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Home My WebLink About204-223 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O Lt - ~3 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 11111111I1111111111 RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. , o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: ~ o Other:: Oalo 1i17 J 0 7 I I 151 mP Project Proofing 111111111111111111I mP BY: ~ Oato 1$1'7 J 07 ;). x 30 = --1oó + Date: , 151 Scanning Preparation BY: = TOTAL PAGES /PO (Count does not include cover sheet) 151 p 1/11111111111111111 Production Scanning Stage 1 Page Count from Scanned File: {¡; L (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ oalolJl7/07 If NO in stage 1, page(s) discrepancies were found: YES NO 151 vvtf NO BY: Stage 1 BY: Maria Date: 151 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked III "1/11111" 1111I 1 0/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 0) i July 6, 2011 Mr. Tom Maunder � L ., 9- Alaska Oil and Gas Conservation Commission "1 r ri A 333 West 7 Avenue i l Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L5 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L5 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 05 Date: 05/30/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ WeU Name PTD # API # cement pumped cement date inhibitor sealant date L5 1890090 500292190800 0.4 NA 0.4 na 1.7 5/23/2011 15-04 1861910 500292167900 Sealed conductor NA NA NA NA NA 15-05 1870690 600292174200 Sealed conductor NA NA NA NA NA 1508 1870300 _ 500292171100 Sealed conductor NA NA - NA _ NA NA L5-09 1901240 500292208600 Sealed conductor NA NA NA NA NA 15-12 1870100 500292169400 Sealed conductor NA NA NA NA NA L5-13 1831840 500292105900 0.6 NA 0.6 NA 1.7 5/24/2011 L5-15 i 1881090 500292186800 Sealed conductor NA NA NA NA NA L5-16 2060830 500292170001 Sealed conductor NA NA NA NA NA L5-17 A 2042230 500292188901 0.1 NA 0.1 NA .85 5/30/2011 L5-18 1900830 500292208000 2.7 NA 2.7 NA 11.9 5/30/2011 15-19 1900680 500292205200 P&A 9/24 NA NA NA NA NA L5-21 1870570 500292173200 Sealed conductor NA NA NA NA NA L5-23 1900500 500292203900 Sealed conductor NA NA NA NA NA L5-24 1850660 500292132700 0.1 NA 0.1 NA .85 5/30/2011 L5 -25 1881350 500292188600 Sealed conductor NA NA NA NA NA L5-26 1901100 500292207900 1 NA 1 NA 3.4 5/30/2011 15-28 2060700 500292171701 Sealed conductor NA NA NA NA NA L5-29 1870450 500292172400 Sealed conductor NA NA NA NA NA 15-31 1901300 500292209100 0.8 NA 0.8 NA 3.4 5/28/2011 L5-32 1881020 500292186100 0.3 NA 0.3 NA .85 5/28/2011 L5-33 1890470 500292194300 0.3 NA 0.3 NA .85 5/28/2011 L5-34 1980850 500292288300 0.3 NA 0.3 NA .85 5/28/2011 15 -36 1890360 500292193300 0.6 NA 0.6 NA 1.7 5/28/2011 • ~ -~ ~ 03/01 /2008 DO NOT PLACE ,.. - ~. :~_ - ANY NEW MATERIAL UNDER THIS PAGE F:\I.aserFiclte\CvrPgs_Inserts\Microfitm Ma~er.cbc )ÇJ-~~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042230 Well Name/No. PRUDHOE BAY UN LIS L5-17A Operator BP EXPLORATION (ALASKA) INC MD 11780 Completion Date 12/15/2004 Completion Status i-OIL Current Status i-OIL TVD 8761 ~ --~- --~~--_._- REQUIRED INFORMATION API No. 50-029-21889-01-00 UIC N Mud Log No Samples No Directional Survey Yes --~-"._,._.._---~~._------- ~-~-----~- DATA INFORMATION Types Electric or Other Logs Run: GR I ROP I PRESS, GR lOlL I BHC I Density I CNL I Caliper Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number oED 0 Asc Rpt (data taken from Logs Portion of Master Well Data Maint PSP PRODUCTION PROFILE/GRlCCLlSTP PSP PRODUCTION PROFI LE/G RlCCLlSTP/DE FT/GHOST 9800 11704 Case 8/30/2005 Mem Prod Prof w/DEFT & GHOST Mem PSP GR/CCLlSTP/DEFT/GHOS T Interval Start Stop 35 11780 35 11780 9804 11726 Name Directional Survey Directional Survey Log Log Scale Media Run No OH/ CH Received ..------- 1/21/2005 .w/ 3116/2005 5 Blu 2 Production 0:.0- ; Log Production 11"09 Production .! Rpt 14006 LIS Verification ;)..og 14006 Gamma Ray v '" log 14006 Gamma Ray 5 Blu 9804 11726 Case 3/16/2005 2 5 Blu Well Cores/Samples Information: 0 0 8nt2006 25 Blu 10293 10765 Open 7/8/2006 25 Blu 10293 10765 Open 7/8/2006 Sample Set Sent Received Number Comments Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y I N. Daily History Received? Y/N IN Chips Received? _YI N Formation Tops Analysis . Y I N Received? Comments . GR, ROP w/Graphics GR GR . DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042230 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UN LIS L5-17A API No. 50-029-21889-01-00 MD 11780 TVD 8761 Completion Status i-OIL Current Status i-OIL UIC N Completion Date 12/15/2004 Comments: Compliance Reviewed By: Date: . . <Ii¡ \ . . '&111 BAKEl HUGHII Transmittal Form INTEQ ~.., 11, \ Anchorage GEOScience Center To: <, AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 RECE'VED Attention: Robin Deason AUG ,., 7 7006 Alaska Oil & Gas Cons. eommisllOn Anchorage Reference: L5-17 A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth LoK. þlueline ~ .GR/Directional TVD Log '. LAC Job#: 798668 Date: Aug.03, 2006 Sent By: Deepa Joglekar R~cei:'ed By: (1 tÈI\.- Date: 7r/o-:+! {~(p PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 .:;JÒL{-dd3 IllØfI! ,...~~~KI::':'.., taII," .....".... = ::': ,.,-'.".. "'''',",<,,,, . i i ¡ , ,.,.....' ~, ~v:;;..._:~·~.<;;. _ u ;n ._:-: ...." _ ."...." --~._---" 08/30/05 Scblumbepger NO. 3460 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI J b# L D "f D t BL CI CD . e I 0 og' eSCrlp1l0n ae o or Z-15 1'S'i·· UI!.,'{ 11084273 PPROF W/DEFT/GHOST/CALlPER 07/08/05 1 L5·17A 1r.',j -À.U 11075898 MEM PPROF W/DEFT/GHOST 07/03/05 1 DS 04-26 l~ r'"-JN 11072873 PRODUCTION PROFILE 07/30/05 1 S-14A ?~I.f-O'11 10893047 LEAK DETECTION LOG 10/17/04 1 G-21 1.'f{¡¡-{rÌö 10942221 MEM PPROF & IPROF 06/29/05 1 DS 05-20B ~ ~'-i .- J..}1.j 10942220 MEM INJECTION LOG 06/26/05 1 E-31A ::t c ç - tt ;... 10928640 MEM PPROF, IPROF & WARMBACK 06/14/05 1 D-29 l~ç-l.·rJ 11084274 RST 07/09/05 1 1 l~;:JJ 3 L2-28 It' r - a j~- 11016453 RST 07/27/05 1 1 IJ;V,íf C-13A (t17-¡Lj ~ 11015900 MCNL 07/05/05 1 1 I J).) r OWDw-sw/'V iì .- .,13 if 10893096 RST-BORAX CHANNEL DETECTION LOG 03/24/05 1 1 iJ).). v- 06-08A lC:j)--1 c.¡ J 11062628 RST 05/17/05 1 1 IJ ).')..1 12-29 J ,"{'1- ~3'.L 11012867 RST 01/07/05 1 1 1.?]'J.8 C-19BÀIJ ,:;- Qt, r 10928632 MCNL 05/12/05 1 1 i? .2. ;U/ G-27 I XI\¡- 11 (,¡ 10942221 MCNL 06/29/05 1 1 j ~ 1 3~ F-02A ?V~--C v(r.¡ 10928630 MCNL 05/08/05 1 1 13 J.J ì 03-33B ). () S- - CJ J ~ 10913011 US IT PDC-GR 03/19/05 1 1 r,,¡ ~ )... MPK-22 " L'./5 -:.. {).t 2.. 10893106 USIT 04/20/05 1 . BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ;1 ~ ~,~'\\ \ -- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995?A' ..-2t38 '. ' .r£L ATTN: Beth ,./ f~/ / Úì / ~ , . I Received by: ¡'f1 . _. I · STATE OF ALASKA . RECEIVE ALASKA OIL AND GAS CONSERVATION COMlrSSION 0 REPORT OF SUNDRY WELL OPERATIONSUL 12 2005 1. Operations Performed: _AlaSka Oil & Gas C8~ Eg '. Abandon 0 RepairWellD Plug PerforationsD Stimulate ŒI r mmlSSIOn Alter Casing D Pull TubingD Perforate New PoolD AnchoraJle WaiverD Time Exten onD Change Approved Program D Operation Shutdown 0 Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [R] ExploratoryD 204-2230 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-21889-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.00 L5-17 A 8. Property Designation: 10. FieldlPool(s): ADL-034631 Prudhoe Bay Field I Lisburne Oil Pool 11. Present Well Condition Summary: Total Depth measured 11780 feet true vertical 8760.7 feet Plugs (measured) Tagged TD @ 11717 (07/03/2005) Effective Depth measured 11780 feet Junk (measured) None true vertical 8760.7 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 35 - 115 35.0 - 115.0 1490 470 SURFACE 4215 10-3/4" 45.5# J-55 35 - 4250 35.0 - 4088.9 3580 2090 PRODUCTION 10446 7-5/8" 29.7# L-80 34 - 10480 34.0 - 8687.6 6890 4790 LINER 478 5-1/2" 17# L-80 10293 - 10771 8545.7 - 8917.2 7740 6280 LINER 4 3-1/2" 9.3# L-80 10225 - 10229 8494.2 - 8497.2 10160 10530 LINER 1335 3-3/16" 6.2# L-80 10229 - 11564 8497.2 - 8869.9 LINER 188 2-7/8" 6.16# L-80 11564 - 11752 8869.9 - 8770.2 13450 13890 Perforation depth: Measured depth: Slotted Liner 10735-11564,11622-11738 True vertical depth: Slotted Liner 8888-8870, 8838-8776 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 28 - 10284 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Hydro Set Pack @ 10193 2-7/8" Swell Packer @ 11565 4-1/2" HES WellStar TRSSSV @ 2075 12. Stimulation or cement squeeze summary: RBDMS 8Ft JUL 13 2005 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 530 8968 78 585 Subsequent to operation: 1838 24881 105 1108 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI Service 0 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ! OilŒJ GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr Title Petroleum Engineer AI. AI ¿1( Ad. -.-I Signature L 1": ~_. Phone 564-5174 Date 7/11/05 ð - Form 10-404 Revised 4/2004 n '-...' ~\L . . L5-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/18/05 ACID TREATMENT. CTU # 9.23/8" COIL. PERFORM BOP TEST AND INSTALL WELD ON CONNECTOR. RU & KILL WELL WITH FILTERED 2 % KCL.. 05/19/05 ACID TREATMENT. CTU # 9. 2 3/8" COIL. FINISH WELL KILL WITH FILTERED 2 % KCL. RIH WITH 2.50" OD DJN. TAG XO TO 2 7/8" LINER AT 11552' CTM. PUMP FIRST STAGE ACID JOB WITH NOZZLE AT 11550' CTM AS PER PROGRAM. POOH PUMP 1.75" BALL THRU COIL. MU AND RIH WITH 2.3" JSN. PUMP DIESEL DOWN CT X TUB ANNULUS. PUMP 2ND STAGE OF ACID JOB TREATMENT WITH NOZZLE AT 11000' PER PROGRAM.. OS/20/05 ACID TREATMENT/N2 LIFT. CTU # 9. 2 3/8" COIL. FINISH 2ND STAGE OF ACID TREATMENT. START N2 LIFT, NOZZLE AT 10150' CTM TO KO WELL THROUGH ASRC, START GAS LIFT AT 2.0MM ALSO. POOH WITH WELL FLOWING AT 12MM GAS/DAY, 3300 BPD FLUID, 1550 PSI WHP. SHUT WELL IN TO RDMO CTU. RESUME FLOW BACK 4 HOURS LATER AFTER CTU OUT OF WAY. NOTIFY DSO OF WELL STATUS.. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 223 50/50 METHANOL WATER 135 DIESEL 90 FILTERED 2% KCL WATER 87 2% KCL WATER 281 2% KCL WATER WITH 0.2% F103 & 0.2% W54 151 15% HCL ACID 800 15% SXE ACID 240 15% VDA ACID 2007 TOTAL Page 1 , TREE = ? . WELLHEAD - FMC L5-1 ~ 'A "'AÆTYNOTES' 90' @ 10978' ACTUA TOR = AXELSON AT! SSSV H2S {PPM} 50. KB. ELEV = 55' BF. ELEV = KOP= 2900' Max Angle = 124 @ 11657' 2075' 1-14-1/2" HES WELLSTARTRSSSV, 10= 3.813" I Datum MD = 10700' . Datum1VD= 8800' SS GAS LIFT MANDRELS ~ ST MD 1VD DEV TYÆ VLV LA TCH PORT DATE I 10-314" CSG, 45.5#, J-55, 10 = 9.953" I 4250' L ~ 1 3508 3480 22 KBG-2 DOME BK 16 12/21/04 2 6042 5397 41 KBG-2 SO BK 20 12/21/04 3 7377 6395 43 KBG-2 DMY BK 0 12/15/04 4 8745 7405 44 KBG-2 DMY BK 0 12/15/04 5 10104 8402 41 KBG-2 DMY BK 0 12/15/04 Minimum ID = 2.313" @ 11621' 2-7/8" X NIPPLE I I I 10172' 1-14-1/2" HES X NIP, 10 = 3.813" I :8: ::::, 10193' 1-17-5/8" x 4-1/2" BOT S-3 PKR, 10 = 3.875" I I . 10217' 1-14-1/2" HES X NIP, 10 = 3.813" I I 10225' 1-13.70" BTM DEPLOY SLV, ID = 3.00" I - 1-3-1/2" x 3-3/16" XO, ID=2.780" I 1 0229' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958'1 10284' 10284' 1-14-1/2" WLEG w /6" NO-GO, ID = 3.958" I ITOPOF 5-1/2" LNR I 10293' I I I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 10480' ... ~ II I I , , MILLOLJT WINDOW 10766' - 10771' TOPOFWHIPSTOCK H 10766' ~ ", , , " " I TOP OF CEMENT I 10817' crc ", 'ì 19400 LBS OF 20/40 SAND, FCO'D I 110SO' . '. I I I I I IPBTD 11094' I I I I I I 15-1/2" LNR, 17#, L-80, .0232 bpf,ID=4.892" I 11142' I I I I I I 13-3/16" SOLID/PRE-DRILLED LNR, 6.4#, L-80, .0077 bpf, ID = 2.813" I I I I 11564' H 3-3/16" X 2-7/8" XO, ID = 2.440" I 11564' I 18 - 1-12-7/8" SWELL PKR, 10 = 2.992" I """" I 11565' ÆRFORA TION SUMMARY REF LOG: I . I 11621' 1-12-7/8" X NIP, 10 = 2.313" I ANGLEATTOPÆRF: N/A Note: Refer to Production DB for historical perf data I I SIZE I SPF INTERV AL Opn/Sqz DATE I I I I PRE-DRILLED 10735 - 11564 3-3/16" LNR 12/14/04 I I PRE-DRILLED 11622 - 11738 2-7/8" LNR 12/14/04 I I I PBTD I 11738' I I I 12-7/8" SOLlD/PRE-DRILLED/SLOTTED LNR, 6.16#, L-80, .0058 bpf, ID = 2.440"/2.380" H 11 52~ I TD I 11780' DATE REV BY COMMENTS DATE REV BY CO MENTS LISBURNE UNrr 01/30/89 ORIGINAL COMPLETION WELL: L5-17A 07/16/91 WORK OVER ÆRMrr No: 2042230 12/15/04 JDMITLH CTD SIDETRACK API No: 50-029-21889-01 12/21/04 GJBITLH GL V C/O SEC 2, T11 N, R15E, 44.68' FEL & 3263.64' FNL 01/18/05 JDMlPAG CORRECTIONS BP Exploration (Alaska) " & STATE OF ALA SKA . ALAS IL AND GAS CONSER II A TION CO SSION WELL COMPLETION OR RECOMPLI ~TION REPORT AND LOG 1a. Well Status: a Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 a Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 12/15/2004 204-223 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/5/2004 50- 029-21889-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/13/2004 PBU L5-17A 1823' NSL, 155' WEL, SEC. 02, T11N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: t).ð. vV 1642' NSL, 626' WEL, SEC.~T11N, R15E, UM 55.0' Prudhoe Bay Field I Lisburne Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1633' NSL, 665' WEL, SEC. 03, T11 N, R15E, UM 11780 + 8761 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 717271 y- 5974950 Zone- ASP4 11780 + 8761 Ft ADL 034631 ------ ------~ -- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 711529 y- 5974606 Zone- ASP4 ~- 2075' MD Total Depth: x- 711490 y- 5974596 Zone- ASP4 --- - - - -- -- --- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aYes ONo NI A MSL 1900' (Approx.) 21. Logs Run: t::JI"" _ GR I ROP I PRESS, GR / DIL I BHC I Density I CNL / Caliper 122. CASING, liNER AND CEMENTING RECORD "l....~. ( . L~ j;¡ CASING SETTING EPTH MO . SETTING EPTH TVD HOLE CEMENTIN^ .... . ......, ;"C;- OUNT SIZE WT. PER FT. GRADE lOP I:3OTTOM Top BoTTOM SIZE [lULLED 20" 91.5# H-40 Surface 115' Surface 115' 30" 5150#Sl ð Inti!;" 10-3/4" 45.5# J-55 Surface 4250' Surface 4089' 13-1/2" 1600sxASIII. "l;JffQiJø8:150sxASI'v 7-5/8" 29.7# L-80 Surface 10480' Surface 8688' 9-7/8" 325 sx Class 'G' :-< ''""'~' 4¿ Ð:¡f~ f'J 5-1/2" 17# L-80 10293' 10766' 8546' 8913' 6-3/4" 150 sx Class 'G' F;nr'h~. - w ftf'!; S~¡"I 3·3116" x 2·7/8" 6.4# 16.16# L-80 10225' 11752' 8494' 8770' 4-1/4' x 3-314' Uncemented Slotted Liner Go. 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD ... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/16" Slotted Section 2-7/8" Slotted Section 4-1/2", 12.6#, L-80 10284 ' 10193' MD TVD MD TVD 10735' -11564' 8888' - 8870' 11622' - 11738' 8838' - 8776' 25. ACID,FRACTQRE,CEMENr$OuEEZE,ETC. .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): December 23, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-BSl CHOKE SIZE í GAS-Oil RATIO 1/12/2005 10.7 TEST PERIOD .. 164 1,934 42 104 11,835 Flow Tubing Casing Pressure CALCULATED ... Oll-BSl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 5~ 2,450 24-HoUR RATE 367 4,339 94.25 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None -/,,"¿:;;',- RBDMS 8Ft JAN 2 4 2005 '4&~ CF ~ ~'\1 .. '" .......\ Form 10-407 Revl~ I~Ó03 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARK 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Wahoo 5.3 Wahoo 5.2 Wahoo 5.1.2 10760' 10800' 10856' 8908' 8939' 8971' None Invert Wahoo 5.1.2 Wahoo 5.2 Wahoo 5.3 11209' 8976' 11386' 8941' 11397' 8937' 11420' 8930' 11508' 8897' 11594' 8854' 11622' 8838' 11631' 8833' 11649' 8823' 11675' 8808' 11737' 8776' Wahoo 6.1.1 Wahoo 6.1.2 Wahoo 6.2 Wahoo 6.3 Wahoo 6.3 Wahoo 6.3 Wahoo 7.1 Wahoo 7.2 (Top Lisburne) 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date PBU L5-17A Well Number Prepared By NameINumber: Drilling Engineer: Terrie Hubb/e, 564-4628 Ted Stagg, 564-4694 204-223 Permit No. I A roval 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 1 0-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 11 /22/2004 12/15/2004 2 Spud Date: 11/22/2004 End: 12/5/2005 11/20/2004 21 :00 - 23:00 2.00 MOB P PRE RREL from 10-11 @ 2100 hrs Move off well and set down parallel to well row. Do final cleanup and checks. Warm up moving system 23:00 - 23:15 0.25 MOB P PRE Safety mtg re: rig move 23:15 - 00:00 0.75 MOB P PRE Drive down 10 Pad and enter Spine at 2330 hrs. Begin move to Lisburne 11/21/2004 00:00 - 01 :00 1.00 MOB P PRE Standby at MPU turnoff while WO GPB Security 01 :00 - 00:00 23.00 MOB P PRE Move from MPU turnoff to just past the East Security Checkpoint with stops for crew changes at Z-Pad and OS 14 11/22/2004 00:00 - 05:30 5.50 MOB P PRE Move from East Security Checkpoint to L5 Pad and set down on Pad 05:30 - 13:00 7.50 MOB P PRE WO well and Pad prep. Spot camp. Little Red displaced IA and tbg to kcl water. 13:00 - 16:00 3.00 MOB P PRE Remove well house & flow line. Inspect pad with DSO. 16:00 - 20:00 4.00 MOB P PRE WO TS to shoot grade and level Pad Phz 1 20:00 - 21 :00 1.00 MOB P PRE Jack up rig and move down Pad and level up over well 21 :00 - 21 :30 0.50 WHSUR P DECOMP Accept rig for operations at 2100 hrs 11/22/04 Prespud/operations mtg re: scope, status, pitfallls 21 :30 - 00:00 2.50 WHSUR P DECOMP Rig up to circ. Load pits w/ 290 bbls hot SW Spot cuttings box, TL shack, power to camp DSM open SSV, then pull BPV 11/23/2004 00:00 - 01 :45 1.75 WHSUR P DECOMP RDMO DSM Fill mud pumps and lines w/ SW and PT (did extensive maint on move) 01 :45 - 03:30 1.75 WHSUR P DECOMP Revese circ IA to tubing wi SW and taking diesel FP outside. Pump at initial 8 bpm w/ both pumps, but had problem wi belt guard on #1 and had to SO to fix. Rev circ at 5 bpm/500 psi DSM RU tiger tank and hardline 03:30 - 05:50 2.33 WHSUR P DECOMP Circ down tbg w/ returns thru IA with hot SW wi both pumps 8 bpm/400 psi while wo FMC 05:50 - 06:30 0.67 WHSUR P DECOMP SD pump, check for balance 06:30 - 07:30 1.00 WHSUR P DECOMP Install two way check. FMC hand on location to assist. 07:30 - 09:30 2.00 WHSUR P DECOMP Hold PJSM. NO tree. Remove from cellar. 09:30 - 18:00 8.50 WHSUR P DECOMP Hold PJSM. NU 13-5/8" BOPS on wellhead. 18:00 - 00:00 6.00 WHSUR P DECOMP Crew chg. Hold PJSM and continue to NIU 13-5/8" BOP stack. Install riser. Hook-up choke/killlines and hyd control lines. 11/24/2004 00:00 - 00:15 0.25 WHSUR P DECOMP Finish NU 13-5/8" BOP stack. 00:15 - 06:00 5.75 WHSUR P DECOMP Notify AOGCC. Pressure test BOP stack 350psi low 3500psi high. Load pipe shed with 15.5# DP 06:00 - 07:00 1.00 WHSUR P DECOMP Finished BOP test Held PJSM with creww on way forward Checked annulus, Pressure was seen. 07:00 - 08:00 1.00 WHSUR P DECOMP Blow down surface lines and install 31 ft landing jt with 9" LH acme threads. RU to circulate long way through BPV. 08:00 - 11 :30 3.50 WHSUR P DECOMP Circulate at 1.5 bpm 180 psi through BPV. Vp = 315 bbl Loaded pipe shed with 110 jts DP and prep. 153 jts in pipe shed 11 :30 - 13:00 1.50 WHSUR P DECOMP SO pumps, checked flow, OK, SI casing valve, rig up and PT choke line to 3500 psi. 13:00 - 14:30 1.50 WHSUR P DECOMP PU Lubricator and RU to pull BPV Pull BPV and layout tools 14:30 - 15:30 1.00 PULL P DECOMP Screwed into hanger, PU, pulled out hanger at 80k and pulled Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 11/24/2004 14:30 - 15:30 1.00 PULL P DECOMP up to 140k, no movement Pulled up to 140-145 k 6 times with no movement. FP at 9418 ft, close to GLM # 4, where we are circulating through 15:30 - 18:00 I 2.50 PULL P DECOMP Wait on Eline unit to chem cut 3-1/2" tubing. Circulating and loading pipe shed with more DP 18:00 - 18:50 I 0.83 PULL P DECOMP MIRU SLB Eline 18:50 - 19:10 0.33 PULL P DECOMP PJSM with all crews. Review plan forward for handling SLB cutting tools. 19:10 - 20:00 0.83 PULL P DECOMP RU E-line sheave, entry sub and pack-off. Pull to 120k and set slips. P/U 2-12gr string shot charges. 20:00 - 00:00 4.00 PULL P DECOMP RIH with string shot tag at 10040' area. Attempt again after tie-in at GLM #4. Tag at 10050'. TOH unable to work past SSSV at 2124', Pump at 5bpm to keep SSSV open and pull through with string shot after numerous attempts. LID S8 and P/U chemical cutter. 11/25/2004 00:00 - 03:30 3.50 PULL P DECOMP RIH with chemical cutter. Still unable to get past 10050' and cut at our 1st choise depth at +/- 10228' just seal assembly. Pull up to middle of 1st full tbg joint above GLM #4. Make cut at 9484'. Good indication at surface that cut was made. TOH. RD SWS 03:30 - 06:00 2.50 PULL P DECOMP Pull tbg hanger assembly to surface and LID. Start LID of 3-1/2" tbg. 06:00 - 15:30 9.50 PULL P DECOMP LD 3-1/2" Tubing and misc jewerly Unloaded 4-3/4" DC ad fishing tools Lay down 45 jts and then unloading pipe shed Recovered 296 jts tubing 1-17.13 ft cut off pup 1 SSSV and CIM 3-Merla GLM with 10 ft PJ's 74 band and all control lines Cutoff jt is 17.03 ft 15:30 - 18:20 2.83 PULL P DECOMP Cleaned floor, brought in 124-3/4" DC and 103-1/2" HWDP Tailed and 00 & 10 cleaned out. Loaded pipe shed with BOT fishing tools 18:20 - 18:30 0.17 PULL P DECOMP PJSM review BHA handling precautions. 18:30 - 21:45 3.25 PULL P DECOMP P/U BHA #1 (708.05') 21 :45 - 00:00 2.25 PULL P DECOMP Bring remaining 3-1/2" 13.3# DP into pipe shed and tally. Make-up kelly. 11/26/2004 00:00 - 01 :30 1.50 PULL P DECOMP Continue loading pipe shed with remaining 13.3# DP. 01 :30 - 06:00 4.50 PULL P DECOMP P/U 3-1/2" 13.3# and 15.5# S-135 DP 06:00 - 06:15 0.25 PULL P DECOMP TL meeting in Doghouse 06:15 - 08:00 1.75 PULL P DECOMP PU 3-1/2" DP 13.3 15.5 #/ft 08:00 - 09:00 1.00 PULL P DECOMP SO. PJSM on removing spools and choke panel with Crane 09:00 - 11 :50 2.83 PULL P DECOMP PU 3-1/2" 15.5 #/ft S-135 DP 11 :50 - 13:00 1.17 PULL P DECOMP PU kelly and circulated bottoms up. 323 bbls 13:00 - 13:30 0.50 PULL P DECOMP RIH with rotary and tagged top of fish at 9484 ft, 38.5 ft kelly in on jts # 288 Set OS, PU to 190k , 60 k over. No movement. PU 4 time without jarring from 60k to 90 k over string wt, no movement PU and jarred twice and came free, PUH, have 9k extra drag. 13:30 - 15:15 1.75 PULL P DECOMP PUH to 9448 ft and circulated bottoms up. Qp = 5 pbm at 1040 psi Vp =323 bbl's Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 11/26/2004 15:15 - 18:00 2.75 PULL P DECOMP POOH with fish. running trip sheet 18:00 - 18:20 0.33 PULL P DECOMP TL meeting after crew change 18:20 - 20:00 1.67 PULL P DECOMP POOH to overshot w/fish. 20:00 - 23:20 3.33 PULL P DECOMP Back-off overshot and and I/d cut-off jt. GLM #4 is just below cut-off jt. This GLM is the one we have been circulating through whenever pumping fluids in the wellbore. Below this mandrel the string is wet and we are also seeing gas perculating to surface. Change elevators. Known obstruction is 17 jts below GLM. 23:20 - 00:00 0.67 PULL P DECOMP Drift and confirm there's no obstruction in GLM#4 assembly. I LID same. M/U TIW valve, close annular, open choke line to I gas buster. Try to circulate out trapped gas. Pressured tbg up I to 1000psi and pressure held. Must have a good plug somewhere. 11/27/2004 00:00 - 02:45 2.75 PULL N DPRB DECOMP R/U 2" drift on 70' of wireline. Drift 2jts at a time and LID 16jts. Found obstruction 10' into 17th jt continue to have gas 02:45 - 06:00 I perculating out. 3.25 PULL N DPRB DECOMP R/U 3-1/2" "Hot-Tap" just above next connection. Drill 3/4" hole. Bleed off 7 gal green cement. LID jt. Still have trapped pressure. PU and hot tap above next connection. Bleed-off 6gal cement. Hot tap next connection. 06:00 - 06:20 0.33 PULL N DPRB DECOMP TL meeting in Doghouse and way forward concerning HOT 06:20 - 09:05 I tapping tubing and jewerly 2.75 PULL N DPRB DECOMP HOT tapping all tubulars, solid cement from XO above GLM # 5 down 09:05 - 09:30 0.42 PULL N DPRB DECOMP OOH, HOT tap jt#1 above Seal assy, Seall assy not plugged Recovered all of seal assy fish. Top of retrievable packer fish at 10244 ft 09:30 - 10:30 1.00 PULL P DECOMP Clean up floor, remove tubing from pipe shed, RU to PU BHA #2 10:30 - 10:50 0.33 PULL P DECOMP PJSM on PU BHA#2 10:50 - 13:00 2.17 PULL P DECOMP Install wear bushing and PU BHA#2 13:00 - 17:00 4.00 PULL P DECOMP RIH, out of derrick, with BHA# 2 ITCO Spear 17:00-18:10 1.17 PULL P DECOMP PU 25 jts off rack 18:10 -18:25 0.25 PULL P DECOMP TL Meeting in dog house 18:25 - 19:25 1.00 PULL P DECOMP P/U kelly on jt #312 break circulation 2bpm 1050psi check wts. 142k up 102k dwn. RIH to 10227'. Make connection. RIH tag packer at 10253'. Engage spear. P/U several times to 240k. Cock jars pull to 200k jarred packer loose. PU good indication packer free and dragging a little. 19:25 - 20:35 1.17 PULL P DECOMP Circulate 3 bottoms-up. 4.5bpm 3450psi. 20:35 - 00:00 3.42 PULL P DECOMP Standback and blowdown kelly. TOH. Tight in places first 6 stds. 11/28/2004 00:00 - 06:15 6.25 PULL P DECOMP TOH with packer assembly. LD accelerator and 1 DC 06:15 - 06:30 0.25 PULL P DECOMP TL Meeting in Doghouse, Topic, LD 1 DC, handling fish using HOT tap 06:30 - 07:00 0.50 PULL P DECOMP Service Rig 07:00 - 08:30 1.50 PULL P DECOMP POOH LD 11 DC. 08:30 - 09:00 0.50 PULL P DECOMP LD Pkr assy Recoverd PBR, PKR (with all elements) and tail pipe assy. Note tail pipe not plugged. 09:00 - 13:30 4.50 CLEAN P DECOMP Load out fish and 4-3/4" DC and fishing tools Load 2-7/8' DP and 3-1/8" DC in Pipe shed, Prep. CDL Change out tongs to run work string Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 11 /22/2004 12/15/2004 2 Spud Date: 11/22/2004 End: 12/5/2005 11/28/2004 13:30 - 15:30 2.00 CLEAN P DECOMP PU and RIH, 4 3-1/8" DC and 27 jts 2-7/8" DP 15:30 - 19:00 3.50 CLEAN P DECOMP RIH with 3-1/2" DP out of derrick. Phase II driving conditions called at 1750 hrs. Crews still inbound at 1845 hrs. 19:00 - 19:20 0.33 CLEAN P DECOMP Crew change and TL meeting. 19:20 - 22:30 3.17 CLEAN P DECOMP Continue RIH with 4-3/4" mill. Tagged cement at 10297'. 22:30 - 00:00 1.50 CLEAN P DECOMP P/U kelly. Start milling cement. 5.0 bpm, 1290psi, 60rpm, 200amps, up WI 134k, dwn WI 115k, rot WI 122k Pumping hi-vis sweep on each connection. Drilled to 10405' 11/29/2004 00:00 - 06:30 6.50 CLEAN P DECOMP Continue drilling hard cement II 10405' to 10569' Qp = 252 gpm Pp ==1700psi RPM = 60rpm @ 340 amps WOB = 2-3k Av = 176/394 fpm. Pumping BIO sweeps Loading pipe shed with 4-1/2' tubing and prep-ing 06:30 - 14:20 7.83 CLEAN P DECOMP Drilling moderate to hard cement 10,569 It to 10,817 ft Qp = 252 gpm; Pp = 900 psi; RPM = 66 rpm Torque = 350 amps WOB = 2-3 k A V = 176/ 394 Vp == 274 bbl. ROP = 30 to 80 fph Pumping 30 bbl 2 ppb BIO sweeps/ connection. 14:20 - 19:30 5.17 CLEAN P DECOMP Cir bottoms up while working kelly. 1st pill unloaded lots of cement Cir 2 pill aroud along with 20 sxs citric acid to neutralize the fluids 19:30 - 00:00 4.50 CLEAN P DECOMP TOH standback 10 stds putting bit into 7-5/8" csg. Mix and pump 30 bbl weighted brine pill. Continue TOH laying down drillpipe 11/30/2004 00:00 - 06:00 6.00 CLEAN P DECOMP Lay down drill pipe. 06:00 - 06:20 0.33 CLEAN P DECOMP TL meeting in the doghouse, talked about drill pipe handling 06:20 . 06:50 0.50 CLEAN P DECOMP Unloading pipe shed, conduct crews walk around. 06:50 . 12:45 ' 5.92 CLEAN P DECOMP POOH LD DP, well taking some fluid, will investiagate once OOH 12:45·13:00 0.25 BOPSU P DECOMP Pull wear bushing. 13:00 . 14:00 1.00 CLEAN P DECOMP Clear floor of misc BHA tools and handling equipment. 14:00·15:30 1.50 EVAL C DECOMP Install 7" lubricator in BOP stack and close annular. RlU SWS. 15:30·17:00 1.50 EVAL C DECOMP RIH with US IT log to 10293'. 17:00 -18:10 1 .17 EV AL C DECOMP Start up pass running 6000'/hr 18:10-18:30 0.33 EV AL C DECOMP Pre tour safety meeting while running e-line logs. 18:30 - 20:15 1.75 EVAL C DECOMP Email US IT main logging pass to town engineers while logging a repeat section over cretatious interval. Discuss log with town. Log showed no internal or external casing corrosion. The pipe looked brand new. POOH with USIT log. 20:15 - 21:30 1.25 EVAL C DECOMP Lay down SWS US IT logging tool string. Rehead SWS eline for running PDS multi finger caliper tool. PU PDS MFCT. 21 :30 - 00:00 2.50 EVAL P DECOMP RIH, Log PDS MFCT from top of cement at 10817' to top of 5-1/2" liner at 10293'. POOH. Continue to load pipe shed with 4-1/2" tubing while running logs. 12/1/2004 00:00 - 01 :00 1.00 EVAL P DECOMP Finish MFC log. 01 :00 - 02:00 1.00 EVAL P DECOMP Tag up at surface, check for good MFC data. RD Schlumberger and PDS eq. PDS hand reports that raw MFC caliper data looks like good pipe for setting whipstock 10750'-10770'. He will prepare final data and deliver to the rig later today. 02:00 - 03:00 1.00 RUNCO RUNCMP PU elevators, air slips. Change dies in air slips. Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17:30 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 23:00 L5-1 7 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 1.00 0.50 14.00 0.50 0.50 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Preparelcheck liner tally. Safety meeting prior to running completion. Begin running 4-1/2" completion as per procedure. All connections below packer are bakerlocked. All tbg connections torqued to 3500 ftllbs. MU and test SSSV for 15/min - ok. Continue plu 4-1/2" tbg tag top of 5-1/2" liner with no-go. LID 2 jt and p/u space-out pups. P/U 1 full jt and tbg hanger RUNCMP MU connection from SSSV to tbg hanger and test. RUNCMP PJSM with all rig hands, Baker, FMC, HES discussing plan forward, hazards, and mitigations to hazards. RUNCMP Land tubing hanger. PT control lines. Run in lockdown screws. MU hose from IA to rig choke system and test. Hook up hose to TIW valve on top of landing joint. RUNCMP Pump 290 bbls of 2% KCL with 2 bbls of EC1124A corrosion inhibiter. Pumping down the tubing followed by 170 bls of straight 2% KCL. Taking returns from IA. Pump at 3.0 bpm max as per Baker hand. Initial pump pressure was 908 psi, then dropped down to 180 psi. 23:00 - 00:00 RUNCMP 12/2/2004 00:00 - 01 :00 1.00 RUNCMP 01 :00 - 01 :55 0.92 RUNCMP 01 :55 - 02:45 0.83 RUNCO RUNCMP 02:45 - 03:00 0.25 WHSUR P RUNCMP 03:00 - 06:00 3.00 WHSUR P RUNCMP 06:00 - 06:20 0.33 WHSUR P RUNCMP 06:20 - 08:00 1.67 WHSUR P RUNCMP 08:00 - 11 :00 3.00 WHSUR P RUNCMP 11 :00 - 12:30 1.50 WHSUR P RUNCMP 12:30 - 18:00 5.50 BOPSU P RUNCMP 18:00 - 18:30 0.50 BOPSU RUNCMP 18:30 - 19:40 1.17 BOPSU RUNCMP 19:40 - 20:30 0.83 BOPSU RUNCMP 20:30 - 20:45 RUNCMP Note, at 240 bbls away, we got a considerable amount of mouesey material back over the shakers. The material had a PH of 9.5, did not have a cement odor, and did not feel like particulate material when touched. Fluid in place. Break off TIW valve. Drop ball and rod. MU TIW valve. Pressure up to 3000 Ibs on tubing to set packer. Pressure held like a rock. Continue with tubing pressure test. Got good test. Initial pressure = 3250 psi. Final pressure after 1/2 hour = 3200 psi. Bleed pressure on tubing to 1500 psi. PT IA to 3000 psi for 1/2 hour. Good test. Initial pressure = 3170 psi, final pressure = 3150 psi. Bleed tubing pressure to 0, got good indication of shear at DCK shear valve in upper GLM (#1). Pump 2 bbls both ways to ensure valve has sheared completely. Pump 1.5 bpm at 175 psi. Good shear. Rig down landing joint. Set TWC. PT ok. Hold safety meeting Re: ND 13-5/8" stack. ND 13-5/8" stack and clean pits. Crew change PJSM review plan forward. Finsih ND 13-5/8' BOP stack NU 11" X 4" adapter and make SSSV tie-in. Test to 5K. Also PU 7-1116' BOP stack and change out 3" rams to 2-3/8 combi's. NU 4-1/8" production tree and test to 5K. NU 7-1/6" TOT BOP stack. Alerted AOGCC for BOP test. Chuck Scheve wavied witnessing test. Body test on BOP's passed ok. PJSM with rig crew to discuss plan forward for night tour. RU lubricator and pull TWC. Pressure up SSV, remove shipping cap and install fuseable cap. RU Little Red. Pump 60 bbls of diesel down the lA, thru the DHC valve in the upper GLM, and back from the tubing. Safety meeting with SL crews and rig crew prior to starting SL Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 11/22/2004 12/15/2004 2 Spud Date: 11/22/2004 End: 12/5/2005 work. Rig up SWS slickline unit. SL Run #1, retrieve ball and rod.7 12/3/2004 Lay down BHA #1, recovered ball and rod. Filled hole. Took 5 bbls of KCL to fill. 00:20 - 01:1 0 0.83 RUNCMP Run SL BHA #2, recover DKC valve from upper GLM. Took 5 bbls to fill well. Well appears to be drinking a little. 01 :10 - 01 :50 RUNCMP Run SL BHA #3, set dummy GLV in upper station. Set dummy ok. Filled well while swapping BHA's, and the well took 10 bbls. Definitely drinking. 01 :50 - 03:40 RUNCMP Run SL BHA #4, fish RHC plug from lower X nipple. Retrieved plug and all seals ok. Filled well while swapping BHA's, and the well took 5 bbls. 03:40 - 05:45 RUNCMP Run SL BHA #5, drift run for whipstock. Running 3.70" x 10' drift. Made it to 10822' SLM, TO from cleanout run was 10817'. Looks good. POOH. 05:45 - 06:15 RUNCMP OOH well took 6bbls to fill. RD slickliners. 06:15 - 06:30 WEXIT Crew change and PJSMITL meeting. Review plan forward. 06:30 - 11 :00 WEXIT Pressure test 7-1/16" BOP stack, choke manifold and floor valves at 300psi low 3500psi high. Test accumulator. Open well. Took 6 bbls to fill. 11 :00 - 11 :45 0.75 STWHIP P WEXIT Bring BTT and SWS tools to rig floor. 11 :45 - 12:00 0.25 STWHIP P IWEXIT PJSM review plan forward. Installation of RA tags and picking STWHIP! P up tools. 12:00 - 13:00 1.00 WEXIT Install 3 RA tags in BTT whipstock 8.90' from the TOWS. MU SWS sheave. MU SWS tools to BTT WS. 13:00 - 15:45 2.75 STWHIP P WEXIT RIH 85'/min make tie-in pass useing CET log 28 Jan 89. Make several passes to align WS tray to HS. Get on depth putting TOWS at 10765' with 0 TF. Fire setting tool - good indication after 35 sees. PU make another tie-in RIH tag TOWS at 10765'. 15:45 - 17:10 1.42 STWHIP P WEXIT Log gr/CCL back to 10000'. 17:10 - 17:30 0.33 STWHIP P WEXIT TOH. UD tools. G/CCL confirms WLEG is at 10284'. WLEG is 4' inside of top of 5-1/2" liner hanger. 17:30 - 18:00 0.50 STWHIP P WEXIT P/U injector. 18:00 - 18:30 0.50 STWHIP P WEXIT PJSM with all crews. Discuss activities forward for night tour, hazards and mitigations to hazards. 18:30 - 20:00 1.50 STWHIP P WEXIT Pull end of coil off of reel and stab into injector. Filled the hole at 19:45, the well took 5 bbls of seawater. 20:00 - 23:00 3.00 STWHIP P WEXIT Cut 1500' of coil with hydraulic cutter. Filled hole at 20:20, and it took 4 bbls. 23:00 - 00:00 1.00 STWHIP P WEXIT Fill hole, took 3 bbls. Prepare end of coil for pumping slack management. 12/4/2004 00:00 - 01:15 1.25 STWHIP P WEXIT Fill coil with 2% KCL. Pump slack management. 01 :15 - 03:30 2.25 STWHIP P WEXIT Attach CTC, build upper QC. 03:30 - 04: 15 0.75 STWHIP P WEXIT Make up BHA #4. 3.80" WM, 3.80 go, 3.79" no-go string mill. Baker TT straight motor. 1 Joint of PH6, BHI MWD BHA. 04:15 - 06:30 2.25 STWHIP P WEXIT RIH with BHA #4, to begin window milling. Pumping new mud at minimum rate down the coil thru an open EDC. Stop at 10630'. 06:30 - 07:00 0.50 STWHIP P WEXIT Log tie-in -13' correction. Close EDC 07:00 - 08:00 1.00 STWHIP P WEXIT RIH tag whipstock pinch-point at 10766' BHi tools quit. Swapping fluids in well from 8.5ppg KCL to 8.75ppg Flo-Pro Printed: 12/16/2004 4:01 :31 PM BP Operations Su Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 12/4/2004 07:00 . 08:00 1.00 STWHIP P WEXIT mud. Mud at bit rates = 2.60 in 2.35 out. Mud at surface rates = 2.60 in 2.10 out. Out rate increased to 2.20 prior to TOH for BHi tool change out. 08:00 . 10:30 2.50 STWHIP N DFAL WEXIT TOH 10:30 - 12:00 1.50 STWHIP N DFAL WEXIT Diagnose problem. Found bad Flow·Sub and replaced. All other tools tested good. 12:00·14:00 2.00 STWHIP N DFAL WEXIT RIH. Tagged on whipstock pu to flag corrected to flag. PU start I pump 2760fs creep in hole got to pinch point and motor stalled I (normal) and BHi tool comms failed again. On the bright side I returns are close to 1: 1 14:00·16:45 2.75 STWHIP N DFAL WEXIT TOH 16:45 - 18:00 1.25 STWHIP N DFAL WEXIT Coil e-line tests fine. Again the problem is the Flo-Sub. Both of the failed subs have recently been serviced at the DH shop but are the old style subs with a major portion of the electrical pin connector is made of ceramic. They test fine until you wiggle them hard and then there's continuity. The new style pins have more metal on the threaded portion where the coil wire attaches. We discussed completely reheading but the obvious problem is the flo-subs. MU new sub and BHA. 18:00 - 18:30 0.50 STWHIP N DFAL WEXIT Pre tour safety meeting. Discuss plan forward for night tour. 18:30 - 19:00 0.50 STWHIP N DFAL WEXIT Make up BHA #6 to mill window. 00261 gauges 3.80". String mill gauges 3.80 go, 3.79" no go. 19:00 - 20:45 1.75 STWHIP N DFAL WEXIT Shallow hole check ok. RIH with BHA #6 to mill window. 20:45 . 22:00 1.25 STWHIP P WEXIT Shut EDC. Dry tag top of WS with pumps down. Make -21' correction. PU, kick on pumps. RIH. Free spin=2660 psi at 2.55 bpm. Pit volume=288 bbls. Tag WS at 10766'. Milling at 2.56/2.26/2700 psi. Losing about 0.25 bbllmin, 15 bbllhr. Call for new mud to have on location as needed. 22:00 - 00:00 2.00 STWHIP P WEXIT 22:00 update. Depth=10766.9'. DHWOB=900 Ibs. 2.52/2.3/2750 psi. IAP=480 psi, OAP=30 psi. Pit vol=269 bbls. 24:00 update. Depth=10769.0', DHWOB=1500 Ibs. 2.53/2.58/2740 psi. IAP=560 psi, OAP=55 psi. Pit vol=225 bbls. Losses seem to have healed up. 12/5/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Continue milling window. Losses have healed up completely. 2.55/2.57/2747 psi. IAP=590 psi, OAP=60 psi. Pit vol=226 bbls. DHWOB=1000 psi. 01:00 - 02:10 1.17 STWHIP P WEXIT Continuing to mill. At 10769.9'. Taking new mud off of the vac truck. DHWOB and motor work trending down. Probably past the 1/2 way point. Getting good metal on the ditch magnets. Still have 100% returns. 02:10 - 02:40 0.50 STWHIP P WEXIT Pits full of new mud. PVT =435 bbls. 2.6/2.6/2800 psi. 02:40 - 03:00 0.33 STWHIP P WEXIT 10771.5', Possibly thru the window. Try drilling. Making hole. Preliminary window depths 10766'-10771.4'. 03:00 - 03:40 0.67 STWHIP P WEXIT 10775', Started losing returns again. Drilling at 2.55/2.33/3350 psi. ROP=10 fph. Drilled to 10782' 03:40 - 04:40 1.00 STWHIP P WEXIT Ream/Backream window. Returns have mostly healed up again. 04:40 . 06:30 1.83 STWHIP P WEXIT Dry drift the window down and up. Slick as a whistle. POOH to pick up build section BHA. Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 11/22/2004 End: 12/5/2005 11 /22/2004 12/15/2004 2 12/5/2004 06:30 - 09:30 09:30 - 09:45 09:45 - 12:00 12:00 - 12:30 12:30 - 14:15 14:15 - 16:00 16:00-16:15 16:15 - 16:55 16:55 - 18:00 18:00 - 18:30 18:30 - 00:00 3.00 STWHIP N I DPRB WEXIT 0.25 STWHIP P WEXIT 2.25 STWHIP P WEXIT 0.50 STWHIP P 1.75 STWHIP P WEXIT WEXIT 1.75 STWHIP P WEXIT 0.25 STWHIP N 0.67 STWHIP N SFAL WEXIT SFAL WEXIT 1.08 STWHIP N 0.50 STWHIP P 5.50 STWHIP P WEXIT WEXIT WEXIT Lift off injector from lubricator. Notice well is flowing +/- 1/4bpm MU injector to lubricator. Shut in annular pressure built to 55psi. Open well and bleed off quickly with small flow. RIH to 1000' circ BU. Trip to surface. Well still flowing small about. Might be balloning effect from losses. Open EDC (lost comms with tools, shows open circuit) and RIH to 4000'. Circ BU showing normal bbg of 32u trip to surface. Small flow. RIH to 300' wo pump TOH. I UD complete BHA #6. Install lubricator cap and monitor well. 156 bbls in active pit at 0940hrs. Check out all BHi componets for open circuit. Found SLB's cable between reel junction box and collector bad. Well giving back small stream at 0950 hrs...continue to monitor. MU new BHA on walk and check. Sametime make repairs to SLB cable. No downtime. Well still giving back samll amount of mud 1-1/2 bbls over last 2 hrs. Close SSSV to avoid mess at floor while PU BHA. P/U build section BHA. (65.09') Open SSSV (4800psi) RIH no pressure beneath SSSV. Tag at 10796' correct to 10782'. Up wt=43k dwnwt=26k ; Drill build section f/10782' Q in=2.70 Q out=2.40 FSP=2570 WOB=.5k frequent stalls. Drill to 10795'. Lost comms again with tools as before. Same cause, the SLB's jumper wire. The wire used is the same as the coils e-line. It is stiff and the connection to the collector is a very poor design for this wire and should be replaced with a stronger connecter. Either that or replace the jumper with a more resilient wire. TOH to 10000' pump at min rate. Trace problem. Same as before, the SLB's jumper wire. The wire used is the same as the coils e-line. It is stiff and the connection to the collector is a very poor design for this wire and should be replaced with a stronger connecter. Either that or replace the jumper with a more resilient wire. Install another jumper wire. Same type. RIH back to bottom. Drill ahead f/10795' 2.76/2.54 FS=2970 MW=100 Safety meeting Re: plan forward for tour. Drill ahead build section with slow ROP. ROP is 10-20 fph. IAP=503 psi, OAP=90 psi. Pit volume=362 bbls. Free spin = 2630 psi at 2.74 bpm. Drilling at 2.74/2.6/2950 psi. Losing fluid at about 9 bph. Bringing on remaining 85 bbls of mud from vac truck. Had another problem with the SWS eline collector. Fixed by tightening set screws. Printed: 12/16/2004 4:01:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-1 7 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/6/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/15/2004 12/6/2004 00:00 - 01 :35 1.58 DRILL P PROD1 Continue drilling ahead. Slight losses. 2.7/2.65/3029 psi. Pit vol=382 bbls. IAP=550 psi, OAP=126 psi. ROP=25 fph. 01 :35 - 03:35 2.00 DRILL P PROD1 Well is landed. POH. Pumping minimum rate to replace voidage. Not pumping full rate on way OOH. Letting well breath and hopefully be static when we get to surface. Return rate slowly dropped and stabalilzed at what we expected as the well "exhaled" as we POOH. 03:35 - 03:45 i 0.17 DRILL P PROD1 Safety meeting while POOH with BHA to discuss BHA swap. 03:45 - 04:00 I 0.25 DRILL P PROD1 Flow check. Well is giving us some mud back (breathing). It is flowing with a pencil sized stream. Shut SSSV to isolate well. Watch for flow. No flow observed. Proceed with BHA changeout. 04:00 - 06:10 2.17 DRILL P PROD1 Lay down BHA #7. Hughes bit recovered graded 6,4. Ringed on the pilot section. Broken cutters on both the pilot and wing cutter sections. Open SSSV..no pressures seen. Replace orienter which was weak on last run. Adjust motor AKO to 1.0 deg. Pick up a new Hycalog DS100 bicenter bit. 06: 10 - 07:50 1.67 DRILL P PROD1 RIH. Same time held PJSMITL in OP's cab. Reviewed plan forward for the day, reviewed LL from yesterday. RIH to 10750'. 07:50 - 09:30 1.67 DRILL P PROD1 Log tie-in to GR marker at 10754'. -24' correction.. MAD pass and survey tagged at 10931'. Corrected TO to that depth. 09:30 - 12:35 3.08 DRILL P PROD1 Drill ahead. up wt 39k Q=2.5 in 2.3 out 2710 free-spin anuular= 4640 bore= 5053 WOB= 1-3k 20-30'/hr. Trip gas= + 7k. Drilled to 10993' final flow rate 2.5/2.5 Numerous drill offs and sticky pick-ups to 50k. 12:35 - 13:00 0.42 DRILL P PROD1 Wiper trip to window. 13:00 -16:10 3.17 DRILL P PROD1 Drill ahead. Q= 2.5 in 2.4 out 8.7/8.7 2720fs 4611ann 5220 bore 9.95ecd 1-2kwob 20-25'/hr Drilled to 11057'. Continue to have every so often and the pick-ups are 45-60k. 16:10 -16:20 0.17 DRILL P PROD1 Make a short wiper trip. 116:20 -19:40 3.33 DRILL P PROD1 Drill ahead f/11057' 2.51/2.44 (@ 1710 hrs drilling at 11074' total mud losses for the day stands at 93bbls or about 10bbl/hr) 19:40 - 20:00 0.33 DRILL P PROD1 Wiper trip to shoe. PU at 40 klbs, slightly sticky. 20:00 - 21 :30 1.50 DRILL P PROD1 Resume drilling from 11103'. Free spin = 2800 psi at 2.7 bpm. Drilling at 2.7/2.7/2900 psi. 263 bbls in the pits. IAP=550 psi, OAP=160 psi. Taking on new mud from vac truck. ROP=16 fph. Holding high side tool face to begin buifd to 105 deg INC. 21 :30 - 00:00 2.50 DRILL P PROD1 Drop rate to 2.5 bpm to try to get more weight on bit. 2.5/2.45/2787 psi. Finished taking mud on. Pit volume = 394 bbls. 1217/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Continue drilling. Trying to climb up at a higher buifd angle to cross the structure, and get some idea of structural dip. Inc = 96 deg. Drilling at 2.67/2.66/3020 psi. IAP=560 psi, OAP=155 psi. 01 :00 - 01 :50 0.83 DRILL P PROD1 Pit volume at 01 :00 is 373 bbls. We have lost 21 bbls in the last 3.5 hours, or 6 bbls/hr. Continue drilling ahead. ROP=20 fph. 01:50 - 02:10 0.33 DRILL P PROD1 Wiper trip to shoe. PU off bottom at 47 klbs, then pulled smooth at 38 klbs. Pickups have been heavy for entire OH section, may be differential sticking due to fluid losses. Pit volume at 01 :50 is 369 bbls. Lost 4 bbls in last 50 minutes. Smooth to shoe. 02:10 - 02:30 0.33 DRILL P PROD1 Log tie in pass over formation marker at 10759'. (Sure glad we Printed: 12/16/2004 4:01:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/6/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/15/2004 121712004 02: 10 - 02:30 0.33 DRILL P PROD1 ran an RA tag). Make -5.5' correction. 02:30 - 02:50 0.33 DRILL P PROD1 Wiper trip back in hole. No problems back to bottom. 02:50 - 04:00 1.171 DRILL P PROD1 Resume drilling. IAP=560, OSP=217 psi. Pit volume=362 2.001 DRILL bbls. Drilling at 2.69/2.63/3025 psi. Free spin = 2850 psi. 04:00 - 06:00 P PROD1 Pit volume 355 bbls. Lost 7 bbls in last 1 :10 hours. Hit a very 06:00 - 06:50 I I hard spot at 11210'. We have been nibbling thru it slowly for the past 1/2 hour. 0.83 DRILL P PROD1 Wiper trip to 10790'. Upwt 40k dwn wt 23k. Same time held PJSMITL review objectives for the well and plan forward for the day. Hole slick on wiper trip. 06:50 - 08:05 1.251 DRILL P PROD1 Drifl ahead f/11225' Free-spin: 2.52/2.48 8.78/8.80ppg 2600psi free-spin 4640 annular 5240 bore 1 0.02ppg ecd. Drilling 3-400 mw pit vol 338. Drilled to 11241. Stacking wteight again. Make another wiper trip and clean things up. 08:05 - 08:50 0.75 DRILL P PROD1 Wiper trip and tie-in. -5' correction 08:50 - 09:20 0.50 DRILL P PROD1 Drill ahead fl corrected depth of 11236'. Wiper trip gas = 1500u. Drill to 11248' and starting stack bad again. 09:20 - 09:50 0.50 DRILL P PROD1 Make short 250' wiper trip. 09:50 - 11 :40 1.83 DRILL P PROD1 Drill ahead f/11242' drilling good to 11257'. PU off bottom trip up 100' and sending down 135bbls of new mud straight from vac truck to see what reaction we get, wt transfer etc. Mud turned corner at bit 2.5bpm 2800 free-spin 2.5/2.5 8.6in/8.830ut. Drilling ahead 1/11257' 200psi mw 2k wob 20'/hr smooth drilling. Pushed on it at 11269' got 28-30'/hr then stalled. Backed off to 20-25'/hr drill ahead. Back to old mud out the bit at 11274'. 11 :40 - 12:20 0.67 DRILL P PROD1 Wiper trip. 12:20 - 13:40 1.33 DRILL P PROD1 Resume drilling. 2.5/2.45/3025 psi. Pit vol=455 bbls. 13:40 - 14:20 0.67 DRILL P PROD1 We are at the 11300' decision point. Make wiper trip whife calling town. Plan forward is to drill ahead high side, building to cross the initial mudstone at 105+ degrees. Sticky pickup as normal, wiper was smooth after that. 14:20 - 16:50 2.50 DRILL P PROD1 Resume drilling. 2.54/2.54/3020 psi. Pit vol=445 bbls. IAP=560 psi, OAP=230 psi. ROP=21 fph. Tool face=highside. 16:50 - 17:20 0.50 DRILL P PROD1 Mini wiper up to 11000'. No problems. 17:20 - 19:00 1.67 DRILL P PROD1 Drill ahead to 11355'. 19:00 - 21 :30 2.50 DRILL P PROD1 Drill ahead. 2550 psi @ 2.53 in/2.60 out fs. 300-400 dpsi. WOB: 2-3k#. ROP: 20-25 fph. WHP/BHP/ECD: 4/4542/9.84. I NC/AZlTF: 104/236/315 deg. Displace well to new mud system. Not much change in weight trnasfer or ROP. ROP variable. Make several 30' wipers. 21 :30 - 00:00 2.50 DRILL P PROD1 POOH to check bit and to PU tractor tool for test run. Pin hole in coif at +1-9415'. (This is a 60% wear spot, 354K running ft total). Flag pin hole and spool on to reel. Continue to POOH filling hole across top. 12/8/2004 00:00 - 00:30 0.50 DRILL P PROD1 LD BHA assembly. 00:30 - 00:45 0.25 DRILL N DFAL PROD1 Hold PJSM with crews before blowing down reel. Discuss plan , fluids, hazards, and more. 00:45 - 03:00 2.25 DRILL N DFAL PROD1 Displace mud from coil with 35 bbls water and 10 bbls MEOH. Blow down with N2. Take rtns out to tiger tank. 03:00 - 04:00 1.00 DRILL N DFAL PROD1 Unstab coil. Pull back to reel and secure same. 04:00 - 05:00 1.00 DRILL N DFAL PROD1 Prep to drop reel. 05:00 - 06:00 1.00 DRILL N DFAL PROD1 Lower reel to low boy truck, and pick up new reel. Printed: 12/16/2004 4:01 :44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-1 7 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/6/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/15/2004 12/8/2004 06:00 - 06:30 0.50 DRILL N IDFAL PROD1 Safety meeting to discuss reel swap out, hazards, and mitigations to hazards. 06:30 - 12:30 6.00 DRILL N DFAL PROD1 Heat reel bushings with a rosebud, pull reel bushings. Install new bushings. Change grapple on stabbing cable and restring thru injector. 12:30 - 12:50 0.33 DRILL N DFAL PROD1 Safety meeting prior to stabbing pipe. 12:50 - 13:45 0.92 DRILL N DFAL PROD1 Stab pipe into injector. 13:45 - 17:00 3.25 DRILL N DFAL PROD1 Need to pump enough slack back to build bulkhead on reel end. Only 2' of wire sticking out of reel now. Prep end of eline with shrink wrap. Come on line with pumps reverse circulating. Spear with methanol then follow with hot 120 degf water. Pump 1 full volume at low rate. Pump 1 volume at max I rate. 17:00 - 19:30 2.50 DRILL IN DFAL PROD1 Break off hardline in the reel house. Check for slack at reel. No movement of wire. Need to pump with mud. Stab back on. Come on line with mud. Pump 1 coil volume. No movement. Pump several more coif volumes. No success. Suspect e-line maybe stuck in place, possibly as a result of surface cement IN pump test performed with this reel. 19:30 - 21 :00 1.50 DRILL DFAL PROD1 Decide to re-arrange plumbing inside reel to accomodate short e-line pig taif sticking out of coil. Re-configure transducer "y" fitting. Install and test pressure bulk head assembly. Meg e-line. Good test. 21 :00 - 22:45 1.75 DRILL N DFAL PROD1 Install hardline inside reel. Install e-line head on coil. E-line head/cable test good. Pressure and pull test coil connector. 22:45 - 23:00 0.25 DRILL P PROD1 L5 Pad evacuation alarm sounds. Evacuate rig. Determine from LPC board that alarm was only a test. Return to rig. 23:00 - 00:00 1.00 DRILL P PROD1 MU tractor on one jt PH6 dp in rotary. Pump & pressure test tool. Wheels opened & turned as per design. Max flow rate was 1.8 bpm. 12/9/2004 00:00 - 00:30 0.50 DRILL C PROD1 MU lateral BHA (#9) with Welltec tractor and Hycalog bicenter bit. 00:30 - 04:30 4.00 DRILL C PROD1 Stab coil. Get on well. RIH. Shallow test BHA. Continue to RIH. Getting some gas & crude in rtns. Hold 100 psi WHP whife RIH. Send worst of it outside to tiger. 04:30 - 05:00 0.50 DRILL C PROD1 Log gr tie in. Add 10' correction. RIH to 10950'. 05:00 - 05:20 0.33 DRILL C PROD1 Make several pull tests with tractor from 10950 to 11000. Vary pump rate and record negative DHWOB from mwd. 05:20 - 05:30 0.17 DRILL C PROD1 RIH to TO at min circ rate. 05:30 - 06:00 0.50 DRILL C PROD1 Tagged up 11' early. (Depth descrepency due to tractor pulling???) Drill ahead with tractor. 3150 psi@ 2.57 bpm in. Drill ahead at 30 fpm. Tractor generating 1.9k# to 2.9k# WOB according to DHWOB sensor. 06:00 - 06:30 0.50 DRILL C PROD1 Pre tour safety meeting with crews coming on tour. Continue with tractor test in the meantime. 06:30 - 07:00 0.50 DRILL C PROD1 Successful tractor test completed. 5' of formation drilled. PUH to repeat pull test at same depth as previously attempted. Position tool at 10950'. Rezero DHWOB cell. Attempt pull test with tractor. Still getting 2000 Ibs pull from tractor when pumps are engaged at full rate. 07:00 - 10:00 3.00 DRILL C PROD1 POOH to lay down Well Tec tractor. 10:00 - 10:15 0.25 DRILL C PROD1 Pre job safety meeting whife POOH re: laying down tractor. 10:15 - 11:15 1.00 DRILL C PROD1 Tag up with BHA #9. Lay down Well Tec tractor with xlo's. Printed: 12/16/2004 4:01:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/6/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/15/2004 12/9/2004 10:15 -11:15 1.00 DRILL C PROD1 Check bit. Bit graded 0,0 Make up BHA #10. Same hycalog bicenter bit, 1.2 deg motor, BHI MWD tool. 11:15-13:40 2.42 DRILL P PROD1 RIH with BHA #10 to resume drilling lateral section. 13:40 - 13:55 0.25 DRILL P PROD1 Make tie in pass over RA tag. Make -18' correction. 13:55 - 14:25 0.50 DRILL P PROD1 RIH to resume drilling lateral section. Gas cut returns. 14:25 - 15:00 0.58 DRILL P PROD1 Free spin 2626 psi at 2.58 bpm. 11387', begin drilling 2.58/XXX/2890 psi. Taking returns thru the gas buster. Out MM not reading due to gas cut returns. IAP=570 psi, OAP=44 psi. Pit volume = 353 bbls. Initial ROP=20 fph. 15:00 - 16:00 1.00 DRILL P PROD1 Pit volume at 15:00=346 bbls. Returns have cleaned up from gas. Drilling at 2.57/2.41/3406 psi. ROP=15 fph. 16:00 - 17:00 1.00 DRILL P PROD1 Pit volume at 16:00=337 bbls. Drilling at 2.59/2.57/2700 psi. Well seems to take fluid for the first few hours, then loss rate slows down. 17:00 - 18:00 1.00 DRILL P PROD1 Pit Volume at 17:00=331 bbls. Drilling at 2.59/2.54/2755 psi. Still losing fluid. 18:00 - 22:00 4.00 DRILL P PROD1 Drill ahead. 2650 psi @ 2.66 in/2.60 out fs. 200-400 dpsi. WOB: 3-4k#. ROP: 15-20 fph. WHP/BHP/ECD: 44/4530/9.84. IAlOAlPVT: 548/109/325. Inc/AzlTf: 108/231/300 deg. Hole sticky, with BHA slip sticking, and numerous stalls. Acts like a mud problem, although system is fairly new. 22:00 - 23:00 1.00 DRILL P PROD1 Wiper trip to window. Log gr tie in due to 6' depth discrepency between mwd & coil readings. Make a -5 correction. Hole very smooth in both directions. 23:00 - 00:00 1.00 DRILL P PROD1 Drill ahead from 11470'. 2660 psi @ 2.66 in/2.53 out. 12/10/2004 00:00 - 04:00 4.00 DRILL P PROD1 Drill ahead from 11475'. Stacking all available coil weight. Difficult to make any progress. Ordered new mud system. 04:00 - 05:00 1.00 DRILL P PROD1 Wiper trip to window. Hole smooth in both directions. 05:00 - 06:00 1.00 DRILL P I PROD1 Drill ahead from 11505'.2700 psi @ 2.59 in/2.57 out. Resume [ drilling at 10-15 fph after wiper trip. 06:00 - 06:30 0.50 DRILL P I PROD1 Pre tour safety meeting. 06:30 - 07:20 0.83 DRILL P PROD1 Not making any ROP. Could have damaged bit. Make a wiper trip to see if it improves ROP. Clean to the window and back in the hole. 07:20 - 09:00 1.67 DRILL P PROD1 Attempt to resume drilling. 2.61/2.52/2990 psi. IAP=580 psi, OAP=270 psi. Pit vol=268 bbls. Managed to get thru hard spot, and continue drilling. ROP is slower now than we have seen for past few days. Drilling about 10-15 fph. About half of previous days ROP. 09:00 - 12:00 3.00 DRILL P PROD1 Drilling ROP about 10-15 fph. It has been pretty consistent for past 2 hours. Swap to new mud. Didn't see any change in ROP with new mud around. 12:00 - 13:30 1.50 DRILL P PROD1 New mud on board. Pit volume=395 bbls. Adding 1% Flolube to system. (4.4 drums). Adding it in at the rate of 1 drum per hour, system will be up to concentration over 1.5 circulations. 13:30 - 16:15 2.75 DRILL P PROD1 PU clean off bottom at 39 klbs. POOH to pick up 3.75" PDC bit. Shut pumps down when pulling thru the mud stones 11425'-11398'. Pumped at full rate thru an open EDC while POOH. Stopped at 200' and trapped 500 psi on the well. Shut the SSSV, checked for flow. No flow observed. 16:15 - 17:45 1.50 DRILL P PROD1 Tag up at surface with BHA #10. Break off injector. Break off bit and change out the motor. Bit recovered in surprisingly good shape, and graded 4,2 chipped, slight ring. Printed: 12/16/2004 4:01:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-17 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/6/2004 12/1 5/2004 2 Spud Date: 11/22/2004 End: 12/15/2004 12/10/2004 17:45 - 18:30 0.75 DRILL P PROD1 Run back in hole with BHA #11. New motor and a Hycalog concentric reamer bit. (3.75"). 18:30 - 20:15 1.75 DRILL P PROD1 Open SSSV with 450 psi WHP. WHP dropped to 355. I Continue to RIH holding 300 psi WHP while circulating through EDC at 1.9 bpm. No gas found under SSSV. Continue to hold / reduce WHP towards whife RIH. ,20:15 - 21:30 1.25 DRILL P PROD1 Open choke at 10560. Appear to be getting some flow from well. Suspect well is breathing, but not sure. CBU before entering open hole. Micro out densities as low as 7.2 ppg noted during circulation. No gas alarms. 21 :30 . 22:00 0.50 DRILL P PROD1 Monitor well. WHP increased to 310 psi with full column of 8.7 mud in IA. Translates into 9.4 ppg EQMW. Discuss with town. 22:00 - 00:00 2.00 DRILL N FLUD PROD1 'Call for MI to weight up 570 bbls flo pro to 9.6 ppg. Will mix at mud plant and transport out to location when ready. 12/11/2004 00:00 - 06:00 6.00 DRILL N FLUD PROD1 Wait on weighted up mud from MI. 06:00 - 06:30 0.50 DRILL P PROD1 Safety meeting Re: WHP, and swap to new mud. 06:30 - 07:00 0.50 DRILL P PROD1 New mud on location. RIH, swapping to new mud. 07:00 - 07:55 0.92 DRILL P PROD1 Resume drilling. Tagged up at 11560'. Free spin = 2700 psi at 2.58 bpm, with new 9.6 mud to the bit, but with 8.7 mud on the backside. Drilling at 2.57/2.61/2930 psi. ECD with 8.7 mud on the backside is 9.97 ppg. Pit vol = 0, taking new mud on from vac trucks. 07:55 - 09:00 1.08 DRILL P PROD1 New mud back to surface. 2.58/0.99/3215 psi. BHP=4920 psi. ECD=10.75 bbpg. 09:00 - 10:00 1.00 DRILL P PROD1 Drilling ahead. Still losing returns. 2.59/1.16 bpm. BHP=4998 psi, ECD=10.94. 10:00 - 10:20 0.33 DRILL P PROD1 Drilling ahead. Slight improvement in losses. 2.61/1.31/3250 psi. BHP=5006 psi, ECD=10.96. 10:20 - 11 :20 1.00 DRILL P PROD1 Drilling break. Probably expected mudstone. ROP 110 fph. 2.58/1.2/3574 psi. BHP=5035 psi, ECD=11.03 ppg. Pit vol=130 bbls. 11 :20 - 12:00 0.67 DRILL P PROD1 Pit volume = 60 bbls. New mud truck just arrived on location. Whew! Drilling ahead 2.58/1.69/3570 psi. The balloon is filling up. 12:00 - 13:00 1.00 DRILL P PROD1 Drilling ahead. Returns continue to slowfy improve. 2.58/1.76/3285 psi. BHP=5013 psi, ECD=11.1 ppg. ROPa solid 20 fph. 13:00 - 14:00 1.00 DRILL P PROD1 Drilling ahead. 2.57/2.05/3320 psi. BHP=4968 psi, ECD=10.92 ppg. 14:00 - 14:35 0.58 DRILL P PROD1 Drilling ahead. 2.52/2.15/3150 psi. BHP=4967 psi, ECD=10.93 ppg. Pit volume=232 bbls. New truck of mud on location. 14:35 - 15:10 0.58 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 39 klbs. Dropping pump rate to zero when pulling by mudstones. 15:10 - 15:20 0.17 DRILL P PROD1 Log tie in pass down over GR charecter at window. Make -2' correction. 15:20 - 15:40 0.33 DRILL P PROD1 10750' BHP test at window. Pull up above window. Shut down pumps. Watch well to see if it will stabalize. 0.0/0.3. Well is flowing. Watch for 5 minutes. Still getting return rate of 0.17 bpm. Bring on pumps to full rate. 2.71/1.71 and stable. Trap 300 psi on the wellhead. Down on the pumps and monitor. WHP stabalizes at 322 psi. This would seem to confirm supercharging of the formation and forrnation Printed: 12/16/2004 4:01:44 PM Legal Well Name: L5-17 Common Well Name: L5-17 Spud Date: 11/22/2004 Event Name: DRILL+COMPLETE Start: 12/6/2004 End: 12/15/2004 Contractor Name: NORDIC CALISTA Rig Release: 12/15/2004 Rig Name: NORDIC 2 Rig Number: 2 Phase 12/11/2004 15:20 - 15:40 0.33 DRILL P PROD1 breathing. Note, when we bled WHP to 0, lAP dropped from 835 to 575 psi, or by 260 psi. There appears to be tubing by IA communication. The most likely candidate is a leaking dummy in station #1 that was replaced after the workover was completed. Wifl need to get slickliine to replace valve and test IA after rig moves off location. 15:40 - 16:20 0.67 DRILL N DFAL PROD1 MWD tool not working. Troubleshoot surface equipment. 16:20 - 18:00 1.67 DRILL N DFAL PROD1 POH pumping to replace pipe voidage and let well "breath". 18:00 - 18:30 0.50 DRILL N DFAL PROD1 Monitor well whife holding PJSM.TL mtg with night crew. No WHP, very slight flow. Close SSSV. 18:30 - 19:30 1.00 DRILL N DFAL PROD1 LD BHA. Change out mwd tools. Change out bit. Hycalog concentric garded 0-0-1 19:30 - 20:15 0.75 DRILL N DFAL PROD1 MU replacement MWD tools. MU HTC STR335 bit. Test same. 20:15 - 22:45 2.50 DRILL N DFAL PROD1 RIH to 1500'. Open SSSV. No flow and no WHP. Continue to RIH. 22:45 - 23:00 0.25 DRILL N DFAL PROD1 Log gr tie in from 10790'. Subtract 20' correction. 23:00 - 23:20 0.33 DRILL N DFAL PROD1 RIH. Pin holed pipe near horses head. Flag hole at 11,111' and spool back onto reel. 23:20 - 00:00 0.67 DRILL N DFAL PROD1 POOH to change reels. 12/12/2004 00:00 - 01 :45 1.75 DRILL N DFAL PROD1 Continue to POOH with pin holed coil. Shut SSSV. 01 :45 - 02:00 0.25 DRILL N DFAL PROD1 Hold PJSM in ops cab before BHA & coil operations. 02:00 - 02:45 0.75 DRILL N DFAL PROD1 Get off well. Unstab coil. Pull and LD BHA assembly. Circulate coil to water. 02:45 - 03:15 0.50 DRILL N DFAL PROD1 Blow down coil with N2. Take rtns to tiger tank. 03:15 - 06:00 2.75 DRILL N DFAL PROD1 Unstab coil from injector. Secure on reel. Remove hard line, pressure bulk head & other plumbing from bad reef. 06:00 - 06:30 0.50 DRILL N DFAL PROD1 Safety meeting prior to changing out reef. 06:30 - 08:00 1.50 DRILL N DFAL PROD1 Open bomb bay doors. Drop bad reel onto flatbed traifor. Close BB doors. Change reel bushings. Open BB doors. Pickup new reel. 08:00 - 12:15 4.25 DRILL N DFAL PROD1 Make up hardline inside reel, including electrical connection. Make up cable and slip connector for stabbing pipe. Stab pipe into injector. Seal end of cable. 12:15 - 17:00 4.75 DRILL N DFAL PROD1 Pump slack management, and build upper quick connect. Pull test and PT same. 17:00 - 17:45 0.75 DRILL N DFAL PROD1 Make up BHA #13. 1.2 degree motor with Hycalog concentric I reamer 3.75" bit. 17:45 - 18:00 0.25 DRILL N DFAL PROD1 RIH with BHA #13. 18:00 - 18:30 0.50 DRILL N DFAL PROD1 POOH. MWD and or e-line failure. 18:30 - 18:45 0.25 DRILL N DFAL PROD1 Hold PJSM before getting off well. Discuss trouble shooting plan with BHI & SLB. 18:45 - 20:00 1.25 DRILL N DFAL PROD1 Get off well. Unstab coil. Find that e-line pulled out of coil connector. Attempt to pump slack back into reef. 3.9 bpm @ 4100 psi. Able to pump 25' of e-line into coil. Cut coil to expose e-line. 20:00 - 21 :30 1.50 DRILL N DFAL PROD1 MU coil-e-line connector. Test same. 3000 psi, pull 35K#. 21 :30 - 22:30 1.00 DRILL N DFAL PROD1 MU lateral BHA #14, 1.2 deg mtr with Hycalog concentric 3.75" bit (new). Stab coif. Get on well. Surface MWD tools. 22:30 - 00:00 1.50 DRILL N PROD1 Open EDC. RIH circulating at 12/13/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Continue to RIH with drilling assembly. Got 10-20 bbls of cross Printed: 12/16/2004 4:01:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/6/2004 12/15/2004 2 Spud Date: 11/22/2004 End: 12/15/2004 12/13/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 linked mud back from under sssv. Possibly due to too much lubricant, or mixing with crude from well. Small amount of gas in returns. Send to tiger tank. Continue to RIH. 01:00-01:15 0.25 DRILL N DFAL PROD1 Log GR tie in from 10795. Subtract 25' correction. 01:15 - 02:00 0.75 DRILL P PROD1 RIH to TO. 40k# up, 21 k# dn wt. Set down at 11631'. PU and circulate. RBIH no problem. Hole smooth to bt. 02:00 - 05:30 3.50 DRILL P PROD1 Drill ahead from 11700'. 3325 psi @ 2.55 in/1.50 out. 400-600 dpsi. WOB:2-3k#. ROP: 30-60 fph. WHP/BHP/ECD: 29/4930/10.86. Inc/Az: 124/256 deg. IAlOAlPVT: 648/34/278 bbls. Orient to 180 deg TF to drop angle. 05:30 - 06:15 0.75 DRILL P PROD1 Drilled into the Kavik at approximately 11735'. Driled ahead to 1780' to see it on the GR log. Call TO at 11780', make wiper trip to window to tie in. 06:15 - 06:30 0.25 DRILL P PROD1 Hold PJSM with rig crews to discuss plan forward for the day while logging tie in pass over the RA tag. Made a 0.0' I correction. 06:30 - 07:05 0.58 DRILL P PROD1 RBIH to get final TD tag. Weight bobble at 11706' on way in ¡the hole, but fell thru it easily. Tagged bottom at 11780'. 07:05 - 09:45 2.67 DRILL P PROD1 , POH. No problems in open hole on way OOH. Open EDC at I the window. POOH pumping at full rate. 09:45 - 10:45 1.00 DRILL P PROD1 Tag up with BHA #14. Lay down BHA. Bit recoverd at 1,1 (Paint gone). 10:45 - 11 :00 0.25 EVAL P PROD1 Safety meeting prior to picking up logging BHA. 11 :00 - 12:00 1.00 EVAL P PROD1 Make up BHA #15. Reeves logging BHA with Res-Sonic-Density-Neutron-GR-Caliper Tools. 12:00 - 14:20 2.33 EV AL P PROD1 RIH with BHA #15. Logging tools below BHI MWD BHA. Caliper clock set to open at 15:00. 14:20 - 14:30 0.17 EVAL P PROD1 Log tie in pass over RA tag in window using BHI Gr tool in MWD to get us on depth. Make -22' correction 14:30 - 15:05 0.58 EVAL P PROD1 Log down from window to TO. Had 1 weight bobble at 11610', but fell thru easily. Tagged bottom at 11778'. Waited on bottom for 6 minutes. 15:05 - 16:00 0.92 EVAL P PROD1 Log up from TO to 10500'. Slick in open hole. 16:00 - 18:00 2.00 EVAL P PROD1 POOH. Paint flags at 10087' (9900' EOP), and 9287' (9100' EOP). 18:00 - 18:15 0.25 EVAL P PROD1 Hold PJSM before pulling and laying down logging tools. Discuss nuclear source handling, etc. 18:15 - 19:30 1.25 EVAL P PROD1 Get off well. Unstab coil. LD Reeves logging tools. 19:30 - 21 :00 1.50 EVAL P PROD1 Dwonload and evaluate log data. RU floor to run liner. Log data is good. 21 :00 - 00:00 3.00 CASE P RUN PRO Hold PJSM in ops cab. MU 3-3/16" x 2-7/8" liner assembly w/ swell packer.. 12/14/2004 00:00 - 02:30 2.50 CASE P RUNPRD Continue to MU 3-3/16 x 2-7/8 slotted liner assy. 02:30 - 02:45 0.25 CASE P RUN PRO RU to run 1-1/4" CSH. 02:45 - 04:15 1.50 CASE P RUN PRO Run CSH. Verfiy stung into o-ring sub. Lay down last joint and space out with pups. 04:15 - 05:00 0.75 CASE P RUNPRD MU deployment sleeve and GS spear to liner assembly. MU Inteq mwd tools on top of liner. Stab coil. Get on well. 05:00 - 07:45 2.75 CASE P RUN PRO Verify SSSV is open. RIH with liner assembly. Stop at first flag at 9100' EOP. Make -15.3' correction. 07:45 - 08:35 0.83 CASE P RUN PRO Weight check at window =49 klbs. RIH weight is 24 klbs at 42 fpm. Tag up at 11740'. PU, RIH again, made it thru the Printed: 12/16/2004 4:01:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/6/2004 12/15/2004 2 Spud Date: 11/22/2004 End: 12/15/2004 12/14/2004 07:45 . 08:35 0.83 CASE P RUN PRO second time. Looks like we are pushing something. Weight rough. Made it to 11749', PU @ 51 klbs. RIH smooth to 11749', then draggy to 11759'. PU at 47 klbs clean. RIH with pumps on trying to wash thru it if there is debris in front of us. Set down at 11760'. Continue working it. PU, then tagged up at 11754'. We lost 6' of hole as we worked it. The current depth of the swell packer is just into the 3.75" hole. We need to confirm packer depth before proceeding. 08:35·09:15 0.67 CASE P RUNPRD Kick pumps on. PU at 39 klbs. Confirmed release from the liner. PU to 11650'. Log down with BHI GR tool until tagging top of liner. Make a -4' correction. Bottom of liner is at 11744'. This puts the swell packer just above the 3.75" hole. We need to work it deeper. 09: 15 . 09:40 0.42 CASE P RUNPRD Latch back into the GS profile. PU at 50 klbs. Confirmed we have the liner. Work pipe to attempt to get it deeper. RIH at 70 fpm, tagged up at 10754'. PU at 54 klbs RIH, set down at 10748'. PU, RIH at 80 fpm. Set down at 10756'. PU, 56 klbs. RIH at 100 fpm, set down at 11753'. PU at 55 klbs. RIH at 100 fpm. Set down at 11754'. PU, kick pumps on to 1.75 bpm, 3400 psi. RIH at 30 fpm, trying to wash our way thru. Set down at 11744', waited for 30 seconds, and got weight back. Looks like we made a few feet. Stack weight. Trying to wash thru. Seem to be making hole slowly. Feeding pipe as we circulate. Probably washing thru something. Depth appears to be at 10752'. Not making any more progress. 09:40 - 10:25 0.75 CASE P RUNPRD Pumps on, PU at 42 klbs, released from liner. PU, log down from 11670' to confirm depth again. The DHWOB sensor indicated that we tagged up at 11751.5'. This is an accurate tied in depth for the bottom of the liner. At this measured depth we are 28.5' off of bottom. The top and bottom of the swell packer is 11564.9/11578.5'. The element begins 16" from the bottom connection. The bottom of the element is at 11577.1'. This is 7.1' below where the 3.75" hole started. Consult with town. This depth is adiquate to ensure proper setting of the swell packer. TOL @ 10225' 10:25 - 11 :50 1.42 CASE P RUNPRD On line with 30 bbls 2% KCL preflush, followed by 20 bbls of Lithium Hypochlorite bleach. 11 :50 - 13:30 I 1.67 CASE P RUN PRO POOH laying lithium hypochlorite in open hole. Circulating at minimum rate to replace pipe voidage while POOH. 13:30 . 15:30 2.00 CASE P RUNPRD At surface. Hold PJSM in Ops cab to discuss handling BHA. Get off well. Unstab coif. LD CSH wash pipe. 15:30 - 16:00 0.50 CASE P RUN PRO MU nozzle assembly w/ stinger. 16:00 - 17:00 1.00 CASE P RUNPRD Displace coil to water . 17:00·19:00 2.00 CASE P RUNPRD RIH. Displace / dillute 9.6 mud in tbg while RIH to TOL. 19:00 - 19:30 0.50 CASE P RUNPRD Slow down RIH speed to a crawl and slow down pump rate to 1.2 bpm while getting about 30 bbls X-linked mud back and WHP as high as 200 psi. Swap to diesel 19:30 - 19:55 0.42 CASE P RUNPRD Park at 10100' and fin displace diesel to nozzle 2.4/2900 while getting crude and gas back w/130 psi WHP @ 1/1 returns 19:55 - 21:45 1.83 CASE P RUNPRD POOH displacing well bore from 10100' to diesel for underbalance and FP following pressure schedule. Close TRSSSV w/850 psi WHP. lAP 1000, OA 0 Used 150 bbls Printed: 12/16/2004 4:01 :44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-17 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/6/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/15/2004 12/14/2004 19:55 - 21:45 1.83 CASE P RUNPRD diesel 21 :45 - 22:00 0.25 CASE P RUNPRD Tag up. Secure well. Line up to displace CT to N2 while cool down N2 pumper Move camp to L 1 Pad 22:00 - 22:15 0.25 RIGD P POST PJSM before pumping N2. Discuss schedule, hazards, etc with crew. 22: 15 - 00:00 1.75 RIGD P POST Blow down reel with N2 to reduce weight for move. 12/15/2004 00:00 - 04:00 4.00 RIGD P POST Continue to clean pits. NO BOPS. NU tree cap. Test same. Release rig at 0400 hrs. Printed: 12/16/2004 4:01 :44 PM ObP . Baker Hughes INTEQ. Survey Repor~ Map Coords Bii. 8A.KUt IILIGIIIS I.NTEQ Company: BP Amoco Date: 1/17/2005 Time: 14:11:55 Page: 1 Field: Lisbume Co-ordinate(NE) Reference: Well: L5-17, True North Site: Lis OS 05 Vertical (TVD) Reference: 10: 17 1/81198900:0055.0 Well: L5-17 Section (VS) Reference: Well (O.00N,O.00E,245.00Azi) Wellpath: L5-17 A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Lis OS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Easting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: L5-17 Slot Name: 17 L5-17 Well Position: +N/-S 4813.97 ft Northing: 5974950.40 ft Latitude: 70 20 3.099 N +E/-W 5050.70 ft Easting : 717271.36 ft Longitude: 148 14 13.914 W Position Uncertainty: 0.00 ft Wellpath: L5-17A Drilled From: L5-17 500292188901 Tie-on Depth: 11765.00 ft Current Datum: 10 : 17 1/8/1989 00:00 Height 55.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/9/2004 Declination: 25.18 deg Field Strength: 57645 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.00 0.00 0.00 245.00 Annotation MD TVD ft ft 10700.00 8860.30 TIP 10765.00 8912.40 KOP 11400.00 8936.49 MD as of 120904 1530 hrs 11550.00 8877.16 4 11655.00 8819.41 5 11775.00 8762.24 TO Survey: Start Date: Company: Engineer: Tool: Tied-to: Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 35.00 0.00 0.00 35.00 -20.00 0.00 0.00 5974950.40 717271.36 0.00 0.00 100.00 0.37 141.05 100.00 45.00 -0.16 0.13 5974950.24 717271.49 -0.05 0.57 200.00 0.43 144.62 200.00 145.00 -0.72 0.55 5974949.70 717271.93 -0.20 0.06 300.00 0.27 128.58 300.00 245.00 -1.17 0.95 5974949.26 717272.34 -0.37 0.19 400.00 0.50 141.77 399.99 344.99 -1.66 1.41 5974948.78 717272.81 -0.57 0.24 500.00 0.17 137.24 499.99 444.99 -2.11 1.78 5974948.34 717273.20 -0.72 0.33 600.00 0.40 138.52 599.99 544.99 -2.48 2.11 5974947.98 717273.54 -0.86 0.23 700.00 0.15 121.95 699.99 644.99 -2.82 2.45 5974947.66 717273.89 -1.03 0.26 800.00 0.38 123.83 799.99 744.99 -3.07 2.84 5974947.42 717274.28 -1.28 0.23 900.00 0.08 156.65 899.99 844.99 -3.32 3.14 5974947.18 717274.59 -1.45 0.32 1000.00 0.12 98.60 999.99 944.99 -3.40 3.27 5974947.10 717274.73 -1.53 0.10 1100.00 0.18 148.58 1099.99 1044.99 -3.55 3.46 5974946.96 717274.92 -1.64 0.14 1200.00 0.18 111.09 1199.99 1144.99 -3.74 3.69 5974946.77 717275.15 -1.76 0.12 1300.00 0.20 125.87 1299.99 1244.99 -3.90 3.98 5974946.62 717275.44 -1.96 0.05 1400.00 0.27 139.29 1399.98 1344.98 -4.18 4.27 5974946.35 717275.75 -2.10 0.09 tÅGC( ~)À-) ObP . Baker Hughes INTEQ. Survey Report Map Coords _íi. BAKD IIUGfIH ,--~--"-- INTEQ Company: BP Amoco Date: 1/17/2005 Time: 14:11 :55 Page: 2 Field: Lisbume Co-ordinate(NE) Reference: Well: L5-17, True North Site: Lis OS 05 Vertical (fVD) Reference: 10: 171/8/198900:0055.0 Well: L5-17 Section (VS) Reference: Well (O.00N,0.00E,245.00Azi) Wellpath: L5-17 A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Oft 1500.00 0.48 125.77 1499.98 1444.98 -4.60 4.76 5974945.94 717276.25 -2.37 0.23 1600.00 0.62 105.51 1599.98 1544.98 -4.99 5.63 5974945.58 717277.12 -2.99 0.24 1700.00 0.87 88.13 1699.97 1644.97 -5.11 6.91 5974945.49 717278.41 -4.10 0.33 1800.00 0.85 83.54 1799.96 1744.96 -5.00 8.40 5974945.65 717279.90 -5.50 0.07 1900.00 0.77 94.71 1899.95 1844.95 -4.97 9.81 5974945.71 717281.30 -6.79 0.18 2000.00 0.80 95.52 1999.94 1944.94 -5.10 11.17 5974945.63 717282.67 -7.97 0.03 2100.00 0.87 96.20 2099.93 2044.93 -5.25 12.62 5974945.52 717284.13 -9.22 0.07 2200.00 0.88 94.43 2199.92 2144.92 -5.39 14.14 5974945.43 717285.65 -10.54 0.03 2300.00 0.93 95.03 2299.90 2244.90 -5.52 15.72 5974945.34 717287.23 -11.91 0.05 2400.00 1.13 90.94 2399.89 2344.89 -5.60 17.51 5974945.31 717289.02 -13.50 0.21 2500.00 0.73 96.99 2499.87 2444.87 -5.70 19.13 5974945.26 717290.64 -14.93 0.41 2600.00 0.85 269.95 2599.87 2544.87 -5.78 19.02 5974945.18 717290.54 -14.80 1.58 2700.00 2.85 277.33 2699.81 2644.81 -5.46 15.81 5974945.40 717287.32 -12.02 2.01 2800.00 4.85 274.56 2799.58 2744.58 -4.81 9.13 5974945.86 717280.62 -6.24 2.01 2900.00 8.32 265.98 2898.91 2843.91 -4.98 -2.30 5974945.36 717269.20 4.19 3.60 3000.00 12.50 261.79 2997.24 2942.24 -7.03 -20.24 5974942.79 717251.33 21.32 4.25 3100.00 16.13 263.41 3094.12 3039.12 -10.17 -44.76 5974938.94 717226.91 44.86 3.65 3200.00 17.80 265.86 3189.77 3134.77 -12.87 -73.81 5974935.40 717197.96 72.33 1.82 3300.00 18.92 267.75 3284.68 3229.68 -14.61 -105.25 5974932.75 717166.58 101.56 1.27 3400.00 19.57 269.77 3379.09 3324.09 -15.31 -138.20 5974931.09 717133.67 131.72 0.93 3500.00 21.77 270.20 3472.65 3417.65 -15.32 -173.50 5974930.07 717098.39 163.71 2.21 3600.00 25.15 270.50 3564.37 3509.37 -15.07 -213.30 5974929.16 717058.59 199.68 3.38 3700.00 27.82 270.83 3653.87 3598.87 -14.54 -257.89 5974928.40 717014.01 239.87 2.67 3800.00 32.48 270.99 3740.31 3685.31 -13.74 -308.10 5974927.74 716963.80 285.04 4.66 3900.00 35.35 272.72 3823.29 3768.29 -11.90 -363.85 5974927.96 716908.02 334.79 3.03 4000.00 38.52 271.65 3903.22 3848.22 -9.63 -423.89 5974928.49 716847.95 388.24 3.23 4100.00 42.67 270.48 3979.13 3924.13 -8.45 -488.93 5974927.79 716782.90 446.69 4.22 4200.00 43.10 270.94 4052.41 3997.41 -7.61 -556.98 5974926.66 716714.86 508.01 0.53 4300.00 42.90 271.30 4125.54 4070.54 -6.27 -625.17 5974926.02 716646.66 569.24 0.32 4400.00 42.72 271.22 4198.90 4143.90 -4.78 -693.11 5974925.55 716578.71 630.19 0.19 4500.00 42.37 271.69 4272.58 4217.58 -3.06 -760.70 5974925.30 716511.10 690.72 0.47 4600.00 42.03 271.87 4346.66 4291.66 -0.98 -827.84 5974925.44 716443.93 750.69 0.36 4700.00 42.90 271.85 4420.42 4365.42 1.21 -895.32 5974925.68 716376.42 810.92 0.87 4800.00 43.72 272.50 4493.19 4438.19 3.82 -963.86 5974926.30 716307.83 871.94 0.93 4900.00 44.08 272.68 4565.25 4510.25 6.95 -1033.13 5974927.42 716238.51 933.40 0.38 5000.00 44.48 272.98 4636.84 4581.84 10.40 -1102.86 5974928.85 716168.71 995.14 0.45 5100.00 44.48 274.37 4708.19 4653.19 14.89 -1172.78 5974931.31 716098.69 1056.61 0.97 5200.00 44.50 275.44 4779.53 4724.53 20.88 -1242.60 5974935.28 716028.73 1117.35 0.75 5300.00 44.22 275.74 4851.02 4796.02 27.69 -1312.18 5974940.07 715958.98 1177.54 0.35 5400.00 43.73 276.40 4922.99 4867.99 35.03 -1381.23 5974945.41 715889.76 1237.01 0.67 5500.00 43.62 276.67 4995.32 4940.32 42.89 -1449.84 5974951.28 715820.95 1295.87 0.22 5600.00 43.38 276.35 5067.85 5012.85 50.70 -1518.23 5974957.10 715752.37 1354.56 0.33 5700.00 42.40 275.88 5141.12 5086.12 57.95 -1585.90 5974962.38 715684.52 1412.82 1.03 5800.00 41.67 275.77 5215.39 5160.39 64.75 -1652.51 5974967.25 715617.74 1470.32 0.73 5900.00 41.22 275.85 5290.35 5235.35 71.45 -1718.36 5974972.04 715551.73 1527.17 0.45 6000.00 41.27 275.83 5365.54 5310.54 78.15 -1783.95 5974976.84 715485.98 1583.77 0.05 6100.00 41.08 276.34 5440.81 5385.81 85.13 -1849.41 5974981.92 715420.34 1640.16 0.39 6200.00 41.18 276.20 5516.13 5461.13 92.32 -1914.79 5974987.21 715354.78 1696.38 0.14 6300.00 40.97 276.24 5591.52 5536.52 99.43 -1980.11 5974992.43 715289.29 1752.57 0.21 6400.00 40.83 276.21 5667.10 5612.10 106.53 -2045.20 5974997.64 715224.02 1808.56 0.14 6500.00 40.37 276.27 5743.03 5688.03 113.61 -2109.89 5975002.84 715159.16 1864.20 0.46 6600.00 41.02 276.99 5818.85 5763.85 121.14 -2174.66 5975008.49 715094.20 1919.71 0.80 ObP . Baker Hughes INTEQ. Survey Report Map Coords .ií. BAlCH IUGIIIS ~-~-~ INTEQ Company: BP Amoco Date: 1/1712005 Time: 14:11 :55 Page: 3 Field: Lisbume Co-ordinate(NE) Reference: Well: L5-17, True North Site: Lis OS 05 Vertical (TVD) Reference: 10: 17 1/8/198900:0055.0 Well: L5-17 Section (VS) Reference: Well (O.ooN,0.00E,245.00Azi) Wellpath: L5-17A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 6700.00 41.53 276.22 5894.00 5839.00 128.72 -2240.19 5975014.17 715028.49 1975.90 0.72 6800.00 41.73 275.42 5968.75 5913.75 135.46 -2306.27 5975018.99 714962.23 2032.95 0.57 6900.00 41.97 275.11 6043.24 5988.24 141.58 -2372.71 5975023.18 714895.65 2090.57 0.32 7000.00 42.38 274.64 6117.35 6062.35 147.29 -2439.61 5975026.95 714828.62 2148.79 0.52 7100.00 42.53 273.51 6191.13 6136.13 152.08 -2506.94 5975029.79 714761.18 2207.78 0.78 7200.00 42.62 273.16 6264.77 6209.77 156.02 -2574.48 5975031.77 714693.56 2267.33 0.25 7300.00 42.98 272.66 6338.14 6283.14 159.47 -2642.33 5975033.25 714625.64 2327.37 0.49 7400.00 43.28 272.17 6411.12 6356.12 162.35 -2710.64 5975034.15 714557.28 2388.06 0.45 7500.00 42.95 272.39 6484.12 6429.12 165.06 -2778.93 5975034.89 714488.94 2448.81 0.36 7600.00 42.93 272.67 6557.33 6502.33 168.07 -2846.99 5975035.92 714420.83 2509.22 0.19 7700.00 42.98 272.75 6630.52 6575.52 171.29 -2915.05 5975037.17 714352.70 2569.54 0.07 7800.00 42.68 272.35 6703.86 6648.86 174.32 -2982.97 5975038.23 714284.73 2629.82 0.40 7900.00 42.03 271.95 6777.75 6722.75 176.85 -3050.29 5975038.81 714217.37 2689.76 0.70 8000.00 41.60 271.73 6852.28 6797.28 178.99 -3116.93 5975039.02 714150.70 2749.25 0.45 8100.00 40.95 272.62 6927.44 6872.44 181.49 -3182.85 5975039.60 714084.74 2807.94 0.88 8200.00 41.15 272.35 7002.85 6947.85 184.34 -3248.46 5975040.55 714019.07 2866.20 0.27 8300.00 41.52 272.21 7077.94 7022.94 186.96 -3314.45 5975041.26 713953.04 2924.90 0.38 8400.00 42.08 272.05 7152.49 7097.49 189.44 -3381.06 5975041.81 713886.39 2984.22 0.57 8500.00 42.67 272.01 7226.36 7171.36 191.83 -3448.41 5975042.25 713819.00 3044.25 0.59 8600.00 43.22 272.03 7299.56 7244.56 194.23 -3516.50 5975042.67 713750.87 3104.95 0.55 8700.00 43.87 271.97 7372.04 7317.04 196.63 -3585.35 5975043.08 713681.98 3166.33 0.65 8800.00 44.18 272.02 7443.95 7388.95 199.05 -3654.80 5975043.49 713612.49 3228.25 0.31 8900.00 44.82 272.01 7515.27 7460.27 201.52 -3724.85 5975043.92 713542.40 3290.70 0.64 9000.00 45.03 272.10 7586.08 7531.08 204.05 -3795.42 5975044.41 713471.79 3353.59 0.22 9100.00 45.12 272.11 7656.69 7601.69 206.65 -3866.18 5975044.96 713400.99 3416.61 0.09 9200.00 44.22 271.86 7727.81 7672.81 209.09 -3936.44 5975045.36 713330.70 3479.26 0.92 9300.00 42.82 270.91 7800.32 7745.32 210.76 -4005.28 5975045.04 713261.84 3540.94 1.55 9400.00 42.52 270.46 7873.85 7818.85 211.57 -4073.05 5975043.88 713194.08 3602.02 0.43 9500.00 42.27 270.15 7947.70 7892.70 211.93 -4140.47 5975042.29 713126.68 3662.98 0.33 9600.00 41.78 269.81 8021.99 7966.99 211.91 -4207.42 5975040.33 713059.76 3723.66 0.54 9700.00 41.40 269.29 8096.78 8041.78 211.39 -4273.79 5975037.88 712993.43 3784.04 0.51 9800.00 40.83 268.84 8172.12 8117.12 210.31 -4339.54 5975034.91 712927.75 3844.08 0.64 9900.00 40.73 268.63 8247.84 8192.84 208.87 -4404.84 5975031.58 712862.52 3903.87 0.17 10000.00 40.77 268.47 8323.60 8268.60 207.22 -4470.10 5975028.03 712797.34 3963.71 0.11 10100.00 40.73 268.29 8399.35 8344.35 205.37 -4535.35 5975024.30 712732.18 4023.62 0.12 10200.00 40.57 268.11 8475.22 8420.22 203.33 -4600.46 5975020.37 712667.15 4083.50 0.20 10300.00 40.92 268.26 8550.98 8495.98 201.26 -4665.69 5975016.41 712602.01 4143.50 0.36 10400.00 40.83 268.12 8626.60 8571.60 199.19 -4731.10 5975012.45 712536.69 4203.65 0.13 10500.00 39.53 268.29 8703.00 8648.00 197.17 -4795.59 5975008.56 712472.29 4262.95 1.30 10600.00 37.98 268.00 8780.98 8725.98 195.15 -4858.15 5975004.73 712409.82 4320.51 1.56 10700.00 37.05 269.23 8860.30 8805.30 193.67 -4919.03 5975001.49 712349.01 4376.30 1.19 10765.00 36.39 269.55 8912.40 8857.40 193.26 -4957.89 5974999.95 712310.18 4411.70 1.06 10800.77 44.98 267.50 8939.50 8884.50 192.62 -4981.17 5974998.64 712286.92 4433.07 24.30 10829.08 55.16 265.70 8957.65 8902.65 191.31 -5002.81 5974996.70 712265.33 4453.24 36.29 10860.10 66.11 263.70 8972.84 8917.84 188.79 -5029.69 5974993.40 712238.55 4478.66 35.74 10888.80 76.57 262.00 8982.01 8927.01 185.40 -5056.63 5974989.23 712211.72 4504.51 36.87 10918.30 85.90 260.24 8986.50 8931.50 180.90 -5085.40 5974983.90 712183.09 4532.49 32.17 10948.06 89.25 258.85 8987.76 8932.76 175.50 -5114.63 5974977.66 712154.02 4561.26 12.19 10978.31 91.03 256.50 8987.68 8932.68 169.05 -5144.18 5974970.35 712124.68 4590.77 9.75 11009.13 91.58 254.43 8986.98 8931.98 161.31 -5174.01 5974961.76 712095.09 4621.07 6.95 11038.47 90.72 252.80 8986.39 8931.39 153.04 -5202.15 5974952.67 712067.20 4650.07 6.28 11070.59 89.80 249.28 8986.25 8931.25 142.60 -5232.52 5974941.36 712037.14 4682.01 11.33 11101.20 91.37 248.77 8985.94 8930.94 131.65 -5261.10 5974929.58 712008.90 4712.54 5.39 ObP . Baker Hughes INTEQ. Survey Report Map Coords B.. BAKØ HUGIll. --,------ INTEQ Company: BP Amoco Date: 1/17/2005 Time: 14:11 :55 Page: 4 Field: Lisbume Co-ordinate(NE) Reference: Well: L5-17, True North Site: Lis OS 05 Vertical (TVD) Reference: 10: 17 1/8/198900:0055.0 Well: L5-17 Section (VS) Reference: Well (O.OON,O.00E,245.00Azi) Wellpath: L5-17A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11130.53 93.89 248.19 8984.59 8929.59 120.90 -5288.35 5974918.05 711981.97 4741.78 8.82 11162.84 95.53 244.96 8981.94 8926.94 108.10 -5317.90 5974904.41 711952.81 4773.96 11.18 11192.53 97.40 245.52 8978.59 8923.59 95.75 -5344.68 5974891.28 711926.39 4803.46 6.57 11222.65 99.11 242.33 8974.27 8919.27 82.65 -5371.45 5974877.41 711900.01 4833.26 11.92 11252.00 99.31 239.36 8969.57 8914.57 68.54 -5396.75 5974862.57 711875.13 4862.15 10.01 11282.07 99.06 236.66 8964.77 8909.77 52.81 -5421.93 5974846.13 711850.43 4891.61 8.90 11319.36 101.46 233.08 8958.12 8903.12 31.71 -5451.93 5974824.16 711821.05 4927.73 11.43 11353.03 1 05.43 234.59 8950.30 8895.30 12.38 -5478.36 5974804.08 711795.19 4959.85 12.57 11384.13 107.76 231.93 8941.41 8886.41 -5.44 -5502.24 5974785.58 711771.84 4989.02 11.10 11412.02 108.85 229.36 8932.65 8877.65 -22.23 -5522.72 5974768.20 711751.86 5014.67 9.58 11437.46 109.85 226.59 8924.22 8869.22 -38.29 -5540.55 5974751.63 711734.50 5037.62 11.00 11466.23 112.30 226.12 8913.88 8858.88 -56.82 -5559.97 5974732.55 711715.62 5063.06 8.65 11499.33 114.71 223.64 8900.68 8845.68 -78.32 -5581.39 5974710.44 711694.84 5091.56 10.01 11530.68 118.39 226.90 8886.66 8831.66 -98.06 -5601.30 5974690.13 711675.51 5117.94 14.98 11562.32 121.90 223.20 8870.77 8815.77 -117.37 -5620.66 5974670.27 711656.71 5143.65 15.01 11592.91 123.79 229.05 8854.17 8799.17 -135.18 -5639.17 5974651.93 711638.73 5167.95 17.21 11627.97 123.93 240.28 8834.59 8779.59 -151.97 -5662.85 5974634.46 711615.54 5196.52 26.59 11657.44 124.38 248.15 8818.03 8763.03 -162.57 -5684.78 5974623.23 711593.93 5220.87 22.15 11695.36 124.04 257.08 8796.68 8741.68 -171.92 -5714.66 5974613.02 711564.34 5251.90 19.49 11729.25 116.63 257.91 8779.58 8724.58 -178.24 -5743.20 5974605.87 711536.00 528Q.43 21.97 11737.66 115.03 257.82 8775.91 8720.91 -179.83 -5750.60 5974604.07 711528.65 5287.81 19.05 11780.00 107.00 257.00 8760.74 8705.74 -188.45 -5789.14 5974594.34 711490.38 5326.38 19.05 lREE = _? WELLI-EAD = FM:: AClUATOR = AXELSON KB. B.BI = 55' BF. ElBl = KOP = 2900' M3x Angle = 124 @ 11657' D:llum MD = 10700' D:llum TV D = 8800' SS 10-3/4" COO, 45.5#, J.55,ID= 9.953" Minimum D = 2.313" @ 11621' 2-718" X NIPPLE 4-1/2" lBG, 12.6#, L-80, xxx bpf, 10=3.958" TOP OF 5-1/2" Lt-R 10480' 10284' 10293' 7-5'8" COO, 29.7#, L-80, ID= 6.875" TOPOFWHPSTOCK H 10766' I L5-17 A SAFETY NOTES: 900 @ 10978' CAT I SSSV H2S (PPM) 60. . 2075' 4-112" I-ES WB.LSTAR lRSSSV, 10 = 3.813" GAS UFT MANDRELS MD TVD DEV TYÆ VL V LA lCH 3508 3480 22 KBG-2 DOME BK 6042 5397 41 KBG-2 so BK 7377 6395 43 KBG-2 avtY BK 8745 7405 44 KBG-2 avtY BK 10104 8402 41 KBG-2 avtY BK 10172' 10193' 10217' 10225' 10229' 10284' , , ... , , , , , , ~ I I I I I I I I I I , , , , , , , , , ) I I I I I I I I 13-3/16" SOLID'PRE-I:JU.LEDLt-R, 6.4#, L-80, .0077 bpf, 10= 2.813" H 11564' I TOPOFCEMENT 9400 LBS OF 20/40 SAND, FCaD 11094' 11142' PERFORATION SUfvfl.1ARY REFLOO: Afo.GLEAT TOP~: NIA Note: Refer 10 R-oduction DB for hislorcal perf data SIZE SA" INlERII AL Opn/Sqz DATE FRE-DRlLLBJ 10735 - 11564 3-3/16" Lt-R 12/14/04 FRE-DRlLLBJ 11622 -11738 2-7/8"LNR 12/14/04 Œ@J-f 2-7/8" SOLIDIPRE-I:RILLED Lt-R, 6.16#, L-80, .0058 bpf, 10 = 2.440" 11738' 11752' 11780' 1 I I I I I I I DATE REV BY COMl..1ENTS 01/30/89 ORIGINÄL COM PlETION 07/16/91 WORKOVæ 12/15/04 JDMITLH CTDSDETRACK 12/21/04 GJBITLH GLV C,o DA 1E REV BY COM~S PORT [}6, 1E 16 12/21/04 20 12/21/04 o 12/15'04 o 12/15'04 o 12/15'04 4-1/2" HES X NIP,ID = 3.813" I MLLOUTWNDOIIV 10766' - 10771' 3-3/16" X 2-7/8" XO, 10 = 2.440" 2-7/~ SWELL A<R,ID = 2.992" 11621' 2-7/~ X NIP,ID= 2.313" LISBLRNE UNT WB.L: L5-17A ÆRMT No: ~042230 API No: 50-02~21889-01 SEC2, T11N, R15E. 44.68' FB. & 3263.64'FNL EIP fxploratlon (Alaska) · ~~~~Œ lID~ ~~~~[ß~ .. AI/ASIiA OIL AlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L5-17 A BP Exploration (Alaska) Inc. Permit No: 204-223 Surface Location: 1823' NSL, 155' WEL, SEC. 02, TllN, RI5E, UM Bottomhole Location: 1640' NSL, 610' WEL, SEC. 03, TIIN, RI5E, UM Dear Mr. Stagg, Enclosed is the approved application for permit to redrill the above development well. This permit to redrill 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. 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's petroleum field inspector at (907 65 (pager). BY ORDER 9f!HE COMMISSION DATED thiS'¡::day of November, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · .STATEOFALASKA. ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 WG+ i!/2{zoo1 OCT 2 8 2004 1a. Type of work o Drill fif Redrill rb. Current Well Class o Exploratory o Dew'~19~f]leqt,qil , 0 ,fv1ultipl~,Zone.. . ORe-Entry o Stratigraphic Test o Service o Dev~EiAt¡~S)&1!Sìtñgle li3:ôM'nJ;';SW 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name ãndít!kl~r: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU L5-17A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11732' TVD 8770' Prudhoe Bay Field I Lisburne 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 034631 1823' NSL, 155' WEL, SEC. 02, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 2019' NSL, 5015' WEL, SEC. 02, T11N, R15E, UM 11/21/04 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1640' NSL, 610' WEL, SEC. 03, T11N, R15E, UM 2560 14158' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 717271 y- 5974950 Zone- ASP4 (Height above GL): 55.0' feet 3490' away from L5-21 16. Deviated Wells: Kickoff Depth: 10770 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 124 deQrees Downhole: 3468 Surface: 2578 11¡s.(.;aT'ry~i ~~". , / / II Ip:"'··..·~ ...."'~·'ãôt Qin fc;t.orsaCKSr);/; // Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (includina staae data) 4-1/4" x 3-3/4" 3-3/16" x 2-7/8" 6.2# / 6.16# L-80 TCI//ST 1438' 10285' 8485' 11732' 8770' Uncemented Slotted Liner 119. PRESENT W¡::LLCONDITIONSUMMARY(TobåC()l'I1plet~forRadriUA.N[jRe,"eotJ'yOperªtioos) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 11142 9224 None 11050 9184 None E··;·<I';/ i/ ..,;;.,~ 181 TE <::t.. ,rot. "",I Conductor 115' 20" 2150# Poleset 115' 115' ~I ¡rf¡:¡r.p. 4250' 10-3/4" 1600 sx AS III, 350 sx Class 'G' 4250' 4089' Inter TOD ìob 150 sx AS I Produr.tjon 10480' 7-5/8" 325 sx Class 'G' 10480' 8688' Liner 847' 5-1/2" 150 sx Class 'G' 10293' - 11140' 8546' - 9223' Perforation Depth MD (ft): 10635' - 10990' IPerfOration Depth TVD (ft): 8809' - 9097' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer / )' 1'. ..... . Prepared By Name/Number: Permit To Drill API Number: Permit Approval See cover letter for Number: 2.04' - 2-2 50- 029-21889-01-00 Date: ;;7~.kGl" other requirements Conditions of Approval: Samples Required DYes ,Ø'No Mud Log Requiréd { o Yes ~No Hydrogen Sulfide Measures .ßfYes 0 No Directional Survey Required ::aves 0 No Other: Té.:·~t- ßOP~CO pst' i ~~ OR\G\NAL // !#tl/ - APPROVED BY AODrov1.Ln. : THE COMMISSION Date Form 10-401 RÊwised1Ì6/2004'-'" "- f¥1bm~ In l1uplicate . . BP L5-17A RWO/CTD Sidetrack Summary of Operations: Well L5-17 is scheduled for a through tubing sidetrack with coiled tubing. Prior to CTD sidetracking, the 2 7/8" tubing and packer will be recovered and new 4 Y2" tubing and packer will be installed per the proposed schematic. The sidetrack, L5-17 A, will kick off from a window milled from a mechanical whipstock set in Lisburne Zone 5 and will target Lisburne Zones 5 and 6. Approximately 962 ft of 3.75"-4 118" open hole is planned to access the target. The well will be completed with a 3 3/16"x 217/8" pre-drilled, un-cemented liner. A "Swell Packer" will be installed on the pre-drilled liner to facilitate shut-off of production from the distal end of the sidetrack, if needed. Pre-rig work: See Sundry 10-403 filed for this job. Nordic 2 RWO - Tubing swap: Planned for Nov. 21, 2004 1. RU Nordic 2 with 11" BOPE. Test stack. 2. Pull 2 7/8" tubing. Recover 2 7/8" packer and tailpipe. 3. Install 4 Y2" tubing with packer, 5 GLMs, TRSSSV and 41116" tree. 4. PT completion. / Nordic 2 CTD - Underream liner, Set Whipstock, Mill window, Drill and Complete sidetrack: 1. NU 7-1116" CTD BOPE. Test. 2. Underream 5 Y2" liner, run PDS calliper log. . 3. Set mechanical whipstock at approx. 10,755' MD (8,845'ss)~ 4. Mill 3.80" window in 7" liner. 5. Directionally drill-962' of 3.75"-4 118" open hole (planned TD 11,723' MD, 8770ss). 6. Log open hole with GRlResistivity/Density/NeutronlSonic. / 7. Run 3 3/16" x 2 7/8" pre-drilled liner wi Swell Packer from TD to approx. 10,285' MD (8485'ss). 8. Displace well to diesel. RD Nordic 2. Mud Program: · RWO: 2% KCI and 2ppb Biozan. · CTD: PIo-Pro (8.6 - 8.7 ppg). Viscosified 6% KCI will be used for drilling if losses are total. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 1,438ft of 3 3/16"x 2 7/8" slotted, un-cemented liner with one Swell Packer to be located in upper Zone 5. Well Control: · BOP diagrams are attached. · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is approx. -124 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. A full suite of memory open hole logs will be run at TD consisting of GRlResistivity/Sonic/Density/Neutron. . . Hazards · L5 is not an H2S Pad. Most wells on L5 Pad measure between 20 and 35 ppm H2S in produced fluids. · Lost circulation risk is considered moderate. Drilling may be done with viscosified water if losses are total. Reservoir Pressure · Pore pressure was measured on 10/14/04 to be 3468 psi at 8900'TVDss (7.5 ppg). · Maximum surface pressure with gas (0.1 psilft) to surface is 2578 psi. I SAFElY NOlES: CAT ISSSV H2S (PRv1) 60. I 1REE = WELLHEAD = ACTUA TOR = KB. B..EV = BF. B..EV - KOP= Max Angle = Datum MD = Datum TVD- _? FI\C AXELSON 55' L5-17 2900' 45 9100' 10693' 8800'SS 2124' -13-1/2"AVA13Œ1RSSSV,ID-2.812" . c ST fvD TVD FORT DATE 2 2850 2849 3 5631 5091 4 7915 6789 5 9508 7954 6 10133 8424 Minimum ID = 2.205"@ 10344' OTIS XN NIPPLE 10-3/4" CSG, 45.5#, J-55, ID = 9.953" 13-1/2" 1BG-IPC, 9.3#, L-80, .0073 bpf, D = 2.992" TOP OF 2-718" 1BG-IPC 10245' 31/2" X 2718" XO 10258' BAKER FBRSEAL ASSY, ID =2.34" 10275' -17-5/8" X 2 718" BKR HB PKR, ID = 2.34" I TOP OF 5-1/2" LNR 27/8" 011S XN NIP, ID =2.313", WINO GO, ID = 2.205" 10355' -127/8" BAKER WLET/TLBING TAIL I 10355' HELMDTTLOGGBJ 08/08/91 I 10344' 10355' 2-7/8" TBG, 6.5#, L-80, 0.00579 bpf, D = 2.441" 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ÆRFORA 110N Sl1IIIfIN\. RY REF LOG: LT/CNL 50S ON 01/24/89 ANGLE AT TOP PERF: 39 @ 10540' Note: Refer to Production œ for historical perf data SIZE SFF INlERVAL Opn/Sqz DATE 2-1/8" 1 10540-10584 S 02/15/89 2-1/8" 1 10608-10634 S 02/15/89 2-1/8" 1 10635-10730 0 02/15/89 2-1/8" 4 10730-10750 0 07/01/96 2-1/8" 4 10775-10868 0 07/01/96 2-1/8" 4 10880-10990 0 06/30/96 9400 LBS OF 20/40 SAND, FOO'D 11050' 11094' 11142' 5-1/2" LNR, 17#, L-80, 0.0232 bpf, ID = 4.892" LISBURNE UNIT WELL: L5-17 PERMIT I'b: 88-139 AA f\b: 50-029-21889-00 SEC 2, T11N, R15E 44.68 FB.. 3263.64 FN... BP Exploration (Alaska) [)\lE REV BY COMfvENTS DATE REV BY COMfvENTS 01/30/89 ORIGINAL COMR..EnON 10/02/01 Ri'-VTP OORRECTIONS 07116/91 WORK OVER 11/01/01 GROtlh fIN\. Y 2000 MLL CMf,FCO SAN 01/05101 SIS-CS CONVERlED TO CANV AS 03102101 SIS-LG FINAL TREE '" WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= ? FMC AXELSON 55' 2900' 45 @ 9100' 10693' 8800'SS 10-3/4" CSG, 45.5#, J-55, ID = 9.953" I TOPOF 5-1/2" LNR I 17-5/8" CSG, 29.7#, L-80, 10 = 6.875" I . . I SAFETY NOTES: CAT I SSSV H2S (PPM) 60. I L5-17 A Proposed Completion . 4 1/2" TRSSSV 4 GlMs 4 1/2" Half Muleshoe 1 jt. into 5 1/2" liner 4 1/2" x 7 5/8" Packer 4 1/2" Tailpipe wI X Nipple 33/16" Liner 11094' "- 2 7/8" Pre-Drilled liner ~x Nipple (2.313") "'- SWEll Packer Whipstock to be set at 10,770 at top of Zone 5. REV BY COMMENTS ORIGINAL COMA-ETION WORK OVER SIS-CS CONVERTED TO CANV AS SIS-LG FINAL \ 3 3/16" Pre-Drilled liner 11050' -19400 LBS OF 20/40 SAND, FCO'D I 15-1/2" LNR, 17#, L-80, 0.0232 bpf, ID = 4.892" , PBTD I 11142' DA TE REV BY COMMENTS 10/02/01 RNITP CORRECTIONS 11/01/01 GRCltlh MAY 2000 MILL CMT,FCO SAN LISBURNE UNIT WELL: L5-17 PERMIT No: 88-139 API No: 50-029-21889-00 SEC2, T11N, R15E 44.68 FEL 3263.64 FNL BP Exploration (Alaska) DATE 01/30/89 07/16/91 01/05/01 03/02/01 . BP-GDB Baker Hughes INTEQ Planning Report . Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: Lis OS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5969995.70 ft 712359.13 ft Latitude: 70 19 Longitude: 148 16 North Reference: Grid Convergence: 15.771 N 41.402 W True 1.62 deg Well: L5-17 Slot Name: 17 L5-17 Well Position: +N/-S 4813.97 ft Northing: 5974950.40 ft Latitude: 70 20 3.099 N +E/-W 5050.70 ft Easting : 717271.36 ft Longitude: 148 14 13.914 W Position Uncertainty: 0.00 ft Wellpath: Plan#115 L5-17A 500292188901 Current Datum: 10: 171/8/198900:00 Magnetic Data: 10/21/2004 Field Strength: 57641 nT Vertical Section: Depth From (TVD) ft 35.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L5-17 10700.00 ft Mean Sea Level 25.24 deg 80.91 deg Direction deg 245.00 Height 55.00 ft Targets L5-17A Polygon115.1 0.00 87.08 -5883.59 5974867.00 711387.99 70 20 3.933 N 148 17 5.727 W -Polygon 1 0.00 87.08 -5883.59 5974867.00 711387.99 70 20 3.933 N 148 17 5.727 W -Polygon 2 0.00 -381.54 -5628.05 5974406.00 711656.99 70 19 59.326 N 148 16 58.254 W -Polygon 3 0.00 -41.19 -5047.92 5974763.00 712226.99 70 20 2.677 N 148 16 41.321 W -Polygon 4 0.00 418.97 -5287.70 5975216.00 711973.99 70 20 7.201 N 148 16 48.332 W L5-17A Fault 0 0.00 -398.41 -6841.10 5974354.00 710444.98 70 19 59.150 N 148 17 33.675 W -Polygon 1 0.00 -398.41 -6841.10 5974354.00 710444.98 70 1959.150N 148 17 33.675 W -Polygon 2 0.00 -370.90 -6582.19 5974389.00 710702.98 70 19 59.423 N 148 1726.115 W -Polygon 3 0.00 -592.28 -6434.53 5974172.00 710856.98 70 19 57.247 N 148 1721.798 W -Polygon 4 0.00 -609.04 -6097.86 5974165.00 711193.98 70 19 57.085 N 148 1711.967 W -Polygon 5 0.00 -770.53 -5945.47 5974008.00 711350.98 70 19 55.498 N 148 17 7.514 W -Polygon 6 0.00 -807.91 -5622.40 5973980.00 711674.98 70 19 55.133 N 148 16 58.080 W -Polygon 7 0.00 -713.16 -5301.50 5974084.00 711992.98 70 19 56.067 N 148 16 48.712 W -Polygon 8 0.00 -759.50 -5117.76 5974043.00 712177.98 70 19 55.612 N 148 16 43.346 W -Polygon 9 0.00 -950.45 -4950.21 5973857.00 712350.98 70 19 53.735 N 148 16 38.450 W -Polygon 10 0.00 -803.79 -4797.89 5974008.00 712498.98 70 1955.179N 148 16 34.005 W -Polygon 11 0.00 -768.16 -4611.78 5974049.00 712683.98 70 19 55.530 N 148 16 28.572 W -Polygon 12 0.00 -778.45 -4464.00 5974043.00 712831.98 70 19 55.430 N 148 16 24.257 W -Polygon 13 0.00 -639.08 -4301.89 5974187.00 712989.98 70 19 56.802 N 148 16 19.526 W -Polygon 14 0.00 -684.16 -4127.12 5974147.00 713165.98 70 19 56.359 N 148 16 14.422 W -Polygon 15 0.00 -617.20 -3952.10 5974219.00 713338.98 70 19 57.019 N 148 16 9.312 W -Polygon 16 0.00 -476.81 -3790.95 5974364.00 713495.98 70 19 58.400 N 148 16 4.609 W -Polygon 17 0.00 -313.72 -3446.07 5974537.00 713835.98 70 20 0.006 N 148 15 54.541 W -Polygon 18 0.00 -287.47 -3178.18 5974571.00 714102.98 70 20 0.265 N 148 15 46.719 W -Polygon 19 0.00 -279.31 -2803.77 5974590.00 714476.98 70 20 0.347 N 148 15 35.786 W -Polygon 20 0.00 -353.47 -2626.84 5974521.00 714655.98 70 19 59.618 N 148 15 30.618 W -Polygon 21 0.00 -279.31 -2803.77 5974590.00 714476.98 70 20 0.347 N 148 15 35.786 W -Polygon 22 0.00 -287.47 -3178.18 5974571.00 714102.98 70 20 0.265 N 148 15 46.719 W -Polygon 23 0.00 -313.72 -3446.07 5974537.00 713835.98 70 20 0.006 N 148 15 54.541 W -Polygon 24 0.00 -476.81 -3790.95 5974364.00 713495.98 70 19 58.400 N 148 16 4.609 W -Polygon 25 0.00 -617.20 -3952.10 5974219.00 713338.98 70 19 57.019 N 148 16 9.312 W . . BP-GDB Baker Hughes INTEQ Planning Report -Polygon 26 0.00 -684.16 -4127.12 5974147.00 713165.98 70 19 56.359 N 148 16 14.422 W -Polygon 27 0.00 -639.08 -4301.89 5974187.00 712989.98 70 19 56.802 N 148 16 19.526 W -Polygon 28 0.00 -778.45 -4464.00 5974043.00 712831.98 70 19 55.430 N 148 1624.257 W -Polygon 29 0.00 -768.16 -4611.78 5974049.00 712683.98 70 19 55.530 N 148 16 28.572 W -Polygon 30 0.00 -803.79 -4797.89 5974008.00 712498.98 70 19 55.179 N 148 16 34.005 W -Polygon 31 0.00 -950.45 -4950.21 5973857.00 712350.98 70 19 53.735 N 148 16 38.450 W -Polygon 32 0.00 -759.50 -5117.76 5974043.00 712177.98 70 19 55.612 N 148 16 43.346 W -Polygon 33 0.00 -713.16 -5301.50 5974084.00 711992.98 70 19 56.067 N 148 16 48.712 W -Polygon 34 0.00 -807.91 -5622.40 5973980.00 711674.98 70 19 55.133 N 148 16 58.080 W -Polygon 35 0.00 -770.53 -5945.47 5974008.00 711350.98 70 19 55.498 N 148 17 7.514 W -Polygon 36 0.00 -609.04 -6097.86 5974165.00 711193.98 70 19 57.085 N 148 17 11.967 W -Polygon 37 0.00 -592.28 -6434.53 5974172.00 710856.98 70 19 57.247 N 148 1721.798 W -Polygon 38 0.00 -370.90 -6582.19 5974389.00 710702.98 70 19 59.423 N 148 1726.115 W L5-17A T115.2 8770.00 -159.12 -5742.66 5974625.00 711535.99 70 20 1.512 N 148 17 1.605 W L5-17A T115.1 8862.00 192.40 -4961.11 5974999.00 712306.99 70 20 4.975 N 148 16 38.790 W Annotation 10700.00 10770.00 10790.00 10945.00 11125.00 11320.00 11590.00 11732.00 10707.14 10752.07 10759.53 10801.31 10858.35 11008.00 11241.00 11431.00 11446.00 11526.00 11611.00 11634.00 11646.00 11666.00 11696.00 8805.30 8861.43 8877.35 8940.57 8935.34 8929.68 8848.45 8770.35 8811.00 8847.00 8853.00 8886.00 8921.00 8938.64 8932.08 8913.60 8909.51 8880.34 8836.79 8824.03 8817.38 8806.33 8789.86 TIP KOP end 9 DLS / begin 35 DLS end 35 DLS / begin 12 DLS 5 6 7 TO Wahoo Z6.1.2 Z6.1.1 Mudstone Z5.3 Upper Z5.2 TZ5.1.2 TZ5.1.2 TZ5.2 TZ5.3 TZ6.1.1 TZ6.1.2 TZ6.2 BZ6.3 Mudstone TZ6.3 Mudstone TZ6.3 TZ7.1 Plan: Plan #115 Similar to Ted's Case115 Principal: Yes Date Composed: Version: Tied-to: 10/21/2004 1 From: Definitive Path Plan Section Information 10700.00 37.05 269.23 8805.30 193.67 -4919.03 0.00 0.00 0.00 0.00 10770.00 36.34 269.58 8861 .43 193.23 -4960.85 1.06 -1.01 0.50 163.73 10790.00 38.14 269.58 8877.35 193.15 -4972.96 9.00 9.00 0.00 360.00 10945.00 91.79 269.58 8940.57 192.15 -5108.32 34.61 34.61 0.00 0.00 11125.00 91.50 247.95 8935.34 157.30 -5283.74 12.01 -0.16 -12.02 269.55 11320.00 91.78 224.52 8929.68 49.73 -5444.66 12.01 0.14 -12.02 271.02 11590.00 123.68 230.50 8848.45 -122.55 -5630.94 12.00 11.81 2.21 9.31 11732.00 122.50 250.82 8770.35 -180.23 -5733.85 12.00 -0.83 14.31 88.34 . BP-GDB Baker Hughes INTEQ Planning Report . 10759.53 36.45 269.53 8853.00 193.28 -4954.64 5975000.07 712313.42 4408.75 1.06 163.52 10770.00 36.34 269.58 8861.43 193.23 -4960.85 5974999.84 712307.22 4414.40 1.06 163.49 10770.71 36.40 269.58 8862.00 193.23 -4961.28 5974999.82 712306.80 4414.78 9.00 360.00 10775.00 36.79 269.58 8865.44 193.21 -4963.83 5974999.73 712304.24 4417.10 9.00 360.00 10790.00 38.14 269.58 8877.35 193.15 -4972.96 5974999.40 712295.12 4425.40 9.00 360.00 10800.00 41.60 269.58 8885.02 193.10 -4979.37 5974999.17 712288.72 4431.23 34.61 0.00 10801.31 42.06 269.58 8886.00 193.09 -4980.24 5974999.14 712287.84 4432.03 34.61 360.00 10825.00 50.25 269.58 8902.39 192.97 -4997.31 5974998.52 712270.79 4447.55 34.61 0.00 10850.00 58.91 269.58 8916.87 192.82 -5017.66 5974997.78 712250.45 4466.06 34.61 0.00 10858.35 61.80 269.58 8921.00 192.77 -5024.92 5974997.51 712243.19 4472.66 34.61 0.00 10875.00 67.56 269.58 8928.12 192.65 -5039.96 5974996.97 712228.16 4486.34 34.61 0.00 MWD 10900.00 76.21 269.58 8935.88 192.48 -5063.70 5974996.11 712204.44 4507.93 34.61 360.00 MWD 10925.00 84.87 269.58 8939.99 192.30 -5088.34 5974995.21 712179.82 4530.33 34.61 360.00 MWD 10945.00 91.79 269.58 8940.57 192.15 -5108.32 5974994.49 712159.86 4548.50 34.61 0.00 end 35 10950.00 91.79 268.98 8940.41 192.09 -5113.31 5974994.28 712154.86 4553.05 12.01 269.55 MWD 10975.00 91.76 265.97 8939.64 190.99 -5138.27 5974992.46 712129.95 4576.14 12.01 269.54 MWD 11000.00 91.73 262.97 8938.88 188.58 -5163.14 5974989.33 712105.16 4599.70 12.01 269.44 MWD 11008.00 91.72 262.01 8938.64 187.54 -5171.07 5974988.06 712097.26 4607.32 12.01 269.35 TZ5.1. 11025.00 91.69 259.97 8938.13 184.88 -5187.85 5974984.91 712080.57 4623.66 12.01 269.32 MWD 11050.00 91.65 256.96 8937.41 179.88 -5212.33 5974979.21 712056.24 4647.96 12.01 269.26 MWD 11075.00 91.60 253.96 8936.70 173.61 -5236.52 5974972.24 712032.25 4672.53 12.01 269.17 MWD 11100.00 91.55 250.95 8936.01 166.07 -5260.35 5974964.02 712008.65 4697.31 12.01 269.09 MWD 11125.00 91.50 247.95 8935.34 157.30 -5283.74 5974954.57 711985.52 4722.22 12.01 269.01 5 11150.00 91.55 244.95 8934.67 147.32 -5306.65 5974943.93 711962.91 4747.20 12.01 271.02 MWD 11175.00 91.60 241.94 8933.99 136.15 -5329.00 5974932.12 711940.89 4772.18 12.01 270.94 MWD 11200.00 91.64 238.94 8933.28 123.82 -5350.74 5974919.16 711919.53 4797.09 12.01 270.85 MWD 11225.00 91.68 235.94 8932.56 110.37 -5371.80 5974905.11 711898.87 4821.86 12.01 270.77 MWD 11241.00 91.70 234.01 8932.08 101.19 -5384.89 5974895.56 711886.04 4837.60 12.01 270.68 TZ5.2 11250.00 91.71 232.93 8931.82 95.84 -5392.12 5974890.00 711878.97 4846.42 12.01 270.62 MWD 11275.00 91.74 229.93 8931.06 80.26 -5411.66 5974873.86 711859.90 4870.71 12.01 270.59 MWD 11300.00 91.76 226.92 8930.30 63.68 -5430.35 5974856.75 711841.70 4894.65 12.01 270.50 MWD 11320.00 91.78 224.52 8929.68 49.73 -5444.66 5974842.38 711827.80 4913.52 12.01 270.41 6 11325.00 92.37 224.62 8929.50 46.17 -5448.17 5974838.72 711824.39 4918.20 12.00 9.31 MWD 11350.00 95.33 225.10 8927.82 28.49 -5465.76 5974820.54 711807.32 4941.62 12.00 9.32 MWD 11375.00 98.29 225.60 8924.86 11.04 -5483.42 5974802.60 711790.18 4965.00 12.00 9.35 MWD 11400.00 101.25 226.10 8920.61 -6.12 -5501.09 5974784.93 711773.01 4988.27 12.00 9.41 MWD 11425.00 104.21 226.61 8915.11 -22.95 -5518.73 5974767.60 711755.86 5011.37 12.00 9.49 MWD 11431.00 104.91 226.73 8913.60 -26.93 -5522.96 5974763.49 711751.75 5016.88 12.00 9.61 TZ5.3 11446.00 106.69 227.05 8909.51 -36.79 -5533.49 5974753.33 711741.51 5030.60 12.00 9.64 TZ6.1. 11450.00 107.16 227.13 8908.35 -39.40 -5536.30 5974750.64 711738.78 5034.24 12.00 9.72 MWD 11475.00 110.12 227.67 8900.36 -55.43 -5553.73 5974734.11 711721.82 5056.82 12.00 9.75 MWD 11500.00 113.07 228.23 8891.16 -71.00 -5570.99 5974718.05 711705.02 5079.04 12.00 9.92 MWD 11525.00 116.02 228.82 8880.78 -86.06 -5588.03 5974702.51 711688.43 5100.84 12.00 10.13 MWD 11526.00 116.14 228.84 8880.34 -86.65 -5588.70 5974701.89 711687.77 5101.70 12.00 10.37 TZ6.1. 11550.00 118.97 229.44 8869.24 -100.57 -5604.79 5974687.51 711672.09 5122.17 12.00 10.38 MWD 11575.00 121.91 230.09 8856.57 -114.50 -5621.24 5974673.12 711656.05 5142.96 12.00 10.66 MWD 11590.00 123.68 230.50 8848.45 -122.55 -5630.94 5974664.79 711646.59 5155.16 12.00 10.99 7 11600.00 123.71 231.94 8842.90 -127.76 -5637.43 5974659.39 711640.26 5163.24 12.00 88.34 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 11634.00 123.67 236.84 8824.03 -144.23 -566D.42 5974642.27 711617.76 5191.03 12.00 91.14 BZ6.3 11646.00 123.61 238.57 8817.38 -149.56 -5668.86 5974636.69 711609.47 5200.94 12.00 91.86 TZ6.3 11650.00 123.59 239.15 8815.17 -151.28 -5671.71 5974634.89 711606.67 5204.25 12.00 92.81 MWD 11666.00 123.46 241.45 8806.33 -157.89 -5683.30 5974627.95 711595.28 5217.55 12.00 93.13 TZ6.3 11675.00 123.37 242.74 8801.38 -161.41 -5689.94 5974624.24 711588.75 5225.05 12.00 94.40 MWD 11696.00 123.11 245.73 8789.86 -169.04 -5705.75 5974616.15 711573.16 5242.61 12.00 95.11 TZ7.1 11700.00 123.05 246.30 8787.68 -170.40 -5708.81 5974614.70 711570.14 5245.96 12.00 96.75 MWD 11725.00 122.63 249.84 8774.12 -178.25 -5728.29 5974606.30 711550.90 5266.93 12.00 97.06 MWD 11732.00 122.50 250.82 8770.35 -180.23 -5733.85 5974604.16 711545.40 5272.80 12.00 98.98 TO . Plan: Plan #115 (L5--17/Plan#115 Ls..17A) Created By: Brlj Potnls Date: 1012112004 COnu.1ct !r¡fom~atio; Dìt6(;t (907) 564~4102 E-maiI;PotnisBP@BP.mm ¡NTEQ; (eO?) 267~f¡(:>OO Hughes 8akid¡ Azimuths to True North Magnetic North: 25.24' Magnetic Field Strength: 57641nT Dip Angle: 80.91' Date: 10/21/2004 Model: bggm2004 T l LEGEND L5-17(L5-17) -- Plan#115l5-17A .... .5 i: = = ... ..... - + - .c 1:: o z- - - . , --. .c .. :s -300 o en BP Amoco waLLPATH DETAILS PIa"Ø11a LI-17A SOO2121"1Ht1 P_tW.II.-th, La.17 T"o.MD, 10700.00 .... 10,171/1/1", 00100 1f.8Oft ....-... V.s.aø... ~~ C::J!t; :::::~ ...10 US.o.· .... .... 35.00 REFERENCE INFORMATION Co-ordinate (N/E~ Reference: Well Centre: L&.17, True North v;:~g ~:::~~~~ ~~t~'r~ ~~~ÖN~g~Õ~)el Measured Depth Reference: 10: 171/81198900:00 55.00 Calculation Method: Minimum Curvature SRTION DI!TAlU ... M' ,~ AD TVI ..... ..,." ..... """ -..... 1 10700.00 37.05 HO.23 88OL30 103,87 ""8.03 ... 0.00 4a7a.30 2 10770.00 3e.M ZtlLU 8881.43 1113.23 .......u 1M 183.73 "'.... 3 10780.00 3&.1.. 2e8.SI "77.35 '83.15 -4872." 8.00 380.00 44H.4O .. 1084$.00 ".79 208.51 Ø40.57 182.11:1 -5101L32 34.81 0.00 a4&.5Q 5 1112LOO 111.110 247.88 8835.34 157.30 -ue:t.74 12.01 2t111.1I5 4722.22 8 11320.00 lI1.n 224.52 -._ 40.73 -M4t.1MI 12.01 271.02 ...... 711580.0012:1._ 230..50 884&.411 .122.N -5830.84 12.00 ." 5111&18 8 11732.00122.50 250.82 8770.38 -1ao.z:s -5733.U 12.00 "'34 5272.80 ANNOTATIONS TAAGETDETAlLS 1VD MD ........11.. N.",. "'" +NI-5 +EI-W St.pe '.30 10700.00 TIP t~mt~"6., 877g:~ :m:tl :!FJ:5 ~ 1063 10770.00 KOP L6-17AT15.1 8862.00 1112.40-491'11.11 Point 7.3'10710.00 .1MI.DI.$I....1 0"71ot41.o0 .... 31 DLS I bot ..3411111.00 I ....11310.00 . .M11...'OO 7 0.31 U73I.o0 TD '.0010707.14 w..... Z'.1.1 7.0010712.07 Z'.1.1 M.d.... :s.oo 107".53 ZI.3 r::: ~::G:f: ¥1~;':'.2 ............._ 77.... "32.0'11241.00 TZS.Z "13... 11431.00 TZI.3 a....5111441.o. TZL'.1 '''0.34 115za.oo TZt.1.2 '13'.7111'11.00 TZI.Z 1124.D3 11.34.00 1IZt.3 Mud.... "17.3'11141.0. TZI.3 M8Út_. .....33 11....00 TZ'.3 .78....11....00 TZ7.1 . PM 4900 49~0 4¡},¡0 49~0 49!80 5000 5020 5~0 5060 5080 51 ~O -6200-6100-6000-5900-5800-5700-5600 -5500 -5400-5300 -5200-51 00-5000-4900 -4800 45160 4580 4600 46~0 46~0 46'60 4680 4700 4720 4740 4760 478~ 4800 4d2'0 48~0 4860 Vertical Section at 245.00· [20ft/in] ....a7i e i!881 = £!a8: .c D,8840 & C88, ¡ U88 :e &891 > &89' ë ' ~89 P!¡¡n1l1l5L5-17A 500292188901 LS-17 10700.00 Pare~j:~IM~: Rig: Ref. Datum: V.Section An". 245.00· Tool MWD SURVEY PROGRAM SurveyfPlan ~:PIenB5Vl Ikpth Fm Depth To I0700.00tt732.00 COMPANY DETAILS BP^,- CalculatiOfl Method: Minirnwn Ctuvature =~=; ~~¿~inderNor1h En'orSurfiIce: Elliptica1+Ca&ing Warning Method: Rules Based ANTI-COLLISION SETTINGS InterpoIarion MethodMD + Statmn.rva1: 10.00 Depth Range From: 10770.00 To: 11732.00 Maximwn Range: 1369.70 Reference: Plan: Plan #115 SM t7 Longitude L8titude WELL DETAILS ....... N"""",, +EI-W +N/-S N~ :171/81198900:00 55.00ft Origin starting +EJ-W FromlVD 0.00 35.00 . . Origin +NI-S 0.00 LEGEND L5-l7 (L5-l7), NOERRORS Plan#1l5 L5-l7A Plan #115 HAl HUGHESi -- Dale'_ 0.<- CrœtedBy.BrijP",,,... 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'i;. ...........: ......:.:;.;>.: .~/.x // i/:" .:-'::....~ .................................................., ...s.:·.···» ~t\':'l?j?T::- .......... ~·'\r/;>c:;. ::2·:~·..!i\ .................................... . ··~""\·.;·\..·..·\.:0::i:J ~ 2~\r······\Sfr~····:··································.\~::.:..\~ ~'2:jF ... ....... .. ...... .... i/./.~ ~:...;..,....,.......... o -326 ----300 -250 -200 --150 -100 --100 50 '--200 ---250 --50 -0 -50 INTEQ PM .T 4376.30 4414.40 442"-40 4548.50 4722.22 4913.52 ~]5S.]6 52n.&O V/£ I/£VV.. TF~ 0.00 163.73 160.00 0.00 269.5~ m.02 9.31 88,34 Dl... !:~ 34.61 12.01 12.01 12.00 11.00 :cnON DETAILS +Nr-g +EI·W 193.67 -4919.03 193.23 -4%0.85 193.1S -4972.96 192.\5 ·S\ð3.32 157.30 -5283.74 49.13 -5444.66 -122.S~ -5630.94 -180.23 -573.U~ A.; TVD 269.23 8860.30 269.~8 89]6.43 269.58 8932.35 269.SIt 8995.51 247.95 8990.34 224.52 8984.68 230.50 8903.45 250.82 8825.35 loc 37.05 36.34 38.14 9\.79 9UO 91.78 23.68 22.50 MD 0700.00 0770.00 0790.00 0945JII} 112'-00 1320.00 t~90.00 1732.00 So' I , ¡ , ~ , 180 Travelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation n OOft/in] '--300 -326 · . Plan: Plan #115 (L5-17/Plan#115 L5-17 A) r--'"'I ¢:: ~ ~ o .- -+-> Cd $-; Cd P.t (]) r./J. ~ ~ (]) u o -+-> (]) .l:J ~ (]) u 10600 10800 11000 11200 11400 11600 11800 Measured Depth [ft] I - L5-17 (L5-17) . BP-GDB Anticollision Report . M 4250.00 10480.00 10770.00 11732.00 4088.94 8687.60 8916.43 8825.35 10.750 7.625 5.500 2.875 12.250 8.500 6.000 3.750 103/4" 75/8" 5 1/2" 2 7/8" Plan: Plan #115 Similar to Ted's Case115 Principal: Yes Date Composed: Version: Tied-to: 10/21/2004 1 From: Definitive Path Summary 10770.00 8916.43 10770.00 8916.43 36.58 36.75 269.58 0.00 5.500 0.00 0.00 0.00 Pass 10780.00 8924.43 10780.00 8924.49 36.58 36.79 269.58 0.00 5.500 0.09 0.00 0.09 Pass 10789.99 8932.34 10790.00 8932.56 36.58 36.84 88.12 178.54 5.500 0.35 0.00 0.35 Pass 10799.93 8939.97 10800.00 8940.64 36.58 36.89 88.35 178.77 5.500 1.01 0.00 1.01 Pass 10809.75 8947.12 10810.00 8948.74 36.58 36.93 88.60 179.02 5.500 2.29 0.00 2.29 Pass 10819.39 8953.73 10820.00 8956.84 36.58 36.97 88.75 179.17 5.500 4.16 0.00 4.16 Pass 10828.78 8959.78 10830.00 8964.96 36.58 37.02 88.84 179.26 5.500 6.62 0.00 6.62 Pass 10837.87 8965.23 10840.00 8973.10 36.59 37.07 88.90 179.32 5.500 9.64 0.00 9.64 Pass 10846.61 8970.09 10850.00 8981.24 36.59 37.11 88.94 179.36 5.500 13.19 0.00 13.19 Pass 10854.99 8974.38 10860.00 8989.40 36.59 37.16 88.97 179.39 5.500 17.24 0.00 17.24 Pass 10862.97 8978.13 10870.00 8997.58 36.59 37.20 88.99 179.41 5.500 21.75 0.00 21.75 Pass 10870.55 8981.37 10880.00 9005.76 36.60 37.25 89.01 179.43 5.500 26.70 0.00 26.70 Pass 10877.73 8984.14 10890.00 9013.96 36.60 37.29 89.02 179.44 5.500 32.05 0.00 32.05 Pass 10884.51 8986.49 10900.00 9022.17 36.61 37.34 89.02 179.44 5.500 37.77 0.00 37.77 Pass 10890.89 8988.47 10910.00 9030.40 36.61 37.39 89.03 179.45 5.500 43.83 0.00 43.83 Pass 10896.89 8990.11 10920.00 9038.64 36.61 37.43 89.04 179.46 5.500 50.20 0.00 50.20 Pass 10902.54 8991.47 10930.00 9046.88 36.62 37.48 89.04 179.46 5.500 56.86 0.00 56.86 Pass 10907.83 8992.57 10940.00 9055.15 36.62 37.53 89.05 179.47 5.500 63.77 0.00 63.77 Pass 10912.80 8993.45 10950.00 9063.42 36.63 37.57 89.06 179.48 5.500 70.92 0.00 70.92 Pass 10917.47 8994.14 10960.00 9071.71 36.63 37.62 89.06 179.48 5.500 78.28 0.00 78.28 Pass 10921.85 8994.67 10970.00 9080.00 36.64 37.66 89.07 179.49 5.500 85.84 0.00 85.84 Pass 10925.96 8995.07 10980.00 9088.32 36.64 37.71 89.07 179.49 5.500 93.58 0.00 93.58 Pass 10929.81 8995.35 10990.00 9096.64 36.65 37.76 89.08 179.50 5.500 101.48 0.00 101.48 Pass 10933.43 8995.53 11000.00 9104.97 36.65 37.80 89.08 179.50 5.500 109.53 0.00 109.53 Pass 10936.84 8995.62 11010.00 9113.32 36.65 37.85 89.09 179.51 5.500 117.72 0.00 117.72 Pass 10940.05 8995.65 11020.00 9121.67 36.66 37.90 89.09 179.51 5.500 126.02 0.00 126.02 Pass 10943.07 8995.62 11030.00 9130.03 36.66 37.94 89.09 179.51 5.500 134.44 0.00 134 .44 Pass 10946.71 8995.52 11040.00 9138.40 36.66 37.98 88.88 179.51 5.500 142.96 0.00 142.96 Pass 10951.91 8995.35 11050.00 9146.77 36.65 38.01 88.22 179.47 5.500 151.50 0.00 151.50 Pass . BP-GDB Anticollision Report . 10957.10 8995.19 11060.00 9155.16 36.63 38.04 87.55 179.42 5.500 160.05 0.00 160.05 Pass 10962.26 8995.03 11070.00 9163.55 36.61 38.06 86.86 179.35 5.500 168.60 0.00 168.60 Pass 10967.42 8994.87 11080.00 9171.94 36.60 38.09 86.15 179.27 5.500 177.17 0.00 177.17 Pass 10972.55 8994.72 11090.00 9180.35 36.58 38.10 85.44 179.17 5.500 185.74 0.00 185.74 Pass 10977.67 8994.56 11100.00 9188.76 36.55 38.12 84.72 179.07 5.500 194.32 0.00 194.32 Pass 10982.78 8994.40 11110.00 9197.18 36.52 38.13 84.00 178.96 5.500 202.91 0.00 202.90 Pass 10987.87 8994.25 11120.00 9205.60 36.49 38.13 83.27 178.84 5.500 211.49 0.00 211.49 Pass 10992.96 8994.09 11130.00 9214.01 36.46 38.14 82.53 178.71 5.500 220.08 0.00 220.08 Pass 10998.03 8993.94 11140.00 9222.43 36.43 38.14 81.79 178.58 5.500 228.67 0.00 228.66 Pass ."Ìj< 1 itF BOP· Tree I Master Valve ~ 1 e . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ft¿¿ ¿ 5-/7# PTD# 2oC:¡ - 2-h,3 ~Y Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlbore ·segment of LATERAL existing weD . Permit No, API No. . (If APJ Dumber Production. sbould continue 10 be reported as last two. (2) digits a function· of tbe original API number. stated are between 60-69) above. PJLOT HOLE )n accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) .' and API number (SO - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION .' compliance witb 20 AAC 25..0SS~ Approval to periorate aDd produce is contingent upon issuance of ~ conservation order approving a spacing u ception. (Company Name) assumes tbe liability of any protest 10 the spa cing . e:J ception tbat may occur. DRY DITCH AlJ dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 30' .' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample iIiter-vaJs tbrougb target ZODes. .. . . o o Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, LISBURNE OIL - 640144 Well Name: PRUDHOE BAY UN LIS L5-17A _ Program DEV PLORATION (ALASKA) INC Initial ClasslType DEV Ll-OIL GeoArea 890 Unit 11650 On/Off Shore On - Administration Permit fee attache_d _ _ - - - ~ _ _ _ Yes 2 _LeasenulJlber _appropriate_ _ _ - - - - - Yes - - - - - - - - - - 3 Vniqueweltnarne_and n~mber _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ yes - - - - - - - - - - - - - - - - . ~ 4 WellJocated In_a_defioe_dpool_ _ _ _ _ _ - - - - - _Yes - - - - 5 WellJocated proper _distance from driJling uoit bouodary_ _ Yes 6 WellJocated pr_oper _distance from otber weUs_ Y_es 7 _S_utficieoLacreage_aYélilable in_drilling unjL _ _ _ - - - - - Yes - - - - 8 Jtdeviélted, js_ weJlbore platìocJu_ded _ _ _ _ _ _ _ Yes 9 Q~rator oOly affected party _ _ _ _ - - - - - Yes - - - - - 10 _O-perator bas_appropriate_ bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ Yes - - - - - - . - - - - - - - - - - - - ~ 11 P_e01Jit can Þe iss~ed wjtbout conservatioo order _ _ _ _ _ Yes Appr Date 12 Permit can Þe iss~ed wjtbout éldmioistratille_ approval _ Y_es RPC 11/1/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocated withio area and strata _authorized by_lnjectioo Ord_er # (put 10# in_c_omrneots)_ (For NA 15 _AJI weUs_withlnJl4_mile_area_of reyiew jdeotified (For servjceJlI[e[l oolYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; _duration_of pre-pro_ductioo less than 3 lJlontbs_ (For_selYice well onJy) _ _ _NA 17 ACMP_ finding 9f Con_slstencyh_as bee_nJssued_ for_ this project _ _NA - - -- - - - - - - - - Engineering 18 C9ndu_ctor sÌ(Ìng_provided _ _ _ - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - 19 _S_urface_casin9-protects all_known USDWs _ _ _ _ _ - - -- NA 20 _CMT vol adeQ~ate_ to circ_ulate_o_ncood_uctor_ & SUIt csg _ - - -- __NA 21 _CMT vol adeQu_ateJo tie-inJong_string tOSJrf csg_ _ _ _ - - - - - - - - -- NA - - - - 22 _CMT wiIJ coyeraJI koowRProductiye borizon_s_ _ _ No_ Slotte_d, _ _ 23 _C_asing designs adeQua_te for C,_T, B&_ permafrost _ Yes - - - - - - - - - 24 Adequatetankage_or re_serye pit _ - - -- _ _ _ _ _ _ Yes CTDU. 25 JtaJe-drilL has_a_ to-403 for abandonment been ¡¡pproved _ _ - - - -- _ Yes 11J1J200~L 26 Adequate_wellbore sepélr¡¡tjo_n_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - ~ - - - - - - - - - - 27 JtdjvertefJect-uired, does jtmeet reguJations_ _ _ _ _ _ _ _ _ _ - - - -- NA Sidetrack. _ _ _ _ _ _ _ Appr Date 28 _Drilliog fJujdprogram schelJlatic_& ect-uipJistadequ¡¡te_ _ _ Yes Max MWS:Z ppg. _ _ _ _ _ WGA 11/2/2004 29 _BPP_Es,_ d_o they meet reguJatioo _ _ _ _ _ _ _ - - - _ Yes - - - - - - - -- 30 _B_QPEpress raJing appropriate; test to (puJ psig in_colJlmeots)_ . . _ _ _ . _ Yes Test to _350Q psi. _ MSf' 2578 P$Î. 31 _Choke manifold complies w/API 8.1'-53 (May 84) _ . . - - - ~ · _ Yes 32 Worts wiJI occur withoutoperatio_n _shutdown_ _ _ - - - - - Yes 33 Js presence_ of H2S gas_ probable. _ _ _ No_ NoLan H2S pad. 34 Meçbanicalcoodition _of wells withio AOß yerified (For servjce well only) . · _ _NA Geology 35 Permit can Þe iss~ed w!o hydrogen sulfide lJleas_ures _ _ . - - -- No 36 D_ata_preselJted on potential overpres.sure 7:00e$ _ _ . - - - - - _ _NA_ Appr Date 37 _Seismic_analysjs_ Qf sballow gasz90es _ _NA - - - - ~ - - - - - - - 38 S_eabed _coodjtiolJ Sllrvey(if off-sh_ore) _ _ _ . _ - - - - - - - - - - · _ NA 39 _ Conta_ct namelphoneJor_wee~ly progressrepo_rts [exploratoryonlYl . - - - - .NA - - Geologic Date: Engineering Date ~bl;' %~ Commissioner Commissioner: mmissioner PIS 111't-(~ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. " , **** REEL HEADER MWD 06/08/03 BHI 01 . . **** RECE\VED AUG 0 7 1006 AIastæ. 01\ & Gas eons· eommissiOO And\C)tag8 LIS Customer Format Tape # ;i6 **** TAPE HEADER **** MWD 03/12/13 798668 01 3.0" CTK 1¡¡ .. *** LIS COMMENT RECORD *** !!!!!!!!!!!! ! !!!!!! Remark File Version 1.000 !!!!!!!!!!!! ! ! !!!!! Extract File: 1dwg.1as -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10765.0000: STOP.FT 11780.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block ~MNEM.UNIT Value #--------- ------------------------- 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------~4----------- Starting Depth Ending Dept:,h Level Spacing Absent Value BP Exploration (Alaska), Inc. L5-17A Lisburne 70 deg 20' 3.099" N 148 deg 14' 13.914" W North Slope Alaska Baker Hughes INTEQ 3.00" CTK 13-Dec-04 500292188901 ----------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks 02 11 15 MSL o KB 55 KB 55 N/A W/A N/A DIRECTIONAL section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 :)04 -'dd~ . . (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Gamma and Directional Sub, and a Hydraulic Orientor Sub, with Near Bit Inclination Sensor. (6) The data presented here is final and was not depth shifted to a PDC(Primary Depth Control) log. The INTEQ MWD is the PDC for well L5-17A. (7) The sidetrack was drilled from L5-17 through a milled window in 5 1/2n liner. Top of Window 10765.0 ft.MD (8857.4 ft.SSTVD) Bottom of Window 10774.4 ft.MD (8862.5 ft.SSTVD) (8) The interval from 11741' MD (8719.5' SSTVD) to 11780' MD (8705:'r" SSTVD)was not logged due to sensor to bit offset. (9) Tied to L5-17 at 10754.5 ft.MD (8848.9 ft SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 8757.92, 8757.43, DISPLACEMENT -0.493164 Tape Subfile: 1 63 records... Minimum record len~~h: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 x** ÌNFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 15-17a 5.xtf 150 BP Exploration (Alaska) Inc. L5-17A Lisburne North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per BP Exploration instructions, the MWD Gamma Ray is the PDC for this borehole. . . *** INFORMATION TABLE: CIFO MNEM CBAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 .. , * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 25 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10765.000000 11780.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 34 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 '* * *' 1~ \ INFORMATION TABLE: CONS VALU MNEM --------------------------------- WDFN LCC CN 15-17a.xtf 150 BP Exploration (Alaska) . . WN FN COUN STAT L5-17A Lisburne North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Jhis file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type i,,: 0 Datum Frame Size is': 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F ..", '- 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPS MWD 68 1 F/HR Size Length 4 4 4 4 ------- 8 Total Data Records: 49 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 10765.000000 11779.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 58 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/12/13 ~ ' 798668 01 . **** REEL TRAILER **** MWD 06/08/03 BRI 01 ~ ), Tape Subfile: 4 Minimum record length: Maximum record length: ~ ~ " . . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS ~ \ '" \ :I;¡ . ~ . . . Tape Subfile 2 is type: LIS DEPTH GR ROP 10765.0000 18.8700 -999.2500 10765.5000 18.8700 -999.2500 10800.0000 12.2967 18.0400 10900.0000 18.8700 32.2800 11000.0000 18.2900 57.3500 11100.0000 27.8600 29.0600 11200.0000 26.4100 17.9400 11300.0000 29.0200 21. 9100 11400.0000 172.2600 17.8000 11500.0000 29.3100 29.0800 11600.0000 20.9000 17.1600 11700.0000 21. 8700 2.9500 11780.0000 -999.2500 38.2000 Tape File Start Depth 10765.000000 Tape File End Depth 11780.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet 1.,) . '\. . . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 10765.0000 19.8850 -999.2500 10765.2500 18.8700 -999.2500 10800.0000 12.3933 15.6000 10900.0000 18.0000 54.3500 11000.0000 20.9000 54.3300 11..1.00.0000 25.5400 28.6700 11200.0000 26.9900 16.4700 11300.0000 29.8900 17.7700 11400.0000 174.0000 18.1800 11500.0000 29.3100 61.5700 11600.0000 18.5800 16.9300 11700.0000 24.5600 1.5200 11779.7500 -999.2500 18.3000 Tape File Start Depth 10765.000000 Tape File End Depth 11779.750000 Tape File Leve,l Spacing 0.250000 Tape File DeptlÌ Units feet " , 1;:' . . . Tape Subfile 4 is type: LIS " . ,~ " " .