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Home My WebLink About204-085 _ tit 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. ~ 0 lJ- - 0 S S Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES BY: CMaria~ Date: 7// '-1-1 () b Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 11I1111111111111111 ;¡;CAN DIGITAL DATA ~Ior Items: ~skettesl No. I Greyscale Items: \ ~~ o Other, NofType: o Poor Quality Originals: o Other: NOTES: BY: ~ Date 'Z~Lf/ðb I I Project Proofing Date 7/1 <f/O b BY: ¡M;;) Scanning Preparation d- x30= &ó + BY: Date: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 11/1111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: '~ 1111111111111111111 ~ 3 = TOTAL PAGES ~-3 (Count does not include cover sheet) /5/ /5/ /5/ 11I1111111111111111 NO /5/ rnr NO /5/ 1111/111111I111111I ReScanned BY: Maria Date: /5/ Comments about this file: II 11111111I111111I Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page. doc • • • 4,4). V/7, cv THE STATE Alaska Oil and Gas � ® 1 1L1 1 � Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 p APR 2 % I Fax: 907.276.7542 John McMullen SCNI gam Engineering Team Leader cs BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02 -06B Sundry Number: 313 -165 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. , oerster Chair // DATED this / / day of April, 2013. Encl. II STATE OF ALASKA • ALAR OIL AND GAS CONSERVATION COMMISSION OTS 4/19i/ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 A (T i C 1. Type of Request: ❑ Abandon ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 204 -085 • 3. Address: ® D evelopment ❑ S ervice 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20086 -02 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 02 -06B • Will planned perforations require a Spacing Exception? ❑ Yes ® No , 9. Property Designatior 10. Field / Pool(s): ADL 028308 • Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13081' ' 9073' ' 13046' 9069' 11620', 11870' Unknown, 12986' Casing Length Size MD ND Burst Collapse Structural Conductor 114' 30" 114' 114' 880 , Surface 1216' 20" 1216' 1216' 1530 520 Intermediate 2711' 13 -3/8" 2711' 2711' 4930 2670 Production 11022' 9 -5/8" 11022' 8755' 5750 3090 Liner 6737' 7" 3407' - 10144' 3396' - 8199' 7240 5410 Liner 2930' 3 -1/2" x 3- 3/16" x 2 -7/8" 10151' - 13081' 8203' - 9073' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11450' - 13000' 9006' - 9062' 4 -1 /2", 12.6# 13Cr80 10040' 5 -1/2 ", 17# x 4 -1/2" 12.6# L -80 10134' - 10482' Packers and SSSV Type: 7" x 4 Baker S - packer; Packers and SSSV 9903' / 8041' 9 - 5/8" x 5 - 1/2" Baker'SAB' packer MD (ft) and ND (ft): 10346' / 8331' 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: April 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips, 564 -5913 Printed Name: Jo u n Title: Engineering Team Leader E ail: Ron.Phillips @bp.com Signature: Phone: 564 -4711 Date: 3 3 Commission Use Only Conditions approval: Notify Commission so that a representative may witness � 1 2 I �� Sundry Number: r ❑ Plug Integrity tiBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance V. Other: RB 1 \ DMS APR 2 2 . 41 � Vvi ate p 1 1/5 p/ ctv� rv1 pp?' o''f p zi- 2G f]a C ZS / IZ L Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: /0 _ iiD 7 / 9 APPROVED BY /� Approved By: l 14---- COMMISSIONER THE COMMISSION Date: ` "`( / ! ~ /3 Form 10-403 Revised 42012 Approved application is valid for 12 months from the date of approval Submit In Duplicate ;I ° F 41 ./3 , .- �,,, ORIGINA • • To: Alaska Oil & Gas Conservation Commission From: Ron Phillips 0 b p CTD Engineer Date: March 29, 2013 Re: 02 -06B Sundry Approval Sundry approval is requested to plug the 02 -06B perforations as part of the drilling and completion of proposed 02 -06C coiled tubing sidetrack. • History and current status: The 02 -06 was originally completed in 1977. The well was coil sidetracked in 1996 (02 -06A). Well 02 -06B was drilled in June 2004, as a 1600' horizontal well completed with 350' perfs in Z2A. In January 2005 10' Z2BI was added. In October 2009 a RWO was performed on the well and new tubing was installed. It was put on production on February 2010. In May 2010 a plug was set, shutting in all perfs and 50' Z2BI were added. In March 2011 another plug was set and 50' of Z2BI was added. Only the heel of the well is producing from Z2BI. In April 2012 a RST was run to evaluate potential lenses. The oil rate never recovered. Well 02 -06B is no longer a • competitive producer due to high GOR and has no remaining well work options. The proposed sidetrack will access a 45 acre block in the Z1B /2A sands in the western part of DS -02. Proposed plan 02 -06B is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around May 5, 2013. The existing perforations will be isolated by a CIBP set pre - rig, __ as well as the liner top packer set post rig. The sidetrack, 02 -06C, will exit the existing 3- 3/16" liner and kick off in zone 3 and land in zone Z2. This Sundry covers plugging the existing 02 -06B perforations via the 02 -06C liner top packer set post rig with slickline (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. • • Required Permit? Pre -Rig Work (scheduled to begin April 1st, 2013) 10-403 PTD 1. F MIT -IA to 3,000 psi. No No 2. C Dummy WS drift to 11,300' MD. No No 3. C Load and kill well. No No 4. C Set CIBP at 11,200' MD. No No 5. C Test CIBP to 2,500 psi. No No 6. V PT MV, SV, WV. No No 7. V Bleed wellhead pressures down to zero. No No Bleed production , flow and GL lines down to zero and blind 8. V flange. No No 9. 0 Remove wellhouse and level pad. No No Required Permit? Rig Work (scheduled to begin May 5th, 2013) 10-403 PTD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. No No 3. Set 3- 3/16" monobore whipstock at 11,080' MD. No No 4. Mill 2.74" window at 9,078' and 10' of rathole. No Yes 5. Drill Build: 3.00" 830' OH, (18 deg DLS planned). No Yes 7. Drill lateral: 3.00" OH, 1548' (12 deg DLS planned). No Yes 8. Run 2 -3/8" liner leaving TOL at 10,000' MD. No Yes 9. Pump primary cement job: 7.9 bbls, 15.8 ppg, TOC at 11,300'. 1 No Yes 10. Perform liner cleanout and GR /CCL /MCNL log. No Yes 11. Perform injectivity test on liner lap. No Yes 12. Perforate liner based on log interpretation ( 800'). No Yes 13. Freeze protect well to 2,500' MD. No Yes 14. Set BPV and RDMO. No Yes 'Cement top left outside window for future sidetrack option. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set GLV's 3. Set liner top packer with slickline. 2 4. ASRC flowback /well test. 2 Approved alternate plug placement per 20 AAC 25.112(i) Ron Phillips CTD Engineer 564 -5913 CC: Well File Joe Lastufka - TREE= 41/16" CNV • WELLHEAD = aW Sip Lock 02-06B SA NOTES: ' e 4-1/2" CHROME TBG "' ACTUATOR = BAKER WELL ANGLE > 70° @ 11388' INITIAL KB. ELEV = 64' ∎ 1 , 0 1 •4 BF. B-E/ = �1� jIj • I 4 1757' f — {9 -5/8" HES CEMENTER KOP = 11018' �� • 1�h Max A l e 94° @ 12134' , • . ER 1770' H ISO -ZONE EXTERNAL CSG FKR D = 8.71' Datum MD= 11156' , 1795' H9 5i8 CSG PATCH, 47# L -80, D = 8.681" Datum TVD = 8800' SS 1 2025' —141/2" X NF? D = 3.813" 1 GAS LET MANDRELS 20" CSG, 944, 1+40 /133#, K -55, 1 1216' ST ND ND D V TYPE VLV LATCH FORT DATE D = 19.124" / 18.78" 4 3649 3625 21 KBG-2 DONE BK MA 10/12/09 13 -3/8" CSG, 72#, N-80, D= 12.347" H 2711' r NO ( �� 3 6536 5793 52 KBG-2 SO SBK-2C NA 10/12/09 1 2 8669 7211 45 KBG-2 DMY SBK -2C NA 10/04/09 9 5/8'x7" BKR C2 ZXP LTP w / 11.62' —1 3407' 11 11 1 9794 7970 50 KBG-2 OW SBK-2C NA 10/04/09 TEBK SLV & FLEX LOCK HGR, ID= 6.29' � j 4 4 9872' H4-11r X NIP, D = 3.813" 1 1 1 ' 1 1 Minimum ID = 2.440" @ 12267' 1 ! ►_. _. 1 9903' 1—{7" x a yr BKR S-3 PKRt D = 3.875' 3 -3/16" X 2 -7/8" XO 0 , 1 'j 1 9937' H4-1/' HES x NP, 0= 3.813" 1 • ' 1 , , 1 1000$ H4 -112" XN NP, 0= 3.725" 4 1/2' 113G, 12.6#, 13CR 80 VAM TOP --I 10040' ` I i 1 10040' 4 1/2" WLEG, D = 3.958' .0152 bpf, . D 3.958" '4 1∎ 1 10086' HT' x 4 1/2" X0, ID= 3.958" 17" LNR, 264, L-80, BTC-M .0383 bpf, D= &276" H 10086 L 10127' 1-- 14-112" x 5-1/2" XO, D = 3.958" 1 /2" 1BG STUB (09/22109) 1 10134' 10144' MOUE 5/$" x 511MOUE OV EiSHOT w /SEALS, 1 iii ._ 1 10151' H5 -1/2" B PERM KR FA FM PKR, D = 3.625" 1 NR EST. L TOC (??r??m. ) 1 0155' b , 10155' H BKR C2 TEBACK SLV, 0 = 4.0' 11 1, ) 1 10163' 3.781` BKR DI31OY kENT SLV, I) = 3.0" 10182' 3-112" l-ES X NP, D = 2.813" • 1. ■ • 1 • . 1023' 5 1/2" BKR SLUNG SLV, D = 4.223 �1 l ` 1 3 10 290' H 5 -1 /2" BKR SBR A SSY , D = 0=3.9 -4 : 14 Cmt'd- 1 5-1/2" TBG,17 #, L -80, .0232 bpf, D= 4.892" H 10358' ' ' : , 1 10346 H9-518 X 5-1/2" BKR SAB FKR 1 Behind 1 1 I , ' I' 10358 - 5 7 in' X 41/2" XO, D = 3.958" 1 CT LNR 4-1/2" TBG,12.6#, L -80, .0152 bpf, D = 3.958" H 10482' ( . A •.� I 10419' H4tn "BKRRMP, MILLED I'D =3.80" 1 ► •♦ ♦ ► . ♦ 4 _. ► ►•i4i 4 • 1 1 0436' ` 1 - -1E1MDTT LOGGED 11/07/86 1 ► ■ 4 • I • • ►....,4 ••• 1 10908' 13 -1/2" 1 XN MP, D =2.$1" ► ... ►'..4 ► ❖4► ► w /N1000, 13= 2.75' ❖ . • . 4,t ,*.,4 13 -1/2 LNR, 8.814, L -80, .0087 bpf, D = 2 -990" I 10941' ► �� v.�� 10941' 1_13-1/2" X 3 - 3/16" XO, D = 2.80' ► ❖.•• ► CEMENT RAMP WINDOW (02 -0613) 11022' - 11032' 9- 518" CSG, 40#, N-80, D= 8.681" H — 11026 1 — ►. ♦ ♦ ♦..4 ∎••• ♦..4 • ••• 11620' — 33116'CBP(03/20/11) SUMMARY SUMMARY RY ■••••. 4 ? ?? H FISH -BOT CBP (PUSFH) TO BTM 03/20/11) REF LOG: MCNJCCQJGR ON 06/03/04 ► ♦ ►••••••• •`` 11870' H CBP(05/23 /10) ► 1 ANGLE AT TOP PERF: 87° @ 11450' ►.•.•.•.•.•• • • • .4/ ...s Refer to Roduction DB for historical pert data � `� 1 12267' 1--13 - 3116" X 2 XO, ID = 2.440" SIZE SPF INTERVAL Opn/Sgz DATE SQZ �( 2" 6 11450 - 11475 O 03/22/11 12986' Ft3H: FASDREL DEBRIS 2" 6 11550 - 11575 O 03/22111 ` (11/01/09) 2" 6 11725 - 11750 C 05/23/10 3 -3/16" LNR, 6.2#, L -8017* 12267' 2" 6 11775 - 11800 C 05/23/10 .0076 bpf, D = 2.80" , 2" 6 12264 - 12294 C 01/06/05 1 FT3TD 13046' 2" 6 12650 - 13000 C 06/04/04 4(iiii 2 -7/8" LINFt, 6.164, L -80 SR., .0058 bpf, D = 2.441" H 13081' - DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 2/? ?177 ORIGINAL COMPLETION 03/25/11 RW /PJC CEPS/ FERFS (03/22/11) WE-L: 02 -068 08/27/96 CTD SIDETRACK (02 -06A) 03/22/13 BSE/JMD FIXED XN NP ID (03/14/13) FERMI` No: '040850 06/04/04 JDM /KAK CTD SIDETRACK (02 -068) 04/02/13 RP/JMD CORRECTED CMT RAN' DEPTH API Nb: 50 -029- 20086 -02 10/06/09 014 RWO SEC 36, T11N, R14E, 1300' FN.. & 1815' FWL 05/31 /10 RNWPJC CEP/ ADPERFS (05/23/10) 03/03/11 PJC DRAWING CORREC•TONS BP Exploration (Alaska) TREE= 4- 1/16" CM' WELLFEAD = CM/ Sip Lock • 02-06C 51 1138 NOTES: * ** 4-1/2 CHROME TBG*** >70° ACTUATOR = BAKER KTE ELEV = -- - - - - -- v ,, e 11 BF. ELEV = _�_ A , N m 1757' — I9 -5/8" FES c 'iTER KOP-- 11018' 1, 1x Max Angle = 94° @ 12134' OM •1 1 H ISO -ZCW EXTERNAL CSG FKR, ID = 8.71" Datum MD = ---111567 1795' H9 5/8" CSG PATCH, 47# L -80, ID = 8.681" um Dat TVD = 8800' SS I 2025' — I4 -1/2" X NIP, D = 3.813" GAS LIFT MANDRELS 20" CSG, 94#, H-40/133#, K -55, 1216' ST MD TVD DEV TYPE VLV LATCH PORT DATE ID = 19.124" / 18.78" 4 3649 3625 21 KBG-2 DONE BK N/A 10/12/09 13- 318" CSG, 72#, N-80, D = 12.347" H 2711' ;� ; 3 6536 5793 52 KBG-2 SO SBK-2C N/A 10/12/09 IN 9 518" x 7" BKR C2 ZXP LIMN 111.62' H 3.407' � � 1 2 8669 7211 45 KBG-2 DMY SBK -2C WA 10/04/09 l v A 1 9794 7970 50 KBG-2 DMY SBK -2C WA 10/04/09 TIEBK SLV & FLEX LOCK HGR, D = 6.29" � � 11 ' 9872' -- I4 -1/2" X NP, D = 3.813" ri Minimum ID = 1.995" @ 10,945' • _ 4 _. � C 9903' —17" x 4 1/2" BKR S -3 PKR, D = 3.875° 2 -318" LNR 1 . 9937' —I4 -112' HES X NP, D = 3.813 I • „ � 10000” • �� "5 10008' 1TOL 4 - 1/2' XN NP, D = 3.725° 4 1/2" TBG, 12.6 #, 13CR 80 VAM TOP, H 10040' �� &1 i 10040 1-14 112" V4LEG, D = 3 -958" r. 0152 bpf, .113.958" r' r. V 10086' --j7' x 4 1/2" XO, D = 3.958" 7" LW, 26#, L -80, BTC-M, .0383 bpf, ID= 6.276" —1 10086' : 10127' — 14 - 1/2" x 5-1/2" XO, D= 3.958" I 5-1/2" TBG STUB (09/22/09) 10134' _ 10144' — 5/8" x 5 1/2" LNOUE OVERSHOT w /SEALS, t_x .- I i 10151' H5 BKR FA REM/ PKR, D = 3.625" L E S T . LIAR TOC ( ? ?/ ? ?/ ? ?> I— 10155' l ' , 10155' 1---1 BKR C 2 T I E B A C K S L V , D = 4 -0" I ;• 10163' — 3.781" BKR DEFLOY MBJT SLV, D = 3.0" kl 10182' — 3-1/2° HES X NP, D 2.813" I 14 9 -5/8" X 5-1/2" BKRSAB PKR I—{ 10346' 1 5-1/2" TBG,17 #, L -80, .0232 bpf, ID = 4.892" —I 10358' I 4 'r 1 4-1/2" TBG 12 -6# L-80, .0152 bpf, D= 3.958" J 10482' i P . I � 4 � 4 � 4 ► � 4 � • • i I 10582' I--ITSGR I • ► ► 4 • 4 i 4 ► ► ►i 04 3-1/2" HES XN NP, D2.75" • H 10908' 4• ••• w /NOGO D= 2.635' Drifted 2.70" ► • ►•�•�� / ► I. • • 4 • 0004 3-1/2" LNR 8.81 #, L -80, .0087 bpf, D = 2.990" — 1 0941' •+&4' ►444441 P k . . i.1i •4444444 � ♦41 14♦ 3-1/2" XO 3- 3/16 ", D = 2.80" H 10941' I X4 ► / 4 4 4 4 4 4 / / 1••• •••1 •••1 ■ ■••• 9-5/8" CSG, 40#, N-80, D = 8.681 " —I — 11026 I — ■•••••41 / 11022' 11032' -4 Cement ramp window (02 -06B) ►444 441 ► 4 4 4 4 4 4 1 4444t, 11,080' H3-3/15" PKR WS (02 -06C:) PERFORATION SIRAAARY ►4444. �. 44444. ) 11,300' I—ITOC 444♦ \ ► 44 ♦44444♦ REF LOG: MCNL/CCL/GR ON 06 /03/04 / 4 4 4444 4 4 44 4. /44444444 ANGLE AT TOP RTE: 87° 11450' ► ■ , @ .. ■4 ■4.• ∎.� 2 - /E LNR 4.7 #. L-80 srL 13458' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11450 - 11475 0 03/22/11 3 -3/16" CIBP 1 11200' , 2" 6 11550 - 11575 0 03/22/11 2" 6 11725 - 11750 C 05/23/10 2" 6 11775 - 11800 C 05/23/10 2" 6 12264 - 12294 C 01/06/05 2" 6 12650 - 13000 C 06/04/04 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNTf 2/ ? ?177 ORIGINAL COMPLETION 03/25/11 RW /PJC CEPS/ FR S (03/22/11) WELL: 02 -06B 08/27/96 CTD SIDETRACK (02 -06A) 03/15/13 Rif ' Proposed sidetrack (dir plan 4) FERMT No: 2040850 06/04/04 JDM /KAK CTD SIDETRACK (02 -06B) AR No: 50- 029 - 20086 -02 10/06/09 D14 RWO SEC 35, T11N, R14E, 4139.49' FEL & 3113.14' FNL 05/31 /10 RM CEP/ ADPERFS (05/23/10) 03/03/11 PJC DRAWING CORRECTONS BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM is' - Choke Panel Standpipe 2" Circulation Line — ,MM11 Driller Gauge ' • M 10 .1'• MM 8 MM 9 Manual Choke • CIRCULATING MANIFOLD — • : MM 20 MM 22 ells e • s , 4 SLB Transducer _ • • • • MM 6 7- 1/16" 5kpsi BOP ,, PVT Sensor • -- Air Blow down - - i MM • Blind Shears Line Y f • ' Es — Baker Choke Si MM 21 � MM 5 2" Combi TOT mt3A5 BUS �a I' !� Kill Line P/S Rev Cir Line j : s Z • r 4 � iv. l a `a^�Y ■ . • . _ al BOP 24 I I f— I .- — •• � Coiled Tubing — 2-3/8" Combi �� rlaalear ., � tr rely ...MIk11t111MI1O — Ba er Choke 2" Combi TOT r MM 1 *e MP1 in • MM 13 • ! I- Kill Line Outlet 1— Cement Line to Ground if Mud •tin 4410 -+ / NI s In „, Tranducers COILED TUBING # Choke Line CIRCULATING SYSTEM Cellar Area iiii 14 To Inner Reel Outlets � Valve - r,,�, HP raillIlliIl HP7 HP3 ■ Mi1s =' it 1111 ewer mem HP2 HP1 - _ - V HP1! 4 ,. - • 4 cement line N2 SLB NORDIC'S 2 Circulate Manifold CHOKE MANIFOLD in Cellar P 11 N2 TnFlow f CM 85 C„ _ * �_ -I Ni M . , ._- ..¢'('}, Gauge ## .. .. .. 93k E Test Pump Inlet — .. ........ -- C) CM3 • HDI Gauge CM18 # Flow f/ HC' 0114 Tp TT : - •. 4Way Block CM14 CM1 CM8 To PITS • CM5 CNN CM11 CM 16 la C. " "e` Baker Choke Line ill Baker Choke Line ' NCR from wall III BAKER CHOKE LINE CM7 CM13 PRIMARY FLOW PATH ; raker Choke Line ® CM 26 CM2 AM CM20 1 M 1 : :_ ;:; — ..MA V FLOW PATH me — us ___ CM 30 CHOKE LINE C M 75 CM10 Tige Tank — CM 25 1 Outside , • • • Pagelofl Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 Lei form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and ;,/ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • �� - Roby, David S From: O'BhenAuthier, Erin (PRA) <Ehn.OBhenAuthier@op.conn~ Sent: Tuesday, April 09, 2013 11:34 AM To: Roby, David S (DOA) Subject: FW: Sundry application for PBU well 02-06B Dave, This bounced back. Please let me know if you get this. From: O'Bnen Authier, Erin (PRA) Sent: Tuesday, April O9,2O1] 11:32 AM To: Dave Roby (mailto:dave.roby@alaska.gov) Cc: Phillips, Ron; Lundgren, [ad E; McBride' @os|e| Plawman, Tom; Siks, Benjamin Subject: RE: Sundry application for PBU well 02-06B Dave, You are "spot on" - monthlv allocated tests don't quite capture what the real performance of 2'068. Recentwe/|testy (plot below) show that the well never recovered after we ran an RST (reservoir saturation tool) in april 2012 to look for any remaining add perf potentlal. The gas rate stayed the same, but the Iiquid rate never came back. The last three tests were >100,000 gor, with oil rate ranging from 166opd to 182 bopd, gas rate steady at ~25O00much], with 6% water cut. With no significant add perf potential, it was decjded to sidetrack. At this Iow rate, the remaining black oil Is only l3K8BC)(6MBO black oi|=reserves). The forecast /<1D06op6 black oil) was run thru12/2Ul4 with Il9&ontime. | highly doubt the well will get even 21% an tirne with the gor so high. They tested for any recharge after 3 month shut in and saw less oil rate with sarne gas rate. The history of the well: 6/O4]58'Z2Aperfy, rate fell off within 6 months yo... 1/05 added 10' Z2B1, +200bopd and kept on full time until it had integrity issues. Shut in 2008 & 2009 for prod casing leak. 10/09 RWO got well back on line, but well never quite recovered to what it was before the RVVO, suspect a bit uf damage. 5/1O set plug toS|35D'IA&50'28| and added SO']8/ closer to heel ofwell. Couldn't sustain flow, went high gor and SI. 3/11 set second plug and added SO/Z8|in heel ofwell. Well flowed pretty good until we ran the RST. 4/12 ran RST for add perf potential. Well never carne back — not sure why so damaged. With two plugs in the well, remaining weUwork was very limited. Primary reserve target in the area is 2A/1B. Current open perfs are 2B1 lens. Any lens potential (Z2C & 2Bu/2B1) will be logged in new sidetrack and perf'd later in life of new sidetrack. Hope this helps. Any other questions, please caIl. 907'564-5362 Erin COACVA . 0 5. Welt /est/Ste& 0.1 Plot WEIL OZ-05ELTRLIDHCK Dotes MINI 06/19/2004 to 04109/2013 Plot is hmited, Low 0 Hilt 100000 .,- i 1 I.. 1 1 ' -: _ t..Y ....,11 .1 .i.:-.1 117 ION I -- _ - -----......_..-- - • ... .. . . - - ... — .... . ..... ..:::::: . :,-T •Fis• : .: , . - .. Ilk-7 " . - ... . , - _ - — . . "`. , - ' . - 7 ' * . - - .. . . . : °. . : . , — \ Atte li m s t . , • \ . ' i T ----} / .„ _._ ........._._ . 0 • ' : . - 4 ' _. Alt ;* ....lyt& '"•V . .... . . ...... . .. • • • • • • • •• •• • /4 .. - ' ' ....•■••••••""... : .. ..11.. ..... *•°' . . '" it tf—tt.t.: „ ...X . ...a, .... .•••• ..t_ ° I ° .'-'. ; V. :' V — - ii, 3 . .." i&N, to .. — - : w — Ili—. — •— : , 0,4 o I! . 0 s . I.. :044: • - . I ' . , . . ... . .. i - -- I 4... ' ' . 4.: . - - - -- -- - -It ... - . . .... , .. ...—........ . . ; . . , — ° ... . , . . . . ------- ...... .. ... . . . .. .... . -"- . ... ...... .. -IPA- - .•11 4 1,-■;:: - 'Att** -ow 4 ----- --.--- "?. . . .. . .. „-. ...... . .. .... . . ..- . . .„ ....... .. i - — villas , 1 t ■ ... :1. III , ... , ANL .. , - - _..... , From: Siks, Benjamin Sent: Tuesday, April 09, 2013 9:49 AM To: O'Brien Authier, Erin (PRA) Subject: FW: Sundry application for PBU well 02-06B Hey Erin, Just got this from Ron Phillips, could you follow up with Ryan for me? They didn't include you on the original email, and I figured you'd be the most important person to have on it, since you're the RE and all. Hope your day gets better. Cheers, Ben Ben Siks BP Exploration Alaska, Inc. Geologist - GD New Wells Delivery 0: (907)-564-4502 1 • • C: (907)- 229 -0865 From: Phillips, icon Sent: Tuesday, April 09. 2013 9:36 AM To: Lundgren, Carl E; Siks, Benjamin; McBride, Noelle; Plawman, Tom Subject: FW: Sundry application for PBU well 02 -06B 1 ear". The AOGCC would like us to provide more explanation as why well 02 -06B is considered non - competitive. Can you please provide this information to me. so I can send it to David Roby with the AOGCC. Please see his email below, Thanks. Ron Phillips Coil Tubing Drilling Enginee Alaska Drilling & Wells Office (907) 564 -5913 Cell (907) 317 -5092 From: Roby, David S (DOA) [mailto:dave.roby(aalaska.gov) Sent: Monday, April 08, 2013 5:22 PM To: Phillips, Ron Subject: Sundry application for PBU well 02 -06B Ron, I am reviewing your application to plug the subject well for redrill and am specifically looking at potential for lost reserves and have a couple of questions. The reason stated for wanting to abandon the current wellbore is because the well produces at a high GOR and is no longer competitive. Looking at the production data we have in our database it does not appear that the GOR for this well is excessively high compared to other wells on this pad. For example, for the last several months of sustained production the well was producing in the neighborhood of 500 BOPD with a GOR in the 55 -60 MSCF /STB range. The GOR for the subject well was 5 to 10 MSCF /STB higher than the pad average during that time, but there seem to be several other wells on the pad that produce on a regular basis at a higher GOR than the subject well, such as: Well Oil Rate (BOPD) GOR (MSCF /STB) 02 -09C 600 -800 70 -80 02 -07A 800 -900 65 -70 02 -08B 250 -300 90 -95 02 -10B 500 - 600 — 65 02 -16C — 500 75+ 02 -32B 500 -550 75+ 02 -33B 700+ 65+ 02 -35B 700 -750 65+ 02 -38 350 - 400 ^'85 02 -37 300+ ^'70 02 -36A ^'400 — 70 Back in November /December 2011 the 02 -06B was reported to be producing about 325 BOPD at a GOR of 80+ MSCF /STB (prior to this the well was producing in the 300 -500 BOPD range and showing rapidly increasing GOR, from about 30 MSCF /STB rising to 50+ MSCF /STB in just a few months). I don't see anything in our well files that would explain why oil rate had generally improved and GOR had dropped from this peak and somewhat stabilized beginning in January 2012 until the well was shut in in July 2012. Based upon the data in our production database it is hard to 3 e S ! understand why this well in particular is considered to be non - competitive while comparable, and in some cases worse, wells are still being produced on a continuous basis. Could you please provide more explanation as why this well is considered non- competitive? Could there be a difference in the production allocation being reported to us versus what was seen for this well in the instantaneous well tests? Thanks in advance, Dave Roby Sr. Reservoir Enaineer Alaska Oil and Gas Conservation Commission X907)793 -1232 4 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 ,� LI a " RECEivE Mr. Tom Maunder AUG r 1 2f11fi Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Nikita & G � $ On• Como ss• Anchorage, Alaska 99501 Ancharag9 Subject: Corrosion Inhibitor Treatments of GPB DS -02 Dear Mr. Maunder, s; S FE' 1 9 ?Oil Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 2 -06B 2040850 500292008602 6' _ NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 • 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A _ 25.5 5/18/2011 STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSIC. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate la Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ L O 204 -0850 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 sL 50- 029 - 20086 -02 -00 8. Property Designation (Lease Number) : .• 9. Well Name and Number: ADLO- 028308 .. PBU 02 -06B 10. Field /Pool(s): • PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13081 feet Plugs (measured) 11870, 11620 feet true vertical 9073.37 feet Junk (measured) 12986, 11865 feet Effective Depth measured 13046 feet Packer (measured) 1770. 3407 9903. 10151 10346 feet true vertical 9068.56 feet (true vertical) 17.703,396 8041. 8203 8331 feet Casing Length Size MD TVD Burst Collapse Structural Conductor SEE ATTACHED Surface S APR 0 8 201 Intermediate RECEIVEL Production Liner MAR ".4 %" , 5 2 , Liner Perforation depth: Measured depth: SEE ATTACHED - _ Nuke NA Gas Carts; Ccnrvssran True Vertical depth: _ - _ R rzi e Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 31 - 10035 31 - 8127 5 -1/2" 17# L -80 10134 - 10358 8192 - 8338 4 -1/2" 12.6# L -80 10358 - 10482 8338 - 8418 Packers and SSSV (type, measured and true vertical depth) ISO -ZONE EXTERNAL CSG PKR 1770 1770 7" BKR C2 ZXP LTP 3407 3396 4 -1/2" BKR S -3 PKR 9903 8041 5 -1/2" BKR FA PERM PKR 10151 8203 5 -1/2" BKR SAB PKR 10346 8331 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 371 13,141 28 901 Subsequent to operation: 438 13,462 28 397 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 Service ❑ Stratigraphic p Daily Report of Well Operations X 16. Well Status after work: Oil r 0 Gas ❑ WDSPL ❑ GSTOR p WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na . - Last ,�, \ Title Data Manager Signatu - 1111k Phone 564 -4091 Date 3/29/2011 Form 10404 Revised 10/2010 MOMS MAR 8 0 1011 43/9?-- y 7 // Su bmit O riginal On P!/41F A O�! l/. # 02 -06B 204 -085 CASING ATTACHMENT C ONDUCTOR 735' 20" 94# H -40 30 765 30 765 1530 520 CONDUCTOR 451' 20" 133# K -55 765 1216 765 1216 2320 1500 PRODUCTION 1757' 9 -5/8" 47# L -80 33 1790 33 1790 6870 4760 PRODUCTION 302' 9 -5/8" 47# N -80 1790 2092 1790 2092 6870 4760 PRODUCTION 3007' 9 -5/8" 40# S00 -95 2092 5099 2092 4865 6820 3330 PRODUCTION 5130' 9 -5/8" 47# S00 -95 5099 10229 4865 8255 8150 5080 PRODUCTION 797' 9 -5/8" 53.5# N -80 10229 11026 8150 8758 LINER 6660' 7" 26# L -80 3426 10086 3414 8160 7240 5410 LINER 41' 4 -1/2" 12.6# 13CR80 10086 10127 8160 8187 8430 7500 LINER 17' 5 -1/2" 17# L -80 10127 10144 8187 8199 7740 6280 LINER 790' 3 -1/2" 9.3# L -80 10151 10941 8203 8703 10160 10530 LINER 1326' 3- 3/16" 6.2# L -80 10941 12267 8703 9011 • LINER 814' 2 -7/8" 6.16# L -80 12267 13081 9011 9073 13450 13890 • 02 -06B 204 -085 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02 -06B 6/4/04 PER 12,650. 13,000. 9,054.13 9,062.47 02 -06B 1/6/05 APF 12,264. 12,274. 9,010.26 9,012.37 02 -06B 1/6/05 APF 12,274. 12,294. 9,012.37 9,017.02 02 -06B 2/6/08 BPS 10,908. 13,000. 8,682.47 9,062.47 02 -06B 8/15/09 BPS 10,177. 12,264. 8,220.35 9,010.26 02 -06B 11/1/09 BPP 10,177. 13,000. 8,220.35 9,062.47 02-06B 5/23/10 BPS 11,870. 13,000. 9,000.06 9,062.47 02 -06B 5/24/10 APF 11,725. 11,750. 9,003.12 9,002.89 02 -06B 5/24/10 APF 11,775. 11,800. 9,001.91 9,000.47 02 -06B 3/21/11 BPS 11,620. 11,870. 9,001.99 9,000.06 02 -06B 3/22/11 APF 11,450. 11,475. 9,005.9 9,006.34 02 -06B 3/22/11 APF 11,550. 11,575. 9,005.46 9,003.98 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 02 -06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/19/2011 CTU #8, 1.75" Coil, Job Scope: Set CIBP and add perforations to reduce GOR MIRU CTU. M/U BTT / PDS Memory logging tools and 2.62" drift. PT lubricator and IChecks. Load well with KCL /safe tube. RIH with PDS memory tools with 2.62" OD 1 i nozzle, TOL 16.03'. 11770'- 11,200' log interval. ** *Job in Progress * ** 3/20/2011 CT -8 1.75" Scope of work: Drift tag, jewellry log, set CIBP, & add perfs to reduce GOR. PDS GR/CCL Memory Log from 11770 to 11,200' paint flag at 11,600'. RD Logging tools, good data. MU BOT tools & CIBP. RIH with CIBP. Set CIBP at 11650'. POH. Lay out BTT tools. PJSM. M/U SWS 2" perf BHA with 25" of guns at 6 spf. RIH. BOT CIBP moving down hole /not holding pushed to bottom. POOH. Lay down guns, Icut coil, 150'. Inspect chains, change pack offs. « «« « <Job Continued on 3 -21 -11 WSR » » »> 3/21/20111 CT-8 1 3/4" Scope of Work: Drift/Memory Depth log GR/CCL., Set CIBP, Add 1 Perfs. 1MU lubricator, BOT Hook up & MU PDS Memory logging tools, & RIH. Wash liner 1down/up 3 times from 11000 - 11760. Log Memory GR/CCL from 11760- 11000'. 1POH. Layout logging tools. Good data. PJSM. M/U BOT CIBP and setting tools. �t$� RIH at 60 fpm. Correct depth at flag and RIH to CIBP setting depth of 11620'. iLaunch 1/2" ball and set CIBP. POOH RD setting tools, MU & RIH w /SLB 25' x 2" x 16 -SPF 2006PJ TCP guns. «« <Job in Progress » »» 3/22/2011 CT -8 1 3/4" Job Scope: Drift/Depth log, set CIBP & add Perfs * ** *Continued from WSR 3- 21- 11 * * ** RIH w /2" x 25' TCP gun. Tagged CIBP @ 111,626' CTD, Shot first set of perfs 11,550- 11,575' corrected depth, 6 SPF x 60 degree phasing. POOH. RD spent guns, cut 150' CT. M/U CTC Pull test, M/U checks and Hyd Disc and press test. M/U 25' SWS 2" PJ perf guns and 6 spf. PT Lubricator. RIH at 80 fpm. Correct to CIBP at 11620'. Fire perf guns at 11.450 - j 11.475'. POH. Freeze protect 4-1/2" tubing with 60/40 meth to 2500'. Lay out BHA. 1All shots fired. Secure well and rig down CTU. 'PERFORATING SUMMARY: 11,550 - 11575' and 11,450 - 11,475'. 50' total at 6 4( --iSPH, 2" SWS PJ charges. BOT 3-3/16" CIBP set at 11,620'. ««< Job Complete » »> FLUIDS PUMPED BBLS 367 60/40 McOH 700 1% KCL SL SAFE LUBE 1067 TOTAL • TREE= 4- 1/16" CIW W • ELLHEAD = CNV Slip Lock 02-06 @ 18 *" 4 -1 (2" CHROME TBG * ** >70° ACTUATOR = BAKER KB. ELEV = ._ . 64' ■• 1 • 1 1 1 1 / 1 1 BF. ELEV - 'A ',41 14 V 1757' 1 - 518" HES CEMENTER KOP= 11018' 1I 11 - 1.1• • -! 1770' I - 1 ISO -ZONE EXTERNAL CSG PKR, ID = 8.71" I Max Angle =..- 94° 0 12134' ►�� •'i Datum MD = 11156' 1795' 1--I 9 5/8" CSG PATCH, 47# L -80, ID = 8.681" Datum TVD = 8800' SS , 2025' H 4 -1/2" X NIP, ID = 3.813" 1 20" CSG, 94 #, H-40 /133#, K -55, 1216' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ID = 19.124" / 18.78" 4 3649 3625 21 KBG -2 DOME BK N/A 10/12/09 113 -3/8" CSG, 72 #, N -80, ID = 12.347" I - I 2711' 1 3 6536 5793 52 KBG -2 SO SBK -2C N/A 10/12/09 9 5/8" x 7" BKR C2 ZXP LTP w / 11.62' - 3407' 1 ►; 2 8669 7211 45 KBG -2 DMY SBK -2C N/A 10/04/09 1 ► 1 9794 7970 50 KBG -2 DMY SBK -2C N/A 10/04/09 TIEBK SLV & FLEX LOCK HGR, ID = 6.29" 1 1 ► 4 I 9872' I - - 1/2" X NIP, ID = 3.813" 1 1 Minimum ID = 2.440" @ 12267' �� . . � : _ 9903' I x 4 1/2" BKR S -3 PKR, ID = 3.875" I 3 -3/16" X 2 -7/8" XO • • A 993T I- I4 -1/2" HES X NIP, ID = 3.813" I 1 ► 10008' 4 -1/2" XN NIP, ID = 3.725" 4 112" TBG, 12.6 #, 13CR -80 VAM TOP, 10040' �1 �1 10040' j 4 1/2" WLEG, ID = 3.9588" .0152 bpf, . ID= 3.958" � ►� 10086' - 7" x 4 1/2" XO, ID = 3.958" 1 I7" LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" I - I 10086' .. - 10127' 1 - 14 - 1/2" x 5 -1/2" XO, ID = 3.958" I 5 -112" TBG STUB (09/22/09) I - I 10134' 10144' --19 518" x 5 1/2" UNIQUE OVERSHOTw /SEALS, 1 ir ... 10151' I- 15 -1/2" BKR FA PERM PKR, ID = 3.625" I I EST. LNR TOC ( ? ? / ? ? / ? ?) I 10155' 1 10155' ( - j BKR C2 TIEBACK S L V , ID = 4.0" I �1 ■ � 10163' H3.781" BKR DEPLOYMENT SLV, ID = 3.0" I • 1 10182' 1 - I3 - 1/2" HES X NIP, ID = 2.813" 4, ►' 10233' I - I5 - 1/2" BKR SLIDING SLV, ID = 4.223" I 1 1 �� imi + 10,1 I 10 290' I- )5- 1 /2 " BKR SBRASSY,ID =3.90" ( Cmt'd- I5 -1/2" TBG,17 #, L -80, .0232 bpf, ID = 4.892" I 10358' ! '! NN 10346' I-19-5/8" X 5 -1/2" BKR SAB PKR I Behind 1 4 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" H 10482' I ► ►;, 1 10358' 1 X 4 -1/2" XO ID = 3.958" I CT LNR rv. - ov. 1 10419' I -14- 112" B KRRNIP,MILLEDID =3.80" I ∎•�•�• ■► 11 10436' -I ELMD TT LOGGED 11/07/86 I ► �OD i • ∎OO •• •�•� ►�� 10908 I 3 -1/2 HES XN NIP, ID = 2.75" ►••4 ►••4 ► 00• •••�•� ► I3 -1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.990" I 10941' 10941' H3 -1/2" X 3- 3/16" XO, ID = 2.80" 1 j •j • • • • ■ • • •j j • CEMENT RAMP WINDOW (02 -06B) 11010' - 11026' 9 -5/8" CSG, 40 #, N -80, ID = 8.681" " - 11026 n ► + ; ' O O Oi � 11620' H3-3/16" CIBP (03/20/11) I ------------- PERFORATION SUMMARY •�•�•�••• ∎ � � - - BO • ED TO BTM 03/20111) 1 REF LOG MCNL /CCL/GR ON 06/03!04 •••••••••••• •, . • • • •• • • • • ` 11870' - HES CIBP (05123/10) I ANGLE AT TOP PERF: 87° 0 11450' ►•••••••j•�•�•j •j• /( Note: Refer to Production DB for historical ` perf data p 12267' H3-3/16" X 2 -7/8" XO, ID = 2.440 1 SIZE SPF INTERVAL Opn /Sqz DATE it 2" 6 11450 - 11475 / 0 03/22/11 12986' 1 FISH: FASDRILL DEBRIS 2" 6 11550 - 11575 V 0 03/22/11 2" 6 11725 11750 C 05123/10 3- 3/16" LNR, 6.2 #, L -80 TCII, 12267' (11/01/09) 2" 6 11775 - 11800 C 05/23/10 .0076 bpf, ID = 2.80" 2" 6 12264 - 12294 C 01/06/05 1 PBTD 1 13046' ■ 2" 6 12650 - 13000 C 06/04/04 ,yi, I2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" 1-1 13081 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 2l? ?177 ORIGINAL COMPLETION 03/25/11 RW /PJC CIBP'S/ PERFS (03/22/11) WELL: 02 -06B 08/27/96 CTD SIDETRACK (02 -06A) PERMIT No: ° 2040850 06/04/04 JDM /KAK CTD SIDETRACK (02 -06B) API No: 50- 029 - 20086 -02 10/06/09 D14 RWO SEC 35, T11 N, R14E, 4139.49' FEL & 3113.14' FNL 05/31/10 RMH/PJC CIBP/ ADPERFS (05/23/10) 03/03/11 PJC DRAWING CORRECTONS BP Exploration (Alaska) STATE OF ALASKA ~y ALASKA AND GAS CONSERVATION COMMIS RECE~VEt~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ /~P Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter F&QI~~~~OlIS. ~OtYNItISS10(1 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to D ~ Name: Development ^~ Exploratory ^ 204-0850 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20086-02-00 8. Property Designation (Lease Number) : \ 9. Well Name and Number:. ADLO-028308 PBU 02-06B 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13081 feet Plugs (measured) 10177 feet true vertical 9073.37 feet Junk (measured) None feet Effective Depth measured 13046 feet Packer (measured) 9903 10346 true vertical 9068.56 feet (true vertical) 8041 8331 Casing Length Size MD TVD Burst Collapse Structural Conductor 114 30" surface - 114 surface - 114 Surface 1216 20"94# h-40 surface - 1216 surface - 1216 1530 520 Intermediate 2711 13-3/8" 72# N-80 surface - 2711 surface - 27111 5380 2670 Production 11348 9-5/8" 40# N-80 surface - 11022 surface - 8755 5750 3090 Liner 6737 7" 26# L-80 3407 - 10144 3396 - 8199 7240 5410 Liner 2930 3-1/2"X3-3/16"X2-7/8" 10151 - 13081 8203 - 9073 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 21 - 10358 21 - 8338 4-1/2" 12.6# L-80 10134 - 10480 8191 -8416 Packers and SSSV (type, measured and true vertical depth) 7-1/2"X4-1/2" BKR S-3 PKR 9903 8041 9-5/8"X5-1/2" BKR SAB BKR 10346 8331 12. Stimulation or cement squeeze summary: Intervals treated (measured): A~ ~~p l i ~! . 7 j ] x V Yil~~ ;d m ~ f J! y~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 442 23520 45 1262 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 5/24/2010 02-06B 204-085 PERF ~4TTACHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-066 6/4/04 PER 12,650. 13,000. 9,054.13 9,062.47 02-066 1/6/05 APF 12,264. 12,274. 9,010.26 9,012.37 02-06B 1/6/05 APF 12,274. 12,294. 9,012.37 9,017.02 02-06B 2/6/08 BPS 10,908. 13,000. 8,682.47 9,062.47 02-066 8/15/09 BPS 10,177. 12,264. 8,220.35 9,010.26 02-066 11/1/09 BPP 10,177. 13,000. 8,220.35 9,062.47 02-06B 5/23/10 BPS 11,870. 13,000. 9,000.06 9,062.47 02-06B 5/24/10 APF 11,725. 11,750. 9,003.12 9,002.89 02-06B 5/24/10 APF 11,775. 11,800. 9,001.91 9,000.47 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE LJ s • 02-06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/22/20101 CTU 9 w/ 1.75" CT. Scope; memory log/ CIBP/ Add pert. MIRU. *'"job continued on WSR - - 5/23/2010iCTU 9 w/ 1.75" CT. Scope; memory log/ CIBP/ Add pert. Load and FP tbg. RIH w/ SLB GR, CCL inside 2.2" carrier w/ 2.5 nozzle for drift. sat down @ 11420, puh dragging debris. Pulled up into 3.5" tbg/ come online down !backside while RIH and drift to 12004. PUH logging @ 40 fpm, pint flag @ ~ 11900' cont. log to 11400. pooh. LD logging tool, correlate to reference log. Set HOWCO WRBP-2 CIBP for 3-3/16" at 11870'. ,POH. RIH w/ MHA, 2" x 20' PJ2006 HMX, 6 spf pert gun. Tie into CIBP shoot 11775-11800' pert interval._ start pooh. **job contiuued on WSR 05-24-10"* 5/24/2010iCTU 9 w/ 1.75" CT. Scope; Add pert. ** Continued from WSR 05-23-10** ;Resume pooh w/ gun run #1, from interval 11775-11800' all shots fired. RIH w/ gun #2. Tie into btm shot @CIBP, pull up to depth 11725-11750'. good ;indication of firing. pooh. RDMO to Y-01. **Job Complete** Perforated 11725-11750' and 11775-11800' **Held emergency well control drill** FLUIDS PUMPED BBLS 77 50/50 METH 337 1 % XSKCL 180 1% XS KCI W/0.6% SAFE LUBE 414 Total TRE1== ~ 4-1/16" CM/ WELLHEAD = CNV Slip Lock ACTUATOR= BAKER KB. ELEV = 64' BF. ELEV = KOP= 11018' Max Angle = 94° @ 12134' Datum MD = 11156' Datum TVD = 8800' SS ~ o2-osa (20" CSG, 94#, H-40 & 133#, K-55, ID = 18.78" ~ 1216' 13-318" CSG, 72#, N-80, ID = 12.347" 2711' 9 518" x 7" ZXP Packer 3407' Minimum ID = 2.440" @ 12267' 3-3/16" X 2-7/8" XO !4 1/2" 12.6#, 13Cr-80, tbg. ID=3.958" ~~ 10040, 7" LNR, 26#, L-80, BTGM, ID = 6.276" 10086' TOP OF 5-1/2" TBG STUB (09122/09) 10134' EST. LNR TOC (??/??/??) ~-{ 10155' 5-1/2" TBG,17#, L-80, .0232 bpf, ID=4.892" (~ 10358' 4-112" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" i-j 104$0' ~3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID=2.990" ~ 10941' PERFORATION SUMMARY REF LOG: MCNL/CCL/GR ON 06/03/04 ANGLE AT TOP PERF: 78 @ 12264' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12264 - 12294 O 01!06/05 2" 6 12650 - 13000 O 06/04/04 S ES: *** 4-1 /2" CHROME TBG *** >70° @ 11388 9-5/8" HES CEMENTER ISO-ZONE EXTERNAL CSG PKR, ID = 8.71" 9 5/8" CSG PATCH, 47# L-80, ID = 8.681" 4-1/2" X NIP, ID = 3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3649 3625 21 KBG-2 DOME BK N/A 10/12109 3 6536 5793 52 KBG-2 SO SBK-2 N/A 10/12109 2 8669 7211 45 KBG-2 DMY SBK-2 N/A 10/04!09 1 9794 7970 50 KBG-2 DMY SBK-2 N/A 14104/09 4-112" X NIP, ID = 3.813'-~ 7" x 4 1/2" BKR S-3 PKR, ID = 3.875" X Nipple / RHGM Plug ID = 3.813" 4-1/2" XN NIP, ID = 3.725", 4 1!2" WLEG 7" x 4 1/2" XO. ID = 3.958" 10144' 9 5/8" x 5 112" UNIQUE OV ERSHOT w /SEALS 10151' 5-112" BKR FA PERM PKR, ID = 3.625" 10155' BKR C2 TIEBACK SLV, ID = 4.0" 10163' 3.781" BKR DEPLOYMEM SLV, ID = 3.0" 10182' 3-112" HES X NIP, ID = 2.813" 10233' 5-112" BKR SLIDING SLV, ID = 4.223" 10290' S-1/2" BKR SBR ASSY, ID = 3.90" Cmt'd- 10346' - {9-518" X 5-1/2" BKR SAB PKR~ Behind 10358' S-112" X 4-1/2" XO, ID = 3.958" CT LNR 10419' 4-1/2" BKR R NIP, MILLm ID = 3.80"' 10436' ELMD TT LOGGED 11107!86 10908' 3-1/2" HES XN NIP, ID = 2.75" w /NOGO, ID = 2.635" 10941' 3-1/2" X 3-3116" XO, ID = 2.80" '/KW ~j725 CEMENT RAMP WINDOW (02-O6B} 11010' - 11026' ~S °' r~77s.rr ~P nP7o M~ ~ L/' 12267' 3-3/16" X 2-7/8" XO, ID = 2.440" 12986' FISH: FASDRILL DEBRIS (11 /01 /09) 9-5/8" GSG, 40#, N-80, ID = 8.681" 11350' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" PBTD 13046' ~ 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 13081' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/27/96 CTDSIDETRACK(02-O6A) 11105!09 HJW/SV MILL FASDRILL (11101!09) 06/04/04 JDM/KA CTD SIDETRACK (02-O6B} 12/10/09 GJF/SV XN NIP ID CORR 10/06/09 D14 RWO 10/06/09 SV DRLG HO CORRECTIONS 10/12/09 JLJ/PJC GLV C!O 10/28/09 AW/SV DRLG DRAFT FINAL PRUDHOE BAY UNIT WELL: 02-O6B PERMIT No: 1040850 API No: 50-029-20086-02 SEC 35, T11 N, R14E, 4139.49' FEL & 3113.14' FNL BP 6cploration (Alaska) STATE OF ALASKA A OIL AND GAS CONSERVATION COM~ION ~~~~~~~~ RE ~T OF SUNDRY WELL OPERATIONS ~; t:: ~ ~ 9 2009 1. Operations Performed: ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Er~!$It~~ ~ I~i~il3. ~iol~11~111$$~~ ~ ARer Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ~~ChOfB~@ ^ Change Approved Program ^ Operation Shutdown ^ Pertorate ^ Time EMension 2. Operator Name: 4. Well Class Before Work: . Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 204-085 3. Address: ^ Service ^ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20086-02-00 7. Property Designation: ,~. Well Name and Number: ~ ADL 028308 ' PBU 02-06B 9. ield / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured '°`., 13081' feet true vertical ~ gp73' feet Plugs (measured) 10176' Effective depth: measured 13046' feet Junk (measured) NOne true vertical gp6g' feet Casing Length Size MD ND Burst Collapse Structural Conductor 114' 30" 114' 114' 880 Surface 1216' 20" 1216' 1216' 1530 520 Intermediate 2711' 13-3/8" 2711' 2711' S380 2670 Production 11348` 9-5/8" 11022' 8755' S750 3090 Liner 6737' 7" 3407' - 10144' 3396' - 8199' 7240 5410 Liner 2930' s-v2° x 3-3/16^ x 2ais° 10151' - 13081' 8203' - 9073' Perforation Depth: Measured Depth: 12264' - 13000' True Vertical Depth: 9010' - 9062' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr80 10040' 8130' ' 5-1/2", 17# x 4-1/2", 12.6# L-80 10134' - 10480' 8192' - 8416 Padcers and SSSV (rype, measured and true vertical depth): ~~~ x 41l2" Baker'S-3' packer; 9903' 8041' 9-5/8" x 5-1/2" Baker'SAB' packer 10346' 8331' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~,g ~+~t~~~f/~t~~.+ E'i('~ ;f ~ 1,~, ~U~i~ Treatment description including volumes used and final pressure: Pull tubing f/ ~5000'. Pull 3-1/2" scab liner f/ -10,150'. Cut, pull & dress tubing to -10134'. Cut, pull & dress 9-5/8" casing to -1,790'. Run 9-5l8" Tieback to 1,795' & cement w/ 127 Bbls Class 'G' (Yield 1.16). Clean out & run 7" casing from 3407' - 10144'. Cement with 197 Bbls Class'G' (Yield 1.16). Run 4-1/2" Chrome Tubing. Top Job Cement: 99 Bbls (Yield 1.16). 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: `~4 13. Attachments: ^ Copies of Logs and Surveys run ~• Well Class aRer work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations ~ Well Schematic Diagram • Welt Status after work: ~ pil ^ Gas ^ WDSP! ^ GSTOR ^ WAG ^ GINJ ^ WtNJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A 'rf C.O. Exempt: Contact Aras Worthington, 564~102 309-257 Printed Name Terrie Hubble Title Drilling Technologist ~' ~ p ~~d sy N~~ Si t ` Ph D na ure ate one 564-4628 9 l Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 ~~m ~ )~ t'~~ ~ Submit Original Only ~y ~ ~..~ ~ ~'~, `~~ G `~ . • 02-06B, Well History (Pre Rig Workover) Date Summary 7/27/2009 T/I/O/00= 80/160/10/50. Temp= SI. Bled WHPs to 0 psi & Assist Cameron w/ PPPOT (RWO prep). AL spool disconnected & blinded. T FL C~ surface, bled TP from 80 psi to 0 psi in 15 min. IA FL C~3 surface bled IAP from 160 psi to 0 psi in 20 min. OA FL C~1 surface, bled OAP from 10 psi to 0 psi in 5 min. OOA FL C~3 surface, bled OOAP from 50 psi to 0 psi in 10 min. Assisted Cameron Wellhead Tech w/ PPPOT. Final WHPs= 0/0/0/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 7/28/2009 WELL S/I ON ARRIVAL. PULL 3 1/2" PXN FROM 10905' SLM / 10908' MD. LEFT WELL SI, NOTIFY DSO. 8/15/2009 T/I/O/00=200/120/0/0 Assist E-Line, Load TBG, MIT-T PASS to 3000 psi (RWO Prep) Pumped 5 bbls neat meth & 250 bbls cude to load Tbg. E-Line sets Fasdrill Plug. Pumped 4.9 bbls crude down Tbg to bring to test pressure. On 1st test, Tbg lost 250 psi in the 1st 15 mins and 100 psi in the 2nd 15 mins for a total pressure loss of 350 psi in 30 min test. Pass. Bled Tbg, bled back (-2.5 bbls). DSO & PE. notified of results. 8/15/2009 WELL SHUT-IN ON ARRIVAL. LRS FLUID PACK WELL, T/I/0: 0/150/350 PSI. SET HALLIBURTON FASDRILL PLUG WITH MID-ELEMENT AT 10177'. TOP OF PLUG AT 10176'. T/I/O: 0/300/700 PSI. PLUG PRESSURE TEST PASSES: LOST 250 PSI IN FIRST 15 MIN. AND 100 PSI IN SECOND 15 MIN. SHOOT 5' TUBING PUNCH FROM 10120' - 10125'. GOOD INDICATION AT SURFACE. FINAL T/I/O: 0/225/350 JOB COMPLETE. 8/16/2009 Attempt to Confirm TxIA Communication post Tbg punch. (RWO prep) Pumped 1.5 bbls crude down IA to pressure up to 1000 psi, monitored pressures for 30 min with no indication of TxIA comm. Bled IAP to 80 psi (-2 bbls). Pumped 2.4 bbls crude down Tbg to pressure up to 1000 psi, monited pressures for 30 min. Tbg lost 60 psi, IA remained stable. Bled Tbg to 0 psi (-1.5 bbls). Repressured Tbg to 2520 psi with 3.2 bbls crude, Tbg lost 120 psi in 15 mins. Pressured Tbg to 3500 psi with an additional 1.1 bbls. Tbg lost 100 psi in the 1 st 15 mins and 60 psi in the 2nd 15 mins 40 psi in the 3rd 15 mins for a total pressure loss of 200 psi in 45 mins. Bled IAP from 340 psi to 0. Repressured Tbg to 3500 psi with 0.3 bbl. Monitored pressure for 4 hrs. 20 min. Tbg lost 240 psi. Bled TP to 500 psi (3.2 bbls). Pressured up IA to 1000 psi with 2.2 bbls crude, IA lost 60 psi in 60 mins. Bumped IA up to 1000 psi with 0.1 bbls, IAP remained ~ stable for 30 mins. Pressured IA to 2500 psi with an additional 3.6 bbls crude. IA lost 360 psi in 15 mins. Repressured IA to 2500 psi, IA lost 340 psi in 15 mins, repressured to 2500 psi, IA lost 340 psi in 15 mins, repressured to 2500 psi, IA lost 340 psi in 15 mins., repressured to 2500 psi, IA lost 320 psi in 15 mins. Pressured IA to 3000 psi, IA lost 960 psi in 30 mins. Repressured IA to 3000 psi with 2.3 bbl to establish LLR of 3.2 gpm (see log). Bled down Tbg and IA (-3.6 bbls). Tags hung on WV, IA. Valve positions upon departure: SV, WV, SSV=closed. MV, IA, OA, OOA=open, operator notified. FW HP's=260/240/120/0. 8/19/2009. T/I/0=325/220/100/20 MITOA to 2000 psi PASSED (RWO Prep) Pressured up OA w/1.4 bbls crude. On first test, OA lost 60 psi in first 15 min & 0 psi in second 15 min. for a total of 60 psi in 30 min. Notified DSO & PE of results. FWHP's = 325/220/100/0 Tags hung. CV, SV, WV & SSV = S/I MV, IA, OA & OOA = Open. 8/21/2009 WELL SI ON ARRIVAL. INITIAL T/I/O/00 = 0/200/100/0 TAG TOL AT 5006'. CUT TUBING AT 5002' IN FIRST JOINT ABOVE SLPR PACKER WITH 4.15 SLB POWERCUTTER. CCL - CUT DEPTH 11.6', CCL STOP DEPTH 4990.4'. GOOD INDICATION OF CUT AT SURFACE. FINAL T/I/O/00 = 100/100/100/0. SWAB AND SSV CLOSED UPON DEPARTURE. DSO NOTOFIED. JOB COMPLETE. 8/24/2009 T/I/O/00 = 125/0/60/20 Temp = SI Injectivity test down IA and Tbg (RWO prep). Pumped 5 bbls meth, 9.5 bbls crude down IA to pressure up to 3500 psi. Monitored pressures for 15 mins, TxIA psi fell to 2580/2500 psi. Pumped 106 bbls crude down IA up Tbg taking returns to FL to verify circ path. Currently rigging up to IA to circ TxIA with seawater. Page 1 of 2 ~ ~ 02-06B, Well History (Pre Rig Workover) Date Summary 8/25/2009 Circ-Out TxIA to Seawater (RWO). Pumped 574 bbis 120°F seawater down IA taking returns up Tbg to flowline. Pumped 83 bbls 60°F diesel down IA, U-tubed TxIA for 1 hr to freeze protect. Pressured up TxIA to 3000psi, monitored for 30 mins. Bled WHP down. Bled back -5 bbls. FWHP's = 0+/0+/0/0. Swab shut, Wing shut, SSV shut, Master open, IA, OA, OOA, open. 8/27/2009 T/I/O/OOA= 0/0/0/0 Circ Out. (RWO Prep) Pumped into the IA with a 3 bbl 60/40 methanol spear followed by 585 bbls of 9.8# NaCI brine followed by 34 bbls of diesel for freeze protect. U-Tube freeze protect into the Tbg. Pressure up TxIA with 0.6 bbls of diesel, monitor pressure for 45 min. TxIA lost 20 psi every 15 min for a total loss of 60 psi in the 45 min. Plug appears to still be holding. Freeze protect Flowline with 7 bbls of 60/40 methanol, 33 bbls of crude and a 10 bbl diesel tail, according to the new freeze protect recipe. Final WHP's = 0/Vac/Vac/0 Valve positions at the time of departure: Swab, Companion, Wing, SSV = Closed / Master, IA, OA, OOA = Open Page 2 of 2 ` ~ ~ BP EXPLORATI4N Page 1 of 19 C}peration~ Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 ' Date From = To Hours Task Code NPT Phase Description of Operations 9/14/2009 12:00 - 00:00 12.00 RIGD P PRE Rig down Top drive and mud manifold, Skid rig floor to lay over Derrick. Jack rig up prepare to pull off of well. 9/15/2009 00:00 - 10:00 10.00 RIGD P PRE PULL OFF OF WELL 5-03 (PAD OPERATOR WITNESSED MOVING OFF OF WELLI). INSTALL FRONT BOOSTER WHEELS. REMOVE BOP'S FROM PEDESTAL AND SET ON CRADDLE. MOVE AROUND WEST SIDE OF PAD. INSTALL REAR BOOSTER WHEELS. LOWER WIND WALLS. LOWER DERRICK. 10:00 - 00:00 14.00 RIGD X WAIT PRE WAITING ON RIG MATS TO BE LAYED ON DS-5 ACCESS ROAD. (DUE TO RIG MATS BEING USED FOR NORDICS RIG MOVE). LAY HERCULITE FOR D-14 RIG CAMP ON DS-2. 9/16/2009 00:00 - 03:30 3.50 RIGD X WAIT PRE CONTINUE TO WAIT ON RIG MATS TO BE LAYED ON DS-5 ACCESS ROAD. (DUE TO RIG MATS BEING USED FOR NORDICS RIG MOVE). 03:30 - 05:30 2.00 MOB P PRE MOVE OFF OF DS-5, RIGHT ON WEST DOCK ROAD TO DS-2. 05:30 - 12:00 6.50 RIGU P PRE RAISE WIND WALLS, INSTALL BRACES FOR WIND WALLS, SKID RIG FLOOR INTO MOVING POSITION, LOWER BRIDLE LINES AND REMOVE YOKE, LOWER GSECTION. 12:00 - 16:00 4.00 RIGU P PRE R/D REAR BOOSTERS, HANG CELLAR DOORS, P/U MOUSEHOLE, HANG BRIDAL LINES. 16:00 - 17:00 1.00 RIGU P PRE SPOT RIG OVER WELL 2-066. SKID RIG FLOOR. 17:00 - 22:00 5.00 RIGU P PRE ICK UP TOP DRIVE, UNTIE LINES IN DERRICK AND R/U FLOOR, POWER UP TOP DRIVE. 22:00 - 00:00 2.00 RIGU P PRE CLEAR RIG FLOOR OF TOOLS AND EQUIPMENT, M/U QUILL SHAFT, CHANGE OUT SAVER SUB, M/U PIPE HANDLER. 9/17/2009 00:00 - 02:30 2.50 RIGU P PRE CONTINUE RIGGING UP TOP DRIVE - INSTALL ELEVATOR LINKS, KELLY HOSE 02:30 - 03:30 1.00 RIGU P PRE R/U DSM LUBRICATOR AND TEST TO 500 PSI - PULL BPV - TUBING=O, IA=O, OA=O PSi. TAKE ON 9.8 PPG BRINE TO PITS. (TUBING ON VAC WHEN BPV WAS PULLED.) 03:30 - 05:30 2.00 RIGU P PRE CONTINUE RIGGING UP MUD MANIFOLD ON RIG FLOOR. 05:30 - 07:30 2.00 KILL P DECOMP R/U AND TEST SURFACE LINES FOR KILLING WELL TO 3500 PSI,(GOOD TEST). (RIG ACCEPTED C~ 0600 ON 9/17/2009) 07:30 - 08:30 1.00 KILL P DECOMP SAFETY STAND DOWN WITH RIG CREW. MEETING TOPIC: RELAY 2009 SAFETY EXPECTATIONS TO CREWS. 08:30 - 12:00 3.50 KILL P DECOMP PJSM - CIRCULATE OUT FREEZE PROTECT - PUMP 3 BPM WITH 280 PSI 60 BBLS DOWN ANN. - SWAP HOSES AND PUMP 3 BPM WITH 180 PSI 100 BBLS DOWN TUBING. MONITOR WELL AND R/D CIRC. LINES. 12:00 - 12:30 0.50 KILL P DECOMP SERVICE RIG AND INSPECT EQUIPMENT. 12:30 - 13:30 1.00 KILL P DECOMP INSTALL BPV AND TEST FROM BELOW TO 1000 PSI FOR 10 CHARTED MINUTES. 13:30 - 15:30 2.00 KILL P DECOMP BLEED OFF ADAPTER VOID AND CONTROL LINES - N/D TREE AND ADAPTER FLANGE. 15:30 - 18:30 3.00 BOPSU P DECOMP INSTALL SPACER SPOOL - TO TALL REMOVE SPACER SPOOL. 18:30 - 00:00 5.50 BOPSU P DECOMP N/U BOP'S Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPL~RATION Page 2 of 19 Operations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Da#e From - Tca Hours Task Code NPT Phase D~scription af Operatians 9/18/2009 00:00 - 01:30 1.50 BOPSU P DECOMP RIG UP TO TEST BOP'S - PERFORM BODY TEST AND GRAY LOCK CLAMP LEAKING ~ 13" HUB BELOW TUBING SPOOL. 01:30 - 05:00 3.50 BOPSU N SFAL DECOMP USE FAS-TORQUE WRENCH TO RETIGHTEN CLAMP, PUMP MAXED OUT AND CLAMP STILL LEAKING. BORROW FAS-TORQUE PUMP FROM DOYON-16 05:00 - 11:00 6.00 BOPSU P DECOMP TEST IBOP, UPPER KELLY VALVE, AND FLOOR VALVES WHILE RETIGHTENING GRAY LOCK CLAMP. TEST CHOKE VALVES. CHOKE VALVE #10 AND ANNULAR DID NOT PASS TEST. 11:00 - 19:00 8.00 BOPSU C DECOMP PJSM - N/D BOP'S AND RELATED HOSES AND LINES. SET BOP'S BACK ON PEDESTAL. REMOVE YOKE AND ANNULAR FROM BOP'S AND SWAP FIITINGS TO NEW ANNULAR. I 19:00 - 00:00 5.00 BOPSU C DECOMP PJSM - INSTALL NEW ANNULAR AND YOKE. SET BOP'S ON WELL - N/U CHOKE HOSE AND RELATED LINES. S ~ 9/19/2009 00:00 - 04:00 4.00 BOPSU C DECOMP CONTINUE N/U BOP'S AND RELATED LINES AND HOSES. 04:00 - 07:00 3.00 BOPSU P DECOMP TEST ANNULAR WITH 3-1/2" TEST J~., TEST CHOKE VALVES #10, #3 -TEST LOWER PIPE RAMS WITH 3-1/2" TEST JT. - KOO T UPPER PIPE RAMS WITH 5-1/2" TEST JT.. 07:00 - 09:30 2.50 BOPSU P DECOMP REMOVE BLANKING PLUG - RIG UP DUTCH SYSTEM - WSTALL DSM LUBRICATOR AND TEST TO 500 PSI - PULL BPV. 09:30 - 11:30 2.00 PULL P DECOMP M/U SPEAR ASSEMBLY AS FOLLOWS: BULLNOSE, PACKOFF ASSY., 4.805 ITCO SPEAR, AND X-O. P AR HANGER BACK OUT LDS HANGER PULLED FREE ~ 162K MOVED UP HOLE 132K 11:30 - 13:30 2.00 PULL P DECOMP PUMP SOAP SWEEP AND CIRCULATE SURFACE TO SURFACE ~ 4 BPM WITH 170 PSI. 13:30 - 15:00 1.50 PULL P DECOMP PULL HANGER TO FLOOR AND B/O AND UD SPEAR ASSY. AND HANGER. 15:00 - 16:00 1.00 PULL P DECOMP PJSM - R/U CASING EQUIPMENT - PULL 5-1/2" 17# TBG. FROM'5,000' TO 4,800'. SCHLUMBERGER SPOOLING CONTROL LINE. 16:00 - 17:00 1.00 PULL N SFAL DECOMP REPLACE HYDRAULIC HOSE FOR TUGGER. 17:00 - 20:30 3.50 PUIL P DECOMP CONTINUE UD TUBING FROM 4,800' TO 2,800'. UD SSSV. R/D CONTROL LINE SPOOIER. 20:30 - 00:00 3.50 PULL P DECOMP CONTINUE tJD 5-1/2" 17# TUBING FROM 2,800' TO SURFACE. RECOVERED 180 JTS. OF 5-1/2" TUBING - 1) CUT JT.= 21.96' FLARE 6-3/8" - 1) SSSV. - 40) RUBBER CLAMPS - 2) STAINLESS STEEL BANDS. 9/20/2009 00:00 - 01:00 1.00 PULL P DECOMP RIG DOWN CASING TOOLS AND CLEAR RIG FLOOR OF TOOLS AND EQUIPMENT. 01:00 - 02:00 1.00 PULL P DECOMP CLEAN RIG FLOOR 02:00 - 04:00 2.00 FISH P DECOMP PJSM - MOBILIZE BAKER FISHING BHA TO FLOOR & DOYON HANDLING TOOLS. 04:00 - 06:00 2.00 FISH P DECOMP PICK UP 3-1/2" SPEAR ASSEMBLY AS FOLLOWS: 1-1/4" BULL NOSE, 3-1/2" SPEAR PACKOFF ASSY, 1-1/4" EXT, ITCO SPEAR W/ 3.417" GRAPPLE, 2-3/8" EXT, 3-5/8" STOP SUB, 2) 2-3/8" SPEAR EXT, X-O, 6-1/4" BUMPER SUB, 6-1/4" OIL JARS, X-O, 6) 6-1/4" DC'S, X-O, 6-1/4" INTENSIFIER, Printed: 10/28/2009 3:52:48 PM • ~ BP EXPLORAT~ON Page 3 Qf 19 Operations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To ~ Hours Task I Code NPT I Phase Description of Operations 9/20/2009 04:00 - 06:00 2.00 FISH P DECOMP X-0.=242.38' 06:00 - 07:30 1.50 FISH P DECOMP RIH WITH SPEAR ASSY. FROM 242' TO 1,200' WITH 4" DP FROM PIPE SHED 1X1. 07:30 - 09:30 2.00 FISH P DECOMP SLIP & CUT DRILLING LINE - SERVICE RIG AND CHECK EQUIPMENT. 09:30 - 12:00 2.50 FISH P DECOMP CONTINUE RIH FROM 1,200' TO 3,534' PICKING UP 4" DP iX1 FROM PIPE SHED. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG AND INSPECT EQUIPMENT. 12:30 - 14:30 2.00 FISH P DECOMP CONTINUE RIH FROM 3,534' TO 4,910' PICKING UP 4" DP 1X1 FROM PIPE SHED. FILL DP - PARAMETERS: PUW=130K, SOW=120K, 1.2 BPM ~ 320 PSI. 14:30 - 15:30 1.00 FISH P DECOMP CONTINUE RIH TAG STUMP ~ 5,010' SET DOWN ON STOP SUB ~ 5,014' - P/U 20K OVER AND PRESSURED UP TO 2,000 PSI BLEEDING OFF SLOWLY. BLEED OFF PRESSURE. P/U TO 50K OVER AND PRESSURE UP TO 1,000 PSI PACKER BROKE FREE, P/U 10' PUW=165K. 15:30 - 18:30 3.00 FISH P DECOMP CBU ~ 3 BPM WITH 1850 PSI, OVERBOARD DIESEL CUT RETURNS ~ 200 BBLS AWAY, SHUT ANNULAR AND TAKE RETURNS OUT IA. TAKE 275 BBLS TO S~OP TANK BEFORE 9.8 PPG BRINE BACK. OBSERVE WELL FOR 15 MIN. HANG CEMENT LINE AND STAND BACK 1 STAND OF DP. BLOW DOWN TOP DRIVE. 18:30 - 20:00 1.50 FISH P DECOMP RIG UP TEST EQUIPMENT AND TEST PRODUCTION CASING TO 1 000 PSI FOR 10 CHARTED MIN. GOOD TEST) R/D TEST EQUIPMENT. 20:00 - 22:00 2.00 FISH P DECOMP POH WITH 3-1/2" SCAB LINER FROM 10,150' TO 5,140' STANDING BACK 4" DP IN DERRICK. 22:00 - 00:00 2.00 FISH P DECOMP UD INTENSIFIER, STAND BACK 2) STANDS OF 6-1/4" DC'S, AND UD JARS AND SPEAR ASSY. CLEAR FLOOR OF BHA. 9/21/2009 00;00 - 01:00 1.00 FISH P DECOMP R/U DOUBLE STACK TONGS TO LAY DOWN 3-1/2" SCAB LINER. 01:00 - 07:30 6.50 FISH P DECOMP PJSM - POH LAYING DOWN 3-1/2" STL SCAB LINER TO PIPE SHED. RETRIEVED 162) JTS - 2) PUP JTS - 1) SEAL STINGER - LAST JT. HAD HOLES PUNCHED IN IT. 07:30 - 09:30 2.00 FISH P DECOMP RIG DOWN CASING TOOLS AND REMOVE FROM FLOOR. 09:30 - 10:00 0.50 FISH P DECOMP RIG UP DUTCH SYSTEM. 10:00 - 15:30 5.50 FISH P DECOMP SPOT E-LINE UNIT - MOBILIZE E-LINE TOOLS TO RIG FLOOR - RIG UP SHEAVES - INSTALL LUBRICATOR, PACK OFF, AND GREASE HEAD 15:30 - 16:00 0.50 FISH P DECOMP PRESSURE TEST SWS BOP ASSY. TO 500 PSI FOR 5 CHARTED MIN. 16:00 - 22:30 6.50 FISH P DECOMP RIH WITH 4.5" GUAGE RING/JUNK BASKET. MADE SEVERAL ATTEMPTS TO GET INTO 5.5" STUMP ~'5,000'. RIH TO 10,113' AND TAGGED HARD BOTTOM 3 TIMES. CONFIRM WITH ANCH. ENGINEER DEPTH IS FAR ENOUGH. 22:30 - 23:30 1.00 FISH P DECOMP POH FROM 10,113' WITH GUAGE RING/JUNK BASKET ON E-LINE. 23:30 - 00:00 0.50 FISH P DECOMP P/U LUBRICATOR AND UD GUAGE RING. 9/22/2009 00:00 - 01:00 1.00 EVAL P DECOMP R/D JUNK BASKET/GAUGE RING, EMPTY OUT BASKET AND FOUND 8 CHUNKS OF SOFT RUBBER ELEMENTS. R/U 4.5" JET CUTfER TO CUT 5.5" TUBING. Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLORATION Page 4 afi 19 Operations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date' From - To Hc~urs Task Code NPT Phase Description of Operations 9/22/2009 01:00 - 03:00 2.00 EVAL P DECOMP RIH WITH 4.15" JET CUTTER WITH SCHLUMBERGER E-LINE TO 10,142' - CUT 5.5" TUBING @ 10.132', COLLAR LOCATED ~ 10,120'. INITIATED DETONATOR TWICE WITH GOOD SURFACE READINGS 03:00 - 05:00 2:00 EVAL P DECOMP POOH WITH JET CUTTER, JET CUTTER MISFIRED, TROUBLESHOOT MISFIRE, FOUND DETONATOR BURNED BUT DID NOT FIRE 05:00 - 06:30 1.50 EVAL N DFAL DECOMP WAITING ON BACK UP DETONATOR FROM DIFFERENT BATCH 06:30 - 08:00 1.50 EVAL N DFAL DECOMP RIH WITH 5-1/2" JET CUTTER WITH NEW DETONATOR. 08:00 - 09:00 1.00 EVAL N DFAL DECOMP LOG INTO POSITION AND CUT 5-1/2" TUBING AT i0,131' ELMD. GOOD SURFACE INDICATION OF POSITIVE FIRE. 09:00 - 10:30 1.50 EVAL N DFAL DECOMP POOH WITH JET CUTTER ASSEMBLY. 10:30 - 11:30 1.00 EVAL P DECOMP LD JET CUTfER ASSEMBLY WITH SCHLUMBERGER REPS. PUMU USIT LOGGING TOOL ASSEMBLY. 11:30 - 14:00 2.50 EVAL P DECOMP RIH WITH USIT LOGGING TOOL ASSEMBLY. RUN USIT IN EMENT DETECTION MODE FOR THE 9-5/8" CASING FROM 3,000' TO SURFACE. RUN REPEAT PASS ACROSS TOP OF CEMENT. FIELD PICK TOP OF CEMENT AT -2,050' WITH STRINGERS OBSERVED UP TO -1,800'. POOR CEMENT OBSERVED FROM 2,400' - 2,700'. POOH WITH USIT LOGGING TOOL ASSEMBLY. 14:00 - 15:00 1.00 EVAL P DECOMP RD SCHLUMBERGER E-LINE EQUIPMENT AND SEND USIT INFORMATION TO ANCHORAGE ENGINEERING. ~ 15:00 - 17:00 2.00 FISH P DECOMP PUMU BHA #3 AS FOLLOWS: BULLNOSE, PACKOFF, SPEAR, BUMPER SUB, JAR, XO, 6 EA DRILL COLLARS, XO, ACCELERATOR, XO. OAL = 229.99'. 17:00 - 18:00 1.00 FISH P DECOMP RIH WITH BHA #3 ON 4" DRILL PIPE FROM THE DERRICK. 18:00 - 18:30 0.50 FISH P DECOMP IN WITH 50 STANDS OF DRILLPIPE. ESTABLISH PARAMETERS PRIOR TO LATCHING THE FISH. PUW = 130K , SOW = 120K. BREAK CIRCULATION AT 2.1 BPM / 120 PSI. RIH AND SEE PRESSURE INCREASE TO 150 PSI AS SLIDING INTO TOP OF THE 5-1/2" TUBING STUMP AT 5,008'. CONTINUE RIH AND BOTTOM OUT AT 5,017'. PICK UP ON FISH AND PULL THE FISH FREE WITH PUW = 200K (70K FISH WEIGHT). PICK UP 5' AND PARK THE BHA. 18:30 - 20:00 1.50 FISH P DECOMP CIRCULATE BOTTOMS UP WITH 9.8 PPG BRINE AT A RATE OF 8 BPM / 1,220 PSI. PUMPED A TOTAL OF 565 BBLS WITH CLEAN RETURNS OBSERVED THROUGHOUT THE CIRCULATION. FLOW CHECK THE WELL - STATIC. 20:00 - 22:00 2.00 FISH P DECOMP POOH WITH BHA #3 STANDING BACK 4" DRILLPIPE IN THE DERRICK TO 4,862'. 22:00 - 23:30 1.50 FISH P DECOMP PJSM. UD INTENSIFIER, STAND BACK COLLARS AND REMOVE SPEAR FROM TUBING STUB. PULL CUT JOINT, OAL = 6.70" WITH 6.375" FLARE. 23:30 - 00:00 0.50 FISH P DECOMP MOBILIZE AND R/U POWER TONGS. PREPARE FLOOR TO PULL 5.5" TUBING. 9/23/2009 00:00 - 01:00 1.00 FISH P DECOMP UD SPEAR AND CUT JOINT. THE CUT JOINT = 6.05'. CONTINUE TO R/U TO PULL 5.5" TUBING. 01:00 - 01:30 0.50 FISH P DECOMP GREASE TOP DRIVE AND LUBRICATE RIG. PERFORM RIG INSPECTIONS. 01:30 - 09:00 7.50 PULL P DECOMP PULL AND UD 5.5" TUBING. PUMP ACROSS TOP OF HOLE Printed: 10/28/2009 3:52:48 PM ~ ~ BP" EXPLORATION Page 5 of 19' Operations Sumrnary R~part Legal Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 I-; _ i I J_ I- , 9/23/2009 01:30 - 09:00 7.50 PULL P 09:00 - 10:00 I 1.001 PULL I P 10:00 - 10:30 I 0.501 CASE I P 10:30 - 11:30 I 1.001 FISH I P 11:30 - 12:00 I 0.501 FISH I P 12:00 - 12:30 I 0.501 FISH I P 12:30 - 14:00 I 1.501 FISH I P 14:00 - 15:00 I 1.001 FISH I P 15:00 - 21:30 I 6.501 FISH I P 21:30 - 23:00 I 1.501 FISH I P 23:00 - 00:00 I 1.001 FISH I P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations DECOMP WITH 9.8 PPG BRINE. RECOVERED A TOTAL OF 185 ADDITIONAL JOINTS OF 5-1/2" TUBING AND 1 CUT JOINT = 8.47'. BETWEEN BOTH FISHING RUNS, THE TOTAL NUMBER OF 5-1/2" JOINTS RECOVERED = 366 JTS. TUBING IN GOOD CONDITION. TUBING HAS 8-RD THREADS. DECOMP RD 5-1/2" HANDLING EQUIPMENT AND LAY DOWN THE BEAVER SLIDE. DECOMP CLOSE THE BLIND RAMS AND PRESSURE UP THE WHOLE WELLBORE TO 3,500 PSI AND ATTEMPT TO GET A GOOD PRESSURE TEST ON THE 9-5/8" CASING - FAILED TEST. IT TOOK 8 BBIS TO ACHIEVE 3,500 PSI. LOST APPROXIMATELY 1,000 PSI IN 5 MINS. BLEED THE PRESSURE OFF. DECOMP CLEAR AND CLEAN THE RIG FLOOR TO PROVIDE ADEQUATE WORKING SURFACE DECOMP START PICKING UP BHA COMPONENTS TO THE RIG FLOOR. DECOMP PRE-TOUR CHECKS / INSPECTIONS AND SERVICE THE RIG. DECOMP PUMU BHA #4 AS FOLLOWS: DRESSING SHOE, 3 EA WASHPIPE EXTENSIONS, DRESSING MILL, WASHOVER JUNK BASKET, DOUBLE PIN SUB, 9-5/8" SCRAPER, BIT SUB, 8.4375" STABILIZER (FOR DRIFT), BUMPER SUB, XO, 6 EA DRILL COLLARS, XO, PUMP OUT SUB, XO. OAL = 228.39'. WASHOVER LENGTH TO INNER MILL = 15.80'. DECOMP RIH WITH THE 8.4375" STABILIZER TO DRIFT 53#, 8.535" ID CASING FROM SURFACE T0 72'. ONLY ABLE TO GET IT 3" INTO THE 9-5/8" CASING. OVERPULL 15K TO PULL FREE. UD STABILIZER AND M/U DRILL COLLARS TO BHA. DECOMP RIFf WITH 4" DP FROM 228' TO 3,200' (HAD TO WORK SCRAPER THRU 72' OF 53# CASING). RECIPROCATE SCRAPER THRU ZXP PACKER SETTING DEPTH FROM 3,150' TO 3,270' 4 TIMES. CONTINUE TO RIH OUT OF DERRICK TO 5,075'. SINGLE IN HOLE OUT OF PIPE SHED, CONTINUE TO RIH. DECOMP ESTABLISH PARAMETERS: PUW = 190K, SOW = 150K, ROT. WT = 165K, 60 RPM / 5-7K TORQUE. CIRCULATE AT 3 BPM / 200 PSI. TAG TUBING STUMP AT 10,133' AND ROTATE DOWN OVER STUMP AT 60 RPM / 7-9K TORQUE WITH 1-2K WOM. INCREASE PUMP TO 5 BPM / 500 PSI AND TAG INNER MILL ON STUMP AT 10,148' (SHOE DEPTH). DRESS OFF STUMP FROM 10,133' TO 10,134' AT 60 RPM / 7-10K TORQUE WITH 5K WOM. ROTATE OVER STUMP 2 TIMES AND WORK OVER STUMP WITH OUT ROTATION - GOOD. SET DOWN INNER MILL ON STUMP 5K WITH 50 PSI PUMP INCREASE. PICK UP 3' OFF OF STUMP FOR CIRCULATION. DECOMP PUMP 30 BBL HI-VIS SWEEP DOWN DRILL PIPE INTO ANNULUS AT 5 BPM / 600 PSI WITH SHOE OVER STUMP UNTIL ENTIRE SWEEP ENTERED ANNULUS. P/U ABOVE STUMP AND INCREASE PUMP RATE TO 9.5 BPM / 2,030 PSI. ROTATE AND RECIPROCATE WITH 20 RPM AND 60' Printed: 10/28/2009 3:52:48 PM ~ ~ _ __ BP EXPLORATION Page 6 of 19 Operations S'ummary Repart Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2009 23:00 - 00:00 1.00 FISH P DECOMP 9/24/2009 00:00 - 01:00 1.00 FISH P DECOMP 01:00 - 01:30 0.50 FISH P DECOMP 01:30 - 05;00 3.50 FISH P DECOMP 05:00 - 08:00 3.00 FISH P DECOMP 08:00 - 08:30 0.50 CASE P DECOMP 08:30 - 09:00 0.50 EVA~ P DECOMP 09:00 - 10:30 1.50 EVAL P DECOMP 10:30 - 12:00 1.50 EVAL P DECOMP 12:00 - 12:30 0.50 EVAL P DECOMP 12:30 - 14:00 1.50 EVAL P DECOMP 14:00 - 14:30 0.50 EVAL P DECOMP 14:30 - 16:00 1.50 EVAL P DECOMP STROKES. FINISH CIRCULATING SWEEP AT 9.5 BPM / 2,030 PSI. RECOVERED SANDS, FINE METAL SHAV(NGS AND LARGE RUBBER CHUNKS. CIRCULATE UNTIL CLEANED UP. BLOW DOWN LINES. INSPECT TOP DRIVE AND LUBRICATE RIG. INSPECT AND SERVICE RIG EQUIPMENT. POH WITH BHA #4 FROM 10,134'. PUMP ACROSS TOP OF HOLE WTIH 9.8 PPG BRINE. PJSM. STAND BACK DRILL COLLARS. UD BHA AS PER BAKER. INSPECT WEAR PATTERN ON THE INNER MILL AND GOOD INDICATION OF BEING ON TOP OF THE STUMP. EMPTY OUT JUNK BASKET. RECOVERED FRAC SAND, SHAVINGS AND A SMALL PIECE OF CONTROL LINE CLAMP. CLEAR AND CLEAN RIG FLOOR. CLOSE THE BLIND RAMS AND PRESSURE TEST THE WELLBORE FROM SURFACE AGAINST THE 9-5/8" CASING TO 1,000 PSI FOR 10 CHARTED - ( OMPETENT KILL WEIGHT BRINE BARRIER). IT TOOK 2.3 BBLS TO ACHIEVE TEST PRESSURE. PRE-JOB SAFETY MEETING WITH THE WSL, TOOLPUSHER, CREW AND HALLIBURTON REP. PUMU 9-5/8" RTTS ASSEMBLY WITH HALLIBURTON REP. RIH WITH THE 9-5/8" RTTS ON 4" DRILL PIPE FROM THE DERRICK. THE PURPOSE OF THIS RUN IS TO TEST THE 9-5/8" CASING AND FIND IF AND WHERE THE LEAK IS IN THE CASING. SLIP AND CUT DRILLING LINE. PRE-TOUR INSPECTIONS OF TOP DRIVE, DERRICK, PVT, DRAWWORKS AND CROWN. RESUME RIH WITH 9-5/8" RTTS ON 4" DRILL PIPE FROM THE DERRICK. IN WITH 63 STANDS OF DRILL PIPE. ESTABLISH PARAMETERS: PUW = 130K , SOW = 120K. SET THE 9-5/8" RTTS AT 5,997' CENTER OF ELEMENT. SET 20K DOWN TO VERIFY SET. CHECK THE OA = 0 PSI. BREAK OUT TOP DRIVE, MU HEADPIN WITH CEMENT LINE AND RU TEST EQUIPMENT. TEST THE 9-5/8" CASING BELOW THE RTTS TO 3,500 PSI FOR 30 CHARTED MINS - GOOD TEST. LOST LESS THAN 100 PSI IN THE 30 MINUTES WITH SIGNS OF STABILIZATION AT THE END. BLEED DOWN AND LINE UP TO TEST THE 9,~- /8" CASINC FROM ABOVE THE RTTG T[) SuRFACF, BLEED DOWN AND RD TEST EQUIPMENT. 16:00 - 16:30 0.50 EVAL P DECOMP RELEASE THE 9-5/8" RTfS PER HALLIBURTON REP. 16:30 - 17:30 1.00 EVAL P DECOMP POOH TO RE-SET THE 9-5/8" RTl'S HIGHER IN THE HOLE AND PROVE COMPETENT 9-5/8" CASING ABOVE THE PROPOSED LINER TOP PACKER SET DEPTH. 17:30 - 18:00 0.50 EVAL P DECOMP IN WITH 39 STANDS OF DRILL PIPE. ESTABLISH PARAMETERS: PUW = 102K , SOW = 100K. SET THE 9-5/8" RTTS AT 3,715' CENTER OF ELEMENT. SET 20K DOWN TO VERIFY SET. BREAK OUT TOP DRIVE, MU HEADPIN Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLORATION: Page 7 af 19 Operations Summary Report Lega! Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - Ta Hours Task Code NPT 9/24/2009 17:30 - 18:00 0.50 EVAL P 18:00 - 19:30 1.50 EVAL P 19:30 - 21:30 2.00 EVAL P 21:30 - 23:30 2.00 FISH P 23:30 - 00:00 0.50 FISH P 9/25/2009 00:00 - 01:00 1.00 FISH P 01:00 - 04:00 3.00 FISH P 04:00 - 05:30 1.50 FISH P 05:30 - 06:30 1.00 FISH P 06:30 - 08:30 2.00 FISH P 08:30 - 10:00 1.50 FISH P 10:00 - 10:30 0.50 CLEAN P 10:30 - 11:30 1.00 CLEAN P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations DECOMP WITH CEMENT LINE AND RU TEST EQUIPMENT. CHECK THE OA = 0 PSI. DECOMP LINE UP TO TEST FROM BELOW. UNABLE TO ACHIEVE A GOOD TEST. BLEED DOWN. LINE UP TO TEST THE 9-5/8" CASING ABOVE THE RTTS TO SURFACE. TEST FROM 3,715' TO SURFACE TO 3,500 PSI FOR 30 CHARTED MIN - PASSED. TEST LOST 40 PSI FIRST 15 MIN AND 10 PSI SECOND 15 MIN. OA = 0 PSI. RELEASE RTTS AND BLOW DOWN EQUIPMENT. MONITOR WELL FOR 10 MIN - STATIC. DECOMP POH WITH RTTS STANDING BACK IN DERRICK. UD RTTS. DECOMP P/U 9-5/8" RBP WITH (2) STANDS DRILL COLLARS. RBP WILL BE USED AS BARRIER FOR WELLHEAD WORK. RIH ON 4" DP TO 1,898' (COE = 1,903'). PUW = 90K, SOW = 90K. M/U TOP DRIVE TO DP. SET RBP WITH 15K DOWN WEIGHT, PULL 10K OVERPULL TO CONFIRM SET. DECOMP R/U TO TEST. SHUT ANNULAR AROUND DP. DECOMP TEST 9-5/8" RBP BARRIER TO 3,500 PSI FOR 10 CHARTED MIN - PASSED. BLEED OFF AND OPEN ANNULAR. BLOW DOWN LINES. DECOMP DUMP 2,200# OF 20/40 RIVERSAND DOWN DP. CIRCULATE 1 DP VOLUME AT 1.5 BPM TO CLEAR SAND. DECOMP POH WITH RBP RETRIEVING TOOL. UD HALLIBURTON TOOL. DECOMP PUMU BHA #5: 8.25" M.S. CUTTER, XO, POS, XO, (6) DRILL COLLARS, XO, AND XO. OAL = 192.68'. CUTTER WILL BE USED TO CUT 9-5/8". DECOMP RIH WITH BHA #5 ON 4" DRILL PIPE FROM THE DERRICK. IN WITH 18 STANDS OF DRILL PIPE. ESTABLISH PARAMETERS: PUW = 90K , SOW = 90K. TAG TOP OF THE SAND AT 1,845' (53' OF SAND ABOVE THE TOP OF THE 9-5/8" RBP). DECOMP PICK UP HOLE AND BREAK CIRCULATION AT 4.7 BPM / 450 PSI TO EXTEND KNIVES AND LOCATE THE COLLAR ABOVE PROPOSED CUT DEPTH. FIND COLLAR AT 1,779'. F~JI -l 10' AND PARK THE BHA TO CUT THE 9-5/8" CASING AT 1,789'. ESTABLISH PARAMETERS: RW = 90K , 50 RPM , WORK CIRCULATION RATE UP TO 70 SPM / 930 PSI WITH 5,000 FT-LBS OF TORQUE. OBSERVE 30 PSI OF PRESSURE ON THE OA INDICATI{VG A CUT. STAY ON THE CUT FOR A FEW MINUTES TO ENSURE GOOD CUT WORKING CIRCULATION PRESSURE UP TO 1,200 PSI. OA INCREASED TO 100 PSI. SHUT DOWN PUMP AND PICK UP 5'. BREAK CIRCULATION TO EXTEND KNIVES AT 5.4 BPM / 500 PSI AND RIH TO LOCATE THE CUT - OK. OPEN THE OA AND ATTEMPT TO CIRCULATE OUT THE 13-3/8" X 9-5/8" ANNULUS IN PREPARATION FOR ARCTIC PACK CIRC OUT AND SUCCESSFUL AT 2 BPM / 100 PSI. SHUT IN THE OA. DECOMP HOLD PRE-JOB SAFETY MEETING WTIH WSL, TOOIPUSHER, CREW, MI MUD ENGINEER, LITTLE RED HOT OIL AND CH2M HILL ON ARCTIC PACK CIRC OUT. DECOMP OPEN PUMP OUT SUB WITH BAKER REP WITH 1,200 PSI. Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLORATION Page 8 of 19 Op~rations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 9/25/2009 10:30 - 11:30 1.00 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 14:30 2.00 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:00 1.00 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 19:00 2.00 FISH P 19:00 - 20;00 1.00 FISH P 20:00 - 22:00 2.00 FISH P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations DECOMP PRESSURE TEST LITTLE RED SERVICES TO 2,500 PSI - OK. BREAK CIRCULATION DOWN THE DRILL PIPE WITH 120 DEGF DIESEL AT A RATE OF 2 BPM / 625 PSI FOR 20 BBLS. SHUT DOWN LITTLE RED, CLOSE THE PIPE RAMS AND OPEN THE OA. RESUME PUMPING WITH LITfLE RED FOR AN ADDITIONAL 50 BBLS OF HEATED DIESEL TAKING RETURNS UP THE OA AT A RATE OF 2 BPM / 700 PSI. SHUT DOWN LITTLE RED AND LINE UP TO DISPLACE THE DIESEL INTO THE OA WITH THE RIG PUMP. BREAK CIRCULATION AND PUMP 20 BBLS OF 120 DEGF 9.8 PPG BRINE DOWN THE DRILL PIPE AT 2 BPM / 120 PSI. SHUT DOWN PUMPING AND SHUT IN THE OA. DECOMP ALLOW THE 70 BBLS OF DIESEL TO SOAK IN THE 13-3/8" X 9-5/8" ANNULUS FOR 1 HOUR. DECOMP OPEN THE OA AND RESUME CIRCULATING DOWN THE DRILL PIPE WITH 120 DEGF 9.8 PPG BRINE UNTIL ALL OF THE DIESEL IS DISPLACED FROM THE OA. CIRCULATING AT A RATE OF = 2 BPM / 70 PSI. ONCE THE DIESEL WAS FULLY DISPLACED, PUMPED A 35 BBL SAFE SURF O PILL AT 5 BPM / 420 PSI. DISPLACED THE PILL INTO THE 13-3/8" X 9-5/8" ANNULUS WITH 9.8 PPG BRINE AT A RATE OF 6 BPM / 730 PSI. FINISHED DISPLACING THE PILL WITH 9.8 PPG BRINE OUT OF THE OA AT A RATE OF 2 BPM / 60 PSI. ONCE THE PILL WAS COMPLETELY OUT OF THE OA, INCREASED THE RATE TO 6 BPM / 580 PSI UNTIL CLEAN 9.8 PPG BRINE RETURNS OBSERVED ON SURFACE. ALL DEAD CRUDE RETURNS FROM THE OA AND NO ARCTIC PACK. SENT260 BBLS OF CRUDE AND DIESEL FOR RECYCLE. DECOMP SHUT IN OA. BLOW DOWN 2" HARDLINE TO THE TIGER TANK. OPEN THE RAMS AND CIRCULATE BOTTOMS UP BETWEEN THE 4" DRILL PIPE AND 9-5/8" ANNULUS WITH 9.8 PPG BRINE AT A RATE OF 12 BPM / 180 PSI. SHUT DOWN AND IvfONlTOR WELL STATIC - OK. DECOMP POOH WITH BHA #5 STANDING BACK DRILL PIPE IN THE DERRICK. DECOMP BREAK OUT AND LAY DOWN BHA #5 COMPONENTS. KNIVES SHOWED GOOD INDICATION OF WEAR AND HAVING CUT THE 9-5/8" CASING. PUMU BHA #6 AS FOLLOWS: BULL NOSE, SPEAR PACKOFF, SPEAR, SPEAR EXTENSION, STOP SUB, XO. OAL = 14.83'. THE PURPOSE OF THIS BHA IS TO SPEAR THE 9-5/S" AND DE-COMPLETE. DECOMP BOLDS WITH CAMERON REP. MONITOR OA THRU 2" - STATIC. PULL HANGER FREE WITH 255K. 1 LOCK DOWN PIN SHEARED TO PULL FREE. FELL OFF TO PUW OF 127K TO FLOOR. HAD TO WORK HANGER THRU BOP STACK. DECOMP UNLATCH SPEAR AND B/O HANGER. L/D HANGER AND SPEAR. DECOMP M/U XO AND CIRCULATING PIN. CBU AT 9 BPM / 300 PSI. RETURNS HAVE TRACES OF CRUDE AND CLEANED UP ON FINAL CIRCULATION. MOBILIZE AND ASSEMBLE 14" P~inted: 70/28/2009 3:52:48 PM ~ ~ BP EXPLORf4TION Page 9 of 19 Qperations Summary Report Legal Well Name: 02-06 Common Weil Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hc~urs Task Code NPT Phase ' Description of Operations 9/25/2009 20:00 - 22:00 2.00 FISH P DECOMP UHT POWER TONGS. 22:00 - 00:00 2.00 FISH P DECOMP PJSM. L.UD 9-5/8" CASING TO 1,100'. 9/26/2009 00:00 - 01:30 1.50 FISH P DECOMP CONTINUE TO UD 9-5/8" CASING. , PUMP ACROSS HOLE WITH 9.8 PPG BRINE. PULLED A TOTAL OF 39 JOINTS OF 9-5/8" CASING, 7 BOWSPRING CENTRILIZERS AND 1 CUT JOINT (10.58' OAL). 01:30 - 02:30 1.00 FISH P DECOMP R/D POWER TONGS. CLEAN AND CLEAR RIG FLOOR. 02:30 - 04:30 2.00 FISH P DECOMP MOBILIZE BHA #7 TO RIG FLOOR AND M/U PER BAKER REP. DRESS MILL SHOE, WP EXTENSION (7.44" SWALLOW), INNER MILL, JUNK BASKET, SCRAPER, BRUSH, FLOAT SUB, BUMPER SUB AND DRILL COLLARS. OAL = 231'. BHA WILL BE USED TO DRESS OFF 9-5/8" CASING S7UMP. 04:30 - 05:00 0.50 FISH P DECOMP INSPECT TOP DRIVE AND LUBRICATE RIG. 05:00 - 06:00 1.00 FISH P DECOMP RIH WITH BHA #7 ON 4" DP. 06:00 - 06:30 0.50 FISH P DECOMP IN WITH 16 STANDS AND ESTABLISH PARAMETERS: PUW = 91 K, SOW = 91 K. TAG THE TOP OF THE 9-5/8" STUMP AT 37' IN ON STAND #17 = 1,789'. SWALLOW THE STUMP AND TAG INNER MILL WITH THE SHOE AT 1,796' (INNER MILL AT 1,789'). DRESS OFF 1' PER BAKER REPS INSTRUCTIONS. 50 RPM , RW = 91 K, 1,000 FT-LB TORQUE, 3 BPM / 70 PSI , WEIGHT ON MILL = 5K. PICK UP OFF OF IT AND SWALLOW THE STUMP WITH NO ROTATION TO CONFIRM TOP OF STUMP AT 1,790'. 06:30 - 07:00 0.50 FISH P DECOMP PUMP SAFE SURF O PILL AROUND AT A RATE OF 8 BPM / 320 PSI. ONCE THE PILL RETURNED TO SURFACE DEPLOY A HI-VIS PILL TO AID IN CLEANING THE HOLE. ONCE THE HI-VIS SWEEP REACHED THE BIT, PICK UP OFF OF THE STUMP AND ROTATE AND RECIPROCATE THE PIPE WHILE DISPLACING THE SWEEP OUT OF THE HOLE. 07:00 - 07:30 0.50 FISH P DECOMP SHUT THE PUMP DOWN AND PICK UP HOLE. COME DOWN OVER THE STUMP WITH NO PUMP AND NO ROTATION TO ENSURE WE CAN GET OVER THE STUMP. RIH WITH THE SHOE WITH NO PROBLEMS TO 1,797' WHICH PUTS THE TOP OF THE 9-5/8" STUMp AT 1,790'. FLOW CHECK THE WELL FOR 15 MINS - STATIC. 07:30 - 08:30 1.00 FISH P DECOMP POOH WITH BHA #7 STANDING BACK 4" DRILL PIPE IN THE DERRICK. 08:30 - 09:30 1.00 FISH P DECOMP ON SURFACE WITH BHA #7. BREAK OUT AND LAY DOWN COMPONENTS WITH BAKER REP. INSPECT WEAR PATTERN ON INNER MILL AND GOOD INDICATION OF MILLING ON 9-5/8" STUMP. EMPTY OUT JUNK BASKET AND RECOVERED APPROXIMATELY 3 LBS OF METAL SHAVINGS. 09:30 - 10:00 0.50 BOPSU P DECOMP PRE-JOB SAFETY MEETING ON ND BOPE AND TUBING SPOOL. 10:00 - 13:00 3.00 BOPSU P DECOMP ND THE 13-5/8" 5K BOPE AN CREW CHANGE AT NOON AND PERFORM PRE-TOUR INSPECTIONS. 13:00 - 15:00 2.00 WHSUR P DECOMP ND THE ADAPTER FLANGE AND REMOVE FROM THE TUBING SPOOL WITH CAMERON REPS. ND TUBING SPOOL AND REMOVE FROM THE WELLHEAD UTILIZING Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLORATION Page 10 t~f 19 Operations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 ' Date From - Tv Hours Task ~ Code NPT 9/26/2009 I 13:00 - 15:00 I 2.00 I WHSUR ~ P 15:00 - 15:30 I 0.50 I W HSU R ~ P 15:30 - 17:30 I 2.00 I WHSUR I P 17:30 - 19:00 I 1.50I WHSUR I P 19:00 - 00:00 I 5.00 I WHSUR I P I9/27/2009 I00:00 - 01:30 ~ 1.50I WHSUR I P 01:30 - 02:30 I 1.00 I WHSUR ~ P 02:30 - 05:00 I 2.501 WHSUR I P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations DECOMP BRIDGE CRANES. UTILIZE LOADER TO REMOVE ALL COMPONENTS FROM THE CELLAR AREA. DECOMP HOLD PRE-JOB SAFETY MEETING WITH THE WELL SITE LEADER, TOOLPUSHER, RIG CREW, CAMERON REPS AND WACHS CUTTER REP ON TORCH CUTTING THE 30" CONDUCTOR. DECOMP USE CELLAR PUMP TO VAC OUT RAIN WATER IN THE CELLAR AS LOW AS POSSIB~E TO BE ABLE TO CUT THE 30" AS LOW AS POSSIBLE. DRAIN RAIN WATER OUT OF 30" X 20" ANNULUS AND SUCK OUT. TORCH CUT THE 30" W(TH THE RIG WELDER. PICK UP ON BOTH HALVES OF THE 30" THAT WERE TORCH CUT WITH THE BRIDGE CRANES AND REMOVE FROM THE CELLAR. DECOMP WIPE DOWN AND PREPARE THE 20" FOR CUTTING WITH THE WACHS CUTTER. VAC OUT REMAINING RAIN WATER IN TFiE BOTTOM OF THE CELLAR. THERE IS A COLLAR ON THE 20" RIGHT AT PAD LEVEL WHICH WE WILL NOT BE ABLE TO CUT BELOW WITH THE WACHS CUTTER. WILL HAVE TO CUT IT RIGHT AT THE TOP OF THE COLLAR. DECOMP PJSM FOR MAKING OUTSIDE WACH'S CUT ON 20". OOA FLOWING CRUDE WITH PENCIL SIZED STREAM. BLEED DOWN, FLOW SLOWLY TAPERING OFF. R/U TO RUN 9-5/8" CASING. DECOMP MONITOR WELL. WELL HAS STEADY STREAM OF APPOX 1/8" AFTER 2 HRS. SHUT IN TO 100# GAUGE, ANNULUS BUILT TO 2 PSI AFTER 30 MIN. CONFlRM WITH RWO ENGINEER TO PROCEED WITH CUT. DECOMP SUCK OUT CRUDE FROM ANNULUS. PREP CELLAR WTIH TOOLS FOR WACH'S CUT. SUCK OUT 30" X 20" ANNULUS OF CRUDE AND WATER WITH VAC TRUCK. DECOMP PJSM WITH RIG CREW, CAMERON, WACH'S REP AND VAC TRUCK DRIVER. CUT 20" CASING WITH WACH'S CUTTER. CASING ROSE 12" AFTER CUT TO EXPOSE 13-3/8" WITFi ENOUGH ROOM TO INSTAIL EXTERNAL WACH'S CUTTER. HOLD ANOTHER PJSM WITH CREW. CUT 13-3/8" CASING WITH WACH'S CUTTER. DECOMP PULL PERMAFRO T W LLH AD 13- " AN , 05:00 - 07:00 I 2.001 WHSUR I P 07:00 - 08:00 1.00 CASE P 08:00 - 08:30 0.50 CASE P 08:30 - 09:00 0.50 CASE P SECTION OUT OF CELLAR. CLEAN OUT CELLAR OF . 'HE'ZO'~fil~'D 13-3/8" ARE LEANING AGAINST THE 30". LOOK AT THE SITUATION WTIH THE WEIL SITE LEADER, TOOLPUSHER, DRILLER AND WELDER. WILL NEED TO CENTER UP AFTER THE 9-5/8" IS RUN PRIOR TO CEMENTING. WILL BUILD WEDGES AND SECURE BETWEEN THE 20" AND 13-3/8". THE 9-5/8" WILL BE CENTERED THROUGHOUT THE CEMENT JOB WTIH COME-A-LONGS. TIEB1 RU TO RUN 9-5/8" CASING..SPOT CEMENT HEAD AND DOYON CASING EQUIPMENT. TIEB1 PRE-JOB SAFETY MEETING ON RUNNING 9-5/8" TIE-BACK TO SURFACE WTIH WELL SITE LEADER, TOOLPUSHER, RIG CREW, HALLIBURTON REP AND BAKER REPS. TIEB1 PU 9-5/8" BOWEN CASING PATCH AND ECP ASSEMBLY. Printetl: 10/28/"L009 3:52:48 PM ~ ~ BP EXPLORATION Page 11 af 19 Qperation~ Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Da#e From - To Hours Task C€~de NPT Phase Description of Operations 9/27/2009 I08:30 - 09:00 I 0.50I CASE ~ P 09:00 - 13:30 I 4.501 CASE ~ P 13:30 - 14:00 I 0.50 I CASE I P 14:00 - 16:00 I 2.00 ~ WHSUR I P 16:00 - 17:00 I 1.00 17:00 - 17:30 I 0.501 WHSUR I P 17:30 - 18:00 ~ 0.50 18:00 - 21:00 ~ 3.00 ~ R TIEB1 PU HES ES CEMENTER AND MU TO THE PATCH ASSEMBLY. PU 9-5/8" XO JOINT FROM BTC TO CS HYDRIL 563 AND MU TO ES CEMENTER. MU BOTH BTC CONNECTIONS ABOVE AND BELOW THE CEMENTER TO THE MARK AND BAKERLOK'D. ONE CENTRALIZER WAS PLACED ON THE XO JOINT. TIEB1 RIH WITH JOINTS OF 9-5/8", 47#, L-80, HYDRIL 563 CASING. USING JET LUBE SEAL GUARD ON ALL CONNECTIONS. MAKING UP TO OPTIMUM TORQUE OF 15,800 FT-LBS WITH TORQUE TURN EQUIPMENT. PLACING ONE FREE FLOATING CENTRALIZER PER JOINT. TAKING ALL PIPE DISPLACEMENT INTO THE CELLAR AND SUCKING OUT WITH VAC TRUCK. TIE61 RAN A TOTAI.OF 44 FULL JOINTS OF 9-5/8", 47#, L-80, CS HYDRIL CASING. THE 45TH JOINT WILL BE CUT TO INSTALL THE WELLHEAD ON TOP OF IT. RAN A TOTAL OF 45 FREE FLOATING CENTRALIZERS. ESTABLISH PARAMETERS PRIOR TO ENGAGING THE TOP OF THE 9-5/8" STUMP. PUW = 125K , SOW = 125K. TAG THE TOP OF THE 9-5/8" STUMP AT 1,791' AND SET THE WHOLE STRING WEIGHT ON IT. PULL UP TO 30K OVER TO ENSURE GRAPPLE IS SET - OK. PULL TEST THE CASING TO 250K - OK. SLACK OFF ALL THE WEIGHT COMPLETELY ON THE CASING PATCH. RU XO TO BTC AND CEMENT HEAD WITH HALLIBURTON REP. TIEB1 CLEAN UP IN THE CELLAR. DUE TO THE 20" AND 13-3/8" LAYING AGAINST THE 30" CONDUCTOR, USE RIG WELDER TO MAKE AND INSTALL WEDGES BETWEEN THE 20" AND 13-3/8" TO CENTER THE PIPE. INSTALL WEDGES TO CENTER THE 9-5/8" INSIDE OF THE 13-3/8" IN PREPARATION FOR THE CEMENT JOB. CLEAR AND CLEAN THE RIG FLOOR OF UNNECESSARY EQUIPMENT AFTER RUNNING 9-5/8" CASING. TIEB1 BACK UP AND SPOT THE SCHLUMBERGER CEMENTERS. RU TO THE CEMENT LINE. BACK UP AND SPOT THE CH2M HILL VAC TRUCKS TO THE CELLAR FOR RETURNS AND TO THE SCHLUMBERGER CEMENTERS FOR DISPLACEMENT FLUID. TIE61 DECISION MADE WITH CAMERON REP TO INSTALL WEDGES BETWEEN THE 30" AND 20" TO ENSURE 7HAT THE WELLHEAD/TREE WILL BE VERTICAL AND WON'T MOVE INSIDE THE 30". CUT AND INSTALL WEDGES WiTH THE RIG WELDER. TIEBi RU IN THE CELLAR TO TAKE RETURNS FOR WARMING UP THE FLUID IN PREPARATION FOR THE CEMENT JOB. COVER THE TOP OF THE 13-3/8" X 9-5/8" ANNULUS IN THE CELLAR WITH ANCHORED HERCULITE TO MINIMIZE FLUID RELEASE ONCE THE ES CEMENTER SHIFTS OPEN. TIEBi PRE-JOB SAFETY MEETING WITH THE WELL SITE LEADER, BAKER PRODUCTION AND FISHING REPS, AND RIG CREW ON INFLATING THE ECP, OPENING THE ES CEMENTER AND CIRCULATING BRINE UNTIL 80 DEGF RETURNS. TEST 9-5/8" BAKER PATCH TO 1,000 PSI FOR PflfltBtl: 10/'Lt5/ZUUy 3:5"L:4H F'M ~ ~ BP EXPLQR~4TIDN Page 12 0~ 19 Operatians Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To 'Hours Task Gode NPT Phase ' Description of Operations 9/27/2009 18:00 - 21:00 3.00 REMCM P TIE61 10 MIN. SET ECP PER BAKER AND TEST TO 2,000 PSI FOR 10 MIN (TOOK 13.9 GAL TO INFLATE). SHEAR ES CEMENTER WITH 3,050 PSI AND ESTABLISH CIRCULATION INTO CELLAR USING CELLAR PUMP TO CAPTURE FLUID BACK TO PITS. CHART ALL TESTS. CIRCULATE 90 DEGF 9.8 BRINE AT 2.5 BPM / 50 PSI UNTIL 80 DEGF BRINE AT SURFACE. CIRCULATED A TOTAL OF 220 BBLS. 21:00 - 23:30 2.50 REMCM P TIEBi CEMENT PJSM WITH RIG CREW AND 3RD PARTY CONTRACTORS. FINISH R/U OF TRUCKS / HOSES TO CELLAR TO TAKE RETURNS. COMPLETE CEMENT TRUCK STALL TESTS, TEST SLB LINES TO 4,500 PSI. BATCH UP FIRST TUB TO WEIGHT OF 15.8 PPG "G" CEMENT WITH GASBLOK. USE DIRTY BRINE TRUCK AND CELLAR PUMP TO TAKE BRINE RETURNS FROM CELLAR. START PUMPING CEMENT AT 22:06 HRS. PUMP 127 BBLS (615 SACKS) OF CLASS "G", 15.8 PPG, 1.16 FT3/SK CEMENT AT 4.5 BPM / 200 PSI. CEMENT PUMPED AWAY AT 22:36 HRS. DROP PLUG (GOOD SIGN). DISPLACE CEMENT WITH 9.8 BRINE FROM CEMENT TRUCK AT 6.5 BPM / 400 PSI - CAUGHT CEMENT 43 BBLS INTO CIRCULATION. SHUT DOWN DIRTY BRINE TRUCK FROM TAKING RETURNS, SWAP TO CONTAM TRUCK AND SUPER SUCKER FOR CEMENT RETURNS IN CELLAR. CONTINUE DiSPLACiNG CEMENT AT 7.5 BPM / 520 PSI. CONTAMINATED CEMENT RETURNS SEEN AT SURFACE AT 103 BBLS INTO DISPLACEMENT WITH GOOD CEMENT RETURNS 70 SURFACE THROUGHOUT DISPLACEMENT. SLOW PUMPS TO 2.5 BPM / 330 PSI TO BUMP PLUG - BUMP PLUG. ES CEMENTER CLOSED AT 1,550 PSI, BUMP PLUG WITH 1,800 PSI. DISPLACED CEMENT WITH 131 BBLS. CIP AT 23:06 HRS. BLEED PRESSURE OFF, CHECK FLOATS - GOOD. RETURNED 24 BBLS OF CEMENT TO SURFACE. 23:30 - 00:00 0.50 REMCM P TIEB1 WASH UP CELLAR OF EXCESS CEMENT. EVACUATE FLUIDS FROM SLOP TANK WITH DIRTY TRUCKS. WASH UP CEMENT LINES AND R/D HARDLINE. USE VAC TRUCK TO SUCK OUT 9-5/8" CASING DOWN BELOW CUT DEPTH. R/D VAC TRUCKS AND SLB CEMENTERS. 9/28/2009 00:00 - 00:30 0.50 WHSUR P TIE61 CONTINUE TO SUCK OUT 9-5/8" CASING JOINT TO BELOW WACH'S CUT. CREW CHANGE, PRE-TOUR CHECKS. 00:30 - 01:30 1.00 WHSUR P TIEB1 PJSM. MAKE WACH'S CUT ON 9-5/8" CASING WITH CAMERON REP. UD CASING JOINT AND REMOVE WACH'S CUTTER. CUT JOINT LENGTH 29.87' LEAVING 6.71' CUT JOINT ON TOP. PREP CASING TOP FOR SLIPLOCK WELLHEAD. 01:30 - 05:00 3.50 WHSUR P TIE61 PJSM. INSTALL CIW SLIPLOCK WELLHEAD PER CAMERON REP. DS2 PAD-OP VISUALY CONFIRMED ORIENTATION OF WELLHEAD AND ANNULUS VALVES. TEST SLIPLOCK CASING SEALS TO 3,800 PSI FOR 30 MIN. Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLQRATION Page 13 of ~ 9 Operations Summary R~port Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hc~urs Task Code NPT Phase Description of Operations 9/28/2009 01:30 - 05:00 3.50 WHSUR P TIE61 COMPRESS REVERSE SLIPS ON BOTTOM OF SLIPLOCK. CAMERON REP VISUALLY CONFIRMED NO VR PLUGS IN ANNULUS VALVES. 05:00 - 06:00 1.00 WHSUR P TIE61 SET TEST PLUG IN WELLHEAD. N/U DOUBLE ANNULUS VALVE TO IA. N/U DSA TO WELLHEAD. 06:00 - 15:30 9.50 BOPSU P TIEB1 NU SPACER SPOOLS ON TOP OF THE WELLHEAD. CUT OFF THE STABILIZER PLATES ON THE 30" X 20" TO ENSURE THE BOPE AND RISER WILL BE VERTICALLY ,/ FUNCTIONAL AS WELL AS LEAVING THE WELLHEAD IN i yN~~ THE MOST VERTICAL POSITION POSSIBLE. PLACE THE ~ STACK ONTO THE SPACER SPOOLS AND NU FLOW RISER. NU CHOKE AND KILL LINES. INSTALL NEW , STABILIZER PLATES ON THE 30" X 20" WITH THE RIG ~ WELDER TO KEEP THE WELLHEAD ASSEMBLY FROM MOVING WITHIN THE 30" CONDUCTOR. 15:30 - 20:30 5.00 BOPSU P TIE61 P.ERFORM W EEKLY BOPE TEST TO 250 PSI LOW AND 3,500 PSI PER BP / AOGCC REGULATIONS. EACH TEST HELD FOR 5 CHARTED MINS. THE RAMS WERE TESTED WITH 4" AND 4-1/2" TEST JOINTS. THE ANNULAR WAS TESTED WITH 4" TEST JOINT. THE TEST WAS WITNESSED BY WELL SITE LEADER AND TOOLPUSHER. THE STATE'S RIGHT TO WITNESS THE TEST WAS WAIVED BY BOB NOBLE ON 9/28/2009 AT 0630 HRS. UD TEST JOINTS AND BLOW DOWN LINES. 20:30 - 22:00 1.50 BOPSU P TIEB1 PULL TEST PLUG AND SET WEAR RING, 9.125" ID. CLEAN AND CLEAR RIG FLOOR. 22:00 - 23:00 1.00 REMCM P TIEB1 PJSM. M/U BHA #8: ROCK BIT, (4) BOOT BASKETS, LBS, P.O.S &(6) DRILL CO~LARS WITH 217.15' OAL. PURPOSE OF THIS BHA IS TO DRILL CEMENT AND 23:00 - 23:30 0.50 REMCM P TIEB1 RIH WITH DRILL ASSEMBLY TO TOP OF CEMENT AT 1,728'. P/U AND ESTABLISH PARAMETERS. PUW, SOW AND RT WT = 90K. 70 RPM / 1 K TORQUE, 6 BPM / 180 PSI. 23:30 - 00:00 0.50 REMCM P TIEB1 DRILLTHRU CEMENT FROM 1,728' TO 1,756' WITH 1K WOB AND 70 RPM / 1 K TORQUE. CIRCULATE AT 6 BPM / 250 PSI. 9/29/2009 00:00 - 04:30 4.50 REMCM P TIE61 TAG PLUG RETAINER AT 1,756' AND DRILL THRU PLUG WITH 70 RPM / 1-2K TORQUE & 3K WOB TO 1,758'. CIRCULATE AT 6 BPM / 210 PSI. GOT BACK SMALL CEMENT PIECES, RUBBER AND ALUMINUM SHAVINGS. CONTINUE TO DRILL THRU CEMENT FROM 1,758' TO 1,833'. ROTATE PIPE DURING CIRCULATION, PUMP 20 BBL HI-VIS SWEEP AT 12.5 BPM / 830 PSI, RECOVERED CEMENT, RUBBER AND ALUMINUM SHAVINGS. CONTINUE TO SLIDE IN HOIE TO TOS AT 1,848'. DRY DRILL ON TOP OF SAND FOR 10 MIN DOWN TO 1,854'. P/U TO CIRCULATE 20 BBL HI-VIS SWEEP FROM 1,848' AT 12 BPM / 750 PSi, ROTATE PIPE DURING CIRCULATION. RECOVER SAND, CEMENT, RUBBER. 04:30 - 06:00 1.50 REMCM P TIEB1 POH WITH BHA #8 TO DRILL COLLARS. 06:00 - 06:30 0.50 REMCM P TIEB1 ON SURFACE WITH BHA #8. EMPTY OUT JUNK BASKETS AND RECOVERED 2 EA BRASS PLUGS, ALUMINUM CHUNKS AND VARIOUS PIECES OF CEMENT AND Printed: 10/28/2009 3:52:48 PM ~ • BP' EXPLQRAT~ON ` Page 14 of 19! t~-perations Summary R~port Legal Weli Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Gode NPT Phase Description of Operations 9/29/2009 06:00 - 06:30 0.50 REMCM P TIEB1 RUBBER. 06:30 - 07:30 1.00 CLEAN P CLEAN PUMU BHA #9 AS FOLLOWS: RCJB, 4 EA JUNK BASKETS, 9-5/8" SCRAPER, BIT SUB, BUMPER SUB, XO, 6 EA DRILL COLLARS, XO, XO. OAL = 227.61'. THE PURPOSE OF THIS BHA IS TO CLEAN OUT THE WELL OF ALL TNE JUNK 07:30 - 08:30 1.00 CLEAN P CLEAN RIH WITH BHA #9 ON 4" DRILL PIPE FROM THE DERRICK. 08:30 - 09:00 0.50 CLEAN P CLEAN TAG TOP OF THE JUNK AT 1,851'. DRY DRILL 2' TO 1,853' WITH 30 RPM , 2-3K WOB , 1,000 FT-LB OF TORQUE. JET DOWN AT 10 BPM / 1,600 PSI WITH SAME ROTATIONAL PARAMETERS TO 1,858'. POOH 10' TO 1,848' TO CIRCULATE BOTTOMS UP AT 10 BPM / 1,600 PSI WITH SAND AND ALUMINUM RETURNS OBSERVED ON SURFACE. 09:00 - 10:00 1.00 CLEAN P CLEAN POOH WITH BHA #9 STANDING BACK DRILL PIPE IN THE DERRICK. 10:00 - 10:30 0.50 CLEAN P CLEAN ON SURFACE WITH BHA #9. BREAK OUT AND LAY DOWN SCRAPER. INSPECT JUNK BASKETS AND RECOVERED 2 EA BRASS PLUGS, 9 CHUNCKS OF ALUMINUM AND SAND. RE-MAKE UP SAME BHA WITHOUT THE SCRAPER AS BHA #10 TO CONTINUE CLEANING OUT ON TOP OF THE RBP. 10:30 - 12:00 1.50 CLEAN P CLEAN RfH WITH 8HA #10 ON 4" DRILL PIPE FROM THE DERRICK TO TOS AT 1,859'. JET DOWN TO 1,869' AT 10 BPM / 1,600 PSI, ROTATE 30 RPM / 1 K TORQUE. PUW/SOW/RT WT = 90K. CBU AT MAX RATE, SAND IN RETURNS. 12:00 - 14:30 2.50 CLEAN P CLEAN POH WITH RCJB. CLEAN OUT BOOT BASKETS, MINIMAL RECOVERY OF JUNK. DE-MOBILIZE BHA AND CLEAR RIG FLOOR. 14:30 - 15:00 0.50 CLEAN P CLEAN SHUT BLINDS AND TEST CASING TO 3,500 PSI FOR 30 MIN - CHARTED. TEST LOST 60 PSI FIRST 15 MIN, AND 20 PS! SECOND 15 MIN - PASSED. 15:00 - 17:30 2.50 CLEAN P CLEAN RIH WITH RBP PULLING TOOL TO 1,860. PUW = 75K, SOW = 80K. WASH DOWN AND LA 1,898'. CBU AT 10 BPM / 550 PSI. PULL 10K OVER AND RELEASE RBP, FLOW CHECK - STATIC. VERIFY RELEASE BY PULLING UP HOLE WITHOUT DRAG. 17:30 - 18:30 1.00 CLEAN P CLEAN RIH OUT OF DERRICK TO 3,720'. DROP 225" RABBIT WITH 100' SLICKLINE TAIL. 18:30 - 20:30 2.00 CLEAN P CLEAN POH AND UD RETRIEVING TOOL AND RBP. RABBIT RECOVERED ON TOP OF RETRIEVING TOOL. 20:30 - 22:00 1.501 CASE I P RUNPRD I RU TO RUN 4.5" SHOE TRACK AND 7" CASING. SET 172 22:00 - 00:00 2.001 CASE I P 9/30/2009 I 00:00 - 10:00 I 10.00 I CASE I P CENTRILIZERS ON FLOOR. RUNPRD PJSM. M/U OVERSHOT WITH V-PACKING (14.3' SWALLOW). OVERSHOT HAS TWO SETS OF SHEAR SCREWS, BOTTOM SET HAS 4 SCREWS AND TOP SET HAS 1 SCREW REMOVED FOR WEEPHOLE. BAKERLOCK ALL CONNECTIONS FROM LANDING COLLAR DOWN. M/U BTC CONNECTIONS TO MARK. RUN 7", 26#, BTC-M CASING USING BEST-O-LIFE ON ALL CONNECTIONS. M/U CONNECTIONS TO MARK, AVERAGE TORQUE = 8,800 FT-LBS. RUNPRD CONTINUE TO RUN 7", 26#, BTC-M CASING USING Printed: 10/28/2009 3:52:48 PM ~ ~ BP EXPLORATION Page 15 of 19' Operations Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ~ Hours Task ~ Code NPT 9/30/2009 I00:00 - 10:00 I 10.00 I CASE ~ P 10:00 - 12:00 I 2.00 I CASE I P 12:00 - 14:00 I 2.00 I CASE I P 14:00 - 14:30 I 0.50I CASE I P 14:30 - 16:00 I 1.501 CASE I P 16:00 - 18:00 I 2.00 I CEMT I P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations RUNPRD BEST-O-LIFE ON ALL CONNECTIONS. MU CONNECTIONS TO MARK, AVERAGE TORQUE = 8,800 FT-LBS. FILL CASING EVERY 5 JOINTS. RAN A TOTAL 171 JOINTS OF CASING AND 172 CENTRILIZERS. ONE CENTRALIZER GOING ON INSERT LANDING COLLAR JOINT. RUNPRD P/U LINER TOP PACKER ASSEMBLY AND M/U TO LINER. ESTABLISH LINER PARAMETERS, PUW = 200K, SOW = 180K. CIRCULATE LINER VOLUME OF 253 BBLS AT 5 BPM / 200 PSI. RUNPRD M/U (6) DRILL COLLARS TO LINER. RIH FROM 6,800' TO 10,070' FILLING EVERY 10 STANDS. PUW = 250K, SOW = 190K, BREAK CIRCULATION STAGING UP TO 6 BPM / 560 PSI. RUNPRD WORK DOWN TO SWALLOW STUB AT 10,134', 1ST SET OF SHEAR SCREWS VERIFIED, UNABLE TO SEE SECOND SET. STACK OUT AT 10,148', VERIFY OVERSHOT SWALLOW AT 14'. MARK FOR SPACE-OUT AT 4' OFF STUB. RUNPRD UD SINGLE. P/U CEMENT HEAD AND R/U LINES. ANCHOR SWIVEL WITH SUPER TUGGER AND RABBIT PUP FOR DRILL PIPE WIPER PLUG. M/U TO STRING AND M/U TOP DRIVE. EASE DOWN TO BOTTOM OF OVERSHOT AND SPACE OUT 4' OFF STUB. SHOE AT 10144'. BREAK CIRCULATION AND STAGE PUMPS TO CEMENTING RATE AT 6 BPM / 660 PSI. RUNPRD PJSM WITH RIG CREW AND CEMENTERS. ESTABLISH TASK LEADERS AND MAKE ENVIRONMENTAL CHECKS. 16:10 PUMP 5 BBLS WATER. 16:20 PRESSURE TEST LINES TO 4500 PSI - OK. 16:29 START CEMENT. 16:34 25 BBLS AWAY AT 6.2 BPM WITH 430 PSI. 16:46 100 BBLS AWAY AT 6.2 BPM WITH 362 PSI. 16:59 175 BBLS AWAY AT 6.2 BPM WITH 352 PSf. 17:03 SHUT DOWN WITH 196.5 BBLS PUMPED. SWITCH OVER TO 9.8 PPG BRINE, DROP WIPER DART AND KICK OUT. VERIFIED DART AWAY. DISPLACE AT 6 BPM. 17:16 WITH 38 BBLS AWAY NO VISABLE LATCH UP. 17:27 100 BBLS AWAY AT 6.0 BPM WITH 252 PSI. 17:44 200 BBLS AWAY AT 5.9 BPM W ITH 1290 PSI. 17:53 250 BBLS AWAY AT 5.5 BPM WITH 2O51 PSi. SLOW TO 3 BPM WITH 2O30 PSI. BUMP PLUG WITH 291 BBLS AWAY. CIP AT 18:05. Sacks 944. Yield 1.16. No losses. Printed: 70/28/2009 3:52:48 PM ~ • BP EXPLQRaT{ON Page 16 af 19 Operations Sumrnary R~port Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 ; Date From - To Hours Task Code NPT Phase Description of Operations 9/30/2009 18:00 - 19:00 1.00 CEMT P RUNPRD WITH SCHLUMBERGER, PRESSURE UP TO 3,100 PSI, SET HANGER. S/O LINER WEIGHT+20K ADDITIONAL. BLEED PRESSURE TO CHECK FLOATS - NO FLOW. PRESSURE UP TO 4,500 PSI AND SET PACKER. BLEED PRESSURE AND REMOVE HOSES. SWAP OVER TO RIG PUMPS. ROTATE 15 TURNS TO THE RIGHT AND PRESSURE UP TO 1,000 PSI, UNSTING TO OBSERVE PRESSURE DROP. CIRCULATE AT 5 BPM / 300 PSI FOR 20 BBLS, SLOW DOWN PUMP RATE TO 1.5 BPM AND S/O AND SET 55K DOWN ON LINER TOP, SHEARED DOG SUB WITH GOOD SURFACE INDICATION OF PACKER SET. 19:00 - 20:30 1.50 CEMT P RUNPRD P/U 13' AND CONTINUE CIRCULATING AT 11.5 BPM / 1,050 PSl. RECIPROCATE PIPE DURING CIRCULATION. CIRCULATED 20 BBLS EXCESS CEMENT BACK TO SURFACE. PUMP HI-VIS NUT PLUG SWEEP TO CLEAR DP AT 11.5 BPM / 1,050 PSI. 20:30 - 23:30 3.00 CEMT P RUNPRD POH STANDING BACK 4" DP. L/D (6) DRILL COLLARS. UD BAKER PUSHER TOOL. DOG SUB INDICATES GOOD SET. 23:30 - 00:00 0.50 CEMT P RUNPRD CLEAN AND CLEAR RIG FLOOR. PREP FLOOR TO P/U BHA #11. 10/1/2009 00:00 - 01:00 1.00 CLEAN P CLEAN PRE-TOUR CHECKS. MOBILIZE 6-1/8" DRILL BIT ASSEMBLY, BHA #11 FOR DRILLING OUT CEMENT FROM LANDING COLLAR TO 7" X 4-1/2" XO. OAL = 218.47'. 01:00 - 02:30 1.50 CLEAN P CLEAN M/U BHA #11 AND RIH TO 218'. RIH ON 4" DP TO 690'. 02:30 - 04:00 1.50 CLEAN P CLEAN PJSM. CUT AND SLIP DRILLING LINE. INSPECT TOP DRIVE. 04:00 - 07:30 3.50 CLEAN P CLEAN CONTINUE TO RIH WITH BHA #11 FROM 690'. EASE THRU LINER TOP AT 3,407' WITHOUT OBSTRUCTION. CONTINUE TO RIH WITH 4" DP OUT OF DERRICK. 07:30 - 11:30 4.00 CLEAN P CLEAN TAG CEMENT AT 9,987'. PUW = 182K, SOW = 145K, RT WT ~=~~60K, 80 RPM / 4-5K TORQUE. DRIIL CEMENT WITH 10K WOB, 80 RPM / 4-5K TORQUE, 7 BPM / 1,410 PSI TO LANDING COLLAR AT 10,017. DRILLED UP PLUG AND FLOAT EQUIPMENT AND WORKED DOWN TO 10,086' AND STOPPED ON 7" X 4.5" XO. WORK PIPE TO CONFIRM DEPTH. 11:30 - 13:00 1.50 CLEAN P CLEAN PUMP HI-VIS SWEEP, ROTATED 30 RPM AND RECIPROCATE PIPE WITH 10 BPM / 2,630 PSI. OVERBOARD SWEEP. SMALL PIECES OF RUBBER AND CEMENT CUTTINGS AT SURFACE. SHUT DOWN. BLOW DOWN TOP DRIVE. 13:00 - 14:30 1.50 CLEAN P CLEAN SHUT ANNULAR AND TEST 7" & 9-5/8" CASING TO 3,500 PSI FOR 30 MIN - CHARTED. LOS7 70 PSI FIRST 15 MIN AND 30 PSI SECOND 15 MIN - PASSED. R/D TEST EQUIPMENT. 14:30 - 16:30 2.00 CLEAN P CLEAN PUMP 25 BBLS SPACER AND DISPLACE WITH 620 86LS OF 120 DEG 1% KCL AT 11.5 BPM / 3,050 PSI. MONITOR WELL FOR 30 MIN. 16:30 - 20:00 3.50 CLEAN P CLEAN PJSM. POH STANDING BACK IN DERRICK. 20:00 - 21:00 1.00 CLEAN P CLEAN UD BHA #11 AND CLEAN OUT JUNK AND CEMENT FROM ALL BOOT BASKETS, MINIMAL RECOVERY. 21:00 - 22:30 1.50 CLEAN P CLEAN P/U BHA #12 DRILL OUT ASSEMBLY FOR DRIILING OUT 4.5" TYPE II LANDING COLLAR WITH SOLID ALUMINUM Printed: 10/28/2009 3:52:48 PM ~ ~ ' BP EXPLORATION Page 17 afi 19' ' Qperatians Summary Report Legal Well Name: 02-06 Common Well Name: 02-06 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date' From - To Hc~urs Task Code NPT 10/1/2009 21:00 - 22:30 1.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 10/2/2009 00:00 - 04:30 4.50 CLEAN P 04:30 - 08:00 3.50 CLEAN P 08:00 - 10:00 2.00 CLEAN P 10:00 - 17:00 7.00 CLEAN N SFAL 17:00 - 00:00 7.00 CLEAN P 10/3/2009 00:00 - 01:30 1.50 CLEAN P 01:30 - 03:30 2.00 CLEAN P 03:30 - 04:30 1.00 WHSUR P 04:30 - 08:30 4.00 RUNCO 08:30 - 22:30 14.00 RUNCO P 22:30 - 23:00 0.50 RUNCO 23:00 - 00:00 1.00 RUNCO 10/4/2009 00:00 - 01:30 1.50 RUNCO 01:30 - 03:00 1.50 RUNCO P Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of Operations CLEAN SEAT. OAL = 312.08' CLEAN RIH OUT OF DERRICK. EASE THRU LINER TOP AT 3,407', DID NOT SEE ANY OBSTRUCTION. CLEAN CONTINUE TO RIH OUT OF DERRICK. CLEAN ESTABLISH PARAMETERS. PUW = 202K, SOW = 147K, RT WT = 165K WITH 60 RPM / 4-5K TORQUE. SLOW PUMP RATE 2.7 BPM / 270 PSI. DRILL CEMENT FROM 10,080' TO 10,101' WITH 1-2K WOM, 70 RPM / 5K TORQUE. TIGHT OBSTRUCTION SLOWING ROTATION AT 10,101', WORK THRU TO TOP OF TYPE II LANDING COLLAR AT 10,101'. MILL WITH 2-3K WOM WITH 100 RPM / 8K TORQUE, CIRCULATE AT 3.5 BPM / 650 PSI. ROTATE AND RECIPROCATE THRU TYPE II COLLAR DEPTH AT 10,101'. WASH TO 10,136', WENT INTO 5.5" STUMP AT 10,134' AND WORKED THRU STUMP TO CONFIRM OPEN. CLEAN PUMP HI-VIS SWEEP TO INSIDE 7" LINER. SHUT DOWN DROP BALL AND OPEN PUMP OUT SUB (SHEARED AT 2,100 PSI). PULL OFF BOTTOM AS SWEEP EXITED MILL, HANG UP OFF BOTTOM AND WORK THRU OBSTRUCTION. CONTINUE TO CIRCULATE SWEEP AT MAX RATE AND OVERBOARD SWEEP WITH MINIMAL RECOVERY AT SURFACE. CLEAN FLOW CHECK WELL - STATlC. IRON ROUGHNECK JAWS WOULD NOT CLOSE. TROUBLE SHOOT WITH ELECTRICIAN AND MECHANIC. ~CLEAN POH L/D DRILLPIPE FROM 10,060'. I CLEAN CREW CHANGE, PRE-TOUR CHECKS. CONITNUE TO UD 4" DRILLPIPE. CLEAN UD BHA #12. EMPTY (4) BOOT BASKETS WITH MINIMAL CEMENT AND ALUMINUM SHAVINGS IN EACH BASKET. MILL BODY HEAVILY SCARRED, MILL FACE IN GOOD CONDITION, MILL IN GAUGE. RECOVERED 1 PIECE 2" X 2" OF CONTROL LINE BANDING FROM PREVIOUS 5.5" ~ DE-COMPLETION. CLEAN CLEAR RIG FLOOR OF BAKER HANDLING TOOLS. PULL WEAR BUSHING. RUNCMP LOAD PIPE SHED WITH 252 JOINTS OF 4.5" VAMTOP COMPLETION. MOBILIZE TORQUE TURN EQUIPMENT, SINGLE JOINT ELEVATORS AND COMPENSATOR. RUNCMP M/U 4.5" JEWLERY WITH WSL WITNESS. BAKERLOCK ALL CONNECTIONS BELOW PACKER. RUN 4.5", 12.6#, ~ 13CR80, VAMTOP COMPLETION PER RUNNING ORDER USING JET LUBE SEAL GUARD ON CONNECTIONS WITH M/U TORQUE TO 4,440 FT-LBS. RAN A TOTAL OF 230 JOINTS. PUW = 160K, SOW = 125K. RUNCMP P/U ADDITIONAL 3 JOINTS. RIH AND TAG 7" X 4.5" XO AT 10,086'. UD EXTRA JOINTS TO TAG. RUNCMP M/U TUBING HANGER. C/O ELEVATORS AND P/U LANDING JOINT. M/U TO STRING. RUNCMP FINAL PARAMETERS: PUW = 160K, SOW = 125K. LAND TUBING HANGER AND RILDS WITH CAMERON REP. RUNCMP RU/ TO REVERSE CIRCULATE WITH HEATED 1% KCL FOLLOWED BY CORROSION INHIBITOR. FINISH TAKING Printed: 10/28/2009 3:52:48 PM i ~ BP EXPL4RATION Page 18 of 19 Qperations Summary Report Legal Well Name: 02-06 ICommon Weil Name: 02-06 I Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON i 4 Date From - To ~ Hours Task , Code NPT 10/4/2009 01:30 - 03:00 1.50 03:00 - 06:00 3.00 06:00 - 08:00 I 2.00 08:00 - 09:30 I 1.50 09:30 - 11:30 I 2.001 BOPSUR P 11:30 - 16:30 I 5.001 BOPSUR P 16:30 - 20:00 I 3.501 WHSUR I P 20:00 - 21:00 I 1.00 I WHSUR I P 21:00 - 00:00 I 3.00 ~ 10/5/2009 00:00 - 00:30 0.50 RUNCOi~'IP I, 00:30 - 02:30 2.00 WHSUR ~ P 02:30 - 04:00 I 1.50 ~ WHSUR I P 04:00 - 05:00 I 1.00 05:00 - 07:00 I 2.00 I R Spud Date: 12/24/1970 Start: 9/10/2009 End: 10/5/2009 Rig Release: 10/5/2009 Rig Number: 14 Phase Description of OperatiQns RUNCMP ON FLUID TO PITS. RUNCMP PJSM. REVERSE CIRCULATE IN FOLLOWING ORDER AT 3 BPM / 270 PSI: -153 BBLS OF HEATED 1% KCL, 120 BBLS OF HEATED 1% KCL WITH CORROSION INHIBITOR AND 197 BBLS OF HEATED 1% KCL. RUNCMP DROP BALL AND ROD. PRESSURE UP TUBING TO 4,000 PSI TO SE PACKER AND HOLD FOR 30 MIN (LOST 90 PSI FIRST 15 MIN, 40 PSI SECOND 15 MIN - PASSED). BLEED TUBING TO 1,500 PSI, R/U ON IA. PRESSURE IA TO 3,500 PSI FOR 30 MIN (LOST 150 PSI FIRST 15 MIN, 50 PSI SECOND 15 MIN - PASSED). BLEED TUBING TO 0 PSI, DKC -SV SHEARED AT 2,700 PSI. PUMP DOWN IA AT 2 BPM / 600 PSI AND DOWN TUBING AT 2 BPM / 400 PSI. RUNCMP UD LANDING JOINT AND TEST EQUIPMENT. CLEAR RIG FLOOR OF 4.5" TORQUE TURN EQUIPMENT. RUNCMP DRY ROD TWC WITH CAMERON REP. TEST TWC FROM ABOVE TO 3,500 PSI FOR 10 MIN - PASSED. TEST FROM BELOW TO 1,000 PSI FOR 10 MIN - PASSED. R/D TEST EQUIPMENT. RUNCMP PJSM. DRAIN STACK. N/D FLOW LINE, RISER, BOPE AND SPACER SPOOLS. BARRIERS ARE TESTED TWC AND 3 1/2" FASDRILL. RUNCMP N/U ADAPTER FLANGE AND TREE. CAMERON TEST ADAPTER FLANGE TO 5,000 PSI FOR 30 MIN - PASSED. TEST TREE WITH DIESEL TO 5,000 PSI FOR 5 MIN - PASSE0. RUNCMP R/U DSM LUBRICATOR AND TEST TO 500 PSI. PULL TWC. UD LUBRICATOR. RUNCMP SPOT AND R/U HOT OIL TRUCK. PJSM WITH CREWS. PRESSURE TEST LINES TO 3,500 PSI. PUMP 150 BBLS OF DIESEL FREEZE PROTECT AT 2 BPM / 1,100 PSI DOWN IA. SHUT DOWN PUMPS OPEN AND ALLOW WELL TO U-TUBE. RUNCMP CONTINUE TO ALLOW WELL TO U-TUBE DIESEL. RUNCMP R/U DSM LUBRICATOR TO TREE AND TEST WITH DIESEL TO 500 PSI. SET BPV. L/D LUBRICATOR. TEST FROM BELOW WITH HOT OIL TO 1,000 PSI FOR 10 MIN - PASSED. R/D LITTLE RED. RUNCMP REMOVE DOUBLE ANNULUS VALVES AND SECURE WELLHEAD. SPOT SLB CEMENTERS AND VAC TRUCKS FOR TOP JOB. STRING HOSES TO CELLAR. INTERV PJSM WITH RIG CREW, TRUCK DRIVERS AND CEMENTERS. P/T LOW PRESSURE HOSE WITH C-PUMP TO 120 PSI. LOWER HOSE IN 13 3/8" X 20" ANNULUS. INTERV PUMP CLASS G, 15.8 PPG CEMENT INTO 20" X 30" ANNULUS AND FILL WITHIN 2' OF SURFACE AT 1 BPM WITH 800 PSI. SHUT DOWN AND SWITCH TO 13 3/8" X 20" ANNULUS AND PUMP AT 1 BPM WITH 100 PSI. DISPLACING WATER AND CRUDE. FILL 3 ANNULUS WITH CEMENT AND CAP OFF W ITH 5 GALLON BUCKETS OF C~MENT. Printed: 10/28/2009 3:52:48 PM • • BP EXPLORATfC7N Page 19 c~f 19 Operations Summary R~port Legal Well Name: 02-06 Common Well Name: 02-06 Spud Date: 12/24/1970 Event Name: WORKOVER Start: 9/10/2009 End: 10/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/5/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Haurs Task Code NPT Phase Descriptian of Operations 10/5/2009 05:00 - 07:00 2.00 REMCM P INTERV Pump 13 bbls into 20" x 30" annulus. Pump 85 bbls into 13 3/8" x 20" annulus. Place 1 bbl into 9 5/8" x 13 3/8" annulus. Pump 99 bbls. Yield 1.16 ft3/sk. Sacks 480. SECURE CELLAR AND R/D TRUCKS. RELEASE RIG AT 0700 HRS ON 10-5-09. rnntea: iw~tvzuus ~:oe:aa rnn TREE= ~ 4-1/16" CNV WELLH~AD = CNV Slip Lock ACTUATOR = BAKER KB. ELEV _ 64 BF. ELEV _ KOP = _ 11018' Max Angle = 94° @ 12134' Datum MD = 11156' Datum N D= 8800' SS ~ ~V DRAFT I 20" CSG, 94#, H-40 & 133#, K-55, ID = 18.78" ~~ 1216, 13-3/8" CSG, 72#, N-80, ID = 12.347~ 2711 ~ 9 5/8" x 7" ZXP Packer 3407~ Minimum ID = 2.440" @ 12267' 3-3/16" X 2-7/8" XO I I4 1/2" 12.6#, 13Cr-8Q tbg. ID=3.958" ~ 10040~ ~ 7" LNR, 26#, L-80, BTGM, ID = 6.276" 10086~ TOP OF 5-1/2" TBG STUB (09/22/09) 10134~ I EST. LNR TOC (??/??/??) ~ 10155~ 3-1/2" HES FASDRILL (08/16/09) 10176~ @ 11388' J$72~ ~ --~4-1/2" X NIP, ID = 3.813" ~ 9903~ 7" x 4 1/2" BKR S-3 PKR, ID = 3.875" 9937~ X Nipple / RHGM Plug ID = 3.813" 10008~ 4-1/2" XN NIP, ID = 3.725" 10040~ 4 1/2" WLEG 10086~ 7" x 4 1/2" XO, ID = 3.958" 10127~ 4-1 /2" x 5-1 /2" XO, ID = 3.958" 10144~ 9 5/8" x 5 1/2" UNIQUE OVERSHOTw/SEALS 10151' 5-1/2" BKR FA PERM PKR, ID = 3.625" 10155~ BKR C2 TIEBACK SLV, ID = 4.0" 10153~ 3.781" SKR DFpLOYMEM SLV, ID = 3.0" 10182~ 3-1/2" HES X NIP, ID = 2.813" ~~ 10233~ 5-1/2" BKR SLIDING SLV, ID = 4.223" 10290' 5-1/2" BKR SBR ASSY, ID = 3.90" Cmt'd- 10346~ 9-5/8" X 5-1/2" BKR SAB PKR Behind 5-1/2" TBG,17#, L-80, .0232 bpf, ID = 4.892" 10358~ CT LNR 10358' S-1 /2" X 4-1 /2" XO, ID = 3.958" 4-1/2" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" 10480' 10419~ 4-1/2" BKR R NIP, MILLm ID = 3.80" 10436~ ELMD Tf LOGGED 11/07/86 10908~ 3-1/2" HES XN NIP, ID = 2.75" 1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" I-i 10941' PERFORATION SUMMARY REF LOG: MCNL/CCL/GR ON 06/03/04 A NGLE AT TOP PERF: 78 @ 12264' Note: Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12264 - 12294 C 01 /06/05 2" 6 12650 - 13000 C 06/04/04 9-5/8" CSG, 40#, N-80, !D = 8.681" 11350' ~~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" ' ~-~ 3-1/2" X 3-3/16" XO, ID = 2.80" CEMENT RAMP WINDOW (02-066) 11010' - 11026' 12r 267~ 3-3/16" X 2-7/8" XO, ID = 2.440" PeT~ 13046' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 13081' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/27/96 CTD SIDETRACK (02-O6A) O6/04/04 JDM/KA CTDSIDETRACK(02-06B) 10/06/09 D14 RWO 10/06/09 SV DRLG HO CORRECTIONS 10/12/09 JLJ/PJC GLV C/O PRUDHOE BAY UNff WELL: 02-06B PERMff No: ~2040850 API No: 50-029-20086-02 SEC 35, T11 N, R14E, 4139.49' FEL & 3113.14' FNL BP 6cploration (Alaska) rr~ *** 4-1 /2" CHROME TBG *** >70° 9-5/8" HES CEMENTER ~ ISO-ZONE IXTERNAL CSG PKR, ID = 8.71" 9 5/8" CSG PATCH, 47# L-80, ID = 8.681" 4-1/2" X NIP,ID = 3.813" GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATCH I~RT DATE 4 3649 3625 21 KBG-2 DO1utE BK N/A 10/12/09 3 6536 5793 52 KBG-2 SO SBK-2 N/A YO/12/09 2 8669 7211 45 KBG-2 DMY SBK-2 WA 10/04/09 1 9794 7970 50 KBG-2 DMY SBK-2 WA 10/04/09 10/00/09 Schb' 11er NO. 5410 Alaska Data Consulting Services Company: State of Alaska 2525 Gumboil Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE Pig r 01/25/07 1 L4.03 AY1M -00032 PRODUCTION PROFILE ry f 09/09/09 1 L5-05 AP30 -00061 PRODUCTION PROFILE o_ at q 09/15/09 1 03 -24A AZCM -00042 LDL (L} i .11/.,G 09/14/09 1 07 -329 BOCV -00027 JEWELRY LOG/GR W/PRESS/TEMP .9 /llyjr:111a 0 W -214 AYS4 -00095 INJECTION PROFILE _.Z"tjnzyl 09/12/09 0 07 -21 T -00018 PRODUCTION PROFILE 09/25/09 1 AYS4-00098 07 -21 AYS4 -00088 PRODUCTION PROFILE 0 09/17/09 1 W -04 B8K5 -00003 PRODUCTION PROFILE I 1 09/24/09 1 P2 -53 AP30-00060 PRODUCTION PROFILE ,,fly. r, 09/13/09 1 MIIEIIIM AWL8 -00037 PRODUCTION PROFILE ^ic t. 09/25/09 0 AWLB -00035 INJECTION PROFILE nirjr,11 f;11j,,S 09/19/09 0_ AYTO -00029 QMMWL"PSZF'.�Lt?cleallEMMOI 09/19/09 11111131111111111MEMOMMIMMINII Millilla AWJI -00050 I „l F.aI nfi i►5CJ1farivi: 09/20/09 0MMIIMIMIIIIIIIIIIMIIIIIMMIIIIIIIIIIII W -30 AYIM -00034 PLUGBACK W/X -FLOW CHECK 09/12/09 0 3- 37/L -35 83S0 -00024 PRODUCTION PROFILE LJ im. 09/16/09 0 J NK-09 AP30 -00057 USIT /11 t 09/07/09 1 W -07A AWJI -00047 MEM CEMENT EVALUATION e„r� 09/07/09 1 11 -10 AYTU -00054 �r i2'�. 08/28/09 1 02 -068 ANHY -00111 11,,„, et 4kWillriF ''S_ k 09/21/09 1 G -18A AWJI -00048 MEM CEMENT BOND LOG --t) r •r 4/ 05(17I05 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 \\2 200 c9d ~ • @ °.mA ~ 3 ~`, ~q~x ~~ ~,..s-a _~ ap~,_:. ~~ ~ .....~~ ~a~ i-'; ~_ ".. j' ~~~~y~ ~~~ ~; ~~ ~g~ ~~ ~~~ ~ ~p~ ~~ ~ ~~,~~ ~ ~ ~ g ~ ~ ~~ SEAN PARNELL, GOVERNOR ~sY ~-7S~ QI~j ~sa~ t7rv-.7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'1`IO1~T CODII~iISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 ~ ~ Anchorage, Alaska 99519-6612 ~ D f,, ~- ~ .K Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-06B Sundry Number: 309-257 4:. ^~}eS4~,F.1~~. r`t1'a.~ {~5 ~n ` ~ V V~:I Dear Mr. Reem: ~ ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleuxn field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair i"°~ DATED this~ day of August, 2009 Encl. STATE OF ALASKA ~'~~~ ALA~ OIL AND GAS CONSERVATION COMP~ION APPLICATION FOR SUNDRY APPROVAL ,r,~,_ 2o aac 2s.2so ~. -^~~ ~~~.~~~~~~=.~~~ :~~~1. `~ s~ 1(;~~~ 1. Type of Request: ^ Abandon ~d ~~~k ^ Suspend ^ Operation Shutdown ^ Perforate 1~~~,l~ ~~i~j~g~ ,,, r ~ X "l'9~1K4~ "T3T~~1..7-"" ~.;; {,.,.a~~.~Y6~~at~4P e~F~ ~ ~ Alter Casing , w ~ Repair Well .^ Plug Perforations ^ Stimulate ^ Re-Enter Syty~~~~Ef/ell ^ Change Approved Program ~ Pull Tubing ,^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 204-085 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20086-02-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 02-066 - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028308 ~ 64' ~ Prudhoe Bay Field / Pfudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): . Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13081 ~ 9073 ~ 13046- 9069 - 10908' None a in en th ize M TVD B rst II e Structural 114' 0" 11 ' 114' urf ce 1216' 20" 1216' 1216' 1 30 520 Intermediate 2711' 13-3/8" 2711' 2711' 0 2670 Pr in 1134' -/" 11 875' 70 300 Lin r 5143' 3-1/2" 5008' - 1 151' 4800' - 820 ' Liner 2930' s-v2" x 3-3/16~~ X z-~ia~~ 10151' - 13 81' 8203' - 9073' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12264' - 13000' 9010' - 9062' S-1/2", 17# x 4-1/2", 12.6# L-80 10480' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 10346' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~~Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 1, 2009 ,~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras worthington, 56a-ato2 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature y7~_. Phone 564-5743 Date:~ ~~ Q Teme Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity t~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ ~!_ '~ST z Sd 0 S~ /`l hN.~+.l.s.r TtS '~ m w~ Other: 3 5()(~ ~ SG j ~ Subsequent Form Required: ~~ `~~L( ~~ ~ APPROVED BY ~" ~ A roved B COMMISSIONER THE COMMISSION Date D Form 10-403 R~ised 06/2006 ~~R~~1~JAL ~ ~~~~~~~~~~~4zQ~~ Submit !n Duplicate r~''~~~`~ ~. 7~~.~e~ • • ~ ~ GP 02-06B Expense Rig Workover Scope of Work: Pull 3-'/z" scab liner and 5%2" completion. Run and cement 7" scab liner to --3200' MD. Cut and pull 9-5/8" casing, run new 9 s/e' casing and cement to surface, run 4-'h" 13Cr80 premium thread completion. MASP: 2340 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: August, 2009 Claudia Hernandez Aras Worthington Pre-Riq Work Reauest: W 1 PPPOT-T and PPPOT-IC. S 2 Drift 3'/z" liner to PXN lu C~ 10,908' MD. Pull PXN lu . E 3 Set 3'/2" composite plug ~ 10,177' MD (middle of 10' pup above X-nipple reference liner tally dated 6/1/2004}. MITT to 3500 psi to verify plug is a competent barrier to the Ivishak. E 4 Tubing punch 10' of holes in 3'/z" scab liner. Tbg punch holes to be located in the bottom of the first full joint of liner above the PBR locator (10,125' - 10,135' reference liner tall dated 6/3/2004 . F 5 Circulate the well with 9.8 ppg kill weight brine through the tbg punch holes and the holes in the 5%2" tbg. Freeze protect wellhead with diesel as needed . MITOA to 2500 si. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time . W 7 Set a BPV in the tubin han er. O 8 Remove the well house & flow line. Level and build-u the ad as needed for the ri . Proaosed Procedure 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. ND tree. NU BOPE incfuding 3%z" x 6" VBRs. Pressure test to 3500 psi. 3. Pull and LD 3-'h" scab liner. 4. RU E-line and jet cut the 5~/z" tbg ~10,100' MD. - 5. Pull and LD the 5'/2" L-80 completion down to the cut. 6. Run 9 5/8" casing scraper. 7. Run 7" scab liner w/ PBR seal assy to ~3200' MD. Cement scab liner. Note: Pipe rams will not be changed to 7" as the well has a tested barrier (composite plug) and a full column of monitor-able KWF covering the cretaceous. 8. Drill out 7" shoe tract and then 4~/z" landing collar. 9. Pressure test 7" scab liner to 3500 psi for 30 minutes. 10. Run USIT log to determine top of cement in 9-%8" x 13-3/8" annulus. 11. Set retrievable bridge plug 100' below the top of cement. 12. Cut and pull 9-s/e" casing from above the top of cement. Note: Pipe rams will not be changed to 9- g/a" as the well has two tested barriers (Fasdrill and~iBP) to the reservoir. 13. ND BOPE. t Kw~ ~- ~ • • 14. Make inside cut on 13 3/8" casing and outside cut on 20" conductor. Remove Gen 1 wellhead in entirety. 15. Run and fully cement new 9-s/8' premium threaded casing to surface. 16. Cut off 9 5/8" casing at surface and install Cameron Slip-lock Wellhead. Test casing packoff to 3800 psi. 17. NU BOPE and test to 3500 psi. 18. Drill out shoe-tract. 19. Clean out to retrievable bridge plug and test casing to 3500 psi for 30 minutes. 20. Retrieve RBP. 21. Run 4-'/2" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at ~9900' MD. 22. Displace the IA to packer fluid and set the packer. 23. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 24. Set BPV. ND BOPE. NU and test tree. RDMO. i VElLHEAD= MCEVOY • ,CTUATOR = AXELSON :B. ELEV =~ 64' ~ O~ O~ SAFETY NOTES: ***PROD CSG LEAK. OPER LIMITS: MAX IAP 0 PSI, MAX OAP =1000 PSI, MAX OOAP = B S00 PSI ( 2/06 WAIVER)*** PASSED MIT-T 3500# TO SCAB LNR PATCHED CSG LEAK 5489' 5000ft 5/17/04 ,F. ELEV = ? @ . i, .OP = 11018` & 6059'. PC LEAK LLR 16.8 GPM @ 2000# ° ' I 1ax Angle = 94 @ 12133 ~atum MD = 11188' ~atum ND = 8800' SS ID = 4 1/2" BAKER PFVE SSSV NIP 562" ' 5 I" CSG, 94#, H-40 & 133#, K-55, ID = 18.78" 1216' . , - 2197 13-3/8" CSG, 72#, N-80, ID = 12.347" 2711 ~ " ~ ' 5 1/2" BKR SLPR RETRIEVABLE PKR ID = 3 4" TOP OF 3 1/2 SCAB LINER 5008 , . 5008 10149~ BKR SEAL ASSY, ID = 3.0" " BKR FA Pff / KR !D = 2 98" ' S-1 2 2M P , . 10151 EST. TOP OF LINER CEMENT 10155~ 10155~ BKR C2 TIEBACK SLV, ID = 4.0" 10163~ 3.781" BKR DEPL.OYMENT SLV, ID = 3.0" 10182' 3-1/2" HES X NIP, ID = 2.813" Minimum ID =2.440~~ @ 12267~ ~ ~ 10233' 5-1/2"BKRSLIDINGSLV, ID=4.223" 3-3/16~~ X 2-7~8~~ X~ ID = 4 223" 10290~ 5-1/2" BKR R NIP , . 1/2" BKR SBRASSY ID = 3 90" 10296' 5 - . 10346~ 9-5/8" X 5-1/2" BKR SAB PKR Behind MILLEDID=4.75~~ CT LNR 5-1/2" TBG,17#, L-80, .0232 bpf, ID = 4.892" 10358' " " " ~ X 4-1/2 XO, ID = 3.958 5-1/2 10358 M ILLm ID = 3 80" 10419~ 4-1/2" BKR R NIP , . 0152 b " TBG 12 6# L 80 D = " 1 4 0' D TT LOGGED 6 ~ •-1/2 , . , - , . pf, I 3.958 0 8 ELM 11/07/8 10436 p 10908~ 3-1/2" HES XN NIP, ID = 2.75" 10908' 3-1/2" PXN PLUG (02/06/08) 1/2" LNR 81# L 80 0087 b ID = 2 8 f 990" 10941' , , - , . p - . , . 10941~ 3-1/2" X 3-3/16" XO, ID = 2.80" PERFORATION SUMMARY REF LOG: MCNUCCL/GR ON 06/03/04 ANGLE AT TOP PERF: 78 @ 12264' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12264 - 12294 C 01/06/05 2" 6 12650 - 13000 C 06/04/04 9-5/8" CSG, 40#, N-80, ID = 8.681" ' 2-7/8" LNR, 6.5#, L-80 ,.0058 bpf, ID = 2.441" CEMENT RAMP WINDOW (02-06B) 11010' - 11026' ~ 2267~ ~-~ 3-3/16" X 2-7/8" XO, ID = 2 11350' r''" \ 12307' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 12267' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 13046~ PBTD 13081' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/27/96 CTD SIDETRACK (02-O6A) 03/26/O6 TEL/PJC PULL PXN PLUG @ 10908' WELL: 02-06B O6/04/04 JDM/KA CTD SIDETRACK (02-O6B) 02/06/08 TA/PJC SET PXN PLUG @ 10908' PERMff No: ~2040850 01/06/05 KCF/TLP ADD PERFS API No: 50-029-20086-02 01/11/06 DAV/PJC X NIP CORRECTION @ 10908 SEC 35, T11 N, R14E, 4139.49' FE1 & 3113.14' FNI 01/16/06 KSB/PAG SET PXN 7TP (01/11/06) 03/22/06 RPFi/PJC WANER SFTY NOTE UPDATE BP Exnloration (Alaskal I TR~ = MCEV OY WEILHEAD = MCEVOY ACTUATOR = AX~SON KB. ~EV = 64' BF. ~LEV = ? KOP = 11018' Max Angle = 94° @ 12133' Datum MD = 11188' Datum TVD = 8800' SS 0~06B Proposed ~ to ~ 20" CSG, 94#, 1+40 & 133#, K-55, ID = 18.78" ~--~ 1216' ~ 13-3/8" CSG, 72#, 1~80, ID = 12.347^ 2711' 9 5/8" x T' Z~ Packer ~3200' I 7" Liner,26#, L-80, BTGM, Fully Cemented I 41/2" TBG,12.6#, 13Cr-80, .0152 bpf, ID = 3.958" Minimum ID = 2.440" @ 12267' 3-3/1 6" X 2-7/8" XO EST. TOP OF LINER CBNBYT ~-~ 10155' 5-1/2° TBG,17#, L-80, .0232 bpf, ID = 4.892" ~--i 10358' '~ ~ 4-1/2" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" H 10480' ~3-1/2" LNR $•a1#, L-80, .0087 bpf, ID=2.990" ~ PERFORATION SUNINARY REF LOG: MCNUCCL/GR ON 06/03/04 ANGLE AT TOP PERF: 78 @ 12264' Note: Refer to Production DB for historical perf data SIZE SPF ~(TB2VAL Opn/Sqz DATE 2" 6 12264 - 12294 C 01 /O6/05 2" 6 12650 - 13000 C O6/04l04 ~9-5/8" CSG. 40#, N-80, ID = 8.681" ~--( 11350 2-7/8" LNR, 6.5#, L-80 ,.0058 bpf, ID = 2.441" 1230T (~~AS I IFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 KBG-2 2 KBG-2 3 KBG-2 3 KBG-2 x i= ~- j /.. X 4 1/1" JUJ 10149' BKR SEAL ASSY, ID = 3.0" 10151' S-1/2" BKR FA PERM PKR, ID = 2.98" 10155~ BKR C2 TIEBACK SLV, ID = 4.0" 10163~ 3.781" BKR DEPLOYMBYT SLV, ID = 3.0" 10182' 3-1/2" HES X NIP, ID = 2.813" 10346~ 9-5/8" X 5-1/2" BKR SAB PKR MILL~ ID = 4.75" 10358' 5-1/2" X 4-1/2" XO, ID = 3.958" 10419~ 4-1/2" BKR R NIP, M ILL~ ID = 3.80" 10436' ~W~ TT LOGGm 11/07/86 1~8' 3-1 /2" HES XN NIP, ID = 2.75" 10908' 3-1/2" PXN PLUG (02/06/08) 10941' 3-1 /2" X 3-3/16" XO, ~= 2.80" CBNBVT RAMP WINDOW (02-068) 11010' - 11026' ~~sr I-13-3/16~ x 2-~~a° xo, ~_ 3-3/16" LNR 6.2#, L-80, .0076 bpf, ID = 2.80" H 12267' ~ 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~ DATE REV BY COMMENTS DATE REV BY COMMQJTS 08/27/96 CTD SIDETRACK 02-06A) 03/26/O6 TBJPJC PULL PXN PLUG cQ 10908' 06/04/04 JDM/KA CTD SIDETRACK 02-06B) 02/O6/08 TA/PJC SET PXN PLUG ~ 10908' 01/06/05 KCF/TLP ADD PERFS 01/11/O6 DAV/PJC X NIP CORRECTION (c~ 10905 01/16/06 KSB/PAG SETPXNTTP(01/11/O6) 03/22(O6 RPWPJC WANERSFTY NOTEUPDATE 13046' PsTo PRUDHOE BAY UNff WH.L: 02-06B PB2Mff No: ~2040850 AR No: 50-029-20086-02 SEC 35, T11 N, R14E, 4139.49' F~ & 3113.14' FNL BP 6cploration (Alaska) • • _-~. MICROFILMED 03/01/2008 DO NOT PLACE =~:; '. ,.. -, ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc STATE OF ALASKA ~90~ ALAS OIL AND GAS CONSERVATIOf~} COMMIS ~~g ~ ~ ~~~$ REPORT OF SUNDRY WELL OPERATION~ska Oil & Gas Cnns_ Cnmmissinn 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other p UL G Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Lp~~ ~! Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment '. Exploratory 204-0850 ~ 3. Address: P.O. Box 196612 Stratigraphic SerVICe 6. API Number: Anchorage, AK 99519-6612 50-029-20086-02-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 64 KB ' PBU 02-066 , 8. Property Designation: 10. Field/Pool(s): , ADLO-028308 ' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13081. feet Plugs (measured) None true vertical 9073.37 , feet Junk (measu red) None Q ,~~pp~~®'~~> ~ FE[ ~ ~f ~o~~ ~ Effective Depth measured 13046 - feet C~ bi~@ true vertical 9068.56 , feet Casing Length Size MD TVD Burst Collapse Conductor 735 20" 94# H-40 30 - 765 30 - 765 1530 520 Conductor 451 20" 133# KI-55 765 - 1216 765 - 1216 2320 1500 Production 46 9-5/8" 53.5# N-80 26 - 72 26 - 72 7930 6620 Production 3007 9-5/8" 40# SOO-95 2092 - 5099 2092 - 4687 6820 3330 Production 781 9-5/8" 53.5# N-80 10229 - 11010 8255 - 8747 7930 6620 Production 5130 9-5/8" 47# SOO-95 5099 - 10229 4865 - 8255 8150 5080 Production 2020 9-5{8" 47# N-80 72 - 2092 72 - 2092 6870 4760 Surface 2686 13-3/8" 72# N-80 26 - 2712 26 - 2712 4930 2670 Liner 5933 3-1/2" 8.81# L-80 5008 - 10941 4800 - 8703 Liner 814 2-7/8" 6.16# L-80 12267 - 13081 9011 - 9037 13450 13890 Perforation depth: Measured depth: C 12264 - 12274 C 12650 - 13000 _ _ True Vertical depth: 9010 - 9012 9054.13 - 9062.47 _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 21 - 10358 4-1/2" 12.6# L-80 10358 - 10482 Packers and SSSV (type and measured depth) 3-1/2" SLPR Liner Hanger Packer 5008 3-112" Baker FA Packer 10151 5-1/2" Baker SAB Packer 10346 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): pp~~ ppe ~i1d-S [3!"~ ~~~ °~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 436 23962 73 866 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Developm ent Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG %~'' GINJ 1~ WINJ WDSPL i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NJA if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 ~ ~ 1 ~~A Date 2/13/2008 F r 1- i i na n • • 02-06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ :SUMMARY - _ .__ 2/5/2008; "**WELL SHUT IN ON ARRIVAL*'"' (secure well) ;DRIFTED W/ 2.805" CENT TO XN-NIP @ 10,908' MD. +'+'': SET 3-1/2" PXN PLUG BODY C~ 10908' MD (4 EA 3/16" EO-PTS.) 2/5/2008 T/I/0=1700/140/0 Assist slickline. Load tubing MITT 2000 psi Pumped 2 bb `meth, 190 bbls crude down Tubing to load. Stand by for SJL to set plug body ***Continue on 2-6-08**" 2/6/2008 ***CONTINUED FROM 02/05/08 WSR**" (secure well) SET P-PRONG IN PXN PLUG BODY @ 10908' MD. ' LRS MIT-T TO 2000 PSI, PASSED & BLED BACK TO 0 PSI. 1***WELL LEFT S!l & DSO INFORMED **" _,__~__ ...,_.a. .__~___,_ ,.__.__.. __.._a._..... _..___M._. __.,.. _.rw.ro~__.,,~ 2/6/2008 `**Continued from 2-5-08""* Load Tbg, MIT T PASSED to 2000 psi. Pumped 28 bbls crude down Tbg at minimum rate while S/L ran prong. MITT to 2000 psi, pumped 3.8 bbls crude to reach test pressure. Tbg lost 60 psi in 15 min. 30 sp i in 2nd 15 min for a total loss of 90 psi in 30 min. PASS -Additional test lost 20 psi in 15 min, 20 psi in 2nd 15 min for a total loss of less than 40 psi in 30 min, PASS. Bled back Tbg , FWHP's=500/0/0 *"Annulus valves open to gauges, Master and Wing valves tagged on departure""` FLUIDS PUMPED BBLS 32 CRUDE 32 Total 02-06B (PTD #2040850) Interna~iver Cancellation -Not Operable Well Page 1 of 1 Re , James B DOA J9 ( ) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer ~~ ~ ~ I b~w All, [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, December 31, 2007 5:54 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS1 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Dean, James A; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E Subject: 02-06B (PTD #2040850) Internal Waiver Cancellation -Not Operable Well ;,; An internal waiver was issued for a PC Leak on natural producing well 02-06B (PTD #2040850) on 03/22/06. The dispensation from the Well Integrity System Policy for this well has expired. If not already done, please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. .~--- The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 ~~1~~~N ~ ~ ~~~~ Pager: (907) 659-5100 x1154 1 /16/2008 ) J~.~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040850 Well Name/No. PRUDHOE BAY UNIT 02-06B Operator BP EXPLORATION (ALASKA) INC Spu..l ;t;) ~ ~().()&( API No. 50-029-20086-02-00 MD 13081...... TVD 9073 .,/ Completion Date 6/5/2004"'- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: SGRC COMBINED GR & EWR, MGR, eeL, CNL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey t Directional Survey Iæ D Tap 12989 Induction/Resistivity 4 12989 LIS Verification ~ C Lis 13595 Induction/Resistivity ¡L" 1 Sonic Log Log Run Scale Media No 2 Blu Directional Survey' (data taken from Logs Portion of Master Well Data Maint . Interval OH/ Start Stop CH Received Comments 10711 13081 7/16/2004 IIFR 7/16/2004 10471 13034 2/3/2005 GR/EWR4/ROP 10471 13034 2/3/2005 GRlEWR4/ROP 10500 13081 Open 2/22/2006 ROP NGP EWR plus Graphics 9800 12971 Case 3/3/2006 MNCL & Jewlery Log, Memory GRlCCLlCNL 3J Jun-2004 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y6> Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ Sample Set Number Comments . ~ ÒIN Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040850 Well Name/No. PRUDHOE BAY UNIT 02-06B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20086-02-00 MD 13081 ~tion Date 6/5/2004 Current Status 1-01L J UIC N Date: .,( 7 va-... ~<;o TVD 9073 Completion Status 1-01L Compliance Reviewed By: . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 j04-DB;:) 1350S-- RE: MWD Formation Evaluation Logs 02-06B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-06B: LAS Data & Digital Log Images: 50-029-20086-02 1 CD Rom /J- /J (ý)cÆQ£~h ,:;-I:J;:) 7 u;, . . dtJ 1- 0 ~ii WELL LOG TRANSMITTAL l~-' f'\ f1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 2, 2005 RE: MWD Formation Evaluation Logs: 02-06B, AK-MW-3093399 I LDWG formatted Disc with verification listing. API#: 50-029-20086-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed: ¡ U .... _ STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION CO . SSION REPORT OF SUNDRY WELL OPERATIONS· 1. Operations Performed: Stimulate 0 .....,;( , Abandon 0 Repair Well 0 PluQ PerforationsD Otherl t . "., - Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensiorÎ [J Change Approved ProgramD Operation Shutdown 0 Perforate [K] Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drìll Number: Name: Development ŒJ ExploratoryD 204-0850 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20086-02-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 02-06B 8. Property Designation: 10. Field/Pool(s): ADL-028308 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13081 feet true vertical 9073.4 feet Plugs (measured) None Effective Depth measured 13046 feet Junk (measured) None true vertical 9068.6 feet Casing Length Size MD TVD Burst Collapse Conductor 735 20" 94# H-40 30 - 765 30.0 - 765.0 1530 520 Conductor 451 20" 133# K-55 765 - 1216 765.0 - 1216.0 2320 1500 Production 46 9-5/8" 53.5# N-80 26 - 72 26.0 - 72.0 7930 6620 Production 3007 9-5/8" 40# SOO-95 2092 - 5099 2092.0 - 4864.7 6820 3330 Production 781 9-5/8" 53.5# N-80 10229 - 11010 8254.6 - 8747.2 7930 6620 Production 5130 9-5/8" 47# SOO-95 5099 - 10229 4864.7 - 8254.6 8150 5080 Production 2020 9-5/8" 47# N-80 72 - 2092 72.0 - 2092.0 6870 4760 Surface 2686 13-3/8" 72# N-80 26 - 2712 26.0 - 2712.0 4930 2670 Perforation Depth: Measured depth: 12264 - 12274, 12274 -12294, 12650 -13000 True vertical depth: 9010.26 - 9012.37,9012.37 - 9017.02,9054.13 - 9062.47 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 21 - 10358 4-1/2" 12.6# L-80 @ 10358 - 10482 Packers & SSSV (type & measured depth): 5-112" Baker SAB Packer @ 10346 3-1/2" Baker FA Packer @ 10151 3-1/2" SLPR Liner Hanger Packer @ 5008 12. Stimulation or cement squeeze summary: RBDMS 8FL FEE 2 8 2005 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 297 12.5 131 80 634 Subsequent to operation: 274 11.9 105 100 781 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ ServiceD Copies of Logs and Surveys run_ 16. Well Status after proposed work: Daily Report of Well Operations_ ! OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 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 Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature .£4.0 A. 0.- ;t¡~ , ~\ I fJt°îe : 564-4657 Date 2/18/05 I J Form 10-404 Revisecl 4/2004 !, \ \} !-, ¡ \> iÌ .1..... . . 02-068 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/06/05 Perforate 12264'-12274' 6 SPF, 12274'-12294' 6 SPF FLUIDS PUMPED BBLS 100 60/40 Methonal 107 1 % KCL 207 TOTAL Page 1 TRS;:= . MCEV OY WELLHEAD := MCEV OY . 02-068 S~.ES: ***PROD CSG LEAK. OPERATING ACTUA TOR := AXEL50N LIMITS. lAP = 500 PSI, MAX OAP = 1000 PSI, MAX KB. ELEV - 64' OOAP = 500 PSI (11/15/03 WAlVER)*** PASSED MIT·T BF. ELEV := ? 3500# TO 5000ft 5/17/04. SCAB LNR PATCHED CSG KOp:= 11018' LEAK @ 5489' & 6059'. PC LEAK LLR 16.8 GPM @ 2000# Max Angle - 94° @ 12133' Datum MD := 11188' Datum TVD := 8800'55 ~ ~ . I 2197' 5-1/2" BAKER PFVE SS5V NIP, ID:= 4.562" I 120" CSG, 94#, H-40 & 133#, K-55, ID = 18.78" I 1216' 0 113-3/8" CSG, 72#, N-80, ID = 12.347" I 2711' ~ TOPOF 31/2" SCAB LINER I 5008' h r-: 5008' -i 5 1/2" BKR SLPR RETRIEVABLE PKR, ID = 3.4" , F-' F-' I ( > ( > ~ --I 10149' -i BKR SEAL ASSY, ID = 3.0" I oj- - I EST. TOP OF LINER CEMENT I 10151' -15-1/2" BKR FA PERM PKR, ID = 2.98" I 10155' I ...........-- 10155' -1BKR C2 TIEBACK SLV, ID = 4.0" I ----- 10163' -13.781" BKR DEPLOYMENT SLV, ID = 3.0" I I · 1 10182' -i 3-1/2" HES X NIP, ID = 2.813" I Minimum ID = 2.440" @ 12267' I I 10233' !-f5-1/2" BKR SLIDING SLV, ID:= 4.223" I 3-3/16" X 2-7/8" XO 10290' -15-1/2" BKR R NIP, ID = 4.223" I 10296' 1-15-1/2" BKRSBRASSY ID = 3.90" I :8 - 10346' 9-5/8" X 5-1/2" BKR SAB PKR I Behind ~ , CT LNR MILLED ID = 4.75" 15-1/2" TBG,17#, L-80, .0232 bpf, ID = 4.892" H 10358' I - 145-1/2" X 4-1/2" XO, ID = 3.958" I --..¡ 10358' I 10419' --14-1/2" BKR R NIP, MILLED ID = 3.80" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10480' I I 10436' H ELMD TT LOGGED 11/07/86 I 10908' 1--!3-1/2"HESXNNIP,ID:=2.813" I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" I 10941' I 10941' -13-1/2" X 3-3/16" XO, ID = 2.80" I I PERFORA TION SUMMARY I I REF LOG: MCNLlCCLlGR ON 06/03/04 :> CEMENT RAMP WINDOW 11010' - 11026' ANGLEATTOPPERF: 78 @ 12264' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 12267' H 3-3/16" X 2-7/8" XO, ID = 2.440"1 2" 6 12264 - 12294 0 01/06/05 I 2" 6 126S0 - 13000 0 06/04/04 19-5/8" CSG, 40#, N-80, ID:= 8.681" I 11350' ~ I 13046' H PBTD I 12-7/8" LNR, 6.5#, L-80 , .0058 bpf, ID:= 2.441" I 12307' : 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID:= 2.80" I 12267' I 12-7/8" LNR, 6.16#, L-80, .00S8 bpf, ID:= 2.441" H 13081' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 08/27/96 CTD SIDErRACK (02-06A) WELL: 02-06B 06/04/04 JDM/KA CTD SIDErRACK (02-068) PERMIT No: 2040850 01/06/0S KCFITLP ADD PERFS API No: 50-029-20086-02 see 3S, T11 N, R14E, 4139.49' FEL & 3113.14' FNL '. BP Exploration (Alaska) .... . . " .. STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPlETION REPORT AND lOG ..... 1a. Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IBI Development o Exploratory DGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/5/2004 , 204-085 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/27/2004 50- 029-20086-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/1/2004 PBU 02-06B 1300' SNL, 1815' EWL, SEC. 36, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 3531' SNL, 3213' WEL, SEC. 35, T11N, R14E, UM 64' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 4769' SNL, 4318' WEL, SEC. 35, T11N, R14E, UM 13046 + 9069 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 688575 y- 5949925 Zone- ASP4 13081 + 9073 Ft ADL 028308 TPI: x- 683605 y- 5947570 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 682532 y- 5946306 Zone- ASP4 (Nipple) 2197' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL 22. CASING, liNER AND CEMENTING RECORD .7~~~~ ,,.,- .......17,., .GRAþÊ . §eTTllII$UEPTI-{.Mf;) SE1TING .DI;!"T\i ..T\ID ~<::i > ,"" ·.rop ! BOTTOM Tófi I BOTTOM .\ . 30" 157.5# B Surface 114' Surface 114' 39" Fondu, Circulated to Surface 20" 94# / 133# H&K Surface 1216' Surface 1216' 26" 1030 sx Fondu 13-3/8" 72# N-80 Surface 2711' Surface 2711' 17-1/2" 1309 sx Fondu, 485 sx Class 'G' 9-5/8" 53.5# /47# /40# S&N Surface 11022' Surface 8755' 12-1/4" 1990 sx Class 'G', 100 sx Fondu 3-1/2' x 3-3/16' x 2-7/8' 8.81# /6.2# /6.16# L-80 10151' 13081' 8203' 9073' 4-1/8' x 3-3/4' 128 sx Class 'G' 3-1/2" 8.81# L-80 5008' 10151' 4800' 8203' N/A Liner Tieback 23. Perforations open to Production (MD + TVD of To,e and 24. TIRII\Jt:: .\ ......,............ Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 5-1/2", 17#, L-80 10358' 10346' MD TVD MD TVD 4-1/2", 12.6#, L-80 10358' - 10480' 12650' - 13000' 9054' - 9062' 25. \ . < ÁC'D: . - ....... ETÇ.\" >,\ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 35 Bbls of MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 26, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF W A TER-Bsl CHOKE SIZE I GAS-Oil RATIO 6/25/2004 12.2 TEST PERIOD ... 389 5,093 17 43.34 13,071 Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 91E 300 24-HoUR RATE 766 10,019 34 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". ~~:',ë;;í;;,;,n JUl' it 3 1t: ~ Nooe I~I ~. G/d" . 1...: ',¡!.. ORIGINAL 1'.., I.·.'~' I V lED St:~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE --.s (') r c;, 28. GEOLOGIC MARKERS 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". Sadlerochit / Zone 4B 10763' 11053' 8592' None Top of CGL / Zone 3 Base of CGL / Zone 2C 8778' 11153' 8862' 2358 / Zone 28 11261' 8938' HOT 13025' 9066' 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 0 PBU 02-06B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 204-085 Permit No. / 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 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/22/2004 15:00 - 17:00 17:00 - 18:00 5/23/2004 18:00 - 00:00 00:00 - 04:30 04:30 - 06:30 06:30 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 15:00 15:00 - 16:30 16:30 - 18:00 18:00 - 19:45 19:45 - 21 :30 21 :30 - 00:00 5/24/2004 00:00 - 01 :00 01 :00 - 01 :20 01 :20 - 01 :40 ND tree cap. PRE Spot rig over well. Accept rig for work on DS 02-06B at 09:00, 5/23/04. PRE NU BOP. PRE Test BOPE to 250 13,500 psi. Test witnessed by AOGCC rep. Jeff Jones. PRE Pull BPV wI DSM lubricator. Bring fishing tools to rig floor. Load pits with 1 % KCI. DECOMP Cut off CTC and install Baker eTC. Pull test CTC to 40,000 Ibs. Fill coil and PT CTC. DECOMP PU fishing BHA #1 wI hydraulic GS spear, Circ. sub w/ burst disc, jar, 427/8" PAC Des, accelerator, lockable swivel, eTC. PT inner reel valve. DECOMP RIH with BHA#1 fishing assembly. - RIH at 100 fpm. - Displacing well to 1% KCI fluid at 0.3 bpm. DECOMP Stop at 10,298' MD. CBU until returns indicate uniform fluid colum. - PU weight at 42k. - Maintaining 150 psi max on tiger tank. - Returns include MEOH, Crude, and Gas. - Max IA pressure 250 psi, when gas was coming to surface. - Max OA at 300 psi. - Volume pumped: 230 bbls at midnight. DECOMP Stop at 10,298' MD. CBU until returns indicate uniform fluid colum. - Maintaining 150 psi max on tiger tank. - Returns include MEOH, Crude, Gas, and KCI. - IA pressure at 5 psi, OA pressure at 500 psi. - Total volume pumped: 368 bbls (2 bottoms up). 2.00 MOB P PRE 1.00 MOB P PRE 6.00 MOB 4.50 MOB 2.00 MOB P P P PRE PRE PRE 2.00 MOB P PRE 0.50 MOB P 1.00 BOPSU P 5.00 BOPSU P 1.50 BOPSU P 1.50 FISH P 1.75 FISH P 1.75 FISH P 2.50 FISH P 1.00 FISH P PJSM. Move rig off well. Complete post rig pad inspection wI pad operator. RD hard line and tiger tank. Move rig to west side of pad. from F-28A to DS 2. Pre job meeting with security, Drilling HSE advisor, and tool service for rig move. Move rig from F pad to DS 2. Move rig from F-28A to DS 2. Spot rig in front of 02-06. Pre pad inspection performed. Pre job meeting for backing over well. Back rig up to well. Confirm two valves are installed on tubing x production casing annulus due to a production casing leak. Set up scaffolding in cellar to remove tree cap. Note: Due to height of well head and tree, the tree was ND to the top of the master valve prior to moving over the well. Therefore, use of the standard tree work platform that attaches to the swab valve flange was not possible. 0.33 FISH 0.33 FISH P P PU 39k, SO 20k -- pumps on 2.5 bpm. PU 39k, SO 21 k -- pumps off. DECOMP Shut down pumps and monitor well. DECOMP Shut down pumps. RIH. Engage fish at 10,389' MD. Flag pipe. Correct coil depth to 10,384' MD. Printed: 6/7/2004 9:02:14 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/24/2004 01 :20 - 01 :40 0.33 FISH P DECOMP - PU fish with 5k over. - Flag pipe at 10,348' (10,200 EOP) - SO on fish. - PU wt 43k with pumps off. (Bouyant liner weight = 3900 Ibs) - No jarring required. 01 :40 - 03:45 2.08 FISH P DECOMP POOH with fish at 75 fpm. - Monitoring pit volume for displacement. - Circulating across the top of hole. 03:45 - 04:00 0.25 FISH P DECOMP PJSM for LD BHA and fish. NOTE: OA pressure steadily decreasing, currently 365 psi. 04:00 - 06:15 2.25 FISH P DECOMP Lay down 2-7/8" FL4S L-80 tubing. 06:15 - 07:30 1.25 REMCM P DECOMP PJSM w/ day crew. MU cement nozzle and stinger. MU injector. 07:30 - 09:30 2.00 REMCM P DECOMP RIH and tag top of cut liner. Correct depth to ELMD of cut, 11,090'. +3.3' correction. 09:30 - 10:45 1.25 REMCM P DECOMP CBU at 3.7 bpm, 2,800 psi. Gas returns to surface prior to bottoms up. Circulate until returns cleaned up. 10:45 - 11 :30 0.75 REMCM P DECOMP Start to batch mix cement after well bore cleaned up. Continue circulating at 2.8 bpm, 1586 psi. Cement up to weight, 17 ppg, at 11 :25. Shut down pump and switch over to cement pump. 11:30 -12:30 1.00 REMCM P DECOMP Pump 10 bbls of fresh water. PT cement lines to 4,000 psi. Pump 50 bbls of 17.3 ppg class G cement. Follow with 5 bbls of fresh water. Displace cement with 1 % KCI. Lay in cement 1 for 1 from 11,084' to 10,140'. 12:30 - 13:00 0.50 REMCM P DECOMP Pull up hole at 5 fpm, 2 bpm, 900 psi. 13:00 - 13:30 0.50 REMCM P DECOMP Start pumping biozan pill. RIH pumping 3 bpm, 1,700 psi. Wash out cement to end of tubing tail at 10,480'. 13:30 - 15:30 2.00 REMCM P DECOMP POOH circulating contaminated cement from well bore. 15:30 - 16:35 1.08 STWHIP P WEXIT LD stinger and nozzle. PU Hughes 4 1/8" bicenter bit, Weatherford straight motor, MWD, 2 joints 2 3/8" PH6, DS MHA. 16:35 - 18:20 1.75 STWHIP P WEXIT RIH to 10,000'. 18:20 - 21:45 3.42 STWHIP P WEXIT Wait on cement to reach 1,700 psi compressive strength. 21 :45 - 22:20 0.58 STWHIP P WEXIT RIH slowly. Increasing rate to 2.5 bpm. At EOP flag, correct coil depth -3'. Tag TOe at 10,502' MD. - 4500 Ib PU - 1900 Ib SO 22:20 - 00:00 1.67 STWHIP P WEXIT Mill cement from 10,502' MD to 10,677' MD - 2.4 bpm in / 2.56 bpm out - 1675 psi off bottom circulating pressure - 1758 psi on bottom circulating pressure - UCA at 3200 psi - Drilling at 170 fph initially. - Wipe hole at 30 - 40 foot intervals to prevent sticking coil. - ROP slowed to 70 fpm at 10,638' MD. 5/25/2004 00:00 - 06:00 6.00 STWHIP P WEXIT Mill cement from 10677' MD to 10876' MD - 2.6 bpm in /2.7 bpm out - 1790 psi off bottom circulating pressure - 1915 psi on bottom circulating pressure - UCA at 3200 psi - Drilling at 40 fph. Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/25/2004 00:00 - 06:00 6.00 STWHIP P WEXIT - Wipe hole at 30 - 40 foot intervals to prevent sticking coil. - Bled OA pressure from 780 psi to zero psi. - Tie in 10,500' MD - 10,800' MD GR with BHCS (1/29/71)-- correct + 1 ' 06:00 - 08:00 2.00 STWHIP P WEXIT Drill cement to 10,960' at 60-80 fph. 08:00 - 10:00 2.00 STWHIP P WEXIT POOH. 10:00 - 11 :40 1.67 STWHIP P WEXIT LD BHA. PU D331 3.80" diamond mil, Weatherford 1.25 deg AHM, MWD, orienter, 2 jts 2 3/8" PH6, Weatherford MHA. 11 :40 - 13:30 1.83 STWHIP P WEXIT RIH to 10785'. 13:30 - 13:48 0.30 STWHIP P WEXIT Tie - in Correction -3'. 13:48 - 13:53 0.08 STWHIP P WEXIT Ream pilot hole to 10,960'. 13:53 - 15:56 2.05 STWHIP P WEXIT Mill cement from 10960' MD to 11008' MD -TF High Side - 2.7 bpm in /2.8 bpm out - 2800 psi off bottom circulating pressure - 3030 psi on bottom circulating pressure - Drilling at 20-30 fph. -48K Up Wt -16K SO Wt 15:56-17:15 1.32 STWHIP P WEXIT Mill cement from 11008' MD to 11020' MD -TF 175L - 2.7 bpm in /2.8 bpm out - 2800 psi off bottom circulating pressure - 2900 psi on bottom circulating pressure - Drilling at 20 fph. -48K Up Wt -16K SO Wt 17:15 - 19:20 2.08 STWHIP P WEXIT POH for window mill. Tie -in =+2 correction Flag EOP 10500. MD = 11022 ft after tie-in. 19:20 - 20:00 0.67 STWHIP P WEXIT M/U window milling BHA with 3.80" He Diamond Mill, 3.0 deg WF motor, MWD, Orienter, 2 jts PH6 and MHA. OAL = 128.44 ft. 20:00 - 22:00 2.00 STWHIP P WEXIT RIH to flag at 10500' EOP. - 1 ft CTD. RIH. 22:00 - 22:15 0.25 STWHIP P WEXIT Orient TF to 170L. 22:15 - 22:24 0.15 STWHIP P WEXIT RIH. Tag TD at 11021.9 ft. Correct to 11022 ft. Flag CT at 11,022'. Pick up 1 ft. 22:24 - 00:00 1.60 STWHIP P WEXIT Time Mill window as per milling procedure. 2.6 bpm, 2320 psi, 168L. Swap well to 2% KCL water with 2 PPB Biozan. Milling at 11021.4' at 0000 hrs. 5/26/2004 00:00 - 03:00 3.00 STWHIP P WEXIT Time Milling window as per milling procedure. 2.6 bpm, 2320-2420 psi, 500# WOB, 168L, Seeing motor work and WOB. Milled to 11022.6 ft. 03:00 - 04:00 1.00 STWHIP P WEXIT Time Milling window as per milling procedure. 2.6 bpm, 2320-2490 psi, 1500# WOB, 173L, Good WOB, Ledge is started. Milled to 11023.3 ft. 04:00 - 05:00 1.00 STWHIP P WEXIT Time Milling window as per milling procedure. 2.6 bpm, 2320-2600 psi, 2000# WOB, 176R, Milled to 11024.3 ft 05:00 - 13:00 8.00 STWHIP P WEXIT Time Milling window as per milling procedure. 2.6 bpm, 2320-2650 psi, 3000# WOB, 164R, Milled to 11027 ft. Stalled. PU Continue to drill open hole to 11036'. Stopped making progress. POH for crayola mill. 13:00 - 15:00 2.00 STWHIP P WEXIT POH Printed: 6/7/2004 9:02: 14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/26/2004 15:00 - 16:00 1.00 STWHIP P WEXIT LD window mill. Window mill in gauge with visible wear across the center of the mill. PU 3.78 Diamond crayola mill with 2.25 WF motor. 16:00 - 18:00 2.00 STWHIP P WEXIT RIH correct to flag. Correction -4'. 18:00 - 19:30 1.50 STWHIP P WEXIT Ream down thru window with 165R TF. 3 Stalls to exit window. Ream down to 11,032 ft CTD [ not tied-in ¡. Back ream window. 19:30 - 21 :30 2.00 STWHIP P WEXIT Ream window with 175L TF. Swap well over to FloPro while reaming window. Ream up and down a total of 3 times. Last TF was 102L. Stop pump, RIH dry thru window. Window is clean. Back ream final pass. FloPro to surface. 21 :30 - 21 :45 0.25 STWHIP P WEXIT POH with window dressing BHA to 10780'. 21 :45 - 22:15 0.50 STWHIP P WEXIT Log GR tie-in. Added 2 ft to CTD. Corrected TD is 11032 ft. EOP flag at 10,894.5 ft. 22:15 - 00:00 1.75 STWHIP P WEXIT POH with window dressing BHA. 5/27/2004 00:00 - 00:30 0.50 STWHIP P WEXIT LlO Window Dressing BHA. 00:30 - 01 :00 0.50 DRILL P PROD1 Held Pre-Spud meeting and reviewed well plan and hazards with all personnel. Reviewed procedure, hazards and mitigation for M/U MWD Build BHA. 01 :00 - 01 :45 0.75 DRILL P PROD1 M/U 4-1/8" used He Bi-center bit, 1.69 deg BHI motor, Sperry MWD, orienter and SWS MHA. Cut off 3 ft of coil, M/U SWS eTC. Pull 1 press test CTC. BHA OAL = 65.46'. 01 :45 - 03:40 1.92 DRILL P PROD1 RIH with BHA #6, Sperry MWD with 1.69 Deg BHI motor. SHT tools - OK. RIH, 0.3 bpm, 1250 psi. full returns. Correct depth at CT Flag. -1.1 ft CTD. 03:40 - 03:50 0.17 DRILL P PROD1 RIH clean thru window with 160L TF. Tag TD at 11,032 ft. 03:50 - 05:40 1.83 DRILL P PROD1 Drilling Build section in Z2 and Z3. Top of Z3 at 11050'. 2.6/2.6 bpm, 2700 -3400 psi, 160L TF. 20 FPH. Several stalls. 36K up wt. 20K dwn wt. Drilled to 11,075'. 05:40 - 06:00 0.33 DRILL P PROD1 Orient TF to low side. 06:00 - 07:30 1.50 DRILL P PROD1 Drilling build section in Zone 3. -2.7/2.7 bpm @ 2900 psi 2800 psi =FS. Irradic TF Look like fault at 11084'. 07:30 - 09:45 2.25 DRILL P PROD1 Drilling build section in Zone 3. -2.5 1 2.5 bpm @ 2720 psi 2600 psi = FS. -TF 160L, -Drill to 11 091.Stalling. POH to look at bit. 09:45 - 11 :45 2.00 DRILL P PROD1 POH. 11:45 -12:10 0.42 DRILL P PROD1 Bit 8-6 rung out 12:10 - 14:15 2.08 DRILL P PROD1 RIH no problem at window. Tag bottom and correct +3'. 14:15 - 16:40 2.42 DRILL P PROD1 Drilling build section in Zone 3. -2.6/2.6 bpm @ 2820 psi 2700 psi = FS. -TF 170L, 10fph. 16:40 - 18:45 2.08 DRILL P PROD1 Drilling build section in Zone 3. -2.6 / 2.6 bpm @ 2880 psi 2700 psi = FS. -TF 20L, ROP 10 fph gradualling increasing to 18 fph @ 11131'. Drilled to 11,144'. 18:45 - 19:00 0.25 DRILL P PROD1 Orient to 30L. Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/27/2004 19:00 - 21 :20 2.33 DRILL P PROD1 Drilling 23. 2.6 I 2.6 bpm, 280-3600 psi, 30L, 33 deg incl, 30 FPH, better drilling. Drilled to 11,199 ft. 21 :20 - 21:40 0.33 DRILL P PROD1 Orient TF to 30R. 21 :40 - 23:00 1.33 DRILL P PROD1 Drilling 22, 2.7 I 2.7 bpm, 3000 - 3800 psi, 30R, 45 deg incl, 35 fph, Drilled to 11,240'. 23:00 - 00:00 1.00 DRILL P PROD1 Drilling 22, 2.7 I 2.7 bpm, 3000 - 3800 psi, 40R, 49 deg incl, 35 fph, Drilled to 11,250'. 5/28/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drilling 22, 2.7 I 2.7 bpm, 3000-3600 psi, 44R, 51 deg incl, Drilled to 11258'. 00:30 - 01 :00 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 01 :00 - 01 :30 0.50 DRILL P PROD1 Drilling 22, 2.7 I 2.7 bpm, 3000-3600 psi, 44R, 51 deg incl, Stacking wt with no stalls. Drilled to 11260'. 01 :30 - 03:30 2.00 DRILL P PROD1 POH for new bit. 03:30 - 04:00 0.50 DRILL P PROD1 C/O bit. Bit #5, [ 8,6,1,]. Pilot was cored. M/U 4.125" HCC Bi-center bit#6 Re-build bit. 04:00 - 06:00 2.00 DRILL P PROD1 RIH with MWD BHA #8, build BHA with 1.69 deg motor and 4.125" bi-center bit. OAL = 65.34 ft. 06:00 - 06:15 0.25 DRILL P PROD1 Log down with GR at 10780'. Correction +8.5". 06:15 - 06:25 0.17 DRILL P PROD1 RIH to 11262'. 06:25 - 08:45 2.33 DRILL P PROD1 Drilling Build section in 22 . 2.6/2.6 bpm, 3025 psi, 30L TF, 40-100 FPH. 36K up wt. 20K dwn wt. Drilled to 11,415 08:45 - 09: 10 0.42 DRILL P PROD1 Wiper to window 09: 1 0 - 09:55 0.75 DRILL P PROD1 Drilling Build section in 22 . 2.7 I 2.7 bpm, 3125 psi, HS TF, 80 FPH. 36K up wt. 20K dwn wt. Drilled to 11470. 09:55 - 12:00 2.08 DRILL P PROD1 POH 12:00 - 13:00 1.00 DRILL P PROD1 LD drilling assembly Bit graded 6-6. PU 4.54" drift assembly. 13:00 - 14:50 1.83 DRILL P PROD1 RIH with drift 4.54". Drift SSSV nipple. 400# wt loss running down thru nipple. Clean pulling thru it. Continue to RIH to tag SS at 10200. Flag end of pipe 10,146'. 14:50 - 16:30 1.67 DRILL P PROD1 POH. 2.3 bpm 70 fpm @ 1170 psi. 16:30 - 18:30 2.00 DRILL P PROD1 UO drift BHA. M/U MWD RES Lateral BHA with 1.37 deg motor and Bit #7, Re-build HYC, DS100, 3.75x4.25" bi-center bit. 18:30 - 20:30 2.00 DRILL P PROD1 RIH with MWD RES BHA #10. OAL = 91.03'. SHT tools - OK. RIH to flag on CT. Correct -2.5 ft CTD. 20:30 - 21 :00 0.50 DRILL P PROD1 Log GR tie-in at 10762 ft. -2 ft CTD. 21 :00 - 22:00 1.00 DRILL P PROD1 Log MAD pass down from window to TD with RES I GR tool. 2.7 I 2.7 bpm, 2950 psi. 15 fpm. Tag TD at 11,471'. 22:00 - 23:15 1.25 DRILL P PROD1 Drilling lateral in 22. 2.7 I 2.7 bpm, 3050 - 3600 psi, 70R, 90 deg incl, 80 fph, Drilled to 11,550 ft. 23: 15 - 00:00 0.75 DRILL P PROD1 Drilling lateral in 22. 2.7 I 2.7 bpm, 3050 - 3600 psi, 90R, 92 deg incl, 80 fph, Drilled to 11,600 ft. 5/29/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Drilling 22 lateral, 2.8 I 2.8 bpm, 3100 - 3600 psi, 80R, 92 degincl, Drilled to 11645'. 01 :30 - 02:15 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 02:15 - 02:45 0.50 DRILL P PROD1 Drilling 22 lateral, 2.8/2.8 bpm, 3100 - 3600 psi, 110R, 91 deg incl, Drilled to 11652'. Very slow drilling. 02:45 - 03:00 0.25 DRILL P PROD1 Orient TF to 120L. 03:00 - 05:45 2.75 DRILL P PROD1 Drilling 22 lateral, 2.8 I 2.8 bpm, 3100 - 3600 psi, 130L, 91 Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/29/2004 03:00 - 05:45 2.75 DRILL P PROD1 deg incl, Very slow drilling, 5 fph, 60% Chert, Several stalls. Swap to new FloPro while drilling. Drilled to 11,657'. 05:45 - 08:00 2.25 DRILL P PROD1 POH for new bit. 08:00 - 10:00 2.00 DRILL P PROD1 Change out bit (grade 8-5-L T-N-X-I-BT-PR) Down load memory data. MU Bit #8, Re-build HYC, DS100, 3.75x4.25" bi-center bit on 1.37 deg motor. 10:00 - 12:00 2.00 DRILL P PROD1 RIH. Shallow hole test good. Continue to RIH. Tag botton correct -3'. 12:00 - 15:00 3.00 DRILL P PROD1 Drilling Z2 lateral, 2.8/2.8 bpm, 3250 psi, 2900 psi FS, 130L, 89 deg incl, Drilled to 11,802. ROP decreasing from 100+ to 30+. Samples 11,700 and 11,75060% Chert. 15:00 - 15:45 0.75 DRILL P PROD1 Wiper to window. Hole in good condition. 15:45 - 19:00 3.25 DRILL P PROD1 Drilling Z2 lateral, 2.6/2.6 bpm, 2880 psi, 90L, 90 deg incl, ROP dropped off. Still 60% chert. Drilled to 11,863'. 19:00 - 21 :30 2.50 DRILL P PROD1 POH for new bit. 21 :30 - 21:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O bit and check MWD tools. 21 :45 - 22:30 0.75 DRILL P PROD1 C/O Bit, bit #7 graded at [8,5,1]. M/U New HYC D100 Bicenter Bit #8. No re-built bi-center bits left. Check orienter and MWD scribe. OAL = 91.03 ft. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with MWD RES BHA # 12, 1.37 deg motor and HYC Bi-center bit. SHT - OK. RIH. 5/30/2004 00:00 - 00:30 0.50 DRILL P PROD1 RI H with MWD RES lateral BHA, BHA #12, 1.37 deg motor, HYC Bi-center bit. 00:30 - 01 :00 0.50 DRILL P PROD1 Log GR tie-in. -3 ft CTD. 01 :00 - 01 :30 0.50 DRILL P PROD1 RIH, clean hole, tag TD at 11,866 ft. 38K up wt. 01 :30 - 01 :45 0.25 DRILL P PROD1 Orient TF to 100L. 01 :45 - 03:00 1.25 DRILL P PROD1 Drilling Z2 lateral, 2.7/2.7 bpm, 3000 - 3600 psi, 90L, 88 deg incl, slow hard drilling, several stalls. 60% chert. Drilled to 11880'. 03:00 - 05:00 2.00 DRILL P PROD1 Drilling Z2 lateral, 2.7/2.7 bpm, 3000 - 3600 psi, 80L, 88 deg incl. slow ROP, several stalls, hard drilling, 60% chert. Drilled to 11,900'. 05:00 - 06:00 1.00 DRILL P PROD1 Drilling Z2 lateral, 2.7/2.7 bpm, 3000 - 3600 psi, 80L. 88 deg incl, better drilling below 8937' TVDSS. Drilled to 11,914'. 06:00 - 09:20 3.33 DRILL P PROD1 Drilling Z2 lateral, 2.6/2.6 bpm, 3000 - 3200 psi, 2800 psi FS, 89L, 89 deg incl, Drilled to 12000'. 09:20 -10:15 0.92 DRILL P PROD1 Wiper to the window. Hole in good shape. 10:15 - 13:45 3.50 DRILL P PROD1 Drilling Z2lateral, 2.7/2.7 bpm,3200 psi, 2800 psi FS, 45L, 89 deg incl, Drilled to 12150'. ROP 25. 13:45 - 14:45 1.00 DRILL P PROD1 Wiper to window. Hole in good condition. 14:45 - 18:00 3.25 DRILL P PROD1 Directionally drill Z2 lateral 2.7/2.7 bpm @ 3100 psi. TF 135R ROP 48. Begin drilling drop thru N22 to Z2A target zone. Stalling. Drill to 12220' 2.6 / 2.6 bpm @ 3300 psi ,3000 psi FS. TF 167 R, Inc 87. ROP 28- 34 showing gradual increase as it decends thru zone 2B to N22 shale. 18:00 - 20:00 2.00 DRILL P PROD1 Drilling Z2. 2.8 /2.8 bpm, 3200 - 3800 psi. 82 deg incl. 40fph. Drilled to 12,250'. 20:00 - 22:00 2.00 DRILL P PROD1 Drilling Z2. 2.8 /2.8 bpm, 3200 - 3800 psi, 78 deg incl. 30fph, Drilled to 12,300'. Drilled 4.25" hole to 12.300' with bi-center bits. 22:00 - 00:00 2.00 DRILL P PROD1 POH for new bit. Flag CT at 10600' EOP. POH while circ. at 2.6 bpm. Printed: 6f7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 5/31/2004 00:00 - 00:30 0.50 DRILL P PROD1 POH for new bit and motor. 4.25" hole drilled to 12,300' with bi-center bits. 00:30 - 00:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. 00:45 - 02:30 1.75 DRILL P PROD1 C/O Bit and motor. Down load and test Sperry Resistivity/GR. Bit #8 [ 8,6,1 j, M/U new 1.37 deg motor and new 3-3/4" Bit #9, HYC DS49HGJ. Check orienter and MHA. OAL = 91.02 ft. 02:30 - 04:30 2.00 DRILL P PROD1 RIH with MWD RES BHA #13, SHT - OK. RIH to flag. -7 ft CTD. 04:30 - 05:00 0.50 DRILL P PROD1 Log GR tie-in. Added 4 ft. CTD. 05:00 - 05:45 0.75 DRILL P PROD1 RIH and tag TD at 12,303'. 05:45 - 06:00 0.25 DRILL P PROD1 Drilling Z2lateral, 2.7/2.7 bpm, 3100 - 3600 psi, 100L, 35 FPH, Drilled to 12,318'. 06:00 - 10:00 4.00 DRILL P PROD1 Orient TF to highside. Drill N22 and land in Zone 2A. 2.5/2.4 @ 3400 psi, 3000 psi FS, Inc 82.6 @ 12400'. ROP 88. Drill to 12450'. Loss rate 10 bph. 10:00 - 11 :00 1.00 DRILL P PROD1 Wiper. Hole in good condition. Clean thru th N22. 11 :00 - 12:00 1.00 DRILL P PROD1 Drilling Z2 lateral, 2.5/2.4 bpm, 3250 psi, 25L, 35 FPH, Drilled to 12,464. Drilling with -12K surface wt. thru Shale stringer ROP 25. Swap to new Flo Pro with 12ppb Kla-Gard and 3% Lubtex. Continue to drill 12:00 - 14:00 2.00 DRILL P PROD1 Orient 100L. Drill to 12500 formation kicked us up. Suspect fault at 12454'. 14:00 - 14:15 0.25 DRILL P PROD1 Orient 160L 14:15 -15:30 1.25 DRILL P PROD1 Drilling Z2lateral, 2.6/2.6 bpm, 3170 psi, 170L, 40 FPH, Drill to 12600'. Losses stopped. 15:30 - 17:00 1.50 DRILL P PROD1 Wiper to window. Over pull in shale @ 12550 & 12450. Trip back to bottom clean. Tag at 12595. 17:00 - 17:10 0.17 DRILL P PROD1 Orient high side. 17:10 - 18:45 1.58 DRILL P PROD1 Drilling Z2 lateral, 2.6/2.6 bpm, 3200 psi, 17L, ROP 50-80 , Drilled to 12657'. 18:45 - 21 :00 2.25 DRILL P PROD1 Drilling Z2lateral, 2.7/2.7 bpm, 3200 - 3600 psi, 15 fph, 92 deg incl, Stacking wt. Slow ROP, very little motor work. Drilled to 12,694'. 21 :00 - 21 :30 0.50 DRILL P PROD1 Wiper trip to 12400' to ream shales. Overpull and motor work at 11450 ft. Ream this area. RIH. 21 :30 - 23:15 1.75 DRILL P PROD1 Drilling Z2. 2.7 / 2.7 bpm, 3200 - 3500 psi, 40 fph, Stacking wt. Very little motor work. Good sand, should be drilling much better. Spud to clear face of bit. Drill with light wt to wash face of bit. Bit appears to be balled, unable to clear it. Drilled to 12,750 ft. 23:15 - 00:00 0.75 DRILL P PROD1 POH to check bit and BHA. Flag CT at 10,600' EOP. POH while circ to surface. 6/1/2004 00:00 - 01 :45 1.75 DRILL P PROD1 POH to check BHA and Bit. Circ. to surface. 01 :45 - 02:30 0.75 DRILL P PROD1 PT CTC-OK. Check Bit [ 1,1, I ]. but flow ports were washed out from inside, which may have diverted flow from two ports [2 ports are restrictedj, and caused bit to ball and not clear. Motor and orienter OK. M/U rebuilt Bit #10, 3-3/4" HYC DS49. Re-run 1.37 deg motor. OAL = 91.02'. 02:30 - 04:15 1.75 DRILL P PROD1 RIH with MWD RES BHA #14. Correct depth at flag, -7.5 ft. 04: 15 - 04:35 0.33 DRILL P PROD1 Log tie-in with GR at 10,762 ft. Log down. Added 4 ft to CTD. 04:35 - 05:40 1.08 DRILL P PROD1 RIH, reamed 22N shales from 12,300-12500 ft. RIH to TD. Printed: 617/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 6/1/2004 04:35 - 05:40 1.08 DRILL P PROD1 Tag bottom at 12,748 ft. 05:40 - 05:50 0.17 DRILL P PROD1 Orient TF to 120L. 05:50 - 07:45 1.92 DRILL P PROD1 Drilling Z21ateral, 2.6/2.6 bpm, 3050 - 3400 psi, 120L, 80 fph, much better drilling, 4K WOB, Drilled to 12853 ft. 07:45 - 08:45 1.00 DRILL P PROD1 Wiper to window. 10000'. SCR problem .6 bpm @ 19 fpm on one motor. Mototr work at 12500 -12350. 08:45 - 09: 15 0.50 DRILL N RREP PROD1 POH to 10000'. SCR problem.6 bpm @ 19 fpm on one motor. 09:15 - 09:30 0.25 DRILL N RREP PROD1 Investigate SCR I generator problems change assignments. Unable to recreat condition which caused one motor to carry excess load. 09:30 - 09:45 0.25 DRILL N RREP PROD1 RIH to window depth 09:45 - 10:50 1.08 DRILL P PROD1 Wiper Tag at 12849' 10:50 - 11 :25 0.58 DRILL P PROD1 Orient 120L. Drilling Z2 lateral, 2.6/2.6 bpm, 3600 psi, 90L, 110 fph, Drilled to 12880 ft. 11 :25 - 11 :30 0.08 DRILL P PROD1 Orient 120R 11 :30 - 13:00 1.50 DRILL P PROD1 Drilling Z2 lateral, 2.6 I 2.6 bpm, 3400 psi, 109R, 100 fph, Drilled to 12,973'. 13:00 - 15:30 2.50 DRILL P PROD1 Wiper trip to window. Reamed 22N shales from 12500-12300'. Worst part is at 12,315'. RIH. Sat down in 22N shale at 12450'. Orient to 70L. Ream thru shale. 15:30 - 16:45 1.25 DRILL P PROD1 Drilling, drop down looking for HOT, 2.6 I 2.6 bpm, 3400 psi, 82 deg incl, 109R, 120 fph. TD well @ 13080'. 16:45 - 17:50 1.08 DRILL P PROD1 Wiper trip to window. Saw little wt bobble @ 12450' with no motor work. PUH into window to 10797' for GR tie-in. 17:50 - 18:05 0.25 DRILL P PROD1 Log down GR & tie into marker @ 10762'. Added 7' to CTD. 18:05 - 20:00 1.92 DRILL P PROD1 RBIH. Reaming shale section from 12,300 - 12,500' MD at 15 fpm. 20:00 - 22:50 2.83 DRILL P PROD1 POOH, spotting liner running pill. - Final TD picked at 13,081' MD. - EOP flag at 10,100' for TD and 8,000' for window. 22:50 - 00:00 1.17 DRILL P PROD1 LD BHA. Download RES data. HOT came in @ 13040' & 9003' vdss. 6/2/2004 00:00-01:15 1.25 CASE P RUNPRD MU coil connector. Pull test to 40k. Pressure test to 4000 psi. 01:15 - 01:45 0.50 CASE P RUNPRD Pump Dart: - Coil volume at 53.3 bbls 01:45 - 02:15 0.50 CASE P RUNPRD Rig up liner running tools. - Approximately 1 bph static losses. 02:15 - 06:50 4.58 CASE P RUNPRD PJSM. Run liner. - 25 joints 2-7/8" (1 joint shoe track) - Fill pipe. - 42 joints 3-3/16" - 24 joints 3-1/2" - Confirm tubing joints left in shed. 5 each 2-7/8", 3 each 3-3/16", 25 each 3-1/2". 06:50 - 09:00 2.17 CASE P RUNPRD RIH with liner on CT. See 1st flag (+2' off) @ 10932'. Correct CTD to 10930'. Check up wt - 44k, down wt - 22k. RIH smoothly @ 50fpm thru window. Continue RIH @ 70fpm. Saw slight wt bobbles across shale sections. See 2nd flag (-3' off) @ 13027'. Tag TD @ 13083' CTD. P/U @ 48k. RBIH @ 14k & retag TD @ same depth. 09:00 - 09:40 0.67 CASE P RUNPRD Load 5/8" steel ball & circ with mud @ 2.17/2.17bpm, 2500psi. Set down 10k on CTLRT. Continue circ ball to seat. Slow down Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 5/21/2004 6/5/2004 N1 Spud Date: 12/24/1970 End: 6/5/2004 6/2/2004 09:00 - 09:40 0.67 CASE P RUNPRD to 0.46bpm & 1290psi @ 39bbls away. Ball on seat @ 44.2bbls. Pressure up to 3600psi & release CTLRT. P/U @ 31k & confirm release. Set back 10k on CTLRT. 09:40 - 10:30 0.83 CASE N WAIT RUNPRD Circ mud around @ 2.5/2670psi while W.O. KCL trucks. 10:30 - 13:00 2.50 CASE P RUNPRD Displace well to 2% KCI at 3.13/3.13bpm & 1800psi. Meanwhile R/U Dowell cementers. Ship back used mud to MI. 13:00 - 13:15 0.25 CEMT P RUNPRD PJSM with all personnel concerning cementing operations. 13:15 - 14:00 0.75 CEMT P RUNPRD Fill rig pits with 2% KCL. Mix 30bbls of 2ppb# biozan displacement fluid. Meanwhile continue displacing well to 2% KCL at 3.15/3.15bpm & 1200psi. 14:00 - 15:20 1.33 CEMT P RUNPRD Batch mix 26.4bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 14:00hrs. Flush/PT lines to 4k. Pump 26.4bbls cmt slurry @ 2.40/2.34bpm & 1800psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 27bbls bio-KCL @ 2.66/2.60bpm & 1380psi. CTWP engage LWP @ 53.6bbls away. Shear plug with 2600psi. Continue displacing LWP @ 2.17/2.08bpm, 2000psi & bump @ 74.4bbls away with 1000psi over. Bleed off & check floats - held. Pressure up to 200psi & sting out of liner. 25.3bbls cmt pumped around shoe. CIP @ 15:15hrs. 15:20 - 17:00 1.67 CEMT P RUNPRD POOH @ 100fpm pumping @ 0.55bpm to replace CT voidage only. 17:00 - 18:00 1.00 CEMT P RUNPRD OOH. PJSM. UD CTLRT. 18:00 - 19:30 1.50 CLEAN P CLEAN PJSM. Pick up 2.3" mill, 2-1/8" motor, 2jts 1-1/4" CSH and MCNUGR/CCL logging tools. 19:30 - 21 :00 1.50 CLEAN P CLEAN RIH with 94 joints of 1-1/4" CS Hydril 21 :00 - 21 :30 0.50 CLEAN P CLEAN Make up coil connector. 21 :30 - 23:00 1.50 CLEAN P CLEAN RIH to 9900' MD at 90 fpm. - Cement above 500 psi compressive strenght as per SLB rep. 23:00 - 00:00 1.00 EVAL P RUNPRD Log at 30 fpm from 9900' MD - 10155' MD (TOL) at 0.5 bpm and 630 psi. Reciprocate across liner top at 1.5 bpm and 2100 psi. Log at 30 fpm from 10155' MD to 11,767' MD at 0.5 bpm and 470 psi. 6/3/2004 00:00 - 01 :00 1.00 EVAL P RUNPRD Log at 30 fpm from 11,767' MD to 12,267' MD (LSL) at 1.0 bpm and 1470 psi. Reciprocate across LSL sub at 1.5 bpm and 2100 psi. Log at 30 fpm from 12,267' MD to 13,045' MD (PBTD) at 1.0 bpm and 2000 psi. Tag PBTD at 13,042' MD. Downpass complete. At PBTD and 1.0 bpm, circulating pressure = 2750 psi. 01 :00 - 03:40 2.67 EV AL P RUNPRD POOH, spotting 70 bbls of perf pill. Logging up at 60 fpm at 0.5 bpm, monitoring displacement to 4900' MD. Continue to POOH. 03:40 - 04:40 1.00 CLEAN P CLEAN Drop ball to open circ sub. Circulate cement contaminated mud out of hole, treating with citric acid. 04:40 - 05:40 1.00 CLEAN P CLEAN POOH racking back 1-1/4" CS Hydril DP. 05:40 - 06:00 0.33 CLEAN P CLEAN LD logging/cleanout BHA. Download MCNUCCUGR data. TOL logged @ 10154' & PBTD logged @ 13046.5'. 06:00 - 07:15 1.25 CLEAN P CLEAN M/U & RIH jetting swizzle stick & jet BOP's. POH & UD swizzle Printed: 6/7/2004 9:02: 14 AM - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 6/4/2004 23:40 - 00:00 00:00 - 01 :45 0.33 RUNCO 1.75 RUNCO stick. M/U Baker 4.54" OD drift on 1 jt of 2-3/8" PH-6 tbg & MHA. M/U injector. RIH Baker 4.54" OD drift thru 4.562" ID SSSV NIP @ 2197'. Continue drifting to 2300'. PUH clean with Baker 4.54" OD drift thru 4.562" ID SSSV NIP. POOH to surface. OOH. PJSM. UD Baker 4.54" OD drift. M/U Baker indexing mule shoe & GBH loactor seal assy, 'FA' L TP & R/tool on 1 jt of 2-3/8" PH-6 tbg & MHA. M/U injector. RIH with Baker 'FA' L TP BHA#18 to 10000'. Up wt check- 34k. Slack off wt - 20k. RIH @ 30fpm & observe 5k drag @ 10138'. P/U clean & continue RIH past 10154' (TOL ELM D). Locate & set down 10k @ 10159'. P/U clean to 10140'. RBIH, locate & reset 10k @ same depth - 10159' CTD. P/U to ball drop position @ 10150'. RUNCMP Load/launch 1/2" AI ball & chase @ 2.0/2.0bpm, 850psi. Set down 10k @ 10159'. P/U to up wt @ 10153'. P/U to 10152' to place locator l' above C2 sleeve. Ball on seat @ 50bbls. Pressure up to 2900psi to set pkr & shear setting tool. Top of 'FA' L TP from ELMD is @ 10149'. LTP element is @ 10150'. POOH with Baker setting tool. Paint EOP flag @ 4900'. 12k O/pull @ SSSV. Continue POOH to surface. OOH. PJSM. UD Baker setting tool. R/U & PJSM for RIH 3-1/2" scab liner assembly. MU 162 jts of 3-1/2" STL scab liner with K-22 Anchor seal assy, PBR & seal locator. - String wt. at 35k - BHA length at 5152.55'. RUNCMP RIH to 10,100' MD with liner at 80 fpm, slowing to 20 fpm at 2197' for the SSSV. - Cleaning pits. - Pumping at 1 bpm at 350 psi. - Pumping clean 2% double slick KCL due to cement contamination in previous system. - No sign of SSSV at 2197' MD. RUNCMP Circulate well to clean 2% KCI at 2.1 bpm (1100 psi). RUNCMP Circulate well to clean 2% KCI at 2.1 bpm. Pressure decreased from 1100 psi to 500 psi with clean fluid. RUNCMP Sting in to FA packer. - PU at 56k - SO at 25k - Sting in at 10, 145'CTMD, pressure increase to 100 psi. - Bleed off, set down 15k. - Pick up to shear at 61k. - Pick up to 10,114' MD at 2.5 bpm RUNCMP Drop 3/4" ball and set packer. - Circulate down 40 bbl at 2 bpm to get over goose neck. - Decrease rate to 0.3 bpm. - Ball on seat at 43.1 bbls. Bleed off. - RIH to PBR, Pick up 1 ft. - Pressure up to 2100 psi to set hanger/packer. - Pick up and slack off to confirm set. 08:00 - 08:30 0.50 RUNCMP 08:30 - 08:50 0.33 RUNCMP 08:50 - 09:00 0.17 RUNCMP 09:00 - 09:30 0.50 RUNCMP 09:30 - 12:20 2.83 RUNCMP 12:20 - 13:00 13:00 - 14:40 1.67 RUNCMP 14:40 - 15:30 0.83 RUNCMP 15:30 - 16:00 0.50 RUNCMP 16:00 - 22:30 6.50 RUNCMP 22:30 - 23:40 01 :45 - 02:00 0.25 RUNCO 02:00 - 02:40 0.67 RUNCO Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 03:20 - 03:25 - Packer setting depth at 5,006' MD. Pressure test 3-1/2" x 2-3/8" annulus to 2000 psi for 30 minutes. - Initial test lost from 2000 psi to 1840 psi in 15 minutes. Suspect bleeding into coil as pressure increased from 992 psi to 1230 psi while the IA pressure remained constant. - Re-test annulus to 2000 psi for 30 minutes. Will not test. All indications that the packer is set as no pressure increase is seen in the IA and the packer setting procedure proceeded as predicted. Time IA Coil Annulus o 130 1198 1970 5 125 1367 1846 - Decision made to shear ball seat and test the system as a whole. RUNCMP Shear ball seat and release from packer. - Sheared ball seat at 2800 psi. - PU wt = 18k RUNCMP Pressure test entire completion to 2000 psi for 30 min. - 1.9 bbls to pressure up. - Initial pressure 2018 psi (IA 133 psi) - Final pressure 1926 psi (IA 125 psi) POOH with packer setting tool from 10,130' MD. - POOH at 80 fpm circulating at 0.5 bpm for pipe displacement. - Slow down at 2197' MD for SSSV nipple. LD setting tool. Test coil connector, test OK. Tested crossover, disconnect and swivel at Baker, test OK. Weld on coil connector. Load pipe shed with perf guns. Pull test weld-on CTC to 35k & P/test to 3500 psi - OK. PJSM on P/U & RIH perf guns & 1-1/4" CHS tbg. M/U 17jts of 2" HSD 6spf 2006PJ guns & blank with CBF firing system. M/U lower MHA, XO, 60jts of 1-1/4" CSH tbg, XO & upper MHA. BHA OAL - 2227.21'. M/U Injector. Establish circ @ 0.38bpmI70psi. RIH with perforating BHA#20 to 7150' circ perf pill @ min rate. Up wt check - 23k. Slack off wt - 14k. RIH smoothly @ 30fpm with CTC going thru TOL. Continue RIH @ 50-70fpm wt checking every 1000' as follows: Depth Up S/O 8000' 27k 16k 9000' 31k 17k 10000' 34k 19k 11000' 38k 20k 12000' 39k 19k 13049' 38k 19k Tag PBTD 2x @ 13049'. Pull to P/U wt & correct CTD to 13046.5' (PBTD as per MCNL log). PUH to ball drop postion @ 13013'. Hook-up PSSD (portable seismic shot detection) sensor to WHD. OTHCMP Pump a total of 30bbls perf pill ahead. Load 1/2" AL ball. Blow 03:25 - 04:00 04:00 - 04:50 RUNCMP 04:50 - 05:00 RUNCMP 05:00 - 06:15 1.25 PERFO OTHCMP 06:15 - 07:00 0.75 PERFO OTHCMP 07:00 - 07:15 0.25 PERFO OTHCMP 07:15 - 08:15 1.00 PERFO OTHCMP 08:15 - 09:20 1.08 PERFO OTHCMP 09:20 - 12:40 3.33 PERFO P OTHCMP 12:40 - 13:25 0.75 PERFO P Printed: 6/7/2004 9:02:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-06 02-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/21/2004 Rig Release: 6/5/2004 Rig Number: N1 Spud Date: 12/24/1970 End: 6/5/2004 13:25 - 15:10 1.75 PERFO P OTHCMP 15:10-15:40 0.50 PERFO P OTHCMP 15:40 - 16:30 0.83 PERFO P OTHCMP 16:30 - 16:45 0.25 PERFO P OTHCMP 16:45 - 17:45 1.00 PERFO P OTHCMP 17:45 - 19:45 2.00 PERFO P OTHCMP 19:45-21:15 1.50 RIGD P POST 21 :15 - 23:45 2.50 RIGD P POST 6/5/2004 23:45 - 00:00 00:00 - 02:00 POST POST 0.25 RIGD P 2.00 RIGD P 02:00 - 04:30 2.50 RIGD P POST ball into CT with 10bbls perf pill behind. Position guns for btm shot @ 13000'. Chase ball @ 2.0bpm/3700psi. Slow to 1.0bpm/2000psi @ 40bbls. Ball on seat after 51 bbls away. RBIH to 13005'. PUH very slowly & ramp up to 4000psi with btm shot @ 13000'. Observe guns fire with good pressure drop indication & vibration on PSSD. Perforated interval = 12650'- 13000'. PVT = 277bbls. POOH with perf gun BHA @ 30-60fpm pumping down the CT @ 0.67bpm & 1370-220psi. POOH to 7000' (CTC in 5-1/2" tbg). PVT = 240bbls - 4bbls losses while POOH to 7000'. SID pump & flowcheck well for 30 mins - well stable. POOH with perf gun BHA @ 85fpm pumping across the WHD @ 0.7bpm & 70psi WHP. PVT = 213bbls - total of 6bbls losses. OOH. Held PJSM for RIB 1-1/4" CSH. Meanwhile SID pump & flowcheck well - stable. SIB injector. UD MHAs & RIB 30stds of 1-1/4" CSH tbg. PJSM. R/U & UD perf guns. ASF! PU nozzle. RIH to 2500' MD. Pump 35 bbl of MeOH. POOH. LD Nozzle. PJSM. Blow down CTU. - Pressure test lines to 3000 psi. - 25 bbls corrosion inhibitor. - 10 bbls MeOH - Pump 20,000 scf of N2. - Max pressure 2200 psi, limiting pressure to the tiger tank at 150 psi. - Return 55 bbls from coil. Flow check well. Dry rod in BPV. Spool coil back to the reel. Clean pits. Nipple down BOPE. NU and test tree cap. RIG RELEASE @ 04:30 HRS ON 06/05/2004. Printed: 6/7/2004 9:02:14 AM . . 24-Jun-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 02-068 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,711.00' MD 11,018.00' MD 13,081.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I () J J,) m 'i. Signed L1 otw I Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ~ tJ '->1 ~ b¥)- Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 02 02-06B Job No. AKMW3093399, Surveyed: 1 June, 2004 Survey Report 15 June, 2004 :µ C/ (" ......... Your Ref: API 500292008602 Surface Coordinates: 5949924.97 N, 688574.63 E (70016' 04.6751" N, 148028' 30.0007" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 J IJ OG ....; \ Surface Coordinates relative to Project H Reference: 949924.97 N, 188574.63 E (Grid) Surface Coordinates relative to Structure Reference: 1101.44 N, 962.29 E (True) Kelly Bushing Elevation: 64.00ft above Mean Sea Level Kelly Bushing Elevation: 64.00ft above Project V Reference Kelly Bushing Elevation: 64.00ft above Structure Reference !51=JE!r"'r"'Y-!5UJ1 DAILLING ·SeAVICes A Halliburton Company DEFINITIVE . . Survey Ref: svy4273 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-06B Your Ref: API 500292008602 Job No. AKMW3093399, Surveyed: 1 June, 2004 BPXA North Slope A/aska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 10711.00 52.250 257.000 8496.07 8560.07 2133.16 S 4647.42 W 5947676.05 N 683982.10 E 5106.09 Tie On Point MWD Magnetic 10800.00 51.650 258.350 8550.93 8614.93 2148.13 S 4715.89 W 5947659.38 N 683914.04 E 1.372 5173.65 10900.00 50.990 259.890 8613.43 8677.43 2162.86 S 4792.54 W 5947642.72 N 683837.77 E 1.371 5248.35 11000.00 50.350 261.460 8676.81 8740.81 2175.40 S 4868.87 W 5947628.28 N 683761.79 E 1.373 5321.73 . 11018.00 50.230 261.750 8688.31 8752.31 2177.42 S 4882.57 W 5947625.91 N 683748.14 E 1 .407 5334.79 Window Point 11048.69 38.850 258.860 8710.15 8774.15 2180.99 S 4903.76 W 5947621.82 N 683727.05 E 37.656 5355.20 11078.30 34.100 255.710 8733.96 8797.96 2184.83 S 4920.92 W 5947617.55 N 683709.99 E 17.239 5372.18 11111.32 28.040 251.670 8762.23 8826.23 2189.56 S 4937.28 W 5947612.41 N 683693.76 E 19.399 5388.86 11148.03 34.830 246.310 8793.54 8857.54 2196.50 S 4955.09 W 5947605.03 N 683676.12 E 19.986 5407.85 11180.54 40.250 240.330 8819.32 8883.32 2205.44 S 4972.74 W 5947595.65 N 683658.70 E 20.073 5427.63 11213.51 46.670 242.970 8843.24 8907.24 2216.17 S 4992.70 W 5947584.42 N 683639.02 E 20.233 5450.29 11246.98 51.770 247.190 8865.10 8929.10 2226.81 S 5015.68 W 5947573.21 N 683616.31 E 17.976 5475.59 11278.55 56.070 245.430 8883.69 8947.69 2237.07 S 5039.03 W 5947562.37 N 683593.22 E 14.346 5501.03 11314.22 62.050 242.970 8902.02 8966.02 2250.40 S 5066.55 W 5947548.36 N 683566.04 E 17.776 5531.59 11355.22 66.880 233.120 8919.72 8983.72 2269.99 S 5097.85 W 5947527.98 N 683535.25 E 24.658 5568.41 11387.84 73.040 230.490 8930.90 8994.90 2288.94 S 5121.91 W 5947508.44 N 683511.67 E 20.345 5598.52 11421.83 80.330 231.890 8938.72 9002.72 2309.65 S 5147.67 W 5947487.09 N 683486.44 E 21.818 5630.97 11463.18 89.690 236.280 8942.32 9006.32 2333.77 S 5180.99 W 5947462.14 N 683453.73 E 24.980 5671.69 11499.34 90.660 242.620 8942.20 9006.20 2352.14 S 5212.11 W 5947443.00 N 683423.08 E 17.737 5707.79 11534.13 90.480 246.500 8941.86 9005.86 2367.08 S 5243.52 W 5947427.27 N 683392.05 E 11.164 5742.54 11563.07 93.920 249.320 8940.75 9004.75 2377.96 S 5270.31 W 5947415.73 N 683365.54 E 15.365 5771.31 . 11598.66 92.330 254.950 8938.81 9002.81 2388.85 S 5304.12W 5947403.99 N 683332.02 E 16.415 5806.30 11628.10 91.890 262.530 8937.72 9001.72 2394.59 S 5332.95 W 5947397.53 N 683303.34 E 25.773 5834.49 11668.58 89.630 261.770 8937.18 9001.18 2400.12 S 5373.05 W 5947391.00 N 683263.40 E 5.890 5872.55 11704.07 86.610 256.720 8938.35 9002.35 2406.73 S 5407.88 W 5947383.52 N 683228.74 E 16.572 5906.45 11738.75 90.840 256.890 8939.12 9003.12 2414.65 S 5441.63 W 5947374.76 N 683195.20 E 12.207 5940.00 11769.94 92.690 250.730 8938.16 9002.16 2423.33 S 5471.55 W 5947365.33 N 683165.50 E 20.612 5970.53 11799.55 93.740 245.260 8936.50 9000.50 2434.41 S 5498.95 W 5947353.57 N 683138.39 E 18.782 5999.93 11834.50 89.870 242.970 8935.40 8999.40 2449.65 S 5530.37 W 5947337.54 N 683107.36 E 12.864 6034.83 11870.98 87.930 239.620 8936.10 9000.10 2467.17 S 5562.36 W 5947319.23 N 683075.83 E 10.610 6071.29 15 June, 2004 - 11:24 Page 2 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-06B Your Ref: API 500292008602 Job No. AKMW3093399, Surveyed: 1 June, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11901.91 87.140 233.810 8937.43 9001.43 2484.12 S 5588.18 W 5947301.64 N 683050.44 E 18.940 6102.04 11934.26 86.080 231.340 8939.34 9003.34 2503.74 S 5613.82 W 5947281.38 N 683025.29 E 8.296 6133.87 11976.19 90.000 225.730 8940.78 9004.78 2531.48 S 5645.20 W 5947252.87 N 682994.62 E 16.314 6174.56 12008.86 86.340 222.000 8941.82 9005.82 2555.01 S 5667.82 W 5947228.78 N 682972.59 E 15.990 6205.54 12038.00 89.070 217.420 8942.99 9006.99 2577.40 S 5686.42 W 5947205.93 N 682954.56 E 18.285 6232.42 . 12071.78 92.690 217.950 8942.47 9006.47 2604.13 S 5707.06 W 5947178.69 N 682934.60 E 10.831 6263.14 12102.33 92.160 213.190 8941.17 9005.17 2628.95 S 5724.81 W 5947153.43 N 682917.47 E 15.663 6290.40 12133.53 94.010 210.730 8939.50 9003.50 2655.38 S 5741.30 W 5947126.60 N 682901.65 E 9.856 6317.31 12166.50 90.750 215.130 8938.13 9002.13 2683.01 S 5759.20 W 5947098.52 N 682884.45 E 16.599 6346.02 12196.92 87.840 219.360 8938.50 9002.50 2707.22 S 5777.61 W 5947073.86 N 682866.66 E 16.876 6373.58 12235.10 82.910 222.360 8941.58 9005.58 2735.99 S 5802.49 W 5947044.48 N 682842.50 E 15.101 6409.00 12268.22 77.800 222.180 8947.13 9011.13 2760.14 S 5824.45 W 5947019.78 N 682821.16 E 15.438 6439.68 12303.74 74.980 224.820 8955.48 9019.48 2785.18 S 5848.20 W 5946994.15 N 682798.04 E 10.733 6472.36 12334.41 75.950 220.950 8963.18 9027.18 2806.93 S 5868.40 W 5946971.90 N 682778.39 E 12.617 6500.37 12367.53 79.820 226.230 8970.14 9034.14 2830.37 S 5890.72 W 5946947.92 N 682756.66 E 19.478 6531.03 12400.88 82.640 230.460 8975.23 9039.23 2852.26 S 5915.34 W 5946925.41 N 682732.60 E 15.120 6563.02 12431.14 82.380 227.820 8979.17 9043.17 2871.89 S 5938.03 W 5946905.23 N 682710.41 E 8.692 6592.24 12461.67 84.410 222.530 8982.68 9046.68 2893.26 S 5959.53 W 5946883.32 N 682689.45 E 18.451 6621.22 12493.51 91.810 217.420 8983.73 9047.73 2917.62 S 5979.95 W 5946858.45 N 682669.65 E 28.233 6650.64 12536.96 88.280 215.660 8983.70 9047.70 2952.53 S 6005.82 W 5946822.91 N 682644.66 E 9.078 6689.78 12576.34 85.200 210.900 8985.94 9049.94 2985.38 S 6027.38 W 5946789.53 N 682623.93 E 14.379 6724.17 12610.03 85.290 205.260 8988.74 9052.74 3014.99 S 6043.18 W 5946759.53 N 682608.88 E 16.685 6751.94 . 12642.33 89.780 201.740 8990.13 9054.13 3044.57 S 6056.04 W 5946729.64 N 682596.76 E 17.656 6777.10 12679.25 91.370 203.850 8989.75 9053.75 3078.60 S 6070.34 W 5946695.26 N 682583.32 E 7.156 6805.60 12712.81 90.400 198.920 8989.24 9053.24 3109.84 S 6082.57 W 5946663.73 N 682571.87 E 14.970 6830.98 12745.30 90.570 194.870 8988.96 9052.96 3140.92 S 6092.01 W 5946632.42 N 682563.21 E 12.476 6853.81 12777.70 88.900 187.640 8989.11 9053.11 3172.67 S 6098.33 W 5946600.52 N 682557.69 E 22.901 6874.19 12812.86 89.600 182.360 8989.57 9053.57 3207.69 S 6101.40 W 5946565.44 N 682555.51 E 15.147 6893.20 12848.09 89.160 176.720 8989.95 9053.95 3242.90 S 6101.11 W 5946530.25 N 682556.67 E 16.057 6909.36 12885.96 88.720 172.660 8990.65 9054.65 3280.59 S 6097.61 W 5946492.65 N 682561.12 E 10.782 6923.81 12923.72 87.140 179.890 8992.02 9056.02 3318.22 S 6095.16 W 5946455.10 N 682564.51 E 19.586 6939.17 12958.45 85.460 185.000 8994.26 9058.26 3352.83 S 6096.64 W 5946420.46 N 682563.90 E 15.459 6956.60 12995.72 83.170 190.990 8997.96 9061.96 3389.54 S 6101.79 W 5946383.63 N 682559.67 E 17.131 6978.25 13033.51 82.030 200.680 9002.84 9066.84 3425.55 S 6112.00 W 5946347.38 N 682550.37 E 25.606 7004.06 13058.77 82.110 201.390 9006.32 9070.32 3448.90 S 6120.98 W 5946323.81 N 682541.97 E 2.802 7022.88 15 June, 2004 -11:24 Page 3 of 4 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-06B Your Ref: API 500292008602 Job No. AKMW3093399, Surveyed: 1 June, 2004 North Slope A/aska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 13081.00 82.110 201.390 9009.37 9073.37 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 3469.40 S 6129.01 W 5946303.11 N 682534.46 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 242.240° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13081.00ft., The Bottom Hole Displacement is 7042.83ft., in the Direction of 240.487° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10711.00 11018.00 13081.00 8560.07 8752.31 9073.37 2133.16S 2177.42 S 3469.40 S 4647.42 W 4882.57 W 6129.01 W Tie On Point Window Point Projected Survey Survey tool prof/ram for 02-068 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10711.00 0.00 8560.07 8560.07 BP Conventional Gyro (02-06) 9073.37 MWD Magnetic (02-06B) 10711.00 13081.00 BPXA Dogleg Vertical Rate Section Comment (0/100ft) 0.000 7039.54 Projected Survey . . 15 June, 2004 - 11:24 Page 4 of4 DríllQuest 3.03.06.002 4-1/2" TBG, 12.6#, L-BO, 6.5#, PERMIT No: SEC35, T11N, Sf> . . FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 02-06B BP Exploration (Alaska) Inc. Permit No: 204-085 Surface Location: 1300' SNL, 1815' EWL, SEC. 36, TI1N, RI4E, UM Bottomhole Location: 4538' SNL, 4335' WEL, SEC. 35, TI1N, RI4E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you :ftom 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 t ess any required test. Contact the Commission's petroleum field inspector at (907) 659 60 ger). e ly, BY ORDER OF THE COMMISSION DATED tbis..2:'àay of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. vJ41\- S/20 I ¿()04 . STATE OF ALASKA I RECEIVED ALASKA~IL AND GAS CONSERVATION CO MISSION· .. PERMIT TO DRILL MAY 1 8 2004 20 MC 25 005 ^1",..It", fI,l 1<. r~>", r{lf1~ rb. Current Well Class ° Exploratory III Development QiL .h0.M.y!tiple Zone o Stratigraphic Test 0 Service 0 Development~' E)'8M'gle Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 P8U 02-068 /~ 6. Proposed Depth: 12. Field / Pool(s): MD 12850 TVD 8989ss Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028308 o Drill III Redri/l 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1300' SNL, 1815' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 3443' SNL, 2872' WEL, SEC. 35, T11 N, R14E, UM Total Depth: 4538' SNL, 4335' WEL, SEC. 35, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688575 y- 5949925 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18. Casing program Size Casino 4-1/8" x 3-3/4" 3-3/16" x 2-7/8" 8. Land Use Permit: 13. Approximate Spud Date: May 29, 2004 / 14. Distance to Nearest Property: 26,000' 9. Acres in Property: 2560 11020 ft Maximum Hole Angle 93° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 64' feet 07-02A is 854' away at 12612' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3275 psig Surface: 2320 .r-pSi9 To~~WP~~P~~ôttÔl11lcJ.oT MD TVD MD TVD (includin staae data) 10250' 8204' 12850' 8989' 106 sx Class 'G' 5000' 4730' 10250' 8204' Liner Tieback - .~ N/A 3-1/2" Weiaht 6.2# / 6.5# 9.2# Grade L-80 L-80 ..... Couclina Lenath TCII / STL 2600' STL 5250' Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12307 vè;l::;IIIY Structur;:¡ r.nnrll Jctor Surface Intermediate Prorluctinn Liner Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): 9075 None 12262 9070 None Lenqth Size . . ·MD I vu .'. 114' 1216' 2711' 11348' 1913' 30" 20" 13-3/8" 9-5/8" 2-7/8" Fondu, Circulated to Surface 1030 sx Fondu 1309 sx Fondu, 485 sx Class 'G' 1990 sx Class 'G', 100 sx Fondu 103 sx Class 'G' 114' 1216' 2711' / 11348' 10394' - 12307' 114' 1216' 2711' 8974' 8362' - 9075' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 9004' - 9068' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program 18120 MC 25.050 Requirements Date: Perforation Depth MD (ft): 11400' - 12252' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer Sionature -rrJ11N1 )<:iJ/JJ1/'J/J fi'h,ú Phone 564-4388 Date '5/t<g/()4 I {} - .. 1'\_1. . , . Permit To Drill IAPI Number: Permit Approval Number:.20~ .../"j 9' J;" 50-029-20086-02-00 Date: Conditions of Approval: Samples Required I D Yes ~ No Mud Log Required H+~ n Sulfide Measures ~Yes D No Directional Survey Required Ol11e, lé'+~; J ¡DO 'I" ì pe ( c.. O. ., t ¿, · 000 . ADDmved Bfi-JJL(}I/¡ n Q I ~ I " I ~ I ~~ED~~~~'DN Form 10-401 ~d 12'Zð03 , ' '. Contact Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 . I See cover letter for other requirements DYes ~No ~Yes D No Date bJiµ!fv/ 1ubmit~n D~licate . . BP 02-06B Sidetrack Pre CTD Summary (phase 1) ]) E]ine -Set CIBP at approx. ] 1, ]20' (-8754'TVDss), cut 27/8" liner at approximately 11,090'. / CTD Sidetrack Summary (phase 2) 1) Pull 2 7/8" liner, lay in cement for c~nt ramp. 2) Mill 3.8" window at ] ] ,020' md. 3) Drill 3.75" openho]e sidetrack to 12,850' planned TD with MWD/gamma ray. / 4) Run 3-3/16" x 2-7/8" liner completion, cement. / 5) Run MCNL, Perforate 6) Run 3 W' tieback from liner top to 5000ft. Mud Program: · Phase]: 8.4 ppg seawater · Phase 2: 8.7 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. ./ Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program:.. · A 3-3/16" x 2-7/8" cemented liner cOmp]e~iQ &../.0.··)10,250' (-8204ssTVD) to TD at 12850'. The liner cement volume is planned to be 22 . s of 15.8 ppg class G. · A 3 Yz" tieback will be run 5000' - 10,25 . . Parent Well Casings Hole Size Burst (psi) Collapse (psi) 13 3/8" 72# N-BO 53BO 2670 9%" 47#, N-80 6B70 4760 Sidetrack Casings 3-3/16" 6.2#, L-80, TCII- Prod LNR 41/8" 8520 7660 2Ys" 6.5#, L-BO, STL - Prod LNR 3 '%" 10570 11170 3 %" 9.2# L-BO STL - tie back 10160 10530 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 2-06b will be approximately 854' ctr-ctr away from well 07-02A at 12612'md · 2-06B will be approximately 26,000' from the unit boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray log will be run over all of the open hole section. · A CNL/GR/CCL cased hole log will be run after the liner has been cemented. Hazards / · Drill site 2 is not considered an HzS pad. The closest BHL 02-26a had a reading of 7ppm in 1994, the neighboring wells at surface 2-5A and 2-34A had readings of 6ppm in 1994 and 1999. · Loss circulation is considered a low risk, one fault is prognosed on the well path. Reservoir Pressure · Res. press. is estimated to be 3275 psi at 8800'ss (7.0 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2320 psi. .-/ P'¡¡¡NiI"nt Wølfpatb: Tw <m WiÞ: P¡,,¡u#1ö 1)2.((l:B 5J'.10292Cì)I16}2 02:,,(16: 116.2.0.ÚO N~tl.u..1 11 : 0$ 9i241199ß 15;4\:i M.UOft Rig: R~. n~tJ;ll'm V,$$Ctlø.n ..." ~1r¿S ~~~ii :::¡~~ 64.00 - Plan: Pian #10 (0200SIPtan#10 02-06B} 5/18/2004 / '~v, ' " " ¡:J'iEJ ,____ --"'~- me CP : '~'w , J-~ ---- , , '~¿vv , .. , '¿0U ,; , ~~, f " '¿<Ow, . _A' , " , d <v' ~ '~" ' '- / ,2800 ." ,', , , , : ~v, '"v, " '~ , :, ~ , v~, \ , ,3300 : , , ... .,'.', , ~ , 'v~ - -l-~~~ i:_:~ f:~':~· ,3500 , ~~~:~ 'Vvv : ~~ .: '~-A- "n:~ OAA MM -- _Co ___ -- "- _A. ' 'M 5750 5800 5850 5900 5950 6000 6050 6100 6150 6250 6300 6350 6400 6450 6500 Vertical Section at 242.24" . BP-GDB Baker Hughes INTEQ Planning Report . -..~~------.-~--~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638.44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: 53.847 N 58.060 W True 1.43 deg Well: 02-06 Slot Name: 06 02-06 Well Position: +N/-S 1100.89 ft Northing: 5949924.88 ft Latitude: 70 16 4.674 N +E/-W 963.98 ft Easting : 688574.63 ft Longitude: 148 28 30.001 W Position Uncertainty: 0.00 ft Wellpath: Plan#10 02-06B 500292008602 Current Datum: 11 : 06 9/24/1996 15:49 Magnetic Data: 5/18/2004 Field Strength: 57600 nT Vertical Section: Depth From (fVD) ft 34.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-06 11020.00 ft Mean Sea Level 25.35 deg 80.87 deg Direction deg 242.24 Height 64.00 ft Targets 02-06B Polygon 1 0.1 0.00 -2242.51 -5157.73 5947554.00 683475.00 70 15 42.602 N 148 31 0.085 W -Polygon 1 0.00 -2242.51 -5157.73 5947554.00 683475.00 70 1542.602 N 148 31 0.085 W -Polygon 2 0.00 -2407.40 -5604.03 5947378.00 683033.00 70 1540.977 N 148 31 13.068 W -Polygon 3 0.00 -2724.26 -6053.14 5947050.00 682592.00 70 15 37.857 N 148 3126.129W -Polygon 4 0.00 -3043.35 -6254.20 5946726.00 682399.00 70 15 34.717 N 148 31 31.972 W -Polygon 5 0.00 -3247.02 -6270.31 5946522.00 682388.00 70 15 32.714 N 148 31 32.436 W -Polygon 6 0.00 -3436.60 -6290.07 5946332.00 682373.00 70 15 30.849 N 148 31 33.006 W -Polygon 7 0.00 -3495.62 -6090.47 5946278.00 682574.00 70 15 30.270 N 148 31 27.197 W -Polygon 8 0.00 -3297.12 -6027.48 5946478.00 682632.00 70 15 32.223 N 148 31 25.369 W -Polygon 9 0.00 -2886.81 -5794.11 5946894.00 682855.00 70 15 36.260 N 148 31 18.589 W -Polygon 10 0.00 -2524.96 -5263.85 5947269.00 683376.00 70 1539.823 N 148 31 3.167 W -Polygon 11 0.00 -2336.50 -5080.06 5947462.00 683555.00 70 1541.678 N 148 30 57.823 W 02-06B Fault 1 0.00 -2186.09 -5014.27 5947614.00 683617.00 70 1543.158 N 148 30 55.912 W -Polygon 1 0.00 -2186.09 -5014.27 5947614.00 683617.00 70 15 43.158 N 148 30 55.912 W -Polygon 2 0.00 -2853.86 -4713.88 5946954.00 683934.00 70 15 36.592 N 148 30 47.159 W 02-06B Fault 2 0.00 -2450.97 -6659.52 5947308.00 681979.00 70 15 40.540 N 148 31 43.780 W -Polygon 1 0.00 -2450.97 -6659.52 5947308.00 681979.00 70 1540.540 N 148 31 43.780 W -Polygon 2 0.00 -3242.48 -6451.27 5946522.00 682207.00 70 15 32.757 N 148 31 37.701 W 02-06B T10.3 8929.00 -2719.56 -5721.90 5947063.00 682923.00 70 15 37.906 N 148 31 16.491 W 02-06B T10.1 8940.00 -2296.13 -5134.07 5947501.00 683500.00 70 15 42.075 N 148 30 59.396 W 02-06B nO.2 8940.00 -2417.68 -5393.21 5947373.00 683244.00 70 1540.877 N 148 31 6.934 W 02-06B nO.5 8983.00 -3133.33 -6136.42 5946639.00 682519.00 70 1533.833 N 148 31 28.543 W 02-06B T10.4 8986.00 -2917.45 -5968.94 5946859.00 682681.00 70 15 35.958 N 148 31 23.675 W 02-06B T10.6 8989.00 -3232.55 -6168.91 5946539.00 682489.00 70 15 32.857 N 148 31 29.486 W . BP-GDB Baker Hughes INTEQ Planning Report . ""'""'"-~--~ 10711.00 8496.08 TIP 11020.00 8689.61 KOP 11034.00 8699.08 3 11122.00 8770.15 4 11458.64 8940.12 5 11678.64 8940.12 6 12028.64 8931.57 7 12153.64 8928.62 8 12321.23 8957.70 9 12488.73 8986.78 10 12688.73 8983.90 11 12763.73 8982.85 12 12850.00 8989.02 TD Plan: Plan #10 Date Composed: 5/18/2004 Identical to Lamar's Plan #10 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10711.00 52.25 257.00 8496.08 -2133.16 -4647.42 0.00 0.00 0.00 0.00 11020.00 50.22 261.78 8689.61 -2177.64 -4884.08 1.37 -0.66 1.55 120.06 11034.00 44.62 261.78 8699.08 -2179.11 -4894.27 40.00 -40.00 0.00 180.00 11122.00 27.02 261.78 8770.15 -2186.45 -4945.05 20.00 -20.00 0.00 180.00 11458.64 90.00 229.82 8940.12 -2321.93 -5176.62 20.00 18.71 -9.49 325.00 11678.64 90.00 256.22 8940.12 -2420.84 -5370.95 12.00 0.00 12.00 90.00 12028.64 92.68 214.29 8931.57 -2615.74 -5652.12 12.00 0.76 -11.98 274.00 12153.64 90.01 229.06 8928.62 -2708.80 -5734.98 12.00 -2.13 11.81 100.00 12321.23 69.90 229.06 8957.70 -2816.38 -5859.01 12.00 -12.00 0.00 180.00 12488.73 90.00 229.06 8986.78 -2923.89 -5982.96 12.00 12.00 0.00 0.00 12688.73 91.63 205.11 8983.90 -3082.25 -6102.68 12.00 0.81 -11.97 274.00 12763.73 89.97 196.27 8982.85 -3152.34 -6129.14 12.00 -2.20 -11.80 259.50 12850.00 81.83 189.85 8989.02 -3236.04 -6148.58 12.00 -9.44 -7.44 218.00 Survey 10711.00 52.25 257.00 8496.08 -2133.16 -4647.42 5947676.09 683982.38 5106.10 0.00 0.00 TIP 10725.00 52.15 257.21 8504.66 -2135.63 -4658.21 5947673.36 683971.66 5116.80 1.37 120.06 MWD 10750.00 51.98 257.59 8520.02 -2139.93 -4677.45 5947668.57 683952.53 5135.83 1.37 119.93 MWD 10775.00 51.81 257.97 8535.45 -2144.10 -4696.68 5947663.93 683933.42 5154.78 1.37 119.70 MWD 10800.00 51.65 258.35 8550.93 -2148.13 -4715.89 5947659.42 683914.32 5173.66 1.37 119.46 MWD 10825.00 51.48 258.73 8566.48 -2152.02 -4735.08 5947655.05 683895.23 5192.45 1.37 119.23 MWD 10850.00 51.31 259.12 8582.07 -2155.77 -4754.25 5947650.82 683876.16 5211.17 1.37 118.99 MWD 10875.00 51.15 259.50 8597.73 -2159.39 -4773.40 5947646.72 683857.10 5229.80 1.37 118.75 MWD 10900.00 50.99 259.89 8613.44 -2162.86 -4792.54 5947642.77 683838.06 5248.35 1.37 118.51 MWD 10925.00 50.82 260.28 8629.21 -2166.20 -4811.65 5947638.95 683819,04 5266.82 1.37 118.26 MWD 10950.00 50.66 260.67 8645.03 -2169.41 -4830.74 5947635.27 683800.04 5285.21 1.37 118.02 MWD 10975.00 50.50 261.07 8660.90 -2172.47 -4849.81 5947631.73 683781.05 5303.51 1.37 117.77 MWD 11000.00 50.35 261.46 8676.83 -2175.40 -4868.86 5947628.33 683762.09 5321.73 1.37 117.52 MWD 11020.00 50.22 261.78 8689.61 -2177.64 -4884.08 5947625.71 683746.93 5336.24 1.37 117.27 KOP 11025.00 48.22 261.78 8692.87 -2178.18 -4887.82 5947625.07 683743.20 5339.81 40.00 180.00 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 11034.00 44.62 261.78 8699.08 -2179.11 -4894.27 5947623.98 683736.77 5345.95 40.00 180.00 3 11050.00 41.42 261.78 8710.77 -2180.67 -4905.08 5947622.15 683726.01 5356.24 20.00 180.00 MWD 11075.00 36.42 261.78 8730.22 -2182.92 -4920.62 5947619.51 683710.53 5371.03 20.00 180.00 MWD 11100.00 31.42 261.78 8750.96 -2184.91 -4934.42 5947617.17 683696.79 5384.18 20.00 180.00 MWD 11122.00 27.02 261.78 8770.15 -2186.45 -4945.05 5947615.37 683686.20 5394.29 20.00 180.00 4 11125.00 27.51 261.04 8772.82 -2186.65 -4946.40 5947615.13 683684.85 5395.59 20.00 325.00 MWD 11150.00 31.76 255.68 8794.55 -2189.18 -4958.49 5947612.30 683672.83 5407.47 20.00 325.66 MWD 11175.00 36.18 251.48 8815.28 -2193.16 -4971.87 5947608.00 683659.56 5421.16 20.00 330.32 MWD 11200.00 40.72 248.10 8834.85 -2198.54 -4986.44 5947602.24 683645.12 5436.56 20.00 333.80 MWD 11225.00 45.34 245.30 8853.13 -2205.30 -5002.09 5947595.09 683629.65 5453.56 20.00 336.45 MWD 11250.00 50.01 242.91 8869.96 -2213.39 -5018.71 5947586.60 683613.24 5472.03 20.00 338.51 MWD 11275.00 54.74 240.83 8885.22 -2222.73 -5036.16 5947576.82 683596.03 5491.82 20.00 340.12 MWD 11300.00 59.49 238.98 8898.79 -2233.26 -5054.31 5947565.84 683578.15 5512.79 20.00 341.39 MWD 11325.00 64.26 237.30 8910.57 -2244.90 -5073.03 5947553.73 683559.73 5534.77 20.00 342.39 MWD 11350.00 69.06 235.75 8920.47 -2257.56 -5092.16 5947540.60 683540.92 5557.60 20.00 343.19 MWD 11375.00 73.87 234.30 8928.42 -2271.15 -5111.58 5947526.53 683521.85 5581.11 20.00 343.80 MWD 11377.12 74.27 234.18 8929.00 -2272.34 -5113.23 5947525.30 683520.23 5583.13 20.00 344.26 02-06B 11400.00 78.68 232.92 8934.35 -2285.55 -5131.12 5947511.64 683502.68 5605.11 20.00 344.29 MWD 11425.00 83.51 231.59 8938.22 -2300.67 -5150.64 5947496.04 683483.54 5629.43 20.00 344.59 MWD 11450.00 88.33 230.28 8940.00 -2316.38 -5170.00 5947479.85 683464.59 5653.87 20.00 344.80 MWD 11458.64 90.00 229.82 8940.12 -2321.93 -5176.62 5947474.14 683458.11 5662.32 20.00 344.89 5 11475.00 90.00 231.79 8940.12 -2332.27 -5189.30 5947463.49 683445.69 5678.35 12.00 90.00 MWD 11500.00 90.00 234.79 8940.12 -2347.21 -5209.34 5947448.05 683426.04 5703.04 12.00 90.00 MWD 11525.00 90.00 237.79 8940.12 -2361.08 -5230.13 5947433.66 683405.60 5727.91 12.00 90.00 MWD 11550.00 90.00 240.79 8940.12 -2373.85 -5251.62 5947420.36 683384.44 5752.87 12.00 90.00 MWD 11575.00 90.00 243.79 8940.12 -2385.48 -5273.75 5947408.19 683362.60 5777.87 12.00 90.00 MWD 11600.00 90.00 246.79 8940.12 -2395.93 -5296.46 5947397.17 683340.17 5802.83 12.00 90.00 MWD 11625.00 90.00 249.79 8940.12 -2405.17 -5319.68 5947387.35 683317.18 5827.69 12.00 90.00 MWD 11650.00 90.00 252.79 8940.12 -2413.19 -5343.36 5947378.74 683293.72 5852.37 12.00 90.00 MWD 11675.00 90.00 255.79 8940.12 -2419.96 -5367.42 5947371.37 683269.83 5876.82 12.00 90.00 MWD 11678.64 90.00 256.22 8940.12 -2420.84 -5370.95 5947370.40 683266.32 5880.36 12.00 90.00 6 11700.00 90.18 253.67 8940.09 -2426.39 -5391.58 5947364.34 683245.85 5901.19 12.00 274.00 MWD 11725.00 90.39 250.68 8939.97 -2434.04 -5415.38 5947356.09 683222.25 5925.81 12.00 274.00 MWD 11750.00 90.60 247.68 8939.75 -2442.93 -5438.74 5947346.62 683199.12 5950.63 12.00 273.98 MWD 11775.00 90.80 244.69 8939.45 -2453.02 -5461.61 5947335.96 683176.51 5975.56 12.00 273.96 MWD 11800.00 91.01 241.70 8939.05 -2464.29 -5483.91 5947324.13 683154.49 6000.55 12.00 273.92 MWD 11825.00 91.21 238.70 8938.57 -2476.71 -5505.60 5947311.18 683133.13 6025.53 12.00 273.87 MWD 11850.00 91.40 235.71 8938.00 -2490.25 -5526.61 5947297.12 683112.47 6050.42 12.00 273.81 MWD 11875.00 91.60 232.71 8937.34 -2504.86 -5546.88 5947282.00 683092.57 6075.17 12.00 273.75 MWD 11900.00 91.79 229.72 8936.61 -2520.51 -5566.36 5947265.87 683073.49 6099.69 12.00 273.67 MWD 11925.00 91.97 226.72 8935.79 -2537.16 -5584.99 5947248.76 683055.29 6123.93 12.00 273.58 MWD 11950.00 92.15 223.73 8934.89 -2554.75 -5602.72 5947230.73 683038.00 6147.82 12.00 273.48 MWD 11975.00 92.33 220.73 8933.91 -2573.25 -5619.51 5947211.82 683021.68 6171.29 12.00 273.37 MWD 12000.00 92.49 217.73 8932.86 -2592.60 -5635.30 5947192.09 683006.38 6194.28 12.00 273.26 MWD 12025.00 92.65 214.73 8931.74 -2612.74 -5650.06 5947171.58 682992.13 6216.72 12.00 273.13 MWD 12028.64 92.68 214.29 8931.57 -2615.74 -5652.12 5947168.53 682990.15 6219.94 12.00 273.00 7 12050.00 92.23 216.82 8930.65 -2633.10 -5664.53 5947150.87 682978.18 6239.00 12.00 100.00 MWD 12075.00 91.70 219.78 8929.80 -2652.70 -5680.01 5947130.88 682963.19 6261.84 12.00 100.11 MWD 12100.00 91.16 222.73 8929.17 -2671.49 -5696.49 5947111.69 682947.19 6285.17 12.00 100.21 MWD 12125.00 90.63 225.68 8928.78 -2689.41 -5713.92 5947093.34 682930.22 6308.93 12.00 100.28 MWD 12150.00 90.09 228.63 8928.62 -2706.40 -5732.24 5947075.89 682912.32 6333.07 12.00 100.33 MWD 12153.64 90.01 229.06 8928.62 -2708.80 -5734.98 5947073.43 682909.64 6336.61 12.00 100.35 8 . BP-GDB Baker Hughes INTEQ Planning Report . ~"'V_.V___ INTEQ 12175.00 87.45 229.06 8929.09 -2722.79 -5751.12 5947059.04 682893.87 6357.40 12.00 180.00 MWD 12200.00 84.45 229.06 8930.86 -2739.13 -5769.95 5947042.23 682875.45 6381.68 12.00 180.00 MWD 12225.00 81.45 229.06 8933.93 -2755.39 -5788.69 5947025.51 682857.12 6405.83 12.00 180.00 MWD 12250.00 78.45 229.06 8938.29 -2771.51 -5807.28 5947008.93 682838.94 6429.80 12.00 180.00 MWD 12275.00 75.45 229.06 8943.94 -2787.47 -5825.68 5946992.52 682820.95 6453.51 12.00 180.00 MWD 12300.00 72.45 229.06 8950.85 -2803.21 -5843.83 5946976.33 682803.21 6476.90 12.00 180.00 MWD 12321.23 69.90 229.06 8957.70 -2816.38 -5859.01 5946962.79 682788.36 6496.46 12.00 180.00 9 12325.00 70.35 229.06 8958.98 -2818.70 -5861.68 5946960.40 682785.74 6499.91 12.00 360.00 MWD 12350.00 73.35 229.06 8966.77 -2834.26 -5879.63 5946944.39 682768.20 6523.04 12.00 0.00 MWD 12375.00 76.35 229.06 8973.30 -2850.07 -5897.85 5946928.13 682750.37 6546.53 12.00 0.00 MWD 12400.00 79.35 229.06 8978.56 -2866.09 -5916.31 5946911.66 682732.32 6570.33 12.00 0.00 MWD 12425.00 82.35 229.06 8982.53 -2882.26 -5934.96 5946895.03 682714.09 6594.35 12.00 0.00 MWD 12450.00 85.35 229.06 8985.21 -2898.54 -5953.73 5946878.28 682695.73 6618.55 12.00 0.00 MWD 12475.00 88.35 229.06 8986.58 -2914.90 -5972.59 5946861.46 682677.29 6642.86 12.00 0.00 MWD 12488.73 90.00 229.06 8986.78 -2923.89 -5982.96 5946852.20 682667.15 6656.22 12.00 360.00 10 12500.00 90.09 227.71 8986.77 -2931.38 -5991.38 5946844.51 682658.92 6667.16 12.00 274.00 MWD 12525.00 90.30 224.72 8986.69 -2948.67 -6009.43 5946826.77 682641.31 6691.19 12.00 274.00 MWD 12550.00 90.51 221.73 8986.51 -2966.89 -6026.55 5946808.13 682624.65 6714.82 12.00 273.99 MWD 12575.00 90.72 218.73 8986.24 -2985.97 -6042.69 5946788.65 682608.99 6737.99 12.00 273.97 MWD 12600.00 90.92 215.74 8985.88 -3005.87 -6057.82 5946768.38 682594.37 6760.65 12.00 273.94 MWD 12625.00 91.13 212.75 8985.43 -3026.53 -6071.88 5946747.38 682580.83 6782.71 12.00 273.89 MWD 12650.00 91.32 209.75 8984.90 -3047.90 -6084.85 5946725.69 682568.41 6804.14 12.00 273.84 MWD 12675.00 91.52 206.76 8984.28 -3069.91 -6096.68 5946703.39 682557.13 6824.86 12.00 273.77 MWD 12688.73 91.63 205.11 8983.90 -3082.25 -6102.68 5946690.91 682551.44 6835.92 12.00 273.70 11 12700.00 91.38 203.78 8983.61 -3092.51 -6107.34 5946680.54 682547.04 6844.82 12.00 259.50 MWD 12725.00 90.83 200.83 8983.13 -3115.63 -6116.83 5946657.19 682538.13 6863.99 12.00 259.47 MWD 12750.00 90.28 197.88 8982.88 -3139.21 -6125.11 5946633.40 682530.44 6882.30 12.00 259.41 MWD 12763.73 89.97 196.27 8982.85 -3152.34 -6129.14 5946620.18 682526.74 6891.98 12.00 259.38 12 12775.00 88.91 195.43 8982.96 -3163.18 -6132.22 5946609.27 682523.94 6899.75 12.00 218.00 MWD 12800.00 86.54 193.58 8983.96 -3187.36 -6138.48 5946584.94 682518.29 6916.55 12.00 218.01 MWD 12825.00 /84.19 191.72 8985.98 -3211.67 -6143.94 5946560.50 682513.44 6932.70 12.00 218.08 MWD 12850.00 81.83 189.85 8989.02 -3236.04 -6148.58 5946536.02 682509.41 6948.17 12.00 218.23 TD . BP-GDB Anticollision Report . ~~~- 1216.00 2711.00 11020.00 12850.00 1215.99 2710.96 8753.61 9053.02 20.000 13.375 9.625 2.875 26.000 17.500 12.250 3.750 20" 133/8" 9 5/8" 2 7/8" Plan: Plan #10 Identical to Lamar's Plan #10 Principal: Yes Date Composed: Version: Tied-to: 5/18/2004 1 From: Definitive Path Snmmary PB DS 02 02-06 02-06 V3 11020.00 11020.00 0.01 0.00 0.00 Pass: NOERRORS PB DS 02 02-06 02-06A V4 11020.00 11020.00 0.01 0.00 0.00 Pass: NOERRORS PB DS 02 02-25 02-25 V1 Out of range PB DS 07 07-02A 07-02A V1 12612.35 12070.00 854.88 281.28 573.60 Pass: Major Risk PB DS 07 07-19 07-19 V1 Out of range PB DS 07 07-19A 07-19A V1 Out of range Site: PB DS 02 Well: 02-06 Rule Assigned: NOERRORS Wellpath: 02-06 V3 Inter-Site Error: 0.00 ft 11020.00 8753.61 11020.00 8753.61 36.24 37.56 261.78 0.00 9.625 0.01 0.00 0.00 Pass 11029.98 8760.26 11030.00 8760.01 36.35 37.71 264.26 2.48 9.625 0.34 0.00 0.34 Pass 11039.90 8767.32 11040.00 8766.42 36.43 37.83 263.85 2.07 9.625 1.30 0.00 1.30 Pass 11049.75 8774.58 11050.00 8772.84 36.49 37.94 263.97 2.19 9.625 2.63 0.00 2.63 Pass 11059.49 8781.99 11060.00 8779.27 36.55 38.04 264.13 2.35 9.625 4.28 0.00 4.28 Pass 11069.12 8789.52 11070.00 8785.71 36.61 38.15 264.27 2.49 9.625 6.26 0.00 6.26 Pass 11078.61 8797.13 11080.00 8792.15 36.66 38.25 264.39 2.61 9.625 8.55 0.00 8.55 Pass 11087.95 8804.80 11090.00 8798.60 36.72 38.35 264.50 2.72 9.625 11.15 0.00 11.15 Pass 11097.11 8812.50 11100.00 8805.07 36.77 38.44 264.59 2.81 9.625 14.05 0.00 14.05 Pass 11106.11 8820.20 11110.00 8811.56 36.82 38.54 264.69 2.91 9.625 17.21 0.00 17.21 Pass 11114.93 8827.89 11120.00 8818.08 36.86 38.63 264.79 3.01 9.625 20.63 0.00 20.63 Pass 11123.81 8835.76 11130.00 8824.64 36.91 38.72 264.85 3.52 9.625 24.28 0.00 24.28 Pass 11133.88 8844.64 11140.00 8831.23 36.97 38.83 264.97 6.00 9.625 27.82 0.00 27.82 Pass 11144.16 8853.55 11150.00 8837.85 37.03 38.93 265.42 8.62 9.625 31.05 0.00 31.05 Pass 11154.61 8862.45 11160.00 8844.51 37.09 39.03 266.16 11.33 9.625 33.99 0.00 33.99 Pass 11165.21 8871.29 11170.00 8851.20 37.14 39.12 267.12 14.11 9.625 36.63 0.00 36.63 Pass 11175.92 8880.02 11180.00 8857.92 37.19 39.21 268.32 16.97 9.625 38.99 0.00 38.99 Pass 11186.72 8888.61 11190.00 8864.68 37.23 39.29 269.73 19.92 9.625 41.07 0.00 41.07 Pass 11197.55 8896.99 11200.00 8871.46 37.26 39.36 271.38 22.97 9.625 42.90 0.00 42.90 Pass 11208.39 8905.14 11210.00 8878.28 37.29 39.43 273.25 26.15 9.625 44.49 0.00 44.49 Pass 11219.19 8913.01 11220.00 8885.13 37.31 39.48 275.38 29.47 9.625 45.88 0.00 45.88 Pass 11229.93 8920.56 11230.00 8892.01 37.32 39.53 277.75 32.95 9.625 47.10 0.00 47.10 Pass 11240.56 8927.78 11240.00 8898.92 37.33 39.57 280.39 36.62 9.625 48.19 0.00 48.19 Pass 11251.05 8934.63 11250.00 8905.86 37.33 39.60 283.28 40.47 49.21 0.00 49.21 Pass 11261.38 8941.10 11260.00 8912.81 37.32 39.62 286.40 44.47 50.22 0.00 50.21 Pass 11271.52 8947.19 11270.00 8919.74 37.31 39.63 289.72 48.62 51.28 0.00 51.28 Pass Nordic 1 bighole All Measurements are from top of Riser 5/17/2004 ~ CD CJ) a: top of bag BAG 7 1/16" 5000psi bttm of bag middle of slips Blind/Shears .......................... middle of pipes TOTs .....................·····7 1/16" 5000psi middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi middle of blind/shears .......................... middle of pipe/slips TOTs .....................·····7 1/16" 5000psi Flow Tee . . TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 106 "Mastercard Check" C"" "-. I F? DA TE J-) ,- -> ,,(.)(,,/ ...,,,/ it I . , / PAY TO THE \'<"þ;-. -61... /i' 1\ (1" .' ¡ ·0' t:':c.' ,1") $ J. 'lv'') ¿x:.;, ORDER OF ~·~-'-"'-L~· \J '-- L.AJ . i/\. ~ D \/'i () 0)., ..H·---~--" l )\,\Q ~ ~AV )ì1J /\/ ('rv'- ./ I OtT--~-"-'---'''''=-'~==~'--ÕO[LARS - ' -- '-- ~.......... - ~.,. First National Bank Alaska Anchorage, AK 99501 O/~ ~,., () . .p. - - ~ MEMO ì l::-) rQ" fj) ~IJ /i ,/ 'AJlú!. Ö~.-' 'tJ-(i? .' I: ~ 25 2000(;OI:qq ~~III(; 22 7111 ~ 5 5(;11- 0 ~O(; . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /¿;4 02-Òbt PTD# 2o<¡-oç'S ~ Development Service Exploration Stratigraphic CHECK WBA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing weD . Permit No, API No. . (If API Dumber ProductioDshould continue to be reported as last two (2) digits a function' of the original API number. stated are betweeD 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(1), an (PH) records, data aDd logs acquired for the pilot bole must be dearly differentiated In both name (Dame on permit plus PH) and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater -than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iliter:vals through target zones. o o Well bore seg Annular Disposal ~~ Program DEV On/Off Shore 11ß5Q Well Name: PRUDHOE_SAY UNIT 02-06B DEV /1-0IL GeoArea 890 Unit . Sidetrack. CTDU. 5/1 a/20M. Sidetrack. Max. MW8~ I PP9c . MS~ 2320 P$i._ Test to 3500_ psi Ye$ Ve$ _Y~$ Ve$ Y~$ Ve$ Y~s Y~s Y~s .Y~s Y~s Y~s Yes NA _NA NA NA NA NA NA NA Yes Y~s Ve$ Y_es Y~s NA Yes Y~s Y~s _Y_es _ Y~s_ No NA __ Initial ClassfType 640150 PRUDHOE BAY, PRUDHOE OIL INC Field & Pool P~rmit fee attached leas~ number _appropri¡¡te n_arn~_a!ld OLlmb_er .U_n[que welt Wel JQc¡¡t~d in_a_define_d_ppol Wel JQc¡¡t~d pr_operd[stançe from driJling unit WeIUQc¡¡t~d proper .d[stance_ from otber welJs boundary indriIJio9 Llnjt incJuded _S_utficient J(d~viated _Operator only- affected party _Operator bas_apprppr[ate_ bond [nJorce P~rmit P~rmit acreageavail¡¡ble js_ weJlbQre plat ~a!l be issued withQut co_nservation order ~ao be iSSLled wjtbQut ad_ministrative.apprpvaJ t be approved before 15-day wait Can perm in_comm_e!lts) (For # (put 10# servjc~ well only) _ _ _ than:3 months (For _service well QnJy) Well JQc¡¡ted within area and_strat¡¡authorized by Injectipo Ord_er _AJlwelJs.within 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Administration Date 5/19/2004 Appr RPC _1l4J1JiIß_are_a_of review øuratiQn_of pre-proøuGlipn tess_ ~çMPFinding _of Consistenc;yh_as been Jssued_ forJbis prpjeçt 18CÞnductor string_prQvided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 119 _Sm"fac~ca$ingprote~ts aiL known USDWs _ 120 _CMT VÞI adeQu_ate_ to circulate_ on _conductpr 8. $urf csg 21 _CMT vol adeQuateJo tie-in IQng _stri!lg to surf ~g 22 CMTwilJ c;overa)l koownpro_duc;tive bQri;¡:ons id~ot[fied (Fpr injector Pre-p rod UQ3d Engineering Casing desig!ls adeQuate for C,T, B _&_ Rermafr_ost Aøequate tankage_or reserve pit be~!l ¡¡PPJQved -'tare-drill, has a 10c4_03 fOJ ¡¡bandonment _Aøequate_we)lbore separ¡¡tjo_n_proposed t meet reguJations_ Ifdiverter req).lired, dQes list adequate _Drilling fJujd_prQgram $~hematic_& equip BOPEs, do they meet reguJaJion ,~ r~"':....n ~nl.\rt'\nr:"."'o.' _test to -<puJ Choke man 'I IR~-53 (May 84) psig in_comments) !,",,_I.I'_':1 ~1""''''''!.''''-f''''._I~L'\õi _B_OPEpres" WQrk Wi1l pccur Js presence_ Qf L MechanicaLcPI ditio!l PfWellS within ,A.OR verified (fpr_ operation shutdown 23 24 25 26 27 28 29 30 31 32 33 34 Date 5/20/2004 Appr WGA servjceW!'!1J onlY-) .-IZS gas prQbable No NA NA NA P~rmit ~a!l be iSSLled '1110 hydrogen s_ulfide meas_ures _D_ata_preseoted on_ pote_ntial pveJPres_suœ _Zones 35 36 37 38 39 Geology Appr RPC _S_eismic_analysis_ Qf sbaJlow gas_zpnes (if of{ -s hwe) we!'!kly prpgressreports Date namelphon_eJor Engineering Commissioner _S!'!abedcondjtipo survey CQntact Date: Date 5/19/2004 Geologic Commissioner: e e 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 infonnation, 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 infonnation. e e dOc/é)q~ Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 28 15:24:39 2005 # fJ..-q~' Reel Header Service name.. . . . . . . . . . . .LISTPE Date. .... . . . ......... .. . .05/01/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ... . . . . . . . . . . . UNKNOWN Continuation Number..... .01 Previous Reel Name.. .....UNKNOWN Comments.. ............. ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.. ... . . . . . ......... . .05/01/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # WELL CASING RECORD 1ST STRING 2-06B 500292008602 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 28-JAN-05 MWDRUN 3 MWDRUN 5 MWD RUN 6 MWOO03093399 MWOO03093399 MWOO03093399 BUD JAHN BUD JAHN BUD JAHN KOLSTAD / HO LAULE / WHIT LAULE / WHIT MWDRUN 7 MWDRUN 8 MWD RUN 9 MWOO03093399 MWOO03093399 MWOO03093399 BUD JAHN BUD JAHN BUD JAHN LAULE / WHIT LAULE / WHIT LAULE / WHIT MWD RUN 10 MWD RUN 11 MWD RUN 12 MWOO03093399 MWOO03093399 MWOO03093399 BUD JAHN BUD JAHN BUD JAHN LAULE / WHIT LAULE / WHIT LAULE / WHIT 36 UN 14E 1300 1815 64.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.800 9.625 11022.0 · e 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. MWD RUNS 1 - 7 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. A CEMENT 'RAMP' WAS DRILLED DURING RUNS 1 & 2. THE WINDOW WAS MILLED ON RUN 3, AND 2' OF NEW HOLE WERE ALSO DRILLED. THE TOP OF THE WINDOW WAS 11022' MD AND THE BOTTOM WAS 11028'MD. THE PURPOSE OF RUN 4 WAS DRESS THE WINDOW - NO DATA WERE ACQUIRED. RUNS 5 - 7 DRILLED THE BUILD SECTION. 4. MWD RUNS 8 - 12 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4). RESISTIVITY DATA FOR THE OPEN-HOLE INTERVAL ABOVE RUN 8 WERE ACQUIRED WHILE RIH FOR RUN 8. THESE MAD DATA WERE MERGED WITH THE MWD DATA FOR RUN 8. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER CCNL GAMMA RAY LOG RUN IN 2-06B ON 2 JUNE 2004. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED VIA E-MAIL BY WALTER TIFENTAL (SIS/BP) ON 20 JANUARY 2005. 6. MWD RUNS 1 - 12 REPRESENT WELL 2-06B WITH API#: 50-029-20086-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13081'MD/9009'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name. ..... ...... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/01/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: 1 and clipped curves; all bit runs merged. .5000 # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ e START DEPTH 10471. 0 11001.0 11001. 0 11001.0 11001.0 11001.0 11021.5 e STOP DEPTH 13034.0 13048.0 13048.0 13048.0 13048.0 13048.0 13080.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10471.0 10473.0 10489.5 10501.5 10512.5 10525.0 10529.0 10531.5 10539.0 10543.5 10550.0 10554.5 10579.0 10582.5 10584.5 10587.5 10589.0 10592.0 10614.0 10619.5 10627.0 10640.0 10644.0 10650.0 10652.5 10657.0 10666.5 10671.5 10675.0 10680.5 10682.5 10687.0 10693.5 10697.0 10700.5 10717.5 10720.0 10749.5 10758.5 10761.0 10764.0 10769.5 10779.5 10799.5 10812.0 10819.5 10844.0 10853.5 10858.0 10872.0 10884.0 10894.5 10902.0 10916.0 10920.0 10930.0 10955.5 10961.5 10970.5 10983.5 GR 10471.0 10473.0 10487.0 10500.0 10509.5 10525.5 10528.5 10532.5 10539.0 10544.5 10550.0 10553.5 10578.5 10582.0 10584.5 10587.0 10589.0 10591.5 10613.0 10617.5 10627.5 10639.5 10643.5 10650.0 10653.0 10657.0 10667.5 10672.0 10674.5 10680.0 10681.5 10686.5 10693.0 10697.0 10700.0 1071 7.0 10718.5 10748.0 10756.0 10759.0 10762.5 10768.0 10776.5 10799.0 10812.5 10820.5 10845.0 10855.0 10857.5 10871.0 10882.0 10891.5 10900.0 10915.0 1091 7.5 10929.0 10953.5 10959.0 10969.0 10982.0 11004.5 11008.0 11022.5 11028.0 11033.0 11037.5 11039.0 11041.5 11046.0 11051.0 11056.5 11066.0 11073.0 11077.5 11079.5 11088.5 11109.0 11133.0 11154.5 11157.5 11160.5 11183.5 11186.0 11194.0 11197.0 11202.0 11211.5 11218.5 11238.5 11252.0 11265.5 11269.5 11275.0 11276.5 11280.0 11285.0 11297.5 11299.5 11303.0 11317.0 11332.5 11336.0 11345.0 11357.0 11373.5 11375.0 11377.0 11399.5 11406.0 11454.5 11458.0 11474.0 11527.0 11543.5 11558.5 11568.5 11595.5 11613 . 0 11617.0 11627.5 11634.0 11647.0 11663.5 11674.0 11687.5 11715.5 11740.0 11744.5 11751.5 11755.5 11761.5 11767.0 11794.0 11799.5 11807.5 11809.0 e e 11004.5 11007.0 11022.0 11028.0 11031.0 11035.5 11037.5 11040.0 11043.0 11050.0 11054.5 11064.0 11072.0 11075.5 11077 . 0 11085.5 11108.0 11131.0 11152.5 11153.5 11158.0 11181.0 11183.0 11189.5 11193.5 11197.5 11208.0 11215.0 11239.0 11251.5 11265.0 11269.0 11274.0 11275.5 11279.5 11284.5 11296.5 11298.0 11302.5 11316.0 11332.0 11337.0 11345.0 11357.0 11374.0 11375.5 11377.0 11398.5 11405.5 11454.5 11456.5 11472.0 11528.0 11544.0 11560.5 11570.0 11596.0 11615.0 11618.5 11627.0 11631.5 11646.5 11661.5 11673.0 11684.5 11715.0 11736.0 11740.5 11746.0 11751. 5 11758.0 11 764.0 11789.5 11794.0 11802.0 11804.0 11820.0 11844.5 11853.0 11863.5 11870.5 11879.5 11889.5 11895.0 11906.0 11920.5 11940.0 11964.0 11975.0 11992.0 12025.5 12113.0 12121.5 12143.0 12156.0 12165.5 12172.5 12206.0 12223.5 12247.5 12256.5 12291.0 12313 . 0 12318.0 12324.0 12327.5 12334.0 12337.5 12346.0 12349.5 12360.0 12364.0 12370.0 12386.0 12424.5 12445.5 12458.5 12460.5 12469.5 12489.0 12497.5 12505.5 12516.0 12531. 5 12546.5 12587.5 12614.0 12625.5 12653.0 12680.5 12685.0 12743.5 12780.5 12829.5 12850.0 12853.5 12855.5 12860.5 12881. 5 12893.0 12910.5 12928.5 12933.0 12946.5 12952.5 12957.0 12959.0 13080.0 $ # MERGED DATA SOURCE PBU TOOL CODE . 11815.0 11845.5 11855.0 11861.0 11868.0 11878.5 11888.5 11897.0 11905.0 11921.5 11936.0 11965.0 11974.5 11992.0 12025.5 12107.5 12116.0 12141.5 12153.0 12160.0 12165.5 12204.5 12218.0 12244.5 12254.0 12298.5 12317.5 12323.0 12329.5 12332.0 12338.0 12344.0 12352.0 12354.5 12365.5 12370.0 12376.0 12388.0 12427.0 12447.5 12464.0 12465.5 12475.5 12494.0 12500.5 12507.0 12518.5 12537.5 12553.0 12584.0 12610.0 12623.5 12650.0 12675.5 12681.0 12739.5 12776.0 12827.5 12849.5 12851.5 12853.5 12859.5 12878.5 12891.5 12909.5 12929.5 12935.0 12948.5 12953.0 12958.5 12960.0 13081. 0 BIT RUN NO MERGE TOP e MERGE BASE e e MWD MWD MWD MWD MWD MWD MWD MWD MWD $ 3 5 6 7 8 9 10 11 12 10471.0 11030.0 11091.5 11260.0 11470.0 11657.0 11863.0 12300.0 12750.0 11030.0 11091.5 11260.0 11470.0 11657.0 11863.0 12300.0 12750.0 13081.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type. ........ ....... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point... ...... .... .Undefined Frame Spacing..................... 60 .1IN Max frames per record......... ... .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10471 13080 11775.5 5219 10471 13080 ROP MWD FT/H 0.07 3905.86 77.3271 4118 11021.5 13080 GR MWD API 17.24 238.26 43.278 5127 10471 13034 RPX MWD OHMM 1.1 2000 19.6792 4095 11001 13048 RPS MWD OHMM 0.42 2000 27.9927 4095 11001 13048 RPM MWD OHMM 0.1 2000 34.616 4095 11001 13048 RPD MWD OHMM 0.03 2000 44.4734 4095 11001 13048 FET MWD HOUR 0.25 77.51 7.26939 4095 11001 13048 First Reading For Entire File.... ..... .10471 Last Reading For Entire File... ..... ...13080 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/01/28 Maximum Physical Record. .65535 File Type.. . . . . ......... .LO Previous File Name...... .STSLIB.001 e Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 3 .5000 START DEPTH 10471.0 11021.0 STOP DEPTH 11000.5 11030.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .... ......... ....0 Data Specification Block Type. ....0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ..... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record.... .........Undefined Absent value.... . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 26-MAY-04 Insite Memory 11030.0 10471.0 11030.0 49.0 51. 0 TOOL NUMBER TLG016 3.800 2711.0 KCL Water 8.30 .0 .0 o .0 .000 .000 .000 .000 .0 137.5 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 e e GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10471 11030 10750.5 1119 10471 11030 ROP MWD030 FT/H 0.69 7.82 2.76684 19 11021 11030 GR MWD030 API 18.76 238.26 45.5218 1060 10471 11000.5 First Reading For Entire File..........10471 Last Reading For Entire File.. ........ .11030 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......05/01/28 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Next File Name... ....... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 File Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 11001.0 11030.5 STOP DEPTH 11061.0 11091.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-MAY-04 Insite Memory 11091.0 11030.0 11091.0 38.9 50.2 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG016 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 2711.0 # BOREHOLE CONDITIONS MUD TYPE: Flo Pro e tit MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.60 60.0 9.4 21000 6.0 .000 .000 .000 .000 .0 141.7 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .. . . . . .... . . .0 Data Specification Block Type.....O Logging Direction......... ........Down Optical log depth units.......... .Feet Data Reference Point...... ...... ..Undefined Frame Spacing........ ............ .60 .1IN Max frames per record..... ........Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11001 11091. 5 11046.3 182 11001 11091. 5 ROP MWD050 FT/H 0.07 60.36 17.9073 123 11030.5 11091.5 GR MWD050 API 22.76 131.85 40.7691 121 11001 11061 First Reading For Entire File..........11001 Last Reading For Entire File.......... .11091.5 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name. ......... .STSLIB.004 Physical EOF File Header Service name........ .....STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 File Type. . . .... . . . . . . . . .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER e FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 6 .5000 START DEPTH 11061.5 11092.0 STOP DEPTH 11231.0 11260.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ..... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value.... . . . . . . . . . . . . . . . . . . -999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Rep 68 68 68 Code Units FT FT/H API Size 4 4 4 Nsam 1 1 1 MWD060 MWD060 28-MAY-04 Insite Memory 11260.0 11091. 0 11260.0 34.8 46.7 TOOL NUMBER TLG016 4.125 2711.0 Flo Pro 8.60 65.0 9.3 21000 6.0 .000 .000 .000 .000 .0 141.5 .0 .0 Offset o 4 8 Channel 1 2 3 e e First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11061.5 11260 11160.8 398 11061.5 11260 ROP MWD060 FT/H 0.07 1144.2 40.3876 337 11092 11260 GR MWD060 API 19.37 50.55 23.7769 340 11061.5 11231 First Reading For Entire File........ ..11061.5 Last Reading For Entire File.......... .11260 File Trailer Service name... ......... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......05/01/28 Maximum Physical Record..65535 File Type.. . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name......... ....STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. . . . . . .05/01/28 Maximum Physical Record. .65535 File Type. ............. ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 11231.5 11260.5 STOP DEPTH 11439.5 11470.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 28-MAY-04 Insite Memory 11470.0 11260.0 11470.0 57.5 73 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG016 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 2711.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): Flo Pro 8.60 65.0 e tit MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.3 21000 6.0 .000 .000 .000 .000 .0 145.9 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units...... .... . Feet Data Reference Point..... .........Undefined Frame Spacing..................... 60 .1IN Max frames per record........ .... .Undefined Absent value... . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD070 MWD070 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11231. 5 11470 11350.8 478 11231. 5 11470 ROP MWD070 FT/H 13 .99 180.9 106.315 420 11260.5 11470 GR MWD070 API 17.24 140.4 35.5947 417 11231.5 11439.5 First Reading For Entire File... .......11231.5 Last Reading For Entire File. ..........11470 File Trailer Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...05/01/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name........ ...STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 File Type. . .... . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD e e header data for each bit run in separate files. 8 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH 11000.5 11000.5 11000.5 11000.5 11000.5 11440.0 11470.5 STOP DEPTH 11625.5 11625.5 11625.5 11625.5 11625.5 11614.5 11657.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction. .......... ..... . Down Optical log depth units.......... .Feet Data Reference Point.... ..........Undefined Frame Spacing............ . . . . . . . . .60 .1IN Max frames per record. .......... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 29-MAY-04 Insite 4.3 Memory 11657.0 11470.0 11657.0 90.5 93.9 TOOL NUMBER 78012 158428 4.125 11348.0 Flo Pro 8.60 60.0 9.3 21000 6.0 .080 .035 .175 .185 60.0 147.1 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel e e DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11000.5 11657 11328.8 1314 11000.5 11657 ROP MWD080 FT/H 0.1 773.61 84.882 374 11470.5 11657 GR MWD080 API 23.65 45.89 36.67 350 11440 11614 . 5 RPX MWD080 OHMM 1.1 2000 27.6943 1251 11000.5 11625.5 RPS MWD080 OHMM 0.42 2000 54.4027 1251 11000.5 11625.5 RPM MWD080 OHMM 0.1 2000 71.6129 1251 11000.5 11625.5 RPD MWD080 OHMM 0.03 2000 91.3464 1251 11000.5 11625.5 FET MWD080 HOUR 0.38 77.51 19.1825 1251 11000.5 11625.5 First Reading For Entire File..........11000.5 Last Reading For Entire File.......... .11657 File Trailer Service name....... ......STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. . . . . . .05/01/28 Maximum Physical Record..6S535 File Type. . . . . . . . . . . . . . . . LO Next File Name. ..........STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...05/01/28 Maximum Physical Record. .65535 File Type.... . . . . . .. . ... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 7 header data for each bit run in separate files. 9 .5000 START DEPTH 11615.0 11626.0 11626.0 11626.0 11626.0 11626.0 11657.5 STOP DEPTH 11818.0 11831.5 11831.5 11831. 5 11831.5 11831.5 11863.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 29-MAY-04 Insite 4.3 Memory 11863.0 11657.0 e BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type. ....0 Logging Direction.......... ...... .Down Optical log depth units....... ... .Feet Data Reference Point...... ....... .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 11863.0 89.6 93.7 TOOL NUMBER 78012 158428 4.125 11348.0 Flo Pro 8.60 65.0 9.0 21000 5.8 .080 .040 .175 .185 70.0 147.1 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11615 11863 11739 497 11615 11863 ROP MWD090 FT/H 0.51 157.47 65.1753 412 11657.5 11863 GR MWD090 API 27.7 106.27 45.6624 407 11615 11818 RPX MWD090 OHMM 5.16 17.72 8.53927 412 11626 11831. 5 RPS MWD090 OHMM 6.19 18.83 10.636 412 11626 11831.5 RPM MWD090 OHMM 7.12 22.08 12.2941 412 11626 11831.5 RPD MWD090 OHMM 8.87 30.56 16.6224 412 11626 11831.5 FET MWD090 HOUR 0.29 11.51 2.60546 412 11626 11831. 5 e e First Reading For Entire File...... ....11615 Last Reading For Entire File... ........11863 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. ......05/01/28 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Next File Name... ....... .STSLIB.008 Physical EOF File Header Service name........ .....STSLIB.008 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name... ....STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 8 header data for each bit run in separate files. 10 .5000 START DEPTH 11818.5 11832.0 11832.0 11832.0 11832.0 11832.0 11863.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): STOP DEPTH 12254.5 12267.5 12267.5 12267.5 12267.5 12267.5 12300.0 30-MAY-04 Insite 4.3 Memory 12300.0 11863.0 12300.0 77.8 94.0 RESIS. 4 TOOL NUMBER 78012 158428 4.125 11348.0 Flo Pro 8.60 65.0 9.5 25000 7.4 e e RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .110 .055 .080 .110 72.0 150.0 72.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... . Feet Data Reference Point...... ...... ..Undefined Frame Spacing....... ............. .60 .1IN Max frames per record............ . undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11818.5 12300 12059.3 964 11818.5 12300 ROP MWD100 FT/H 0.93 711.98 45.3859 874 11863.5 12300 GR MWD100 API 17.96 119.72 41. 3548 873 11818.5 12254.5 RPX MWD100 OHMM 6.09 46.39 14.4467 872 11832 12267.5 RPS MWD100 OHMM 7.27 47.93 16.9505 872 11832 12267.5 RPM MWD100 OHMM 7.79 44.8 18.3955 872 11832 12267.5 RPD MWD100 OHMM 10.18 46.17 22.3369 872 11832 12267.5 FET MWD100 HOUR 0.38 10.13 2.0367 872 11832 12267.5 First Reading For Entire File......... .11818.5 Last Reading For Entire File...... .... .12300 File Trailer Service name.... .........STSLIB.008 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation... ....05/01/28 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record..65535 e File Type.. . . . . . . . . . .. .. .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 9 e header data for each bit run in separate files. 11 .5000 START DEPTH 1,2255.0 1,2268.0 1,2268.0 1,2268.0 1.2268.0 1,2268.0 1.2300.5 STOP DEPTH 1,2705.0 1.271.8.0 1.271.8.0 1,271.8.0 1,271.8.0 1.271.8.0 1,2750.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ....... ...0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point........ ..... . Undefined 31,-MAY-04 Insite 4.3 Memory 1,2750.0 1,2300.0 1,2750.0 75.0 91.. 8 TOOL NUMBER 7801,2 1,58428 4.1,25 11348.0 Flo Pro 8.60 60.0 9.2 22500 6.0 .1,00 .038 .1,80 .110 55.0 1,56.0 55.0 55.0 e e Frame Spacing.................... .60 .1IN Max frames per record... ..........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWDll 0 FT/H 4 1 68 4 2 GR MWDllO API 4 1 68 8 3 RPX MWDllO OHMM 4 1 68 12 4 RPS MWDllO OHMM 4 1 68 16 5 RPM MWDllO OHMM 4 1 68 20 6 RPD MWDllO OHMM 4 1 68 24 7 FET MWDII0 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12255 12750 12502.5 991 12255 12750 Rap MWDllO FT/H 0.53 3905.86 95.4061 900 12300.5 12750 GR MWDllO API 19 167.17 52.2925 901 12255 12705 RPX MWDllO OHMM 5.03 69.38 20.7994 901 12268 12718 RPS MWDll 0 OHMM 5.39 62.12 21.8013 901 12268 12718 RPM MWDllO OHMM 6.07 88.52 22.5938 901 12268 12718 RPD MWDllO OHMM 10.41 104.4 28.6219 901 12268 12718 FET MWDllO HOUR 0.32 9.13 1.82528 901 12268 12718 First Reading For Entire File......... .12255 Last Reading For Entire File.......... .12750 File Trailer Service name. ........... .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.OI0 Physical EOF File Header Service name............ .STSLIB.OI0 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/01/28 Maximum Physical Record..65535 File Type. ..... . . . . . . . . . .LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET Rap $ 10 header data for each bit run in separate files. 12 .5000 START DEPTH 12705.5 12718.5 12718.5 12718.5 12718.5 12718.5 12750.5 STOP DEPTH 13035.0 13049.0 13049.0 13049.0 13049.0 13049.0 13081.0 # LOG HEADER DATA · e DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ..... ...0 Data Specification Block Type. ....0 Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point... ...........Undefined Frame Spacing.... .... ............ .60 .1IN Max frames per record............ . Undefined Absent value.... . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 01-JUN-04 Insite 4.3 Memory 13081. 0 12750.0 13081.0 82.1 90.6 TOOL NUMBER 78012 158428 4.125 11348.0 Flo Pro 8.70 65.0 9.3 33500 5.4 .070 .029 .130 .080 65.0 164.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD12 0 FT/H 4 1 68 4 2 GR MWD12 0 API 4 1 68 8 3 RPX MWD120 OHMM 4 1 68 12 4 RPS MWD120 OHMM 4 1 68 16 5 RPM MWD12 0 OHMM 4 1 68 20 6 RPD MWD12 0 OHMM 4 1 68 24 7 FET MWD120 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12705.5 13081 12893.3 752 12705.5 13081 ROP MWD120 FT/H 13 .68 1454.39 111.636 662 12750.5 13081 GR MWD120 API 22.26 91.72 46.0746 660 12705.5 13035 '" e e RPX RPS RPM RPD FET MWD120 OHMM MWD120 OHMM MWD120 OHMM MWD120 OHMM MWD120 HOUR 6.53 8.15 8.91 9.43 0.25 29.75 16.9402 662 12718.5 13049 29.12 18.0945 662 12718.5 13049 29.46 18.5777 662 12718.5 13049 35.11 23.1229 662 12718.5 13049 7.75 1.79861 662 12718.5 13049 First Reading For Entire File..... .....12705.5 Last Reading For Entire File... ....... .13081 File Trailer Service name. ........... .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name....... ....STSLIB.011 Physical EOF Tape Trailer Service name.. . . . . . . . . . . .LISTPE Date.......... .......... .05/01/28 Origin..... ............. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments....... ........ ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... ......... .LISTPE Date. .. . . . . . ... .. . . . . . . . .05/01/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Next Reel Name. ......... . UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File