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206-070
• STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIIIIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull Upper Straddle IBJ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 206-070 3. Address: P.O.Box 196612 Anchorage, Development IJ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21717-01-00 7. Property Designation(Lease Number): ADL 0034630 8. Well Name and Number: LISB L5-28A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: NECEI Total Depth: measured 12800 feet Plugs measured feet true vertical 8789 feet Junk measured feet JUN 2 3 2016 Effective Depth: measured 12800 feet Packer measured 10406 feet �-a true vertical 8789 feet Packer true vertical 8550.56 feet J O G CC Casing: Length: Size: MD: TVD: Burst: Collapse: LJ Structural Conductor 79 20"91.5#H-40 41 -120 41-120 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate Production 10685 7-5/8"33.7#L-80 39-10723 39-8817 7900 6560 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10726-12800 feet True vertical depth: 8819-8789 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-10452 37-8589 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"HES TRSSSV 1983 1983 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 0 7 206 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: 334 3843 1285 1700 649 Subsequent to operation: Shut-In 1000 0 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations fl Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 6._____,_--_-_-0-- g �_ Phone +1 907 564 4424 Date 6/22/16 Form 10-404 Revised 5/2015 r VL 7-/c/P‘.. RBDMS L.v JUN 2 4 2016 Submit Original Only • • m OO = CD OD QD d' O O 00 M M OD 00 00 0 N N O N- c N- U 1; 0 0 0 0 0 0 0 0 0 CO O M O O M 7 V O N O M M m r M lj) I- 00 00 O I- r- O 00 O O O CO v- .- O O OO N O O CO CO I� CO to M CO CO CO CO CO CI i I I I i I-' CO CO CO O 6) N- 00 6) f- t V O M O N- N- 00 00 00 AN, C O M M O M N N N- T- 0 0 0 0 0 V r V- 0 C) Cl i I I i i i I .- CO O V) < N 0 OD CD 0 0 C)it) N V O M O O O M C _J _a m H J o CI 000 0 0 Y . cccc CO J J J J J 4t Li) N- O O CO CO N _N O ° O 06 CV `- CV U 00 O M M N CO 00 00N N O ,- O O r- Nr N N CD ir) O C O ON 00 O co C) N Nr O QD C O Ct Z a,0 O W W H UU co « CD U0ILWoZ Z c O W W W m O D D Z Z_ Z_ D UcncndJJJ � • 0 Packers and SSV's Attachment LISB L5-28A SW Name Type MD TVD Depscription L5-28A SSSV 1983.11 1983.01 4-1/2" HES TRSSSV S L5-28A TBG PACKER 10406.44 8550.56 4-1/2" Baker S-3 Hydro Set Packer L5-28A PACKER 10451.22 8587.97 5-1/2" Baker ZXP Hydro Set Packer L5-28A 5 8A PACKER 10695 8792.79 2-7/8" Baker KB Packer . ` • • f I z k 13 D 0 92 0 O o a) 2 0 G S i- \ k m \< f -c / ƒ 0 \ I z-e - > U > / a) co 0 / ¢ I § % LU ƒ k 0) \ / O Cl) ƒ § Icu * I a / cm.c -J / m W m 0 % k E / b q. m 2 $ p a) c m a / C ® m a. • 0 < N- L CO 2 ,5 70 - / 2I- 2 / it E C < R E $ ECR I 0 0 E e @ / p \ 0 o < N. k \ / Z O « / $ / \ U— \ / / / _TD q / � / / AEE < pc ƒ � 2p3 \ \\ \ / 0 \ < ƒ o O i 8 ( F G U \ / Q tn / E o b a O > 0 � � O < / \ a) \ ƒ g ƒ ƒ $ ƒ 0 � \ / 9 \ z22 $ } k \ \ Ce - m q < r < I @ E O \ / � $ / E0 ° \ wf RS » � ® » � � � N' / « ^6 % \ CI ± ± ± \ ± a < h k 9 < 7 / E / —/ ƒ ± ± E / % - 0 < 0 < w Z .� / ? \ / / / 0 % 2 –1 / / \ \ I- / / / / \ SE / \ L w w 6 2 7 2 R E a .@ R u e / < < < / 3 \ / < \ 0 3 - k t ± ± t < : O E a f 0 / i : 5 ± / % / % \ / \ / / - 2 N- \ \ I \ r @ r < TREE= 4"`M/ Ill L5-28A _` "' "'''� NOTES:WELL ANGLE>-70"L 10805'. WELFEAD= FMC ACTUATOR= AXELSON L5-28AL1 OKB.ELEV= 60' BF EI.EV= KOP= 2600' Max Angle= 98'@ 10958' I 1983' —{4-1/2"HES 1NELLSTAR IFLSSSV,D=3.813" Datum MD= 10788' Datum ND= 8900'SS GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,L-80,D=9.953" -E 4194' A k 5 2795 2790 14 KGB2 DOME BK 16 06/23/06 4 5180 4690 39 KGB2 DOME BK 16 06/23/06 3 7607 6402 47 KGB2 DOME BK 16 06/23/06 2 9121 7515 39 KGB2 SO BK 24 07/09/15 Minimum ID = 3.813" @ 1983' I 1 10309 8469 33 KGB2 DM" BK 0 07/09/15 4-1/2" HES WELLSTAR TRSSSVJ , 10376' —Ia-l/rHES xMP,El=3.813" ►� ��� 10397' H 7-5/8"X 4-1/2'BKR S-3 PKR,D=3.958" I 10421' --14-1/2"HES X tom,D=3.813" 10430'JH BOT 7-5/8"X 5-1/2'ZXP PBR,ID=4.90" 4-112"TBG,126#,L-80,.0152 bpi,D=3.958"'1— 10443' I ,-1 !N 10441' 1 BOT ZXP Lt\Ft TOP PKR ��41 11 10443' --IBOT 4-1/2"WLEG ,•41.10141 10448' HBOT HCM 7-5/8"X 5-1/2"LM HGR •114 1111 •I•j X141 10454' -H4-v2"x 5-1/2"xo 114* 1111 11 •�1111 X111 3-3/8"MLLOUT WINDOW(L5-25AL1) 10684'-10697' 14 11•1 1 0/4* X111 4* �4` L5-28AL1 Barefoot Completion, 3.0" X41 11 /1/4 '/1/ BKR KB WS FKR,ID=2.35" 1--f10695' 11' 11 T0D __ j•/•III �•A' { 12535' 2-7/8"XN NP,ID=2.313" H 10705' .144 X111 w/POLISHED BORE NO-GO,D=2.205" 111• X114 A.A. 4�1• 3-3/8"MLLLOUT WINDOW (L5-25A)10714'-10726' BAKERWHPSTOCK --I10717' 1y'', 114 RA TAG— 10723' •••, ;, 144 4. I, 441 IIN II L5-28A Barefoot Completion,D=3.0" •/4 44 41 ►1/ N4 11 X44 /1' ;at 1111 PBTD 10749' 4.01••�•�,1•44 4 TD H 12800' 4144141414 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" J 10787' iiii141 4 • i�411,11/ . :.4114. . : 11120' —PRONG FROM PXN PLUG111•.1111A4 IIIktII. SET @ 10702',LOST 02/14/93 PBTD H 11177• 1.1.1.1.1.1.1.1.1.1.1• 1111111141411111414141 1141414141414441414141 7-5l8"CSG,33.7#,L-80,D=6.765" H 11268' M.A.A1A1A1AW DATE I REV BY C0Pf NTS DATE REV BY COMMENTS LISBURNEUNT 05/31/871 ORIGINAL COMPLETION 06/09/16 WS/JMD PULLED LTPw/SLD SLV&X LOCK WELL: L5-28A 02/14193 WORK OVER _ PERMIT PT Nb: 2060700(710) 07/28/06 NORDIC i RWO/CTU ARNo: 50-029-21717-01 (60) 03/05/16 MAS/TLH DATUM ND CORRECTION(06/10/15) SEC 1,T11 N,R15E,2148'FSL&29'FWL 03/05/16 TBD/TL.H PULL U PER ISO SLV(02/05/16) 03/16/16 DJS/JMD SET LIP w/SLDSLV&X LOCK BP Exploration(Alaska) STATE OF ALASKA • *ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set LTP w/Mingle Sleeve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-070 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21717-01-00 7. Property Designation(Lease Number): ADL 0034630 8. Well Name and Number: LISB L5-28A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12800 feet Plugs 9 measured feet MAR 31 2016 true vertical 8789 feet Junk measured feet Effective Depth: measured 12800 feet Packer measured 10406 feet AO G CC true vertical 8789 feet Packer true vertical 8550.56 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 41 -120 41 -120 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate Production 10685 7-5/8"33.7#L-80 39-10723 39-8817 7900 6560 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10726-12800 feet 1i i� 16 True vertical depth: 8819-8789 feet feet r U Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-10452 37-8589 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"HES TRSSSV 1983 1983 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: 334 3843 1285 1700 649 Subsequent to operation: Shut-In 1000 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature "lict,,,t1_ Phone +1 907 564 4424 Date 3/31/16 Form 10-404 Revised 5/2015 VTL 4/1 Z A `L V/21/1 RBDMS LV APR 0 1 2016 Submit Original Only • • a) N o • � rn000c000cocoo o v cn sLn O 'sr N N U • O o 0 0 0 0 0 0 i O) Co r O c') • V LC) N O m r M LC) 1,- Co CO O 1"-- CO CO O N 0 CO r r 0 0 CO O O CO CO N- CO LC) CO CO CO CO CO CO i H CO N CO r r CO 6) N- CO O N- CO CO CO in CO CO O CO N E O N N O N � I� (` O � � V r 0 0 0 0 0 r r r r r v o (13 ....4• E I I I I I I I I Q N cornvco0, C))LO vmMo00 <) r r r Jo ,`i coCocos, 00 Y J J J J J J N LLO *j L() Ln CSO CSO . r co r O U `� - - - - - a0 N 00 aO N O co co 'co- c.16 O I� V N N r r rn Ln co O L(� C O N CO r co • , co (.1 r O Z 0)O _O • Lu W H U0 0C6 DU UOLLLOca. aZ Z Q O W W W pp O D D a Z Z_ Z_ J 0 co co d J J J I- • • Y Y U O Cdal _ O Y �+ O LO (00 N ID %> a a U N O d _ J Cti d. 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ItT� 10397' H7-5/8"X4-1/2"BKR S-3 PKR,D=3.958' ' 10421' —14-1/2"HES X NP,D=3.813" 10430' —1130T 7-5/8"X 5-1/2"ZXP EBR,D=4.90'n 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 1— 10443• * �� 10441' —BOT ZXP LNR TOP PKR 1 .�1 4. 10443' HBOT4-1/2"WLEG ;1�1 01 10448' --I BOT HCM 7-5/8"X 5-1/2"LM HGR 45 KB BKR LTP,ID=2.31"(03/12/16) --1 10667' 011 11 .111 1111 10454' —4-1/2"x 5-1/2"x0 '747,4.."-i . 1111 2-7/8"BKR CMD SLD SLV HES X PROFLE —1 10677' ' '717►i �► i'.1/1 (ID=2.31")w/ORIFICE SUB NSTALLED iQ 1111 3-3/8"MLI LOUT WINDOW(L5-25AL1) 10684'-10697 (2-.188"PORTS),D=1.25"(03/12/16) i1� •♦�/ 1 0111 4.4. 4 L5-28AL1 Barefoot Completion,D 3.0" 1 11t 0.1 BKR KB WS PKR D=2,35" — 10695' !1• ♦ ♦11111 1D — 12535' , 2-7/8"XN NP,ID=2.313" — 10705' t�4d 111 ri 111 w/POLISHED BORE NO-GO,ID=2.205" i1� 11.1 111 1111 3-3/8"MLLOUT WPIDOW (L5-25A) 10714'-10726' BAKERVVFIPSTOCK —1 10717' 1 11# RA TAG — 10723' ,1'10 r ,11 011 •1�1�t L5-28A Barefoot Completion,0=3.0" X11 111 4. 1111. ,111 0111 PBTD --f 10749' 4!.4,,,, 1111 TD H 12800' 11.11111401. ��1....i.�.i.4.111 4-1/2"LNR 12.64,L-80,.0152 bpf,0=3.958" H 10787 ,�������1.11/1` �1/111i���'11.1.1 .1111/1111�..`I'1'1'1 11120' —PRONG FROM PXN PLUG . .10. SET@ 10702',LOST 02/14/93 PBTD -1 11177 1.1'1'1'1'1'1'1'1'1'1' 1111111111111111111111 1111111111111111111111 7-5/8"CSG,33.7#,L-80,D=6.765" H 11268' i1I iAiII.w.61i1w.Ii1. DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 05/31/87 ORIGINAL COMPLETION 01/03/00 JKJ PJC GLV CORRECTIONS(06/23/06) WELL. L5-28A 02/14/93 WORK OVER 07/31/15 GJF/JMD GLV C/O(07/09/15) PERMIT No 2060700(710) 07/28/06 NORDIC's RWO/CTU 03/05/16 MASRLH DATUM TVD CORRECTION(06/10/15) AR No: 50-029-21717-01(60) 04/02/08 GJF/PJC SET ISO SLEEVE(03/17/08) 03/05/16 TBD/TLH RLL UPPER ISO SLV(02/05/16) SEC 1,T11N,R15E,2148'FSL&29'FWL 11/27/09 DMS/SV PULL I 111(11/24/09) 03/16/16 DJS/JMD SET LTP w/SI13 SLV&X LOCK 03/23/14 GJF/PJC TRSSSV CORRECTION BP Exploration(Alaska) Image Projeefi We11 Hisfiory File Gover 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. ~~ ~ - ~ ~Q Well History File Identifier Organizing ~done~ RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ~~..~,,a~ iuiiiiiimiuim DIG TAL DATA Diskettes, No.' ^ Other, No/Type: Re,~a„~ee~ea iuiuiiiuiiouii OVERSIZED {Scannable) Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: /s/ --r--r Project Proofing III IIIIII IIII II III BY: Maria Date: /s/ Scanning Preparation ~ x 30 = ~_-- + 3 =TOTAL PAGES ,/~ Q ~ / (Count does not include cover sheet) '/1 /~ ~ J BY: Maria Date: /G PlQ /s/ '~ V 0 r Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scann~ng Preparation: ~ES NO BY: Maria Date: / ~ ~~ /s! Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II (I) II I I III ReScanned Ill lllilllllll IIIII BY: Maria Date: lsl Comments about this file: o v ~,~kaa iiiimiiiiumm 10/6/2005 Well History File Cover Page.doc • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 - 6612`. July 6, 2011 i Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 6 _ ®► f 0 333 West 7 Avenue � / Anchorage, Alaska 99501 5 _ [�, Subject: Corrosion Inhibitor Treatments of GPMA L5 )141).'' ' Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L5 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator . • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 05 Date: 05/30/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped demerit date inhibitor sealant date L5-01 1890090 500292190800 0.4 NA 0.4 na 1.7 5/23/2011 L5-04 1861910 500292167900 Sealed conductor NA NA NA NA NA 1.5-05 1870690 500292174200 Sealed conductor NA NA NA NA NA L5-08 1870300 500292171100 Sealed conductor NA NA NA NA NA 1.5-09 1901240 500292208600 Sealed conductor NA NA NA NA NA L5-12 1870100 500292169400 Sealed conductor NA NA NA NA NA L5-13 1831840 500292105900 0.6 NA 0.6 NA 1.7 5/24/2011 L5-15 1881090 500292186800 Sealed conductor NA NA NA NA NA 1.5-16 2060830 500292170001 Sealed conductor NA NA NA NA NA 1.5 -17 2042230 500292188901 0.1 NA 0.1 NA .85 5/30/2011 L5 -18 1900830 500292206000 2.7 NA 2.7 NA 11.9 5/30/2011 1.5 -19 1900680 500292205200 P&A 9/24 NA NA NA NA NA L5-21 1870570 500292173200 Sealed conductor NA NA NA NA NA L5-23 1900500 500292203900 Sealed conductor NA NA NA NA NA L5-24 1850680 500292132700 0.1 NA 0.1 NA .85 5/30/2011 1.5-25 1881350 500292188600 Sealed conductor NA NA NA NA NA L5-26 1901100 500292207900 1 NA 1 NA 3.4 5/30/2011 ri a> 1.5-28 A 2060700 500292171701 Sealed conductor NA NA NA NA NA L5-29 1870450 500292172400 Sealed conductor NA NA NA NA NA L5-31 1901300 500292209100 0.8 NA 0.8 NA 3.4 5/28/2011 1.5 -32 1881020 500292186100 0.3 NA 0.3 NA .85 5/28/2011 1.5 -33 1890470 500292194300 0.3 NA 0.3 NA .85 5/28/2011 1.5-34 1980850 500292288300 0.3 NA 0.3 NA .85 5/28/2011 1.5 -36 1890360 500292193300 0.6 NA 0.6 NA 1.7 5/28/2011 ,~ h .~,. ~ ~~ .. .. *r4 w- ~ ,, :~c ~` ~. ti ° ~.~~,. } ,r ~ + _. .c e ~ ~ yt 4 y` ~' • ,~,.. ~' ~ ~.. MICROFILMED. 6/30/2010. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc a ~ '~~- DATA SUBMITTAL COMPLIANCE REPORT 7~7~ZOOs Permit to Drill 2060700 Well Name/No. PRUDHOE BAY UN LIS L5-28A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21717-01-00 MD 12800 TVD 8789 Completion Date 7/27/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / ROP /PRESSURE (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments wED D Asc Directional Survey 10694 12800 Open 9/7/2006 Disk also has L5-28A L1 apt Directional Survey 10694 12800 Open 9/7/2006 ~6g Pressure 5 Blu 1 10200 10700 Open 10/4/2006 SPL, PRES, TEMP, GR, CCL 30-Jul-2006 Log Pressure Blu 10650 10701 Open 3/22/2007 Mem STPL, GR< Temp, Pres, Spin 30-Jan-2007 ~Rpt 15225 LIS Verification 10700 12799 Open 6/14/2007 LIS Veri, GR, ROP w/Graphics TIF g 15225 Gamma Ray 25 Blu 10713 12800 Open 6!14/2007 MD GR 9-Jul-2006 g 15225 Gamma Ray 25 Blu 10713 12800 Open 6/14/2007 TVD GR 9-Jul-2006 Log Production 2 Blu 1 10200 10750 Case 10/3/2007 PPL, Pres, Temp, GR, CCL, Gradio, ILS, FBS 31- Aug-2007 /,~D C Las 15934 Production 1 613 Case 2/15/2008 LAS, Spin, Temp, Pres, w/PDF and Tif graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? 'tip' Analysis ~'f?'Rr Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~N DATA SUBMITTAL COMPLIANCE REPORT 7ni2oos Permit to Drill 2060700 Well Name/No. PRUDHOE BAY UN LIS L5-28A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21717-01-00 MD 12800 ND 8789 Completion Date 7/27/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: _ __--- Compliance Reviewed By; _ __________________ Date: 1. ~ µ!_ i * ! TI~~I N~'/1~",4L ~~. ProActive Diagnostic Services, Inc. To: AOC~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and :`agfc~ Serve `~ IG:A ~f~ic~t~y`5~,~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245,8952 1) Production Profile 2) Signed Print Name: 13-Fetr08 L5-28A C'it ~~~ LtwlP ~ ~U(o-O~-O ~ (SS3y 1 EDE 50-029-21717-01 Date ' "-'~` _ °' ~~iJ~ PROACTNE DUIGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAtiE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorage(a~memoryiog.com WEBSITE : ww~nr.memor~loo.com C:\Documents and Settings\Owner\Desktop\Tiansndt BP.doc 09/28/07 Schiub~rer NO.4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell 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 Field: Prudhoe Bay Wall .In6 $ 1 nn flaorrin4inn rlafn RI Rnlnr Rr1 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 1 W-42 11745235 MEM SBHPS/TEMP 09/14/07 1 Z-07A N/A SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE rj 08/31/07 1 X-33 11849931 SBHP SURVEY T - [.JL 08/31107 1 E-14A 11686784 LDL -~ 09/23/07 1 01-15A 11855509 DDL ~ - a~ (~ 09/22/07 1 D-21 11626119. PRODUCTION PROFILE '`jfa -ti 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C _ 09106/07 1 11-32 11630498 PRODUCTION PROFILE ~ L _ 09/03/07 1 L-01 11745233 MEM LDL a Q ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ZC 09105/07 1 Z-16 N/A SBHPS/JEWELRY / 09/13/07 1 14-26 11676959 LDL -/j 09/09/07 1 04-02A 11630504 LDL ~ 09111/07 1 14-37 11695075 LDL - 09113/07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09/09/07 1 YLtASt AI:RNVWLtUIat KtGt1Y 1 IiY ,IhNIN(i ANU_Ktt UKNINC+ UNt LUNY tAGM I V: BP Exploration (Alaska) Ina ' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 6 ~~ ~a ~8~~fi_/ Date Delivered: ~,, ~ e,~t ~ ,. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth Received by: Transmittal F®rm ~; BAKER NIJGNES INTEQ To: AOGCC 333 West 7r'' Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken 1 LDWG Compact Disc (Includes Graphic Image files) '~ 1 LDWG lister summary 1 blueline - GR Measured Depth Log ~~ 1 blueline - GR TVD Log Anchorage GEOScience Center -, LAC Job#: 1163028 Sent By: Deepa J/oglekar Date: May 24, 2007 Received By: n _ _ ~~(~ ~ Date: /~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska. 99518 ~~~, ~~ ~,~~~ Direct. (907) 267-6612 FAX: (907) 267-6623 ~~ - - - , ;,~ _, -,~'~ --- --{ -J - ~- =~; __ __ _ ~_ ~~ `'~ti ._ 03/15/2007 SGhlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~-0~~` Wnll Inh $ 1 n.. r1e~...1..11..n NO. 4184 Company: State of Alaska Alaska Oil 8 Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n.,F., n~ n_~__ Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A . 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-066 NIA MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02119/07 1 03-02 11626072 USIT CORROSION EVALUATION 02122/07 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 ~ 11549359 RST 12!26106 1 1 U-066PB1 40011873 OH EDIT MWD/LWD 05/01105 2 1 U-06B 40011873 OH EDIT MWDILWD 05/08/05 2 1 r ~c...ac ~vr~~rv rrccvvc ncvc~r ~ o l Jivlrn\V NI'~v RC 1 URIYI nll7 VIVC I.VYT CHI,R 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 -~- ~ - ,, 900 E. Benson Blvd. ~'' k9 ,~~_ ~ Anchorage, Alaska 99508 6 Date Delivered: ~+~~~ ~ ~ ;?~~~(-~' :^,~ a ~,` ~,t .. _ ; tall .-,- ~~k' . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i Received by: ~ ~ :~` 1~{ Schlumherger Alaska Data 8~ Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jeh # ~~~~~ ~C~ Q ~ 2~C~ ^a12Ska Gfi & CsBS CO(tS. GC~i';T~S~ic~; ~(i@ I ee nQC(`~i llflAn n~~Y NO.3980 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay cti r•.,i.., r•n 10/02/06 LS-28A 11320994 STATIC PRESSURE LOG 07130!06 1 P2-508 11212876 LDL 07/17/06 ~ 1 H-26 11225990 LDL 07/09/06 1 K-02D 11209593 SCMT 07/20106 1 J-09A 11321005 LDL 08/29106 1 D.S. 04-19A N/A INJECTION PROFILE 08/02106 1 J-06 11321006 PRODUCTION PROFILE 08/29106 1 G-24 NIA SCMT 08/08/06 1 2-18/L-16 11225986 LDL 07/04/06 1 F-05A 11216212 MCNL 09/03/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Hlasica uata ts< C;onswting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~~ ._~-~~ RECEIVED AUG 2 ~~~ STATE OF ALASKA IL AND GAS CONSERVATION COM SION Alaska Oil & ~(~SC~~ON OR RECOMPLETION REPORT AND LOG Anchorage Drilled Underbalance 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/27/2006 12. Permit to Drill Number 206-070 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/29/2006 13. API Number 50-029-21717-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/9/2006 14. Well Name and Number: PBU L5-28A FWL, SEC. 01, T11N, R15E, UM 2147 FSL, 29 Top of Productive Horizon: 1873' FSL, 1102' FWL, SEC. 36, T12N, R15E, UM 8. KB Elevation (ft): 60' 15. Field /Pool(s): Prudhoe Bay Field / Lisburne Pool Total Depth: 2984' FSL, 470' FEL, SEC. 35, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 12800 + 8789 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 717446 y- 5975280 Zone- ASP4 10. Total Depth (MD+TVD) 12800 + 8789 Ft 16. Property Designation: ADL 034630 TPI: x- 718370 y- 5980315 Zone- ASP4 Total Depth: x- 716766 y- 5981380 Zone- ASP4 11. Depth where SSSV set 1983' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: GR/ROP/PRESSURE 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 1860# Poleset 10-3/4" 45.5# K-55 / L-80 Surface 4194' Surface 3980' 17-1/2" 1365 sx AS III 325 sx Class 'G' 7- /8" 33.7# L-80 Surface Surface 8810' 12-1/4" 569 sx Class 'G' 300 sx CS I 4-1/2" 12.6# L-80 10430' 1 71 8571' 8810' Tieback 82 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 3" Open Hole Completion 4-1/2", 12.6#, L-80 10443' 10397' MD TVD MD TVD 10715' - 12800' 8810' - 8789' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 10717' Set Whipstock for L5-28A 26. PRODUCTION TEST Date First Production: July 27, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 8/22/2006 Hours Tested 12 PRODUCTION FOR TEST PERIOD OIL-BBL 542 GAS-MCF 13,311 WATER-BBL -0- CHOKE SIZE 176 GAS-OIL RATIO 24,561 FIOW TUbing Press. 864 CaSing PreSSUre 1,300 CALCULATED 24-HOUR RATE• OIL-BBL 1,084 GAS-MCF 26,621 WATER-BBL -0- OIL GRAVITY-API (CORK) 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". ~ ® Non coMPLE'TtON fia'P o f rcl~ ~.birat-J /d 7/6 ~~$~~l rr,~ TE I Form 10 312/2003 ~ CONTINUED ON REVERSE SIDE ~~ ~lG~~IA~. ~DINIS ~Ft~ AUG 2 8 2006 28. GEOLOGIC MARK 29. ORMATION TESTS Include and brie y summarize test results. List intervals tested, NAnnE MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Wahoo 4.7 10729' 8821' None Top Wahoo 4.6 10761' 8845' Top Wahoo 4.5 10812' 8867' Top Wahoo 4.5 (Invert) 10905' 8867' Top Wahoo 4.6 (Invert) 11170' 8840' Top Wahoo 4.6 (Revert) 11280' 8837' Top Wahoo 4.6 (Invert) 11391' 8835' Top Wahoo 4.7 (Invert) 12376' 8799' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ' / ~ C ` Signed Terrie Hubble Title Technical Assistant Date ~/ ~f ~'i Q (Q PBU L5-28A 206-070 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Greg Sarber, 564-4330 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). Irene 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 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. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 47 Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours Task Code II NPT Phase Description of Operations 6/1/2006 20:30 - 20:45 0.25 MOB P 20:45 - 22:00 1.25 MOB P 22:00 - 00:00 2.00 I MOB I P 6/2/2006 00:00 - 02:00 2.001 MOB ~ P 02:00 - 05:30 I 3.50 I MOB I P 05:30 - 06:00 0.50 BOPSU P 06:00 - 06:15 0.25 BOPSU P 06:15 - 09:00 2.75 CLEAN P 09:00 - 13:30 I 4.501 CLEAN I P 13:30 - 17:15 I 3.751 CLEAN I N I FLUD 17:15 - 23:15 I 6.00 I CLEAN I N I SEAL 23:15 - 00:00 I 0.751 CLEAN I P 6/3/2006 00:00 - 01:45 ~ 1.751 CLEAN P 01:45-02:00 0.25 WHSUR~P 02:00 - 03:00 I 1.00 I W HSUR I P 03:00 - 04:30 1.50 WHSUR P 04:30 - 05:00 0.50 WHSUR P 05:00 - 06:00 1.00 WHSUR P PRE Safety mtg re: move off well PRE Move off of L5-16 and move down the Pad past L5-28 and set down PRE Safety mtg Use Veco 150T crane to pick the 13-5/8" BOP from behind the well and set on a lowboy. Move all to L5-28 and set stack behind well Use crane to remove HES spooler and set SWS spooler on floor. RDMO crane Remove herculite and mats from L5-16 and set same around L5-28 Peform Post and Pre Pad inspections w/ DSO. Close out L5-16 Unit Work Permit and initiate same for next well PRE Fin set herculite and rig mats Safety mtg re: move over well Move over well and set down PRE Accept for operations at 0200 hrs 6/2/06 RU cellar to circulate. Spot misc equipment. DSM MIRU tiger tank/hardline. Take on rig water. WO kill fluids and DSM to pull BPV WHDTRE MIRU DSM lubricator WHDTRE Crew change and PJSM with DSM valve crew. DECOMP RU lines in cellar to tree and IA. Pressure test same. Take on KCL water in pits. DECOMP Pressure test lines. Open IA, tbg, and OA. All pressures are zero. Pump down IA to displace diesel from tbg. Swap to pumping down tubing do displace diesel in the IA. Mix two drums Safe surf into 290 bbls to help clean up pipe before pulling completion. Take returns to tiger tank. Some gas with btm sup from tubing. DECOMP Wait on vac truck with additional KCL (field is short on trucks). Replace main circuit breaker in SCR room for genset #2 while waiting on fluids. DECOMP Offload truck into pits and send for another load Replacement circuit breaker failed. Get a game plan, investigate failures-appears replacement breaker was bad from the start. Remove breaker from gen #1 (which is tom down for scheduled rebuild). Do some testing and determine this breaker should work .. but it didn't. More investigation determines that generator #2 has a problem and needs attention from Cat. Electrician from Nordic 1 is over hours Spend one hour tracking down tripped breakers in ops cab DECOMP Crew THA for moving forward w/ one generator (#3) Check out various systems and prep to circ DECOMP Open up to well SITP 0, IA 0, OA 0. Circ 3.0/720 w/ 265 bbls 1% KCI at 120E taking returns from IA while WO FMC DECOMP Chk for flow, none Safety mtg re: ND tree DECOMP Set FMC BPV. PT from below to 500 psi and held, but had slow bleed off to formation. Found IA on vac later DECOMP ND 3" tree and adaptor flange and load out DECOMP FMC check landing jt threads and set blanking plug DECOMP NU 11" x 13-5/8" DS adaptor flange Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task ~ Code NPT '_ - -- 6/3/2006 06:00 - 06:30 0.50 WHSUR P 06:30 - 13:00 6.50 WHSUR P 13:00-19:30 I 6.501WHSURIP 19:30-21:30 I 2.001 WHSURIP 21:30 - 00:00 I 2.501 PULL I P 6/4/2006 100:00 - 01:00 I 1.001 PULL I P 01:00 - 05:15 I 4.251 PULL I P 05:15 - 19:00 I 13.751 PULL I P 19:00 - 20:00 I 1.001 FISH I P 20:00 - 20:15 0.25 FISH P 20:15 - 21:30 1.25 FISH P 21:30 - 22:30 ~ 1.00 ~ FISH ~ P 22:30 - 00:00 1.50 FISH P 6/5/2006 00:00 - 01:15 1.25 FISH P 01:15 - 02:00 0.75 FISH P 02:00 - 03:45 I 1.751 FISH I P 03:45 - 06:00 2.25 FISH P 06:00 - 06:30 0.50 FISH P 06:30 - 15:00 8.50 FISH P 15:00 - 16:00 1.00 FISH P 16:00 - 18:15 2.25 FISH P 18:15 - 20:00 1.751 FISH I P 20:00 - 22:30 I 2.501 FISH I P 22:30 - 00:00 1.50 FISH P 6/6/2006 00:00 - 06:00 6.00 FISH P 06:00 - 08:30 2.50 FISH P Page 2 of 47 Spud Date: 6/2/2006 Start: 6/1/2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase I Description of Operations DECOMP Crew change and PJSM/THA to discuss NU of BOPS. DECOMP Skid BOPs into cellar. NU same. MU choke and kill lines. Attach hydraulics. NU riser assembly. Get good high pressure body test. DECOMP Test BOP equipment as per permit. AOGCC witness waived by C. Scheve. DECOMP Pull blanking plug. Use FMC and DSM valve crew to dryrod pull BPV and took several tries. Found cement chunks on top of BPV. RDMO DSM DECOMP MU landing jt to hanger. BOLDS. Pull hanger to floor w/ 72k, clean. Fill hole w/ 28 bbls. LD landing jt, hanger and one full joint. MU CL to spooler PVT 399 DECOMP CBU 6.0/650 w/ 350 bbls and lost 10 bbls Safety mtg re: LD tubing DECOMP LD 4 ea 3-1/2" 9.3# L-80 IBT pups. POOH LD 3-1/2" tubing. Recovered 72 SS steel bands and complete single CL DECOMP Continue to POOH and LD 3-1/2" tubing and jewelry. Crew change and PJSM at 0600/1800. Finish laying down completion and load out on sills for NORM and DTS. Jet cut was flared circumferentially at avg 4.0". All tubing was very good shape w/ no external pitting and had more than 1/2 of IPC still attached DECOMP Bring BOT fishing tools to floor. Back out lifting sub from landing jt DECOMP Safety mtg re: MU BHA/first Hite back DECOMP MU BHA #1 (6.625" OD cutlip guide, OS w/ internal mill and grapple, oil jars) DECOMP MU 6 stds 4-3/4" DC's Hole taking 7 bph DECOMP TIH w/ stood back 3-1/2 DP DECOMP Continue TIH w/ DP out of derrick DECOMP Load 3-1/2 DP singles in pipeshed while fix leaking air boot on riser top section DECOMP Continue TIH w/ DP out of the derrick (-5000'). Losing 7 bph static DECOMP Break circ. Finish load pipeshed w/ a total of 340 jts DECOMP Crew change and PJSM. Service crown and blocks. DECOMP Run in hole with BHA picking up singles from pipe shed. DECOMP Pressure test kelly valves to 3500 and 250 psi. DECOMP Tag top of seal assembly fish at 10,546'. 130k# up, 106k# down wt. Pick up and begin circulating at 3 bpm/480 psi. Set down on fish and begin milling. 210 amps on rotary. DECOMP Finish dressing flare off of tubing stub and slack off to catch w/ grapple at 10556'. Fish were biting. Begin initial jarring at 20k over and gradually work up to 75k over. After 20+jar licks, pulled seals out of seal assy and fish moved freely at 140k. LD two joints, blow down and set back kelly DECOMP CBU while displace KCI to tiger tank w/ 2 ppb biozan 6.0/1700 w/ 350 psi induced whp due to 2" hardline. Reduce rate to 4.0/750 w/ 175 psi induced due to excessive losses DECOMP TOH w/ seal assy DECOMP Continue TOH w/ seal assy from packer #1 DECOMP Stand back drill collars and fishing tools. LD overshot with seal Printed: 7/37/2006 11:00:56 AM BP EXPLORATION Page 3 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To 5-28 5-28 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase Spud Date: 6/2/2006 : 6/1/2006 End: 7/27/2006 Release: 7/27/2006 Number: Description of Operations 6/6/2006 06:00 - 08:30 2.50 FISH P DECOMP assembly fish. 08:30 - 10:30 2.00 FISH P DECOMP MU packer milling assembly. 10:30 - 21:00 10.50 FISH P DECOMP Run in hole with milling assembly. CDL. Continue TIH. PU 2 singles for 321 total 21:00 - 00:00 3.00 FISH P DECOMP PU kelly. Establish parameters 138k, 114k 5.0/900 PVT 340 Ease in hole and tag at 10567' (22.5' in on kelly). Begin milling at 50 rpm w/ 250 amps. Gradually add rpm's and start making steady hole at 90 rpm w/ 400 amps max (13k '/Ibs) and mill to 10569' 6/7/2006 00:00 - 02:30 2.50 FISH P DECOMP Continue milling packer slips and progress slows to zero at 10570'. Appear to be spinning on top of packer. No sign of rubber to surface. Losses are less than 5 bph 02:30 - 14:00 11.50 FISH P DECOMP Blow down and set back kelly. LD single TOH to check mill and boot baskets (wet trip due to biozan). Dropped rod and opened pumpout sub with 2300psi. Pumped 20bbls 9.6ppg slug. Continue THA to BHA 14:00 - 15:15 1.25 FISH P DECOMP Standback DC's. LD and empty junk subs. A few pieces of misc metal. No rubber. Mill face in good shape which might indicate that packer released and it along with the tbg below to the next jet cut was rotating preventing any further milling. 15:15 - 16:45 1.50 FISH P DECOMP PU spear assembly BHA #3. 16:45 - 23:00 6.25 FISH P DECOMP TIH 23:00 - 00:00 1.00 FISH P DECOMP PU 2 singles and kelly. Use backup wt indicator. Establish parameters 160k, 117k 2.0/550 Ease in hole at find top of packer at 10575' on jt #322 + 10' kelly. Set spear grapple first try 6/8/2006 00:00 - 04:00 4.00 FISH P DECOMP Start jarring at 20k over and increase to max over one hr. Jar at 290k for 3 hours w/ no movement while occassionally tripping rig generator #2 breaker and circulating to cool jars 04:00 - 06:00 2.00 FISH P DECOMP Release grapple, drop bar to open circ sub, pump pill. Blow down and set back kelly. LD 3 singles. Inspect derrick. Secure well for crew change. 06:00 - 06:15 0.25 FISH P DECOMP PJSM review pipe handling procedures, hazards. Key on staying focused throughout job. STOP the job if nessasary to talk or fix anything perceivied to be wrong or not understood. 06:15 - 11:00 4.75 FISH P DECOMP Continue TOH to 100 stands. 11:00 - 14:30 3.50 FISH N DECOMP Install electrical breaker for generator #1 and phase in with SCR. 14:30 - 15:40 1.17 FISH P DECOMP Continue TOH to 130 stands. 15:40 - 16:20 0.67 FISH N DECOMP Attempt to bring gen #1 on line. Breaker continues to trip. Will continue working on it tomorrow. 16:20 - 18:00 1.67 FISH P DECOMP Continue TOH. 18:00 - 18:15 0.25 FISH P DECOMP Crew change/safety mtg 18:15 - 19:15 1.00 FISH P DECOMP Standback DC's. LD spear assy complete 19:15 - 19:30 0.25 FISH P DECOMP Safety mtg re: MU milling assy 19:30 - 21:30 2.00 FISH P DECOMP Bring milling assy tools to floor. MU BHA. MU DC's, PU single 21:30 - 00:00 2.50 FISH P DECOMP TIH w/ DP and BHA #4 6/9/2006 00:00 - 02:00 2.00 FISH P DECOMP CDL 50' 02:00 - 06:00 4.00 FISH P DECOMP Continue TIH w/ mill 319jts in hole. 06:00 - 06:30 0.50 FISH P DECOMP Crew changeout. PJSM review plan forward. 06:30 - 07:15 0.75 FISH P DECOMP PU 2 singles and kelly. Up wt 160k dwn wt 89k. 07:15 - 09:00 1.75 FISH P DECOMP RIH dry tag 321jts plus 22.5' kelly (10566'). With 10k WOB Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 4 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours ~ Task ~ Code ~ NPT Phase Description of Operations 6/9/2006 ~ 07:15 - 09:00 1.75 ~ FISH I P DECOMP 09:00 - 11:30 ~ 2.501 FISH ~ P DECOMP 11:30 - 12:00 0.50 FISH P DECOMP 12:00 - 14:10 2.17 FISH P DECOMP 14:10 - 15:30 I 1.331 FISH I P I I DECOMP 15:30 - 16:00 0.50 FISH P DECOMP 16:00 - 16:30. 0.50 FISH P DECOMP 16:30 - 19:00 2.50 FISH P DECOMP 19:00 - 19:45 0.751 FISH P DECOMP 19:45 - 21:15 1.501 FISH P DECOMP 21:15 - 22:45 I 1.501 FISH I P I I DECOMP 22:45 - 00:00 1.25 FISH P DECOMP 6/10/2006 00:00 - 05:30 5.50 FISH P DECOMP 05:30 - 06:00 0.50 FISH P DECOMP 06:00 - 06:20 0.33 FISH P DECOMP 06:20 - 07:30 I 1.171 FISH I P I I DECOMP 07:30 - 08:15 0.75 FISH P DECOMP 08:15 - 14:00 5.75 FISH P DECOMP 14:00 - 14:15 0.25 FISH P DECOMP 14:15 - 16:00 1.75 FISH P DECOMP 16:00 - 22:30 6.50 FISH P DECOMP 23.75' kelly in. Break circulation. Rotating string wt 118K w/ 390amps. Small amount of gas to surface after CBU. PU continue circulating and monitoring well. AOGCC given 24hr notice for weekly BOP test. Planned for after next TOH. Mill on upper SB -3A packer starting from 10566' 4-5k wob, 80rpm's, 390amps, Ov= 5bpm, Op= 1033psi Milled 16". Stopped to swap SSSV spools with Veco crane. PJSM review crane operations. Swap out spools. Continue milling operations. Checked wts and dry tag. May have actually milled less than 6". Milling with 8-10k at 80rpm's. Ocassional torque up to 450amps but most of the time staying between 380-400amps. Free-spin off bottom 350-360amps. Stopped rotating. PU and RIH hard tag top of packer several times. Did something downhole. PP increased 800-1000psi and loosing 1 bpm to formation. Milled ahead but stacking wt. Work pipe and knock off whatever was on us. PP back to 1050psi. PU and check wts wo pump up 160k dwn 89k same as begining. Shutdown pumps and dry drill. Rotating string wt 119k (wo pump). Mill with 18-20k, 380-400amps. A few spikes in torque but making no headway. Mashed on it with 50k with no increase in torque values. PU and RIH hard again serveral times. Adjust brakes. Continue milling wo pumps and spudding occasionally w/ no progress and normal rotating torque Mix and pump 15 bbl of 20#/bbl coarse nut plug pill and shut down pump w/ 10 bbls out nozzle Resume dry drill w/ occasional spudding. Pump out rest of pill 1 bbl/20 min. While dry rotating finally got some movement and slowly chased w/o rotating 8' downhole to 32' kelly in which is 10576'. PUH 158k, clean Flush pill from BHA, drop ball-on-rod to open circ sub at 2500 psi. Pump 20 bbl weighted pill. Blow down kelly and set back. LD 2 singles TOH Continue TOH w/ mill Stand back DC's Crew change. PJSM review plan forward to break down BHA. DC's and BHA componet handling precautions. Stand back remaining DC's. Service break bolt baskets. Fill hole close blind rams. LD and empty boot baskets. Few small pieces of slip retainer rings and couple handfulls of smaller misc metal. LD jars and bumper sub. Pull wear bushing and install test plug. Test BOPE 250psU3500psi 5 min each. Check accumulator bottoles pre-charge pressure and accumulator drawdown. AOGCC rep John Crisp wavied witnessing test. PJSM review for to PU fishing tools. PU BHA #5 TIH w/ drillpipe w/ spear Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Page 5 of 47 Legal Well Name: L 5-28 Common W ell Name: L 5-28 Spud Date: 6/2/2006 Event Nam e: REENTE R+COM PLET E Start : 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALIST A Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ ~ Description of Operations -- 6/10/2006 - 22:30 - 00:00 1.50 - - - - FISH P DECOMP Inspect drilling line. PT upper and lower kelly cocks as part of weekly BOPE test 6/11/2006 00:00 - 01:00 1.00 FISH P DECOMP PU two singles (322 jts) and kelly. Establish parameters 2.0/520 158k, 89k. Ease in hole and lose wt at 13' in or 10583' 01:00 - 02:00 1.00 FISH P DECOMP PUH to 165k and trip jars. Stack 25k at 15' in and 2.0/600 Incr jar licks up to 180k and packer pulled free, but dragging. Kelly out w/ 3 singles until pulling clean w/ 20k over w/ no swab. 02:00 - 03:15 1.25 FISH P DECOMP Drop bar, open circ sub at 2500 psi. Pump 20 bbl weighted pill PVT 385 Blow down kelly and set back 03:15 - 06:00 2.75 FISH P DECOMP TOH w/ packer #1 dragging 10-20k initially w/ a few 40k overpulls at casing collars. After 20 stds was pulling clean, but swabbing if pulling too fast. Pulled to 45 stds 06:00 - 06:20 0.33 FISH P DECOMP Crrew change. PJSM review swabbing problems and pulling tight at times. 06:20 - 13:00 6.67 FISH P DECOMP Continue TOH 13:00 - 15:30 2.50 FISH P DECOMP LD fish: Upper SB-3 packer/pups, 1jt 3-1/2" tbg, RHC collar/pups, 1 /2 jt 3-1 /2" tbg where jet cut was made and it was speared into the other half jt a good 10'. That was locked up so tight we also retrieved the seal assembly on the lower packer. Answers the question of having to jar earlier. 15:30 - 16:45 1.25 FISH P DECOMP Clean up floor and tools. Inspect and grease crown, drawworks. 16:45 - 19:30 2.75 FISH P DECOMP PU BHA #6 and DC's 19:30 - 21:45 2.25 FISH P DECOMP CDL 50', adjust drawworks brakes 21:45 - 00:00 2.25 FISH P DECOMP TIH w/ DP 6/12/2006 00:00 - 02:30 2.50 FISH P DECOMP Continue TIH w/mill and prt tool 02:30 - 03:20 0.83 FISH P DECOMP PU 6 singles. PU kelly 03:20 - 04:45 1.42 FISH P DECOMP Establish parameters 139k, 100k at 2.0/500 138k, 110k 3.0/1430 60 rpm 275 amps PVT 407 Ease in hole looking for packer. See prt enter bore about 14' in on kelly and DP pressure slowly rises indicating junk. Incr rate to 5.0/1420 and attempt to wash junk out of packer bore. Finally able to enter packer bore until set down w/ mill at 24' in on kelly (10692'). Able to circ 1.0/320 and pull out of packer too 04:45 - 06:00 1.25 FISH P DECOMP Wash back into packer bore while increasing pump rate 06:00 - 13:00 7.00 FISH P DECOMP Start milling on pkr with 22.5' kelly in. Have trapped pressure of 1800psi so dry milling. 4-5k wob, 60-70rpm's 400amps pressure is slowly falling. Clear obstructions. Milling away with normal stalls 2-3k wob 70-80rpm's. Milled 2-1/2' and packer released was able to lower 10'. PU with drag. 13:00 - 14:30 1.50 FISH P DECOMP Work tight packer 90-200k. Finally freed up at 210k. Confirm able to circulate and not swabbing well. Well not taking fluid nor is well showing signs of rising gas bubble. 14:30 - 17:45 3.25 FISH P DECOMP Drop bar and open pumpout sub. Open sub and CBU at 5bpm. Gas to surface after pumping 220bb1s turn into gas buster. Pumping at 2.4bpm keeping buster under 2psi. Shutdown pump. 17:45 - 18:15 0.00 FISH P DECOMP Open annular, monitor well during crew change. Appears stable 18:15 - 22:00 3.75 FISH P DECOMP Resume circ 2 ppb biozan and incr rate to 5.0/920 to pits Safety mtg re: fluid swap Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date ;From - To I Hours I Task I Code I NPT _ __ 6/12/2006 (18:15 - 22:00 3.75 ~ FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 6/13/2006 ~ 00:00 - 05:00 ~ 5.00 ~ FISH ~ P 05:00 - 06:30 1.50 FISH P 06:30 - 07:15 0.75 FISH P 07:15 - 07:30 0.25 FISH P 07:30 - 09:15 1.75 FISH P 09:15 - 10:25 1.17 FISH P 10:25 - 12:00 1.58 FISH P 12:00 - 12:45 I 0.751 FISH ( P 12:45 - 15:00 2.25 FISH P 15:00 - 16:00 1.00 FISH P 16:00 - 19:00 3.00 FISH P 19:00 - 23:00 4.00 FISH P 23:00 - 00:00 1.00 FISH P 6/14/2006 100:00 - 00:15 I 0.251 FISH I P 00:15 - 03:10 I 2.921 FISH I P 03:10 - 03:30 I 0.331 FISH I P Page 6 of 47 Spud Date: 6/2/2006 Start: 6/1/2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase I Description of Operations DECOMP Close annular and circulate one pit dry of biozan while taking returns to tiger tank. Begin displacement to fresh 1 % KCI and gradually incr rate to 5.0/1580 w/full returns w/ 320 psi induced back pressure due to hardline. Incr rate to 6.0/1830 w/ 480 psi induced and had 1/1 returns. Monitor well, stable DECOMP Blow down kelly and set back DECOMP TOH slow at 140k w/ no drag and watching for swabbing. Hole taking correct fill DECOMP Continue TOH w/ packer #2 Safety break-watch grizzly dig up ground squirrel den Lesson-always have an exit DECOMP Standback DC's DECOMP LD fish: rec'vd Baker FB-1 packer and seal bore extension only. Total length 5.95' Fish remaining in the hole: XO coupling, Miilout ext, XO, pup jt, XO, SW nip, XO, XO, WLEG total 21.87' DECOMP PJSM review plan forward with SLB SL ccrews. DECOMP RU slickline equipment. DECOMP RIH w/ 4.50" LIB tagged at 10797' (uncorrected) DECOMP POH. LIB shows bullseye 1/2" dot square in the middle. Possible 4"-5" OD mark on extreme edge of LIB. Discuss with town. DECOMP RD slickliners. Plan forward is to run junk mill and casing scrapper. DECOMP PU BHA #7 DECOMP TIH 20 stds. DECOMP Cut & slip drilling line DECOMP RIH with 325 jts DP (162X std) DP DECOMP PU 3 jts of DP and tagged (hard) ~ 10,788 ft. PU at 140k and confirmed tag at 10,788 ft. The tag is 8.86 ft high to WLMD of 10,797 ft. LD single, there is 328 jts DP in the hole plus BHA. PU Kelly and break circulation. DECOMP Circulate at 6 bpm and RIH and tagged at 10,788 ft Pushed down to 10,794 ft PU and confirmed tag 3 times using 30k string wt. DECOMP Circulate BU while working kelly at 8 bpm / 3,065 psi. Pump 44 bbl 9.4 ppg 2 ppb biozan sweep around. V=430 bbl. When biozan sweep reached surface, black scale material covered the shaker screen. Mixed up another 35 bbl 3 ppb biozan sweep and pumped it around. No fluid lost to formation while circulating at 8 bpm and 3,000 psi. 2nd sweep came back and was cleaner. DECOMP Shut annular and PT wellbore to 550 psi and then double blocked MP. 1 min 487 psi. 1 min 450 psi 2 min 417 psi 3 min 450 psi. 5 min 421 psi. 6 min 396 psi. Re-test 505 psi. 1 min 450 psi 2 min 417 psi 3 min 399 psi Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Page 7 of 47 Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To 5-28 5-28 REENTE NORDIC NORDIC Hours I R+COM CALIS 2 Task PLET TA I Code ~ E NPT Start Rig Rig ~ Phase Spud Date: 6/2/2006 : 6/1/2006 End: 7/27/2006 Release: 7/27/2006 Number: Description of Operations 6/14/2006 03:10 - 03:30 0.33 FISH P DECOMP 5 min 360 psi 7 min 340 psi 8 min 286 psi 03;30 - 04:30 1.00 FISH P DECOMP Break circulation, work pipe and pump 19.5 17#/bbl barite pill. Displaced pill with 65 bbl 2% and SD. (dry job) Set Kelly back, dropped 2.26" hollow drift with wire attached. 04:30 - 08:00 3.50 FISH P DECOMP POOH standing DP back in the derrick. Got to 80 stds. Town now wants to circulate out 17ppg mud spotted on bottom. Possible interference with USIT log. 08:00 - 08:45 0.75 FISH P DECOMP MU TIW and check if circulation is possible with the hollow drift & wire in the drillpipe. 6bpm ~ 1000psi Break off TIW. Called and postponed USIT for 10-11 hrs' 08:45 - 11:50 3.08 FISH P DECOMP TIH. PU kelly tagged top of fish 28' kelly in 10794'. 11:50 - 14:30 2.67 FISH P DECOMP Circulate at 2.65bpm 1250psi mud wt differential accounts for 275psi. Take 17ppg mud to cuttings tank. Continue circ long enough to monitor return rate confirm 1:1 14:30 - 16:00 1.50 FISH P DECOMP Standback and blowdown kelly. TOH 16:00 - 16:30 0.50 FISH P DECOMP Adjust brakes. Also check circuit breaker on generator #1. 16:30 - 22:00 5.50 FISH P DECOMP Continue TOH. Recovered Bugs and his leash 22:00 - 23:00 1.00 FISH P DECOMP LD BHA and stand DC in derrick 23:00 - 00:00 1.00 FISH P DECOMP Load out Baker tools and clean floor Loaded pipe shed with liner and running tools 6/15/2006 00:00 - 00:20 0.33 EVAL P RUNPRD Spotted SLB Eliners and held PJSM on Hazards associated with PU tools and running log 00:20 - 02:50 2.50 EVAL P RUNPRD PU eline tools and RU to run USIT log 02:50 - 03:45 0.92 EVAL P RUNPRD RIH with USIT Logging tool to 10,750 ft 03:45 - 07:00 3.25 EVAL P RUNPRD PUH logging at 3,600 fph from 10,750 ft to 9,100 ft SD rotating transducer and RIH to tag top of fish Tagged top of fish at 10,788 ft. PUH and logged repeat section from 10,780 ft to 10,500 ft. POOH with logging tool. LD same LD SLB shooting nipple 07:00 - 07:30 0.50 CASE P RUNPRD RU tools to run 4-1/2" liner 07:30 - 07:45 0.25 CASE P RUNPRD PJSM: review plan forward for liner running order. Point out pinch pionts on a crowed floor. 07:45 - 11:25 3.67 CASE P RUNPRD PU 4-1/2" 12.6# L80 shoe track, 2 jts liner, PU and test floats. PU remaining liner and BOT liner hanger. Have spotted ASRC heater and separator. 11:25 - 11:50 0.42 CASE P RUNPRD Clear floor and setback liner running equipment. 11:50 - 22:30 10.67 CASE P RUNPRD TIH with liner on 3-1/2" DP. Same time loaded a-coil reel into rig. Tagged at 11,788 ft. PU and LD 2 jts and spaced out with 3- 6 ft 3-1/2" PJ PU single and RIH and tagged againg to confirm PBTD. Tagged at 10,788 ft. PU 2 ft for hanger and packer setting Set 10,786 ft 22:30 - 00:00 1.50 CASE P RUNPRD Circulate bottoms up at 10,780 ft at 4 bpm and 800 psi. RU Cementers vac trucks. 6/16/2006 00:00 - 00:30 0.50 CASE P RUNPRD Held PJSM on Cementing liner. Discussed all hazards assoicated with job bu all crew members. 12 issues identified and midigated. Had new hand on location a identified his mentor. 00:30 - 01:15 0.75 CEMT P RUNPRD RU Lake Charles and started circulating. RIH and tagged. top of fish at 10,788 ft and it was going in the hole with 10k wt set on it. Pushed fish to 10,794 ft stacked 30 k and it didn't move. Printetl: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task Code I NPT I Phase -- -- ~ - ~ -- L- --- 6/16/2006 00:30 - 01:15 0.75 CEMT P RUNPRD 01:15 - 02:30 1.25 CEMT P RUNPRD 02:30 - 03:15 I 0.751 CEMT I P I I RUNPRD 03:15 - 04:45 I 1.501 CEMT I P I I RUNPRD 04:45 - 05:30 I 0.751 CEMT I P I I RUNPRD 05:30 - 06:00 0.50 CEMT ~ RUNPRD 06:00 - 06:15 0.25 CEMT P RUNPRD 06:15 - 21:00 14.75 BUNCO RUNCMP 21:00 - 00:00 3.00 BUNCO RUNCMP 6/17/2006 00:00 - 01:45 1.75 BUNCO RUNCMP 01:45 - 03:00 1.25 RUNCOI~' RUNCMP 03:00 - 03:30 0.50 BUNCO RUNCMP 03:30 - 20:00 16.50 BUNCO RUNCMP 20:00 - 20:30 0.50 BUNCO RUNCMP 20:30 - 00:00 ~ 3.501 RUNCOAI'p RUNCMP 6/18/2006 00:00 - 05:30 5.50 RUNC01~1P RUNCMP 05:30 - 06:00 0.50 BUNCO RUNCMP Page 8 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations PUH and set shoe at 10,787 ft. Batched up 20 bbl cement and at density at 01:25 hrs. Pumped 3 bbl water, SD and PT to 5300 psi (OK) Pumped 17 bbl water at 6 bpm at 1300 psi. Switched to cement. Pumped 17 bbl of 15.9ppg Clas "G" cement at 4-5 bpm at 1200 psi to 300 psi. SD, lined out Lake Charles and dropped dart. Pumped 22 bbl of water at 5-6 bpm and caught fluid. Pumped 56 bbl and reciprcated DP with cement around 10 to 15 ft. With 65 bbl behined cement parked shoe at 10,787 ft in up stroke position. Lanched LW D with 72.6 bbls (2 bbl over) Lanched at 2,300 psi and landed LWD at landing collar with 4.2 bbl pumped. (Vol total - 76.9 bbls)Inc pressure to 1000 psi. OK Cement in place at 02:30 hrs 6/16/2006 Pressured up to 2,500 psi, slacked off DP and hanger didn't set.. Picked back up and increased DP pressure to 2700 psi. Slacked off and set 50k down on hanger. Hanger set. Pressured up to 4500 psi. Saw small pressure spike at 3,300 psi (evidence packer set). Released pressure, floats held. PU, set slips, rotated 15 turns to right and PU. Released from liner. Pressured up to 1000 psi, PU DP, pressure bleed off to 400 psi, inc Op to 5 bpm Pumped 50 bbl up the annulus, SD, RIH and set dogs on packer using 50 k. Packer set. Switched to pumping with rig. PU 23 FT to circulate wellbore. Circulating excess cement to surface at 6 bpm and 1,700 psi. With 260 bbl pumped cement to surface, divert to cuttings box. Pumped 40 bbl cement contaminated fluid to cuttings box. Switched to keeping fluid at 320 bbls. Op = 6 bpm at 1663 psi Pumped a total of 500 bbl up annulus. RD cement head and well slight underbalance. RU and circulate well while RD cement head. Cirululated 25 bbl and well balanced. POOH LD DP Crew change. PJSM reivew hazards and procedures for LDDP. LDDP Clean pits 3,4,5 super suck cuttings tank and moveout. ASRC held PJSM with Veco crane operators and bed truck for installation on Diesel Tank Farm. Building diesel tank farm. OOH LD LRT. RIH with DC and PU kelly and break down. Finish RD kell and set kelly outside for transportation to Price Pad. POOH LD DC Make ready to conduct weekly BOP test. AOGCC John Spaulding wavered the witness of BOP test. Set test plug. BOP Test at 250/3,500 psi and loading pipe shed. ASRC's tank farm is RU and they layed out and RU hardline. Held PJSM on PU and handling 4-1/2" tubing. Odentified hazards and midigated same. Run 4-1/2" Completion as per Liner Summary 56 jts in at midnight RIH with 4-1/2" Completion Ran 199 jts, RU HALCO Spooler, PU TRSSSV and hook up control lines. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 9 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date j Name: L ell Name: L e: Name: From - To ~ 5-28 5-28 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT 6/18/2006 06:00 - 06:15 0.25 BUNCO 06:15 - 12:15 6.00 BUNCO 12:.15 - 12:25 0.17 BUNCO 12:25 - 16:00 3.58 BUNCO 16:00 - 19:30 3.50 BUNCO 19:30 - 21:30 2.00 BUNCO 21:30 - 00:00 2.50 RIGD P 6/19/2006 00:00 - 02:00 2.00 RIGD P 02:00 - 04:00 2.00 RIGD P 04:00 - 04:30 0.50 RIGD P 04:30 - 06:00 1.50 RIGD P 06:00 - 06:20 0.33 RIGD P 06:20 - 08:30 2.17 RIGD P 08:30 - 18:00 9.50 BOPSU P 18:00 - 18:20 0.33 BOPSU P 18:20 - 00:00 5.67 BOPSU P 6/20/2006 00:00 - 03:00 3.00 BOPSU P Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase Description of Operations RUNCMP Cew change. PJSM review what happening on rig floor. Review plan forward. Stress importance for working safely. Another crew change coming at noon. Stay focused! RUNCMP MU control line to SSSV and test to 5000psi. Continue running tbg putting control line SS band on each jt. ASRC MU 2" gas line to/ from gas control skid back. Veco Well Support helping. Check requirements for scaffolding to access. lift gas valves on Lisb. gas header. MU same. Check tbg wt above TOL 65k down 106k up. RIH tag bottom of PBR. Calculate spaceout to have WLEG 8' into the 11' PBR after landing tbg hanger. LD 2jts. MU 5.83' pup PU 1 full jt. RUNCMP Crew change. PJSM reivew past operations and plan forward. Ask crews to especially carefull with only 6hrs sleep. RUNCMP MU tbg hanger and tie-in SSSV control line. MU landing jt. Land tbghead and check alignment..good. PU unland hanger, close annular. Reverse in 290bb1 of clean SW mixed with corrision inhibitor at 3 bpm. RUNCMP Land tubing hanger. RILDS. Drop Ball/Rod. Pressure up to 3500psi and set BOT S3 packer. Hold for 30 min. Swap cellar hoses around to test IA Test IA to 3500 psi for 30 min. (OK) Bleed down tubing and DCK valve sheared at 1000 psi. Rev cir 10 bbl through DCK valve RUNCMP FP IA using 65 bbl of 62 bbl diesel using LR BOTCIIW and set TWC and PT with LR to 500 psi OK. RD LR POST ND riser & BOPE POST ND 13-5/8" BOPE and riser Set 13-5/8" on trolley POST Installed 11" 5k X 4-1/16" adaptor with single new 4-1/6" 5k master valve Pressure tested adaptor seal to 5,000 psi and PT the TRSSSV control line to 5,000 psi for 15 min (OKj. POST Finish the Workover part of the project Make ready to move rig off of well. Hold PJSM on moving off. Move off well. POST RU crane to set BOP trolley on carrier POST Crew change. PJSM with crane operators. Review plan forward and hazards. POST Spot carrier close to crane. Make several picks off rig floor. Pick and place 13-5/8" BOP stack on carrier. RD crane. PRODOP Spot rig in behind wellhead. Start NU 7-1/16" BOP stack from top down utilizing rig blocks. At the flow cross at 1730hrs Last 12 hrs ASRC: Remote ESD stations were tested, working well, waiting to position them around job. Ran 602 3" hardline from tank farm to drill rig. Did not tie in to rig yet. Preparing Inlet to separator for initial UT inspection. Final inspections on upright tanks were Ok'd today. PRODOP Crew change with PJSM on plan forward and all hazards associated with NU BOPs. PRODOP NU BOPS Tested SSV at 5000 psi and it closed at 5.5 sec PRODOP Finished NU stack off well. PJSM on moving over well. PU Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 6/20/2006 00:00 - 03:00 3.00 BOPSU P 03:00 - 06:00 3.00 BOPSU P 06:00 - 06:15 0.25 BOPSU P 06:15 - 16:00 9.75 BOPSU P 16:00 - 20:00 4.00 BOPSU P 20:00 - 00:00 6/21 /2006 00:00 - 06:00 06:00 - 09:00 09:00 - 13:30 13:30 - 16:00 16:00 - 17:30 17:30 - 19:30 19:30 - 20:30 20:30 - 21:30 21:30 - 00:00 6/22/2006 00:00 - 03:00 03:00 - 05:00 05:00 - 06:00 06:00 - 10:30 4.001 BOPSU~ P 6.00 BOPSU P 3.00 BOPSU P 4.50 BOPSU P 2.50 MOB P 1.50 MOB P 2.00 BUNCO 1.00 BUNCO 1.00 BUNCO 2.50 BUNCO 3.00 BUNCO 2.00 BUNCO 1.00 BUNCO 4.50 BUNCO 10:30 - 18:00 7.501 BUNCO Page 10 of 47 Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase ~ Description of Operations PRODOP BOPE and move over well. Set down and tighten BOP's. PRODOP Install 4-1/8" 5k Wing valve. Secure stack at 3 points mid way down stack using chains Installed 4-1/16" SSV. Stabbed 2-3 ft SLB lubricator. Working on kill and choke lines. PRODOP Crew change. Line out crews on what needs done to start BOP test. Still have working at heights to consider and working around overhead loads. PRODOP Continue to NU choke/kill lines. MU Koomey control lines. Function tested all ram bodies, all tested correctly. Installed SSV remote on rig floor. Conducted body test on BOP stack to 4000 psi (OK) PRODOP RU to BOP. Installed offside IA valve and pulled VR plug. Finish rigging up transducers and other componets in cellar. PRODOP Begin pressure test BOP equipment as per UBD test procedure. 250 psi low, 3500 psi high as per AOGCC permit. Witness waived by Jeff Jones, AOGCC. Repair actuator assembly on Koomey PRODOP Continue to test BOP equipment as per well plan. PRODOP Crew change, PJSM. Change out lower 2-1/16" valve. Finish BOP test ASRC working on PLC tie-in. Finished BOP test. Repaired MP1 cir manifold valve. PRODOP RU to pull TWC with lubricator. Pulled same and RD valve crew. RU to run 4-1/16" flowline to outside cellar after locating the borrow pieces. PRODOP Rig on standby for APT meeting at PBOC Rig on standby with 2 people dry watch the rig and working on electrical breakers PRODOP Travel to location, Finish up with electrical breaker replacement. Held PJSM with slick line, determined hazards and midigation form same. PRODOP Hold PJSM with rig crew and slickline hands. Discuss safety issues, rig up, procedures, and more. RU SLB slick line. Bring tools to floor. PRODOP Run in hole with 3.60" od retrieving tool. Tag up solid at 370' SLM. POOH. Found ice packed in btm of tool. PRODOP Decide to rig up coil to wash through ice plug. Rig down SLB slickline unit to side of pad. Order 290 bbls 2% kcl with 2 ppb biozan. PRODOP Hold PJSMs with rig crew to discuss rigging up run coil. Rig up floor. Pick up lubricator and packoff. Unsecure coil from reel. Stab coil. MU coil connector. PRODOP Continue to prep coil to pump slack. Reverse circulate. E-line still at coil end. PRODOP MU nozzle assembly. Get on well. Run in hole circulating at 1 bpm. Pass through 370' with no problem. Continue in hole to 2500' displcaing well to 90 deg biozan. Circulate out of hole. PRODOP At surface. Get off well. Remove BHA. Set back injector. PRODOP RIH and retrieved rod & ball. Held crew change PJSM with SLB and Nordic. IA pressure at 150 psi, bleed down to allow for setting GLV Pulled DGLV # 2 PRODOP RIH to pull DGLV's. Pulled station 2 & 3. Run station No 5-4 Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ;From - To Hours Task Code 6/22/2006 10:30 - 18:00 7.50 RUNCOI~P 18:00 - 23:30 5.50 BUNCO~rp Srp 23:30 - 00:00 0.50 6/23/2006 00:00 - 01:45 1.75 01:45 - 03:45 2.00 03:45 - 06:30 2.75 06:30 - 09:30 3.00 BUNCO 09:30 - 11:45 2.25 BUNCO 11:45 - 12:00 0.25 BUNCO 12:00 - 16:00 4.00 CLEAN P 16:00 - 17:45 1.75 CLEAN P 17:45 - 21:00 3.25 CLEAN P Page 11 of 47 Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: NPT j Phase ~ Description of Operations PRODOP PRODOP PRODOP PRODOP PRODOP PRODOP PRODOP PRODOP PRODOP W EXIT W EXIT W EXIT 21:00 - 23:30 2.50 CLEAN P W EXIT 23:30 - 00:00 0.50 CLEAN P W EXIT 6/24/2006 00:00 - 00:30 0.50 CLEAN P W EXIT 00:30 - 01:00 0.50 EVAL P W EXIT 01:00 - 03:45 2.75 EVAL P W EXIT 03:45 - 05:30 I 1.751 EVAL (P I I W EXIT 05:30 - 07:00 I 1.501 EVAL I P I I W EXIT 07:00 - 07:15 I 0.251 EVAL I P I I W EXIT 07:15 - 08:20 1.08 EVAL P W EXIT 08:20 - 10:30 2.17 EVAL P W EXIT GLV. Took several runs for #4. Continue to run GLVs on slickline. Call for LRS to pump hot diesl down IA after setting #4. RU LRS pump truck. Hold PJSM. Circulate 50 bbls 120 deg diesel down IA. Take rtns out tubing. Continue to pump 50 bbls 120 deg F diesel down IA. Average 450 psi at 1 bpm. Rig down LRS. Continue with slickline work. Set GLV #5. Drop ball & rod assy. Allow to fall onto seat. Pressure test tbg to 2000 psi. Tested for 15 min. IA increased to 300 psi due to expansion Test OK. Bleed presure down. RIH and pulled ball and rod and retrieved the RHC plug. RIH with 3.625" 19ff Dummy whipstock. Tagged at 10,466 ft WLMD. Tight PUH, jarred 3 times with WL's oil jars and at 10,422 ft pulled free. POOH with dummy whipstock. LD WL PU injector, install Kendel CTC pull tested to 32k and BHI head up eline. While trying to PT the CTC found the suction on MP1 is plugged with solids. Thick black /grey material layed with frac sand Tested MP1, fine. PT CTC to 3800 psi (OK). PU BHI's MHA and BOT's motor and mills RIH with fill cleanout BHA. Bump past first GLM at 2795'. Continue in hole. Circ at 0.75 bpm and start washing downhole. Tag cmt at 10,449'. Increase rate to 1.61 bpm at 1450 psi. Wash through ok. Tag several "stringers" from 10,500' to 10,695'. Tag "btm" at 10,818'. This should be landing collar at 10,749'. Not sure what source of depth discrepency is. Will verify depths with a-logs. 34k# up wt, 18k# do wt at 10,750'. Circulate out of hole at 80%. At surface. Get off well. Lay down BHA. Continue to lay down clean out BHA. Rig up SLB slickline. Hold PJSM. Run dummy whipstock (19' x 3.625") to 10,466'. Work through tight spot. Continue to RIH to 10,657'. Stuck. Jared off lower WS assembly. POOH to re-pin GS to fish. Redress tool to fish WS. Run in hole. Latch fish. Jar free. POOH. Fish recovered. Rig down slick line. Flowline to ASRC is connected. The hardline to the tiger tank 1502 unions have been turned around the correct way. Held PJSM with SLB and Nordic crew on RU and running eline in the well. Identified the hazards as per energy sources and midigation all hazards RU SLB eline to run a 3.80" gauge ring and JB. RIH with 3.8" GR/JB. Tagged at 10648 ffTie-in to orginal CBL and confirmed linerjewerly (OK) Worked several times but unable to pass 10648 ff. POOH and recovered several pieces of rubber from junk basket. Printed: 7/31/2006 17:00:56 AM BP EXPLORATION Page 12 of 47 Operations Summary Report Legal Well Name: L5-28 Common. Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Hours Task Code NPT Phase Description of Operations ---Date From - To ~ -_ __! - !- --~- _ __ 6/24/2006 10:30 - 13:40 ~ 3.17 EVAL ~ N ~ SFAL W EXIT ~ RD SLB and moved truck. RU to SW and flushed all surface 13:40 - 16:30 2.831 EVAL N SFAL W EXIT 16:30 - 17:00 I 0.501 EVAL I P 17:00 - 19:00 2.00 EVAL P 19:00 - 20:00 1.00 CLEAN P 20:00 - 22:00 2.00 CLEAN P 22:00 - 00:00 2.00 CLEAN P 6/25/2006 00:00 - 00:45 0.75 CLEAN P 00:45 - 01:30 0.75 CLEAN P 01:30 - 04:00 2.50 CLEAN P 04:00 - 04:45 0.75 CLEAN P 04:45 - 07:10 2.42 CLEAN P 07:10 - 08:00 0.83 CLEAN P 08:00 - 08:15 0.25 EVAL P 08:15 - 10:00 1.75 EVAL P 10:00 - 12:00 2.00 EVAL P 12:00 - 13:45 1.751 EVAL P 13:45 - 17:15 I 3.501 WHIP I P 17:15 - 18:15 18:15 - 18:30 18:30 - 19:30 1.00 WHIP P 0.25 STWHIP P 1.00 STWHIP P 19:30 - 22:30 22:30 - 23:00 23:00 - 00:00 6/26/2006 100:00 - 03:15 3.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 3.25 STWHIP P W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT lines and CT to flush clean. RU CT to window milling BHA RIH with encoder open and 3.8" window milling BHA. Changed encoder on injector. Wt check 33k up, Op = 2.7 bpm at 3,000 psi Washing to bottom from 10,430 ft, Op = 2.6 bpm at 3,442 psi Tagged at 10,660 ft with motor work. Eline tagged at 10,648 ft corrected. PU clean. Cleaning out liner Taking lots of WOB and stalling. Biozan pill out, POOH to change mills At surface. Get off well. Unstab coil. LD BHA tools. Configure MW D tools after deciding to run the DPS with GR tool. MU BHA with Baker TT motor and 3.8" od "Pirranha" mill. Run in hole with BHA #3 Continue to run in hole with clean out assembly. Tag btm at 10652'. Pick up to 10540'. Log gr tie in to ccl/gr log. Subtract 4' correction. Tag btm. Mitl ahead from 10,651'. 3320 psi at 2.43 bpm. 31k# up, 14k# do wt. Mill to 10660'. Wt check ok. Continue milling ahead. Pick up every 10' to check weight. Milling with 200-300 psi mtr work, 10k-12k WOB. Noting a lot of cement over shaker. Tag something harder at 10,749'. Should be landing collar. Make two slow reaming passes up and down from TD to 10,640' Open EDC. Circulate out of hole. LD milling BHA Held PJSM on way forward on RU and running GR /JB, SCMT log and running an setting the WS at 10717 ft MD RU SLB Eline, RIH with 3.75" GR and tagged at 10747 ft MD, PUH LD GR/JB and PU 1-11/16" SCMT. and RIH and tagged at 10,750 ft Logged up found the major 4-1/2" collar at 10,709 ft ELMD. PUH logging from 10,750 ft 9,900 ft. POOH LD CMT and RU BOT whipstock Note. Conducted HSE walk through with Jerry Bixby, Herb Williams Lewis Cussack, DSO and DS Lead. The ATP will be signed off by Herb Williams and Area Manager as per agreed upon RIH with BOT whipstock Tied in and set TOWS at 10717 ft at 2 deg LHS, RA Marker ~ 10, 725.60 ft. Logged off and POOH RD SLB Eline Crew change. PJSM to discuss BHA makeup. MU BHA #4 (DIMS #11, window milling assembly). Stab coil. Surface test MWD. Get on well. Run in hole. Log gr tie in from 10,515'. Subtract 5' correction. Close EDC. Continue in hole. Tag WS at 10,715'. Mill ahead from 10,715'. 3000 psi at 2.53 bpm. 32k# up, 15k# do wt. Continue to time mill window. 6 minutes per 0.1 ft. WOB: 2-4k#. Printed: 7/31/2006 17:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/1 /2006 Rig Release: 7/27/2006 Rig Number: i Date From - To Hours Task I Code NPT Phase i -- ~- ~ -- 6/26/2006 00:00 - 03:15 I 3.25 STWHIP~ P I ~ WEXIT 03:15 - 04:13 0.97 STWHIP P WEXIT 04:13-19:00 14.78 STWHIP P WEXIT 19:00 - 19:15 0.25 STWHIP P WEXIT 19:15 - 19:45 0.50 STWHIP P WEXIT 19:45-21:45 2.00 STWHIP P WEXIT 21:45 - 22:30 0.75 STWHIP P WEXIT 22:30 - 23:00 I 0.501 DRILL I P I I PROD1 23:00 - 00:00 1.00 DRILL P PRODi 6/27/2006 00:00 - 03:15 3.25 DRILL P PROD1 03:15 - 05:30 I 2.251 DRILL I N I SFAL I PROD1 05:30 - 12:30 I 7.001 DRILL I P I I PROD1 12:30 - 14:30 I 2.001 DRILL P I PROD1 14:30 - 15:45 I 1.251 DRILL I P I I PROD1 15:45 - 16:30 0.75 DRILL P PROD1 16:30 - 17:15 0.75 DRILL P PROD1 17:15 - 18:15 1.00 DRILL P PROD1 18:15 - 18:45 0.50 DRILL P PROD1 18:45 - 22:00 ~ 3.25 ~ DRILL P ~ (PROD1 Rage 13 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations Mill ahead from .10,716' to 10,725 ft time milling. (12 ft window) At 10,725 ft, outside 7-5/8" casing. Still time drill to where the string mill is outside the 7-5/8" casing also. Op = 2.5 / 2.5 bpm at 3050 ps on bottom Vp = 324 bbls Drilliling rate hole at 0.2 fpm from 10,725 ft to 10,735 ft Back reaming 10,735 ft to 10,708 ft. Pumped high vis sweep down and followed by 2% KCL with corrosion inhibitor and 02 scavenger. Overdisplace by 70 bbls to ensure wellbore is free of biozan. Dry drift window. Hole smooth. Pull up hole. Log GR tie in. Subtract 2.5'. Tag TD at 10,732'. Circulate out of hole at min rate. At surface. Get off well. Unstab coil. LD BHA. W lndow mill and string reamer gauged 3.79" go, 3.78" no-go. Change out leaking lubricator under injector. This is the 2nd leak in three days with green o-rings. RU to pump a-line slack. Get on well. Reverse circulate to push slack back in to reel. Cut excess coil (44' coil and 6' wire). Re-head a-coil. Sim Ops: Test flow line from well head to separator. Verify valve line up. Fluid pack line. Low pressure test line and each valve from tree to separator to 400 psi. Hlgh pressure test line and valves to 3200 psi. All tested good. Pressure test coil connector. Connector leaking. Re-head e-coil. Pressure and pull test the same. Pull tested and PT the CTC (ok) Finish up the punch list for UBD. Working on the remote LEL monitor and calibrating. Making ready to conduct trial run with Pressure deploying BHA. Test wireline packoff with no wire to verify it will seal. Re-test with wire in pack off. Both tests good. Take section of 4-1/2" lubricator to Baker machine shop to install 1/2" port as per SLB & TOT approval. Make up lubricator assembly. Install hoses and sheave assembly. Install quick dump valves on all four remote ESD stations. Install quick dump hydraulic plumbing on primary ESD in cellar. Test all systems. All ok. Pressure test lubricator assembly. Good test. Hold PJSM UBD commission meeting with day crew. Discuss safety issues, ESD operation, communications, priority of crew safety over all else. Emphasized that each person has the right and obligation to report and /or shut down any un-safe activity or situation. Begin practice pressure deploy of BHA. Crew change/safety mtgs Identified that we will need a plattorm/ladder to safely reach the 2-3/8" slip ram locks ASRC continue to improve SSV ESD quick dump and alarm and get to 19 sec closure time. VECO fin load diesel tanks. SWS engrs and elec tech calibrate UTIM. Nordic find another scaffold and erect to reach the 2-3/8" slip ram locks. SWS Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 14 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To Hours ~ Task Code ~ NPT 6/27/2006 ~ 18:45 - 22:00 ~ 3.251 DRILL P 22:00 - 23:00 I 1.00 (DRILL I P 23:00 - 00:00 I 1.001 DRILL I P 6/28/2006 100:00 - 03:00 I 3.00 DRILL ~ P 03:00 - 06:00 I 3.001 DRILL I P 06:00 - 08:00 I 2.00 I DRILL ~ P 08:00 • 10:00 I 2.001 DRILL I P 10:00 - 12:00 I 2.001 DRILL I P 12:00 - 13:45 I 1.751 DRILL I P 13:45 - 15:30 1.75 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 17:00 I 1.001 DRILL I P 17:00 - 18:00 I 1.001 DRILL I P 18:00 - 19:00 I 1.001 DRILL I P 19:00 - 19:45 I 0.751 DRILL I P Spud Date: 6/2!2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase; Description of Operations PROD1 install HP double ball valves (for purge) on lubricator and PT ~ 3000 psi w/ no leaks, but WHP bled back thru kill line check. Set back lubricator PROD1 Install tree cap. PT stack thru kill line at 500 psi. Bleed off thru Baker choke and kill line check valve leaked. Circ thru kill line over the top at 3.8 bpm and recovered a 1 /2" x 6" piece of wood on shaker. Retest kill line check and held 750 psi jft. Bleed off pressures. PT new bleed off line from manual choke to tiger tank at 1000 psi Test rig evac alarm, H2S and LEL to verify all personnel knew the sound and could hear/see from their workstation PROD1 Review Deployment procedure. Make a dry run thru procedure. Modify a few steps to fit the task PROD1 Continue practice pressure deploy while MU build assy. Find several areas in procedure that need revision PROD1 Review pressure Undeployment procedure. Find too many faults w/ procedure as written to even practice. Need to revise procedure PROD1 Crew change. Hold sit down mtg with Blade, ASRC, WSL's to discuss deploy/undeploy procedures. Decide to eliminate "zero WHP" option. PROD1 Finish revisions to deploy procedure. Have SLB/Nordic day crew review procedure. Blade revising un-deploy procedure. Have SLB/Nordic crew review this procedure. PROD1 Time out for rig visit by S. Marshall, G. Christman, and H. Williams. Reviewed Hazid process for UBD project. Discussed steps used to get from Hazid up to the final ATP. Had informal meeting in Ops cab with most of crew. Discussed training for hands, project objectives, and a few specific equipment details, as well as a few of the procedures unique to UBD. PRODi Practice un-deploy with revised procedure with day crew. Had some trouble gettting BHA back through lower TOT double gate. Cycled annular while pulling on slickline and got through. PROD1 Practice deploying using revised procedure. PROD1 Go through start up valve position check list to ensure all valves are configured correctly. Call for L5 DSO. PROD1 Repair SLB weight sensor on injector. Replace 3' lubricator section under injector. Walk through valve positions with Blade and Nordic driller. PROD1 Stab coil. Test MWD. Get on well. Test lubricator against 2" combi's. PROD1 Crew change/safety mtg Review startup procedure w/ Hite crew. Final checks to be sure all valves are open. Open TRSSSV and hold 4200 psi. PVT 286 PROD1 RIH w/ BHA #5 while taking displacement returns to ASRC seperator. Park at 500' to open EDC. Break circ down CT w/ 2% KCI and continue RIH 0.4/100 w/ 74F surface temp, 47.5E on BHI at 500'. IA=O, OA =0 Catch fluid after 5 bbls 0.3/740. ASRC hold choke at 20/64" and WHP built to 1100 psi. Reduce and hold WHP at 700 psi 0.4/850. RIH w/ bit to 2100'. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 15 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 6/1 /2006 Rig Release: 7/27/2006 Rig Number: Spud Date: 6/2/2006 End: 7/27/2006 Date From - To Hours Task ;Code 6/28/2006 ~ 19:00 - 19:45 0.75 ~ DRILL ~ P 19:45 - 20:30 ~ 0.75 ~ DRILL ~ P 20:30 - 20:45 I 0.251 DRILL I P 20:45 - 21:45 I 1.001 DRILL I P 21:45 - 22:00 0.25 DRILL P 22:00 - 22:30 0.50 DRILL P 22:30 - 00:00 I 1.501 DRILL I P 6/29/2006 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:45 I 1.251 DRILL I P 03:45 - 04:45 I 1.001 DRILL I P 04:45 - 05:30 0.75 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 07:15 0.75 DRILL P NPT Phase ! Description of Operations L - --_ _ PROD1 __ _- - - PUH 4.7k w/ complete BHA thru TRSSSV at 1983', clean. RBIH thru 2100', clean PROD1 Continue RIH 0.4/860 holding 700 psi whp. PVT 268. Begin 5 bbls McOH down the IA PROD1 Park at 5500' to investigate excessive fluid return from injector packoff PROD1 Resume RIH 0.4/960/760 w/ 23/64" return line choke. Open GLG valve from flowline and see 2520 psi. Downstream of meter is 1380 psi and rate is 1.290 MMSCFD (set point for ESD is 1.0 MMSCFD). See probable opening of GLV top station at 1380 psi and pressure stabiiized at 1330 psi. Begin 1 bbl McOH every 15 min initially to prevent hydrates. KCI in 76 deg, gas in 89 deg, BHT(BHI) 114F, W HT at test unit 61 F Park at 8200' to check in/out liquid rate and getting avg 1.0 bpm 'extra' back, however choke at metering skid seems to cycle open/closed at this low of GLG rate PROD1 Log tie-in down from 10525' 0.4/770, Corr -10' PROD1 Park at 10564' and circ 0.3/630 thru open EDC holding 650 psi whp w/ 1930 psi IAP ~ avg 1.1 MMSCFD w/ return rate of 1100-1600 bpd on 38/64" choke. Move CT occasionally. Recovered 158 bbls so far PROD1 Increase GLG rate to 1.5 MMSCFD which stabilized the metering skid choke at constant open and incr'd the liquid return rate to 2400-3000 bpd w/ choke open to 40/64. Recovered 245 bbls by 2330 hrs. Incr pump rate to 1.0 bpm (1.0/800) and bhp stabilized at 3750 psi. Recovered 270 bbls by midlnite (100 bbls from the well) of which was about 1/3 each diesel, crude and water PROD1 Continue to stabilze well while circ 1.0/850 holding 650 psi on surface choke w/ 1.5MMSCFD GLG at 2000 psi IAP w/ avg 2500 bpd liquid return of which est 10% is crude. Incr pump rate to 1.25 bpm for 30 min, then Incr to 1.6 bpm and 1.75 MMSCFD. At 0120 hrs had recovered 177/380 bbls from IA. Incr GLG to 2.0 MMSCFD. At 0230 hrs had recovered 202/340 bbls and now at avg 0.4 bpm 'extra' PROD1 Incr GLG rate to 2.25MMSCFD. Wt chk 31.8k. At 0300 hrs incr rate to 2.75 MMSCFD Using two VECO trucks to RT 2% KCI. Total returns are 760 bbls and have recovered 240/340 bbls. Crude returns have tapered off to zero PROD1 Red pump rate from 1.6/1850 to 1.5/1600 holding 670 psi whp w/ 2.75 MMSCFD at 2145 psi GLG (supply is 2510 psi} w/ 0.4 bpm additional rate. DHP is 3500 psi/ECD 7.83 and both slowly dropping. Choke is 90/64" PROD1 Reboot ASRC PC and takes a while to get data back PROD1 Incr GLG rate to 3.5 MMSCFD. Wt chk 34k. 1.5/1420 w/ 650 psi choke pressure. DHP 3430 psi. Have recovered 313/340 and this doesn't count slippage (53 bbls). Ready to drill, wo crew change while fin staiblize well PROD1 Crew change and PJSM to discuss ops. PROD1 Shut off gas and KCL. Allow fluid flow to stabilze (stop). Close ECD. Bring gas and KCL back on. 3.5mmscf/1.6 bpm with 745 psi WHP. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 16 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ;Hours Task I Code NPT ~ Phase Description of Operations 6/29/2006 07:15 - 13:00 5.75 DRILL P PROD1 Run through window ok. Orient to HS. 1457 psi fs at 1.53 bpm in. Drill ahead from 10,735' Gas in: 4.5 mmscfd. Choke: 176/64. Gas Skid In: 2487 psi/116 deg F. Gas Skid Out: 2200 psi/64 deg F. WHP/BHP/ECD: 700/3216/7.07 ppg. 13:00 - 18:15 5.25 DRILL P PROD1 Drill ahead from 10780'. Hit a hard spot at 10,790'-96'. Having trouble getting weight to bit. Several overpulls picking up, up to 10k# over (normal up wt : 35k#). Increase pump rate to 1.7 bpm in w/ 2250 psi circ press fs. Finally work through. Continue drilling ahead. 18:15 - 21:40 3.42 DRILL P PROD1 Shoot FL in IA w/ DHD. Required SI of GLG while PU off btm at 35.4k and reduction in pump rate to 0.5 bpm. Showed FL at 1800' ?. Repeat 30 min later w/ the same result (1870'). Will use BHI temp sensor to try to identify while POH Resume drilling from 10826' and get into some higher penetration rate areas seperated by slow streaks w/ GR avg 25-35 api. Land build at 10840' and continue w/ LH turn. Getting higher than expected DLS of 45+ avg. Drill w/ 1.7/1960 w/ 176/64" (FO) choke holding 730 psi whp w/ max gas rate of 4.6 MMSCFD at 2150 psi IAP w/ 3285 psi DHP (7.15 ECD). Sit on a hard spot at 10891' for 40 min. Now at 97 deg on NBI 21:40 - 22:10 0.50 DRILL P PROD1 Wiper to window 35k off bottom, then a few very minor overpulls with one at 10780'. Hole is clean both directions 22:10 - 22:50 0.67 DRILL P PROD1 Attempt to drill ahead from 10891'. Red rate to 1.5 bpm and gradually add wt to 3k. DHP 3200 psi. After 40 min, able to resume drilling. Drill 4' more feet and complete the turn at 10895' 22:50 - 23:20 0.50 DRILL P PROD1 Wiper to window w/ minor overpulf at 10780'. Pull thru window at 0.5 bpm and was clean. Park at 10680'. SD pump, SI GLG. Open EDC. Resume 1.5/600 and open GLG at 4.5 MMSCFD 23:20 - 00:00 0.67 DRILL P PROD1 Attempt to determine FL in annulus by logging temp change at GLM's Log temp change from 20' below to 20' above GLM #5 at 10309' while circ thru open EDC at 1.43/670 and 4.5 MMSCFD GLG rate at 1'/min (one data pt/min). Initial 156.8F. Determine this is not an instantaneous reading (like a SWS a-line temp log) since the BHI sensor is encased in the tool body. Temp is 152.8E across GLM and 150.8E 10' above it 6/30/2006 00:00 - 00:10 0.17 DRILL P PROD1 No definitive change at GLM #5, still 150.8E 00:10 - 00:30 0.33 DRILL P PROD1 POOH to station #4 at 9121' at 60'/min (low gear-still above 30k string wt) and see 10F drop from 9700' to 9170' 00:30 - 01:10 0.67 DRILL P PROD1 Log from 20' below to 20' above GLM #4 at 9121'. Starting temp is 140.7E and ending temp is 130.6E 01:10 - 01:40 0.50 DRILL P PRODi RIH from 9100' at 50-60'/min 1.5/950 w/ 4.4 MSCFD at 2126 psi and monitor temp change. Temp change shows nothing abnormal and reacts too slow. DHP/ECD shows change at GLM #5 depth. RIH to 10500'. Decide to POOH at normal pulling speed (except to log at 50'/min from 100' below to 100' above each mandrel) under present dynamic conditions. Will then reverse the procedure while RIH to 10500'. Then, we should be able to use BHI data to determine which station is passing the gas. Based on the CT string wt it is obviously deep 01:40 - 03:15 1.58 DRILL P PROD1 POOH at normal pulling speed at 1.5/870 w/ 4.4 MMSCFD at 2128 psi holding 700 psi whp on full open choke while slowing Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date I From - To i Hours I Task I Code I NPT I Phase 6/30/2006 101:40 - 03:15 03:15 - 05:00 1.581 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 1.751 DRILL I P 05:00 - 05:30 I 0.501 DRILL I P 05:30 - 07:00 I 1.501 DRILL I P 07:00 - 07:30 0.501 DRILL P 07:30 - 09:30 I 2.001 DRILL I P 09:30 - 10:30 I 1.001 DRILL I P 10:30 - 10:45 I 0.251 DRILL I P I I PROD1 10:45 - 12:15 1.501 DRILL P PROD1 12:15 - 14:30 I 2.251 DRILL P PROD1 14:30 - 15:30 I 1.001 DRILL I P I I PROD1 15:30 - 18:00 I 2.501 DRILL I P 18:00 - 00:00 I 6.001 DRILL I P PROD1 PROD1 Page 17 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations pulling speed across each mandrel to 2600' and logging data based on time w/ BHI RIH at normal speed at 1.5/750 w/ 4.6 MMSCFD at 1970 psi holding 700 psi whp on full open choke while slowing speed to 50'/min across mandrels. Field scrutiny of data was inconclusive as to where gas is entering and will be left for others to interpret Park at 10500'. SI GLG w/ 2000 psi on IA. Circ w/ KCI at 1.6/600 while wo IAP to decrease and watch return rate go to zero POOH 1.69/1260 after IA stabilized at 1700 psi and returns were zero. Lost all returns at 4850'. Continue to maintain 520 psi WHP. Close TRSSV. Continue to pull out of hole. Hold PJSM in Ops cab to review un-deploy procedure. Dlscuss procedure line by line. Assign positions. Emphasize that we are not in a hurry, ask any question, any one can stop the job if not comfortable or procedure is unclear. Tag up. RIH to undeploy position. Undeploy BHA w/ 520 psi WHP. Note slight leak from swab valve. Grease both swab valves. Perform function test of all rams as required by biweekly ROPE test DHD crew rigged up to shoot fluid level in IA. Fluid level indicated at 2200'. This is close to a 6.65" od TRSSSV inside 6.8" ID casing. Discuss with GL design engineer John Kendra. We both agree that shallow return is due to the large od TRSSSV. So fluid level surreys will not work for this completion geometry. Hold PJSM in Dog House to discuss pressure deploy procedure. Pressure deploy lateral drilling BHA (0.8 deg mtr, for diesel, HTC bicenter). Stab coil. Test MW D. Get on well. Run in hole. Open TRSSSV. Come on line with gas down IA. Start at 1 mmscfd and slowly increase to 3mmscfd. Inject 1 BPH methanol. Getting erratic high level alarms from separator. These are false readings. Not sure why. Log GR tie in from 10,510'. Subtract 10' correction. Run in hole and log RA tag. Find RA tag at 10723'. Run in hole (smooth) Drill ahead from 10896'. 1800 psi fs at 1.57 bpm in. 4.7mmscfd gas with 2197 psi out of GL skid. WHP/BHP/ECD: 687/3450/7.45 ppg. Grind away on a hard spot at 10,910'. Continue grinding at 10910' using 2% KCI. Perform the normal routine of trying to get bit to drill such as vary pump rates, pick up occasionally, sneak-up on it, rotate orientor, etc. Did not spud and could not stack more than than 4.1k wob (BHI). See motor differential when wt is stacked so motor is assumed okay 1.59/1720 w/ 4.7 MMSCFD/2178 psi holding 720 psi whp on full open choke 3350 DHP/7.34 ECD at 152.8E BHCT. Adding 1 bbl/4 hrs McOH to GLG Elect to postpone swap to diesel until steady progress is being made. However, prepare pump #1 for diesel use Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 18 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours j Task ;Code NPT ~ Phase I Description of Operations i __ 7/1/2006 100:00 -01:45 1.75 ~ DRILL ~ P PROD1 ~ Continue drilling w/ KCI on a hard spot at 10911' 01:45 - 06:45 ~ 5.00 ~ DRILL ~ P ~ ~ PROD1 06:45 - 09:00 ~ 2.25 ~ DRILL ~ P ~ ~ PROD1 09:00 - 09:30 ~ 0.50 ~ DRILL ~ P ~ ~ PROD1 09:30 - 12:00 I 2.501 DRILL I P l I PROD1 12:00 - 12:30 I 0.501 DRILL t N I SFAL I PROD1 12:30 - 13:00 0.50 DRILL N SFAL PROD1 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 15:30 2.001 DRILL P ~ PROD1 15:30 - 18:00 ~ 2.501 DRILL P PROD1 18:00 - 19:00 I 1.001 DRILL I P I I PROD1 19:00 - 20:00 I 1.001 DRILL I P I I PROD1 20:00 - 22:00 I 2.001 DRILL I P I (PROD1 1.44/1200 w/ 4.6 MMSCFD at 2147 psi w/ 700 psi whp and 3234 psi DHP (7.07 ECD). Spud a couple times, max wt that can be put on bit is 3.7k Got a drill off and made a quick foot-encouraging ... DHP is as low as 3130 psi Test pump #1 for one hour after being rebuilt for diesel use No oil in samples, H2S in gas is 20-30 ppm. May have made another foot, but with cycling CT and stacking max wt counter shows 10916.5'. Est TD at 10914'. Time to trip for a bit change. Discuss how to handle KCL and gas rates with Blade. Decide to leave EDC closed. Circ out of hole at 1.36 bpm. Reduce gas from 4.5 to 3.0 mmscfd down to lmmscfd. Increase WHP per schedule to maintain BHP. At surface. TRSSSV in open position. Hold PJSM to review un-deploy procedure. Discuss assignments, hazards, operations. Also discuss this is the first flowing well un-deployment. Begin undeploy procedure. Discover small hydraulic leak in lower TOT blind shear ram open line. Continue to undeploy. LD BHA. Bit appears to be green. Hold PJSM in dog house with ASRC, Nordic, Blade to discuss procedure to repair hydr line. Write procedure to depressurize lines and BOP stack. Determine procedure to make weld repair. Discuss plan to re-pressurize system once repair is complete. Notify WCS station to hold all traffic to Niakuk. Hold PJSM with all hands to discuss procedure for bleed down etc. Bleed down GL skid, GL line to IA, BOP stack & well head, and 4" line to separator. Purge line with air. Weld repair line in cellar. Fill and pressure test line to 3000 psi. Hold PJSM to discuss pressure deployment and bringing the well back on gas lift. Review Blade procedure for same. Open TRSSSV. Repressure GL and return lines. Bring on gas. Change out motor to tight setting to provide more power to get through hard spot. WHP: 1100 psi. PU and deploy lateral drilling assembly. Test MWD. Run ih hole to 300'. Open EDC and circ w/ KCI. Continue in hole. Log tie-in to RA pip. Corr -11' Wiper to TD was clean. Took 10 bbls to catch fluid in CT. Start slow ream from 10900' and see first wob at 10909.6'. Had 2.Ok max by 10912.3'. Had wob loss w/ incr in dill and started to 'drill' at 10912.5' Drill from 10912.5' while break in bit slow 1.46/1480. Incr GLG to 4.5 MMSCFD at 2120 psi while open choke to full open at 128/64". Initial DHP is 3450 psi/7.5 ECD. Broke out of hard stuff at 10913.5' and drill a quick 3' to 10916.5'. PU w/ 5k overpull. Drill ahead w/ fast and slow streaks to 10926' Drill from 10926' at fairly steady pace w/ avg 25'/hr at Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 19 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task 'Code NPT Phase Description of Operations 7/1/2006 20:00 - 22:00 2.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PRODi 7/2/2006 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:05 0.33 DRILL P PRODi 01:05 - 04:00 2.92 DRILL P PRODi 04:00 - 04:15 0.25 DRILL P PROD1 04:15 - 09:30 5.25 DRILL P PROD1 09:30 - 12:00 2.50 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 15:00 2.50 DRILL P PROD1 15:00 - 15:15 0.25 DRILL P PROD1 15:15 - 17:15 2.00 DRILL P PROD1 17:15 - 19:00 1.75 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 19:50 0.33 DRILL P PROD1 1.46/1510 w/ 100 psi dill and 1.5k wob. GLG is still 4.5 MMSCFD ~ 2160 psi. FO choke has 705 psi by w/ 3325 psi DHP/7.3 ECD with both continuing to decline after the trip. Drill to 10947' before finding another hard spot. Continue drilling in and out of hard spots Penetration slowed at 10961' 1.46/1510/90L at 99 deg incl w/ avg 2k wob w/ 4.5 MMSCFD ~ 2150 psi on FO choke w/ 700 psi by showing 3270 psi DHP/7.15 ECD. Drilled to 10969' Continue drilling from 10969' w/ KCI 1.46/1520 w/ 4.5 MMSCFD Stacking. PU 40.2k. W iper to window was clean both ways Drill from 10971' w/ slow penetration 1.46/1480/90L w/ 2.5-3.4k wob w/ 4.5 MMSCFD ~ 2152 psi w/ 3298 psi DHP at 98 deg 0300=10977', 0400=10981' Wiper to window after seeing unexplained instantaneous drops in DHP to +/-3065 psi and then over a minute rising to 3600+ psi. Has occurred 4 times since 0130 hrs. Total return rate has increased by 100 bbls over the same time frame. No oil in returns. Assume porous area 10926-960' may be giving up a little fluid Drill from 10981' w/ slow penetration 1.43/1340/80L at 97 deg wl 4.4 MMSDCF @ 2150 psi w! 3230 psi DHP (varies 3050-3650). Drill to 11,000'. ROP averaging 2-3 FPH. Need +/- 20 feet to get out of hard rock. Decide to trip. Circulate out of hole. Leave EDC closed. Adjust fluid rate out to compensate for coil displacement removed from well (0.38 bbls per 100'). This should maintain a constant BHP while tripping. Slowly reduce GLR from 4.5 to 1.0 mmscfd. This allows the WHP to be reduced to facilitate undeployment. At surface. Hold PJSM with Nordic crew after noon change out. Review un-deploy procedure line by line. Discuss hazards. Assign tasks. Pressure undeploy drilling BHA. Flowing WHP: 1150 psi. Check motor and change bit (HYC Raptor bi-cent) Hold PJSM to review pressure deploy procedure. Gas flow from well caused some hydrate formation across the primary choke in the manifold building. (So that's why the WHP was increasing !) DSO bypassed choke. Discussed situation with ASRC and DSO. Will resume pumping methanol: 1 bbl every 3 hours while circulating with coil in hole, 1 bbl every hour when out of hole with gas flowing. Also, ASRC will run gas rtns through surface heater when coil is out of hole. Change bit (HYC raptor bi-cent). Check motor (ok). Pressure deploy BHA. Run in hole. Begin circulating KCL down coil at 1.53 bpm. Re-boot ASRC well test computer. Park at 10745'. Close EDC following procedure. Log tie-in, -11' Wiper in hole 1.43/650 w/ 4.0 MMSCFD at 2600 psi DHP was clean to 10970' and set down twice w/ TF 180 out at 90R. Also had 6k overpull. Orient to drilled TF and ream by at 2'/min w/ 0.4k wob to 10997' which is TD Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To ~ Hours ~ Task ~ Code ( NPT 7/2/2006 19:50 - 20:20 0.501 DRILL P 20:20 - 21:30 I 1.171 DRILL I P 21:30 - 21:50 I 0.331 DRILL I P 21:50 - 22:15 I 0.42) DRILL I P 22:15 - 23:15 I 1.001 DRILL I P 23:15 - 00:00 I 0.751 DRILL I P 7/3/2006 100:00 - 01:00 I 1.001 DRILL I P 01:00 - 02:00 I 1.001 DRILL I P 02:00 - 03:00 I 1.001 DRILL I P 03:00 - 04:20 I 1.331 DRILL I P 04:20 - 06:30 I 2.171 DRILL I P 06:30 - 06:45 I 0.251 DRILL I N 06:45 - 09:45 I 3.001 DRILL I N Start: 6/1 /2006 Rig Release: 7/27/2006 Rig Number: Phase PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 Page 20 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations Drill from 11000' 1.42/760/85L at 97 deg w/ 4.5 MMSCFD 2022 psi w/ DHP 2650 psi (5.8 ECD) Choke is 60/64" and WHP is 740 psi Drill from 11007' 1.42/820/85L at 97 deg w/ 4.5 MMSCFD ~ 2037 psi w/ DHP 2720 psi (5.94 ECD) Drill from 11023' 1.42/870/85L at 97 deg w/ 4.5 MMSCFD ~ 2054 psi w/ DHP 2760 psi (6.04 ECD) Have had high tool vibration when drilling. Need survey. PUH and were temporarily immobile 20' off btm w/ 10k over. RBIH. PUH w/ steady 41 k past 10980'. W iper to 10900' and normal up wt is 39k w/ this DHP. Ream back to TD 15.1k and catch survey Drill from 11028' 1.44/945/85L at 97 deg w/ 4.5 MMSCFD 2060 psi w/ DHP 2770 psi (6.04 ECD) Drill from 11042' 1.46/1010/85L at 97 deg w/ 4.5 MMSCFD ~ 2070 psi w/ DHP 2860 psi (6.2 ECD) Choke still 60/64"/whp=780 psi. Penetration rate slowly increasing Drill from 11060' 1.44/1 1 00/8501 60L at 97 deg w/ 4.5 MMSCFD ~ 2100 psi w/ DHP 3000 psi (6.5 ECD). DHP continued to climb to 3200 psi while drill to 11090'. No oil or incr in fluid rate. Penetration rate now is 40-60'/hr. Assume solids may be building up Overpull w/ no MW at 10990', 10960'. Pull to 45k at 10960' w/ no MW. RBIH twice and can't go down. Backream slow and able to continue OOH. Continue wiper to window 1.5/1350 w/ 3150 psi DHP. Red rate to come thru window. Circ 1.5/1200 while POH past GLM #5 to 10300' and was clean. See dramatic incr in DHP as BHA went past GLM indicating it is passing gas. RBIH 0.5/100, thru window clean. Set down at 10964' w/ TF 45 deg out and pickup 8k heavy. Orient correctly and finish wiper Drill from 11090' 1.45/1274/160L to level out at 91 deg in this high porosity zone w/ 1 k wob, no differential, +8.4k string wt w/ 4.5 MMSCFD ~ 2139 psi holding 700 psi on 85/64" choke w/ DHP at 3033 psi (6.56 ECD) Drill from 11112' 1.46/1285/85L to level out at 91 deg w/ 4.5 MMSCFD @ 2150 psi w/ 3167 psi DHP (6.94 ECD) holding 700 psi by on 85/64" choke Drill from 11132' 1.46/1275/80L to level out at 91 deg w/ 4.5 MMSCFD ~ 2145 psi w/ 3080 psi DHP (6.74 ECD) holding 700 psi by on FO 128/64" choke. Still having to surrey off bottom. No oil or increase in flow. Also, starting to drill w/ neg wt Unable to get surreys even when off btm. Pull up to 10970'. Shut down pump. Attempt survey. Bad G-totals. Will need to change tools. Circulate out of hole with reduced gas rate. Tool (DGS) started working again. Ran back outside window. Tool failed again. Pull out of hole for real this time. Maintain WHP, fluid and gas rates as per Blade recommendation to attempt to keep a stable BHP. Hold PJSM with rig crew. Tag up and position BHA for un-deployment. Reduce WHP to 1200 psi. Printed: 7/37/2006 11:00:56 AM BP EXPLORATION Page 21 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ;Hours Task Code -~_ _- ~ _ I!--- __ ~ NPT 7/3/2006 09:45 - 11:00 1.25 DRILL N DFAL PROD1 11:00 - 12:30 1.50 DRILL N DFAL PROD1 12:30 - 14:00 1.50 DRILL N DFAL PROD1 14:00 - 16:15 2.25 DRILL N DFAL PROD1 16:15 - 16:45 0.50 DRILL N DFAL PROD1 16:45 - 18:15 1.50 DRILL P PROD1 18:15 - 19:20 1.08 DRILL P PROD1 19:20 - 19:45 0.42 DRILL P PROD1 19:45 - 20:00 0.25 DRILL P PROD1 20:00 - 20:20 0.33 DRILL P PROD1 20:20 - 21:00 0.67 DRILL P PRODi 21:00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:20 0.33 DRILL P PROD1 22:20 - 00:00 1.67 DRILL P PROD1 7/4/2006 00:00 - 00:40 0.67 DRILL P PROD1 00:40 - 03:15 2.58 DRILL P PROD1 03:15 - 04:00 0.75 DRILL P PROD1 Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase Description of Operations Pressure un-deploy BHA. Continue flowing gas and injecting methanol. Hycalog Raptor bit in ok condition. Two broken nose cutters, similar to previous T-rex run. Grade 2-1. Swap out MW D tools. Test same on catwalk. MU "diesel" motor and set to 0.8 deg. PJSM. PU motor and MWD. Pressure deploy same. WHP: 1120 psi. Run in hole Log GR tie in from 10,730'. Subtract 12' correction. Bring pump on line and run in hole. Drill ahead from 11,159'. Initial readings before well has stabilized after trip: 660 psi fs at 1.46 bpm in. 3.5mmscfd in. WHP/BHP/ECD: 635/2551/5.59 ppg. Break bit in slowly with low WOB. Drill from 11186' 1.48/985/110L w/ 4.5 MMSCFD ~ 2040 psi w/ 2616 psi DHP (5.74 ECD) on F0 choke at 690 psi bp. Break thru at 11190' and drill at 100'/hr to 11216' at 94 deg and heading to 91 deg Concurrently have safety mtg re: swap to diesel Drill on another hard spot at 11216' while make final checks of diesel plumbing. Do a wiper and can't get above 11182' initially. Then, 10960' acts the same. Slow backream both and saw no MW to get by. Continue wiper to window. ASRC fin activating line heater. DHP 2738 psi Swap to 10 bbls mineral oil spacer (7.2 ppg) while fin wiper to window. Wiper back to TD. Had correct DTF at 10960' and nary a bobble. Had sli bobble at 11182', then clean to TD Swap to diesel (6.80 ppg) and incr rate 1.6/1550/160L while drill from 11216'. Fin load pits w/ 420 bbls KCI. Initially plan to use pump #2 for diesel and pump #1 for water. Had measureable, but minor amount of oil recovered from previous sweet spot Drill ahead and with mineral oil at bit 1.6/1620/170L w/ 4.5 MMSCFD @ 2107 psi w/ 2840 psi DHP (7.3 ppg). After diesel at bit had dramatic drop in pump press to 1.66/1020 Drill ahead at 40-60'/hr 1.6/980/85L and have first diesel back to surface. DHP has dropped to 2740 psi so start pinching back on choke. Pinching back increases whp. Need to reduce gas since over one hr DHP is now 2500 psi w/choke at 82!64" W iper to 11150' to check for cuttings. New up wt is 43k at 20'/min w/ 2500 psi DHP. Minor overpull at 11180', otherwise clean Drill from 11283' 1.66/1150/80L while cut back on gas rate to 3.5 MMSCFD ~ 1960 psi w! 50/64" choke holding 800 psi whp and 2550 psi DHP (5.61 ECD) By 11312' (TOS-note 252'/day) were stabilized at 3.5 MMSCFD w/ 44/64" choke holding 850 psi whp w/ 2820 psi DHP W iper to window was clean both directions Drill from 11312' with slower penetration rate at 1.65/1230/45L to hold 91 deg w/ 3.5 MMSCFD ~ 2088 psi, 2900-3000 psi DHP at 46/64" choke and 780 psi whp At 11354', penetration rate is less than 15'/hr (suspect dull bit) and DHP has stabilized at 3050 psi. Gradually open choke to Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 22 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To L5-28 L5-28 REENTE NORDIC NORDIC ~ Hours R+COM CALIST 2 Task PLET A Code i E NPT 7/4/2006 03:15 - 04:00 0.75 DRILL P 04:00 - 06:30 2.50 DRILL P 06:30 - 09:00 2.50 DRILL P 09:00 - 11:45 2.75 DRILL P 11:45 - 14:00 2.25 DRILL P 14:00 - 18:00 4.00 DRILL P 18:00 - 19:30 1.50 DRILL P Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase Description of Operations PROD1 reduce DHP to see if penetration rate can be improved. Also having to surrey off bottom PROD1 Pump 5 bbls mineral oil as a test to see if it improves slide. During some pickups it is hard to get back to bottom. It worked Continue drilling at a slow pace 1.64/1355/60L and holding 92 deg w/ 3.5 MMSCFD @ 2068 psi w/ 3010 psi DHP and 62/64" choke at 690 psi whp PROD1 Drill ahead from 11380'. 1430 psi fs at 1.65 bpm in. 3.0 mmscfd at 2041 psi w/ 62/64 choke. WHP/BHP/ECD: 682/3073/6.74 ppg. DHWOB: 0.3 to 0.77 k#. ROP: 15 to 60 fph. Difficult to get to btm, but drilling ok when on btm. PROD1 Drill ahead from 11,445'. 1230 psi fs at 1.67 bpm in/2.1 out. 3.0 mmscfd at 2054 psi in w/ 128/64 choke (wide open). WHP/BHP/ECD: 644/3028/6.64 ppg. PROD1 Short trip to window. Get hung up at 10,965'. Work pipe up and down. Pull to 46k# max. Unable to go down: Pump 5 bbl min oil sweep. Increase gas from 3.0 to 4.5 mmscfd to increase BHP a little. Begin pumping diesel with 2x concentration of DRA (4 gal per 290 bbls). Continue to work pipe. W Ith sweep around, began being able to run in hole. Then slowly pulled out of hole. No overpull at 10,965' second time through. Continue short trip up to GLM at 10,309'. Run back in hole. PROD1 Drilling in UBD Mode at 75R TF Of = 1.53/ 2.01 bpm Og = 3.5/3.53 mmcf/dy WHP 671 psi BHP = 3,089 psi w/ EDC at 6.7ppg CTP = 1388 psi on bottom. ROP at 25-30 fph when able to drill without stacking Having some problems getting back to bottom after PU due to stacking. Pumped 5 bbl mineral oil pill to see the results. No results Having trouble getting back to bottom. SD pump and well is pulling 0. 3 bpm out of tank farm. Run out of diesel allotment at the CTOP, hauling diesel from Colville until midnight. PRODi Continued sliding problems. Make short 1-2' drilling bursts then loose what little motorwork we have which is only 50-100psi at best. PU and work at length trying to return to bottom. Of = 1.60 / 2.00 bpm CTP = 1870psi on bottom Anne (BHP) = 3072psi 6.77ECD 19:30 - 19:45 0.25 DRILL P PROD1 Make short wiper trips and work back to bottom. Good indicator we are back on bottom is the differential pressures we see between the internal and external BHP. While off bottom during these small wiper trips the DPRESX is 360psi. While on bottom it climbs to +/- 440psi. This is our motorwork. Very slight amount. 19:45 - 20:45 1.00 DRILL P PROD1 Drill ahead with <1k WOB +/- 80psi MW. Drill to 11562' Make several small wiper trips and work to bottom. Drill to 11565'. Call AOGCC of pending BOP test. 20:45 - 00:00 3.25 DRILL P PROD1 TOH 44k off bottom pulled 20k over at 10962' RIH no problem, no MW seen. Continue TOH pumping at 1.6bpm shut-off gas Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 23 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code ! NPT Phase ' Description of Operations 7/4/2006 20:45 - 00:00 3.25 DRILL P PROD1 7/5/2006 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 00:30 0.25 DRILL P PROD1 00:30 - 03:00 2.50 DRILL P PRODi 03:00 - 06:00 3.00 BOPSU P PROD1 06:00 - 07:45 1.75 BOPSU P PROD1 07:45 - 09:45 2.00 BOPSU P PROD1 09:45 - 20:00 10.25 BOPSU P PROD1 20:00 - 21:50 1.83 BOPSU P PROD1 21:50 - 22:20 0.50 DRILL P PROD1 22:20 - 22:30 0.17 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL N PROD1 7/6/2006 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 05:30 4.50 DRILL N PROD1 05:30 - 09:20 3.83 DRILL P PROD1 09:20 - 09:30 0.17 DRILL P PROD1 09:30 - 12:00 2.50 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 injection at 10500'. We plan to rehead and perform Slack Management prior to next BHA so swap to KCL at 3200' to completely evacuate coif of diesel. Stop at 1900' and close SSSV. shut BOP #8 valve. Line up and bleed down WHP to TT. POH and tag up. RIH 2.7'. Monitor well. Call AOGCC again, no call-back Monitor well and bleed off migrating gas to TT. PJSM: Review Pressure Undeployment procedures and precautions. Pressure Undeploy BHA #16 Test BOPS Test lower 2" combi's and blind rams prior to opening for visual inspection. Crew change, PJSM and talked about procedures and way forward. Serviced valve. John Crisp wavered wittnessing the BOP test. Valve Crew enroute to set BPV. Bleed dow flowline pressure to ASRC tank. RU to set BPV in tubing hanger Set BPV and held OK. RU to conduct forthnight BOP test. Open bottom BOP doors and check condition of slip rams. OK. They had a very small bubble on rubber element. Replaced both blocks and door seals. Inspected body and no errosion was seen. Conducting forthnight BOP test. Testing ~ 250 / 3,500 psi. RU lubricator to pull BPV. Unable to totally unseat BPV. RD lubricator. Flush stack with water. RU again and work BPV out. Note 300psi on well. RD lubricator. Close MV and bleed pressure to Tiger Tank. Note: Having electical problems with gen #2 and #3. Fired up #3 to service #2 and #3 wouldn't produce any voltage. SD #2 added oil and firedback up and it quit producing voltage. So running only #1. Call for Rig #1 electrican. PU injector. Cut-off Kendall CTC and BHi UOC. PJSM review plan forward for Slack Mgmt and cutting coil. Insulate end of a-line. Stab on well. Bring up pump slowly. Only able to pump at 1.8bpm for 2minutes before seeing "brownout" conditions. SD pumping. Heard some movment of a-line. PT inner reel valve 400psi and 3500psi. Electrican working on identifying SCR/generator problems. Stab off well. E-line still hanging out of coil. Behead the SLB slickline unit. Revert back on downtime. Continue looking for actual problem with Gen #2 and #3 not being able to come on-line. Talking with IPS in Houston trying to trace out problem. Combination of fuses and PWM (Pulse Width Modular) board. Stabbed on well, conducted slack management (36 ft). Cut off 250 ft CT and megged line. Installed MHA, pulled tested to 30k and PT to 3500 psi. Set injector back and PU BHI's BHA with agitator PJSM on pressure deplying BHA Pressure Deploy BHA, wnt as per program design with 200 psi above TRSSSV RIH, open up to tank in in farm, ordered diesel trucks and lined out to pump. RIH to 500 ft and open EDC after equalizing. Fluid packed above SSSV and equalized across SSSV and locked Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 24 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase ! Description of Operations 7/6/2006 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 14:15 1.75 DRILL P PROD1 14:15 - 14:30 0.25) DRILL P I PROD1 14:30 - 16:23 ~ 1.88 ~ DRILL ~ P ~ ~ PROD1 16:23 - 18:30 I 2.121 DRILL I P I I PROD1 18:30 - 19:40 I 1.171 DRILL I P I I PROD1 19:40 - 22:15 I 2.581 DRILL I P I I PROD1 22:15 - 23:10 0.92 DRILL P PROD1 23:10 - 00:00 0.83 DRILL P PROD1 7/7/2006 100:00 - 00:40 I 0.671 DRILL I P I I PROD1 00:40 - 01:45 I 1.081 DRILL I P I I PRODi 01:45 - 03:05 ~ 1.33 ~ DRILL ~ P ~ ~ PROD1 03:05 - 03:50 0.75 DRILL P PROD1 03:50 - 04:00 0.17 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 open with 4500 psi RIH unbalancing wellbore starting at 1.2 mmcf/day. While RIH at 3,331 ft gas to to surface, inc Og to 3.0 mmcf/day Stopped at 10.550 ft Logged down to 10,572 ft Corrected to -12 Inc Of to 2 bpm and establish correct UB pressures at 3050 psi SD GL and fluid. Close EDC. RIH to pass WS. Open well and started Of at 1.6 bpm and Og at 3.0 mmcf/day. RIH and tagged at 11,563 ft Drilling directional in UB mode at 90R TF Of = 1.60/ bpm Qg = 3.mmcf/dy WHP 597psi BHP = 2700 psi w/ EDC at 5.85ppg CTP = 1,220 psi off bottom. Delta P on motor is 200 psi with 2.0 k WOB ROP at 35-40 fph constant Increased BHP to 2,900 psi using reduced GL volume and choke setting WHP increased to 2890 psi. CTW 13k w/ 2-3k WOB PU to reset BHI weight-on-bit indicator then couldn't get back to bottom. Lost 50' on each try. Wiper trip to 10800' no problem seen at 10560'. RIH start 5bb1 sweep downhole at 11100'. No problem at 10590' going in. RIH CTW 14k C~3 11600' 41'/min Drilling ahead f/ 11633' good wt transfer drilling 40-50' hr. Of =1.64 Og = 2.8mmcf CTP fs 2000psi 2-300psi MW WHP= 685 BHP= 3023 trending down Started pumping diesel treated with Lube 776 at 11650' Pumped 5bbl sweep at 11680' and again at 11750 prior to wiper trip. Wiper trip to 10800' no problems. Drilling ahead f/ 11750' 50-60'/hr w/ 1 k wob 150R TF Of in = 1.66 Of out= 2.12 Og in = 3.5mmcf Qf out= 3.2 CTP 2000 2-300psi MW WHP= 750 BHP= 3121 ' Continue drilling ahead f/ 11800' Of= 1.65 Og= 3.33mmcf WHP= 746 BHP= 3052 CTP= 2410 on bottom CTW= 12k W06= 1.34 ROP= 70-80'/hr! Wiper trip to window 34k pu wt (better than 43k seen priorr to addition of Lube 776 Drill ahead f/ 11850 TF 270R Of= 1.67 Op= 1792fs Og= 3.5mmcf in 3250 out CTW= 13.8k WOB= 1.3k ROP= 80-90'/hr 2-300psi MW Pump 5bbl sweep to time with wiper trip Wiper trip above window PU wt 33.3K No problems hole slick. Log tie-in +1' correction. RIH f/ 10760' ~ 25'/min 17.6k Drill ahead f/ 11960' to 12,100 ft Of= 1.65 Op= 1800fs Og= 3.5mmcf BHP= 3126 ECD= 6.88ppg Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ;Hours Task 1 Code ~ NPT 7/7/2006 104:30 - 06:00 I 1.501 DRILL I P 06:00 - 09:15 ~ 3.251 DRILL P 09:15 - 12:00 I 2.751 DRILL I P 12:00 - 13:40 ~ 1.671 DRILL I P 13:40 - 16:11 I 2.521 DRILL I P 16:11 - 18:30 ~ 2.32 ~ DRILL ~ P 18:30 - 20:35 I 2.081 DRILL I P 20:35 - 00:00 I 3.421 DRILL I P 7/8/2006 100:00 - 01:15 I 1.251 DRILL I P 01:15 - 04:40 I 3.421 DRILL I P 04:40 - 07:20 I 2.671 DRILL I P Page 25 of 47 Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase Description of Operations _ -- _ --- PROD1 CTW 13.7k WOB 1.53k ROP 80-90'/hr 300psi motorwork BHI tools NOT experiencing any downhole vibration problems last 12 hrs. PROD1 Wiper trip after drilling 150 ft at 23 fpm SD flow and pulled through window at 10, 713 ft. PUH to SO at 10,309 ft. RIH SD fluids at TOWS and RIH maintaining underbalance. Tagged at 12,100 ft PROD1 Drill ahead f/ 12,100 ft to12,250 ft in Wahoo 4.7 at 60L to 5L TF Of= 1.60 Op= 3.2mmcf/day Og= 3.5mmcf, Choke at 50/64", Ps = 624 psi BHP= 3,070 psi ECD= 6.60 ppg CTW = 15k WOB 1.4k ROP= 80-90'/hr Delta P(motor) = 300psi At 12,155 ft, ROP reduced from 90 to 40 fph, formation change Hole angle increased ,had to turn TF down. At 12,237 ft, started 5 bbl pill prior to making wiper trip. PRODi Wiper trip after drilling 150 ft lateral. CT up wt at 33k up and and 17k down PROD? Drill ahead f/ 12,250 ft to 12,332 ft in Wahoo 4.7 at 65L- 95RTF Of= 1.61 bpm, Og= 3.5mmcf, Choke at 50/64" to 100/64", Ps = 618 psi BHP= 2,956 psi ECD= 6.50 ppg CTW = 15k WOB 1.8k ROP= 20-78/hr Delta P(motor) = 200psi ROP will decrease as we climb in TVD. At 12,332 ft ROP slowed down to a crawl PROD1 Drilling at 80R to 135R TF in UBD mode WOB 2k, ROP slow trying to drill at the top of Wahoo 4.7 caprock and into Wahoo 4.8 porosity. Of= 1.61 bpm, Og= 3.5mmcf/day, Ps =630 psi BHP= 3,050 psi ECD= 6.8 ppg Delta P(motor) = 200psi Broke through cap rock at 12,384 ft (54 ft long at 95 deg) ROP picked up to 70 fph Started sweep at 12,386 ft PROD1 Wiper trip 33k avg pull wt. No overpulls through hard transition to zone 4.8 no other hole problems. RIH wt near btm 17k. tag btm 30k pick-up wt. PROD1 Drill ahead f/ 12396' Of= 1.62 free-spin 2146 psi Og= 3.5mmcf, choke ~ 70/64", Ps= 612 psi BHP= 3105 ECD= 6.81 ppg Not making any headway. WOB indicates 5k but no motorwork. Orient to 90L (180 from where drilled) and backream/ream through hard transition area several times. PROD1 Not making hole. Tried several TF's and small short trips. Applying WOB not a problem. Little or no motorwork. PROD1 TOH. Stop at 10,680'. Open EDC continue TOH. Advise town geo. Agreed to TOH for new bit and no flow test at this time. PROD1 Pressure undeploy BHA #17 whp= 1100psi Og= 3.4mmcf Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 26 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: ~ i Date ;From - To Hours Task Code ; NPT Phase ~ Description of Operations 7/8/2006 04:40 - 07:20 2.67 DRILL P PROD1 07:20 - 07:40 0.33 DRILL P PRODi 07:40 - 07:50 0.17 DRILL P PROD1 07:50 - 09:45 1.92 DRILL P PROD1 09:45 - 12:04 2.32 DRILL P PROD1 12:04 - 12:18 0.23 DRILL P PROD1 12:18 - 13:20 1.03 DRILL P PROD1 13:20 - 14:17 0.95 DRILL P PROD1 14:17 - 18:35 4.30 DRILL P PROD1 18:35 - 19:30 0.92 DRILL P PROD1 19:30 - 20:20 0.83 DRILL P PROD1 20:20 - 20:35 0.25 DRILL P PRODi 20:35 - 22:25 1.83 DRILL P PROD1 Of in= 0 Of out= 2.0 to 0.5 bpm. Crew change and PJSM with undeploying BHA while flowing. well. Changed out bit, motor(0.17 tolerance) 1.0 deg bend. agitator, packoft. PJSM on deploying BHA while flowing well Pressure deploy BHA as per SOP's with 1000 psi W HP and Qo = 0.5 bpm RIH to 200 ft and open EDC Og = 3.5-4.5 mmcf/day Of = 0.64/ 1.61 bpm Increased Of and Og while TIH to 1.00 bpm and 4mmcf/day. Logging tie-in from 10,550 ft. (-10 ft) 10,565 ft RIH to 10,705 Rand inc Of and choked well back to achieve BHP at 2500 psi SW I and RIH past whipstock area at 10, 713 ft to 10. 760 ft. Open well and start gas and liquid RIH maintaining underbalance of 2,700 to 3,150 psi Drill ahead f/ 12,393 ft to 12,550 ft in top Wahoo 4.7 started at 95RTF Since ROP has improved to 50 fph, turned TF to 150 R and drop hole angle to 90.5 deg Geologist says we shot through area. Need to drop to 87 deg and then leveled out at 90R Of= 1.64 bpm, Og= 3.5mmcf, CTP= 2,525 psi off bottom Ps = 617 psi, BHP= 2,900 psi ECD= 6.30 ppg CTW = 12k, WOB 2.20k ROP= 20-50/hr Delta P(motor) = 100psi. ASRC heater's electric motor for blower has quit. ASRC electrican has taken it off and looking for replacement. Pumped 5 bbl minerial oil sweep timed to wiper trip. Plan forward is to maintain 90.5 deg until further notice from town. W iper trip pulling 26'/min 1.65bpm C 2830psi. PU wt 36k off bottom. Pull to 10800' no problems. Wiper back to btm. 42'/min Drilling ahead f/12550' Of 1.63 bpm, Og 3.4mmcf, CTP= 2880 psi off bottom Ps= 761 psi, Vt= 62F BHP= 3268 psi, ECD= 7.2ppg CTW= 13300, WOB= 1 k ROP= 45-50'/hr Delta P (motor) 130 psi Experiencing higher pressure problem in separator, checking this out.... PU off-bottom sort out problem with separator. Sp increasing to 845psi. Lisburne header pressure at the choke has risen. Normal 450-500psi now 750-800psi. Pad Operator aware of problem and helping. Most likely hydrates, pumping methanol at separator and rigging up to apply heat at choke. Taking partial returns to Flowback tank. Slugging meth at the header. This is helping. Sp decreasing now to 748psi. Also trying to source a new 2HP electric motor for heater. Have Lisburne electrican checking availability at C Pad whse. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 27 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date !From - To Hours Task !Code NPT ~ Phase ! Description of Operations 7/8/2006 20:35 - 22:25 1.83 DRILL P PROD1 Running back in hole. Decrease gas lift to 3.Ommcf. 22:25 - 00:00 1.58 DRILL P PROD1 Drilling ahead f/ 12564' 128R TF Of= 1.59 Og= 3.3mmcf, CTP= 2940 psi Ps= 775 psi, Vt= 58.4 Vc= 78/64ths BHP= 3380 psi, ECD= 7.44PP9 CTW= 14.1 k, WOB= 1+k, ROP 65-70'/hr BHi tools vibration tolerances in the red/yellow zone Delta P 150-200psi Leaning on bit trying to decrease vibrations. Pumping 1/2bbl meth every 1/2hr 12596' open choke to 84/64th Ps= 742 psi Og 3.6mmcf trying to lower BHP. Now at 3387 psi, flow dill fluctuates from -.3 to +.7 Advised geo that we could be approching the maximum reach and still stay underbalanced. Will slowly inc gas up to 4.Ommcf At 12620' increase lift gas to 3.8mmcf and take choke to 90/64ths (note: the L-5 header choke is wide open at 104/64ths) Lisburne elec may have located a motor for heater. At 12659' increase lift gas to 3.95mmcf BHP= 3396 psi choke= 90/64 +.10 out rate. W06= 1k ROP= 50-70'/hr 7/9/2006 00:00 - 00:50 0.83 DRILL P PROD1 Continue drilling ahead f/ 12666' Of= 1.59 Og= 3.9mmcf BHP= 3382 psi Vp= 821 WHP= 849 Hp= 820 Return rate +.15 to .30bpm Slightly maintaining UB mode CTP= 2950fs 150-200psi MW W06= 1k ROP= 40-50'/hr Started 5 bbl minerial oil sweep for wiper trip Lisburne electrican working to replace heater motor. 00:50 - 02:45 1.92 DRILL P PROD1 Wiper trip to 10800' 36.4k PU 28'/min CTP= 2960 psi 02:45 - 05:15 2.50 DRILL P PROD1 Drill ahead f/ 12700' to 12800' TD Of= 1.62 Og= 3.9mmcf BHP= 3408 psi V p= 816 W H P= 844 Return rate +.30 to .50 bpm CTP= 3200fs 100psi MW WOB 1k 70-80'/hr 0340hrs blockage finally disappeared at header: Vp= 685 psi Vt= 57.7f WHP 714 psi but only lasted 1 hr. Now back up to 750psi Pumped 5 bbl sweep in prep for final wiper trip. 05:15 - 07:15 2.00 DRILL P PROD1 Wiper tripping back to lower GLM at 10307' at 25'/min 1.65bpm Pulled to 10750 ft seen some soilds at top of BHA, RIH to 10,850 to surge solids above WS. SWI and pulled above WS and started well flowing again. LPC electrican is installed a new motor on the line heater. Og = 3.5 mmcf/day Of = 1.54 bpm Pwh = Ps at 700 psi Ts = 56 deg, pumping MEOH down stream of separator. LPC DSO is cycling manifold choke to check for restrictions. 07:15 - 10:15 3.00 EVAL P PROD1 RIH and SWI, open EDC and Allowing wellbore to stablize prior to flow test period. 10:15 - 14:20 4.08 EVAL P PRODt Well stablized some what with fluid surges seen in the separator. Flow test Summary BHP = 2294 psi Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 28 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To 5-28 5-28 REENTE NORDIC NORDIC Hours R+COM CALIST 2 i Task PLET A Code E PT 7/9/2006 10:15 - 14:20 4.08 EVAL P 14:20 - 18:00 3.67 EVAL P 18:00 - 22:15 4.25 EVAL P 22:15 - 22:25 0.17 EVAL P 22:25 - 00:00 1.58 EVAL P 7/10/2006 00:00 - 03:50 3.83 EVAL P 03:50 - 06:30 2.67 EVAL P 06:30 - 06:45 0.25 EVAL P 06:45 - 07:30 0.75 EVAL P 07:30 - 10:45 3.25 EVAL P 10:45 - 1 f :05 0.33 EVAL P Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase ~ Description of Operations PROD1 WHP = 1297 psi at 35/64" choke WHT=61 F Ps = 676 psi at 82.1 F Ph = 672 psi Qo = 0.57 bpm = 820 bopd Ogl = 4.12mmcf/day Og = 0.69 mmcf/day Ow = 0 bwpd PROD1 Finished Step Rate #1 at 2300 psi. Open Choke to get<1700 psi FBHP PROD1 Crew changeout. Fresh Nordic crews brought them up to speed. Start 2nd phase of test. BHP = 1677 psi WHP = 820 psi at 82/64" choke WHT=56.1 F Ps = 740 psi at 98 F Ph = 740 psi Qo = .70 bpm Ogl = 4.28mmcf/day Og = .58 mmcf/day Ow = 0 bwpd SI lift gas at 2215hrs PROD1 TOH pumping min rate PROD1 Made it to 10265'. Appear to have problem with the injector's Counter Balance Valve. Mechanic called. No problem with injector. Problem seems to be paraffin on the coil. We can RIH back to starting point and POH about 15' past the previous depth then the injector's gripper blocks start to slip slightly. Start pumping .8bpm down the kill line and continue POH slowly. Helping some but will ojnly be able to POH <20'/min. PROD1 Continue TOH after flow testing well. Initially only able to pull +/- 20'/min gradually pipe came cleaner. Pull rate 50'/min after 8800'. Pulling normal by 8300'. Continue pumping .8bpm of diesel through kill line. Returns rates from well = 1.24bpm At 2000' swap to KCL pump 20 bbls and follow with diesel. Hold PJSM with all crews discussed procedures and hazards for Pressure Undeploying BHA. New crew members with Nordic walked through procedures and valve identification etc. Close EDC at 500'. Tagged up 164'? RIH 30' and POH tagged the same place. Counter may have got off from earlier problems. Good tag. RIH 2,7' PROD1 Pressure undeploy BHA #18 PROD1 LD motor, agitator and motor. Bit was fine with 1 gauge insert broken, micro dull characteristic. Clean floor in preparation of RU eline. PROD1 Held PJSM with Team and SLB Eline personnel on RU the lubricator Decided the way forward and how to load the pipe shed with the required equipment PROD1 Loading pipe shed with lubricator, bleeding gas lift line down to atmosphere PROD1 PJSM concerning PU tools and PT lubricator to 3500 psi. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 29 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: ~ j i Date ~ From - To ' Hours ~ Task ~ Code NPT Phase ~ Description of Operations 7/10/2006 10:45 - 11:05 0.33 EVAL P PROD1 11:05 - 12:30 1.42 EVAL P PROD1 12:30 - 16:00 3.50 EVAL P PRODi 16:00 - 21:30 5.50 EVAL P PROD1 21:30 - 21:45 0.25 EVAL P PROD1 21:45 - 22:00 0.25 EVAL P PROD1 22:00 - 00:00 2.00 EVAL P PRODi Discuss hazards and midigated with team. PU tools 3.785" tapered swedge, sheave and lubricator in the derrick. PT lubricator. Open BOP 17 & 18 and the WHP below the SV is 1573 psi. RIH with 1560 psi WHP with grease tubes. Tagged at 1,992 ft with 3.785" TS which is the TRSSSV with a 3.813" profile nipple. Tried several times to get past. Taking 300 to 400 Ib to get free after tagging. PUH, pulled tight once at 1800 ft and got real tight at 124 ft. Had to jar loose using wire. PUH and closed SV, (Note: top valve only closed 22-3/4 turns). Bleed pressure down to TT. RD tools and LD lubricator in the pipe shed. PU 3.5" wash nozzle and BHI's BHA. Stabbed on well and lined out to to flow through separator. Preheating diesel to 100 deg F and cleaning pits. Fill pits with clean 2% KCL. DSM also tried to changeout choke at sales header for a larger one but the single downstream valve would not hold. Same time RU LRS on off drillers side. Take lines to SLB cement line. PJSM with all crews incl LRS. Reivew plan forward. line-up on rig KCL and PT our lubricator to3500psi. Small leak on inner reel hardline. Good test. Line-up returns to TT, flood LRS lines and PT to 4000psi..god test. Check and line-up ASRC lines from W H to separator to header. WHP = 1150 psi . Open BOP #7 valve. Pressure up system too 1200psi and open BOP #lvalve. RIH to 220' pumping with LRS displace coil with 115-125 deg diesel taking returns through separator. TOH just before tag-up with coil. RIH with hot diesel washing paraffin. Maintaining equal out rates through separator. Of = 1.35 gpm Ot = 125 F Op = 3058 psi WHP = 1720 psi Tagged at 339' PU and work thru easy. Tag again at 380' had to work thru down to 386'. Okay to midnight at 800' 7/11/2006 00:00 - 03:15 3.25 EVAL N DPRB PROD1 Continue washing paraffin f/ 800' at 25'/min Of = 1.46 Of out = 1.40 Ot = 110-125 F WHP=1190 psi No problem going thru SSSV to 2010' pull up to 1970 wash back to 2020'. Increase to 35'/min to 2600' then increase to 45'/min to 3400'. No problmes. Seen. Shut down LRS and continue RIH at normal speeds. Pumped total of 250bb1s hot diesel. Have 90 bbls remaining. Tagged at 10662' uncorrected 10733' on ERAD counter. Should be top of whipstock. Thought of doing a CCL log to confirm depth but BHi CCL tools are not functioning correctly. Haven't been since their new Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 30 of 47 Operations Summary Report Legal Well Name: L 5-28 Common W ell Name: L 5-28 Spud Date: 6/2/2006 Event Nam e: REENTE R+COM PLET E Start : 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALIST A Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 7/11/2006 00:00 - 03:15 3.25 EVAL N DPRB PROD1 software upgrade several months ago. 03:15 - 04:30 1.25 EVAL N DPRB PRODt TOH to 2100' 04:30 - 06:15 1.75 EVAL N DPRB PROD1 TOH at 35'/min pumping at 1.5bpm with Little Red. Taking returns thru separator. Matching in/out rates from separator to Little Red rate. Displace remaining diesel in coil with 2% KCL. 06:15 - 07:00 0.75 EVAL N DPRB PROD1 OOH, close SV and depressure top half of BOP's 07:00 - 07:15 0.25 EVAL N DPRB PROD1 Held PJSM on RU and deploying SLB's 3.785" TS BHA. 07:15 - 09:00 1.75 EVAL N DPRB PROD1 PU 5-1/2" Lubricator with pump in sub and BOP's PU tool string with 3.785" TS. 09:00 - 15:45 6.75 EVAL N DPRB PROD1 RIH and small tag at 620 ft and then solid tag at 1992 f f (TRSSSV), same as yesterday. PUH an cycled SSSV twice without any results. PUH and tool became stuck at 625 ft. RU triplex pump and MEOH trailer. Pumped through pump in sub on rig floor to remove possible hydrates at 625 ft. Pumped 7 bbl MEOH. SD triplex, WHP increased to 2100 psi. Packed off above tool string. SD, after 10 minutes tool string jumped and lost SLB tool down hole. PUH 168 ft to 453 ft, confirmed tool is gone. Held PJSM on way forward. RU to bleed pressure down above SSSV to extract wire. Bleed down to 700 psi and WHP shot up to 1200 psi again. Held JSA on pulling wire out of hole under pressure. PU on wire, found the wire itself is tight in the hole at 1500 Ib. RU to pump meoh down tubing to try and free up wire. Pumped 1 bbl MEOH and pressure increased from 1,300 to 1,600 psi. SD and monitored WHP. In 10 min the WHP dropped to 1,300 psi. Pump MEOH down well and worked aline. Finish pumping the 6 bbl of MEOH. 15:45 - 16:00 0.25 EVAL N DPRB PROD1 Held PJSM on attaching the tanner hose to the grease head. Identified all of the hazards and midigated. 16:00 - 18:00 2.00 EVAL N DPRB PROD1 Attached tanner line to grease head and checked cable coming out of grease tubes. Pump MEOH in grease head 2nd collar from bottom. Having trouble pumping tanner/meoh into grease head. Pumping MEOH and conducting crew change. LRS pre-heating 100bb1s of diesel to 100F. 18:00 - 18:15 0.25 EVAL N DPRB PROD1 PJSM: review operations with oncoming crews. 18:15 - 23:30 5.25 EVAL N DPRB PROD1 Unable to pump fluids through tanner line. RU to apply steam to lower grease tube. Review procedure and write up THA and Manrider permit. Apply steam for 20 min and try to move cable. No success. Re-apply steam for 30 min no success. (only able keep man on bosans chair for that length of time before legs start to fatigue). Make several wraps with steam hose around tubes and point steam to most likely area of hydrate build-up and leave on for 45min. Still unable to move line. Back off pressure on grease tubes. Pump 10 bbls meth hopeing to to have some meth returns to slop tank. Nothing but small amount of low pressure gas. Shut down pumping meth. Slowly close upper swab valve to detect if a-line is even present in stack, after 19 turns felt some resistance. Fully re-open SV. 23:30 - 23:45 0.25 EVAL N DPRB PROD1 Have Banksman back in Little Red. RU same to valves #17/#18 on stack. 23:45 - 00:00 0.25 EVAL N PROD1 PSJM with team. Review plan forward for pumping diesel. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 31 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours- Task Code NPT Phase Description of Operations 7/12/2006 00:00 - 01:30 1.50 EVAL N DPRB PROD1 Clear rig floor and cellar of personnel. Little Red PT lines to 4000 psi. Begin pumping 116 bbls heated diesel down tbg. Keeping slight tension on a-line and monitoring for any returns from grease tubes. Of = 1.5 bpm Ot=190F Intial Op = 1500 psi Final 1560 Initial WHP = 1335 psi Final 1375 After pumping 100 bbls seen some movement on a-line. Continued pulling a-line and it exited the lubricator. Spring actuated ball valve closed. Also closed upper blind rams. Continuned pumping diesel. Appears we recovered all of the e-line. 01:30 - 02:00 0.50 EVAL N PRODi RD LRS. Close MV. Lower SW will only close 5-1/2 turns, upper SW 20-1/2 turns. Must be some wire still in stack. Bleed off stack/lubricator pressure to slop tank. 02:00 - 02:15 0.25 EVAL N PROD1 PJSM review plan foward to LD lubricator and W L BOP's. 02:15 - 03:30 1.25 EVAL N PROD1 Back off Otis connection PU lubrricator. Still have wire showing. Strip out 20' wire then LD lubricator on catwalk. LD BOP's. Cut a-line, make a loop and stuff line back in, install nightcap. Open blind rams. Remove nightcap then remove e-line. End on wire shows where blinds cut and held the wire. Still hjave some wire in stack that's preventing SV's from being closed. Reinstall nightcap and blowdown stack to Tiger Tank. 03:30 - 06:00 2.50 FISH N PROD1 With T-bar try to fish remaining wire in BOP stack. Have recovered 1 -30' section and working on another. It too 30'. Cycle SV's 17-1/2 on upper 12-1/2 on lower. Still have a little more. Little huh, recovered all remaining wire. Huge birds nest which clearly shows the end that was made up to head. 06:00 - 07:00 1.00 FISH N PROD? Crew change folllowing TL Meeting. PJSM on RU W ireline to fish BHA 07:00 - 16:50 9.83 FISH N PROD1 MIRU wirel ine BOP Held extra PJSM on RU lubricator on riig floor. Parked Eline truck on location and left well control equipment on rig floor. Headed up wireline. Had SLB wireline change out. Held PJSM with new crew. Finish RU lubricator and fishing tools. PT lubricator and BOP's to 3000 psi .Leak on bottom /lower combi's equalizing port. Held PJSM on harzards changing equalizing plug with only on well barrier. Alerted town on present operations Changed out 16:50 - 17:00 0.17 FISH N PROD1 Flooded lubricator and PTlubricator & BOP's to 3000 psi. (OK), bleed pressure down to 1500 psi. Open MV 23-1/2 turns. 17:00 - 18:00 1.00 FISH N PROD1 RIH with fishing tools Didn't tag the fish but did tag the top of the SSSV (3.83" No/Go) POOH and closed SV's 23-1/2 turns. RU to fluid pack the well above the SSSV to equalize across to open function test and determine integrity. 18:00 - 18:20 0.33 FISH N PROD1 PJSM: crew changeout with Nordic and slickliners. Get everyone lined out again. 18:20 - 20:15 1.92 FISH N PROD1 Bleed down lubricator to TT. PU lubricator and changeout SL tools. PU tools to check SSSV. Pressure up well to 700psi. Open SSSV. WHP stabilized at 520 psi. 20:15 - 21:15 1.00 FISH N PROD1 RIH w/ SL and Flapper Checker. Tagged SSSV as expected. TOH and check tools. Looked normal. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To i Hours Task I Code ~ NPT Phase 7/12/2006 21:15 - 23:25 2.17 FISH ~ N PROD1 23:25 - 00:00 ~ 0.58 ~ FISH ~ N ~ ~ PROD1 7/13/2006 00:00 - 01:30 1.50 FISH N DPRB PROD1 01:30 - 02:00 0.50 FISH N PROD1 02:00 - 02:20 0.33 EVAL P PROD1 02:20 - 03:45 1.42 EVAL P PROD1 03:45 - 06:00 2.25 EVAL P PROD1 06:00 - 09:45 ( 3.751 EVAL I P 09:45 - 10:10 I 0.421 EVAL I P 10:10 - 11:30 1.33 EVAL P 11:30 - 12:30 1.00 EVAL P 12:30 - 13:30 1.00 WHSUR P 13:30 - 14:10 I 0.671 STWHIPI P 14:10 - 18:00 I 3.831 STWHIPI P 18:00 - 18:20 0.33 STWHIP P 18:20 - 19:50 1.50 STWHIP P 19:50 - 22:00 I 2.171 STWHIPI P 22:00 -23:20 1 1.331 STWHIPI P 23:20 - 00:00 ~ 0.67 ~ STWHIP~ P 7/14/2006 100:00 - 02:00 I 2.00 I ST W H I P I N PROD1 PROD1 PROD1 PROD1 PROD1 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 DPRB PROD2 Page 32 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations PU 3.50" LIB w/ 3.70" centrilizer. RIH tagged at 10720' SLM POH. LIB showed perfect 3/4" doughnut on lower side. PU overshot RIH. Latch fish give it 3 licks wth oil jars. TOH w/ 9001bs extra weight. TOH slowly with fish. Recovered all SLB tools. LD same. MU 3.785" drift 5' spacer bar and 3.69" centrilizer on SL RIH with gauge to 10700' no problems. POH PU 3.70" dummy whipstock. RIH to 10700'. POH WHP has stayed fairly steady all night at 475 psi. POOH, closed SSSV and WHP stablized at 550 psi with no bleed down. Cycled SSSV and tried it again without success. Talked with WL and decided on way to RU DWS and 3.785" tapered swedge 5 ft above DWS RIH and tagged lightly at 10714 ft. POOH bleed off WHP = 800 psi Held PJSM with crew and slickliners on RD and the associated hazards. Determined way forward with the agrrement that anyone can stop the job. RD slickline tools and lubricator. PJSM on RU eline lubricators and tools Closed MV, bleed pressure down and open SV's. Conducted BOP function test Pressured up and closed SV and open MV. PJSM on PU & RU SLB Eline lubricators and WS. Covered several operational issues and midigated said issues. Tallked about several HAZARDS and how the said hazards will be midigated and at the end of the PJSM, all the crew agreed on the way forward. Flound the SV are leaking, Serviced the MV, closed MV and equalized pressure and open the SV and serviced both.Found the rigs grease gun failed to operate. Called for grease crew to service MV and SV's. Checked tanner injection port (OK) Rehead rope socket eline through grease tube. PJSM with oncoming crews .Review plan forward with BTT and SLB crew. RU SLB side entry sub and BOP's. PU SLB lubricator w/ grease tube assemblies. Rethink picking up SLB / BTT tools. MU SLB tools into lubircator. PU whipstock assembly. Install 2 pip tags 8.60' below TOW then lower into stack down to upper SV. Install C plate and dog collar. PU lubricator with SLB tools. Unable to get high enough to MU tools. Close MV and open upper SW. Lower whipstock 3' more into well. Insure WS highside is scribed to SLB WPP tools. MU tools, MU lubricator. Pressure test lubricator. O-ring leaking between BOP's and pump-in sub. Strip lubricator up and separate tools. Remove WS and put in Changeout o-ring. Pressure test lubricator to 3000 psi. Okay Open well WHP 700psi. RIH with 3-5/8" x 4-1/2" BTT Monobore Whipstock assembly up wt 650#. Taking weight at 245' and stopped at 258'. Pulling 2-400# over. Try several times to easily RIH but continually setting down. Forget this. POH Tag up at surface with BTT whipstock assembly after being Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 33 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: L ell Name: L e: Name: From - To 5-28 5-28 REENTE NORDIC NORDIC Hours ~ R+COM CALlST 2 Task j PLET A Code' E NPT 7/14/2006 00:00 - 02:00 2.00 STWHIP N DPRB 02:00 - 02:15 0.25 STWHIP N DPRB 02:15 - 04:50 2.58 STWHIP N DPRB 04:50 - 08:00 3.17 STWHIP N DPRB 08:00 - 09:10 1.17 STWHIP N DPRB 09:10 - 10:30 1.33 STWHIP N DPRB 10:30 - 11:20 0.83 STWHIP N DPRB 11:20 - 13:10 i.83 STWHIP N DPRB 13:10 - 16:15 3.08 STWHIP N DPRB 16:15 - 18:20 2.08 STWHIP N DPRB 18:20 - 19:05 0.75 STWHIP N DPRB 19:05 - 20:00 0.92 STWHIP N DPRB 20:00 - 20:10 0.17 STWHIP N DPRB 20:10 - 22:30 2.33 STWHIP N DPRB 22:30 - 22:45 0.25 STWHIP N 22:45 - 00:00 1.25 STW H I P N Spud Date: 6/2/2006 Start: 6/1/2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase Description of Operations PROD2 unable to RIH past 258'. Shut in well. Bleed-off lubricator pressure. Break lubricator. Separate SLB/BTT equipment. Breakdown whipstock and put back into protective sleeve. LD same. LD SLB tools and lubricator. PROD2 PJSM: go over plan forward for pressure deployment of motor / mills. PROD2 Pressure Deploy BHA #20. Test tools, good. Open well. WHP 787psi PROD2 RIH pumping 1.5bpm ASRC ambient temp diesel and cleaning out at 20-30'/min. Quickly took wt at 527' then pass thru. Come back to surface and start again. Washing at 20-30 fpm pumping ambient diesel and taking returns to ASRC separator Q(in/out) 1.52 / 1.49 bpm at 2,369 psi. Tagged hard at 510 ft / 999 ft, CT weight and 150 psi motor work., WHP = 542 psi. Pushing something to bottom. RIH to 1,935 ft. PROD2 PUH to re-wash tubulars PROD2 RIH to spot xylene in the wellbore from 2000 ft to surface. Held PJSM with LRS and team on pumping xylene and 180 deg F diesel. Q = 1.5 / 1.52 bpm at 2,461 CTP PROD2 Open well to LRS and pump Xylene down CT annulus. Q at 1.bpm ,Started POOH with CT while bull heading xylene W HP climbed from 550 psi to 900 psi.. Vp = 17.1 bbls, flushed surface lines with 3 bbl of diesel. Finish POOH to allow xylene to soak. Xylene in place at 11:00 hrs Table talk with crews on spill and H2S responses. PROD2 Let xylene soak. WHP 500 psi. Hooked up LRS to CT and PT to 3500 psi. PROD2 Open ASRC inlet and fluid packed the CT with 40 bbl's of 180 deg F. RIH at 40 fpm with 190 deg F diesel coming out the mill. Pumped 100 bbl of 190 deg F diesel to 3800 ft. SD and switch to pumping ambient diesel from tank farm. RIH to 10,713 ft, touched WS PROD2 POOH pumping 1:1 while POOH. Finished hauling in all of the diesel with 1 % Lube 776. Started 190 deg F diesel down CT at 4,600 ft. SD pump and SWI pulling through SSSV. POOH laying in hot diesel. Tag up at surface. PROD2 RIH w/o pump slowly looking for any problem areas. 20'/min to 600' 30'/min to 1000' looks ok. Bring LRS back on line at 1.5 bpm taking returns thru ASRC 1:1 lay-in hot diesel back to surface. PROD2 POH laying in hot diesel back to surface. Displace hot diesel from coil with 20 bbls KCL pump 10 of that at surface to flush system. PROD2 PJSM: review pressure undeployment procedures and hazards. PROD2 Close SSSV bleed down tbg to TT. SSSV still leaks by. Continue on with Pressure Undeployment of BHA #20. PROD2 PJSM: review procedures and hazards for RU of SLB a-line equipment. Also discuss plan for PU BTT whipstock. PROD2 Install nightcap on well. Close MV and lower SV open upper SW. (this will make maximum room for PU whipstock assembly) PU 10' lub section and mousehole it. Bring up 30' Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: i i Date From - To Hours ~ Task Code NPT Phase 7/14/2006 22:45 - 00:00 1.25 ~ STW HIP N PROD2 7/15/2006 ~ 00:00 - 01:35 ~ 1.58 ~ STW HIP N ~ DPRB ~ PROD2 01:35 - 04:10 I 2.581 STWHIPI P I I PROD2 04:10 - 06:15 2.08 STWHIP N DFAL PROD2 06:15 - 08:45 2.50 STWHIP N DFAL PROD2 08:45 - 11:00 I 2.251 STWHIPI N ( I PROD2 11:00 - 12:45 I 1.751 STWHIPI P I I PROD2 12:45 - 14:30 I 1.751 STWHIPI P I I PROD2 14:30 - 17:00 I 2.501 STWHIPI P I I PROD2 17:00 - 20:00 I 3.001 STWHIPI P I I PROD2 20:00 - 22:15 2.25 STWHIP P PROD2 22:15 - 22:45 0.50 STWHIP P PROD2 22:45 - 00:00 I 1.251 STWHIPI P I I PROD2 7/16/2006 100:00 - 00:25 I 0.421 STWHIPI I I PROD2 00:25 - 16:30 I 16.081 STWHIPI I I PROD2 Page 34 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations section lub on skate. Hang sheave/e-line and take to max height in derrick. PU lub with 'blue' winch. MU SLB's side-entry-sub and BOP's Continue MU SLB equipment. PU BTT Gen II Monobore Whipstock. Install 2 pip tags 8.60' from TOW. Install pressure gauges. MU to SLB tools insure WS highside is scribed to SLB W PP tool. MU lubricator. PT to 3000psi. Bleed down to 300psi. OPen SV and MV. Open SSSV. RIH with whipstock no problems. Wt check at 1950' 8501bs. Go past SSSV w/o problems. RIH to 10420' then SLB had dead short. Checked wiring in collector..checked good. Problem is downhole. POH OOH, closed lower SV and MV. Depressured lubricator and pop off well. Clamped Tools and LD Eline running tools. BOT check Whipstock (OK). Eline trouble shooting electrical short. Found a rubber boot in the head that had a slot cut into it. This was the cause of the electrical short. Meg line and check tool string continuity. RU tools. Confirrned scribe line with DD set at high side. Stabbed on well. PT to 2000 psi OK. Bleed down to 500 psi and open well.. RIH with WS Took 100 Ib to get the WS through the SSSV, RIH Tie-in useing log from setting the firstWS. CCL to TOWS is 14.01' On depth work a-line numerous times to put WS tray to highside. Initially at -71 deg then flopped to +60. W PP tool not working as good as expected. See better results working tools between 10687' and 10672.9' taking HS TF from +60 to +7. Set whipstock, good surface indication and weight loss. TOWS at 10687' TOH. Same time bleed down well to 0 psi. Packer seems to be holding good. Hold PJSM to review LD SLB tools and equipment. At surface close both Sw V's. Flush lubricator with water to TT. Pop off lubricator. LD logging tools. Cut-off 2-3/8" Kendal CTC and remove BHi UOC. Read head with 3" CTC Pull test to 35k. PT to 3000 psi PU 3.8" DSM (3.8" No/Go) and 3.79" String mill. RIH taking returns to ASRC. Open EDC at 436 ft Tie-in at HRT. Corrected to -3 ft 10, 555.1 ft RIH to TOW and tagged at 10,687 ft Circulate well to 2% KCI through open EDC at 2.20 bpm With 190 bbl's pumped, SD pump and lined out to tiger tank Cir 210 bbl and checked fluid condition (ok) turn to pits. SD pump and closed EDC Circulating and mixing biozan at 2 ppb Op = 2.47 bpm at 2880 psi off bottom, 28.6k up and 17k down RIH and work down on WS. Started window at 10, 687 ft Time mill at 0.1 ft / 6 minutes (1 fph) Op=2.53/2.60 bpm CTP = 3600 psi. MW= 300-500 psi. Appears to have exited 7-5/8" csg at 10697'. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date I From - To I Hours I Task I Code I NPT 7/16/2006 116:30 - 18:20 ~ 1.831 STWHIP 18:20 - 19:30 I 1.171 STWHIP 19:30 - 21:45 I 2.251 STWHIP 21:45 - 21:55 0.17 STWHIP 21:55 - 23:30 1.58 STWHIP 23:30 - 00:00 0.50 WHSUR 7/17/2006 00:00 - 06:00 6.00 WHSUR P 06:00 - 11:00 I 5.00 I W HSUR I P 11:00 - 14:00 ~ 3.00 DRILL P Page 35 of 47 Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: Phase I Description of Operations PROD2 Drilling formation f/ 10,697' to 10,707 ft Op (in/out) = 2.54 / 2.60 CTP = 3,500 psi MW = 300 psi WOB = 3-4k Window 10,684.5 ft to 10, 697 ft (12.5 window) Rat hole from 10,697 ft to 10,707 ft Geo sample showed 40% formation. Will correct WS setting depth after logging RA marker. PROD2 Reaming window area from 10, 707 ft to 10, 680 ft Some motor work at 10, 697 ft, 10, 687 ft and 10, 684 ft Reamed again, clean. Dry tagged at 10, 707 ft. OPen EDC PROD2 Conduct fluid swap to clean 2% KCL POOH chasing clean KCL to surtace. PROD2 OOH, conducted PJSM on LD milling BHA and PT BOPE PROD2 Flow Check, Pop off well. Chuck Sheave with AOGCC will witness BOP Test. Window mill 3.8" Go and 3.79" No/ Go. String mill 3.79 No Go. Good wear pattern on window mill. Remove 3" MHA and dress wire for slack management. Change CT packoff Greasing valves on BOP stack PROD2 BOP Test with Check Shieve with AOGCC PROD2 BOP test with AOGCC witnessing. 200psi low / 5 min 3500 psi high / 5 min. Inspector Chuck Shieve has some concerns with having 1 manual valve and check valve on Kill Line side of stack rather than 2 manual valves. He will discuss this with AOGCC further this morning. PROD2 Continue testing ROPE after crew changeout. Testing choke maniflod. Check pre-charge pressures on N2 bottle. Make needed repairs to Koomey tri-plex pump. Perform accumulator drawdown test. PROD2 Cut 3" MHA. Prep end of coil. RU and pump slack management. Cut off 55' of coil. Meg ohm coil -good. Trim EOP. Install CTC pull test to 35k. Install 8Hi UOC Same time: PSJM review plans and hazards/midigations for adding 2nd valve on Kill Line side of BOP stack. 14:00 - 20:00 6.00 BOPSU P PROD2 By request of AOGCC installing an additional manual valve on the Kill Line side of the BOP stack. There will be 2 manual valves and a check valve. 20:00 - 21:15 1.25 BOPSU P PROD2 PT the the new installed manual gate valve and repositing of the check valve to 250 / 3500 psi. 21:15 - 21:35 0.33 DRILL P PROD2 Held PJSM on hazards associated with PU BHA and deploying in underbalance mode. 21:35 - 22:45 1.17 DRILL P PROD2 PT CTC to 3500 psi. PU BHA#22, confirmed scribe. Cir 7 bbl biozan out of CT. Set counter to 60.1 ft Set 2-3/8" combi's on BHI's BHA. PT to 900 psi . 22:45 - 00:00 1.25 DRILL P PROD2 RIH to 200 ft, open EDC and circulated KCL to pit 1 to ensure no biozan is in the flow stream. Wellbore with clean KCL. Set BOP valve in correct position. ASRC started GL down IA at 3.00 mmcf/day w/ 1/2 bbl MEOH every 1/2 hr. Started diesel down CT at 0.5 bpm. Lightly tagged the SSSV at 1,983 ft, PU and went through. RIH working to line out surface equipment. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 36 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 7/17/2006 22:45 - 00:00 1.25 DRILL P PROD2 Having trouble with FCV on the GL skid, unable to open electrically from control room. 7/18/2006 00:00 - 01:00 1.00 DRILL P PROD2 RIH while working on FCV on gas skid 01:00 - 01:15 0.25 DRILL P PROD2 Tie in from 10,530 ft down. Corrected -11 ft TOWS ~ 10,687.40 ft RA Marker ~ 10,696 ft BOW ~ 10699.40 ft 01:15 - 02:30 1.25 DRILL P PROD2 Work CT and trouble shoot the problem with the FCV on GLT. Gas to surface BHP dropped to 3400 psi Checking power and logic going to the GLT from the ASRC control room. Only gas going down IA is the FCV leakage. Checked the electrical and logic command going to the GLT and its OK. Pull the panel of the FCV electrical box on the GLT skid and ckeck the input voltage. Timed out breaked in the electrical panel on the GLT skid. Reset and cycled the FCV and it work, Set GL set point at 16% for 2.5mmcf/day and back in business. Ogl = 3.2 mmcf/day Og = 0.72 mmcf/day BHP 3721 psi Of = 1.61 bpm WHP = 517 psi and Ps = 487 psi with choke set at 128/64ths SD GLT and Op. Closed EDC 02:30 - 02:50 0.33 DRILL P PROD2 Set TF at 10R RIH tagged bottom at 10,707 ft Open inlet to separator, started GL @ 3.5 mmcf/day and fluid ~ 1.65 bpm. BHP at 3132 psi 02:50 - 04:07 1.28 DRILL P PROD2 Drilling build section in Wahoo 25.1.1 at HS TF. Having trouble holding TF with reactive torque and CT movement. ROP & WOB smooth out at 10, 720 ft Op = 1.68 / 1.6 bpm WHP = 549 psi to 800 psi Well unstable, lowering choke setting to get well stable from CTP = 2,070 / 2,100 psi WOB = 2.0 - 4.5 klbf ROP 20 - 50 fph. BHP = 3127 -2850 psi Ogl = 3.5 mmcf/day. Red Og to 2.8 mmcf/day after unloading well.and closed choke to 58/64 04:07 - 12:00 7.88 DRILL P PROD2 Drilling build section in Wahoo 25.1.1 at 10-30L TF. Op = 1.64 bpm WHP = 760 psi CTP = 2,085 / 2,500 psi WOB = 2.0 - 4.5 klbf ROP 20 - 80 fph. BHP = +2900 psi,. Leveling out Ogl = 2.8 mmcf/day. choke ~ 40/64 Mini wiper trip at 10,745 ft to 10,714 ft Increased the Ps and open the choke to 128/64ths. Using the separator pressure to assist in controlling BHP. RA Marker at 10,694.3 ft TOWS at 10,685.7 ft 12:00 - 12:15 0.25 DRILL P PROD2 Drilling build section in Wahoo 25.1.1 at 240 TF. Op = 1.68 bpm WHP = 680 psi CTP = 1140 / 1224psi WOB = 1.8 klbf ROP 50-80 fph. BHP = 2900 psi Leveled out the last 3.5 hrs Og = 3.12 / 3.22 mmcf/day. choke ~ 128/64ths Increased the Ps and open the choke to 128/64 the Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT Phase ~ -_ -_ 7/18/2006 12:15 - 14:50 2.58 (DRILL ~ N ~ DPRB ~ PROD2 14:50 - 17:30 2.67 DRILL P PROD2 17:30 - 18:30 1.00 DRILL P PROD2 18:30 - 20:45 I 2.251 DRILL I P I I PROD2 20:45 - 21:30 0.75 DRILL P PROD2 21:30 - 22:00 0.50 DRILL P PROD2 22:00 - 23:30 1.50 DRILL P PROD2 23:30 - 00:00 0.50 DRILL P PROD2 7/19/2006 00:00 - 02:14 2.23 DRILL P PROD2 02:14 - 02:25 0.18 DRILL P PROD2 02:25 - 02:30 I 0.081 DRILL I P I I PROD2 02:30 - 03:00 I 0.501 DRILL I P I I PROD2 03:00 - 03:35 I 0.581 DRILL I P I I PROD2 03:35 - 03:40 I 0.081 DRILL I P I I PROD2 03:40 - 03:55 I 0.251 DRILL I P I I PROD2 03:55 - 04:00 0.08 DRILL P PROD2 04:00 - 04:50 0.83 DRILL P PROD2 Page 37 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations Work tight hole at 10,950 ft. Pulling up to 56k and working down to zero Unable to turn orienter. Pumped 5 bbl mineral oil sweep. Worked CT down.Pumped another 6 bbl ' Working CT between 35k down to -9k Pumped 3 bbl mina) oil pill. Reduced Op to 0.5 bpm and worked CT with no movement. Ordered 50 bbl of sweep from MI's plant After being given permission from SLB, pulled up to 62k and pop free. POOH. Tagged up, RIH 2.7 ft Crew change TL meeting. Following TL night crew conducted a PJSM and talked through pressure undeploying BHA. Weil was left flowing to ASRC at 1.00 mmcf/day and WHP at 700 psi. Pressure undeploy BHA with well flowing to ASRC. Job went good. LD BHA. Change out bit, motor and orienter. PJSM on pressure deploying BHA. Talked through procedures and mitigated hazards Pressure deploy BHA Set counters to 60.60 ft RIH RIH and adjust diesel and gas rates Tie-in at 10,530 ft and correct to GR at 10, 524 ft. Corrected -2 ft RIH to 10, 650 ft and SD pump and. close inlet at separator, orient TF to HS and RIH. Start Pump and wash to bottom at 1.60 bpm. BHP at 2800 psi. Tagged bottom at 10, 970 ft. Backed ream to check hole condition Pulled little tight at 10,902 ft Clean trip back to 10, 971 ft.ange the setting to 0.8 deg bend) Drilling invert section at 80 L TF. Building up to 107 or 110 deg to enter mudstone at 8728 ft TVD NBI at 104.6 deg. Of = 1.57 / 1.34 bpm; CTP = 1300 psi Og = 2.44 / 4.13 mmcf/day (still unstable) WOB = 1.06k at an ROP of 50 fph BHP = 3080 psi WHP = 855 psi Taking alot of CTW to get 0.88 k WOB. Did a PU at 10,9999 ft and was clean. except at 10,960 ft there was a slight bobble Drilling invert section at 80 L TF to enter mudstone at +107 deg at 8,728 ft TVD. Last survey at 10,966 ft 106 deg hole angle Of = 1.55 / 1.81 bpm; Increase choke from 44 to 48/64. Flow rate out cycling CTP = 1293 psi. IA/OA = 2025/ 0 psi Og = 2.42 / 3.45 mmcf/day. WOB = 1.1k at an ROP of 50-70 fph BHP = 2956 psi WHP = 620 psi Losing motor work PU for short wiper PU clean to 10, 970 ft. RIH to 11, 014 ft Drilling invert section at 80 L TF to enter mudstone at +106 deg at 8,728 ft TVD. Of = 1.55 / 1.55 bpm CTP = 1293 psi. IA/OA = 2025/ 0 psi Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 38 of 47 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To '; L5-28 L5-28 REENTE NORDIC NORDIC Hours R+COM CALIS 2 Task PLET TA Code ~ E NPT ~ Start Rig Rig Phase Spud Date: 6/2/2006 : 6/1/2006 End: 7/27/2006 Release: 7/27/2006 Number: Description of Operations 7/19/2006 04:00 - 04:50 0.83 DRILL P PROD2 Og = 2.42 / 2.3 mmcf/day. W OB = 1.1 k at an ROP of 20-70 fph BHP/ECD = 2893 psi/ 6.36ppg WHP = 640 -700 psi Stacking, PU for small wiper trip at 11,043 ft due to stack and very little motor work 04:50 - 05:15 0.42 DRILL P PROD2 Wiper trip to base of WS PU 35k and clean pick ups CTP lower on the BHA due to larger tolerance setting on motor. Still seeing some small over pull at 10, 960 ft otherwise clean to 10, 750 ft Clean trip back to bottom. 05:15 - 05:40 0.42 DRILL P PROD2 Drilling invert section at 80 L TF Of = 1.55 / 1.55 bpm CTP = 1293 psi. IA/OA = 2025/ 0 psi Og = 2.42 / 2.3 mmcf/day. WOB = 1.ik at an ROP of 20 fph BHP/ECD = 2893 psi/ 6.36ppg WHP = 640 -700 psi ROP slow with stack and little WOB 05:40 - 08:45 3.08 DRILL P PROD2 Drill lateral/invert to 11,120'. 1070 psi fs at 1.59 in/2.01 out. Choke: 128/64. DHW0B:3.0-3.5k#. WHP/BHP/ECD: 781/3031/6.69 ppg. GL: 2.59 mmscfd at 2049 psi. 104 -107 deg incl at bit. Continue turn to west while holding build angle. Enter mud stone at 11,092' to 11,112'. Drill to 11,120'. 08:45 - 09:30 0.75 DRILL P PROD2 Short trip to window. Hole appears to be smooth. 09:30 - 14:30 5.00 DRILL P PROD2 Drill ahead from 11,120'. 1100 psi fs at 1.56 in/1.86 out. Choke: 128/64. DHWOB: 1.0 - 2.0 k#. WHP/BHP/ECD: 721/3057/6.75 ppg. Gas: 2.53 in / 2.89 out mmscfd at 2042 psi at 60 deg f. ROP variable. Appear to be in and out of hard spots with fast drilling in between. Pump 5 bbl mineral oil sweep. 14:30 - 15:30 1.00 DRILL P PROD2 Make wiper trip to outside window. Log gr tie in. Add 3' correction. Run back in hole. Hole smooth in both directions. 15:30 - 16:45 1.25 DRILL P PROD2 Drill ahead from 11,250' to 11,270'. TF 90R. Getting a lot of vibration near btm. Having a lot of trouble keeping the BHA moving. Discuss with town. Decide to trip for agitator. Discuss tripping plan with ASRC. 16:45 - 19:00 2.25 DRILL P PROD2 Circulate out of hole. Pumped 24 bbl KCL down CT and displaced to bit with diesel 19:00 - 19:10 0.17 DRILL P PROD2 Zeroed counter and RIH 2.7 ft Deployment depth 19:10 - 19:20 0.17 DRILL P PROD2 PJSM on pressure undeploy BHA while flowing well to ASRC. Mitigated hazards concerning poor communication, over head lifts and pinch points. Review the procedures and planned the way forward 19:20 - 20:50 1.50 DRILL P PROD2 Pressure undeploy BHA with well flowing 20:50 - 22:20 1.50 DRILL P PROD2 LD BHA, will re-run motor, changed motor bend to 0.8 deg and PU rerun agitator . 22:20 - 00:00 1.67 DRILL N PROD2 Found a diesel smell in the rigs loft, investigated and found diesel leaking out of the kelly hose which is located in the loft. Pulled kelly hose to rig floor. Kelly hose full of diesel, unable to drain at this time. leave hose on floor for obseration and rebuild valve # MM10 to standpipe. 7/20/2006 00:00 - 01:30 1.50 DRILL N SFAL PROD2 Repair standpipe valve and pressure test to 3,500 psi Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/1 /2006 Rig Release: 7/27/2006 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 7/20/2006 01:30 - 01:45 0.25 DRILL P PROD2 01:45 - 03:30 1.75 DRILL P PROD2 03:30 - 06:00 2.50 DRILL P PROD2 06:00 - 06:20 0.33 DRILL P PROD2 06:20 - 06:45 0.42 DRILL P PROD2 06:45 - 10:45 4.00 DRILL P 10:45 - 11:45 1.00 DRILL P 11:45 - 13:30 1.75 DRILL P 13:30 - 15:00 1.50 DRILL P 15:00 - 17:15 2.25 DRILL P 17:15 - 19:00 1.75 DRILL P 19:00 - 20:15 20:15 - 23:40 23:40 - 00:00 7/21 /2006 00:00 - 01:40 01:40 - 02:15 02:15 - 02:30 02:30 - 04:15 1.251 DRILL I P 3.42 DRILL P 0.33 DRILL P 1.67 DRILL P 0.58 DRILL P 0.25 DRILL P 1.75 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Page 39 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations PJSM following rig repair Pressure deploy BHA Set counters, RIH to 200 ft and open EDC Log gr tie in is casing f/ 10,530'. Subtract 11' correction. Continue to run in hole. Set down briefly at 11,093' (btm of mud stone). PU and run through ok. Tag btm at 11,267'. Drill ahead from 11266'. 1460 psi fs at 1.48 in /variable rate out (slugging). DHWOB: 0.7 to 1.5 k#. WHP/BHP/ECD: 855/2917/6.46 ppg. Gas (mmscfd): 3.0 in/3.33 out. INC/AZM/TF: 96.5/235.0/1208. ROP averaging 40 fph. Level off inclination to 90 deg. Wiper trip to window. Hole very smooth. Re-boot SLB computer at window. Run back to btm. Hole smooth Drill ahead to 11,445'. Weight transfer since short trip has deteriorated. Having trouble even getting BHA to btm. Make several short wiper trips. Vary pump rate, running speed. Scratch our way to 11,449'. Discuss with rig team. Decide to pump 90 bbls diesel with MI 776 (one hour of drilling/pumping). ROP and weight transfer improved a little. Downhole vibration greatly reduced. GR shows a lithology change.. Apparently we are in another hard interval. Drill ahead from 11,471'. 1550 psi fs at 1.45 in/1.45 out. DHWOB: 1.4 k#. WHP/BHP/ECD: 847/3029/6.7 ppg. Gas (mmscfd): 3.08/2.96 out. Continue to try and drop angle to increase TVD. ROP slowly increasing. Drilling w/ 758 TF from 11,419 ft to 11,538 ft Of = 1.51 / 1.81 bpm, Qo is slightly cycling CTP = 1450 psi. IA/OA = 2076/ 0 psi Og = 2.97 / 3.11 mmcf/day. WOB = -1.5 to-2.5 k at an ROP of 5-22 fph BHP /ECD /WHP = 2990 psi/ 6.60ppg / 750 psi. BH vibration all in the red at this time After conversing with town, decided to lower BHP to 2,700 psi with inc. GL to 4.00 mmcf/day and reducing Ps. Target TVD ss at 8,688 ft and a MD of approximately 11,620 ft W iper trip to window. Pulled tight in the first 30 ft off bottom. Worked clean POOH Clean to 10, 750 ft. RIH to 11,538 ft. After conversing with town, conduct trip due to low ROP after tagging bottom on wiper trip BHP at 2600 psi, WHP 753 psi while conducting wiper trip. Stacked out at 11,400 ft and 11, 408 ft Having trouble RIH beyond 11,400 ft (hole angle drop off) to 11,528ft. Unable to get to 11, 538 ft POOH, pulled tight at 11,450 ft until 11, 400 ft, then pulled smooth, Pulled tight with motor stalled at 11,090 ft. Worked through on second attempt. POOH. PJSM on pressure undeploying. Pressure uneploy BHA while flowing well to ASRC at W HP = 900 psi LD BHA as per SOP's PJSM on pressure deploying and servicing SV in the process Pressure deploying BHA Well flowing at 46/64" choke WHP = Printed: 7/31/2006 11:00:56 AM • • BP EXPLORATION Page 40 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase ! Description of Operations I 7/21/2006 02:30 - 04:15 1.75 DRILL P PROD2 872 psi OI = 864 bfpd 60% oil 04:15 - 06:15 2.00 DRILL P PROD2 RIH, open EDC at 200 ft 06:15 - 06:30 0.25 DRILL P PROD2 Log gr tie in from 10530'. Subtract 8' correction. Close EDC. Run through window. 06:30 - 07:15 0.75 DRILL P PROD2 Continue to run in hole. 39k# up, 13k# down wt near btm at 1.40 bpm in. 07:15 - 10:15 3.00 DRILL P PROD2 Drill ahead from 11,538'. 690 psi fs at 1.3 in/1.9 bpm out. DHWOB: not working ?. Having to really push on it to make it drill. WHP/BHP/ECD: 983/2606/5.78 ppg. Gas:(mmscfd) 4.0 in/4.74 out. TF high side to try and level off. ROP slowly increasing. Level off at 8788' TVD. 10:15 - 12:15 2.00 DRILL P PROD2 Drill ahead from11,622. Perform weight check. 29k# up, 13k# do wt. 1080 psi fs at 1.54 in/2.0 out. DHWOB: 0.5 - 0.8 k#. WHP/BHP/ECD: 1013/2701/6.01 ppg. Gas: 4.1 in/6.0 out. Able to drill at 30-40 fiph with -4k# coil wt (this is pushing very hard). Still not finding best porosity zone, but ROP seems to be slowly increasing, with adequate wt transfer for drilling. DHWOB looks low at 0.5k#. Pump a 5 bbls mineral oil sweep. Gas rate has been slowly increasing from 11,610' md. Oil rate is also increasing. Hopefully this is mostly solution gas associated with increased oil production. 12:15 - 13:15 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. No evidence of mudstone either in or out. Ran right to btm with good wt transfer. 16k# do wt, 36k# up wt once back at 11,700'. 13:15 - 16:00 2.75 DRILL P PROD2 Drill ahead from 11,700'. 950 psi fs at 1.55 in/2.18 out. DHWOB: 0.5 - 1.Ok#. WHP/BHP/ECD: 977/2580/5.72 ppg. Gas: 4.08 in/7.08 out. Plan is to drop slowly at 88-89 deg inc. Had some good drill breaks between 11,700 and 11,780'. Gained 3 deg incl in one drill break. Gas is leveling off at 9.0 to 10.0 mmscfd. 16:00 - 19:12 3.20 DRILL P PROD2 Drill ahead from 11,800'. 19:12 - 19:24 0.20 DRILL P PROD2 Conversed with town on adding tube 776. They approved following wiper trip for data collection by SLB prior to adding tube 776. Wiper trip 19:24 - 19:35 0.18 DRILL P PROD2 Drilling w/ 85 TF from 11833 ft to 11835, ft Of = 1.55 / 3.4 bpm CTP = 1400 psi. IA/OA = 1935/ 0 psi Og = 2.44 / 8.56 mmcf/day. WOB = 1.OOk on BHI DPS. ROP 20-30 fph. CT is stacking up while adding WOB to drill from 6 k to -4k BHP /ECD /WHP =2700 psi 19:35 - 20:34 0.98 DRILL P PROD2 Drilling w/ 25L TF from 11,835, ft. Need to build TVD from 8695 ft to 8687 ft by 12,129 ft Started pulling diesel with 1 %Lube 776 out of tank farm. once Lube 776 exited bit, WOB improved Of=1.55/3.4 bpm CTP = 1400 psi. IA/OA = 1935/ 0 psi Og = 2.44 / 8.56 mmcf/day. WOB = 1.OOk on BHI DPS. BHP /ECD /WHP =2700 psi With Lube 776 in well bore, ROP PU to 90 fph and WOB improved from negative CTW to 9k of CT weight avialable to Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 41 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/21/2006 19:35 - 20:34 0.981 DRILL P PROD2 +drill with. ROP's increased from 25 fph to 80 fph with 7k CT wt. 20:34 - 23:10 2.60 DRILL P PROD2 Drilling w/ 30L-20L TF from 11,835, ft. Of = 1.68 / 2.7 bpm. Steady 0:5 bpm of production CTP = 2000 psi. IA/OA = 1935/ 0 psi SD GL Og= 12.68 to 9.4mmcf/day. ROP 20-60 FPH WOB = .50k on BHI DPS. WOB Drilling with Ok to 5k CTW BHP /ECD /WHP =2965 / 6.51 / 950 psi Getting survey off bottom due to vibration 23:10 - 00:00 0.83 DRILL P PROD2 Wiper trip at 11,950 ft Clean trip out 7/22/2006 00:00 - 00:50 0.83 DRILL P PROD2 Finished wiper trip to 11,950 ft 00:50 - 04:15 3.42 DRILL P PROD2 Drilling w/ 90-10L TF from 11,950, ft. to 12058 ft Of = 1.61 / 2.4 bpm. Steady 0.5 bpm of production. CTP = 2250 psi. IA/OA = 1853/ 0 psi Og= 9.54 to 8.6 mmcf/day. No gas lift ROP = 30-60 FPH WOB = 1-.150k on BHI DPS. CTW 5-2.5k available BHP /ECD /WHP =2858 / 6.33 / 892 psi Getting survey off bottom due to vibration.. 04:15 - 05:30 1.25 DRILL P PROD2 Wiper trip, swapped to DRA in tank 1 and used on PUH then switched back to Lube 776 05:30 - 06:45 1.25 DRILL P PROD2 Drilling w/ 30L TF from 12058, ft. to Of = 1.61 / 2.4 bpm. Steady 0.5 bpm of production. CTP = 2415 psi. IA/OA = 1853/ 0 psi Og= 9.00 mmcf/day. No gas lift ROP = 40-60 FPH WOB =1.50k on BHI DPS. CTW 5-2.5k available BHP /ECD /WHP =2979 / 6.33 / 892 psi 06:45 - 07:00 0.25 DRILL P PROD2 100 ft wiper trip. Having a little trouble drilling. 32k# up, 14k# do wt near btm at 1.63 bpm in. Drilling improved after short wiper. 07:00 - 09:30 2.50 DRILL P PROD2 Drill ahead from 12,104'. 2100 fs at 1.61 in /2.35 out. DHWOB: 0.5 to 1.0 k# (tool working erratically) WHP/BHP/ECD: 905/2880/6.38 ppg. IA/OA/PVT: 2540/40/339 bbls INC/AZM/TF:96/232/145R. Gas out: 8.5-9.5 mmscfd. Gas lift in continues to be shut in due to production from formation. Resume pumping DRA after discussion with town. Coil pressure has dropped approximately 500 psi. (5 gal DRA per 290 bbls) 09:30 - 10:30 1.00 DRILL P PROD2 Wiper trip to above window. 33k# up wt near TD 10:30 - 10:45 0.25 DRILL P PROD2 Log GR tie in from 10,530'. Subtract 8' correction. 10:45 - 13:00 2.25 DRILL N DFAL PROD2 Start in hole. DPS sub data is cutting in and out. This started on btm several hours ago and has gotten worse. Decide to POH to replace DPS and check rest of BHA. Review Undeploy procedure with day crew. 13:00 - 15:00 2.00 DRILL N DFAL PROD2 At surface. Pressure undeploy BHA as per procedure. Slickline parted at rope socket during pull test. Slip and cut slickline. Continue to un-deploy BHA. 15:00 - 18:10 3.17 DRILL N DFAL PROD2 LD BHA assembly. Change out motor, bit, DPS and check valves. Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Start: 6/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To 7/22/2006 15:00 - 18:10 18:10 - 18:40 18:40 - 20:40 20:40 - 22:30 22:30 - 22:50 22:50 - 23:00 23:00 - 00:00 7/23/2006 00:00 - 02:10 02:10 - 04:00 Hours I Task I Code I NPT I Phase 3.17 DRILL N 0.50 DRILL N 2.00 DRILL N 1.83 DRILL N 0.33 DRILL N 0.17 DRILL N 1.00 DRILL N 2.17 DRILL P DFAL IPROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 1.831 DRILL I P 04:00 - 04:10 ~ 0.17 ~ DRILL ~ P 04:10 - 04:30 I 0.331 DRILL I P 04:30 - 07:00 I 2.501 DRILL I P 07:00 - 07:30 0.50 DRILL P 07:30 - 10:30 3.00 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Page 42 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations OA pressure has increased to 810 psi, probably due to thermal resulting from warm produced fluids. Rig up bleed line to tiger tank hard line. Held PJSM following crew change. Covered hazards involved and mitigated. Covered H2S Safety data Sheet with crew. PT lubricator after rehead slickline and breking lubricator apart. Pressure deploy BHA with WHP of 1,150 psi Og = 19mmcf/day and 1296 bfpd RIH to 300 ft and open EDC IA/OA = 1526/73 initially Log tie in at 10, 530 ftCorrected -4 ft RIH, CWI and SD pump and close EDC WHP equalized at 1635 psi. RIH past WS RIH Op 1.5 bpm Og = 12.36 mmcf/day Tagged at 12,180 ft Drilling w/ 80L TF from 12175, ft. to 12,262 Ot = 1.6 / 2.27 bpm. Steady 0.8 bpm of production. CTP = 2139 psi. IA/OA = 1478 / 0 psi Og= 9.15 mmcf/day. No gas lift ROP = 50-90 FPH WOB =0.8k on BHI DPS. CTW 7k available BHP/ECD/WHP=2673/5.9/898 psi Stacking problems due to directional profile and solids dunes at present time. Drill a few feet and have to PU and run at it to get WOB. BHP spikes while drilling, evidence of solids build up below the major gas entry. W iper trip. Started 5 bbl sweep piull down CT while RIH. BHP increase 400 psi while RIH at 11, 860 ft at the gas major gas enty spot Drilling w/ 80L TF from 12,262, ft. to 12,276 Of = 1.6 / 2.22 bpm. Steady 0.7 bpm of production. CTP = 2000 psi. IA/OA = 1478 / 0 psi Og= 11 mmcf/day. No gas lift ROP = 100 FPH WOB =1.15k on BHt DPS. CTW 10k available BHP/ECD/WHP=2723/6.03/915 psi Cleaned hole up well on that wiper trip. ROP at 100 fph. Lost 100% Qo out, 50% gas rate out and WHP dropped 300 psi . BHP didn't change. Sweep in casing at this time. PUH to allow wellbore to stablize. At 12,150 ft, oil and gas rate back to 0.5 bpm and 9.46 mmcf/day. RIH from 12,050 ft to TD. Took survey off bottom Drilling w/ 60L TF from 12,276, ft. to 12465 ft Of = 1.6 / 2.45 bpm. CTP = 2000 psi. IA/OA = 1478 / 0 psi Og= 9.0 mmcf/day. No gas lift ROP = 20-50 FPH WOB =0.5k on BHI DPS. CTW 8-1k available BHP /ECD /WHP =2723 / 6.03 / 915 psi. Weight transfer is a challenge. Erratic ROP. Wiper trip to 11,750'. Hole smooth past 11,870'. Drill ahead from 12,230'. 1600 psi fs at 1.64 in/2.49 out. DHWOB: 0. to 0.5k#. WHP/BHP/ECD: 840/2863/6.34 ppg. IA/OA/PVT: 1591/10/296 Printed: 7/31/2006 11:00:56 AM Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 7/23/2006 107:30 - 10:30 L5-28 L5-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task ~ Code 3.00 ~ DRILL ~ P BP EXPLORATION Page 43 of 47 Spud Date: 6/2/2006 Start: 6/1/2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: NPT Phase Description of Operations PROD2 10:30 - 11:40 1.17 DRILL P PROD2 11:40 - 11:50 0.17 DRILL P PROD2 11:50 - 12:40 0.83 DRILL P PROD2 12:40 - 15:00 2.33 DRILL P PROD2 15:00 - 17:45 2.75 DRILL P PROD2 17:45 - 21:09 3.40 DRILL P PROD2 21:09 - 00:00 I 2.851 DRILL I P I I PROD2 7/24/2006 100:00 - 00:27 I 0.451 DRILL I P I I PROD2 00:27 - 01:30 I 1.051 DRILL I P I I PROD2 01:30 - 03:00 I 1.501 DRILL I P I I PROD2 bbls. Gas lift is shut in. Og out is 10.95 mmscfd. Wiper trip to window. Hole smooth past 11,870'. Log GR tie in from 10,530'. Add 3 ft correction. Wiper trip back in hole. Smooth on trip in. Drill ahead from 12,381'. 32k# up, 14k# do wt at TD. Tag btm. Drill ahead at 70 fph for 20 ft. Begin losing wt to bit. ROP erratic. Varying from 5 to 50 fph. Most likely due to wt transfer. Begin diesel with 1.75% MI 776 lubricant. Release three Veco transports so we can start drawing down diesel on location. Weight transfer greatly improved with 1.75% MI776 diesel out of bit. CT surface wt: 3k# - 5k# weight Wiper trip to window. Hole smooth in and out. Drilling w/ 60L TF from 12,465, ft. to 12,528 ft Of = 1.6 / 2.45 bpm. CTP = 1600 psi. IA/OA = 1516 / 0 psi Og= 11.0 mmcf/day. No gas lift ROP = 3-30 FPH WOB =0.5k on BHI DPS. CT1N 8-k available BHP /ECD / W HP =2894 / 6.04 / 842 psi. Weight transfer is a challenge. Erratic ROP. Wiper trip and wait on diesel. Pulled tight at 12,032 ft which is depth of the 150 fph drilling break. SD Pump and well in to go through WS. RIH and tied in at 10, 530 ft. (+4 ft) SWI and pump to go throgh WS. RIH. Drilling w/ 60L TF from 12,528, ft. to 12,532 ft Of = 1.6 / 2.38 bpm. CTP = 1600 psi. IA/OA = 1516 / 0 psi Og= 11.6 mmcf/day. No gas lift ROP = 60- FPH WOB =0.5k on BHI DPS. CTW 8-k available BHP /ECD / W HP =2894 / 6.04 / 842 psi. Wiper trip to 11, 875 ft, conversed with town on plan forward. Will pump sweep to see if it assist in sliding. Pump 5 bbl sweep down CT and RIH Drilling w/ 120R TF from 12,532, ft. From GR log encountered shale 12, 496 ft MD. Geologist wants to turn down Of = 1.6 / 2.38 bpm. CTP = 1600 psi. IA/OA = 1516 / 0 psi Og= 11.6 mmcf/day. No gas lift ROP =FPH WOB =0.5k on BHI DPS. CTW 8 to-4k Ibf Just stacking CT in the hole. BHP /ECD / WHP =2894 / 6.04 / 842 psi. Strated drilling with 5 bbl mineral oil pill exiting the bit and no ROP, just stacking. Starts at 7k then stacks down to -4 k down. Just stacking CT in the well. With 5 bbl mineral out plus 23 bbl diesel out, oil rate and gas rate dropped off for a short peroid of time then back to normal. At 12, 532 ft pumped another 3 bbl sweep. CT Life presently at a weld and it's at 20%. 2nd sweep out of bit and no change. Same flow characteristic as before, 22 bbl out, the gas and oil Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/24/2006 01:30 - 03:00 03:00 - 05:30 L5-28 L5-28 REENTER+COMPLETE Start: 6/1/2006 NORDIC CALISTA Rig Release: 7/27/2006 NORDIC 2 Rig Number: Hours Task i Code ~ NPT~ Phase 1.50 DRILL P PROD2 2.50 DRILL P PROD2 05:30 - 07:15 I 1.751 DRILL I P I I PROD2 07:15 - 08:45 1.50 DRILL P PROD2 08:45 - 09:00 0.25 DRILL P PROD2 09:00 - 11:30 2.50 DRILL P PROD2 11:30 - 12:30 ~ 1.00 ~ DRILL P I PROD2 12:30 - 17:30 I 5.001 EVAL I P I I PROD2 17:30 - 18:45 I 1.251 EVAL I P I I PROD2 18:45 - 21:20 I 2.581 EVAL I P I I PROD2 21:20 - 22:30 I 1.171 EVAL I N I DPRB I PROD2 22:30 - 22:45 I 0.251 EVAL I N I DPRB I PROD2 22:45 - 00:00 1.25 EVAL N DPRB PROD2 7/25/2006 00:00 - 00:20 0.33 EVAL N DPRB PROD2 00:20 - 01:30 I 1.171 EVAL I N I DPRB I PROD2 01:30 - 02:10 I 0.671 EVAL I N I DPRB I PROD2 Page 44 of 47 Spud Date: 6/2/2006 End: 7/27/2006 Description of Operations flow rates drop off and then came back to normal. PUH and reduced Op to 1 bpm and try to drill. No luck Wiper trip to base of WS Qo = 0.8 bpm and Og = 11.7mmcf/day Tagged bottom and tyring to drill with 120R TF Of = 1.6 / 2.38 bpm. CTP = 1600 psi. IA/OA = 1516 / 0 psi Og= 11.6 mmcf/day. No gas lift ROP=O WOB =0.5k on BHI DPS. CTW 8 to-4k Ibf Just stacking CT in the hole. BHP / ECD /WHP =2874 / 6.04 / 842 ps Pump 5 bbl mineral oil sweep. Town called to indicate well has reached total depth. Wiper trip to window. Hole smooth. Log GR tie in. Add 3' correction. Corrected TD is 12,535'. Circulate out of hole. Continue to flow well. Hold PJSM with crew while pulling out. Leave 20 bbls water in the coil end. Tag up. SIWHP: 1250 psi. Pressure undeploy BHA as per standard procedure. Surface test agitator with air. Rattled a little bit, then quit. Cycled air on and off several times. Additional agitation. Begin well test. Intitial rates: 1250psi WHP, Og: 23 2 mmscfd, Qo: 1400 bpm, 74.5 deg F. Final rates: 1240 psi WHP, Og: 22.4 mmscfd, Qo: 1360 bpd, 75.5 deg F Crew change, TL and PJSM with night crew on pressure deploying clean out BHA Pressure deploying cleanout BHA. RIH with slickline and tagged 20.5 ft below rig floor. THis is the spacer spool above the lower combi's Tried it twice and tagged at the same place. Pressure undeploy and call for LRS and line out 3.5" jetting nozzle with stinger. Held PJSM on nozzle deployment PU nozzle BHA Lt = 9.17 ft PT lubricator to 3000 psi. OK, line out to displace 20 bbl KCL to TT. Held PJSM and discussed hazards in RU and pumping 190 deg F diesel down CT RU LRS and PT lin to reel house to 4000 psi. PT LRS to 4000 psi. OK. LRS pressured up to 1150 psi to equalize for open the SV's. Open SV's 23-1/2 turns WHP = 1025 psi Started diesel down CT and heating to 190 F RIH cleaning out wellhead. Op = 2750 psi. Having trouble keeping LRS truck running. RIH washing pariffin. Unable to get nozzle through wellhead. Snubbing force too high for CT at -94001bf. Tagged something at 20 ft and washed through. Unable to work our way in the hole with a 1,750 psi WHP. SWI, WHP increased to 2,054 psi. Talked with town and they approved to fluid pack wellbore. with tank farm diesel. Fluid packing wellbore with diesel at 3.5 bpm Pi = 2054 psi Vp = 125 bbl's = 8226 ft Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 45 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 i Date From - To Hours I Task j Code NPT 7/25/2006 01:30 - 02:10 0.67 EVAL N DPRB 02:10 - 03:00 0.83 EVAL N DPRB 03:00 - 03:15 0.25 EVAL N DPRB 03:15 - 08:30 5.25 EVAL N DPRB 08:30 - 11:00 2.50 EVAL N DPRB 11:00 - 14:00 3.00 EVAL N DPRB 14:00 - 16:00 2.00 EVAL N DPRB 16:00 - 18:00 2.00 WHIP P 18:00 - 18:30 0.50 WHIP P 18:30 - 20:00 1.50 WHIP P 20:00 - 22:00 2.00 WHIP P 22:00 - 22:20 0.33 WHIP P 22:20 - 00:00 1.67 WHIP P 7/26/2006 00:00 - 00:30 0.50 WHIP P 00:30 - 02:00 1.50 WHIP N DPRB 02:00-03:00 1.00 WHIP N DPRB Spud Date: 6/2/2006 Start: 6/1 /2006 End: 7/27/2006 Rig Release: 7/27/2006 Rig Number: i Phase Description of Operations PROD2 P2 = 500 psi. Started LRS at 1.5 bpm, open ASRC inlet taking returns. PROD2 RIH slowly jetting wellhead CTP = 2250 psi WHP = HP = 500 psi. RIH to 58.7 ft and washed back up to surface several times .No fluid coming to ASRC, close inlet. WHP = 206 psi. Pumped 90 bbl of 190 deg F diesel and chased it with 20 bbl of KCL, followed by 20 bbl of tank farm diesel. Open to ASRC and take returns. SD pump and tagged up. Shut in SV's PROD2 PJSM on undeploying and deploying BHA. PROD2 Stand injector back, Undeploy nozzle BHA and deploy Mill cleanout BHA. No problems in well head Transferring diesel to LRS. Load 90 bbls in LRS. Heat diesel. PROD2 Wash in hole with 190 deg diesel and clean out BHA. 1735 psi fs at 1.39 bpm. Temp in: 182 deg F. No returns until at +/- 6000'. Returns slowly increased to 1.0 bpm. Seeing some evidence of paraffin. Able to make steady progress in hole. Wash to 10,650'. PROD2 Circulate out of hole pumping diesel. Tag up. Wash back down to 100'. Shut down LRS. Hold PJSM to review un-deploy. Tag up. Open EDC and circulate 20 bbl water pill to flush BHA and lubricator. PROD2 Pressure undeploy BHA. 464 psi WHP. Lay down tools to re-configure for hook assembly. WEXIT MU Baker whipstock fishing BHA. (Powercomms, EDC, DGS, HOT, GS spear, hook sub) Scribe hook to orienter. Pressure deploy BHA. BHA secured in slips. WEXIT Hold extended PJSM in ops cab to discuss finishing deployment w/ oncoming crew WEXIT Fin deploy fishing BHA. WEXIT RIH w/ WS retrieval tool w/ initial 360 psi WHP w/ well SI. Park at 500' and discuss opening EDC. Elect to leave EDC closed until latched onto fish due to BHI concerns of differential pressure and BTT concerns of shearing bait sub if pressuring up on the CT. Resume RIH and WHP stabilized at 440 psi. Having trouble recieving BHI data in ops cab-will have to use radio comms to verify TF and commands w/ BHI engr shack WEXIT 10600' 30.8k, 17k Orient to HS (170L offset) and RIH looking for TOWS. RIH to 10697' CTD and see sli wt loss (which is where WS should be w/ normal corr of -10'), RIH to set down at 10720' CTD and stack 5k. PUH w/ 33k to 10716' and park. Pressure up on CT w/ 2.4 bbls diesel to match WHP of 426 psi. Open EDC. PUH to 35.1 k and lost wt back to 31 k. Assume fish is on WEXIT POH w/ WS w/o pump WEXIT Fin POOH w/ WS assy. Close EDC at 450' Safety mtg re: undeploy WEXIT Tag up w/ 450 psi whp. Gained 50 psi the last 3000'. Closed lower combi's and had minor bleed by. Close upper combi's and had same. Whitey valve above rams continued slow bleed of gas. Monitor W HP from lower TOT's at 388 psi. Equalize pressures and open both rams. RIH/POH 50' w/ normal wts WEXIT Tag up w/ 377 psi whp. Closed lower combi's and had minor bleed by. Close upper combi's and had same. Close annular Printed: 7/31/2006 11:00:56 AM BP EXPLORATION Page 46 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code ~ NPT Phase Description of Operations 7/26!2006 02:00 - 03:00 1.00 WHIP N DPRB WEXIT 03:00 - 05:00 2.00 WHIP N DPRB WEXIT 05:00 - 06:30 1.50 WHIP N DPRB WEXIT 06:30 - 08:30 2.00 WHIP P WEXIT 08:30 - 11:30 3.00 DHB P POST 11:30 - 14:30 3.00 WHSUR P POST 14:30 - 16:00 1.50 WHSUR P POST 16:00 - 19:00 3.00 WHSUR N SEAL POST 19:00 - 20:30 1.50 WHSUR N SEAL POST 20:30 - 00:00 3.50 WHSUR N SEAL POST 7/27/2006 00:00 - 02:20 2.33 WHSUR N SEAL POST 02:20 - 03:45 1.42 W HSUR N SEAL POST 03:45 - 05:00 1.25 W HSUR N SEAL POST and monitor 20 min w/ no bleed by. Assume paraffin is on BHA which won't allow rams to fully close and gas is breaking out??? WHP rose to 60 psi over one hour w/ both combis closed Back feed LRS diesel while open rams back up LRS bullhead 190E diesel down kill line at 1.0 bpm ~ 425 psi while reciprocate CT -50'. Pump 60 bbls. Hold PJSM to discuss continuing un-deployment. Close lower 2-3/8" combis with 425 psi WHP. Bleed lubricator. Combis holding. Repeat with upper combis. These held ok too. Proceed with undeployment. Whipstock tray recovered. Lay down MWD and other tools. Call SLB e-liners to recover PIP tags from tray. PJSM to test SSSV. Close SSSV. Bleed ASRC equipment. Monitor tbg pressure. No increase in 1 hour. SSSV holding 435 psi. Transfer diesel in tank farm to transports. Replace slickline on spooler with new 0.125 line. Rig up DSM lubricator. Pressure well to 300 psi. Cycle and service master and swap valves. Master very tight. Lesson learned: will need to cycle and service master while drilling well. Once per week during BOP pressure and/or function tests. Continue to clean pits. Continue to off load diesel trom uprights into transports. Unable to properly function master valve. Valve left in open position. Discuss with town team. Discuss with Wells Operations Supervisor. Re-test SSSV. Fluid pack. well. Close valve. Isolate BOPS by double blocking kill, choke, and flow line to ASRC. Monitor well head pressure with tree cap in place. WHP increased from 0 to 260 psi in 30 minutes. TRSSSV failed. Master valve needs to be replaced. Call for slickline unit (on V-Pad). Continue to RD location for move to L5-16. Safety mtg: re bleed off IA Begin bleeding off 1340 psi gas from IA thru 1/2" line connected to 1/2" needle valve at bottom of downcomer on ASRC flowline and send to LPC via HP header Safety mtg re: MIRU SWS slickline unit MIRU SWS slickline lubricator and BOP's. PT lub w/diesel at 500 psi. Open dual SV's to 300 psi WHP. RIH w/ 3.75" GR and wire brush. Brush the open TRSSSV for 15 min. POOH w/ no debris on tools Swap to bleeding IA to tiger tank at 540 psi SWS WL set 4-1/2 'X' plug in TRSSSV nipple at 1983' w/ 300 psi WHP. POOH. Standback lub, install tree cap. Bleed off 300 psi above X plug and monitor no flow for 10 min. PT above plug to 1000 psi and held for 10 min. Bleed off pressure and monitor no flow while RD WL lubricator and BOP's. RDMO SWS slickline WO BTT while monitor tubing for flow MU BTT WL retrievable 4-1/2" plug onto BHI MWD assy and Printed: 7/31/2006 11:00:56 AM n BP EXPLORATION Page 47 of 47 Operations Summary Report Legal Well Name: L5-28 Common Well Name: L5-28 Spud Date: 6/2/2006 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 7/27/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code; NPT Phase ~ Description of Operations ' I 7/27/2006 03:45 - 05:00 1.25 WHSUR N SFAL POST openhole deploy 05:00 - 05:05 0.08 W HSUR N SFAL POST RIH w/ BHA to 204' 05:05 - 05:25 0.33 W HSUR N SFAL POST Pressure CT to 3900 psi and set plug w/ top at 200'. PUH 10'. PT plug to 1000 psi for 10 min 05:25 - 05:30 0.08 WHSUR N SFAL POST POH 05:30 - 06:45 1.25 W HSUR N SFAL POST Chk for flow. LD setting assy. MU nozzle assy. Set back injector. 06:45 - 07:15 0.50 W HSUR P POST Set two way check valve with DSM crew. 07:15 - 09:00 1.75 DEMOB P POST Remove stem cover and inspect master valve. Prep for N2 blow down of coil. ASRC continuing to rig down. Finish draining tank farm hoses. Break down hose assemblies. Call for electrician to disconnect power sources to ASRC. Begin to disassemble handy berm. "A good plan -executed today- is better than a perfect plan executed next week" -George Patton, reprinted from the L5-16A well plan. 09:00 - 12:00 3.00 DEMOB P POST Sim Ops: Rig up N~ to blow down reel. Hold PJSM with rig crew. Notify ASRC about bleed down. Rig up N2 pumper. ASRC rigged up GL supply bypass out side of cellar. PJSM. Double block 4" flow line from rig for blow down. Use GL gas to blow down ASRC separator, heater, and lines down LPC flow line. IA has been bled to zero 12:00 - 14:00 2.00 DEMOB P POST Unstab and secure coil to reel. Clean out both flow back tanks. Rig down non-flanged ASRC lines. 14:00 - 17:00 3.00 BOPSU P POST PJSM with crews. ND BOPs. Coordinate with RD of 4" flow line and GL line to cellar. Secure IA and OA in cellar. Move rig camps down pad. Spot crane to remove L5-18 well house. 17:00 - 18:00 1.00 W HSUR N SFAL POST ND master valve Peak crane remove L5-18 well house 18:00 - 22:00 4.00 W HSUR P POST NU blind flange to wing valve on tree. ND check valve from GL side of IA and replace w/ flange and 2" bullplug. Dress opposite side of IA w/ same NU new 4" CIW tree using ASRC loader after Nordics wouldn't start ... PT tree at 5000 psi w/diesel RREL ~ 2200 hrs Future operations will be found under L5-16 Printed: 7/31/2006 11:00:56 AM r b ~ BP Alaska P Baker Hughes INTEQ Survey Report ~i.~ BAKER HYtG1~S INTEQ Company: BP Amoco Date. 7/27/2006 Ti me: 10:28:58 Page: 1 Field: Lisburne Co-ordinate(NE) Reference: WeIL• L5-28, True North Site: Lis DS 05 Vertical (TVD) Reference: 19:28 4/14/1987 00:00 60.0 Well: L5-28 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpath: L5-28A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 Site: Lis DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Easting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: L5-28 Slot Name: 28 L5-28 Well Position: +N/-S 5138.83 ft Northing: 5975280.33 ft Latitude: 70 20 6.293 N +E/-W 5235.04 ft Easting : 717446.43 ft Longitude: 148 14 8.524 W Position Uncertainty: 0.00 ft Wellpath: L5-28A Drilled From: L5-28 Tie-on Depth: 10694.09 ft Current Datum: 19:28 4/14/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/12/2006 Declinafion: 24.75 deg Field Strength: 57626 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 280.00 Survey Program for Definitive Wellpath Date: 7/7/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 50.00 10694.09 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 10713.00 12800.00 MWD (10713.00-12800.00) MWD MWD -Standard Annotation MD TVD _ft ft 10694.09 8792.02 TIP 10713.00 8808.03 KOP 12800.00 8789.44 TD Survey: MWD Start Date: 7/9/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10694.09 32.22 12.55 8792.02 8732.02 4987.70 1066.89 5980296.64 718368.21 -184.58 0.00 MWD 10713.00 32.07 12.51 8808.03 8748.03 4997.52 1069.07 5980306.52 718370.11 -185.02 0.80 MWD 10745.15 39.79 3.82 8834.06 8774.06 5016.16 1071.61 5980325.22 718372.10 -184.28 28.73 MWD 10774.35 57.49 358.99 8853.29 8793.29 5037.98 1072.02 5980347.04 718371.88 -180.90 61.84 MWD 10804.86 74.22 355.20 8865.73 8805.73 5065.67- 1070.55 5980374.68 718369.61 -174.65 55.98 MWD 10835.66 89.00 351.87 8870.21 8810.21 5095.86 1067.12 5980404.75 718365.30 -166.02 49.16 MWD 10865.31 93.39 336.20 8869.59 8809.59 5124.26 1058.99 5980432.91 718356.36 -153.09 54.86 MWD 10895.22 94.78 321.17 8867.45 8807.45 5149.68 1043.54 5980457.86 718340.17 -133.45 50.34 MWD 10928.60 97.29 316.19 8863.93 8803.93 5174.60 1021.63 5980482.14 718317.55 -107.55 16.63 MWD 10958.07 98.39 313.39 8859.91 8799.91 5195.17 1000.91 5980502.10 718296.25 -83.58 10.13 MWD 10988.79 97.03 310.32 8855.79 8795.79 5215.48 978.24 5980521.74 718273.00 -57.72 10.85 MWD ~.~~~~2~ b ~ BP Alaska ~ sN~~r P Baker Hughes INTEQ Survey Report LNTEQ Company: BP Amoco Date: 7/27/2006 Time: 10:28: 58 Page: 2 Field: Lisburne Co-ordinate(NE) Reference: Well: L5-28, True North Site: Lis DS 05 Vertical (TVD) Reference: 19:28 4/ 14/198700:00 60 .0 Well: L5- 28 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpath: L5-28A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Iucl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11021. 37 97 .42 306. 85 8851 .69 8791. 69 5235. 63 952. 98 5980541. 15 718247 .17 -29 .35 10 .63 MWD 11052. 47 97 .68 305. 68 8847 .61 8787. 61 5253. 87 928. 12 5980558. 66 718221 .79 -1 .70 3 .82 MWD 11082. 04 93 .84 304. 60 8844 .64 8784. 64 5270. 80 904. 07 5980574. 88 718197 .26 24 .93 13 .48 MWD 11129. 78 92 .02 304. 40 8842 .20 8782. 20 5297. 80 864. 78 5980600. 73 718157 .20 68 .31 3 .84 MWD 11162. 29 94 .07 302. 65 8840 .47 8780. 47 5315. 73 837. 72 5980617. 87 718129 .63 98 .08 8 .29 MWD 11193. 00 93 .58 299. 37 8838 .42 8778. 42 5331. 51 811. 46 5980632. 88 718102 .93 126 .68 10 .78 MWD 11224. 55 91 .13 298. 23 8837 .13 8777. 13 5346. 70 783. 84 5980647. 26 718074 .88 156 .52 8 .56 MWD 11260. 43 89. 98 297. 77 8836 .78 8776. 78 5363. 54 752. 16 5980663. 18 718042 .73 190 .64 3 .45 MWD 11291. 98 89. 40 291. 95 8836 .95 8776. 95 5376. 80 723. 55 5980675. 60 718013. 74 221 .12 18 .54 MWD 11322. 36 89. 64 287. 15 8837 .20 8777. 20 5386. 96 694. 93 5980684. 93 717984. 84 251. 07 15 .82 MWD 11352. 57 92. 05 283. 97 8836 .76 8776. 76 5395. 06 665. 83 5980692. 18 717955. 53 281. 13 13. 21 MWD 11382. 48 92. 91 281. 27 8835 .46 8775. 46 5401. 59 636. 68 5980697. 86 717926. 20 310. 97 9 .47 MWD 11412. 52 92. 71 277. 98 8833 .99 8773. 99 5406. 61 607. 10 5980702. 02 717896. 49 340. 97 10 .96 MWD 11442. 46 93. 09 281. 29 8832 .48 8772. 48 5411. 61 577. 62 5980706. 17 717866. 88 370. 87 11. 11 MWD 11474. 00 92. 71 284. 20 8830 .88 8770. 88 5418. 56 546. 90 5980712. 22 717835. 97 402. 33 9. 29 MWD 11503. 18 91. 13 285. 60 8829 .90 8769. 90 5426. 06 518. 72 5980718. 90 717807. 59 431. 38 7. 23 MWD 11532. 65 92. 63 286. 62 8828 .94 8768. 94 5434. 23 490. 42 5980726. 25 717779. 07 460. 67 6. 15 MWD 11551. 59 93. 07 288. 11 8827 .99 8767. 99 5439. 88 472. 37 5980731. 37 717760. 86 479. 43 8. 19 MWD 11583. 11 93. 63 293. 22 8826 .15 8766. 15 5450. 98 442. 94 5980741. 61 717731. 12 510. 34 16. 28 MWD 11616. 13 93. 67 298. 00 8824 .05 8764. 05 5465. 22 413. 23 5980754. 98 717701. 01 542. 07 14. 45 MWD 11649. 98 89. 92 301. 90 8822 .99 8762. 99 5482. 10 383. 93 5980771. 01 717671. 23 573. 86 15. 98 MWD 11672. 02 91. 06 306. 17 8822 .80 8762. 80 5494. 44 365. 67 5980782. 81 717652. 62 593. 99 20. 05 MWD 11705. 16 93. 43 311. 66 8821 .50 8761. 50 5515. 23 339. 91 5980802. 84 717626. 28 622. 96 18. 03 MWD 11735. 89 94. 44 315. 87 8819 .39 8759. 39 5536. 43 317. 78 5980823. 39 717603. 54 648. 44 14. 06 MWD 11770. 55 93. 84 321. 92 8816 .89 8756. 89 5562. 46 295. 06 5980848. 75 717580. 08 675. 33 17. 50 MWD 11801. 19 91. 31 325. 35 8815 .51 8755. 51 5587. 11 276. 92 5980872. 86 717561. 23 697. 48 13. 90 MWD 11831. 98 88. 39 324. 57 8815 .59 8755. 59 5612. 31 259. 24 5980897. 54 717542. 83 719. 26 9. 82 MWD 11861. 78 88. 35 319. 41 8816 .44 8756. 44 5635. 77 240. 90 5980920. 46 717523. 82 741. 40 17. 31 MWD 11897. 22 93. 05 317. 05 8816 .00 8756. 00 5662. 20 217. 31 5980946. 19 717499. 47 769. 22 14. 84 MWD 11933. 63 92. 41 311. 24 8814 .27 8754. 27 5687. 51 191. 22 5980970. 74 717472. 66 799. 31 16. 04 MWD 11965. 36 92. 07 309. 69 8813 .03 8753. 03 5708. 09 167. 10 5980990. 60 717447. 95 826. 64 5. 00 MWD 12002. 73 90. 60 307. 23 8812 .16 8752. 16 5731. 32 137. 85 5981012. 98 717418. 04 859. 48 7. 67 MWD 12044. 22 88. 26 302. 99 8812 .57 8752. 57 5755. 18 103. 92 5981035. 84 717383. 44 897. 04 11 .67 MWD 12081. 15 87. 00 297. 10 8814 .10 8754. 10 5773. 65 71. 99 5981053. 37 717350. 99 931. 68 16 .30 MWD 12110. 68 88. 91 293. 43 8815 .15 8755. 15 5786. 24 45. 31 5981065. 18 717323. 96 960. 15 14. 00 MWD 12139. 83 88. 82 287. 82 8815 .73 8755. 73 5796. 50 18. 05 5981074. 65 717296. 41 988. 78 19. 24 MWD 12184. 88 93. 25 284. 09 8814 .92 8754. 92 5808. 88 -25. 24 5981085. 77 717252. 78 1033. 56 12. 85 MWD 12211. 68 97. 39 282. 69 8812 .43 8752. 43 5815. 06 -51. 20 5981091. 19 717226. 66 1060. 19 16. 30 MWD 12245. 08 95. 56 283. 49 8808 .67 8748. 67 5822. 57 -83. 52 5981097. 77 717194. 13 1093. 33 5. 97 MWD 12279. 55 92. 70 275. 92 8806 .18 8746. 18 5828. 36 -117. 38 5981102. 57 717160. 12 1127. 68 23. 42 MWD 12314. 29 93. 76 271. 40 8804 .22 8744. 22 5830. 57 -151. 98 5981103. 78 717125. 47 1162. 14 13. 34 MWD 12347. 94 94. 72 277. 79 8801 .73 8741. 73 5833. 26 -185. 42 5981105. 49 717091. 97 1195. 53 19. 15 MWD 12380. 33 95. 30 283. 35 8798 .90 8738. 90 5839. 17 -217. 12 5981110. 49 717060. 11 1227. 79 17. 19 MWD 12410. 62 94. 03 286. 75 8796 .44 8736. 44 5847. 01 -246. 27 5981117. 48 717030. 75 1257. 85 11. 95 MWD 12440. 95 91. 12 292. 70 8795 .07 8735. 07 5857. 24 -274. 78 5981126. 87 717001. 96 1287. 70 21 .82 MWD 12474. 06 91. 83 298. 67 8794 .22 8734. 22 5871. 57 -304. 59 5981140. 34 716971. 74 1319. 55 18 .15 MWD 12504. 79 90. 72 296. 90 8793 .54 8733. 54 5885. 89 -331. 77 5981153. 86 716944. 16 1348 .80 6 .80 MWD 12538. 25 90. 87 306. 69 8793 .07 8733. 07 5903. 50 -360. 17 5981170. 64 716915. 26 1379 .83 29 .26 MWD 12569. 79 90. 48 312. 08 8792 .70 8732. 70 5923. 51 -384. 54 5981189. 92 716890. 33 1407 .30 17 .13 MWD 12599. 94 89. 98 317. 29 8792 .58 8732. 58 5944. 70 -405. 97 5981210. 49 716868. 30 1432 .08 17 .36 MWD 12630. 09 89. 74 321. 44 8792 .65 8732. 65 5967. 57 -425. 60 5981232. 78 716848. 01 1455 .39 13 .79 MWD 12662. 16 90. 72 325. 62 8792 .52 8732. 52 5993. 36 -444. 65 5981258. 00 716828. 21 1478 .63 13 .39 MWD 12696. 70 93. 28 328. 48 8791 .32 8731. 32 6022. 32 -463. 43 5981286. 40 716808. 61 1502 .15 11 .11 MWD BP Alaska ~ Ba~R.~ by Nuc~ll~s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 7/27/2006 Time: 10:28:58 Page: 3 Field: Lisburne Co-ordinate(NE) Reference: We1L L5-28, True North Site: Lis DS 05 Vertical (TVD) Reference: 19:28 4/14/1987 00:00 60.0 Well: L5-28 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpatb: L5-28A Survey Calculsfion Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N!S E/VV MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 12726.62 90.48 334.94 8790.33 8730.33 6048.63 -477.59 5981312.30 716793.69 1520.67 23.52 MWD 12765.26 90.78 341.12 8789.91 8729.91 6084.45 -492.04 5981347.68 716778.21 1541.12 16.01 MWD 12800.00 90.78 341.12 8789.44 8729.44 6117.32 -503.28 5981380.20 716766.02 1557.89 0.00 MWD L5-28A and L5-28AL1 Draft Completion • I 1983' I 14-1/2" Halliburton TRSSSV, ID = 3.812" 10-314" CSG, 45.5#, L-80, ID = 9.953" I-I 41 4 1 /2" 12.6#, L-80, I BT-Mod T LM' 2795 MD 5179 7606 9121 10309 10,376` X Nipple, 3.813" ID 10397' 7-5/8" X 4-1/2" Baker S3 Packer 10421' 4-1/2" X NIP, ID= 3.813" 10,430` Top BOT ZXP PBR (ID=5.75") 10,437` BOT 5 1/2" WLEG stung into PBR 10,441' BOT ZXP Liner top Packer 10,448' BOT HMC Liner Hanger ' ~ Guidestock available for ~ ll installation in KB Packer Baker KB Whipstock Packer (2.45" ID) 10,698' XN Nipple 2.205" ID 10,705 L5-28AL 1 Zone 4 & 5 I PXN plug and prong set in XN Nipple with 2 Petredat gauges made up to bottom of PXN plug Baker whipstock 10,717` 4 1/2" 12.6#, L-80 IBT-Mod BOT Landing Collar 10,749 L5-28A Zone 4 I 11120 ~ PRONG FROM PXN PLUG SET @ 10702', LOST 02!14/93 ~7D I~ 11177' 7-5/8" CSG, 33.7#, L-80, ID = 6.765" I--I 11268' ~ , ~ ~ ~, ~a~ ~ ~ ~ k ~ . ~' ~ ~ A 1 ~ j ; ~~ ~, ~, ~ ~. ~aua-78i~ ®IIi A1QD G.~5 COI~TSERQATIOIQ COrII-IISSIOI~T Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Lisburne Pool, L5-28A BP Exploration (Alaska) Inc. Permit No: 206-070 Surface Location: 2147' FSL, 29' FWL, SEC. O1, T11N, R15E, UM Bottomhole Location: 2881' FSL, 367' FEL, SEC. 35, T12N, R15E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cath P. Foerster Commissioner DATED this da of Ma 2006 Y Y~ cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • FRANK H. MURKOWSK/, GOVERNOR p4 ~: STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMA~ION PERMIT TO DRILL 20 AAC 25.005 EGA- s jZt~zoo~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class O Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is' proposed ' or' ^ Coalbed Methane' ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L5-28A3~'°~L°o~° 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12706 TVD 8709 12. Field /Pool(s): Prudhoe Bay Field / Lisburne 4a. Location of Well (Governmental Section): Surface: 2147' FSL 29' FWL SEC 01 T11N R15E UM 7. Property Designation: ADL 034630 Pool , , . , , , Top of Productive Horizon: 1767' FSL, 1079' FWL, SEC. 36, T12N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 8, 2006 Total Depth: 2881' FSL, 367' FEL, SEC. 35, T12N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6,320 4b. Location of Well (State Base Plane Coordinates): Surface: x-717446 y-5975280 Zone-ASP4 10. KB Elevation (Height above GL): 6p' feet 15. Distance to Nearest Well Within Pool: 2,850 16. Deviated Wells: Kickoff Depth: 10717 feet Maximum Hole Angle: 110 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3512 Surface: 2622 18. Casin Pro ram: Specifications To - Settin De th -Bottom Quanti of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data None - O en Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11280 Total Depth TVD (ft): 9299 Plugs (measured): None Effective Depth MD (ft): 11178 Effective Depth TVD (ft). 9210 Junk (measured): 11120 .Casing Length ize Cement Volume MD TVD Conductor /Structural 110' 20" 1860# Poleset 110' 110' Surface 4194' 10-3/4" 1365 sx AS III, 325 sx Class 'G' 4194' 3980' Intermediate Produ i n 11268' 7-5/8" 569 sx Class 'G', 300 sx CSI 11268' 9289' Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat O Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoin is true and correct. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg ~/C 6, ::J }fj'L+$c~„ Title CT Drilling Engineer a P~epar~eYNam~N~mbe~. Si nature . ~ L -` ' Phone 564-4694 Date J f(6 ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: a O .. p P Number: Permit Approval 50- 029-21717-01-00 Date: "'- ZZ- O See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales j Samples Req'd: ^ Yes ,~No Mud Log Req'd: ^ Yes ~(No I ~S l- ~p p t- •f -n 3 5p p ~ Ste' ~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No °p~ ~ ~-~ z.s. 0 3 3 ~ ~~, ~ ~ h ~., (a.~. c.e.d ~.r" ~l -'~ o~~ ~~.~C;~.s a ~. ~r,~tr>- d ^~~1 APPROVED BY THE COMMISSIO ~ a ~'-ZG-"(J ,COMMISSIONER Form 10-401 Revised 12/2005 1 1 i~;~ t ~ ~ ~~~ f t ~ Submit In Uupucate • • BP L5-28A, AL1 UBCTD Sidetrack Discussion of Operations: Well LS-28 is scheduled for a through tubing sidetrack to be drilled underbalanced with coiled tubing.~LS-28 was drilled in 1987 and has produced. approx. 3.2 MMBO to date. The well has cycled since early 1997 and can be produced for only 4 days before reaching MGOR. Extensive stimulation work has been performed and further opportunities for well work are unattractive. Prior to the CTD sidetrack, Nordic 2 will swap tubing to 4 %2" and install a 4 '/Z" scab liner in L5-28. That work is in progress under Sundry Approval 306-120. The sidetracks, LS-28A and LS-28AL1 will kick off from separate windows milled from mechanical whipstocks set in Lisburne Zone 4. LS-28A will target Zane 4 and LS- 28AL 1 will target both Zone 4 and Zone 5. Both sidetracks are targeting layers of high porosity while hunting ~ for fractures. If fracturing, or high productivity, is not encountered in LS-28A then an open hole sidetrack in a different azimuth direction will be considered but will not be permitted at this time due to uncertainty over the need or the strategy for an alternate well path. If an open hole sidetrack of LS-28A proves to be n j ed, based on LS-28A results, then a Permit application for an additional lateral will be submitted at that time. This will be the first underbalanced CTD operation in the Lisburne field. Planning for success in both HSE and production has been extensive and ongoing. Blade Energy Partners, consultants in underbalanced drilling, have been employed to assist in project planning and personnel training and will be on-site during drilling operations to advise on all underbalanced operations. Well control equipment has been designed specifically for the planned operation and procedures have been written to cover each aspect of the operation. Crew training has focused on HSE, new equipment and procedures and on gas handling, Specific scenario training on a UBD simulator is being carried out for all decision makers on the ~ rig and associated town staff. All relevant contractors, crew and engineering staff have completed HAZid and HAZop procedures and the overall planning has been Peer Reviewed by operating partners and outside experts. underbalanced coil drilling operation will use either Z% KCl or diesel as a power fluid and gas lift to achieve 00 -30 si underbalance while drilling. Return fluids, including formation fluids, will flow to an ASRC se ,_ or where fluids will be separated, measured and flowed to the Lisburne Production Center (LPC) at about 600 psi line pressure. There will be no flaring or compression involved in the project. ~ The BOP stack drawing is attached. This stack incorporate _6~ns, an annular preventor, two flow spools, two Swab valves and a Master valve. The UBD flow spool is located below double swab valves such that produced fluids do not flow through the upper four rams. A ESD valve on the outlet of the UBD flow spool along with double rams (shear/seal and 2" pipe/slip combi) located below the UBD flow spool provide emergency shut in capability in the event of a flow line leak. Equipment and procedures for pressure deploying/undeploying the drilling BHA have been refined for the UBD process. A tubing retrievable SSSV will be installed during the workover to provide additional pressure control ~ capability. Drawings are attached that describe the BOP stack, the P & ID of the full process spread and a flow diagram that includes all surface equipment. Post RWO Status: LS-28 will be re-completed with 4 '/2" tubing and 4 %2" scab liner. All original perfs will be isolated. Summary of Underbalanced Drilling and Completion Operations: 1. Rig up 2" CTE, UBCTD drilling stack and BOPE. Test BOPE. ~ 2. RU slickline. Pull ball and rod, RHC plug. Install GLV's per UBD requirements. Drift to PBTD for whipstock. Run Memory GRICCL from PBTD for depth control and collar log. • • 3. PU Baker 4 %2" monobore whipstock on CTE-line and set whipstock @ 10,717' MD (8752ss). 4. Mi113.80" window with 2%KCl and bio sweeps. 5. Drill LS-28A lateral in UB mode using 2°lo KCl and/or diesel as the drilling fluid and gas lift. Flow ~ test LS-28A for 6 hours. 6. Set Baker packer with tailpipe and PXX plug to isolate LS-28A. Install whipstock into packer (10,687'MD, 8727ss). 7. Mi113.80" window with 2% KCl and bio sweeps. 8. Drill LS-28AL1 in UB mode using diesel and/or 2 %KCL as the drilling fluid and gas lift. Flow test LS-28AL1 for 6 hours. 9. Recover whipstock tray. Recover PXX plug. Install hollow guidestock. 10. Set BPV. RD and move to LS-16. Mud Program: • Window milling: 2% KCl and 2ppb Biozan sweeps. • CTD: 2% KCl or diesel as power fluid with gas lift for underbalance. Viscosified mineral oil sweeps may be used during drilling. ~. ~ n ~~ , b.16~0- • Kill Weight fluid: 2% KCl kill weight fluid will be on location. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind &; Inject or Pad 3. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • None. All laterals will be completed. open hole. ~ Well Control: • BOP schematic, P & ID drawing and fluid flow diagrams are attached. • Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and tom si. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is approx. 110 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging • An MWD Gamma Ray will be run over the entire open hole section. Hazards mitigated through training, procedures, and UBD equipment • Hydrogen Sulfide- Max HZS measured on pad is (~0 fpm (3/27/92) on LS-12. Both LS-28 and AL ~- gas are expected to have 60 ppm HZS. ~/ • Max BHP is expected to be 3512 psi ~ 8900'ss (7.6 ppg). Maximum anticipated wellhead pressure w/ full column of gas is 2622 psi. ~ • Combustible Power Fluid -Diesel -Flash Point 100 deg F o Fire, Environmental, Health (exposure), impact on other equipment (elastomers) • Combustible Lift Fluid -Natural Gas o Fire, HZS, Health (exposure) • Produced Fluids -Oil and Natural Gas o Fire, Environmental, HZS, Health (exposure), impact on other equipment (elastomers) • Pressure - 650 to 1000 psi on surface. o Leaks, loss of containment, pipe whip • SIMOPS - Drilling/Production. • • • New Procedures for most people involved -Human Error. • Additional Equipment -Escape areas, slips and trips. • Poor Hole Cleaning -Stuck Pipe • Hoie Instability - Mudstones Reservoir Pressure • Pore pressure was measured to be 3512 psi at 8900'TVDss (7.6 ppg}. • Maximum surface pressure with gas (0.1 psi/ft) to surface is 2622 psi. BP Drilling Contacts • Ted Stagg 564-4694, 240-8074 cell • Mark Johnson 564-56b6, 240-8034 cell Attachment List Proposed schematic Existing schematic LS-28A directional plan LS-28A L1 directional plan Lisburne UBD block flow diagram Lisburne UBD BOP stack-up Lisburne UBD P&ID Lisburne UBD site layout Tosrn~oJ TREE _ WfiLFEAD = MCEVOY ACTUATOR= AXELSON KB. ELEV = 60' BF. ELEV = KOP = 2600' Mau Angle = 52 @ 7200' DatumMD= 10773' DatumTVD= 8800'SS SAFETY NOTES: CAT I SSSV H2S (PR+rt) 70 2186' H3-1 /2" CAMOO TRDP SSSV, ID= 2.812" r_nc i iFrruaNnaFi c r/ L5-28 ~ I~~I~V ~~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2826 2819 15 MGFMiO RK 2 7989 6669 46 MGFMiO RK 3 10376 8526 33 MGFMiO RK 4 10468 8603 33 MGFMHO RD-1.5 ' 10.3/4" CSG, 45.5#, L-80, ID = 9.953° H 4194' Minimum ID = 2.812" @ 2186' CAMCO TRPD SSSV ' H 3-1 /7' SVUS NIP, ID = 2.813" 10554' ~--~ 7-5/8" X 3-1/2" BKR S 63-A PKR, D = 2.992" 10627' 3-1/Z"SWSNIP,ID=2813" 10688' H 7-5/8" X 3-1/2° B!(R FB-1 FKR, ID = 4.00" ~3-1 /2" SWS NIP,ID = 2.813" ~ I' 3112" TBG-iPC, 9.3#, L-80, OD087 6pf, D = 2.992" r 1 10717' (--13-1 /2" WLEG, ID= 3.0" 10717' ELMDTTLOG t1r1AVALABLE PERFORATgN SUMMARY REF LOG: ZDL (RAW) DA ON 04/30/87 ANGLE AT TOP PERF: 33 ~ 10726' Nrdc.- I~fa in Prnrlirtim nR ftu hFtnriral nE!d data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/3" 'S 10726-10804 O 06/11/87 2-113" *S 1 0915-1 1048 O 06/11/87 2-1/3" *S 10610-10714 S 11/28/92 *Select'ae Shams PBTD 11177' 7-5/8" CSG, 33.7#, LSO, ID = 6.765" 11268' 11120' DATE REV BY G01MUENTS DATE REV BY ODMMENTS 05131187 ORIGINAL GOMFtETK)N 01/09/01 SIS-CS CONVERTED TO CANVAS 02!14/93 WORK OVER 0302/01 SIS-LG FINAL 10!02101 RNRP CORRECTbNS ~ROPG FROM PXN PLUG SET ~ 10702', LOST 02/14/93 LISBt1RNE UNff WELL: L5-28 PERMT No: $7-037 API No: 50-029-21717-00 SEC 1, T11N, R15E 4117.1 FEL 3135.04 FNL BP Exploration (Alaska) L5-28A Proposed UBCTD Sdtrks U 10-3/4" CSG, 45.5#, L-80, ID = 9.953" 4 1 /2" 12.6#, L-80, I BT-Mod Liner Hanger/Packer 10,500`MD L5-28AL1: 10,687 MD, 8727ss L5-28A: 10,717 MD, 8752ss i ~4-1/2" Halliburton TRSSSV, D= 3.812" ~ 5 GLM's Deepest GLV ~ 10380`MD (8469ss) 10475' 1~4-1/2" X NIP, D = 3.813" L5-28AL 1 Zone 4 & 5 L5-28A Zone 4 4 1 /2" 12.6#, L-80 IBT-Mod 11,120 MD PsTD ~~~n' 11120' ~ PRONG FROM PXN PLUG SET @ 10702', LOST 02/14/93 7-5/8" CSG, 33.7#, L-80, ID = 6.765" Marker ue tns 1Un weuoore 8,736 8,736 ft TVD 8,709 8,709 ft TVD 8,709 8,709 ft TVD 8,763 8,763 ft TVD Cick Off 8,752 ft TVD 10,717 ft MD )e rtr KO 5,128 ft AD KO Pt 10,717 AD New Hole 1989 Total MD 12,706 TVD TD 8,709 DLS rlwnl100 Tnnl Far_n Lanath Curve 1 9 0 20 Curve 2 ~ 45 -10 145 Curve 3 45 -90 120 Curve 4 12 -90 255 Curve 5 12 106 185 Curve 6 12 90 275 Curve 7 12 -90 520 Curve 8 12 87 469 ~ i,ysy~ • • Drawn: 5/12/2006 15:42 Plan Name: Case 'C~ ? ~ ! , L5-28 7,500 7,000 L5-28A Case 201a 6,500 May 12, 2006 Ted x4694 0 J u ~ 6,000 H ~ E v a 5,500 s a ~~ 5,000 4,500 -1,500 -1,000 -500 0 500 1,000 1,500 X distance from Sfc Loc 1 Well Name L5-28 CLOSURE - Distance 6,027 ft Az 355 deg NEW HOLE EIW X N/S Y Kick Off 923 5,029 TD - --- State Plane 716.872 5.9£51.280 Surface Loc 717,446 5,975,281 DLS deg1100 Tool Face Length Curve 1 9 0 20 Curve 2 45 -10 145 Curve 3 45 -90 120 Curve 4 12 -90 255 Curve 5 12 106 185 Curve 6 12 90 275 Curve 7 12 -90 520 Curve 8 12 87 469 1,989 • Drawn: 5/12/2006 15:42 Plan Name: Case 'F1~t - • • Lisburne UB-CTD Heater Chemical Test Separator 5000 psi Injection 1376 psi@186 F Block Flow Dia ram g 2.5 MM BTU 2X Sgal 36 MMscfd 27-Apr-O6 30 gpd 11000 bpd liquids L-5 Header L-5 Header to LPC Trace Solids -- Oil 2850 bopd ____ Test Gas 16.5 mmscf/d Separator Water/KCI 2304 bpd - Pressure Ship Solids to LS-32 (28) DSO to L5-24 (16) Clean Out Production Header + Heat ------- - - 14o F __ KCL - Da4mweP ar DRA Mixing + Defaamer +0.8 Yo Safelube -- -- + 1.7 Ib/bbl + oncor 404 Wells Process Upsel Diesel o.7s Ibnwl In Line 2 Phase sodium L5-28 --------- --- -- --= Vent to Flowback 1600 bbl Melabysulfide L5-16 16.Smmscf/tlgas Healer r-1aoF ASRC Separator T-1aoF Tank +4ooppm +o.osfix 2650 bpd effluent ~ P-550psi P-550p& DRA J313 T-55 F --- P - fi50 psig T -140 F __- E1a.7pa_ Diesel KCI Solids ------ ----- ASRC Nordic Pressure ship to Tank Rig Slop Tank Farm Tanks Reservoir Ls-1fi T 165 F SIaAC Gas 11.5 mmsd/d T xxx Flawing Oil 850 bopd Ls-za T 174 F aldtic -Water 135-bopd- TxxxFlowmg Fluid Injected Via CT - __2304 bpd Gas Ll%Mandral lnjectionJ---L T-60F O to 5 MMSCf/d P- as req'd FlowbackTank ___ N2 ASRC Contingency For KCI Mud ___ syalam. WouM be req'tl _for LS-i6 P - 500 _ 0 ] -- Mud Pump 1 - Mud Pump 2 ~ ____ - - Gas Metering Skid Feed Gas 2500psi T-40F Gas Lift Header Methanol Lisburne Process-Block Flow rev 4/29/2006 • • L5-28 Stack rev4 4/29/2006 i 0 z 1 l- i~ d- T ,, ~- ~ ~ / ,~ I I I ~, ~_ ~ _-_._..447' WIND -- _-- ~6^ ~ o o ~ 9m ip -- - -__ ~ ~I 36 ~ ~ I ~ ~. ~~ ~ _ 34' , , ~., , 2 ~~~ a __ ~- , 29~. ~~ ~~;; ~~ , , ~ ~ ~ ---- ~ ~ Nordi .. .~ ~ ~n f, ,,, ~ g f i -- -~ I -~ ~_ 6 ~- ~ ~,'~ ~ 4 i '~. ~ o -- - j 2~ -~-' _ _,~_ , X19; ~-_ ~~ 4c 17 ~~ -- ~ 18 ;, ~~16 ' 5 ~ 15 ~ ~ ~~ 1 ~ 13 _ ~' i ~~ - , ;12 ~ 9 ~ ~_~ I~ I ~~ 5 _. N T-- I ~ ~ ~ __ ~~ ,.: ~4 i -1 ~- -- -_ _ 1 Enter/Exit :_ ~,~` ,~ f ~~ -- 1 ~~ J ~. Enter/Exit N WELL PRODUCER ' DATE :03/28/2006 SCALE : 1 " = 250' MAP DATE :2004 - WELLINJECTOR ® PBU DSL5 bs14495.dgn • TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF First National Bank Alaska Anchorage, AK 99501 MEMO ~ / ~ v7J • 89-6i 1252 269 DATE t/ ~~I~ ~~~o $ ~~~~® ~:~25200060~:99L4~~~6227~~~~5561~' 02.69 • ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ (,J ~-~-- ~ $'~ PTD# -~~`~~O Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name~,has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\jody\transmittal checklist i 1 - - __ ~_ N ~ p ;; a~ a N W N ~ O a > Q ~. ~, I ~ - '. ii ~I! C~~ ~' ~ OBI '~ ~. li O ~'. I O ~I ~ ~, O ~ ~, C E O i d O i J ~ ~ ~ ~ ~ ~~ ~' ~ i ~ it W w~ ~. I N ~ III _~ ~ NI a oi~ o ~: ~ ~ ~, o ' ~ ~, ~~ a ~ a .v ~ II m ui o ~ ~ ~' o U O, O, x i, Z'~ O Z U M to ~: ~: ~ I a, ; I w~ ~ : o. , N~ U1 fp N~ N~ N~ N~ tlD N~ N fA, N~ VD .. N, N N N N' N N' (A~ N ~ ~ ~,. a~~ a~ a~~ d~ a~~ a~, a~~ a~: a~~ a~ a~~ a~, a~ Q Q Q. Q. Q Q, Q: Q. o Q a~: a~ a~: Q. a~: a~~ d~ d: a~, a~~ Q. o: Q. Q Q. Q i Q >•, } } >-, ~ ~ ~, ~, } >- } } } Z, Z, Z, Z. Z Z, Z. Z Z Z ~, } } Z ~ >- >-, }, }: }, Z, Z: Z. Z. Z. Z LL T I ' U w, a c - ~~ E: 3, I- o , ~, m: p Z ~ ~ : T N C c' t' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .. ~ ~ O• ICI ~' N N I ~W i ~ ~ f0 ~ ~ ~~ ~ ~ UY O Vl: ~~ ~ UpOfi ~ ~ ~ ~ y: ~ ~Q ~ ~ O. W: ~ Xi Z I ~ a ~ ~ ~ ~ > •C: ~O N. ~ ~. d ~ ~ ~ ~+ ~, ~, N• ~ a~ c> m c o N N o d O. c~ ~ N i 3 .,: o m ~ ,N. d, c o. - Q, ~ 3. ~ a. ~: N Q ~ ~ y ~: ° '~ ~ T ~: :~ 4 ~ p ~ ° o ~ E a~i ~ •~ o rv -o O: , ~ N N y m r O) ~ ~~ Z ,in m °: ; d ar i ~ pY c rn a ~ c w° c 'Q °' Q' ; m N a> ~ of w ~ Z, ..a o c, .o. ~ o m ~ ~. °: a~ a a. ~~ o ~ y m: o o~ o~ y, ~ ~ ~ ~ c' ' c` ~' o o a~ w O ~ ~ ~ ~ E -, 'O. ~ C C E. ~, N O fog ~ C G in ~~ y, c O a~S~ ~ a: ~ C: CT L: rn Q' N L O: ~ ~ N. ~ w w' C U ~ ~~ U~ ~ ~~ Vi O O~ T ~ ~~ N. C ~ V' •4 .OQ ~ ~~ tl O, « d O ~~ 3: ~, >~ N N T ~ a. ~~ O C: ~ C.. p. O• G 00~ O y. f6: O N ~~~ 16 Q' N a' N' T O O) O N E' oo. ° `~ °~ r a o' ° °~' c' m o: p c a w Z' o E ~' ; a~ o ~ L m 3 a I Q :: ° ~ ~ a m °: w ~ r a. «r ~ v N m' `°' c ~? N M m 'N ~ ~ o N' oa o: 3 I o •c S ~ 3. o Z m. o ~ u, ~ `-° ~ n ° 3, 3 a~i: ~ a~ ... ~N: ~ v_. N' •~, .°-~ 3, ~ ~ O n ° u°i o. ~ ~ ~ o 13 °?: t a~ o O o c': •~ v_ 'v >~ o a~°i n v. v o o, '~ o: o, , ~o ~ o o c a o ~ °~~ v° ~~ a~~ n °~ o. rn c I -a~ o N: Z p~ HI aai' n -p m d ~ .n ~ o > > a c ~ ~i, V' d o' 43 p Y v ai ~ ~ •o m' ~' rn o ~' °' c' o N. o otS ~, L m a~ ~ 0 0 01 m' ~ n N N ~ s' ~ ~', o; of a. m' iv m, p' rn p o ~' 01 >, .c v •3. 2 ~°' uNi ° ~ o n a~-i O, ,pf0, ~ 5. a o. m 3 a m m. p a~ 3. c rn ~ ~' s as m ~; Y. m~ 'S n ~, m o ~: o o. p~ T m ii ~ ~, ~ c -o a v, o N: N a: a s w v c I N •N m. a~ > o? ~: s~~ N '~ ~, p a c m c~ c' m v a a o~ ~ 3 v' o w c ~ ~ m _ a~' ..'' m m m ~ o t '~ ~ E ~' y ~ ~ I o. cf0i, m m ~ a ~ ~ ~ -~ a ~ °' ~ ~ ~ v°i U ~' c' to ~, ,`, aci ~' o 0 0 .~ ~ ° ° ~ o n ~ ~ > >' •3 0 a v o- r oy v% Y ;' N m = a . ~ n. m, m o. N n. c. ~ m c w w a~ s E :°. ~! m E' N g - - - +,~- d m: m ~ ~, c 3 ~. ~ c. ~. F- I- I-, 'N a~, y, ? - n. a o. a a v. I ~ ;n y m c ~ y "c ~' ° °, ~ a a. o. m, m. m. ~ - ~ U, o, ° ~, ~; ~, m v: m a. 'v - O:, O: t, m ! p m a~ o o, V ~ a, ~ ~ ~ ~' ~ cn, ~-; o o a, a, v. S' a a: ¢, ~ v. <n v, v, c.z ~ a. ~- a. ~- o. m, m v ~', ~'', ~', a, o, m, m: v, w d ~ N M a to f0 f~ aD O O ~ N M~ ~~ M O n O O ~ N M V U) f0 ~ ~ N M~~ (D f~ GO O) ~ _ _ ~ N N N N N N N N_ N N M M M M M i M M M M M U o co co o o F, ad. N a~+ N r N N ~.. O O O ~ ~ Q N ', ~ N ~` O N ~ C ~ ~ M Q O .+ ~~ J N c L i s ~ a ~ o ~ ~aa as ~I` a~ II~a~ W I t7 V c\ I ~1 . V ~i `m c O U '~ a N~ a'~ E O U ~' N 0 (_ rnp C c O .C •N c o w U a3 m C U O O N N U • • Well I-lisiory 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 Nistory file and to simplify Tending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • **** REEL HEADER **** MWD 07/05/16 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MGdD 06/07/09 1163028 Ol 2.38 CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 10714.0000: Starting Depth STOP.FT 12800.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska) Inc. WELL. WELL: L5-28A FLD FIELD: Lisburne LOC LOCATION: 70 deg 20' 6.293" N 148 deg 14' 8.524" W 2147' FSL, 29'FWL CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska 5RVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.38 CTK DATE. LOG DATE: 09-Jul-06 API API NUMBER: 50029217170100 Parameter Information Block #MNEM.UNIT Value Description #--------- --------------- ---------- SECT. O1 Section TOWN.N 11N Township RANG. 15E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 60.0 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F N/A Elevation of Kelly Bushing EDF .F 60.0 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 ao~ -o~d ~ ~ 5aa 5 • • Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2} All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5} Tools ran in the string included Casing Collar Locator, and Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Directional, Outer Downhole Pressure, and Downhole Weight on Bit), a and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log as there is no common interval with L5-28 well below casing and this well. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) This well was drilled from L5-28 through a milled window in 4.5" liner: Top of Window 10714.6 ft.MD (8749.4 ft,SSTVD) Bottom of Window 10726.4 ft.MD (8759.2 ft.SSTVD) (8) The interval from 12770.0 ft.MD to 12800.0 ft.MD (8730.0 ft.to 8729.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied to L5-28 at 10700 ft.MD (8737.0 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units} ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN L5-28A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN L5-28A FN Lisburne COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • The data presented here is final has not been depth shifted. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F J Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MGTD 68 1 F/HR 4 4 8 Total Data Records: 50 Tape File Start Depth = 10700.000000 Tape File End Depth = 12799.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 59 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU • ------------------ WDFN L5-28A.xtf LCC 150 CN BP Exploration (Alaska) WN L5-28A FN Lisburne COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 100 Tape File Start Depth = 10700.000000 Tape File End Depth = 12799.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 109 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD C~ 06/07/09 1163028 01 **** REEL TRAILER **** MWD 07/05/16 BHI 01 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • i Tape Subfile 2 is type: LIS DEPTH GR ROP 10700.0000 -999.2500 -999.2500 10700.5000 -999.2500 -999.2500 10800.0000 27.4000 19.0000 10900.0000 22.3000 46.9000 11000.0000 25.9000 7.9000 11100.0000 17.2000 25.6000 11200.0000 48.4000 59.3000 11300.0000 15.5000 26.2000 11400.0000 42.9000 58.7000 11500.0000 44.3000 56.6000 11600.0000 19.2000 32.2000 11700.0000 11.7000 20.3000 11800.0000 20.6000 82.7000 11900.0000 12.1000 84.3000 12000.0000 23.5000 90.9000 12100.0000 13.1000 96.4000 12200.0000 13.5000 43.7000 12300.0000 18.6000 68.3000 12400.0000 20.5000 922.6000 12500.0000 21.3000 60.0000 12600.0000 20.2000 63.7000 12700.0000 22.9000 63.8000 12799.0000 -999.2500 -999.2500 Tape File Start Depth = 10700.000000 Tape File End Depth = 12799.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GR ROP 10700.0000 -999.2500 -999.2500 10700.2500 -999.2500 -999.2500 10800.0000 27.4000 19.0000 10900.0000 22.3000 46.9000 11000.0000 25.9000 7.9000 11100.0000 17.2000 25.6000 11200.0000 48.4000 59.3000 11300.0000 15.5000 26.2000 11400.0000 42.9000 58.7000 11500.0000 44.3000 56.6000 11600.0000 19.2000 32.2000 11700.0000 11.7000 20.3000 11800.0000 20.6000 82.7000 11900.0000 12.1000 84.3000 12000.0000 23.5000 90.9000 12100.0000 13.1000 96.4000 12200.0000 13.5000 43.7000 12300.0000 18.6000 68.3000 12400.0000 20.5000 922.6000 12500.0000 21.3000 60.0000 12600.0000 20.2000 63.7000 12700.0000 22.9000 63.8000 12799.0000 -999.2500 -999.2500 Tape File Start Depth = 10700.000000 Tape File End Depth = 12799.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~, Tape Subfile 4 is type: LIS • Lisburne CTUBD N0~9 Pressure Test UBD BOP Stack /Rig Choke Manifold Revision of June/2/2006 JOB DESCRIPTION FOR: HAZARDS MlT-GATION P.Test UBD BOP Stack / Rig Choke Manifold 1 Install two-wa check back- ressure valve . 2 Notify AOGCC representative 24 hrs in advance of ressure test. 3 Document the placement, and type of all BOP Rams. Diagram of each BOP Stack and related Well Control E ui ment, with s ecifications 4 Using AOGCC regulations pressure test Pipe Rams, Blind Rams and associated valves on Stack and Rig Choke Manifold to 400psi low test and 3500psi high test. Using AOGCC regulations, Annular will test to 400psi low test and 2500 si hi h test. 5 Function test BOP Rams, Annular, and HCR (Never function test Combination Rams or Annular w/o correct i e "oint in hole . 6 Inspect BOP Test Sub -Must have upset to prevent blowing out of stack under pressure, must have proper O.D. for annular tested, and must be of proper rating for test pressure. Ensure Test Hose connections are matched to test hose and have correct ressure ratin . 7 Hold Pre-Test Safety Meeting, all testing standards will be covered as well as job assignments for all involved. Testing procedures and all safety aspects will also be covered, requiring involvement from all team members. Safety is our greatest concern. Ac uire Permit. 8 Notify all non-essential personnel to clear the rig until testing is complete. Signs and barriers are in lace. 9 Install 2" test joint. Note - 2" test joint must be long enough to extend down thru Lower set of 2" Combination Pipe/Slip Rams (BOP15). 10 Hook u test um hose to to of test 'oint. 11 Open all valves on Mud Cross (between BOP11 and BOP12), and all valves on choke manifold (except valves going outside rig - Ensure valves CM9, CM10, CM11, CM17, CM18, CM22, CM23, BOP9, and BOP18 are closed on ri choke manifold . 12 Verify Test Pump Pop-off (Relief Valve) is set, line is clear, and test pump is operational and ro erl lined u . 13 Close upper 2" rams (BOP11). Fill test joint, stack, and choke w/ H2O. Open up er 2" rams BOP11 . CTUBD N019 Pressure Test BOP Stack /Rig Choke Manifold Rev2 1 of 6 aa~ - orb Lisburne CTUBD N019 Pressure Test UBD BOP Stack /Rig Choke Manifold • Revision of June/2/2006 • 14 All test pressures are to be verified by company man and AOGCC Representative (if test not waived by the State of Alaska). Pressures are not to exceed manufacturer's rating on equipment. Test and Working pressures of all BOPE Equipment and the Clients Wellhead must be verified. Low-pressure tests are to be held for 5 minutes, and High-pressure tests are to be held for 5 minutes. For Pipe/Slips and Blind/Shear Rams -Close Rams at 1500psi and increase the manifold pressure to 3000psi for testing. Pressure testin must be charted. 15 Close upper 2" Combis (BOP11), ensure Choke HCR (BOP6), Wing Valve (BOP8), Outside Manual Valve on Lower 2" Pipe/Slips (BOP18), and Kill Line Manual Valve (BOP2) are closed. Open Annular (BOP16) and increase manifold pressure to 3000psi. Test to specified pressures, verify, and bleed off. Note:. Kill Line Check Valve (BOP19) must be crippled in order to enable a flow path when testing Manual Kill Line Valve (BOP2). Valves MM3, MM7, MM9, Manual Choke MM20, and Baker Choke MM21 must also be open to com lete the flow ath. 16 Bleed manifold pressure to 1500psi, open Upper 2" Combis (BOP11). 17 Close Lower 2" Combis, (BOP15). Test to specified pressures, verify, and bleed off. Bleed manifold pressure to 1500 psi, open HCR (BOP6) and Lower Combis (BOP15). 18 perform draw down test at this time. 19 Rig down and remove 2" test joint, Pick up and rig up 2-3/8" ported test joint. 20 With port positioned below 23~$" Lower Combis (BOP13), close Annular (BOP16), fill test joint, choke and kill lines. Close Upper 23~$" Combis (BOP12), Inside Manual Valve off of Lower 2" Combis (BOP17), and ESD (BOP9). Increase manifold pressure to 3000psi, pressure test to specified pressures. (BOP1, BOP7, BOP8, and BOP18 should be open). We are testing against a closed BOP9 and BOP17. Verify and bleed off. 21 Bleed manifold pressure to 1500psi, open Upper 238° Combis (BOP12). CTUBD N019 Pressure Tit SOP Stack /Rig Choke Manifold Rev2 2 of 6 Lisburne CTUBD N019 Pressure Test UBD BOP Stack /Rig Choke Manifold • Revision of June/2/2006 . 22 Close Lower 238" Combis (BOP13). Increase manifold pressure to 3000psi, pressure test to specified pressures. BOP1, BOP7, BOP8, and BOP18 should be open. We are testing against a closed BOPS and BOP17. Verify and bleed off. 23 Bleed manifold pressure to 1500psi, open Lower 238" Combis (BOP13). 24 Position test joint port above Lower 23~$" Combis (BOP13). Close Annular (BOP16), Lower 238" Combis (BOP13), Manual Valve to Rig Choke Manifold (BOP5), and Manual Kill Line Valve (BOP2). Open HCR (BOP6). Increase manifold pressure to 3000psi and test Annular (BOP16) to specified pressures (Refer to step 4), verify, and bleed off. 25 Bleed manifold pressure to 1500psi, open Lower 23~$" Combis (BOP13) and Annular (BOP16). Rig down and remove test joint from BOP's. 26 Hook up test pump to Lower Manual Outer Kill Line Valve (BOP18). Close Upper Blind/Shear Rams (BOP10) -Open BOP2, BOP9, BOP17, BOP18, MM3, MM7, and Baker Choke MM21. Ensure BOP5, BOP8, MM5, MM8, and MM12 are closed. Increase manifold pressure to 3000psi. Test to specified pressures, verify, and bleed off. Note: This test will ensure Kill Line Check Valve (BOP19) holds pressure. BOP19 will need to be un-crippled before this test. 27 Bleed manifold pressure to 1500psi, open Upper Blind/Shear Rams (BOP10). Shut Upper Swab Valve (BOP7), Manual Kill Line Valve (BOP2), MM3, MM7, and Baker Choke MM21. Open MM5 and MM12. Test to specified pressures, verify, and bleed off. 28 Shut Lower Swab Valve (BOP1). Test to specified pressures, verify, and bleed off. Open Lower Swab Valve (BOP1). 29 Shut Lower Blind Shears (BOP14). Increase manifold pressure to 3000psi. Test to specified pressures, verify, and bleed off. Bleed off manifold pressure to 1500psi, open Lower Blind Shears (BOP14). Close BOP17 and BOP18 -LOCKOUT. Rig down hose and test pump, take to Rig Choke Manifold. CTUBD N019_Pressure Test BOP Stack /Rig Choke Manifold Rev2 3 of 6 Lisburne CTUBD N019 Pressure Test UBD BOP Stack /Rig Choke Manifold Revision of June/2/2006 • 30 Rig hose and test pump to CM14 on Rig Choke Manifold. Turn on water to test pump to purge air from hose and choke manifold. Ensure HCR Valve BOP6, CM9, CM10, CM11, CM15, CM17, CM18, CM22, and CM23 are closed. CM1 -CM8, CM12, CM13, CM14, CM20, CM21, Tri-Flow Choke CM75, and Manual Choke CM85 are open. Test to specified pressures, verify, and bleed off. 31 Close CM3, CM4, CM7, CM8, CM11, and CM19. Open CM9, CM10, and CM15. Test to specified pressures, verify, and bleed off. 32 Close CM1, CM2, CM6, and CM13. Open CM3, CM4, CM7, CM9, CM11, CM15, CM20, and CM21. Ensure that Tri-Flow Choke CM75 and Manual Choke CM85 remain open. Test to specified pressure, verify, and bleed off. 33 Close choke valve CM14 and Open CM1. Test to specified pressure, verify, bleed off. 34 Rig down hose and test pump. Open CM14, function test Manual Choke CM85 and Tri- Flow Choke CM75 and leave closed. Line up valves on Stack and Rig Choke Manifold as per valve positioning upon UBD Start-Up (Refer to CTUBD N001). 35 Assign Pump. 36 Notify all crew members of intent to pump, if o.k., come on line with the pump at minimum rate. 37 Shut down pump if pressure appears above normal and double check all valves. 38 When returns are seen at the pits shut down pump. 39 Close choke and do a full system test of all surface equipment with the mud pumps. Pump trips will trip when pressure reaches 1500psi (If not they must be repaired before testing continues). Reset trips to 5000psi. Test system to 300psi (low) and 5000psi (high). Verify and bleed off. 40 Line up to pump down the kill line, reversing the coil. Close inner reel valve. Test system to 300psi (low) and 5000psi (high). Verify and bleed off. Remove back-pressure valve if in use. 41 Remove injector from well and circulate coil to prevent freeze up if temperature dictates. CTUBD N019_Pressure Test BOP Stack /Rig Choke Manifold Rev2 4 of 6 - - Lisburne CTUBD N0~9 Pressure Test UBD BOP Stack /Rig Choke Manifold Revision of June/2/2006 Ste Activit Standpipe (Mud) Manifold + SLB High Pressure Manifold Pressure Test 1 To be develo ed 2 3 3 4 5 6 7 8 9 10 Accumulator Test Draw down test can be done now by running a proper sized joint in BOP - 2-3/8" test joint or 2" test joint. 1. At accumulator record system pressure (3000psi), turn electric pump to off position and shut off air-to-air pump. 2. Close both 2-3/8" pipe/slips and the Variable Rams. Close annular and the HCR. DO NOT CLOSE -Blind/Shears. 3. Record pressure after function of BOPE 4. Prepare to time system pressurization. 5. Turn electric pump to on position. 6. First 200-psi w/electric pumps only. After first 200psi, both electric and air pump can be used. 7 Note time lapse from pressure to a 200psi pressure gain on system. 8. Continue to time pressurization until system is at 3000psi and both electric and air pumps are at off position. Record the time. 10. Open all pipe/slip and Variable rams, HCR, and Annular. 11. Record nitrogen bottle pressures. 12. Remove Test Joint from BOPE 13. Fill out State of Alaska BOPS Test Report. 14. Accumulator nitrogen pre-charge pressure should be checked and recorded once a month. Specific Safety Precautions Tools CTUBD N019 Pressure Test BOP Stack /Rig Choke Manifold Rev2 5 of 6 M ~ - - Lisburne CTUBD N019 Pressure Test UBD BOP Stack /Rig Choke Manifold Revision of June/2/2006 June 2, 2006 Earl Dietrich Blade Ener Changed Valve #'s REV.3 gy Added Hazard/Miti ation CTUBD N019_Pressure Test BOP Stack /Rig Choke Manifold_Rev2 6 of 6
