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206-083
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN t 5 inin 1. Operations Performed //11 Abandon ❑ Plug Perforations ❑ Fracture Stimulate [I Pull Tubing ❑ Operation td P, f' (' ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Acid Stimulation 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number. 206-083 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6API Number: 50-029-21700-01 -00 7 Property Designation (Lease Number): ADL 028320 8. Well Name and Number: PBU L5 -16A 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: Total Depth: measured 10875 feet Plugs measured None feet true vertical 8975 feet Junk measured None feet Effective Depth: measured 10875 feet Packer measured 8715 feet true vertical 8975 feet Packer true vertical 8521 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 42-122 42-122 1490 470 Surface 3967 10-3/4" 41 -4008 41 -4000 5210 2480 Intermediate Production 9059 7-5/8" 38-9097 38-8874 7900 6560 Liner 294 4-1/2" 8803-9097 8602-8874 8430 7500 Perforation Depth: Measured depth: 8876-10875 feet True vertical depth: 8670-8975 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 36-8802 36-8602 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8715 8521 true vertical depth) 4-1/2" HES WellStaf TRSSSV 2177 2177 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8876'- 10875'(L5 -16A) Treatment descriptions including volumes used and final pressure: RIH with Stimulation Packer BHA. Sting in to ML KB Packer and set. Pump ETCHNDA acid stage into motherbore (1-5-16A). Open circ -sub and then pump ETCH/VDA acid stage into L5-16AL1. Pump Stimulation #3 down the backside into L5-16AL2. Well was on a vac during the entire stimulation. Acid Volumes. Pumped: 111 bbls VDA and 259 bbls ETCH. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McF Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 95 1404 54 0 632 Subsequent to operation: 797 5103 1099 2435 779 14. Attachments: Ireq�i.d per 20 roc 25.070.25.071, s 2s.2es7 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Sauve, Mark A Contact Name: Sauve, Mark A Authorized Title: GPMA/Llsburne Lead PE Contact Email: Mark.SaUveCbp.com Authorized Signature: Date Contact Contact Phone: +1 907 564 4660 Form 10-409 Revised 04/2017 gBDMS (!G JAN 16 2020 Submit Original Only Daily Report of Well Operations PBU L5 -16A ACTIVITVnATF Q [BARRAw ***WELL S/I ON ARRIVAL*** (Acid) TAGGED TRSV AT 2,177' MD WITH 3.84" NO-GO CENT RAN FLAPPER CHECKER TO TRSV AT 2,177' MD RAN 3.50" LIB TO TOP OF KB PKR AT 8,969' MD TAG BOTTOM AT 9,106' SLM WITH 1.90" CENT & 1.50" S. BAILER 12/8/2019 ***CONT WSR ON 12/9/19*** ***CONT WSR FROM 12/8/19*** (acid) SWCP 4521 RIG DOWN 12/9/2019 ***WELL S/I ON DEPARTURE*** CTU#8 1.75" CT. Job Scope: Acid Stimulation MIRU CTU. MU & RIH w/ Baker PISS ( Pressure Indicating Seal Sub) BHA. Bullhead well w/ 1% KCL & diesel. Well was still dead after pumping 248 bbls of diesel. Attempt to sting into the ML KB Pkr at 8940' ctm. Did not see any circ pressure changes while attempting to sting in. Pooh pumping diesel down backside. Redress seal sub and reconfigure BHA. Re -run Baker PISS (pressure indicating seal sub). RIH and stab into ML KB Packer at 8958' ctm. Able to sting in and ensure seal integrity, seat shifted at 2400 psi. Pump diesel down the backside while stung in and unable to maintain fluid level at surface at rates below 3.0 bpm. Unsting and POOH. Make up Stimulation Packer BHA and RIH. 12/22/2019 ...Continued on WSR 12-23-19... CTU #8 - 1.75" Coil, 0.156" wt ***Cont. from WSR 12-22-19*** Job Objective: Acid Stimulation RIH with Stimulation Packer BHA. Sting in to ML KB Packer and set. Pump ETCHNDA acid stage into motherbore. Open circ -sub and then pump ETCHNDA acid stage into L1. Pump Stimulation #3 down the backside into L2. Well was on a vac during the entire stimulation. Was unable to underbalance the well with diesel, the well remained on a Vac. Release Baker Pkr. Pooh. Recovered ball. Lost 1 element. Freeze Protect Tbg w/ 42.5 bbls diesel. 12/23/2019 ***Job Complete*** TREE= 4-1/6" CIW 1A 3-LHEAD = CNV ACTUATOR= CIWSH3000 KB. ELEV = W. BF. ELEV = NA KOP= 3800' Max Angle = 99" @ 9326' Datum M7= 9087 Datum TVD= 89001SS 3/4" CSG, 45.5#, K - TO L-80 VAM R. 91.5#. H-40, D= SAFETY NOTES: WELL ANGLE> 70° @ 9206'. �5i ��� � ***CAT I SSSV H2S (PPM) 250 "• 10-3/4" CSG, 45.5#, L-80 VAM, D=9.953"4006' Minimum ID = 2.010" @ 8973' 2-7/8" XN NIPPLE (KB PKR ASSN 1-12" TBG, 12.6#, L-80 13T -M, .0152 bpf, D = 3.958" TOP OFA 12^ LNR PERFORATION SUM10ARY REF LOG: ANGLEAT TOP PERF= 23° @ 8876' Note: Refer to Production DB for historical pert data SQE SPF INEWAL Opn/Sgz I SHOT T SOZ 2-1/2" 6 8876-8900 O 07/17/18 1229/19 1 6973' 1 ' BKR WHIPSTOCK' BKR WHIPSTOCK (06/14106)) —L!p!T ELM fELM f RA PP TAGS (TWO) (06/14/06)9106' . 4-12" SCAB LNR 12.6#, L -80167-M, D=3.958" 9206' 1 7-5/8" CSG, 33.7#, L-80 NSCCJBUTT, D= 6.765" I 1 2177' 1 QAS I PT M4Nn PPI R = 3.813" ST MD TVD DEV TYPE VLV I LATCH I PORT DATE 5 2781 2780 2 KBG-2 DOME BK 16 1229/19 4 4708 4694 4 KBG-2 SO BK 20 1229/19 3 6387 6371 9 KBG-2 DMV BK 0 05/17/09 2 7603 7509 26 KBG-2 DMY BK 0 05/17/09 1 8616 8430 24 KBG-2 DMY BK 0 05/17/09 FES X NP, ID = 3.813- 7 -5/8"X .813" 7 -5/8"X 4-12 BKR S-3 4-1/2" H6 X NP, ID = 3 I4-1/2" WLEG, D 2 958" 7-5/8" X 5-12" ZXP LTP w / 115' PTR. D = 4.810" 5-1/2" X 4-12" XO, L2 (OPEN HOLE COMPLETION) ® --"so' 3.80" MILLOUT WINDOW (L5 -16A -L2) 8936' - 8947' L1 (OPEN HOLE COMPLE ) 3.80"MILLOUTWIJDOW(L5-16A-1-1) 8961'-8974' L5 -16A (OPEN HOLE 3.80" MILLOUT WINDOW (L5 -16A) 9097'-9109- DATE 097'-9109' LISBURE UNIT WELL: L5 -16A PERMIT No: 2060830,(40),(50) APINo:50-029-21700-01,(60),(61) SEC1,T11N,R15E 1788'FSL819'FWL DATE REV BY COMMENTS DATE REV BY I COMMENTS 03M7107 RWN 41 ORIGSUSPENDED 09/19/17 JMGtJMD PULLED STRADDLE PKR(9/16/17) 06/03187 NORDIC ORIGINAL CONPLETION 05107/18 KP/JMD TREE CIO (05/02118) 06101106 NORDIC RWO 07/17/18 MS1JMD PERFS (07/17/18) 09101/06 NORDIC MULTI- LAT(L5-16A, AL18.AL2) 01/0220 JPK/JMD GLVC/O(1229/19) 12/04/08 RRD/PJC SET STRADDLE PKR 1123708 BP Exploration (Alaska) 06/01/09 SEW/TLH GLV C/O (05/17)09) STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMIS EPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Rednll 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Remove Patch El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 206-083 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21700-01-00 7. Property Designation(Lease Number): ADL 028320 8. Well Name and Number: PBU L5-16A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL RECEIVED 11.Present Well Condition Summary: OCT7 Total Depth: measured 10875 feet Plugs measured None feet C` 1 o 2017 true vertical 8975 feet Junk measured None feet Effective Depth: measured 10875 feet Packer measured 8715 feet AOGCC true vertical 8975 feet Packer true vertical 8521 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 42-122 42-122 1490 470 Surface 3967 10-3/4" 41-4008 41 -4000 5210 2480 Intermediate Production 9059 7-5/8" 38-9097 38-8874 7900 6560 Liner 403 4-1/2" 8803-9206 8602-8951 8430 7500 Perforation Depth: Measured depth: 9098-10875 feet True vertical depth: 8875-8975 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36-8802 36-8602 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8715 8521 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): sates DEC 2 1 2017 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: 287 2930 252 0 620 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,6 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas 0 WDSPL ❑ 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 Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: GPMA/Lisburn ead Contact Email: Mark.Sauvenbp.com Authorized Signature: e_----..._ Date: f ...-/7_1-4- Contact Phone: +1 907 564 4660 ✓ Form 10-404 Revised 04/2017 Vn- Z // /lil /,� RB Dovia \V OCT 2 5 2017 Submit Original Only • • Daily Report of Well Operations L5-16A / AL2 ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL***(Profile Mod) DRIFT W/3.805" G. RING &TAG Straddle packer @ 8902' SLM JAR ON 45 KB STRADDLE PATCH FOR 2 HOURS W/0.125"WIRE TO 1800 LB 9/15/2017 ***CONT. ON 09/16/17 WSR*** ***CONT. FROM 09/15/17 WSR*** (Profile Mod) PULL 45 KB STRADDLE PATCH FROM 8902' SLM (one rubber element not recovered). RUN 4-1/2" BRUSH & 3 PRONG 3.50" WIRE GRAB, STOP @ 8912' SLM (nothing recovered) 9/16/2017 ***WELL TURNED OVER TO DSO*** TREE= 4-1/6"FMC `"EL" 'D `IW L5-1 6A SAFETY NOTES: O V WELL ANUE?70°@ 9206'. CAT l H S{PPM)250 AGTUATOR= AXELSON KB. = Gtr AL1 & AL2 BF.ELEV= KOP= NA 3800' Coax Angle= 99"@ 9326' If Datum MD= 9082' Datum TVD= 8900'SS 2177' —14-1/2"FES WELLSTAR TRSSSV,D r 3.813" 10-314"CSG,45.5#,K-55 BUTT -L65' XO TO L-80 YAM GAS UFT MASS ST MD TVD DEV TYPE VLV LATCH PORT DATE 20"OONDIJCTOR 91.5#,H-40,D=19.124" —j 80' LI5 2781 2780 2 KBG-2 OW BK 0 05/17/09 4 4708 4694 4 KBG-2 DMY BK 0 05/17/09 10-3/4"CSG,45.5#,L-80 VAM,D=9.953" H 4006' 3 6387 6371 9 KBG-2 DMY BK 0 05/17/09 2 7603 7509 26 KBG-2 DMY BK 0 05/17/09 Minimum ID =2.010" @ 8973' 1 8616 8430 24 KBG-2 DMY BK 0 05/17/09 2-7/8" XN NIPPLE (KB PKR ASSY) I I 8684' H4-1/2"FES XI43,D=3.813" ZI X 8704' H7-5/8"X4-1/2 BKR S-3 PKR,ID=3.870" ' , 8728' H4-1/2"FES X MP,D=3.813" 1 4-1/2"TBG, 12.6#,L-80 BT-M, —I 8792' _0152 bpi,D=3.958" 4._ . 8792' 14-1/2"WLEG,D=3.958" TOP OF 4-1/2"LNR —I 8803' 8803' 17-5/8"X 5-1/2"ZXPLTPw/11.5'PBI,D=4.90" ♦• TS \ 8820' H5"BOT FMC LM HGR,ID=4.810" ♦•• 4 8827' —I5-1/2"X 4-1/2"XO,D=3.958" i♦i • i♦•4 \ ♦�• L2(OPEN HOLE COMPLETION) )\ ♦♦i, %i %i; TD H 11500' i by Date 20-MAY-2015 Transmittal Number: 93426 40, BPXA WELL DATA TRANSMITTAL RECEIVED Enclosed are the materials listed below. MAY 2 0 2015 (BPXA LOG DATA) AOGCC If you have any questions,please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 04-21, 04-22, 04-33, C-01, C-31, L1-09, L2-03, L3-15, L3-31, L4-30, L5-01, L5-15, L5-16A, L5-16AL1, L5-16AL2, L5-31, L5-33, L5-36 04-21 185-212 2511H . 04-22 185-233 425345 04-33 186-035 as Please Sign and Return 'ne copy of this transmittal to; C-01 172-030 _7544 I C-31 188-006 251k5 gancpdc@bp.com L1-09 185-001 254y 9 L2-03 185-247 25 7 50 Doug Dortch L3-15 185-266 ;25-4.51 Petrotechnical Data Center SCANNED MAY 2 7 2015 L3-31 186-034 ,257852 L4-30 188-101 25153• L5-01 189-009 251E4Attn: State of Alaska - AOGCC L5-15 188-109 ,0751555 Attn: Makana Bender W. 7th Ave, Suite 100 L5-16A 206-083 2515(0• 333 L5-16A L1 206-084 25157- Anchorage, Alaska 99501 L5-16A L2 206-085 25 i L5-31 190-130 2515/ L5-33 189-047 2S' ,o• _L5-36 189-036 z5-116,l • Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 Image Projeet 1Nell History File C®Ver gage XHVZE This page identifies those items that were not scanned during the initial production scahning 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 IQ - ~~ ~ Well History File Identifier Organizing (done) ^ Two-sided IIIII'I()IIIIIIIIII ^ Rescan Needed IIIII'lIIIIII!)IIII RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: "l ~ ~, /s/ Scanning Preparation ~ x 30 = _~ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ Q ~~, f O ~j /sl '~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: __~YES NO BY: Maria Date: 1 ~ °a..~~~ !s/ ~M y `I'~ Stage 7 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 III II I I III Rescanned III IIIIIIIIIII VIII BY: Maria Date: !sl Comments about this file: o ~v~~,~k,a iiumiuiiumii 10!6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 � Post Office Box 196612 Anchorage, Alaska 99519 -6612 July 6, 2011 'g3 Mr. Tom Maunder 6-- Alaska Oil and Gas Conservation Commission )>C1(QP\ 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L5 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L5 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Lisburne 05 Date: 05/30/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ WeU Name PTD # API # cement pumped cement date inhibitor sealant date 15-01 1890090 500292190800 0.4 NA 0.4 na 1.7 5/23/2011 L5-04 , 1881910 500292167900 Sealed conductor NA NA NA NA NA L5-05 1870690 500292174200 Sealed conductor NA NA NA NA NA 15-08 1870300 500292171100 Sealed conductor NA NA NA NA NA 15-09 1901240 500292208600 Sealed conductor NA NA NA NA NA 15-12 1870100 500292169400 Sealed conductor NA NA NA NA NA L5-13 1831840 500292105900 0.6 NA 0.6 NA 1.7 5/24/2011 15-15 1881090 500292186800 Sealed conductor NA NA NA NA NA L5-16 A 2080830 500292170001 Sealed conductor NA NA NA NA NA L5-17 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 15-19 1900680 500292205200 P&A 9/24 NA NA NA NA NA 15-21 1870570 500292173200 Sealed conductor NA NA NA NA NA L5-23 1900500 500292203900 Sealed conductor NA NA NA NA NA L5-24 1850880 500292132700 0.1 NA 0.1 NA .85 5/30/2011 L5-25 1881350 500292188600 Sealed conductor NA NA NA NA NA 15-26 1901100 500292207900 1 NA 1 NA 3.4 5/30/2011 15-28 2060700 500292171701 Sealed conductor NA NA NA NA NA L5-29 1870450 500292172400 Sealed conductor NA NA NA NA NA L5-31 1901300 500292209100 0.8 NA 0.8 NA 3.4 5/28/2011 L5-32 1881020 500292186100 0.3 NA 0.3 NA .85 5/28/2011 L5-33 1890470 500292194300 0.3 NA 0.3 NA .85 5/28/2011 L5-34 1980850 500292288300 0.3 NA 0.3 NA .85 5/28/2011 15-36 1890360 500292193300 0.6 NA 0.6 NA 1.7 5/28/2011 • r~~ ~~` ~~ .. .. t ,~,~. ,~ ~: ~ . ~,..,~ j . ~',, , , ~- MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATE RI/~L UNDER THIS .PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • Maunder, Thomas E (DOA From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Thursday, January 29, 2009 10:13 AM _ .__ To: Maunder, Thomas E (DOA) Subject: Emailing: L5-16AL2.PDF Attachments: L5-16AS,2~PDF ~_4r~. L5-16AL2.PDF (37 KB) «L5 -16AL2 . PDF» The message is ready to be sent with the following file or link attachments: L5-16AL2.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. S U Mi~cc~ ~~v,~ c~ ~ ~ ~~~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) ~.:5 w~~~ :So`~~5 ~.s^« ~~a Sent: Thursday, January 29, 2009 8:58 AM To: 'Preble, Gary B (SAIC)' G~c~~€S ~Q ~©~~~ ~~~~~b~~S Subject: L5-16A (206-083) and L5-16AL2 (206-085) (~>~vC~OV\ . Gary, You have submitted dual 404s for the work done to isolate LS-16AL2 in the LS-16A wellbore, however you included the procedure not the operations summary. Could you please send the ops summary? Email is fine. Tom Maunder, PE AOGCC Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 4:59 PM To: 'Preble, Gary B (SAIC)' Subject: L5-16A (206-083) Gary, Last one for today!! I briefly looked at the 404 submitted for placing the patch to isolate L5-16AL2 (206-085). Has a 404 for L5-16AL2 been submitted? It may be in the stack and !haven't gotten to it yet. Thanks in advance. Tom Maunder, PE AOGCC STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~~~ /~?~/~~~ 1. Operations Abandon ~ Repair Well Q - Plug Perforations ~ Stimulate ~ ` Other ~ PATCH TUBING Pertormed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension 918 0-8920 Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 1~ Exploratory r 206-0830. 3. Address: P.O. Box 196612 StratigraphiC ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-21700-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 60 KB ' L5-16A 8. Property Designation: 10. Field/Pool(s): ADLO-028320 ~ PRUDHOE BAY Field/ LISBURNE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10875 ~ feet Plugs (measured) None true vertical 8974.54 - feet Junk (measured) None Effective Depth measured 10875 - feet true vertical 8975 - feet Casing Length Size MD TVD Burst Collapse Conductor 120' 20" 91.5# H-40 Surface - 120' Surtace - 120' 1490 470 Surface 4006' 10-3/4" 45.5# L-80 Surface - 4006' Surface - 3998' 5210 2480 Production 9559' 7-5/8" 29.7# L-80 Surface - 9559' Surtace - 8918' 6890 4790 Liner 2072' 4-1/2" SL 12.6# L-80 8803' - 9098' 8602' - 8873' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 8792' 3.70 SINGLE SET BAKER PATCH 0 ~9'1'Q X920' $~05-~~13 Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" BKR S-3 PKR 8704' ~SO~QH LOWER KB PKR " " ~ 8969' ' ~S ~~ ~ ~ \ 45 KB UPPER STRADDLE PKR 8905 "~ 45 "KB" LOWER STRADDLE PKR 8925' ~~ 12. Stimulation or cement squeeze summary: la4 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: 557 26619 13 1358 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~° ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' - Gas ~ WAG GINJ ~ W INJ W DSPL ~` 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 Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 12/16/2008 I Form 10-404 Revised 04/2006 ~ ~a~ ~~ ~ 2oas ~-~~~ Submit Original Only L5-16A 206-083 PFRF ATTA[_I-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L5-16A 9/1 /06 OH 9,098. 10,875. 8,874.75 8,974.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • L5-16A ~ t..,s' -1 ~ Ps ~ ~ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/20/2008 *""WELL SHUT-IN ON ARRIVAL""* INITIAL T/IA/OA: 2200/2200/0 PSI STANDBY FOR SWS CRANE TO RIG UP EL1NE FOR JEWELRY LOG/PATCH I *'"*CONTINUED 21-NOV-2008**" _ _ '~ 11/21/2008 ***CONTINUED FROM 20-NOV-2008*** INITIAL T/IA/OA: 2200/2200/0 PSI RIG UP ELINE FOR JEWELRY LOG / PL LOG WITH X/Y CALIPER 8380-9050 FT, VERIFY L2 LATERAL DEPTH FROM 8910-8920FT. -NOV-2008*"'` "*'` "*" 11/22/2008 CONTINUED FROM 21-NOV-2008 ` T/IA/OA: 2200/2200/0 PSI MISRUN ON PATCH SETTING PASS DUE TO BAD IGNITER. REATTEMPT PATCH SET. ~ **''JOB CONTINUES 23-NOV-2008**" 11/23/2008 "**CONTINUED FROM~22-NOV-2008'`*" INITIAL T/IA/OA: 2200/2200/50 PSI 20' 3.70" BAKER PATCH SET ACROSS L2 LATERAL (8910-8920.5 FT) FROM 8905-8925 FT. PATCH TOP 8905 FT PATCH WLEG 8931.5 FT, MIN ID 2.313". ~ INAL T I O = 210 22 0/50 ***JOB COMPLETE"** t i u-. _~._.~ .-......~ ~ __ ~ ...._ FLUIDS PUMPED BBLS 1 diesel .5 MEOH WHILE POOH 1.5 Total • • by To: C. Olsen / J. Bixby, GPB Wells Operations Supervisor October 17, 2008 From: Shane Wills, Wells Group Scheduler Justin Nash, Lisburne PE Subject: L5-16AL2: GSO AL2 Lateral Isolation IOR: 200 BOPD LSL05WL16-N Attached is a procedure to install a ~20' 4 ~/z" Baker Single Set Patch with a Sliding Sleeve across the upper lateral of the L5-16A. This job includes the following major step: Step Type Procedure 1 S Drift with Baker Dummy Patch to 8969' DD 2 E Run Gamma Ray CCL Correlation Log Set Baker 4-1/2" Baker Single Set Patch w/ Sliding Sleeve • Current Status: • Last test: • Max Deviation: • BHP: • BHT: • Min. ID: • Last TD tag: • Last DH Ops: • Latest H2S Value: Obiective• P -Cycle (no gas lift). 582 BOPD, 14 BWPD, 25,910 MCFD, GOR=44,480 (09/17/08) 99° at 9,326' MD 3,177 psi C«3 8900'SS taken on 04/18/06 173 F C~ 8900'SS taken on 04/18/06 3" open hole sections, XN profile @ 8,973' MD, ID= 2.010" 9095' SLM (09/06/2008). SL D&T, PDS Caliper (09/06/2008). 60 ppm on 1/7/07. Isolate the upper-most lateral by installing a retrievable Baker ~20' 4-1/2" Single Set Patch with a Sliding Sleeve and Tail Pipe Assembly with Elements at 8905' (upper) and 8925' (lower). The top of the lateral window is C 8910' and the bottom of the window is @ 8920.5'. L5-16AL2 Lateral Isolation •h With Sliding Sleeve • Background Information: The L5-16 well was drilled and completed in July 1987 with 3-1/2" TBG in zones 6, 5, 4 and 1. After 19 years of production (1.53 mmbbls), various acid jobs and three cement squeezes, the well was sidetracked in June, 2006. The original 3-1/2" completion was pulled and a 4-1/2" tubing completion was run to 9,475' MD. A whipstock was then set at 9097' MD and the first of three multilaterals were drilled under-balanced with UBCTD. The well initially produced at high rates, although after one year the GOR started to increase. In August 2007 the well reached MGOR and had to be cycled. Since that time the well has been a sporadic cycle producer, but has struggled to produce with a GOR below 40,000, and be a full time producer. Real time inflow data obtained during the UBCTD drilling of the upper lateral showed that this lateral was responsible for the majority of the gas (see attached presentation for additional information). The intent is to shut-off the high gas producing lateral, making the well a competitive full time producer. A sliding sleeve will be incorporated into the patch to allow the lateral to be produced without pulling the straddle. A tubing tail assembly with nipple reducer will allow the well to be secured with a TTP. A tubing Caliper is included which clearly shows the lateral window to be straddled. **NOTE** - PDS caliper is 2' shorter than the tubing tally. - PDS GR/CCL run on 5/31/2006 was revised on 9/19/2008 putting it on depth with the tubing tally. Electronic revised GR/CCL copies were emailed to the Wells Group Project Aide on 10/3/2008. - On 6/11/2008 SL pulled KB tray and packer for previous patch procedure and hung up in the TRSSSV. On 9/6/2008 KB tray and packer were fished out with no issues. Packer still retained all elements. (See Attached WSR's) Any questions concerning this program please contact: Justin Nash at 564-4752 (work), 522-0726 (home), 440-6782 (cell), or Jennifer Julian at (work) 564-5663, (cell) 240-8037, (home) 274-0929. CC: Well Files Sam French Amy Frankenburg Ross Warner Justin Nash G ANC Wellwork GPB, LPC DS Ops ' ` L5-16AL2 Lateral Isolation Patch With Sliding Sleeve • PROCEDURE: • Ensure Baker hand on location while setting patch. (Contact Carl Diller 907-317-7755, or Bob Harris 907-240-0427 with any questions regarding Straddle Packer assembly and location). • Drift & Tag with SL for straddle assembly. • Tag Lower KB Packer C«~8969' DD with E-Line and log up to GLM #1 @ 8616', Tie-in with memory jewelry log 5/31/2006, revised on 9/19/2008. • Note: Top of L1 @ 8937', this correlates with the Li open-hole completion on the WBS @ 8961' DD. • All equipment has been ordered and is available from Baker. Pre-Patch Slickline: 1. MIRU S-line unit. 2. MU and RIH, with 20' x 3.7" OD Baker dummy patch D&T to Lower KB Packer @ 8969' DD. • Locate X Nipple C~ 8728' DD (Use Jewelry Log 5/31/2006, Revised on 9/19/2008). Jewelry log 5/31/2006 was revised on 9/19/2008 to get it on depth with tubing tally. Copies have been sent to the slope. Ensure correct tie-in is used, depth control is very important because of tight window. 3. RDMO E-Line Set Straddle 1. MIRU E-line unit. 2. MU and RIH with Gamma Ray and CCL (Jewelry Log) • Log up from Lower KB Packer (~ 8969' DD • Tie-In to X Nipple C 8928' DD • Log up past GLM Station 1 @ 8616' DD 3. POOH 4. MU and RIH with Baker Single Set 4-1/2" KB straddle assembly (upper packer, sliding sleeve in closed position, lower packer, XN nipple, and tail pipe), -20' element to element. (See attached schematic) 5. Tie-in to Lower KB Packer @ 8969' DD (Use Jewelry Log performed in step 2 above), make necessary correction. Ensure correct tie-in is used, depth control is very important because of tight window. • NOTE: Bottom section of patch assembly (XN Nipple & Tail Pipe) could possibly slide into lower KB Packer. Be careful to ensure patch assembly does not get stuck. 6. PUH and set upper element C~ 8905' ELM. • Top of Window @ 8910' • Bottom of Window C~ 8920.5' • Set Upper element Cagy 8905' ELM • Set Lower Element C~ 8925 ELM 7. POOH 8. RDMO ' L5-16AL2 Lateral Isolation Patch With Sliding Sleeve WBS ~~ ~J T(i¢s ~~~~ w~-- ACTW-TORE KB. O.fV = ~.~,_ ~_ ' Mlrot A = 98' 9326' Dialum MD= 9Dl2' Dwklm TVQ ~ 8800' SS 10-3r4" CSG. <6.it. K 86 BUIT ~' XO TO L-80 VAM ODHDUCTOR, 81.6/. H•40. D = ! 8.124' ~' 314' CSQ 1,'I.Si. L-80 VAM, O ~ 8.953" A/inirnum D = 2.490" Q 8973' 2 7/8" XN NIPPLE (KB PKR AS$1() 4-1n"TB~, lz.sa. L-80 sr-~ .0152 bpf, ID = 3.958" s~rr noT~: wei. ANGLE> 70• ~ sst~•. L5-1~6A ~~-T)a~,-~~~,~a~, AL1 8~ AL2 2177' FISFI i63MOV ED {o91o6ros) [SAS LFR Wthltl~i3 ST ND TVO DEV TYPE VLV LATCH PORT D11TE 5 27x1 2780 2 N®(i~2 &C 16 06111ro8 4 4708 ~L894 a 1a~2 DD4VIE ~c !6 o6nlro6 3 6387 8371 8 Mi9i132 DAME ~C 10 OBM1roB 2 7808 7308 26 KBC.2 DDME 6K 18 OBIitroB 1 8616 8430 24 1(813-2 SO BK 24 08/11106 HESXNP,D~3.613'~ X 4-!!2 ~(R S-3 PKR D = 9.870" D ~ 4.610" ~ {oPer How COI~LETION) 3.60' MILLOUT WNDOW {L6-16A-L2) 8878' - 894 L1 {OPEN HOLE COMPLLRiON) D = 2.4f1 ~• 3.80.1iALLUtlr VINDOUV {LS-1lA-L1) 8.987' • 8874' t5.16A {OPEN HOLE COIIN'LF`i'FOi~ -M, eD ^ D= 3.80^ M6_Latn vwuoaNV {~e-+eA> eoo~' - s1os~ DATE ~ 8Y OO+IT DATE ITV BY COM~3 07!971$7 IgAM141 alifi 3lISPE1~ 09m&08 i09ro8J08) OBdD3/87 NOPQIC 1 pplG~lAL CWIIPLBTION 08A9lOi MC~mIC 2 11N10 08189A6 NDRDIC 2 MtA,TI. LAT (L6-t6A, A1.1 i AL2) OS108NJ8 ICSBIPJC DRLODRgFTCOFRSCTgN3 08128106 .IG 13FI { ? LISBU~ LA~Yf Y11QL: l5-!6A PF3~Aff nb: aoeoa3o. fw). (~) fl P9 Wb: 50.029.21700.01. (60j, (61) SEC !. T! 1K R76E 1788' F$1. d• 19' fV0 BP 6cpbratbn {Absks) . w L5-16AL2 Lateral Isolation Patch With Sliding Sleeve by Well: L5-16 21 Baker Straddle Assembiy Baker Thru-Tubing Straddle Completion Date: ~~~ ~i~.s Baker Oil Tools Co. Man: OD ID Length 45 "KB" Upper Straddle Parker 4" GS Fishing iredc Up 3.70" 2.3T' 5.76' 2 718" Sn Pin Down 30K SlNSar Release 9 Ch 2 7/8" Sn Pup Joint 2.875" 2.38" TBD X-0 2 T/8" Sn B x 2 718" CSH P 2.875" 2.3$" TBD Bskar Slidir~ sleeve 2.312" "BX" pr~ik 3.17" 2.312" 3.64' 2718"CSHBxP x-o 2 7i8" csH e x 2 718" sn P 2.875" 2.38" TBD 2 718" sn Pup Joint 2.875" 2.38" TBD x-o 2 718" sn B x 3 X12" sn P 3.500" 2.38" TBD 45 "KB" Lower straddle Packer 3'l," STL Box Up 2 7i8" Sn Pin Down 70" 3 37" 2 5.49' 30K Shear Release , . 9Ch Haliitnuton 2 718" "XN" TBD 2.205" TBD wi 2.205" No-Go Tail Pipe wl WLEG 2.875" 2.3T' TBD - ~ L5-16AL2 Lateral Isolation Patch With Sliding Sleeve Proaosed Straddle Assembly TREE: 4-116" FI~,~C waLHFr+D = :;rrr ACTLL4TOR ~ AXE-SON KB. ~La/ = 50' E9F. ~.~, - I~ KOP Q 3800' Max Angle 9 99° ~ 9326' Calum A`:- OOF.2' c~,t:~~» r: c : eap~~ == 70 L-80 VAM Minimum ID ^ 2.010" ~ 8973' 2 718" XN N~PLE KB PKR AS31() L5 16A 'A~„'~: wEa.LA~c~Le>' To' e92os°- ~ "'CAT ! $SSV NI23 (PP61) TSO »' AL1 ~ AL2 j')~' FESMR~IOY®{OEII08106) CHAS LFT W f1fIRFl A ST MD TVD DN TYPE VLY LATCH PORT QATE 8 2781 2780 2 KBG-2 DOAE BK 18 OBH1106 ~ 4708 x694 • KBG-2 DOME BK 16 OBltt~J5 3 8387 6311 9 KBG-2 DOME BK t6 0611 t.p6 7 '603 '509 ?F KaC-^ -~"~ GK ~ C~i;t NUo ' 66'5 85J~ [a M;~~.~ S'--. ~ s,;iIVU~~ ~ Cerroer Upper Element @8906' ~ ~ SGdng Sleeve ~ Top of Window @8910'. Cenbr Lower Eternorn @ 89126' 3.80' Ml.LOl1T YJMDOtIV{LL1M-LZ) 8938' - 88aT L1 (OPBi HOLE COMPLETION 3.80- MLLOUT WNDOW (LS46A-LtI 8981' - 8974' LS16A (OPEN HOLE COMPLETION 3.60' MLLOUT 1MNDOW (L8.16A) 9097'. 9109' DATE { RF,- F3Y OOM GATE REV BV 03x17187 RWNat OPoOSUESPEtIDED 09IOtY06 SW1.AD R6YgVEDFL9H100706106 06/03/87 NORDIC 1 ORIGINAL COMPLETION 06!01706 NORDIC 2 RWO 09!01106 NORDIC 2 MULTI. LAT (L6.16A, AL1 t AL1) 05~08/G6 KS[i.1'JC i7Rl.G (NtA FT CORRBCTgNS 08!28108 BSFJPJC PULL KB GUCESHOEfFISrI 08/22 LISBL1fiE UNfF Vral: lS•16A PE37AMT No' 20EW830, (40-. (501 ARNO: 50.029-21 7 00.01, (80), (61) BP FxpbrNbn (AIBSkM) WELL LOG S TRANSM/TTAL .,. ProActive Diagnostic Services, Inc. Ta: AOGCC 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 ProActnre Diagnosi~c Services, Inc. Attn~--Robert. A. Richey 3 T3Q West International Airport Road ~ o~~o~ Suite C Anchorage, AK 99518 p(o~i 3 f Fax: (907) 2458952 1] Jewelry Log 31-May-06 L5-16A EDE 50-029-21700.01 -~ 'r~ ~ ~~,;~~ ~~ 2) * * * * Reprint* * * * * * * Please replace previous diskwith this one* ~~~; ~l ~ ~ I'~ r i Signed : ~, X~ ±`r~ Date I 'n"":` -'a. ° tit ~~~" ~`"' r~ ti~'CI~d Print Name: ~,~5~t-i ~.~ ~~.~,~..~~;~ ~ ~~" r~,~~~ -~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907245-88952 E-NU-IL : pdsanchoraae unmemorylog.com WEBSITE : www.memorylog,com C:\Documents and Settings\Owner\Desktop\Tiv~smit_BP.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2060830 Well Name/No. PRUDHOE BAY UN LIS L5-16A Operator BP EXPLORATION (ALASKA) INC MD 10875 TVD 8975 Completion Date 9/1/2006 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-029-21700-01-00 UIC N Mud Log No Samples No Directional Survey Yes ~~ DATA INFORMATION Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset Typ ed/Fmtt Number Name Asc Directional Survey ftpt Directional Survey ~!~ ~ ~ 15220 ~-'o~erifrcatlIIR (ti 1t~. J..og 15220 Gamma Ray ,le6g 15220 Gamma Ray Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments 9073 10875 Open 9/7/2006 Disk also has L5-16A L1, L5-16A L1 P61, &L5-16A L2 9073 10875 Open 9/7/2006 9064 10875 Open 6/14/2007 LIS Veri GR, ROP w/ Graphics 25 Blu 9097 10875 Open 6/14/2007 MD GR 6-Aug-2006 25 Blu 9097 10875 Open 6/14/2007 TVD GR 6-Aug-2006 Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~ N Chips Received? ~- Formation Tops ~ / N Analysis `~XPI-- Received? Comments: ---- -- -- Compliance Reviewed By: ____ .____ Date: ~ ~ 'Transmittal F®rm ,~ ., ;~%s -~ -- BAKER HUGHES INTEQ Anchorage GEOScieace Center To: AOGCC 333 West 7`h Ave, Suite 1100 Anchorage, Alaska ~, ~~ _ 99501 ~ - '~ ___ ~= Attention: Christine iVlahnken ~~ -, Reference: LS-16A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 1194703 Sent By: Deepa Joglekar Date: iVlay 24, 2007 Received By: ~ ~- Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska ~~~ - 0`~~j ~ _ 9918 (5 ~~ ~ Direct: (907) 267-6612 FAX: (907} 267-6623 - -- 'y ___. _.- --- _. ..'., '7 7 ~EIVEC~ STATE OF ALASKA ALASKH IL AND GAS CONSERVATION COM~SION SEP 2 9 2006 WELL COMPLETION OR RECOMPLETION REPORT AND L~i~ka Ci6 ~ Cas Cans. Commission Arrchcrraoe 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. 9!1/2006 12. Permit to Drill Number 206-083 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/31/2006 13. API Number 50-029-21700-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/5/2006 14. Well Name and Number: PBU L5-16A 1788 FSL, 19 FWL, SEC. 01, T11N, R15E, UM Top of Productive Horizon: 1201' FSL, 1063' FWL, SEC. 01, T11N, R15E, UM 8. KB Elevation (ft): 60 15. Field /Pool(s): Prudhoe Bay Field / Lisburne Pool Total Depth: 336' FNL, 1470' FWL, SEC. 12, T11 N, R15E, UM 9. Plug, Back Depth (MD+TVD) 10875 + 8975 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 717447 y- 5974920 Zone- ASP4 10. Total Depth (MD+TVD) 10875 + 8975 Ft 16. Property Designation: ADL 028320 TPI: x- 718508 y- 5974365 Zone- ASP4 Total Depth: x- 718960 y- 5972840 Zone- ASP4 11. Depth where SSSV set 2177' 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: MWD GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD 'SETTING DEPTH ND HOLE AMOUNT SIZE WT: PER FT. .GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 120' Surface 120' 30" 1800 # Poleset 10-3/4" 45.5# L-80 Surface 4006' Surface 3998' 13-1/2" 1300 sx AS III 325 sx Class 'G' 7-5/8" 29.7# L-80 Surface Surface 8875' 9-7/8" 425 sx Class 'G' 4-1/2" 12.6# L-80 8803' 09 ' 8603' 8875' Scab Lnr 97 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 Open Hole Completion 4-1/2", 12.6#, L-80 8792' 8704' MD TVD MD TVD 9098' - 10875' 8875' - 8975' 25. ACID, FRACTURE,.:CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 9097' Set Whipstock 2500' Freeze Protect w/ 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: September 1, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 9/27/2006 Hours Tested 13 PRODUCTION FOR TEST PERIOD OIL-BBL 447 GAS-McF 7,938 WATER-BBL 12 CHOKE SIZE 114 GAS-OIL RATIO 17,756 Flow Tubing Press. 794 Casing Pressure 350 CALCULATED 24-HOUR RATE OIL-BBL 825 GAS-MCF 14,654 WATER-BBL 22 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 ~~~ ,state "none". ® f~?^7 None ' ~ ~ ~ ~~~/t~do~•J ~6 / / ~ ~~3 ~~~//,,~~~~ VE IE1? ~ ~XJ Form 10-407 Revised 12/2003 ~~ CONTINUED ON REVERSE SIDE ~ ~~' d ~~ ~ ~ ~UO~ G 28. GEOLOGIC MARKS 29. ~ORMATION TESTS Include and brie mmarize test results. List intervals tested, NAnne MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Wahoo 5.1.1 9088' 8866' None Wahoo 4.8 9093' 8870' Wahoo 4.7 9121' 8895' Wahoo 4.6 9161' 8928' Wahoo 4.2 (Invert) 9278' 8955' Wahoo 4.3 (Invert) 9353' 8944' Wahoo 4.4 (Invert) 9498' 8925' Wahoo 4.5 (Invert) 10045' 8910' Wahoo 4.6 (Revert) 10493' 8934' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0~~ ~9~0~ Signed Terrie Hubble Title Technical Assistant Date PBU L5-16A 206-083 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. ! A royal No. Driaing Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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. IreM 22: Attached supplemental records for this well should-show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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 Page 1 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task ~ Code NPT 7/27/2006 22:00 - 00:00 I 2.00 ~ MOB ~ P 7/28/2006 100:00 - 02:45 I 2.75 I MOB I P 02:45 - 03:40 I 0.921 MOB I P 03:40 - 06:15 I 2.58 I MOB I P 06:15 - 07:30 1.25 MOB P 07:30 - 10:00 2.50 RIGU P 10:00 - 12:15 I 2.251 BOPSUFI P 12:15 - 12:45 0.50 BOPSU P 12:45 - 00:00 11.25 BOPSU P 7/29/2006 100:00 - 01:00 I 1.00 I BOPSUp P 01:00 - 04:00 I 3.00 I RIGU I P 04:00 - 06:30 I 2.501 RIGU I P 06:30 - 13:00 I 6.501 RIGU I P Spud Date: 5/12/2006 Start: 7/27/2006 End: 9/1 /2006 Rig Release: 9/1/2006 Rig Number: Phase ~ Description of Operations PRE Safety mtg re: move off well Move off of L5-28 and move halfway down the Pad to L5-16 and set down. Lower BOP's w/ blocks and set on mat. MI manlift. Begin opening doors of TOT BOP's for inspection. Meanwhile, lay herculite on L5-16. PU mats from L5-28 and set on herculite using ASRC loader since Nordic loader is inoperable Peak crane is on standby until rig can be moved onto mats PRE Finish set mats on herculite. Set well barricade on L5-18 w/ ASRC loader. Nordic loader inoperable Continue checking TOT BOP's for wear Perform Post Pad inspection of L5-28. Accept rig at 0000 hrs PRE Safety mtg re: move onto mats Move rig onto mats in front of well PRE Resume BOP inspection using manlift Use Peak crane and ASRC loader to demob from L5-28 and remob of ASRC equipment and tanks PRE Move rig over well. Rig up tank farm berm for diesel uprights. PRE NU BOPs. Rig up riser, kill and choke lines. Begin to rig up 4" flow line. Spot upright tanks in berm area. Install stairs to uprights. PRE Body pressure test BOP stack. Held 500 psi. Slight leak at 3400 psi. Choke line greylock leaking. Disassemble and trouble shoot same. BOP test witness waived by J. Crisp, AOGCC. PRE Open master valve. WHP is zero. Set two way check to prep for BOP test. PRE Test BOP equipment. Record and annotate test data on SLB data system. Had to grease lower SV to get it to hold, otherwise no problems Continue to rig up ASRC equipment. Rlg up 4" flow back line. Secure to VSMs. Spot heater and separator. Rig up hard line to L5-20 flow line. Nordic 1 electrician working on gen #2. Fill pits w/ 70 bbl FW and 290 bbls used Flo Pro mud. Spot rig flowback tank PRE RU DSM lubricator and pull TWC SWS fin prep rigging up reel hardline Nordic loader is still inoperable. Using ASRC loader. ASRC has 3 man crew PRE PU injector and install gooseneck. Install internal grapple in new CT and PT. Pull CT to floor and stab thru injector. Install new packoff. DSM RU hardline to rig tiger tank. Nordic install gas lift hardline PRE Fill CT w/ rig water pumping forward. Reverse slack back over upper swab. Cut off 86' of CT and dispose PRE Make up a-coil head test same. Test inner reel valve. Continue to rig up ASRC lines. Pressure test flow line to ASRC heater. Fin repair Nordic loader. Install hard line jumper from rig cement line to tiger tank line. Install a 2" 5k valve on the IA in cellar. Make up well head and guage guards. Work on berm around rig. Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 2 of 33 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To ~ i 5-16 5-16 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code I, E NPT Start Rig Rig Phase Spud Date: 5/12/2006 : 7/27/2006 End: 9/1/2006 Release: 9/1/2006 Number: Description of Operations 7/29/2006 06:30 - 13:00 6.50 RIGU P PRE Sim Ops: SLB a-line crew rigged up on L5-28 to log flow test from upper lateral. 13:00 - 14:30 1.50 STWHIP P WEXIT Make up window milling BHA (window mill, string reamer, 2-7/8" extrem mtr w/ Inteq tools) Begin loading diesel into tank farm. 14:30 - 16:15 1.75 STWHIP P WEXIT Start in hole. Tag and mill up 3'-4' of ice at 60'. Continue to run in hole. Take returns to tiger tank. Tag whipstock at 9092 uncorrected. 16:15 - 16:45 0.50 STWHIP P WEXIT Log GR tie in from 8870' 31 k, 21 k. Begin circulating mud down coil. Add 6' correction. 16:45 - 19:00 2.25 STW HIP P WEXIT Begin time milling dual string window from 9098' w/ used Flo Pro mud 19:00 - 20:00 1.00 STWHIP P WEXIT Time mill from 9099.0' 2.4/3980 w/< 50 psi dill and 0.5k wob, 15.1 k Getting good metal on magnets 20:00 - 21:00 1.00 STWHIP P WEXIT Time mill from 9100.0' 2.4/3860 w/ <50 psi dill and 0.5k wob, 16.Ok 21:00 - 22:00 1.00 STWHIP P WEXIT Time mill from 9101.0' 2.4/3780 w/ <50 psi and 0.5k wob, 16.7k 22:00 - 00:00 2.00 STWHIP P WEXIT Time mill from 9102.0' 2.4/3770 w/ <50 psi and 0.5k wob, 17.5k to 9104.0' 7/30/2006 00:00 - 02:15 2.25 STWHIP P WEXIT Mill from 9104.0' 2.4/3800 w/ 2.4-5.2k wob, 150-300 psi dill 15.2k to 9106.0' EL unit on L5-28 still wo well to stabilize 3 year-old tagged grizzly bear checked out location on ODS for 15 minutes before wandering off toward L4 Watched the sun fully set at 0130 hrs for the first time since May 02:15 - 02:40 0.42 STWHIP P WEXIT PUH 28.8k, clean. Chk FS at 2.4/3630. Ease back in hole and got motor work at 9104.5' 02:40 - 03:15 0.58 STWHIP P WEXIT Restart time mill from 9104.5' 2.39/3650 w/ 3.6k wob, 500 psi dill 14.2k 03:15 - 06:00 2.75 STWHIP P WEXIT Resume time mill from 9106.0' 2.4/3650 w/ 1-3k wob, 500 psi dill 13.6k and mill to 9109' 06:00 - 09:00 3.00 STWHIP P WEXIT Mill from 9109.0'. DHWOB: 6k#. Stall at 9110'. Pick up and resume milling. 09:00 - 10:00 1.00 STWHIP P WEXIT Rop picked up. Apparently drilling formation. 20 fph with 2k DHWOB. Sim Ops: SLB slickline rigged up on L5-28 to open lower lateral up. 10:00 - 12:00 2.00 STWHIP P WEXIT Make several passes up and down throughwindow. Dry drift window. W Indow and open hole smooth. 12:00 - 14:00 2.00 STWHIP P WEXIT Circulate out of hole. Displace well to 2% KCL. No fluid losses to formation noted. 14:00 - 15:00 1.00 STWHIP P WEXIT At surface. Flow check. Get off well. Unstab coil. LD milling BHA. Gauge on mill: 3.8 go, 3.79 no go. 15:00 - 15:45 0.75 DRILL P PROD1 MU build assembly (2.6 deg X-treme w/ HCC STRWD). Stab coil. Test MWD tools. Get on well. 15:45 - 17:15 1.50 DRILL P PROD1 Run in hole w/ EDC open. Circ KCL at min rate. 17:15 - 18:00 0.75 DRILL P PROD1 Log GR tie in from 8890', no corr . RIH and tag TD at 9121'. PUH and park at 9048' 18:00 - 00:00 6.00 DRILL P PROD1 WO slickline unit to pull isolation plug on L5-28 so it can be produced from both laterals while L5-16 drilling is in progress. No significant progress (still bailing window milling debris) was made by 2330 hrs so advised slickline to RD so GL operations Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT ~ Phase 7/30/2006 ~ 18:00 - 00:00 6.00 DRILL P ~ I PROD1 7/31/2006 100:00 - 00:30 I 0.501 DRILL I P 00:30 - 00:50 I 0.331 DRILL I P 00:50 - 02:10 I 1.331 DRILL I P 02:10 - 03:10 I 1.001 DRILL I P 03:10 - 04:10 I 1.001 DRILL I P 04:10 - 05:10 I 1.001 DRILL I P 05:10 - 06:45 I 1.581 DRILL I P 06:45 - 12:00 I 5.251 DRILL I P 12:00 - 14:00 I 2.001 DRILL I P 14:00 - 15:45 I 1.751 DRILL I P 15:45 - 18:00 I 2.251 DRILL I P 18:00 - 18:30 0.50 DRILL P 18:30 - 19:45 1.25 DRILL P 19:45 - 20:00 0.25 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 23:35 1.58 DRILL P Page 3 of 33 Spud Date: 5h 2/2006 End: 9/1 /2006 Description of Operations could begin on L5-16. DSO left SI until receiving further instructions PT gas lift line. BOP4 (IA valve) leaked at stem. DSM change out 2" 5k valve. ASRC PT at 2500 psi w/GLG Safety mtg re: startup procedure Open valuing PUH 31.7k slow while begin circ 10 bbls mineral oil spacer down CT 1.0/820. Take returns to the pits after ASRC needed to change out a diesel supply hose Swap to diesel at 0.5/330 and take returns to ASRC seperator. Hold off on swapping to GLG when BHI reports aproblem /w their tool. Start GLG at 1.0 MMSCFD while RIH slow RIH thru window, clean. Incr pump rate and tag at 9120' 28.2k Begin drilling w/diesel 1.5/3540 w/ 1.0 MMSCFD (0.8 bpm returns) at 1700 psi GLP at 150F, 4300 psi DHP (9.4 ECD) and go nowhere fast. Made 2' in one hour .. . Drill from 9122' to 9125' 1.5/3000/500 w/ 0.5-5.Ok wob and 0-400 psi dill w/ 1.5 MMSCFD at 1900 psi GLP w/ 1.3 bpm extra returns (KCI) and see first 'oil' back (diesel) Using 3 transports to haul diesel from COTP. Tank farm was full at start, Colville had 1200 bbls Drill from 9125-9132' w/ steady, but slow penetration rate at 1.55/2300/500 w/ 1-4k wob and 0-300 psi dill w/ 1.5 MMSCFD at 2080 psi GLP w/ 1.3 bpm extra returns w/ 27k up wt, 23k do wt at 3600 psi DHP (7.9 ECD) w/ FO choke Drill from 9132' 1.6/2000/500 w/ 1-4k wob and 0-200 psi dill w/ 2.5 MMSCFD at 2100 psi GLP w/ avg 2.0 bpm extra retums w/ 26k, 22k at 3310 psi DHP (7.2 ECD) w/ FO choke. Have 460 bbls total liquid recovered at 0510 hrs so increased GL rate to 2.5 MMSCFD Drill from 9145'. 1100 psi fs at 1.5 bpm in/out. DHWOB: 2.0-3.Ok#. Gas: 2.54 mmscfd in at 2133 psi / 45.5 deg F. Well is slugging. WHP/BHP/ECD: 504/2930/6.38 ppg. Crossed a fault (?) at 9169'. Lost rtns and 60 bbls diesel. Had to increase pump rate to 2.4 bpm to re-fill coil and regain positive coil pressure. Close choke to 32/64" to try and increase BHP, which had dropped to 2200 psi (4.8 ppg). Slowly regain returns and BHP. Gradually open choke setting. Drill ahead from 9225. 750 psi fs at 1.73 in/ variable rate (slugging) out. DHWOB: 1.5-2.5k#. WHP/BHP/ECD: 541/2502/5.4 ppg. Variable ROP. Flnish build section at 9,252'. Projected incl: 93.5', azm: 122, TVD: 8,898', avg dogleg: 54 deg. Pull out of hole. Circ at min rate. Reduce Og in to 1.54 mmscfd. Hold PJSM to review undeploy procedure. At surface. Pressure undeploy as per procedure. Crew change. Safety mtg re: fin undeploy w/ 500 psi Pull BHA into lub. Close SV's. Red GLG to 0.5 MMSCFD. LD BHA. Change motor setting and bit. Bit was 1-0-I Safety mtg re: pressure deploy Pressure deploy lateral BHA w/ 500 psi RIH w! BHA #3 w/o pump w/ EDC closed. Incr GLG to 1.5 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9h /2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 7/31/2006 22:00 - 23:35 1.58 DRILL P PROD1 23:35 - 00:00 0.42 DRILL P PROD1 8/1/2006 00:00 - 00:10 0.17 DRILL P PROD1 00:10 - 00:45 0.58 DRILL P PROD1 00:45 - 03:00 2.25 DRILL P PROD1 03:00 - 03:20 0.33 DRILL P PROD1 03:20 - 06:15 2.92 DRILL P PROD1 06:15 - 07:00 I 0.751 DRILL I P I I PROD1 07:00 - 10:30 I 3.501 DRILL I P I (PROD1 10:30 - 11:30 I 1.001 DRILL I P I I PROD1 11:30 - 12:15 I 0.751 DRILL I N I DFAL I PROD1 12:15 - 14:00 1.75 DRILL N DFAL PROD1 14:00 - 16:15 2.25 DRILL N DFAL PROD1 16:15 - 18:00 1.75 DRILL N DFAL PROD1 18:00 - 18:15 0.25 DRILL N DFAL PROD1 18:15 - 18:30 0.25 DRILL N DFAL PROD1 18:30 - 20:00 1.50 DRILL N DFAL PROD1 20:00 - 20:20 0.33 DRILL N DFAL PROD1 20:20 - 20:30 0.17 DRILL N DFAL PROD1 20:30 - 21:15 0.75 DRILL N SFAL PROD1 21:15 - 23:00 I 1.751 DRILL I N I SFAL I PROD? Page 4 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations MMSCFD Log tie-in down from 8880' Fin log tie-in, +1' Corr RIH thru window, clean. Circ 20 bbls diesel to fill CT 1.5/380 (and hole) while PUH 31.5k BHP 2074 w/ 1.5 MMSCFD. Precautionary ream to TD. Lost wt 3 times at 9160'. RIH to TD in three stages at 0.5 bpm and backream slow to 9150' until clean Drill from 9250' (8895' TVD) 1.55/930/600/908 on 64/128" choke w/ 2.5 MMSCFD ~ 1880 psi w/ 2500 psi DHP ~ 5.5 ECD w/o fluid returns. BHP rose to 3200 psi while increasing GLG to 3.2 MMSCFD. After fluids reached surface, slowly opened choke, then cut back on gas to 2.75 MMSCFD. Drilling break at 9310'. Try to hold 96 deg while invert to 8840' TVD. Drilled to 9350' W iper to window 32.2k and back to TD was clean Drill from 9350' 1.60/750/560/1258 w/ 2.5k wob, 200 psi dill on 80/64" choke w/ 2.25 MMSCFD ~ 1700 psi w/ 2200 psi DHP ~ 4.76 ECD while knocking down angle from 100 deg back to 96 deg. There is no production from the well and are getting less gas back than putting in Drill from 9435' to 9450'. Wiper trip to window. 32k# up, 22k# do wt at window. Hole smooth. Drill ahead from 9450'. 750 psi fs at 1.62 in/1.74 out. DHW0B:2k-3k#. WHP/BHP/ECD: 555/2355/5.01 ppg. Gas: 2.43 in/2.0 out mmscfd at 2513 psi and 44 deg F. Continue to climb at 97-98 incl toward target TVD estimated to be 8848'. ROP up to 90 fph. Drill into a hard spot at 9532'. Work our way through it. Pump a 5 bbls min oil sweep. Reduce Gas in to 1.5-1.9 mmscfd to try and increase ECD. Wiper trip to window. Hole smooth except for set down at 9532;. Use last of straight diesel and now using 1 % EMI-776 On btm. Unable to drill ahead. Getting 3K# DHWOB. Coil pressure increases slowly once bit is on btm. No drill off at all. Suspect the motor has failed. Pull out of hole to change motor. Tag up. Hold PJSM. Pressure undeploy BHA. Bit was 1-3-I w/ chipped cutters and stator rubber in nozzle. Motor had seized up MU new motor and RB bit. Pressure deploy w/ 500 psi Crew change/safety mtg prior to fin deployment Fin deployment RIH w/ BHA #4 w/ EDC closed and w/o pump w/GLG at 1.4 MMSCFD Log tie-in down from 8910', corr +1'. RIH thru window, clean Wiper in hole while fill CT 1.6/380. BHI MWD PC locked up about the same time as a set down at 9270' w/ TF 180 deg out Slow wiper up hole while BHI reboots main MWD PC and tries to sync up the others PUH thru window and park. SD pump and block in diesel, SD GLG to 0.5 MMSCFD BHI calls uncle (Celle) to get help with reboot of main PC. Have had the same problem last two Hiles, but were able to Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours Task Code NPT Phase 8/1/2006 21:15 - 23:00 1.75 DRILL N SFAL PROD1 23:00 - 23:35 0.58 DRILL N SFAL PROD1 23:35 - 00:00 0.42 DRILL P PROD1 8/2/2006 00:00 - 02:05 2.08 DRILL P PROD1 02:05 - 02:45 I 0.671 DRILL I P I I PROD1 02:45 - 03:55 I 1.171 DRILL I P I I PROD1 03:55 - 04:30 0.58 DRILL P PRODi 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 06:40 0.67 DRILL P PROD1 06:40 - 07:05 0.42 DRILL P PROD1 07:05 - 07:35 0.50 DRILL P PROD1 07:35 - 09:30 t 1.921 DRILL I P I I PROD1 09:30 - 09:45 0.25 DRILL P PROD1 09:45 - 10:45 1.00 DRILL P PROD1 10:45 - 11:40 0.92 DRILL P PROD1 11:40 - 13:40 2.00 DRILL P PROD1 13:40 - 16:30 2.83 DRILL P PROD1 Page 5 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations reboot RIH. Continue to have problems with BHi computers. Able to run tools only from the MWD computer. If more than 1 command is given from the DD computer then both computers crash. Drill ahead f/ 9550' to 9560' Of = 1.53 in 2.75 out 74/64" choke Og 1.57 mmcf CTW = 12.4k WOB = 1-2k ROP = 14'/hr TF= 195 dropping angle to match dip BHP = 2873 EDC= 6.24ppg Continue underbalance drilling f/ 9560' Of = 1.52bpm 1040psi free-spin 100-300psi MW Og = 1.90 mmcf 84/64" to 128/64" CTW 11.3k WOB = 2-3k ROP = 20-30'/hr TF = 195 BHP = 2966psi EDC = 6.44ppg Wiper trip to window while geo's figure out where we are at. PU wt 30k. Slight overpull at 9420' , 9345' (36k) Drill ahead f/ 9605'. Geo's have decided to level off at 90 degs. Of = 1.60 850psi fs Of out 1.30 to 2.40 BHP 2716psi Og = 2.72mmcf 128/64" choke WOB = 1-2k ROP = 80-90"/hr TF 280 degs Pumped 5 bbls sweep at 9675'. Wiper trip to 9115'. Hole good condition. Continue drilling ahead f/ 9700 to 9800' Of 1.6 925psi fs Of out 3.3 BHP = 2553 psi Og = 2.25mmcf 110/64" choke setting WOB 2.6 ROP 70-80'/hr TF 908 Wiper to window Reboot BHI PC's, then log tie-in, corr -2' RIH thru window, clean. DHP at window 1700 psi. Wiper 1.6/400 to TD was clean Drill from 9800' 1.55/1000/550/85L w/ 100-300 psi dill, 2-3k wob holding 91 deg w/ 2.25 MMSCFD @ 2070 psi w/ 110/64" choke and 2000 psi DHP slowing increasing to 2900 psi (6.4 ECD) as wellbore filled w/ increased pump rate from drilling. Also, started getting increase in flow of 0.3 bpm 'extra' fluid beginning about 9820' 200' wiper, clean Drill from 9900' 1.57/1020/610/908 w/ 100-300 psi dill, 2-3k wob, w/ 2.6 MMSCFD @ 1915 psi w/ 110/64" choke and 2900 psi DHP slowly decreasing to 2540 psi as output from wellbore started contributing to extra 'out' rate of 0.3-2.5 bpm (slugging). Pump 5 bbl mineral oil sweep and drill to 9950' Wiper to window 31.7k was clean both directions Drill from 9950' 1.55/900/540/908 w/ 100-200 psi dill, 2-3k wob w/ 2.6 MMSCFD ~ 1820 psi on 110/64" w/ 2500-2900 psi DHP w/ extra out rate avg of 0.3 bpm avg (not stable) at 70-110'/hr Ran into a hard spot at 10044' at the same time the geo's decided to dive rather than continue the 91 deg climb. Pump a Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 6 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date !From - To Hours Task Code ! NPT Phase Description of Operations 8/2/2006 13:40 - 16:30 2.83 DRILL P PROD1 10 bbl mineral oil pill to tide us over while grind away 1.63/940/580/1608 w/ 3-5k wob Drill to 10050' and penetration rate is slowly improving. Drilling w/ no progress got the 'out' rate stable to see a steady 0.3 bpm extra which was 100% oil 16:30 - 17:30 1.00 DRILL P PROD1 Drill from 10050' 1.6/900/610/1658 w/ 100-200 psi dill, 2-3k wob w/ 2.55 MSCFD C 1800 psi on 110/64" choke w/ 2400 psi DHP at 30-50'/hr. Pump 14 bbl mineral oil pill 17:30 - 18:30 1.00 DRILL P PROD1 Wiper to window. Hole good condition. 18:30 - 23:00 4.50 DRILL P PROD1 Drilling ahead f/ 10075' currant parameters to start: Qf = 1.50 875psi free-spin 2-300psi MW Of out = 0.96 BHP = 2633 psi ECD = 5.7ppg WHP = 590 psi 110/64" choke settingDiving to maintain 88 deg. Back into harder streak at 10998' to 10102'. Make a short BHA length wiper trip. Drop TVD a few feet continued ratty drilling. Drill back up looking for better porosity. Notning there, go back down. (stopped hauling diesel from COTU and started hauling from Colville stocks) Drilling ahead 40'-65'/hr from 10145'. Pump 5 bbl sweep while at 10200' 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip back to window. 33k of bottom. Hole good. 8/3/2006 00:00 - 00:20 0.33 DRILL P PROD1 Finished wiper trip to bottom. Hole in good shape. BHI has corrected most of the problems with their computers. DD is now able to make changes on his computer. 00:20 - 02:15 1.92 DRILL P PROD1 Drilling ahead f/ 10226' Of = 1.56 850psi free-spin Of out = 1.96 Og = 2.64 mmcf BHP = 2640psi WHP = 570psi ECD = 5.56ppg Choke = 100/64" CTW = 16.5k WOB = 1-2k ROP 40-60'/hr Ran into a hard spot at 10279'. 02:15 - 05:00 2.75 DRILL P PROD1 Drilling ahead slowly at 10279' Of = 1.57 550 psi free-spin 150psi MW Of out = 1.63 BHP = 2370psi WHP = 575 ECD = 5.15ppg CTW 11.5k WOB = 2.7k ROP <1'/hr Changing TF's and making short wiper trips. Weight transfer good. Acting like a weak motor and bit has made 730'. 05:00 - 07:05 2.08 DRILL P PROD1 TOH. PU off bottom 33.2k 07:05 - 09:30 2.42 DRILL P PROD1 Pressure undeploy w/ 588 psi on 1.5 MMSCFD GLG w/ average 0.3 bpm liquid return of 100% hydrocarbons Change bit and motor. Bit was 4-6-1 w/ broken cutters, ringing and rubber in two nozzles Meanwhile, determine that 3 transports have returned with Jet A instead of diesel from Colville storage tanks. Two tanks on location have 70/30 Jet A/diesel-tag them out of service temporarily. Send other tanker back to VECO where SWS takes a sample for Reed vapor test 09:30 - 11:45 2.25 DRILL P PROD1 Pressure deploy BHA w/ 520 psi on 1.55 MMSCFD GLG w/ average 0.3 bpm liquid return of 100% hydrocarbons (not a steady rate) PT CTC @ 3000 11:45 - 13:15 1.50 DRILL P PROD1 RIH w/ BHA #5 w/ EDC closed w/o pump 13:15 - 13:30 0.25 DRILL P PROD1 Log tie-in down from 8901', corr +1' SWS okays use of comingled fluids 13:30 - 14:10 0.67 DRILL P PROD1 RIH thru window, clean. Wiper to TD 1.56/425/530 while incr Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Page 7 of 33 Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 8/3/2006 13:30 - 14:10 0.67 DRILL P PROD1 the GLG from 1.5 to 2.0 MMSCFD at initial 1947 psi DHP. Set 14:10 - 16:10 2.00 DRILL P PROD1 16:10 - 17:30 1.33 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 20:25 2.42 DRILL P PROD1 20:25 - 21:55 1.50 DRILL P PROD1 21:55 - 00:00 2.08 DRILL P PROD1 8/4/2006 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:20 0.58 DRILL P PROD1 01:20 - 05:25 4.08 DRILL P PROD1 05:25 - 05:40 0.25 DRILL P PROD1 05:40 - 06:35 0.92 DRILL P PROD1 06:35 - 06:55 0.33 DRILL P PROD1 06:55 - 07:25 0.50 DRILL N PROD1 down at 9289' w/ TF 90 deg out. Rest of hole was clean See MW at 10275' so stop to get cutting pattern established, then ease in hole a tenth at a time to 10287.8' and find TD. Soaking didn't help-it's still hard Drill from 10279' 1.5/850/650/1008 w/ 0-0.5k wob, 50-100 psi dill w/ 2.5 MMSCFD ~ 2030 psi on 50/64" choke w/ 2800 psi DHP. Drill to 10286' before breaking out of hard stuff Drill from 10286' 1.47/720/660/608 and level out to hold 88 deg in 1 B Drilling ahead f/ 10310' Of = 1.52 free-spin 650psi 2-300psi mw Of out = 2.00 BHP = 2590psi WHP = 680psi ECD = 5.4 Og = in/out 2.49 / 2.67 CTW 12.6k WOB = 2-3k ROP 40-45'/hr Dropping angle to maintain 84 deg and good porosity in Unit C1 according to latest geo plan. Wiper trip to window following 5 bbl mineral oil sweep. Hole conditions good. Drilling ahead f/ 10420' Of 1.51 free-spin 710psi 2-300psi MW Of out 2.10 BHP 2655psi WHP 636psi Og = 2.55 64/64" choke setting CTW 12.1k WOB 2-3k ROP 30-40'/hr TF 270 NBI 83.56 10430' start dropping angle Drilled ahead f/ 10492' to 10501'. Continually dropping in TVD looking for the good porosity. Have dropped 25' without finding it. Making a slow wiper while town discuses plan forward. Drill ahead f/ 10501' building angle back to 82-83 and leveling off. Of = 1.50 free-spin 700psi Of out 1.74 BHP = 2562 EDC = 5.55ppg WHP = 668 Og = 2.57mmcf 64/64" choke CTW 12.7k WOB 2k ROP 24'/hr TF 285 NBI 79.9 deg at 10502' At 10516' increase choke to 96/64" in an effort to increase return flow. Requested by town geo. Before Of in/out 1.50 / 2.00 WHP= 660psi BHP = 2560psi After 1 hr drilling at 10544' Of in/out 1.51 / 1.67 (dropped from a 1.85 high) WHP = 624psi BHP = 2409 psi At 10552' increase Og to 3.Ommcf gradual incresase in returns Of out = 1.97 after 20 min. Drill ahead f/ 10570' Of = 1.51 free-spin 710psi Of out = 1.85 BHP = 2343psi WHP = 668 Og = 3.Ommcf ROP = 24'/hr Wiper to window from 10575' was clean thru window Log tie-in down from 8910', corr -7' RIH. SWS has depth dill w/ BHI and can't keep counters sync'd Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 8 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ;Hours Task Code NPT ~ Phase Description of Operations 8/4/2006 07:25 - 08:10 0.75 DRILL P PROD1 - Wiper back to TD was clean. Worked on getting SWS counter to read correctly. Ended up changing out encoder, NPT 20 min 08:10 - 11:15 3.08 DRILL P PROD1 Drill from 10575' 1.55/700/640/1008 w/ 2-3k wob, 50-100 psi dill at 80 deg w/ 3.0 mmscfd ~ 1800 psi w/ 96/64" choke w/ 2420 psi DHP at 25'/hr 11:15 - 12:45 1.50 DRILL P PROD1 Drill on a hard spot at 10625' 1.6/790 w/ 3k wob, 300 psi dill w/ 3.0 mmscfd GLG One benefit of slow or no penetration rate is that w/o any surface adjustments, the well becomes stable. The stabilized rate is +/-0.3 bpm which is 100% hydrocarbons at 2370 psi DHP at 57F w/ 650 psi whp on 96/64" choke while getting back less gas than used Drill to 10627'. Stack full wt on bit and get 3k wt, but no differential 12:45 - 13:30 0.75 DRILL P PROD1 Wiper thru window was clean 13:30 - 15:00 1.50 DRILL P PROD1 POOH for bit while reducing GLG in stages to 1.5 mmscfd 15:00 - 17:00 2.00 DRILL P PRODi Pressure undeploy w/ 570 psi FWP on 1.8 mmscfd. Well flowed initially 0.5 bpm and slowly decreased to 0.3 bpm in an hour, started slugging, then started flowing at 0.3 bpm steady Bit was 2-4-I w/ broken and chipped cutters 17:00 - 18:15 1.25 BOPSU P PROD1 Function test BOPE rams as part of biweekly BOPE test. Grease and function SV's, MV and WV 18:15 - 18:30 0.25 DRILL P PROD1 PJSM review procedures for pressure deployment of BHA #6 18:30 - 21:25 2.92 DRILL P PROD1 Pressure deploy BHA #6. Tools tested good. 21:25 - 23:20 1.92 DRILL P PROD1 RIH with EDC closed. 23:20 - 23:25 0.08 DRILL P PROD1 Log tie-in +3' 23:25 - 00:00 0.58 DRILL P PROD1 Wiper trip to bottom. Of 1.46 8/5/2006 00:00 - 00:15 0.25 DRILL P PROD1 Continue RIH to TD. Hole good. 00:15 - 05:15 5.00 DRILL P PROD1 Drill f/ 10627' Of = 1.55 930psi free-spin (aggitator) 2-300psi MW Of out 1.82 avg BHP = 2517psi WHP = 632psi 64/64" choke setting CTW 14.3k WOB 2-3k 15-20'/hr TF 1208 - 180 Dropping angle looking for porosity. Hit small fault at +/- 10633'. Drilled to 10747'. Making an early wiper trip for goe's to make a plan forward. 05:15 - 06:25 1.17 DRILL P PROD1 Wiper trip thru window. 32k pick-up off bottom. 06:25 - 06:45 0.33 DRILL P PROD1 Log tie-in down from 8910', corr -7' 06:45 - 07:45 1.00 DRILL P PROD1 RIH thru window, clean. Wiper to TD tagged at 10742' 07:45 - 13:40 5.92 DRILL P PRODi Drill from 10742' (8900' TVD) 1.53/1050/625/90L w/ 2-2.5k wob, 100-150 psi dill w/ NBI showing 81 deg on 64/64" choke, 2.55 mmscfd ~ 1900 psi w/ 2560 psi DHP. Plan to drop to 8910' TVD by 10820' still looking for the Wahoo 4.5. Drill at 20-25'/hr. At 10770' penetration rate increased to 60'/hr for 6', but was a shale. Drill in 50-70 api rock at 20'/hr avg to 10875' (8915' TVD). Contribution from well is <0.3 bpm. Avg DHP is 2470 psi w/ 2.5 mmscfd GLG. Pump 5 bbl mineral oil pill 13:40 - 15:30 1.83 DRILL P PROD1 Wiper to window was clean. Wiper back in hole to 9500' and was clean. Receive word that TD has been called. Wiper back to window, clean. Incr GLG to 4.0 mmscfd. Pull thru window, clean and continue up hole in 4-1/2" liner past the bottom GLM. RBIH to 9077 and park for test 15:30 - 18:00 2.50 EVAL P PROD1 Stabilize well prior to flowtest at 2000 psi DHP Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ! Task Code; NPT Phase - -- - - L 8/5/2006 18:00 - 23:00 5.00 ~ EVAL ~ P ~ PROD1 23:00 - 00:00 I 1.00 I EVAL I P 8/6/2006 100:00 - 01:00 I 1.00 I EVAL I P 01:00 - 03:30 2.50 DRILL P 03:30 - 03:45 0.25 DRILL P 03:45 - 06:00 2.25 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 09:15 2.25 CLEAN P 09:15 - 10:45 1.50 CLEAN P 10:45 - 11:30 I 0.751 CLEAN I P 11:30 - 13:00 I 1.50 I CLEAN I P 13:00 - 14:30 I 1.50 I CLEAN I P 14:30 - 15:00 I 0.501 CLEAN I N i SFAL I W EXIT 15:00 - 16:00 I 1.001 CLEAN I P I I W EXIT 16:00 - 16:30 0.50 CLEAN P WEXIT 16:30 - 17:30 1.00 CLEAN N SFAL WEXIT 17:30 - 19:15 1.75 CLEAN P WEXIT 19:15 - 21:30 I 2.251 CLEAN I P I I W EXIT Page 9 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations Having problems stabilizing well at 2000 psi. Decresed inlet gas f/ 4.Ommcf to 3.5mmcf choke at 20/64" BHP drifting down to 1800psi. Called and okayed with town to test at 1800psi. Still unable to stabilize BHP as it drifted to +/- 1700psi. Maintained 1700psi avg for 1-1/2 hr w/ 0.15 avg flow. At 2100 hrs call town again make adjustments and bring BHP back up to 2000psi. Avg flow from well has been .06bpm maintained 2000psi BHP for 3/4hr called it good after talking to S. French. Open choke setting to 128/64" maintain 1.57 mmcf inlet gas and drawdown BHP to 1500psi. Continue flow testing well. Avg BHP= 1300psi outflow = 0.25bpm WHP = 700psi 110/64" choke TOH PJSM review procedures and job assignments for Pressure Undeploying BHA #6 Undeploy BHA. LD BHA. Adjust motor to 0 deg. Reconfigure BHA w/o DGS and add used 3.80" D331 and string reamer. Bit was 1-1-I Pressure deploy BHA #7 MIRU LRS and diesel transport Start ambient diesel down CT at 1.5/1700 w/ well open to flow w/o GL SI. RIH 50'/min w/o fluid returns. Watch WHP fall from 500 psi to 360 psi as diesel loaded up the well. Then watch WHP rise to 420 psias the gas got displaced from the well. RIH to 3000', clean. PUH to 2500' while pumping 100 bbls to fluid pack the well PT LRS ~ 4000 psi. LRS pump 10 bbls ambient diesel, 25 bbls 80/20 xytene/diesel, 3 bbls diesel down the BS at 1.3/500 psi. Final WHP 290 psi Wait one hour to let xylene soak. Then wait 1/2 hr for ASRC to reset ESD. WHP is 220 psi Open choke to test seperator. Start GLG at 1.3 mmscfd. Start LRS w/ 180 deg diesel down CT at 1.5/1070 while move CT up hole slow. After hot diesel at mill, POH to surface at 1.46/2120. RBIH at 1.5/2240 at 100'/min w/ 180 deg diesel Park at 3800' and work on SWS footage counters. LRS red rate to 0.5/600 Find out that COTP won't be making diesel for a while due to the spill Continue RIH 100'/min at 1.5/1500 at 160 deg to tag at 9120' CTD (due to counter error). SD GLG Receive word that GPB will be in a phased SD, but Lisburne unaffected POOH displacing heated diesel w/ ambient 1.5/1800 Park at 5500' to replace pins on injector 0.6/200 Fin POOH w/ cleanout assy filling hole w/diesel 0.6/110 At 1500' close SSSV continue OOH shutdown pump last 250'. Tag up. Bleed down WHP and ASRC equipment. Isolate ASRC and bledd remaining pressure to TT. WeII still blowing slughtly. Pump 30 bbls KCL down annulus. Bleed off residual pressure and well dead. PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 WEXIT WEXIT WEXIT WEXIT WEXIT Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 10 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 8/6/2006 19:15 - 21:30 2.25 CLEAN P WEXIT Unstab injector and setback. LD cleanout BHA. 21:30 - 00:00 2.50 WHIP P WEXIT Service BHi tools for next run. Hold PJSM for PU whipstock. PU BTT 4.5" KB WhipstocWPacker assembly w/ 2.188" XN nipple. Install 2 Petrodat gauges set for 40 days run time. MU tailpipe .Use ThreadLok on connections. Install 2 pip tags 8.60' from TOWS. MU BHi tools to WS. MU injector stab on well. 8/7/2006 00:00 - 05:00 5.00 WHIP P WEXIT Pressure up well to 550psi and open SSSV. WHP 515psi. RIH slowly with EDC open. Fair amount of 'snubbing' going down -5k to -7k more normal as we got deeper. Check PU wt at 2100' 7.5K RIH wt 1k checked SSSV pressure 4500psi. RIH and tagged the SSSV at 2214'. PU wt 10k come to 2170'. RIH slow again and tagged 2208'. Max setdown was 3k below RIH wt of Ok. PU with anticipation to orient 180 degs pulled tight to 15.5k at 2192'set in neutral wt unable to orient. Make some phone calls. Limit max pull to 16k anything over 18k could shear the pin. Pull to 15.5k no movement. Able to RIH to 2196'. And able to orient while RIH. Oriented to 75R. Try pulling again to 16k with no movement but can still go down. Close the ASRC choke. Pump 0.5bpm/550 through EDC to possibly flush debris from around WS packer element or slips. Still can not PU. One set of slips must be engaging csg preventing ability to PU but retracts and allows RIH. We dont want to go in hole any further. Presently believe the packer element is above the SSSV and in the best position to go ahead and set the packer/slips. (if we run further in the well there's a chance we could put the packer element in a position to not seal. If we dont obtain a good seal then undeploying the BTT setting tools will become a major problem. Overall BHA length once WS is set will only be 4' shorter due to the setting rod being still attached. Upon BTT request will close SSSV and bleed down well just to check if the WS assembly is above the SSSV. Dump SSSV pressure and bleed down well. 05:00 - 06:00 1.00 WHIP P WEXIT Monitor well. Bieed down to 30psi then SI to obseve for any build up. Appears the SSSV has closed and is holding. Crunching numbers we feel the bottom of the WS assmbly is at 2184'. WHP holding at 32psi for last 1/2hr. Close EDC. Pump at min rate setting tool sheared at 2400 psi. Dump pressure. PU 5k and free. WS set. TOWS at +/- 2160'. TOH filling hole and taking any returns through ASRC to flowback tank keeping pressure off the well. 06:00 - 06:30 0.50 WHIP P WEXIT POOH w/ setting assy 06:30 - 07:00 0.50 WHIP P WEXIT Bleed off 320 psi whp to flowback tank 07:00 - 07:30 0.50 WHIP P WEXIT LD WS setting assy complete. No indicators of paraffin, etc. Load out tools 07:30 - 10:00 2.50 WHIP P WEXIT Wait on BTT fishing tools 10:00 - 10:50 0.83 WHIP P WEXIT MU WS fishing tools and open hole deploy 10:50 - 11:20 0.50 WHIP P WEXIT RIH w/ BTT'hook' on hyd GS w/ BHI MWD assy w/o pump taking returns thru rig choke and hardline to tiger tank 11:20 - 11:45 0.42 WHIP P WEXIT 2130' 7.6k, 2.3k. RIH to 2150', orient hook to 60R. RIH to 2174' CTD and set down w/ 2k 3 times at 60R, 5 times at 50R and finally got an overpull Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page ~ ~ of 33 Operations Summary Report Legal Well Name: L5-16 Common W ell Name: L5-16 Spud Date: 5/12/2006 Event Nam e: REENTE R+COM PLET E Start : 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALIST A Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ Description of Operations 8/7/2006 11:45 - 13:00 1.25 WHIP P WEXIT POH @ 50'/min. No recovery, no marks 13:00 - 13:40 0.67 WHIP P WEXIT RIH w/ same BHA ~ 80'/min 13:40 - 15:00 1.33 WHIP P WEXIT 2130' 7.6k, 2.3k RIH to 2150', orient to 60R. Try several times at 60R, 50R at 2173'. Orient 360 deg to change the stops. Start at 0 deg and work around the clock every 30 deg w/o success. Resume working at 50-60R where we have had overpulls 15:00 - 15:15 0.25 WHIP P WEXIT Pump down CT w/diesel at 1.0/600 to use circ port opposite of hook to force tool to side. Took 5 bbls to catch fluid and returns. RIH at 55R and stack 2.5k at 2173'. PUH w/ 3.4k over. Best indicator yet 15:15 - 16:00 0.75 WHIP P WEXIT POH @ 50'/min to check for recovery 16:00 - 16:45 0.75 WHIP P WEXIT No recovery. Check tool and could see where tool had made friction bite. Need more angle in well or more bend in tool. Remove hook and send w/ BTT fisherman to shop to modify. BTT hand is also out of hours 16:45 - 19:30 2.75 WHIP P WEXIT Wait on tools 19:30 - 20:00 0.50 WHIP P WEXIT Pump 30 bbls KCL to further kill well. Monitor and bleed off pressure. Well perculating air/gas. 20:00 - 20:30 0.50 WHIP P WEXIT PU Whipstock Tray hook retrieval assembly. 20:30 - 21:05 0.58 WHIP P WEXIT RIH CT wt -4k first several 100' RIH to 2100 check PU wt 4k. RIH wt 1.5k 21:05 - 21:15 0.17 WHIP P WEXIT With hook oriented to 55R RIH tagged at 2178' setdown 3k PU 10k continue POH 6k steady. 21:15 - 22:00 0.75 WHIP P WEXIT TOH 50'/min to 116'. 22:00 - 22:30 0.50 WHIP P WEXIT Pop off well. POH to BHI tools and install C-plate. Tugger line remaining BHA. No WS traay. No marks on hook. 22:30 - 22:50 0.33 WHIP P WEXIT MU BHA again. 22:50 - 00:00 1.17 WHIP P WEXIT RIH to 2150' PU wt 5000-5200# RIH oriented 55R tag at 2178'. Initial PU 7-8k at 2140 pu wt 6.5k Run back in hole 25'/min tag at 2178 slack-off and orient to 60R. PU 14k slacking back to 6.5k. RIH to 2177' at 65R 1 k setdown orienter came back to 55R PU 8.7k Orient in 5 deg increments to the right and re-try. No change. Orient back to 60 deg. Just not seeing anything that tells us we're close to alignment. 8/8/2006 00:00 - 01:00 1.00 WHIP P WEXIT Continue attempting to hook whipstock. Nothing consistant while orienting at different TF's. WS set lastnight at 60R. Contine at this TF +/- 5 Begs with varying RIH speeds. Even try 180 deg out. 01:00 - 01:40 0.67 WHIP P WEXIT TOH same wts as previous TOH to 104'. 01:40 - 02:15 0.58 WHIP P WEXIT Pop off well. POH to BHI tools and install C-plate. Tugger line remaining BHA. No tray. LD hook assembly and BHI tools. 02:15 - 03:15 1.00 WHIP P WEXIT Redress BHI LOC. PU BTT's new designed overshot with GS and knuckle joint or OSGSK for short. 03:15 - 04:15 1.00 WHIP P WEXIT RIH to 2150'. Wt check 51001bs. RIH pumping 1 bpm at 30'/min tag TOWS at 2172.2' tag with 3k. SD pump. PU 8k then slackoff. PU wt 8k. RIH w/o pump setdown with 5k. PU wt 9k then drops off to 7k. Work back down over WS with pump on setting down 5-6k several times. SD pump and let pressure drop to 0. PU 15.k then broke back to 7k. TOH 04:15-05:00 0.75 WHIP P WEXIT TOH 05:00 - 06:15 1.25 WHIP P WEXIT Pop off well. POH to BHI tools and install C-plate. Tugger line Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date - From - To ~ Hours Task Code I NPT ~ Phase 8/8/2006 105:00 - 06:15 ~ 1.25 WHIP P ~ ~ WEXIT 06:15 - 10:40 I 4.42 f WHIP I P J I WEXIT 10:40-11:101 0.501WHIP IP I (WEXIT 11:10 - 11:40 0.50 WHIP P WEXIT 11:40 - 12:20 0.67 WHIP P WEXIT 12:20-13:00 I 0.671WHIP IP I (WEXIT 13:00-14:451 1.751WHIP IP I (WEXIT 14:45 - 15:25 ~ 0.67 WHIP P WEXIT 15:25 - 16:10 0.75 WHIP P WEXIT 16:10-17:05 I 0.921WHIP IP I (WEXIT 17:05 - 17:50 0.75 WHIP P WEXIT 17:50 - 18:30 0,67 WHIP P WEXIT 18:30-20:301 2.OOIWHIP IN (SFAL (WEXIT 20:30 - 00:00 3.50 WHIP N SFAL WEXIT 8/9/2006 00:00 - 01:30 1.50 WHIP N SFAL WEXIT 01:30-03:15 I 1.751STWHIPIP I (WEXIT Page 12 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations remaining BHA. No tray. Inspect OS assembly. No marks to indicate it engaged TOWS. MU swivel on top of hook assembly. This should allow the shroud and hook to self align to the WS tray slot. Find hook is not aligned w/ tray guide (shroud). Send to BTT for straightening Wait on BTT to straighten the hook Displace the CT to KCI water Visual inspection while looking down the stack showed a loose 4" OD x 1"piece of Hydril rubber which was recovered. Another piece the same size was also missing from the annular. Slickline also recovered a piece on L5-28 MU BHA #12RR (Overshot, GS, knuckle) after BTT recommmended this would be the best choice after finding a 1" piece of rubber in the same tool on the prior run RIH w/ BHA #12RR w/o pump 2150' 8.5k/2.2k RIH to set down at 2172.6' and stack 5k. PU w/ no overpulls. Start pump 1.0/1500. Wash in hole to 2173' and stack 5k. SD pump, PUH and had 2k over. Repeat w/ 6k down. No overpulls Set down with 600#'s WOB and rotate orienter, gained wt back and RIH 0.4' setdown 6k. PU but no overpull. TOH. Recovered WS tray. No junk or paraffin on tray. No gouge marks. Inspection at BTT shop showed hook had at one time engage slot. Possible we may have pulled tray from packer lastnight on first try with modified hook bend when there was 14k overpull on first try but then lost the tray. Remove BHI 2-3/8" head PuII test CTC to 40k. Behead with 3". Test UOC a-line connection..good. PU 3" BHI tools. BTTjars and GS. RIH to 2150' With closed EDC fluid pack hole at tbpm/680psi pump 15 bbls with no fluid to surface. Wt check 11k. RIH pumping 1 bpm. Tagged at 2184.5' shut-in choke to TT SD pump let pressure bleed down coil thru baker choke. PU to 9k only. Bring on pump RIH 30'/min tag PU but latched in. Keep pump off and wait 30 minutes for fluids to equalize in wellbore. (well is taking fluid) RIH and engage GS wo pump on. PU and latched wait for jars to relax. PU to 45k and packer released. Wait for packer element to relax TOH slight drag across tbg collars.. good indications pkr on. OOH, closed MV and LD packer. Recovered all fish No evidence of paraffin on packer or tray. Load out BOT tools. Large pieces of element hanging in the the open hole. Closed MV,both SV's and top blind shears. ND riser and inspect rubber element. Change out rubber element in annular. Finished installing annular elements. PT annular to 250 / 2500 psi OK. RD test joint Held PJSM on PU Venturi basket. PU 3-5/8" ventruri basket with 9/16" ball in place. Fill hole and messed around with air in well bore. Stabbed on well. PT the CT annulus to 550 psi with closed SSSV. SD and open SSSV and WHP dropped to 0 psi. Lined out to diesel tank # 1 Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 13 of 33 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To 5-16 5-16 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase Spud Date: 5/12/2006 : 7/27/2006 End: 9/1/2006 Release: 9/1/2006 Number: Description of Operations 8/9/2006 03:15 - 05:10 1.92 STWHIP P WEXIT RIH at 1.5 bpm at 1,300 psi filling CT with diesel. Wt Check at 2,130 ft = 6k. RIH pumping at 1.5 bpm and 1500 psi CTP. Stopped at 9,050 ft, open EDC. 05:10 - 07:00 1.83 STWHIP P WEXIT POOH replacing CT voidage with diesel. Close SSSV. 07:00 - 07:25 0.42 STWHIP P WEXIT Well dead. LD BHA. Breakdown ventruri basket., nothing but smallamount of metal shavings. 07:25 - 07:45 0.33 STWHIP P WEXIT PU 3.70" x 8' BTT dummy whipstock. 07:45 - 13:00 5.25 STWHIP P WEXIT RIH -2k at first. RIH to 2150' wt check 7-8k. RIH 30'/min 3-4k to 1-1.5k at 2210-220' RIH to 2300'. PU back thru SSSV 17'/min 6-7k 7.6-9K thru valve area PU to 2165'. RIH 17'/min 3.6-4k Better this time thru SSSV no slack off. Continue RIH 50-60'/min down to 9075' wo problems. TOH..looks good. 13:00 - 18:00 5.00 STWHIP P WEXIT Wait on whipstock. In machine shop having parts turned down then BTT needs to assembly. Arrive at 1745 18:00 - 18:15 0.25 STWHIP P WEXIT Held PJSM on PU and handling MWDS tool and BOT Whipstock and settting tool 18:15 - 20:20 2.08 STWHIP P WEXIT PU L2 BHA with BHI's MWD system 20:20 - 00:00 3.67 STWHIP P WEXIT RIH and PT to 600 psi before open SSSV RIH passed slowley through nipples and GLM 8/10/2006 00:00 - 00:30 0.50 STWHIP P WEXIT RIH with WS and packer BHA 00:30 - 01:20 0.83 STWHIP P WEXIT Tie-in at 8930 ft (-1 ft correction) RIH and load CT with diesel Confirm Tiein after loading CT 01:20 - 01:40 0.33 WHIP P WEXIT SD pump, closed EDC and set packer and whipstock at 8960 ft HS TF. Set packer with 3200 psiPUH and re-open EDC. 01:40 - 02:35 0.92 STWHIP P WEXIT Displacing wellbore fluids to flo-pro Op = 2.0 / 2.0 bpm at 2,950 psi. WHP = 560 psi at ASRC Pumped 40 bbls KCL and then switch to Flo-Pro for milling 02:35 - 02:40 0.08 STWHIP P WEXIT POOH chasing clean flo-pro to surface While POOH lost 1 chain bearing. SD and replaced 02:40 - 03:30 0.83 STWHIP N SFAL WEXIT Change roller bearing on injector head Circulating well to flo-pro while inspecting chain rollers bearings 03:30-06:30 3.00 STWHIP P WEXIT POOH 06:30 - 07:00 0.50 STWHIP P WEXIT Check well for pressure. Dead.. LD WS setting tools 07:00 - 08:15 1.25 STWHIP P WEXIT PU window milling BHA: 3.80" window mill and 3.79" no-go string mill, BTT straight 2-3/8" motor. 08:15 - 08:35 0.33 STWHIP P WEXIT RIH to 1100'. 08:35 - 08:50 0.25 STWHIP P WEXIT Pressure test tbg and WS packer to 1600psi for 15 min. No leak-off 08:50 - 10:45 1.92 STWHIP P WEXIT RIH to 8890' 10:45 - 11:00 0.25 STWHIP P WEXIT Log tie-in -1' correction 11:00 - 00:00 13.00 STWHIP P WEXIT RIH dry tagged TOWS at 8960' With pump tagged at 8961.1' Start time milling window Op = 2.55bpm @ 3,930 to 4178 psi. Mw 100-200psi Tagged the 7-5/8" casing at 8,968.5 ft 8/11/2006 00:00 - 01:30 1.50 STWHIP P WEXIT Milling window Op = 2.54 bpm at 4,340 psi. At 8,974.1 ft, outside 7-5/8" casing. Stalled at 8,974.3 ft. Reamed back to 8,974.3 ft. TOW = 8961.1 ft RA Marker = 8969.7 ft BOW = 8973.6 ft 01:30 - 02:35 1.08 STWHIP P WEXIT Drilling formation from 8,973.6 ft to 8,984.3 ft at 2.57 bpm at 4156 psi CTP Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date ~ From - To 8/11/2006 01:30 - 02:35 L5-16 L5-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/27/2006 Rig Release: 9/1/2006 Rig Number: Hours Task ~ Code I NPT Phase i - _- - _ - -- 1.08 STWHIP~P WEXIT 02:35 - 04:10 I 1.581 STWHIPI P 04:10 - 06:15 2.08 STWHIP P 06:15 - 07:00 0.75 STWHIP P 07:00 - 10:00 3.00 BOPSU P 10:00 - 20:00 10.00 BOPSU P WEXIT WEXIT WEXIT PROD1 PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 23:00 2.50 DRILL P PROD1 23:00 - 23:10 0.17 DRILL P PROD1 23:10 - 00:00 0.83 DRILL P PROD1 8/12/2006 100:00 - 04:15 I 4.251 DRILL I P I I PROD2 04:15 - 05:30 1.25 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 07:45 1.75 DRILL P 07:45 - 08:00 0.25 DRILL P 08:00 - 11:25 3.42 DRILL P 11:25 - 11:35 0.17 DRILL P 11:35 - 13:00 1.42 DRILL P 13:00 - 15:45 I 2.751 DRILL I P 15:45 - 15:55 0.17 DRILL P 15:55 - 16:45 0.83 DRILL P 16:45 - 18:00 1.25 DRILL P 18:00 - 20:53 2.88 DRILL P PROD2 PROD2 PROD2 Page 14 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations Conducting fluid swap while drilling rathole OA pressure rose 200 psi to 330 psi while milling window Reaming window from 8,984 ft to 8,959 ft. Dry tagged at 8,984 ft PUH and open EDC, POOH Close SSSV LD window milling BHA Close MV. Bleed down accumulator. Start visual inspection of all BOP componets Bottom 2" PS and lower blinds look as new. Inspect upper 2-3/8" P/S...same condtion. Bi-Weekly BOP test 300psi low 3500psi high (AOGCC given 24 and 1 hr notice) Installed new pack-offs PJSM on handling slipping and cutting Drilling line CDL (50 ft) and slip and cut slickline for pressure deploying PJSM on slack management PU Injector and remove XO and found 36 ft of spare /lose monocable cable coming out of CT. "Two for the price of one". Checked wire left in CT and its OK. Stabbed on well. Rev cir and cut CT Cut off 80 ft coiled tubing. Installed slick 2" CTC and pull tested to 30k, Changed out CTC with 2.2" no/go CTC. Pull CTC to 36k, OK. Head up BHI cable to UOC. Meged line and PT to 3,500 psi. PU BHI's BHA Stab on well Line out ASRC to take returns from well. Started 5 bbl MEOH down IA during initial startup RIH to 8900' (pumping min rate 0.14 bpm start-up gas injection at 1.0 mmcf) PROD2 Log tie-in -1' PROD2 Shutdown pump. Continue gas injection to stabilize well. Choke full open at 128/64" Increase gas rate to 2.5mmcf at 0820. Inc gas rate to 3.5mmcf at 0900 Bring on pump rate slowly f/ 1.0 to 1.25 then 1.50 bpm +/- 300psi CTP ~ 10:45 well stabilized bhp= 2250 pinch choke down to 95/64" BHP stabilized +/- 2400psi PROD2 Close EDC. RIH thru window to 8984'. PROD2 Just off bottom free-spin only 270psi at 1.57bpm BHP 2300psi Pinch back choke to 75/64". Tag bottom attempt to drill ahead. On bottom motor appears to be stalling with 300psi additional pressure or MW. Somethings not right. Possible the motor rotor/stator clearance is too much for drilling with KCL. Motor set at .29 where normal motor setting for drilling with waterbase fluids is closer to .10 Despite repeated attempts with light WOB motor continues to stall. PROD2 TOH shut in GL both at the choke and manual valve. Open EDC pump at 1.4bpm At 1500' close SSSV. Isolate seperator. PROD2 PJSM review LD of BHA w/wo pressure deplyment. PROD2 Bleed down 150psi well pressure to TT. Slight blow. Pump 5 bbls dwn tbg. Still small blow. PROD2 Pressure undeploy BHA. PROD2 LD BHA, Bit had chipped cutters on BC guage. Motor turned Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 15 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task ~ Code' NPT Phase Description of Operations 8/12/2006 18:00 - 20:53 2.88 DRILL P PROD2 freely. PT entire BHA and found EDC has some drips when pressured up. Changed out EDC /HOT and open well to TT and checked integrity of SSSV Gas bleed back from ASRC. Closed manual valve on flowline. Normal deploy BHA PT above SSSV to 500 psi OK. Open SSSV using 4500 psi 20:53 - 22:40 1.78 DRILL P PROD2 RIH with EDC closed at Op ~ min 22:40 - 22:55 0.25 DRILL P PROD2 Log tie-in starting at 8,900 ftCorrected -3.5 ft 22:55 - 00:00 1.08 DRILL P PROD2 SWI , SD pump, set TF to HS and RIH. At 8,974 ft, open well and started MP at 1.5 bpm Drilling build section Whaoo 6.1 at HS TF Op = 1.61 bpm CTP X800 psi off bottom. Ogl = 2.5mmcf/day. Pumping 1 bbl MEOH /hour Choke 100 / 64ths WHP = 663 psi BHP = 3400 psi, still working at achieving underbalance. Tagged bottom at 8,982.5 ft and stalled, Taking some time to get started. 8/13/2006 00:00 - 04:15 4.25 DRILL P PROD2 Drilling build section in W 6.1 at HS TF from 8984 ft Op = 1.71 bpm CTP X880 psi off bottom. Qgl = 2.5-3.5 mmcf/day. Pumping 1 bbl MEOH /hour Choke 128 / 64ths: WHP = 634 psi; BHP = 3130 psi WOB 2.2 -- 4.Ok; ROP = 10-25 fph 04:15 - 06:00 1.75 DRILL P PROD2 06:00 - 09:30 3.50 DRILL P PROD2 09:30 - 10:00 0.50 DRILL P PROD2 10:00 - 11:05 1.08 DRILL P PROD2 11:05 - 12:35 1.50 DRILL P PROD2 TOW = 8960.40 ft RA Marker = 8969.00 ft BOW = 8973.00 ft Drilling build section in W 6.1 at HS TF from 9037 ft Op = 1.71 bpm CTP @750 psi off bottom. Ogl = 3.5 mmcf/day; Choke 128 / 64ths: W HP = 634 psi; BHP = 3130 psi WOB 1-4k; ROP = 15-30 fph Increased GL rate 3.5 mmcf/day to test if we can get to the underbalance mode. Drilling ahead f/ 9072' at 45L TF Op = 1.70 CTP FS = 765 Ogl = 3.5 mmcf, choke 128/64" WHP= 676psi, BHP = 3162 psi Reduce Op = 1.50 bpm CTP FS = 500psi to help reduce BHP WOB 1-3k, ROP = 15'/hr 4k will stall motor 07:45 BHP = 3150 psi increase Ogl f/ 3.5 to 4.5 this actually increased BHP slightly. Cut back Ogl to 4.0 mmcf/day Drilling ahead f/ 9106' 45L TF Op = 1.52 CTP 500psi 100-150psi MW Ogl = 4.Ommcf/day BHP= 3180psi WHP = 688 HdrP = 588 WOB 2-3k ROP= 15-20'/hr W iper trip to just below window. SD pump open EDC trip above window. Pump at 0.5bpm attempt to stabilize well at a lower BHP PU to 8826' -RIH 1.5bpm 250psi BHP = 2300 psi Close EDC below window RIH to bottom Drill ahead f/ 9119' 45L TF Op= 1.52 CTP = 264psi 100-150 psi MW (1150psi stall pressure) Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task Code NPT Phase I ~ 8/13/2006 ~ 11:05 - 12:35 ~ 1.50 DRILL P PROD2 12:35 - 14:40 2.08 ~ DRILL P ~ ~ PROD2 14:40 - 16:45 I 2.081 DRILL (P I I PROD2 16:45 - 17:15 I 0.501 DRILL I P I I PROD2 17:15 - 19:15 2.00 DRILL P PROD2 19:15 - 21:25 2.17 DRILL P PROD2 21:25 - 21:35 0.17 DRILL P PROD2 21:35 - 22:00 0.42 DRILL P PROD2 22:00 - 23:30 I 1.501 DRILL I P I (PROD2 23:30 - 23:45 I 0.251 DRILL I P I I PROD2 23:45 - 00:00 I 0.251 DRILL I P I I PROD2 8/14/2006 100:00 - 01:00 I 1.001 DRILL I P I I PROD2 01:00 - 01:20 I 0.331 DRILL I P I I PROD2 01:20 - 05:25 I 4.081 DRILL I P I I PROD2 05:25 - 07:05 ~ 1.67 ~ DRILL ~ P ~ ~ PROD2 Page 16 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations Ogl 4.1 mmcf/ day BHP = 2252 psi out 4.0 mmcf/day Choke = 45/64" WOB = 2-5k ROP = 25-40'/hr (Higher rates with less BHP) BHP slowly climbing @ 9130' BHP = 2635 adjust choke to 55/64" BHP leveled off at 2765- 2800 psi Predicted 89 deg at bit. Averaged 49 deg doglegs during build section. TOH for lateral BHA. Opened EDC below window continue TOH .64 pump rate PJSM review pressure deployment procedures and hazards. Tag-up. Zero counter. RIH 2.7' Start pressure undeployment of BHA #19 Change motor setting to 1.0 deg PU new Hycolog Raptor bicenter bit. Pressure deploy BHA #20 with crew change and TL meeting RIH Tie-in from 8,900 ft to 8,950 ft, corrected (- 2 ft) SWI and RIH and open well back up at 8,975 ft. Tagged bottom at 9153 ft MD Drill ahead f/ 9,153 tt 120E TF Need to drop to 8788 ft TVD then invert pat. Working at getting underbalance Op= 1.45 CTP = 850psi 300-700 psi MW Ogl = 4.1/4.0 mmcf/ day BHP = 3000 psi Choke = 128/64" WHP 693 psi HP = 578 psi WOB = 2-5k ROP = 50-70fUhr ROP slowed down from 50 fph to 0 fph, PUH short wiper. TVD at 8785 ft. Drill ahead f/ 9,216 ft 90R TF Op= 1.45 CTP = 850psi 300-700 psi MW Ogl = 4.1/4.0 mmcf/ day BHP = 3073 psi Choke = 128/64" WHP 688 psi HP = 586 psi WOB = 2-5k ROP = 15-30 ft/hr Drill ahead f/ 9,216 ft 90R TF Op= 1.45 CTP = 850psi 300-700 psi MW Ogl = 4.1/4.0 mmcf/ day BHP = 3073 psi Choke = 128/64" WHP 688 psi HP = 586 psi WOB = 2-5k ROP = 15-30 ft/hr W iper trip to base ofW S at 8980 ft Reduced Op to 1.3 bpm to see if this will reduce the BHP below 3000 psi Drill ahead f/ 9,250 ft 75R -120R - 150E - 90L TF Op= 1.45 CTP = 650-850psi 300-700 psi MW Ogl = 4.2-4.0 /4.0 mmcf/ day BHP = 3169 psi Choke = 128/64" WHP 688 psi HP = 586 psi WOB = 2-4k ROP = 15-40 fUhr Having trouble getting BHP below 3000 psi Reduced Og to 4mmcf/day At 9328 ftBHP = 2,967 ft, it takes time to get BHP below 3000 psi ROP PU at 9,315 ft to 68 fph. Wiper trip at 9,375 ft. Come to window shutdown pump. Open EDC continue up hole to lower GEM. RIH min rate to below window. Close EDC Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 17 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: ~ i Date From - To ;Hours Task i Code i NPT Phase Description of Operations 8/14/2006 05:25 - 07:05 1.67 DRILL P PROD2 continue RIH to bottom 07:05 - 11:40 4.58 DRILL P PROD2 Drili ahead t/ 9375' SOL TF Op = 1.50 freespin 260psi 200-300psi MW Ogl = 4.11 mmcf/day varying choke after wiper trip to establish a lower BHP WHP = 693 HP = 593 WOB 1-3k ROP= 40-50'/hr ROP slowed significantly around 9430' and held the slower rates to 9487' 11:40 - 12:30 0.83 DRILL P PROD2 Wiper trip to 8980' 20'/min good coming up. RIH with as drilled TF's no problem to TD 12:30 - 17:00 4.50 DRILL P PROD2 Drill ahead f/ 9487' Op = 1.41 free-spin 300 spi 100-150psi MW Op out = 0.86 Ogl = 3.56mmc/day BHP = 3140 psi 128/64" choke WHP =620 psi HP = 570 psi WOB = 2-3k ROP = 10-15'/hr Returns coming closer to 1:1 around 9505' and maintaning that. ROP inc to 30-50'/hr from +/- 9540' 17:00 - 19:00 2.00 DRILL P PROD2 Drill ahead f/ 9,590 ft to 9,650 ft Op = 1.44 free-spim 300 psi 200-400psi MW Op out = 1.46 Ogl = 4.0 inc to 4.1 mmcf WHP = 633 HP= 580; BHP = 3050 psi WOB 2-3k ROP= 40-50'/hr Gr API= 17-19 19:00 - 20:00 1.00 DRILL P PROD2 Wiper trip to 8980 ft Tie in starting at 8,983 ft. No correction. RIH clean 20:00 - 22:50 2.83 DRILL P PROD2 Drill ahead f/ 9,650 ft w/ 90L-80L-75L TF. Op = 1.45 / 1.46 bpm Ogl = 4.3 to 4.5 mmcf WHP = 643 HP= 580 psi; BHP = 2964 psi WOB 2-3k ROP= 25-60'/hr Increase in BHP at 9,688 ft MD, PU hole clean BHP inc again at 9740 ft at 22:40 hrs. PUH, clean 22:50 - 23:52 1.03 DRILL P PROD2 Wiper trip Tagged at 9,425 ft with drilled tt PU and RIH set down 9,456 ft with motor work. PUH, RIH without prroblem tagged bottom at 9747 ft 23:52 - 00:00 0.13 DRILL P PROD2 Tagged bottom and BHP Increased to 3875 psi PUH, work CT BHP came down a little, PUH, Tagged bottom again and BHP both guages increased vertically, DPS failure Failure has occurred before on DPS board when BHT > 162 deg F 8/15/2006 00:00 - 00:20 0.33 DRILL P PROD2 PUH to 9621 ft The annular ppressure dropped to 2,936 psi. RIH to and watch BHP's Could have a computer Glitch with the DPS at higher BHT of 163 deg F. Tagged bottom and its acting OK 00:20 - 00:45 0.42 DRILL P PROD2 Drill ahead f/ 9,746 ft w/ 90L TF. After drilling 10 ft the BHP values changed abruptly Op = 1.45 / 1.46 bpm Ogl = 4.5 mmcf WHP =643 HP= 580 psi; BHP = 2992 psi WOB 2-3k ROP= 25-60'/hr 00:45 - 03:05 2.33 DRILL P PROD2 POOH, Closed in S2 and S3 values on separator. PUH slowley through WS area. DP at motor at <50 psi. POOH Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ! From - To Hours Task Code NPT Phase 8/15/2006 00:45 - 03:05 2.33 DRILL P PROD2 03:05 - 05:30 2.42 DRILL P PROD2 05:30 - 06:00 0.50 DRILL P PROD2 06:00 - 06:15 0.25 DRILL P PROD2 06:15 - 07:35 1.33 DRILL P PROD2 07:35 - 10:00 2.42 DRILL P PROD2 10:00 - 10:20 0.33 DRILL P PROD2 10:20 - 12:20 2.00 DRILL N DPRB PROD2 12:20 - 15:00 I 2.671 DRILL I N I DPRB I PROD2 15:00 - 16:00 I 1.00) DRILL I N I DPRB I PROD2 16:00 - 17:30 I 1.501 EVAL I P I I PROD2 17:30 - 21:45 I 4.251 EVAL I P I I PROD2 Page i 8 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations reducing Ogl to 2.5mmcf/day Tagged up and set counter and RIH 2.7' for pressure deployment. Field PJSM Pressure undeploy BHA. FW HP = 630 psi using 2.35 mmcf/day Well flowing to ASRC at 0.6 to 0.7 bopd at 8-10% WC. with 1.2 mmcf/day. LD BHA, Change out DPS and confirm integrity of MWD tool. PJSM with new crews. Cover deployment procedures and hazards. Alert guard to shutdown traffic approching pad, and alert DSO that gas will be vented to TT. Pressure deploy BHA #21 RIH to 8983' wo pump and closed EDC Ogl = 2.5in 3.21 out steady Of = .61 steady Oc = WC +/- 30% WHP = 700 psi HP = 552 psi Log tie-in -3.5' correction RIH pumping 1.4bpm 250 psi free-spin SD pump at 9375' RIH with 50-60L'as drilled toolfaces' at 20'/min tagged at 9408' PU 31k to 9380' RIH 30'/min setdown same. PU bring pump on to .6 bpm RIH tag same. PU 9370' orient 30L RIH 30'/min .6 bpm Hope PU orient to 70L RIH tagged same place, PU (hole angle here 90 deg) orient 15L pump at 1 bpm RIH Call discuss problem with town. From 9300' RIH 50'/min .5bpm 50-60L TF 19k dwn set down 9013' PU to 9380' 28-30k Set pump at 1.4 bpm 215 psi RIH f/ 9400' at 5'/min 55L TF taking wt at 9008' slow to 20'/hr at 9111' slowly ream thru holding 55L TF 3.4K WOB Ream to 9418' where it stopped making progress. PU 41 k off btm back to 9370'. RIH slow to 9406' Time drill from 9406.1' ~ .1' ft / 2 min 3-4k WOB Continue time reaming f/ 9408.1' ~ .1'/2 min 3-4k wob no MW CTP = 210 psi PUH and reduced choke to 55 beans, increased Op and try to increase the BHP > 3000 psi. RIH and set down at 9413 ft MD with motor work. BHP unstable, PU and adjust choke to 45 beams and inc Op to 1.6 bpm. With FBHP at 3100 psi tried to work past 9410 ft MD and still seeing motor work. Worked down to 9418 ft MD without much Tuck getting past shale between 9,375 ft to 9,460 ft. After talking with town, PUH to look at flow testing Open EDC and parked CT at 8,920 ft Set up wellbore parameters to flow test AL1 lateral TD at 9,759 ft MD 4 hour flow test. Choke: 38/64 WHP: 829 psi BHP: 1520-1530 psi. O gas in: 4.47 mmscfd Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code ! NPT ~ - - - ~ 8/15/2006 17:30 - 21:45 ~ 4.25 ~ EVAL P 21:45 - 23:00 I 1.251 DRILL I N 23:00 - 00:00 1.00 DRILL N 8/16/2006 00:00 - 00:45 0.75 DRILL N 00:45 - 02:45 2.00 DRILL N 02:45 - 03:45 1.00 DRILL N 03:45 - 05:15 05:15 - 09:30 1.50 DRILL N 4.25 DRILL N 09:30 - 11:00 11:00 - 14:30 14:30 - 14:45 14:45 - 16:15 16:15 - 18:30 18:30 - 20:00 20:00 - 23:30 1.50 DRILL N 3.50 EVAL N 0.25 STKOH N 1.50 STKOH C 2.25 STKOH C 1.50 STKOH X 3.50 STKOH X Start: 7/27/2006 Rig Release: 9/1/2006 Rig Number: Page 19 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Phase Description of Operations PROD2 O gas out: 5.44 mmscfd O oil: 0.4 bpm (+/- 570 BOPD) Water cut is dropping as well bore cleans up. DPRB IPROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 PROD3 PROD3 DFAL PROD3 DFAL PROD3 23:30 - 00:00 0.50 STKOH X DFAL PROD3 8/17/2006 00:00 - 00:45 0.75 STKOH X DFAL PROD3 00:45 - 02:45 2.00 STKOH X DFAL PROD3 02:45 - 03:00 0.25 STKOH X DFAL PROD3 03:00 - 03:30 0.50 STKOH C PROD3 03:30 - 06:10 I 2.67 I STKOH I C I I PROD3 06:10 - 09:37 ! 3.45 ! STKOH ! C ! ! PROD3 09:37 - 10:55 ~ 1.30 ~ STKOH ! C ! ! PROD3 Pull out of hole to 5000'. Spot and rig up LRS pump truck. Hold PJSM to discuss pumping hot diesel. Replace failed injector chain bearing. Pressure test LRS line to rig to 4000 psi. Pull out of hole washing with 150 deg diesel. 1.75 bpm at 3100 psi. EDC is closed. Maintain WHP from 950 to 1020 psi. Continue to wash out of hole. Displace coil to KCL water. Hold PJSM to discuss un-deployment. Shut in gas lift and ASRC choke. Complete rig down of LRS. Pressure undeploy BHA. WHP: 975 psi. Make up clean out BHA assembly (D331 diamond mill and string reamer on straight mtr, 3.79" od) Hold PJSM. Pressure deploy BHA. WHP: 1150 psi. RIH cleaning out tubulars with 3.8" mills Op = 1.6 to 1.7 bpm at 75 fpm RIH to 8945 ft , PUH and SI GL and allow wellbore to load up. Held PJSM on pressure or normal undeploying of BHA. Planned way forward and discussed hazards associated with task. Bleed WHP down and well on vac. Pressure undeploy BHA Talked to town and worked on plan forward. Worked up directional plan and emailed to SLB Anchorge for drag calculation. Sent results to Asset team for approval. Open Hole sidetrack Held PJSM on conducting open hole sidetrack. Talked about pressure deploying BHA and setting assignments Pressure deploy sidetrack BHA. RIH to sidetrack well. Start tie in log. DPS tool failed. Reboot, power on and off. Cannot communicate with tool. Pull out of hole for MW D. Circ at min rate to keep the coil full. Gas rate in: 2.51 mmscfd. PJSM in Ops cab. Pressure undeploy BHA. Brass cap on R60 bit intact. WHP: 712 psi. Replace DPS sub. Test MWD tools. PJSM. Pressure deploy BHA. WHP: 710 psi. Finish pressure deploying BHA. Run in hole. Log gr tie in. Add 2' correction. Run in hole. Take weight at 9425'. Get motor work. Repeat three times. Should have knocked brass cone off by now. Begin troughing for sidetrack at 9240'. Trough to 9260' at 175E toolface at 20' per hr. Make three passes. Note motor work. Weight transfer appears to be good. 275 psi fs at 1.5 bpm in. Gas lift at 3.6 mmscfd in. FBHP = 2,666 psi Back reamed from 9,260 ft to 9,240 ft at 0.2 fpm Op = 1.5 bpm Reamed from 9240 ft to 9260 ft at 0.2 fpm Op = 1.58 bpm FBHP = 2616 psi Ogl 4.5 mmcf/day Locked brake at 9,260 ft for 30 minutes. Time drill at 3 min/ 0.1 ftfor3ftto9263ft Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 20 of 33 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ; Name: L ell Name: L e: Name: From - To ~ _ __ ~ 5-16 5-16 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase ~ ! Spud Date: 5/12/2006 : 7/27/2006 End: 9/1/2006 Release: 9/1/2006 Number: Description of Operations -- 8/17/2006 09:37 - 10:55 1.30 STKOH C PROD3 _ Name of Sidetrack is L5-16AL1-01 10:55 - 14:08 3.22 STKOH C PROD3 Control drilled at 5 to 8 fpm at 90L-40L then to HS TF. Op = 1.58 / 1.11 bpm FBHP = 2637 psi WHP = 703 psi at 128/64 choke At 9,250ft, inc in GR units 20 to +100 API units. This is 1/2 down our trough arera between 9,240 ft to 9,260 ft Peaked at 9,265 ft at +100 API units then dropped sharply like a fault to 20 API at 9270 ft 14:08 - 15:10 1.03 STKOH C PROD3 Back ream HS OHST in preparation of coming out of hole. 15:10 - 17:00 1.83 STKOH C PROD3 POOH. Tag up at surface. 17:00 - 19:30 2.50 STKOH C PROD3 Hold PJSM. Pressure undeploy ST BHA. WHP: 1050 psi. R60 ST bit in very good shape, one chipped and one broken cutter (1-1-I) 19:30 - 21:45 2.25 DRILL C PROD3 Hold PJSM. Pressure deploy 2.0 deg mtr w/ Hycalog bicenter. WHP: 1042 psi. 21:45 - 23:45 2.00 DRILL C PROD3 Run in hole with build BHA. Slowly increase gas in rate while RIH. 23:45 - 00:00 0.25 DRILL C PROD3 Log GR tie in from 8900'. 8/18/2006 00:00 - 03:30 3.50 DRILL C PROD3 Drill ahead from 9304'. to 9370 ft w/ 260 psi fs at 1.54 bpm in. Well not yet stable and continues to slug/unload. DHWOB: 2-3k#. Gas in: 4.34 mmscfd. WHP/BHP/ECD: 620/2259/4.98 PPg• TF at highside. Build to 105 to 107 deg incl. Hold angle and drill ahead. Encounter multiple "mudstones", not sure what is going on. 03:30 - 04:45 1.25 DRILL C PROD3 W iper trip to window. Call town geo to discuss drilling plan. Decide to drill ahead to 8760', then roll over to lateral. 04:45 - 06:10 1.42 DRILL C PROD3 Unable to get past upper "mudstone". Work pipe. Vary pump rate and running speed. TF at 40L, as originally drilled. Keep setting down at 9122'. No motor work noted. Attempt with TF highside. Try several high side TF orientations. W Iper back to window. No combination of pump or running speed is working. No motor work and no overpulls. Just cannot get past 9122'. 06:10 - 07:30 1.33 DRILL C PROD3 POOH 07:30 - 08:30 1.00 DRILL C PROD3 Pressure Undeploy BHA following PJSM that identifed the Hazards and delgated the work area hands. Restricted pad while undeploying 08:30 - 12:30 4.00 DRILL C PROD3 Wait on plan forward while flowing well. Wait on BOT tools Ogl = 1.50 mmcf/day 01=0.2bpm at 20 to 30%WC Og = 1.51 mmcf/day WHP = 1,029 psi on 15/64" choke. 12:30 - 14:05 1.58 DRILL C PROD3 PJSM on PU BOT tools with associated hazards PU 3.70" Dummy whipstock drift with BHI's MWD. Pressure deploy as per SOP's. 14:05 - 15:45 1.67 FISH C PROD3 Set counters RIH with 3.7 DWS to 8960 ft 15:45 - 17:20 1.58 FISH C PROD3 POOH with 3.70" Dummy whipstock 17:20 - 19:30 2.17 FISH C PROD3 Held PJSM Pressure on undeploying drift BHA. Pressure undeploy BHA 19:30 - 21:15 1.75 FISH C PROD3 Lay down drift. MU and scribe HOT to whipstock ret tool. PJSM. Pressure deploy WS retrieval BHA. WHP: 250 psi. 21:15 - 22:45 1.50 FISH C PROD3 Equalize coil/annular pressure. Open EDC. Run in hole. Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 21 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase ~ Description of Operations 8/18/2006 21:15 - 22:45 1.50 FISH C PROD3 WHP: 250 psi. No gas in. 22:45 - 23:00 0.25 FISH C PROD3 Log gr tie in from 8900'. 23:00 - 23:15 0.25 FISH C PROD3 28k# up, 18k# do wt with no pump rate. Oriented to low side. Run in hole to 8975' (past TOWS). Pick up. Overpulled to 34k# (5k# over up weight). Good indication WS on hook. 23:15 - 00:00 0.75 FISH C PROD3 Pull out of hole at 70-80 FPM. Slow down at GLMs and SSSV. 8/19/2006 00:00 - 01:30 1.50 FISH C PROD3 Continue to pull out of hole with whipstock tray retrieval assembly. Close EDC. Hold PJSM. 01:30 - 03:15 1.75 FISH C PROD3 Hold PJSM. Close EDC. Pressure undeploy BHA. Tray fell off hook onto swab valve. Fish same with hook on tugger line. 03:15 - 05:15 2.00 FISH C PROD3 MU wash stinger on CSH pup. Pressure deploy with MW D minus the orienter. 05:15 - 07:00 1.75 FISH C PROD3 Run in hole. 07:00 - 07:10 0.17 EVAL C PROD3 Log tie-in corrected -2 ft. Pumped 10 bbl sweep down CT 07:10 - 07:30 0.33 EVAL C PROD3 RIH, wt check at 8968 ft = 26k at 1.6 bpm With sweep at nozzle tagged at 8979 ft, PU and tagged again at 8979 ft. Pumped sweep around and the PUH and Open EDC. 07:30 - 09:15 1.75 EVAL C PROD3 POOH at 1.76 bpm, Held PJSM concerning pressure undeploying cleanout BHA and identified and mitagated the hazards 09:15 - 10:30 1.25 EVAL C PROD3 Pressure undeploy BHA as per SOP's 10:30 - 10:45 0.25 EVAL C PROD3 PJSM with SLB Wireline on RU and running tools to retrieve XN plug and guages. Identified hazards and new people involved in task. Mitigated risk and agreed to stop the job if need- be. 10:45 - 12:30 1.75 EVAL C PROD3 RU slickline Conducted weekly BOP function test 12:30 - 13:30 1.00 EVAL C PROD3 RIH with equalizing prong to 8,980 ft Set down 8,980 ft . POOH and see marks on prong, but did see any WHP change 13:30 - 14:50 1.33 EVAL C PROD3 RIH wih 2" GS to retrieve plugJarred on for 15 min, POOH weighting heavier. SW I and unstab from well. Recovered 2.188" XN plug and Petadat Gauges. 14:50 - 15:00 0.17 EVAL C PROD3 PJSM with slickline crew on RD and the hazards associated with such a task 15:00 - 16:00 1.00 EVAL C PROD3 RD slickline 16:00 - 18:00 2.00 EVAL C PROD3 RU to run Whipstock. Close SSSV and try and bleed down well above 2,250 ftWHP = 0 psi, some gas still venting from wellbore. 18:00 - 21:15 3.25 STWHIP C PROD4 Crew change. Hold PJSM to discuss deployment. Deploy whipstock and setting BHA. Had to use an extra three ft lubricator section to cover whipstock tools. WHP: 0 psi (SSSV is closed). 21:15 - 23:30 2.25 STWHIP C PROD4 RIH to 210'. Open EDC. Pressure well to 300 psi and pump open EDC. WHP: 15 psi. Continue to RIH at 75 fpm. Slow down at SSSV and GLMs. Continue in the hole. 23:30 - 00:00 0.50 STWHIP C PROD4 Log gr tie in from 8919'. Subtract 2' correction. 8/20/2006 00:00 - 00:30 0.50 STWHIP C PROD4 27.5k# up, 19k# do wt. Close EDC. Tay oriented to high side. Pressure coil to 2600 psi, pkr set and shear released. Set down 1.5k#. Packer appears to be set. Pull up hole to 8900. Open EDC. Top of whipstock at 8936'. Pkr tbg tail at 8959'. 00:30 - 01:30 1.00 STWHIP C PROD4 Displace coil annulus with KCL. 2450 psi at 2.48 bpm. Pull out of hole taking returns through ASRC to LPC. 01:30 - 02:30 1.00 STWHIP C PROD4 Park coil at 2533'. Continue to circulate. RU bleed line from IA Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Start: 7/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ; NPT Phase 8/20/2006 01:30 - 02:30 1.00 ~ STWHIP C ~ PROD4 02:30 - 04:00 1.50 STWHIP C PROD4 04:00 - 04:45 0.75 STWHIP C PROD4 04:45 - 08:30 3.75 STWHIP C PROD4 08:30 - 10:10 1.67 STWHIP C PROD4 10:10 - 10:20 0.17 STWHIP C PROD4 10:20 - 10:40 0.33 STWHIP C PROD4 10:40 - 17:30 I 6.831 STWHIPIC I IPROD4 17:30 - 22:00 I 4.501 STWHIPI C I I PROD4 22:00 - 22:45 I 0.751 STWHIPI C I I PROD4 22:45 - 23:30 0.75 STWHIP C PROD4 23:30 - 00:00 0.50 STWHIP C PROD4 8/21/2006 100:00 - 02:00 I 2.001 STWHIPIC I I PROD4 02:00 - 03:15 1.25 STWHIP C PROD4 03:15 - 04:00 0.75 STWHIP C PROD4 04:00 - 06:30 2.50 BOPSU C PROD4 06:30 - 14:00 7.50 BOPSU C PROD4 14:00 - 19:30 I 5.501 BOPSUpC I PROD4 19:30 - 21:45 I 2.251 DRILL I C I I PROD4 21:45 - 22:15 I 0.501 DRILL I C I I PROD4 Page 22 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations to separator flow line. Bleed down IA to 300 psi. Test packer to 1000 psi WHP. Ok. Flow check well. Resume pulling out of hole. Hold PJSM. Tag up BHA. Get off well. Unstab coil. LD tools. Rig up to reverse circulate through coil. Rig up hydraulic cutter. Cut off 62' of coil. (14, 902 ft CT on reel) Cut 4 ft wire (15, 238 ft wire left @ 97%) Installed CTC (without no/go) and pull tested to 37k OK. BHI Behead CTC and UOC RIH to 200 ft, open EDC RIH cir at 1.50 bpm Tie in at 8900 ft (+ 6 ft correction) Close EDC RIH and tag TOW at 8,935.8 ft Op = 2.58 bpm at 3083 psi off bottom Milling window as per BOT SOP's from 8935.8 ft to 8942.7 ft (6.90 ft) Op = 2.58 bpm at 3,080 / 3215 psi off bottom. Vp = 215 bbls 0.1 ft/ 6 min. Milling window as per SOPs. Mill from 8943.4 to 3379 psi at 2.58 bpm. DHWOB: 4-5k# Continue milling. ECD and BHP are fluctuating. Don't know why. Pick up. Up wt and do wt normal. Continue to mill ahead. Pit volume is constant. WOB is steady. Drill 10' of formation. Dress window by reaming at 1 fpm up and down for several passes. Continue to dress window. Make several up and down passes reaming window. Take biozan fluid outside to tiger tank. Dry drift. Slight bobble running in at 8943'. Call it good. Complete displacement to KCL water. Open EDC. TOW 8935.8 ft RA Marker 8944.4 ft BOW = 8946.8 ft These numbers will be corrected if need-be following the build section Circulate out of hole. Hold PJSM for laying down BHA. At surtace. Get off well. Unstab coil. Lay down BHA. Rig up and service master and two swab valves. Perform bi-weekly BOP equipment test. Recorded all tested intervals on SLB's Coil computer system and bartong recorder chart. Wittness waived by J. Jones, AOGCC but witnessed by BP WSL. Check Valve on BOP kill side failed test. PJSM ,repaired check valves and re test, check precharge on N2 bottle and conduct accumulator drawdown test. RD PT equipment. Behead BHI CTC and tested and tested inner reel valve. Help N2 Hazid mtg at rig. Documented my P. Brand w/ Blade. Run in hole. Bring on GL at 2.44 mmscfd. Slowly increase gas to 4.5. Log gr tie in from 8900'. Add 1' correction. Close EDC. Orient to HS TF. Gas in =gas out (+/- 4.5 mmscfd) Well appears to be stable. GLT pressure spikes. indicate that 5 GLMs opened on trip in. Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 23 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours ( Task !Code' NPT ~ Phase Description of Operations 8/21/2006 (22:15 - 00:00 ~ 1.75 ~ DRILL (C ~ ~ PROD4 Drill ahead from 8957. 270 psi fs at 1.52 bpm in. DHWOB: 8/22/2006 100:00 - 03:00 I 3.001 DRILL C 03:00 - 04:00 I 1.001 DRILL I C 04:00 - 04:30 I 0.501 DRILL I X 04:30 - 06:21 I 1.851 DRILL I C 06:21 - 06:50 I 0.481 DRILL I C 06:50 - 07:10 I 0.331 DRILL IX 07:10 - 07:30 0.33 DRILL X 07:30 - 07:45 0.25 DRILL C 07:45 - 08:45 1.00 DRILL C 08:45 - 10:45 I 2.00 I DRILL I C 10:45 - 12:30 1.75 DRILL C 12:30 - 13:30 1.00 DRILL C 13:30 - 15:30 2.00 DRILL C 15:30 - 15:45 0.25 DRILL C 15:45 - 18:30 2.75 DRILL C 18:30 - 19:00 1 0.501 DRILL I C 1.5-2.5k# Gas in/out: 4.40 to 3.35-4.65 mmscfd. Drill ahead with HS toolface. WHP/BHP/ECD: 742/3006/6.48 ppg IA/OA/PVT: 2090/65/197 bbls. Confirm that RA tag is at 8944'. PROD4 Continue to drill build section. ASRC choke and heater bypassed. WHP/BHP/ECD: 644/3045/6.54 ppg. Gas in/out: 4.32/4.10 mmscfd. TF: 35L. ROP: 20-40 fph. DHWOB: 3-4.5k#. 360 psi at 1.5 bpm in. No "keeper" surveys yet, but minimum dog leg rate appears to be 46 deg/100. PROD4 Drill ahead from 9037'. 373 psi at 1.48 bpm. DHWOB: 1.5-2.5k#. WHP/BHP/ECD: 662/3244/7.15 ppg. Gas in/out: 4.23/4.14 mmscfd. PROD4 Pull into casing and circulate. Revise directional plan with Town team. PROD4 Drill ahead from 9057'. Increase turn to left as build is ahead of schedule. TF:60L. PROD4 Drilling build section in Wahoo 5.3 HS TF Landing target = 8,766 ft at 88 deg hole angle Geological challenging at this point. Op = 1.51 / 1.51 bpm CTP - 600 psi on btm FBHP/WHP = 3300 / 666 psi Og(in/out) = 4.40 / 4.15 mmcf/day W OB / ROP = 0.5 to 1.00 k / 23-30 fph PROD4 PUH and revise directional plan with town geologist. Closed in well and pulled bit above whipstock at 8,936 ft. PROD4 Open EDC and circulate waiting on revised geological plan. PROD4 RIH and land at 8767 ft at 90 deg and finish out turn PROD4 Drilling build section in Wahoo 5.3/PU3 90L TF Land at 90 deg and put TF into all turn Op = 1.51 / 1.39 bpm Well unstable in annulus CTP - 600 psi on btm FBHP/WHP = 3450 / 674 psi Og(in/out) = 4.40 / 4.25 mmcf/day WOB/ROP=0.5to2.Ok/ 40 fph PROD4 POOH, SW I at 8,960 ft to pass through window area. Open EDC POOH. At 700 ft reduced Ogl to 1 mmcf/day and bring WHP to 1100 psi to 1200 psi. PROD4 OOH, Pressure undeploy BHA WHP at 770 psi. Bit graded 1-1-I. PROD4 MU HTC re-build bit. Adjust motor to 1.0 deg. Hold PJSM. Pressure deploy BHA with 1102 psi. PROD4 Run in hole. Check SSSV. Continue to RIH. Initial Gas rate in: 2.37mmscfd. Circ at min rate through EDC. PROD4 Log gr tie in from 8900'. No correction. Shut in well. Close EDC. PROD4 RIH tag btm at 9150. Build smooth. Drill ahead. 270 psi fs at 1.6 bpm in. Gas in/out: 3.51/3.33 mmscfd. DHW06:1-3k#. WHP/BHP/ECD: 637/3204/7.03 PPg• PROD4 Wiper to window, clean Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 24 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/22/2006 119:00 - 20:30 I 1.501 DRILL I C I I PROD4 20:30 - 21:00 I 0.501 DRILL I C I I PROD4 21:00 - 22:50 I 1.831 DRILL I C I ! PROD4 22:50 - 23:25 0.58 DRILL C PROD4 23:25 - 00:00 0.58 DRILL C PROD4 8/23/2006 100:00 - 01:00 I 1.001 DRILL I C I I PROD4 01:00 - 01:40 0.67 DRILL C PROD4 01:40 - 01:50 0.17 DRILL C PROD4 01:50 - 02:20 0.50 DRILL C PROD4 02:20 - 04:10 1.83 DRILL C PROD4 04:10 - 04:55 0.75 DRILL C PROD4 04:55 - 06:30 1.58 DRILL C PROD4 06:30 - 07:15 I 0.751 DRILL I P I I PROD4 07:15 - 10:30 I 3.251 DRILL I P I I PROD4 10:30 - 11:30 I 1.001 DRILL I P I I PROD4 11:30 - 13:15 I 1.751 DRILL I P I I PROD4 13:15 - 15:30 2.25 DRILL P PROD4 15:30 - 17:00 1.50 DRILL P PROD4 17:00 - 18:30 1.50 BOPSU P PROD4 18:30 - 20:15 ~ 1.75 ~ DRILL ~ P ~ ~ PROD4 Drill from 9250' 1.52/380/90L w/ 650 psi whp on FO choke w/ 3100-3250 psi DHP W iper to window, clean Reboot SWS PC Drill from 9350' 1.62/610/110L w/ 640 psi whp on FO choke w/ 3100-3150 psi DHP (6.82 ECD) at 4.0 MMSCFD/2140 psi at 50-70'/hr at 91 deg in 12 api rock Wiper to window, clean Drill from 9450' 1.65/620/120L w/ 640 psi whp on FO choke w/ 3100-3150 psi DHP at 4.0 mmscfd Drill from 9486' 1.6/600 and started getting extra gas back. Reduce GLG rate from 4.0 mmscfd to zero in 40 min while pinching back choke from 128/64 to 40/64" over the same time. BHP got as low as 2800 psi. Drill ahead at 1.63/270 while swap to right side at 9500'. Appears well is producing about 2.70 mmscfd gas w/ trace of oil from 9400-9450'. Start adding GLG after BHP starts to rise. Drill to 9550' while continuing at 93 deg Wiper to window, clean. Wiper to above btm GLM. RBIH Log tie-in down from 8900', corr +1.5' W iper to TD, clean Drill from 9550' 1.5/400/908 at 93 deg w/ 760 psi whp on 32/64" choke w/ 3.6 mmscfd GLG at 2090 psi w/ 3000-3150 psi DHP getting sli less water back than pumped w/ tr slugs of oil (23 bbls in 4 hrs). Slowly open choke to maintain 3100 psi bhp, now at 96/64" Wiper to window, clean Drill from 9650' 1.6/600/1208 at 93 deg w/ 635 psi whp on 128/64" choke w/ 3.65 mmscfd GLG at 2110 psi w/ 3100-3150 psi DHP while still losing <0.1 bpm fluid w/ no oil. Get back into 12 api rock at 9620' Wiper trip to window. Reduce pump rate through mudstone at 9010'. Run in hole, smooth in both directions. Drill ahead. 337 psi at 1.53 in/1.1 out. DHWOB: 1.0-2.5k#. WHP/BHP/ECD: 635/3166/6.97 ppg. IA/OA: 2092/85. Gas in/out: 3.90/3.73 mmscfd. Choke: variable to maintain target BHP, but mostly wide open. Apparently in a hard spot. Wiper trip to window. 28.6k# up wt off btm. Hole smooth. Eliminate J-313 in KCL water. Continue with Safe-tube. Drill ahead to 9930. Drilled fast for a while, after short trip, then slowed again. Getting 3.5k# DHWOB and 350 psi motor work. May be on a hard spot. Bit has 780' on it. Decide to trip for agitator and bit change. Circulate out of hole. Maintain 3000-3200 psi BHP. PJSM. Tag up at surface. Pressure undeploy BHA. Flow well at 1.5 mmscfd GLG w/ 1200 psi whp on 20/64" choke w/ slugging returns of mostly water and 2.0 mmscfd extra gas Remove and replace 3" kill line hose due to bubbles on external cover Change bit, motor and add agitator. BHI replace upper check valves. MU BHA and pressure deploy Continue flowing well and gas rate is increasing. By 1930 hrs well is (not stable, but) flowing 0.75 bpm oil, <0.2 bpm water Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 25 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task Code i NPT Phase ' Description of Operations 8/23/2006 ~ 18:30 - 20:15 ~ 1.75 DRILL P ~ PROD4 20:15 - 22:00 I 1.751 DRILL I P I I PROD4 22:00 - 22:15 0.25 DRILL P PROD4 22:15 - 22:50 0.58 DRILL P PROD4 22:50 - 00:00 I 1.171 DRILL I P I I PROD4 8/24/2006 100:00 - 04:15 I 4.251 DRILL I P I I PROD4 04:15 -.04:45 0.50 DRILL P PROD4 04:45 - 06:15 1.50 DRILL P PROD4 06:15 - 06:30 0.25 DRILL P PROD4 06:30 - 07:30 1.00 DRILL P PROD4 07:30 - 09:00 I 1.501 DRILL I P I I PROD4 09:00 - 10:45 1.75 DRILL P PROD4 10:45 - 11:00 0.25 DRILL P PROD4 11:00 - 11:40 0.67 DRILL P PROD4 11:40 - 16:00 4.33 DRILL P PROD4 16:00 - 18:15 I 2.251 DRILL I P I I PROD4 18:15 - 18:30 0.25 DRILL P PROD4 18:30 - 20:20 1.83 DRILL P PROD4 20:20 - 20:35 0.25 DRILL P PROD4 20:35 - 22:55 2.33 DRILL P PROD4 and 4.5-7 mmscfd gas at 1200 psi at 30/64" choke so SI the GLG. By 2015 hrs well was stabilizing at 0.3 bpm oil, 0.1 bpm water w/ 3.5 mmscfd gas at 1180 psi whp on 30/64" choke RIH w/ BHA #33. Pump test agitator at 500', okay. RIH circ thru bit at 0.3/950 while flowing well at previous parameters. Open up to GLG at 5000' Geo's advise that the TD of well is being revised from the original program depth of 10470' to 10818' and give target point of 10300'/8757' TVD at 87 deg Log tie-in down from 8900', corr -6' RIH thru window, clean. W Iper to TD was clean to tag at 9920' Drill from 9920' 1.5/900/125L at 90 deg w/ 1000 psi whp on 36/64" choke w/ 3.5 mmscfd GLG at 2080 psi w/ 3000-3150 psi DHP. Open choke and lower whp as wellbore loads up w/ fluid. Drill at slow penetration rate (still hard) while drop angle to 87 deg Drill from 9956' 1.5/800/110L w/ 650 psi whp on 80/64" choke w/ 3.25 mmscfd C~? 2050 psi w/ 3050-3150 psi dhp at 87 deg w/ very slow penetration rate. Had nearly full returns of fluid and gas and up to 0.1 bpm oil. Drill to 9964' w/ no progress over the last 2 hrs Wiper to window POOH for bit Close EDC. Flow test agitator at 500'. (OK) Tag up at surface. PJSM. Pressure undeploy BHA. WHP: 1150 psi. HTC bit had several small chips and flat wear spots on nose cutters. MU a HYC bi center on 1.0 deg X-treme mtr with agitator (s/n: AS-218-41-114). Pressure deploy with 1160 psi WHP. RIH to 200'. Open EDC. Run in hole circulating at 0.5 bpm. Log GR tie in from 8900'. Run through window. Close EDC. RIH to btm. Tag at 9968'. Drill ahead from 9968'. 838 psi fs at 1.53 in/1.5 out. DHWOB: 3.5 - 4.5k#. Gas in/out: 4.5/4.5 mmscfd. WHP/BHP/ECD: 685/3150/6.9 ppg. Some slugging. Adjust choke to compensate. Drill from 9968' to 9974' at 25-30 fph. ROP then dropped to near zero. Weight transfer appears to be good. Discuss with Town. Decide to pull out of hole for CRX 2.75" bit. Open EDC once above window. Adjust flow out as per schedule to maintain BHP. Shut off gas at 1000'. SI at seperator w/ initial 640 psi Safety mtg/crew change Pressure undeploy BHA LD BHA. Found bit had many chipped/broken cutters and was tracking on the nose. Also, had one plugged (w/ stator rubber) nozzle. LD motor Safety mtg re: pressure deploy w/ 830 psi MU BHA w/ new 2.73" HYC CRXE bit, used motor w/o agitator. BHI change upper checks. Pressure deploy w/ final 1020 psi w/ well SI at seperator Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 26 of 33 Operations .Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours i Task ~ Code NPT 8/24/2006 22:55 - 00:00 1.08 DRILL P 8/25/2006 00:00 - 00:25 0.42 DRILL N 00:25 - 01:00 0.58 DRILL P 01:00 - 01:15 0.25 DRILL P 01:15 - 01:50 0.58 DRILL P 01:50 - 04:30 2.67 DRILL P 04:30 - 09:00 4.50 DRILL P 09:00 - 12:00 3.00 DRILL P 12:00 - 14:15 2.25 DRILL P 14:15 - 15:15 1.00 DRILL P 15:15 - 16:45 1.50 DRILL P 16:45 - 19:00 2.25 DRILL P 19:00 - 19:15 0.25 DRILL P 19:15 - 19:40 0.42 DRILL P 19:40 - 23:50 4.17 DRILL P 23:50 - 00:00 0.17 DRILL P 8/26/2006 00:00 - 01:15 1.25 DRILL P Spud Date: 5!12/2006 Start: 7/27/2006 End: 9/1 /2006 Rig Release: 9/1 /2006 Rig Number: Phase Description of Operations PROD4 RIH w/ BHA #35. Had trouble getting started in hole due to 1000 psi whp. Open EDC at 200'. RIH circ 1.5/1060 after open well to flow. Adjust choke to maintain avg 950 psi whp w/ 3.0 mmscfd to match equiv 3100 psi bhp PROD4 Park at 4500' and replace one bearing on injector chain PROD4 Continue RIH 1.5/350 circ thru EDC w/ 3.0 mmscfd adjusting choke at avg 900 psi to maintain 3100 psi bhp PROD4 Log tie-in down from 8910', corr -1.5' PROD4 Wiper to TD was clean. Precautionary ream from 9950' to TD tagged at 9970.5' PROD4 Break in bit w/ max 1.5k wob for 30 min-still hard. Drill ahead from 9971' very slowly 1.5/320/100L w/ 650 psi whp on FO choke at 3.6 mmscfd ~ 2090 psi w/ 3100 psi dhp using 2.2k wob max. Still hard, but drills off slowly PROD4 Drill ahead from 9974'. 700 psi fs at 1.74 in/var out. DHWOB: 1.5-2.5k#. WHP/BHP.ECD: 652/3250/7.16 ppg. Gas in/out: 4.22/var out. Choke is full open. Continue to get a lot of foam, which is affecting gas and liquid out rates. Adding de-foamer with ASRC at increasing rates. This in not helping. Call Hot Water Plant and cut the amount of J-313 in half. Not able to get more than 2.5k# DHWOB. This is hlaf of the 5.04# we were able to get with the agitator in the hole on previous run. Pump a 7 bbl mineral oil sweep. PROD4 Drill ahead from 10005'. ROP improving. Foam dissappeared after pumping mineral oil sweep. ROP is consistently increasing. Projected TVD is 8944'. Should be "below" chert, but will stick with this bit a while longer. Inc: 84.5 TVD: 8946'. SHould be well below chert based on TVD. ROP still low, 6-8 fph. PROD4 Wiper trip back to window. Circulate out of hole following TVD/press schedule. Reduce gas in to 1.5 mmscf once inside tbg. Shut off gasand fluid at 3000'. PJSM at 2000'. Tag up. Space out. PROD4 Undeploy BHA. Change out motor and bit. WHP: 943 psi. Hycalog CRX (concentric reamer) bit graded 3-1-I. One nose cutter had half of face diamond sheared off. Rest of cutters looked good. PROD4 MU lateral drilling assembly (new 1.0 deg x-treme with Hycalog rebuild bi-center bit, agitator s/n: AS-218-41-114). WHP: 960 psi. PROD4 Pressure deploy BHA. RIH to 200'. Test agitator. Ok. Open EDC. Continue to run in hole circulating at 1.6 bpm. Generator #1 is down-CAT man on location. Using #2 and #3 when drilling PROD4 Log tie-in down from 8910', corr -2.5' PROD4 Wiper to TD tagged at 10038' was clean PROD4 Drill from 10038' 1.54/1250/10L and level out to intersect 10300' target at 8757' TVD w/ 650 psi whp on FO choke w/ 3.6 mmscfd C~ 2080 psi maintaining 3100-3200 psi dhp. Break in bit, then drill at avg 30+'/hr to 10140' where penetration rate picked up to 60'/hr PROD4 Wiper to window PROD4 Wiper to window was clean. See 0.9 mmscfd increase in gas Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: L5-16 L5-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/27/2006 Rig Release: 9h /2006 Rig Number: Date From - To Hours Task Code j NPT Phase i 8/26/2006 00:00 - 01:15 1.25 DRILL P PROD4 01:15 - 03:20 2.08 DRILL P PROD4 03:20 - 03:45 I 0.421 DRILL I P I I PROD4 03:45 - 04:45 1.00 DRILL P PROD4 04:45 - 05:10 0.42 DRILL P PROD4 05:10 - 05:55 0.75 DRILL P PROD4 05:55 - 08:00 2.08 DRILL P PROD4 08:00 - 09:30 1 1.501 DRILL I P I I PROD4 09:30 - 12:15 I 2.751 DRILL I P I I PROD4 12:15 - 14:15 2.00 DRILL P PROD4 14:15 - 16:30 2.25 DRILL P PROD4 16:30 - 18:45 I 2.251 DRILL I P I I PROD4 18:45 - 19:30 0.751 DRILL ~ P PROD4 19:30 - 21:45 2.25 DRILL P PROD4 21:45 - 23:45 2.00 DRILL N SFAL PROD4 Page 27 of 33 Spud Date: 5/12/2006 End: 9/1 /2006 Description of Operations returns and 0.3 bpm water after back at TD Drill from 10190' (8753' TVD) 1.54/850/908 w/ 690 psi whp on FO choke w/ 3.75 mmscfd ~ 2100 psi w/ 3000-3200 psi dhp while drilling at 87 deg and 60+'/hr. Drill into higher penetration rate areas at 10230', 10250', 10265' and had corresponding increase in gas. BHP decreased to 2960 psi and were getting extra 2.0 mmscfd, 0.7 bpm water and 0.1 bpm oil. Close choke to incr dhp Drill from 10275' 1.5/600/1208 while red glg to 1.5 mmscfd and further reduce choke to 44/128" after dhp got as low as 2875 psi. Drill to 10285' and need to geohuddle W iper to window while geodecide Log tie-in down from 8910', corr +3' Wiper back to TD. Hole smooth. Drill ahead from 10,285'. 1050 psi fs at 1.62 in/out. DHWOB: 3k#. Gas in/out: 3.2/var. WHP/BHP/ECD: 634/3165/6.95 ppg. Choke full open. ROP: 30-50 fph. TF low side to begin rapid drop towards W5.2, across fault zone. Angle slow to drop, then took off. Projection at bit: 79 deg incl. Make wiper trip to window to allow extended discussion of directional plan forward. Decide to hold 79 deg until additional GR correlations can be made. Hole very smooth. Drill ahead from 10,384' to 10,500'. 1070 psi fs at 1.69 in. Hold 79 deg inc. Pass through a few GR markers. Looks like we are in the W5.3. Increase incl to 84-85 deg to continue drop through W5.3 towards a landing in W5.2. Gas from formation is increasing, particularly when BHP drops below 3100 psi. Reduce injected gas to 3.0 mmscf. Wiper trip to window. Hole smooth in both directions. Drill ahead from 10,500'. 1000 psi fs at 1.52 in/out. DHWOB: 1.5 to 2.5k#. WHP/BHP/ECD: 790/3050/6.78 ppg. Gas in/out: 3.17/5.83 mmscfd. Holding incl at 83 to 85 deg. ROP: 30-50 fph. Getting some emulsion in rtns. ROP has dropped to zero, even with 4k# DHWOB. Pump a 5 bbls min oil sweep. No improvement. Wiper trip to window. Open EDC. Circulate out of hole. Suspect a bit or motor problem. 28k# up weight near bottom. At 3000' and w/ GLG shut off, had 16 mmscfd returns on FO choke. Begin pinching choke back, but too late Park at 200' and circ 1.7/1800 thru EDC. Well is flowing 13.2 mmscfd on 50/128" choke at 1380 psi. SI well at ASRC. Bullhead 50 bbls KCI thru EDC w/ max inj press 1.7/2700 w/ 1610 psi whp and FIP 1.7/2150 w/ 1100 psi whp. SD pump, close EDC, close TRSSSV. Fin POOH/safety mtg. Tag up w/ 990 psi whp Pressure undeploy w/ 987 psi whp. Bit was micro dulled 2-1-I Prep to pressure deploy w/ 1027 psi whp. Found gen #3 not putting out voltage after being taken down for an oil change during the BHA swap. Since gen #1 is also down for major repairs, and two gensets are needed to drill, elected to wait at Printed: 9/5/2006 11:09:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/26/2006 ~ 21:45 - 23:45 23:45 - 00:00 8/27/2006 00:00 - 01:30 01:30 - 03:35 03:35 - 03:55 03:55 - 04:50 04:50 - 05:20 05:20 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 11:15 11:15 - 13:00 13:00 - 14:45 14:45 - 15:45 15:45 - 18:20 18:20 - 19:45 19:45 - 21:35 21:35 - 00:00 BP EXPLORATION Operations Summary Report L5-16 L5-16 REENTER+COMPLETE Start: 7/27/2006 NORDIC CALISTA Rig Release: 9/1/2006 NORDIC 2 Rig Number: Hours I Task I Code' NPT I Phase Page 28 of 33 Spud Date: 5/12/2006 End: 9/1/2006 Description of Operations 2.00 DRILL N SEAL PROD4 surface for electrician to arrive and investigate the problem. Found and repaired a bad PWM (voltage regulator). Test generator alone SWS inspecUservice injector chain and replace one bearing 0.25 DRILL P PROD4 Safety mtg re: pressure deploy w/ 1078 psi 1.50 DRILL P PROD4 MU drilling BHA and pressure deploy w/ 1075 psi 2.08 DRILL P PROD4 RIH w/ BHA #37 to 200' w/ 1068 psi whp. Chk agitator, open EDC, pump thru EDC 1.5/2000, RIH, open TRSSSV w/ 1130 psi whp. Open well to flow on 64/128" choke thru heater. Start GLG at 2.5 mmscfd, but shut that down at 2000' after 6.0 mmscfd is coming back. Incr pump to 1.7/2000 and pinch choke to 50/128" holding 1700 psi initial whp while RIH 0.33 DRILL P PROD4 Log tie-in down at 8910', corr 0.5'. Close EDC 0.92 DRILL P PROD4 Wiper to TD 1.6/980 holding 1000 psi whp to achieve 3000 psi dhp 0.50 DRILL P PROD4 Drill from tag at 10532' 1.64/1100/95L w/ 820 psi whp on 80/128" choke w/o glg and returning 4.9 mmscfd to maintain 3050-3100 psi dhp. Drill at 85 deg at 50-70'/hr after break-in of bit to 10550' 1.17 DRILL P PROD4 Slow wiper while geohuddle. GR change at 10510' was unexpected 1.00 DRILL P PROD4 Drill ahead from 10,550'. 1200 psi fs at 1.71 in/out. DHWOB: 3-4k#. WHP/BHP/ECD: 856/3056/6.70 ppg. ROP: 20-40 fph. Incl: 83 deg. Gas in/out: 0/4.24 mmscfd. Occasional slugs of oil out. No foam. Taking rtns through ASRC heater to treat minor emulsion from downhole. 1.00 DRILL P PROD4 Short wiper trip for geohuddle with town. 2.75 DRILL P PROD4 Drill ahead from 10,550'. Seeing a lot of down hole vibration. Reduce pump rate from 1.75 to 1.45 bpm. Vibration reduced. ROP slowing. May be on a hard spot. Pump 5 bbls mineral oil pill. ROP and weight transfer improved with mineral oil, indicating this is not just a hard spot. 1.75 DRILL P PROD4 Wiper trip to window. Hole smooth. 1.75 DRILL N PROD4 Hot water plant has shut down. Trucks diverted to MI plant for KCL. Pull back into casing circulating at minimum rate. Pit volume: 170 bbls at 1315 hrs. 1.00 DRILL P PROD4 Fluid has arrived from MI. Run back in hole circulating at 1.47 bpm. 2.58 DRILL P PROD4 Drill ahead from 10,650'. ROP 30-40 fph for 20', then weight transfer deteriorated again. Work pipe. Pump 5 bbl min oil sweep. 1.42 DRILL P PROD4 Drill from 10750' 1.55/1800/1208 holding 89 deg w/ 900 psi whp on FO choke w/ glg off, but returning 8 mmscfd while holding 3050 psi dhp. Seeing occasional steady oil up to 0.4 bpm, but avg is 0.25 bpm. Water has increased too and is about 0.3 bpm avg which is verified by a BHT of 187E and increasing. Pump 7 bbls mineral oil and not much help on wt transfer 1.83 DRILL P PROD4 Wiper to window was clean both directions 2.42 DRILL P PROD4 Drill from 10785' w/ better weight transfer. Geosteered to hold 92 deg (following the dip) and then found the sweet spot at 10845'. Penetration rate incr to 90'/hr and went from neg string wt to 11.5k w/ 0.5k wob. With a stabilized 3050 psi dhp, the Printed: 9/5/2006 11:09:23 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/27!2006 Rig Release: 9/1/2006 Rig Number: Date !From - To Hours Task Code NPT Phase ~ -- _- 8/27/2006 21:35 - 00:00 2.42 DRILL P PROD4 8/28/2006 00:00 - 00:20 0.33 DRILL P PROD4 00:20 - 01:20 1.00 DRILL P PROD4 01:20 - 01:45 0.42 DRILL P PROD4 01:45 - 02:55 1.17 DRILL P PROD4 02:55 - 04:30 I 1.581 DRILL I P I I PROD4 04:30 - 06:30 2.00 DRILL P PROD4 06:30 - 08:45 2.25 DRILL P PROD4 08:45 - 11:15 I 2.501 DRILL I P I I PROD4 11:15 - 16:00 I 4.751 DRILL I P I I PROD4 16:00 - 18:15 ~ 2.25 ~ DRILL ~ P ~ ~ PROD4 18:15 - 20:30 I 2.251 DRILL I P I I PROD4 20:30 - 21:30 I 1.001 DRILL I P I I PROD4 21:30 - 00:00 2.50 DRILL P PROD4 8/29/2006 00:00 - 00:20 0.33 DRILL P PROD4 00:20 - 03:30 3.171 DRILL P I PROD4 03:30 - 05:20 I 1.831 DRILL I P I I PROD4 Page 29 of 33 Spud Date: 5/12/2006 End: 9/1/2006 Description of Operations well is making 7.1 mmscfd, 0.2 bpm H2O, 0.25 bpm oil Drill from 10915' to 10935' while pump 7 bbl mineral oil pill W iper to window, clean. Used glg assist Log tie-in down from 8910', tort 3.0' Wiper to TD tagged at 10935' was clean Geocision-will follow dip and stay in sweet drilling spot of W5.3 until 11100' Drill from 10935' 1.55/860/1058 and continue to follow the dip at 92+ deg w/ 860 psi whp on FO choke w/o glg. Well is making avg 7.3 mmscfd, 0.25 bpm H2O, 0.25 bpm oil at 3050-3100 dhp. Pump 7 bbls mineral oil pill. Drill to 11038' W iper to window. Hole smooth. Drill ahead from 11,038'. 1400 psi fs at 1.52 bpm in/out. DHWOB: <1k#. WHP/BHP/ECD: 84313046/6.68 ppg. Gas in/out: 0.0/6.9 mmscfd. Intl: 88.6. Wiper trip to window. Bring on 3.6 mmscfd gas to help clean. hole. Shut off gas when not needed. Hole smooth in both directions. 29k# up wt, 11 k# do wt near bottom. Drill ahead from 11,150. TF pointed straight down as per Town Team. 1020 psi fs at 1.52 bpm in/out. DHWOB: 0.3 to 1.9k#. Gas in/out: 0/8.42 mmscfd. WHP/BHP/ECD: 904/3077/6.77 ppg. Increase safelube concentration from 0.4% to 1.3% (three drums per vac truck load (165 gal safelube per 290 bbls kcl)) Pumped a few mineral oil sweeps. Weight transfer still erratic, but seems to have improved overall. ROP varying from 30 to 60 fph. Wiper trip to window, clean. Used glg to avoid killing well and to help lift cuttings Drill from 11300' 1.6/1100/5L attempting to head back up in the W5.2 w/ 820 psi whp on FO choke holding avg 3100 psi dhp w/ the well making 6.2 mmscfd, 0.35 bpm water, 0.1 bpm oil. Back into 12 api rock at 11290' and drilling 40-60'!hr and can't get above 90 deg at bit w/ TF straight up Drill from 11373' at 15'/hr. Started seeing an increase in gas from the last 70' of hole drilled. Also, BHI started seeing an increase in tool vibration. Pumped a 5 bbl mineral oil pill and did a mini wiper as pill exited bit. Then, couldn't get back to TD of 11388'- had zero string wt Wiper to window was clean. Used glg as before Finish wiper to TD tagged at 11388'. Last 200' lost a bunch of string wt, but got bit to bottom and started drilling w/ 1.67k wob and 5k positive surface wt. Start 7 bbls mineral oil Drill from 11388' 1.6/1300/10L at 90 deg incl w/ 860 psi whp on FO choke holding 3100 psi dhp. Well stabilized at 7.3 mmscfd, 0.3 bpm H2O, 0.15 bpm oil. Drilled to 11409' and stacked out. Picked up BHA length while wo mineral oil pill to get to bit. Got back to bottom easy, then bit took off at 60'/hr while inclination got bumped from 90 deg to 96 deg. Drilled w/ 1.5k wob, 5k surface wt and 400 psi dill to 11500' where geo's called TD (still drilling at 60'/hr w/ NB incl at 98 deg!) Slow wiper while chase 10 bbl mineral oil pill to bit. Well producing stable at 7.25 mmscfd, 0.25 bpm H2O, 0.3 bpm oil Printed: 9/5/2006 11:09:23 AM • BP EXPLORATION Page 30 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Spud Date: 5/12/2006 Event Name: REENTER+COMPLETE Start: 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 9h /2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/29/2006 ~ 03:30 - 05:20 ~ 1.83 ~ DRILL ~ P ~ ~ PROD4 at 3080 psi dhp 05:20 - 05:50 I 0.501 DRILL I P 05:50 - 11:00 I 5.171 EVAL I P 11:00 - 12:30 I 1.50 f EVAL I P 12:30 - 14:30 I 2.00 I EVAL I P 14:30 - 18:30 ~ 4.00 ~ EVAL ~ P 18:30 - 18:40 0.17 EVAL P 18:40 - 19:30 0.83 STWHIP P 19:30 - 21:00 I 1.501 STWHIPI P 21:00 - 21:20 I 0.331 STWHIPI P 21:20 - 23:00 1.67 STWHIP P 23:00 - 00:00 1.00 BOPSU~j P 8/30/2006 00:00 - 00:30 0.50 BOPSU P 00:30 - 00:45 0.25 STWHIP P 00:45 - 03:00 2.25 STWHIP P 03:00 - 04:55 I 1.921 STWHIPI P 04:55 - 06:15 I 1.331 STWHIPI P 06:15 - 06:35 I 0.331 STWHIPI P 06:35 - 08:45 2.17 STWHIP P 08:45 - 09:05 0.33 STWHIP P Wiper to window PROD4 POOH thru window, open EDC. PUH to lower GLM while jetting. Also, incr glg to start drawdown. RIH, SI ~ CT PROD4 Park at 8914'. Flow well. Target BHP is 2600 psi. L5 operator will put well through L5 separator too, to compare rates. Choke: 54/64ths. WHP: 1445 psi. BHP: 2510 psi. PROD4 Continue well test #1. Qoil: 0.8 bpm, Ogas: 14.4 mmscfd, trace water. BHP: 2430 psi, WHP: 1393 psi, Choke: 54/64ths. PROD4 End test #1 ~ 14.2 mmscfd (declining), <0.1 bpm H2O, 0.75 bpm oil (stable) w/ 1390 psi whp (declining) on +/- 54/64" choke 2350 psi (declining) dhp Begin drawdown to next test point PROD4 Begin test #2 w/ initial target of 2100 psi, but unable to get there. Start test w/ FO choke at 2180 psi dhp (declining slowly) w/ 16.9 mmscfd (declining slowly), <0.1 bpm H2O, 0.95 bpm oil (steady) at 1020 psi whp (declining slowly) PROD4 Final is 16.2 mmscfd, <0.1 bpm H2O, 0.9 bpm oil at 2140 psi dhp w/ 984 psi whp on FO choke PROD4 Open EDC, move CT at 30k. Start ambient diesel pretreated (leftover from earlier drilling operations) w/ EMI776 and corr inhib down CT at 1.83/360. Red choke to 64/64" PROD4 POOH while fin displace wellbore to diesel and maintain 100 psi OB to formation. Close TRSSSV w/ 1500 psi whp PROD4 Park at 200', circ 20 bbls KCI to bit while have safety mtg re: fresh crew/undeploy. Close EDC. POH PROD4 Pressure undeploy w/ 580 psi. PROD4 Function test BOP rams as part of biweekly test. Function and service MV, SV's, WV while BHI reconfigure BHA for next two runs. Vac truck start to empty two uprights of diesel PROD4 Fin service tree valves. MIRU LRS. Continue vac upright diesel tanks PROD4 Safety mtg re: pressure deploy PROD4 MU used 3.80" D331 and 3.79" SR on used motor w/ MWD. Pressure deploy. Change packoff. Inspect CT above CTC, okay PROD4 Have difficulty getting started in hole-injector trips out. RIH w/ BHA #38 pumping 135 deg diesel w/ LRS and circ 1.0/1400 w/ open choke at 550 psi whp. Open TRSSSV w/ 1500 psi whp. Attempt to bleed whp to FL pressure, but getting too much gas. RIH circ 1.5/1500 holding 1300-1600 psi while RIH and continued getting 6 mmscfd gas back while being overbalanced up to 600 psi. RIH to 8940' and was clean PROD4 POOH while circ 1.5/1250 while adjust choke to keep min 200 psi overbalance. Gas slowly declined PROD4 PJSM to discuss undeploying cleanout BHA. Discuss personnel assignments, and task hazards. PROD4 Undeploy BHA #38, cleanout run BHA. PROD4 PJSM Re: deploying drift run BHA. Discussed job assignments, hazards and mitigations. Note -BHI found 3 small pieces of rubber that appear to be from a 1502 hardline seal. Stopped the job. Held discussion with rig, ASRC, and Blade Energy parnters. There is the Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 31 of 33 Operations Summary Report Legal Well Name: L5-16 Common W ell Name: L5-16 Spud Date: 5/12/2006 Event Nam e: REENTE R+COM PLET E Start : 7/27/2006 End: 9/1/2006 Contractor Name: NORDIC CALIST A Rig Release: 9/1/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours i Task Code NPT Phase Description of Operations 8/30/2006 08:45 - 09:05 0.33 STWHIP P PROD4 possibility that this rubber is either from the rig system, or from the LRS/Vac truck system that was used during the clean out run with hot diesel. The plan forward is to PT all rig hardlines and look for leaks during the deployment. All suction lines to rig tank farm will also be checked. 09:05 - 10:30 1.42 STWHIP P PROD4 Deploy BHA #39, dummy whipstock BHA. PT'd all hardlines to 3500 psi. No leaks observed. PT kill line to 2000 psi. No leaks observed. Examine suction 602 lines. No leaks observed. Continue with deployment. 10:30 - 14:10 3.67 STWHIP P PROD4 RIH with drift BHA. Stop at 200', open EDC. RIH to top of TRSSSV. Pressure up WHP to 1700 psi. Open SSSV. RIH pumping thru the whipstock at 0.5 bpm. No problems running in. Ran down to 8900'. POOH. No problems POH. 14:10 - 14:30 0.33 STWHIP P PROD4 PJSM re: undeploying WS drift BHA. 14:30 - 16:00 1.50 STWHIP P PROD4 Undeploy BHA #39, drift BHA. 16:00 - 16:15 0.25 STWHIP P PROD4 PJSM Re: Deploying fishing BHA. 16:15 - 18:00 1.75 STWHIP P PROD4 Deploy BHA #40 to fish whipstock tray. 18:00 - 19:30 1.50 STWHIP P PROD4 RIH with BHA #40 to recover whipstock tray pumping thru EDC 0.2/500 w/ well SI. Open TRSSSV w/ 315 psi 19:30 - 19:45 0.25 STWHIP P PROD4 Log tie-in down from 8910', did not Corr -1' 19:45 - 20:00 0.25 STWHIP P PROD4 29k, 15k Ease in hole to 8942' CTD and latched on first try. PUH w/ 5k, stop and open jars. Pulled free w/ 9k over 20:00 - 21:50 1.83 STWHIP P PROD4 POOH w/ WS while circ 20 bbls KCI and displace w/ diesel to EDC w/ well SI @ max 415 psi 21:50 - 00:00 2.17 STWHIP P PROD4 Pressure undeploy w/ initial 415 psi and final 135 psi. Recovered WS complete. LD fishing tools. Reconfigure MWD assy for stinger run 8/31/2006 00:00 - 03:00 3.00 STWHIP P PROD4 Pressure deploy BTT'snorkel' (stinger) BHA #41. Set MWD tool too high in the pipe-slips the first time. Remove and inspect tool, okay. Reset at normal spot. Bleed IA from 680 psi to 540 using ASRC tiger tank 03:00 - 04:45 1.75 STWHIP P PROD4 RIH w/ BHA #41 w/ 50 psi whp while circ 0.5/200 3 bbls KCL + 30 bbls 2# biozan + 2 bbls KCI and displace to stinger w/ diesel w/ well open to flow 04:45 - 05:10 0.42 STWHIP P PROD4 Tag at 8955' CTD. Incr pump rate to 1.5/700 w/ spacer at nozzle. Jet top of XXN plug w/ pill then chase pill w/ diesel 05:10 - 06:30 1.33 STW HIP P PROD4 POOH w/ stinger assy jetting diesel 06:30 - 06:35 0.08 STWHIP P PROD4 PJSM Re: Undeploying stinger BHA. 06:35 - 08:30 1.92 STWHIP P PROD4 Undeploy stinger BHA. 08:30 - 09:00 0.50 STWHIP P PROD4 PJSM with rig crew and SLB slickline crew. Discuss the hazards of third party opertions on the rig. The slickline crew is instructed that the Nordic driller is the person in charge of the rig and that all operations of rig related equipment such as TRSSSV and swab valves is to be conducted by the rig crew. Lifting operations and overhead loads discussed. 09:00 - 10:30 1.50 STWHIP P PROD4 Rig up SLB slickline unit. 10:30 - 11:00 0.50 STWHIP P PROD4 SLB crew change today. Hold an additional safety meeting with new SLB crew and rig crew. Discuss same issues as above. 11:00 - 12:45 1.75 STWHIP P PROD4 Continue rigging up the SLB slickline unit. 12:45 - 15:30 2.75 STWHIP P PROD4 PT SLB lubricator to 500 psi and 2000 psi. RIH with run #1 to equalize pressure accross X plug in 2-7/8" tubing tail below KB packer for L2 window. Tagged up at 8963' SLM. POOH. Got Printed: 9/5/2006 11:09:23 AM BP EXPLORATION Page 32 of 33 Operations Summary Report Legal Well Name: L5-16 Common Well Name: L5-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 8/31 /2006 12:45 - 15:30 2.75 STW H I P P 15:30-17:40 2.17 STWHIP P 17:40 - 18:45 1.08 STWHIP P 18:45 - 19:00 0.25 STWHIP P 19:00 - 20:00 1.00 STWHIP P 20:00 - 22:10 2.17 STWHIP P 22:10 - 23:00 0.83 STWHIP P 23:00 - 00:00 1.00 WHSUR P 9/1/2006 00:00 - 00:30 0.50 WHSUR P 00:30 - 00:45 0.25 WHSUR P 00:45 - 03:00 2.25 WHSUR P 03:00 - 06:00 3.00 RIGD P 06:00 - 14:30 8.50 RIGD P 14:30 - 14:50 0.33 RIGD P 14:50 - 16:30 1.67 RIGD P 16:30 - 18:00 1.50 RIGD P 18:00 - 21:30 3.50 RIGD P Spud Date: 5/12/2006 Start: 7/27/2006 End: 9/1/2006 Rig Release: 9/1 /2006 Rig Number: Phase Description of Operations PROD4 "ring" on prong, which is a good indication that we equalized pressure accross the X plug. PROD4 MU SL BHA #2, PT to 2000 psi. Good PT. RIH to retrieve X plug. Got good overpull. POOH. Recovered X lock plug and Petredat gauges. PROD4 Pick up Baker guidestock to pipe shed (24'). WO WL crews to XO PROD4 Safety mtg re: MU toolstring PROD4 MU WS assy to WL tool string. Tool string is too long to use SV's so had to bleed pressure off above master first. PT lub ~ 2000 psi Finish load out mud materials PROD4 RIH w/ BTT Guidestock tool w/ eccentric wt bar and set tool in packer GS profile at 8956' SLM. Beat down 4 times to shear pin and left Guidestock as planned. POOH. Bleed off 50 psi whp PROD4 RDMO slickline lub, BOP's and SWS unit Poor timing for slickline work on L5-17 (under reel house) since vac trucks and N2 pumper already set up. Rlg will be gone < 2 days PROD4 Freeze protect tubing w/ 35 bbls ambient diesel at 1.5/70. SI TRSSSV w/ 50 psi. Well was on vac MIRU SWS N2 PROD4 Dry rod TWC and PT at 1000 psi from above Find IA valve was shut. ASRC resume bleeding IA from 500 psi thru jumper and bleed to 200 psi over 3 hrs, then SI PROD4 Safety mtg re: N2 PROD4 Blow down reel w/ N2 (0.5 NPT) and bleed off Load out BHI equipment Begin vac and cleaning pits POST Install internal grapple and PT. Pull CT back to reel and secure.. RD gooseneck off injector. Prep injector for removal from rig for rebuild Begin to depressure ASRC equipment POST Continue depressurizing ASRC equipment. Clean rig pits. Suck back lines to dirty vac truck. Empty tank farm diesel into vac truck and send to wells group for re-use POST PJSM with ASRC hands, boom truck operator and BP WSL re: crane lifts to rig down stairs and walkways for tank farm. Winds 12 mph, gusting to 23 mph, measured by an annamometer from the top of tank farm. Discussed that limits are above maximum by 3 mph, and that a high wind asscessment document is needed. ASRC supervisor, BP WSL, and crane truck operator are in agreement that the lifts can be performed in a safe manner. Lifting plan agreed upon that minimizes risk. Lifts will be made with boom truck parked as close as possible to lifts, and picks made lowering equipment straight to ground with no equipment swings. POST Continue with rig down, lifting operations in progress at ASRC tank farm. POST Lower coil reel onto transport trailer. Continue with rig down. POST Flnish vac pits, cuttings box, ASRC flowback tank Continue to load out trucks w/ rig and ASRC equipment Printed: 9/5/2006 11:09:23 AM by BP Alaska ~ker Hu hes INTE Surve Re art g Q Y //~'~ ~~~~ Company: BP Amoco Date: 8/30/2006 Time: 14:31:00 Page: 1 Field: Lisbume Co-ordinate(NE) Reference: . WeIL L5-16, True North Site: Lis DS 05 Vertical (TVD) Reference: ' 9:16 3/2/1987 00:00 60.0 Welle L5-16 Section (VS) Reference: Well (O.OON,O.OOE,145.62Azi) Wellpath: L5-16A Survey Calculation Method:. Minimum Curvature Db: Orade 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: L5-16 Slot Name: 16 L5-16 Well Position: +N/-S 4778.96 ft Northing: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Easting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Wellpath: LS-16A Drilled From: L5-16 Tie-on Depth: 9073.95 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/16/2006 Declination: 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 0.00 145.62 Survey Program for Definitive Wellpath Date: 5/16/2006 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 60.00 9073.95 1 : Schlumberger GCT multi shot GCT-MS Schlumberger GCT multishot 9097.00 10875.00 MWD (9097.00-10875.00) MWD MWD -Standard Annotation MD TVD ft ft 9073.95 8852.61 TIP 9097.00 8873.83 KOP 10875.00 8974.54 TD Survey: MWD Start Date: 8/1/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD ft Inch deg Azim deg TVD ft Sys TVD ft N/5 ft E/W ft, MapN ft MapE ft VS ft DLS Toot- degJ100ft 9073.95 22.87 128.27 8852.61 8792.61 -581.32 1038.71 5974369.40 718501.59 1066.29 0.00 MWD 9097.00 23.02 128.57 8873.83 8813.83 -586.91 1045.75 5974364.03 718508.79 1074.87 0.83 MWD 9130.75 30.04 128.00 8904.01 8844.01 -596.23 1057.59 5974355.05 718520.88 1089.25 20.81 MWD 9160.19 46.04 125.50 8927.12 8867.12 -607.00 1072.11 5974344.71 718535.72 1106.33 54.59 MWD 9190.85 62.18 122.98 8945.04 8885.04 -620.88 1092.61 5974331.43 718556.61 1129.36 53.05 MWD 9220.74 77.85 118.53 8955.23 8895.23 -635.15 1116.69 5974317.87 718581.09 1154.74 54.24 MWD 9250.33 94.10 123.09 8957.30 8897.30 -650.22 1141.95 5974303.53 718606.77 1181.44 57.01 MWD 9291.16 97.87 133.54 8953.03 8893.03 -675.34 1173.77 5974279.34 718639.30 1220.14 27.07 MWD 9326.35 99.18 136.74 8947.81 8887.81 -700.01 1198.31 5974255.40 718664.55 1254.35 9.73 MWD 9355.57 99.28 141.12 8943.13 8883.13 -721.75 1217.25 5974234.22 718684.12 1282.99 14.80 MWD 9387.84 96.91 145.14 8938.58 8878.58 -747.30 1236.42 5974209.24 718704.01 1314.90 14.35 MWD ab~- ~g~ by BP Alaska • g Faker Hu hes INTEQ Surve Re ort g Y p INTEQ Company: BP Amoco Date: 8/30!2006 Time: 14:31:00 Page: 2 Field: Lisburne Co-ordinate(NE) Reference: WeIL• L5-16, True North Site: Lis DS 05 Vertical (TVD) Reference: 9 : 16 3/2/1987 00:00 60.0 Well: L5- 16 Section (VS) Reference: Well (O.OON,O.OOE,145.62Azi) Wellpath: L5- 16A Survey Calculation Method: Minimum Curvature Dh: Orade Survey MD Inc! 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 9426.90 97.49 152.01 8933.68 8873.68 -780.35 1256.61 5974176.79 718725.15 1353.58 17.51 MWD 9457.09 97.44 156.83 8929.75 8869.75 -807.34 1269.53 5974150.19 718738.85 1383.15 15.83 MWD 9486.09 97.19 158.88 8926.06 8866.06 -833.98 1280.37 5974123.87 718750.46 1411.26 7.06 MWD 9516.92 97.13 154.43 8922.22 8862.22 -862.06 1292.49 5974096.16 718763.39 1441.28 14.32 MWD 9544.76 96.10 152.29 8919.01 8859.01 -886.77 1304.89 5974071.81 718776.50 1468.68 8.48 MWD 9572.82 93.03 152.27 8916.78 8856.78 -911.53 1317.90 5974047.44 718790.22 1496.46 10.94 MWD 9603.29 89.34 152.87 8916.15 8856.15 -938.57 1331.93 5974020.83 718805.03 1526.69 12.27 MWD 9638.22 88.05 150.96 8916.94 8856.94 -969.37 1348.37 5973990.51 718822.35 1561.40 6.60 MWD 9685.82 89.31 144.58 8918.04 8858.04 -1009.61 1373.73 5973951.04 718848.87 1608.93 13.66 MWD 9715.50 91.19 147.45 8917.91 8857.91 -1034.21 1390.32 5973926.92 718866.16 1638.60 11.56 MWD 9744.49 91.31 151.69 8917.28 8857.28 -1059.20 1405.00 5973902.37 718881.56 1667.51 14.63 MWD 9779.48 90.84 154.26 8916.62 8856.62 -1090.36 1420.89 5973871.69 718898.35 1702.20 7.47 MWD 9811.37 89.98 153.08 8916.39 8856.39 -1118.94 1435.04 5973843.53 718913.31 1733.78 4.58 MWD 9840.76 89.43 150.46 8916.54 8856.54 -1144.83 1448.94 5973818.05 718927.96 1763.00 9.11 MWD 9872.48 89.40 147.63 8916.87 8856.87 -1172.03 1465.25 5973791.34 718945.05 1794.65 8.92 MWD 9900.47 90.08 144.90 8916.99 8856.99 -1195.30 1480.79 5973768.53 718961.26 1822.64 10.05 MWD 9931.10 91.83 144.86 8916.48 8856.48 -1220.35 1498.41 5973744.00 718979.60 1853.26 5.71 MWD 9966.96 94.11 152.35 8914.62 8854.62 -1250.89 1517.05 5973714.01 718999.12 1889.00 21.80 MWD 9996.93 93.75 155.62 8912.57 8852.57 -1277.76 1530.17 5973687.54 719013.00 1918.57 10.95 MWD 10029.02 92.52 160.59 8910.81 8850.81 -1307.48 1542.11 5973658.18 719025.80 1949.85 15.93 MWD 10064.87 92.32 161.34 8909.30 8849.30 -1341.34 1553.79 5973624.67 719038.46 1984.39 2.16 MWD 10097.68 86.42 163.55 8909.66 8849.66 -1372.61 1563.68 5973593.71 719049.25 2015.78 19.20 MWD 10127.06 87.00 167.32 8911.35 8851.35 -1400.99 1571.06 5973565.55 719057.45 2043.37 12.96 MWD 10158.79 88.76 170.11 8912.52 8852.52 -1432.08 1577.26 5973534.66 719064.55 2072.53 10.39 MWD 10187.80 86.70 173.10 8913.67 8853.67 -1460.75 1581.49 5973506.12 719069.61 2098.59 12.51 MWD 10218.78 89.49 178.30 8914.70 8854.70 -1491.61 1583.81 5973475.34 719072.82 2125.37 19.04 MWD 10253.45 85.28 181.79 8916.28 8856.28 -1526.23 1583.79 5973440.74 719073.80 2153.93 15.76 MWD 10295.95 89.62 187.28 8918.17 8858.17 -1568.53 1580.43 5973398.36 719071.67 2186.94 16.45 MWD 10335.06 88.51 190.22 8918.81 8858.81 -1607.18 1574.48 5973359.56 719066.85 2215.48 8.03 MWD 10367.70 86.05 192.29 8920.36 8860.36 -1639.15 1568.12 5973327.42 719061.42 2238.27 9.85 MWD 10398.26 84.85 191.18 8922.79 8862.79 -1668.98 1561.92 5973297.43 719056.09 2259.39 5.34 MWD 10429.05 86.57 187.64 8925.09 8865.09 -1699.26 1556.90 5973267.01 719051.95 2281.55 12.75 MWD 10459.81 80.01 185.05 8928.68 8868.68 -1729.60 1553.53 5973236.59 719049.45 2304.69 22.91 MWD 10490.99 80.02 183.02 8934.09 8874.09 -1760.23 1551.37 5973205.91 719048.18 2328.75 6.41 MWD 10523.37 81.27 179.82 8939.35 8879.35 -1792.17 1550.58 5973173.96 719048.32 2354.66 10.49 MWD 10553.18 84.08 182.20 8943.15 8883.15 -1821.72 1550.05 5973144.41 719048.65 2378.76 12.31 MWD 10590.93 80.88 188.46 8948.10 8888.'10 -1858.96 1546.59 5973107.08 719046.27 2407.54 18.49 MWD 10620.94 85.81 195.51 8951.58 8891.58 -1888.09 1540.39 5973077.79 719040.92 2428.08 28.53 MWD 10649.67 89.62 201.11 8952.73 8892.73 -1915.33 1531.38 5973050.30 719032.70 2445.47 23.56 MWD 10678.25 87.23 210.31 8953.51 8893.51 -1941.04 1519.00 5973024.24 719021.07 2459.70 33.24 MWD 10708.53 83.62 210.90 8955.93 8895.93 -1967.02 1503.64 5972997.84 719006.47 2472.46 12.08 MWD 10740.80 80.71 203.39 8960.33 8900.33 -1995.44 1489.06 5972969.01 718992.72 2487.69 24.75 MWD 10775.74 80.53 199.50 8966.03 8906.03 -2027.52 1476.45 5972936.58 718981.05 2507.05 11.00 MWD 10805.10 86.60 196.42 8969.32 8909.32 -2055.26 1467.47 5972908.59 718972.88 2524.87 23.15 MWD 10835.99 85.47 191.13 8971.46 8911.46 -2085.17 1460.13 5972878.47 718966.41 2545.42 17.47 MWD 10875.00 85.47 191.13 8974.54- 8914.54 -2123.33 1452.63 5972840.12 718960.01 2572.67 0.00 MWD r" t TREE= 4-1i6" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 55' BF. ELEV = NA KOP = 3800' Max Angle = 27 @ 7400' Datum MD = 9082' Datum TV D = 8800' SS L 5 ~ ~ 6 /-~ SAFETY NOTES: CAT I SSSV H2S (PPW~250 AL1, AL1-PB1, AL2 FROM CTD/DRLG -DRAFT 41/2" TRSSSV, D = 3.812" ~ 2,177 ~ 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~ 4 1 /2" 12.6#, L-80, I BT-Mod. Tbg PERFORATION SUMMARY REF LOG: ON ??l??/?? ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 8936 - 11500 OPEN HOLE 09/01/06 8960 - 9757 OPEN HOLE 09/01 /06 9097 - 10875 OPEN HOLE 09!01'06 Liner Hanger/Packer 8802` MD - L5-16AL2:Window 8936` MD ~ Guidestock Tray (See Detail Attached) ~ X Nipple in upper packer 8954`, 2.31" ID L5-16AL1: Window 8960` MD Lower KB packer top @ 8969` MD XN Nipple in KB packer 8973`, 2.010" No go - L5-16A:Window 9097` MD g20b, 4 1 /2" 12.6#, L-80, I BT-Mod $~'t~s` M D R Pero ~--q' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2781 2780 2 KBG-2 DOME BK 16 06!11/06 4 4708 4694 4 KBG-2 DOME BK 16 06/11/06 3 6387 6371 9 KBG-2 DOME BK 16 06/11/06 2 7603 7510 26 KBG-2 DOME BK 16 06/1 1 1 8616 8431 24 KBG-2 SO BK 24 0611 1 4 1/2" X Nipple - 8664' MD 4 1/2" x 7 5/8" Baker Packer 8704 MD 4 1/2" X Nipple - 8727` MD wc-t~ 8 ~`l2' L5-16AL2 TD=11500` OH Sidetrack @ 9260' L5-16AL1 TD=9757' AL1-P61 TD=9370 L5-16A TD=10875` DATE REV BY COMMENTS DATE REV BY COMMENTS 03/17187 ORIGINAL COMPLETION 06/01/06 NORDIC2 RWO 06/11!06 KSB/PAG GLV C/O 06!14/06 GJB/TLH MILL CMT & WHIPSTOCK SET 09!02!06 GS/PAG NORDIC 2 DRLG CORRECTIONS LISBURNE UNfT WELL: LS-16A PERMIT No: 187-0190 API No: 50-029-21700-00 ? SEC 1, T11N, R15E 1788' FSL & 19' FWL BP Exploration (Alaska) ALASKA OIL AHD GAS COHSERQATIOI~T CODII-iISSIOH Greg Sarber CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR ~ ~ 333 W. 7'" AVENUE, SUITE 100 ~, ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-16A BP Exploration (Alaska) Inc. Permit No: 206-083 Surface Location: 1788' FSL, 19' FWL, SEC. O1, T11N, R15E, UM Bottomhole Location: 292' FNL, 1562' FWL, SEC. 12, T11N, R15E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill 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) 6607 (pager). Sincerel J DATED this~day of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. • • BP L5-16A, AL1, AL2 UBCTD Sidetrack Discussion of Operations: Well L5-16 is the 2"d of two planned underbalanced CTD, thru tubing sidetrack wells planned for the summer of 2006. L5-16 was originally drilled in March of 1987, and completed in zones 4,5, and 6. It has produced at total of 1.53 MMBO since it was originally brought on line in 1987. Currently the well is cycling between 400-500 BOPD. The well is typically on line for approximately 5 days until it reaches MGOR of 30,000 SCF/STB. The well is shut in for approximately 20 days. The cycle has been repeating for the last several years. No outstanding integrity issues exist with the parent wellbore. / Extensive stimulation work has been performed on this well and there is little opportunity for further well work. Nordic 2 rigged up on L5-16 on May 12, 2006, and successfully completed a workover in preparation for the CTD UBD sidetrack. That work was completed under Sundry Approval 306-120. The sidetracks, L5-16A, L5-16A L1, and L5-16A L2 will ki~-off from separate windows milled from mechanical whipstocks set in Lisburne Zone 4. Targets for the 3 laterals are in zone 4, 5, and 6. If real time well testing does not indicate that the wells have encountered fracturing or high productivity rock, an open hole sidetrack in a different azimuthal direction will be considered, but will not be permitted at this time f due to uncertainty over the alternate well path. If an open hole sidetrack of L5-16A proves to be needed, then a Permit application for an additional lateral will be submitted at that time. This is the 2"d of 2 CTD underbalanced wells planned for the Lisburne field this summer. Extensive planning for success has been made, and is ongoing. Blade Energy Partners, which is a consulting firm specializing in UBD has been engaged to assist in project planning, personnel training, and onassistance during the drilling phase of the project. `~' Well control equipment has been designed specifically for the planned operation and procedures have been written to cover each aspect of the operation. There has been HSE and operational training conducted for the town and field staff using a UBD simulator. All relevant contractors, crew and engineering staff have completed this training. HAZid and HAZop procedures have been completed and overall planning has been Peer reviewed by operating partners and outside experts with specialization in coil tubing and underbalanced drilling operations. This underbalanced coil tubing drilling eration will use diesel as the power fluid and gas lift to achieve an underbalance of 00-40 psi while drilling. Return fluids will flow to an on site separator supplied by ASR . `T-tfe fluids will be separated and measured, then flowed to the Lisburne Production Center (LPC) at about 60~psi line pressure. There will be no flaring or compression involved in the project. The BOP stack drawing is significantly different~than a standard CTD rig up, and is attached. This stack incorporates 6 BOP rams, an annular preventor, 2 flow spools, 2 swab valves, and a master valve. The UBD flow spool is located below dguble swab valves such that produced fluids do not flow through the upper four rams. An ESD valve on the outlet of the UBD flow spool along with double rams (Shear/seal and 2" pipe/slip • • combination) 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 used successfully on the managed pressure drilling campaigns in the Kuparuk field in the past few years, and have been refined for the UBD process at Lisburne. A tubing retrievable SSSV has been installed during the workover specifically to provide additional pressure control capability. The attached drawings describe the BOP stack, the P & ID of the full process spread and a flow diagram that includes all surface equipment. Summary of Underbalanced Drilling and Completion Operations: 1. Move rig over well from L5-28. 2. Rig up 2" CTE, UBCTD Stack and BOPE. PT BOPE. ` 3. Mill L5-16A window with 2% KCL and biozan sweeps. (Top of window at 9100' ~ MD, 8817' SS) 4. Drill L5-16A lateral using diesel/lift gas to achieve underbalance. 5. TD lateral and flow test well for 6 hours. 6. Set Baker whip c packer with tailpipe and PXX plug to isolate L5-16A. (Top of window at 040' D, 8761' SS) 7. Mill L5-16A L dow with 2% KCL, and biozan sweeps. 8. Drill L5-16A L1 lateral using diesel/lift gas to achieve underbalance. ~ 9. TD L1 lateral and flow test well for 6 hours. 10. Recover whipstock tray, and PXX plug. Set guidestock in L5-16A L1 lateral packer. 11. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A L1. (Top of window at 8923"MID, 8653' SS) 12. Mill L5-16A L2 window with 2% KCL, and biozan sweeps. 13. Drill L5-16A L2 lateral using diesel/lift gas to achieve underbalance. 14. TD L2 lateral and flow test well for 6 hours. 15. Recover whipstock tray and PXX plug from L2 whipstock. Install hollow guidestock into L2 packer. 16. Set BPV. RD and move off well. Post RWO Status: • L5-16 has been worked over. The original perforations have been successful squeezed off. A 4-1/2" scab liner has been run and cemented. The production tubing has been replaced with new 4-1/2" L-80 tubing. A gas lift design has been run and the well is ready for the drilling phase of operations. Mud Program: • The window will be milled with 2% KCL with %z ppb Biozan. Sweeps will be 2 ppb Biozan. • The 3 lateral sections will be drilled with diesel as the power fluid with gas lift used to underbalance the well. Viscosified mineral oil sweeps will bs used for hole cleaning during drilling. • • • Kill Weight Fluid. 2% KCL will b t e rig pits on location. BHP with 2% KCL will be 3864 psi. Measured BHP is 318j psi. 2% KCL will overbalance the formation pressure by 680 psi. OH/Tubing fume = 153 bbls. Disposal • During the drilling phase all fluid and gas returns from the well will be pumped down the L5 pad production line and sent to the Lisburne Production Center for recycling. • All drilling and completion waste fluids and any other Class II wastes will go to Grind and 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: • The BOP schematic, P & ID drawing, and fluid flow diagrams are attached. • Pipe rams, blind rams and the CT pack-ff will be pressure tested to 400 psi and 3500 ~ psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional: • See attached directional plans. Maximum planned hole angle is approximately ~97 deg. • Magnetic and inclination surveys will be taken every 30'. No Gyro survey will be run. Logging: • An MWD Gamma Ray log will be run of the entire open hole section. Hazards mitigated through training, procedures, and UBD equ ent: • Hydrogen Sulfide -Maximum H2S measured on L5 pad is 60~ppm (3-27-92) on L5- 12. L5-16 has recorded H2S at 50 ppm on 1-9-2006, and the lift gas has an H2S concentration of 60 ppm. • Maximum BHP is expected to be 3184 psi @ 8900' SS (6.9 ppg). Maximum, anticipated surface pressure with a full column of gas to surface is 2294 psi. • A combustible power fluid will be used. (Diesel) Flash Point 100 deg F o Fire, Environmental, Health (exposure), impact on other equipment (elastomers) • A combustible artificial lift fluid will be used. (Natural Gas) o Fire, H2S, Health (exposure) • Produced Fluids will be present in returned fluids. (Oil and Natural Gas) o Fire, Environmental, H2S, 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 • Hole Instability - Mudstones • Reservoir Pressure: • • Bottom Hole Pressure was measured at 3184 psi at 8900' TVDSS (6.9 ppg,) • Maximum surface pressure with gas (0.1 psi/ft) to surface is 2294 psi. ~ BP Drilling Contacts: • Greg Sarber 564-4330, 242-8000 cell • Ted Stagg 564-4694, 240-8074 cell • Mark Johnson 564-5666, 240-8034 cell Attachment List Proposed schematic Existing schematic L5-16A directional plan L5-16A L1 directional plan L5-16A L2 directional plan Lisburne UBD block flow diagram Lisburne UBD BOP stack-up Lisburne UBD P&ID Lisburne UBD site layout Slti F ETY NdT~: L'JiT I X11 F~ (PP 19~iG L5-16 Post Workover 2177' +~+R• ina~~, a .3Bt~• I 5 GLM's #1 - 8,615 #2 - 7,602' #3 - 6, 387' #4 - 4, 708' i #5 - 2,781' io~,~~• ems, 45.5, Leo, o - 999• 404$' ~ 8683' - 4 1 /2" X Nipple 8704' - 1 /2" x 7 5/8" Baker SB3-A Packer 8727' - 4 1/2" X Nipple I 61 R• TB D, 13bN, L-B0, BT-Y~1 $ ,7$~' -4 1/2" x 7 5/8" HMC hanger and ZXP packer Packer @ 8,802', Hanger @ 8,820' 8964 M D 4 1 /2" Scab Liner Cemented inside 7 5/8" liner 4 1/2" 12.6#, L-80, IBT-Mod Scab Liner @ 9,206' M - Top of fill ~ 9280 9378 MD PeTO 8479' 1-68' ~, a.lN, L-0G, ~ -6815' 9$59' ~ L5-16A, AL1, AL2 ~ Prop. UBCTD Sdrtks. ~ 1G-311' ~~, 15.x, L-~0, O - 9953' 4 1/2" 12.6#, L-80, IBT-Mod. Tbg. ~J 31L F ETY NOTE: CJLT I ~1~ Fib (PP i~a0 I~~a•Tx®+1, a -3e~r 5 GLM's 1 - 8615' 2 - 7602' 3 - 6387' 4 - 4708' 5 - 2781' 8704' - 4 1/2" x 7 5/8" Baker Packer Liner Hanger/Packer 8802' MD L5-16AL2: 8923 MD, 8653ss L5-16AL1: ($96 MD, 8687'ss , .~ L5-16A: 9100 MD, 8817ss 4 1/2" 12.6#, L-80, IBT-Mod 9,206` MD~ PeTO 8479' 1 8727' - 4 1/2" X Nipple L5-16AL2 Zones 5 & 6 BP Alaska by Baker Hughes INTEQ Planning Report BA ~R ^ s INTEQ Company: BP Amoco Date: 6!1112006 Time: 15:34:05 Page: l Field: Lisburne Co-ordinate(NE) Reference: Well;`L5-16, True North Site: ' Lis DS 05 Vertieal (TVD) Reference: 9:163/2/1:987 00:00 60.0 Well: L5-16 Section(VS)Reference: Well (O.OON,O.OOE,180.QOAzi) Wellpsth: Platr 2, L5-16A Survey CaknlationMethod: MinimumCurvature Db: OraGe Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: 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: L5-16 Slot Name: 16 L5-16 Well Position: +N/-S 4778.96 ft Northing: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Easting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, L5-16A Drilled From: L5-16 targets from Dan, 05-17-2006 Tie-on Depth: 9073.95 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/16/2006 Declination: 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 0.00 180.00 Plan: Plan #2 Date Composed: 5/1 612 0 06 Version: 9 Principal: Yes Tied-to: From: Definitive Path Targets Map Msp <- Latitude ----~ <-- Longitude ---> Naroe Description TVD +N/-S +E/-W Northing Easting Deg Min 'Sec Deg Min` Sec Dip. Dir. Annotation MD TVD ft ft 9073.95 8852.61 TIP 9100.00 8876.60 KOP 9120.00 8894.87 End of 9 Deg/100' DLS 9282.00 8967.55 End of 45 Deg/100' DLS 9482.00 8941.40 5 9632.00 8922.84 6 9932.00 8888.50 7 10032.00 8878.40 8 10282.00 8870.46 9 10452.00 8891.19 10 10652.00 8930.26 11 10822.00 8952.73 TD Plan Section Information MD Inct Azim TVD +N/-5 +E/-W DLS Build Tarn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9073.95 22.87 128.27 8852.61 -581.32 1038.71 0.00 0.00 0.00 0.00 9100.00 23.04 128.61 8876.60 -587.64 1046.67 0.83 0.65 1.31 38.11 9120.00 24.84 128.61 8894.87 -592.70 1053.01 9.00 9.00 0.00 0.00 9282.00 97.74 128.61 8967.55 -675.51 1156.70 45.00 45.00 0.00 0.00 9482.00 97.07 152.81 8941.40 -827.84 1281.31 12.00 -0.34 12.10 90.00 9632.00 97.03 134.67 8922.84 -947.36 1368.99 12.00 -0.03 -12.09 271.00 9932.00 95.68 170.87 8888.50 -1208.02 1502.98 12.00 -0.45 12.07 90.00 10032.00 95.87 158.81 8878.40 -1303.87 1528.94 12.00 0.19 -12.06 271.50 10282.00 87.70 187.72 8870.46 -1549.21 1557.77 12.00 -3.27 11.56 105.00 10452.00 78.39 169.41 8891.19 -1716.99 1561.72 12.00 -5.47 -10.77 242.00 10652.00 79.41 193.85 8930.26 -1911.57 1556.12 1200 0.51 12.22 90.00 BP Alaska by Baker Hughes INTEQ Planning Report s,>~R ~ Illlueir~is INTEQ Company: BP Amoco Date: 6/l1/2006 Time: 15:34:05 Page: 2 Field:: isbume Co-ordinate(NE) Reference: WeIL• L5-16, True North Sitet Lis DS 05 Vertieal (TVD) Reference: 9 :16 3/2/1987 00:00 60. 0 Welly L5'-16 Section(VS)Reference: `Well (OOON,O.OOE,180.O OAzi) Wellpath: Plan 2, L5-16A Survey Calculation Method: Minimum Curvature Db: O rade Plan Section Information NID Intl Azim 1'VD +N/-S +E/-W ' DLS BuiM Turn TFO T><rget ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 10822.00 85.54 174.21 8952.73 -2078.77 1544.54 12.00 3.60 -11.55 286.00 Survey MD Inel Azim Sys TVD N/S >r/VV MspN MapE DLS ` YS TFO Tooi ft deg deg ft ft ft ft ft degllOQft ft deg 9073.95 22.87 128.27 8792.61 -581.32 1038.71 5974369.40 718501.59 0.00 581.32 0.00 MWD 9100.00 23.04 128.61 8816.60 -587.64 1046.67 5974363.32 718509.73 0.83 587.64 38.11 MWD 9120.00 24.84 128.61 8834.87 -592.70 1053.01 5974358.44 718516.21 9.00 592.70 0.00 MWD 9130.00 29.34 128.61 8843.77 -595.54 1056.57 5974355.71 718519.85 45.00 595.54 0.00 MWD 9140.00 33.84 128.61 8852.29 -598.81 1060.66 5974352.56 718524.04 45.00 598.81 0.00 MWD 9150.00 38.34 128.61 8860.37 -602.49 1065.26 5974349.02 718528.74 45.00 602.49 0.00 MWD 9160.00 42.84 128.61 8867.96 -606.55 1070.35 5974345.11 718533.94 45.00 606.55 0.00 MWD 9170.00 47.34 128.61 8875.02 -610.97 1075.88 5974340.85 718539.60 45.00 610.97 0.00 MWD 9180.00 51.84 128.61 8881.50 -615.72 1081.83 5974336.28 718545.68 45.00 615.72 0.00 MWD 9190.00 56.34 128.61 8887.36 -620.77 1088.16 5974331.41 718552.15 45.00 620.77 0.00 MWD 9200.00 60.84 128.61 8892.57 -626.09 1094.82 5974326.28 718558.97 45.00 626.09 0.00 MWD 9210.00 65.34 128.61 8897.10 -631.66 1101.79 5974320.92 718566.09 45.00 631.66 0.00 MWD 9220.00 69.84 128.61 8900.91 -637.42 1109.01 5974315.37 718573.48 45.00 637.42 0.00 MWD 9230.00 74.34 128.61 8903.98 -643.36 1116.44 5974309.65 718581.08 45.00 643.36 0.00 MWD 9240.00 78.84 128.61 8906.30 -649.43 1124.04 5974303.81 718588.85 45.00 649.43 0.00 MWD 9250.00 83.34 128.61 8907.85 -655.59 1131.76 5974297.87 718596.75 45.00 655.59 0.00 MWD 9260.00 87.84 128.61 8908.62 -661.81 1139.55 5974291.88 718604.71 45.00 661.81 0.00 MWD 9270.00 92.34 128.61 8908.60 -668.05 1147.36 5974285.87 718612.70 45.00 668.05 0.00 MWD 9280.00 96.84 128.61 8907.80 -674.27 1155.15 5974279.88 718620.67 45.00 674.27 0.00 MWD 9282.00 97.74 128.61 8907.55 -675.51 1156.70 5974278.69 718622.25 45.00 675.51 0.00 MWD 9300.00 97.73 130.79 8905.13 -686.90 1170.42 5974267.70 718636.30 12.00 686.90 90.00 MWD 9325.00 97.71 133.82 8901.77 -703.57 1188.74 5974251.56 718655.09 12.00 703.57 90.29 MWD 9350.00 97.66 136.84 8898.42 -721.19 1206.16 5974234.46 718673.01 12.00 721.19 90.70 MWD 9375.00 97.59 139.87 8895.11 -739.70 1222.62 5974216.43 718690.00 12.00 739.70 91.11 MWD 9400.00 97.50 142.89 8891.82 -759.06 1238.09 5974197.53 718706.02 12.00 759.06 91.51 MWD 9425.00 97.39 145.92 8888.58 -779.22 1252.51 5974177.80 718721.03 12.00 779.22 91.90 MWD 9450.00 97.26 148.94 8885.39 -800.11 1265.86 5974157.30 718734.97 12.00 800.11 92.30 MWD 9475.00 97.11 151.96 8882.26 -821.69 1278.09 5974136.09 718747.82 12.00 821.69 92.68 MWD 9482.00 97.07 152.81 8881.40 -827.84 1281.31 5974130.03 718751.22 12.00 827.84 93.06 MWD 9500.00 97.10 150.63 8879.18 -843.57 1289.77 5974114.56 718760.14 12.00 843.57 271.00 MWD 9525.00 97.13 147.61 8876.08 -864.86 1302.51 5974093.65 718773.48 12.00 864.86 270.73 MWD 9550.00 97.14 144.58 8872.97 -885.45 1316.34 5974073.47 718787.90 12.00 885.45 270.36 MWD 9575.00 97.13 141.56 8869.87 -905.27 1331.24 5974054.09 718803.38 12.00 905.27 269.98 MWD 9600.00 97.10 138.54 8866.77 -924.29 1347.17 5974035.54 718819.85 12.00 924.29 269.61 MWD 9625.00 97.05 135.51 8863.70 -942.44 1364.08 5974017.89 718837.28 12.00 942.44 269.23 MVW 9632.00 97.03 134.67 8862.84 -947.36 1368.99 5974013.12 718842.32 12.00 947.36 268.86 MWD 9650.00 97.02 136.84 8860.64 -960.16 1381.45 5974000.69 718855.15 12.00 960.16 90.00 MWD 9675.00 97.00 139.87 8857.58 -978.70 1397.94 5973982.63 718872.17 12.00 978.70 90.27 MWD 9700.00 96.96 142.89 8854.55 -998.08 1413.43 5973963.71 718888.21 12.00 998.08 90.64 MWD 9725.00 96.90 145.91 8851.53 -1018.26 1427.87 5973943.96 718903.23 12.00 1018.26 91.00 MWD 9750.00 96.81 148.93 8848.55 -1039.17 1441.24 5973923.44 718917.20 12.00 1039.17 91.37 MWD 9775.00 96.71 151.95 8845.60 -1060.76 1453.48 5973902.21 718930.06 12.00 1060.76 91.73 MWD 9800.00 96.60 154.97 8842.70 -1082.97 1464.58 5973880.33 718941.80 12.00 1082.97 92.08 MWD 9825.00 96.46 157.98 8839.86 -1105.74 1474.49 5973857.86 718952.36 12.00 1105.74 92.43 MWD 9850.00 96.31 161.00 8837.08 -1129.01 1483.19 5973834.86 718961.74 12.00 1129.01 92.78 MWD 9875.00 96.13 164.01 8834.37 -1152.71 1490.66 5973811.38 718969.89 12.00 1152.71 93.11 MWD 9900.00 95.95 167.02 8831.74 -1176.78 1496.88 5973787.51 718976.80 12.00 1176.78 93.44 MWD 9925.00 95.74 170.03 8829.19 -1201.15 1501.83 5973763.29 718982.45 12.00 1201.15 93.75 MWD 9932.00 95.68 170.87 8828.50 -1208.02 1502.98 5973756.46 718983.81 12.00 1208.02 94.06 MWD 9950.00 95.73 168.70 8826.71 -1225.65 1506.16 5973738.93 718987.49 12.00 1225.65 271.50 MWD 9975.00 95.79 165.69 8824.20 -1249.90 1511.67 5973714.85 718993.71 12.00 1249.90 271.28 MWD 10000.00 95.84 162.67 8821.66 -1273.82 1518.45 5973691.13 719001.18 12.00 1273.82 270.98 MWD 10025.00 95.86 159.66 8819.11 -1297.36 1526.47 5973667.84 719009.88 12.00 1297.36 270.68 MWD BP Alaska by Baker Hughes INTEQ Planning Report BAI~R ^ s INTEQ Company: BP Amoco Date: 6/11/2006 Time: 15:34:05" Page: 3 Field: Lisburne' Co-ordinate(NE) Reference: ; ' WeIL• 15-16, True North Site: Lis DS 05 Vertical (TVD) Reference: 9 :16 3/2/1987 00:00 60 .0 Weil: L5- 16 Section (VS) Reference: Well (O:OON O.OOE,180.OOAzi) Wellpat6: Plan 2, L5-1 6A Survey GalenlatioaMethod: Minimum Curvature Db: O rade Survey MD Incf Azim Sys T~'D N/S E/W MapN MapE DIS - VS TFO Toot $ deg deg -ft - ft , ft ft ft deg/100ft ft deg.. 10032.00 95.87 158.81 8818.40 -1303.87 1528.94 5973661.41 719012.54 12.00 1303.87 270.37 MWD 10050.00 95.31 160.91 8816.65 -1320.69 1535.11 5973644.77 719019.19 12.00 1320.69 105.00 MWD 10075.00 94.51 163.81 8814.51 -1344.42 1542.66 5973621.27 719027.42 12.00 1344.42 105.20 MWD 10100.00 93.71 166.71 8812.71 -1368.54 1549.00 5973597.35 719034.46 12.00 1368.54 105.45 MWD 10125.00 92.89 169.60 8811.27 -1392.96 1554.12 5973573.09 719040.29 12.00 1392.96 105.66 MWD 10150.00 92.07 172.49 8810.19 -1417.63 1558.01 5973548.54 719044.89 12.00 1417.63 105.83 MWD 10175.00 91.25 175.38 8809.47 -1442.48 1560.65 5973523.78 719048.25 12.00 1442.48 105.95 MWD 10200.00 90.42 178.26 8809.10 -1467.43 1562.04 5973498.88 719050.36 12.00 1467.43 106.04 MWD 10225.00 89.58 181.14 8809.10 -1492.43 1562.17 5973473.90 719051.21 12.00 1492.43 106.08 MWD 10250.00 88.75 184.02 8809.47 -1517.40 1561.04 5973448.91 719050.81 12.00 1517.40 106.08 MWD 10275.00 87.93 186.91 8810.19 -1542.27 1558.66 5973423.98 719049.15 12.00 1542.27 106.04 MWD 10282.00 87.70 187.72 8810.46 -1549.21 1557.77 5973417.02 719048.47 12.00 1549.21 105.95 MWD 10300.00 86.68 185.81 8811.34 -1567.06 1555.65 5973399.11 719046.87 12.00 1567.06 242.00 MWD 10325.00 85.28 183.15 8813.09 -1591.92 1553.71 5973374.21 719045.64 12.00 1591.92 242.09 MWD 10350.00 83.89 180.48 8815.45 -1616.79 1552.92 5973349.32 719045.58 12.00 1616.79 242.28 MWD 10375.00 82.52 177.79 8818.41 -1641.61 1553.29 5973324.53 719046.67 12.00 1641.61 242.53 MWD 10400.00 81.16 175.09 8821.96 -1666.31 1554.83 5973299.89 719048.92 12.00 1666.31 242.85 MWD 10425.00 79.82 172.37 8826.09 -1690.82 1557.52 5973275.47 719052.32 12.00 1690.82 243.23 MWD 10452.00 78.39 169.41 8831.19 -1716.99 1561.72 5973249.43 719057.27 12.00 1716.99 243.68 MWD 10475.00 78.41 172.22 8835.82 -1739.23 1565.31 5973227.31 719061.51 12.00 1739.23 90.00 MWD 10500.00 78.45 175.28 8840.83 -1763.57 1567.98 5973203.05 719064.88 12.00 1763.57 89.43 MWD 10525.00 78.53 178.35 8845.82 -1788.03 1569.34 5973178.64 719066.95 12.00 1788.03 88.82 MWD 10550.00 78.64 181.40 8850.77 -1812.53 1569.39 5973154.16 719067.71 12.00 1812.53 88.21 MWD 10575.00 78.78 184.46 8855.66 -1837.01 1568.14 5973129.65 719067.17 12.00 1837.01 87.60 MWD 10600.00 78.95 187.51 8860.49 -1861.41 1565.58 5973105.19 719065.32 12.00 1861.41 87.00 MWD 10625.00 79.16 190.56 8865.24 -1885.64 1561.72 5973080.86 719062.17 12.00 1885.64 86.42 MWD 10652.00 79.41 193.85 8870.26 -1911.57 1556.12 5973054.78 719057.32 12.00 1911.57 85.84 MWD 10675.00 80.18 191.16 8874.34 -1933.67 1551.22 5973032.55 719053.06 12.00 1933.67 286.00 MWD 10700.00 81.04 188.24 8878.41 -1957.98 1547.06 5973008.13 719049.61 12.00 1957.98 286.48 MWD 10725.00 81.93 185.35 8882.12 -1982.52 1544.14 5972983.51 719047.40 12.00 1982.52 286.95 MWD 10750.00 82.84 182.46 8885.43 -2007.24 1542.45 5972958.75 719046.43 12.00 2007.24 287.38 MWD 10775.00 83.76 179.59 8888.35 -2032.07 1542.01 5972933.93 719046.71 12.00 2032.07 287.76 MWD 10800.00 84.70 ~ 176.72 8890.86 -2056.92 1542.81 5972909.11 719048.23 12.00 2056.92 288.10 MWD 10822.00 85.54 174.21 8892.73 -2078.77 1544.54 5972887.32 719050.60 12.00 2078.77 288.39 3.50" • • ~~ f [ !T ~ ! !` ! , ~ i~ ', 't{ L1t i~U ,(lltilll '(T( Etl[ li~i i-111 iii ~IIE lii~ ~{i~~ f~ii -f !~ Ifl_~.~~ ~ rl~ I(~~ il' l~`t- ti i l ~ a i ~ i t 1 t t ~ ~ ill }tfl - tt 11 ~. it ~{ii i1+ tltr 4t1~ k(~( 111 (1 i~Ffi~r Itr~~`'!i tit + Iil tiF 1 r F ':' I~ ~ ~ t ~~ '~~ ~ `~ - ,I ~~1' r~~-~1?I ~t~~'1H ~-~frt!I{ ~1{~~iti ern Irlr~ti ~ {~ -1~ ~#~~'~;~ +~ ; ~ i' Ci~ ~r~ 1~~~{~ ~~F, ~ a ~. ~}i ~ i i ~ ji.'I ; ti I ylli.-+I 4 Llrl -:l i'1 r I ~ }+ j ., i ! fi ! 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Lis DS 05 Co-ordinate(NE) Reference: Well: L5-1 6, True North Reference We14 L5-16 Vertical (TVDj Reference: 9:16 3/2/1987 00:00 60.0 Reference Wellpath: Plan 2, L5-16A Db: Orade NO GLOBAL SCAN: Using user deTined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9073.95 to 10822.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/1 6/2006 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 60.00 9073.95 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 9073.95 10822.00 Planned: Plan #2 V8 MWD MWD - Standard Casing Points MD' TVD Diameter Hole Size Name ft ft in in 10822.00 8952.73 3.500 4.500 3.50" Summary - OftseYWellpath . --> Reference OfLret ' Ctr-Ctr No-Go Allowable Site - Well We0path MD MD Distance Area. Deviation Warning ft ft ft' ft ft L5-16,PIan 2, L5-16A,P 10822.00 10822.00 0.00 123.37 -123.37 FAIL: Major Risk Lis DS 05 L5-16 L5-16 V1 9100.00 9100.00 0.00 92.74 -92.74 FAIL: Major Risk Lis DS 05 L5-16 Plan 1, L5-16AL2 VO PI 9310.79 9200.00 181.04 67.16 113.88 Pass: Major Risk Lis DS 05 L5-16 PIan3, L5-16AL1 V1 Pla 9082.03 9100.00 55.29 83.91 -28.63 FAIL: Major Risk Site: Well: Rule Assigned: Major Risk Wellpath: L5-16,PIan 2, L5-16A, PIan #2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg. deg in ft ft ft 9073.95 8852.61 9073.95 8852.61 11.12 0.00 128.27 0.00 4.500 0.00 66.53 -66.53 FAIL 9100.00 8876.60 9100.00 8876.60 11.17 0.08 128.61 0.00 4.500 0.00 66.74 -66.74 FAIL 9200.00 8952.57 9200.00 8952.57 11.19 1.39 128.61 0.00 4.500 0.00 70.90 -70.90 FAIL 9300.00 8965.13 9300.00 8965.13 11.46 2.69 130.79 0.00 4.500 0.00 74.13 -74.13 FAIL 9400.00 8951.82 9400.00 8951.82 11.61 4.15 142.89 0.00 4.500 0.00 74.87 -74.87 FAIL 9500.00 8939.18 9500.00 8939.18 11.94 5.56 150.63 0.00 4.500 0.00 76.30 -76.30 FAIL 9600.00 8926.77 9600.00 8926.77 13.16 7.30 138.54 0.00 4.500 0.00 80.48 -80.48 FAIL 9700.00 8914.55 9700.00 8914.55 14.00 8.90 142.89 0.00 4.500 0.00 83.66 -83.66 FAIL 9800.00 8902.70 9800.00 8902.70 14.48 10.12 154.97 0.00 4.500 0.00 85.87 -85.87 FAIL 9900.00 8891.74 9900.00 8891.74 14.62 10.84 167.02 0.00 4.500 0.00 87.15 -87.15 FAIL 10000.00 8881.66 10000.00 8881.66 16.05 12.56 162.67 0.00 4.500 0.00 92.22 -92.22 FAIL 10100.00 8872.71 10100.00 8872.71 16.85 13.72 166.71 0.00 4.500 0.00 95.41 -95.41 FAIL 10200.00 8869.10 10200.00 8869.10 16.66 13.89 178.26 0.00 4.500 0.00 95:65 -95.65 FAIL 10300.00 8871.34 10300.00 8871.34 16.65 14.12 185.81 0.00 4.500 0.00 96.51 -96.51 FAIL 10400.00 8881.96 10400.00 8881.96 19.18 16.82 175.09 0.00 4.500 0.00 104.94 -104.94 FAIL 10500.00 8900.83 10500.00 8900.83 20.33 18.13 175.28 0.00 4.500 0.00 109.37 -109.37 FAIL 10600.00 8920.49 10600.00 8920.49 19.66 17.69 187.51 0.00 4.500 0.00 108.98 -108.98 FAIL 10700.00 8938.41 10700.00 8938.41 20.57 18.69 188.24 0.00 4.500 0.00 112.43 -112.43 FAIL 10800.00 8950.86 10800.00 8950.86 23.42 21.55 176.72 0.00 4.500 0.00 121.49 -121.49 FAIL 10822.00 8952.73 10822.00 8952.73 23.98 22.10 174.21 0.00 4.500 0.00 123.37 -123.37 FAIL Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aaia Cfr-Ctr No-Go Albwable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H3)istance Area Deviatron Warning ft ft tt ft ft ft deg deg in ft ft ft 9100.00 8876.60 9100.00 8876.60 11.17 11.22 128.61 0.00 0.00 92.74 -92.74 FAIL 9190.31 8947.54 9200.00 8968.47 11.17 11.59 307.91 179.30 25.11 81.81 -56.70 FAIL 9239.43 8966.19 9300.00 9060.12 11.29 12.01 308.03 179.42 95.83 74.42 21.41 Pass 9263.00 8968.70 9400.00 9151.86 11.36 12.27 308.00 179.39 183.19 71.12 112.07 Pass 9275.98 8968.22 9500.00 9243.59 11.41 12.72 308.01 179.40 276.45 69.84 206.61 Pass 92,90.10 8966.46 9600.00 9335.31 11.45 1316 309.14 179.55 372.25 69.49 3;0277 Bass BP Alaska • ~R ~ by Nuc~s Anticollision Report INTEQ Company: l3P Amoco Date: 6/11/2006 Time: 14:57: D5 Fage: 2 Field: Lisburne Reference Sker Lis DS 05 Co-ordinate(NE) Reference: Welk LS-16, True North Reference Wep: L5-16 _ Vertical (TVD) Reference: 9:168/2/1987 00:00 60.0 Refereece Wellpathq Plan 2, L5-16A Db: Oracle Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAzis Ctr-Ctr No-Go Allowable MD TVD MD TV[) Ref Offset. TFO+AZI TFO-HS Casing/HSt)istauce Area Deviation Warning Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: Plan 1, L5-16AL2 VO Plan: Plan #1 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr Nato Albwable MD TVD MD TVD Ret Offset TFO+AZI TFO-liS Casing/H~istance Area Deviation Warning ft ft ft ft ft ft_ de9 _ deg. in ft ft ft 9310.79 8963.68 9200.00 8807.35 11.48 11.10 161.47 29.38 3.500 181.04 67.16 113.88 Pass 9417.58 8949.54 9300.00 8800.64 11.63 11.30 190.52 45.50 3.500 214.23 79.33 134.90 Pass 9508.42 8938.13 9400.00 8795.04 12.04 11.70 205.67 56.05 3.500 258.24 89.07 169.17 Pass 9548.93 8933.11 9500.00 8791.58 12.54 12.16 208.60 63.89 3.500 324.08 97.56 226.52 Pass 9571.89 8930.26 9600.00 8785.68 12.82 12.40 211.06 69.12 3.500 408.83 102.44 306.39 Pass 9580.60 8929.18 9700.00 8780.75 12.92 12.48 213.58 72.69 3.500 502.82 104.92 397.90 Pass 9589.47 8928.08 9800.00 8775.76 13.03 12.50 214.93 75.12 3.500 597.76 106.38 491.38 Pass 9605.16 8926.14 9900.00 8769.01 13.22 12.57 214.62 76.71 3.500 688.52 107.94 580.58 Pass 9991.40 8882.54 10000.00 8764.04 15.87 14.27 244.43 80.72 3.500 738.83 122.69 616.14 Pass 10325.00 8873.09 10100.00 8761.84 17.29 15.65 264.96 81.82 3.500 781.23 132.37 648.86 Pass 10356.65 8876.18 10200.00 8762.72 18.09 16.61 261.85 82.09 3.500 829.57 137.97 691.60 Pass 10383.56 8879.56 10300.00 8769.32 18.77 17.34 259.75 82.88 3.500 897.65 142.50 755.15 Pass 10400.00 8881.96 10400.00 8781.32 19.18 17.85 259.05 83.96 3.500 980.15 145.58 834.57 Pass 10411.49 8883.78 10470.00 8791.41 19.45 18.04 258.70 84.85 3.500 1043.90 147.10 896.81 Pass Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: PIan3, L5-16AL1 V1 Plan: Plan #t3 V14 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingBglistance AreA ' Deviation Wareing ft ft ft ft ft ft deg. deg. in ft ft ft. 9082.03 9297.96 8860.05 8965.40 9100.00 9200.00 8838.55 8836.51 11.13 11.46 10.81 11.15 125.47 120.52 357.10 349.98 3.500 3.500 55.29 132.09 83.91 61.15 -28.63 70.95 FAIL l Pass 9343.95 8959.23 9300.00 8829.82 11.52 11.30 97.51 321.40 3.500 167.10 84.12 82.97 Pass 9354.06 8957.88 9400.00 8823.46 11.54 11.32 81.12 303.79 3.500 243.88 95.13 148.75 Pass 9349.00 8958.56 9500.00 8816.91 11.53 11.32 72.04 295.32 3.500 334.21 98.60 235.61 Pass 9334.98 8960.43 9600.00 8810.42 11.51 11.32 65.80 290.77 3.500 426.83 99.85 326.99 Pass 9328.84 8961.25 9700.00 8804.06 11.50 11.33 61.94 287.66 3.500 522.78 100.55 422.24 Pass 9332.97 8960.70 9800.00 8798.03 11.51 11.34 60.15 285.37 3.500 619.40 101.05 518.35 Pass 9344.65 8959.14 9900.00 8792.59 11.53 11.38 59.83 283.64 3.500 712.73 101.50 611.23 Pass 9361.89 8956.84 10000.00 8787.97 11.55 11.46 60.58 282.30 3.500 799.80 102.00 697.81 Pass 9375.00 8955.11 10100.00 8784.74 11.57 11.61 60.96 281.09 3.500 885.32 102.61 782.71 Pass 9388.07 8953.38 10200.00 8783.78 11.59 11.61 61.51 280.06 3.500 979.51 102.70 876.81 Pass 9389.48 8953.20 10300.00 8785.14 11.59 11.64 60.67 279.05 3.500 1077.51 102.78 974.73 Pass 9384.68 8953.83 10400.00 8788.77 11.59 11.66 59.19 278.15 3.500 1174.68 102.79 1071.89 Pass 9375.00 8955.11 10500.00 8794.51 11.57 11.71 57.22 277.35 3.500 1267.24 102.84 1164.41 Pass 9361.10 8956.95 10600.00 8802.11 11.55 11.81 54.82 276.63 3.500 1352.11 103.04 1249.07 Pass 9350.00 8958.42 10700.00 8814.91 11.53 11.87 52.72 275.87 3.500 1433.29 103.13 1330.16 Pass Lisburne UB-CTD Heater Chemical Test Separator F 5000 psi Injection 1376 psi@186 Block Flow Diagram 2.5 MM BTU 2X 5gal 36 MMscfd 30 gpd 11000 bpd liquids ~7-Apr-06 - + Heat 140 F P-SOOpsi T -140 F L_5 L-5 Header Header to LPC Test Separator Trace Solids Oil 2850 bopd Gas 16.5 mmscf/d Water/KCI 2304 bpd Pressure Ship to L5-32 (28) to L5-24 (16) Production Header + auuppm Demulsifier + Defoamer Wells L5-28 L5-16 16.5 mmscf/d gas 2850 bpd effluent T-55F P - 650 prig In Line 2 Phase "'''"- Vent to Fbwback Heater r-1ao F ASRC Separator raao F Tank P-550psi P-550psi T -140 F R14.7psi Qnliric Pressure ship to Slop Tank Reservoir L5-16 T 165 F Static Gas 11.5 mmscf/d T ~ocx Flowing Oil 850 bopd L5-za Water 135 bopd T 174 F Static T noc Flowing ', Fluid Injected Via CT - z3oa bpd Gas Lift Mandrel Injectbn T - 60 F 0 to 5 MMscf/d P- as req'd Contingency For KCI Mud System. Would be req'd for LS-16 Fbwback Tank ASRC P - 5000 psi Mud Pump 1 Mud Pump 2 Gas Metering Skid Feed Gas 2500psi P - xxx T-40F Gas Lift Header DSO Clean Out KCL DRA Mixing +0.6 % Safelube + 1.7 Ib/bbl Concor404 Diesel +0.751b/bbl Sodium 1600 bbl Metabysulfide + Opp ppm + 0.068% DRA J313 Diesel KCI ASRC Nordic Tank Rig Farm Tanks Methanol Lisburne Process-Block Flow rev 4/29/2006 L5-?6 Stack rev4- 4~?~1~Qfi • • • • .... ~ s e o~ --- \ e D L~B ~~ e }j ~ ~~ ~ ~dA ~I "i a I~ V . ~ ~~a Jn -- _ ~, i ~ A ~J ` 8 1 `B m R 'l C '~ ~ 0 ~i jF ~ Zi_~ I S ~ t'- ! u . ~ I '~r i! I ~ ~ J ~~ ~` 9 _ ! i- t° ~ „~ ~ 9p J ii ~ o"-i E I o R %~ 1 / ~ $ F o i ~ _ ~o o l ~~ n m ~- '', s ~ o, } ~ yy C i. - ~ ~ i o o o o/ m" i. ff i ~r` I ~ I -- J - m ~ 9N~p ', [ f -~ n o ~ _ I. ... .... '~ s n ~ ; ~ F - r * ( 1 r° ~~ L _°~ s _~ r r ~ m~ a ~ _ i ~S r#a \ ~ r ~, - m m `--- Pt- (} Jr-Jr- ~~fil- -- ~~ ` '~~ £ H d y ~ ~ 41 F f-iB -_ ~ , l~ 1 3 ~~ S ; '~: ~ `^ ~ ~ ~ I b i ~ 3,~ ~-a¢ - -- ~ : : ~ a ~ r t C : - m +" 1 ~ ---- +drt ~` ~ ~ ~ s~ _ - - ~ E c ~~ ~ ~ a to s 0 ~ ~ F i :tit a ~„ e mm Fo i c a t c i-a _ ~; ___; 44.7' ~ ,,~ h 1 ih I co r' 935 I ~ (4) c a~ a WIND -_ ~-- 361 ~r ~ ,~ r ' ~=-'. ., ; lid ,' .? r ,--.~ ~, . _ I :, ,'~ ~~ ~~ r .~. ,, ti •~ , 'S __ ,_o r ~~` 18 c North 2 ~, -- F ~I ~ >~ €~ ^ g-a 0 N r ^ 4,; 4917 h ~` 150 ft radius ~~ .'' •. 50 fl radius -- Nordic 2 ~ of i ° ;,,~ m C .~ a a 11 N co co c!~ ~~~ Enter/Exit " ~' i a j'. i' WELL PRODUCER ^ DATE :03/28/2006 SCALE : 1" = 2510' MAP DATE :2004 PBU - DSLS WELL INJECTOR ~ bst 4495.dgn • TERRIE L NUBBLE BR 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(//9~~9501 .MEMO G-. ~ ~ ! ~O ~ - ~! ~-+l_.// as-sitz5z 278 DATE _t,l~''-__--~l.C? lC~. ~ ~~_ ~:i25200060~:99L4~~~6227~~~L55611• 0278 • TRANSMITTAL LETTER CHECKLIST WELL NAME--~~~.~-~ ~. ^~~~'/ PTD# ~ ~.6 ' d ~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-Olv'S TEXT FOR APPROVAL LETTER I 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) j 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 2.055. 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 i 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 NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /2~i06 C:ljody\transmittal_checklist ~~~_ ~_~_ WELL. PECMIT CHECKLIST Field & Pool, PRUDHOE BAY, LISBURNE OIL • 640144 __ Well Name: PRUDHOE BAY UN_LIS L5.16A_ _program DEV _ ____ Well bore seg PTD#:206083C C ompany BP EXPLORATION (ALASKA) INC __ _ _ ___ _ _ _ Initial Class/Type _ _ DEV! 1.OIL_ _ GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal Administration R ''11 Permitfee attached_ - ~ Yes ',2 Lease number appropriate- Yes 3 Unique well name and number - Yes ',4 Well located in a defined pool _ Yes 15 Well located proper distance from-drilling unit-boundary- - _ - Yes - - I6 WelUocated proper distance from. other wells- - Yes - 7 Sufficient acreage available in drilling unit- .. - - _ Yes - .. , 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate_bond in force - Yes - 111 Permit.can be issued without cpnservation order_ _ - - _ _ - - - Yes _ _ - - - _ _ 112 Permit_can be issued without administ[ative-approval - - - - - Yes _ - - Appr Date !,13 Can permit be approved before 15-daywait_ - _ _ - _ _ - - . .. Yes - - RPC 6116/2006 ~i14 Well located within area and strata authorized by_Injection Order# (put 10# in comments)-(For- NA- - - - ~115 All wells within 114-mil_e area of review identified (For. sevice well only) - _ .. - - NA_ - - ',16 Pre•produced injector_ duration of pre production less tha43months-(For service welt only) - NA_ ',17 Nonconven. gas conforms to AS31.04,030(j,1.A),~.2.A-D) . _ - - - . - _ - tJA_ _ 118 Conductor stnng_provided - NA- - . - . - ----- Engineering 'I~19 Surface casing protects all known-USDWs - - . - - _ NA 120 CMT-vol-adequate to circulate on conductor& surf csg NA_ - I~121 CMT vol adequate-to tie-in long string to surf csg_ _ _ - _ - - - - - - NA_ - - - - _ ~~22 CMT will cover all known-productive horizon_s_ - - - No_ - - - -Open-hole completion. _ i23 Casing designs adequate for C, T B &-permaf[ost- - - - - - - - - - - - - - - - - NA- - . - . , , .None-planned, - - i24 Adequate an_kage or reserve pit Yes - . - . _ (;TQl1. 25 If a-re-drill, has a 10-403 far abandonment been approved Yes - - - - - - 3/3012006.- - - 'i26 Adequate wellbore separation_p[oposed _ Yes I27 If diverter required, does itmeet-regulations- - - - - - - NA_ - Sidetrack. - - - - ~~28 Drilling fluid program schematic & equip list adequate- - .. - . Yes - - - - UBD operations. approved, Appr Date 29 BOPEs, do they meetregulation - - - - - - - - - - - - Yes WGA 6H9/2006 130 BOPEpress rating appropriate; test to-(put psig incomments)_ - - - - . - Yes - - - - Test tg 3500_psi. -MSP.22.94 psi.- - ~!131 Choke-manifold cornplies w/API-RP-53 (M_ay 84)_ - - .. Yes X132 Work will occur- without operation shutdown _ _ _ - - - - . - - _ _ - _ - _ - Yes _ _ - - - _ X33 is presence of H2$ gas_ probable - - --- - - - - - - - - - - - - - - Yes - . - . - 60- ppm expected, _ - - ',34 Mechanical condition of wells within AOR verified GForservice well only) - - - . NA- - - - - j35 Pefmit can be issued wlohydrogen-sulfide measures - - - _ No- __ _ - - -- Gedlogy I36 Data presented on potential ove-rpressure zones - - NA- _ _ - j37 Seismic analysis of shallow gas zones , . _ . - ------------------------ NA- - - Appr Date 'i38 Seabed condition survey-(ifoff.-shore) - - NA- - - - - - - - RPC 611612006 x!,39 Contact namelphone for weekly-progress reports. [exploratory only] - - - - - - - - - - - - - NA Geologic Commissioner: ~~ Date: ~ f 1 g~~ Engineering C~ioner,: Date ,~~~- ~~~ls~~~0~ Pub' Com ion Date • • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding inlorm~ation, 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 07/05/22 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 06/08/06 1194703 01 2.375 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 9064.0000: Starting Depth STOP.FT 10875.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska) Inc. WELL. WELL: L5-16A FLD FIELD: Lisburne LOC LOCATION: 70 deg 20' 2.754" N 148 deg 14' 8.827" W 178 8' FSL, 19'FWL CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 06-Aug-06 API API NUMBER: 50029217000100 Parameter Information Block #MNEM.UNIT Value Description ----------------- SECT. -------------- 01 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 9~~--0~3 ~ t5aa~ • 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 Outer Downhole Pressure, and Downhole Weight on Bit), a Directional, 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 L5-16 well and this well below casing The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) This well was drilled from L5-16 through a milled window in 4.5" liner: Top of Window 9097.0 ft.MD (8813.8 ft.SSTVD) Bottom of Window 9109.0 ft.MD (8824.8 ft.SSTVD) (8) The interval from 10845.0 ft.MD to 10875.0 ft.MD (8912.2 ft.to 8914.5 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied to L5-16 at 8902.0 ft.MD (8633.6 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 L5-16A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN L5-16A 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 ] 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 MWD 68 1 F/HR 4 4 8 Total Data Records: 44 Tape File Start Depth = 9064.000000 Tape File End Depth = 10875.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 53 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU • WDFN L5-16A.xtf LCC 150 CN BP Exploration (Alaska) WN L5-16A 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 MGJD 6 8 1 AAP I 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 87 Tape File Start Depth = 9064.000000 Tape File End Depth = 10875.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 96 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD • • 06/08/06 1194703 01 **** REEL TRAILER **** MWD 07/05/22 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 9064.0000 -999.2500 -999.2500 9064.5000 18.8417 -999.2500 9100.0000 12.6000 1.0000 9200.0000 32.2000 23.5000 9300.0000 45.4667 52.2000 9400.0000 31.6000 40.9000 9500.0000 129.8000 47.3000 9600.0000 39.2000 28.4000 9700.0000 34.4000 99.9000 9800.0000 15.2000 65.7000 9900.0000 12.7000 56.5000 10000.0000 16.8800 104.2000 10100.0000 34.3000 47.8000 10200.0000 29.4000 42.4000 10300.0000 22.9000 79.1000 10400.0000 27.6500 48.7000 10500.0000 17.2000 15.7000 10600.0000 38.3000 55.0000 10700.0000 23.3000 47.4000 10800.0000 57.4000 41.6000 10875.0000 -999.2500 -999.2500 Tape File Start Depth = 9064.000000 Tape File End Depth = 10875.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GR ROP 9064.0000 -999.2500 -999.2500 9064.2500 19.1000 -999.2500 9100.0000 12.6000 1.0000 9200.0000 32.2000 23.5000 9300.0000 45.4667 52.2000 9400.0000 31.6000 40.9000 9500.0000 129.8000 47.3000 9600.0000 39.2000 28.4000 9700.0000 34.4000 99.9000 9800.0000 15.2000 65.7000 9900.0000 12.7000 56.5000 10000.0000 16.8800 104.2000 10100.0000 34.3000 47.8000 10200.0000 29.4000 42.4000 10300.0000 22.9000 79.1000 10400.0000 27.6500 48.7000 10500.0000 17.2000 15.7000 10600.0000 38.3000 55.0000 10700.0000 23.3000 47.4000 10800.0000 57.4000 41.6000 10875.0000 -999.2500 -999.2500 Tape File Start Depth = 9064.000000 Tape File End Depth = 10875.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet C~ r~ u ~~ Tape Subfile 4 is type: LIS
