( I I I I I I OCT 2>' ,,-,'" " r" ".... 1\",1' ¡. i ""~ \' I I I I T ABLE OF CONTENTS ( I 1. General Information [ 2. Daily Summary 3. Daily Operations [ 4. Show Reports 5. Morning Reports 6. BHA's ( 7. Bit Record I 8. Mud Reports 9. Survey Record ( 10. Formation Tops I 11. Formation Evaluation Logs I I I spe....l.,v- sun I CRIL.L.I N t:i SeR\lIc:es I I I ( I ( ( I I ( ( ( I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS 16 Northstar North Slope Alaska United States CD 50-029-l3U91-00 SO- 0 C19 ,- CJ3CFj'tp- AK-AM-2343361 June 28, 2002 Mareh 20, 2003 True 26.290 deg 80.944 deg 57541.969 nT Jun 21,2002 North 70 deg 29 min 28.17 see East 148 deg 41 min 38.38 see 267.80 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Jeff Smith Joe Polya Mike Dinger Ken Lemley Northstar 107 Alaska North Slope spe......l...,v- sun CRU..L.I N G seR\Jlce:s I I I ( ( I ( ( I ( ( I I I I I I I I BP Exploration - Northstar NS16 Daily Summary 06/28/02 Move rig from NS 12 to NS 16 slot. Preparing to spud. Nipple up riser. 06/29/02 Pickup BRA #1 (Bit # 1,16" MX-Cl , TFA= 1.031 ). Clean out 20" conductor. Rig up and run wireline gyro survey. Drill 16" hole to 334' MD. Trip out of the hole to pick up BHA #2. (Rerun Bit #1), with MWD. Trip back in hole and continue drilling to 1004" MD. Rigged down Gyros, Samples seen at shakers as usual for this interval (clays and gravels).. Maximum Rap in this interval was 688 ft/hr at 383' MD. No methane gas was seen on the gas chromatograph, but a maximum gas of 37 units was seen at 355' MD due to mud additives Dril-N-Slide and Torque trim present in the spud mud that was thinned for use from the mud used to drill the 8 ~" drilling interval on well NSI2. 06/30/02 Drill from 1004' to 3514' MD. Circulate bottoms up. Trip out of the hole to Run 13 3/8" casing. Maximum Rap in this interval was 627 ftlhr at 1020' MD. Maximum gas was 56 units at 2625' MD. First traces of methane gas was noted at 1165' MD. Continuous methane gas was first encountered below 1210' MD. Top of the permafrost was at 1204' MD, 1195' TVD. Base of the permafrost was 1603' MD, 1572' TVD. Top of the SV6 marker was 3311' MD, 3044' TVD. 07/01/02. Continue POOH, layed down BHA #2, Rig up to run 13 3/8" casing.. Run 68# 13 3/8" casing. Tight spots at 1696-1864 MD (2 degree dogleg @ 1700' MD) and 2836' to 3000' MD. Landed casing with no problems. Break circulation at ~ BPM, no packing off, good returns, continue circulating while staging up to 10 BPM. Currently circulating 07/02/02 Finished circulating and conditioning mud. Rig down casing tools. Rig up to cement. Circulate and condition mud. Maximum gas on bottoms up was 30 units. Pumped cement per plan. Displaced cement with rig pumps at 10 bpm.. Bumped the plug at 4874 strokes (97% efficiency). Nipple down riser, Nipple up BOP's. Test BOP's. Pick up BHA # 3 and bit #3 ( 12 'i'4" RS238HF+GS , TFA= .941 ). Trip in hole with the 12 'i'4" drilling assembly. 07/03/02 Continue to Trip in hole with 12 'i'4" drilling assembly. Drill cement, float, shoe and 20' of new hole to 3535' MD. Displaced mud system to PHPA. Performed F.I.T. to 12.5 ppg EMW. Drilled 12 'i'4" hole from 3535 to 5002' MD. Maximum gas was 122units at 4922 MD. Maximum Rap was 600 ft/hr at 4052' MD. Top of the SV5 marker was 3622' MD, 3310' TVD. Top of the SV4 marker was 3989' MD, 3622' TVD. Top of the SV2 marker was 4443' MD, 4012' TVD. Top of the SVl marker was 4886' MD, 4400' TVD. 07/04/02 Drill ahead from 5002' to 7383' MD. Hard streaks were experienced in the lower Ugnu formation, slowing us down to under RaP's of 5 Feet per hour for two hours. Maximum gas of 502 units was recorded from a coal stringer at 6142' MD. Maximum Rap was 557 ft/hr at 6354' MD. Top of the Ugnu formation was 5287' MD, 4758' TVD. Schrader Bluff formation was 7073' MD, 6323' TVD 07/05/02 Drill from 7383' to 8817', serviced draw works, Continue to drill to 9300' MD. Began weighting up mud to 10 PPG while drilling on. At 9420' a large piece of rubber blade from a stabilizer was found over the shakers. POOH enough to find damaged stablilizer, replaced the same and ran back into the hole and continued to drill on to 9438' MD. Maximum gas was 610 units at 9315' MD, Maximum Rap was 294 ftIhr at 9254' MD. Top of the Collville marker was 7683' MD, 6891' TVD. I I r ( I I ( I I I I I I I I I I I BP Exploration - Northstar NS16 Daily Summary 07/06/02 Continue drilling 12 'i'4" hole from 9438' to TD at 10460' MD, 9316 TVD. Maximum gas in this drilling interval was 3491' units at 10,022' MD from the base of the Kuparuk C formation. Maximum Rap was 366 ftIhr at 10080' MD. . Top of the HRZ formation was 9634' MD, 8604' TVD. Base of the HRZ formation was 9740' MD, 8694' TVD. Top of the Kuparuk formation was at 9788' MD, 8736' TVD. Top of the Kuparuk "c" formation was at 10030' MD, 8943' TVD, Miluveach 10396' MD, 9260' TVD. 07/07/02 Continue pumping out of hole f/ 4600' md to 13-3/8" csg shoe @3494' md. Increased pump rate back to 840 gpm while pumping out of the hole to 13-3/8" casing shoe @ 3494' md. Lost ----200 bbls of mud and cuttings over the shakers. Clay balls ranging in size of tennis balls across the shakers. Circulate hi-vis sweep and clean hole. Clay balls the size of footballs unloading from the hole. Slip and Cut Drill Line. Service Top Drive and Lubricate Rig. RIH and wash last stand down -- 2-3' offill. Stacked up at 10030' in the Kuparuk with lOOK -- total string wt was 200k. Worked pipe thru with 3 attempts. Stacked up at 10397' (to of Miluveach). 5 attempts to work pipe thru --unsuccessful. MU Top Drive and circulate down with 100 spm - acted like tight hole, not necessary to rotate -- 2 to 3 feet of fill. Circ and Cond drilling fluid for running casing. Pumped hi-vis sweep -- no noticeable increase in returns with sweep to surface. Increase cuttings at 1.5x bu -- circ until shakers cleaned up at 2.5x bu. Monitor well-- static. Check for swab. POOH to run 9-5/8" casing'. LD 2 singles and stand back stand #1(99) -- no problems. Attempted to POOH with stand #2(98) -- 100K overpull @ 10310' md with top stabilizer at base of Kuparuk sand package at ---- 10135' md. Worked pipe to attempt to pull through with 125K overpull --unsuccessful. Assume top stabilizer hanging up @ base of sand package noted above. Discussion with rig team -- MU top drive, engage pumps and rotate thru tight spot with 60 spm and 60 rpm. Hung up again at 10250' md which correlates with top stab at base of another Kuparuk Sand package @ ---- 10100' md -- backream thru this with same parameters as above. Shut down pumps and rotary at top of stand, run stand back in hole with no problem with evidence of bobbles at 10250' and 10310' md. PU with no pump or rotary and evidence of 50K overpull at these respective depth which again correlate to top stabilizer going thru sand packages at 10135' and 10100' md respectively. Lay Down BHA. Scraped off 1/2 of 5 gal bucket of clay off the stabs -- pretty clean. Bit was in pretty good shape 2-1-WT-N-X-I-BT-TD. However, there the nose cutters were worn 4 and signs of rung pattern developing which was suspected while drilling one or two of the stubborn hard streaks in the lower Ugnu. RSS tool looked to be in good shape. 07/08/02 Pull Wear Ring and Run Test Plug. Wear ring has groove worn in wear pad -- due to slanted conductor and rotating tool joints wearing in one spot. Not useable for another well. Change top set of pipe rams to 9- 5/8". Necessary to remove mousehole to reposition bridge crane. Close annular and test ram doors to 3500 psig for 5 min -- chart. Bleed pressure, pull test plug and LD test joint. Clean rig floor and pull iron rough neck tracks. PJSM -- RU to run 251 joints of 9-5/8" 47# L80 Mod-Btrc Intermediate Casing. LD 5" elevators, bales, PU Franks Casing Tool and RU Casing Tools. Run 85 joints of 9-5/8" casing to 13-3/8" surface casing shoe. Circulate one casing volume -- rig crews perform tour change. Finish RIH with 251 total joints of 251 joints of9-5/8" 47# L80 Mod-Btrc Casing. Entire casing run went well with no problems -- hole was in excellent shape. MU mandrel casing hanger, landing joint, pull spiders and master bushings and land mandrel casing hanger. Pulled landing joint over toward NE with cat head chain and lowered landed mandrel hanger without a glitsch -- did not hang up on any ram cavities. Lay down Franks Casing Tool. Rig up cement head. Break circulation and step rate up to 12 bpm. Circulate excess of one casing volume to allow for crew change. Maximum gas 2550 units at 4000 strokes. 07/09/02 Pump cement job as per well plan. Displace cement with rig pumps. Plug bumped at 7431 strokes. A trace of cement was noted at surface. Rig down cement head and casing handling equipment. Set pack off I I r I I I I I ( I ( I I I I I I I I BP Exploration - Northstar NS16 Daily Summary and inject 230 bbls down annulus. Test BOP's. Pick up 8.5" drilling assembly and MWD. ( Bit #3 8 'l';" Hycalog DS70FN+PV, TFA= .9070). Trip in hole with 8 'l';" drilling assembly. 07/10/02 Drill out float collar and test casing. Drill through float equipment, 9 5/8" casing shoe and 20 feet of new hole to 10480' MD. Increase mud weight to 12.0 ppg. Perform Formation Integrity Test to 14.0 ppg EMW. Begin drilling new 8 'l';" hole from 10480' to 11249' MD. Average Rap was 90 ft/hr with drilling parameters ofWOB 24 klbs, 2800 psi Standpipe pressure and 100 RPM. Top of the Kingak formation was 10976' MD, 9779' TVD. Maximum gas in this daily interval was 375 units at 10466' MD. Maximum Rap in this interval was 257 ftIhr at 11171' MD. 07/11/02 Drilled 8 ~"hole from 11249' Md to the 8 ~"hole section Total Depth of 12105' MD, 10843' TVD. Circulated bottoms up and pumped a Hi viscosity Barafiber sweep. Hole cleaned up . Performed a wiper trip to the 9 5/8" casing shoe. Trip back in the hole to bottom and 10 feet of fill was noted. Circulated the hole clean. Maximum short trip gas was 131 units. Very little sloughing Kingak shale was seen on bottoms up after the wiper trip. Spot a 100 bbl Baratrol pill in the open hole. Trip out of hole for the 7" drilling liner. Top of the Sag River formation was 12064' MD, 10803' TVD. Maximum gas in this daily drilling interval was 305 units at 12105' MD. Maximum Rap was 156 ftlhr at 11652' MD. Bit #3 statistics = 1645 feet, 21.6 hours and 263K revolutions. 07/12/02 Pulled out of the hole to the 95/8" casing shoe and circulated slowly at 35 strokes per minute while waiting on weather for the 7" drilling liner hanger assembly. Trip in hole to bottom at 12105' MD. 6 feet of fill was noted on bottom. Circulated the hole clean with a maximum of 265 units of trip gas. Pumped a 25 bbl Hi viscosity sweep and circulate bottoms up. Hole cleaned up well. Trip out of the hole to the 9 5/8" casing shoe, no overpulls. Pumped a slug and continued tripping out of the hole to surface to run 7" drilling liner. 03/18/03 Trip in hole to top of 7" drilling liner. Wash and ream to 11967' MD. Displace seawater with 9.1 ppg Dril-In fluid mud. Drill float equipment, shoe and 20' of new formation to 12125' MD. Perform Formation Integrity test to 11.5 ppg Equivalent Mud weight. Drill 6 1/8" hole from 12125" to 12424' MD T.D. ( 11156' TVD). Increase mud weight to 9.3 ppg. Circulate 4 hole volumes. Perform MAD Pass with Anadrill to 7" liner shoe. Top of the Shublik formation at 12162' MD, 10898' TVD. Top of the Ivishak formation at 12258' MD, 10992' TVD. Maximum gas for the 6 1/8" production interval was 1120 units at 12108' MD. Bit #4 was a 6 1/8" XR30YD20DGPD, with a TFA of 0.5180. Bit #4 statistics= 319 feet, 23.6 hours, 169 K revolutions. 03/19/03 Complete MAD Pass to 7" drilling liner shoe. Circulate hole clean- More Ivishak formation was seen at shakers. Trip out of hole. Rig up to run 4 'l';" production liner. Begin running production liner on drill pIpe.. 03/20/03 Continue running 4 ~" production liner to 7" drilling liner shoe. Circulate bottoms up. Maximum gas from circulation was 105 units. Continue running 4 ~"liner and land at 12397' MD. Circulate bottoms up. Maximum gas was 91 units. Cement as per plan. Bump plug and back out with running tool, circulate out excess cement. Maximum gas 42 units. Pressure test casing and cement job. Rig up to displace mud with seawater. Complete Gyro survey's and rig down sheaves. Dir drill 16" hole from 1004 to 2336'. Pumps 850 gpm, WOB 30K, Rotary 35 rpm. Dir drill 16" hole from 2336 to 3514'. Casing Point. Pumps 850 gpm, 12:00-22:00 10.00 00:00-01:00 1.00 01:00-12:00 11.00 06/30/02 Drilling and sliding to TD 3514'. Pump sweep, circulate hole clean, POOH at report time. TOP OF PERMAFROST 1204' MD, 1195' TVD BASE PERMAFROST 1603' MD, 1572' TVD SV6 3311' MD, 3044' TVD Complete rig up and sign off Nabors pre-spud check list. PJSM. Accept rig at 0400 hrs. 6/29/2002. Rig up drilling riser. Fill riser with seawater and repair leak. PJSM. Pick up 1.83 deg bent housing with GYro orientation collar. Make up bit #1, new Hughes MX-Cl. Hold pre-spud safety meeting. Clean up spill in cellar. See remarks. Spud well and clean out conductor. Drill 16" hole to 334' with Gyro survey's. Bottom of conductor at 2.39 deg at 275.77 azimuth. Spud well at 1200 hrs. 06/29/2002. POOH with BHA #1 to pick up MWD. Pick up BHA #2 with MWD, and orientation collar. Dir drill 16" hole from 334 to 389'. Run gyro survey. Dir drill 16" hole from 389 to 1007'. Pumps 660 gpm, rotary 35 rpm, WOB 15-25K, On btm 550 psi, Offbtm 500 psi. 14:00-14:30 0.50 14:30-18:30 4.00 18:30-19:00 0.50 19:00-19:30 0.50 19:30-00:00 4.50 00:00-03 :30 3.50 03:30-04:00 0.50 04:00-06:30 2.50 06:30-07:30 1.00 07:30-08:00 0.50 08:00-10:00 2.00 10:00-11 :00 1.00 11 :00-12:00 1.00 12:00...14:00 2.00 06/29/02 Finish berming rig - nippled up riser. Picked up BHA #1 and drilled to 336' MD. POOH, Picked Up BRA #2 , Run Back in hole and drilled to 1004' MD. No Formations at report time. Release rig from NS 12 at 1500 hrs. Prepare to move rig. P JSM. Complete unit permit. Move rig to NSI6. Move went well. Lock out wells under sub during move. Level rig. Make up connections between sub and service unit. Berm around rig and rig up disposal line. 22:00-22:30 0.50 22:30-00:00 1.50 15:00-19:30 4.50 19:30-20:00 0.50 20:00-22:00 2.00 06/28/02 Move rig to NS-16, Prep to Spud:. Operations Breakdown Elapsed Time DP Exploration - Northstar NS16 Daily Operations (I.A.D.C) Time (hrs) I I I I ( II ( I I I ( , I I I I I I I I f I ( ( I ( I ( I I I I I I I I I ,I 22:00-23:30 1.50 WOB 25 to 35K, Rotary 35 rpm. SWU 175K. SWD 150K, SWR 160K. NBP 2000 psi. OFFBP 1850 psi. Top of SV 3312' md. Pump 75 bbl Hi-Vis sweep and circulate clean. Moderate amount of cuttings on bottoms up. Circulate 2 bottoms up. POOH with BHA #2 to run surface casing. 23 :30-00:00 0.50 07/01/02 Continue POOH, Lay Down BHA #2, Rig Up casing tools, Run 13 3/8" casing, landed with no problem Rig up cement head, Break circulation at 1/2 bpm, no packing off, Staged up to 10 bpm, currently circulating at report time. TO was 30 units. 00:00-02:30 2.50 Flow check and pump dry job. Pooh with bha #2. Intermittent tight spots requiring overpull up to 25K. Work through and would not see on second pass up. Hole looks good to run casing and did not swab. Lay down dir bha. Bit grade 1-1-WT-A-E-No-TD. Stabs and bit were balled up. Clean up rig floor. P JSM prior to rig up casing equipment. Install long bails and rig up Franks tool to run casing. Make up shoe track and thread lock. Check floats. Run total of 85 jts, 13-3/8", 681b, BTC, L-80 casing and make up Vetco casing hanger. Land hanger without pumps, and did not see any fill. PUW prior to landing 325K, SOW 125K. Increased drag of approx 25 to 40K iTom 1696 to 1864' and 2836 to 3000'. Rig up cement head. Break circulation and stage up rate to 10 bpm. Role cleaned up good with no losses. 02:30-05:00 2.50 05 :00-06:00 1.00 06:00-06:30 0.50 06:30-09:00 2.50 09:00-21 :00 12.00 21 :00-22:00 1.00 22:00-00:00 2.00 07/02/02 Finish circulating and conditioning mud, pump cement according to well plan, displaced cement with ig pump, @ 95 spm, bumped plug at 4874 strokes, rig down cement head, nipple down riser, nipple up BOP's tested BOP's, Good, Picking up BRA #3 00:00-00:30 0.50 00:30-03:00 2.50 Circulate and pump 75 bbls mud spacer. PJSM prior to cementing. Cement with Halliburton. Pump 5 bbls water. Pressure test to 3500 psi. Held ok. Pump 75 bbls Alpha spacer at 10.3 ppg. Drop bottom plug and pump 453 bbls (618 sacks) lead at 10.7 ppg and tail with 97 bbls (470 sacks) tail at 15.8 ppg. Drop top plug and pump 25 bbls sea water. Switch to mud pump and displace with 496 bbls (4874 strokes) at 95% efficiency at 9 bpm. Slow rate to 3 bpm and bump plug 500 psi over for 2 min. Bleed off pressure. Floats held. Had 600 psi lift prior to bumping plug. No losses. Flush riser and lay down cement head. Clean up floor. Back off landing joint and lay down. PJSM. Nipple down riser. P JSM and nipple up BOP's. Pick up test joint and make up test plug. Pressure test annular to 250/3500 psi for 5 min. Test all rams, stack valves, choke manifold and satèty valves to 250/4800 psi. Held ok. Pull test plug. Install wear bushing. Blow down choke manifold and lines. Rig service, grease top drive, crown sheaves, draw works. 03:00-04:00 1.00 04:00-05:00 1.00 05:00-07:00 2.00 07:00-07:30 0.50 07:30-09:00 1.50 09:00-16:00 7.00 16:00-16:30 0.50 16:30-21 :00 4.50 21 :00-21 :30 0.50 21 :30-22:00 0.50 I I I ( I I I ( I ( ( ( I I I I I I I 22:00-00:00 2.00 PJSM. Pick up BHA #3 (rotary steerable). 07/03/02 Rill with BHA#3, washed down to 3409' - test casing for 30 minutes, OK. Displace old mud with new mud, drilled out shoe, rat hole and 20' of new fOnTIation. Perfonn FIT test to 12.5 PPG. Drilled 3535' to 4300', Flow line plugged, shut down to clear line, continue to drill to 5002' MD. Fonnation Tops SV5 3622' MD, 3310' TVD, SV 4 3989' MD, 3622' TVD. SV2 4443' MD, 4012' TVD, SVl 4886' MD, 4400' TVD 00: 00-04: 00 4.00 04:00-04: 15 0.25 04:15-05:00 0.75 05:00-07:30 2.50 07:30-08:00 0.50 08:00-09:00 1.00 09:00-16:00 7.00 Surface test bias sub for rotary steerable and mwd. Rill to 3381 '. Wash to 3405'. Tagged cement at 3395'. P JSM - Casing and FIT test. Pressure test casing to 3500psi with 9.1ppg mud for 30 minutes. Note: Review D 1, D2, and D5 well control procedures. Drill out shoe track while displacing to new mud. Clean out rat hole and drill to 3534' -- 20' of new formation. FIT to 660 psi with 8.7ppg mud, EMW 12.67 ppg. Blowout kill line. Drill from 3534-4300' md with RSS tool. Notes: 1. RSS tool responding to down links. 2. Conducted D2 drill with crew. Flowline plugged with Clay and overflowedCirculated up mud ring and plugged flow line. Spilled 4 bbl of drilling fluid. Drill from 4300-4997' with RSS tool. Notes: 1. RSS tool responding to down links. 2. Intermittent episodes of bit balling. Pumped walnut hull sweeps as required to clean up, adding SAP at connections and sand sequences also assisting in cleaning bit. 16:00-18:00 2.00 18:00-00:00 6.00 07/04/02 Drilling ftom 5002' MD through 7383' MD. Periodic hard streaks were experienced around 6967" MD Schrader Bluff 7073' MD, 6323' TVD 00:00-00:00 24.00 Drill f/ 4997' - 7375' md with RSS Tool. Notes: 1. Tool responding to down links. 2. Drilled several hard streaks in Ugnu, most notable 6966'-6972' (2-4 fph) 3. Pumped walnut hull sweeps at 500' intervals. 4. Put non rotating stabilizer in string while drilling at 7295' to reduce stick slip and surface vibration. Stabilizer buried one stand (string depth 7180'). Noted immediate response -- reduction in both surface vibration and stick/slip. 5. Added 4 bbls ofEP Lube at 7295' to reduce torque and stick slip. Torque dropped approx. 2000 ft.lb and stick slip dropped from approx. 150 to 70 rpm. Lubricant concentration in system approximately 1.5%. 07/05/02 Drilling from 7383 to 8817. Serviced draw works. Cont to drill to 9300' MD, begin weighting up mud to 10 PPG. At 9420' MD a large piece of rubber from a sabilizer was found on the shakers. POOH, replaced damaged stabilizer, Rill, and drilling on. Colville 7683' MD, 6891' TVD HRZ 9634' MD, 8604' TVD I I ( ( ( ( I ( I I I I I I I I I I I 00:00-14:00 14.00 Drill f/ 7380' - 8817' rod with RSS Tool. Notes: 1. Tool responding to down links. 2. Adding non rotating stabilizers every 7 stands. 3. Maximum stick slip 70 rpm. 4. Pumping walnut sweeps every 500'. Service Top Drive and draw works. Drill f/ 8817' - 9523' md with RSS Tool. Notes: 1. Same as above notes 1 -- 4. 2. Weight up mud system for HRZ (9.8ppg) and Kuparuk (lO.lppg). Recovered blade from non rotating stabilizer at shakers. Blade had sheared off of sleeve. Pull 8 stands of pipe. Layout damaged stabilizer, remainder of sleeve still intact. Replace stabilizer and Rill. Drill f/ 9523' - 9535' md. Notes: 1. Tool responding to down links. 2. Changed spacing on last 2 non rotating stailizers to 1000'. 3. No walnut sweeps last 1000' due to weight up. 14:00-14:30 0.50 14:30-21:30 7.00 21 :30-23:30 2.00 23 :30-00:00 0.50 07/06/02 Continue drilling F/ 9438' to TD of 12 1/4" section at 10460'. Pump sweep, not productive, try circulate hole clean, POOH 10 stands. Slug pipe. POOH to 7850', begin pumping out. Currently at 4850' Abundantly large pieces coming over the shakers. Base HRZ 9740' MD, 8694' TVD, Kuparuk 9788' MD, 8736' TVD, Kuparuk C 10030' MD, 8943' TVD, Miluveach 10396' MD, 9260' TVD 00:00-02:30 2.50 Continue pumping out of hole f/4600' md to 13-3/8" csg shoe @3494' md. Notes: 1. Increased pump rate back to 840 gpm while pumping out of the hole to 13-3/8" casing shoe @ 3494' md. 2. Lost ......200 bbls of mud and cuttings over the shakers. 3. Clay balls ranging in size of tennis balls across the shakers. Circulate hi-vis sweep and clean hole. Note: Clay balls the size of footballs unloading from the hole. Slip and Cut Drill Line. Service Top Drive and Lubricate Rig. Rill and wash last stand down -- 2-3' of fill. Notes: 1. Stacked up at 10030' in the Kuparuk with lOOK -- total string wt \vas 200k. Worked pipe thru with 3 attempts. 2. Stacked up at 10397' (to ofMiluveach). 5 attempts to work pipe thru -- unsuccessful. MU Top Drive and circulate down with 100 spm -- acted like tight hole, not necessary to rotate -- 2 to 3 feet of fill. Circ and Cond drilling fluid for running casing. Note: 1. Pumped hi-vis sweep -- no noticeable increase in returns with sweep to surface. 2. Increase cuttings at 1.5x bu -- circ until shakers cleaned up at 2.5x bu. Monitor well -- static. Check for swab. 02:30-04:00 1.50 04:00-05 :00 1.00 05 :00-06:00 1.00 06:00-10:00 4.00 10:00-13:00 3.00 13:00-13:30 0.50 I I I I I I I I ( I ( ( I I I I I I I 13 :30-21 :30 8.00 POOH to run 9-5/8" casing'. Notes: 1. LD 2 singles and stand back stand #1(99) -- no problems. 2. Attempted to POOH with stand #2(98) -- lOOK overpull @ 10310' md INTI DRILL POH P with top stabilizer at base of Kuparuk sand package at -10135' md. Worked pipe to attempt to pull through with 125K overpull -- unsuccessful. Assume top stabilizer hanging up @ base of sand package noted above. Discussion with rig team -- MU top drive, engage pumps and rotate thru tight spot with 60 spm and 60 rpm. Hung up again at 10250' md which correlates with top stab at base of another Kuparuk Sand package @ -10100' md -- backream thru this with same parameters as above. Shut down pumps and rotary at top of stand, run stand back in hole with no problem with evidence of bobbles at 10250' and 10310' md. PU with no pump or rotary and evidence of 50K overpull at these respective depth which again correlate to top stabilizer going thru sand packages at 10135' and 10100' md respectively. Lay Down BRA. Notes: 1. Scraped off 1/2 of 5 gal bucket of clay off the stabs -- pretty clean. 2. Bit was in pretty good shape 2-1-WT-N-X-I-BT-TD. However, there the nose cutters were worn 4 and signs of rung pattern developing which was suspected while drilling one or two of the stubborn hard streaks in the lower U gnu. 3. RSS tool looked to be in good shape. 21 :30-00:00 2.50 07/07/02 Cont to POOH to the shoe 3549' MD, Shoe packed off, established circulation, Huge quantities of large clay balls (2 to 5 lbs ea) and cuttings passing over the shakers. Packed off possum belly and drag chain. Cleaned up and ran back to bottom. Circulated bottoms up, mud level fluctuation within the possum belly prevented a good reading of trip gas. 979 units was the max that was captured. Circulated 2 Bottoms up. POOH, washed and reamed our way out out from 10323' MD to 10050' MD, currently laying down BRA #3. 00:00-02:30 2.50 Continue pumping out of hole f/ 4600' rod to 13-3/8" csg shoe @3494' md. Notes: 1. Increased pump rate back to 840 gpm while pumping out of the hole to 13-3/8" casing shoe @ 3494' md. 2. Lost -200 bbls of mud and cuttings over the shakers. 3. Clay balls ranging in size of tennis balls across the shakers. Circulate hi-vis sweep and clean hole. Note: Clay balls the size of footballs unloading from the hole. Slip and Cut Drill Line. Service Top Drive and Lubricate Rig. Rill and wash last stand down -- 2-3' of fill. Notes: 1. Stacked up at 10030' in the Kuparuk \vith lOOK -- total string \vt was 200k. Worked pipe thru with 3 attempts. 2. Stacked up at 10397' (to of Miluveach). 5 attempts to work pipe thru -- unsuccessful. MU Top Drive and circulate down with 100 spm -- acted like tight hole, not necessary to rotate -- 2 to 3 feet of fill. 02:30-04:00 1.50 04:00-05 :00 1.00 05:00-06:00 1.00 06:00-10:00 4.00 I I ( ( ( ( [ I ( ( I I I I I I I I I 10:00-13 :00 3.00 Circ and Cond drilling fluid for funning casing. Note: 1. Pumped hi-vis sweep -- no noticeable increase in returns with sweep to surface. 2. Increase cuttings at 1.5x bu -- circ until shakers cleaned up at 2.5x bu. Monitor well -- static. Check for swab. POOH to run 9-5/8" casing'. Notes: 1. LD 2 singles and stand back stand #1 (99) -- no problems. 2. Attempted to POOH with stand #2(98) -- lOOK overpull @ 10310' md with top stabilizer at base of Kuparuk sand package at -10135' md. Worked pipe to attempt to pull through with 125K overpull -- unsuccessful. Assume top stabilizer hanging up @ base of sand package noted above. Discussion with rig team -- MU top drive, engage pumps and rotate thru tight spot with 60 spm and 60 rpm. Hung up again at 10250' md which correlates with top stab at base of another Kuparuk Sand package @ -10100' md -- backream thru this with same parameters as above. Shut down pumps and rotary at top of stand, run stand back in hole with no problem with evidence of bobbles at 10250' and 10310' md. PU with no pump or rotary and evidence of 50K overpull at these respective depth which again correlate to top stabilizer going thru sand packages at 10135' and 10100' md respectively. Lay Down BRA. Notes: 1. Scraped off 1/2 of 5 gal bucket of clay off the stabs -- pretty clean. 2. Bit was in pretty good shape 2-1-WT-N-X-I-BT-TD. However, there the nose cutters were worn 4 and signs of rung pattern developing which was suspected while drilling one or two of the stubborn hard streaks in the lower U gnu. 3. RSS tool looked to be in good shape. 13 :00-13 :30 0.50 13 :30-21 :30 8.00 21 :30-00:00 2.50 07/08/02 Rill with 9.625" casing. No problems. Gradually established circulation up to 12 BPM. Circulated two casing volumes with 2580 units ofmax gas. Lay down casing tools. Rig up cement equipment. Currently preping to cement 9.625" casing. 00:00-01:15 1.25 Pull Wear Ring and Run Test Plug. Note: Wear ring has groove worn in wear pad -- due to slanted conductor and rotating tool joints wearing in one spot. Not useable for another well. Change top set of pipe rams to 9-5/8". Note: Necessary to remove mousehole to reposition bridge crane. 02:30- 03:00 Close annular and test ram doors to 3500 psig for 5 min -- chart. Bleed pressure, pull test plug and LD test joint. Clean rig floor and pull iron rough neck tracks. PJSM -- RU to run 251 joints of9-5/8" 47# L80 Mod-Btrc Intermediate Casing. Notes: LD 5" elevators, bales, PU Franks Casing Tool and RU Casing Tools. Run 85 joints of 9-5/8" casing to 13-3/8" surface casing shoe. Circulate one casing volume -- rig crews perform tour change. 01:15-02:30 1.25 02:30-03:00 0.50 03:00-03:30 0.50 03 :30-06:00 2.50 06:00-11:30 5.50 11:30-12:00 0.50 I I I I ( ( ( I ( I I I I I I I I I I 12:00-19:30 7.50 Finish RIH with 251 total joints of 251 joints of 9-5/8" 47# L80 Mod-Btrc Casing. Note: Entire casing run went well with no problems -- hole was in excellent shape. MU mandrel casing hanger, landing joint, pull spiders and master bushings and land mandrel casing hanger. Note: Pulled landing joint over toward NE \-vith cat head chain and lowered landed mandrel hanger without a glitsch -- did not hang up on any ram cavities. Lay down Franks Casing Tool. Rig up cement head. Break circulation and step rate up to 12 bpm. Circulate excess of one casing volume to allow for crew change. Maximum gas 2550 units at 4000 strokes. 19:30-20:30 1.00 20:30-21: 15 0.75 21:15-00:00 2.75 07/09/02 Complete cement job - displace cement with rig pumps, bumped plug at 7431 stks, trace of cement to surface. Rig down cement head and casing equipment, set pack off, inject 230 bbls down annulus. Test BOP's, Picked up 8.5 BRA, Rlli. 00:00-00:30 0.50 00:30-02:30 2.00 02:30-03:45 1.25 03:45-05:30 1.75 05:30-07:00 1.50 07 :00-09:00 2.00 Complete circulating @ 12 BPM in preparation for cement job. PJSM for cementing. Test lines to 4000 psi. Pump 50 bbls of 11.0 ppg weighted spacer, 317 bbls of 11.2 ppg lead cement followed by 127 bbls 15.9 ppg tail cement. Displace cement w/ rig pump & bump plug w/ 7431 strokes 94.5 % pump efficiency with both rig pumps and Howco flow meter. LID cement head & x-over. Remove elevators & clean floor. LID landing jt. Flush stack, install pack-off & test to 5000 psi, R/U to pump down annulus. P PJSM - Remove 9 5/8" ram blocks & install 4 1/2" X 7" variables. Start pumping down 13 3/8" x 9 5/8" annulus @ 1/2 BPM. Note: Broke down at 1000 psi - final pressure 800 psi. 230 bbls of mud pumped to chase annulus. LID casing running equipment & change bails. RU to test BOPE. Notes: 1. Finish mixing spike fluid for weight up. 2. Cleaning L pits. 3. Changing pump liners to 5 -1 /2" . 4. Welding landing ring on NS 18 conductor in sub. Finish R/U to test BOPs - P JSM Test BOPE to 250 psi/4800 psi -- 5 minutes per test. Blow down kill line. Notes: 1. Function tested panel in pipeshed. 2. Chuck Sheave with AOGCC waived witness ofBOPE Test @ 1500 hrs on 7/8/02. 3. Welder replaced Door in Derrick. 4. Finish welding landing ring on NS 18 conductor in sub. Pull test plug, install bowl protector, & LID test jt. Lubricate rig. PJSM on PIU BRA. P/U BRA # 4 - shallow test MWD. 09:00-12:00 3.00 12:00-13:30 1.50 13 :30-19:30 6.00 19:30-20:30 1.00 20:30-21 :00 0.50 21 :00-21 :30 0.50 21 :30-00:00 2.50 I I I ( ( ( [ ( I I ( ( I I I I I I I 07/10/02 7-10-02 Drill to float collar. Tested casing, Passed. Drill thru float equipment and cen1ent. Brought mud weight up to 12.0 ppg. Run FIT to 14 PPG. Drilling 8.5" hole. Kingak @ 10976' MD, 9779' TVD .00:00-00:30 0.50 00:30-02:30 2.00 02:30-03:45 1.25 03 :45-05 :30 1.75 05:30-07:00 1.50 07:00-09:00 2.00 Complete circulating @, 12 BPM in preparation for cement job. PJS~1 for cementing. Test lines to 4000 psi. Pump 50 bbls of 11.0 ppg weighted spacer, 31 7 bbls of 11.2 ppg lead cement followed by 127 bbls 15.9 ppg tail cement. Displace cement w/ rig pump & bump plug w/ 7431 strokes 94.5 % pump efficiency with both rig pumps and Howco flow meter. LID cement head & x-over. Remove elevators & clean floor. LID landing jt. Flush stack, install pack-off & test to 5000 psi, R/U to pump down annulus. PJSM - Remove 9 5/8" ram blocks & install 4 1/2" X 7" variables. Start pumping down 13 3/8" x 9 5/8" annulus @ 1/2 BPM. Note: Broke down at 1000 psi - final pressure 800 psi. 230 bbls of mud pumped to chase annulus. LID casing running equipment & change bails. RU to test BOPE. Notes: 1. Finish mixing spike fluid for weight up. 2. Cleaning L pits. 3. Changing pump liners to 5-1/2". 4. Welding landing ring on NS18 conductor in sub. Finish RJU to test BOPs - PJSM Test BOPE to 250 psi/4800 psi -- 5 minutes per test. Blow down kill line. Notes: 1. Function tested panel in pipeshed. 2. Chuck Sheave with AOGCC waived witness ofBOPE Test@ 1500 hrs on 7/8/02. 3. Welder replaced Door in Derrick. 4. Finish welding landing ring on NS 18 conductor in sub. Pull test plug, install bowl protector, & LID test jt. Lubricate rig. PJSM on PIU BHA. P IU BHA # 4 - shallow test MWD. 09:00-12:00 3.00 12:00-13:30 1.50 13:30-19:30 6.00 19:30-20:30 1.00 20:30-21 :00 0.50 21 :00-21 :30 0.50 21 :30-00:00 2.50 07/11/02 Drilled to 12105' MD, 10843' TVD. Pumped Hi Vis Barafiber sweep. Hole clean. Wiper trip to shoe. RIH. 10' fill reported on bottom. Circ. hole clean. Short trip gas 131 units max. Very little sloughing Kingak shale. Spot 100 bbl. Barotrol pill in open hole. POOH for 7" liner. Sag River @ 12064' MD, 10803' TVD 00:00-12:00 12.00 Drill from 11267' - 12010' md. Notes: 1. One slide from 11361' to 11395' md. 2. Pump sweeps approx. every 400'. Drill from 12010' - 12105' md. Note: Top of Sag @ 12064' md / 10803' tvdrkb. 12:00-13:30 1.50 I I I ( I ( ( ( I I ( I I I I 13:30-15:00 1.50 15 :00-16:45 1.75 16:45-17:30 0.75 17:30-18:30 1.00 18:30-20:30 2.00 20:30-22:30 2.00 Circulate high vis barofibre sweep wi minimal cuttings seen at shakers. ~lonitor well & wiper trip back to 9 5/8" shoe. Trip to shoe was good with maximum drag of 25K. Monitor well & service top drive. Rill from shoe back to bottom. Tag fill @ 12086 -- (19' offill). Circulate B/U wi minimal cuttings seen @ shakers. Spot 100 bbl. baratrol pill in open hole in preparation for 7" liner. Monitor well. Drop ESS & POH to shoe. Notes: 1) First 10 stands off bottom with drags of 15K to 20K. 2) Dry wiped 3 tight spots one time only @ 11795', 11480' & 11077'. Went back through & pulled back up with no problems. 3) Last 8 stands to shoe were problem free with 10K or less of drag. P JSM - Cut & slip drilling line. 22:30-00:00 1.50 07/12/02 Pulled to shoe and circulated slowly while wating on liner hanger. Rill to bottom @ 12105'. 6' offill on bottom. Circ. hole with 265 units trip gas. Pump 25 bbl hi vis 14.5 ppg sweep. Hole cleaned up well. POOH to shoe. Pumped slug. Cont. POOH to run 7" liner. 00:00-10:30 10.50 Waiting on weather to clear to fly liner/hanger/packer assy, insert landing collar and cement head from West Dock to Northstar Island. Notes: 1) Circulate 35 SPM with bit position 15' below 9 5/8" shoe to prevent any excessive wear on bit, motor or casing. 2) No losses while circulating 35 SPM @ shoe. 3) Performed rig maintenance. 4) Completed yearly boiler inspection -- fired up boilers. 5) First chopper arrived with cement head and insert landing collar -- hold PJSM for RIH while waiting for arrival ofC2 Flex Lock Liner/hanger/packer. Clean ice from derrick & top drive. Notes: 1. Considerable ice formed in derrick from ice fog. 2.·All equipment for running C2 Flex Lock liner hanger assy on location. Perform another wiper trip into openhole section to verify stability of the Jurassic Shales (Miluveach and Kingak). Notes: 1. No problems tripping in hole -- hole in excellent shape. 2. Approximately 10' of fill -- this would have provided 31' of rat hole in the Sag if this would have been a liner run. 3. Establish circulation and carefully ream to bottom to prevent packoff. 4. Witness increase in torque and stand pipe pressure while reaming to bottom. Difficult to detennine ifhole trying to packoff around bit and motor or if we are seeing differential from PDC bit and motor biting into the shale fill -- Conclude differential from motor since no reduction in flowrate and no evidence of ECD increase on PWD to increase fill trying to packoff around upper stabilizer. 5. Narrow VFR window in weather and the HRD liner hanger packer assembly arrived at island at about the time the bit tagged up on fill. Establish circulation, clean out fill, pump sweep, & circulate BIU. Spot Baratroll Baranex pill in open hole. 10:30-11 :00 0.50 11 :00-12:00 1.00 12:00-15:00 3.00 I I ( I ( ( I ( I ( ( I ( I I I I I I 12:00-15 :00 3.00 Notes: 1. Questioned Sperry about possible damage to ESS ifrotate 80 rpm and pump 12 bpm -- thought not to be a problem but not absolutely sure. Returns at shakers were very much a repeat of the same bottoms up for the previous wiper trip. a) Small ground up cuttings at bottoms up. b) Followed by dark flakes of Kingak shale between bottoms up and the hi-vis weighted sweep. c) Sweep brought much of the same with more concentration. d) Hole cleaned while circulating Baranex/Baratrol conditioned pill into openhole, again similar to previous circ POOH and running liner. e) Sperry and Baroid caught samples for borehole stability report. Monitor well- POH to 10' below shoe @ 10444'. Notes: 1) Trip back to shoe was about the same as the last trip wi 20 to 25K of drag. 2) Hole in good shape for running liner. Pump dry job & drop 2 1/2" rabbit. POH to BHA & stand back HWDP. LID BRA. Notes: 1) Did not get good information from ESS to confirm MWD surveys for Jorps -- ESS was dropped on first attempt to POOH to run liner. a) Batteries damaged - possibly from pumping operations once we ran back to bottom & circulated. b) Battery damage most likely occurred after information was down loaded into tool, but could be an indicator of other reasons why tool failed. c) Suspect Information from ESS - Ine1157 deg, Az 56 deg. Clear & clean rig floor. 15:00-17:00 2.00 17:00-17:30 0.50 17:30-22:00 4.50 22:00-23:30 1.50 23:30-00:00 0.50 03/16/03 07:00-12:00 5.00 PJSM for Rig Move from NS12 to NSI6. - Move rig from NS12 to NSI6. - Operations SI and bringing on wells as the rig passes over them. Complete rig move- level up rig. - Prepare cellar for work. ACCEPT RIG ONTO NS16 @ 1400 HRS 3/16/2003****** PJSM for NU BOP's. - Wells in cellar are: NS 15, NS 1 7, and NS 18. Install gas detector in NS 15 wellhouse. - NO Drilling Sweeps - NO BOP's. RU and pull hanger. Run test plug. Pressure test BOP's to 250/4800 psig. - AOGCC Rep. Chuck Scheve out to witness test. 12:00-14:00 2.00 14:00-19:00 5.00 19:00-20:00 1.00 20:00-00:00 4.00 03/17/03 00:00-01 :00 1.00 Continue BOP test to 250/4800 psig. - AOGCC Rep. Chuck Scheve out to witness. Pull Test Plug. Set wear ring. PJSM for diesel displacement. - Test line to G & I to 100 psig wi Sea water. 01 :00-02:00 1.00 02:00-04:00 2.00 Rlli wi 4" DP to 2000' md. Close bag and displace diesel through choke wi sea water from pipe rack. Clean up Trip tank and take on clean sea water for hole fill on TOH. BOP Drill (D 1) Kick while Tripping. Trip out of hole with 4" DP. PJSM for casing/liner test wi HOWCO. - Pressure test lines to 5000 psig. - Close blind rams and test to 4800 psig f/ 30 mins. - Blow down lines. Prespud Meeting held with crews and discussed Lost Circulation. PJSM wi both crews for MU ofBRA#5. MU BRA #5: > Smith 6-1/8" XR30YD20DGPD (TFA=.5181 3x15 Jets); 4-3/4" PDM; NM IB Stab; ADN4; ARC5; MWD, 2x NM DC's; and 4-3/4" PBL Sub (2-port). Shallow Test MWD and new PBL sub. - Retrieve balls from PBL sub. PU 6 Jts total of 4" RWDP from pipeshed. RIH wi BRA #5 wi 24 stds of 4" DP. Change over to 5" handling equipment and Rill to 1 0 1 71 ' md, above 7" liner top @ 10265' md. Break circulation and pump 100 bbls viscosified sea water. - Blow down lines and TD. RIH wi BHA#5 into 7" liner. I 04:00-05 :00 1.00 I 05 :00-07:00 2.00 07:00-08:00 1.00 ( 08:00-08:30 0.50 08:30-09:30 1.00 09:30-11 :30 2.00 I ( 11 :30-15:00 3.50 ( r 15 :00-16:00 1.00 16:00-18:00 2.00 ( 18:00-22:00 4.00 I 22:00-23:00 1.00 23:00-00:00 1.00 I 03/18/03 . 00:00-01 :30 1.50 ( 01 :30-02:30 1.00 02:30-03:00 0.50 03:00-05:00 2.00 I I 05:00-07:00 2.00 07:00-08:30 1.50 I 08:30-09:30 1.00 09:30-10:00 0.50 10:00-10:30 0.50 I I 10:30-11 :00 0.50 11 :00-21 :30 10.50 I I 11 :00-21 :30 10.50 21 :30-00:00 2.50 I Waiting on production to swap fuel gas (power lost to the rig). Trip in hole to 11967'MD. Wash and ream to 12,015' MD. Tagged landing collar. Drill landing collar at 12,015' MD. Drilled through landing collar real quick. NOTE: Initial on bottom torque of 16k ftlb. Very close to the model. Displace well with 9.1 ppg drill in fluid while drilling shoetrack to within 15 ft of shoe. Drill remainder of shoe track. Shoe at 12,094' MD. Drill 20 feet of new formation to 12,125'MD. Condition mud and circulate for FIT. RJU and Perform FIT to 11.5 ppg. NOTE: 1. 9.2 ppg mud in the hole. 2. Surface pressure at 1300 psi. 3.8 bbls pumplreturn Pre-reservoir drilling meeting on well control while monitoring pressure. Drill from 12,125' MD to 12,424'MD. No Drag, No Losses. NOTE: 1. No losses were incurred. 2. Minimal shocks were observed. 3.60 rpm I 90 spm /320 gpm 16k off bottom; 19k on bottom torques. Circulate 100 bbl (4 open hole volumes). MAD pass from 12,424'MD to 7" shoe at 12,095'MD Pumping! Rotating I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY Depth (MD) (TVD) 9800 to 1 0050 ft 8746 to 8961 ft Show Report No. 1 Dateffime: 7/8/2002 I Interpretation: Steam still analysis indicates this portion of the Kuparuk "C" would produce gas and oil. Drilling Mud contained 1.2 % lubricants. No oil odor/sheen visually present in steam still samples. Sst in samples ( 10020-10050') had tr of a dull yel fluorescence and a strong instantanious brt yel cut. ( % Depth 10020 ft Gas x Units 3347 Mud Chlorides (ppm) = 18.5K ---FiõWiiñ¡-------šüëiiõ"ñ------S-hõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 218.3 50.76 = 167.5 - -- C2 33.70 5.70 28.00 - -- C3 26,97 4,55 = 22.42 - - C4 22.78 3.77 = 19.01 - -- C5 16,85 3.57 = 13,28 --PrõaüëIiÕ-ñ------=------=---------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 ( Hydrocarbon Ratios ClIC2 6.0 C1/C3 7.5 C1/C4 8,8 C1/C5 12.6 ( I Depth 10030 ft Gas x Units 3057 Mud Chlorides (ppm) = 18.5K ---Fiõwlfñ¡-------Süëiiõ"ñ-----=-Shõÿ¡-=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 308.1 50.76 = 257,3 - -- C2 41.82 5.70 = 36.12 - -- C3 32.23 4.55 = 27.68 - -- C4 24.32 3.77 = 20.55 - -- C5 17.12 3.57 = 13.55 --Prõaüctiõ-ñ------=------=---------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 I Hydrocarbon Ratios ClIC2 7.1 C1/C3 9.3 ClIC4 12.5 ClIC5 19.0 ( Depth 10040 ft Gas x Units 2491 Mud Chlorides (ppm) = 18.5K --"Frõwlrñ¡-------süëilõñ-----~hõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 405.1 50,76 = 354.3 - -- C2 44.05 5.70 = 38.35 - -- C3 26.55 4.55 = 22.00 - -- C4 17.68 3.77 = 13.91 - -- C5 12.12 3.57 = 8,55 - -- --PrõaüëIiõ"ñ------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 I Hydrocarbon Ratios C1/C2 9.2 C1/C3 16.1 C1/C4 25.5 C1/C5 41.4 I Depth 10050 ft Gas x Units 844 Mud Chlorides (ppm) = 18K --Fiõwliñ¡-------šüëiiõ"ñ-----=-S-hõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 411.5 50.76 = 360.7 - -- C2 41.05 5,70 = 35.35 - -- C3 24.59 4.55 = 20.04 - -- C4 16.15 3.77 = 12.38 - -- C5 11.08 3.57 = 7.51 --Prõaüctiõ-ñ------=----- Analysis Hydrocarbon Ratios ClIC2 10,2 C1/C3 18.0 C1/C4 29,1 C1/C5 48.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1 000.0 --::::----.--~------------------~------'-- -..---, .----.-..--.- -------'-.'-.--'-'''. -.-..-"--'"'.."-..--- -.-.-.--.----.-,---------- ---------------------.- _. _____... ". .___.. ...__._.__ _____.._._....". ~__... _ __..._ .._.n __.._.._. _..._.. ____n.____~___ ----.-..--.--.------------.--.-..--- ._-_._-_._.._~----~- ----.---...-.-.----.. -----------.-- -_..__.__._._----~-- .._.~~_____'h··_.~_.____.__· _._...______.______ _..__.__..___.~._.__ NPH --.------- ---~----~~._----_. 100.0 - -' --- ..~.~.~~~:..~..:_._.._.._.._._. --... ~~-;;-:?~~~~-~ -..--------.-----.-- ,--.---.------..-..-- Gas .. .-..- '-'---- _.._.~_. - '"---.--.- -..--. .-".-......-.-..-. Oil --.--..--.--.-..-..--..,,--------.... --.--.. ,.--.-'"---.------ NPH 1.0 .- u_._u_....._________._.___. ._u___.._ _._____._._______u·._____.___.____.___.__ -. -....---.-.--.-.....---..-.-..,-.- - Hydrocarbon Ratios C1 C1 C1 C1 - - C2 C3 C4 C5 __._~__._._.____.....___.N'...._...~.____~,__.._.____"___.__~________________._h__'.__.___ 1000.0 -~._-~-----_._---------_.._.__._._._._-.-.._.._._-.-_._----.....-.--.--- ._.._..".__...____,__..___._"h.___..__,______~_'__h._ _._~_..__'._~..h..__'__~__._n ---~._~~--- .-------.-------.--.-----.----.---- .h_~___.__._,___._.__.___~_. .__._...__.,,_._,.. ___.......,._......__,... .._.._...........__. ...__~_.,..._._.._"h'. _____________.._,__ ,_____.___..________ ____'h_._..___._._~_'"_,._._..~...__ ___._.___~__._.___~_..___ ..._._..__..___._._....h_,._',_~...h __.~.__~...~.__.._.._,___ NPH .--..--------.----- --.--.---.-----,--.-, --...-,--"."-,,.-.-.-,~- 100.0 --' -- Gas ..."._...,._. ......"._._0>. ___._. ___"h_'__._' ....._.._.___ '"""'~'_h ._'''n._.''._"~.' .__....._ 10.0 Oil _ ,_...._._.....___,.. _.."._n .~_.."'_............._......~_".._..._._...._ ..... ..u_,._...__.....__.........__..."__.~_~,._. ._~._~.~..m.._______._..____..__..., ....,___..._ .._._.".._.....,_,..__, ___. ..._._."n.~_____._...__._,_,_ ~--'_._--------'---- ~_...._~c_~___._..____._____.,.__._ NPH 1.0 "__,.._,_".,,.__,___,,_,,_,__,,__,__,",_ ..._.,_.....__.........h_......__·w......__.R. __._._._....._.__~________. sperry-sun Well Name: NORTHSTAR NS12 Depth (MD) 10060 to 10115 ft Location: NORTHSTAR AREA (TVD) 8969 to 9016 ft DRILLING SERVICES Operator: BP EXPLORATION ALASKA Show Report No. 1A Show Report Report Prepared By: MARK LlNDLOFF DatefTime: 7/8/2002 I Report Delivered To: KEN LEMLEY I I I ( I ( I I I Interpretation: Steam still analysis indicates this portion of the Kuparuk "C" would produce gas and oil. Drilling Mud contained 1.2 % lubricants. No oil odor/sheen visually present in steam still samples. Sst in samples ( 10050-10100') had a trace to 5% of a dull yel fluorescence and a strong instantanious brt yel cut % Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 Depth 10060 ft Gas x Units 1672 Mud Chlorides (ppm) = 18.5 ---FiõWirñ¡-------§-üëiìõñ------š-i'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 454.9 50.76 404.1 - -- C2 56.18 5.70 50,48 - -- C3 35,91 4.55 = 31,36 - - C4 25,37 3,77 = 21,60 - -- C5 16.77 3,57 = 13,20 - -- --Prõëiüët¡õ-ñ------------------------------------------------------------------------- Analysis [X1Gas [X10il nwater nNon-producible Hydrocarbons 2 % Depth 10080 ft Gas x Units # 2800 Mud Chlorides (ppm) = 18.5K --Fiõwlrñ¡-------šüëiìõñ-----~"hõy¡=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 422.4 50.76 = 371.6 - -- C2 55.96 5.70 = 50.26 - -- C3 38.95 4.55 = 34.40 - -- C4 27.37 3.77 = 23.60 - -- C5 17.18 3.57 = 13.61 ---Prõëiüëtíõ"ñ------=------=---------------------------------------------- Analysis [X1Gas [X10il nWater nNon-producible Hydrocarbons 2J % Depth 10100 ft Gas x Units 1817 Mud Chlorides (ppm) = 18.5K ----Fiõwlíñë-------Šüëiìõñ-----~-Ii'õw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 255.3 50.76 = 204.5 - -- C2 40,46 5.70 34.76 - -- C3 20.29 4.55 = 15.74 - -- C4 14.33 3.77 = 10,56 - -- C5 9.32 3~57 = 5.75 ·--Prõëiüëtiõ"ii------=------=---------------------------------------------- Analysis [X1Gas [X10il nwater nNon-produCible Hydrocarbons ..!J % Depth 10115 ft Gas x Units 3183 Mud Chlorides (ppm) = 18.5K ---Frõwlfñ¡-------šüëiìõñ-----=-§h'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 296.2 50,76 = 245.4 - -- C2 39.22 5.70 = 33.52 - -- C3 24.64 4.55 = 20.09 - -- C4 17.45 3.77 = 13.68 - -- C5 11.55 3.57 = 7.98 --Prõëiüëtiõ"ii------=----- Analysis x Gas x Oil C1 C2 Hydrocarbon Ratios C1IC2 8,0 C1IC3 12,9 C1IC4 18.7 C1IC5 30.6 1000.0 .. - - -~--,,_...__.,..,- ..- ,,- ---.-~-_._---- --~----"'-~_._,_._. NPH 100.0 - -. ~~~~~~~::::=~ - ,_0.__- ._,.....___._....._ _" ,".._., _~_,_,__._ Gas ---.-----...-...-....--- .-..--...------ __"·'_''''_·'_''_'·___.,__._,.m...__ Hydrocarbon Ratios C1/C2 7.4 C1/C3 10.8 C1/C4 15.7 C1/C5 27.3 10.0 ' .. ____ ,,_. "'_ .,,_____ n___._.___. ~." -"-.-.,"....-. "--'---'--.-".". -_._..~...._~..._- ~_.. -.,------.-,..-.-.--. .-..,,-.- -.-"".-... ..._,..~"......,~_..,-_.._.._.. -. -_._,.,,--- --.,...-...-..-...-.--.....-..-.-.-.,..--. . -"'~....__.._..... -_._-~...._-_._._... Oil -.---.----------.-.....~-- _...__._._-_.._.__._~ --_._-,--,.__.~.- .._.~----------. --..---..-,-.--.--.. NPH 1 .0 ---.--..------.-.--.--..,---, .,.....-.,...-....-..--.--..,..-.---...-------.--,----- --.--------.----.-.-..-..-.-..."--...-.....-- Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C2 C1 C5 Hydrocarbon Ratios C1/C2 5.9 C1/C3 13.0 C1/C4 19.4 C1IC5 35.6 1000.0 --------.-------------.. -.----.--.----- ---- --~-""- ---- ... ..... . _".._"...__'H_'____ '_"_.__.__.._'__'_'__ _ . _..__.._______.__,__,__,,,"........ .._..., .._..__ .."".__...___._.._....._...~,.._._._ __.____.._.._..__... ",,,m,. _. ___..__,_._ -- --.".----.-.-...-..-.-...-- - -.... . -- -..-....-....,.----...-"...---..........-...-- ... .,'_.._,~- ..,....-.-..-- -."--'-'-'''-.'''-'- _.,_._....-........~._.-_...._-.,-,.......__. ..-....-..-...--...--..--.--.-. ..--.. NPH -- -.-. ----~"..--_. ---.."...-.-.--...-.."...."...........--.-.. .,----......_._...__.._-~..-.._,.._-,--- ..--........-. ...-.....-.--,-----..-.-,-.- -_.-------_._.._~..._......_,. -.-.~...~,.._.._---,_._._._._._-~ ~ .... __ I ....".~,.-,~ 100.0 -.-..- ~~=======..=.. =~:.=::==~===-===--=~ ~==:~~==.~.-~==~-~~ ----.-..-.--..-----...-..-...-.. ......-.----...---.-....--.---. ..-..-.-.-..-----,..-..-..--".-.,.....-- Gas Hydrocarbon Ratios C1/C2 7.3 C1/C3 12.2 C1/C4 17.9 C1IC5 30.8 :;~ ~~~~~~~~~~~~ -....-.. -.---.---..--.---.--.. ".--.... '--'.'''.....---...--._._-'-.._._-.-~ ._."---_._"--_.......,_.._-,,~--- -----------..---------.--- .----.- ----.-.....---..,----- ~._______.____.__.__~_~_ .,______......_J..,..,,__.__~._ _,_.~,,_.__._.~.. .___,~_._.___ NPH 1.0 ---------------------------------------------- ..---_.._---...~-_._-,--..._-_.._. .-.,,- .--- - -~..""_.._._--...~_. .---.---.- I' sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY r 12105 to 12165 ft 10843 to 10901 ft Show Report No, 2 DatefTime: 3/20/2003 Depth (MD) (TVD) Interpretation: Steam still analysis indicates the lower portion of the Sag River would produce oil but samples showed little porosity. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 12105-12150' ) had a trace to 5% of a dull yel fluorescence no cut. ( % Depth 12150 ft Gas x Units 256 Mud Chlorides (ppm) = 21 K ---Frõ,;¡,lrñ¡-------§üciiõñ------!)1i'õW'----------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 8.7 0.77 = 7.9 - -- C2 2.30 0.79 1,51 - -- C3 3.31 0.82 = 2.49 - - C4 3.41 0.72 = 2.69 - - C5 3.62 0.91 = 2.71 --Prõdudiõ-ñ------==------=---------------------------------------------- Analysis [X1Gas [X10il nWater nNon-Producible Hydrocarbons 2 % Depth 12165 ft Gas x Units # 164 Mud Chlorides (ppm) = 21K ---Frõ,;¡,lfñ¡-------§üciiõñ-----~h"õW'.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 6.8 0.77 = 6.1 - -- C2 1.64 0.79 = 0.85 - -- C3 2.84 0.82 = 2.02 - -- C4 3.39 0.72 = 2.67 - -- C5 4.12 0.91 = 3.21 --Präauëi'ío-ñ------==------=---------------------------------------------- Analysis [X1Gas [X10il nwater nNon-Producible Hydrocarbons 3 % Depth ft Gas Units Mud Chlorides (ppm) = --'frõ,;¡,lrñë-------süciiõñ-----=-§h"õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.0 0.00 = 0.0 C2 0.00 0.00 = 0.00 - -- C3 0.00 0.00 = 0.00 - - C4 0.00 0.00 = 0.00 - - C5 0.00 0.00 = 0.00 -Prõdudiõñ------==------=---------------------------------------------- Analysis nGas nOil nWater nNon-producible Hydrocarbons 4 % Depth ft Gas Units Mud Chlorides (ppm) = --'frõW1rñë-------šüciiõñ-----=-~-hÕW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 0.0 0.00 = 0.0 - -- 0.0 0.00 = 0.00 - -- 0.0 0.00 = 0.00 - - 0.0 0.00 = 0.00 - - C5 0.0 0.00 0.00 --Prõduëtiõ-ñ------==----- Analysis Gas Oil ( Hydrocarbon Ratios C1/C2 5.3 C1/C3 3.2 C1/C4 3.0 C1/C5 2.9 ( I Hydrocarbon Ratios ClIC2 7.1 C1/C3 3.0 C1/C4 2.3 C1/C5 1.9 ( ( I Hydrocarbon Ratios C1/C2 =tI:#### C1/C3 =tI:#### C1/C4 =tI:#### C lIC5 = ft:/I:### ( C1 C2 C3 C4 Hydrocarbon Ratios C1/C2 =##### ClIC3 = ##### C1/C4 =tI:#### ClIC5 =##### ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ---_._--,--"-~--- .-- 1000.0 _.._~_..'_._--_._---- _.__...--~-- ..- -.--.-'- . ----...-- --. -..--.-----. --.-.---.. ---_.._,._._~ .---_._~----.- ..-.--- -'-~-- -.-. ,,--..--.,,-.- --' ,,--."-'--"---"- ..----~- --- .---.-,-- '-~'-----'-'---- . -----,0-,_.,._- ___..__.___n____ _..._.._ ,___h__'___'_'_~___ --,._------...- ----.-,-------.. --_.--_.----_.-.--_..- NPH --.- ..--------..------.-..- ,_._--_._--,....-.._-_..~. __h__·."__~_,·_· 100.0 - -. --- .. - '~, .~.'-~--. .'"------_...~._._.- ,_...."~,,.- .-..-.." Gas .. __.,...___ ._...' n·_.._._· _..,. ..__. __..__,_.._ ,.'__". . ___..____,."...,...___.. ._,,,,._,,,__..._. _m'. :":_'_;:;"_~.'_' ...------ ------ 10.0 Oil,---·-·,---------·,,-·--4*- ., ~POH~==___~~-t-i C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 _._----'"_._~_._~-_._..__.- ---,----.------.-.-- .--.-.-.-,-...-.,---......-.---- ----~..._.._------,,~.._- _._~. _'..__.h___.__.________ ...-.- ..-.._..,..__..._..,._...---.......~- .-,--.,.-.....-----.-.--. ---...,,---.-----..- _,.....__._____h__."._··_·_··_ . --. --..-- ~_..-._.._...__._......,._...._.- ,..'-_.. ...__~.___.".._,,_______.__ ~.___.______h..._.______·_ NPH .. ~'"...'""_.._.._.,_.._..,_...- ..- ---..--.-.,...... 100.0 ... ... ..... \ -- ........". =::~:~-£:_~:==~~:::::::::::::::::::~: ~~~:_~:~~~~~~:~::::=::: _..._......._.....,..__...,....... __,_...... n_ ~_.. '·.h' ~...._._.__,__"...,...,_.__~ __~_...____.______~_ _m~___'._·,·_..·····_ _._--~-_.,---~----~_._-- Gas ::._;.:;....,'_.._-,-"...._---_.'"~~...,.~,._~._,.:- .-- -------- 10.0 .. . ._.,..._._"._..,~.,.~..-".-.-_.._--_....... . ....- "..--......---...-.----.-,---..-.- . ....., "-'-""'._~-'-"---'-"'-"-'_. .---,.---.....----.----. -_._--_.~-------.'_._-,-- - ___.._.m_'__._,_·_..__·_____· ____..........._._. _..._-,_._---_.~..------ Oil ,--.----.---- .-------.--..- _'~n·___'__·~·,····__,_·_·_·_· _.._.._.___._..~'"...___.__. --.--.-.. _.-'_._-~---~----' ..------------- ----~.._------ NPH 1.0 ----.-.-..-.-..-.-.--.--.-...---.....-- ---~..__......_.-._.._.., I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY 12250 to 12275 ft 1 0984 to 11009 ft Show Report No. 3A Datemme: 3/20/2003 Depth (MD) (TVD) ( Interpretation: Steam still analysis indicates this upper portion of the Ivishak would produce gas and oil. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 122S0-1227S') showed a S to 10% of a dull yel fluorescence with a slow mlky yel cut. ( % Depth 12250 ft Gas x Units 131 Mud Chlorides (ppm) = 21k ---Fïõwlíñë-------äüëiìõñ------ši1õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 27.1 0.77 26.3 - -- C2 4.08 0.79 3,29 - -- C3 4.00 0.82 = 3.18 - - C4 2.77 0.72 = 2.05 - -- C5 3.57 0.91 = 2.66 -Proðüëtioñ------=------=---------------------------------------------- Analysis x Gas x Oil Water Non-Producible Hydrocarbons 2 I' Hydrocarbon Ratios C1/C2 8,0 C1/C3 8,3 C1/C4 12,8 C1/CS 9.9 I Depth 1226S ft Gas x Units # 388 Mud Chlorides (ppm) = 21 K ---.=rõwlíñ¡-------šüëfiõñ-----='"S-ti'õÿ¡.=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 136.6 0.77 = 13S,8 - -- C2 17.41 0.79 = 16.62 - -- C3 1S.34 0.82 = 14.52 - -- C4 9.07 0.72 = 8.35 - -- C5 6.76 0.91 = 5.85 --Prõðüëtiõ-ñ------=------=---------------------------------------------- Analysis Non-Producible Hydrocarbons 3 I Hydrocarbon Ratios C1/C2 8.2 C1/C3 9.4 C1/C4 16.3 C1IC5 23,2 ( ( Depth 12270 ft Gas x Units 764 Mud Chlorides (ppm) = 21 K ---Fïõwlíñ¡-------Süëiìõñ-----='"Š-ti'õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 208,S 0.77 = 207.8 - -- C2 29.84 0.79 = 29,05 - -- C3 25.43 0.82 = 24.61 - -- C4 15.51 0.72 = 14.79 - -- CS 11.14 0.91 = 10,23 - -- --Prõðüctiõ-ñ------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 Depth 12275 ft Gas x Units 902 Mud Chlorides (ppm) = 21K ---.=iO"Wliñ¡-------ŠücÐõñ-----='"sti'õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 234.9 0.77 = 234.2 - -- C2 31.1 0.79 = 30.28 - -- C3 27.1 0.82 = 26.29 - -- C4 17.5 0.72 = 16.75 - -- CS 11.8 0.91 = 10.84 --Prõðüëtiõñ------=----- Analysis Gas Oil 1 Hydrocarbon Ratios C1/C2 7.2 C1/C3 8.4 C1/C4 14.0 C1/CS 20.3 Hydrocarbon Ratios C1IC2 7.7 C1IC3 8.9 C1/C4 14.0 C1/CS 21.6 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 CS --. - -.- ~._-,..._- 1000.0 -""'-'--"- .-.-.-."---,-..-----------.- --...-..--. _..._------,,---, ---.-- .-.-- - "'-.--....--.--.. _ ....._..._.,,__.__._..__ 'h__m___ -..,-. NPH -----_.._--_..__._---"---_._-_._----.--_...~---~-_._--.---_._--~ - -. --- 1 00.0 -~~~~~~:~:~~:= =:~=-:~~:_==~~.~~~_:.-:-,_,__.____ Gas ...__.......,___.._ _.____".. m._..._ _.._ ___..__._""'"'_..._.___..._.~.... . . --,"-, -..-..---,-..,,-...------.,--.-- .--,.--,..-.---- "..- . - .--- - _._~,.~..~......_.__.- Oil -----------.--- -------.-.--...--..... _..--.._._.._--..-_.~.-._..._._-~'"._.._.- NPH 1.0 -.. .....--..-.-..--.----..---.. . -- .-....--.....,,--.--..---.---- .. __h'___.____ .__.__.._...__....."_m_..._...___.___...._._.___ C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ____._.____.___..__.___.,_._._.,._..____._________.._.._...__.__~.__,... "._._'h._.._._._..____._.__....____._____.._.,_._ 1 000.0 ._-"_._-.._.._._..--~"..._-._.__._--_..._". -...--... "...-.---...-.--..-------- --.-....---.-.,--....-."..--- -.-...--- _____._.._.."....____.__._. _,.,_. .~. __,.. _..._._...__._.___~"......__..__...__ _._._,_.._._______.._......_~.h_ ----.---..-----.-.--- ---_.._---~-~-- ----~._-- .._._._......"..._...._.......,...'._..H....._H..__.. __.'.___.._h.._Uhh""_".__....._._,._.___ _.__.___..,_..____._.....__.__.._.._._ --.-----.-.-.--,-.,--.-.-- --.--.---.-.--.--- -------.-.,....-- -_._-------,-_.. -'---.-.--,,--.--.,.-,,-..-.-,.-,,- --.-..--.-"..--.. --~--""-'~' _h..______.____"___ .._.._,__.__._.~____.._.._ ~_.._.._.,......_..________ NPH ----.----.-,.. .--..--,--...--,.-..-.-.,-- -...--....,.....-------. __._,__.__._____._._._.__ _.____._____.._~u__._..._ .___,.~_____,_._,.___.____ 100.0 ............. ' -- ~~:~~~~~~~~~~~~'~~~~~~~~:~~~~~==~-~~~ . h .. h_. '_"'_'_' _.._ ..____._.....____.._....__ . _..__...._.__.__.__...M ___,_._._._.__._.._______.U.,,_ .___.__._.____._..______,...,._._... Gas -------------,.---.----,--------.-.----- .,=,...::.-:--:--=--=-::;;-';;;------------!!!"_~-'~..:.... 10.0 _ '_'_ u _..____."____._"_... Oil _n "'_'_._"u"'__'.___....".. ...._."....._ _. ._..._.._.".._...."..__ ..._._~....,_ _"__"_'_'''__'_'__n_'_'' ._.",._. .._._....'_..n_~_...""_......_....._...'"_, .._..~....__ U' _...__.".__..._'".__. _'.__~__h._.,____,..,_... ______.____ __._._._..._.__._"__'.h__ _......_~.~-~--,_.-.,_IIIIIIIIIII-......._......~..._.__._~- .__,....,...._.________ NPH 1.0 hh_ ~- -. ~......_-_......_.. "'"---, .--..------ - ._,. .----.-..- -...-.-----.-.--- -.._-... ...-..----.-. I ( sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS16 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY ( 12300 to 12424 ft 11033 to 11156 ft Show Report No. 3B Dateffime: 3/20/2003 Depth (MD) (TVD) ( Interpretation: Steam still analysis indicates this lower portion of the Ivishak would produce oil trending to gas. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 12300-12424' ) showed a 20 to 10% of a yel fluorescence with a slow mlky yel cut. I % Depth 12300 ft Gas x Units 308 Mud Chlorides (ppm) = 21 k ---FfõWifñë-------§üciiõñ------àl1õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 103.0 0.77 102,3 - -- C2 13.95 0.79 13,16 - -- C3 12.96 0.82 = 12.14 - - C4 9.05 0.72 = 8.33 - -- C5 7.23 0.91 = 6.32 - - --Prõai:ictiõ-ñ------------------------------------------------------------------------- Analysis fX1Gas fX10il nwater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios C1/C2 7.8 C1/C3 8.4 C1/C4 12,3 C1/C5 16.2 ( ( Depth # 12350 ft Gas x Units # 103 Mud Chlorides (ppm) = 21K ---FfõWiiñë-------Šüciiõñ-----.:-šl1õy¡=--------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 84.4 0.77 = 83.7 - -- C2 14.73 0.79 = 13.94 - -- C3 15.00 0.82 = 14.18 - -- C4 11.65 0.72 = 10.93 - -- C5 7.23 0.91 6.32 --PrõaüC'fío-ñ------=------------------------------------------------------------ Analysis JqGas fX10il nwater nNon-Producible Hydrocarbons 3 % I Hydrocarbon Ratios C1/C2 6.0 ClIC3 S,9 C1/C4 7,7 C1/C5 13.2 I ( I Depth 12424 ft Gas x Units 172 Mud Chlorides (ppm) = 21K ---.=fõwliñë-------§ücÐõñ-----.:-Š-li'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 43.6 0.77 = 42.8 - -- C2 6.65 0.79 = 5.86 - -- C3 6.96 0.82 = 6.14 - -- C4 6.84 0.72 = 6.12 - -- C5 8.04 0.91 = 7.13 - -- --Prõaüctío-ñ------------------------------------------------------------------------- Analysis fX1Gas nOil nWater nNon-Producible Hydrocarbons 4 % ( Hydrocarbon Ratios ClIC2 7.3 C1/C3 7.0 C1/C4 7.0 ClICS 6.0 I Depth # 0 ft Gas x Units Mud Chlorides (ppm) = ---.=fõwliñë-------§ücÐõñ-----.:-Šhõw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 0.0 0.77 = 0.8 - -- 0.0 0.79 = 0.79 - -- 0.0 0.82 = 0.82 - -- 0.0 0.72 = 0.72 - -- C5 0.0 0.91 = 0.91 - - --PrõaüC'fiõñ------------------ Analysis Gas Oil C1 C2 C3 C4 Hydrocarbon Ratios C1/C2 1.0 ClIC3 0.9 ClIC4 1.1 ClIC5 0.8 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 CS ._ __,_.__..., _n ..._ _.._.._.. __..._~._____..__~__.__ ._._ 1000.0 _'_',UO_'_'_ __. ._~ . .._.."..._. .__ ____·"m___.". _____._.___ .n..___._ ~_____~.___ ____.____._._~~._.______.. _n____.___,.___ -------.-,--------.-.---- - · .- ...-' --.---'"-----.---..--.- ---.-..-------- -..-_..._~-----~ NPH .. - -......-.--.--- -..-.--...---...---..--.. .-,....--- 100.0 - -. --- ~¿~~~;¿~~~ ~~-=~~-~=== =-~=-~====== Gas -..-----.- -..--.".,,-..- .-- .. - .._.__.....~_...__.._..-- 10.0 i~~~~~~ ----- ---- ~-_._'-._~.__..._..._.. -.-.-.---.--.--- -,.-.-.----..--.-------.,,-.-.---,-..--- --_._._"._.._~..._~~----,_.,,- ---.--..---------- Oil ..._.._.___-..___.._ ._.~___,___._.... "..n..__.~~·.·____._,_·____···_,,____·_ NPH 1. 0 n_""""""___"____"____"____""________"_____,_"_________ ,-""----"-----"-"""""-"","""----"- ------..-._--- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 --...---..-----"..,-.-----.,-. ...... --......_~"..,,_..~.._.,,_. ----". 1000.0 ...,,-,-_...."'_.,_.,,"-_.._-_.~_.,_.._-_. .~~....._....~.._.._.,,_.__._--- · ."___'_..'_" ..._.____.n.u_._._._. ,__.. ..._,_.__.__ __._......._....._ .___.__._.n'.' .._.._. -... .,..,--.- ~'-"-'--'-'."---" . -.-.-........---...,,-.-.....-..-- -~---_..-_..-......_-~._..._.._- .-------..--..--..------.-- · -...---. "'-_.,_.~_._....._~-_._.~-~_. ....----.---,--..-..-..-.-..--- ... ...- ..._- .-..---......,----..-. ....,-_. ..~.~..- NPH 100.0 ___._,_._.". .h.__. .._..". _m_m_","_..._ - ...__.._._--,..~._._---,..-...-.~. .-............ .----------.------ ._..~. ..--.-. ------...----- Gas I ~=~___=_~_ _~~:._=:;___ ;;;:-~_,~;-:;;~~ _____. - ~----- ---.-_.!I'II! - ____ ___ .____ __ __ __ _.._..._......-.~..,,-._--....--_.-..---"'-~- --.--.----.,.---..--.-..----- ---. -..-...,-.--...-.'------.- Oil' _~~-=:~=:::::.:::.:::::':::::~~~~_,_".,t::~:=_.:=::::=::::::::"=:::::::::: :"::::::=:=::::~":5:=~==-" --_._,----_._-,---_._-~_. ....- -.--,-.------- -----_._._._-~-_...._...._.__..,--_...- ,-_._._.._~.._---_..__.._~_. ---.-.---..,,-.-.----.--- ~.._,_._.. -.....,-.--.-.......---"...---. .---..----.-.------.---.--.-- -_.._.._-~--_._---_.-._~-- -~--_._-------_..__._-- --....--..--.----..---.---.-...-,,-.- ._..__._...--_._-~- ...-...--,.-..""...--.--,--.-.---,--- ---------- NPH 0.1 ...--."... ..-..-...-.-....--.---.,-......-.-- ._._._...-~-_.._-_._.._--_.- _.._--_.._._...-...__._..~.,_..._,-..- ._ __ ." _'_' ,,_.~ .....____. ._....__ __......._.____.._..___.____..~.__ '''._.......... _·_··__..'_h.___·..··__..··_ Logging Engineer: Reg Wilson / Mark Lindloff * 10000 units = 100% Gas In Air I <&..... "':"L ,::, (,¡,:,..<,;;;~,; )\,' :::,',f ~~iMf~f:i'J::%i'i~ft:~:;i:;'-:':'. .¿~'ll:;:~·'!!·:· >':,~;~{'1i'::,~~1t;i~,$1$~1¥,M~~f:':"'.:"· -.: ¡".'; }l:;~'>2!~%i¡J.{}ä~~.~~J!M~\~:~:~~~~¡Jlì~~fi~~·:;~:~1ßi,:::::?:,::~(~;;~~W~f~~;{;.;;':'~~~ Move rig to NS-16, Prep to Spud. 24 hr Recí to to to to :,::~MPit~!¡~i"::ø:~~~!'t~:~ !\~: 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. , Description of fillings: % Lithology Sst SIt5t Sh units ppg units ppg units ppg %LCM I rt ~~~-: ~](r" ,::::v::=1.'::. """.......,.'''Y'T~·m~1,~:~::~:~J 'Wi .An I ·::;mpt"'l'IIIIIli·tnTT'IiI1'~::',::'u'fiml'!n". "-iI- ~~" ,,@;".,= ~~,..J.",,\!.III!. .~;VU ,"",Mm. ~~.MI!" eonnection Gas ::=~:"t .- _ ft units ppg ft units _ ppg (Å ft units ppg ft units _ ppg ¡~ ft units ppg ft units _ ppg 'J ·1~_uL-:fIf::.~~J",."1\"",,. .,Mr ~.:.~.,. _ t JIIlIU·_....·..·'.'IlIll1[........ Drilling Breaks after Gas during before after ft ft ft % % Mud Cut: ppg Trip CI: 19000 Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ·-~~M~~_!iL,.UW¡.1 : I'. HJ IJmJSi~!tfJœ;::!;g';mJc:='11: Drill Rate during before Depth % % Current Lithology: ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: ;.\¡,. ~..~ ", ·,~·i'~I~~'I:'~)~~~'~~~~~·'1:-·'f~·~ '~,\~'.:...,~;~' .... .\:-t~...t.../~~_~'~~'\~ '...'.,~·~·,1'..."~,,.,..,..;6:"~}~r...,;.~{'·I·.?~'.~,~-.:.:· ~~·í. ..',' -' ''': ~·,,"i/I'·:~·.~..,:·~-.f1,.'t~·1 .....i04...~_ ·\.':r,tf:'~t·:.'..~.....~.' ~".J ~~.!,"'AI~··.·" Jets: \ \ \ \ \ TFA: ------ Total Revs on Bit: Footage for Bit Run Bit Size: Hrs. On Bit: Type: RPM: Bit No.: Wt On Bit: I I I I ( ( '-."... ( --- 8.90 ppg 8.90 ppg ppg o Visc 105 secs API filt 10.0 ml HTHP ml Mud Wt at Max Gas - - - PV 20 cP YI 52 Ibs/100ft2 Gels 13 / 20 / 23 Ibs/100ft2 pH 9.1 Sd Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC 1 6/28/2002 201 o Moved Rig Smith / Clump Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max fUhr @ units @ deg F @ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Mud Wt In Mud Wt Out 24 hr Avg fUhr ( unit~ ( ( fUhr units Deg F R.O.P. Gas· Temp Out Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe....,....,v- sun DRILLING SERVIC::ES ( I " 10000 units = 100°0 Gas In Air :i , ". '1..¡>I'~':,~'.1::~~f~t"~-t~~;\> ,~;:<d~\'::·:~":",,:/:~'.(: 5· 'r'l:j;; -' :,,~,)¡.:.,,:,,~, ""i,j~I,>t·:::,,, '·o~J.':., :T:$;,~~'~,~,:',''"' L"" .: ....~;:~ ,- ..... . , , Logging Engineer: Reg Wilson,' Mark Llndloff 24 hr Rec; Finish berming rig - nippled up riser. Picked up BHA #1 and drilled to 336' MD. POOH, Picked Up BHA #2 I Run Back in hole and drilled to 1004' MD. No Formations at report time. .",?,.t:t~"'.:~!1.~~Ii~~II':'''·\~:.o'¡~~;~'''IIo~~i.*~_' ,.,.~. '," \, " ~(~" "," "·:t··';";"m. ,·.-.i>~i~il.'~;.",,¡'~'!!;;A.;j.:~)··'f1\N~t',,,:.<:., . ..~1.,tf;r· '~..;·('t1~·fpt~w~~~~~~~·'~~ . .~'... .. -' . - .i)t~·~;~tii;;'·~r\<~··(~~\1J1~:~~~~~~'1~~~'~~~~~~~:;~~~~~~iø·~;·_~~_('~,,·l~~ ~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings: Connection Gas and Mud Cut units ppg ft units ppg ft units ppg - - units ppg ft units ppg ft units -ppg - units ppg ft units ppg ft units -ppg lIIIIlijl , r' .1JØ , ,- . ~ 1 I III TI ß:J'::n:Q['NC~-" Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to to to to I Depth , . j"Ì I f.~ ~: I % :;::m:l.·mjl.\w_!\~.tllt\PlkI'~r,'""D ¡1~IIII¡L~l !ID ~j~mJj~'¡¡UI~r;.Iï. I ~UI ~LnTrTC"":E % ;;-.,..:..... .' ,·,·'..·'.'L.' .,... '.',' ..,'... .'" '.' ... .'," ....~, .";__ "::''<' .~'·i:·. .'. ,../.,,'. ,'.",.,,". ;,.', .' .'. '_j)¡. Bit No.: 1 Type: MX-C1 Bit Size: 16 Jets: ~ \ ~ \ ~ \ ~ \ _ \ _ TFA: 1.0310 '. , Wt On Bit: 27 RPM: 0 Hrs. On BIt: 11.5 Total Revs on Bit: 25 Footage for Bit Run 1,004 .;4 I,~':~:"';I. ~ ':" "0',",.' \-...-i- """ý.!~~~·~"u··><1..òi,.:..,<i'~··1I:~'t·~¡,,~..,::,,\!'I"'·~~':,~..:';'"-'?"":".,)."'(""'i"'>!.'Ì-~~~"~'~ ,.·.~r"-'"'' ." ,.\.........;.' !;!""\~~"':-.I~~'!I\'J!IIi.:.'>' ;Ì'I\'~~:~¡;'"'-' ':,'. (,; ';'..., "';". ,..: "'}!\4.~'~ ':', Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 19000 ppm J""i . Short Trip Depth ft Short Trip Gas: Mud Cut: = ppg Short Trip CI: ppm,~ "~:\' Tight Spots: to to to Feel of Filion Bortom: tt J~ ;~Ä'(~i" "., ,j ¡ .~.. ,'''.-p' ,,:.', .¡tJ::, "~~~~r"ì~"'~¡r-II-;'t.:<~r·"'·, ~:', ¡, :..:"!O,!~;;,,;.., :.'!'~~II1~~~·'L"~'J;·.I)~Ít"";. :'~r:.',..\' '....:--,,\.t;,: :':':,1 .,;,;;;' ·~~~~..i'1',,',~..;D.I..tf""¡'f';µ~· ~.t.n'.;¡.,,>',¡; ";,"¡,5i"l'I¡ji-W.~,'¡.1I1L %LCM gpm ·:.:ji ·'.lë: 677 gpm I~! 49 fpm '!, ~ fpm .if " ~ ppg :~jt 1 5 % :.j', . IC r:~\ I % % Current Lithology: ( j¡ .... .'....., ...', > :"., I ". ':. . ,> I --- Visc 136 secs API filt 15.0 ml HTHP ml Mud Wt at Max Gas - - PV 24 cP YI 70 Ibs/1 00ft2 Gel~ 14 / 23 / 25 Ibs/100ft2 pH 8.9 Sd ",..",r.:", "'. Pump and Flow Data 80 spm DH flow 80 spm Total flow spm AV @ DP 1015 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 2 6/29/2002 1,004 1,004 Drilling Smith / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ppg ppg Mud Wt In 9.00 Mud Wt Out 9.00 383 355 892 24 hr Max ft/hr @ units @ deg F @ ft/hr units Deg F Current R.O.P. 85 Gas* 2 Temp Out 60 24 hr Avg 310 ft/hr( 4 unit~ ( ( 688 37 60 I BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe'--'''''y-sun DAIL.L.ING seAVIc:es I Logging Engineer: Reg Wilson / Mark Lindloff , * 10000 units = 100% Gas In Air II .", ' ' ,ì' .,,;; , .' -::,:~ ::¡,':;;~;::; ;;~ : {:-?~1,¡:>~\,*~i'~~f:!~{à~·~.~\.~~~~i~~!~~': ",~:+'~~~~'(~lf'f~~;, i-:> ,:¿;t~~:'\:;::'~'JR'¡~';~~;~~~~~;f~;'<¡fj::.};?A~},*.~5"?:f,~:ìi!"~t~\,:~~:~fii? :~ :-!, : :: ' :' ' ' :: ,: : ~ 1Ø It,,¡~ TOP OF PERMAFROST 1204' MO, 1195' TVO BASE PERMAFROST 1603' MO, 1572' TVO SV6 3311' MO, 3044' TVO . I'<'~. :<'::~ . :'J{'!~~'I:!'I¡,,;,:.:<:::',.:~;:,~f.':'~~~~,~~*;~~~,~~~)i1',:;;;߀i"~~l~«iG_~~~:-t\~i1t~;\'r<t,¥':~~~$.~~~~!I;,1~$i¡i:;<\i,<£~"~.:';i~~j~ ~";~,J'¡;';,,~I~ Drilling and sliding to TD 3514.9. Pump sweep, circulate hole clean, POOH at report time. r-¡ ~i~ '1 . oz. % Lithology Sst Sltst Sh ppg ppg ppg units units units 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: II ~ to to to to --- after Gas during % % % %LCM ,~!ŒÆi~~!I~I~n~:JjI···::,:1'iJ,;iQ,Jl::m:t~:.:.~=t_. Connection Gas and Mud eut ft units ppg ft units ppg ft units ppg J,';', ~" ":/<~ c.: " ,:" "~I'·'';:;>'~'I¡:\'.'~:':.:('·:'' !:,.i~¡;:':';,'''' ", '. ':':~'",--., .'t,o,", ,.,.,¡;:~",p::~";:,,:,.<,,,.,~.,,;,..,. "'''', 0)1, :".:,', -;...: ,\ " '·";~;é",'.r',\!' ""::;·r,... ':,'.,¡ . "':~ Jets: ~ \ ...3Q.. \ ...3Q.. \ ...3Q.. \ _ \ _ TFA: 1.0310 I ',', ' . ".".,', .' . '. ' , ,'...' ", ., ,:ota~.,~~v~ ,~n~.i~:. ,112. '. F~~ta~~ ~~r Bi~ ,~u~ . 3:51,~.. ,~i -~"'~:iP De~:;: 'f;~"· -, ,-, ~7 :-~:::<._."_. ·~'~~~d'~~::"'·'~>~-~::"-"·1 ~~o:·· ;:~.~... .. . - , Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ; _ - J' Tight Spots: to to to Feet of Fill on Bottom: ft ,) ·-:JiL::::::;::;~~.QlIE';"UIC.D=U;¡~Cimt:JC::;=rall:::::~U~,: ft ft ft before after Drilling Breaks % ml Mud Wt at Max Gas ~ ppg 37 Ibs/100ft2 pH 9.1 Sd 2 --- Visc 82 secs API filt 13.5 ml HTHP - - PV 19 cP YI 43 Ibs/1 00ft2 Gel~ 19 / 34 850 61 93 Pump and Flow Data 96 spm DH flow 96 spm Total flow spm AV @ DP 2025 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 3 6/30/2002 3,515 2.511 POOH Smith / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Drill Rate during 16 20.0 Bit Size: Hrs. On Bit: before Depth I t=~:~~y % ( ~ I I ft - units ppg 1 ft _ units ppg ,j ft units ppg ( , ,::::1\0: MX-C1 38 [ Type: RPM: 1 38 Bit No.: Wt On BIt: ( ppg ppg 9.25 9.25 Mud Wt In Mud Wt Out . 1". Current 24 hr Avg 24 hr Max R.O.P, 0 ft/hr 243 ft/hr ( 627 ft/hr @ 1020 Gas* 11 units 20 unit~ ( 56 units @ 2625 Temp Out 72 Deg F ( 72 deg F @ 3514 BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Customer: Well: Area: Lease: Rig: Job No.: I Mudlogger's Morning Report spe.....f'""'v- sun !:J A I LL IN G 5 E A V I c:: E 5 sper-""'.-.v-sun DRILLING SeAVIc:eS Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 ( Mudlogger's Morning Report Current R.OP. 0 Gas * 4 Temp Out 60 24 hr Avg o ft/hr ( 20 unit~ ( ( 24 hr Max ft/hr @ units @ deg F @ o 3490 3514 ft/hr units oeg F o 30 60 ( Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 4 7/1/2002 3,515 o Cementing Smith / Clump o o o Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm oH flow o spm Total flow spm A V @ DP o psi A V @ DC ( Mud Wt In Mud Wt Out 9.30 ppg 9.30 ppg Visc 75 secs API filt 13.0 ml HTHP ml Mud Wt at Max Gas ~ ppg PV 17 cP YI 33 Ibs/100ft2 Gel~ 10 / 20 / 25 Ibs/100ft2 pH 8.0 Sd 1.8 % --- NA Type: N/A Bit Size: N/A Jets: \ TFA: ------ .:¡~:~, , '. ',:¡:"þ., i~':"!"¡~:';'~~!:~i~':<'~'" '_:":~~'~-A_'.~'~~~~~,~~:~~~,~,.:~,~~",",;, ".r., :T~~:~'~:~~~~;~"'~:::":';~~'"'t" ·,:~~\;~~,~r;'L_F~~:~~J~~~.,.~it;~~:,~.~:,~,,,~.,:~; .:.~; (J Trip Depth: 3490 It Trip Gas: 30 Mud Cut . ppg- Trip CI: 18500 ppm Î Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~ Tight Spots: 1696 to 1864 2836 to 3000 to Feet of Fill on Bottom: ft ¡ ,,~m__'i¡~f¡JI!I:.~~:::t::tma:::m;:[~i;;¡'I\m,~' JJ!J¡~)l::1CZ·rld;;~:~J;I:~.n~l!Uflr-~¡I.~II:_ % % % % %LCM ~~¡;;j;~")I]II!I]],n¡¡ LLL:r¡.~;';-· " ( ( ent Lithology: ppg ppg ppg I , , ft units ppg ~----~- ~ ,., Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg '_d...J~=:\D.(~m ~ Iml Drilling Breaks ft units ft units ft units _,~,,_""~'UL.._ ( I Depth Drill Rate during before before after to to to to , J Gas during after % Lithology Sst Sltst Sh ~ í ¡ I W~,~~~~\f¡tf~i~~'t~~!¡,f.:C::~~~~~~~~~~f{~:-~:·_~~~W~~*~~#f~~~~~~»t~;i~~i~-~i!~}I:,,·':p~~~~:ti;,~>t "' 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings: '.~~;~:;!;·~~~~'~~:M~:,:¡\I~~~'\i·;t~~~~,;:,~:ti~f;;'~j',,'rt1J.~w.~,~~~!'t.)~"i,':\'!~~:::;'\~.t.t;t.t:¡¡¡'~~;'i:~:1"i'.'!:';:; :!:~:^'ii:Y,;Ü~*~¡~~~~~~:¡¡;~Ì!IiW,{~'!-.\~i~"t*;~~",<::;1;1Þ~ri1~ti»~:jW~,t.\;~;,;¡Q,~l"~¡.',~, 24 hr Recé Continue POOH, Lay Down BHA #2, Rig Up casing tools, Run 13 3/8" casing, landed with no problem Rig up cement head, Break circulation at 1/2 bpm, no packing off, Staged up to 10 bpm, currently circulating at report time. TG was 30 units. Logging Engineer: Reg Wilson / Mark Lindloff ,"f ~,'" ,.; ~ . :;~;,1~,:~~;:,·~~~:~~~1~: :::'~';';~~;~'~: ~;,....~ :~. ~:f:~~~:~~tf·~:./: ~", , * 1 0000 units = 1 00% Gas In Air ,,', ·r'.,~ ':,.~ I.;~:\; '::;':,:'~'~~?,~~.: .~; ~:,~'.~ ~·:r~~F,'''.:~{~~:~~~~~~ftf;J{$/¡\~h1!:·:': \;·.1~~:~~~~:{}:;:,~:::: .:" ':~ :. spe...,r-"Y- sun DRILLING seRVIc:es Customer: Well: Area: Lease: Rig: Job No.: I Mudlogger's Morning Report ( Current o o 50 R.O.P. Gas* Temp Out ( ( Mud Wt In Mud Wt Out ( Bit No.: Wt On Bit: I Trip Depth: Short Trip Depth Tight Spots: ft/hr units Deg F 24 hr Avg o ft/hr ( o unit~ ( ( BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 o o 51 24 hr Max ftJhr @ units @ deg F @ o o 3514 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 5 7/2/2002 3,515 o RIH Colin / Clump o o o 8,70 ppg 8.70 ppg Vise 47 sees API filt PV 18 eP YI 22 Ibs/100ft2 9.5 ml HTHP ml Mud Wt at Max Gas ~ ppg Gel~ 7 1 9 1 10 Ibs/100ft2 pH 9.5 Sd 0 2 o Bit Size: Hrs. On Bit: Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm DH flow o spm Total flow spm AV @ DP o psi AV @ DC --- Drilling Breaks after before Type: RPM: Hycalog o 12 1/4 0.0 Jets: 3 x 11 \ -- Total Revs on Bit: 6 x 12 \ \ TFA: --- o Footage for Bit Run Current Lithology: % % % % %LCM ~:::ur:-'~~.ti[\-:':L':;:r_r~¡;,l::::m~:tJ[11: !III I W Iii Ilia '·::""I",IIWtm:::~.u:r:::U_I~... I .I~1"~:n::l_"".,".. Connection Gas and Mud eut ft units ppg ft units ppg ft units ppg ft ft ft . :::~J[CJ:lt Depth to to to to k.. ,~ ~\'*,ì;~~~"i-!6~~~Ji. ..V' ,~F~\r~~~ o ft Trip Gas: Mud Cut: ppg Trip C/: 18500 ft Short Trip Gas: Mud Cut: ppg Short Trip CI: to to to Feet of Fill on Bottom: ft lVln·iRJ,ç~ilt¡OOij1I")JvTnl:E::=[['::::~::::Ja:.·:~\U-~~cr~,.... units units units ppg ppg ppg .mIØ.....~¡'X.~~:J." _.....i - l~ ;, ,,~:::~~t:~::~i::::::::~,~::~::::::~~:::~NV"'~~"~~:~'~:..,'~~."%,_,~,,: ,.~, 24 hr Recé Finish circulating and concltlonlng mud, pump cement according to well plan, displaced cement with 1:~: rig pump, ($ 95 spm, bumped plug at 4874 strokes, rig down cement head, nipple down riser, nipple up BOP's tested BOP's, Good, Pickin~ up BHA #3 before Drill Rate during ,~ , Logging Engineer: Reg Wilson 1 Mark Lindloff 1";;' ft units ft units ft units ~¡,,~!.;;;::=~':~~; I fA!! I n'I::C:.~,=-L. ppg ppg ppg .. 10000 units = 100% Gas In Air :l~ ...,,:.,..... '.. ,,~"~._ . , ".'''0..''-'.' ",",,' ",'. ..,,,. "..,. ' ""'..,~ " ~'-.,""" -.' ./6i ";, .,'. ':';;'.~'}<:.~,;···:.';:;'.:'¡~,.;:~:r·f,'~~A..~:~fjJ~~i;;;Ö:/3;~~~:!~:-,t;~IZ~--:·tØ,)t,.:,~~~·,\;,! ;':;¡',.~',~~¥ Gas during after % Lithology Sst Sltst Sh , " ¡¡¡: .. 5pe..........,y- sun DRILLING seRVices Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report ( Current R.OP. 193 Gas* 36 Temp Out 64 600 122 64 24 hr Avg 268 ft/hr ( 36 unit~ ( ( ftlhr units Deg F ( BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 24 hr Max ftlhr @ units @ deg F @ 4052 4922 4955 ppg ppg Visc 64 secs API filt PV 19 cP YI 30 Ibs/100ft2 6.5 ml HTHP ml Mud Wt at Max Gas ~ ppg Gels 10 1 14 1 16 Ibs/100ft2 pH 9.3 Sd 1 % Mud Wt In Mud Wt Out 8.90 9.00 ( . " ....,<r.. . ", .t~~ . '..1..::, .. .... r, " '.. t,~.:'.O- .: "". . ::.', ""';-" ',." .,.., ~'",,:r '. ,;:': ~'l~~;'~ ,:,'. I' ( . Bit No.: Wt On Bit: Bit Size: Hrs. On Bit: 2 10 Type: RPM: Hycalog 139 ( Trip Depth: Short Trip Depth Tight Spots: to ft ft Trip Gas: Short Trip Gas: Current Lithology: % .-,M=~:,.,....~~~_- mUIJ . _ "'X"LI,.....:,L:':ï .." % 12 1/4 9.0 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 6 7/3/2002 5,002 1,487 DRILLING JOE/COLIN Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 110 spm DH flow 105 spm Total flow spm A V @ DP 1910 psi AV @ DC ,:0\ ~., . ,;''''P';:,,'''',:· .: Jets: 3 x 11 -- Total Revs on Bit: 6 x 12 \ \ TFA: --- 71 Footage for Bit Run to ::J .t~C"=t:mJJ:" ..__.~^ Drilling Breaks after before Mud Cut: Mud Cut: to ppg Trip CI: 18500 ppg Short Trip CI: Feet of Fill on Bottom: % %LCM % ... ~,'WII.-.~. I ( ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ml~ ¡ ClllIr.JI!!IL. i ~ , ft ft ft units units units I 11"'-'''--1'''-..-_ u.;:.;:,; . ·lD.llIIl.JI!^ I Depth Drill Rate during before to to to to . ~.... ''- > ~,,~I. Gas during ft units ppg ft units ppg ft units ppg j [ ~~.... % Lithology after Sst Sltst Sh 909 173 259 '.¡,¡¡ ?-~ ~',,- ..'r¡ ''''". ~, ..~, .,' ~ 0.941 0 1 ,487 ppm ppm ft 1<11 '?J' ¡'i 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. , :~J: Description of fillings: ~ ' <"':0:,,.··.. .:··,:~.;''..;',::;~.t~":;~,,¥ *4~.i~~:$;¡~:;~3~~¡f1'it~'ii~i:\~~~~~~i!i'ìr~~$:';~:\I$,~·~"~:::'~t~:;'.,~;;!}'07ti!:í':_~~~!~)~~~,$;;t.~¿.i.~~~:~:~\i~,~i;,,;~;,~~;k~~.1 t:,:.'":.~1ìy,t~1 i . 24 hr Reci RIH with BHA#3, washed down to 3409' - test casing for 30 minutes, OK. Displace old mud with new mud, drilled out shoe, rat hole and 20' of new formation. Perform FIT test to 12.5 PPG. Drilled 3535' to 4300', Flow line plugged, shut down to clear line, continue to drill to 5002' MD. Formation Tops SV5 3622' MD, 3310' TVD, SV4 3989' MD, 3622' TVD. SV2 4443' MD, 4012' TVD, SV1 4886' MD, 4400' TVD Logging Engineer: Reg Wilson 1 Mark Lindloff Î ;1' :1~i * 10000 units = 100% Gas In Air ·I"~ :;~ :: .. c"";AI\"~..~:Ii'~;¡~'''''!--c':M...:~..''''- ,..,;:~~""','h,'".. ~~.., ',,' I'i!t', i,:.>,~\" ;.:<!,~~~~~~~l~t!1~,~"(J}·,\1~. ;.~\~:.17;\'~~.,..~J·"~;,~~~~i1'".. : t ~';J; ~! , .' . .;." .~i~;::.i:i.t;¡;<Ié:\\::;::~<,/i~~~r(~~:~~:ii~~~~,~t i:~:;;~~~fÞ:'rti:.qrJ.'?~~~!¥;~'t~N,~$?·:f"F.¥i:~i\J·;·.i:·::.~·~:,~,~;/>:~: 5pe............v- 5un DRILLI NG SERVices Customer: Well: Area: Lease: Rig: Job No.: [ Mudlogger's Morning Report ( Current 172 64 86 ( ftJhr units Deg F 24 hr Avg 238 ftJhr ( 79 unit~ ( ( 557 502 86 BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 24 hr Max ftJhr @ units @ deg F @ 6354 6142 7154 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 7 7/4/2002 7,383 2,380 DRILLING JOE/COLIN Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 105 spm DH flow 105 spm Total flow spm AV @ DP 2190 psi AV @ DC 888 169 253 gpm ":'; gpm '~"~ .~ fpm % fpm:,; 8.90 ppg Visc ~ secs API ftlt ~ ml HTHP ml Mud Wt at Max Gas ~ ppg 9.00 ppg PV 14 cP YI 26 Ibs/1 00ft2 Gel~ 8 1 11 1 13 Ibs/100ft2 pH 8.5 Sd 0.5 % ;;~ f' ~ ~, ~. , . . . -. ··...:~.'.~I.'~.·.~.~.:~~ ;"'.. '..'... ..~ ::,,,¡"·':./...',o1tt:"\~': '~. '. ......' ;......:.:';'·~I,',~~~:I,,;.~Mì,"l "":".""...~";'~':,',,'..; : I.,~. :..... -~., Jets: 3 x 11 \ 6 x 12 \ \ TFA: O.9410'JI Total Rëvšõn Bit:- -:¡eZ - Footage for Bit Run 3.867 i ';';';: ,". .:~~i:'''-''~I'''' ".!r.!~~:":.¡'.}.,~-~ "M.~".<,\' '~;"· . <,¿i" ':~ ~.,'. '.;"",;~'4.f',."-iJ;,.~i'·~4~~·I·.(.*:·;)¡.'"'{''' '~.~~'¡)!-¡ f('~;O'~f'~-,' ~.;,~, ~-, '.'. ~~~~'-.;~.:;.~#.'~~' ':';:"~r'At\1C'~¥';"': 'o::~"'~i;\i.'",e.:;. .;~;~~+ ~ Mud Wt In Mud Wt Out . 1,.\ '._,~ ( . Bit No.: Wt On Bit: Trip Depth: Short Trip Depth Tight Spots: I [ ft ft ft Depth to to to to , ~.:, . '. ' ' ,,' ; . . . T,' l' . ":... ~,. ~I:~ :.:,.·I::;!..,.::t'~: 'IS' ...,..... ". 12 1/4 29.2 Drilling Breaks after before Mud Cut: Mud Cut: to ppg Trip CI: 18500 ppg Short Trip CI: Feet of Fill on Bottom: ft ft ft Gas during after units units units % Lithology Sst 81tst Sh "'{f. :1::) ppg ppg ppg ¡ " ·..:'~$:~~.~~t~·~~í¥;:_~~~.,_~~~~~~~~~~~;q~~~· 1~·. '.. ~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. I Description of fillings: ,);~~';ï,;-C'!:~~·(;\··1!i:ii,~'·¡!!;~;:9"'~'*;¡~'~;$ir.¡;:r,~:,,¡''1OR.'~~:liM¡¡~~~ð.~;.:A),'f~i~$'~~~~~~i·~~~v..~~~!{~~fiitili~·it~:'A~t?jt~I;~'f;!.;~~~ø~~'".::;'?-~~~~"5:~:~~~'Z::·~,I~·".:' 24 hr Reci Drilling from 5002' MD through 7383' MD. Periodic hard streaks were experienced around 6967" MD .1~IJ(~tm:.~t~~:c::t~lm~J.;;j,~;~~",.r:1lItX]r:-~ Current Lithology: % % % % %LCM '. :~1::Œ:i:::li[~!r)r:,~i1.ì.JjIl.,llJ.jlmJ...t,,!nR.».Jl,!U.r,w~.L."J,:mj~=:r:r:rIE!])~lmt I 1~lj i.·,::~ì~)E:;iŒ··. eonnection Gas and Mud Cut ft units ppg ft units ppg ft units ppg 2 16 Bit Size: Hrs. On Bit: Type: RPM: Hycalog 134 ft Trip Gas: ft Short Trip Gas: to to units units units ppg ppg ppg before Drill Rate during Schrader Bluff 7073' MD. 6323' TVD Ii ,. ,.~~~:i;~:~~:t~,;;:::,;:~:::n';=;:~;1B';',~~jf",~fH'"\é¡;"~'W&~~;i(~~'a~~t;~~~;~~~:;~;':''.~;i~:~,,~:;¡:~.~~:.J to ~ ~ ~ ----'i ~ ' .Å~·".'f';!':.." ' . "'¡;"'1ì ('" >, ,., I...~¡¡,~'·"'O!~ '.',!t!' ',~.!.... ~'t" ~ -AI'" ' ""Iifì"~""~'"' :.~" 1-,·1 ':~':I': , I I~~.."" " ~I. ~ .~~ .Ø'.~'\lt'1·.... :\.!.".' ~ :¡. ,:.t..., I I rI0' 'I. ':... ":,, ...,.~.J\"..~~~,.h~,~~~..~,..~¡\,.l~,.~.~'_~,J..~~'";>~,j ~,~, ~ . i~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ' -N \'. ';'; Description of fillings: j ''lb. I,·'tl·~ , ~ .¡¡¡ I :i,~ I Logging Engineer: Reg Wilson I Mark Lindloff · 10000 units = 100% Gas In Air .1 . . '. .... r>:;~'þ~Q~1?t:;~>r~';~t~7:Y::~}~:::~':~ ~ ..:'.:'\'.... .~:.! -.' ',,:::"; '::~.·-:~·)~;;:j1!l#1t~:~~;;·;,~:~\A~~~~~~;:.:11·/:?~;y~f~\f::;~~:·::;f~~~þ~~~~~~~:~1t~V/~V:l~~:~~~~~~~~~:~:t7i¡:;:.~':',.~,::¡~~ ', ,¡..~~ii:"I.ttiö::l~!1:~:"ð~~:~':!1~;-:~~;":ì¢,;"".~)):,',;i·:i:::;,,.~;·::.~·~f:'ii¡~:.~£rj..;'.:.:ß~.~~' 1¡i:~"*',tri'~:";-~:~i\.,'(,,¡;;¿~~j~;},{'1':ï\¡.\.\t'w-#,;~~~~.}f¡;'{~!.¡~~t~_~~~'~'?:'~;S,r,'" 24 hr Recí Drilling from 7383 to 8817. Serviced draw works. Cont to drill to 9300' MD, begin weighting up mud to 10 PPG. At 9420' MD a large piece of rubber from a sabilizer was found on the shakers. POOH, replaced damaged stabilizer, RIH, and drilling on. Colville 7683' MD, 6891' TVD HRZ 9634' MD, 8604' TVD Mud Cut: _ppg Trip CI: 18500 ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft ¡ 11...,<itl.j~]'iIBL,~lJi'..~,"L!:~~]) .~~m U , JI11t1lI11.';,a~.1W1t~tøœ1.8(r Current Lithology: 50 % SH 20 % SLST 30 % CL YST % %LCM ~ _~::or::i¡Imw:c~l:D:::~==-£':::: nll]![ ¡¡1m [or:::r:D1:r:r:-:.:::::nm[ ml~1I1II11 [I.~iII] i~]l1ß n¡r:::::"~",=-~~~~",,. -¡ % Lithology Sst Sltst Sh Gas during before after Drill Rate during I after Drilling Breaks units units units ft ft ft ~=- Connection Gas and Mud Cut ft _ units _ ppg ft units ppg ft units ppg before Depth . ~ L ;';' I units ppg units ppg units _ ppg ~;;d[';¡"'l--'\'" ft ft ft ( I to Trip Depth: Short Trip Depth Tight Spots: I to Trip Gas: Short Trip Gas: ft ft Bit Size: Hrs. On BIt: Hycalog 163 ( . ;..~ .- .~' · :....'r\I:~·,;>;*'-~~·,~.....t,~...;¡..:,\,~i-·~·..,¡, ,:,;'o::·..::~~"þ"'i".~~HI~.·'~~''¡''~~~'': ·:'~':::·:'''~~~~'~!~;;'J~~~.~~It'~<~.,\:·>~Jt1'1'\>;","'''' ,~..~~..\,.;¡,,~ .,.~~(,.,..(.;t<~.,~.;,~... 0.9410 5.922 Jets: 3 x 11 \ 6 x 12 \ \ TFA: ------ Total Revs on Bit: 278 Footage for Bit Run 12 1/4 43.1 2 Type: 16 RPM: Bit No.: Wt On Bit: . '. ,. /',:. , .~ " , "r·",f,t...¡,~ ~ ~'",<:':.' ',:~'~. \'1.~J~~'>':": <·-:-t. . :..:. '.~ :'~ ' _ '. "'I.",:",. ;, .":; u '·'.'~I~"'·I'.:".~. ~, " . ~"'~ ~}.", r,' ::"'1,~1 '1,1 ,I ".,'~r:':.:I,._,~:::.~ --- 3.8_ ml HTHP _ ml Mud Wt at Max Gas ~ ppg Gels 10 / 17 / 19 Ibs/100ft2 pH 8.5 Sd 0.1 % 10.00 ppg 10.10 ppg Visc 48 secs API flit PV 20 cP YI 30 Ibs/100ft2 Mud Wt In Mud Wt Out :'/' . '" ( .' , . "'~ ...:- ' 'J " . . "::J',.::"\, ~ '. . ;~. .. ..:..: .~ ," I " ., "', .... ~'..' ':""1':"',,:"": ...~,,' .... " . ., . .. ·~L· . . 901 171 257 Pump and Flow Data 106 spm DH flow 107 spm Total flow spm AV @ DP 2860 psi AV @ DC 9294 ) Pump 1 9315 ) Pump2 7154 ) Pump 3 Pump Pres 24 hr Max 294 ftlhr @ 610 units @ 86 deg F @ ( 8 7/5/2002 9,438 2,055 DRILLING JOE/COLIN Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 24 hr Avg 146 ft/hr ( 130 unit~ ( ( ftlhr units Deg F R.O.P, , Gas* Temp Out Current 134 120 86 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sperry-sun t:JRILLING SERVices ( ( ( I ( I I I ( spe....,...,v- sun o A I L_~~~__ 5 e A v I c:: E 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 ,~~ Current 24 hr Avg 24 hr Max R.O.P, 0 ftlhr 136 ftlhr ( 366 ftlhr @ 10080 Gas" 71 units 697 u n it~ ( 3491 units @ 10022 Temp Out 86 Deg F ( 86 deg F @ 7154 ",¡.. ···.c .' .... .<c""........,. ..' "'.:'.', <;::. ...''''': , Mud Wt In ..... Mud Wt Out 10.10 ppg 10.10 ppg - - Vise 46 sees API filt PV 14 eP YI 28 Ibs/100ft2 5.5 ml HTHP 11.0 Mud Wt at Max Gas ~ ppg Gel~ 11 1 17 1 20 Ibs/100ft2 pH 8.9 Sd 0.2 % - ..',.".. ". Bit No.: Wt On Bit: Hycalog o Bit Size: Hrs. On Bit: 2 -37 Type: RPM: '.' ~" !, ;. " .,' '.' Trip Depth: Short Trip Depth .. Tight Spots: ft ft Trip Gas: Short Trip Gas: to ,.,' , Current Lithology: 50 % SH 20 ft ft ft L.., ~JI:t:IIU,,,_ units units units ppg ppg ppg - -,~IRIiI¡II!.." Depth Drill Rate during before to to to to Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 7/6/2002 10,460 1022' POOH JOE/COLIN Pump and Flow Data ) Pump 1 96 spm DH flow gpm - ) Pump 2 96 spm Total flow 897 gpm ) Pump 3 spm A V @ DP 170 fpm Pump Pres 3110 psi AV @ DC 255 fpm .. - ,..,. '" '" --- 12 1/4 52.4 - Jets: 3 x 11 \ -- Total Revs on Bit: 6 x 12 \ \ TFA: 0.9410 ---- 363 Footage for Bit Run 6944' ". .' ,. "," " , If Mud Cut: ppg Trip CI: 18500 ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft J:,::.=:rr~m;;;;:.~~~'I~::ll~¡!JI1~=:U::J....,kÙIlÚ"..~ SLST 30 % CLYST % %LCM to % Drilling Breaks after before Gas during after % Lithology Sst Sltst Sh ':::~3~1:.,¡;:;.;nm~~JU UIUIUUi:¡:'_l,¡[§""ULL! .·L-:rl:::JJIIlI~;:::·,~ll~~~fi!.~~¡w::JC . , . Connection Gas and Mud Cut ft units _ ppg ft _ units ft units _ ppg ft units ft units _ppg ft_units _ I~l[,::.:n."''' 'r:.~.~~1~~~3i~"-- (i:~-=" oz. it 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fiilings: ,/ ~,t~':' .,,~~ ~ - - ppg ppg ppg .... '." ..··.,<t~~:·;:7:'".;,·::¡·~;¡''n),i<!>~~~~~N:~·'!;~.~iÌ:f,~},~:N:$¡::i\é\&f~fl$t~:ei~jîWil1t~\'.\$."t:\~'f,~~f::í~~ï.!!X~'¡';;'>.;tM~t~~\~~:~9Þf;~_:~~t~~~~~i':~:~~;¡;'~;,,~~!:f,~~~~'i~~ , 24 hr Recé Continue drilling F/ 9438' to TO of 12 1/4" section at 10460'. Pump sweep, not productive, try circulate hole clean, POOH 10 stands. Slug pipe. POOH to 7850', begin pumping out. Currently at 4850' Abundantly large pieces coming over the shakers. Base HRZ 9740' MO, 8694' TVD, Kuparuk 9788' MD, 8736' TVD, Kuparuk C 10030' MD, 8943' TVD, Miluveach 10396' MD. 9260' TVD Logging Engineer: Reg Wilson 1 Mark lindloff I, , * 10000 units = 100% Gas In Air " .~'.;~;.~ ". ~\!'~(~·::'.~?!i·~~~:;,:·Y:~· ::'~.~'¡~'~! ·;;:\~/!;.";!~:;::::·¡':\>:~Ti~~qh~:::·?;<:·~~Jt;?::i ,:.tifX:",·: j\::"..Y:::'t:~;~I;.\;>'¡ ';{",~l:~£~·''¡t;;.';;:{:~t!~!''~~~~~~:·;¡;:'¡!~~::!:~;\iI$?~]œ~~Y:;¡i.::t ~ I I I I ( [ ,( I I I ppm ppm ft Current Lithology: 80 % SH 20 % . :C:C:J:1.1:mmJ'frm. 1I1I.:~:~t:·-'-3¡;~'JI:C1&l~, III ~..mll SLST % %LCM :; o % rh. ~ I lilt: .1111 ^-::"~,r:^,.=iI II iI . 5pe.....,.....,y- sun DRILLING SERVICES Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 10 7/7/2002 10,460 o LID BHA #3 JOE/COLIN r~·"'·,,\!"'~~ ~'~~};:~'" ;t~i,~,ß;.~~~~~r.w:~.fj~~·.·~ ..., ~1 , '"r' . ',,~,. ",'. .,', ,.".~H~~~_~t~~~~{J,; '¡II 24 ho~r ~ccumul~tion of Steel Filings from Possum Belly Magnets: oz. :~;ì:1 Description of fillings: ..~~,~ .: . :,~::.;~. ;:\.'1,;.~¥·.,!~,~<.~~,;r't;1~~~~~;'~':~~~'~~~r;~.;.~~~'ti\\;~~'1.~~~~~.ì:~~~~~~~~~'#ií:~¡tf'.i~j~?t:'~Vi¡tþj,~.* !f¿~.:a~~~~~~~~Jj~~~:INI.¡!lð\~!~fÄ:,:,,!;j~";~'!' . 24 hr Recí Cont to POOH to the shoe 3549' MD, Shoe packed off, established circulation, Huge quantities of large clay balls (2 to 5 Ibs ea) and cuttings passing over the shakers. Packed off possum belly and drag chain, Cleaned up and ran back to bottom. Circulated bottoms up, mud level fluctuation within the possum belly prevented a good reading of trip gas. 979 units was the max that was captured. Circulated 2 Bottoms up. POOH, washed and reamed our way out out from 10323' MD to 10050' MD, currently laying down BHA #3. Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data RO.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 Pump 1 0 spm DH flow Gas* 71 units 697 unit~ ( 3491 units @ 10022 Pump 2 0 spm Total flow 0 Temp Out 82 Deg F ( 98 deg F @ 10460 Pump 3 spm A V @ DP 0 Pump Pres 0 psi AV @ DC 0 Mud Wt In Mud Wt Out 5.5 ml HTHP 11.5 Mud Wt at Max Gas .J..Q:2... ppg Gel~ 9 / 11 / 15 Ibs/100ft2 pH 8.9 Sd 0.25 % Visc 43 sees API filt PV 13 cP YI 21 Ibs/100ft2 10.00 ppg 10.00 ppg -- . r.· . .....~.... ..',.r"':,"a Bit No.. N/A Type: N/A Bit Size: N/A Jets: \ \ \ \ TFA: - - - - -- Wt On Bit: 0 RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 " '. '.'::;\.:..,...~' ;~··;.~'·:::Jli'';';!'õi'-:i-I~ -~ ;.-" !,~;ç,~i ,;;;':,,;;:...:¡:~,~Ò~;.> ,;¡o:....~..<,,:t;Ii.~,¡,\..~,t:~,·,~;··;., ..:.. .... .'.'. ~,;.+'t~~f.,;4~~ -;';:~~"i<~t;·}: ..r;t">~ ".'(.. ,';'r'.~,. ..,. ". ";,', Trip Depth: Short Trip Depth Tight Spots: 10460 ft Trip Gas: 979 Mud Cut: ppg Trip CI: 18500 ft Short Trip Gas: Mud Cut: ppg Short Trip CI: 7850 to 3515 to to Feet of Fill on Bottom: .., ._~,..~:1:ff~~S~I1i.~~.\t.lIIJf.:.:I..~ ft units ft units ft units ~'Jm~.,flt::~u:::.1I!,.,,_ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg """"",~'"'' ft units ppg ft units ppg ft units ppg IJC:JIC::' . % Lithology after Sst Sltst Sh ppg ppg ppg JI;J;~~ Drilling Breaks Depth Drill Rate during Gas during before after before to to to to ~" ~ ~.;~:,\.t~>~'J~'¥:~:ë;'.;~: i:¡(~/¢:';;'~~.:~I!F.~:'~''l~¡:' , ;. :;~·:.\;~~~;~~t~~~!,~:~~,~,~~~~~1(~?::.,,:. * 10000 units = 100% Gas In Air ~H ,> ~ ~ :'/,' ~:~>~~.:.,~'."- ~~~~ ~:~~.17~~'~(:~-~:·~~~r~if~~~ ~~~}t;¡J~~fl;,'~~~.:~~:~1,,'~~/lt:~~:~: ¡~~' ~. 10, ~ : .~~"~J Logging Engineer: Reg Wilson / Mark Lindloff ~ 'I· jf, 1:"'. , ·~r1· '·"··i'· "::;)" I·, '; ,j '. ~ 'I, ~ ...:...'..'....:: ',~ : I :tl Logging Engineer: Reg Wilson / Mark Lindloff * 10000 units = 100% Gas In Air I " . ;, " :',:.: ":'.~, ., '..," ;~:~:'~·:;,..;..;m;?!}C_··.:;~k,1J',<,.¡¡;,J.'~'if.f{. },'~<¡,:,r>';H:1,:'.'J;;:,~'1"!;,'<:':'F',~,"~~Jj;¡;'\~C1; ç.,.;!¡,·j~v:~:{ì';~g,,,"4'1;~;¡¡~;¡¡¡,~~.'r,:\J~.~;.~,!~1iìI.~,¡\t¡¡.¡¡¡!¡y~;)~:í.i,f~·:~;~rtk~ìØ!\¡:}·;~y~tj:· ,:"".:",;;' ;I~~;: . _'.. . . -.: . ~ ,0 't,.., ~~, ;. 7'f:"~ .:j~,:,'" :..'~;~,.'~'~'Ü'~""~~~~~·~~':"'-: ~~d'I-:"'':¡ '::¡:~t::.~t.3'~~Jtr~ ". ,~. ..Ii,..~ ,.'~';:~";~·~\LW,,,·:'...~~-; '::)~:<rJ'~"J~.~~I~~~'WJ.,,~;-~r:~1rPj~"'~I\':"""'" ..~"~:J"'~'~~~~~~:ijo:t:~,~~f,~~t..~. .,..:Jf,¡~V~1\ì.j.j,L~;(~~t~,i,~-<· I., .t 'r'...fJ:~· hr Recé RIH with 9.625" casing. No problems. Gradually established circulation up to 12 BPM. Circulated two casing volume with 2580 units of max gas. Lay down casing tools. Rig up cement equipment. Currently preping to cement 9.625" casing. . .,"';l.";': "0' ", '" '.;~~~~"'L;' ·:,~,".·;''''·:'''' :'·~::r.fJ'r.¡>'~:;~~:~i:,'~"""t;>,¡i:','!Ii*~~~ .""f.~,y;~¢,,:·~·.~;~:,¡#!*,;:.~:"''';':.('':~I:~·~·Jlit~~;~:iut~·f'J.«i\~~~~:~':~:;~t'l~~'~,~~~~"":",;'; :~,", ,¡: :-..,. oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ft units ppg - ft units ppg - ft units ppg - :UDU:3 % Lithology after Sst Sltst Sh Gas during before after to to to to Drill Rate during before Depth ~.~ .\;. ....'!- I I I Drilling Breaks Connection Gas and Mud Cut ft _ units ppg ft units _ ppg ft units ppg ~ II ft units ft units ft units ··-·-·:':"~"n~l.."...1ð::.:..v.._.,'" I .~~~~I ~-!.~~~~=-n__nu':;;.D:m!lj~;~:;U¡:- li,~'1II1WIIII""30"'~ ppm ppm ft ppg Trip CI: 18500 ppg Short Trip CI: Feet of Fill on Bottom: 2580 ppg ppg ppg to to Trip Depth: Short Trip Depth Tight Spots: Mud Cut: Mud Cut: to Trip Gas: Short Trip Gas: 1 0453 ft ft -'i ··oJ': I.:,~,,' 1\o\~..~I_.. ,_',1 ~·'\o:\,^~,i~·~~~~,,:";;'::~~~~~;\.:~~~):$~'~;1-1t~~~~~·~.~,~.,~ ~'~;:.~:rt;~~~~{~.~ ,.~ (:1.; r" .',~ç~.~.þ'''.i~~~~~:'~,\-: ",:~~~'!_~.,.'..." ,~·tj;~:·:'f,:'::'~!_-··:~....4Þ. ~.:' "¡...JI/ o Jets: \ \ \ \ \ TF A: ------ Total Revs on Bit: 0 Footage for Bit Run ... .~. .~ \" I N/A 0.0 Bit Size: Hrs, On BIt: Type: RPM: N/A o Bit No.: Wt On Bit: I ~,,jI. ( '.~::.~.:';.r:,~' '~.,.'";, .:. :",.~. ,,'\'~',i.·~': ""'''.~..' :).~"'~".'~"'_.'''. .. !~'.,',..,";"',::.:'/ ~ ~ '. .;" ~~.. ~.,.~.:} ~~. --- HTHP ~ Mud Wt at Max Gas ~ ppg 7 / 10 / 12 Ibs/100ft2 pH 8.5 Sd 0.25 % N/A o """.'. ,"," ~\ .ò. .t:....~, '" ", ":~~,,, . ,"-'~'I, ' 1 0.00 ppg 10.00 ppg Mud Wt In Mud Wt Out ( 6.5 ml Gel~ Visc 49 secs API filt PV 11 cP YI 19 Ibs/100ft2 ( Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow Gas· 16 units 196 unit~ ( 2580 units @ 10453 ) Pump 2 0 spm Total flow 0 - Temp Out 74 Deg F ( 80 deg F @ 10460 ) Pump 3 spm A V @ DP 0 - Pump Pres 0 psi AV @ DC 0 11 7/8/2002 10.460 o Cementing JOE/COLIN Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe""""'y-sul, r:J A I LL IN G 5 e A v I c:: e 5 I ( I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12 7/9/2002 1 0,460 o RIH W/BIT # JOE/MIKE spe"--'''''y-5un CRILLI NG seRVIc:es ( Current 24 hr Avg 24 hr Max Pump and Flow Data RO.P, 0 ftlhr 0 ftlhr ( 0 ftlhr @ 0 Pump 1 0 spm DH flow Gas" 0 units 0 unit~ ( 0 units @ 0 Pump 2 0 spm Total flow 0 Temp Out 70 Deg F ( 75 deg F @ 10460 Pump 3 spm A V @ DP 0 Pump Pres 0 psi A V @ DC 0 ';". '",' . I, !#~. I, .'.,,: ,;.. ~,,,.~.; ;< . '.;'''' . - ',',.' -,:,;, ,"';'" ,\" -:: +' ....,. ~:" :'~: .,'C". '~ ..'I~\ ".~ ":~ '~~.r.... '" ..... . .' . . . .~. '. ..'. :4.:' I'... .. .':'. ,,"~n. ( I Mud Wt In Mud Wt Out 10.00 ppg 10.00 ppg Visc 44 secs API filt PV 10 cP YI 18 Ibs/100ft2 6.6 ml Gels HTHP 0.0 Mud Wt at Max Gas ~ ppg 7 ! 9 1 11 Ibs/100ft2 pH 8.5 Sd 0,25 % -- I Bit No.: Wt On Bit: 3 o Type: RPM: HYC DS70FNPV Bit Size: o Hrs. On Bit: 8 1/2 0.0 Jets: 13 \ 13 \ 13 \ 15 \ 15 \ 15 TFA: 0.9070 ------ Total Revs on Bit: 0 Footage for Bit Run 0 ~~ .:. I Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 19000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ent Lithology: 80 % SH 20 % ¡;:.:~ IIUIIII ~~.~::-t ,rJ1::rn:I::nn::;I:~:::¡~,.¿;..;;el!.~~¡;C::;~~~It;xn;::r~::.u:. :'.;. . '.:..... ·J/·~·;;):\>'ftM."{(,.ç,+i,~~~'!;~;¡:~i£~~,~~'¡)~~¡..~z:¡~~¡¡ì\ti-);¡.'i,.'jI¡,!,;;,·)r,:tï.~>;i~i~iI?,;~;'\Î~'f..:No1!iö~~;¡~';:"'ii~~ì'0ii~'~{I,;t.~~4'J,$i\':¡' .i!';~~&.~;-:K~:':t~,*r~ki~~¥,.~I~~"'í~~!;'; . , ( I ft units ft units ft units <4fWP"lllnu a 1-: M".._ ,..".n- R1 ppg ppg ppg n : I I r.::UD:IT:::::J::n Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ___Il:.I,J!'\t.... before Drill Rate during after before Gas during ft units ppg ft units ppg ft units ppg U!tL % Lithology ~ after Sst Sltst Sh Drilling Breaks Depth to to to to '.~ .. ,.."i . , ,.~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. i.":~:;f,T:\';¡I1~t~{!~~~~~~~HÇ~~~0¡t!*~f~ii,;;~W~~·~~:·%¡$~Mit~~~~:1(';¡}-Jr,:;¡,;..,·:,¡~.,·,¡:~·~~$.ft;~~!>~~:~tÎl::M*_~fi-~.~~W;i;.\:~,:«'~.,~'J<i\~(~i\t.~~~_h~þ.'·;:· .'-::; hr Recé Complete cement job - displace cement with rig pumps. bumped plug at 7431 stks, trace of cement to surface. Rig down cement head and casing equipment, set pack off, inject 230 bbls down annulus Test BOP's. Picked up 8.5 BHA. RIH. Logging Engineer: Reg Wilson 1 Mark Lindloff * 10000 units = 100% Gas In Air ( Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 13 7/10/2002 11 ,249 789 DRILLING JOE/MIKE 5pe"'~Y-5un DR I LLI N G seRV I c: e 5 I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P, 102 ft/hr 90 ft/hr ( 257 ft/hr @ 11171 Pump 1 72 spm DH flow Gas" 73 units 62 unit~ ( 375 units @ 10466 Pump 2 72 spm Total flow 515 Temp Out 104 Deg F ( 104 deg F @ 11260 Pump 3 spm AV @ DP 251 - Pump Pres 2800 psi AV @ DC 473 ( Mud Wt In Mud Wt Out 12.00 ppg 12.00 ppg Vise 50 sees API tilt PV 29 cP YI 26 Ibs/100ft2 6.2 ml HTHP 12.5 Mud Wt at Max Gas ~ ppg Gels 12 / 44 / 50 Ibs/100ft2 pH 8.6 Sd 0.1 % -- ( .0" Bit No.: Wt On Bit: 3 21 Type: RPM: HYC DSìQFNPv Bit Size: 8 1/2 Jets: ~ \ ~ \ ~ \ ~" ~ \ ~ TFA: 0,9070 :,~ .' ...., ~~"i'" HrS,'~,n ,~;~"o;,;~; " ,:~,tal :~V,:.:~Bit:, " .,~~:O~~:: ::~:t,:~n ," ,~~~."..J ft Trip Gas: Mud Cut: 'ppg Trip CI: 51000 ppm t ~¡ ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~ to to Feet of Fill on Bottom: ft ï .'" '~'T"', ~ . /,.:",~'r.·~.I""S~';~:~: I Trip Depth: Short Trip Depth light Spots: to before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh %LCM m:I3~~..~~",1ie~:I!,!I!IJJ¡,lI~~JI.lii(,:;;', ( ,... ,. I i+h"l"n\l' 20 % SH 80 % SLST o % % ..., '~,~-';~~,L~.,JID~J,Ll.",_?C\1Bn~~, Iß~œlllllm~.~J)I;~Hm:;;;.;..-:" ;~ ft units ppg ft units ppg ft units ppg -·'-rtt;"---.~ICII:;nrIa"':m:-J--JJ;;¡-=- Connection Gas and Mud Cut ft units ppg ft un~ ppg ft units ppg _ "l\\\ua_~~&;;;;~:""Irr ft units ft units ft units 114~'::"'1l~_ro>:r.. .. ppg ppg ppg ( ( Drilling Breaks I Depth I to to to to iI~$.{~~~~:W!Im;ú::~~~L~,""'~"'" ' '.' " :'V>~ ~'.'~ ·'~~.j1lro~~ _.' . ; 24 hour accumulation of Steel Filings from Possum Belly Magnets: .... Description of fillings: ':',',:~~~,' oz. ;'".i·;j{i:,: ','¿;;' '::'":~:~,~;.'~\~;lJi!j:.',(,~1'1'ft.·:,,,$~:(;ë":-;:iWP¡;~:~\':$}W';'~i.,l'ì'('4~*"~HW;;::~;i:i:;'~f'~ž;i'(,'i.t-,\,"'..;~~.~:;;';:~'~(;J~~í&i~~~~~~¡;¡i,~~~~::¡I"!'~!:;~;'i,l, '<\':':'A~~.-q~:~;!\f¥-i1i-~r.:,.~¡¡)~,/ . 24 hr Recé Drill ti float collar. Tested casing, Passed. Drill thru float equipment and cement. Brought mud weight up to 12.0 PPG. Run FIT to 14 PPG. Drilling 8.5" hole. Kingak 10976' MD, 9779' TVD Logging Engineer: Reg Wilson / Mark Lindloff * 10000 units = 100% Gas In Air J ¡.t , :' ~:"~' ~,,:. <,-" ,,?,,·~~;·~··~:t:11;;:~t~7j.?i.~.';~~~~i~0rf\~;':~~Ii:::~:~;~~~[~~';:~~~~~~:'f~~~f~:Îß~~I~:( ,,;':. ..:',~" ";tii*N,:;~~~·;~1d~~tJ.!i_.l~~t:,"~,~"~¡:t~~~~~~~~~,~~~::'~~:'.j~,;~ ;:' * 10000 units = 100% Gas In Air ,¡ii, ".·,'i;i:~:,.~~.7i'I;.'~"'~~~ï;:~¡%~'~::~~~):;~~~~~-1~~40j~~i¡'<1!~~;tj!:'~lti\t,Ï ;~~l,t$,'ft~$~*~r¿7.·}~~~J.·:~~?[n'j~~· ~:~:'. ,~}:',~'.{i:~~~rf!~~~,:~~¡j:;',,*i~~:·:,·~::;,:\¡~'~1~~:~!;:\~" ~:,:~":1¡~tI Logging Engineer: Tom Mansfield / Doug Wilson '" ~ Sag River @ 12064' MO, 10803' TVD ¡~,' '··:~~:~'"'::~!,,~,~\i!'~';i'¡ :;j~1.i;~l';".~ ,~~t(:p~"!1t~;'!<I:",\.:¡i,i!i\'íI,~I;:·~.';'<:t\~\~~~<\"'W"'1!;iI$;~~,~;~;!\f~fct~1(ø~t¡!Í!1t.tœ{~t3,~~J~wr~::;;~>~'~;'1'-;;¡¡~~ i{'~*k~tí:('*~,~~%1i;~~l,Y~;'i'i>~IK::'/ i(";:i~·1"~,· ~¡:ir:-!I!;~;";1;",,·,::~.;;'¡,\?(ci." 24 hr Recê Drilled to 12105' MO, 10843' TVO. Pumped Hi Vis Barafiber sweep. Hole clean. Wiper trip to shoe. RIH. 10' fill reported on bottom. Circ. hole clean. Short trip gas 131 units max. Ver¡ little sloughing Kingak shale. Spot 100 bbl. Barotrol pill in open hole. POOH for 7" liner. ~ '1,' j.'~~:~;;¡::~~~~',:'·:'·~Jt~f:.~·t:~,¡'~;·:1~f?e~~;¡:~S\~~~~~~~~Wt~~.~~,~~:~~~,~~rt:,·h~~~4~~~~Yt~>~·:,~,~",:~'1~·~·.:::::t~~lf¡:·:q:q~ , 'I' ':f:'~:' oz. i ~ ~ after Gas during % Lithology Sltst Sh Sst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: before after to to to to Drill Rate during before Depth ft units ft units ft units "m::øg~-g;: Connection Gas and Mud Cut ft _ units ppg ft units _ ppg ft _ units ppg ft units _ ppg ft units ppg ft· units _ ppg .l~J(C~¡""7¡;[:n.t~~f.:J[::JJnÎ~~t~.:1!P:II IJl)1(tlUJnl! j] ~ n Drilling Breaks Mud Cut: _ ppg Trip CI: ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft I ~~.f¡l1ml~nr~.,U¡~~~.~."11:~ 1111~~~n ~~ 20 % SLST 30 % SST % %LCM ' '~':X~~O~...:11C~.=i&fi~~::;:~_I!I~~llrL¡OOl~~,._1 ppg ppg ppg ,; . ..". ~·~~t; SH 50 % Current Lithology: I I ( ~:. .,....'i.·~~I;.;~:)~.;.: ,~i'", -~.~~:.~~,~'5,..':"G"fI.',:".":r-,\' ~..1(·1'·'~" ,:~·;'r',~r:t.~!-;·-r~\~. ,,",¿,1~1.. .·~I ~<' I".~'''' 131 Jets: 13 \ 13 \ 13 \ 15 \ 15 \ 15 TFA: 0.9070 ------ Total Revs on Bit: 263 Footage for Bit Run 1,645 8 1/2 21.6 to to Trip Depth: Short Trip Depth Tight Spots: Trip Gas: Short Trip Gas: 12105 ft ft -~..' '~~"'~::!'~':".: ,'t,'" ",r- .r-",~~..(~·;tK.....,..~,.:, '.t . .... _ -).t~;t:h~I'" I~~_..I..- ·';.t'f ',,"".~.': ' -, ,IA..."J· Type: HYC DS70FNPV Bit Size: RPM: 80 Hrs. On Bit: Bit No.: 3 Wt On Bit: 21 ., . ,~'"" ~"-:,,, ': "I-' -- -.:,......').;,'.'_. ..\.I·'!·..~,.:-.,..'..:>,;;,J...,.;,'.~,..,:,',····.'\..' .....:... .,>:,......, ··}·:-.·;·i~t... "t~.'\~:·':;· . .... _. . n, HTHP ~ Mud Wt at Max Gas ~ ppg 6 / 26 / 31 Ibs/100ft2 pH 8.5 Sd 0.25 % Pump and Flow Data 65 spm DH flow 65 spm Total flow spm A V @ DP 2700 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 462 225 424 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 14 7/11/2002 12,105 856 POOH for 7" liner Polya / Dinger . u: . "'~ 12.00 ppg 12.00 ppg 4.6 ml Gel~ Visc 45 secs API filt PV 17 cP YI 22 Ibs/100ft2 11652 12105 24 hr Max ft/hr @ units @ deg F @ \!i'.,.,;,.", BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Mud Wt In Mud Wt Out 156 305 24 hr Avg 75 ft/hr ( 170 unit~ ( ( ft/hr units Deg F R.O.P, Gas* Temp Out Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe....,f"'""V- sun DAILLING seAVIc::es I I ( ( I I * 10000 units = 100% Gas In Air ",':'" '~~;(~~, :~~~,." ,:~~,{; t~,~,~' ¿.r:'<'!:i-;,~. ;;. :;:<:: I¡!;:;r~~~"'~"',:'~y~~~r::?<:}t:~~ !~\~:ifi~¿t"~r:ir~~¡:g¡¡)'. :'¥ ,\~"':"> 1:;~~;;:~:i~{~~~~~:~P*'~:~~~.f¢I':;~\!;i~~~}~~·$i~~e~~ ~;B~~~i~~~f!~'!~;~F!":'~"" ,,::,: , . '.' Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Rec¡ Pulled to shoe and circulated slowly while wating on liner hanger. RIH to bottom @ 12105'. 6' of fill on bottom. Circ. hole with 265 units trip gas. Pump 25 bbl hi vis 14.5 ppg sweep. Hole cleaned up well. POOH to shoe. Pumped slug. Cont. POOH to run 7" liner. . ';.:' (:', '. , . 011...','.1_,,", ""'~.:, ·..·I..'·~·~'~'!', ... 't"~¡ ·':·..~;.:\·~~f\..;· .'¡'I..<,'~'~:.. :1:'·'·"";:r\-:i:ÿI:'.!...~~'··'·~){""":."·' I '..:' :. ../ ,.,' . . .L'~._'" .t. '~ ¡/\\'II'.':it:~~1i~~~:ø~t~~~ai:ti:¡~m;~~;¡,ff,¡~~<t¿~~:.~\,\~~~~'Jf(¥;1llii~~~¡_'" . " .. ""': ,., ". ' " .,. ,~,:::(~~~ffrJ~ìb,'M~~~~t~j; ~:-f~1,,~':X..:~!:~,··~;st~,~;J~!~,~~~~~\~.~...~~,~,.t...~'¥~~Þ~~~~~~hf'š,~~.~~L~~ll:i " ,',. ,:.', r.., ~" ',,', ',,,' "~,,..~~.{~¡fp;~~~~~~~,~!~,,"~~ 4'¡ii-~·", iful 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. i:2:i Description of fillings: % % % %LCM 'J::~JUt:~~~~~~:Ir~_1('~I.B)w.~illOOn!\1)}J.llft~~:::. Connection Gas and Mud Cut ft _ units ppg ft units ppg ft ft units PPQ ft units PPQ ft ft _ units PPQ ft units PPQ ft __ 11 ~~:,+::I:aU'u_JJ H, Jlå\1!itQ;;;;l6J."^'-l:riC~T~'nt I ·1fnr~=.::'n:';OVmr~.i__ Drilling Breaks Gas during % Lithology Sst Sltst Sh before after after units PPQ units PPQ units PPQ b~-Œ:]A-J.~;\ to to to to Drill Rate during before Depth I % Current Lithology: Mud Cut: Mud Cut: to :il~;f.J~ ,z·,"" i;,,~~,·~t~"""",:';'·;'1+; ;.If.f:. ',' ,:.~1; <.,':\. it ':,:::},~¡:C,:',:"f~~~j.~'~!'è:I('!:r,,:,':$¡"::'f";¡:::":.~'S*\~' ,~r",~it'j...~~~~(,;.;(!\,I~~:{,1i:;:,z~~I;~,\\,:~~'''''p\«¢~';V(~,;!!,~¡.\~¡¡t,·it.:"t~m$O:fw;~~'¡"'h 'è~,~,,*,~r:",1j,;"~~""-"("Æ" ,il'* f( . ~~¡, Tnp Depth: I Short Trip Depth tJ( Tight Spots: ',~~~~~~? 265 u Jets: 13 \ 13 \ 13 \ 15 \ 15 \ 15 TFA: 0.9070 ------ Total Revs on Bit: 263 Footage for Bit Run 1,645 8 1/2 21.6 -¡',",", " " .," <,' '"'~, " "l","" '.~." .....! ,I:, ~~,' i'.i,_,· "," .., ~~..""'.¡':" ;, --- ppg 0.25 % HTHP 10.2 Mud Wt at Max Gas 8 1 24 1 30 Ibs/100ft2 pH 8.6 Sd 4.6 ml Gel~ Visc 51 secs API filt PV 22 cP YI 20 Ibs/100ft2 Pump and Flow Data spm DH flow spm Total flow spmAV@DP psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ 15 7/12/2002 12,105 o POOH for 7" liner Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 to 12105 to Trip Gas: Short Trip Gas: ft ft 3 Type: HYC DS70FNPV Bit Size: 21 RPM: 80 Hrs. On Bit: Bit No.: Wt On Bit: ~:'~'" .,~ ,~~~' ....~ :,,"." '" ':,..,: '~ : " ,'.-" ' 12.20 ppg 12.20 ppg Mud Wt In Mud Wt Out 24 hr Avg ft/hr ( u n it~ ( ( ft/hr units Deg F ( R.O,P. Gas* Temp Out Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe""'r'y-sun DRILLING SERVlc::es I ·,~,,,:~~·~,.¡,+~~:~:~~~~~;.ti~.~:~j¡~~~·":~¡¡ :F:,~')1';:/:~"¡';r~W:::~~~'J,::t(t!'~4tts~\~~!~:t!h~~;~;ï~f;fi;,:({~~r\:!;~~tt:~:~~~~;ÿ~tl:~~,,;¡~<{\;~j'j~~¡'~f~~;~f{~1§ì:~\;;~m~\:~h~·:~ . ;: * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield I Doug Wilson 24 hr Recê Rig up and run 7" liner. Circulated liner. Cemented liner @ 12094'. Max gas of 95 units. Preparing to displace well to seawater. :.,~ ~~r. I.'i".", ' ;':'11.,~J"""I~~I,,;, ..~'.~.:~ ," .' '. ;.....: .;,.,..,~....~', ~1';~1~1.f&~:(1 lt:t:::~~·:I~ ·...~:w,t.: :....,qp:1 i''i"t;''·¡~'·,· w:~··.f:·,.i.:,,'.¡""""':~.~,:.'¿~,,'I"~',;:.: ~·~.·I ,~~~,\.t.~.q,'~~""..~~ !:':;"': ~"(',,,<~t.·~,~i .....:.~~~~f1:.\'-;~~.,. oz. ':¡¡;~"\f.i":'I,~"_~""",, {',l~:'.¡:".\,,,· ""ifì', " ,,', ,," it!ùØ ,,'~...... " ',~ 1: ~"""'¡". ' d.. ~ 1fl~.~ .':i~' ,t~\ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ~~~, ~'~'~. to to to to % Lithology Sst 81tst Sh Gas during Depth Drill Rate during after after before before Drilling Breaks ft units _ ppg ft units _ ppg ft units ppg IImllllØEJ¡r]~l\1Y,tDr~ Connection Gas and Mud Cut ft _ units ppg ft _ units _ ppg ft _ units _ ppg 1 _I L,~ ft units _ ppg ft units ppg ft units ppg "::~;:Jm:::I::.=:=t.:~':]f",::ë,::ï1~~~~JII ( :;~l~I1:_~iI~~.re:::~:~ [l1l~"""~::::::m:..L~~Ì1.. Type: Bit Size: Jets: \ \ \ \ \ TFA: - - - -- RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run , ·'"':~';.~A~ "·;¡(f";·t::t(:~';;:'iiì~K~ìt:*.~N~"{;'i,~,,;,,¡\'i.,,tIi;*~":':<!'f";·'~~~,~.;':'~j,,~,::t:h~(·"'~~:~':~""'i1;<;~~<:'~!.0d4:'\i:~~~1~~~~¥:\~;¡.t':1jl;''''~,,,*;~it.':;:;¡.~·~;~·' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ~,:òt~' .-".-"'~'-; ,.-.,..'.--.,......' ·,,,·...·.."""''''.T''·.'_. y,,,,,-~,.~,,,,,,,·,,-<n.,...,,~,-.,,,,,.,.-,......·,~,.,-.-, "'."..,wf"·".,..,......""\."........,.....,·....,.,w.........,,.,...,.."-,,'~,...''''''''"''''''.,.,,_.....-.......'''',~.,....,.,.,'<'I''i'''\~'''!''''....~"~I"!'1i~_II";:;'I"·i!.i·.,·.~"~...·,.,!'.~,,.(.;~;.<I':..·~,..~'\..~>I___;.._À.o,-".'O"~""~"~.~~~~;:\ O~~~.t~!Wì'$~~'f\i Current Lithology: % % % % %LCM ( ppg 0.25 % HTHP 10.8 Mud Wt at Max Gas --2- I ~I ~lbs/100ft2 pH 8.6 Sd I I 12.10 ppg 12.10 ppg Mud Wt In Mud Wt Out ( 4.6 ml Gel~ Visc 54 secs API filt PV 21 cP YI 20 Ibs/100ft2 Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ 24 hr Avg ft/hr ( unit~ ( ( ft/hr units Deg F R.OP. Gas* Temp Out cementing 95 Current I 16 7/13/2002 12,105 o Disp. wi seawater Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: spe..........,v- sun DRILLING SERVIc::es I Mudlogger's Morning Report BP Alaska NorthStar NS 16 North Slope NorthStar N8 16 Nabors 33E AK AM 22106 Customer: Well: Area: Lease: Rig: Job No.: I ' <" ¡'..~:~~;, ,{ :·:~f?Þ?~W%:Úwf:f,:9kt;iJ;~'{t,~~:.~;j~:;",:" ,/'" "q;~~1')~~~~'~~"~"!~:~~"Y~'!:i~\~'~",:~,,,:':'" ~;";~:\~";~'0i:: ,:~:~!~i>è~ï~:~::I!;',~~~~~:Ät~\':';~i;:\!:~'$f~~~;~~:~', * 10000 units = 100% Gas In Air I> ifWi.' Logging Engineer: Tom Mansfield / Doug Wilson Displace well with seawater. POOH. Freeze protect well. Clean pits. 24 hr Rec¡ ~·;I:::;~'·..'i\:~~y!.IÇ_' It· .' · '.' _, " '~~\~~'ii'l"l~£1~¡i~~~~'~~~~~1~~~;;~~~~tI~;*"R' "Mf,·;..rr·j ~."l.tI. ~~~"'~~~~ h·fr· \'., ~, '" ' ~~ .~.\" ,~)1ti;:'~~·~"f~.;.~:.~~,_~¡mn:~~~~,;,~.~,~,~ ,~~~~~:,~J)~-l~:.~~"' /'~,.,1t.' '~~~I 24 hour accumulation of Steel Filings from Possum Belly Magnets: i¡~1 DescriPt,ion",of ~ì,lIings: ," " , ,,'" " ~ - . t·, , :; ~.;. .,~,.' ':t'~~' .~~{?j : ;t: ~~~:~:;~:~~~~?~·¡~t~~~~~~!~J~ß~~ß'~~~~':?\~~'.~'~~~~~;·G~~~f';·';~itt~~~þ~~!f;i~~~:.'~~t~.~.çi~'<'i~;~'?;/':\"/~,.~:J~~,!~:.i.f~;;;";_'1·.~~~~;~~B:~~~r,';':t'~if~~~·i1:i, ~~:~tr~:::"'!:~ ~~,;, ':~.,~ ~ : .{~: '" ;'",~~~ '¡"~:~~$,·~"~,~:,:Ÿ;,,.1':'!:.~Þ~-,~; :~. , ' "l~' ml HTHP Mud Wt at Max Gas _ ppg ~~, Gels / / Ibs/100ft2 pH Sd % ~~~ --- - -rf.' ,"" ,1o,,,' ',',' ~"" ;,~,; :":·:~"7',~,.:,~<",.:.Ii·,'" "".':;",,~,- ,:, ""-'~'"',:;,:;r.'',''''' :' ,"'" ,',' '" ";",, ,""',,, .' ¡" "-'~i' ,it Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: i )\~~ ------ ~'t J Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ~ ~:\¡'':<1'' --; },..;,,;;,~¥ '-~(; ',¡,~':''':*I$U~~ßw~~;':';~'á('?{«",*~~"',t'~~~~r>ifl':~~~/J''+-;,t''i-\;::,,~ ~Mi1M\w."~,,,,*,,~íIìH'~~,~I'J!;n~~~,,,,~·\-i,<^9!· :t'i ;, Ø'! fti:~J,: &1 ~¡ I Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm ~I Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~:¡¡ Tight Spots: to to to Feet of Fill on Bottom: ft I. . I '·¡:n:U:D;Ií.lI..\¡IU.î.___WI.\~~~~:,~~,( t Lithology: % _ % % % %LCM _ _~11 '~1l:~~llll'~J:]I11lIln~r~lœtBtmŒ':1~~DUt.. I i 1 \.I) ~J I, % Lithology Sltst Sh units ppg units ppg units ppg oz.. Sst Gas during before after after Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg API filt I bs/ 1 00ft2 ". -,'. '~,~.,:"ar;." ·1~.~·· .'.:1~'''' .._,~.. gpm gpm fpm fpm Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC 24 hr Max fUhr @ units @ deg F @ 17 7/14/2002 12,105 o Rig up/down Polya / Dinger Pump 1 Pump 2 Pump 3 Pump Pres ,,~. " Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 to to to to I Drill Rate during before Depth ( ft units ppg ft units ppg ft units ppg ~··'r:Rf~;,A1:,~Jf.I¡"~· I ( ( It·" '. ~ I 28 secs cP YI ppg ppg Mud Wt In Mud Wt Out Vise PV 8.50 8.50 .. ~_",.,.¡, "':", .. L'!~.; . ~ ( , " 24 hr Avg fUhr ( u n it~ ( ( fUhr units Deg F R.O,P. Gas* Temp Out I Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report 5pe........,v- sun DRf LLf N G SEAV I c: E 5 I I Customer: Well: Area: Lease: Rig: Job No.: I spe...,....,v- sun DRI LLI N G SERV I c: e 5 ( Mudlogger's Morning Report BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AKAM00023433651 ,,:~j(l", Current 24 hr Avg 24 hr Max R.O.P, 0 fUhr 48 fUhr ( 145 fUhr @ 12348 Gas* 51 units 235 unit~ ( 1120 units @ 12108 Temp Out Deg F ( deg F @ I _. i, ,-'., ," '"' . . ';' S~.. '(';. ~--r.·,é·.; '·~;.rJ'·~" "~~~~"'ft"7«1t~,í.~\p·~·S~·~<RI.~.t·t·~~:'~'¡' ;l-:"?~ ü~~~~,·~I.(,:,~ tf..1~..~ ~I:~..¡·,·:.... ...k~I:'/"\·~·~ -; ""'." ~ I,"~ .~-~.r.~J~~·~}þI~:\ ".~_.~),~;'I,~'·:""~.c·~):\t~f)':'~: ·,~l",_..., .J.;.:~·· - .':.. ~~ . -j . Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 18 3/18/2003 12.424 319 Circulating Kidd/ Holt Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 90 spm DH flow spm Total flow spm A V @ DP 1725 psi AV @ DC . .' ... -. J\ '. ':. Mud Wt In Mud Wt Out 9.30 ppg 9,30 ppg Visc 42 secs API filt PV 10 cP YI 27 Ibs/100ft2 4.2 ml HTHP Mud Wt at Max Gas Gel~ 12 / 15 / 27 Ibs/100ft2 pH 9.1 Sd -- ( . ". ," ~. t -.... :.1~, .;r:.,,~ """'.'::"':""~'I~.':: ",.,~';::,~~<:..' ,:;:;:::; .. "¡-.,','". .".:,: "., J: r.~·, .",,:.~,.'_:~,:,C~<, .~.'::'~>"',~. I·' ~ ..~'.;:;..~ ..... .,' 1,...~·. .....~. ..;'?I'....'.. . ·..i.',.~'-. ~. .~ Bit Size: Hrs. On Bit: Bit No.: Wt On Bit: 3 26 Type: XR30YD20DGPD RPM: 70 I .... . ,': . ( Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 320 132 788 gpm gpm fpm fpm Mud Cut: Mud Cut: to ppg Trip CI: 21000 ppg Short Trip CI: Feet of Fill on Bottom: ppg 0.1 % 6 1/8 23.6 Jets: 15 \ 15 \ 15 \ \ \ TFA: 0.5180 ------ Total Revs on Bit: 169 Footage for Bit Run 319 25 % SST 5 after before I 70 % CONG . V",)'C;:;h::¡: ",,-".,:,\''¡:~~~.;.f'"¡\..I,~~~'":!~''''' ír"'!·· :,:.", ·:,.i'·',"¡:f';.~~~~~;!!:~t'~¡'>~·~?·(':!ii!ÞiC::'~:~~:~r~¡'J~;·;!¡~~,:\,·,',::'_,\i'!,i~;.o*iot\<! ' ~~4 Current Lithology: % SLST %LCM % " " e:a:::;J;t:ttt~illjM~1ii'J. ,ill ~J II Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ·~u;r:~::~·-·]c:r J..nd~.lmlE!fIV;:-r~~nrr.·I·I·'···-UX--·ïl.1 Drilling Breaks i''Ô.. ;~,.':~;",~, '.':'; '·~>~··~ t::~S~;'~~;?'"j ~1~~~~~~~iliW~~~f~f~~1;~1~-~!.ki~,'.'~';~~~}~1~~~~~~\f~:,~'~~i·ì~~~~~'~;,~~.Þt~~f::~;~~:h·~?;~I\;·~~fr.il-C~' ':" !::', 1 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. 1.! ~~ì~ Description of fillings: . '. .' "... ."., ,,,,, ., , . 9.'."" è:",c,. :.~: t .,., ',t .:,' ; ""'"'''''' M' 'oil"." "I"" '~'.~ ,. ,'.' . . "'. . · ; ~-"1",,;-}""'''''''', .',,,;,,- '. -,. . ,J 24 hr Rec; RIH to the top of the 7" liner, Wash and ream to 11967'MD, Displace mud with 9.1 PPG MW J.~': Drill float equipment, drill out 20' of new formation, to 12094' md, Perform FIT to 11.5 ppg EMW. Drill F/12125 T/12424' TO, Weight up to 9.3 ppg, circulate 4 hole volumes. Mad pass up to shoe. ( ( Depth Drill Rate during before I to to to to Top of Shublik 12162 MD, 10898' TVD Top of Ivishak 12258' MD, 10992" TVD Logging Engineer: Tom Mansfield / Doug Wilson ft units ft units ft units .~"Œ .LD~"ßX:~.. . Gas during after % Lithology Sst Sltst Sh ~ ~ ~ ; . . ~ * 10000 units = 100% Gas In Air " ,"':,~ ;",. ;'~:'::~~N~¥¥ji~}~j;~~~:~~~_iê~k~f~I~§"~Jj;,~,'Af:~~2~:;~:~~$&tþì¡'~1.:~~%\~~jt(~~~~f:¡,$~~~~~~~~_t~~~~t~~~';i~\~,W:~¥f' I ( ( I ( I ( I I ( I 5pe............v- sun I:J A I LL IN G 5 E R V ICE 5 Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 16 North Slope NorthStar NS 16 Nabors 33E AK AM 22106 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 3/19/2003 12,424 o RIH w/casing Kiddl Holt '.'~ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm DH flow spm Total flow spm AV @ DP o psi AV @ DC .~ ",:.:." ,. L '; ..,,··J:-t.r..¡.~ ' , .......... '. ø :.' '.' . . "~~" .' ;:~'~~}".,::~.,",~ ~.\\ ":'-:.:,,;'-~-~~~,:'),>~vt, (.' --- '. ',1 :,,¥:i':";'~"'¡,,:¿""~"":"":.,,·,~ '; .:,." units units units % Lithology Sst Sltst Sh oz. 24 hr Recé Complete MAD Pass up to 7" liner, Circulate hole clean, saw more of the Ivishak formation ,~ come over the shakers, POOH, Rig up and begin running 4.5" liner. Mudlogger's Morning Report Gas during after o o o gpm gpm fpm fpm , . Current R.O.P. 0 Gas" 0 . Temp Out 78 24 hr Max o ftjhr @ o units @ deg F @ o o ~.. ppg ppg Visc 42 secs API filt PV 11 cP YI 25 Ibs/100ft2 4.0 ml HTHP Mud Wt at Max Gas _ ppg Gel~ 12 / 14 / 16 Ibs/100ft2 pH 9.0 Sd 0.1 % )' ,.\~ ._>~. :";.. . . ::=::::J:::.::t~!J,.m~4lJíj l ¡ l j . '~1ift',; ~ r n:.~ . urrent Lithology: 70 % CONG 25 % SST 5 % SLST % %LCM ,::~~~=ll~r.::IUJ l=œ:D'C:~~rl'Jl\Ulll ,.~~Ji..:MJ::r Connection Gas and Mud Cut ft units ppg ft units ppg ft ft units ppg ft units ppg ft ft units ppg ft units ppg ft ~'::JYltw;l.""....Jd:f.J~:;.:;X"~.gl·q;:Jì\~'¡¡'~;;~~~~ ::::::ø~:lmJ'L oR] ~ .~"'. ,o·~·");."'~):.:'.Í!.~:~l;:':~!¡~t~:4~,t:'iji¡I1i;(w,;':?,~"&;;~:;;-;:-;f~~9.A~~~~~~;~r;:~jç:;r.~jv.~~'*~~~~~1t.;~~~)¡jR"'tl~,~Q)~~~~~,r: ~.:.,. 'o:,,:~ '~i I: ~ I: "~; Top of Shublik 12162 MO, 10898' TVD I", ~t Top of Ivishak 12258' MO, 10992" TVD i Logging Engineer: Tom Mansfield / Doug Wilson * 10000 units = 100% Gas In Air ',,: ',':,., I :,~'. :,;;¡:"i<¡.!'mi~~,),I' ~1!IAf.'¡¡;i >ii"':: '¡¡.,'¡!.i'h".'r;:~~~~~i:m~"¡J,~~~~~~~~'¡~Wm¡li.a~~d:f¡~-,~~~~~~'ii:I:r::~¥iIit_:!!I'Î.~ ~:rj;;r"~~;\ I~dk . 'I~!.~' ''t~t~'·~~ Vl~ ...~;-,:,~, '\ .... ~I'~ .:" .,"", .¡t~~j~~~~~if';íf~~~'! "j.4t;t-~~~~~~1í~~~:[\~,.~~~~~;;~~~~~:r.'~~~~~~¡.~~'~mt'lrr:,,~'~w!<'~IRJ ".,~ ~-.,¡. ..~l - :':~ ,".....-!..~:J',;.,'1'., ,~ ·1<,!,,\;·,\·,~.~,~~\:\.:..~;~~:,1~'~.f:'.;· .:;,..:.t~, "','" .,.,.~:. 24 hr Avg o ftjhr ( 50 unit~ ( ( fUhr units Deg F ',;. Of"," ., J':.~.."'.'. -.. . ~ : .'. ~~ .'. . r:;¡ ~ ·'r: Bit No.: Type: Bit Size: Jets: \ \ \ TFA: ') ------ .~;; :,WI ~:..~;:~...""...;",,,,,, ,::~: ,~~" 'c""""":':·;~;:.,:..ø'... ""...::~~~~,:;:,~:, i.ð_ .F~~,:,:,f;:~:~~:.,o.~ .i" ..i ".,~ ~.~. Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 21000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft " Mud Wt In Mud Wt Out 9.30 9.30 Drilling Breaks Depth Drill Rate during before after before to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: ûescription of fillings: Schlumberger BHA# 1 Job # 40007742 Date In 29-Jun-02 Date Out 29-Jun-02 Hole Size 16 Customer BP AOW Time In 8:00 Time Out 16:00 Hole Sect Surface Well NS-16 Depth In 201 Depth Out 334 Bha Type Steerable Field Northstar TVD In 201 TVD Out 334 Hrs BRT 8.0 Rig Nabors 33E Drlg Hrs 0.6 Drlg Ft 133 A vg ROP 222 AFE # 831312 Slide Hrs Slide Ft Slide ROP #OIV:O! DD's Rinke/Overman Rot Hrs 0,6 Rot Ft 133 Rot ROP 222 I Co. Men Clump/ Smith Pump Hrs 1.4 Rotate % 100 Slide % PDM Run # 1 R/S 5/6 PDM Jet Blk Inclln 2.39 Az In 275.77 Bit>Srvy 43.0 PDM Ser# 962-1126 Stages 3.0 Bearing Mud Incl Out 2.49 Az Out 280.72 T/F Corr PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM 1 000 A vg DIs Max Ds Plan Dls ( Mud Type Sea H20 Spud Mud Wt 9.6 Sand % RPM GPM SPP On BHT F Mud Vis 144 Solids % DIg TQ WOB SPP Off Item Description Vendor SIN OD ID Stab OD F.N. Connections Length Cum Length ( I Bit #1 MX-C1 TFA=1.031 Hughes 6004904 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std POM 1.83· 7 5/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 ( 3 Orienting Sub 6 5/8 H-90 P Ana GLOO-105 8 2 3/4 6 5/8 H-90 B 1.46 28.81 4 MONEL STAB 6 5/8 H-90 P ( Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 34.30 5 MONELLC 6 5/8 H-90 P Ana 1 O-HA-O 11 8 2 13/16 6 5/8 H-90 B 9.69 43.99 6 MONELLC 6 5/8 H-90 P [ 1 Alia 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 B 9.96 53.95 7 MONEL STAB 6 5/8 H-90 P Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 59.55 ( 8 X-OVER 6 5/8 H-90 P Ana ANA614 7x8 2 7/8 1.20 41/2 IF B 3.09 62.64 I I I3HA and Run Objective Clean out Conductor, _.~.._."_._---_._---,-_. ----... -~--- ....... '--"'~'",' ~-,,--_. ..,"~~ -------_. -~.__..._--- survey Bottom Hole Location, Rat hole to pick BHA BHA and Run Results I _p______,_.___,___ ..._.___,___ .,..__.___________n'_' \ Why POOH I Comments I cha~,~.~, ~~~_/ _~~~~__~,~_~v:'~~n~~~~L~~~__ , BHA Weight Dry Wi 10,694 Buoyed Wt 9,130 Incl Angle Buoy+lncl Wt 9,130 Bit Data IADC # Footage 133 Hrs 0,6 k Revs Grade not graded ~omment rerun in next BHA on this well Tool Motor Jars Bit #1 Hrs. In 62.0 Hrs. Out 63.4 0.6 0.6 1.4 Bit To AIM=X', Res=X', GR=X', 0&1=43', PWO=X', Oens=X', Nuet=X' Schlumberger BHA# 2 Job # 40007742 Date In 29-Jun-02 Date Out 01-Jul-02 Hole Size 16 Customer BP ADW Time In 16:00 Time Out 6:00 Hole Sect Surface Well NS-16 Depth In 334 Depth Out 3514 Bha Type Steerable Field Northstar TVD In 334 TVD Out 3218 Hrs BRT 38,0 Rig Nabors 33E Drlg Hrs 18.8 Drlg Ft 3180 Avg ROP 169 A FE # 831 312 Slide Hrs 7.1 Slide Ft 935 Slide ROP 132 DD's Tunnell / Bosse Rot Hrs 11.7 Rot Ft 2245 Rot ROP 192 Co. Men Polya / Dinger Pump Hrs 24.0 Rotate % 71 Slide % 29 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 2.49 Az In 280.72 Bit>Srvy 67.8 PDM Ser# 962-1126 Stages 3.0 Bearing Mud InclOut 31.52 Az Out 269.04 T/F Carr 92.6 PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM 1000 Avg Dls 1.5 Max Ds 3.3 Plan Dls 2.5 ( Mud Type Sea H20 Spud Mud Wt 9.1 Sand % 2 RPM 35 GPM 850 SPP On 1800 BHT F Mud Vis 93 Solids % 4.4 DIg TQ 8 K Nibs WOB 35 SPP Off 2000 Item Description Vendor SIN OD ID ,StabOD F.N. Connections Length Cum Length Bit #1 MX-C1 ( TFA=1.031 Hughes 6004904 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std PDM 1.830 7 5/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 ( 3 MONELLC 6 5/8 H-90 P Ana 10-HA-011 8 2 13/16 6 5/8 H-90 B 9.69 37.04 MONEL LC 6 5/8 H-90 P 4 Ana 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 B 9.96 47.00 ( 5 MONEL STAB 6 5/8 H-90 P Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H-90 B 5.25 52.25 6 MWD 65/8 H90 P ( Ana 173 8 1/4 3 1/4 1.52 6 5/8 H90 B 29.18 81.43 7 MONEL X-OVER 6 5/8 H90 P Ana LWD SB102 8 1/2 2 13/16 6 5/8 FH B 1.41 82.84 8 Down hole filter sub 6 5/8 FH P I Ana DFS 838 AK 8 3 3/8 6 5/8 H90 B 2.20 85.04 9 Orienting Sub 6 5/8 H-90 P Ana GLDD-105 8 2 3/4 6 5/8 H-90 B 1.46 86.50 ( 10 MONEL ST AS 6 5/8 H-90 P Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 92.10 11 MONEL DC 6 5/8 H-90 P Ana 831-021DC 7 15/16 2 13/16 6 5/8 H-90 B 30.94 123.04 ( 12 MONEL DC 6 5/8 H-90 P Ana 831-020DC 8 2 13/16 6 5/8 H-90 B 31.01 154.05 13 MONEL STAB 6 5/8 H-90 P I Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 159.54 14 MONEL DC 6 5/8 H-90 P corrosion ring Ana 831-012DC 7 7/8 2 7/8 6 5/8 H-90 B 30.58 190.12 15 HYDJARS 6 5/8 H90 P DAILEY 1417-1121 7 9/16 3 1.20 4 1/2 IF B 30.95 221.07 16 26 Jts. HWDP 5" 4 1/2 IF P NAD 26 HWDP 5 3 4 1/2 IF B 786.67 1007.74 17 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 1007.74 , BHA and Run Objective Drill surface with 2.50/100 curve ,...__.~_._..._._..~._......_~------_._-_._-_... BHA Weight Dry wt 71.449 Buoyed Wt 61,545 Incl Angle 32 Buoy+lncl wt 52.465 Bit Data IADC # 117 Footage 3180 Hrs 18.8 k Revs 120 k Grade 1-1-WT-A-E-IN-NO-TD Tool Motor Jars Bit # 1 Hrs. In 63.4 159.7 0.6 Hrs. Out 87.4 178.5 19.4 24.0 -"-'-'~---~"--'------"--'-'- BHA and Run Results Good run. Why POOH! Comments ~:_~~~_~~~, p'~i~,!__ ,_..__.____._.______, Bit To IAIM=X', Res=X', GR=65.76', 0&1=67.75', PWD=X', Dens=X', Nuet=X' '.;omment I Schlumberger BHA# 3 Job # 40007742 Date In 03-Jul-02 Date Out 07 -Jul-02 Hole Size 12 1,4 I Customer BP ADW Time In 0:30 Time Out 23:30 Hole Sect Intermediate Well NS-16 Depth In 3514 Depth Out 10460 Bha Type RSS Field Northstar TVD In 3218 TVD Out 9316 Hrs BRT 119.0 ( Rig Nabors 33E Drlg Hrs 50,2 Drlg Ft 6946 Avg ROP 138 AFE # 831312 Slide Hrs Slide Ft Slide ROP #DIV.'O! DD's Rinke/ Robertson Rot Hrs 50.2 Rot Ft 6946 Rot ROP 138 Co. Men Polya/ Birkbeck Pump Hrs 77.7 Rotate % 100 Slide % PDM Run # R/S PDM Jet Inclln 31.52 Az In 269.04 Bit>Srvy 59,6 PDM Ser# Stages Bearing Incl Out 28.18 Az Out 262.33 T/F Corr N/ A PDM Size Rev/Gal Rubber Avg Dls 0.6 Max Ds 2.2 Plan Dls ( Mud Type Polymer Mud Wt 10 Sand % .25 RPM 160 GPM 900 SPP On 3000 BHT F Mud Vis 71 Solids % 6 DIg TQ 19.0 WOB 20 SPP Off 3000 Item Description Vendor SIN OD ID StåbOD F.N. Connections Length· . Cum Length #2 RSX238HF+GS ( TFA=,941 Hycalog 202936 12 1/4 3x11,6x12 6 5/8 Reg P 1.00 1.00 2 PO Bias Unit 6 5/8 Reg B Ana 90177 9 5/16 Tool 1.35 NC 70 B 3.22 4.22 [ 3 PO Extention Sub NC 70 P Ana 90146 9 1/4 Tool 7 5/8 Reg P 1.31 5.53 4 PO Control Collar 7 5/8 Reg B [ Control Unit 127 Ana 90031 9 3/16 Tool 2.32 6 5/8 Reg B 10.07 15.60 5 XO FLOAT SUB 6 5/8 Reg P "float" Ana GLDD117 8 2 13/16 6 5/8 H90 B 1.97 17.57 6 MONEL STAB 6 5/8 H-90 P ( Ana HA-O 19 8 2 7/8 12 3/16 2.36 6 5/8 H-90 B 5.57 23.14 7 CDR 6 5/8 H90 P Ana 8039 8 5/16 3 1/4 15.15 6 5/8 FH B 22.82 45.96 ( 8 MWD 6 5/8 H90 P Ana 196 8 3 1/4 2.29 6 5/8 H90 B 28.40 74.36 MONEL X-OVER 6 5/8 H90 P 9 Ana LWD SB102 8 1/2 2 13/16 6 5/8 FH B 1.41 75.77 ( 10 Down hole filter sub 6 5/8 FH P Filter Ana DFS 838 AK 8 3 3/8 6 5/8 H90 B 2.20 77.97 11 MONEL STAB 6 5/8 H-90 P I " Totco ring" Ana HA-008 8 2 7/8 12 1/4 2.30 6 5/8 H-90 B 5.48 83.45 12 MONEL DC 6 5/8 H-90 P Ana 831-021DC 7 1 5/16 2 13/16 6 5/8 H-90 B 30.94 114.39 13 MONEL DC 6 5/8 H-90 P I Ana 831-020DC 8 2 13/16 6 5/8 H-90 B 31.01 145.40 14 MONEL STAB 6 5/8 H-90 P Ana HA-006 8 2 7/8 12 1/4 2.45 6 5/8 H-90 B 5.60 151.00 15 MONEL DC 6 5/8 H-90 P "corrosion ring" Ana 831-012DC 7 7/8 2 7/8 6 5/8 H-90 B 30.58 181 .58 16 HYDJARS 6 5/8 H90 P DAILEY 1417-1121 7 9/16 3 1.20 4 1/2 IF B 30.95 212.53 17 26 Jts. HWDP 5" 4 1/2 IF P NAD 26 HWDP 5 3 4 1/2 IF B 786.67 999.20 18 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 1001.57 BHA and Run Objective Drill toTO. BHA Weight -_.~,-~--_.."_.._,_.__.__. .__.".__.._.._--~..,'.- Dry Wt 68,169 BHA and Run Results IGood run RSS wor~ed ~~~~~~_~~_.._,_____._ Buoyed Wt 57,785 Incl Angle 34 Why POOH / Comments I!._~____________.__.________,...__,,_____________ Buoy+/nc/ Wt 47,906 Bit To Res=29.29', GR=40.29', PWO=31.04', D&I=59.57',MWD GR=57.58' Bit Data Tool Hrs. In Hrs. Out IADC # Motor 77,7 Footage 6946 Jars 178.5 228.7 Hrs 50,2 Bit#2 50.2 k Revs 482 k RSS 0.0 77.7 Grade 2-1-V'lT-N-X-I-BT-To ':;omment Schlumberger BHA# 4 Job # 40007742 Date In 09-Jul-02 Date Out 12-Jul-02 Hole Size 8 1 i2 Customer BP ADW Time In 22:00 Time Out 23:45 Hole Sect Intermediate Well NS-16 Depth In 10450 Depth Out 12105 Bha Type Steerable Field Northstar TVD In 9316 TVD Out 10842 Hrs BRT 73.8 I Rig Nabors 33E Drlg Hrs 21.6 Drlg Ft 1655 Avg ROP 77 AFE # 831312 Slide Hrs 1.3 Slide Ft 72 Slide ROP 55 DD's Rinke Rot Hrs 20.3 Rot Ft 1583 Rot ROP 78 ( Co. Men PolyaJ Dinger Pump Hrs 46.7 Rotate % 96 Slide % 4 PDM Run # 2 R/S 7/8 PDM Jet Blk Inclln 28.18 Az In 262.33 Bit>Srvy 61.9 PDM Ser# 675-3346 Stages 5.0 Bearing Mud Incl Out 13.30 Az Out 267.83 T/F Corr 15.5 PDM Size 6 3/4 Rev/Gal 0.275 Rubber RM100D Avg Dls 1.0 Max Ds 1.8 Plan Dls 0.7 ( Mud Type Polymer Mud Wt 12 Sand % .25 RPM 100 GPM 500 SPP On 2500 BHT F Mud Vis 45 Solids % 13.3 DIg TQ 19.0 WOB 20 SPP Off 2900 Item Description Vendor SIN OD ID StélbOD ' F.N. Connections Length Cum Length I Bit#3 DS70FNPV TFA=.907 Hycalog 202317 8 1/2 3x133x15 4 1/2 Reg P 1.00 1.00 6 3/4 XP 1.15° 4 1/2 Reg B 2 *float* Ana 675-3346 6 3/4 Tool 8 3/8 19.03 4 1/2 XH B 25.33 26.33 [ 3 COR (PWD) 4 1/2 XH P Ana 7125 6 3/4 Tool 11.91 5 1/2 FH B 21.87 48.20 4 MWD 5 1/2 FH P ( Ana 344 6 3/4 Tool 1.64 4 1/2 XH B 27.81 76.01 5 NM XO 4 1/2 XH P Ana LWD-BA-259 6 15/16 3 5 1/2 FH B 1.58 77.59 6 Downhole filter Sub 5 1/2 FH P ( Ana CB~028-JS 6 13/16 2 318 4 1/2 XH B 2.76 80.35 7 NM STABILIZER 4 1/2 XH P *Totco Ring* Ana IMSZSS-FA 01 6 3/4 2 13/16 8 1/2 2.45 4 1/2 XH B 5.62 85.97 I 8 NM FLEX 4 1/2 XH P Ana MMFL-FA 014 611/16x5 2 13/16 2.50 4 1/2 XH B 31.02 116.99 NM FLEX 4 1/2 XH P 9 Ana MMFL-FA 016 6 3/4x 5 2 13/16 2.50 4 1/2 XH B 31.01 148.00 ( 10 NM FLEX 4 1/2 XH P Ana MMFL-FA 021 6 3/4x 5 2 13/16 2.50 4 1/2 XH B 31.02 179.02 11 X-OVER 4 1/2 XH P *corrosion ring* Ana 3TXOS-FE 104: 6 3/4 2 3/4 41/2 IF B 1.98 181.00 12 3 Jts HWDP 4 1/2 IF P NAD (3) 5" HWDP 5 3 41/21FB 91.53 272.53 13 HYDJARS 41/2 IF P DAILEY 1416-1574 6 1/2 2 3/4 1.69 4 1/2 IF B 32.63 305.16 14 23 Jts HWDP 41/21FP NAD (23) 5" HWDP 5 3 41/21FB 695.14 1000.30 15 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 1002.67 16 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 1002.67 BHA and Run Results \ Why POOH I Comments As above ---.-~----------.---'------.-_._--".---- BHA . Weight Dry Wt 20,499 Buoyed wt 16,752 Incl Angle 20 Buoy+lncl wt 15.742 Tool Motor Jars Bit #3 176.3 Hrs. Out 46,7 197,9 21.6 46.7 BHA and Run Objective Bit Data lADe # Footage 1655 Hrs 21.6 k Revs 300 k Grade 1-1-WT -A-X-I-ER-PTD Bit To AIM=X', Res=31.69', GR=42.69', 0&1=61.93', MWD GR=59.94' PWD=33.44', Dens=X', Nue' :;omment ESS failed due to pumping and rotating Drill to 8 1/2 hole TO, stay in target ___..__... .,,__...__ _."_.~____...,_"".,, ..._____n_...____ ___..____,_._... .__ Hrs.ln ~~~_C._~_~,~/~ T~_,_ .. ,. ._._._. ._.__. _.,._ "..... ... __,._._.,__u____·..··..··__ I ,," '" Schlumberger I Job # 40007742 I Customer BP AOW Well NS-16 I Field Northstar I Rig Nabors 33E AFE # 831312 I DD's Levad , Co. Men PolyaJClump (' I PDM Run # 4 : PDM Ser# 475-2757 PDM Size 4 3/4 Mud Type Oril-N I BHT FD:~:riPtíon Item I r ( I ( ( I I I I I R/S 7/8 Stages 2.0 Rev/Gal 0.330 Mud Wt 9.2 Mud Vis 41 Vendor SIN 2 XR30Y0200GPO Smith ML5770 Bit #4 TFA=.518 4 3/4 POM SSS 1.1 e Ana 475-2757 *Float NM IB Stab Ana 807 3 4 AON4 Ana 74 5 ARC5 Ana 62 6 MWO - SlimPulse Ana 4741 7 NM DC Ana NMDC-EA-002 8 NM DC Ana NMDC-EA-003 9 PBl Sub (2-Port) leatherfo 475PBl17 10 HYO JAR DAILEY· 1400-1407 11 6 Jts HWDP 4" HWOP NAD 12 72 Jts. OP 4" 720P 4 NAD 13 XO 400008C NAD 14 Dart Valve Sub CM7996 BPX 15 OP 5" to Surface OP NAD BHA and Run Objective Date In 17 -Mar-03 Time In 12:00 Depth In 12,105 TVD In 10,842 Drlg Hrs 10.8 Slide Hrs 0.0 Rot Hrs 10.8 Pump Hrs 20.8 PDM Jet 8 Bearing OSB Rubber RM1000 Sand % 0.1 Solids % 0.6 OD ID 6 1/8 3X15 Jets Tool BHA# Date Out 19-Mar-03 Time Out 14:30 Depth Out 12,424 TVD Out 11,158 Drlg Ft 319 Slide Ft 0 Rot Ft 319 Rotate % 100 Inclln 13.30 Az In 267.83 Incl Out 9.01 Az Out 272.11 Avg Dls 2.0 Max Ds 2.4 RPM 70 GPM 320 DIg TQ 16.5 WOB 20 $tabOD F.N. Bottom C~rin 'In/oUt Top Conn 5 7/8 5 15/16 5 3/4 5 1/4 BHA Weight Dr¡ Wt 46,602 Buoyed Wt 40,071 Inel Angle 10 Buoy+lncl wt 39,462 "---SCfiTITmDerger I-'nvate Bit To Oens=35.5', Nuet=38.65', Res=59.94', GR=64.86', 0&1=93.92', GR=96.92' Rotary drill to TO, drop 1/100'. -----,-,._-~~.'_., '_.'-~--- ..,.,,------......---.'-.--........"'-.-.-.-..-- .---- 4 3/4 4 3/4 2 1/4 4 3/4 Tool 4 3/4 Tool 4 13/16 Tool 4 3/4 2 1/4 4 3/4 2 1/4 4 3/4 2 1/4 5 1/4 2 1/4 4 2 11/16 4 3 5/16 6 1/4 2 5/8 6 3/4 3 1/8x4 1/2 5 4 1/4 BHA and Run Results I Bha droppe.9.,_~_~.~g.', walk rig~~,~1 00' ___...._ ;-o~ating. Rotate 100% to TO. WhyPOOHIComments POOH for,~~~__~~od run. 1.55 3 1/2 Reg P 3 1/2 Reg B 31/2IF'B 3 1/2 IF P 3 1/2 IF B 3 1/2 IF P 3 1/2 IF B 3 1/2 IF P 3 1/2 IF B 3 1/2 IF P 31/21FB 3 1/2 IF P 3 1/2 IF B 3 1/2 IF P 3 1/2 IF B 3 1/2 IF B 31/2 IF P 3 1/2 IF P HT40 HT 40 P HT40 B HT 40 P HT 40 B HT 40 P 41/21FB 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 2.10 17.78 1.47 1.48 1.85 Bit Data IADC # Footage 319 Hrs 10.8 k Revs 114 k Grade 4-2-BT -A-E-I-JO- TO ~omment 5 Hole Size 6 1/8 Hole Sect Production Bha Type Steerable Hrs BRT 50.50 Avg ROP 29.54 Slide ROP 0.00 Rot ROP 29.54 Slide % 0 Bit>Srvy 93.92 T/F Corr 257.1 Plan Dls 1.0 SPP On 1650 SPP Off 1500 Length Cum Length 0.75 23.49 4.87 24.86 23.17 33.84 30.88 31.01 8.09 30.12 184.06 2260.88 1.88 2.37 Tool Motor Jars Bit #4 Hrs. In 43.4 100.6 0.0 0.75 24.24 29.11 53.97 77.14 110.98 141.86 172.87 180.96 211.08 395.14 2656.02 2657.90 2660.27 2660.27 Hrs. Out 64.2 111.4 10.8 20.8 - ,...-- ~ - ,......, - ~ - ~ ~ --. ~ -- -.--¡ Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS16 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR 7" inch at DRILLING SERVICES Rig: NABORS DRLG RIG 33E 4 1/2" inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 2343361 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out Whr % GRADE 1 1 MX-C1 6004904 16 1.031 201 334 133 .6 222 35 Not Graded 2 1 rr MX-C1 6004904 16 1.031 334 3514 3180 18.8 169 35 120K 29 1-1-WT-A-E-IN-NO-TO 3 2 RSX238HF+GS 202936 12.25 0.941 3514 10460 6946 50.2 138 160 482K 0 2-1-WT -N-X-I-BT - TO 4 3 OS70FNPV 202317 8.5 .907 10460 12105 1655 21.6 77 100 300K 4 1-1-WT-A-X-I-ER-PTO 5 4 XR30YD200GPO 6.125 0.518 12105 12424 319 23.6 14 74 168 6 - - - - - -, - ......- ~ - - - - - Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS16 13.375" inch at 3494 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 10435 ft lease: NORTHST AR 7" inch at 12094 ft DRILLING SERVICES Rig: NABORS DRilLING RIG 33E 4.5" inch at ft Mud eompany: BAROID DRilLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22106 Depth MW Vis PV yp Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ib/gal sec LB/100 10S/10M ml/30 ml@deg F 32's % % % % mgelhg ppm ppm Uö/~6/U~ ~U1 6.9 1U:) ~U :)~ 1 3/~U/~3 1U.U ~ 4.U U.U 9ö.U U U.U 11.1 U.U4 U.UU/1.4U 19UUU Ö4U Î-'rep to :;pua Uö/~II/U~ 1UU4 9.U 13Þ ~4 (U 14123/~:) 1:).U ~ 4.6 U.4 94.6 1.:) U.U 6.9 U.U4 .06/.~:) 19UUU 1~4U '\mll mg Uö/3U/U~ 3Þ14 9.3 6~ 111 4J 19/34137 13.:) ~ ö.4 u.ö 93.U ~.U 7.:) 9.1 U.3U U.~:)/U.:):) 16ÞUU 1~UU ¡"UUH U7/U1/0~ 3:)14 9.3 (:) 17 33 1 U/~U/~:) 13.U ~ (.U U.:) 9~.:) 1.6 6.U 6.0 U.UU U.UUlU.öU 19UUU 1~~U '\;t:Mt:N liNt;¡ U7/U~/U~ J:)14 6.7 47 16 ~~ 7/1111U 9.:) ~ ~.:) U.U 97.Þ 1.4 U.U 9.:) U.~U U.2:)/U.(U 19UUU 94U KIH U flU3/U~ 49:):) 6.9 öö 19 3U 1U/1411Ö 9.3 1 4.U U.:) 9:).:) 1 ~.O 9.3 U.~U U.1U/U.% 180UU 1U6U 'ùrlllmg U7/U4IU2 (37:) 6.9 ö6 14 ~ö 6/11113 6,:) 1 4.1 1.:) 94.4 .:)U 3.:) IS.:) U.UU U.U4IU.3:) 16UUU 94U LJrlIII n 9 U flU:)/U2 94JU 1U.U 4ö ~U 3U 1U/17/19 3.6 ~ 1U.U 2.U 66.U .1U :).U 6.:) U.UU .U4/U.ÖO 160UU 6UU 'ùrllllng U7IUö/U2 1U4öU 1U.1 4ö 14 ~6 11/17/2U :).Þ 11.U 1 1U.U 1.~ 66.6 .~U 6.:) 6.ö U.2U U.UIS/U. (0 16:)UU 64U .....UUH U7/U flU2 1 U4tiU 10.U 4J 13 ~1 9/1111:) :).:) 11.:) 1 1U.U 1.U 69.U .~O 1U.U 6.9 U.1U U.0:)/7.UU 19UUU 62U '\..¡u tsHA "3 U7/U6/U2 1U4öU 1U.U 49 11 19 fl1UI12 6.:) U.6 1 1U.U 1.U 69.U .~:) 1U.U 6.:) U.UU U.U4/U.3U 165UU 9ÖU '\;ementmg 9.ö~ U "UII/U2 1U4öU 1U.U 44 1U 16 7/1111 1 6.ö 1 1U.U 1.U 611.U .~O 11.U 6.5 U.U4 U.UO/U.3U 19UUU IIUU KIH W/6.5 tslt U"1U/U2 11~ÖU 12.U :)U ~II ~ö 1214415U 6.2 1~.5 ~ ~U.U ~.U (6.U .1U 6.U 6.6 U.UU U.1U/U.ISU 51UUU 1~4U 'ùrllllng U"11/U2 1~1U5 12.U % 17 22 6/~ö/31 4.ö 1U.Ö 1 17.U ~.U 61.U .~5 6.U 6.5 O.ÖU U.1 :)/1.UU 52UUU 1UUU ¡"UUH for 7" U7/121U2 1~1U:) 12.~ :)1 ~~ 2U 6/2413U 4.ö 1U.~ 1 16.U ~.U 6U.U .~5 9.U 6.6 U.U5 U.U111 .~U :)3UUU 1UUU ¡"UUH for ,.. U7I13/U2 U1U5 n.1 :)4 ~1 2U 1/15116 4.ö 1U.6 1 19.U 2.U (9.U .~5 II.U 6.5 O.U:) U.U2I1.2U 54UUU 116U 'ùISP seawater U7I14/U2 1~1U5 6.:) ~6 U U U U.U U.U U 1.U U.U 911.U U U.U U.O O.UU U.UUlU.UU 16UUU U ~ea water Uf/1:)/U~ 121:)0 6.b ~6 U U U O.U U.U U 1.U U.U 119.U U U.U U.O U.UU U.UUlU.UU 111UUU 1UUU ~ea water U3/1 flUJ 124~4 9.3 4~ 1U U 1211:)/" 4.~ U.O 1 7.U 1.U 9~.U .1 u.ö 9.1 0.1U U.0:)/1.1U ~1UUU 12UU "IInaa ...ass U3116/U3 1~4~4 9.3 4~ 11 ~5 1211411ö 4.U U.U 1 7.U 1.U 92.U .1 U.Ö II.U U.1U U.0:)/1.1Ö ~1UUU 1~UU KIH W/4.5 l;sng Page 1 of 3 **Projections and Interpolations in Italics** 6/16/2003-4: 1 0 PM ns 16final surveys.xls Survey I Client: BP Exploration Alaska Survey Computation Method: Minimum Curvahrre Field: Northstar DLS Computation Method: Lubinski ,I Structure: Northstar PF Vertical Section Azimuth: 267.800° Well: NS16 Vertical Section Origin: N 0.000 ft, E 0.000 It Borehole: NS16 TVD Reference: Borehole: KB UWUAPI#: 50-029· 55.8 It above MSL [I Date: July 11,2002 Magnetic Declination: 26.290° Grid Convergence: 1.23170678° Total Field Strength: 57541.969 nT Scale Factor: 0.99992902 Dip: 80.944° Declination Date: July 05, 2002 [I Location: N 70 29 28.174, W 148 41 35.878 Magnetic Declination Model: BGGM 2002 : N 6030971.560 ftUS, E 659829.810 ftUS North Reference: True North Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Coordinate Reference To: Wellhead (True) ( Comment MD Incl Azim TVD VSec NS EW Closure CIAzim DLS (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0) (0 ¡100ft) Tie-In 0.00 0.00 267.80 0.00 0.00 0.00 0.00 0.00 0.00 Gyro 50.00 0.94 282.89 50.00 0.40 0.09 -0.40 0.41 282.89 1.88 [ 3yro 100.00 1.39 278.89 99.99 1.39 0.28 -1 .40 1.43 281.19 0.91 3yro 150.00 2.24 275.10 149.96 2.95 0.46 -2.97 3.01 278.75 1.72 Gyro 200.00 2.39 275.77 199.92 4.95 0.65 -4.98 5.02 277.42 0.30 ( 3yro 269.00 2.54 273.98 268.86 7.90 0.90 -7.94 7.99 276.4 7 0.24 3yro 361.00 2.49 280.72 360.77 11.87 1.41 -11.94 12.02 276.75 0.33 Gyro 450.00 2.76 280.11 449.68 15.85 2.15 -15.94 16.09 277.67 0.30 Gyro 540.00 3.34 277.39 539.55 20.55 2.87 -20.68 20.88 277.89 0.66 t 3yro 630.00 4.93 271.58 629.31 27.00 3.31 -27.14 27.35 276.95 1.82 Gyro 720.00 5.79 272.70 718.92 35.38 3.63 -35.54 35.73 275.83 0.96 Gyro 810.00 7.38 276.28 808.32 45.62 4.48 -45.83 46.04 275.58 1.82 ( 3yro 843.00 7.95 279.91 841.03 49.95 5.10 -50.18 50.44 275.80 2.27 V1WD DMAG 933.38 9.34 286.36 930.38 63.01 8.24 -63.38 63.91 277.41 1.87 MWD DMAG 1028.89 11.60 282.98 1024.29 79.63 12.58 -80.17 81.15 278.92 2.45 ( \AWD DMAG 1123.71 13.90 274.23 1116.78 100.15 15.57 -100.82 102.02 278.78 3.16 V1WD DMAG 1219.39 15.75 271.83 1209.27 124.53 16.83 -125.27 126.39 277.65 2.04 MWD DMAG 1314.14 16.66 273.18 1300.25 150.88 17.99 -151.68 152.74 276.76 1.04 MWD DMAG 1409.45 18.76 274.53 1391.04 179.70 19.96 -180.60 181.70 276.31 2.24 I VlWD DMAG 1503.93 20.84 272.53 1479.93 211.55 21.90 -212.54 213.67 275.88 2.32 MWD DMAG 1599.00 23.64 269.29 1567.93 247.46 22.41 -248.51 249.51 275.15 3.21 MWD DMAG 1694.87 26.08 265.29 1654.91 287.74 20.44 -288.74 289.46 274.05 3.09 \1WD DMAG 1790.01 28.82 262.16 1739.34 331.46 15.60 -332.31 332.67 272.69 3.25 \t1WD DMAG 1882.86 29.69 264.05 1820.34 376.68 10.16 -377.35 377.49 271.54 1.37 MWD DMAG 1978.38 30.93 266.35 1902.81 424.83 6.15 -425.38 425.42 270.83 1.78 V1WD DMAG 2072.62 31.50 268.16 1983.41 473.66 3.81 -474.16 474.17 270.46 1,16 \t1WD DMAG 2168.92 30.96 269.24 2065.75 523.58 2.68 -524.07 524.08 270.29 0.81 .\t1WD DMAG 2265.53 30.80 270,92 2148.67 573.12 2.74 -573.65 573.66 270,27 0.91 MWD DMAG 2362.71 30.66 271.72 2232.20 622.69 3.89 -623.30 623.31 270.36 0.44 \¡1WD DMAG 2458.01 31.65 268.49 2313.76 671.94 3.96 -672.58 672.60 270.34 2.04 MWD DMAG 2552.39 31.30 269.41 2394.26 721.20 3.05 -721.85 721.86 270.24 0.63 MWD DMAG 2648.36 31.39 270.86 2476.22 771.08 3.17 -771.77 771.78 270.24 0.79 MWD DMAG 2743.14 31.60 267.08 2557.05 820.56 2.28 -821.26 821.26 270.16 2.09 MWD DMAG 2838.55 31.72 266.63 2638.26 870.64 -0.4 7 -871,26 871.26 269.97 0.28 ,'v1WD DMAG 2933.88 29.79 267,61 2720.18 919.38 -2.93 -919.94 919.95 269.82 2.09 Page 2 of 3 .....Projections and Interpolations in Italics..... 6/16/2003-4: 1 0 PM ns 16final surveys.xls I Comment MD Incl Azim rYD YSec NS EW Closure CIAzim DLS I (ft) n n (ft) (ft) (ft) (ft) (ft) n (0/1 DOft) ( .J1WD DMAG 3029,84 29,89 267,67 2803.42 967,12 -4.90 -967.65 967,66 269,71 0.11 ,,1WD DMAG 3124.90 30.51 268.03 2885.57 1014,94 -6.69 -1015.43 1015.46 269.62 0.68 MWD DMAG 3221 .44 31.26 267,72 2968.42 1064.50 -8.53 -1064,95 1064,99 269.54 0.79 MWD DMAG 3316.59 31.97 268.30 3049.45 1114.37 -10.26 -1114.80 1114.85 269.47 0.81 ( .J1WD DMAG 3409.86 31.70 268.34 3128.69 1163.57 -11.70 -1163.98 1164.04 269.42 0.29 3446.83 31.52 269.04 3160.18 1182.94 -12.14 -1183.35 1183.41 269.41 1.11 ,v1WD DMAG MWD DMAG 3602.01 31.10 267.68 3292.76 1263.58 -14.45 -1263.95 1264.04 269.35 0.53 I 'v1WD DMAG 3696.89 31.62 267.17 3373.78 1312.95 -16.67 -1313.28 1313.39 269.27 0.62 v1WD DMAG 3793.31 31.82 266.19 3455.80 1363.64 -1 9.60 -1363.89 1364.03 269.18 0.57 ,IiWD DMAG 3888.26 32.15 265.81 3536.33 1413.91 -23.11 -1414.06 1414.25 269.06 0.41 ( \>IWD DMAG 3983.92 31.75 265.41 3617.50 1464.49 -26.99 -1464.53 1464.78 268.94 0.47 \i1WD DMAG 4079.27 31.47 264,37 3698,70 1514.40 -31.44 -1514.31 1514.64 268.81 0.64 v1WD DMAG 4173,31 30.90 263.69 3779.15 1562.99 -36.50 -1562.74 1563.16 268.66 0.71 MWD DMAG 4267,53 30.39 262.50 3860.22 1610.85 -42.27 -1610.41 1610.97 268.50 0.84 ( MWD DMAG 4363.74 30.22 261.74 3943.28 1659.16 -48.92 -1658.50 1659.22 268.31 0.44 v1WD DMAG 4459.43 29.82 260.41 4026.13 1706.70 -56.35 -1705.79 1706.73 268.11 0.81 MWD DMAG 4555.46 29.48 260.40 4109.59 1753.81 -64.26 -1752.64 1753.81 267.90 0.35 MWD DMAG 4651.24 29.06 260.14 4193.14 1800.24 -72.18 -1798.79 1800.24 267.70 0.46 I \i1WD DMAG 4746.57 28.42 259.67 4276.73 1845.64 -80.21 -1843.92 1845.66 267.51 0.71 v1WD DMAG 4841.21 27.87 259.76 4360.18 1889.84 -88.18 -1887.84 1889.90 267.33 0.58 MWD DMAG 4934.90 27.43 260.53 4443.17 1932.93 -95.62 -1930.68 1933.05 267.16 0.60 ( Ii1WD DMAG 5027.97 26.86 260.58 4525.99 1975.05 -102.59 -1972.57 1975.23 267.02 0.61 v1WD DMAG 5123.53 26.64 260.87 4611.32 2017.74 -109.53 -2015.02 2017.99 266.89 0.27 MWD DMAG 5217.67 26.67 262.36 4695.45 2059.72 -115.68 -2056.79 2060.05 266.78 0.71 MWD DMAG 5313.06 26.60 263.71 4780.72 2102.33 -120.87 -2099.24 2102.72 266.70 0.64 ( Ii1WD DMAG 5406.09 26.60 264.73 4863.91 2143.90 -125.06 -2140.68 2144.33 266.66 0.49 MWD DMAG 5501.63 26.54 265.95 4949.36 2186.60 -128.54 -2183.27 2187.05 266.63 0.57 MWD DMAG 5596.52 26.61 267.01 5034.22 2229.04 -131.14 -2225.64 2229.50 266.63 0.51 ( Ii1WD DMAG 5691.50 26.64 268.62 5119.13 2271.60 -132.76 -2268.17 2272.05 266.65 0.76 Ii1WD DMAG 5786.77 26.60 269.16 5204.30 2314.28 -133.59 -2310.85 2314.71 266.69 0.26 MWD DMAG 5881.06 26.35 269.60 5288.70 2356.30 -134.05 -2352.88 2356.70 266.74 0.34 I \i1WD DMAG 5976.44 26.25 270.58 5374.21 2398.52 -133.98 -2395.14 2398.89 266.80 0.47 V1WD DMAG 6072.87 26.19 272.43 5460.72 2441.03 -132.86 -2437.73 2441.35 266.88 0.85 MWD DMAG 6166.64 26.33 273.08 5544.81 2482.36 -130.87 -2479.17 2482.62 266.98 0.34 MWD DMAG 6261.78 26.14 272.74 5630.15 2524.25 -128.73 -2521.17 2524.45 267.08 0.25 I V1WD DMAG 6356.60 26.17 272.17 5715.26 2565.91 -126.94 -2562.93 2566.07 267.16 0.27 MWD DMAG 6453.98 26.12 272.09 5802.68 2608.70 -125.35 -2605.81 2608.82 267.25 0.06 MWD DMAG 6548.62 25.93 272.25 5887.72 2650.10 -123.78 -2647.30 2650.20 267.32 0.21 I 'vIWD DMAG 6643.75 26.40 272.22 5973.11 2691.93 -122.14 -2689.22 2691.99 267.40 0.49 V1WD DMAG 6738.20 26.91 271.76 6057.52 2734.18 -120.67 -2731.57 2734.23 267.4 7 0.58 MWD DMAG 6833.00 27.24 270.95 6141.93 2777.25 -119.65 -2774.70 2777.28 267.53 0.52 V1WD DMAG 6928.58 27.50 270.40 6226.81 2821.13 -119.14 -2818.64 2821,16 267.58 0.38 \1WD DMAG 7022.43 27.91 269.86 6309.90 2864.73 -119.04 -2862.27 2864.75 267.62 0.51 MWD DMAG 7119.26 28.54 268.82 6395.22 2910.51 -119.57 -2908.06 2910.52 267.65 0.83 MWO DMAG 7221.83 28.86 268.60 6485.19 2959.76 -120.68 -2957.30 2959.77 267.66 0.33 \1WD DMAG 7315.05 28.63 268.62 6566.92 3004.58 -121.77 -3002.12 3004.59 267.68 0.25 MWO DMAG 7408.15 28.47 268.61 6648.70 3049.07 -122.84 -3046.60 3049.08 267.69 0.17 MWD OMAG 7503.39 28.23 268.63 6732.51 3094.29 -123.93 -3091.82 3094.30 267.70 0.25 MWD DMAG 7598.11 28.08 268.87 6816.03 3138.98 -124.91 -3136.50 3138.99 267.72 0.20 MWD DMAG 7694,13 27.95 268.57 6900.79 3184.08 -125.91 -3181.59 3184.08 267.73 0,20 I I Comment MD Incl Azim TVD VSec NS EW Closure CIAzim DlS I (ft) n (0) (ft) (ft) (ft) (ft) (ft) (0) (°11 DOft) I MWD DMAG 7787.96 27.79 268,07 6983.74 3227,94 -127,20 -3225.43 3227.94 267,74 0,30 \i'WD DMAG 7889.62 27.44 267.73 7073.82 3275.06 -128.92 -3272.52 3275.06 267.74 0.38 í'viWD DMAG 7987.35 27.07 267.30 7160.70 3319.81 -130.86 -3317.24 3319.82 267,74 0.43 MWD DMAG 8079.84 26.76 267,17 7243.17 3361,68 -132.88 -3359.05 3361.68 267.73 0.34 I "'WD DMAG 8174.64 26.44 266.22 7327,94 3404,12 -135.33 -3401.43 3404.12 267.72 0,56 8270.27 26.69 266.96 7413.47 3446.87 -137.87 -3444.12 3446.88 267.71 0.43 MWD DMAG MWD DMAG 8368.44 26.67 267.34 7501.19 3490.95 -140.06 -3488.14 3490.96 267.70 0.17 ( MWD DMAG 8461.77 26.59 267.33 7584.62 3532.78 -142.01 -3529.93 3532.79 267.70 0.09 MWD DMAG 8565.89 27.00 268.90 7677.56 3579.71 -143.55 -3576.84 3579.72 267.70 0.79 MWD DMAG 8661.33 27.57 269.48 7762.38 3623.45 -144.16 -3620.59 3623.46 267.72 0.66 ( MWD DMAG 8756.14 27.86 269.07 7846.31 3667.53 -144.72 -3664.68 3667.53 267.74 0.37 MWD DMAG 8851.96 28.29 268.93 7930.86 3712.62 -145.51 -3709.77 3712.62 267.75 0.45 ,MWD DMAG 8947.56 28.69 267.97 8014.88 3758.21 -146.75 -3755.35 3758.22 267.76 0.64 MWD DMAG 9041.91 29.01 267.66 8097.52 3803.74 -148.48 -3800,84 3803.74 267.76 0.37 MWD DMAG 9134.86 29.54 267.53 8178.60 3849.19 -150.39 -3846.25 3849.19 267.76 0.57 ( MWD DMAG 9238.41 30.65 268.10 8268.19 3901.11 -152.36 -3898.14 3901.11 267.76 1.11 MWD DMAG 9334.58 31.47 268.20 8350.57 3950.73 -153.97 -3947.73 3950.73 267.77 0.85 MWD DMAG 9423.65 31.83 268.22 8426.39 3997.47 -155.43 -3994.44 3997.4 7 267.77 0.40 ( MWD DMAG 9519.46 32.14 268.94 8507.66 4048.21 -156.68 -4045.18 4048.21 267.78 0.51 MWD DMAG 9613.99 32.68 270.03 8587.46 4098.85 -157.13 -4095.84 4098.85 267.80 0.84 MWD DMAG 9714.23 31.42 269.41 8672.42 4152.01 -157.39 -4149.03 4152.01 267.83 1.30 (MWD DMAG 9808.76 30.31 268.77 8753.57 4200.50 -158.15 -4197.52 4200.50 267.84 1.22 MWD DMAG 9903.73 30.66 268.24 8835.41 4248.67 -159.41 -4245.68 4248.67 267.85 0.46 MWD DMAG 9997.85 31.05 267.36 8916.21 4296.94 -161.27 -4293.92 4296.94 267.85 0.63 MWD DMAG 10092.54 31.99 265.18 8996.93 4346.42 -164.50 -4343.31 4346.42 267.83 1.56 ( MWD DMAG 10187.02 30.96 264.74 9077.51 4395.69 -168.83 -4392.44 4395.69 267.80 1.12 MWD DMAG 10281.30 29.06 262.96 9159.14 4442.72 -173.86 -4439.32 4442.73 267.76 2.23 MWD DMAG 10374.64 28.13 261.59 9241.10 4487.19 -179.86 -4483.59 4487.19 267.70 1.22 (MWD DMAG 10398.98 28.18 262.33 9262.56 4498.61 -181.46 -4494.96 4498.62 267.69 1.45 MWD DMAG 10539.99 28.44 262.14 9386.70 4565.17 -190.50 -4561.22 4565.20 267.61 0.20 MWD DMAG 10634.53 26.94 262.66 9470.41 4608.91 -196.31 -4604.76 4608.95 267.56 1.61 I MWD DMAG 10730.34 26.13 263.62 9556.13 4651.56 -201.43 -4647.26 4651.62 267.52 0.96 MWD DMAG 10824.24 25.28 263.44 9640.74 4692.18 -206.02 -4687.73 4692.25 267.48 0.91 MWD DMAG 10918.33 23.86 264.20 9726.31 4731.21 -210.24 -4726.62 4731.29 267.45 1.55 MWD DMAG 11013.11 23.01 263.91 9813.27 4768.82 -214.14 -4764.11 4768.92 267.43 0.91 I MWD DMAG 11105.75 22.37 263.50 9898.74 4804.46 -218.06 -4799.63 4804.58 267.40 0.71 MWD DMAG 11201.31 22.50 263.94 9987.06 4840.84 -222.05 -4835.88 4840.98 267.37 0.22 MWD DMAG 11297.96 22.05 264.56 10076.50 4877.40 -225.72 -4872.33 4877.56 267.35 0.53 ( MWD DMAG 11389.45 22.62 265.29 10161.13 4912.13 -228.79 -4906.96 4912.29 267.33 0.69 MWD DMAG 11483.67 21.66 265.25 10248.40 4947.60 -231.72 -4942.35 4947.78 267.32 1.02 MWD DMAG 11579.48 20.02 265.94 10337.94 4981.66 -234.35 -4976.33 4981.85 267.30 1.73 MWD DMAG 11674.15 18.21 266.09 10427.39 5012.65 -236.50 -5007.26 5012.84 267.30 1.91 MWD DMAG 11767.85 16.99 266.77 10516.70 5040.97 -238.27 -5035.53 5041 . 17 267,29 1.32 ~WD DMAG 11863.25 15.52 267.85 10608.28 5067.67 -239.54 -5062.20 5067,87 267.29 1.57 ~"WD DMAG 11957.31 14.51 268.18 10699.13 5092.04 -240.38 -5086.56 5092.23 267.29 1.08 I MWD DMAG 12043.27 13.30 267.83 10782.57 5112.69 -241.10 -5107.20 5112.89 267.30 1.41 . ?rojected Survey 12105.00 13.30 267.83 10842.64 5126.89 -241.64 -5121.39 5127.09 267.30 0.00 I I ns 16final surveys.xls Page 3 of 3 "'Projections and Interpolations in Italics'" 6/16/2003-4: 1 0 PM I r I I ( NS16 Prognosed Tops Actual Depths Formation TVDss TVDrkb MDrkb TVDss TVDrkb MDrkb Top Permafrost ! , i-F) 1:::n:; i :::: jl} 1139 1195 1204 Base Permafrost \.:;¡() I~j:; ì 6:--i 1516 1572 1603 SV6 - top confining zone _~.UO= ~U:\8 ~~~~1:2 2988 3044 3311 Surface casing point 3,174 3322 3508 3144 3200 3494 SV5 - base confining zone :'.2Óh ~~32~ ~; (1 I 3 3254 3310 3622 SV4 _~.55: _~6! ~ :1 (j.-1- ~¡. 3566 3622 3989 SV2 - top upper injection zone 3.960 -W it) 44()3 3956 4012 4443 SVl - top major shale barrier -L~6 i .¡-[ 17 -f:-:59 4347 4403 4890 TMBK - top lower injection zone - Top Ugnu 4,,¡-(Q "[760 5250 4702 4758 5287 WSl - top Schrader Bluff - Base Ugnu 6.39,cf 6450 7' ! ~~ 6267 6323 7037 CM3 - Base lower injection zone (top Colville) 6.835 6801 7676 6835 6891 7683 THRZ-TopHRZ 8,511 RS78 9597 8548 8604 9634 BHRZ - Base HRZ 8.620 8676 9708 8638 8694 9740 Top Kuparuk 8.670 8726 9765 8680 8736 9788 Kuparuk C 8.831 8887 9948 8887 8943 10030 Top Miluveach 9,i 99 9255 10367 9204 9260 10396 Intermediate casing point 9,250 9306 10425 9238 9294 10435 Intermediate logging point 9,250 9306 10425 9238 9294 10435 Kingak 9.1'23 9779 10955 9723 9779 10976 Top Sag River 10.768 10824 12076 10747 10803 12064 Geol. Target 10,768 10824 12076 10747 10803 12064 Intermediate casing point 10,808 10864 12118 10787 10843 12105 Top Shublik 10,858 10914 i2170 10842 10898 12162 Top Ivishak 10,950 11006 11166 10936 10992 12258 Total Depth 11,080 11136 12400 11100 11156 12424 Oil - Water contact 11,100 11156 12420 Top Kavik Top Lisburne ( I ( I I ( I r I I I I I I Formation Logs NORTHSTAR NS16 I I I I I I I I I I I I I I I I I I I END OF WELL REPORT REPORT FROM SPUD TO TOP SAG RIVER c!)Oð -ldl BP EXPLORATION ALASKA sper-ar-aV-5un [J R I L..L..I N G 5 E FI V I c: E 5 T ABLE OF CONTENTS I 1. General Information 2. Daily Summary 3. Daily Operations 4. Show Reports 5. Morning Reports 6. BHA's 7. Bit Record 8. Mud Reports 9. Survey Record I 10. Formation Tops 11. Formation Evaluation Logs I I I I spe.....l.....v- sun ¡:¡ ptl L.L.I N t:ii Së R\l1 c: e 5 I I I [ II GENERAL WELL INFORMATION I Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: I I Company Representatives: Company Geologist: I I I I I Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS12 Northstar North Slope Alaska United States 50-029-23091-00 AK-AM-22092 June 7,2002 June 28, 2002 True 26.312 deg 80.943 deg 57541.033 nT Jun 4, 2002 North 70 deg 29 min 27.28 see East 148 deg 41 min 35.84 see 120.750 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Jeff Smith Joe Polya Mike Dinger Ken Lemley Northstar 107 Alaska North Slope sparr·"v-sun CRt'-'-1 N G SER\JIc:es BP Exploration Daily Sumlnary NS 12 06/07/02 Move rig from NS06 to NS12 slot. Preparing to spud. Nipple up riser. 15/08/02 Pickup BHA # 1 (Bit # 1, 16" MX -C 1 , TF A = 1.031 ). Clean out 20" conductor. Some excess metal noted across shakers (approx. 1-21bs.) Drill 16" hole to 260' MD. Rig up and fW1 wireline gyro survey. Bottom of I )nductor across dard line for collision with NS13 well path. Ran gyro every 30 feet to 550' MD, then switched to 90 _Jot gyros. Samples seen at shakers as usual for this interval (clays and gravels). Drill to 603' MD. Maximum ROP in this interval was 556 ft/hr at 512' MD. No methane gas was seen on the gas chromatograph, but a maximum gas of " ~ units was seen at 201' MD due to mud additives Dril-N-Slide and Torque trim present in the spud mud that was "41Ïnned for use from the mud used to drill the 8 ~" drilling interval on well NS06. 16/09/02 Drill from 603' to 785' MD. Circulate bottoms up. Trip out of the hole to pickup BHA #2 (Rerun Bit #1 ), ,lith MWD. Trip in hole and continue drilling from 785' to 2233' MD. Continue running gyro to 1450' MD. Maximum ROP in this interval was 684 ft/hr at 1067' MD. Maximum gas was 27 units at 1647' MD. First traces of 1 Lethane gas was noted at 1086' MD. Continuous methane gas was first encountered below 1213' MD. Top of the permafrost was at 1212' MD, 1195' TVD. Base of the permafrost was 1625' MD, 1585' TVD. , l6/10/02 Drill from 2233' to 3647' MD. Total Depth of the 16" section was at 3647' MD, 3217' TVD. Pumped a weep and circulated bottoms up 3 times until hole was clean. Trip out of the hole. Lay down BHA #2. Rig up to run 68# 13 3/8" casing. Top of the SV6 marker was 3486' MD, 3088' TVD. Maximum ROP from 2233 to 3647 1 Tas 532 ft/hr at 2427' MD. Maximum gas was 20 units at 2360' MD. Bit # 1 statistics= 3446 feet, 21.6 hours and 125.8 K revolutions. 16111/02 Rig up to run 13 3/8" casing. Repair Frank's tool-leaking. Run 68# 13 3/8" casing. Tight spot at 1100' lviD. Rig down casing tools. Rig up to cement. Circulate and condition mud. Maximum gas on bottoms up was 12 Ilmits. Pumped cement per plan. Displaced cement with rig pumps at 10 bpm.. Bumped the plug at 5070 strokes ( 7% efficiency). Nipple down riser. ~06/12/02 Nipple up BOP's. Test BOP's. Pick up BHA # 3 and bit #3 ( 12~" RS238HF+GS , TF A= .941 ). Trip in ole with the 12 ~" drilling assembly. 106113/02 Trip in hole with 12 ~" drilling assembly. Drill cement, float, shoe and 20' of new hole to 3667' MD. Þisplaced mud system to PHPA. Performed F.I.T. to 12.5 ppg EMW. Drilled 12 ~"hole from 3667 to 4401' MD. Rotary steerable tool failed. Pumped a Hi viscosity walnut wseep and Trip out of the hole. Pulled 3 stands, then ·"'umped out to the 13 3/8" casing shoe, due to swabbing and tight hole. Maximum gas was 24units at 3488 MD. 1aximum ROP was 535 ft/hr at 3467' MD. Top of the SV5 marker was 3834' MD, 3370' TVD. Top of the SV4 marker was 4214' MD, 3686' TVD. I 6/14/02 Trip out of the hole to change out rotary steerable assembly. Trip in hole with new rotary steerable assembly and rerun Bit # 3. Trip gas was 43 units. Drill ahead from 4401' to 7061' MD. Maximum gas of 1189 '-··nits was recorded from a coal stringer at 6629' MD. Maximum ROP was 610 ft/hr at 4618' MD. Top of the SV2 larker was 4703' MD, 4092' TVD. Top of the SVl marker was 5222' MD, 4497' TVD. Top of the Ugnu formation was 5726' MD, 4897' TVD. I 6115/02 Drill from 7061' to 8216' MD. Pumped a Hi viscosity 11.4 ppg LCM sweep. Circulated the hole clean. Trip out of the hole with tight spots at 7325' to 5445' MD. Pumped out of the hole from 5445' Md to the 13 3/8" lasing shoe. Circulated bottoms up at the 13 3/8" casing shoe with moderate amount of scrapings and wall cake. The mount of material coming over the shakers cleaned up after bottoms up. Trip out of the hole and change MWD to tools with CDR assembly. Rerun Bit #3. Maximum gas in this drilling interval was 167 units at 8090' MD. I BP Exploration ; Daily Summary NS 12 ï ~lVIaximum ROP in this interval was 400 ft/hr at 7772' MD. Top of the Schrader Bluff formation was 7758' MD, l,549' TVD. I ¡ IJ6/16/02 Trip in hole to 13 3/8" casing shoe. Slipped and cut drilling line and service top drive. Continue tripping in hole. Trip in went well. Maximum trip gas of 396 units was recorded. Drilled ahead from 8216' to 9067' MD. t [aximum gas in this drilling interval was 301 units at 8497' MD with a mud weight of 9.1 ppg. Maximum ROP was (¿03 ft/hr at 8298' MD. Top of the Colville formation was 8386' MD, 7045' TVD. 15/17/02 Drill 12 'l4" hole from 9067' to 10862' MD. Maximum gas in this drilling interval was 1116' units at 10564' MD from the base of the Colville formation. Maximum ROP was 220 ft/hr at 10691' MD. Mud weight was ;T\CreaSed to 10.0 ppg by bleeding in spike fluid at 10300' MD. Top of the HRZ formation was 10680' MD, 8888' . YD. Base of the HRZ formation was 10760' MD, 8953' TVD. Top of the Kuparuk formation was at 10800' MD, ~985' TVD. Top of the Kuparuk "c" formation was at 10977' MD, 9127' TVD. ~ 6/18/02 Drilled ahead. Top of the Miluveach formation was 11479' MD, 9538' TVD. Reached Total Depth for the 12 ~"interval at 11520' MD, 9574' TVD. Worked on pump, while circulating bottoms up with one pump. Pumped r Hi viscosity LCM sweep and circulated hole clean. Short tripped to 7939' MD. Pulled slightly tight through the :RZ. Tripped back in the hole. Took weîght through the top of the HRZ and Miluveach top. Pumped a Hi viscosity LCM sweep and circulated 1 ~ times to clean the hole. A short trip gas of 1369 units was recorded. Begin to Trip '~ut of the hole for the 9 5/8" casing run. 06/19/02 Continued trip out of hole. Laid down BHA. Installed 9 5/8" casing rams and tested seals to 3500psi. Run r I with 95/8" casing. 06/20/02 Continued to run in 9 5/8" casing. Stacked up at 11172'MD, unable to work pipe up or down. Annulus I 'as packed off, regained circulation and washed down last 8 joints with 3.1 bpm circulation. Made up casing hanger ld washed to land. There was approximately 15' offill at bottom of hole. Continued to circulate with Frank's tool at 8 bpm with no losses. Rigged up to cement and circulated to condition mud...Maximum gas at bottoms up was 2150 ["nits. Pumped cement as per plan. Began cleaning poits and nippling up. 06/21/02 Nippled up and tested BOPE. Ran in hole with bit #3 to 11368'. Washed down to top of float equipment I" ld pressure tested casing with 10.1 ppg mud to 4100 psi. 06/22/02 Drilled out shoe track and 20' of new hole to 11540' while bleeding in 16.4 ppg spike mud to raise weight ) 12.4 ppg. Two cirulations were required to balance out mud evenly to 12.4 ppg. Performed FIT with 800 psi _.)plied surface pressure. Directional drilled 8 ~" hole from 11540' to 12230' with an average gas of 50 to 75 units. Topped Kingak formation at 11855' MD, 9854' TVD. Had difficulty holding tool faces during slides. ~6/23/02 Topped Sag River formation at 13100' MD, 10867' TVD. Maximum gas from the Sag River was 240 units. Reached total depth for 8 ~"hole section at 13135' MD, 10895' TVD. Circulated a high viscosity sweep. potted a Therma- Thin pill prior to performing a short trip to the 9 5/8" casing shoe. Minor amounts of sloughing .L~ingak shale noted prior to short trip. Maximum drag reported during short trip of25K over. I 6/24/02 Completed wiper trip to shoe and serviced top drive. Ran back to bottom to clean out hole. Worked utrough tight spots where weight stacked up to 100K at 12300',12378', and 12665'. Washed through a tight spot at 13000'. Hole was then clean to bottom with no fill reported. Circulated a sweep and spotted new mud on bottom. hort trip gas was 400 units. Bottoms up showed minor amounts of splintered Kingak. Dropped Sperry-Sun ESS tvol and pulled out of the hole. Began running 7" liner. BP Exploration - Northstar NS 12 Daily Operations (I.A.D.C) 'I ~me { 's) Elapsed Time Operations Breakdown ~/07 /02 ,[ ',:00-00:00 4.00 : 108/02 t :00-03:00 3.00 Move Rig from NS06 to NS 12. I :00-05 :45 2.75 ( ):45-08:00 2.25 I :00-09:45 1.75 1':45-10:15 0.50 ,.15-12.00 1.75 ~:00-13 :30 1.50 I :30-14:00 0.50 kOO-14:30 0.50 I· :30-15:00 0.50 :00-15:30 0.50 ):30-16:30 1.00 ( , I 1 I I I I Make connections between Sub and Service Unit, Berm Rig and rig up disposal line. Note: Accepted Rig on NS12 Well @ 0300 hours on 6/8/02. Nipple Up Riser. Note: New 2 piece scoping riser design -- eliminates 2 connections and eliminates risk of riser falling onto adjacent wells during nipple up. Drift Riser with 13-3/8" casing hanger, fill with sea water and check for leaks -- none. Safety standdown with morning tour crew -- evaluate work areas for hazards. Check Oil in Top Drive while Staging Gyro Equipment to Rig Floor. PU BHA components. Safety standdown with day tour crew -- evaluate work areas for hazards. RU turn buckles on riser. Clean out Riser -- Spud well while drilling to 230' md. Held Pre-Spud Meeting and PJSM for RU Gyro. RU Gyro. Gyro Survey inside conductor at 174' md -- 2.46 deg incl & 297 deg az. Notes: 1. Project to 5.25' @ 230' md & 297 deg az which puts the wellbore 2' over the hardline toward NS 13. 9' away from NS 13 wellbore center. Do not expect to get any closer than 5' from NS13 well bore center while navigating close approach. 2. Contact Drillling Team Leader as per Drilling Policy requirement and discuss forward plan. a) NS 13 was left shut in since rig move and will be kept shut in until clear ofNS 13 close approach. b) Check NS13 9-5/8" x 13-3/8" annulus pressure -- 100 psi. Pressure up to 500 psi and monitor. Assign 2 men to monitor the annulus pressure while drilling by close approach. Provide men with mechanics stethescope to monitor casing for collision nOIse. c) Clean ditch magnets and monitor while drilling ahead. d) Do not drill more than 60' without performing a gyro survey to monitor directional results. e) Contract drilling team leader if plan fails to maintain minimum of 5' clearance from NS 13 wellbore center. I :30-22:30 6.00 ~:30-00:00 1.50 I ( ,/09/02 ):00-03: 15 3.25 t ~:15-05:00 1.75 I :00-08:45 3.75 ,.45-11.00 2.25 I, :00-12:00 1.00 C:00-16:30 4.50 (30-17:30 1.00 0.50 ' ':30-18:00 11:00-00:00 6.00 '1/10/02 ):00-11 :30 11.50 I :30-13:30 2.00 , :30-14:00 0.50 I :00-17:30 3.50 7:30-19:30 2.00 I :30-20:00 0.50 ):00-23:00 3.00 I ~:OO-OO:OO 1.00 ! 'I lll/02 :00-01 :30 0.50 I :30-11 :30 :1 BP Exploration - Northstar NS12 Daily Operations (I.A.D.C) Drilling and fW1 Gyro every 30'. At 473' md, 2.49 deg incl & 132.50' deg Az. Drill and slide 90'. Gyro @ 561' md, 3.06 deg incl & 106.54 deg Az. Notes: Cleared NS13 by 3.7' @ 354' md. Drill & Slide to 784' while running gyro survey every 30 to 60 feet as necessary to manage downhole close approach with NS 13 and NSI0. POOH to PU remaining BHA -- MWD, etc. PU remaining BHA while RIH to 784' md -- Test MWD. Drill & Slide to 1120' md while running gyro survey every 30 to 60 feet as necessary to manage downhole close approach with NS 13 and NSI4. Lost Power -- turbines shut down due to turbine overload while attempting to optimize solonox mode -- technician up trouble shooting solonox mode with turbirtes. Drill and Slide to 1474' while running gyro survey as needed. Run Gyro Survey -- Jorps confirmation of MWD survey measurement of 16.76 deg incl & 79.53 deg az @ 1216' md. Rig Down Gyro & Wireline Sheave. Drill and Slide from 1474' md to 2236' md. Complete build section rotating ahead. Inclination 37.18 deg and AZ 73.87 deg -- 10' right and l'low on plan. Drill ahead 16" surface hole from 2236' md to TD @ 3647' rod! 3218' TVD. Circulate for 13-3/8" casing run. Pump 80 bbls bentonite sweep. CBU 3 times until clean. PullS stands. Monitor well. Pump dry job. POOH. LD BHA #2. Near miss occured (see remarks). Clear and clean floor. PJSM fl running 13-3/8" casing. Reviewed near miss with tong line. RU to run casing. Run 13-3/8" float equipment and Bakerlock connections. 1 st Casing Joint has fixed SV rigid centrailizer. Next SV rigid centrailizers are floating with stop rings. Called Frank's tool hand to location after tool was broke down at end of job to familarize the roustabout pusher in care and maintenance of the fill-up tool. RIH with 13-3/8" 68# L80 Btrc Casing -- 89 joints total. Notes: ~ j II ( { l :30-12:30 1.00 I I' ~:30-13 :00 0.50 I :00-14:30 1.50 I :30-17:00 2.50 I I i ':00-18:00 1.00 BP Exploration - Northstar NS 12 Daily Operations (I.A.D.C) 1. Pipe stacked up at ~ 1100' Ut 28) requiring string to be PU and SO to get thru. 2. Pipe stacked up again on joints 78 and 79 (~31 00' with lithology change from clay into sand). 3. Pipe stacked up again during joints 85, 86 and 87 (top of SV6). Able to slack off and work pipe in hole with 10 to 20K downweight. When necessary PU and free pipe with 275K to 300K upweight-- then continue to SO. 4. RIH with last 2 stands and landing joint with 75K string weight. 5. Landed pipe with 75K down on hanger. 6. Lost total of23.6 bbls of mud running casing. MU mandrel casing hanger and landing joint and land hanger. Notes: 1. Shut down operation and held P JSM around the rotary table to discuss plan to make up casing hanger and landing joint. 2. Scope of operaiton changed during job -- shut down and discussed new plan, hazards and risk mitigation, Lay down Frank's Tool. Establish circulation and circulate minimum of one casing volume -- 561 bbls total. Pumped 75 bbls of treated mud spacer. Note: Held PJSM for cementing. Pump the Cement Job as follows: 1. Pump 5 bbls Sea Water and test cement lines to 3000 psi. 2. Mix and pump 75 bbls of 10.3 ppg spacer. 3. Drop bottom plug. 4. Mix and pump 476 bbls of lead (644 sx). 5. Mix and pump 100 bbls of tail (488 sx). 6. Drop top plug and displace cement out of suface lines with 25 bbls. Displace cement @ 10 bpm with 9.1 ppg drilling fluid. Notes: 1. 175 bbls of cement to surface. 2. Bumped plug @ 97% efficiency with mud pump #1 (5065 stks). 3. Held pressure for 2 minutes -- static. 4. Bled pressure and checked floats. Flush cement out of riser, drip pan, flowline, bypass line and trough. Pull riser and lay down in pipe shed. Magna-flux pad eye in derrick for tugger sheaves and Magna-flux the tugger on floor. Pulled the upper scoping section of riser and laydown in pipe shed. ND the lower section of scoping riser. f ':00-20:00 2.00 , :00-20:30 0.50 ):30-22:30 2.00 I :30-00:00 1.50 1/12/02 ):00..03 :00 3.00 I :00-09:00 6.00 I :00-10:30 1.50 ):30-12:00 1.50 I Replaced 2 tugger sheaves in derrick complete with lines and shackles. Pulled Scoping riser and ND Riser Base, MU Multibowl and NU BOPE stack. Note: Pull Test Tugger lines with dynamometer out of critical path. Clean up 5 gallon drilling fluid spill in cellar (see Remarks). Bell Nipple and Flowline. 1_:00-16:00 4.00 >:00-22:00 6.00 il I :00-22?0 0.50 ~.30-00.00 1.50 I ,(13/02 , ,:00-01 :30 1.50 l :30-03 :30 2.00 1,:30-04:30 1.00 k30-05:15 0.75 I I ;:15-07:15 2.00 I : 15-09:30 2.25 I :30-10:00 0.50 ,:00-11 :00 1.00 I I ,:00-12:00 1.00 1':00-16:00 4.00 BP Exploration - Northstar NS 12 Daily Operations (I.A.D.C) Note: Install 2 new air boots in scoping bell nipple. Finish NU the BOPE Koomey lines, turnbuckles, etc. Install Test Plug, Test BOPE to 4500 psi high I 250 psi low for 5 minutes each. Pull Test Plug. Notes: No failures, necessary to repair leak in fitting on Test Pump near gauge. Install Wear Ring. MU Bit, Bias Tool, Control Collar and MWD -- Flow test Bias and MWD. I I I :30-18:30 ~:30-20:00 I 1.00 1.50 Finish MU BHA #3 -- Rotary Steerable Assy RiH wi hwdp and dp -- wash down last stand& tag cement @ 3512' md. Drill cement to the shoe & circ cement out of hole. Test Casing to 3600 psi for 30 minutes -- 8.9 ppg mud weight. Notes: 1. Discussed Well Design and Well Control Practices. a. Reviewed the D 1 Kick While Tripping Drill. b. Reviewed the D2 Kick While Drilling Drill. c. Reviewed the D5 Well Kill Drill. Drill Float Collar @ 3548' md. Drill Cement to FS @ 3631' md, clean out rathole to 3647' md and drill 20' of new formation to 3667' md. Finish displacement to new mud. Note: Started displacement to new mud while drilling the float shoe. Perform FIT to 12.5 ppg EMW with 650 psi and 8.6 ppg drilling fluid. Prepare shaker room and pits to drill ahead after displacement. Notes: 1. Change over shaker screens. 2. Rinse out L Pit and ship mud to G&I for disposal. 3. Shipped 600 bbls of mud stored in G&I to rig pits. Drill ahead fl 3667' - 3834' md with Rotary Steerable Tool (RSS). Note: RSS in neutral setting. Drill ahead fj 3834' - 4190' md with RSS. Notes: 1. Signaled RSS for 36 deg tool face with 20% setting @ 3834' md. 2. No directional response detected from above setting. 3. Signaled RSS for 45 deg tool face with 60% setting @ 4022' md. 4. No directional response detected from above setting. Drill ahead fj 4190' - 4401' md with RSS. Decision to POOH to check RSS. Notes: 1. Signaled RSS for 36 tool face @ 100% setting @ 4117' md. 2. No directional response detected from above setting. 3. Signaled RSS for 341 deg tool face with 100% setting @ 4290' md. 4. No directional response detected from above setting. 5. Last Survey @ 4363' md is 31.7 deg incl & 71.0 deg az. 6. 15' or 5 deg low on angle & 4' or 4 deg left of plan. Sweep hole, monitor well and pump dry job. Attempt to POOH -- Well swabbing and unable to wipe offball. 1":00-17:30 1.50 I :00-21 :30 1.50 I . :30-22:30 1.00 ~:30-22:45 0.25 I ~:45-23:15 0.50 I I : 15-00:00 0.75 )/14/02 I : 00-01 : 15 1.25 l: 15-03:00 1.75 kOO-04:00 1.00 I :00-12:00 8.00 BPExploration - Northstar NS 12 Daily Operations (I.A.D.C) Necessary to pump out of hole to shoe. Note: Lesson Learned: Do not waste time with dry job when tripping through SV sands -- sticky clays require pumping out of hole. Pump dry job #2 and pooh to the BHA#3. P JSM -- Stand back the BHA. Circulate thru Control Collar and Bias Tool. Note: DD suspects that one of the two turbines in control collar is jammed. LD Control Collar and Bias Tool. Note: Inspect bit -- good condition; however, has piece of aluminum from drilling float equipment wedged in between two blade in nose of bit -- DD to send bit pictures to town. PJSM -- MU bit to new Control Collar and Bias Tool. I ):00-14:00 2.00 0.50 ~:00-14:30 ( 1:30-00:00 9.50 ~/15/02 ( :00-10:00 10.00 , f ):00-12:00 2.00 I :00-16:00 4.00 I I >:00-20:00 4.00 I :00-20:00 4.00 \ Finish MU BHA#4 -- Rotary Steerable Tool (RSS). RIH with BHA#4 on hwdp and dp. Wash thru tight spot @ 3900' - 4120' md. Finish RIH to 4401' md. Drill fl 4401' - 5452' md with RSS tool. Notes: 1. Pumped walnut hull sweep as bit started drilling to prevent balling. 2. Sweep every 500 feet or as required. 3. RIH with RSS setup for 0 tool face for 60% -- tool responding. Drill fl 5452' - 5831' md with RSS tool. Note: RSS tool responding well to downlinks. Circulate while changing shaker screens. Drill fl 5831' - 7066' md with RSS tool. Note: RSS tool responding well to downlinks. Drill f/7066' - 8217' md with RSS tool. Notes: 1. RSS tool responding well to downlinks. 2. Installed 2 non rotating stabilizers and plastic rotary bushing guard to effectively dampen the drill pipe harmonics and prevent excessive vibration of the top drive and derrick as was experienced on NS07 well. Pump hi-vis weighted sweep with nut plug & barafibre -- monitor well. POOH to 5455' md. Notes: 1. First 9 stands pulled trouble free. 2. Stand 10 required wiping twice due to swabbing @ 7257' md. Top of Schrader Bluff is at 7758' md. 3. Next 8 stands pulled with no problem. 4. Stands 19 thru 28 required wiping due to swabbing. Pump out of hole fl 5445' md to 13-3/8" surface shoe @ 3631' md. Notes: Stand 29 swabbed and attempts to wipe were unsuccessful. 2. Top ofUgnu formation is @ 563ß' md. I :00-21 :00 1.00 BP Exploration - N orthstar NS 12 Daily Operations (I.A.D.C) CBU with bit and bias tool positioned II' below the 13-3/8" shoe. Blow down top drive & mud line -- monitor well. Notes: 1. Pump @ 900 gpm and rotate @ 140 rpm. 2. Caught samples at shakers for mud engineer and mud loggers to analyse to determine content of what was pumped up into the shoe from the tight hole -- verdict is pending. POOH to hwdp, Monitor well for 10 minutes and continue to POOH with hwdp. Handle BHA#4, LD MWD tool and PU CDR. Notes: 1. Check bit -- graded O-O-CT -N-X-I-NO-CK. 2. Bit looked good with no wear on 90% of cutters -- there were 3 chipped teeth on the nose of bit but each had good cutters trailing on other blades -- decision to run bit. 3. Pictures of bit sent to Anchorage team via D D. I , :00-22:00 1.00 ~:00-22:30 0.50 I :30-00:00 1.50 I I ./16/02 t :00-02:00 2.00 ~:00-04:00 2.00 kOO-05: 15 1.25 1 : 15-06:30 1.25 ):30-08: 15 1.75 I 1.75 s: 15-1 0:00 I \:00-12:00 2.00 1.00 ~:00-13:00 t:00-13:30 0.50 I :30-14:00 0.50 1:00-14:30 0.50 I :30-00:00 9.50 I I ,-/17/02 :00-12:00 12.00 I I ~:OO-OO:OO 12.00 I Finish MU BHA#5 with RSS/MWD/CDR. RIH to 13-3/8" surface casing shoe @ 3631' md. Fill pipe, PJSM and Change Out Saver Sub. Slip and Cut Drilling Line. Service Rig: 1. Top Drive Maintenance -- Rig electrician clean brushes. 2. Lube rig -- tuggers, sheaves, etc. Trouble shoot and repair IBOP pressure switch. RiH to 7088' md -- no problems. Note: Crew change. Finish RiH to 821 7' md -- no problems and no fill. Establish circulation and downlink to RSS. Drill fl 8217' - 8242' md with RSS tool. Note: RSS tool responding to downlinks. Clean Suction Screen on # 1 Mud Pump. Drill fl 8242' - 9060' md with RSS tool. Nates: 1. RSS tool responding to downlinks. 2. Address,ng Torque and Slip Stick -- See Operations Section in Remarks. 3. Installing Non Rotating Stab -- addresses surface vibration but no noticeable signs of torque benefit. Drill fl 9060' -10000' md with RSS tool. Notes: 1. RSS tool responding to downlinks, 2. Add non-rotating stabs between stands 80&81 and 87&88. 3. Non-rotating stab already in place between stands 73&74. 4. Adding EP Mud Lube, Torq Trim and BDF-263 to effectively combat torque and stick/slip. Drill fl 10000' -10868' md with RSS tool. ~ il BP Exploration - Northstar NS12 Daily Operations (I.A.D.C) Note: 1. RSS tool responding to downlinks. 2. Added non-rotating stab between stands 94&95 and 101 & 102. 3. Adding EP Mud Lube, Torq Trim and BDF-263 to effectively combat torque and stick/slip. I '18/02 ,: 00-06: 00 6.00 I :00-06:30 0.50 , J:30-12:00 5.50 ( :00-14:00 2.00 r.00-14.30 0.50 k30-15:30 1.00 I :30-17:30 2.00 , :30-18:30 1.00 I :30-19:00 0.50 ,:00-21 :00 2.00 I I I 2.00 l :00-23 :00 ( 0.50 ~:00-23:30 I I I ~ :30-00:00 0.50 I .119/02 ):00-01:30 1.50 I· :30-08:00 6.50 I :00-10:15 2.25 :15-10:45 0.50 ):45-12:30 1.75 I Drill fl 10868' - 10923' md. Note: 2 Downlinks to RSS @ 0.5 hrs each. Troubleshoot SCR#4. Drill fl 10923' - 11438' md. Note: 2 Downlinks to RSS @ 0.5 hrs each. Drill fl 11438' - 11520' md -- intermediate TD. Circ and Cond Mud. Repair Washout on swedge on pulastion dampener of #2 mud pump. Circ and Cond while pumping Hi-Vis Sweep. Monitor Well-- POOH to 11000' md. Note: Pulled with 25 to 35K over pull. Pump Dry Job and Blow Down Lines. Continue to POOH to 7939' md -- average overpull25 to 35K. Notes: LPulled with 50K overpull at 10800' md in the HRZ -- wiped. 2. LD all five non rotating drillpipe rubbers. 3. Decision to RIH to TD for wiper trip based on: a) Discussion with rig team about last well. b) Review of NS06 drilling report and remarks about HRZ and pumping to bottom. c ) Want to base decision on one results of good wiper trip. Monitor Well and RIH to 11460' md. Note: Stacked up all string weight @ 10,800 md -- top of Kuparuk. Necessary to work pipe to get thru -- no pumping required, Wash fj 11479' - 11520' md, Notes: 1. Attempt to RIH with no pumps -- stack up at 11479' md -- top of Miluveach. 2. Work pipe several times to get thru tight spot -- unable to advance. 3. Fill pipe and wash down f/11479' to 11520' md -- acted like tight hole. 4. 3 feet of fill. Circulate Hi-Vis Sweep. Circulate out Hi-Vis sweep and clean hole. POOH with Bit #2 to run casing. Overpu1l40 to 50K on first 5 stands. Pump dry job. Continue to POOH with overpull of 25 to 30K. Hole good to run casing. Hold PJSM and Lay down Anadrill BHA. Clean up rig floor. Pull wear bushing and run test plug. Wear bushing had significant L.30-13:30 1.00 ):30-14:00 0.50 I 00-14?0 0.50 . .30-15.00 0.50 ):00-17:00 2.00 1.00-21 :30 4.50 l :30-22:00 0,50 ( .:00-00:00 2.00 I '20/02 .. J~00-07:30 7.50 I :30-10:00 2.50 I I :00,. 11 :00 1.00 l :00-12:30 1.50 1):30-13:00 0.50 :00-14:30 1.50 ~:30-15:30 1.00 (30-19:30 4.00 I I ):30-20:30 1.00 1':30-21:00 0.50 :00-23:00 2.00 ~ : 00-00: 00 1.00 I t/21/02 '=00-01 :00 1.00 :00-02:00 1.00 ~:00-11 :30 9.50 I I l :30-12:30 1.00 I BPExploration - Northstar NS 12 Daily Operations (I.A.D.C) key seat wear and will not be suitable for re-use. Install 9-5/8" casing rams. Pressure test door seals to 3500 psi. hold ok. Clean up rig floor. Service top drive. Hold P JSM and rig to run 9-5/8" casing. Review recent power tong incident with crew. Run 9-5/8" casing. Make up shoe track and thread lock. Circulate casing volume at shoe. No losses. String weight 205K up, 175K down. Continue to run 9-5/8" casing. Rigid centralizers on bottom 164 joints. Continue to fW1 9-5/8" casing. Stack up at 11172'. String weight prior to stack up 325K up, 210K down. Unable to work through obstruction at 11172' with 150K down and unable to pull free with 225K over. Attempt to circulate, annulus was packed off. Regain circulation and casing came free immediately. Wash last 8 joints to bottom with 3.1 bpm and good hole conditions. note: Drag was 50K less while washing to bottom than the hole drag encountered prior to stack up at 11172'. Make up casing hanger. Wash in hole and land, approx 15' fill. Circulate with Franks tool at 8 bpm.. No losses. Lay down Franks tool and rig up cememt head. Circulate and condition hole at 10 bpm for 8500 strokes. No losses. Pump 5 bbls water and pressure test cement lines to 4000 psi. Pump 50 bbls Alpha spacer at 11.0 ppg. Drop btm plug. Mix and pump 380 bbls Lead with 3% Econolite + 0.4% CFR-3 + 0.5% Halad-344 at 11.2 ppg and tail with 116 bbls Class G + 0.2% CFR-3 + 0.35% Halad-344 + 0.150/0 HR-5 at 15.9 ppg. Drop top plug and pump 25 bbls water. Complete displacement with rig pump at 10 bpm. Slow rate to 5 bpm at 8000 strokes at 1300 psi. Bump plug 500 psi over with 8173 strokes and hold 5 min. No decline. Bleed off casing. Floats held. No losses. Lay down cement head and landing joint. Change out bails and install elevators. Install packoff and test to 5000 psi for 10 min. Held ok. Displace 9-5/8" x 13-3/8" annulus with 218 bbls 10.1 ppg drilling mud. Broke down at 1000 psi. Inject at 2 bpm at 600 psi, Begin changing out casing rams. P JSM and install 4-112 x 7" variable bore rams. Rotate kill line flange on BOP side outlet and re-install hose. Pressure test BOP's. Test all rams, stack valves, choke manifold and safety valves to 250/4800 psi for 5 min each. Held ok. Pressure test annular to 250/3500 psi for 5 min. Held ok. Perform accumulator test. Initial pressure 2950 psi. Final pressure 1650 psi. Recharge time 3 min, 6 sec. Tests witnessed by MMS Randy Howell and AOGCC John Crisp. Pull test þlug and run wear bushing. I 30-13?0 1.00 .30-15.00 1.50 ;:00-17:30 2.50 1.30-22:00 4.50 ~:00-22:30 0.50 r 30-23 :00 0.50 kOO-OO:OO 1.00 I )/22/02 I :00-02:30 2.50 ~:30-06:00 3.50 I ,:00-06:30 0.50 ( :30-00:00 17.50 I I '23/02 19.50 J:00-19:30 (30-20:30 1.00 :30-21 :30 1.00 I I r30-23:00 1.50 " :00-00:00 1.00 )/24/02 1':00-00:30 0.50 :30-01 :30 1.00 l :30-03:00 1.50 I ~ :00-05 :30 2.50 I :30-06:00 0.50 >:00-07:30 1.50 I BP Exploration - Northstar NS 12 Daily Operations (I.A.D.C) Service rig and top drive. P JSM and slip and cut 102' drilling line. P JSM and pick up Anadrill BHA. Set motor at 1.15 deg, orient MWD and make up bit #3. RIH with bit #3 to 11368'. Repair top drive. Wash down to top of float equipment. Mud wt in = Mud wt out 10.1 ppg. Pressure test casing with 10.1 ppg mud to 4100 psi. Held ok. Hold safety meeting and discuss well control operations with crew. Drill out shoe track and 20' new hole to 11540'. Begin to bleed in 16.4 ppg spike mud to raise density to 12.4 ppg while drilling shoe track. Complete spike mud additions. Two additional circulations were required to balance MW in = MW out to 12.4 ppg. Perform FIT with 12.4 ppg mud and 800 psi applied surface pressure. Drop 20 psi in 10 min. Dir driIl8-l/2" hole from 11540 to 12230'. Ave gas 50 to 75 units. Drilling Parameters: 520 gpm, Torque on bottom 17,000 ft-lbs, WOB 17,000 Ibs, RPM 100, On btm 3000 psi, Offbtm 2650 psi. RWT 260K, DWT 225K, UWT 305K. Having difficulty holding tool face during slides. Dir dri1l8-l/2" hole from 12230 to 13074'. Clean out suction screens on mud pumps. Dir driIl8-l/2" hole from 13074 to 13135'. Casing Point. Top of Sag at 13101'. Gas from Sag peaked at 240 units from previous background of 150 units. Drilling Parameters: 520 gpm, Torque on bottom 19,000 ft-lbs, WOB 20,000 Ibs, RPM 100, On btm 3200 psi, Off btm 2850 psi. RWT 265K, DWT 230K, UWT 320K. Each stand worked once prior to connection. Had some difficulty holding tool face during slides. Pump Hi-Vis sweep and circulate clean balancing Therma- Thin slug in open hole. Sweep brougbt up twice the volume of cuttings, as per the volume of drilled cuttings. Wiper trip to shoe. Hole real good with max 25K over. Complete wiper trip out to shoe. Last 3 stands of trip were good. Service top drive. RIH for clean out trip. Stack up to 100K and work clean at 12300', 12378', 12665'. Were able to work through and did not have to wash in. Wash through tight spot at top of Sag at 13ÙOO' and clean to btm, No fill. Circ sweep and spot new mud on bottom. Bottoms up cuttings showed minor amounts of splintered shale. Drop ESS tool and flow check. POOH with dir BHA to shoe. Drag was approx 10K higher than on BPExploration - Northstar NS 12 Daily Operations (I.A.D.C) previous trip, and did pull 25K over several times to a max of 50K. Hole did not swab, Flow check and pump dry job, Drop rabbit. POOH with dir BHA to run liner. Increase in return flow from 10 to 30% with hole fill pump on and airated mud at flow nipple. Suspect hole fill procedures, monitor well to confirm well static. Circulate bottoms up from bit and confirm no gas cut mud in annulus. Well static. POOH to dir BHA. Flow check and PJSM. Lay down BHA. Recover ESS tool and rabbit. Bit l-I-CT -A - X - IN - LN - TD. Clean up rig floor. Rig up floor to run liner. PJSM for running liner. Make up shoe track and landing collar with BBL shoe and threadlock. Check floats. Make up torque 12800 ft-lbs. Run total of 44 jts, 7", L-80, Hydril-521 liner. Make up Baker liner hanger asembly and rig out handling equipment. Circulate liner volume. Liner weight 35K. I 7:30-08:00 0.50 I ,00-12:00 4.00 ~.00-13 .00 1.00 LOO-14:00 1.00 I ~00-16:00 2.00 J.00-18.00 2.00 I :00-18?0 0.50 , .3 0-19 . 00 0.50 ):00-19:30 0.50 I :30-23:00 3.50 I :00-23:30 0.50 ) :30-00:00 0.50 I I I I I I I I I I I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 8370 to 10635 ft 7032 to 8852 ft Show Report No. 1 Daterrime: 6/19/02 Depth (MD) (TVD) ( Interpretation: Steam still analysis indicates that these selected samples would produce gas or non producible. Drilling Mud contained 1-2% lubricants. No cuttings samples were taken in this interval. No visual oil sheen was detected on drilling mud samples used in steam still analysis. No oil odor was detected on drilling mud samples used in steam still analysis SPOT STEAM STILL SAMPLES FROM COLVILLE FORMATION DUE TO FIRST INDICATION OF C2-C5 GASES % I Depth # 8370 ft Gas x Units 281 Mud Chlorides (ppm) = 19.5k ---¡:iõ\Ñlrñ¡-------§-uciiõ"ñ------§li'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 37.3 1.01 = 98571 - -- C2 0.15 0.06 = 9835 - -- C3 0.23 0.11 = 5754 - - C4 0.26 0.13 = 3356 - -- C5 0.22 0.08 = 2060 -PrõdüëTiõ-ñ------====-------=---------------------------------------------- Analysis fXlGas nOil nwater nNon-producible Hydrocarbons 2 % Depth 8665 ft Gas x Units 100 Mud Chlorides (ppm) = 19.5k --Frõ\Ñlrñë-------§uciiõ"ñ-----~li'õy¡.:::"--------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 12.07 1.01 = 80.59 - -- C2 0.64 0.06 = 0.58 - -- C3 0.69 0.11 0.58 - -- C4 0.50 0.13 = 0.37 - -- C5 0.36 0.08 = 0.28 --Prõðüëtiõñ------====-------=---------------------------------------------- Analysis nGas nOil nwater nNon-Producible Hydrocarbons 3 % Depth 10635 ft Gas x Units 716 Mud Chlorides (ppm) = 19k ---¡:rõWirñë------šuciiõ"ñ-----=-sli'õy¡-----------------------------------------.,.----- ppm ppm ppm (Steam Still PPM's in 1000's) C1 32.08 6.13 = 25.95 - -- C2 4.15 1.36 = 2.79 - -- C3 3.57 2.12 = 1.46 - -- C4 2.79 2.28 = 0.51 - -- C5 1.89 1.81 = 0.08 - -- --pñ)ðüëTiõ-ñ------------------------------------------------------------------------- Analysis fXlGas JXlOil nWater nNon-producible Hydrocarbons ..!J % Depth ft Gas x Units Mud Chlorides (ppm) = ----¡:iõ\Ñliñë-------suciiõ"ñ-----=-sli'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) = ##### = ##### ##### ##### = ###If:#. I Hydrocarbon Ratios ClIC2 10.0 C1/C3 17.1 ClIC4 29.4 ClIC5 47.9 I Hydrocarbon Ratios C1/C2 138.0 C1/C3 138.0 C1/C4 215.5 C1/C5 288.8 I Hydrocarbon Ratios C1/C2 9.3 C1/C3 17.8 ClIC4 50.6 ClIC5 320.4 Hydrocarbon Ratios ClIC2 =##### C1/C3 =##### ClIC4 =##### C1/C5 =##### ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 - _."_____n___.__...__._,_"__.___. _,________.._._.._______ _._..._-,~..,----,-.._._-_._- --_._--_._.__._-,------------~ ---. ---,-,.- --.----.---- -- -,....-..-...-- ,-----.-..-..----- NPH ___.,__~~~:__.:--._n-"."."",...,-H,.,.,".'~~H, -- -- -" ,. .,.;;;;,. ~:....-~.....-..-!,',-:,,',' - ,- '.-"'-- . 100.0 10.0 Gas --------------------- -------------- ---...-- Oil ---.-.--.-.--. -..---. NPH 1.0 - - - - --~--~.....---.-._-----------_._--_.._--_. -.----..------ C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -.--..-",--.,--..-, ..-"..-.....-..-,..,,-.-...-.., --, -..--. .-.---...--.---..--,-.-...-.- . ....---- _.-..-.,,-_...."'~""_'_..- 1 000.0 --.-..---------..--- --...-- --..,--.--------. __.___,___._.___._.____ ___........_._.....H_._ ..,.._____,___.______..____._,__.. p,_______._.__,_.._~.,,_._._,,__. -.,-->. --. ----.....-----..-...-.--." .....--.--".. ., -'~'--."'-'."-''''~ .... -.....,---.-,........- ._._..._-~_. .--..,.-- .-.--. --...-..--........-...-."...---.-.-.'''-- _. .. _. _ _ ".._______ ._~.~ ,_.,_ _'_"'_'_'.'__._.n__.__._....,_.. __.._....____..__ .______,,_·.__..._._.___.·.._R.."__._. ___,._,....>_,_...___.,_,.'"...._____ _ NPH 100.0 Gas 10.0 Oil _.-.._...___.___..__.._.___._ ..__ _..._..._n._.___ .--..._. .--.--------........------..---..-. ...--"" . ._--.-._..~ -.. -,-.--...--- NPH 1.0 ~ ii sperry-sun DRilliNG SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY [ Depth (MD) (TVD) 10977 to 11479 ft 9127 to 9538 ft Show Report No. ~ DatefTime: 6/19/02 Interpretation: Steam still analysis indicates this portion of the Kuparuk "c" would produce gas. Drilling Mud contained 2 % lubricants. which were detectable visually in steam still bottles ( Torque Trim ). Mud lubricant odor was also detected. No oil odor/sheen visually present in steam still samples. Cuttings samples ( 10980-11070) had <5% dull yel fluorescence and a very faint green/yellow cut fluorescence. Cuttings samples ( 11150-11200') had 15% fluorescence and cut fluor as above ( From Mud Lubricants) .KUPARUK tIC" I % I Depth # 10980 ft Gas x Units 740 Mud Chlorides (ppm) = 19.5k ---¡!io""Wiiñi-------Šü¿iiõñ------!fti'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 37.4 0.86 98571 - -- C2 6.21 0.32 = 9835 - -- C3 5.79 0.79 = 5754 - - C4 4.35 1.39 = 3356 - -- C5 3.01 1.43 = 2060 --PrõaüëTiõ-ñ------==------------------------------------------------------------ Analysis [X1Gas nOil nwater nNon-Producible Hydrocarbons 2 % Depth 11070 ft Gas x Units 741 Mud Chlorides (ppm) = 19.5k --Fiõwirñë-------ši¡¿iiõñ-----~-ti'õy¡.:::..-------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 41.88 0.86 = 80.59 - -- C2 5.96 0.32 = 5.64 - -- C3 4.70 0.79 = 3.92 - -- C4 3.67 1.39 = 2.28 - -- C5 2.78 1.43 = 1.36 - -- --Prõaüd¡õ-ñ------------------------------------------------------------------------- Analysis (Xl Gas nOil nwater nNon-producible Hydrocarbons 3 % Depth 11150 ft Gas x Units 382 Mud Chlorides (ppm) = 19.5k ---FiõWifñë------Šü¿iiõñ-----~hõy¡------------..---------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 9.68 0.86 = 8.82 - -- C2 1.87 0.32 = 1.55 - -- C3 2.09 0.79 = 1.30 - -- C4 2.25 1.39 = 0.86 - -- C5 2.05 1.43 = 0.62 --PrõaüëTíoñ------==------=---------------------------------------------- Analysis (Xl Gas (Xl Oil nWater nNon-Producible Hydrocarbons 4 % Depth 11200 ft Gas x Units 457 Mud Chlorides (ppm) = 19.5k ---Fiõwlfñë------Šü¿iiõñ-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 7.73 0.86 = 6.88 - - C2 1.85 0.32 = 1.53 C3 ~ 0.79 --:¡ß2 - -- C4 2.71 1.39 = 1.32 - - C5 2.57 1.43 1.15 -lPrõaüëTíoñ------==----- Analysis x Gas x Oil Hydrocarbon Ratios C1/C2 10.0 C1/C3 17.1 C1/C4 29.4 ClIC5 47.9 I Hydrocarbon Ratios C1/C2 14.3 C1/C3 20.6 C1/C4 35.3 C1/C5 59.4 I 1 Hydrocarbon Ratios ClIC2 5.7 C1/C3 6.8 C1/C4 10.2 C1/C5 14.3 ( Hydrocarbon Ratios C1/C2 4.5 . C1/C3 4.2 C1/C4 5.2 ClIC5 6.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 NPH .m. n_.._.. __..__ _....__ . no _..._____._..___._..... ._"._.__....~.....__..n'. _ _ 100.0 --- .....""",,"" _iti'··-':.;",...····~ ........-..-~-.~ ;;,¡,¡...-.-.--~ . _.. _h._..._...h _ Gas ~~:==-~~ =--::::n~,_",_" __~~_-_=_~~_.___~~:~~_ .- ---------- 10.0 .....::':' ,:'..,:~.,"":,,::,,:',,':,,.,,:_:' Oil _ _. __.____m ~_._____._._"__ ._.._-".._-'_._...._.,,~_._.,_.._...__._..._. NPH 1.0 __ ____...n__...._...,__..... C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -.--........-, -.,--...---... --".-.-.....,..----...,,- 1 000.0 -. . -- -,. ._..._~-_... -. --., -,...,.__..__.__._.._-_._~._._..__._.. -"---'--.-'---"-.' ,--..-..., .----.-. _,_._.._ ..._____.____.__ ._.__.___....____._..._._.__,...~ __._.._._h ._.'.__."n....,~,..,_...._.._,_." _.,_.__..._ __.___n__.....'._____.·_,___... ___.._._,_.__.."._______ _____.,_~,.___._.____._ NPH . ._ _.'.,,,.. _"n.__~"".."._....__. ,~___~__.',"_mn._~"_ _ __...___.._,.. .__.__n__.~___..,,_.""_..___..__" --- 100.0 --- ---_._._-~--- Gas -.-.---.-.--.-----.,.---. -~-----~-"_.,.,._.-.--_.- _.._--".._--_._."'.,-"-,......~~"- ~-~._~_._,-._._-- --- ..--...---.... 10.0 -. -".-----...-.---...- --..-----------..---. .-------.--- -----_.---,- NPH 1.0 sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS12 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 10977 to 11479 ft 9127 to 9538 ft Show Report No. 2B DatefTime: 6/19/02 Depth (MD) (TVD) Interpretation: Steam still analysis indicates this portion of the Kuparuk "C" would produce gas. Drilling Mud contained 2 % lubricants, which were detectable visually in steam still bottles ( Torque Trim ). Mud lubricant odor was also detected. No oil odor/sheen visually present in steam still samples. Cuttings samples ( 11200-11300' ) had 20% dull yel fluorescence and a very faint green/yellow ring cut fluorescence. .KUPARUK "C" 1 % I Depth # 11250 ft Gas x Units 261 Mud Chlorides (ppm) = 19.5k ---¡:iõWiiñ¡-------§üëiiõñ------§-ti'õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 11.7 0.86 98571 - -- C2 2.39 0.32 9835 - -- C3 2.63 0.79 = 5754 - - C4 2.92 1.39 3356 - -- C5 2.89 1.43 = 2060 - -- --Prõðuctiõ-ñ------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 2 Hydrocarbon Ratios C1/C2 10.0 ClIC3 17.1 C1/C4 29.4 ClIC5 47.9 Depth 11300 ft Gas x Units 157 Mud Chlorides (ppm) = 19.5k ---¡:iõWirñë-------§üëiiõñ-----~1iõÿ¡-=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 8.87 0.86 = 80.59 - -- C2 1.85 0.32 = 1.52 - -- C3 2.24 0.79 = 1.45 - -- C4 2.65 1.39 = 1.26 - -- C5 2.67 1.43 = 1.24 --Prõðüct¡õ-ñ------=------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios C1/C2 ClIC3 C1/C4 C1/C5 52.9 55.5 64.0 64.9 [ Depth ft Gas x Units Mud Chlorides (ppm) = ---¡:iõwlrñë-------šüëtlõñ--..--~ti'õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 = ~ C2 = ~ C3 = ~ C4 = ~ C5 = ~ --Prõðuctiõ-ñ-----------------------....------..--..--..----------------------------------- Analysis Non-Producible Hydrocarbons 4 Depth ft Gas x Units Mud Chlorides (ppm) = --1=iõŸllTñë..------§üëÜõñ-----="Š-ti'õÿ¡---------------------------------------------..- ppm ppm ppm (Steam Still PPM's in 1000's) = ####If. = ####If. = ####If. = ####If. ####If. [ Hydrocarbon Ratios C1/C2 =tI#### C1/C3 =tI#### ClIC4 =tI#### ClIC5 =tI#### C1 C2 C3 C4 C5 --Prõðuctiõ-ñ------=------ Analysis Oil Hydrocarbon Ratios C1/C2 = tI#### C1/C3 = tI#### C1/C4 = tI#### C1/C5 =tI#### ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0' ..-...-. -. -.. ,-. -. -. -..- -- ---_._~_..- .....---.. . NPH --- 100.0 - - .=- -- -.~~-~:-.=:~:-~~~.~~~-_.__.__.- Gas - - ...- .~-,.~"..- 10.0 . .. _...._ ~_.. ._.._. .._.n _...., n. _._ .. _n___"'___ _._._ __._ .__,,__ .--...-.. _.__..._..._--~.._.._.~.._..~.. ----.__.._..~......_-~----~- ......_-_._.,--,_._--,_...~...__. . ._.. _ . _._,__,~ .."_..___,..__.__~,__...__._ ..... _..... _u..__ 01 I --....,----.-----------,--.- -------.--..--.--.-.....- 0'.----.-,----.--,--- --.--..--.--..--.-.----.-.-...-,,--. ...---.--.---.--."...-...-.----.-. NPH 1.0 - ._,-'"..-... ...-.. .__.._"'....__._.~.....-..--....,-,.,."..-._..-.,--_..._-_....,-.- ---..---. '--"-.."'--- ..~--,-_.. C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 . -' ...._._.._...,,--_...._.~ -- ..,- ,- ...--. 1000.0 . ~.._~-...._,,-~"..__.. .-.---.-, -. --.- .- _..~_.,-~..~-_............_- .,,-.--.....-. ... _._._,----_.~ --...- -,...--.---.. --..._~~~. .....-- _..__._-~._.._- .----..,.. '-"~..~''"~ ._"..._.._..__..~~_......,_.. . ....__..~~_._. NPH .__.._---~--_._----------- ---.------ --- 100.0 .----..---..---.....--.-..-. ._..,-_.....-.._....._~._.~"_..._--,--- ~ ~_ - .___.. .____ ___._..._ ._.,u__ _._ .._._..__..__......_.,_._ ".__..__...__~ _,.__."__..__" ,__.._~_ ._..._._____ _..._~-_....~-_._-_.__._-- ----_.__._-_.~......_._. _......,-~-_.._.~_._.._-_._-_._._- Gas _.-.._~_.._-_._-,._.........__...._""- ..----....---,..-..-.-.---. -------~..._._-----....~-- --::--:-:.-:: -;;;;;-;;;-..---.-- ...~-~~-_.__._.- 10.0 -'-'-'-"~~-""- -.,,-.---.--.-,,-,-- .__...._--.._-_._..,.~~.".._---..-._- ---.---,-."..--..- Oil _,.. .""'.__"_.'~ _.___~. nn_~_.'__._.__.n_.._."_ ._h_..._........._".__ --..--...--.-".---..- ,,--."-_._,-,,-- .-.- --_.. --.,,-. ----,---- .-.--,-- NPti 1.0 . _.._,..__...__.. ,_,..~ ._u, ._ __.~.._.__...._._.__......~_ ,_......___.__~_....._.,____. ....____.._~ . ~~~.;. :i,/ ,:i~~::::J)tf:;Y:;:";':~"'~~~~~~"!J!¡:11¡~~~0::"!~I~~~~:!)¿~¡f.;~'r.:ptt;~~:~?!·:f:~~~1t~~;~~~~~If~t~<1~~i~f¡;,~':~·;; ;~:jti5íi5.,t¡r.,§~~!~;.¡~:\~~~n~~.~i: ;,. :. :':::'!':':'-, ';'::; , .. :i; ;., I~ I' ~" \"", ..'.:,' , units = 100% Gas In Air ·~i h: '" 1 0000 24 hour accumulation of Steel Filings from Possum Belly Magnets: :¡ Description of fillings: '~~.~., .. .. " ". ...... . :.:- " .. "~'-"', , " ' " ~I ','.',¥,,!,'. 24 hr Reci Moved Rig from NS-06 to NS-12, Preparing to spud. 1~ :~ ;:~J . ,-,!,,~ ~~ ',.,'~',v,,·".. .~ ~~ 'î, Logging Engineer: Doug Wilson / Mark Lindloff ';~ 1 ·..!"',~i\ï~;·I\\;:¡:'f!" oz. Current lithology: % % % % %LCM - .111 m .J1!~~rnßn - Connection Gas and Mud Cut ft units ppg ft units -ppg ft units -ppg - .. ft units ppg ft units ppg ft units -ppg - ft units ppg ft units -ppg ft units ppg - I - . Drilling Breaks Depth Drill Rate Gas % lithology I ~. before during after before during after Sltst Sh Sst ! ~ ! to , r to to to ';i~~~;::ii)~~~\Ì.¡ìli~¡\lt*,*~~~~~~~"'I1i:~~Ji.L~¡¡g'- t~; Bit No.: NA Type: NA Bit Size: Jets: _ \ _ \ _ \ _ \ _ \ _ TFA: l~t On Bit: 0 RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 1. ',"',=..ITI_I~~¡_C.&~~~I~_~~~'(:L:d¡ I! n~~~M!i""fII$IR1~MUIl~J w;~~~,,· ~ ~ ~ Trip Depth: ft Trip Gas: Mud Cut: _ ppg Trip CI: 25000 ppm ~i ~ Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm ¡ t Tight Spots: to to to Feet of Fill on Bottom: ft I riw~.m _ l1m~~~. ::r"';:"'llllii, IlillJfl..m¡- - nnrit<lJ"7l1DU.....I. _[iillilllliLln'-1~:·:.J:t:~ I I gpm gpm fpm. fpm .t\'" V~'t I,,"".' 1i I ~. " ,~ .¡ i~1 % 7.4 ml HTHP 0.0 ml Mud Wt at Max Gas Gel~~ / ~ / ~ Ibs/1 00ft2 pH 9.5 Sd I 10.10 ppg 10.10 ppg Visc 58 secs API filt PV 25 cP YI 24 Ibs/1 00ft2 Mud Wt In Mud Wt Out ppg o ~~:i¢,^:~·!;'t~ t~~~l~g.~~-M\t~êf.:~",;~~t'1V;ii.t\,~~,,·~~}~~m¡~¡~t~~"1i:hW;~~:'~'~Ä'<\f~m' lff:;"',*f~~~ii;r\~~"~~~~~~tfk~~~.1~'$'~\"fi7'\r.!)~¥'{./.,~g'~#.·"'~·~~~;\,,*N;)¡)~>;'i;,;tt:'.\i.;·t:-<\' ~,..; ,~ Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow Gas" 0 units 10 u n it~ ( 0 units @ 0 ) Pump 2 0 spm Total flow --º. Temp Out 70 Deg F ( 70 deg F @ 0 ) Pump 3 spm AV @ DP 0 Pump Pres 0 psi AV @ DC 0 I : ._do:; ~':;';~::"-~~I ·::~·_..,:·..·~)~I..":·: ," "-:~.: ~ ", ":."-, . ., " . - ~....,. . . . .0""'. a¥'. . ~.. .. ." 1 6/7/02 o o Prep to Spud Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 5pe""f"""'\I- 5Wn Mudlogger's Morning Report BP Alaska NorthStar NS 12 North Slope NorthStar NS 12 Nabors 33E AK AM 22092 Customer: Well: Area: Lease: Rig: Job No.: ______0 ____ DRILLING SERVIc::es ----..-.---.- :"1' ·'::".;·:i'¡i'~~'.:.' , : ',,',<, ,:"·::.';"'··,,':'~\tlt-;~..:.~·;,!~<,~·¡,:,:·~·;:;'t,.:,:..',:,~::;j" .:;:, .f;, :".,,.:. ;:!¡:,'î·1'i;(.·.", ."'i: ::;;'~'.:'>~:¡".: ~:.: ¿õ":...·;. ',;\'-:<" :. t' " ,'" ."" . ~ ....,....;.. ' \!,r ~.: ~ ~~~.L~ G ;~"'~\,h':,i'~~_W¡~~~I'~}~;!:¡b7ì~~;;"(:,¡j~,(i:t11~if~~~';2ii\..~;;(.jf~"'!1~~.I~IW~,~ " [i.~~~~'Ì~::.~.~,',';~¡'~f:~~~~~~""\l¡:!:~!i>J¡qt$¡~~lí~'1'5},J,>';],;<~'$;::~;¡·~¡l\~;¡¡:~¡f~~~~";:¡1;i~~~___~~r~ff.f;'~.Kí:. Customer: BP Alaska Report No.: 2 Well: NorthStar NS 12 Date: 6/8/02 Area: North Slope Depth 603 Lease: NorthStar NS 12 Footage Last 24 hrs: 603 Rig: Nabors 33E Rig Activity: Drilling Job No.: AK AM 22092 Report For: Polya 1 Clump Shows: S.§.~VII::ES . ·~.~t"~~t·,::'~~·~;":~·,;':'·~.,..c'·~·r .. ~ ,..~:,.~~.. ._;........~.~J .;~~~.-:';'\~:;·. ·;.:~·l..'~..·":";:.. '1., ," .~:.', ",. '. "iI I ! I ,~ ..(1 Pump and Flow Data ~,' Pump 1 73 spm DH flow gpm)lfi Pump 2 72 spm Total flow 613 gpm I Pump 3 spm AV @ DP 48 fpm ~ :tŠ,' "."". """'::'~:~~~:'""%:~S.. ~:i"~.~. ~~.G ~..,~~, . IPm, 1:~~';1I'~1~·. .~..;::. ....:,.;'.. . '':'',,, .~ '.'1.:.:: r:, _', ~':~1-....,,<r:·.if"'~ . §:: spe....,....,v- sun :~,'i~ '" Mudlogger's Morning Report .' I R.O.P. Gas" Temp Out Current 352 2 68 ftJhr units Deg F 24 hr Avg 224 ftJhr ( 1 0 unit~ ( ( 556 24 68 24 hr Max ft/hr @ units @ deg F @ 512 201 595 I .;; ·;_·¡'J":-,:t',~t_~.~~"J:':':'''' :;:':..1:::.:,. ...... ..~.;;..:r,z~:'~;'';~~..i,,,;,,.:i~:..:.:'~~-:f.,·~~.~·~~:~r...~:;.;~'·,l'O:. I ì,2=:'~~::~~:=:~"C:,~::::'::::;",::::,::.::~~·1..~~:.,~::s~.,o~··,ì .F! Bit No.: MX-CI Type: HUGHES Bit Size: 16 Jets: ~\ ~ \ ~ \ ~\ _ \ _ TFA: 1.0310 I:;¡.' Wt On Bit: -2 RPM: 45 Hrs. On Bit: 3.0 Total Revs on Bit: 17 Footage for Bit Run 603 :: TriPDePth:-L1~P~U:~~;~::~'.·. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm . , I'. Tight Spots· to to to __ Feet of Fill on Bottom' ft 1 I Current Lithology: % % % % %LCM - - [ Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units -ppg - Drilling Breaks [ J ~l I to to to to Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh - - - - - - - - I Depth - - - - - - - -~ "'~?'Iti1!""Ü:i:JO) ';M,JIIII.... , '. _. 'iii I,'.,'.,'., 24 hour accumulation of Steel Filings from Possum Belly Magnets: I Description of fillings: i~~~:r¡O~tmì'.t~wt}~~__ ". . ,... ," . "'~'JjJ;~_¡"'~'" ,.. . "'. ;,1it 24 hr Recé P/U BHA, RIH T/201', Drill T/260, Ran wireline survey. Bottom of conductor across hard line. ~~ Ran gyro every 30' to 550' then switched to 90' gyro's Mostly gravel and clays coming over the shakers. .,}~; I :fä· :~f; W;' Logging Engineer: Doug Wilson / Mark Lindloff ~:..;S~~~~~~ij~~~~~~~{~~~~~~~~:::·'··~ oz. ~ ¡:¡'. , , L'r; * 10000 units = 100% Gas In Air " Logging Engineer: Doug Wilson I Mark Lindloff * 10000 units = 100% Gas In Air ~ ..i¿ , ..': ;:;~::~"~~';::iJ':Ù:f.~;~';:~;~J~&;:j1J~'~'¡~~f~{~;~~~~1r::~~¡:Wj~?;¿~'~;:~::;U(:~,:! ~::>'»itq~~f.::h·~::: ~;:~~f~~+J;~:'~i:;;;~:t~;¡;~:··~t.:.;rt~::':!:f~?;L~f(;i?i~.(;.!~;;~.:;.. . ;~ft 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. . Descnptlon of fillings: ~ -;2~-~'~~~~~~~'""~~ Running Gyro till 1450' . IJI. Top of the Permafrost came in at 1212' MO, 1195' TVO, Base of the permafrost was 1625' MO, and 1585' TVO % Lithology Sst Sltst Sh units _ppg units _ppg units _ ppg after Gas during before after ~"t-......."".,.. Drill Rate during before Drilling Breaks ft ft ft Connection Gas and Mud eut ft un~s ppg ft _ units ppg ft units ppg ppg ppg ppg % %LCM m1JD¡¡nUIIM~ul.""y!.AL.J."mJ_ "... to to to to [ I Depth units units units I ft ft ft % Current Lithology: % _ % "lw,_".::':'~-:::JJt JU j JI!1JlIIIIIIIlJ _Jim At ~I~ 1111 ~I ~ßIIJ . ... Mud Cut: _ ppg Trip CI: 20000 ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft '_~.!\_n4C:J-Uü]~~:I~=::J., 1. 031 0 2,233 ..~., ft Trip Gas: ft Short Trip Gas: to to JJJ. ,R! _:.:=u_._....._u......A::::.,""'"/ ~j ~ IWJ I Jets: 12 \ 20 \ 20 \ 20 \ \ TF A: ------ Total Revs on Bit: 66 Footage for Bit Run 16 12.9 Type: HUGHES Bit Size: RPM: 48 Hrs. On Bit: ,::']1D,:::~Jl:Dr.:...,_... Trip Depth: Short Trip Depth Tight Spots: '""I'r~ 'n MX-CI 10 I Bit No.: Wt On Bit: ',.,...," ",- ), ·,,:.,,!IIt·:~~...'..h¡a:<;;..;.1Ct·;.T,)',.-n:~~~t¡ëJ~~~::I:~~::).:,.-::::;,' r·..t:.l;,"·4':;~;~':r. , ~.'u'.r,:;...\I41o:~,<,·¡{'~.:.:..~:i~..'I. '-"~,~::-:'d~c,": ;:;,;'-.~. ~~·=:~~-r~:Ai~ I!'.....j¡;.!~~~~"..;. :J',_ :! :.. Pump and Flow Data Pump 1 97 spm DH flow _ gpm If Pump 2 99 spm Total flow 829 gpm 1~ Pump 3 spm AV @ DP 65 fpmj§ - ~) Pump Pres 1435 pSI A V @ DC ì8 fpm .~ .'.' ".. .. "'.".--1:'.:~~'1'_'tJ:i&t ~t(: ¡ :~.: ,;,;: ; .:1r.,:I..:'~.;"'z,:o;~.....a,.·M~1'~'~J: ,;,''õ-"I-;'''', :':" :",:"¡"', .' :.. ,.-... ~...:-:. :-.:" .... ,"J=-'~' " ::.."">:·,t",, '~"'~:'¡"!\I':"~,;r: . ..., ,"I:::..t'.;: -'. '¡,:.'T -'....:. ,¡._ 'c' ¡::'f_~~'.-;:,,:;. ,.~~ Mud Wt In 9.00 ppg Visc 82 secs API filt 7.8 ml HTHP 0.0 ml Mud Wt at Max Gas ppg :1" Mud Wt Out 9.00 ppg PV 18 cP YI~ Ibs/1 OOft~eIE~ l ~ l ~ Ibs/1 00tt2 pH ~ Sd 0.75 o? .~ ¡J.-,:,;,. 3 6/9/02 2,233 1,630 Drilling Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1067 1647 990 24 hr Max ft/hr @ units @ deg F @ 684 27 80 24 hr Avg 265 ft/hr ( 9 unit~ ( ( ft/hr I Current 215 14 60 ,'" ':'" .,~ ,'.,,·,~I,:;~~·~~:';.;.,~~;,~iÀ;~;,i";, }{j:·.~ì);::':, ,~~>- 't':: ·;~·.i~,,<~':· ,~~,~~'~,~~~[,~~f~.:~,":·~',~'~·,i:·~~~\:~~,~~~~,~~~;:t~~1:~\~',: b~~~,.,,~ ,_~;.. . .....' J,., ~~ '\ '$;l~~;' ~..:.,~',,~',:'..~,...\: "'... Deg F units Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spel'"""'''''V- sun ô-Ä.""L.L.I N G SERVICES .-.-.....-----....----..-...----- BP Alaska NorthStar NS 12 North Slope NorthStar NS 12 Nabors 33E AK AM 22092 ." * 10000 units = 100% Gas In Air ~ .: : ::;" ::. '. ¡~:' l::~¡~;;¡:~%~;~~}:#~:~~¡t~:!~~t}~~vj~'~~~~.~~~~~?t~\;:rh~:M!~~~:@f:~4:·:F~'(j~!i~~;pi·~:,];·;gv:~g~.;t~~~~rt~jèr~';~~~;!~;;Wf~¡~è~'¡;::': :;:.;~~.. Logging Engineer: Doug Wilson / Mark lindloff ~~~1It1Dtrjl];;m;:'=~¡~I;'J~.ltm:.J nl.:"TUmt....~·x;.IJ;tI.~II·lt 24 hr Rec, Continue to drill to 3647" MD. Pumped sweep and circulated three bottoms up until hole was clean POOH, lay down BHA#2, Rigging up to run 13.375" casing at report time. The Top of the SV6 came in at 3486' MD, 3088' TVD Connection Gas and Mud Cut ft units ppg ft units ppg ft units -ppg - ft units ppg ft units ppg ft units -ppg - ft units ppg ft units ppg ft units -ppg 1 - - Drilling Breaks I ! Depth . Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to to to to "=~IW Pump and Flow Data Pump 1 93 spm DH flow _ gpm Pump 2 92 spm Total flow ~ gpm Pump 3 spm AV @ DP 61 fpm .' ~- ~' Pump Pres ~ pSI AV @ DC ~ fprn ;'¿I . ".......-, -..' .' '.d~'''''~'.''''_.'',.'_'''''' _...~.. .~. .",-""\,'1"· ~,._.......;.,......... -.-~". .,.....,...~-~""-_.~_. ,- -..'.. .. .,,~J ',- ,'-" -...... , ~..,., ~_...._-........~..~-"-,.~,._'",.~, p. . "-"~." . ,'.., . 'I a.. ·......10.,· "_10"" '-""r'~:yr~ o/lIlii"...._.· .' ~".-. .;-01"....,. .. '" ,~r'-liIIII·~Tõ-.t.y,.- _---,¡.1-~... ....... ..-,-,¡g.~.""c,_.JII;-..-......." ,_ .r'" .... I .., .,.. _, ,... I" ~_~...·õ.'"o1I.., '"""':'.".....II¡¡¡IIII"... ~....,... "~' ....~.-.~~1I..- ....'. Mud Wt In 9.10 ppg Visc ~secs API filt 7.5 ml HTHP ~ml Mud Wt at Max Gas _ppg Mud Wt Out 9.10 ppg PV 15 cP VI 29 Ibs/100ft2 Gels 14 / 20 / 0 Ibs/100ft2 pH 8.5 Sd 0.75 % . - - --- - - I ':: :.....,:;.~' ·:..'..',f....~¡)": 'i¡..,.::d,.h'Ii;.~~.,¡~:r.,¡';"'~...,"~"¡¡;~.·· J~~./4'\~~:t''f;.;.~i(~j;i".'\.~:·'P'\aNi;'~~'''''''~~iI»; (;~ ':'¡.,;.',·~d':Î",'\~'·'·¡;'·":"·:;''''''';:-:'~ :':':-0,'.':"' i~·~"'~' ;.,.....:~:!~; ':';0.;," ';.: . r..~¡"., ~, ,..~ ,¡BitNo.: MX-CI Type: HUGHES Bit Size: 16 Jets: 12\ 20\ 20\ 20\ \ TFA: 1.0310 I Wt On Bit: 0 RPM: 0 Hrs. On Bit: 12.9 Total R~n Bit: 125.8 - Footage for Bit Run 3,647 ~~~~~1~~~=_-=_..~::::h\.."....._,......_____~- /, " :tt~IÎ\\?t., ~ Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 20000 ~ Short Trip Depth It Short Trip Gas: Mud Cut: = ppg Short Trip CI: d4 Tight Spots: to to to Feet of Fill on Bottom: .1M>i~ oz. %LCM % ppm ppm ft .i::~=:I.~:,',.. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: % % Current Lithology: % 2427 2360 13647 24 hr Max fVhr @ units @ deg F @ ;"~ R.O.P. :f: Gas· .~. Temp Out 24 hr Avg 212 ft/hr ( 12 unit~ ( ( fVhr units Deg F Current o o 72 532 20 85 ~, r ~ í<, ,:~:~-,,~:~.~, ~,,~""'; !.\t~'~ ~;~~~,: ~~!{~~~.~:,:,~~{~; "~': - '.::~ ~.~:";)~ ~ ;f~1~~~1: ,;.,~ ;~~ ~;~I'~~' ~ : {oj" -. ',:'. ~,'. ;:Y~,~.~~¡:~f.;~·~:~-R~~ ~·~t~\~$~~~;~~·~ ,:.. ~~~i;~;~~it~'t~~~~:~,~?~;;: ~~: ',~', ~~;t),~t·~ ~<'~:'S ,~' ,:.~{: :'"'y~~i<~ 'r:'~"í:;J~~,;"\~fJ';:'(;ì~~'~~~~~,;;'~~~R~ (~~rf~:i~~t;'~j ,~,~~w~~~~~-":~~'~Il~,\, 1..: fI ¡;;¡ 4 6/10/02 2,233 1,414 Running Casing Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: , -' .~... ., .':.'~ ~. .~ '."~".j :.......:.I':"'..~...: :'::.:-' Mudlogger's Morning Report BP Alaska NorthStar NS 12 North Slope NorthStar NS 12 Nabors 33E AK AM 22092 Customer: Well: Area: Lease: Rig: Job No.: spe.....r'\I-sun D A I L...L I N G 5 S'R V I c: E 5 "...\.,..:....",.~;. .:,",:..-:..!..~~~~~:.. ..... ,'," " ~:-.(""1~,'!'t~~',,~ ' .... r .... ':!~~.!~M I ,'~.. ·i~¡ "~ ~; .l.~..' ~" ", ~ " ·ì '~¥' ~ . . .,,,', .,~...~:.. .·;:··,;,:~:,~\;î,.ffl'¡<iir~~\';<òJ~"'il'~'-.'· :~:~\('¡'\;ir.~~rí.~".; Customer: Well: Area: Lease: Rig: Job No.: ~; ,iij";,, ji i\~ ,~ :~ "i DRILLING spe...,...-.v-sun SEAVIc:es ,,:;.~~¡'¡?,~:¡'¡:~;J,':"':"" ,.- ''!' ~:':." .~i!'l·~i:&4\-.~:~,,:,::~9~;:,~~~~;;'U~~:i::,"·.!;.·;·.,· BP Alaska Report No.: 5 NorthStar NS 12 Date: 6/11/02 North Slope Depth 3,647 NorthStar NS 12 Footage Last 24 hrs: 0 Nabors 33E Rig Activity: N/U BOP's AK AM 22092 Report For: Polya 1 Dinger Shows: . .ijij ~ii I· . . Mudlogger's Morning Report , ,;~:,:,;;; ''.~':·\''':;·:;\¡;'~;;.~'\\è;~·~Þ'~I.$;:';';''·'*'' :·::':":·~:"::"::~;'1~*i!J;:,*_,·t~!~~;!'W:¡i'"¿:'''~~;;m,~'~¡¡·;~,'?~~~'~~Mi#¡I1i';'i~j:",~,,)~;;~,:;,~:<,·;i:%~~"~:t¡¡ÌI~t;;:~~~~~t~:;~~i:~3!Äc~,;,,;,';): : ;~:.:~ 24 hr Max Pump and Flow Data o ftlhr @ Pump 1 0 spm DH flow _ gpm.· 12 units@3647Pump2 0 spm Total flow --L gpml 64 deg F @ 3647 Pump 3 spm AV @ DP --L fpm Pump Pres 0 psi A V @ DC --L fpm : ... ~::..._'_,"'.;¡Ø';¡':I:o.;.'¡J\"I(:~~=.'M :'.!.··;I,:.:J""·'~H~~:""'·>.~~p.':':·~:,.,.!;:.r.,rM. '.~:..~.~,;;¡¡¡.r~-:, ;...:.~¡:.:m>"¡t:<;':o1';'::"' .:¡'·o1IIiI"~:':J.I"':o;;:;'';W~~r·''~'='"·~;/'~ ..:-:~,., ...:~ ,. Mud Wt Out 9.30 ppg PV....!.§... cP YI~ Ibs/1 OOft2 -~ü :.:r~ '", ',..,.,..:'." "d'" "'.,',..,,,''''~.;r;~.: 1~' Bit No.: N/A Type: NJA Bit Size: N/A Jets: _ \ _ \ _ \ _ \ _ \ _ TFA: Wt On Bit: 0 RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ,_,.IIIW..".!U!I!:~t:r::':.~~:m..:::wr~D':'':':JI'':1J1Ð1:\tIU:r~t.mr::tr1U~~~a ~nM1l:':::1:'jL~,(I;:'."" Current o o 64 -i;, R.O.P. :~ Gas· * Temp Out ~~'" I Mud Wt In I Trip Depth: Short Trip Depth Tight Spots: Current Lithology: - - ft ft ft units - units - units - Depth to to to to ~ .'''\W~1tT'''" ftlh r units Deg F 24 hr Avg o ftlhr ( unit~ ( ( 9.30 API ¡lit HTHP 0.0 ml Mud Wt at Max Gas ppg 7.4 ml VISC 43 secs ppg - - - . . Gels 12 / 21 / 23 Ibs/100ft2 0.25 % 8.5 Sd pH - --- .. ft Trip Gas: ft Short Trip Gas: to to % % - Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: N/A , < .¡ ppm ~ ppm 1 ft - - '''~''~t~ % % %LCM - ppg ppg ppg 11f.L.".. I~ ~ II 1111 Connection Gas and Mud Cut ft units _ ppg ft units _ppg ft units _ ppg Imm ,Iml r, ir-:::nI~ ft ft ft units _ppg units _ppg units _ppg n_.._____:~ Drilling Breaks before Drill Rate during Gas during after % Lithology Sst Sltst Sh - - - - - - - - i - - - - - - - - ... after before ~ '0"""'''\' I ... ;~ I 24 hour accumulat'ion of Steel Filings from Possum Belly Magnets: . oz. i1, Description of fillings: t'" .'\~~4<\t~~":J~~~~::.~;;;:~~.: ".. 24 hr Rec¡ Repair Frank's fill-up tool, (Leaking), Run 13.375" casing, Went good, rig down csaing tools, Rig up cement head, Circulate and condition mud, pumped cement job Displace cement with Rigt pump at 10 BPM. Bumped Plug at 5070 stks, nipple down Riser. :j Logging Engineer: Doug Wilson / Mark LindloH · 10000 units = 100% Gas In Air ~ '" .-;~~:~~!::iÞt~~;?~.r~~~:·i:i;ii¿?f~::.~~:t:1~S:¿~!Û~~tt~~~~~~~tß~?~~t?~:~§1fi;~~~m~$~s¡,?y.~~~:P:~?il¡t~i~~}¡';f¡?~;t~~~~~~~~~;;~'.~i:·· :'/:'!~' 7+~~,,~¡;~ "A, , ., ::i{~~~~j(~!'i:,.¡;'....I.tl¡í~~\..·': ~,'. r;t_ff I L- ~ I N c¡¡ SERVICES ··::··"1ì'~~ ~~~'i.,\·.rfttlt1:~~~i:i:~:' ·~~:t:*;i~~~'.1~,*!~~;~~'ì#'!:I.M,*·H"¡:;'I;',:V~-::r~..:,·· '.~:: ',<: ,;, .. ,"~; I'll i~;'! ¡ ~:;;,.·,':x!i·.f:r.l(lj,:~i··' .: ,:".: :. Customer: BP Alaska Report No.: 6 Well: NorthStar NS 12 Date: 6/12/02 Area: North Slope Depth 3,647 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: RIH Job No.: AK AM 22092 Report For: Polya 1 Dinger Shows: " ':h~ ')~ , ' sper'r'v-sun Mudlogger's Morning Report I ,,':'~ :~~,:.,!,;,:t~,::i ~:',,:: -: ·,~,..~,r ,:~a.¡ "~::. :..' ¡~: ~ '.:Y,...· . 'H,. ',." -. .: ..~.~~·~:~"':~t::~:;¡,·:. I.'';' : J~':' ~ ,.>L;. r:~;,.... .".~ ~¡'~ -, ~....¡ I: .." . .:~, '. , .\ ': ~ "J; " .:..t":. :'.~ .,;, ;l' ~:.: ~~.:, ',~' ,;;.-.., :~ :;, ~..,.' . ..~:'~~~r;-:. '~f':',' ~;·',\.1~;':!'"'::ì.:';.~~ì'!.~~""¡~~,,'\o.-; l;~·,:. '".:: "",,'"' Current 24 hr Avg 24 hr Max Pump and Flow Data ~ .\;~~ ;;. R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ Pump 1 0 spm DH flow gpm ~: t; '; Gas· 0 units unit~ ( 0 units @ 0 Pump 2 0 spm Total flow 0 gpm ~ .:; Temp Out 70 Deg F (70 deg F @ 3647) Pump 3 spm AV @ DP 0 fpm ~ . Pump Pres 0 psi A V @ DC ----0- fpm I .,,, , ' , ..-. "....,',,..,<-.,-~......_.;¡,,,.¡". do ';' '., (...,...'....QL.. """''' .-~-,..-"·;'iI:i.;tI~"""· .""','··¡""O:I."".' ..:1""..,. - ·1.,·...:...I....··,~-.-............... < _.....""""_.....;.:...~.,. _.. ~..I:'..._1t~L ......L~"'...~¡ ..~,...~ ....it. ,.," ~:.. ~-.""" ~"""" ""'~I~.,..~.-.",: ',·ff. ;w...~,\...-,.,-r<.-,S'I~... ""_..-,::.--' I I. ,../,., '.....10;..,_ '/" """---~tl!l';'l·I"';I 'ro-l'·"'."iI.I,IiI'I--'I-'-'."'~~-.}'J ¡t,," ....., '''''',IIIß""IiIf'IiT" . '..V.-pr..' --,.lIIiI6.· 'F.' ,..~~ -:~ ~ I ,-" Mud Wt In 9.10 ppg Vise 43 sees API filt 8.3 ml HTHP 0.0 ml Mud Wt at Max Gas _ ppg I:'~ :,~.~ Mud Wt Out 9.10 ppg PV 16 eP YI 18 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH ~ Sd ~ % ' ;~:!. '·.c;·~ "., ,-i1~-¡;~;1·~.:'!¡'f,~Tor-R'~~;;,~~';:~~;"¡~.:.~~t~-(~-?'~;;~:f~Þ':,,;:~¡;-.,,·:tr''''';;lr<;·.:: ,:,~"'r'~,?,,,,; ·-:-~~-x~,"':r-~·~·..,;;ti#,~,;',"' :~.<, 1~,,",.;:--;:-W: .",:;j~:~t~~;..~H¢~;, .. .' '~'t . ,Z ~. Bit No.: N/A Type: NlA Bit Size: N/A Jets: ... \ \ \, \ TFA: N/A I Wt On Bit:.~~ RPM:. 0 Hrs.OnBit:, 0.0" To~al Re~so~ Bit: 0 -=Footage fO~ Bit Run 0 ,~'"~,,~ ^''" ,. ---'=~h^"~-.:.m~r.-=r..J..:w...,v~_~_T~tI:.~:ïr."'.,~lLl!li.t,,lU:']î" L...~t:x:lX~:t,,\,.,... ! 18000 ppm ~ i ppm ft ft ft Trip Gas: Short Trip Gas: r ~ Trip Depth: I' S.hort Trip Depth ~! T!ght Spots: i ~~,..:,'~~..,_^'_ to to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Current Lithology: % % % % %LCM ft units ft units ft units I Depth to ! f;; to I ¡ " to t~ to ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units _ ppg ft units _ppg ft ft ft units _ppg units _ppg units _ppg I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh -¡ i 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ·r:'''I~~f~~!!alt:l!I.:T~;t.,IT um [~ [mm IIlIJLL\1I1mli!_:I:z1~11U'lmlliJ1¡lnl~~iiD·:~e~n\I1~J~'~::..:1::~11f1 ,," 0" , 24 hr Recé N/U BOP's, Tested BOP's. Pick up BHA #3, RIH. BHA's have not been distributed at report time. oz. Hopefully Mark Lindloff will be going in today and Tom Mansfield will be coming out. Logging Engineer: Doug Wilson / Mark Lindloff ... 10000 units = 100% Gas In Air ~. ,.. ' ?;·'bt't....;j.¡;<;.c-¡~~""'~;.;".r·;·l"w. ··:':t'.'"'7~~~w~m,~:'ò:~.w~:..!I:G;H:~ " .........'.' ,'"^".., ,"',. ··.,...:'W....;¡···n".··,,t·,·1't~~Ìd"1:l;,fj,~<!'r.··~~··:'I-~··..t1····t.:I!tw..;;,m.~r;11.--,-·':;:-' .; ..¡~~ ',;~'~~ "'.t',;~~:~~~m~~~~'~~~~t:~~;;*~"~j~?~*~~#{'~~2~'~~~,~~~~.R\:ì ':' :~~.; t~~,~~:;~ £: ~:;":(;~,:;E~:: ~ ~~~~~~~+~~ ~I~~~~),~,t#~~·;·:i~~~~~H~~Y.?'~ Ji~4~"';~·~~~:~~'~~-î~...h~'1f.Jil~~:~¡I;.}~~';\; ,...' : :.~, ~"-::.'S\'\L"""m.ì;lI'ji"~ 1I~'\X-·t..")-',,\~'\:iiI,~~""i¡·'ltdMitíi~iß~&I ,a~~ÑÏtIIII~h"''''1¡.~'''ih'f'*,..<'''''f!:->.i':'-!-"."N'f--_~J1~~'~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. I,' " Description of fillings: . :: .;~'I"':'::"!~.í~~iì;¡'t!~~~~~)¡t "~Y:IW1J ITIlnøJ ._.J!i.t_UÄ~~~:t~~.i~~~~t?(¡.ß1l~~~~i.i¡';'¡';"~'-· ;;ff 24 hr Reci RIH. Test CSG. Drilled CMT, float collar, plus 20' new hole. Displaced mud system to PHPA. .!~~ F.I.T. = 12.5 ppg equiv. Drilled from 3667' to 4401 '. Rotary steerable failed. Pumped Hi Vis walnut sweep and .:~ POOH. Pulled 3 stnds. Pumped out to shoe do to swab and tight hole. .1,i ".~,;, .eN ,j'; Logging Engineer: Doug Wilson / Tom Mansfield * 10000 units = 100% Gas In Air I ~~~:~~¡i~~~!~~~~~~~~~~1~~j~R~M~~~f~~~~~f;:0~ to to to to Connection Gas and Mud Cut units ppg ft units ppg ft units ppg units ppg ft units ppg ft units ppg units ppg ft units ppg ft units ppg - Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh ft ft ft Depth %LCM % Current Lithology: % % % ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Depth: Short Trip Depth Tight Spots: Mud Cut: Mud Cut: to to to Trip Gas: Short Trip Gas: 4401 ft ft na ;':'~ Mud Wt In 8.70 ppg Visc 52 secs API filt 7.8 ml HTHP ml Mud Wt at Max Gas 8.7 ppg it Mud Wt Out 8.70 ppg PV 14 cP YI~ Ibs/1 OOft2Gels~ / 9 / 10 Ibs/100ft2 pH ~ Sd 0.25 % .~;r~;·~"~";".:¡,~~,.,;,.ø.~~~~~l~~·~~~rftt~~j~~jt.~,_~~t:~~~t',*"'~~. y~'m~i~~~1!'.~_'J~~~~~ :ÎSitNO.: 3 Type: RS238HF Sit Size: 121/4 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 l~on~5'2~__~rs. on~.~ =:,::~~:eforBit Run 754 jr;(\\.~;t'~'~;".:",~~m~~~'~:~:1:::~tiM~~~~.~!iI~~~~':::~'~~r~~~'¥.,~~~~w;~ ,·,,:;~~~\~,~f:_~t~~l'1";~Wi.~."".~'~)Hi¡,~:ç\)¡'":i:,:)\i((!~M1j,Jll L J~j9~î1:~t6~~j~~¿\~i;7i~N~~~~~~_d'i~l~ì~Ni:~;$:$5.W~·î~~;,"~'lr.~}~1~~~~~¡~i'i.:·')'~áj~1 ' Customer: BP Alaska . . .. Report No.: 7 ~ Well: NorthStar NS 12 Date: 6/13/02!: spe....,....,v- sun Area: North Slope Depth 4,401 ~. DR I LL IN G 5 E R V I c: E § Lease: NorthStar NS 12 Footage Last 24 hrs: Rig: Nabors 33E Rig Activity: l II ' M . R Job No.: AK AM 22092 Report For: Pol~ ogger s ormng eport Shows: . .' , ; ';':',';"";~('~:;"¿,,'m~~~~~!>¡¡'¡:~'FF;~'4';1";!;'1'" :~:~i'!-';; ::¡,"9"'f~;':";~~*~~~?c~;¡;::,\i¡~~~~ :';:""·;;;~~")~.;~~V;1·.~;,;~~~;.<'·\:";~f·~,~;.J:f:·.~"');~\';;i}~0\>~~'~"''i;1)~~'' ,:;':¡'i:..",,; ';';)~~:,,~~~~:;I!IJ~~'%~~~;¡'1¡¡;.S""~""'" ,\, Current 24 hr Avg 24 hr Max Pump and Flow Data ~, na ft/hr 209 ft/hr ( 535 ft/hr @ 3467) Pump 1 na spm DH flow _ gpm na units 14 unit~ ( 24 units @ 3488 ) Pump 2 na spm Total flow gpm" 65 Deg F ( deg F @ ) Pump 3 spm A V @ DP = fpm I Pump Pres na psi A V @ DC fpm ; < R.O.P. :t; Gas" ~f Temp Out [ [ ¡ 1 i -~~y ~\ .; '-':'f~' i:·::.~~Y::~¡:~?~~:~~f;~f:,~~·,:~~~~~:.:'i't~"!f·~~~~~l~~~~¡~;~i~;~~~~¡s:%~~~t~~~~E~i~¿~þI~~:~!:~:":';::;·.·' ;:.:~ ;1 24 hour accumulation of Steel Filings from Possum Belly Magnets: ,~tion of fillings: ~.',',' .' ,,'·',""_~.·~aIlUllœ~.ffi.r~Œmm l~~'II~,t.)ICìm:::mill!n~1]~4Ä~ :~~ 24 hr Recé POOH to change out rotary steerable tool. RIH. Trip gas of 43 units. Drill ahead. Max gas of 1189 'Wi units from coal stringer @ 6629'. :;1i SV2 @ 4703' MD, 4092' TVD ;~ SV1 @ 5222' MD, 4497' TVD ~:~{. UGNU @ 5726' MD, 4897' TVD ~~ ,; Logging Engineer: Doug Wilson 1 Tom Mansfield oz. I .. 10000 units = 100% Gas In Air ~ j -~ ~J¡¡~~"'~ ;¡:[;"11[.\1, ~. units _ ppg units _ ppg units ppg ]['T.lm.. ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ppg ppg ppg ft units - ft units - ft units - I l Depth to ~ to ~ to ! to ~ Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh - - - - - - - - - - - - Drilling Breaks '~..1lllltll %LCM % ~:.....,._].'ZaBII. 20 % CLY Trip Depth: 4401 ft Trip Gas: 43 Short Trip Depth ft Short Trip Gas: Tight Spots: to to .U::¡;I~-~-UMl·IIf~m~1lIIJ "1m m ~ - -!JiØ. Current Lithology: 40 % SO 40 % SLT - - 1 - l'~'· _"'W;;~Pl1{;J' Mud Cut: _ ppg Trip CI: ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft . ~~ ~ ~ ; ~t ..·~ii " Bit Size: 12 1/4 Hrs. On Bit: 15.9 ,'i Bit No.: 3 Type: RS238HF Wt On Bit: 15-20 RPM: 155 'W ~ïr,......n~~:~~&1,I'" I Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ Total Revs on Bit: 141 Krevs Footage for Bit Run 3,414 ~~_JJI~~._~ -=.].I.=":=':::':~~....~ .Þ.. .,.. "~c ;.-~c~;oòM-~'M"l·,~.b.::.~-I.~~~t-x:~I~:~:,..,,~:-œr¡·.7,~':~~I'!_~~~;.~~i'.k;~~::'--.:(,j,:~'~·~'C'~4I'_·~;~.¡;r"W lJ\·,~~-::" "N';~;· ,:.·.-:~:i:J~\I:·:~;~"":::: '~.':!,'. :~1JJ ml Mud Wt at Max Gas ~ ppg _ _ _lbs/100ft2 pH 8.6 Sd 0.5 % 5.4 ml HTHP Gel~ 7 1 11 1 Visc 56 secs API filt PV 12 cP YI 27 Ibs/100ft2 9.00 ppg 9.00 ppg Mud Wt In Mud Wt Out . ':':1"'- ... .: :..:.., .-Æ'...'I.::.:.'\...,~:: '''''I.;..~ .~:.~. ....~.. '~!~l'!C;::t'~.,:.~~z!~'It'=..!:..~..!"':'':~\ ~:'._~' ~.-." .w:·:;U~;;:· I ~-Þ·~:,:ÍL~';'~~ ~;.~.~ -r.·:I:=·;"I~J;:':;;'''' ::~"~"'':'''''I::....~.:':.~~.' ......:~.:'...;- .-:-....::..... :. .:: . ,, .... .' ~ n:~.Je,.'""!:·· gpm'~ ~. gpm~ fPm_ fpml 888 169 253 Pump and Flow Data 105 spm DH flow 105 spm Total flow spm AV @ DP 2400 psi AV @ DC ~ Pump 1 Pump 2 Pump 3 Pump Pres 4618 6629 24 hr Max ft/hr @ units @ deg F @ 610 1189 24 hr Avg 216 ft/hr ( 68 unit~ ( ( ft/hr units Deg F Current 92 48 \':;.'- ,;1: Gas* A Temp Out ¿,:: R.O.P. ....... ....:.. ....; ".; ....,,~.....-. ..:..,::..:..:~.~~,~::~~~.,~,~,,¥:...~""",,:.~,~':~~Z::~_':;..~.;;.;¡~~'~.,,,.~:".,..' :_·"~~'~.~~tt.-.3-:·t:~'"~+i~~~·~I.~:'r.;,:·,'::'~.::'~~·"':'.-"- ..'.~;.::~.:", "~._:.:,~~.~~::r~-;·i--::~~'~~:~"~~~.:.''':'.::_ .,\:~).::.~!7~·':'.:~":.; <!2i\ì:.i+;¡¡¡¡:fH\:?<\'i·::i1t;<i'ii1'i\¡ì')¡}'~~1~~~~i~~iìfi~;;'.;'";j:'i';i'..~_~r¡illlmjljO!~J~¡\;iW¡~~1l~~1_~Þ,'\¡;m:~¡'Jt~~'¥ii~{Vi¡¡tr.~1~~11j:~1t:Y2:¡i¡,",<~~,~~?~. Customer: BP Alaska Report No.: 8 ,I Well: NorthStar NS 12 Date: 6/14/02 f Area: North Slope Depth 7,061 .. Lease: NorthStar NS 12 Footage Last 24 hrs: 2,660 Rig: Nabors 33E Rig Activity: Drilling Job No.: AK AM 22092 Report For: Polya / Dinger Shows: Mudlogger's Morning Report DR I LLI N-~-seAv I ~ e-s spe....,....,v- sun ~;'i~~:¡,,~:~~.~r;~~~~~'~~~~~~l~$\i~~~3f~~_i~~"~~~~~Ï<¡~j',,·.~,:,:.'i;'1~1 . Customer: BP Alaska Report No.: 9 ~. Well: NorthStar NS 12 Date: 6/15/02 ~ spe....,....,v- sun Area: North Slope Depth 8,216 D A~LL I N G 5 e A v I c:: e 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 1 155 Rig: Nabors 33E Rig Activity: Tripping Job No.: AK AM 22092 Report For: Polya I Dinger Shows: -'.' Mud Wt In 9.00 ppg VISC 57 secs API filt .~i Mud Wt Out 9.00 ppg PV 13 cP VI 29 Ibs/100ft2 .~",:.:~" Î Bit No.: 3 Type: RS238HF ~ Wt On Bit: 15-20 RPM: 155 ~_' .Jr.~:l(~_[¡n:~!fi:::n.I:b.m ~ ¡ I I Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data na ft/h r 133 ft/hr ( 400 ft/hr @ 7772 Pump 1 spm DH flow gpm na units 65 unit~ ( 167 units @ 8090 Pump 2 spm Total flow gpm,. 95 Deg F ( deg F @ Pump 3 spm A V @ DP fpm Pump Pres psi AV @ DC fpmj\,' . ,: ',':~' '.;~ :,:~..:"'::oo\!.~I"-""I~:"w..~~..,~r::~~~~;-":101 ~""":õI!.:~~;,;:X~.T.,"~ :.(:-~'~-...:.':. .I~; ;·..:~..;.:~.r-.,.I ;.~;;~'r~;.:(T.'..'<;·.;.J."'¡~~'ft: ~I~~>i''''- \>-t J\:.' r;.,~.".;,,;?:. "II::~,: ~.¡ {t 70 ml HTHP Gel~ 10 1 17 1 ml Mud Wt at Max Gas ~ ppg Ibs/100ft2 pH 8.6 Sd 0.25 % --- .. 'W,' w' "', , ,..... ...., ,··~.~~t~. ., Bit Size: 121/4 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ Hrs. On Bit: 24.6 Total Revs on Bit: 217Krevs Footage for Bit Run 4,569 IüliT·n·'11·K[::n:::L--:m.::1I:.~t7::.~:t~~]._..kl~ ~ ~ "ill.,",,: Trip Depth: 8216 ft Trip Gas: na Mud Cut: ppg Trip CI: Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: Current Lithology: 20 % SO 60 % SLT 20 % CLV % - ppm ~ . ¡ ppm ft %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units -ppg 1 Drilling Breaks , :.l\1"1t'~~tr~ftiC~:~~~-=f.]~iOO!t.ü'.::.,~~.i~t.'~'[l~f.~~1..iIft~'~~~~Ji'''~t\,~t.·~~ n~ Irmlnn~~~~f':,,:" J .24 hr Rec¿ Drilled to 8216'. Pumped Hi Vis, 11.4 ppg LCM sweep. Circ hole clean. POOH wI tight spots @ 7325' , to 5445'. Pumped out from 5445' to shoe. Circ. Out @ shoe wI moderate amount of scrappings and wall cake. :,' Cleaned up after bottoms up. POOH and changed MWD. Re-ran bit #3. I 11 ,'~~. Logging Engineer: Doug Wilson 1 Tom Mansfield * 10000 units = 100% Gas In Air :>:. :.". ""·"~"'·~"'Jx· :r.~;,à·~ "'I'~~~~;~~"~ f1( .':ì'~'~ 1;.' ,'::tI~··~·~~,nl\n:;~i~áIt.'fu::-:··¡^"·~,¡<"··¡:~~~-···:~,r;;~~~~·r·;.... ., ~·,,:I ~:.>:. ~~ ;'~':~I~~·;"~~~k~:t~:'11~::1~~i::'1~·.t~.~,~:.tJ~)~:¡.~J1A~~~~~~·.~,~·:'!!~'t~:,·!,~,~,~ :.:t~-i$~~'~~~'~~~:~~"I:~"¿'~:~..,,~tÆ~~~~~~~~~'~~;-;~f ~?'5'~~;' .'~' :,." ~.,~ Depth Drill Rate during after % Lithology Sst Sltst Sh Gas during before after before to to to to ! ' ,d à ~"" ~ .r:'·~··~~:W.,ø ,', .,' ¡;,:" .. '^' , "1'~' ..... .'....~: 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. Schrader Bluff @ 7758' MD, 6549' TVD , .. ,~ sper"f'""'v-sun . ,:·;~t.ie;,~1i!tZ!;~i!.~_I11.t..ri::"""".' '''i\'':'~..J;~~t ......~:Ü'::.'~~~\SI!ti~!! ..q~r ,·;¡',~;i~-!"~¡~¡;i¡·'i.-'·~,iidi'.!;-,-~'·.:·~~~·.::~ ""'4~W!~"'~~~' .:.';',', ' " Customer: BP Alaska Report No.: 10 Well: NorthStar NS 12 Date: 6/16/02 Area: North Slope Depth 9,067 Lease: NorthStar NS 12 Footage Last 24 hrs: 851 Rig: Nabors 33E Rig Activity: Drilling Job No.: AK AM 22092 Report For: Polya / Dinger Shows: . " . -'..., .-........~ ...I_-..'1.·....~.::~~.\-oÕ ~.:-.: '..~. " . . . ·...1. . 1'""'''1'1''0 ~·..I·_..... ....:. . ~,.":'....~.: .............' ~'. :.. ..,..... .: .:"!,:,.;........-;. .:.... ~..,.:-~ ._~~'J'" ~~..., j,.- ........ I ~ ! t ~' , .:.~. .~. :I,',' ~1 ~:.~'; '2~ g.._~ILL.I~~ seAVlc:es ;',~;:. Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data ~{~ R.O.P. 105 ft/hr 115 ft/hr ( 203 ft/hr @ 8298 Pump 1 105 spm DH flow :n Gas* 122 units 131 unit~ ( 301 units @ 8497 Pump 2 105 spm Total flow 888 ;.~ Temp Out 100 Deg F ( deg F @ Pump 3 spm AV @ DP 169 ", Pump Pres 3000 psi A V @ DC 253 .~~".~ ;':" ,-:;,: ',.~.~:;~~~ø:~r~;"'~~'Qo"ì~~~~I«<I)"'~:~~';¡~~~~~""¡~~~~'¡":"'$Il::::":o!.r~;.: '. ~.~~;"!::I'l;~:;¡:~.:¡ ,.~:, '." Mud Wt In '~l~' Mud Wt Out ~,.~;r . 9.20 ppg 9.20 ppg Visc 55 secs API tilt ~ml HTHP ml Mud Wt at Max Gas ~ppg PV 13 cP VI 29 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.1 Sd 0.5 % -_~íf.~ l.\1J:~~ml¡¡¡ln[~D:gl~11}1¡lìjjf~i~j ¡jìj~~;®'''~Ä~'IriR~_~~~~.~IM_~$~&7~"" Bit No.: Wt On Bit: RR3 Type: 15-20 RPM: RS238HF 155 Bit Size: Hrs. On Bit: 12 1/4 32.0 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TF A: 0.9410 ------ Total Revs on Bit: 285 Krevs Footage for Bit Run 5,420 ~r ..J::ïŒ~_..:Jl"DI!!!I1L::JI1 ) 1 ::r']':U:IJ1~-':Ir~ " - ^," ,..,......- '. t ~ ~~IIIII. - UII ru.:,,__ 1 Trip Depth: 8216 ft Trip Gas: 396 Mud Cut: ppg TripCI: ppm I ~ Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~ i Tight Spots: to to to Feet of Fill on Bottom: ft r - Current Lithology: 85 % CLVST 15 % SLTST % % %LCM - - Connection Gas and Mud Cut I ft units ppg ft units -ppg ft units ppg - ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to - - - - to - - - - to - - - - , , to - - - - ¡ ",~'.'.'. "'- "-rllI"'\I'''' (:;ri::~l"i... -.fII~' ="....'" _.w~~ ; ..- -------'- ".-.\"'....., . ¡:, 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. .., ~: Description of fillings: 1 ~ ~~~~mt~~:I~~~~~·t~p ·drive. ConI. RIH. Trip in went well~ ;r;p~J ! units. Drilling ahead. :~! ,~ ;.!;' :11 Logging Engineer: Doug Wilson / Tom Mansfield COLVILLE @ 8386' MD, 7045' TVD 1 I 1 * 10000 units = 100% Gas In Air "~:, -::~;::¡',:if.'~t~~~~~~~~~~~,~~~,~~W~,~F,~\¡~mþ~ti~;~~~~~4~~~~:,~;, ".¡. ',.' I," .'";..t:".:':ii:tI~W;:,.l~:, :~,:!~¡'~:!~;'1.!" ·à,i+..~__lJll1l,.~'i;¡~~!·~ Customer: BP Alaska Well: NorthStar'NS 12 Area: North Slope Lease: NorthStar NS 12 Rig: Nabors 33E Job No.: AK AM 22092 I '~ +. ~t :-:'i ,~ §i ::,~ ,;7r spe...........\I-sun CAI LL.I N G seAVIc:es 220 1116 115 24 hr Max ft/h r @ units @ deg F @ 10691 10564 10862 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: '. d'~~~~f~~,·¡i..~~ù.t:~":..."i~·,,ù;~:"-·"t~,~·" ;,; ". 11 6/17/02 1 0,862 1,795 Drilling Polya / Dinger Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 105 spm DH flow 105 spm Total flow spm A V @ DP ,~400 psi A V @ DC gpm gpm fpm fpm . Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: 888 f \ III: .~ !'it ar Mud Wt In Mud Wt Out 10.00 ppg 10.00 ppg VISC 44 secs API filt PV 13 cP YI 26 Ibs/100ft2 5.0 ml HTHP 10.5 ml Mud Wt at Max Gas ~ppg Gel~~ 1 ~ I -.!2..lbs/100ft2 pH 8.0 Sd 0.5 % Current Lithology: 60 % ~~.;, !," ',<' ,,;::;, ":'¡'i~~4r~!!1.;~~'r.';;~:J'$}Wi!~~~~i,~~¡t},>~~*~Þ';\i":Ii4~~t~';I;"'"¡¡è(~~:~¡~~;¡tI:\,~;rn~~):Ρr.,~~~":,þ~,;;:~~~F~~*~,-;;t~S:~!~'~':'!·~~: ~~. ,~~ ,*' R.O.P. ~ " ~~~ Gas ~ Temp Out ;~ :¡4 '.::~,.." .·.r:·:I,,:<,~,'Þi.~~''''~~~~A.:~1\''\fiI\J~.~.~'''~iIV.:.·~!~~~.lt:~,,4,\w..'''t ~'.,~~~~~\:Q.~ !.~.7'+'~'';!'';';-~'' Mudlogger's Morning Report , '1'I~~:~~l:~;;]';;,~œ.:":~::JX1tU~:J~W::.:m1m:J;::1t;~~~ Bit No.: RR3 Wt On Bit: 15-20 ,"~l.:JL_,,_ ... Trip Depth: Short Trip Depth Tight Spots: Type: RPM: RS238HF 155 Bit Size: Hrs. On Bit: - 12 1/4 51.0 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TF A: 0.9410 ------ Total Revs on Bit: 462 Krevs Footage for Bit Run 7,215 _ -':':,jm:f\L,D::DI::]jL\'f~nnftD!It:]lI~:J1:~ "" SH 40 % SLTST Current 64 260 115 ft/hr units Deg F 24 hr Avg 96.2 ft/hr ( 295 unit~ ( ( ft Trip Gas: ft Short Trip Gas: to to ppm ppm ft % % %LCM ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units _ ppg ft units _ ppg ft ft ft units ppg units _ ppg units ppg I Depth before to to to to Drilling Breaks Drill Rate during after before Gas during after % Lithology Sst Sltst Sh ,.,',,':~~"''',Ijìtl'.k'':\..'.. : >,~ ,'",_".. ' , ,',"S",~r,'. ~:~:~..' _n' ·~~'I. ~~ <, ,"", ,,,'~,~M',,;,AIï'I,~, : '''''' \1,lj"'~·"ì,",',"<."",':-ì, 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~~mnu~1RIE?Rl,':~~lln\I.m ~mJj ~!!u:;"~": :'; 24 hr Recé Drilled Ahead. !'tm, ~,~ .:~)i¡ "1£ i :~ . ,'~·d.' ¡~ Logging Engineer: Doug Wilson I Tom Mansfield * 10000 units = 100% Gas In Air ~Ii'i ':~::;',,:~~%~f~1~~\f;1~~~~~__~~~ï.~1~~~_~~þ't~~~r~~1;'I:· HRZ @ 10680' MD, 8888' TVD - Base HRZ @ 10760' MD, 8953' TVD - KUPARUK @ 10800' MD, 8985' TVD KUPARUK "C" @ 10977' MD, 9127' TVD f 1 1 1 1 ,.'..,:'1i- ,.':-'(:-'" \",,:.:!;Irloø~~:" .,.. ·.::"j';¡!...·rll#~\)~~·: " ,·:!tr;ltU4~~""~:·~·f-~I~':"'··~"¡:' ." , ';.': , '.' ,i:J .IS'\Ji";rn~æ,,,.I;:"~,,'·,i:~· , Customer: BP Alaska Report No.: '2 Well' NorthStar NS 12 Date' 6/18/02 ·;t~ ~ If'l ~. ,~i! ~.¡., ;~. spe""'''''')I-sun CAlL-LING SEAVlces 11,520 658 Circ & Cond Mud Polya / Dinger Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: North Slope NorthStar NS 12 Nabors 33E AK AM 22092 Area: Lease: Rig: Job No.: $ r':,,'I Mudlogger's Morning Report , Current 24 hr Avg 24 hr Max Pump and Flow Data : .~; R. O. P. NA ft/hr 69.3 ft/hr ( 350 ft/hr @ 11079) Pump 1 105 spm DH flow _ gpm, t t:i. Gas· NA units 244 unit~ ( 819 units @ 11062) Pump 2 105 spm Total flow 888 gpm ~ ~ Temp Out 110 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm_ .~. Pump Pres 3600 psi A V @ DC ~ fpm :.~~. ~r..'.I'·:.·"'Iti¡rt~.~~~I:';' "~~~#-'~~~~~~,~~\I#!~"~~~I:':>1".-7..'~~;~~-:¡;~!~~,~":¡';~~:'~~~~~~-;:..t",~~J, .,~. .~ Mud Wt In 10.15 ppg Visc 43 secs API tilt ~ ml HTHP 10.5 ml Mud Wt at Max Gas ~ ppg }~~ ,~* Mud Wt Out 10.15 ppg PV 14 cP VI 24 Ibs/1 00ft2 Gel~ 8 / 14 / 17 Ibs/100ft2 pH 8.0 Sd 0.25 % ;~t..·:.11..i¡"";'.t)'.ì$~'tJJ,~~¡,I:~\''Ì!¡:':'M~)'.r...x'~Ì\'f;tAA.1;~~~tr~'~1~~~<.~t¡,~~"~~~-;~~",,,I¡,,~~,~.:j'J..:~(i-ri~;, ;¡~;:j.;r:~~t~..~~ ,,::~;J :j;:' i Bit No.: RR3 I. Wt On Bit: 20 RS238HF Bit Size: 121/4 Jets: 3 \ X \ 11 \ 6 X \ 12 TFA: 0.9410 ------ 155 Hrs. On Bit: 61.2 Total Revs on Bit: 553 Krevs Footage for Bit Run 7,873 , ïl1Jn::.l.::.u.:1lIJD..T:Jtl1L~~.,.wr.~,EI_.::cmlŒdX"~~:.u~ Type: RPM: j I Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ft Trip Gas: ft Short Trip Gas: Trip Depth: Short Trip Depth Tight Spots: ppm ppm ft 1369 11520 to to -" ~~. u·,,·...· Current Lithology: 10 % 50 % SLTST SH %LCM SST 40 % % - - - . ft ft ft Connection Gas and Mud Cut ppg ft units ppg ft units ppg - - ppg ft units ppg ft units ppg - - ppg ft units ppg ft units ppg - - Drilling Breaks units - units - units Depth Drill Rate during 100 350 Gas % Lithology before during after Sst Sltst Sh 265 762 200 60 30 10 - 320 819 280 60 20 20 I - - - - - - - - 11 - - - - I ~ . ,,""... j ~ .~ " , i 1 0977 to 11 004 11 050 to 11120 to to before 70 75 after 65 55 .. = >'~"":.'FT"'~' , ..., ~ ~ ,.."'. -.. ," 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ~j_~"~.~~mR'i4Utlmj' .u:~mUØ'>I lJf~\i~ ~.}i~'u.r~1IUHl.~~.~J'{~W:;~ ?~ 24 hr Rece Drilled ahead. Miluveach top @ 11479' MD, 9538' TVD. Reach T.D. for 95/8" CSG @ 11520' MD, 'J 9574' TVD. Worked on Pump. Pumped Hi Vis LCM sweep and circ. hole clean. Short trip to 7939'. Pulled slightly ;~ tight through HRZ. RIH. Took wt. Through top of HRZ and Miluveach. Pump hi vis LCM sweep. Short trip gas of itf 1369 units. Circulated 1 1/2 times to clean hole. Prep to POOH at report time. .~~\ J:~ ~:'~ !i; Logging Engineer: Doug Wilson / Tom Mansfield * 10000 units = 100% Gas In Air i~' :·:":::·:=:<;N~1~"~~~~1)~~1?r1~$i~~~t~~~~3~·~ff~¡~~~~~if~i¡g!.f~i~r¡f~;l~~~l~fWJ~~mp¥i~ry~;¡~:i:á:~'E;-:-,·· 1':. oz. ~ r .,.. ~""r "~~P.~~~"~~i:-:~"~'if~!:~'liD 1If ~ IIJTI~Þ* l1tJ'ti1io'i\'h';M·-:~,.¡>~t8...n~!$,'I1:~m-~,I!»:I~·~~:r·,~~!~·~·b,~,~·i~f:~_¡;'.WaîÌ\'.'¡·"· :~. !t Customer: BP Alaska Report No.: 12 } .~ Well: NorthStar NS 12 Date: 6/19/02 ·1 I spe.....rtV-sun Area: North Slope Depth 11,520 ~.' C R I L..L..I N G 5 E A V I c: E 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 ~ Rig: Nabors 33E Rig Activity: Run 9 5/8" CSG ! \ Mudlogger's Morning Report Job No.: AK AM 22092 Report For: Polya I Dinger ~ :~ Shows: ~n ). J:'~''\'',^, ,1,.....·,;w~~~;)~~:'O\'*!~.:-~~~~~~~~~~,·:~,\S~~~~~"Ò\"'¡~.,',\<~::~·t~~;$,.;~i'~:~~tS~~'!~ì;;i\o~.iê\" ,'C''; ,. Current 24 hr Avg 24 hr Max Pump and Flow Data )~ R.O.P. ftJhr ftJhr ( ftJhr @ Pump 1 spm DH flow gpm ~~ Gas· units unit~ ( units @ Pump 2 spm Total flow gpm' "~ Temp Out Deg F ( deg F @ Pump 3 spm AV @ DP fpm : Pump Pres psi A V @ DC fpm . ~r " .·~o:.:,.:,~~_·¡.;;:t1C'llJIJ)'~~..)~".. .......,.t\!-'~.I;~,~\'!4'~~'l~7.I"I·Q~*-.~~~ ~~~"}II'\';oaIlt:'ttll'lW~~}':'!k1,.''...·.;t I Mud Wt In 10.15 ppg Visc 45 secs API filt 2:L ml HTHP ~ ml Mud Wt at Max Gas ppg "~; Mud Wt Out 10.15 ppg PV 12 cP VI 26 Ibs/1 00ft2 Gel~~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8.0 Sd 0.25 % 1 :;>1 :i~~~'n::t"a::c~:rtí.-:u.::~~~tm%UJit1ØØ,::nt:t'J¡nx::::.:m;~~M_~~~~I~I~t:'''m~ .~~ I l: Bit No.: ~ . Wt On Bit: RR3 20 Type: RPM: RS238HF 155 Bit Size: 121/4 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ Hrs. On Bit: 61.2 Total Revs on Bit: 553 Krevs Footage for Bit Run 7,873 ¡ _h",;L~-.n.""--;I=J__[[I.ll""";jj~m(~~lam_,~~~ II [] \ ¡ , ~¡¡:;::;K'~"1Q:llQl.H1;,' 1,"~!-""'r1111111r' -J[li:m::a:}ll;:&;;':-~~ Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: % % % % %LCM ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft un~s ppg ft units ppg ft ft ft units ppg units _ ppg units ppg 1 Drilling Breaks before Drill Rate during after before Gas during after % lithology Sst Sltst Sh Depth to to to to I' .¡ ~. t . ,,11' , .. " ,'.,' ,." { 24 hour accumulation of Steal Filings from Possum Belly Magnets: oz. ~' Description of fillings: . , .. W"~. ' .. 'll111r"-T"\\I(-'''"''m''I'W'Jn'i'7'~''''l"''t"'tl''h'~'II'''Ai"Uit',''''W't"1"'n¡;¡'''#ij''''''~''fj'IIi'thU'lΡ¡¡ '..fiil.....-·-·~·r.............-.......-" ':." ¡ · :u.~"'..ø! IIIffl' -~~'~~..I~.~~(I\j..!\I\1!,!~,~ ~~,~~;\,.,~...~~~ ",'. POOH. Run 9 5/811 CSG, I ~~j 24 hr Rec¡ .~~ t~': "':"1"1 :~~ "$ ,~~. ':' Logging Engineer: Doug Wilson 1 Tom Mansfield * 10000 units = 100% Gas In Air t ':~':;\.":;;~.{' ~~.. -~-"'~'~:i.."\';'**'" ;'", .... ~ F.¡';'~ ~~~! ...~~..':~.:..-,'~~~: . ,- -, "i . ~ri~~'-":' -~'~~ ~~t.1fi1~~~~r.~,~. ""~~~~'~"Þ~~'>>"\' .~~~_~~.._~~~~~_~~~li._ . ~ ::~:"~·:;:':;~~~:::.·:~~'?~'~~~.41~~_1f1jí~Ë[:¡~~~!t~~~r:~~;;~,*~W~~~~~~~~~~:i~~~.. 1 24 ho~r a,:,umul~tio~ of Steel Filings from Possum Belly Magnets: oz. J,' Descr,ptlo,. of fIllings. I '......Œrl~.';¡;.~JI![ UI iii . '.TfI!~:'1l-·~·~·111_r--·v~~,·';;t¡r~'"'J\"~rr .~!gn~~1I>I_r, '~r~'" , ,"~., , U Jum M...~III'R.1t.."....,,~~....~~,," , ,..,..' "" "', ,," ',"" ,', ,~J¡It,.__~U",,, "'"'",., " L" .' ...~- ;~N;: 24 hr Rec¿ Ran and cemented 9 518" CSG @ 11500'. Max gas bottoms up while Circ. CSG of 2150 units. :1' Currently cleaning pits and preparing to nipple up. ,':~, I. '~¡ ':~: Logging Engineer: Reg Wilson 1 Tom Mansfield ... 10000 units = 100% Gas In Air ,,'/.'[', "",,," "., 'I\¡)" ~ j ,,'-,,' , . I .,.. , ~ ',_. . " " >" , . :, , ,.\ ._~ " ,...,', ~"", X~:..,~, "', ~'b,~,! ':f:~:, I; ~', ". .,', ".: ""~ ,'~1 \,'.',", ,'Jì' ....'~' _'\~~'~' ,". .".,!";:¡'JQ,~,'1'¿'~'\\:·tf~f,··' to to to to % Lithology Sst Sltst Sh Gas during Depth Drill Rate during after before after before Drilling Breaks "]:~'-- Current Lithology: % % % % %LCM - Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg to to Trip Depth: Short Trip Depth Tight Spots: ~;-'k~~rt:il:¡~:~"""JØ.i\oB.~I''''_~~",,*IÌLIK'·;''''''tI!.'1';'I'¡¡''~'''.'ìio,'''_''''~.w,.,.NJ......~~~...,¡....;~;~~~."'..;>I\1"""""';jou.~,~~~_~~~~:.',.~ :4.~ ' ," ,',~-.,~. .-~", ..,i!III',IIi'_....''''.:',,·\IiI!!_~- '.~,....-.-.':>"'..~...........,.,~....._'.~...--'"""..-I'" "'" "~', ~~'i.';: Bit No.: 4 Type: Bit Size: Jets: \ \ \ \ \ TFA: a "I Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: - - Footage for Bit Run ø i ~.~;it.;.;;:~;~mulß: i!!~Jl=::D1:~gæ:LJL')¡, ",lC"-ìl!Cl~\if~..:~.¡¡wr~~BlI :lì,II,m1t!tlm~1 )~ Mud Cut: _ ppg Trip CI: ppm !J Mud Cut: _ ppg Short Trip CI: ppm . to Feet of Fill on Bottom: ft Trip Gas: Short Trip Gas: ft ft 5.5 ml HTHP _ml MudWtatMaxGas _ppg Gel~~ 1 ~I _lbs/100ft2 pH ~ Sd ~ % 10.10 ppg 10.10 ppg Visc 48 secs API filt PV 11 cP YI 18 Ibs/100ft2 Mud Wt In Mud Wt Out rr ~i :';r~t*t,~~¡#':~,~~"\.J'~~~~~~1?,~+~~"'\:~~;'~~~ftW'¡i,:;r")fio!l,~. Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC 24 hr Avg ft/hr ( unit~ ( ( ft/hr units Deg F Current :} R.O.P. i":~ Gas" ';~ ;~ Temp Out 24 hr Max ft/hr @ units @ deg F @ " :' ,".,;,,; ;f."Y¡if:),::>"~,i(~t¡';:{4;"'\!Ô~~'j\:,::!~~,~:~;g.1¡ij'jy:~~~~~,;'¡:_~1fM~'B!~~1~1;~"~#.~Ùi.ii1!'",;¡;~;'~~:~1,¡¡!'1:~~~~~~_~"'~~_~~,~~:'¡:~~~~~."':"")'w"" ::¡~i~~:":¡:~";"' ::'!'~~:I'r~'}!,)i\~i~t~~:'¡;i\i~~~~I,;t\"':'~~~",:: . ·.··.:~~.(~·:iU:¡¡;:t':J:I-¥~~~~¡¡~:~:6;~~S.¡¡..*Iiit'.;t.'":'j;j_#¡i~:·:~itr',:,or,))! ~: Customer: BP Alaska Report No.: 14 it , Well: NorthStar NS 12 Date: 6/20102 1~ .~ sper"r"v-sun Area: North Slope Depth 11,520 ~ :~ c ~ I LL I N G 5 e R v I c:: e 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 ~ .~ Rig: Nabors 33E Rig Activity: Run CSG & CMT i" i~ M . M . Job No.: AK AM 22092 Report For: Polya / Dinger udlogger s ornmg Report Shows: l I: ," ,'.t " ;,~ ~v,·,,~-:,- . ,,<'~~~Ifp.i·,'~"~ìJ,~~iU_~~-; " '~~:':'~C~~~~-r:;~~~';~*!4I!,:=-=~~;:"..:O;"~.~~i~;~:r..,,~; :, ,. Well: NorthStar NS 12 Date: 6/21/02 t ' j Spe.....,...,\ 1- sun Area: North Slope Depth 11.520 ,I C A I LL I N G :e A v I c:: e 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 I",~,:,- Rig: Nabors 33E Rig Activity: RIH to drl out :1 Job No.: AK AM 22092 Report For: Smith / Dinger ii' Mudlogger's Morning Report Shows: t~; .:- . . .:. : ' ;.-. '::.' .,-' ~~",!,¡r.;'\o:p ~,"~~·"""~~i;,,~,'¿':;:1-";'~rI.~;~;"~,'~'\:·~!""¡'\::;::<~:':'I~~1.:;i;!.~¡,#:-!:'I·~Ji..f".~'c--;~~~').f1t,;.:~!:;~':: .·,M.1J!";q<>¡,:~ ,~,,,,~,::,,·~~r.I'O:,1)'~œt,~·¡r~~~.1oJE,·~~S ;\;'I,:"t,U'~i_1\" :"~\'~i',~ (;¡~::-I~"r~ I :.'t Current 24 hr Avg 24 hr Max Pump and Flow Data :;~ R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow _ gpm. ¡:@ Gas" units unit~ ( units @ ) Pump 2 spm Total flow _ gpm. :~ Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP _ fpm; .~ Pump Pres psi A V @ DC fpm ',1ic ., -, ir~~"~~~.~1'IA~\J~ì~~:;(~*"J¡~~,\,:l!t;:;.,çt.\,J:J,:;"-ø;t:,-~Q:~..~~._&\~~rh''''~ Î MudWtln 10.10 ppg Visc ~secs APlfilt 5.4 ml HTHP _ml MudWtatMaxGas _ppg ~ï Mud Wt Out 10.10 ppg PV ~ cP YI~ Ibs/1 00ft2 Gel~~ / ~ / _lbs/100ft2 pH ~ Sd 0.25 % ;: :~}. .··;.·'.,,··.,~,>.-rlt·,+t~:;;i~~~~~~~~¡/i.~.I!~\t4::.':_~·;~'t':1It_"11lt~"'~~~~:,~~~,':,>,~,...·.n·,,4::a.·..... ,'.' .~t~ , , ',- ..... ,.'_",.."....... .w....__~__...Il",JL,_ Jets: 14 \ 14 \ 14 \ 14 14 \ 14 TFA: 0.9020 ------ Total Revs on Bit: Footage for Bit Run iltnC.J..!.!\,.:,::"'I'M Jill, .""''''''',''.._ __ ;,~"1:J¡." ~ Bit No.: , Wt On Bit: 4 Type: RPM: Sec. FS2653 Bit Size: 8 1/2 Hrs. On Bit: '-.-..'.... .., ,.¡ " Trip Depth: ¡! Short Trip Depth ~. Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft , .".......... I i Current Lithology: % % % % %LCM - - I ft ft ft units - units - units ppg ppg ppg Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units _ ppg ft ft ft units _ppg units _ ppg units _ppg . - r Drilling Breaks I ... Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to - - - - to - - - - to - - - - to - - - - ~ ~ù ~i- '.. (~ ;,' 24 hour accumulation of Steel Filings from Possum Belly Magnets: . .. Description of fillings: .~ ..DlrJ1IiUjll.ll~.1m"'~'!D.J:B.,.JIWmn.U~mm~11I~~~~~:' Nippled up and tested BOPE. RIH to drill out at report time. ~ . ~ "I, ..1 " _, .','1' -"·Jt,~.~,,J!.,;.t ., '" "." ¡.i.", ~...,., ,",~"~~",~~..,,.!j, 1\", '>'1'1" ~ ! , I ..J ~ .~ , ' ,m oz. ,_~,I.~·~,: .¡ ~ ;ii Logging Engineer: Reg Wilson / Tom Mansfield ···~~,:~~~~~i::;'t~~,;.;':~~ ~~, ,~<\'"." .. 10000 units = 100% Gas In Air '~ ::J~î~~ii;it~~~_~~~~~~~~~1itg~4ì~~'~~~6~:;:;;::: ;,~ , ,d ':pí,~~~~, ,~~ j, '" ',' Customer: Well: Area: Lease: Rig: Job No.: if ~ :~ ,~t:' spe....,....,v- sun gRILLI N G SERVIc:es Mudlogger's Morning Report ;', :,;, ',;-~þ,.~'\¡:..,!"",;.", ;.~ : ','';''; ,~:""''S1:'~ :-:::'~1!'i':'I<,If"i.-":~'P<:"',"".:''-'.':''.:,.,..~.., ;1: I Current 50 slide ft/hr 100 units 100 Deg F 198 141 100 24 hr Avg 44 ft/hr ( 85 unit~ ( ( '~~l¡{~~~~""¡fí,' Report No.: 16 I;'~ Date: 6/22/02 :' Depth 12.238 Footage Last 24 hrs: 718 Rig Activity: Drilling I~ Report For: Smith / Dinger : Shows: , ... ':p~;-:::t ~'.J'. - ~ .,"1 I, ...:... ~... "'''1' ...."l\'"t".~,.;.;..;t:,iJI, :. ,I"', . '.'I'.'r.. ""..; BP Alaska NorthStar NS 12 North Slope NorthStar NS 12 Nabors 33E AK AM 22092 24 hr Max ft/h r @ units @ deg F @ Pump and Flow Data Pump 1 71 spm DH flow gpm: Pump 2 71 spm Total flow 505 gpm' Pump 3 spm AV @ DP 99 fpm Pump Pres ~ psi A V @ DC 464 fpm, ' ,':""'~., :u;m;::::~~~~&1.~,,(::.lJt'("'~:'::.:J.11..,;;.~~\~tl:.~~1J~.:.:::t~:;";~:_~'~t\f ,IJIf~,\ 1:¡_t~~~~~ , ¡¡ Mud Wt In :'~:~~ iÎ Mud Wt Out 12.40 ppg PV ~ cP YI~ Ibs/1 00ft2 Gels~ / ~ / ~ Ibs/1 00ft2 pH 8.8 Sd ~ % ig¡ þ~~~~Mø':=(Þ.'~tt:~~rt¥.~;4,~~~ I,~~"'A~-': :~~~~'Ø.."Itz'I!i.;.a~'J;~~;:;~'~"~'!:t>II~~,:t1¡H,"':&~l:'t~..,.,~:-"~:::"" ~ ,t",); Î Bit No.: 4 Type: Sec. FS2653 Bit Size: 8 1/2 P Wt On Bit: 20 RPM: 90/151 Hrs. On Bit: 16.5 ~ ¡__..w~n _ _ _ I ¡~' Trip Depth: ~, Short Trip Depth I Tight Spots: ':'.j,~ l.'~ROP ~f . . . ":,~ Gas* ?ï': .~ Temp Out 12.40 ppg Visc 53 secs I 1 ft ft Trip Gas: Short Trip Gas: to 1 - I Current Lithology: % I ft units ppg - ft units ppg - tt units ppg - 1 Depth Drill Rate during before to to to to 'J ,. ..~~.ru,"" ,~_.I\i!l""<'.""'''' _" 12062 11598 12238 API filt 4.8 ml HTHP 11.0 ml Mud Wt at Max Gas ppg Jets: 14 \ 14 \ 14 \ 14 \ 14 \ 14 TFA: 0.9020 ------ Total Revs on Bit: 140 Krevs Footage for Bit Run 718 < I - -.h['mt:~:^" I m í,1]n~".JR)I"~DD to % Connection Gas and Mud Cut tt units - ft units - tt units - Drilling Breaks after before --.111III 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: MudCut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ppm ~ ppm ¡ tt %LCM - % % -, ,4_.L~". ppg ppg ppg ft ft tt units _ppg units _ ppg units _ppg Gas during atter % Lithology Sst Sltst Sh - - - - - - - - i"I\ ..I - - - - ~ - ~ - - - . , .. .. r ·nÞ.~ oz. -- ¡"'_"," IPI '~Hl' '-. ~~~~~'.-I·~'.. "~... ~ =")~:iI~~~;;«;¡JI¡~~IMlIlr'.~liKJm.lI...~"~fmtf'r:,,,, 24 hr Reci Perform CSG test. Drill float equip., cement and 20' new 8 1/211 hole to 11540'. Circulate and bring mud weight up to 12.4 ppg. Perform FIT to 14.0 ppg equiv. Drill ahead. KINGAK @ 11855' MD, 9854' TVD ~.~I:~ ":1 ' 'i .. ':~t ~r'l Logging Engineer: Reg Wilson / Tom Mansfield i~\ii~~:k~~~(":~~~!1.:,~~~;!'":,';·'.-i;, ,~~-., > * 10000 units = 100% Gas In Air ~ 'j\' ,~~.~.rM.~*~.~~~~~~:¡~~m_._,~:¿¡!~:::i¡. :~ ;,,\:,", " ....: ..vt.'I¡r;1iA,~.~~i:.K~ ~,i·.'~~r..-j..m T.1tIl_.k':~~~""~~:;;'~"~.·,~I~'It\.~~.¡b~~';~~~iI4..~J~~~·' '. Customer: BP Alaska Report No.: 17 " Well: NorthStar NS 12 Date: 6/23/02 i sp~I"""V- sun Area: North Slope Depth 13.135 .1 C A I L..L..I N G 5 E A V Ie; E 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 897 ,I Rig: Nabors 33E Rig Activity: .Drillin~ ~, M dl 'M' R Job No.: AK AM 22092 Report For: Smith / Dinger ,~ u ogger s ornmg eport Shows: ,:¡i:;,,,, ,...;~,,:-;¡. ' ' " ," " ~' ..'" -~-, '''''', ':"-:.,, ,,\ "", '-', . ',"" , .' . " , " ". " ,'~' "._. ''4f''~~''''"}''~~~'~t~~~,''1t\MW;IIIIW«I'J..-'nw.;;;tI;'~,~·~'J¡.~~~~~~~~~~~~"W~~,.t""'" , ·1 ~ R.O.P. ~ Gas· I Temp Out ~;. I Pump and Flow Data Pump 1 74 spm DH flow Pump 2 72 spm Total flow 519 Pump 3 spm AV @ DP 102 Pump Pres 2900 psi AV @ DC 477 fpm '",~:':~~f..~r:.'(çg;;)ì~:,~(t~i,{\t\~J~(;'\I.\'1,nN":~L(:L::ID1I1III;M';'~~)mn\t\t~ø¡~~~M~.rCr¡ji)~_.11~ìW¥{¡~ na na ft/hr units Deg F 24 hr Avg 59 ft/hr ( 100 unit! ( ( 203 240 110 24 hr Max ft/h r @ units @ deg F @ 12605 13125 13135 Current 110 Mud Wt In 12.40 ppg Visc 51 secs API filt 5.2 ml HTHP 9.0 ml Mud Wt at Max Gas ~ppg :\(, Mud Wt Out 12.40 ppg PV 2.!... cP YI~ Ibs/1 00ft2 Gels~ 1 ~ 1 ~ Ibs/1 00ft2 pH ~ Sd 0.25 % ;\~~./.~~.)*I~,tìI~:"~':·ìl...,t:..J:rra~1I(~ :~~:::~q:r.::;~';:ll.·IÞ..",:~(I,'~·;~'í.as,1i;.~·..o'.:~~~I:-:'~~.Q4~'~i,tt:1~~~~.1:~.¡.>J :~ Bit No.: 4 Type: Sec. FS2653 Bit Size: 8112 Jets: 14 \ 14 \ 14 \ 14 \ 14 \ 14 TFA: 0.9020 , Wt On Bit: 20 RPM: 90 /151 Hrs. On Bit: 31. 7 Total Revs on Bit: 324 - Footage for Bit Run 1.615 Î' ~,..-:r.:::...!:=-C] 111 U n~ _ _ - If I n II IIH Irru IT :J.Tr:C 1 1m ]1,] I . . ~[UU.",r1.wD::tn:l:_"" Trip Depth: 13135 ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM I Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg I Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh 13112 to 13124 48 125 50 160 240 190 20 20 60 to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. . '··""']'l~~~~;:~!!tatR!t]£rm'»WL,I.n]m 1~I~n]I]J.ltnŒ ]Qì[[!I~][[ 1,[\[ l~_~:, 24 hr Rec, Drilled to 13135' MD, 10895' TVD. Circ. Hi vis sweep and spot Therma- Thin pill. Very little Kingak tJ slough. Short trip to shoe, .,'~. 1",I".;,',',,',t1,." Kingak@11855'MD,9854'TVD ~ Sag River @ 1310Q' MD, 10867' TVD r}~ Logging Engineer: Reg Wilson 1 Tom Mansfield .. 10000 units = 100% Gas In Air "~;;-:::'::::~¿J~~~;: ".',". ,,: , . ...-.... ' ·_~~~_~~.;.:,,1 ¡ ~~%~~~~~''$~)I¡_I~I [jH..m[mI.lllll~ ~[~;~JlIIUlII l JII 11.~~f*f_~4i~~~~~Y¡#ì>S~:::tt'~ rt': Customer: BP Alaska Report No.: 18 ,!!) >;~ Well: NorthStar NS 12 Date: 6/24/02 I spe...,.....\I- sun Area: North Slope Depth 13,135 " " C A I L.L I N G 5 E A V I c: E 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 , , Rig: Nabors 33E Rig Activity: Run 7" liner ~, Job No.: AK AM 22092 Report For: Smith I Dinger :t~ Mudlogger's Morning Report Shows: ~. ~;:~~~~'t\\1i$;~~r.i(I.J;~~~~SA£L')&;~~.¡~~;k¡~¡~$!;~R_1Øt.~~~Ift'~~~;w .~ ~~. Current 24 hr Avg 24 hr Max Pump and Flow Data .~! R.O.P. ft/hr ft/hr ( ft/hr @ Pump 1 72 spm DH flow gpm ~''''i ·1; Gas* units unit~ ( units@Pump272spmTotalflow512gpm .'~ Temp Out Deg F ( deg F @ Pump 3 spm AV @ DP fpm * Pump Pres 2900 psi A V @ DC fpm t~t'; II :~:;t,-~"'"'~''"'''\W_¡.;d'''W'',··¡¡;,n' r~'"t·if"'·I' r··"I'.1 òII"J: "1'''jI··"\;·''·''...,'·''· ~ ·'!IrJ.1·r'....m·_··~'ií..·.·~'f -t''''''''J' '1t:JfI'II"H ·In'w·1II·..II···.o¡-.rW\,''",iitli1U>_>;tï't'A<i!ll\LJlitOI'Ö."'\·..'...··',¡,¡"t'io·'1'''·'.n;i.t.-_.It..,..,._,. , ;¥!~,.~..''''.-".....,,'I^''~,'__.,J''''I''' ..,..~~~"'~~,"'...""'_,.MI!a"-'..~..!t.I',__.''"~..,. ~ u._""..",.nI'.'1II<..''\!i;_~~~~_'"''.p'',I~IIII',':..'"......~~..,~<;\'l'cJo"''''''''' '~ Mud Wt In 12.40 ppg Visc 60 secs API tilt 5.5 ml HTHP 9.8 ml Mud Wt at Max Gas ppg. :~ Mud Wt Out 12.40 ppg PV 28 cP VI 39 Ibs/1 00ft2 Gel~ 12 / 34ï"42 Ibs/100ft2 pH 8.2 SdQ.25 % Ii ,::" - - - - - - - ,r ~' "_¡__mii\liiil.~·--'lt'''·I~'·''~iII'i'n.''''V''\'fIt'."JtI'IUI'ßf'Y¡¡'"I'''ftT'·IO..1i·''W'V-·n'l'üI'\"_'1"..,/.....' '~t"~.'IIIf'"n~-'r"l"_"1II.IiI~~1'iiWJl_._"~~_.""*-i\o.~_" ", . ~ , -~-....-...l~""_...'........~~~.HU-M_·,~"~~~""'''''__~,~IJ.('A!\~\J!:,...~\l.,,!MJiI!~,'''.~.~~ , . .. t ' ¡ ~ ~ Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: I,,: Wt On Bit: RPM: Hrs. On Bit: Total R~n Bit: - - Fõõt;ge k;Bit Run ! ¡ r .:r:.:::r;tJ8![ m Ð.lfì!l.=P _ _ _ :::,,::::::t:1f,m.'fI~tl1iA r \It..:u:n:n~ ~~ Trip Depth: Short Trip Depth Tight Spots: I I 13135 ft ft Trip Gas: Short Trip Gas: 401 Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft to to Current Lithology: % % % % %LCM ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units _ ppg ft ft ft units _ppg units _ppg units _ppg 1 Drilling Breaks before Drill Rate during after before Gas du ring after % Lithology Sst Sltst Sh Depth to to to to I 't'1·f\\;t£~'lll~·I:u.P,I"'"'' ~ ^, ) <6........'- \\1. .u__n ,"'~ .... I ¡" '" ,-,,' .h:t .Xf<~' ,..~.-- ,,'~ x~' " .",,"¡~\\':t"·,Ù"~,~\dfr ;~~W,\-... 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. f"""" i 24 hr Recé Ran to bottom from short trip to shoe. Circulated short trip 'gas of 401 units. Pumped Hi Vis walnut ~. sweep. Circulated hole clean wi very little Kingak sloughing. Spotted 180 bbl of new mud in open hole. POOH to t run 7" liner. ~!! ·~~::::~~~~~I I i~·:~~;:~·l·g~~~~i~t~~~~t:~~ ~'.~I~>:·~:"~·;~':=iÊ;~~~~~~"'>·· .,; I (J RILL I N G 5 E R V I c: E 5 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 , : Rig: Nabors 33E Rig Activity: Cmt 7" liner Job No.: AK AM 22092 Report For: Smith / Clump l~SIlJ~~:'~~.~.:~~~_., 'I Current 24 hr Avg 24 hr Max Pump and Flow Data 'I~ R.O.P. ft/hr ft/hr ( ft/hr@Pump1spmDHflow , Gas* units unit~ ( units @ ) Pump 2 spm Total flow _ gpm . Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP _ fpm r:'· ~La:II"'II¡r_IIII_W!mr:L¡::I'··ur::mr-..J£3:lJIlL4..J"X::~;;.:~:~ fpm , , Mud Wt In 12.40 ppg Visc ~secs API filt 5.6 ml HTHP ~ml Mud Wt at Max Gas _ppg : Mud Wt Out 12.40 ppg PV ~ cP YI~ Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.2 Sd 0.25 % , ma:rI~1..,~·=::ør:,.~. ~..nmœljll!j I~J ~tœrR:::m1t:r.:.cr'[!QŒ:::=:rn:n!~·:I:tl:~¡;L7::m,;;~a.·'·' I f Bit No.: ¡i . ; Wt On BIt: Type: RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ TFA: ------ Total Revs on Bit: Footage for Bit Run ":;LÌI1:1mru........ "" u..~:ItIC1 1 ¡ Trip Depth: 13135 ft Trip Gas: 330 Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft % % % % %LCM ft units ft units ft units I Depth to to to , 1 to ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units _ ppg ft ft ft units _ppg units _ ppg units _ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh .~', 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~ ~ <'I 24 hr Recí Ran and set 7" liner @ 13101 '. Circulated hole and cemented liner. Circulated circulated from top of liner with Max gas of 387 units. Returns were primarily Kingak with a minor amount of Sag River sand. ~~ ; :~ I Logging Engineer: Reg Wilson I Tom Mansfield "~ '~A;~;~ . ....' ,.. ,.Jt~1tl.t!.....~j~¥~~if;'·~:~:;'J'" * 1 0000 ';'.,,",'.'. r ~ '. units =.1~OO~o ~~:~:.~~J I I I I I I 1 I [ 1 I I I I I I ····<~·(:.:w.ll.llln~.IID .- ~l~.Ut rJI1fl!!ltrnlllHlI a_ n ].DI~~W.~¡¡_~'l.dIIUnl!it.Cmmnt: Customer: BP Alaska Report No.: 20 Well: NorthStar NS 12 Date: 6/26/02 Area: North Slope Depth 13,135 Lease: NorthStar NS 12 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: TIH to test liner J M dl ' M . R Job No.: AK AM 22092 Report For: Smith / Clump ,~ij; u ogger s ormng eport Shows: ~~:~~~w,~.n;':;';¡'\,:S':;,UI,.,.-~~:~.i~,1I.M&_~.(taJ..~'¡~t¿i~~..~~...~~~~~ W\tt~..Jr~~~~~..~",l"'ll-.l(Q~J(~~t~ 1:1:";. i .. Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow _ gpm Gas· units unit~ ( units @ ) Pump 2 spm Total flow gpm " . Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm ;~ Pump Pres" psi A V @ DC fpm : "~_'j ¡L:.ò.~' --1--' ImllO '_'''.... iii" "'.. .'.. ,·....--"t"'1:T' '_ftt'W'··· . T·-"..····~,·.."'1\"....~'~,.. 1<" 'III j' ' ^' 'iiIo"""-' '..._'-_.- __'~·,"T~~1»:-iIMI . ,......."..T"" ..~..r1ill_·""·~. ~.,.. ... 'D/"';;;'a" 'I ÎoHi'-', ..., , ,,"'<oJ ".,,«~~_.,,-- ,I£,UJ\".",'III!~,.~.,-",,~.J'-,'" 1J.4..,.~.,.1L_. ~ _~,...l.,^.."II'.,_!IIu~.....""', \..,..~."._II':!I!I~A~~~.,~"d''-'='''¡'''_''N~,~''',!!I!,,,,,,,~-.._~.,,.",,I..~",~I!'",~,~¡.:a~~ ,I I -. spe........v-sun C A I LL I N G 5 E! A V I c= E 5 " Mud Wt In 8.50 ppg Visc _ secs API tilt _ ml HTHP ml Mud Wt at Max Gas _ ppg Mud Wt Out 8.50 ppg PV _ cP YI_lbs/1 OOft2 Gel~_ / _I _lbs/100ft2 pH Sd _ % ~ ~1f'Ii.",,,,,.,,,,,,U"I'n_'ilW. ·-"".l¡-.."-'-.."fdIW'..-'I'·-----l~··'''"II·......·rar·1t^'..·..·....-'.'r..·..TII'I"...."t"...._·.....·,·_,,·..·,,·lII....'tI"'¡'-n"·"1II··..a··......"'t··.."'~,1I\¡\·lI..·..T'\'..M·ml'··~lI"··......,'I'oiI\-'III.···'·".I_i~· , ~ . 1>o.""~¡:o:.:-....«',J!lffi.'"~I.·~~u.~A1m).....J'I. "..·.>""I....·~'...7...."'...""-.r,~... .._.~.....I!ft.....,..::Jt.__.J........U~'....J,"'..............A....J.rd__.J1......",.. J._'1to"\....._._...."."'*'1"'~'"'C'Id~JU_.lW"~~k.....,:-:':,:o.~'1't....~~}~,\'<"I... ;,<:~".3-".......,,,..~~''''~.to~:w;c~~J.:i-.~~~ .. Bit No.: Wt On Bit: .If Type: RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ \ \ TF A: ------ Total Revs on Bit: Footage for Bit Run D;~L;:::I:[I]~~lïl~.r..-:I··'· .. . .n .._ Trip Depth: Short Trip Depth i Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Filion Bottom: ppm ppm ft Current Lithology: % % % % %LCM - ft ft ft Connection Gas and Mud Cut ft _ units ppg ft _ units ppg ft _ units ppg units _ ppg units ppg units ppg units - units units ft ft ft ppg ppg ppg Drilling Breaks Depth Drill Rate during after % Lithology Sst Sltst Sh Gas during II i before after before to to to to ---- ---- ---- . _,.:"-;;z' ..JIULlI Ulßl _11111 JI~ . ""~I ..., -..... ._..~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: . ¡', :,'n:fl)ll" _..Æ...~.~~~. '''-,-''-'''' I , . . '"'lty=···,^, ·,I.L 'I:' ,24 hr Recé Released from liner. Displaced hole wi seawater. Attempted to test casing, test failed. POOH. ;.' Slipped and cut dnllllne. Begin running in hole to test casing. 11 :,~~ :~~ ~: ~. '¥k~ 0]\ Logging Engineer: Reg Wilson I Tom Mansfield ::~ :~~fl·~~.~JI1L~;1J.t~:t:IM..UlUU1JfS.tlIID llilll~~~ßLUL;.~,~_~L~iR~~~~f~;';;:-~[.~ oz. * 10000 units = 100% Gas In Air Schlumberger BHA# 1 Job # 40007658 Date In 08-Jun-02 Date Out 09-Jun-02 Hole Size 16 Customer BP ADW Time In 11:00 Time Out 5:00 Hole Seet Surface Well NS-12 Depth In 201 Depth Out 785 Bha Type Steerable Field Northstar TVD In 201 TVD Out 784 Hrs BRT 18.0 Rig Nabors 33E Drlg Hrs 3.4 Drlg Ft 584 Avg ROP 172 AFE # 831317 Slide Hrs 2.0 Slide Ft 319 Slide ROP 160 DD's Tunnell / Bosse Rot Hrs 1.4 Rot Ft 265 Rot ROP 189 Co. Men Polya / Dinger Pump Hrs 5.3 Rotate % 45 Slide % 55 I PDM Run # 1 RJS 5/6 PDM Jet Blk Inelln 2.50 Az In 297.00 BibSrvy 43.0 PDM Ser# 962-1126 Stages 3.0 Bearing Mud InelOut 6.00 Az Out 52.30 T/F Corr PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM 1 OOD A vg Dls 3.5 Max Ds 5.3 Plan Dls 2.5 I Mud Type Sea H20 Spud Mud Wt 9.6 Sand % 1.75 RPM 45 GPM 600 SPP On 780 BHT F Mud Vis 144 Solids % 7.2 DI9 TQ 4.0 WOB 15 SPP Off 700 Item DeS;~rlþtl(,)fJ (' " Vendor ,SIN,; ID Stab'DD., F.N. Connectlol1$ Lénj¡th'çtJm Length Bit #1 MX-C1 I TFA=1.031 Hughes X27DP 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std PDM 1.830 75/8 Reg B ·float" Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 3 Orienting Sub 6 5/8 H-90 P I \ Ana GLDD-105 8 2 3/4 6 5/8 H-90 B 1.46 28.81 MONEL STAB 6 5/8 H-90 P 4 Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 34,30 I } 5 MONELLC 6 5/8 H-90 P Ana 10-HA-011 8 2 13/16 65/8 H-90 B 9.69 43,99 6 MONELLC 6 5/8 H-90 P Ana 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 B 9.96 53.95 I 7 MONEL STAB 6 5/8 H-90 P Ana HA-016 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 59.55 8 X·OVER 65/8 H-90 P \ ' Ana ANA614 7x8 2 7/8 1.20 41/2 IF B 3,09 62.64 1 I I I ", I II II I " I I aHA and Run Objectlve~!~~~_~~t g9~~~~~?"~~"_,_"_____"___,.__"m"u__.. Isurvey Bottom Hole Location, Rat hole to pick BHA BHA and Run Results averaged 2.4°/100 ft DLS, slide interval I -,---,-----",,,-,,-"---",-",,,,,,,",,---..--- ",-"--"---,,-- --"",,---" Jaried greatly to get average dogleg due to limited differential prs (hY POOH I Comments J c.!'.""~~~!?!c~ up~~~ D~".éi'l~ _ I &Jt To AIM=X', Res=X', GR=X', D&I=43', PWD=X', Dens=X', Nuet=X' BHA Weight Bit Data Tool Hrs. In Hrs. Out Dry Wt 10.694 IADC # Motor 32.2 37.5 Buoyed Wt 9.130 Footage 584 Jars 77.9 81.3 /nc/ Angle Hrs 3.4 Bit #1 22.9 26.3 Buoy+/ncl Wt 9.130 k Revs 16 k 5.3 Grade not graded Comment rerun in next BHA on this well Schlumberger BHA# 2 Job # 40007658 Date In 09-Jun-02 Date Out 10-Jun-02 Hole Size 16 Customer BP ADW Time In 5:00 Time Out 18:30 Hole Sect Surface Well NS-12 Depth In 785 Depth Out 3647 Bha Type Steerable Field Northstar TVD In 784 TVD Out 3218 Hrs BRT 37.5 I Rig Nabors 33E Drlg Hrs 17.2 Drlg Ft 2862 Avg ROP 166 AFE# 831317 Slide Hrs 5.0 Slide Ft 682 Slide ROP 136 DD's Tunnell / Bosse Rot Hrs 12.3 Rot Ft 2180 RotROP 177 Co. Men Polya / Dinger Pump Hrs 24.5 Rotate % 76 Slide % 24 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 6.00 Az In 52.30 BibSrvy 67.7 PDM Ser# 962-1126 Stages 3.0 Bearing Mud InclOut 36.70 Az Out 74.32 T/F Corr 23.6 PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM100D Avg Dls 2.7 Max Ds 5.3 Plan Dls 2.5 I Mud Type Sea H20 Spud Mud Wt 9 Sand % 1.5 RPM 50 GPM 770 SPP On 1520 BHT F Mud Vis 82 Solids % 3.5 Dig TQ 10.0 WOB 30 SPP Off 1360 Item Oest;tlptiøn . Vendor, SIN "'··00 ID Stab 00 0, F.N.' Connections, , Length/. \Çuìn Length Bit #1 MX-C1 I TFA=1.031 HUÇ)hes X27DP 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std PDM 1.83° 75/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 I 3 MONEL LC 6 5/8 H-90 P Ana 10-HA-011 8 2 13/16 6 5/8 H-90 B 9.69 37.04 MONELLC 6 5/8 H-90 P 4 Ana 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 B 9.96 47.00 5 MONEL STAB 6 5/8 H-90 P Ana HA-016 8 2 7/8 15 7/8 2,35 65/8 H-90 B 5.60 52.60 6 MWD 6 5/8 H90 P I Ana 173 8 1/4 3 1/4 1.52 6 5/8 H90 B 29.18 81.78 7 Orienting Sub 6 5/8 H-90 P Ana GLDD-105 8 2 3/4 6 5/8 H-90 B 1.46 83.24 8 MONEL STAB 6 5/8 H-90 P I Ana HA-012 8 2 7/8 15 7/8 2,12 6 5/8 H-90 B 5,25 88.49 9 MONEL DC 6 5/8 H-90 P Ana NMDC-HA-02:: 8 1/16 2 13/1 6 6 5/8 H-90 B 30,83 119.32 I 10 MONEL DC 6 5/8 H-90 P Ana NMDC-HA-01ï 8 2 13/16 6 5/8 H-90 B 30,84 150.16 MONEL STAB 6 5/8 H-90 P 11 Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 155.65 I 12 MONEL DC 6 5/8 H-90 P corrosion ring Ana NMDC-HA-01 E 7 3/4 2 13/1 6 6 5/8 H-90 B 30.57 186.22 13 HYDJARS 6 5/8 H90 P DAILEY 1417-1121 7 9/16 3 1.20 4 1/2 IF B 30.95 217.17 14 26 Jts. HWDP 5" 4 1/2 IF P NAD 26 HWDP 5 3 4 1/2 IF B 786.47 1003.64 15 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 1003.64 II I II I BHA and Run Objective D!~~~~uri~~:_~~~~_~.:~:L~99._~u~_~,________ BHA Weight IBHA and Run Results I ~ood ~,_~f9."~d!,~________ BUO~.~ :: ~~:~~~ I yielded 3.3 degree doglegs Incl Angle 36 I Why POOH I Commenø l~ach_~~~!~_~_p_~L~!___________._________,__,_,._" Buoy+lncl Wt 49,464 I Bit To AIM=X', Res=X', GR=65.76'. 0&1=67.75', PWD=X', Dens=X'. Nuet=X' Bit Data IADC # Footage 2862 Hrs 17.2 k Revs 116 k Grade 2-3-WT-A-E-I-RG-TD Comment DO NOT RERUN Tool Motor Jars Bit #1 Hrs. In 37.5 81.3 26.3 Hrs. Out 62.0 98S 43.5 24.5 Schlumberger BHA# 3 Job # 40007658 Date In 13-Jun-02 Date Out 13-Jun-02 Hole Size 12 1/4 Customer BP ADW Time In 0:01 Time Out 22:30 Hole Sect Intermediate Well NS-12 Depth In 3647 Depth Out 4402 Bha Type RSS Field Northstar TVD In 3217 TVD Out 3846 Hrs BRT 22.5 Rig Nabors 33E Drlg Hrs 3.5 Drlg Ft 755 Avg ROP 216 AFE# 831317 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DD's TunnelV Robertson Rot Hrs 3.5 Rot Ft 755 Rot ROP 216 Co. Men Polya / Dinger Pump Hrs 12.9 Rotate % 1 00 Slide % 0 I PDM Run # R/S PDM Jet Inclln 36.70 Az In 74.32 BibSrvy 38.2 PDM Ser# Stages Bearing InclOut 31.74 Az Out 71.02 T/F Carr PDM Size Rev/Gal Rubber Avg Dls 0.6 Max Ds 0.8 Plan Dls Mud Type Polymer Mud Wt 8.7 Sand % .25 RPM 140 GPM 900 SPP On 1800 , BHT F Mud Vis 52 Solids % 1.4 Dig TQ 12.0 WOB 10 SPP Off 1800 Item ~c"lpt¡ºn Vejjdor SIN, ID, Stab 00 F~M Conl1êCt¡on,~ Lengt1iV: <:ÇumL.Øngrh #2 RS238H F+GS ( TFA=.941 Hycalog 202929 12 1/4 3x11,6x12 65/8 Reg P 1.00 1.00 2 PO Bias Unit 6 5/8 Reg B Ana 90107 9 5/16 Tool 1.66 NC 70 B 3.21 4.21 3 PD Extention Sub NC 70 P I Ana 90071 9 1/4 Tool 7 5/8 Reg P 1.31 5.52 4 PO Control Collar 7 5/8 Reg B Control Unit 223 Ana 90031 9 3/16 Tool 2.32 6 5/8 Reg B 10.07 15.59 I 5 XO FLOAT SUB 6 5/8 Reg P *float* Ana GLDD117 8 2 13/16 6 5/8 H90 B 1.97 17,56 6 MONEL STAB 65/8 H-90 P Ana HA-013-SB 8 2 7/8 12 1/8 2.45 6 5/8 H-90 B 5.44 23,00 I 7 MWD 6 5/8 H90 P Ana 173 8 1/4 3 1/4 1.52 6 5/8 H90 B 29,18 52,18 8 MONEL STAB 6 5/8 H-90 P I Ana HA-017-SB 8 2 7/8 12 3/16 2.40 65/8 H-90 B 5.49 57.67 9 MONEL DC 6 5/8 H-90 P Ana NMDC-HA-02:: 8 1/16 2 13/16 6 5/8 H-90 B 30.83 88,50 I ' 10 MONEL DC 65/8 H-90 P Ana NMDC-HA-01ï 8 2 1 3/16 65/8 H-90 B 30.84 119,34 MONEL STAB 6 5/8 H-90 P 11 Ana HA-002-SB 8 2 7/8 11 7/8 2.40 65/8 H-90 B 5,55 124,89 12 MONEL DC 6 5/8 H-90 P *corrosion ring* Ana NMDC-HA-01€ 7 3/4 2 1 3/16 65/8 H-90 B 30.57 155.46 13 Downhole filter Sub 6 5/8 H90 P I ' Filter Ana DFS-HA-300 8 1/4 5 1/4 6 5/8 H90 B 3.12 158.58 14 HYDJARS 6 5/8 H90 P DAILEY 1417-1121 7 9/16 3 1.20 41/21FB 30.95 189.53 15 26 Jts. HWDP 5" 4 1/2 IF P I ' NAD 26 HWDP 5 3 4 1/2 IF B 786.47 976.00 16 Dart Valve Sub 4 1/2 IF P ,I BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 978.37 17 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 978.37 I 'I I BHA and Run Objective Drill to short trip point at 8100' BHA Weight Bit Data Tool Hrs. In Hrs. Out . ~. .. .__' ._..'~"'.. ,__.__..___..".._.___ _.__.._._._ _h .... I BHA and Run Results Dry Wt 65,217 IADC # Motor 12.9 Buoyed Wt 56,574 Footage 755 Jars 98.5 102.0 -~ - ----- - ------ - - ---------~----_.- I Incl Angle 34 Hrs 3.5 Bit#2 3.5 I Why POOH / Comments I T ~p fO~f>0"'erCJrì\le failure._______ __ 8uoy+/ncl WI 46,902 k Revs 29 k RSS 0.0 12.9 Grade O-O-CT-G-X-I-BT-DTF I Bit To AIM=X'. Res=X', GR=36.16', PWD=X'. D&I=38.16'.GR=X'. Dens=X'. Nuet=X' Comment Schlumberger BHA# 6 Job # 40007658 Date In 21-Jun-02 Date Out 24-Jun-02 Hole Size 8 1/2 Customer BP ADW Time In 15:00 Time Out 18:00 Hole Sect Intermediate Well NS-12 Depth In 11520 Depth Out 1 31 35 Bha Type Steerable Field Northstar TVD In 9574 TVD Out 10897 Hrs BRT 75.0 I Rig Nabors 33E Drlg Hrs 29.2 Drlg Ft 161 5 Avg ROP 55 AFE # 831317 Slide Hrs 14.2 Slide Ft 310 Slide ROP 22 DD's Rinke Rot Hrs 15.0 Rot Ft 1305 Rot ROP 87 Co. Men Dingerl Smith Pump Hrs 47.5 Rotate % 81 Slide % 19 PDM Run # 3 R/S 7/8 PDM Jet Blk Inclln 32.22 Az In 117.24 Bit>Srvy 63.7 PDM Ser# 675-3557 Stages 5.0 Bearing Mud InclOut 35.48 Az Out 125.83 T/F Carr 216.0 PDM Size 6 3/4 Rev/Gal 0.300 Rubber RM100D Avg Dls 0.9 Max Ds 1,9 Plan Dls , Mud Type KCUPolymer Mud Wt 12.4 Sand % .25 RPM 80 GPM 550 SPP On 2900 BHT F 176 Mud Vis 60 Solids % 12.9 Dlq TQ 19.0 WOB 15 SPP Off 3200 Item Description Vendor SIN 00, ID StabOD ' F.N. Connections Length Cum Length Bit #3 FS2653 , TFA .902 Security 5013584 8 1/2 6X14 4 1/2 Reg P 1.15 1.15 2 63/4 XP 1.15° 4 1/2 Reg B Ana 675-3557 6 3/4 Tool 8 3/8 4 1/2 XH B 25.25 26.40 , 3 FLOAT SUB 41/2 XH P Float Ana GLDD015 6 15/16 2 15/16 41/2XH B 1.67 28.07 COR (PWD) 41/2XH P 4 Ana 7125 6 3/4 Tool 11,91 5 1/2 FH B 21.87 49.94 I 5 MWD 5 1/2 FH P Ana Y712 6 3/4 Tool 1,68 4 1/2 XH B 27.86 77.80 6 NM XO 4 1/2 XH P Ana LWD-BA-259 6 15/16 3 5 1/2 FH B 1.58 79,38 7 Downhole filter Sub 5 1/2 FH P Ana CB-028-JS 6 13/1 6 2 3/8 4 1/2 XH B 2.76 82.14 8 NM STABILIZER 4 1/2 XH P , Totco Ana IMSZSS-FA 01 6 3/4 2 13/16 8 1/2 2.45 4 1/2 XH B 5,62 87.76 9 NM FLEX 4 1/2 XH P Ana MMFL-FA 014 6 11 /16x5 2 13/16 2.50 4 1/2 XH B 31.02 118,78 I 10 NM FLEX 4 1/2 XH P Ana MMFL-FA 016 6 3/4x 5 2 13/16 2.50 4 1/2 XH B 31.01 149,79 11 NM FLEX 4 1/2 XH P Ana MMFL-FA 021 6 3/4x 5 2 13/16 2,50 4 1/2 XH B 31.02 180.81 12 X-OVER 4 1/2 XH P "corrosion ring" Ana :>TXOS-FE 104: 6 3/4 2 3/4 4 1/2 IF B 1.98 182.79 13 3 Jts HWDP 4 1/2 IF P NAD (3) 5" HWDP 5 3 4 1/2 IF B 91.53 274.32 14 HYDJARS 4 1/2 IF P DAILEY 1416-1574 6 1/2 2 3/4 1.69 4 1/2 IF B 32.63 306.95 15 23 Jts HWDP 41/21FP NAD (23) 5" HWDP 5 3 4 1/2 IF B 694.94 1001.89 16 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 1004.26 17 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 1004.26 I \ BHA and Run Objective Bit Data IADC # Footage 1615 Hrs 29.2 k Revs 361 k Grade 1 -1-CT-A-X-IN-LN-TD \ Bit To AIM=X', Res=33.43', GR=44.43', D&I=63.69',MWD GR=61.70 PWD=35.18', Dens=X', Nuet=-Comment Drill to TO holding angle .....,,'_._...,_,,~.___ __..,,_ "'" ...... _.'u._ _._,_.____. ._,,~ -""~,.....,,-,- ....--. BHA Weight Dry Wt 20.609 Buoyed Wt 16,716 Incl Angle 33 Buoy+lncl Wt 14,020 Tool Motor Jars Bit #4 Hrs. In 94.1 147,1 25.1 Hrs. Out 141,6 176.3 54.3 47,5 BHA and Run Results turned right 1/100 Why POOH I Comments ~_~~PP~9,har~_uE__t~__1_:~!.2g~_~!l.9________, __,_ TD BHA #: 1 Slide Sheet Client: BP Exploration Alaska Well: NS12 Directional Driller: James Tunnell Field: Northstar Borehole: NS 12 Directional Driller: Jeroen Bosse Structure: Northstar PF UWVAPI#: Job #: Depth In: 201.00 Depth Out: 785.00 Tot Distance: 584.00 Total Time: 3.3 Inclination In: 2.00 Inclination Out: 5.97 Dist Steering: 319.00 % Steer: 54.6 Time Steering: 2,0 % Steer: 59.1 Azimuth In: 1.83 Azimuth Out: 52.54 Dist Rotating: 265.00 % Rot: 45.4 Time Rotating: 1.4 % Rot: 40.9 I Total ROP: 177.0 Steering ROP: 163.6 Rotating ROP: 196.3 Comments: I Rot/Slid I Duration I Md From I Md To I TF I Flow ISPP On BISPP Off , WOB I RPM forq on, Svy Md I Incl Azmth Comment I (R/S) (hr:min) (ft) (ft) (0) (gal/min) (psi) (psi) (1000 Ibf) (c/min) KJ ftlbs (0) (0) R 0:10 201.00 230.00 500 360 360 2.0 30 2 S 0:04 230.00 240.00 M 120 500 380 350 5.0 0 0 S 0:14 240.00 291.00 M 120 500 430 400 8.0 0 0 264.00 2. 00 1.83 R 0:02 291.00 300.00 500 415 400 5.0 35 2 292.00 2.02 11.13 R 0:03 300.00 310.00 500 390 370 7.0 35 2 S 0:08 310.00 330.00 M 180 500 390 380 5.0 0 0 324.00 1.03 49.72 I s 0:13 330.00 363.00 M 190 500 450 400 8.0 0 0 354.00 0.97 69.61 R 0:12 363.00 393.00 500 425 400 5.0 40 2 382.00 1.29 87.72 S 0:09 393.00 418.00 M 160 500 475 425 10.0 0 0 414.00 2.29 135.66 S 0:09 418.00 451.00 M180 500 545 480 15.0 0 0 445.00 2.64 153.94 1 R 0:14 451.00 481.00 500 550 480 8.0 40 3 473.00 2.49 132.50 S 0:15 481.00 512.00 M60 510 575 480 17.0 0 0 S 0:06 512.00 530.00 M60 600 770 670 15.0 0 0 R 0:22 530.00 580.00 600 750 670 10.0 40 3 561.00 3.06 106.54 S 0:10 580.00 603.00 M60 600 710 650 8.0 0 0 very little differential S 0:07 603.00 620.00 M60 600 780 720 17.0 0 0 R 0:09 620.00 670.00 600 745 720 12.0 45 4 651.00 4.19 84.39 I s 0:14 670.00 693.00 M60 600 770 720 18.0 0 0 last 10ft very little differential S 0:08 693.00 728.00 M60 600 800 720 18.0 0 0 R 0:09 728.00 785.00 600 775 720 12.0 45 4 NS 12 Bha·s.xls Page 1 of 1 7/30/02-10:58 AM I Comments: BHA #: 2 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Depth In: 785.00 Inclination In: 6.29 Azimuth In: 62.72 Depth Out: 3647.00 Inclination Out: 36.70 Azimuth Out: 74.32 I Rot/Slid I Duration I Md From I (RIS) (hr:min) (ft) S 0:04 785.00 R 0:03 800.00 S 0:10 821.00 R 0:09 871.00 S 0: 10 909.00 I I Total ROP: 166.2 Slide Sheet Well: NS12 Borehole: NS12 UWVAPI#: Directional Driller: James Tunnell Directional Driller: Jeroen Bosse Job #: Tot Distance: 2862.00 Dist Steering: 682.00 % Steer: 23.8 Dist Rotating: 2180.00 % Rot: 76.2 Steering ROP: 137.3 Total Time: 17.2 Time Steering: 5.0 Time Rotating: 12.3 % Steer: 28.8 % Rot: 71.2 Rotating ROP: 178.0 MdTo I (ft) 800.00 821.00 871.00 909.00 954.00 I Flow ISPP On BlSPP Off BI WOB I (gaVmin) (psi) I (psi) 1(1000 Ibf) 650 1020 970 15.0 650 1050 970 15.0 650 1050 950 20.0 650 1050 950 20.0 650 1100 1000 20.0 RPM trorq on, Svy Md I (c/min) I K/ ftlbs o 0 40 5 810.00 o 0 40 5 900.00 o 0 G-25 R S R S S 0:07 954.00 1000.00 0:12 1000.00 1050.00 G 30 0:08 1050.00 1095.00 0:08 1095.00 1122.00 G-3O 0:07 1122.00 1135.00 G -20 R S R S S 0:37 1135.00 1190.00 0:23 1190.00 1230.00 G ·30 0:22 1230.00 1286.00 0:05 1286.00 1296.00 G ·30 0:31 1296.00 1346.00 G -30 R S R S R 0: 13 1346.00 1380.00 0:35 1380.00 1440.00 G ·24 0:16 1440.00 1474.00 0:49 1474.00 1534.00 G -30 0:22 1534.00 1568.00 S R S R S 0:13 1568.00 1598.00 G -10 0:17 1598.00 1663.00 0:16 1663.00 1698.00 G 15 0:17 1698.00 1758.00 0:11 1758.00 1798.00 G 10 R S R S R 0:12 1798.00 1853.00 0:08 1853.00 1888.00 GO 0:14 1888.00 1947.00 0:12 1947.00 1985.00 G 10 0:13 1985.00 2042.00 R S R R S 0:21 2042.00 2137.00 0:11 2137.00 2160.00 G -90 0:34 2160.00 2233.00 0:29 2233.00 2329.00 0: 10 2329.00 2354.00 G ·5 R R S R R 0:20 2354.00 2424.00 0:29 2424.00 2520.00 0: 16 2520.00 2542.00 G -45 0:24 2542.00 2615,00 0:34 2615.00 2710,00 R R 0:34 2710.00 2804.00 0:29 2804.00 2900,00 NS12 Bha's,xls TF (0) G60 G60 650 650 650 650 650 650 650 650 650 650 650 650 650 650 650 650 650 650 700 700 700 730 730 800 800 800 800 800 800 780 780 780 800 780 800 780 780 1100 1100 1100 1100 1150 1200 1200 1150 1150 1150 1200 1150 1150 1150 1150 1050 1150 1080 1170 1170 1170 1300 1300 1450 1425 1550 1435 1500 1500 1375 1400 1400 1525 1400 1450 1400 1450 1030 1030 1030 1030 1095 20.0 20.0 20.0 20.0 25.0 1095 1100 1050 1050 1050 20.0 35.0 30.0 35.0 35.0 1100 1050 1050 1050 1050 30.0 35.0 30.0 35.0 30.0 950 1050 960 1100 1100 28.0 30.0 22.0 30.0 25.0 1100 1200 1200 1380 1380 15.0 25.0 20.0 22.0 12.0 1400 1400 1400 1400 1300 25.0 30.0 25,0 20.0 25.0 1300 1300 1400 1300 1400 25.0 28.0 28.0 25.0 30,0 1300 1350 25,0 20,0 Page 1 of 2 Incl I Azmth I (0) (0) Comment 6.29 62.72 8.30 74.18 40 o 40 o o 5 1000.00 o 5 o 1100.00 o 11.12 74.42 14.33 78.98 Lost high line power 40 o 40 o o 5 o 1219.00 16.82 6 o o 1314.00 19.11 77.64 Enter Permafrost 75.50 40 o 40 o 40 6 1378.00 20.77 o 1406.77 21.73 8 o 1499.46 23.78 9 74.79 75.24 Run final Gyro 73.98 o 40 o 40 o o 1593.53 26.46 71.75 8 o 1689.15 28.50 73.63 8 o 1784.21 31.20 74.52 40 o 40 o 45 6 o 1878.64 34.02 74.19 8 o 1972.89 36.51 75.50 7 45 o 45 40 o 8 2068.22 36.81 76.44 o 8 2163.28 37.18 73.87 7 2259.12 36.32 74.32 o 48 50 o 50 50 82354.10 37,10 74.57 8 2450,91 36.47 75.15 o 8 2546.33 37.79 74.29 9 2640,79 37.28 73.95 50 48 7 2735.60 8 2830.48 74.77 74.50 37.04 37.01 7/30/02-10:59 AM 7/30/02-10:59 AM Page 2 of 2 NS 12 Bha's.xls 1 ( S 0:07 2900.00 2914.00 G-10S 780 1460 1400 20.0 0 0 R 0:33 2914.00 2995.00 _n 780 1425 1400 25.0 45 8 2926.39 36.66 73.03 R 0:38 2995.00 3090.00 ..- 780 1450 1350 25.0 40 8 3021.00 36.32 73.57 R 0:23 3090.00 3186.00 --- 780 1500 1400 25.0 45 9 3114.91 36.30 74.12 R 0:22 3186.00 3281.00 ..- 780 1470 1400 15.0 45 9 3211.39 37.05 73.40 R 0:23 3281.00 3375.00 --- 780 1500 1400 25.0 50 9 3305.02 37.48 73.52 R 0:24 3375.00 3470.00 --- 780 1500 1360 25.0 50 9 3401.42 37.58 72.32 I R 1:01 3470.00 3564.00 -.. 780 1500 1360 25.0 50 10 3494.74 37.51 73.92 3578.06 36.70 74.32 R 0:47 3564.00 3647.00 --- 780 1520 1360 35.0 50 10 3647.00 36.70 74.32 TO 16" hole I BHA #: 3 I Slide Sheet Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Well: NS12 Borehole: NS12 UWVAPI#: Depth In: 3647.00 Inclination In: 35.75 Azimuth In: 74.50 1 Comments: I I Rot/Slid I Duration I Md From I (A/S) (hr:min) (ft) A 0:21 3647.00 A 0:08 3667.00 A 0: 19 3680.00 A 0:20 3735.00 A 0:26 3831.00 I Depth Out: 4402.00 Inclination Out: 31.81 Azimuth Out: 71.02 Tot Distance: 755.00 Dist Steering: 0.00 Dist Rotating: 755.00 Directional Driller: James Tunnell Directional Driller: Alan Aobertson Job #: % Steer: 0.0 % Rot: 100.0 Rotating ROP: 217.8 RPM lTorq on, Svy Md I (c/min) I K/ ftlbs 100 9 100 9 140 10 3696.32 140 10 3791.30 140 10 3886.53 A 0:43 3920.00 4022.00 840 1430 1400 10.0 140 11 3982.97 A 0:17 4022.00 4117.00 840 1430 1400 10.0 140 11 4076.39 A 0:28 4117.00 4212.00 900 1600 1600 10.0 140 11 4172.37 A 0:10 4212.00 4290.00 900 1600 1600 10.0 140 11 4267.35 A 0:03 4290.00 4307.00 900 1600 1600 10.0 140 12 1 A 0:13 4307.00 4402.00 900 1600 1600 10.0 140 13 4362.63 I 1 NS12 Bha·s.xls Total ROP: 217.8 Steering ROP: 0.0 Md To I (ft) 3667.00 3680.00 3735.00 3831.00 3920.00 I Flow ISPP On BISPP Off , WOB I (gaVmin) (psi) (psi) (1000Ibf) 720 1150 1150 5.0 720 1100 1100 8.0 770 1200 1200 10.0 840 1400 1400 10.0 840 1400 1350 10.0 TF (0) Page 1 of 2 Total Time: 3.5 Time Steering: 0.0 Time Rotating: 3.5 % Steer: 0.0 % Rot: 100.0 Incl Azmth Comment (0) (0) F.l.T test Change shaker sreeens 35.75 74.50 ASS set at neutral 35.11 73.83 34.38 73.92 RSS set at 36@20% 33.86 72.98 Bit balled up 33.36 72.68 45@60% 32.88 72.40 36@100% 32.31 71.9236@100% 341 @100% 341@100% Tool failed 31.81 71.02 7/30/02-10:59 AM 7/30/02-10:59 AM Page 1 of 1 NS 12 Bha's.xls ! ¡ Bh :HA #: 4 Slide Sheet Client: BP Exploration Alaska Well: NS12 Directional Driller: James Tunnell Field: Northstar Borehole: NS 12 Directional Driller: Alan Robertson Structure: Northstar PF UWIIAPI#: Job #: Depth In: 4402.00 Depth Out: 8216.00 Tot Distance: 3814.00 Total Time: 19.1 Inclination In: 32.84 Inclination Out: 36.33 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 72.42 Azimuth Out: 72.47 Dist Rotating: 3814.00 % Rot: 100.0 Time Rotating: 19.1 % Rot: 100.0 Total ROP: 199.3 Steering ROP: 0.0 Rotating ROP: 199.3 Comments: I Rot/Slid I Duration I Md From I Md To I TF I Flow ISPP On ,SPP Off' WOB I RPM forq on, Svy Md I Incl I Azmth I Comment (RIS) (hr:min) (It) (It) (0) (gaVmin) (psi) (psi) (1000 Ibf) (elmin) K/ Itlbs (0) (0) R 0:21 4402.00 4496.00 --- 900 1800 1800 10.0 140 13 4455.24 32.84 72.42 0@60% R 0:13 4496.00 4591.00 _n 900 1800 1800 10.0 140 14 4551.61 34.65 73.47 0@60% R 0:14 4591.00 4688.00 --- 900 1800 1800 10.0 140 14 4648.22 37.07 73.92 0@60% R 0:12 4688.00 4783.00 _n 900 1800 1800 10.0 140 14 4745.52 38.82 75.20 0@60% R 0:15 4783.00 4880.00 --- 900 1800 1800 10.0 140 15 4838.95 39.57 74.99 O@O R 0:15 4880.00 4973.00 .-- 900 1850 1850 10.0 140 15 4933.20 39.27 73.88 O@O A 0:20 4973.00 5067.00 _n 900 1950 1950 10.0 140 15 5027.17 38.97 72.94 O@O A 0:29 5067.00 5163.00 --- 900 2050 2050 10.0 140 14 5122.77 38.31 73.39 O@O A 0:28 5163.00 5258.00 .-. 900 2050 2050 10.0 140 15 5217.81 37.60 72.560@0 R 0:21 5258.00 5354.00 _n 900 2050 2050 10.0 140 15 5314.56 37.73 72.85 36/20% A 0:34 5354.00 5449.00 _n 900 2050 2050 10.0 140 15 5408.47 37.59 74.07 36/20% R 0:29 5449.00 5544.00 _n 900 2050 2050 10.0 140 15 5504.77 37.43 74.97 36/20% R 0:33 5544.00 5639.00 n_ 900 2050 2050 10.0 140 14 5600.10 37.26 75.69 36/20% R 0:31 5639.00 5735.00 --- 900 2050 2050 10.0 140 15 5694.37 36.93 76.85 36/20% A 0:23 5735.00 5828.00 -- 900 2100 2100 10.0 140 16 5787.77 36.89 78.05 36/20% R 0:21 5828.00 5923.00 --- 900 2100 2100 10.0 140 16 5881.50 36.94 78.1236/20% A 0:15 5923.00 6019.00 -.. 900 2150 2150 10.0 140 16 5977.40 36.92 78.66 36/20% A 0:27 6019.00 6113.00 .-- 900 2150 2150 10.0 140 16 6071.92 36.58 78.62254@20% R 0:23 6113.00 6207.00 .n 900 2150 2150 10.0 140 16 6166.17 36.26 77.20254@20% R 0:22 6207.00 6302.00 _n 900 2150 2150 10.0 140 16 6267.04 35.80 75.99 254@20% R 0:02 6302.00 6308.00 --- 900 2150 2150 10.0 140 16 Add Non-rotating stab R 0:22 6308.00 6403.00 .-. 900 2150 2150 10.0 140 16 6361.56 35.45 74.71 254@20% A 0:59 6403.00 6498.00 --- 900 2150 2150 10.0 140 17 6456.93 35.05 74.38 326/20% R 0:27 6498.00 6592.00 _n 900 2250 2250 10.0 140 18 6551.19 35.09 73.48 326/20% A 0:38 6592.00 6688.00 _n 900 2250 2250 10.0 140 18 6646.01 35.26 73.07 326/20% A 0:21 6688.00 6783.00 --- 900 2250 2250 10.0 140 18 6741.12 35.40 72.20 326/20% A 0:40 6783.00 6879.00 _n 900 2250 2250 10.0 140 18 6837.15 35.67 72.24 326/20% R 0:23 6879.00 6973.00 .-. 890 2250 2250 10.0 140 18 6930.94 35.48 72.06 0/20% A 0:46 6973.00 7068.00 _n 900 2250 2250 10.0 140 18 7028.78 35.67 72.55 0/20% R 0:57 7068.00 7164.00 .n 900 2250 2250 10.0 140 18 7125.14 35.96 72.46 0/20% R 0:36 7164,00 7259.00 ... 900 2400 2400 14.0 140 18 7219.37 36.27 72,99 0/20% R 0:24 7259,00 7354.00 .-- 900 2400 2400 14.0 140 18 7315.21 36.26 72.62 0/20% R 0:34 7354.00 7448.00 _e. 900 2400 2400 15.0 140 20 7409.58 36.27 72.92 0/20% R 0:26 7448.00 7543.00 _n 900 2400 2400 15.0 140 22 7503.64 36.19 72,68 0/20% R 0:30 7543.00 7645.00 --. 900 2400 '2400 15.0 140 23 7606,55 36.30 73.44 Add Non-rotating stab R 0:35 7645.00 7740.00 _n 900 2400 2400 15.0 140 23 7701.14 36.31 72.87 0/20% R 0:26 77 40.00 7836.00 n_ 900 2400 2400 15.0 140 22 7797.21 36.42 72.72 0/20% R 0:31 7836.00 7931.00 --- 900 2400 2400 15.0 140 22 7892.49 36.40 72.89 0/20% R 0:38 7931.00 8027.00 n_ 900 2450 2450 15.0 140 22 7988.16 36.48 72.79 0/20% R 0:43 8027,00 8121.00 ... 900 2450 2450 15.0 140 22 8081.68 36,32 72. 56 0/200~ R 0:44 8121.00 8216.00 --. 900 2450 2450 15.0 140 22 0/20°'0 Trip to wipe hole 7/30/02-10:59 AM Page 1 of 1 NS12 Bha's,xls BHA #: 5 Slide Sheet r Client: BP Exploration Alaska Well: NS12 Directional Driller: James Tunnell Field: Northstar Borehole: NS 12 Directional Driller: Alan Aobertson Structure: Northstar PF UWVAPI#: Job #: Depth In: 8216.00 Depth Out: 11520.00 Tot Distance: 3304.00 Total Time: 36.8 Inclination In: 36.75 Inclination Out: 33.00 Dist Steering: 0.00 % Steer: 0,0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 72.53 Azimuth Out: 120.00 Dist Rotating: 3304.00 % Rot: 100.0 Time Rotating: 36.8 % Rot: 100.0 Total ROP: 89.7 Steering ROP: 0.0 Rotating ROP: 89.7 Comments: I Rot/Slid I Duration I Md From I Md To I TF I Flow ISPP On ,SPP Off , WOB I RPM forq on, Svy Md I Incl I Azmth I Comment I (A/S) (hr:min) (ft) (ft) (0) (gal/min) (psi) (psi) (1000Ibf) (c/min) K/ ftlbs (0) (0) A 0:14 8216.00 8231.00 _a. 900 2650 2650 8.0 130 19 0/40% A 1:38 8231.00 8325.00 _u 900 2550 2550 15.0 140 21 8263.13 36.75 72.53 0/40% A 0:53 8325.00 8420.00 _u 900 2850 2850 15.0 140 23 8356.86 37.88 73.61 0/40% A 0:50 8420.00 8515.00 ..- 900 2850 2850 15.0 140 23 8453.06 38.55 73.63 36/20% A 0:47 8515.00 8611.00 .n 900 2850 2850 15.0 140 22 8549.15 38.64 75.11 36/20% A 0:54 8611.00 8712.00 .n 900 2900 2900 15.0 140 23 8650.64 38.43 76.21 Add Non-rotating stab ( A 0:49 8712.00 8807.00 ..- 900 3000 3000 15.0 140 22 8743.96 38.48 77.13 36/20% A 0:53 8807.00 8902.00 --- 900 2950 2950 15.0 150 22 8838.75 38.25 77.91 0 / 0% R 'U:47 8902.00 8998.00 -.- 900 3000 3000 15.0 150 22 8933.86 37.56 78.21 0 / 0% A 0:54 8998.00 9093.00 --- 900 3000 3000 15.0 150 23 9031.95 36.74 78.92 0 / 0% A 0:57 9093.00 9189.00 -_. 900 3050 3050 15.0 150 23 9127.05 36.13 78.89 289/20% R 0:51 9189.00 9285.00 ..- 900 3050 3050 15.0 150 22 9224.48 35.66 79.52 289/20% Add EP Lube R 0:57 9285.00 9388.00 -.- 900 2900 2900 15.0 150 20 9327.23 35.59 79.08315/40% Add Non-rotat stab R 0:59 9388.00 9483.00 --- 900 2900 2900 15.0 150 20 9421.71 36.36 78.40 315/40% I R 0:45 9483.00 9578.00 --- 900 2900 2900 15.0 150 20 9516.58 37.15 77.00 315/40% R 0:56 9578.00 9673.00 -- 900 2850 2850 15.0 150 20 9612.74 37.80 76.36315/40% R 1:08 9673.00 9768.00 --- 900 2850 2850 15.0 150 20 9707.07 38.62 75.87 315/40% ( R 1:02 9768.00 9863.00 --- 900 2850 2850 15.0 150 20 9802.20 38.67 74.82 0/0 R 1:10 9863.00 9958.00 --- 900 2900 2900 15.0 150 20 9897.86 37.60 74.27 0/0 R 0:50 9958.00 10052.00 .-- 900 3000 3000 20.0 150 20 9996.29 36.13 74.930/0 R 0:03 10052.00 10058.00 --- 900 3050 3050 20.0 150 20 0/0 Pick up NR stab R 0:45 10058.00 10154.00 --- 900 3050 3050 20.0 150 21 10090.36 34.62 74.38 0/0 R 0:46 10154.00 10249.00 -- 900 3050 3050 20.0 150 21 10186.74 32.90 75.58 45/40% R 0:47 10249.00 10344.00 --- 900 3100 3100 20.0 150 21 10280.58 32.59 77.89 No joy 23/40% R 0:56 10344.00 10440.00 --- 900 3200 3200 20.0 150 21 10376.37 33.24 81.84 22/60% R 0:50 10440.00 10535.00 --. 900 3200 3200 20.0 150 21 10472.76 34.41 85.51 22/60% R 0:42 10535.00 10630.00 --- 900 3200 3200 20.0 150 21 10566.07 35.22 89.09 22/40% R 1:09 10630.00 10732.00 --- 900 3250 3250 20.0 150 22 10668.18 35.85 91.51 22/40% PU NR Stab R 1 :29 10732.00 10826.00 --- 900 3350 3350 15.0 150 19 10763.43 36.02 93.01 22/40% HRZ R 0:54 10826.00 10868.00 --- 900 3500 3500 15.0 150 19 10859,54 36.15 93.90 22/40% R 1:13 10868.00 10921.00 --- 900 3500 3500 15.0 150 19 22/40% R 1:44 10921.00 11015.00 _n 900 3500 3500 15.0 150 20 10954.85 36.81 97.30 39/80% R 1:03 11015.00 11110.00 --- 900 3500 3500 15.0 150 20 11049.73 37.64 102.86 39/80% R 2:06 11110.00 11204.00 --- 900 3550 3550 20.0 150 22 11143.93 36.83 105.7667/60% R 1:57 11204.00 11300.00 _n 900 3550 3550 20.0 150 23 11236.62 34.85 109.41 67/60% 11333.79 33.17 112.84 11424.28 32.27 117,20 R 1:14 11300.00 11455.00 __a 900 3550 3550 20.0 150 23 11454.42 32.20 117.64 60/80% R 0:34 11455.00 11489,00 --- 900 3550 3550 20.0 150 23 18/1 00% R 0:24 11489.00 11520,00 --- 900 3600 3600 20,0 150 23 18/ 1 00°'0 7/30/02-' 0:59 AM Page 1 of 1 NS12 Bha's.xls ·1 BHA #: 6 Slide Sheet Schlurnberger Client: BP Exploration Alaska Well: NS12 Directional Driller: Rinke Field: Northstar Borehole: NS 12 Directional Driller: Structure: Northstar PF UWUAPI#: Job #: I Depth In: 11520.00 Depth Out: 13135.00 Tot Distance: 1615.00 Total Time: 29.2 Inclination In: 32.96 Inclination Out: 35.48 Dist Steering: 310.00 % Steer: 19.2 Time Steering: 14.2 % Steer: 48.7 Azimuth In: 122.32 Azimuth Out: 125,83 Dist Rotating: 1305.00 % Rot: 80.8 Time Rotating: 15.0 % Rot: 51.3 Total ROP: 55.3 Steering ROP: 21.8 Rotating ROP: 87.2 Comments: I RotJSlid I Duration I Md From I Md To I Course I Avg ROP I TF I Flow ISPP On BISPP Off' WOB I RPM rorq on, Svy Md I Incl I Azmlh I DLS I (RlS) (hr:min) (ft) (ft) (ft) (ft/h) (0) (gal/min) (psi) (psi) (1000 Ibf) K/ ftlbs (ft) (0) (0) (0 / 1 00 ft) R 0:17 11520.00 11540.00 20.00 70.6 --- 500 2200 2050 9.0 75 26 R 0:40 11540.00 11556.00 16.00 24.0 --- 500 2550 2350 16.0 80 20 R 1 :07 11556.00 11651.00 95.00 85.1 --- 550 3050 2900 12.0 100 20 11621.30 32.96 122.32 1.29 I R 1:02 11651.00 11746.00 95.00 91.9 --- 550 3100 2900 12.0 100 20 11680.43 32.83 122.77 0.47 R 1:16 11746.00 11839.00 93.00 73.4 ... 550 3150 2900 15.0 80 20 11770.99 32.36 123.16 0.57 S 1:11 11839.00 11879.00 40.00 33.8 G -40 500 2500 2450 35.0 0 o 11866.52 33.22 123.06 0.90 R 0:25 11879.00 11934.00 55.00 132.0 ... 500 2750 2450 15.0 70 18 R 0:37 11934.00 12027.00 93.00 150.8 .-- 500 2800 2450 75 18 11960.92 33.49 123.59 0.42 S 2:35 12027.00 12052.00 25.00 9.7 G-30 550 2950 2900 45.0 0 0 R 0:06 12052.00 12070.00 18.00 180.0 .-. 520 2900 2600 20.0 75 18 12053.97 34.07 123.53 0.62 S 1 :40 12070.00 12100.00 30.00 18.0 G ·30 520 2700 2600 45.0 0 0 R 0:10 12100.00 12123.00 23.00 138.0 --- 520 2900 2600 15.0 75 17 R 0:46 12123.QO 12217.00 94.00 122.6 ... 520 2900 2600 15.0 75 17 12148.85 34.52 123.75 0.49 S 0:47 12217.00 12237.00 20.00 25.5 G-30 520 2800 2600 40.0 0 0 1 s 1 :22 12237.00 12277.00 40.00 29.3 G·30 520 2850 2650 45.0 0 o 12245.66 35.32 123.72 0.83 R 0:19 12277.00 12310.00 33.00 104.2 --- 520 3050 2650 17.0 90 17 R 1 :32 12310.00 12405.00 95.00 62.0 ... 520 3050 2650 20.0 90 17 12340.95 35.94 123.30 0.70 S 2:19 12405.00 12455.00 50.00 21.6 G ·30 520 2850 2650 45.0 0 18 12436.63 36.83 122.51 1.05 R 0:37 12455.00 12501.00 46.00 74.6 --. 520 3050 2650 20.0 90 18 R 0:41 12501.00 12596.00 95.00 139.0 -.. 520 3100 2700 20.0 100 18 12531.38 36.68 121.68 0.55 R 0:59 12596.00 12691.00 95.00 96.6 --. 520 3100 2700 20.0 100 18 12625.67 35.23 123.53 1.92 S 2:55 12691.00 12771.00 80.00 27.4 G -20 520 2850 2700 45.0 0 o 12720.30 36.07 124.13 0.96 R 0: 13 12771.00 12786.00 15.00 69.2 ... 520 3000 2700 15.0 120 18 R 1:18 12786.00 12881.00 95.00 73.1 .-. 520 3050 2750 15.0 120 18 12813.63 37.47 123.89 1.51 R 0:43 12881.00 12938.00 57.00 79.5 -.- 520 3100 2850 15.0 120 18 12911.23 36.26 124.35 1.27 S 1:25 12938.00 12963.00 25.00 17.6 GO 520 3050 2900 45.0 0 0 R 0:10 12963.00 12977.00 14.00 84.0 --- 520 3200 2900 20.0 90 18 13003.52 36.38 125.16 0.54 ----=~-1 Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS12 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR ?" inch at DRILLING SERVICES Rig: NABORS DRLG RIG 33E inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 22092 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out ftlhr % GRADE 1 1 MX-C1 X270P 16 1.031 201 785 584 3.4 172 45 16K 55 Not Graded 2 1 rr MX-C2 X270P 16 1.031 785 3647 2862 17.2 166 50 116K 24 2-3-WT -A-E-I-RG- TO 3 2 RS238HF+GS 202929 12.25 0.941 3647 4402 755 3.5 216 140 29 0 O-O-CT -G-X-I-BT -OTF 4 2rr RS238HF+GS 202929 12.25 0.941 4402 8216 3814 19.1 200 140 160K 0 O-O-CT -N-X-I-BT -BHA 5 2rr RS238HF+GS 202929 12.25 0.941 8216 11520 3304 36.8 90 150 331K 0 0-1-BT -N-X-I-WT - TO 6 4 FS2653 5013584 8.5 .902 11520 13135 1615 29.2 55 80 361K 19 1-1-CT-A-X-IN-LN-TO - ,--- Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS12 13,375" inch at 3631 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 11500 ft lease: NORTHST AR 7" inch at 13501 ft DRILLING SERVICES Rig: NABORS DRilLING RIG 33E inch at ft Mud Company: BAROID DRilLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22092 Depth MW Vis PV YP Gels Fltr HTHP Cake Sot Oil Water Sd CEC pH Pm I Pf/Mf Chlorides Calcium Comments Date ft Iblgal sec LB/100 10S110M mU30 ml@deg F 32's % % % % mgelhg ppm ppm Uti/U flU;¿ ;¿U1 1U.1 56 ;¿5 ;¿4 1 :$1:$41:$ ( (,4 ;¿ 1U.4 ;¿.U 67.ti U 1U.U 9.5 U.;¿O U.15/;¿.UU ;¿5UUU 14UU "prep to ~pua Uti/UIS/U;¿ 595 9.ti 144 ;¿1 4;¿ ;¿U/:$;¿¡:$ti IS.U ;¿ 6.~ 1.5 9U.U 1.(5 1;¿.U 9.1 U.Uti .111UU ;¿5UUU 1UO ùnlllng Uti/U9/U;¿ ;¿;¿:$:$ 9,U 6;¿ 16 45 ;¿5/3;¿¡U (.IS ;¿ 4,6 1.U 94.4 .75 U.U 8.9 U.UU U.Uti/1.;¿U ;¿UUUU 1UU '\mllmg Uti/1 U/U;¿ :$ti4( 9.1 55 15 ;¿9 14/;¿U/U 7.5 ;¿ 5.~ 1.U 9:$.5 .(5 5.U 1S.5 U.U4 .04IU.9U 19UUU ti4U "kunnmg \;8g Uti/1 1/U;¿ :$64/ 9.:$ 43 16 ;¿1 1;¿f;¿1/;¿:$ (.4 ;¿ 6.5 1.U 9;¿.5 .;¿5 5,U 6.5 U.UU .U4/U. (U 11SUUU ti4U ~u IjU"'~ Uti/1;¿¡U;¿ 364( 9.1 43 16 16 1S/1 ;¿¡U 6,:$ ;¿ 5.5 1,U 9:$.5 U ~.U 9.U U.1U U.U5/U,6U 16UUU 46U "kIH Uti/13/U;¿ 4401 1S,7 5;¿ 14 ;¿;¿ 6/9/1U 7.6 1 4.5 ;¿.U 95.5 .;¿5 1.( 9.4 U."U U.1U/U.4O 19UUU 5"U I nppmg Uti/141U;¿ 6959 9.U 56 1;¿ ;¿7 fl11 5.4 1 7.U ;¿.U 93.U .5 4,5 8.ts U.UU U.U5/U.6U 19UUU 46U ùnlllng Uti/15/U;¿ 1S;¿1ti 9.U 5( 1:$ ;¿9 1U/1 ( 7.U 1 (,5 ;¿.5 9".5 ."5 ti.U 1S.6 U.UU U.U5/U.9U 195UU ti;¿U I nppmg U6/1 ti/U;¿ 911;$ 9.;¿ 55 13 ;¿9 1U/16/;¿U t.U 1 9.U ".5 91.U .5 6.U 6.1 U.UU U.UU/U,8U 1WUU 5UU ùnlllng Uti/17/U;¿ 1U9;¿1 1U.U 44 13 ;¿6 6/15/17 5.U 1U.5 1 11.3 ;¿.5 66.( .5 6.7 6.U U.UU U.UUlU.6U 19bUU 56U ùnlllng Uti/1 IS/U;¿ 115"U 1U.;¿ 43 14 ;¿4 1S/14117 5.U 1U.5 ;¿ 1;¿.U ;¿.U 66.U ."5 1U,U IS.U U.UU U.UU/U.ISU 19UUU 5UU I.U, ror 9 5/6" U1)f19/U;¿ 115;¿0 1U.;¿ 45 1:11: ;¿5 1;¿f1 fl19 5," 1U.6 ;¿ 1;¿.U ;¿,U 1S6.U ."5 1U.U IS.U U.UU U.UU/U.9U 19UUU 6"U "kun 9 5/6" \;8g Uti/"U/U:l 115"U 1U.1 46 11 16 IS/;¿U 5.5 1 1:l.U :l.U 66.U .:l5 14.U 1.( U.UU U.UU/U.9U 19UUU 66U '\;mt 9 5/6" \;8g Uti/;¿1/U:l 115;¿U 1U.1 46 1U ;¿U 9/:lU 5.4 1 1UJ ;¿.U 66.U ."5 14.U 7.( U.UU U.UU/U.65 19UUU (UU Inp In Uti/:l;¿fU:l 1""15 1:l.4 ~3 ;¿:l "4 1U/:$7/4O 4.1S 11.U 1 "U.U ".U 6U.U ."5 1U.U 6.6 U.1U U.Ub/","U 51UUU 1"40 ùnlllng Uti/"3/U:l 1:$135 1;¿.4 51 ;¿1 :$6 14/35/39 5.:l 9,U :l "U,~ ;¿.5 79.5 ,:l5 1U.U 6.4 U.:lU U,U~/:l,:lU 5UUUU 1:$UU I.U, ~non I rip Uti/;¿4IU;¿ 1:$135 1:l.4 tiU :lIS 39 1;¿¡3414:l 5.5 9.6 ;¿ :lU.5 ;¿.5 (9.5 .:l5 1U.U 1S,:l U.UU U.UU/:l.:lU 495UU 13UU "kun ,.. liner Uti/:l5/U:l 1;$135 1;¿.4 ti6 ;¿9 3( 13/3:$/40 5.6 9,6 ;¿ :lU.5 :l.5 79,5 .:l5 1U,U 6.:l U.1U U.U5/:l.:lU 495UU 1:$UU '\;mt ,.. liner ~ - ~ - - ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Northstar Wel] . . . . . . . . . . . . . . . . . . . . .: NS12 A P 1 n umbe r. . . . . . . . . . . . . . .: SO - 02 9 - 23 091- 0 0 Engineer. . . . . . . . . . . . . . . . .: Rathert/Leafstedt Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for pusitions.....: Minimum curvature Method for DLS. ... ... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Drill Floor GL above permanent.......: 15.90 ft KB above vennanent.. . . . . . : NA DF above permanent.......: 50.26 ft ----- Vertical section origin---------------- Latitude (+N/S--).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- PlaLfurm reference point--------------- Lati tude (+NI S-) . . . . . . . . . : -999.25 ft Deparlule (tE/W-)........: -999.25 ft Azimuth trom I'ulary Lable to target: 86.62 degrees - - ~..\ Page 1 of 6 24-Jun-2002 00:44:11 Spud date....... .,....... .: Last survey date.~.......: Total accepted surveys...: MD of first survey.......: MD of last survey........: 08-Jun-02 24-JUIl- 02 148 0.00 ft 13135.52 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date.......... . .: 14-Jun-2002 Magnetic field strength..: 1150.36 HCNT Magnetic dec (+E/W-).....: 26.42 degrees Magnetic dip.............: 80.93 degrees ----- MWD survey Reference Reference G. . . . . . . . . . . . . . : Reference H. . . . . . . . . . . . . . : Reference Dip. . . . . . . . . . . . : Tolerance of G... . . . . . . . . : Tolerance of H...........: Tolerance of Dip. . . . . . . . . : C r i t e ria - - -- - - -- - - -- 1002.69 rnGal 1150.82 HCNT 80.94 degrees (+/-) 2.50 rnGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: Grid convergence (+E/W-).: Total az corr (+E/W-)....: (Total az corr = magnelic Ul.:C Sag applied (Y/N)........: No 26.31 degrees 0.00 degrees 26.31 degrees Ul j d C'UIlV) degree: 0.00 [(c)2002 Anaclril1 IDEAL ID6_1C_10] **Surveys with a tool type of "D-MAG" are MWD surveys that have been corrected with D-Mag. U·· MAG D-MAG D-MAG D-MAG D-MAG GYE GYR GYR D-MAG 1) MAG GYR GYR GYR GYR GYR GYR GYR GYR <;YH GYR GYR GYR GYR GYR GYR TIP GYR GYR GYH GYR - - - -- - - ------ Tool qual type Srvy tool type ------- ----.-- - 3.02 2.32 2.88 2.99 2.76 2.11 2.51 2.62 3.38 2.2'1 3.59 1.66 2.75 2.82 3.36 1.98 1 . r¡ I) 5.37 2.76 3.45 2.68 1.17 4.29 1.17 1.70 0.00 1.38 0.85 2.~1 1.42 DLS (deg/ 100f) 2 of 6 - '14.6'1 74.37 74.33 74.33 74.40 74.77 75.15 75.14 75.14 7S.04 76.79 70.77 70.25 71.61 73.23 330.69 332.35 336.06 711.011 87.54 302.51 310.55 317.33 321.79 326.21 0.00 255.83 261.93 2 7 5 . '12 281.54 241.78 285.87 333.18 384.07 438.47 104.50 133.78 155.61 166.04 201.88 15.53 22.49 33.86 50.70 72.64 5.44 4.13 2.92 2.58 8.06 5.80 6.29 6.57 6.48 6.24 0.00 0.30 1.06 2.37 3.29 233.18 275.30 320.80 369.80 422.32 100.83 129.31 150.41 160.48 195.04 15.12 21.24 31.87 48.11 69.55 -2.66 -1.92 -1.18 2.48 8.05 -4.89 -4.78 -4.45 -4.01 -3.47 0.00 -0.29 -1.05 -2.36 -3.22 63.92 77.02 89.99 103.71 117.92 27.46 34.29 39,89 42,59 52,12 3.55 7.41 11.44 16.00 20.96 4.74 3.66 2.67 0.71 0.35 3.12 4.09 4.83 5.09 5.19 0.00 -0.07 -0.15 0.24 0.66 236.54 279.36 325.55 375.27 428.54 102.27 131.11 152.50 162.71 197.77 15.30 21.64 32.49 48.97 70.66 -2.38 -1.70 -1.03 2.51 8.06 -4.70 -4.53 -4.16 -3.70 -3.16 0.00 -0.30 -1.05 -2.34 -3.18 1556.74 1641.57 1724.01 1803.55 1880.50 1208.77 1299.13 1359.29 1386.10 1471.58 741.17 808.78 898.05 996.61 1094.14 413.85 444.82 472.79 560.69 650.51 263.90 291.88 323.87 353.87 381.86 0.00 50.00 99.99 149.97 173.95 [(e)20():~ Anddl·jll IDEAL ID6_1C_10] 94.07 95.62 95.06 94.43 94.25 119.00 95.00 64.00 28.77 92.69 91.00 68.00 90.00 100.00 100.00 32.00 31.00 28.00 88,00 90.00 90.00 28.00 32.00 30.00 28.00 0.00 50.00 50.00 50.00 24.00 ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) '11.75 73.63 74.52 74.19 75.50 '1'7.64 75.50 '/4.79 75.24 '/3 . 98 52.54 62.72 74.18 74.42 78.98 135.66 153.94 132.50 106.54 84.39 1.83 11.13 49.72 69.61 87.72 0.00 255.83 269.89 294.39 297.37 ------- ------- Azimuth angle (deg) ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ---------------- --------------- Page - 24-Jun-2002 00:44:11 - -- ~ - 26.46 28.50 31.20 34.02 36.51 16.82 19.11 20.'1'7 21.'73 23.78 5.97 6.29 8.30 11.12 14.33 2.29 2.64 2.49 3.06 4.19 2.00 2.02 1.03 0.97 1.29 0.00 0.69 1.06 2.14 2.46 ------ - - -- -- - - Inel angle (deg) ------ - - - - -- - 1 S 9 3 . ~) 3 1689.1S 1784.21 18 'J 8 . 64 ]972.89 1219.00 ]314.00 13'/8.00 1406.'17 1499.46 742.00 810.00 900.00 ]000.00 1100.00 414.00 445.00 473.00 56\ .00 651.00 264.00 292.00 324.00 354.00 382.00 0.00 50.00 100.00 150.00 174.00 -------- Measured depth ( f t ) -- - - - - - - - - - -- ~- - - 26 27 28 29 30 21 22 23 24 2S 16 17 18 19 20 11 12 13 14 15 6 7 8 9 10 1 2 3 4 5 Seq # ANAIJHll.l. SCIILlJM13EH(;EH Survey Report - I)-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D--MAG D-MAG D - t1AG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG I)-MAG D-MAG ------ ------ Tool qual type Srvy tool type ------ ------ 1.37 1.97 2.52 1.97 0.82 0.77 0.56 0.52 0.66 o . '73 1.05 1.01 0.81 0.79 0.77 0.49 0.35 0.90 0.'17 o .7'1 1.49 0.58 0.58 0.17 0.99 0.67 1.67 0.94 0.8'1 0.74 DLS (deg/ 100f) 3 of 6 73.92 73.90 73.89 73.91 73.94 74.20 74.16 74.11 74.05 73.98 74.24 74.23 74.24 74.24 74.22 74.45 74.42 74.39 74.35 74.28 74.61 74.57 74.56 74.56 74.52 74.58 74.64 74.59 74.58 74.60 1892.23 1945.75 2002.34 2062.16 2121.19 1636.97 1688.67 1741.09 1792.22 1842.75 1353.40 1403.66 1473.55 1528.61 1582.88 1067.93 1123.53 1181.15 1237.84 1296.55 782.24 839.79 897.06 954.19 1011.68 495.37 552.56 609.90 666.68 724.64 1818.23 1869.41 1923.72 1981.39 2038.45 1575.11 1624.52 1674.55 1723.25 1771.21 1302.49 1350.84 1418.15 1471.12 1523.26 1028.86 1082.27 1137.60 1191.95 1248.08 754.18 809.53 864.68 919.77 974.97 477.54 532.82 587.97 642.66 698.62 524.00 539.69 555.57 571.49 586.67 445.74 461.00 476.74 492.41 508.48 367:70 381.45 400.24 415.26 430.33 286.21 301.68 317.80 333.94 351.19 207.64 223.39 238.83 253.97 270.04 131.72 146.38 162.09 177.32 192.46 1845.96 1897.97 1953.13 2011.64 2069.49 1598.65 1648.87 1699.74 1749.29 1798.10 1321.90 1370.98 1439.28 1493.05 1545.98 1043.95 1098.18 1154.36 1209.56 1266.61 765.11 821.29 877.26 933.14 989.20 484.47 540.52 596.50 652.00 708.75 3891.04 3971.17 4049.46 4126.19 4198.60 3493.83 3571.63 3652.01 3732.03 3812.78 3096.50 3162.95 3258.34 3335.74 3413.99 2718.48 2794.16 2871.54 2946.05 3022.50 2339.44 2414.35 2489.91 2565.66 2642.42 1956.97 2032.90 2109.69 2185.83 2263.37 [(c)200:¿ AIlaclrill IDEAL ID6_1C_10] 92.61 96.37 96,61 97.30 93.43 96.44 93.42 95.98 94.98 95.28 93.32 83.32 118.26 94.98 95.23 94.61 93.91 96.48 93.63 96.40 95.42 94.46 94.81 94.88 95.91 95.33 95.06 95.84 94.98 96.81 72.42 73.47 73.92 75.20 74.99 72.98 72.68 72.40 71.92 71.02 73.92 74.32 74.50 73.83 73.92 73.57 74.12 73.40 '/3.52 72.32 74.29 73.95 74.77 74.50 73.03 76.44 73.87 74.32 '74.57 75.15 ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Page ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ----------------- --------------- - - 24-Jun-2002 00:44:11 - - ~ 32.84 34.65 37.07 38.82 39.57 33.86 33.36 32.88 32.31 31.81 37.51 36.70 35.75 35.11 34.38 36.32 36.30 37.05 3 '7 .48 3'7.58 37.79 37.28 37.04 37.01 36.66 36.81 37.18 36.32 37.10 36.47 ------ ------ Inel angle (deg) ------ ------- 445~.24 4S51.61 4648.22 4745.52 4838.95 3982.97 4076.39 4172.3'7 4267.35 4362.63 3494.'14 3 5 '/ 8 . 0 6 3696.32 3791.30 3886.53 3021.00 3114.91 ~~211.39 3301).02 ~'1 0 1.'12 2546.33 2640.79 2735.60 2830.48 2926.39 2068.2:¿ 2163.28 2259.12 2354.10 2450.91 -------- - ~ - - -- ~- - - Measured depth (ft) -------- 56 57 58 59 60 51 52 53 54 55 46 47 48 49 50 41 42 43 44 '1 I) 36 37 38 39 40 31 32 33 34 35 Seq # ANADJULL SCHLlJt<1BERGEH Survey Report D-MAG D-MAG D-MAG D--MAG D-MAG D-MAG D-MAG f)-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG I) I>1AC D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type Srvy tool type ------ ------ 0.23 0.19 0.17 0.45 0.36 0.28 0.23 0.35 0.31 0.47 0.87 0.46 0.55 0.31 0.55 0.07 0.34 0.36 O.f)() 0.84 0.81 0.59 0.49 0.82 0.77 0.81 0.71 0.75 0.92 0.23 DLS (deg/ 100f) 4 of 6 ~ ~I 74.19 74.16 74.14 74.13 74.11 74.33 74.29 74.26 74.23 74.21 74.42 74.42 74.41 74.39 74.36 74.11 74.20 74.29 74.16 "74.40 73.86 73.88 73.91 73.96 74.03 73.96 73.94 73.92 73.90 73.87 3598.88 3654.69 3710.26 3771.10 3827.09 3318.91 3373.44 3430.33 3486.69 3542.21 3044.36 3099.40 3153.55 3208.17 3263.14 2760.33 2817.79 2874.18 2930.02 2989.31 2474.93 2533.57 2591.38 2648.18 2704.17 2181.04 2240.32 2300.01 2358.46 2417.56 3462.67 3515.98 3569.09 3627.29 3680.89 3195.53 3247.47 3301.70 3355.47 3408.51 2932.49 2985.54 3037.58 3089.89 3142.38 2654.91 2711.35 2766.79 2821,51 2879.22 2377.39 2433.90 2489.84 2545.07 2599.82 2096.10 2152.92 2210.06 2265.95 2322.39 980.76 997.30 1013.74 1031.46 1047.69 896.53 913.26 930.56 947.51 964.00 817.70 832.36 847.36 863.08 879.49 755.57 767.17 778.31 790,03 803.78 687.97 703.62 718.27 731.76 743.95 602.73 619.66 636,95 654.06 671.63 3514.47 3568.66 3622.65 3681.79 3736.26 3242.83 3295.66 3350.82 3405.50 3459.41 2975.59 3029.42 3082.25 3135.40 3188.77 2694.84 2751.86 2807.87 2863.18 2921.60 2413.82 2471.15 2527.86 2583.79 2639.16 2127.99 2185.71 2243.77 2300.57 2357.95 6184.17 6260.26 6336.13 6419.13 6495.36 5796.77 5873.05 5952.63 6030.77 6106.90 5408.49 5486.38 5563.52 5641.03 5718.62 5021.85 5098.51 5174.24 5250.09 5331.66 4644.86 4721.25 4797.04 4872.23 4946.91 4271.41 4344.32 4418.99 4493.93 4570.51 l ((')2002 Anacir-j]1 IDEAL ID6_1C_I0] 95.84 94.37 94.06 102.91 94.59 96.03 93.79 97.84 96.36 94.23 94.52 95.37 94.26 94.82 95.11 93.73 95.90 94.52 94.25 100.87 93.91 96.30 95.33 94.27 93.40 94.25 93.97 95.60 95.04 96.75 ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- Page 24-Jun-2002 00:44:11 - - -- ~ - 72.62 72.92 72.68 73.44 72.87 72.24 72.06 72.55 72.46 72.99 74.71 74.38 73.48 73.07 72.20 78.12 78.66 78.62 "/7 . 2 0 '/5 . 99 74.07 74.97 75.69 76.85 78.05 73.88 72.94 73.39 72.56 72.85 ------- ------- Azimuth angle (deg) ------- ------- 36.26 36.27 36.19 36.30 36.31 35.67 35.48 35.67 35.96 36.27 35.45 35.05 35.09 35.26 35.40 36.94 36.92 36.58 36.26 35.80 37.59 37.43 37.26 36.93 36.89 39.27 38.97 38.31 37.60 3 7 . "/ 3 ------ ------- Incl angle (deg) ------ --- - - - - - 7315.21 7409.58 7503.64 7606.55 7701.14 6837.15 6930.94 7028.78 7125.14 7219.37 G 3 6 1 . ~) 6 6456.93 6551.19 6646.01 6741.12 5881.50 5977.40 6071.92 G 1 66 . ] '7 (j267 .04 5408.47 5504.77 5600.10 5694.37 5787.77 4933.20 502 '7 . 1 "/ 5122 . T/ 5217.81 5314.56 -------- Measured depth ( ft ) - - - - - - -- - 86 8"/ 88 89 90 81 82 83 84 85 76 "/7 78 79 80 71 72 73 74 75 66 67 68 69 70 61 62 63 64 65 Seq # ANADHI LL SCII! ,UMBERGEH Survey Report l)-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG I)-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG i)-MAG D-MAG ------ ------ Tool qual type Srvy tool type ------ - - - -- - - 1.91 1.37 2.34 2.44 2.36 0.93 0.69 1.17 1.55 1.64 0.61 0.26 0.92 1.21 0.79 0.62 0.57 0.75 0.9t1 0.64 0.48 1.39 0.70 0.97 0.71 0.15 0.11 0.10 0.22 0.06 DLS (deg/ 100f) 5 of 6 ~ ~ ~~:!. 74.52 74.55 74.60 74.69 74.81 74.51 74.52 74.52 74.52 74.52 74.31 74.38 74.42 74.46 74.49 74.04 74.09 74.14 7t1.20 74.25 74.00 73.99 73.98 73.99 74.01 74.09 74.07 74.06 74.04 74.02 5321.25 5371.96 5423.77 5476.73 5528.70 5035.72 5095.12 5154.19 5213.24 5267.70 4747.29 4806.92 4862.26 4918.94 4977.40 4458.01 4516.74 4575.03 4634.09 4690.38 4160.58 4217.39 4276.90 4336.84 4400.04 3884.04 3940.58 3997.39 4052.87 4108.66 5128.32 5177.72 5228.94 5282.25 5335.44 4852.75 4910.22 4967.16 5024.08 5076.60 4570.48 4629.28 4683.71 4739.18 4796.11 4286.27 4343.71 4400.88 4458.94 4514.36 3999.37 4053.73 4110.82 4168.55 4229.80 3735.31 3789.33 3843.63 3896.61 3949.84 1419.86 1431.51 1440.65 1446.53 1449.02 1345.11 1360.14 1375.87 1391.56 1405.97 1283.57 1294.68 1305.52 1317.62 1331.10 1225.45 1238.16 1250.25 1262.00 1272.87 1146.94 1163.48 1180.26 1196.41 1212.07 1064.54 1081.26 1098.03 1114.55 1131.32 5203.11 5253.11 5304.78 5358.34 5411.59 4923.61 4981.87 5039.63 5097.39 5150.66 4638.20 4697.56 4752.54 4808.62 4866.24 4351.07 4409.16 4466.94 4525.59 4581.56 4060.04 4115.27 4173.26 4231.83 4293.90 3791.57 3846.49 3901.68 3955.54 4009.67 8479.86 8558.79 8639.21 8719.30 8795.91 8094.74 8169.04 8244.29 8323.03 8399.73 7708.32 7791.84 7868.30 7944.31 8020.63 7325.33 7399.65 7474.70 7552,88 7629.39 6947.63 7022.18 7097.76 7172.86 7252.25 6572.72 6649.40 6726.36 6801.64 6877.54 l (c)2002 Anadrill IDEAL ID6_1C_10] 96.38 93.84 95.79 96.39 93.31 94.33 95.13 95.66 98.43 94.07 97.43 102.75 94.48 94.87 96.16 93.32 94.79 95.11 98.09 95.10 87.24 93.73 96.20 96.09 101.49 96.07 95.28 95.67 93.52 94.21 75.58 77.89 81.84 85.51 89.09 75.87 74.82 74.27 74.93 74.38 79.52 79.08 78.40 77.00 76.36 77.13 77.91 78.21 78.92 78.89 72.53 73.61 73.63 75.11 76.21 72.72 72.89 72.79 72.56 72.47 32.90 32.59 33.24 34.41 35.22 38.62 38.67 37.60 36.13 34.62 35.66 35.59 36.36 37.15 37.80 38.48 38.25 37.56 36.74 36.13 36.75 37.88 38.55 38.64 38.43 36.42 36.40 36.48 36.32 36.33 10186.'74 10280.58 10376.37 10472.76 10566.07 9'/0, . 07 9802.20 9897.86 9996.29 10090.36 9224.48 9327.23 9421.71 9516.58 9612.74 8743.96 8838.75 8933.86 9031.95 9127.05 8263.13 8356.86 8453.06 8549.15 8650.64 '/7t)'1.21 "/892.49 "I 988 . 1 G 8081.68 81'/5.89 ------------- ------- ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Inel angle (deg) Measured depth (tt:) Page ----------- ------- ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 24-Jun-2002 00:44:11 - -- -. - 116 117 118 119 120 111 112 113 114 115 106 107 108 109 110 101 102 103 104 105 96 97 98 99 100 91 92 93 94 95 Seq # ANADHILL SCHLUMHERGER Survey Report proj ! ) MAC; D-MAG D-MAG D-MAG D--MAG D-MAG U-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D - MAC; D-MAG D-MAG D-I'1AG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D--MAG D-MAG ------ ------ Tool qual type Srvy tool type ------ ------ 0.00 0.54 1.60 0.55 1.92 0.96 1.51 1.2 'J 0.62 0.49 0.83 0.70 1.05 1.29 0.47 0.57 0.90 0.42 2.12 3.01 2.58 2.91 0.47 1.51 0.94 1.32 2.20 3.57 DLS (deg/ 100f) b at 6 -- 83.00 82.55 82.76 80.90 81.23 81.56 81.89 82.23 79.18 79.52 79.87 80.22 80.57 77.63 77.84 78.16 78.50 78.84 76.05 76.34 76.64 76.94 77.04 74.97 75.14 75.32 75.53 75.78 815.12 6636.82 6686.69 6630.28 6656.63 6422.95 6464.40 6505.10 6546.42 6589.90 6220.16 6258.43 6298.27 6338.56 6380.40 6052.34 6075.12 6109.64 6146.37 6183.29 5846.82 5893.55 5936.81 5974.68 5986.76 5585.90 5639.30 5692.86 5745.58 5797.27 6574.27 6603.53 6342.12 6388.76 6434.57 6480.88 6529.36 6109.56 6154.06 6200.15 6246.44 6294.09 5911.74 5938.81 5979.74 6023.08 6066.44 5674.43 5726.90 5776.19 5820.12 5834.29 5394.77 5450.63 5507.08 5563.31 5619.53 860.02 839.16 1015.79 985.98 955.27 924.02 891.18 1167.78 1138.17 1107.39 1076.75 1045.92 1296.98 1279.70 1253.16 1224.90 1196.38 1409.33 1391.59 1371.60 1350.19 1342.52 1448.70 1446.49 1442.46 1435.70 1424.51 6673.34 6613.54 6641.51 6390.98 6435.78 6479.70 6524.09 6570.54 6167.78 6210.46 6254.p5 6299.05 6344.80 5977.92 6003.93 6043.22 6084.82 6126.43 5747.65 5798.98 5847.01 5889.60 5903.29 5470.80 5526.43 5582.55 5638.28 5693.74 ((c)200¿ Anadrill IDEAL lD6_1C_10] SurVéY Projected to total depth: 148 13135.52 35.48 125.83 70.76 10897.24 10790,03 10839.62 10409.61 10485.93 10562.83 10637.59 10715.67 10021.45 10099.84 10179.22 10256.67 10333.69 9659.01 9708.66 9784.95 9865.26 9944.11 9261.07 9337.86 9416.72 9492.84 9518.39 8879.01 8956.13 9033.81 9110.46 9186.05 92.29 61.24 94.75 94.29 94.63 93.33 97.60 93.05 94.88 96.81 95.29 95.68 166.88 59.13 90.56 95.53 94.40 94.20 94.69 95.13 90.46 30.21 102.11 95.25 96.11 95.31 94.88 ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- At Az irn (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) 125.16 125.83 121.68 123.53 124.13 123.89 124.35 123.53 123.75 123.72 123.30 122.51 122.32 122.77 123.16 123.06 123.59 106.97 110.48 113.74 118.29 118.55 91.51 93.01 95.16 98.52 103.96 ------- ------- Azimuth angle (deg) 36.38 35.48 36.68 35.23 36.07 37.47 36.26 34.07 34.52 35.32 35.94 36.83 32.96 32.83 32.36 33.22 33.49 36.81 34.83 33.19 32.25 32.22 35.85 36.02 36.15 36. '/9 37.62 ------ -- -- - -- -- - Incl angle (deg) ------- -------- ------ -------- -------- ---------------- --------------- ------ ------- ------ -------- -------- ---------------- --------------- Page - 24-Jun-2002 00:44:11 - -- -- - - 1 3 0 0:3 . ~) 2 13064 . r/6 12':)31 . ~H~ 12625.67 12720.30 12813.63 12911.23 12053.9'/ 12148.85 12245.66 12340.95 12436.63 11621.30 11680.43 11770.99 11866.52 11960.92 11143.93 11238.62 11333.75 11424.21 11454.42 10668.18 10763.43 10859.54 10954.85 11049 . '73 -------- --- --_._-~._*- Measured depth ( f t ) -------- - - - -- -- -. -- ~ -- 146 14'7 141 142 143 144 145 136 137 138 139 140 131 132 133 134 135 126 127 128 129 130 121 122 123 124 125 Seq # ANAUH 1 L! SCIl! ,lJMBEHGEH Survey Report -, NS/2 Prognosed Tops Actual Depths Formation TVDss TVDrkb MDrkb TVDss TVDrkb MDrkb Top Permafrost 1,149 1206 1215 1139 1195 1205 Base Permafrost 1,519 1576 1614 1519 1575 1614 I SV6 - top confining zone 3,016 3072 3446 3032 3088 3484 Surface casing point 3,175 3231 3643 3161 3217 3647 SV5 - base confining zone 3,297 3354 3793 3314 3370 3833 SV4 3,608 3665 4179 3624 3680 4206 [ SV2 - top upper injection zone 3,964 4020 4689 4039 4095 4705 SVl - top major shale barrier 4,425 4481 5190 4439 4495 5219 TMBK - top lower injection zone - Top Ugnu 4,787 4843 5638 4804 4860 5679 I WSl - top Schrader Bluff - Base Ugnu 6,444 6500 7758 6409 6465 7663 CM3 - Base lower injection zone (top Colville) 7,009 7065 8388 7035 7091 8445 THRZ - Top HRZ 8,784 8840 10581 8832 8888 10679 I BHRZ - Base HRZ 8,874 8930 10690 8894 8950 10756 Top Kuparuk 9,072 9128 10930 8954 9010 10830 Kuparuk C 9,190 6246 11073 9069 9125 10973 Top Miluveach 9,400 9456 11329 9482 9538 11477 I Intermediate casing point 9,500 9556 1 1452 9518 9574 11520 Intermediate loggin~ point 9,500 9556 1 1452 0 0 0 Kingak 9,893 9949 11939 9784 9840 11837 I Fault "47" - throw = 120' 10,315 10371 12461 9684 9740 11717 Top Sag River 10,780 10836 13037 10812 10868 13100 Intermediate casing point 10,790 10846 13049 10841 10897 13135 I Ceol. Tar~et #1 10,791 10847 13050 Top Shublik 10,870 10926 13154 Top Ivishak 10,960 11016 13317 I Depth Horizontal (BHS) 11 ,000 11056 13512 Depth Horizontal (EHS) 11,000 11056 14012 Total Depth 11,000 11056 14012 Oil - Water contact 11,100 111 56 14012 I Top Kavik 11,300 11356 Top Lisburne 11,424 11480 I I I I I I Formation Logs
