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Home My WebLink About207-139• lm~lge Project Well History File hover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q ~ - ~ ~ ~ Well History File Identifier Organizing (acne) ^ Two-sided III II'III II III II III R CAN DIGI AL DATA Color Items: Diskettes, No. ~Greyscale Items; ~Q~~ ^ Other, Norrype; ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Mari - -~--- Scanning Preparation BY: _ Maria Production Scanning P bate: ~ /s/ x 30 = ~ + ~ ~ =TOTAL PAGES (Count does not include cover sheet) Date: Q /s/ IIIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: ~ (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: _~~YES NO BY: Maria Date: I ~ / ~ /s/ ~, l /// Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II (II II II I II II I I III ReScanned II I II II li I I III I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII) III IIII II Date: „Ae,~~~eed~ iuiuuiAiiuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ 10/6!2005 Well History File Cover Page.doc • OF Tire 0. \\I%% THE E STA/E /6., hasa, G:i anoi G':c .? - Cum R !':. ,_ L,,,,I, :\L „._% 1'.� `..-,/,:. d__:, ,- �...+" `u 333 West Seventh Avenue 1-. (�O\ ERIlrOI2 SI-,AN PARv l_L Anchorage Alaska 9950 3572 N tv907 2/9 ,A,,3 John McMullen N�� A� 0 9 2 \ Engineering Team Leader SCP44 BP Exploration (Alaska), Inc. . 0 I'3 a P.O. Box 196612 t 1 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-09C Sundry Number: 314-224 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0- // Daniel T. Seamount, Jr. 1 { Commissioner DATED this/i day of April, 2014. Encl. STATE OF ALASKA RECEIVED ALASK,-,JIL AND GAS CONSERVATION COMMIS.,.ON • APPLICATION FOR SUNDRY APPROVAL APR 0 8 2O14 20 AAC 25.280 1. Type of Request: AOGCC ❑Abandon ®Plug for Redrill ' 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory 0 Stratigraphic Ns 207-139 • 3. Address: 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 ®Development ❑Service \ 50.029-20153-03-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 02-09C • Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10. Field/Pool(s): ADL 028308 • Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11471' • 8871' . 11383' 8876' 10679' None Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" _ 100' 100' 1530 520 Surface 2730' 13-3/8" 2730' 2730' 5380 2670 Intermediate 4644' 9-5/8" 4644' 4476' 6870 4760 Production Liner 6017' 7" _ 3013'-9030' 3012'-8336' 7240 5410 Liner 2593' 4-1/2" 8876'- 11469' 8197'-8871' 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9970'- 11250' 8913'-8878' 4-1/2", 12.6# 13Cr80 8882' Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Packer Packers and SSSV 8805'/8133' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: IN Description Summary of Proposal ®BOP Sketch - 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation, April 25,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston,564-5985 Printed Name: John McMullen 'MH„, y d 0Title: Engineering Team Leader Email: David.Johnston2@bp.com Signature: y/l, at Phone: 564-4711 Date: _ 8, l Commission Use Only Conditions of approval: Notify Commission so that a representative may witness L�— n L 2 ii/ Sundry Number: ❑Plug Integrity 'E BOP Test 0 Mechanical Integrity Test 0 Location Clearance AY r� U qO, Other: 50/' fc6-7 7/.0 35O0 p I .Cl `t 4Itcrhatc p /v% p /aer r �- tet)/J�-oVrcI pry-- ,20 -At-C ZS- 11ZCL ) Spacing Exception Required? 0 Yes []'No Subsequent Form Required: /d — 4 U 7 (--) ....„, 7 % '� APPROVED BY I rfij� Approved By: � COMMISSIONER THE COMMISSION Date: �/d" Form 10-403 Re ' d 1./2012 Appr a gqli�•tr al�p f r 12 months from the date of approval Submit In Duplicate VI- 4115-114 V�IV 1t. cid 4\\�1!�, z/ i %s/, ` il.) f/ /may ' • To: Alaska Oil & Gas Conservation Commission bp From: David Johnston CTD Engineer Date: April 7, 2014 Re: 02-09C Sundry Approval Sundry approval is requested to plug the 02-09C perforations as part of the drilling and completion of proposed 02-09D coiled tubing sidetrack. History and current status: 02-09C was rig sidetracked to its current location in late 2007 to target Zone 1A. This sidetrack work scope restored the IA x OA integrity. The well was completed with a 4-1/2" monobore, which enables this, and future CTD side-tracks. The well reached Marginal GOR rapidly. A plug and perf strategy was unsuccessful in shutting of the gas. There are no additional wellwork options for this bore, and the well is ready for sidetrack. Proposed plan: 02-09D will exit from well 02-09C by the Nordic 1 Coiled Tubing Drilling rig on or around June 1, 2014. The 02-09D sidetrack will exit through the existing 4-1/2" liner and kick off in Zone 1, and target Zone 1A Reserves. The proposed sidetrack is a 2,912' horizontal Ivishak Zone 1 producer, which will access a -48 acre reserves target north of Drill Site 2. The lateral will be completed with a 3-1/2" X 3-1/4" X 2-7/8" L-80 liner which will be Fully cemented and perforated. This Sundry covers plugging the existing 02-09C perforations via the 02-09D liner cement job or a liner top packer set post rig with slick line if Liner lap test fails. (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. F .1. conGvr . GD DSP �"Gi�'� v/ S /7 Dlc� -foo sC � $7-1 0.01 ®'gycCPs, +i.0l Cr w�e4 �P T4U 4'I reoe-v�l/ ��'th/o( C�tr v✓!QK C3cled afif;Ip- o p 0,7 of i�iP filo, r+ for r rOved CCDvQr ft• m r4 l� y/4y Pre-Rig Work (scheduled to begin April 25th, 2014) 1. C Mill 3-1/2" XN nipple at 9321' to 2.80" 2. C Drift to PBTD with dummy whipstock. 3. C FP well to 2,500' with diesel 4. V PT MV, SV, WV. 5. V Set BPV pre rig. 6. 0 Remove wellhouse and level pad. Rig Work (scheduled to begin June 1st, 2014) 71/5 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,368 psi) 2. Pull TWC and Bull Head kill well. 3. Set a 3-1/2" Baker Whipstock (TOWS at 10,362' ELMD). 4. Mill 3.80" window and 10' of rathole. • 5. Drill build: 4.25" OH, 280' (25 deg DLS planned). 6. Drill lateral: 4.25" OH, 2,632' (12 deg DLS planned). 7. Run 3-1/2" x 3-3/16" x 2-7/8" L-80 liner leaving TOL at -9,650' MD. 8. Pump primary cement job: 37 bbls, 15.8 ppg, TOC at TOL -9,650' MD * Pav v z_aqD 9. Perform liner cleanout and MCNL/GR/CCL log. TD 10. Perform liner lap test to 2,400 psi 11. Perforate liner based on log interpretation (-800'). 12. Freeze protect well to 2,500' MD. 13. Set TWC; RDMO. Post-Rig Work 1. 0 Re-install wellhouse, flow line and pull TWC 2._ S Set 45KB liner top packer if needed * 3. S Set GLV's 4. 0 Test Separator *Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) David E. Johnston CTD Engineer 564-5985 CC: Well File Joe Lastufka TREE=. 4-1/16"CNV WELLHEAD= FMC SAFE, /TES:WELL ANNE>-70°@ 9734'. *** ACTUATOR= BAKER 02-09C 2_09C 4-1/2"CHROME TBG'** OKB.ELEV= 58' BE ELEV= 60.43' j I 2011' H9-5/8"HES ES CEUTE/2 KOP= 4597' • Max Angle= 95"@ 10353' 2d"CUPIDUCTOR — ? j • 94#,1+40, 2182' H4-1/2"FES X NP,D=3.813' Datum PAID= 9681' C Datum ND= 8800'SS D=19.124' 2266' H9-5/8"FOC w/CMT BELOW TO 2300' I-9-5/8"CSG,47#,L-80 HY DRL 563,13=8.681" I-- 2026' GAS LFT MANDRELS 3_S M. __ ST PAID TVD DEV TYPE VLV LATCH PORT DATE 13 318"CSG,72#,MN 80,D=12.347" - 2730' 4 2838 2838 2 KBG2-1R DMY BK 0 10/14/13 L 3 5251 4994 27 103G2-1R DMY BK 0 10/14/13 2 7078 6606 26 KBG2-1R DMY BK 0 12/14/07 Minimum ID = 3.725" @ 8869' 1 8654 8000 27 KBG2-1R DMY BK 0 12/14/07 4-112" HES X NIPPLE3013' —9-5/8"x 7"BKR ZXP LNR TOP PKR • ..• w/9.6.11E3KSLV,D 6.30" 0 3029' —19-5/8'X 7"BKR FLEX LOCK LNR I-$GR,0=6.33" • P• 7"LNR,26#,L-80 TC-I XO TO L-80 BTGM 3647' 2 8-1/2"NK.LOUT WINDOW(02-09C) 4644'-4681' WE PSTOCK(11/27/07) --1 4644' ♦.�` ♦♦•♦. Ezsv(11/27/07) —{ 4668' �� 8775' rHESX NP, .813" 8805' --{7"X 4-1/2"BKR S-3 9-5/8"CSG,47#,N-80 XO TO SO-95 BUTT 6618' -0'c I pKR p=3.975" 05-1/2"STUB(11/20/87) H 5826' I-- p L 8839' 14-1/2"HES X NP, I D=3.813" PERFORATION SUMMARY 1 [ 8869' —4-1/2"I IS XN NP, I I iii REF LOG: ?? I 1 D=3.725" ANGLE AT TOP PERF: 85"@ 9970' I 8876' I 7"X S"HR ZXP LIP, ♦♦♦♦♦♦♦♦ . Note:Refer to Roduction DB for historical pert data ♦♦♦♦♦♦♦♦4 SIZE SFF INTERVAL Opn/Sqz SHOT SOZ ♦♦♦♦♦♦♦♦ D• =4.41" 2-7/8" 6 9970-10030 0 12/11/07 ♦•♦•♦deiI' ;•:•:•:- 8882' 14-1/2"VVLEG, 2-7/8" 6 10280-10310 0 12/11/07 •j TREE c 4-1/16"CM/ WELLHEAD- FMC SAFE. ,OTES:WELL ANGLE> 0 @ 2. ,AcTUATOR= BAKER PROPOSED 02 -09D *"*4-1/2"CHROME TBG*** OKB.ELEV= 58' BF.ELEV= 60.43' �4 2011' —19-518"HES ES CEMENTER KOP= 4597' 4 Max Angle= @ 20"CONDUCTOR, — ? 0 Datum MD=. _ 94#,H-40, is 2182' —14-1/2"HES X NP,D=3.813" Datum TVD= 8800'SS D=19.124' 0 ' 2266' H 9-5/8"FOC w/CMT BELOW TO 2300' Y9-5/8"CSG,47#,L-80 HYDRL 563,D=8.681" H 2025' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,MN-80,ID=12.347" H 2730' 4 '2838 2838 2 KBG2-1R DMY BK 0 10/14/13 3 5251 4994 27 KBG2-1R DMY BK 0 10/14/13 2 7078 6606 26 KBG2-1R DMY BK 0 12/14/07 Minimum ID = 3.725" @ 8869' I 1 8654 8000 27 KBG2-1R DMY BK 0 12/14/07 4-1/2" HES X NIPPLE iii 3013' —9-5/8"X 7"BKR ZXP LNR TOP PKR 7"LNR,26#,L-80 TC-II XO TO L-80 BTC-M — 3547' s w/9.6'TIEBK SLV, D=6.30" 4\ 3029' H 9-5/8"X 7"BKR FLEX LOCK LNR HGR,D=6.33" WHIPSTOCK(11/27/07) —1 4644' • 9-5/8"CSG,47#,N-80,ID=8.681" H -4644 \\ 8-1/2"MILLOUT WINDOW(02-09C) 4644'-4681' 1 8775' -14-1/2"HES X NP, D=3.813" C Z:1-- 8805' —17"X 4-1/2"BKR S-3 PKR,D=3.875" 8839' H4-1/2"HES X NP,ID=3.813" ' 1--- 8869' —11.-1/2"HES XN NP MLLED TO 3.80"(_/_/ ) 8876' —17"X 5"HR ZXP LTP,D=4.441" 4-1/2"TBG, 12.6#,13CR-80 VA TOP, —1 8882' .0152 bpf,ID=3.958" 8882' —14-1/2"WLEG,D=3.958" 8898' -�7"X 5"FLIXLOCK LNR HGR D=4.430" 7"LNR,26#,L-80 BTC-M, .0383 bpf,D=6.276" —1 9030' , 8908' —15"X 4-1/2"XO,D=3.958" TOC(_ —9650' 9650 —13.70"DEPLOYMENT SLEEVE,D=3.00" 3-1/2"LNR,9.3#,L-80 c. ,_0087 bpf,D=2.992" H 9690 4-1/7"WHIPSTOCK(_/_/_) H 10362' <I I � 9680' 3 1/2^HES X NP,D=2.813' 4-1/2"LNR, 12.6#,L-80 BT-M, H -10632 s -I3-112"X 3-3/16"XO,D=2.786" x .0152 bpf,D=3.958" w i PERFORATION SUMMARY 4 REF LOG: R 4-1/2"MLLOUT WINDOW(02-09D) 10362'-10372' ANGLE AT TOP PERF: 85°@ 9970' \�` k I, Note: Refer to Production DB for historical perf data 1 k SIZE SPF INTERVAL Opn/Sqz SHOT SQZ w k 2-7/8" 6 9970- 10030 0 12/11/07 10842' -13-3/16"X 2-7/8"XO,D=2.377" 2-7/8" 6 10280-10310 0 12/11/07 2-7/8" 6 10340-10660 0 12/11/07 :, 2-7/8" 6 10710-11050 C 12/11/07 0, , 2-7/8" 6 11210-11250 C 12/11/07 3-1/4"LNI 6#,L-80 TCII,.0079 bpf,D=2.850" --I 10842' PBTD 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" —1 13274' DATE REV BY COMIV6'ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/02/76 PKR 141 ORIGINAL COMPLETION WELL: 02-09': 12/11/80 N1 ES RWO PERMIT No: 06/12/96 N3S CTD(02-09A) API No: 50-029-20153-04 08/19/97 N4/3S CTD(02-09B) SEC 36,T11 N,R14E, 1216'FNL 8 971'FWL 12/14/07 N2ES SIDETRACK(02-09C) '14 JMD BULT PROPOSAL BPExpbration(Alaska) F, ® 11§' -I « a . b m f LLa 41i i 8 E o UM 8 € " - 111 II I I m- 2 04;4 .. . il ell 0 - g ig ,. . . . I I --- . S m H Oil ■ U 2,289. p : 9 ' I loc_I I ni a n CI I II : I ILII = II O o ) 1 1111 III x I _ » LL �ii 8 1 o a 0 - 0 . m 1 Z @ 1 s F\ILI -�- I111 a III a Q I I 8 !i 2 I I I III 1 ji O • 1 •O 1 0U U ES 1- j N I ill I11 Niga 1 : 0 o� Eo „ el .q i •i11 ii i • 111 I Pi .MI6 lif I� _ •�� _ . aia o1a _ 11 J 1 liii W II g 01 0 I , 1 2 ' U 2 (9 i re 1 licl �/� � H_ 5 y K V/ a > J 1 I $I Q I S U 1 1 V g I i mi O o' Im z rc Z NO 12 I N b 1- v y e K « s W_ 1w11 I o8 I 1)11Eir]_M G 1no 1 I rcIII q I I 111=U11 I 11 = Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIllntegrityCoordinator @bp.com] Sent: Saturday, October 19, 2013 8:54 PM To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 Drillsites; G GPB FS1 DS; AK, OPS FS1 DS2 Operator; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; Peltier, Megan; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer 02-09C (PTD#2071390)OA over MOASP Attachments: Producer 02-09C TIO Plot 10-19-13.docx; 02-09C Wellbore Schematic.pdf All, Producer 02-09C(PTD#2071390) OA pressure went over MOASP with the TBG/IA/OA=530/480/1200 psi on October 17, 2013 after failing an MIT-IA.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. DHD: Re-attempt MIT-IA, monitoring OA trends 2. WIE: Further diagnostics as needed A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer SCANNED 1,c)•.Di ghro,r) BP Alaska - Well Integrity Coordinator GING al Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator PBP.com 1 Producer 02-09C (PTD#2071390) TIO Plot 10/19/2013 1.1:020 4 MO • 10130 • +711 2000 00 000 -0006 • • • • 000 072013 011713 019013 00/1013 06'11113 0024/13 01113 0501113 991113 09113 0921113 100513 100203 119112 • • • TREE= 4-1/16"CIW WELLHEAD= FMC SAFETY NOTES:***4-1/2"CHROME TBG ACTUATOR= BAKER 0 2-0 0 C KB.ELEV= 58' BF.ELEV= 60.43' • I 2011' H9-5/8"HES ES CEMENTER KOP= 4597' 20"CONDUCTOR, ? • Max Angle=95°@ 10353' • 94#,H-40, • 2182' -14-1/2"HES X NIP, ID=3.813" I Datum MD= 9681' �4 Datum TVD= 8800'SS ID=19.124' 2266' H 9-5/8"FOC w/CMT BELOW TO 2300' I 9-5/8"CSG,47#,L-80 HYDRIL 563, ID=8.681" H 2025' GAS LIFT MANDRELS STI MD TVD DEV I TYPE VLV I LATCH PORT DATE 13-3/8"CSG,72#,MN-80,ID=12.347" H 2730' 4 2838 2838 2 KBG2-1R DOME BK 16 01/01/08 3 5251 4994 27 KBG2-1R SO BK 20 01/01/08 2 7078 6606 26 KBG2-1R DMY BK 0 12/14/07 Minimum ID = 3.725" @ 8869' 1 8654 8000 27 KBG2-1R DMY BK 0 12/14/07 4-1/2" HES X NIPPLE 3013' i 9-5i8"X7"BKR ZXP LNR TOP PKR • ■ w/9.6'TIEBK SLV, ID=6.30" • • t 3029' H 9-5/8"X 7"BKR FLEX LOCK LNR HGR, ID=6.33" I 7"LNR,26#, L-80 TC-Il XO TO L-80 BTC-M H 3547' t 8-1/2"MILLOUT WINDOW(02-09C) 4644'-4681' • WHIPSTOCK(11/27/07) --I 4644' ��♦ EZSV(11/27/07) --I 4668' '� 8775' i-4-1/2"HES X NIP, ID=3.813" 8805' I-17"X 4-1/2"BKR S-3 9-5/8"CSG,47#,N-80 XO TO SO-95 BUTT H 5618' I- x PKR, ID=3.875" 5-1/2"STUB(11/20/87) —I 5826' i — 17,1 8839' I 4-1/2"HES X NIP, I p IID=3.813" I.� I 8869' I—4-1/2"HES XN NIP, PERFORATION SUMMARY fl I I I�ID ID=3.725" REF LOG: 2', I t ANGLE AT TOP PERF: 85°@ 9970' *1•••••••• 8876' I 7"X 5"HR ZXP LTP, 1♦♦♦♦♦♦♦♦• ID=4.41" Note:Refer to Production DB for historical perf data ••♦•♦•♦♦• SIZE SPF INTERVAL Opn/Sqz DATE �.••••4 j 1'4 11 2-7/8" 6 9970- 10030 0 12/11/07 .♦♦♦♦� 1 8882' I�4-1/2"WLEG, 2-7/8" 6 10280-10310 0 12/11/07 M1 .♦♦♦♦♦ / 1\ ID=3.958" 2-7/8" 6 10340-10660 0 12/11/07 ♦•' •♦I 8898' I�7"X 5"FLEX LOCK 2-7/8" 6 10710-11050 C 12/11/07 •♦♦• •• LNR HGR,ID=4.430" 2-7/8" 6 11210-11250 C 12/11/07 .♦�• ♦♦ 8908' H 5"X 4-1/2"XO, ♦♦� •♦1 •♦♦1- ID=3.958" 9-5/8"CSG,47#,SO-95 BUTT,ID=8.681" H 9021' •♦♦1 I IJ 10679' I�4-1/2"CIBP i�i1 Ξ1 (02/19/10) R I ►♦�•••. PBTD H 11383' I 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, .0152 bpf,ID=3.958' 8882' 7"LNR,26#,L-80 BTC-M, .0383 bpf, ID=6.276" 9030' 4-1/2"LNR, 12.6#,L-80 IBT-M,.0152 bpf, ID=3.958" H 11469' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/02/76 PKR 141 ORIGINAL COMPLETION 01/18/08 TMP/PJC DRLG DRAFT CORRECTIONS WELL: 02-09C 12/11/80 N1 ES RWO 03/17/10 ACB/SV SET CIBP(02/19/10) PERMIT No: '2071390 06/12/96 N3S CTD(02-09A) 01/07/12 SET/PJC GLV C/O(01/01/08) API No: 50-029-20153-03 08/19/97 N4/3S CTD(02-09B) SEC 36,T11 N, R14E, 1216'FNL&971'RAIL 12/14/07 N2ES SIDETRACK(02-09C) 01/09/08 SWC/SV GLV C/O&CORRECTIONS BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 RFC eivE Mr. Tom Maunder 4116 3 20 r Alaska Oil and Gas Conservation Commission Maki ne 333 West 7 Avenue & G at Coo, co Anchorage, Alaska 99501 Anct ssron Subject: Corrosion Inhibitor Treatments of GPB DS -02 ( 2 , O7 - ) 3 Dear Mr. Maunder, " 0 c am Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -328 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -338 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 i i ~~~ ~, }-~ ~~ ~-- ~. ~~, . ~~ _ ~~ 2 ~ z ~+' s, v~ _. .~F; ;~ ~, =~~{ .. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Maricer.doc DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071390 Well Name/No. PRUDHOE BAY UNIT 02-09C MD 11471 TVD 8871 Completion Date 12/14/2007 REQUIRED INFORMATION Mud Log No Samples No Directional Su y Yes " DATA INFORMATION Types Electric or Other Logs Run: USIT / GR / CCL (for new 9-5/8"), MWD DIR / GR / PWD, MWD DIR / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number ame r'ED ~ C Las 15945 nduction/Resistivity ~ ~E p ~ D Asc Directional Survey // ~'Rpt Directional Survey /'i,Ffpt LIS Verification ED C Lis 1626~nduction/Resistivity og Induction/Resistivit y :grog Induction/Resistivity C 17126~ee Notes 4600 11471 Open 2/25/2008 LAS DHRO, RPM, FCNL, GR, NCNL, NPHI, RHOB, RPD, RPS, RPX w.PDF graphics 25 11471 Open 3/7/2008 25 11471 Open 3/7/2008 4350 11471 Open 5/19!2008 LIS Veri, GR, ROP, RPS, FET, RPM, RPX, NPHI, FCNT, NCNT, DRHO, RHOB, PEF 4350 11471 Open 5/19/2008 LIS Veri, GR, ROP, RPS, FET, RPM, RPX, NPHI, FCNT, NCNT, DRHO, RHOB, PEF 25 Col 4644 11471 Open 11/3/2008 MD ROP, EWR, DGR, ALD, CTN 9-Dec-2008 25 Col 4644 11471 Open 11/3/2008 TVD ROP, EWR, DGR, ALD, CTN 9-Dec-2008 0 0 Open 11!3/2008 PDS, EMF and CGM of EWR logs Well Cores/Samples information: Name Operator BP EXPLORATION (ALASKA) INC Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20153-03-00 UIC N Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071390 Well Name/No. PRUDHOE BAY UNIT 02-09C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20153-03-00 MD 11471 TVD 8871 ADDITIONAL INFORMATION Well Cored? Y f~ Chips Received? Y~ % N Analysis Y / N Received? Comments: Completion Date 12/14/2007 Completion Status 1-OIL Daily History Received? Formation Tops _. __ - _ _~ Compliance Reviewed By; __ Current Status 1-OIL N N UIC N _ .__ -- Date.- - - - _QRL /~~~ -- • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 02-09C October 30, 2008 AK-MW-5194551 02-09C: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20153-03 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20153-03 Digital Log Images: 1 CD Rom 50-029-20153-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273=3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ ~~~ -r3~ '~ 1 ~ r a ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska April 30, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 02-09C AK-MW-5194551 1 LDWG formatted CD rom with verification listing. API#: 50-029-20I 53-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _ y _~ f ~_~ } ~. ~, Date: _ y } ~~~ <, ~,~~, BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 /! I Signed: V ~~~~~ ~~j ~l~Oa~Ov 06-Feb-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 02-09C Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 4,599.11 ' MD Window /Kickoff Survey: 4,644.00' MD (if applicable) Projected Survey: 11,471.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~ g Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~„~~-r3~ Date 02-25-2008 Transmittal Number:92929 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 elivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ?-09C o~U'f- 139 ~'Ib9~/`mar L-219 U~~-' 20~-- t~(~ '"-59y°[ 15-04B ~0-~_[3~s '~ tS'9yG 15-04BPB1 O'~o~'[3b ~/59'S/'.} 19 ~~5¢ fwa are roof ct..or~ec~F. die i}P.I' ~#' )3~~ j't'l ~l-I -l9 ~ awe v~of dare i~ you pub ~•f~e 19L1 ~~ f Yl~l ~kl- i 9 ~ l Ple'a~e Sign at~d Retlt~one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 %~-~ ~ rt~-se. ~~nFi~(-Ibte - `~~~ E~L.L) F~ ~ ~Il()ti ~~a~~~ ~lil t~tt~ ~~t~t1Ss ~.~tittttli~~~AtPlk ~tl~hat~ w. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1.2 • ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com) Sent: Monday, February 04, 2008 11:12 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 02-09C / PTD # 207-139 Hi Art, Please reference the following well: Well Name: PBU 02-09C Permit #: 207-139 API #: 50-029-20153-03-00 Top Perf MD: 9970' Bottom Perf MD: 11250' This well began Production on January 31, 2008 Method of Operations is: Flowing Date of Test: 02f01 /08 Hours Tested: 8 24-Hour Rate /Oil-Bbl: 3,144 24-Hour Rate 1 Gas-Mcf; 7,355 24-Hour Rate !Water-Bbl: 107 Test Rate /Oil-Bbl: 1,048 Test Rate /Gas-Mcf: 2,452 Test Rate /Water-Bbl: 36 Choke Size: 59 Gas-Oil Ration: 2,340 Flow Tubing Pressure: 589 Casing Pressure: 1,120 Oil Gravity-APi: Unavailable 2/4!2008 ~~~~1 ~/ GL.d STATE OF ALASKA ~a ~~ ~$ ALASKA~IL AND GAS CONSERVATION COM~SSION JAN ~ 1 2.Q WELL COMPLETION OR RECOMPLETION REPORT AND Lm~'aka Ciil ~ la~;~ ~Ans~ ~01~1155~~~ Anchorage w_w.::__~.v>; 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 12/14/2007 _p.J 12. Permit to Drill Number 207-139 i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/28/2007 ° 13. API Number i 50-029-20153-03-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/9/2007 14. Well Name and Number: PBU 02-09C~ 4064 FSL, 4308 FEL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 537' FSL, 1806' FEL, SEC. 25, T11 N, R14E, UM 8. KB (ft above MSL): 57.11' Ground (ft MSL): 30.3' - 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2118' FSL, 2317' FEL, SEC. 25, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11383 8876 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687729 y- 5949988 Zone- ASP4 10. Total Depth (MD+TVD) 11471 8871 16. Property Designation: ADL 028308 ~ TPI: x- 690186 y- 5951803 Zone- ASP4 Total Depth: x- 689634 y- 5953371 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electroni and rinted information r 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): L//~' ~ ~ ~6 D USIT / GR / CCL (for new 9-5/8"), MWD DIR / GR / PWD, MWD DIR / GR / RES / AZI DENS / NEU, ~~~$:9 j'~''Q 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2 94# H-40 Surface 100' urface 10 ' 32" 300 sx Permafrost II 13-3/8" 72# MN-80 Surface 2130' Surface 2130' 17-1/2" 661 sx Class'G' 5300 sx PF II 9-5/8" 47# L~0/S00-95lN~0 Surface 4 Surface 4476' 12-1/4" 750 sx Class'G' 7" 26# L-80 3013' 9030' 3012' 33 ' 8-1/2" 277 sx Class 'G' 169 x Class 'G' 4-1/2" 12.6# L-80 8876' 11469' 8197' 8872' 6-1/8" 327 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuewG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 8882' 8805' MD TVD MD TVD 997!)' - 10030' 8913' - 8919' 10280' - 10310' 8912' - 8910' '25. Aclo, FRACTURE, CEMENT SQUEEZE, ETC. 10340' - 10660' 8908' - 8893' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 10710' - 11050' 8892' - 8878' 11210' - 11250' 8879' - 8878' 2200' Freeze Protect w/ 158 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATeD 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per~-- 71. JU~L~1 I_t- i~~• None "~~ ~~'~. ~t~N ~ ~ 7Q~~ ~`'b Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9033' 8339' None Shublik 9075' 8376' Sadlerochit 9155' 8445' Zone 4A / 42S6 9280' 8551' Top CGL /Zone 3 9359' 8617' Base CGL /Top Zone 2C 9445' 8687 Zone 2B / 23S6 9516' 8744' Zone 2A / 21 TS 9629' 8827' Zone 1 B 9716' 8874' Zone 1A /TDF 9804' 8900' Base Sadlerochit 10030' 8919' Base Sadlerochit 11294' 8878' Formation at Total Depth (Name): Zone 1A /TDF 9804' 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. d l Signed Terrie Hubble Title Drilling Technologist Date /! ~ 68 PBU 02-09C 207-139 Prepared By NameMumber.~ Terrie Hubble, 564-4628 Well Number Permi No. / A rOVal NO. Drilling Engineer: Travis Peltier, 564-4511 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: Method of Operation: Flowing, Gas Litt, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off. Test Summary Legal Name: 02-09 Common Name: 02-09 Test Date Test Type Test Depth (TMDJ Test Depth (ND) AMW Surface Pressure Leak Off Pressure (BHP) EMW 11/28/2007 FIT 4,681.0 (ft) 4,505.0 (ft) 9.30 (ppg) 750 (psi) 2,926 (psi) 12.50 (ppg) 12/4/2007 FIT 9,030.0 (ft) 8,336.0 (ft) 8.40 (ppg) 1,040 (psi) 4,678 (psi) 10.80 (ppg) r: Printed: 12/20/2007 1:29:01 PM BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date.. From - To Hours Task Code NPT Phase Description of Operations 11/14/2007 22:00 - 00:00 2.00 MOB P PRE Start Moving Sub From Drill Site 14 to Drill Site 2 11/15/2007 00:00 - 15:00 15.00 RIGU P PRE Continue with Rig Move to Drill Site 2 -Move Sub to DS 02 -Place Herculite and berming -Spot over well -Raise Derrick and pin -Raise Cattle chute -R/U Service Loop and Service lines -Bridle Down -Spot Pits ,Shop & Camp -Finish Rigging up intertconnects and equipment Accept Rig @ 15:00 Hrs 15:00 - 16:00 1.00 WHSUR P DECOMP Conduct Pre-spud meeting with Rig Crew -Take on Seawater 16:00 - 17:00 1.00 WHSUR P DECOMP Rig up to to test Tubing and IA -Rig up Secondary annulus valves 17:00 - 21:00 4.00 WHSUR P DECOMP PJSM with DSM and Rig Crews -R/U DSM Lubricator and test to 1000 psi against master valve -Master Valve leaking tested against Swab Valve -Good Test -Pull BPV 21:00 - 23:30 2.50 WHSUR P DECOMP PJSM on test Tubing and IA -R/U and Test to to 2125 psi on 5 1/2" tubing -Test held for 30 minutes and charted, good test -R/U on IA and test to 2000 psi, 18.5 bbls to pressure up -OA tracked to 2000 psi when testing IA -Test held for 30 minutes and charted, good test -R/D lines and blow down 23:30 - 00:00 0.50 WHSUR P DECOMP Rig Schfumberger slickline unit -PJSM with SWS personnel and NAD crew 11/16/2007 00:00 - 01:30 1.50 WHSUR N SFAL DECOMP Unable to Get Schfumberger slickline unit running -SWS mechanic repaired unit 01:30 - 03:30 2.00 WHSUR P DECOMP Hang sheaves and install Lubricator extension, Pump In Sub, Wireline BOP's, slickline Lubricator 03:30 - 04:30 1.00 WHSUR P DECOMP Pressure test lubricator to 1000 psi, good test -Rig up tools to run downhole 04:30 - 07:00 2.50 PULL P DECOMP RIH with slickline to Pull POGLM at 3944' -Unable to release POGLM, POH 07:00 - 08:30 1.50 PULL P DECOMP RIH to 3944' with 4.55" GR, POH 08:30 - 13:00 4.50 PULL P DECOMP RIH with PRT tool to pull POGLM -Parted Slick line @ 3928' -Tie Line together and Pull off of POGLM 13:00 - 16:00 3.00 PULL N SFAL DECOMP Switch over to Braided Line -Test Lubricator to 1000 psi for 5 min, good test 16:00 - 22:00 6.00 PULL P DECOMP RIH and Latch on to POGLM, Jar and released POGLM -POH w POGLM to SSSV @ 2225', Unable to Pull through -Work on Pulling and Jaring POGLM up through SSSV without success -PRT tool unlatched from POGLM POH with PRT to Check Tools 22:00 - 00:00 2.00 PULL P DECOMP Change over tools to 4.55 gauge ring -RIH to top of POGLM @ 2225' Printed: 12/20/2007 1:29:11 PM BP' EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2007 22:00 - 00:00 2.00 PULL P DECOMP -POH with GR -Change over tools to push POGLM down out of SSSV 11/17/2007 00:00 - 03:00 3.00 PULL P DECOMP Finish Changing over tools to Push POGLM down out of SSSV -RIH and Push POGLM out of SSSV -Pushed down to 5790' -Unable to push down beyond 5790' 03:00 - 05:00 2.00 PULL P DECOMP Rig Down SWS slickline unit 05:00 - 08:00 3.00 WHSUR P DECOMP Rig up to tree with circulation lines and displace diesel freeze protect first from the tubing (~50 bbls) and then from the IA (--100 bbls of diesel) with hot (110 degrees) seawater. 3 bpm / 500 psi Taking diesel returns to cuttings tank. Verify the well is dead. 08:00 - 12:30 4.50 WHSUR P DECOMP Dry Rod BPV -Nipple Down Tree & Adaptor -Hanger Neck Welded -Unable to Seat Blanking plug, Brought out another one and Run in with 9 1/4 turns, Verified retrieval Tool - 8 1/4 Left Hand turns 12:30 - 15:00 2.50 BOPSU P DECOMP Nipple up BOP stack and riser -Hook up Lines and turnbuckles 15:00 - 17:00 2.00 BOPSU P DECOMP PJSM on Testing BOP's With NAD Rig Crews, NAD TP, BP WSL -Ri up to test BOP's, -Attempt to test, Unable to Pressure up, -Pressure leaking through blanking plug 17:00 - 20:30 3.50 BOPSU N SFAL DECOMP Trouble Shoot problem with the Blanking plug leaking -FMC Pulled Plug ,inspected and change out ball -Reinstall Blanking Plug -Attempted to test, plug still leaking by 20:30 - 22:00 1.50 BOPSU N SFAL DECOMP Mobilize DSM, Storm packer for tubing, and 2 7/8" PAC pipe 22:00 - 23:30 1.50 BOPSU P DECOMP R/U Lubricator extension and DSM Lubricator -Test to 1000 psi for 5 min -Pull BPV -R/D DSM Lubricator and Extension 23:30 - 00:00 0.50 BOPSU N SFAL DECOMP Rig up to Run Storm packer into 5 1/2" tubing to test BOP's 11/18/2007 00:00 - 00:30 0.50 BOPSU N SFAL DECOMP R/U to run 2 7/8" PAC. pipe below storm packer 00:30 - 02:30 2.00 BOPSU N SFAL DECOMP P/U 38 joints of 2 7/8" PAC for weight under HES RTTS 02:30 - 03:30 1.00 BOPSU N SFAL DECOMP Set RTTS @ 60' 03:30 - 09:00 5.50 BOPSU P DECOMP Test BOPE to 250 psi low, 3500 psi high. -Test witness waive y o o e wit CC. - Test witnessed by WSL Dave Newlon and Joey LeBlanc, TP Bruce Simonson and Charlie Henley -Test 1 Blind Rams, Choke Manifold valves 1,2,3, HCR Kill -Test 2 ,Choke Manifold valves 4,5,6 -Test 3 ,Choke Manifold valves 7,8,9 -Test 4 ,Manual And Super Choke to 1000 Psi -Test 5 ,Choke Manifold valves 10,11 -Test 6 ,Choke Manifold valve 15 Install 5 1/2" Test Joint -Test 7 Annular to 250 low and 2500 psi high Test On Upper Rams Failed 09:00 - 11:00 2.00 BOPSU N SFAL DECOMP Change out 3.5" x 6" Variable Rams Bodies in Upper Pipe Printetl: 12/20/2007 1:29:11 PM BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2007 09:00 - 11:00 2.00 BOPSU N SFAL DECOMP Rams 11:00 - 13:00 2.00 BOPSU P DECOMP Finish Testing BOP Test 13:00 - 16:30 I 3.501 BOPSUR N 16:30 - 19:00 I 2.501 PULL I P 19:00 - 22:30 I 3.501 PULL I P 22:30 - 00:00 I 1.501 PULL P 11/19/2007 100:00 - 02:00 I 2.001 PULL I P 02:00 - 03:30 I 1.501 PULL I P 03:30 - 05:30 I 2.001 PULL I P 05:30 - 06:30 I 1.00 I PULL I P 06:30 - 07:30 I 1.001 PULL I P 07:30 - 15:30 I 8.001 FISH I P 15:30 - 17:00 1.50 PULL P 17:00 - 22:30 5.50 BOPSU P -Test 8, Upper Pipe Rams and Dart -Test 9, TIW Surface Vatve, Manual Kill, HCR Choke -Test 10, manual IBOP on TDS ,Manual Choke SFAL DECOMP R/U to Retrieve RTTS -Pick up RTTS Stinger and running tool -Flush debris -Check for pressure under RTTS -Release RTTS -L/D Running Tool and RTTS -L/D 2 7/8 Pac Pipe -R/D Running Equipment DECOMP PJSM, with SWS and NAD Rig Crew -R/U SWS, BOP's Pump in sub and Extension -Test to 1000 psi for 5 min, O.K. DECOMP RIH with 4.35 gauge Ring and Junk basket -Tag POGLM @ 5862 -Set down on POGLM, no movement -POOH, Minimal Rust in junk Basket DECOMP RIH with 4.15 Jet Cutter -Tag POGLM @ 5862' -Fire SCP Jet Cutter @ 5812' DECOMP POOH with Jet cutter -R/D SWS and clear floor of Wireline equipment DECOMP Rig Up To Pull Tubing P/U Handling equipment from outside Power Tongs, Slips and elevators Make up Spear DECOMP PJSM -Spear Tubing and Pull to confirm Latch -Back out Lock Down Screws and Control line Tubes -Attempt to Pull Tubing hanger to Floor, Pulling 220k -Steam Tubing Spool for 30 min -Pull 120k and Pulled hanger to floor DECOMP CBU @ 485 gpm / 350 psi, -Monitor well, Static -8.5 Seawater in and out DECOMP L/D Tubing Spear and Lay Down Landing Joint -Break out Hanger and Lay Down -Rig up control line Spooling Unit DECOMP La Down 5 1/2" #17 L-80 8 round tubin -145 full joints, (jt # 98 was tubing punched) -2 pup joints, -SSSV Landing Nipple 4 S.S. bands and 29 control line clamps -1 cut joint @ 20.92', Flared to 6.25" DECOMP Rig Down Handling equipment and Clean Floor of extra tools and equipment DECOMP PJSM on testing BOP's -Install Test Plug, Attempted to test, Leaking past test plug -Pull Test plug and inspect, no visible deficiencies seen -Make up another plug that was brought out by FMC tech Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2007 17:00 - 22:30 5.50 BOPSU P DECOMP Ran one 6 1/4" SDC, Double pin XO on bottom of Test plug RIH with test joint ,Seat Test Plug and lock in Test Top and bottom set of Rams to 250 psi low and 3500 psi high Test Bag to 250 Low and 2500 psi high All Good tests, All test held for 5 minutes and charted Test Witnessed by NAD TP Bruce Simonson, BP WSL Dave Newlon, Witnessing of test waived by AOGCC Bob Noble R/D Test Equipment, Plug, SDC & XO Install Wear Ring, 9" ID 22:30 - 00:00 1.50 PULL P DECOMP PJSM on Picking up BHA -Make up overshot fishing BHA 11/20/2007 00:00 - 01:30 1.50 FISH P DECOMP Finish picking up Fishing BHA to 868'. 01:30 - 05:00 3.50 FISH P DECOMP RIH picking up 4" DP to 5809'. Install blower hose. Rack back one stand and pick up DP single. 05:00 - 05:30 0.50 FISH P DECOMP Up weight 145k, down 130k, RT 140k. Free torque 3.5k. Pump at 126 gpm with 130 psi. Wash and ream over fish with 1-3k WOB. 05:30 - 09:00 3.50 FISH P DECOMP Pull and Jar pipe with 300k to 375k up. Max dead pull 400k. Continue to jar with no success. Perform blind back off. Pick up free at 150k. 09:00 - 12:00 3.00 FISH P DECOMP PJSM. Perform inspection of derrick, top drive and draworks. 12:00 - 14:30 2.50 FISH P DECOMP POOH to 868'. Change out handling equipment. 14:30 - 16:00 1.50 FISH P DECOMP POOH with 5-1/2" fish at 18.38'. Pin looking down. Break and lay down overshot and fish. Clear and clean floor. 16:00 - 17:00 1.00 CLEAN P DECOMP Wait on orders from town. 17:00 - 18:30 1.50 CLEAN P DECOMP PJSM. Pick 9-5I8" casing scraper BHA up beaver slide. Steam and prep tools.. 18:30 - 20:30 2.00 CLEAN P DECOMP PJSM. Make up 9-5/8" casing scraper BHA to 888'. Change out handling equipment. 20:30 - 00:00 3.50 CLEAN P DECOMP RIH picking up 4" DP to 5558'. Up weight 140k, down 125k. 11/21/2007 00:00 - 01:00 1.00 CLEAN P DECOMP RIH picking up 4" DP to 5828'. Tag top of 5-1 /2" tubing. Rack back one stand. 01:00 - 02:00 1.00 CLEAN P DECOMP Pump hi-vis sweep surface to surface at 500 gpm with 1700 psi. Pump dryjob, blow down top drive. 02:00 - 03:00 1.00 CLEAN P DECOMP PJSM. Cut and slip 95' of drilling line. Lube Elmago Splines. Inspect traction motor brushes. 03:00 - 03:30 0.50 CLEAN P DECOMP Service top drive, crown and draworks. 03:30 - 05:00 1.50 CLEAN P DECOMP POOH with 9-5/8" scraper assembly to 888'. 05:00 - 07:30 2.50 CLEAN P DECOMP POOH with 9-5/8" scraper BHA. Clear floor. 07:30 - 08:45 1.25 EVAL P DECOMP PJSM. Spot E-line unit. PU and rig up for logging run. 08:45 - 09:00 0.25 EVAL N DFAL DECOMP Troubleshoot USIT which failed during surface test. Change out USIT cartridge and re-test - OK. ', 09:00 - 15:30 6.50 EVAL P DECOMP RIH and log up from 5000' with USIT/CCL/GR:in cement and corrosion mode. POOH and lay down tools. 15:30 - 17:15 1.75 DHB P DECOMP Make up lubricator extension, pump in sub, pack off and EZSV tools. Trouble with surface test. 17:15 - 18:00 0.75 DHB N DFAL DECOMP Troubleshoot tools. Replace GR tool. Make up EZSV. Pressure test to 500 psi - OK. 18:00 - 21:30 3.50 DHB P DECOMP RIH with EZSV on E-line and set with top at 4668'. POOH. CO tools. 21:30 - 00:00 2.50 DHEOP P DECOMP Pressure test to 500 psi - OK.. RIH with string shot to 2020'. Printed: 12!20/2007 1:29:11 PM ~' • $P EXPLORATION Page 5 of 19 C3perations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date ~ From - To ~ Hours I Task I Code ~ NPT (..Phase I Description of Operations 11/21/2007 21:30 - 00:00 2.50 DHEOP P DECOMP Shoot from 2014' to 2026'. POOH. Rig down E-line unit. 11/22/2007 00:00 - 01:30 1.50 ZONISO P DECOMP Make up 9-5/8" RTTS and RIH on 4" DP. 01:30 - 03:00 1.50 ZONISO P DECOMP Purge system of air. Set RTTS at 2350'. Test casing to psi for 30 minutes. Test - OK. Pull up to 2299'. Test cas 03:00 - 04:00 1.00 ZONISO P DECOMP POOH to RTTS. 04:00 - 04:30 0.50 ZONISO P DECOMP Break out and lay RTTS down beaver slide. 04:30 - 06:00 1.50 FISH P DECOMP PJSM. PU/MU casing cutter, XO, stabilizer, DC and HWDP to 834". 06:00 - 07:00 1.00 FISH P DECOMP RIH to 1957'. Install blower hose. 07:00 -08:30 1.50 FISH P DECOMP Pump at 170 gpm with 300 psi. Torque 1k at 30 rpm. Up, down and RT weight 90k. Wash down and tag collar at 2021' for verification. Pull up and cut casing at 2001'. Pump at 200 gpm with 410 psi. Torque 1.4k to 3.2k at 30 rpm. Increase to 365 gpm with 610 psi. Open OA to cuttings tank and establish pumpulation. Shut in OA. Blow down top drive and remove blower hose. 08:30 - 13:00 4.50 FISH P DECOMP PJSM. Rig up head pin and circulating lines to top drive. Pressure test LRS lines to 3000 psi - OK. Displace drill pipe with diesel. Close bag. Line up and pump 160 bbls of 140 degree diesel displacing arctic pak from OA to cuttings tank at 63 gpm with 400 psi. Follow with 30 bbl soap pill and displace OA with clean 110 degree seawater. Pump seawater at 190 gpm with 450 psi. Rig down and blow down circulating lines. Monitor well -static. OA = 0 psi. 13:00 - 14:00 1.00 FISH P DECOMP POOH to 834'. Change out handling equipment. 14:00 - 15:30 1.50 FISH P DECOMP POOH with cutter BHA. Lay down cutter. Pull wear ring. 15:30 - 17:00 1.50 BOPSU P DECOMP Make up 9-5/8" packoff running tool. PJSM. RIH and J into packoff. De-energize packoff with 2 left hand turns. Back out lock down screws, (BOLDS). Pull packoff with 20k. Pull to rig floor and LD. 17:00 - 18:00 1.00 BOPSU P DECOMP Shut down for Thanksgiving dinner. 18:00 - 21:00 3.00 BOPSU P DECOMP Change out top set of rams to 9-5/8". Rig up test joint and plug. Hang 1 stand of HWDP below. Test 9-5/8" rams to 250 psi low, 3500 psi high as per AOGCC. Witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. Rig down test equipment. 21:00 - 22:00 1.00 FISH P DECOMP Make up 9-5/8" spear with 1 joint of 4" DP. Engage 9-5/8" casing. 22:00 - 00:00 2.00 FISH P DECOMP Break flange on bottom of tubing spool. Pull BOP stack and tubing spool to gain access to 9-5/8" emergency slips. Attempt to pull casing free staging to 150k up. No go. Make several attempts with no success. Wrap wellhead and apply steam. Pull 130k up and let steam heat up wellhead and slips. 11/23/2007 00:00 - 01:30 1.50 FISH P DECOMP Continue to steam wellhead and hold PJSM. Pull on 9-5/8" casing, staging up to 250k up, (130k over). Attempt several times working pipe. Pipe pulled free at 240k up. Free up weight 110k. Pull up and lift emergency slips with casing collar and remove slips. Clean out flange and seal ring grooves. 01:30 - 02:30 1.00 BOPSU P DECOMP PJSM. NU spool and install BOP stack turnbuckles and riser. 02:30 - 03:00 0.50 BOPSU P DECOMP Close bag and test flange break against well to 250 psi low, 2500 psi high. Printed: 12/20/2007 1:29:11 PM ~ ~ BP EXPLORATION Page 6 of 19 ,Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date I From - To I Hours I Task I Code l 'NPT I Phase Description of Operations 11/23/2007 03:00 - 11:30 8.50 FISH P DECOMP PJSM. Rig up false bowl and power tongs. Break and lay down landing joint. Break out cut stump and lay down spear. Pull 9-5/8" casing from cut at 2002'. Average break out torque 13k. Recovered 11 bow spring centralizers, 49 full joints and cut joint of 21.28'. Rig down, clear and clean floor. 11:30 - 12:30 1.00 BOPSU P DECOMP PJSM. Change upper rams back to 3-1/2" x 6" variables. 12:30 - 14:30 2.00 BOPSU P DECOMP Make up 4" test joint, install test plug. Test top rams to 250 psi low, 3500 psi high as per AOGCC. Pull test plug. Install wear ring. Rig down test equipment. 14:30 - 17:30 3.00 FISH P DECOMP PU spear, break off bull nose and cup, lay down. Pick scraper and subs up beaver slide. MU jars, bumper sub, scraper boot basket, float sub, XO, drill collars and HWDP to 859'. 17:30 - 18:30 1.00 FISH P DECOMP RIH above stub at 2002'. Hook up blower hose. Run in and tag stub at 2002'. Up and down weight 90k. 18:30 - 19:00 0.50 FISH P DECOMP Pump soap pill surface to surface at 500 gpm with 675 psi. 19:00 - 20:00 1.00 FISH P DECOMP POOH to 859'. 20:00 - 21:00 1.00 FISH P DECOMP Stand back HWDP and drill collars. Break and lay down bit, boot basket, scraper and jar/bumper sub assembly. 21:00 - 23:00 2.00 FISH P DECOMP PJSM. Bring up tool basket. Rig up false bowl. Pick up washpipe shoe assembly. PU jar/bumper sub assembly. Make up junk basket, double pin sub, drill collars and HWDP to 891'. 23:00 - 00:00 1.00 FISH P DECOMP RIH to 1890'. PU drill pipe single. Hook up blower hose, MU last stand. 11/24/2007 00:00 - 01:00 1.00 FISH P DECOMP PJSM. Make up top drive. Establish circulation at 140 gpm with 72 psi. Free torque at 1-2k with 40 rpm. Up weight 90k, down 90k, RT 93k. Run last stand in, tag top of fish at 2002'. Wash over fish to 2022'. Tag collar, mill off centralizer at 3-5k WOB with 5-14k torque. Work up and down several times. Wash down to no-go at 2032', work up and down several times. 01:00 - 03:00 2.00 FISH P DECOMP Circulate sweep surface to surface at 200 gpm with 100 psi. Rotate and reciprocate at 40 rpm. 03:00 - 04:00 1.00 FISH P DECOMP PJSM. Rack back one stand. Lay down single of DP. Remove blower hose. POOH to 891'. Change out handling equipment. 04:00 - 06:00 2.00 FISH P DECOMP PJSM. Stand back HWDP and drill collars. Lay down washpipe BHA. 06:00 - 07:00 1.00 FISH P DECOMP PJSM. Lay tool basket down beaver slide. Clear and clean floor. Pick up backoff BHA. 07:00 - 09:30 2.50 FISH P DECOMP PJSM. PU one stand of collars. MU bull nose. RIH with remaining collars, BHA and one stand of HWDP. Fill pipe on the fly to 869'. Change out handling equipment. 09:30 - 11:00 1.50 FISH P DECOMP RIH to 2022' filling every 5 stands. 11:00 - 14:00 3.00 FISH P DECOMP Make up head pin and test pump. Space out top anchor at 2010' and bottom anchor at 2036'. Up weight 90k, down 95k. Set bottom anchor with 1200 psi, top anchor with 4000 psi. Slack off string weight. Casing collar broke with 1200 psi. Cycle back-off tool 5-1/2 turns to the left. Bleed pressure, PU 95k and verify release of tool. Drop dart to open circ sub. Displace diesel to cuttings tank. Rig down. 14:00 - 15:00 1.00 FISH P DECOMP POOH to 869'. 15:00 - 17:00 2.00 FISH P DECOMP Stand back HWDP. Break and lay down XO, upper anchor, power section, lower anchor, blanking sub, XO and circ sub. Stand back DC and break bull nose. 17:00 - 17:30 0.50 FISH P DECOMP PJSM. Pick up jar/bumper sub assembly. Make up spear and Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 11/24/2007 17:00 - 17:30 0.50 FISH P DECOMP bull nose. Lay down jar. Make up circ sub and XO to 21'. 17:30 - 18:30 1.00 FISH P DECOMP RIH to 2002'. Up weight 55k, down 60k. 18:30 - 19:00 0.50 FISH P DECOMP Swallow fish to the no go and confirm latch. Turn string to the_ 19:00 - 20:00 1.00 FISH P 20:00 - 22:00 2.00 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 23:30 0.50 FISH P 23:30 - 00:00 0.50 FISH P 11/25/2007 00:00 - 01:30 1.50 FISH P 01:30 - 02:00 0.50 FISH P 02:00 - 02:30 0.50 FISH P 02:30 - 03:00 I 0.501 FISH I P 03:00 - 04:00 1.00 FISH P 04:00 - 05:00 1.00 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 07:00 1.00 FISH P 07:00 - 07:30 I 0.50 07:30 - 08:30 I 1.001 BOPSUF~P 08:30 - 09:00 0.50 BOPSU~ P 09:00 - 16:30 7.50 BOPSU P 16:30 - 20:30 I 4.001 BOPSUf~ N I SFAL 20:30 - 21:00 I 0.501 BOPSUF~ N I SFAL 21:00 - 21:30 0.501 BOPSU~ N SFAL 21:30 - 22:00 0.50 BOPSU N SFAL 22:00 - 00:00 I 2.00 I CASE I P 11 /26/2007 100:30 - 05:00 I 3.501 CASE I P 05:00 - 06:30 I 1.501 CASE I P DECOMP POOH to 21'. DECOMP Rig up tongs and back out spear, break and lay down spear and cut casing of 20.00'. Threads look good for screw in. Clear floor and lay tools down beaver slide. DECOMP Change out top drive saver sub and adjust grabber. DECOMP Make up magnet, bit sub, bumper sub and XO to 15'. DECOMP RIH to 764'. DECOMP PJSM. RIH to 1978'. PU stand, MU to top drive. Slack off, hang up at 2020', continue to slack off and tag top of stump at 2022'. Pick up. Circulate at 525 gpm with 600 psi. Clean off 9-5/8" box. Shut down, slack off and hang up again at 2020', continue to slack off and tag top of stump at 2022'. Rack back 1 stand. Blow down top drive. DECOMP PJSM. POOH to 15'. Change out handling equipment. DECOMP Pull magnet to floor. Recover metal shavings. Break out magnet. Lay down magnet and bumper sub. Clear and clean floor. DECOMP Lay magnet and XO down beaver slide. PU mule shoe BHA. DECOMP Make up 7" mule shoe with bow spring centralizer to 27'. DECOMP RIH and tag top of 9-5/8" stump at 2022' with no hang up. Work down into 9-5/8" and tag up at 2034'. Pull up above stump. Slack off and work into stump at 2022' with no problems, continue to slack off and tag up 2' lower at 2036'. Set down 10k then pull off. DECOMP PJSM. POOH to 27'. Change out handling equipment. DECOMP PJSM. Break and lay down mule shoe and centralizer. Clear and clean floor. Pump out stack. DECOMP PJSM. Pick up test joint. Make up wear ring running tool. Remove wear ring. Install test plug. Remove joint. DECOMP PJSM. Change out top rams to 9-5/8". Fill stack and check for leaks. DECOMP PJSM. Make up TIW, dart valves, 4 and 5 inch test joints. DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witnessed by John Crisp with AOGCC. Two lower mud cross valves failed. DECOMP PJSM. Remove and replace lowewr mud cross valves. Troubleshoot manifold pressure gauge on Koomey unit. DECOMP Re-test lower mud cross valves to 250 psi low, 3500 psi high. Inner valve passed, outer valve failed. DECOMP Replace outside lower mud cross valve. DECOMP Retest outside lower mud cross valve to 250 psi low, 3500 psi high. Pull test plug. Blow down BOP equipment. DECOMP PJSM. Change out bales. Pick up and rig up 9-5/8" casing equipment. DECOMP Continue rigging up to run 9 5/8" casing DECOMP PJSM for running casing. DECOMP Run 49 jts 9 5/8" 47# L-80 Hydril 563 casing with screw in .sub and ES cementer. Clear floor. DECOMP MU XO from casing to 4" HT-40 DP and screw top drive into Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date I From - To I Hours ~ Task I Code I NPT E 11/26/2007 105:00 - 06:30 I 1.501 CASE I P 06:30 - 07:45 I 1.251 CASE I P 07:45 - 09:00 I 1.251 CASE I P 09:105 - 010:00 I 0.751 CASE I P 10:00 - 10:30 I 0.501 CASE I P Spud Date: 7/19/1976 Start: 11/15/2007 End: 12/14/2007 I Rig Release: 12/14/2007 Rig Number: Phase Description of Operations DECOMP XO. Rotate string and engage screw in sub in casing coupling at 2022' DPM. MU with 10 klbs torque. Pull test to 150 klbs over string weight - OK. DECOMP RU lines and cement head. Test casing to 2000 psi for 30. minutes - OK. Increase pressure to 2800 psi & open ES cementer. DECOMP Circ heated seawater to warm up well to get 80+ degree returns prior to cementing. DECOMP PJSM with crew and service company personnel prior to job. DECOMP Air up & prime up cementers. Pump 5 bbls water and test lines to 4500 psi. Pump 40 bbls MudPush spacer at 10 ppg. DECOMP Switch to cement. Mix & pump 136.5 bbls (655 sx) 15.8 ppq Class Gslur - 5 bpm 850 psi start. 5 bpm at 980 si end. 10:30 - 11:00 0.50 CASE P DECOMP Release closing plug for ES cementer and displace cement with seawater. 6 bpm @ 650 psi start. 6.5 bpm @ 1350 psi at 140 bbls away. Slow to 2 bpm and land closing plug in cementer at 150.4 bbls away. Increase pressure to 2100 psi and close ES cementer. 11:00 - 11:15 0.25 CASE P DECOMP Hold pressure to ensure cementer is closed. Bleed off pressure and verify no flowback - OK. Cementer closed. Got back -15 bbls cement slumr to surface. 11:15 - 13:00 1.75 CASE P 13:00 - 17:00 4.00 BOPSU P 17:00 - 22:30 5.50 BOPSU P 22:30 - 00:00 1.50 BOPSU P 11/27/2007 00:00 - 01:00 1.00 BOPSU P 01:00 - 03:00 2.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 06:00 2.00 CLEAN P 06:00 - 07:00 I 1.001 CLEAN I P CIP - 1100 hours. DECOMP Rig up supersucker hose and suck casing out to ground level. Suck out stack. Rig down false bowl. Clear floor of casing equipment. DECOMP Rig up bridge crane to BOP stack. Split and raise stack and tubing spool. Install emergency slips with primary packoff. Up weight 210k, slack off and set slips with 100 klbs over string weight. Run in lock down screws. Rig up WACHS cutter and cut casing. Lay down mouse hole and cut joint. Stand BOP stack back. Pull old tubing spool and romove from cellar. DECOMP Prep 9-5/8". Install secondary packoff and new tubing spool. Torque up. Test void and packoff to 3800 psi for 10 minutes - OK. PJSM. NU BOP stack. Install secondary annulus valve. Install 3-1/2" x 6" variable rams in top set. DECOMP Make up test joint. Install test plug. Fill stack and test flange, rams and doors to 250 si low, 3500 si hi has er AO CC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. Pull test plug. Run in wear ring. DECOMP PJSM. Run in lock down screws. Break out wear ring running tool and TIW. Lay down test joint. Pick up clean out BHA. DECOMP PJSM. PU up mills. Break out upper mill. Lay down flex joint and window mill. Pick up jars and BHA to bit. Pick up collars and HWDP to 864'. Change out handling equipment. DECOMP PJSM. RIH to 1987'. Make up top drive. Fill pipe at 375 gpm with 420 psi. Wash down. Install blower hose. DECOMP Pump at 500 gpm with 730 psi. Up, down and RT weight 90k. Wash down and tag TOC at 1997'. Rotate at 70 rpm with 1 k torque off bottom. Drill cement to 2010'. Drill plug and cement to baffle collar with 5-10k WOB and 2-4k torque. Drill through baffle collar and work through to 2030'. Blow down top drive. DECOMP RIH to 4600'. Fill pipe. Up weight 125k, down 115k. Slack off to Printed: 12/20/2007 1:29:11 PM ~ ~ BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date I From - To (Hours I Task I Code I NPT I Phase I Description of Operations 11/27/2007 06:00 - 07:00 1.00 CLEAN P DECOMP and push junk from 4602' to 4665'. Set down 30k. Pick up then slack off and verify EZSV with junk at 4665' with 30k down. Pick up 20'. 07:00 - 10:00 3.00 CLEAN P DECOMP Pump hi-vis sweep followed by 9.2 ppg LSND milling fluid at 465 gpm with 1150 psi. At bottoms up the H2S alarm went off showin 11 m. Shut down pump and shut in well. Both casing and DP showed 0 psi. Monitor showed 0 ppm in pits but hand held monitor held directly over mud in trough showed 11 ppm. Suspect sour mud causing H2S alarm. Held safety meeting with hands and truck drivers. Rigged up to take returns through gas buster out to cuttings tank. Continue displacement with no more H2S readings. Pump until 9.2 ppg LSND milling fluid all the way around. Pump dryjob. Shut down and blow down top drive. 10:00 - 11:00 1.00 CLEAN P DECOMP POOH to 864'. Change out handling equipment. 11:00 - 13:00 2.00 CLEAN P DECOMP POOH. Lay down drill collars and clean out BHA. Clear floor. PU whipstock tools. 13:00 - 14:00 1.00 DHB P DECOMP Test casin to 3500 si for 30 minutes. Test - OK. 14:00 - 16:30 2.50 STWHIP P WEXIT Make up window mill, lower mill, flex joint, upper mill, single HWDP, float and MWD tools. Scribe, install probe and set back. Pick up whipstock slide. MU bull nose and set in table. Install brass lug and check shear pins. RIH. MU bumper sub, drill collars, HWDP and first stand. Perform surface test at 500 gpm with 750 psi - OK. 16:30 - 20:30 4.00 STWHIP P WEXIT RIH to 3771'. Fill pipe and pulse test at 500 gpm with 1250 psi - OK. RIH to 4516'. 20:30 - 21:30 1.00 STWHIP P WEXIT Orient and hook up blower hose. Make up last stand. Up weight 125k, down 115k. Run in and tag at 4665'. Set down 20k and set bottom anchor at 25 to 30 degrees right. Pick up and confirm set. Set down 35k and shear off whi stock slide. 21:30 - 00:00 2.50 STWHIP P WEXIT Mill 8-1/2" hole in 9-5/8" casing to 4647'. Pump at 500 gpm with 1370 psi. Rotate at 90 rpm with 3.5k to 10.5k torque. WOB _ fit' V 2-5k. TOW4644'~ BOW 4661' 11/28/2007 00:00 - 04:00 4.00 STWHIP P WEXIT PJSM. Mill window to 4681'. Pump at 500 gpm with 1390 psi. Rotate at 90 rpm with 5k torque off bottom, 5-8k torque on bottom. WOB 5-15k. Work through window several times with rotary. Kill rotary slack off and work through window with no problems. Up weight 127k, down 115k. Recovered 350 Ibs of metal 04:00 - 05:00 1.00 STWHIP P WEXIT Pump hi-vis super sweep at 500 gpm with 1400 psi surface to surface. Shut down pumps. Slack off and work through window. Window in good shape. Rack back stand. 05:00 - 05:30 0.50 STWHIP P WEXIT PJSM. Perform FIT to 12.5 ppg with 750 psi. .Good test. 05:30 - 07:30 2.00 STWHIP P WEXIT Remove blower hose. Install rubbers. Blow down top drive. Install air slips. POOH to 915'. Change out handling equipment. Monitor well. Rack back HWDP. Stab TIW. Hold PJSM. 07:30 - 10:00 2.50 STWHIP P WEXIT Lay down drill collars. Break out mills. Upper mill in gauge. Lay down mills and 1 joint HWDP. 10:00 - 12:00 2.00 STWHIP P WEXIT PJSM. Pick up test joint and make up wear ring running tool. Remove wear ring. Make up stack jetting tool. Flush stack. PrinfeA: 12/20/2007 1:29:11 PM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2007 10:00 - 12:00 2.00 STWHIP P WEXIT Function all BOPE. Blow down choke and kill lines. Install wear ring. Lay down test joint. Lay mills and BHA down beaver slide. PU 8.5" BHA. Clear and clean floor. 12:00 - 15:30 3.50 STWHIP P WEXIT PJSM. PU motor and make up bit. Install float. Make up MWD tools and scribe offset. PU flex drill collars, ball catcher and CCV. Run HWDP, jars and XO to 824'. Pulse test MWD at 500 gpm with 900 psi. 15:30 - 17:00 1.50 STWHIP P WEXIT PJSM. Pick up drill pipe to 2600'. 17:00 - 18:30 1.50 STWHIP P WEXIT RIH to 4563'. Fill pipe at 3771' and 4563'. Pump at 500 gpm with 1500 psi. Orient to pass through window. 18:30 - 19:30 1.00 STWHIP P WEXIT PJSM. Cut and slip 77' of drilling line. Lube Elmago Spline. Inspect brakes and draworks. 19:30 - 20:00 0.50 STWHIP P WEXIT Service top drive. Install blower hose. 20:00 - 21:30 1.50 DRILL P INT1 Pass window at 4644' with no problem. Wash from 4665' to 4681'. Directional drill ahead to 4765'. Up weight 130k, down ~2,.®q 110k, RT 120k. WOB 10-15k. Pump at 500 gpm with 1450 psi off bottom, 1590 psi on bottom. Rotate at 60 rpm with 5k torque. AST .8, ART .1 Mud weight in and out 9.3 ppg. 21:30 - 00:00 2.50 DRILL N DEAL INT1 Trouble shoot MWD pulse failure. Pressure increase on connection. Signal stopped. Try various pump rates. Cycle pumps on an off several times. Jar and work pipe. No signals. Pump fresh water pill to try and flush MWD tools. Pressure dropped off as water went through tool but no signal recovery. Mix dry job. 11/29/2007 00:00 - 02:00 2.00 DRILL N DFAL INT1 PJSM. Monitor well. Pump dry job. Remove blower hose. Blow down top drive. Install rubbers and air slips. POOH to 823'. Mud weight in and out 9.3 ppg. Up weight 130k, down 105k. 02:00 - 03:00 1.00 DRILL N DFAL INT1 PJSM. Change out handling equipment. Stand back HWDP. Lay down CCV. Stand back Flex drill collars. POOH to TM. 03:00 - 06:30 3.50 DRILL N DFAL INT1 Plug in MWD, turn off tool. Unplug and pull pulser. Break out TM, put in mousehole. Install new pulser and TM tool. Second TM tool failed. Swap TM tool. Plug in, test - OK. 06:30 - 08:00 1.50 DRILL N DFAL INT1 PJSM. Make up flex collars. Pick up CCV and 1 stand HWDP. MWD found partially shattered poppet in pulser. Break out HWDP and stand back. Lay down CCV and stamd bacl flex collars. POOH to bit and break out. Check for debris, none found. Break float and check motor shaft, nothing found. Make up top drive and circulate at 500 gpm with 550 psi to flush motor. Shut down and blow down top drive. Make up bit and BHA to 824'. Change out handling equipment. PU 1 stand DP. 08:00 - 09:30 1.50 DRILL N DFAL INT1 MU top drive. Surface test MWD at 500 gpm with 960 psi - OK. 09:30 - 10:30 1.00 DRILL N DFAL INT1 RIH to 4750'. 10:30 - 13:30 3.00 DRILL P INT1 Directional drill ahead to 4870'. Pump at 550 gpm with 1670 psi off bottom, 1950 psi on bottom. Rotate at 90 rpm with torque 4-6k off bottom, 5-7k on bottom. WOB 5-7k. Mud weight in and out 9.3 ppg. 13:30 - 14:30 1.00 DRILL N DFAL INT1 Trouble shoot MWD detection problems. Switch modes. Hardboot Sperry computers. Reduce mud pump pulsation dampners. Stagger pump speeds. Able to achieve on the fly logs but limited success on correctable surveys. 14:30 - 00:00 9.50 DRILL P INT1 MWD detection improving. Directional drill ahead to 5774' MD, 5458' TVD. Pump at 600 gpm with 2370 psi off bottom, 2550 psi on bottom. Torque 5-6k off bottom, 6-8k on bottom at 100 Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To I Hours ~ Task I Code ( NPT ~ Phase ~ Description of Operations 11/29/2007 114:30 - 00:00 11 /30/2007 100:00 - 03:00 03:00 - 04:00 9.50 DRILL P INT1 3.00 DRILL P INT1 1.00 DRILL N DFAL INT1 04:00 - 00:00 I 20.001 DRILL I P 12/1/2007 100:00 - 20:00 I 20.001 DRILL I P I NT1 INT1 20:00 - 22:00 2.00 DRILL P INT1 22:00 - 23:30 1.50 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 12/2/2007 100:00 - 03:00 I 3.001 DRILL I P I I INT1 03:00 - 04:00 1.00 DRILL P INT1 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 05:00 0.50 DRILL P INT1 05:00 - 07:00 2.00 DRILL P INT1 07:00 - 09:30 I 2.501 DRILL I P I I INT1 rpm. WOB 5-15k. Mud weight in and out 9.3 ppg. ECD 10.15 ppg. Up weight 150k, down 115k, RT 130k. AST 2.38, ART 3.62. Directional drill ahead. MWD tools unable to squire survey. Troubleshoot MWD detection problems. Attempt different pump pressures. Attempt to cycle several times. Directional drill ahead to 6500' MD, 6070' TVD. Pump at 600 gpm with 2575 psi off bottom, 2840 psi on bottom. WOB 5-15k. Rotate at 100 rpm with torque at 6-7k off bottom, 7-9k on bottom. Up weight 164k, down 115k, RT 139k. Mud weight in and out 9.4 ppg. Continue to drill ahead to 7924' MD, 7359' TVD. Pump at 600 gpm with 3420 psi off bottom, 3770 psi on bottom. Rotate at 100 rpm with 8-9k torque off bottom, 9-11k on bottom. WOB 5-15k. Up weight 205k, down 130k, RT 157k. Mud weight in and out 9.3+ ppg. ECD 9.96. AST 4.08, ART 9.26 Drill ahead to 8487' MD, 7856' TVD. Pump at 600 gpm with 3700 psi off bottom, 3960 psi on bottom. Rotate at 100 rpm with 8-10k torque off bottom, 9-11k torque on bottom. WOB 5-15k. Mud weight in and out 10.2 ppg. Up weight 205k, down 140k, RT 165k. Continue to drill ahead to 9030' MD, 8336' TVD. Pump at 475 gpm with 2975 psi off bottom, 3186 psi on bottom. Rotate at 90 rpm with 8-9k torque off bottom, 9-12k torque on bottom. WOB 5-20k. Mud weight in and out 10.2 ppg. Up weight 212k, down 142k, RT 170k. AST 6.42, ART 9.22. Control drill at 8952' with 10k WOB. ROP at 80-90 fUhr. Spot reverse drilling break at 9015 with ROP dropping to 30-50 ft/hr, maintain parameters and spot drilling break at 9029' with ROP increasing to 87 ft/hr picking up off bottom at 9030'. Circulate bottoms up for samples at 480 gpm with 2130 psi. Reciprocate and rotate pipe. TD called at 9030' MD, 8336' TVD. Pump weighted sweep surface to surface at 480 gpm with 3087 psi. Rotate at 100 rpm with 10-11 k torque. Circulate till clean as per Mud Engineer. Pump MWD survey. Mud weight in and out 10.2+ ppg. Up weight 220k, down 140k, RT 170k. PJSM. Monitor well -static. Rack back one stand. Blow down top drive. POOH wet to 8580'. Up weight 225k, down 140k. PJSM. Perform wiper trip to 4750'. A few spots with overpull, wiped clean, no problems. Perform MAD pass from 4750' to 4440' at 300 fph. Clear and clean floor. PJSM. Service top drive, crown and draworks. PJSM. RIH to TD of 9030' MD. Set 25k down at 8862'. Pump and rotate to 8874'. Wiped clean no problems. Pump weighted sweep surface to surface at 500 gpm with 3450 psi. Circulate and condition mud.. Up weight 210k, down 140k, RT 170k. Torque 9-11k. Montior well -static. Pump dry job. Blow down top drive. Install rubbers. Mud weight in and out Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2007 07:00 - 09:30 2.50 DRILL P INT1 10.5 ppg. 09:30 - 13:00 3.50 DRILL P INT1 PJSM. POOH to 824'. Pull 240k off bottom. No problems out of hole. Change out handling equipment. Monitor well. 13:00 - 16:00 3.00 DRILL P INT1 PJSM. Lay down BHA to the last flex collar at 102'. Plug in and download/turn off MWD. Make up top drive and flush MWD with fresh water. Lay down flex collar and remaining BHA to motor. Break bit and LD. Clear and clean floor. 16:00 - 17:00 1.00 DRILL P INT1 PJSM. Run tools down beaverslide. PU test joint. Pull wear ring. Install test plug. LD 4" test joint. ~ 17:00 - 18:00 1.00 BOPSU P LNR1 PJSM. Change out top rams to 7". Pick up 7" test joint. Make up XO and TIW. Fill stack and check for leaks. 18:00 - 19:00 1.00 BOPSU P LNR1 PJSM. Test 7" rams to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Bill Decker and Toolpusher Cleve Coyne. Rig down and install wear ring. 19:00 - 20:00 1.00 CASE P LNR1 PJSM. Rig up to run 7", 26#, L-80, BTC-M and TC-II liner to 9030'. 20:00 - 00:00 4.00 CASE P LNR1 PJSM. Run float equipment. Test floats. Run 7" liner at 80-90 fUmin to 2149'. Up weight 72k, down 66k. Mud weight in and out 10.2+. 12/3/2007 00:00 - 06:30 6.50 CASE P LNR1 PJSM. Run 7", 26#, L-80, BTC-M and TC-II liner to 6000' MD. Run at 80-90 ft/min to window at 4644' then 60-70 ft/min in open hole. Torque turn the TC-II. Fill on the fly and fill up every 10 joints. At window up weight 130k, down 120k. Continue to RIH with 7" liner to 5986'. Pick up liner hanger and liner top packer. 06:30 - 07:00 0.50 CASE P LNR1 Stage pumps up to 210 gpm with 620 psi to break gels. 07:00 - 09:30 2.50 CASE P LNR1 RIH with 7" liner on 4" drill pipe to TD at 9030' with no problems. Fill every 10 stands. 09:30 - 10:00 0.50 CEMT P LNR1 Stage pumps up to 210 gpm with 1040 psi to break gels and condition mud for cement job. 10:00 - 13:30 3.50 CEMT P LNR1 PJSM. Pump 5 bbls water and test lines to 5000 psi. Pump 40 bbls of 10.8 ppg Mudpush I I and divert the 5 bbls of water down the flowline. Follow with 165 bbls of 11.0 ppg lead cement then 35 bbls of 15.8 ppg of tail cement. Stage pumps up to 5 bpm for each cement stage. Kick plug out with 5 bbls of water. Switch over to rig pumps and chase cement with 10.2 ppg mud at 210 gpm. Pressure increasing from 300 psi to 750 psi before latching up at 25 bbls away. Slow pumps to 3 bpm with 204 bbls away and pressure at 1875 psi. Slow pumps to 1.5 bpm with 239 bbls away and pressure at 1200 psi. Bump plug at 255 bbls with 3000 psi. & set Flex-Lock Hanger. Slack off to confirm set Good lift throughout displacement. 100% returns throughout iob - no loses. CIP at 1200 hours. Bleed off, check floats - OK. Pressure up to 4500 psi to set ZXP Packer. Slack off to 60k down and verify hanger set. Line up on SCH pumps and set liner top packer with 4500 psi. Rotate pipe 15 turns to the right and release from packer. Confirm release. Pressure up to 1000 psi and hold, un-sting from packer maintaining pressure then kick in pumps and Printed: 12/20/2007 1:29:11 PM r BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hotars Task Code NPT Phase Description of Operations 12/3/2007 10:00 - 13:30 3.50 CEMT P LNR1 circulate bottoms up at 600 gpm with 2650 psi. 50 Bbls cement to surface. Rotate at 30 rpm and slack off to shear dogs and for verification when out of hole. Break out and lay down single and cement head. Rack back stand of pipe and make up top drive. Up weight 70k, down 67k. 13:30 - 14:30 1.00 CEMT P LNR1 PJSM. Circulate bottoms up at 360 gpm with 540 psi. Shut down, open kill line, pump retarder pill through stack. Blow down choke and kill line. Pump dry job. 14:30 - 15:00 0.50 CEMT P LNR1 PJSM. Attemp to cut and slip drilling line. High winds making operation unsafe. Shut down and resume operations. 15:00 - 16:00 1.00 CEMT P LNR1 PJSM. POOH. Lay down liner running tool. Recovered 100% of tool. Clear and clean floor. 16:00 - 18:00 2.00 BOPSU P PROD1 PJSM. Pick up test joint. Pull wear ring. Pump out stack. Install test plug. Make up TIW to 4-1 /2" test joint. Change top rams back to 3-1/2" x 6" variables. Fill stack and check for leaks - OK. Run in 4-1/2" test joint. 18:00 - 19:00 1.00 BOPSU P PROD1 PJSM. Test rams to 250 psi low, 3500 psi high. 19:00 - 20:00 1.00 DRILL P PROD1 PJSM. Pick 6-1/8" BHA up beaver slide. 20:00 - 23:00 3.00 DRILL P PROD1 PJSM. Make up bit and motor and BHA to TM collar and scribe. Plug in and upload MWD. Pick up remaining BHA to 375'. Change out handling equipment. Surface test MWD -OK. Test at 280 gpm with 1930 psi. 23:00 - 00:00 1.00 DRILL P PROD1 PJSM. RIH with 6-1/8" build BHA on 4" drill pipe to 2057'. Up weight 60k, down 58k. 12/4/2007 00:00 - 03:30 3.50 DRILL P PROD1 PJSM. RIH to 8844'. Fill every 30 stands. 03:30 - 04:00 0.50 DRILL P PROD1 Wash from 8844' to 8942'. -Pump at 250 gpm with 2250 psi -No cement detected 04:00 - 05:00 1.00 DRILL P PROD1 PJSM. Test 7" liner lap and casing to 3500 psi for 30 minutes andrecor -Test was successful 05:00 - 07:00 2.00 DRILL P PROD1 PJSM. Drill up landing collar, and float collar to 9018' -Prepare for mud displacement to 8.4 ppg Flo-Pro -Torque 8.8k @ 250 gpm 2500 psi on 07:00 - 09:30 2.50 DRILL P PROD1 PJSM. Displace well from 10.5 ppg to 8.4 ppg Flo-Pro -Clean out underneath shakers 09:30 - 10:00 0.50 DRILL P PROD1 Drilling ahead from 9018' to 9050' 10:00 - 11:00 1.00 DRILL P PROD1 Circulate and conditioned mud for LOT 11:00 - 11:30 0.50 DRILL P PROD1 PJSM. Performed FIT - MW 8.4 ppg @ 1040 psi -9030' MD ! 8336' TVD 11:30 - 12:00 I 0.501 DRILL I P 12:00 - 00:00 1 12.001 DRILL I P -Good test PROD1 Drilling ahead from 9050' to 9061' -Up Wt. 160k /Down Wt. 145k /ROT Wt. 155k - WOB 10-12k /Torque 3-4k -260 gpm @ 1710 / 1820 psi -Mud wt. in & out 8.4ppg PROD1 Drilling ahead from 9061' to 9468' @ 269 gpm -1935 psi on / 2105 psi off -Up Wt. 175k /Down 143k /ROT WT. 160k -Torque 4-5k off / 6-8k on - WOB 10-15k Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2007 12:00 - 00:00 12.00 DRILL P PROD1 -Mud Wt. in & out 8.4 ppg -Difficulty sliding pump Low Torque /Alpine Beed sweep @ 9425' 12/5/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drilling ahead from 9468' to 9843' @ 265 gpm -1900 psi off / 2080 psi on -Up Wt. 180k /Down 140k /ROT 160k -Torque 4-5k off / 6-Sk on - WOB 10-15k -Mud Wt. in & out 8.4 ppg --Difficulty sliding pump Low Torque /Alpine Beed sweep @ 9468' 12:00 - 00:00 12.00 DRILL P PROD1 Drilling ahead from 9843' to 10029' @ 277 gpm -1946 psi off / 2120 psi on -Up Wt. 180k /Down 145k /ROT 160k -Torque 4-5k off / 6-8k on - WOB 4-6k -Mud Wt. in & out 8.4 ppg --Difficulty sliding pump increase lubricant to 3% and add beads 12/6/2007 00:00 - 04:30 4.50 DRILL P PROD1 Drilling ahead from 10029' to 10080' @ 265 gpm -1920 psi off / 2080 psi on -Up Wt. 180k /Down 145k /ROT 160k -Torque 4-5k off / 5-6k on - WOB 15-20k - Mud WT in & out 8.4ppg -Monitor Well, Well Static 04:30 - 05:00 0.50 DRILL P PROD1 Circulate @ 265 gpm -1920 psi 05:00 - 06:30 1.50 DRILL P PROD1 PJSM, Pump out from 10080' to 8969' -280 gpm @ 1800 psi 06:30 - 08:00 1.50 DRILL P PROD1 Open Circ. Sub @ 8969' -560 gpm @ 2100 psi -Circulate bottoms up -Pump Dry Job -Install rubbers and blowdown Top Drive -Mud Wt. 8.4 In & Out -Monitor Well, Well Static 08:00 - 09:30 1.50 DRILL P PROD1 PJSM, Cut and Slip 260' of Drilling Line -Service Top Drive ,Crown, and Draw works 09:30 - 12:00 2.50 DRILL P PROD1 PJSM, POH from 8969' to 2807' 12:00 - 13:30 1.50 DRILL P PROD1 PJSM, Drop Ball and Close Circ. Sub - Continue to POH from 2807' to 375' 13:30 - 16:00 2.50 DRILL P PROD1 Lay down BHA -Change out Jars due to mandrel defect -Download MWD tool -Clear floor of BHA 16:00 - 17:00 1.00 DRILL P PROD1 Service Top Drive -3 hydraulic hoses were found damaged 17:00 - 19:30 2.50 DRILL N RREP PROD1 Replace 3 hoses on Top Drive 19:30 - 21:00 1.50 DRILL P PROD1 PJSM, P/U motor and M/U Bit -P/U BHA to TM collar 21:00 - 22:30 1.50 DRILL P PROD1 PJSM, upload MWD Printed: 12/20/2007 1:29:11 PM ~ ~ BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date I From - To ~ Hours 1 Task , Code f NPT Start: 11 /15/2007 Rig Release: 12/14/2007 Rig Number: Spud Date: 7/19/1976 End: 12/14/2007 .Phase , Description of Operations 12/6/2007 21:00 - 22:30 1.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 23:30 0.50 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 12/7/2007 00:00 - 04:30 4.50 DRILL P PROD1 04:30 - 09:30 5.00 DRILL P PROD1 09:30 - 12:00 2.50 DRILL P PROD1 12:00 - 00:00 I 12.001 DRILL I P ~ 12/8/2007 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 112/9/2007 100:00 - 06:30 06:30 - 07:30 07:30 - 12:00 6.50 DRILL P 1.00 DRILL P 4.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 - Surface test MWD @ 260 gpm 1085 psi Clean out Nuke ports on tool and load sources PJSM, P1U HWDP and Jars PJSM, RIH from 402' to 495' RIH from 495' to 9930' Fill pipe every 30 stands At Shoe, 250 GPM @ 1,940 psi, PUW 180K, SOW 140K Madd Pass from 9,900' to 9,750' bit depth looking for Gas/Oil Contact 75 FPH max pulling speed 260 GPM @ 1,940 psi, 5 RPM @ 5-6 KWlbs, RTW 160K RIH to 9,853 and Madd Pass to verify gas under run 50 FPH max pulling speed 260 GPM @ 2,015 psi, 5 RPM @ 5-6 Kft/Ibs, RTW 160K Wash and ream from 9,800' to 10,080' 294 GPM @ 2,391 psi, 5 RPM @ 5 Kft/Ibs PUW 180K, SOW 145K, RTW 155K Drill from 10,080' to 10,367', Tagged BSad, come up looking for sand above base. At bit inclination failed, never worked while on bottom drilling 300 GPM @ 2,380 psi off, 2,630 psi on, MW=8.5 ppg W06=5-12K, PUW=175K, SOW=135K, RTW=155K Torque 5.2K off, 6.5K on @ 100 RPMs back ream each joint at 60 RPMs and 300 GPM Difficulty sliding in BSad, pump bead/lubricant sweeps at 10,180', 10,264', and 10,280' Midnight update ADT=5.31, AST=3.72, ART=1.59 Drill from 10,367' to 10,905', Steering as per Geo to find clean productive sand 300 GPM @ 2,425 psi off, 2,650 psi on, MW=8.6 ppg WOB=5-7K, PUW=175K, SOW=135K, RTW=155K Torque 6.OK off, 7.OK on @ 80 RPMs back ream as needed at 60 RPMs and 300 GPM Drill from 10,905' to 11,224', Steering as per Geo to find clean productive sand 300 GPM @ 2,440 psi off, 2,770 psi on, MW In 8.5 ppg Out 8.6 PP9 W06=5-10K, PUW=180K, SOW=135K, RTW=155K Torque S.OK off, 7.OK on @ 80 RPMs back ream as needed at 60 RPMs and 300 GPM Drill from 11224' to 11,471', Steering as per Geo to find clean productive sand 300 GPM @ 2,460 psi off, 2,900 psi on, MW In 8.5 ppg Out 8.6 PP9 W06=5-10K, PUW=180K, SOW=135K, RTW=155K Torque 6.OK off, 7.OK on @ 80 RPMs back ream as needed at 60 RPMs and 300 GPM Circulated a bottoms up -300 gpm @ 2450 psi -Rotated and Reciprocated ~ Pumped out of the hole from 11471' to 9930' Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/9/2007 07:30 - 12:00 4.50 DRILL P PROD1 -300 gpm @ 2300 psi -Madd Pass from 10576' to 10386' @ 275 fph -Madd Pass from 10100' to 9930' @ 275 fph 12:00 - 14:30 2.50 DRILL P PROD1 -PJSM, Madd Pass from 9930' to 9685' @ 275 fph - 300 gpm @ 2350 psi - Pumped out of the hole from 9865' to 8995' - 300 gpm @ 2300 psi 14:30 - 17:30 3.00 DRILL P PROD1 Circulated 15 mins -Dropped 3 balls as per procedure, but the circ sub did not open - Pumped Hi-Vis sweep , 310 gpm @ 2450 psi -RPM 100 and Torque 5-6 K -Monitored well, static -Pumped dryjob -Installed air slips & rubbers 17:30 - 21:00 3.50 DRILL P PROD1 PJSM, POH from 8995' to 402' (wet) 21:00 - 00:00 3.00 DRILL P PROD1 PJSM, UD BHA from 402' -Down Load nukes -Down Load MWD 12/10/2007 00:00 - 01:00 1.00 DRILL P PROD1 Finsh laying down BHA Clean and clear rig floor 01:00 - 01:30 0.50 CASE P RUNPRD PJSM, Rig up Liner running equipment 01:30 - 02:30 1.00 CASE P RUNPRD PJSM with all Personnel Make up shoe track, Baker lok first 3 joints Fi11 liner with mud and Check floats - OK 02:30 - 05:00 2.50 CASE P RUNPRD Run in hole with 63 joints of 4 1/2" 12.6# L-80 IBT-M liner to 2,556' Fill on the fly, top off every 10 Joints Average Torque 3,800 ft/Ibs 05:00 - 06:00 1.00 CASE P RUNPRD Pick up Liner Hanger/Packer assembly Mix and add PAL mix Rig down liner running equipment Run in the hole with 2 joints 4" Drill pipe and 10' pup to 2,672' 06:00 - 06:30 0.50 CASE P RUNPRD Circulate Liner Volume 4 BPM @ 140 psi PUW - 60K, SOW - 58K 06:30 - 11:00 4.50 CASE P RUNPRD Run in hole with 4" drill pipe to shoe @ 9,024' Fill pipe every 10 stands 11:00 - 12:00 1.00 CASE P RUNPRD Circulate and condition mud before going into open hale 5 BPM @ 650 psi PJSM with all personnel Cementers start rigging up 12:00 - 14:00 2.00 CASE P RUNPRD Run in the hole from the shoe to 11,471' Taking weight 10,250', and from 11,250' to 11,471' 14:00 - 15:00 1.00 CASE P RUNPRD Stage pumps up, could not get over 4.0 BPM i rocate i e first 40 minutes, hole sticky, park pipe 11,469' Circulate 2,230 strokes, 4BPM @ 870 psi Hole trying to pack off above 4.0 BPM Full returns with no losses while circulating. PUW=180K, SOW=135K 15:00 - 16:00 1.00 CEMT P RUNPRD Pressure test cement lines to 4,500 psi Pump 30 bbls of MudPUSH II @ 11.5 ppg Pump 68.1 bbls of Class G tail @ 15.8 ppg Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date (From - To Hours ~ Task (Code I NPT Phase Description of Operations 12/10/2007 ~ 15:00 - 16:00 ~ 1.00 ~ CEMT I P ~ ~ RUNPRD ~ kick plug out, positive indication plug left cement head Switch over to rig and displace cement 4 BPM 50 bbls Perf Pill 76.3 bbls 8.6 ppg FloPro 948 strokes to catch cement 1,500 psi increase in pressure when MudPush reached Liner Top Packer 1,505 strokes to pick up liner wiper plug, 800 psi spike 2,167 strokes to bump the plug, bumped plug with 3,500 psi Hanger set. Full returns throughout cement iob, no losses to 16:00 - 16:30 I 0.501 CEMT I P 16:30 - 17:30 1.00 CEMT I P 17:30 - 20:00 2.50 CASE P 20:00 - 23:30 I 3.501 CASE I P 23:30 - 00:00 0.50 BOPSU P 12/11/2007 00:00 - 08:30 8.50 BOPSU P 08:30 - 10:00 1.50 PE 10:00 - 11:30 1.50 PE 11:30 - 19:30 8.00 PE 19:30 - 21:00 I 1.50 P P P P Bleed off pressure, floats held CIP @ 16:04 Slack off and pressure up to 4,000 psi to release running tool, bleed off pressure Pickup 7' to expose dogs Set down 70K to set Liner top Packer, positive indication packer set Pickup and confirm with 20 RPM RUNPRD Pull out of PBR circulating Circulate out excess cement 14 BPM @ 3,030 psi Estimate 20 bbls of cement back to surface RUNPRD Lay down cement head and blow down lines RUNPRD Circulate bottoms up Displace well from 8.6 ppg FloPro to 8.5 ppg Seawater 13.5 BPM @ 2,980 psi 40 bbls Hi Vis Spacer 410 bbls 8.5 ppg Seawater MW in 8.5 ppg, MW out 8.5 ppg Clean under shakers Monitor well, well static RUNPRD PJSM, Pull out of hole from 8,877' Lay down Liner running tool Clean and clear rig floor RUNPRD PJSM, Pull wear ring and rig up to test BOP RUNPRD Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Witnessed waived by Lou Grimaldi with AOGCC. Test witnessed by WSL Joey LeBlanc and NTP John Castle OTHCMP PJSM - PU & RU perforating equipment. OTHCMP Test casing to 3500 psi f/30 minutes. OTHCMP RIH with perforating assembly and tag wiper plug on landing collar 2' high at 11,379' MD. Spaced out and placed guns on depth per DPM with bottom nose at 11,250' MD. OTHCMP Perforate well with 2 7/8" 2906 PJ perf guns at 6 spf. POH 14 stands. Perf Intervals: 9970' - 10,030' 10,280' - 10,310' 10,340' - 10,660' Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours: Task Code NPT Phase Description of Operations 12/11/2007 19:30 - 21:00 1.50 PERFO P OTHCMP 10,710' - 11,050' 11,210' - 11,250' Lost 5 bbls seawater on the initial perforation and lost another 9 bbls POOH 14 stands. 21:00 - 21:30 0.50 PERFO P OTHCMP Circulate BU (minor seawater loss while circulating) and hold PJSM's for path-forward work. 21:30 - 22:30 1.00 PERFO P OTHCMP Cut & slip 84' of drilling line. 22:30 - 23:00 0.50 PERFO P OTHCMP Service TD, blocks, crown & drawworks. 23:00 - 00:00 1.00 PERFO P OTHCMP POH 1X1 and LDDP f/9947' t/8637' MD. Total losses for tour = 19 bbls seawater. 12/12/2007 00:00 - 04:30 4.50 PERFO P OTHCMP Continue to POOH w/perforating string (LD 4" DP f/8637' to 2562' MD). 04:30 - 11:00 6.50 PERFO P OTHCMP RU 2-7/8" power tongs and handling equipement and LD 2-7/8" PAC DP f/2562 t/1332. LD firing head & 2-7/8" pert guns f/1332'. All shots fired. RD 2-7/8" handling equipment. Clear & clean rig floor. 11:00 - 15:30 4.50 PERFO P OTHCMP RIH w/4" DP from derrick to 4299'. POOH LD DP 1x1. Clean and clear rig floor. 15:30 - 16:00 0.50 RUNCO RUNCMP PJSM, Pult wear ring. 16:00 - 18:30 2.50 RUNCO RUNCMP PJSM, RU to run chrome completion. . 18:30 - 00:00 5.50 RUNCO RUNCMP PJSM, run 4-1/2" chrome completion to 4112' MD (avg torque = 4440 Ibs). 12/13/2007 00:00 - 05:30 5.50 RUNCO RUNCMP Continue to run 4-1/2" completion to top of liner at 8876' MD. Avg torque at 4440 ft/Ibs. 130 up/106 down. 05:30 - 06:30 1.00 RUNCO RUNCMP Space-out tubing w/tubing pups (7.92, 9.83, 9.93) + total 205 joints of tubing ran. Tagged bottom of liner 5' high at 8882' MD. Did not see TOL. 06:30 - 07:30 I 1.00 07:30 - 10:30 I 3.001 RU 10:30 - 12:00 I 1.50 12:00 - 14:00 I 2.001 RUNCONTI I DFAL 14:00-15:30 1.50 BOPSUf~P 15:30 - 19:30 4.00 WHSUR P 19:30-21:00 I 1.501 WHSURIP 21:00 - 00:00 I 3.001 RUNCOIWN I DFAL Top of liner at - 8876' MD Bottom of TB at - 8887' MD Spaced-out WLEG at - 8882' MD RUNCMP RD compensator and CO elevators - MU landing joint and hanger. Landed tubing and RILDS. RUNCMP Reverse in clean seawater surface to surface at 3 bpm (200 psi). Corrosion inhibitor spotted in seawater from bottom of top GLM at 2837' MD to top of production packer at 8804' MD. RUNCMP Drop 1-7/8" ball & rod and pressured to 3500 psi to set packer. Successfully tested tubing to 3500 psi f/30 minutes then tested the IA to 3500 psi f/30 minutes (charted both tests). Bled well to 0 si on both sides. RUNCMP Pressured up on IA to 2500 psi and sheared out shear valve in the upper GLM at 2837' MD. Pumped down annulus at 110 gpm w/1100 psi. Pumped down tubing at 110 gpm at 1300 psi, then 160 gpm at 2500 psi. Decision made the shear valve did not fully shear, set TWC and tested to 1000 psi f/below. RUNCMP PJSM. ND BOPE. RUNCMP PJSM. NU adapter flange and tree. Tested adapter PO to 5000 psi 10 minutes (OK). Tested tree to 5000 psi f/10 minutes (OK). RUNCMP PJSM. RU DSM and pull TWC w/lubricator (tested lubricator to 500 psi). RD DSM. RUNCMP PJSM. RU slick line with tree extension, pump-in sub, and pressure control. Tested to 500 psi (OK). Printed: 12/20/2007 1:29:11 PM BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date ~ Frorn - To ~ Hours ~ Task Code ~ NPT 12/14/2007 100:00 - 04:00 I 4.001 RUNCOI~IT1 l DFAL 04:00 - 06:00 2.00 RUNC011~T1 DFAL 06:00 - 06:30 0.50 RUNCO 06:30 - 06:45 0.25 RU 06:45 - 07:45 1.00 RU 07:45 - 10:30 2.75 RU 10:30 - 12:00 I 1.501 RU Spud Date: 7/19/1976 Start: 11/15/2007 End: 12/14/2007 I Rig Release: 12/14/2007 Rig Number: Phase Description of Operations RUNCMP Pulled shear valve w/slick line f/upper GLM at 2837' MD and pump both ways to confirm full open (110 gpm down tubing at 300 psi / 110 gpm down annulus at 350 psi). RUNCMP RD slick-line in preparation to freeze protect well. RUNCMP Hook up lines to tree and IA. Spot & RU Little Red HOS. Test lines to 2000 psi. RUNCMP PJSM with Little Red, Nabors. RUNCMP Reverse in 158 bbls diesel to IA - 3 bpm @ 350 psi. RUNCMP Allow diesel to U tube from IA to tubing to FP tubing and IA to 2200'. RUNCMP Install BPV in tubing hanger. Close all valves and secure well. RELEASE RIG FOR MOVE TO Y-07Ai AT 1200 HRS. Printed: 12/20/2007 1:29:11 PM • Sperry Drilling Services Survey Report Company: BP Amoco llate: 1/11/2008 'l'ime 09:10:46 Pa~c: 1 Field: Prudhoe Bay Co-ordinate(NE) Ref erence: Well: 02-09, True N orth ', Site: PB DS 02 Vertical f'CVD) Refer ence: 02-09C: 57.1 ~VeIL• 02-09 Section (VSi Kcfcren cc: Well (O.OON,O.OOE,30.83Azi) b~'ellpath: 02-09C Survey Calculation l~ iclhod: Minimwm Curvature llb: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 02-09 Slot Name: 02-09 Well Position: +N/-S 1184.62 ft Northing: 5949987.54 ft Latitude: 70 16 5.498 N +E/-W 119.97 ft Easting : 687728.84 ft Longitude: 148 28 54.568 W Position Uncertainty: 0.00 ft Wellpath: 02-09C Drilled From: 02-09 500292015303 Tie-on Depth: 4599.11 ft Current Datum: 02-09 C: Height 57.11 ft Above System Datum: Mean Sea Level Magnetic Data: 1 1 /19/2007 Declination: 23.60 deg Field Strength: 57668 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction f t ft ft deg 25. 18 0.00 0.00 30.83 Survey Program for Definitive Wellpath Date: 1/11/2008 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 99.11 4599.11 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multish ot 4644.00 11425.85 02-09C MWD-IFR-MS Sperry (4644 MWD+IFR+MS MWD +IFR + Multi Station Survey -- bID ~ Ind --- .lziui - f~l) - _ Svs T~'D N/S L/1V 1 1 1lla ~N i•I> >I'. - Tool ft deg deg ft ft ft ft ft ft i 25.18 0.00 0.00 25.18 -31.93 0.00 0.00 5949987.54 687728.84 TIE LINE 99.11 0.00 135.00 99.11 42.00 0.00 0.00 5949987.54 687728.84 CB-GYRO-MS 199.11 0.00 135.00 199.11 142.00 0.00 0.00 5949987.54 687728.84 CB-GYRO-MS 299.11 0.00 135.00 299.11 242.00 0.00 0.00 5949987.54 687728.84 CB-GYRO-MS 399.11 0.00 135.00 399.11 342.00 0.00 0.00 5949987.54 687728.84 CB-GYRO-MS 499.11 0.25 135.00 499.11 442.00 -0.15 0.15 5949987.39 687729.00 CB-GYRO-MS 599.11 0.25 100.00 599.11 542.00 -0.35 0.52 5949987.21 687729.37 CB-GYRO-MS 699.11 0.17 112.00 699.11 642.00 -0.44 0.88 5949987.12 687729.73 CB-GYRO-MS 799.11 0.17 154.00 799.11 742.00 -0.63 1.08 5949986.94 687729.93 CB-GYRO-MS 899.11 0.00 154.00 899.11 842.00 -0.76 1.14 5949986.81 687730.00 CB-GYRO-MS 999.11 0.17 169.00 999.11 942.00 -0.91 1.17 5949986.66 687730.03 CB-GYRO-MS 1099.11 0.00 169.00 1099.11 1042.00 -1.05 1.20 5949986.52 687730.07 CB-GYRO-MS 1199.11 0.00 169.00 1199.11 1142.00 -1.05 1.20 5949986.52 687730.07 CB-GYRO-MS 1299.11 0.00 169.00 1299.11 1242.00 -1.05 1.20 5949986.52 687730.07 CB-GYRO-MS 1399.11 0.50 162.00 1399.11 1342.00 -1.47 1.33 5949986.11 687730.21 CB-GYRO-MS 1499.11 0.50 138.00 1499.10 1441.99 -2.21 1.76 5949985.38 687730.66 CB-GYRO-MS 1599.11 0.25 181.00 1599.10 1541.99 -2.75 2.05 5949984.84 687730.96 CB-GYRO-MS 1699.11 0.50 177.00 1699.10 1641.99 -3.40 2.07 5949984.19 687730.99 CB-GYRO-MS 1799.11 0.33 82.00 1799.10 1741.99 -3.80 2.38 5949983.80 687731.31 CB-GYRO-MS 1899.11 0.50 101.00 1899.09 1841.98 -3.84 3.09 5949983.78 687732.03 CB-GYRO-MS 1999.11 0.75 137.00 1999.09 1941.98 -4.40 3.96 5949983.24 687732.91 CB-GYRO-MS 2099.11 0.67 129.00 2099.08 2041.97 -5.25 4.87 5949982.41 687733.83 CB-GYRO-MS 2199.11 0.58 122.00 2199.07 2141.96 -5.89 5.75 5949981.80 687734.73 CB-GYRO-MS 2299.11 0.25 161.00 2299.07 2241.96 -6.36 6.25 5949981.34 687735.25 CB-GYRO-MS 2399.11 0.17 216.00 2399.07 2341.96 -6.69 6.23 5949981.01 687735.24 CB-GYRO-MS 2499.11 0.00 216.00 2499.07 2441.96 -6.81 6.15 5949980.89 687735.15 CB-GYRO-MS 2599.11 0.00 216.00 2599.07 2541.96 -6.81 6.15 5949980.89 687735.15 CB-GYRO-MS 2699.11 0.83 171.00 2699.07 2641.96 -7.52 6.26 5949980.18 687735.28 CB-GYRO-MS 2799.11 1.75 46.00 2799.05 2741.94 -7.18 7.47 5949980.55 687736.49 CB-GYRO-MS .~ ~ i Sperry Drilling Services Survey Report Company: BP AmoCO llate 1/11/2008 Time: 09:10:46 Page: 2 ~ Freld: Pru dhoe Bay Co-ord mate(NF,j Re ference: Well: 02-09, True North Site: PB DS 02 Vertical fTVD) Kefe rencc: 02 -09C: 57.1 .Well: 02- 09 Section (VSj Referen ce: Well (QOON,O.OOE,30.83Azi) ~~'ellpath: 02- 09C Survey Calculation Alethod: Mi nimum Curvatu re llb: Oracle Sur ce ~~ IVfD Ind !lzim TVI) Sys TVD N/S E/VV NIapN Map1; "1'00l ~ ft deg deg ft ft ft ft ft ft 2899.11 3.67 49.00 2898.94 2841.83 -4.02 10.99 5949983.80 687739.92 CB-GYRO-MS 2999.11 5.50 49.50 2998.61 2941.50 1.20 17.05 5949989.16 687745.85 CB-GYRO-MS 3099.11 8.00 49.50 3097.91 3040.80 8.83 25.98 5949997.01 687754.59 CB-GYRO-MS 3199.11 11.00 46.00 3196.53 3139.42 19.98 38.14 5950008.46 687766.47 CB-GYRO-MS 3299.11 11.50 49.00 3294.61 3237.50 33.14 52.53 5950021.98 687780.52 CB-GYRO-MS 3399.11 12.83 45.50 3392.36 3335.25 47.47 67.97 5950036.68 687795.60 CB-GYRO-MS 3499.11 15.17 38.00 3489.39 3432.28 65.56 83.95 5950055.17 687811.12 CB-GYRO-MS 3599.11 18.33 36.00 3585.14 3528.03 88.60 101.25 5950078.63 687827.84 CB-GYRO-MS 3699.11 20.42 35.50 3679.47 3622.36 115.53 120.63 5950106.03 687846.54 CB-GYRO-MS 3799.11 24.00 33.50 3772.04 3714.93 146.70 141.99 5950137.73 687867.12 CB-GYRO-MS 3899.11 27.25 31.50 3862.19 3805.08 183.19 165.18 5950174.78 687889.39 CB-GYRO-MS 3999.11 30.83 29.00 3949.61 3892.50 225.14 189.57 5950217.32 687912.73 CB-GYRO-MS 4099.11 34.17 28.00 4033.94 3976.83 272.36 215.19 5950265.16 687937.16 CB-GYRO-MS 4199.11 36.00 28.50 4115.76 4058.65 322.98 242.40 5950316.45 687963.09 CB-GYRO-MS 4299.11 35.75 30.00 4196.79 4139.68 374.11 271.03 5950368.27 687990.44 CB-GYRO-MS 4399.11 36.00 30.00 4277.82 4220.71 424.86 300.33 5950419.74 688018.46 CB-GYRO-MS 4499.11 36.00 30.50 4358.73 4301.62 475.64 329.94 5950471.23 688046.80 CB-GYRO-MS 11 4599 36 00 31 00 4439.63 4382.52 526.15 359.99 5950522.47 688075.58 CB-GYRO-MS . 4644.00• . 36.18 . 31.00 4475.90 4418.79 548.82 373.61 5950545.47 688088.63 MWD+IFR+MS 4768.44 35.50 45.52 4576.96 4519.85 605.72 418.39 5950603.47 688131.97 MWD+IFR+MS 4893.49 31.80 49.59 4681.06 4623.95 652.54 469.41 5950651.55 688181.80 MWD+IFR+MS 4988.43 29.63 53.58 4762.68 4705.57 682.70 507.35 5950682.64 688218.98 MWD+IFR+MS 5079.85 28.36 59.70 4842.66 4785.55 707.08 544.29 5950707.93 688255.30 MWD+IFR+MS 5173.65 27.63 58.94 4925.48 4868.37 729.54 582.16 5950731.33 688292.59 MWD+IFR+MS 5267.18 26.92 65.78 5008.63 4951.52 749.42 620.06 5950752.14 688329.98 MWD+IFR+MS 5359.93 26.60 66.50 5091.45 5034.34 766.31 658.25 5950769.98 688367.73 MWD+IFR+MS 5453.62 27.14 69.86 5175.03 5117.92 782.04 697.55 5950786.68 688406.63 MWD+IFR+MS 5546.49 28.29 71.03 5257.25 5200.14 796.48 738.25 5950802.14 688446.95 MWD+IFR+MS 5638.02 27.94 70.14 5337.98 5280.87 810.82 778.93 5950817.48 688487.26 MWD+IFR+MS 5731.08 27.73 71.23 5420.27 5363.16 825.19 819.93 5950832.87 688527.89 MWD+IFR+MS 5824.45 28.97 71.13 5502.44 5445.33 839.50 861.90 5950848.22 688569.48 MWD+IFR+MS 5917.73 29.63 69.55 5583.79 5526.68 854.86 904.88 5950864.65 688612.07 MWD+IFR+MS 6011.13 29.41 69.86 5665.06 5607.95 870.82 948.04 5950881.68 688654.81 MWD+IFR+MS 6104.48 29.93 66.83 5746.18 5689.07 887.88 990.97 5950899.80 688697.30 MWD+IFR+MS 6199.77 29.79 66.55 5828.82 5771.71 906.65 1034.55 5950919.65 688740.39 MWD+IFR+MS 6292.55 29.43 66.90 5909.48 5852.37 924.77 1076.66 5950938.81 688782.03 MWD+IFR+MS 6478.56 29.04 66.71 6071.80 6014.69 960.55 1160.16 5950976.66 688864.61 MWD+IFR+MS 6571.86 28.05 66.70 6153.75 6096.64 978.18 1201.11 5950995.31 688905.11 MWD+IFR+MS 6666.22 27.64 67.36 6237.19 6180.08 995.38 1241.69 5951013.51 688945.24 MWD+IFR+MS 6759.72 26.77 70.20 6320.35 6263.24 1010.86 1281.52 5951029.98 688984.67 MWD+IFR+MS 6851.05 26.59 69.03 6401.95 6344.84 1025.14 1319.95 5951045.22 689022.74 MWD+IFR+MS 6947.56 26.22 67.98 6488.40 6431.29 1040.86 1359.89 5951061.93 689062.27 MWD+IFR+MS 7041.47 25.68 67.80 6572.84 6515.73 1056.33 1397.96 5951078.34 689099.94 MWD+IFR+MS 7133.23 26.05 69.44 6655.41 6598.30 1070.92 1435.23 5951093.85 689136.83 MWD+IFR+MS 7227.44 25.56 69.53 6740.22 6683.11 1085.29 1473.64 5951109.18 689174.87 MWD+IFR+MS 7320.63 27.79 70.31 6823.49 6766.38 1099.64 1512.94 5951124.51 689213.79 MWD+IFR+MS 7414.16 26.94 69.41 6906.55 6849.44 1114.44 1553.30 5951140.31 689253.77 MWD+IFR+MS 7507.63 28.37 67.77 6989.34 6932.23 1130.29 1593.68 5951157.15 689293.74 MWD+IFR+MS 7599.41 28.24 69.36 7070.15 7013.04 1146.19 1634.18 5951174.06 689333.83 MWD+IFR+MS 7693.47 27.48 68.63 7153.31 7096.20 1161.95 1675.22 5951190.83 689374.46 MWD+IFR+MS 7786.15 26.95 68.04 7235.73 7178.62 1177.59 1714.61 5951207.45 689413.45 MWD+IFR+MS 7881.44 27.75 69.38 7320.36 7263.25 1193.48 1755.40 5951224.35 689453.83 MWD+IFR+MS • • Sperry Drilling Services Survey Report Cumpm~y: BP,4f11000 ~~ field: Prudhoe Bay Site: PB DS 02 bVcll: 02-09 IVellpath: 02-09C Survev _-__ _ - __ llate: 1/11/2008 Time: 09:10:46 Page: 3 Co-ordiuate(NI:j Reference: Well: 02-09, True North Vertical ITVD) Reference: 02-09C: 57.1 Section (VS) Rcfcrence~: Well (O.OON,O.OOE,30.83Azi) S^rccy Calculation Method: Minimum Curvature Dh: Oracle MD Incl Azim TVD Sys TVll N/S E/yV D1apN MapE Tool ~~ 1 ft deg deg ft ft ft ft ft ft 7975.76 29.19 70.69 - - 7403.28 -- 7346.17 1208.82 1797.66 5951240.74 689495.69 MWD+IFR+MS 8069.39 28.97 68.39 7485.11 7428.00 1224.72 1840.29 5951257.70 689537.91 MWD+IFR+MS 8163.07 27.13 67.86 7567.78 7510.67 1241.13 1881.17 5951275.12 689578.36 MWD+IFR+MS 8257.29 28.34 67.85 7651.17 7594.06 1257.66 1921.79 5951292.66 689618.55 MWD+IFR+MS 8351.00 28.10 66.68 7733.75 7676.64 1274.78 1962.65 5951310.79 689658.97 MWD+IFR+MS 8443.67 30.43 68.81 7814.58 7757.47 1291.90 2004.58 5951328.96 689700.46 MWD+IFR+MS 8537.31 29.23 68.61 7895.82 7838.71 1308.81 2047.98 5951346.94 689743.42 MWD+IFR+MS 8631.02 26.95 67.91 7978.48 7921.37 1325.15 2088.97 5951364.29 689783.99 MWD+IFR+MS 8724.09 26.93 67.87 8061.45 8004.34 1341.02 2128.03 5951381.13 689822.64 MWD+IFR+MS 8817.23 27.64 69.58 8144.23 8087.12 1356.50 2167.82 5951397.60 689862.03 MWD+IFR+MS 8909.55 25.87 68.52 8226.66 8169.55 1371.35 2206.63 5951413.41 689900.46 MWD+IFR+MS 8985.29 24.45 69.19 8295.22 8238.11 1382.97 2236.66 5951425.78 689930.19 MWD+IFR+MS 9047.90 25.27 68.72 8352.02 8294.91 1392.42 2261.23 5951435.84 689954.50 MWD+IFR+MS 9078.50 30.11 64.45 8379.11 8322.00 1398.11 2274.25 5951441.85 689967.38 MWD+IFR+MS 9110.66 31.35 61.63 8406.76 8349.65 1405.56 2288.89 5951449.66 689981.83 MWD+IFR+MS 9141.32 29.84 62.37 8433.15 8376.04 1412.89 2302.67 5951457.33 689995.42 MWD+IFR+MS 9172.06 33.60 63.21 8459.29 8402.18 1420.27 2317.04 5951465.07 690009.60 MWD+IFR+MS 9203.77 33.21 61.74 8485.77 8428.66 1428.34 2332.52 5951473.52 690024.87 MWD+IFR+MS 9234.85 32.35 60.78 8511.90 8454.79 1436.43 2347.27 5951481.97 690039.42 MWD+IFR+MS 9266.06 31.53 60.33 8538.38 8481.27 1444.55 2361.65 5951490.45 690053.59 MWD+IFR+MS 9298.05 31.01 60.11 8565.72 8508.61 1452.79 2376.07 5951499.05 690067.79 MWD+IFR+MS 9329.43 33.11 62.72 8592.32 8535.21 1460.75 2390.69 5951507.37 690082.22 MWD+IFR+MS 9359.96 34.06 62.35 8617.75 8560.64 1468.54 2405.68 5951515.53 690097.00 MWD+IFR+MS 9391.59 35.58 57.82 8643.72 8586.61 1477.55 2421.32 5951524.93 690112.41 MWD+IFR+MS 9422.16 36.01 53.27 8668.52 8611.41 1487.67 2436.05 5951535.40 690126.88 MWD+IFR+MS 9453.71 35.94 49.64 8694.06 8636.95 1499.21 2450.54 5951547.31 690141.08 MWD+IFR+MS 9484.13 35.91 43.21 8718.70 8661.59 1511.50 2463.45 5951559.91 690153.68 MWD+IFR+MS 9516.03 37.12 35.68 8744.35 8687.24 1526.14 2475.48 5951574.85 690165.34 MWD+IFR+MS 9545.64 40.71 29.86 8767.39 8710.28 1541.78 2485.50 5951590.74 690174.97 MWD+IFR+MS 9578.03 43.91 21.69 8791.36 8734.25 1561.40 2494.92 5951610.58 690183.90 MWD+IFR+MS 9610.20 47.37 12.99 8813.87 8756.76 1583.33 2501.72 5951632.67 690190.14 MWD+IFR+MS 9640.81 50.70 6.11 8833.95 8776.84 1606.10 2505.51 5951655.52 690193.37 MWD+IFR+MS 9671.74 56.30 1.95 8852.35 8795.24 1630.88 2507.22 5951680.34 690194.46 MWD+IFR+MS 9703.56 62.47 0.51 8868.54 8811.43 1658.25 2507.80 5951707.71 690194.36 MWD+IFR+MS 9734.14 68.66 358.77 8881.19 8824.08 1686.07 2507.62 5951735.52 690193.48 MWD+IFR+MS 9765.07 74.63 357.06 8890.93 8833.82 1715.39 2506.54 5951764.81 690191.67 MWD+IFR+MS 9795.53 78.57 352.59 8897.99 8840.88 1744.89 2503.86 5951794.22 690188.26 MWD+IFR+MS 9827.42 83.39 347.46 8902.99 8845.88 1775.89 2498.40 5951825.07 690182.02 MWD+IFR+MS 9858.74 86.85 347.69 8905.65 8848.54 1806.36 2491.69 5951855.37 690174.55 MWD+IFR+MS 9890.89 87.28 350.90 8907.30 8850.19 1837.90 2485.72 5951886.75 690167.81 MWD+IFR+MS 9921.30 86.36 346.01 8908.99 8851.88 1867.64 2479.65 5951916.33 690160.99 MWD+IFR+MS 9952.40 84.87 340.91 8911.37 8854.26 1897.36 2470.82 5951945.81 690151.43 MWD+IFR+MS 9983.66 84.32 341.60 8914.31 8857.20 1926.83 2460.82 5951975.02 690140.70 MWD+IFR+MS 10015.88 84.50 341.76 8917.45 8860.34 1957.27 2450.74 5952005.20 690129.86 MWD+IFR+MS 10041.57 85.43 342.25 8919.70 8862.59 1981.61 2442.84 5952029.33 690121.35 MWD+IFR+MS 10073.74 89.28 341.19 8921.19 8864.08 2012.12 2432.76 5952059.58 690110.52 MWD+IFR+MS 10122.48 91.76 340.85 8920.75 8863.64 2058.20 2416.91 5952105.25 690093.53 MWD+IFR+MS 10166.98 93.80 339.78 8918.59 8861.48 2100.05 2401.94 5952146.71 690077.52 MWD+IFR+MS 10260.61 92.76 339.78 8913.23 8856.12 2187.76 2369.63 5952233.59 690043.03 MWD+IFR+MS 10353.24 95.28 341.58 8906.74 8849.63 2274.95 2339.06 5952319.98 690010.30 MWD+IFR+MS 10446.30 93.75 340.12 8899.41 8842.30 2362.58 2308.63 5952406.82 689977.70 MWD+IFR+MS 10540.52 92.40 340.13 8894.36 8837.25 2451.06 2276.65 5952494.47 689943.52 MWD+IFR+MS 10632.90 89.89 340.38 8892.51 8835.40 2537.98 2245.45 5952580.58 689910.16 MWD+IFR+MS i Sperry Drilling Services Survey Report - Company: BP Al11000 -- - Dater 1/11!2008 True: 09:10:46 Page: 4 Field: Prudhoe Bay Co-ordinatc(NE) Reference: Well: 02-09, True North Site: PB DS 02 Vertical tTVD) Reference: 02-09C: 57.1 ~1~e11: 02-09 Section (VS) Reference: Well (O.OON,O.OOE,30.83Azi) ~Vclipath: 02-09C Survey Calculation ~~iethod: Minimum Curvatw~e DU: Oracle Survey 1~4n Lirl A-iim TVT) tivc TVII N/S F./W ManN Mang Tnol ft deg deg ft ft ft ft ft ft 10726.52 91.56 338.39 8891.33 8834.22 2625.59 2212.49 5952667.34 689875.03 MWD+IFR+MS 10820.22 94.04 338.37 8886.75 8829.64 2712.59 2178.01 5952753.44 689838.39 MWD+IFR+MS 10912.75 93.67 339.70 8880.53 8823.42 2798.80 2144.98 5952838.79 689803.22 MWD+IFR+MS 10946.20 93.52 342.77 8878.43 8821.32 2830.40 2134.24 5952870.12 689791.70 MWD+IFR+MS 10974.64 92.02 344.36 8877.06 8819.95 2857.65 2126.20 5952897.15 689782.99 MWD+IFR+MS 11006.19 88.87 344.28 8876.81 8819.70 2888.02 2117.68 5952927.30 689773.71 MWD+IFR+MS 11069.02 89.11 344.44 8877.92 8820.81 2948.51 2100.74 5952987.35 689755.27 MWD+IFR+MS 11100.20 89.84 343.73 8878.20 8821.09 2978.50 2092.19 5953017.11 689745.98 MWD+IFR+MS 11193.97 89.92 345.11 8878.40 8821.29 3068.82 2067.01 5953106.77 689718.55 MWD+IFR+MS 11286.87 90.71 344.26 8877.89 8820.78 3158.42 2042.47 5953195.72 689691.79 MWD+IFR+MS 11380.61 92.07 343.46 8875.62 8818.51 3248.43 2016.42 5953285.06 689663.50 MWD+IFR+MS 11425.85 92.93 343.49 8873.64 8816.53 3291.76 2003.57 5953328.05 689649.57 MWD+IFR+MS 11471.00 92.93 343.49 8871.33 8814.22 3335.00 1990.75 5953370.94 689635.69 BLIND ~~ 'TREE= Cameron VVElLHEAD= FMC ACTUATOR = KB. ELEV = BF. ELEV = 60.43 31.93 K_OP = Max Angle = 4597 92 ~ 11381 Datum MD = Datum TVD = 8800' SS DRLG DRAFT 02-09C ~~ 9-5/8", 47#, L-80, HYDRIL 563 2025' ES Cementer -~ 2011' Open FO w ith cement bebw to 2300' 2266' 13-3/8" CSG, 72#, MN-80, ®= 12.34T' 2~~ 7"x9-5/8" Liner Top ZXP Packer w / PBR 3013' Min. ID = 3.275" ~ 8869' XN nipple yt.I.S ~¢SV ~ 4668' 5-t /2" Stub ~ -5830' GA S LIFT MANDRELS 5-1/2" Otis Sliding Sleeve, ID = 4.562"~-~ 8507' 5-112" BOT PBR Assembly 8607' 9-5/8" x 5-1l2" Baker SAB Packer 8827• 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.897' 8639' TOP OF 4-112" TBG-PC 8639' 41 /2" Otis XN N~ple, ID = 3.725" 8702' TOP OF 3-112" LNR 8724' 3-117' LNR 9.3#, L-80, ID = 2.992" $728' TOP OF 2-718" LNR 8728" 4112" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8763' TOP OF 7" LNR 8726' 9-5/8" CSG, 47#, N-80, ID = 8.681" 9021' T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9596' ~ 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" ~ 11680' 2182' --~ X' MPP~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 2838 2837 0 KBG2-1 R EMPTY BK 12/14/07 3 5251 4995 27 KBG2-f R OM1' BK 0 12/14/07 2 7078 6603 26 KBG2-1 R OMY BK 0 12/14/07 1 8654 7995 27 KBG2-1 R DMY BK 0 12/14!07 ~I(v4y' To ~ .U75Z DPT, IU = ---~ 8774' ~ x' Nipple 8805' 7" x 4-1/2" S3 PACKER I I 8839' X' Nipple 8869' ag XN' Nipple ~ 8876' 4-112" Liner t 9030' 7" L-80, 26#, ID=6.276" 4-1n" L-8o, X2.6#, 0=3.95&• I 10690 CTM D ~-~ 2-7/8" HES MODEL M CIBP 11616' 2-718"LANDING COLLAR 11678' 2-7/8" DAMS LYNCH BULLET NOSE FLOAT SHOE DATE REV BY COMMENTS DATE REV BY COMMENTS 1997 ORIGINAL COMPLETION 08/19/99 VUORKOV ER 12/14/07 N2ES SIDETRACK PRUDHOE BAY UNfT QUELL: 02-09C Proposed PERMfT No: 1971010 API No: 50-029-20153-03 SEC 36, T11 N, R14E, 1216' FNL 8, 971' FVVL BP 6rploration (Alaska) 02-09C Change in Kick Off Po~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 21, 2007 11;16 AM To: 'Hobbs, Greg S (ANC)' Cc: Honas, Kristopher Subject: RE: 02-09C (207-139) Change in Kick Off Point Page 1 of 3 Oa -- O ~ 3 Greg, Thanks for the additional information. That answers my questions. It appears that the Ivishak has been successfully isolated per the plan. The additional wellbore interval will be isolated by the EZSV that will support the whipstock. Changing the plans is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com) Sent: Wednesday, November 21, 2007 9:42 AM To: Maunder, Thomas E (DOA) Cc: Honas, Kristopher Subject: RE: 02-09C (207-139) Change in Kick Off Point Tom- I grabbed Eli and have him here as we respond as he is the "second string" with Travis on vacation. The removal of the Pack-off Gas Lift Mandrel was the first step of the Rig operations. All Pre-Rig operations per the permit were completed. The ID of the Pack-off Gas Lift Mandrel was 2.3" and this was not big enough to get a jet or chemical cutter through. For this reason. we attempted to pull it with Slickline to cut the tubing deep at the planned KOP. We were able to move it, but not pull it through the SSSV nipple. It was then pushed as deep as possible, and a tubing cut was made above it. We then attempted a blind back-off and retrieved only the bottom 20' of the joint of tubing that we cut. We then moved forward with a higher KOP. One of the contingincies for this well as it was planned with the asset was a higher kick-off based on not being able to remove the Pack-off Gas Lift Mandrel. At this time, we can drill new hole faster than we can make the multiple runs to cut the tubing to the originally planned kick-off point given the pack-off gas lift mandrel still being stuck at about 5800' MD. The new KOP was picked at 4650' MD to be in a competent formation for a shoe. Below is the pre-rig work request with completion dates as well as the digital well file summaries denoting the kill operations as well as the post abandonment pressure tests. Let me know if you need anything else- Sorry about the confusion- and have a Happy Thanksgiving! Greg 1 ~ S ~ Drift tubing to CIBP at 10,690' if possible. DONE 10/25/07 Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. SBHP: 3300 psi SBHT: 190 °F 11 /23/2007 02-09C Change in Kick Off Po • Page 2 of 3 Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 obis Volume of 4-112" from 8724' to 8639': 0.0152 bpf 85' = 1.3 bbls , If unable to tag 10,690' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading 2 C cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. Freeze rotect tubin with diesel to 2200' TVD. DONE 11/10/07 3 S VVOC, drift to TOC, DONE 11/12/07 Test tubing to 2125 psi (reduced for tubular corrosion). Test IA and OA to 2000 psi. Pressure tests are required for competent barriers for drilling operations. 4 F If test fails due to tubing issue, contact ODE. Note: 67% corrosion in tubing at 4,375' with > 20% corrosion in 109 other joints. DONE 11/12/07 5 F Bieed casing and annulus pressures to zero. Done 11/13/2007 V1/hat work has been accomplished so far? According to the steps in the operations plan with the permit to drill, pulling the POGLM was number 1. Does the inability to pull the POGLM affect the coil cementing plans for 02- 096 (197-101) as approved by sundry (306-283)? Based on the proposed KO depth "shallowing up" by about 2000', it would appear that access deeper into the well may not be possible. If the well service work reports are available, I'd appreciate them being submitted. Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC Prom: Vazquez, Eleazar [mailto:vazge0@BP.com] Sent: Wednesday, November 21, 2007 8:58 AM To: Maunder, Thomas E (DOA) Cc: Nonas, Kristopher; Habbs, Greg S (ANC) Subject: 02-09C Change in Kick Off Point Tom, During decompletion operations for We1102-09C a Pack Off Gas Lift Mandrel needed to be pulled out from 3944' MD. More time than what had initially been anticipated was spent pulling out this Pack Off Gas Lift Mandrel without success; therefore, an alternative solution, which included a change in Kick Off Point, was agreed upon. The new Kick Off Point is 4650' MD which is located in the SV Sands. A 10.7 ppg FIT will be needed. A new directional plan was created and it passes all collision risks. Operations proceed as orignally plan and targets remain the same. Attached you can find a copy of the new directional plan together with the new anti-collision report. Please let me know if I can be of any further help, Eleazar "Eli" Vazquez 11123/2007 02-09C Change in Kick Off Point • Page 3 of 3 BP Exploration Alaska GPB Rotary Drilling Engineer Direct: 907.564.5918 Mobile 1:907.240.8137 Mobile 2: 915.346.6430 «02-09C Wp09 comp.txt» «02-09C WP09 AC Report.pdh> «02-09C WPQ9 DRAFT.pdh> «02-09C WP09 AC Plot.pdf» 11 /23/2007 o ~ ~ ~ ~ SARAH PAULA, GOVERNOR ~~ OI~ oasai ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER`TA'1`I011T COMI~'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska, Inc PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 02-09C BP Exploration Alaska, Inc Permit No: 207-139 Surface Location: 4064' FSL, 4308' FEL, SEC. 36, T 11 N, R 14E, UM Bottomhole Location: 2014' FSL, 2257' FEL, SEC. 25, T11N, R14E, UM Dear Mr. Hobbs: 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 an required test, contact the Commission's petroleum field inspector at (907~~~3607 (pager). DATED this day of October, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ''~~J STATE OF ALASKA /-~^p~ ~ALAS~IL AND GAS CONSERVATION COMMI~ hEGEIVED ~(: T 1 6 2007 !d , PERMIT TO DRILL ~ l~``~la;:ka ~,` ,~ ~ 20 AAC 25.005 as COBS. Cortxnlssron 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oit ^ Single Zone 1 c. Specify if well is propo ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: 02-09C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11613 TVD 8878 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4064' FSL 4308' FEL SEC T11N R14E UM 36 7. Property Designation: ADL 028308 Pool , , , , . , Top of Productive Horizon: 662' FSL, 1809' FEL, SEC. 25, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2007 Total Depth: 2014' FSL, 2257' FEL, SEC. 25, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,120' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687729 y-5949988 Zone-ASP4 10. KB Elevation Plan (Height above GL): 2 feet 15. Distance to Nearest Well Within Pool: 575' 16. Deviated Wells: Kickoff Depth: gg25 feet Maximum Hole An le: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3848 Surface: 3026 1 Ca in r "' m: ` n T - S in h - Bo m f nt f. or sa ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin stn a data N/A 9-5/ " 47# BT -M 210 ' urf ce urf 10 ' 0 9 x I 8-1 /2" 7" 26# L-80 BTC-M 6170' 3000' 2999' 9170' 8222' 487 x Class ' ' -1/ " 4-1/ " 1 I T-M 8 1 14' 8 1 x I 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11680 Total Depth TVD (ft): 14 Plugs (measured): 10690 Effective Depth MD (ft): 10690 Effective Depth TVD (ft): 8854 Junk (measured): None sing Length ize_ ement olume Conductor /Structural 1 P r afr I I 1 1' Surface 21 1 - /8" x P rmafro t II 21 21 ' Intermediate 0 1' 9- / " 7 x I 'G' 9 1' 791 ' Pr i n Liner 87 ' 7" 1 sx CI s 'G' 8726' - 9596' 7673' - 406' Liner 2 2-7/8" 1 sx LAR 8724' - 116 7671' - 8814' Perforation Depth MD (ft): 10220' - 10645' Perforation Depth TVD (ft): 8857' - 8858' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing .~ true and correct. Printed Name Greg Hobb Si nature ~ Contact Travis Peltier, 564-x511 Title En ineering Team Leader Prepared By Name/Number: Phone 564-4191 Date ~f ~ ~r Terrie Hubble, 564-4628 Commies' n Use Onl Permit To Drill N m r: 0~0~/.~ D API Number: 50-029-20153-03-00 Permit Ap ro D See cover letter for h r r irem t Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ,,--,,// Samples Req'd: ^ Yes ~jlo Mud Log Req'd: ^~fes trr~n o HZS Measures: ^ Yes (~'No Di onal Survey Req'd: Yes No Other: /~~ ~} ~~ ~ APPROVED BY THE COMMISSION Date ,(/~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ _ _ _ `,/ ~./ ~/ Submit In Duplicate To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission _ From: Travis Peltier, 2ES Drilling Engineer Date: October 15, 2007 Re: 02-09C Sidetrack Permit to Drill Approval is requested for the proposed rotary side track of PBU well 02-09. Well 02-09 is an Ivishak producer that is currently shut-in due to high GOR. The well has been killed with a 1% KCL and 60/40 meth freeze protect. Well 2-09B was sidetracked in August 1997. The well produced at high gas rates (40 mmcfd) and began cycling immediately. The well was moved into the HP system in late 1999 resulting in lower oil and gas rates. Additional perforations were shot in April 2000 with no improvement in production. In February 2001 a CIBP was set, resulting in a successful gas shut off. In January 2006, an isolated 9' Z1 B interval below the 14N shale was perforated. The lower 4' tvd of this interval was perforated in April 2000. The adperfs increased gas production by 10 mmcfd without increasing oil production. The resulting GOR increased to 60,000 scf/bbl, making the well uncompetitive. A March 2006 caliper log indicated high tubing corrosion between the POGLM's at 3944' and 7080' md. The wel! has passed a CMIT IA x OA to 3000 psi indicating good surface casing and tubing integrity. Cumulative production for this well is 1.09 MMbbls oil, 27.8 Bcf gas and negligible water. The 2-09C sidetrack is currently scheduled for Nabors 2ES beginning the first week of November, 2007. 02-09C Permit to Drill Application Page 1 Planned Well Summary Well 02-09C Well Producer Target Sag River T e Rotary Sidetrack Ob'ective AFE Number: PBD 4P 2629 API Number: 50-029-20153-03- 00 Surface Northin Eastin Offsets TRS Location 5,949,987.54 687,728.84 4064' FSL / 4308' FEL 11 N, 14E, 36 Target Northin Eastin Offsets TRS Locations 5,951,928 690,180 662' FSL / 1809' FEL 11 N, 14E, 25 5,952,526 689,945 1266' FSL / 2028' FEL 11 N, 14E, 25 Bottom Northin Eastin Offsets TRS Location 5,953,268 689,697 2014' FSL / 2257' FEL 11 N, 14E, 25 Planned KOP: 6,925'md / 6,303' tvd Planned TD: 11,613' and / 8,878' tvd Ri Nabors 2ES RTE: 28.5' Surface and Anti Collisioin Surface Shut-in Wells: There are no wells requiring surface shut-in prior to moving onto the well. Close Approach Shut-in Wells: There are no wells requiring shut-in prior to moving onto the well. 02-09C Permit to Drill Application Page 2 ~ + Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 81/z"Intermediate Hole Maximum anticipated BHP: 3,848 si at 8,222' TVDss. (9.0 max pore pressure) Maximum surface pressure: 3,026 psi (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: 70 bbls with 10.9 ppg EMW FIT and 10.5 pp MW Planned BOPE test pressure: 250 psi low / 3,500 psi high 7 day test cycle (Pre drilling phase) 14 day test c cle (Drillin o erations) Well Interval: 61/8" roduction interval Maximum antici ated BHP: 3,300 si at 8,819' TVDss. Maximum surface ressure: 2,418 si (based u on BHP and a full column of as from TD @ 0.10 sift) Calculated kick tolerance: Infinite with 8.8 EMW FIT. Planned BOPE test pressure: 250 psi low / 3,500 psi high 14 da test cycle (Drillin o erations) Planned com letion fluid: 8.6 seawater / 7.1 Diesel H2S DS-02 is not designated as an HZS site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 02-10A 6 ppm 02-29C 3 ppm 02-08B 4 ppm 02-31 A 4 ppm Directional Proclram Kick Off Point 6,925 ft MD Maximum Hole Inclination: --93° @ 10,876 ft MD. Proximity Issues: All wells ass ma'or risk Surve Pro ram: Standard MWD + IFR/MS/Cassandra Nearest Well within ool: Well 2-33A @ 575' Nearest Pro ert Line 21,120' to Unit Bounda to the South 02-09C Permit to Drill Application Page 3 • i Logging Program Hole Section: Re uired Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD 6 1/8" roduction: Real time MWD Dir/GR/Res/AzDen/Neutron Cased Hole: USIT\GR\CCL (9 5/8" Casin ) O en Hole: None lanned Mud Program Hole Section /operation: Cut & Pull tubin and Casin .Set EZSV and Whipstock T e Densit MBT PV YP API FL H BRINE 8.6 N/A 9.0 -10.0 Hole Section / o eration: Millin 8 1/2" window at 6,825' and Type Densit ( g Chlorides PV YP API FL H LSND 9.2 <1000 16-30 30 millin < 8.0 9.0 -10.0 Hole Section / o eration: Drillin 8 1/2" interval from -6,825' and to 8,575' and T e Densi Chlorides PV YP API FL H LSND 9.2 - 9.6 <1000 15-25 22-30 5.0 - 7.0 9.0 -10.0 Hole Section / o eration: Drillin 8 1/2" interval from -8,575' and to 9,170' and Type Densit g) Chlorides PV YP API FL H LSND 10.5 <1000 15-22 26-30 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 6 1/8" production interval to TD 11,614' and Tye Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.5 >20,000 8 - 12 22 - 28 6 - 8 9.0 -10.0 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 13 3/8" 9 5/8" 47# L-80 BTC-M 2100' Surface 2,100 / 2,099' 8 Yz" 7" 26# L-80 BTC-M 6170' 3,000' /2,999' 9,170 / 8,222' 6 1/8" 4 ~/z" 12.6# L-80 IBT-M 2594' 9,020' / 8,093' 11,614'/ 8,819' Tubing 4'/i" 12.6# 13Cr-80 VamTOP 9020' Surface 9,020' / 8,093' 02-09C Permit to Drill Application Page 4 Casino /Formation IntearitV Testing • Test Test Point Test Type Test pressure 9 5/8" casing with EZSV EZSV @ 7,000' 30 min recorded 3,500 psi surface 9 5/8" window (8 %" OH) 20' new formation FIT 10.9 ppg EMW 7" liner Float equipment to surface 30 min recorded 3,500 psi surface 7" casing shoe (6 1/8" OH) 20' new formation FIT 8.8 ppg EMW 4'/z" Tubing Packer t~ 8,930' MD 30 min recorded .3,500 psi surface 4 %2" tbg x 7" csg annulus Tubing-Casing annulus from acker8,930 MD 30 min recorded 3 500 psi surface W1,500 si on Tb Cementing Program Casin Strin : 9-5/8" 47# L-80, BTC, Tie-Back Casin Slurry Design Basis• ' Tail slurry: 2100' of 9-5/8" x 13 3/8", 72# casing annulus with 5°~ excess. Tail TOC surface. Fluids Se uence /Volume: Spacer 40 bbls MudPush q Tail Sluny 15.8 ppg Class G -145 bbl (1.17 cu ft/sk) 698 sx. Casin Strin 7" 26# L-80, BTC-M, Intermediate casing -•---~! Slurry Design Basis• ' -~ lead slurry: 3,850' of 7" x 9 5/8" and 1315.5' of 7" x 8 %2" annulus with 20 bbl Casing, 40% OH excess plus liner lap. Lead o OC @ 3,000' MD. Tail slurry: 1000 of 7 x 8 / annulus with 401o OH excess plus ~80` of 7 2ti# Casin shoe track. Tail TOC 8,165' MD. Spacer 30 bbls MudPush II at 11..0 ppg Fluids Sequence / Volu~ Tail Slurry 15.8 ppg Class G - 40.5 bbl (1.17 cu ftlsk) 195 sx. ~~ Lead Slurry 11.0 ppg Lite Crete -154.1 bbl (3.26 cu ft/sk) 265 sx. Casing Strin : 4-112" 12.6# L-80, BTC-M, Production casing Slurry Design Basis• ' Tail slurry: 2647' of 4-1/2" x 6-1/8" annulus with 40% OH excess plus 150' of 7 liner la .Tail TOC 8,816' MD. Fluids Sequence /Volume: Spacer 30 bbls MudPush 11 at 12.0 ppg Tail Slurry 15.8 ppg Class G - 66 bbl (1.17 cu ft/sk) 317.5 sx. DisQosal ,~ Annular In'ection: No annular injection in this well. Cuttings Handling• Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. Alt Class I wastes are to be hauled to Pad 3 for dis I. 02-09C Permit to Drill Application Page 5 Casin /Formation Inte rit Testin Test Test Point Test Type Test pressure 9 5/8" casing 'th EZSV EZSV @ -7,000' 30 min recorded 3,500 psi surface 9 5/8" window (8 " OH) 20' new formation FIT 10.9 ppg EMW 7" liner Float equipment to surface 30 min recor d 3,500 psi surface 7" casing shoe (6 1/8" O 20' new formation FIT 8.8 ppg EMW 4'/z"Tubing Packer @ 8,930' MD 30 mi ecorded 3,500 psi surface 4'/z" tbg x 7" csg annulus Tubing-Casing annulus from acker @ -8,930 MD 30 in recorded 3,500 psi surface W 1,500 si on Tb Cementing Program `~~ S`'p~ E ~ ~ Casin Strin 9-5/8" 47# -80, BTC, Tie-Bac asin Slurry Design Basis: Tail slurry: 2 0' of 9-5/8" x 1 3/8", 72# casing annulus with 5% excess. Tail TOC C~ surfa Fluids Sequence /Volume: Spacer 4 bbls M Push Tail Slurry 15. p lass G -145 bbl (1.17 cu ft/sk) 698 sx. Casing String: 7" 26# L-80, BTC- , I ermediate casing Lead slurry: 5,2 ' of 7" 8'/z" annulus with 40% OH excess plus liner lap. Slurry Design Basis: Lead TOC @ ,950' MD. ' " ' ° Tail slurry: 5 of 7 x 8 /z nnulus with 40 /° OH excess plus ~80 of 7 26# Casin sho track. Tail TOC 11,380' MD. Spacer 30 bbls MudPush I at 11.0 ppg luids Sequence /Volume: Tail rry 1 ass G - 01 bbl (1.62 cu ft/sk) 487 sx. Casing String: 1/2" 12.6# L-80, BTC-M, Production sing Slurry Design Basis: ail slurry: 2720' of 4-1/2" x 6-1/8" annu s with 40% OH excess plus 150' " ' of 7 liner la .Tail TOC @8,807 MD. Spacer 30 bbls MudPush II at 12.0 pp Fluids Sequence / Volu e: Tail Slurry 15.8 ppg Class G - 64 bbl (1.17 u ft/sk) 309 sx. Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to th Grind and Inject station at DS-04. An metal cuttin s should be sent to the North S e Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be h uled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 02-09C Permit to Drill Application Page 5 Geologic Prognosis Formation Tops(TVDss) and Estimated Pore Pressures Est. Formation Tops Uncertainty Commercial Hydrocarbon Bearing Est. Pore Press. Est. Pore Press. Formation (TVDss) (feet) (Yes/No) (Psi) (p g EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells UG4 -5288 (5690MD) WS2 -5946 (6512MD) WS1 -6152 (6790MD) CM3 -6380 (7096MD) CM2 -6848 (7725MD) CM1 -7461 (8548MD) THRZ -7884 (9117MD) BHRZ -8075 (9373MD) TJB -8092 (9396MD) Sa River -8221 (9570MD) Shublik -8261 (9624MD) TSAD / TZ4B -8318 (9698MD) 42 SB -8412 (9807MD) TCGL / TZ3 -8465(9866MD) BCGLITZ2 -8536 (9944MD) 23 SB -8615 (10034MD) 21TS -8700 (10143MD) TZ1 B -8752 (10223MD) TDF -8792 (10306MD) 3300 psi BSAD -8831(10540MD) TD Criteria: Reach planned TD unless drilling conditions deteriorate. Final TD TBD by both rig and town geologist. 02-09C Permit to Drill Application Page 6 ~ ~ Fault Prognosis The 02-09C side track will not cross any faults. No fault crossing expected but the polygon is narrow and bounded by faults at the toe. The perforatable wellbore should maintain at least 100' standoff to faults. If lost circulation encountered in toe, TD will be called early. Fault Coordinates for Ma in X Y Fault #1 First Point 689590 5953720 Fault #1 Second Point 690000 5952980 Fault #2 First Point 689640 5953075. Fault #2 Second Point 689695 5952500 Fault #2 Third Point 689780 5951960 02-09C Permit to Drill Application Page 7 02-09C Operations Summary Current Status: - CIBP at 10690' MD. - CMIT - IAxOA -Passed to 3000 psi (3/19/07) - 1 joint of 5-1/2" tubing corroded 63% @ 4,375' MD [wall penetration only] (3/5/06) - Fluid in cellar (fresh water) (12/13/05) Pre Rig Operations 1. SLICK: Pull POGLV at 3944' MD. Drift tubing through POGLV at 7080' MD to CIBP at 10,690' if possible. 2. COIL: Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-1/2"from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. Freeze protect tubing with diesel to 2200' TVD. SBHP: 3300 psi SBHT: 190 °F 3. SLICK: WOC. Drift to TOC. Be aware of GLM at 7080' 4. FULLBORE: Test tubing to 2,125 psi (reduced for tubular corrosion). Test IA and OA to 2000 psi. Pressure tests are required for competent barrier for rig operations. If test fails due to tubing issue, contact ODE. Note: 67% corrosion in tubing at 4,375' MD with > 20% corrosion in 109 other joints. 5. FULLBORE: Bleed casing and annulus pressures to zero. 6. WELLHEAD: Function tubing and casing LDS. Repair/replace as required. 7. OTHER: Set a BPV. Remove well house and flow line. Level pad as necessary. Note: PPPOT-T (5000 psi) and PPPOT-IC (3500 psi) passed on 9/8/07. Rig Operations 1. Move in. Rig up Nabors rig 2ES. 2. Pull BPV. Circulate out freeze protection and displace with seawater. 3. Run TWC and test to 1000 psi. 4. Nipple down tree. Nipple up BOPE. 5. Test BOPE to 3500 psi high, 250 psi low. Pull TWC. 6. MIRU SWS. RIH with appropriate jet cutter and cut 5-1/2" tubing in the middle of the first full joint above the POGLV at 7080'. 7. Screw in landing joint. Unseat and pull 5-1/2" tubing hanger to floor 8. Circulate well, surface to surface. 9. Lay down landing joint and hanger. 10. Pull 5-1/2" tbg to cut at 7050' MD. Spool up control line. Count bands and clamps. 11. Pick up and RIH with RTTS to 2100' MD. Find leak point in 9-5/8" casing. 12. RU E-line. Run USIT/GR/CCL from cut stub to surface. 13. Drift 9-5/8" casing to 2300' MD. 14. Change one set of BOP rams to accommodate 9-5/8" casing. Test. 15. RU E-line. Run string shot to collar to be backed off. 16. Make up casing cutter for 9-5/8" casing. RIH to 2000' MD. 17. Cut casing. Circulate to verify cut. MU cement line. 18. Circulate annulus clean. POOH. 19. Make up spear assembly. Unseat 9-5/8". 20. POOH and LD 9-5/8" casing. 21. Pick up 13-3/8" casing scraper. RIH, ensure casing is clean. POOH. LD scraper assembly. 22. PU washover pipe. RIH, wash over 9-5/8" casing stub. POOH, LD washover assembly. 23. PU Baker 9-5/8" 47# backoff assy, use drill collars as required. RIH. Tag casing stub. 24. Pressure up on drill pipe to break connection. Back off casing. 25. Drop ball and pressure up to open pump out sub. 26. POH with backoff assy. 27. PU and RIH with Spear assembly. Recover stub. Note if pin or collar is recovered. 28. Update wellhead equipment as per FMC. 02-09C Permit to Drill Application Page 8 ~ i ~~ 5 ~'~`-`~ 29. RU equipment. Run 9-5/8" BTCM casing. Screw in to stub. 30. Split the BOP stack. Install emergency slips. Cut 9-5/8" casing. Install and test packoff. 31. Nipple up BOP. Test. Ensure both sets of variables are installed. 32. Test 9-5/8" above ES Cementer plug to 2000 psi. Open ES Cementer with 2700 psi and establish circulation. 33. Pump cement sufficient to cover from ES Cementer to surface. Test ES Cementer after closure. 34. PU 8-1/2" tri-cone bit. Clean out to ES Cementer. 35. Drill up Cementer Plugs and clean-out to tubing stub. POOH. LD BHA 36. RU Eline. RIH with EZSV. Set ~ 6900' MD. POOH. RD Eline. 37. Test 9-5/8" casing to 3500 psi for 30 minutes. Chart test. 38. PU and RIH with whipstock. 39. Orient and set WS at 6850' MD. 40. Dis lace to 9.2 LSND millin fluid. 41. Mill window. Pump a sweep. P win ow milling assembly. 42. PU 8-1/2" drilling BHA. RIH. 43. Drill 20', perform FIT. 44. Drill to TD, increasing mud weight to 10.5 ppg prior to entering the HRZ. 45. At TD, Circulate sweep. Short trip to the window. Circulate sweep. POH and LD BHA. 46. Rig up liner running equipment. Run 7" 26# liner. 47. Circulate bottoms up at the window. Continue in to TD. 48. Circulate hole prior to cement. 49. Cement liner in place. Set liner hanger/packer. 50. Circulate out contaminated mud and cement. POH. LD running tool. 51. MU and RIH with 6-1/8" build BHA to top of liner. Circulate bottoms up. 52. Test 7" liner to 3500 psi for 30 minutes. Chart same. 53. Drill cement and float equipment. Displace well to Flo Pro drilling fluid. 54. Drill 20'. Perform FIT. 55. Drill build section to soft landing above BSAD. POOH. LD BHA. 56. PU lateral BHA. RIH. 57. MAD Pass in the up direction, capturing 200' of the parent wellbore. 58. Locate the BSAD, drill horizontal section to TD. 59. Circulate sweep. Short trip. Circulate sweep. POOH, LD BHA. 60. PU and MU 4-1/2" liner. 61. RIH with 4-1/2" liner on DP. 62. RU cement equipment. Circulate liner at TD. 63. Cement liner in place. Set liner hanger/packer. 64. POH, LD excess DP. 65. RU and MU perf guns, RIH with 2-7/8" PAC and 4" DP. 66. Perforate overbalance. Pull up to top of liner. Monitor well. Continue to POOH. 67. POH. LD 2-7/8" PAC and 4" DP. 68. RU to run tubing. 69. Run 4-1/2" 13CR-80 completion. 70. Space out and land tubing. 71. Reverse in corrosion inhibited brine 72. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 73. Nipple down the BOPE. Nipple up the tree. 74. Freeze protect the well to 2200' TVD. Install BPV. 75. RDMO. Release rig. Post Rig Operations 1. Pull the ball and rod / RHC plug. 2. Instail gas lift valves 3. Install well house and instrumentation. 4. No "S" riser modifications will be required. 02-09C Permit to Drill Application Oa- O~ ~ Page 9 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Put River sandstone in this fault block is potentially at 10.0 ppg EMW. This pressure is estimated based on original reservoir pressure. II. Lost Circulation/Faults The 02-09C side track will not cross any faults. No fault crossing expected but the polygon is narrow and bounded by faults at the toe. The perforatable wellbore should maintain at least 100' standoff to faults. If lost circulation encountered in toe, TD will be called early. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 70 bbls with 10.5 ppg mud, 10.9 ppg FIT, and an 9.0 ppg pore pressure at the casing shoe. This FIT should prove up adequate formation strength for expected ECD's. B. The Kick Tolerance for the production hole section is infinite with 8.6 ppg mud, 8.8 ppg FIT, and an 7.3 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. IV. Integrity Testing Test P~~int Test Depth 'l'est type I?~I~V (lb/«al) 8'/z" KO 20-ft min new formation FIT 10.9 min 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 min V. Stuck Pipe A. Stuck pipe not anticipated. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal. VI. Hydrogen Sulfide A. DS 12 is not an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 02-10A 6 ppm 02-29C 3 ppm 02-08B 4 ppm 02-31 A 4 ppm VIII. Anti-Collision Issues A. There are no wells that pose a major risk for collision. 02-09C Permit to Drill Application Page 10 TREE = FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV - 58' BF. ELEV KOP = _ _-- Max Angle = 100 @ 10853' Datum MD = 10227 Datum TVD = 8800' SS • 02-09B S OTES: TWO 5-112" POGL.M's. 2-7/8" CIBP SET 10690' CTMD ON 2!25/01. BTM 3 PERF INTERVALS ISOLATED. ***IAxOA COMM. OPERATING PRESSURE OF THE 9-5/8" ANNULUS AND 13-318" ANNULUS MUST NOT IXCEED 1000 PSI (12/10105 WAIVER)*** 13-3/8" CSG, 72#, MN-80, ID = 12.347" F-I 2130' Minimum ID = 2.340" @ 3944' & 7080' 5-1 /2" POGLM 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8639' TOP OF 4-1/2" TBG-PC 8639' TOP OF 3-1/2" LNR ~-1 8724• TOP OF 7" LNR 8726' 3-1i2" LNR, 9.3#, L-80, ?bpf, ID = 2.992" $72$' TOP OF 2-7/8" LNR 8728' 4-1i2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ( 8763' 9-518" CSG, 47#, N-80, ID = 8.681" 9021' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9596' PERFORATION SUMMARY REF LOG: BRCS ON 06/06/75 ANGLE AT TOP PERF: 77 @ 10220' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11!16" 4 10220 - 10240 O 04/19/00 2" 6 10254 - 10294 O 05/17/04 2-1/8" 4 10297 - 10499 O 08/16/97 1-11/16" 4 10453 - 10499 O 08/17(97 1-11/16" 4 10620 - 10645 O 08!17/97 1-11/16" 4 10782 - 10995 C 08/18/97 2-1/8" 4 11075 - 11254 C 08/16!97 2-1/8" 4 11322 - 11615 C 08116(97 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" ~ 11678' TD 11680' I 2220' -~5-1/2" OTIS RQM SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3944 7080 3902 6490 27 35 POGLM POGLM DMY DMY BK BK 0 0 12/06/03 11/07/02 8507' 8607' -{ 8627' -~ 8639' -~ 8702' --~ 8724' -~ 5-112" OTIS SLIDING SLV, ID = 4.562" 5-1/2" BOT PBRASSY 9-5/8" X 5-112" BAKER SAB PKR 5-1 /2" X 4-1 /2" XO, ID = 3.958" 4-1/2" OTIS XN NIP, ID = 3.725" 3-1/2" G SEAL SUB, ID = 2.917" 8{ 728' (--~ 3-112" X 2-7/8" XO, ID = 2.377" j 8762' f--~4-1/2" BAKERSHEAROUTSUB (BEHIND LNR) 8763' 4-1/2" TUBING TAIL .(BEHIND LNR) 8777' ELMD LOGGED 02!10/80 9596' 7" MILLED WINDOW TOP 10690 CTMD I-I 2-7/8" HES MODEL M CIBP 11616' -~ 2-7/8" LANDING COLLAR 11678' 2-7/8" DAVIS LYNCH BULLET NOSE FLOAT SHOE DATE REV BY COMMENTS DATE REV BY COMMENTS 1997 ORIGINAL COMPLETION 12/06/03 DTR/TLP GLV GO 08/19/99 WORKOVER 05(17!04 KEY/KAK ADPERFS 04/02/01 CH/KAK CORRECTIONS 12/21!05 COMlPAG WANERSAFETY NOTE 11/16/02 JRGKK WAVER SAFETY NOTE 01/01/03 JM/KAK GLV GO 08!18/03 CMO/TLP DATUM MD CORRECTION PRUDHOE BAY UNff WELL: 02-09B PERMff No: 1971010 API No: 50-029-20153-02 SEC 36, 711 N, R14E, 1216' FNL & 971' FWL BP Exploration (Alaska) .TREE= FMC WELLHEAD= FMC TES:TW05-112" POGLM's. 2-71e" QBP ACTUATOR = AxasoN Q 2-09 B Post P N A SET ~ 10d9o' CTMD ON 2125101. BTM 3 PERF KB. ELEV = 58' INT'ER1/ALS ISOLATED. •••IAXOA COMM. OPERATING BF. REV = _? PRESSURE OF THE 9-518" ANNULUS AND 13-3/8" KOP= _? ANNULUS MUST NOT EXCEED 1000 PSI (12MOA5 Max Anpls = ]0 ®10853' WAVER)"' Dstum MD = 1022T GAS LIFT MANDRELS Minimum ID = 2.340" ~ 3944' S 7080' 5-1/2" POGLM I I F-}-- 8607' 5-1/2" OTIS SLIDHVG SLV, ID = 4.562" S-1 /2" TBGPC, 17#, L-80, .0232 bpf, ID = 4.892" H 8839' TOP OF PNA Cement 8838' TOP OF 3-1/2" LNR 8724' TOP OF 7" LNR 8726' 3-12' LNR, 9.3#, L-80, _? bpf, ID = 2.992" 8728' TOP OF 2-7/8' LNR 8728' 41/2" TBGP'C, 12.8#, N-80, .0152 bpf, ID = 3.958" H 8783' f 9-5/8" CSG, 47#, N-80, ID = 8.681" 9021' P68=0RATION SUMMARY Rff LOG: BRCS ON O6lO6R5 ANGLE AT TOP FERF: 77 Q 10220' Note: Refer to Production DB for historical perF data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16' 4 10220-10240 C 04!19100 2" 8 10254 - 10294 C 05/17/04 2-1 /8" 4 10297 - 10498 C 08/18/97 1-11/16' 4 10453- 10499 C 08/17/97 1-11/16' 4 10620-10845 C 08/17!97 1-11/16' 4 10782- 10985 C 08/18!97 2-118" 4 11075 - 11254 C 08/18/97 2-1/8" 4 11322- 11815 C 08/16!97 2-7/8" LNR, 8.5#, L-80, .0058 bpf, D = 2.441" 11878' • 8827' -i 9-5/8" X 5-1 /2" BAKER SA B PKR 8839' 5-1 /2" X 4-1/2" XO, ID = 3.958" 8702' 41 /2" OTIS XN NIP, ID = 3.725" A79~ X1/9" rA SFAI Sl1R If] = 9 917" 8728' H 3-1 /2" X 2-7/8" XO, ID = 2.377" 8762' 4.112" BAKER BREAKOUT SUB (BEHIND LNR) 8763' 4-1/2" TUBING TAIL (BEHIND LNR) 8777' ELMD LOGGED 02/10/80 y~~ 7" MILLED WINDOW TOP 2-7/8" PRUDHOE BAY l1C`MT WELL: 02-098 PERMIT No: 1971010 API No: 50-029.20153-02 T11 N, R14~ 1216 FNL b 971' FWL BP 6cploratlan (Alaska) TREE _ FMC WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 58' BF. ELEV = _? KOP= _? Max Angle = JO @ 10853' Datum MD = 10227' Datum TVD = 8800' SS TAMF~'t Q~la' 13-3/8" CSG, 72#, MN-80, ID = 12.347" • 02-09C Proposed ..,~ 2130' 7" LNR, 26#, L-80, .0382 bpf, ID = 6.276" 3000' Whipstock ~ -6850' ~'~ ~!~ Ezsv -6900' Pre Rig Jet Cut -7050' GAS LI ST MD ND DEV TYPE VLV LATCH PORT DATE 2 7080 6490 35 R~GLM DMY BK 0 11/07/02 5-112" Otis Sliding Sleeve, ID = 4.562" 8507' 5-112" BOT PBR Assembly 8607' 9-5/8" x 5-1/2" Baker SAB Packer 8627' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8639' TOP OF 4-1 /2" TBG-PC 8639' 4-1/2" Otis X - ~ X12' LIB 9.3f#, L~ 1~29l~" ~ 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" I 8763' TOP OF 7" LNR 8726' 9-5/8" CSG, 47#, N-80, ID = 8.681" I 9021' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9596' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 11678' - 2000' X' Nipple GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2881 2880 4 POGLM DMY 2 5274 4990 31 POGLM DMY 3 6600 6096 35 POGLM DMY 4 8835 8001 31 POGLM DMY Min. ID = 3.275" ~ 8985' XN nipple ~ 4-1/2" TBG. 12.6#. 13Cr..0152 bof. ID=3.958" 8915' x Nppe L1 7' x 412' Si 8960' x Npple ~89iB5~ XN Npple 9000' 4-12" Liner top 9165' 7" L-B0, 26#, ID=6.276" 4-112" L-B0, 12.6#, 13.958" 10690 CTMD 2-7/8" HES MODEL M CIBP 11616' ~ 2-7/8" LANDING COLLAR 11678' 2-7/8" DAVIS LYNCH BULLET DATE REV BY COMMENTS DATE REV BY COMMENTS 1997 ORIGINAL COMPLETION 12/06/03 DTR/TLP GLV GO 08/19/99 WORKOVER 05/17/04 KEY/KAK ADPERFS 04/02/01 CWKAK CORRECTIONS 12/21/05 COM/PAG WANERSAFETY NOTE 11/16/02 JRGKK WAVER SAFETY NOTE 07/31/06 BML PYOposed Schematic 01/01/03 JNVKAK GLV GO 10/10/07 TMP Updated Roposed 08/18/03 CMOlTLP DATUM MD CORRECTION PRUDHOE BAY UNff WELL: 02-09C Proposed PERMIT No:'1971010 AR No: 50-029-20153-03 SEC 36, T11 N, R14E, 1216' FNL & 971' FWL BP Exploration Alaska) • ~ ~$ r ~ ~ ~ in ne S F F F uQ ~~Tio c a QQyU N ~ F o a o 0 G a y .\7. ~ MMVlON1~OP--MNP- ~~.1 N .D~~.OMPP~O-r-M.p-N a' R v1 P R m G ..pp h R- ~O r! vJ ~ y s P ~ mmmv1rv10heNe-erv E r! 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O J ~~ ~ ~3a~~~~~xN _ - ~ oooooom~~m~mmmmmmm ~ ~q Q~y~ 3 o..E aS ~ a ri c.~i .c r•cM.riccr`mrrice Mrl O Q O-NVMNaONm1~NP1~.0-~nP- ~ U = d ~~~I~a aP =~~5 p N O n / o L O ?PNP--N MMQ~n v~.ph mmmP ~ ~o ~orrmmmmmmmmmmmmmm O-NMI -NMOh~°r•m P~~~~ [U1 (+~uoNL'(' )9~^05 ` ~ Q I~ O O-NMOV~~01~m z - N M c v, ~o n m P - - - -- - - - - • Sperry-Sun BP Planning Report Company: BP Amoco Datc: 8/7/2007 Time: 15:40:41 Page: l Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-09, True North Site: PB DS 02 Vertical (TVD) Reference: 02-09C Plan 58.8 Well: 02-09 Section (VS) Reference: Well (O.OON,O.OOE,32.39Azi) WeQpath: Plan 02-09C Survey Calculation Method: Minimum Curvature Db: Orade Plan: 02-09C Wp 7.0 Date Composed: 8/7/2007 Version: 7 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: U5 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: bggm2007 Site: PB DS 02 TR-11-14 UNITED STATES :North S lope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N From: Map Fasting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-09 Slot Name: 02-09 Well Position: +N/-S 1185.08 ft Northing: 5949988.00 ft Latitude: 70 16 5.503 N +E/-W 120.14 ft Fasting : 687729.00 ft Longitude: 148 28 54.563 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name - ft ft in in 9165.46 8283.80 7.000 8.500 7" 11612.61 8877.80 4.500 6.125 41/2" Formations MD ' "['VD Formations Lithology Dip angle Dip Direction ft ff, deg deg 0.00 UG4 0.00 0.00 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 7022.20 6442.70 CM3 0.00 0.00 7564.26 6910.70 CM2 0.00 0.00 8278.79 7523.70 CM1 0.00 0.00 8772.23 7946.70 THRZ 0.00 0.00 8995.03 8137.70 BHRZ 0.00 0.00 9014.86 8154.70 TJ B 0.00 0.00 9165.46 8283.80 Sag River 0.00 0.00 9212.01 8323.80 Shublik 0.00 0.00 9277.16 8380.80 TSAD / TZ4B 0.00 0.00 9385.02 8474.80 42 SB 0.00 0.00 9448.61 8527.80 TCGL / TZ3 0.00 0.00 9535.89 8598.80 BCGL/TZ2 0.00 0.00 9635.93 8677.80 23 SB 0.00 0.00 9758.30 8762.80 21TS 0.00 0.00 9848.77 8814.80 TZ1 B 0.00 0.00 9920.67 8854.80 TDF 0.00 0.00 10005.30 8893.80 BSAD 0.00 0.00 10064.42 8912.80 TDF 0.00 0.00 Targets Map Map <-- Latitude -> <- Longitude --> lame Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 02-09C Tgt 3 8877.80 3230.29 2049.32 5953268.20 689697. 00 70 16 37.270 N 148 27 54.886 W 02-09C Flt 1 8829ss 8887.80 3684.65 1953.61 5953720.00 689590. 00 70 16 41.739 N 148 27 57.670 W -Polygon 1 8887.80 3684.65 1953.61 5953720.00 689590. 00 70 16 41.739 N 148 27 57.670 W -Polygon 2 8887.80 2934.61 2345.05 5952980.00 690000. 00 70 16 34.361 N 148 27 46.277 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/7/2007 Time: 15:40:41 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-09, True Notch Site: PB DS 02 Vertical (TVD) Reference: 02- 09C Plan 58.8 Well: 02-09 Section (VS) Reference: Well (O.OON,O.OOE, 32.39Azi) Wellputh: Plan 02-09C Survey Calculation Method: Minimum Curvature Db: Oracle 'Targets Map Map <-- Latitude -> <- Longitude --> Name Description TA' D +N/-S +E/-H' Northing Easting Deg J1in Sec Deg Agi n Sec D ip. Dir. ft ft ft ft ft 02-09C Poly 8887. 80 1746.15 2265.39 5951790.00 689950.00 70 16 22.673 N 148 27 48.607 W -Polygon 1 8887. 80 1746.15 2265.39 5951790.00 689950.00 70 16 22.673 N 148 27 48.607 W -Polygon 2 8887. 80 2735.77 2095.00 5952775.00 689755.00 70 16 32.406 N 148 27 53.560 W -Polygon 3 8887. 80 3270.50 1913.27 5953305.00 689560.00 70 16 37.666 N 148 27 58.848 W -Polygon 4 8887. 80 3340.62 2110.09 5953380.00 689755.00 70 16 38.355 N 148 27 53.115 W -Polygon 5 8887. 80 2804.89 2331.81 5952850.00 689990.00 70 16 33.085 N 148 27 46.664 W -Polygon 6 8887. 80 1836.40 2657.78 5951890.00 690340.00 70 16 23.559 N 148 27 37.182 W 02-09C Flt 2 8855ss 8913. 80 3038.56 1987.51 5953075.00 689640.00 70 16 35.384 N 148 27 56.687 W -Polygon 1 8913. 80 3038.56 1987.51 5953075.00 689640.00 70 16 35.384 N 148 27 56.687 W -Polygon 2 8913. 80 2462.34 2028.16 5952500.00 689695.00 70 16 29.717 N 148 27 55.508 W -Polygon 3 8913. 80 1920.35 2099.67 5951960.00 689780.00 70 16 24.386 N 148 27 53.431 W -Polygon 4 8913 .80 2462.34 2028.16 5952500.00 689695.00 70 16 29.717 N 148 27 55.508 W 02-09C Tgt 2 8913 .80 2482.09 2278.74 5952526.00 689945.00 70 16 29.911 N 148 27 48.212 W 02-09C Tgt 1 8928. 80 1878.38 2498.77 5951928.00 690180.00 70 16 23.972 N 148 27 41.811 W Plan Section Information MD Intl Azim TVD +N/-S +E(W DLS Build.' Turn TFO Target ft deg 'deg ft ft ft deg/100ft degl100ft deg/1OOft deg 6800.00 35.00 51.00 6260.16 1404.18 1211.36 0.00 0.00 0.00 0.00 6820.00 36.73 53.83 6276.37 1411.32 1220.65 12.00 8.66 14.19 45.00 6900.00 35.00 51.00 6341.20 1439.88 1257.80 3.00 -2.16 -3.54 222.69 7664.69 30.99 107.37 6997.26 1520.98 1624.55 3.93 -0.52 7.37 121.05 9191.29 30.99 107.37 8305.94 1286.32 2374.73 0.00 0.00 0.00 0.00 9444.20 35.56 40.51 8524.21 1324.00 2488.28 14.00 1.81 -26.44 247.37 9541.34 35.56 40.51 8603.23 1366.95 2524.98 0.00 0.00 0.00 0.00 9804.06 56.08 356.48 8789.85 1539.81 2569.46 14.00 7.81 -16.76 -74.42 9908.83 56.08 356.48 8848.31 1626.59 2564.13 0.00 0.00 0.00 0.00 10186.42 90.03 336.31 8928.80 1878.38 2498.77 14.00 12.23 -7.27 -33.34 02-09C Tgt 1 10214.85 91.37 340.06 8928.45 1904.76 2488.21 14.00 4.70 13.19 70.35 10829.18 91.37 340.06 8913.80 2482.09 2278.74 0.00 0.00 0.00 0.00 02-09C Tgt 2 10869.70 92.67 343.03 8912.37 2520.50 2265.93 8.00 3.21 7.33 66.30 11612.61 92.67 343.03 8877.80 3230.29 2049.32 0.00 0.00 0.00 0.00 02-09C Tgt 3 Survey MD Incl Azim TV"D Sys TVD VS N/S E/yA' DLS NIapN AlapF. 'CooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 6800.00 35.00 51.00 6260.16 6201.36 1834.63 1404.18 1211.36 0.00 5951421.87 688904.90 Start Dir 1 6820.00 36.73 53.83 6276.37 6217.57 1845.63 1411.32 1220.65 12.00 5951429.24 688914.00 Start Dir 3. 6900.00 35.00 51.00 6341.20 6282.40 1889.65 1439.88 1257.80 3.00 5951458.71 688950.42 Start Dir 3. 7000.00 33.12 57.16 6424.07 6365.27 1941.65 1472.75 1303.06 3.93 5951492.70 688994.85 MWD+IFR 7022.20 32.75 58.61 6442.70 6383.90 1952.55 1479.17 1313.28 3.93 5951499.37 689004.91 CM3 7100.00 31.58 63.92 6508.57 6449,77 1988.80 1499.09 1349.56 3.93 5951520.19 689040.67 MWD+IFR 7200.00 30.42 71.21 6594.31 6535.51 2030.87 1518.77 1397.06 3.93 5951541.05 689087.67 MWD+IFR 7300.00 29.70 78.91 6680.90 6622.10 2067.66 1531.70 1445.36 3.93 5951555.17 689135.63 MWD+IFR 7400.00 29.43 86.86 6767.91 6709.11 2098.99 1537.81 1494.22 3.93 5951562.50 689184.32 MWD+IFR 7500.00 29.64 94.82 6854.95 6796.15 2124.73 1537.08 1543.42 3.93 5951563.00 689233.51 MWD+IFR 7564.26 30.03 99.83 6910.70 6851.90 2138.25 1533.00 1575.10 3.93 5951559.71 689265.28 CM2 7600.00 30.32 102.56 6941.60 6882.80 2144.74 1529.51 1592.71 3.93 5951556.66 689282.98 MWD+IFR 7664.69 30.99 107.37 6997.26 6938.46 2154.60 1520.98 1624.55 3.93 5951548.93 689315.02 End Dir 7700.00 30.99 107.37 7027.53 6968.73 2159.31 1515.55 1641.90 0.00 5951543.94 689332.50 MWD+IFR 7800.00 30.99 107.37 7113.25 7054.45 2172.66 1500.18 1691.04 0.00 5951529.80 689382.00 MWD+IFR 7900.00 30.99 107.37 7198.98 7140.18 2186.00 1484.81 1740.18 0.00 5951515.66 689431.51 MWD+tFR 8000.00 30.99 107.37 7284.70 7225.90 2199.35 1469.44 1789.32 0.00 5951501.52 689481.02 MWD+IFR gent Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/7/2007 Time: 15:40:41 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-09, True North Site: PB DS 02 Vertical (TVD ) Reference: 02- 09C Plan 58.8 Nell: 02-09 Section (VS) Reference: Well (O.OON,O.OOE,32.39Azi) Wellpath: Plan 02-09C Survey Calcul ation Method: Min imum Curvature Ub: Oracle Sur~e~ l~tD Incl Azim TVD Sys TVD VS N/S E/W DLS hi&pN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 8100.00 30.99 107.37 7370.43 7311.63 2212.69 1454.07 1838.47 0.00 5951487.38 689530.52 MWD+IFR 8200.00 30.99 107.37 7456.15 7397.35 2226.04 1438.70 1887.61 0.00 5951473.24 689580.03 MWD+IFR 8278.79 30.99 107.37 7523.70 7464.90 2236.55 1426.59 1926.33 0.00 5951462.10 689619.03 CM1 8300.00 30.99 107.37 7541.88 7483.08 2239.38 1423.33 1936.75 0.00 5951459.10 689629.53 MWD+IFR 8400.00 30.99 107.37 7627.61 7568.81 2252.73 1407.95 1985.89 0.00 5951444.96 689679.04 MWD+IFR 8500.00 30.99 107.37 7713.33 7654.53 2266.07 1392.58 2035.03 0.00 5951430.82 689728.54 MWD+IFR 8600.00 30.99 107.37 7799.06 7740.26 2279.42 1377.21 2084.17 0.00 5951416.68 689778.05 MWD+IFR 8700.00 30.99 107.37 7884.78 7825.98 2292.76 1361.84 2133.31 0.00 5951402.54 689827.56 MWD+IFR 8772.23 30.99 107.37 7946.70 7887.90 2302.40 1350.74 2168.80 0.00 5951392.32 689863.31 THRZ 8800.00 30.99 107.37 7970.51 7911.71 2306.10 1346.47 2182.45 0.00 5951388.39 689877.06 MWD+IFR 8900.00 30.99 107.37 8056.23 7997.43 2319.45 1331.10 2231.59 0.00 5951374.25 689926.57 MWD+IFR 8995.03 30.99 107.37 8137.70 8078.90 2332.13 1316.49 2278.29 0.00 5951360.82 689973.61 BHRZ 9000.00 30.99 107.37 8141.96 8083.16 2332.79 1315.72 2280.73 0.00 5951360.11 689976.07 MWD+IFR 9014.86 30.99 107.37 8154.70 8095.90 2334.78 1313.44 2288.04 0.00 5951358.01 689983.43 TJB 9100.00 30.99 107.37 8227.69 8168.89 2346.14 1300.35 2329.87 0.00 5951345.97 690025.58 MWD+IFR 9165.46 30.99 107.37 8283.80 8225.00 2354.87 1290.29 2362.04 0.00 5951336.72 690057.99 7" 9191.29 30.99 107.37 8305.94 8247.14 2358.32 1286.32 2374.73 0.00 5951333.07 690070.77 Start Dir 1 ? 9200.00 30.54 105.15 8313.43 8254.63 2359.56 1285.07 2379.01 14.00 5951331.92 690075.08 MWD+IFR 9212.01 29.98 102.01 8323.80 8265.00 2361.51 1283.65 2384.89 14.00 5951330.65 690080.99 Shublik 9277.16 28.39 83.52 8380.80 8322.00 2376.93 1282.01 2416.27 14.00 5951329.79 690112.40 TSAD / TZ 9300.00 28.45 76.80 8400.89 8342.09 2384.23 1283.86 2426.97 14.00 5951331.91 690123.05 MWD+IFR 9385.02 31.43 53.56 8474.80 8416.00 2419.49 1301.72 2464.65 14.00 5951350.70 690160.27 42 SB 9400.00 32.34 49.99 8487.52 8428.72 2426.95 1306.61 2470.86 14.00 5951355.75 690166.36 MWD+IFR 9444.20 35.56 40.51 8524.21 8465.41 2450.97 1324.00 2488.28 14.00 5951373.57 690183.34 End Dir 9448.61 35.56 40.51 8527.80 8469.00 2453.51 1325.95 2489.95 0.00 5951375.56 690184.96 TCGL / TZ 9500.00 35.56 40.51 8569.60 8510.80 2483.10 1348.68 2509.36 0.00 5951398.75 690203.80 MWD+IFR 9535.89 35.56 40.51 8598.80 8540.00 2503.76 1364.54 2522.92 0.00 5951414.96 690216.96 BCGL/TZ2 9541.34 35.56 40.51 8603.23 8544.43 2506.90 1366.95 2524.98 0.00 5951417.42 690218.95 Start Dir 1 ~ 9600.00 38.48 27.74 8650.13 8591.33 2542.03 1396.13 2544.59 14.00 5951447.07 690237.83 MWD+IFR 9635.93 40.88 20.81 8677.80 8619.00 2564.71 1417.03 2553.97 14.00 5951468.19 690246.69 23 SB 9700.00 46.05 10.13 8724.35 8665.55 2606.68 1459.41 2565.50 14.00 5951510.85 690257.15 MWD+IFR 9758.30 51.48 2.01 8762.80 8704.00 2645.83 1502.94 2569.99 14.00 5951554.47 690260.56 21TS 9800.00 55.66 356.95 8787.57 8728.77 2673.96 1536.46 2569.65 14.00 5951587.97 690259.38 MWD+IFR 9804.06 56.08 356.48 8789.85 8731.05 2676.69 1539.81 2569.46 13.97 5951591.32 690259.11 End Dir 9848.77 56.08 356.48 8814.80 8756.00 2706.74 1576.85 2567.18 0.00 5951628.29 690255.91 TZ16 9900.00 56.08 356.48 8843.39 8784.59 2741.17 1619.28 2564.58 0.00 5951670.63 690252.24 MWD+IFR 9908.83 56.08 356.48 8848.31 8789.51 2747.11 1626.59 2564.13 0.00 5951677.93 690251.61 Start Dir 1 ~ 9920.67 57.47 355.40 8854.80 8796.00 2755.07 1636.47 2563.43 14.00 5951687.79 690250.66 TDF 9990.13 65.78 349.65 8887.80 8829.00 2801.84 1696.96 2555.37 14.00 5951748.06 690241.10 02-09C Flt 10000.00 66.98 348.90 8891.76 8832.96 2808.44 1705.85 2553.69 14.00 5951756.90 690239.20 MWD+IFR 10005.30 67.62 348.50 8893.80 8835.00 2811.97 1710.64 2552.73 14.00 5951761.67 690238.12 BSAD 10064.42 74.88 344.29 8912.80 8854.00 2850.80 1765.00 2539.53 14.00 5951815.67 690223.57 TDF 10068.32 75.36 344.02 8913.80 8855.00 2853.31 1768.62 2538.50 14.00 5951819.27 690222.45 02-09C Flt 10100.00 79.28 341.89 8920.76 8861.96 2873.40 1798.16 2529.44 14.00 5951848.57 690212.66 MWD+IFR 10186.42 90.03 336.31 8928.80 8870.00 2924.71 1878.38 2498.77 14.00 5951928.00 690180.00 02-09C Tg 10200.00 90.67 338.10 8928.72 8869.92 2932.46 1890.90 2493.51 14.00 5951940.38 690174.43 MWD+IFR 10214.85 91.37 340.06 8928.45 8869.65 2941.33 1904.76 2488.21 14.00 5951954.11 690168.79 End Dir : 1 10300.00 91.37 340.06 8926.42 8867.62 2993.35 1984.79 2459.18 0.00 5952033.38 690137.77 MWD+IFR 10400.00 91.37 340.06 8924.04 8865.24 3054.44 2078.76 2425.08 0.00 5952126.47 690101.34 MWD+IFR 10500.00 91.37 340.06 8921.65 8862.85 3115.53 2172.74 2390.98 0.00 5952219.56 690064.91 MWD+IFR 10600.00 91.37 340.06 8919.27 8860.47 3176.62 2266.72 2356.89 0.00 5952312.66 690028.48 MWD+IFR 10700.00 91.37 340.06 8916.88 8858.08 3237.71 2360.70 2322.79 0.00 5952405.75 689992.06 MWD+IFR 10800.00 91.37 340.06 8914.50 8855.70 3298.80 2454.67 2288.69 0.00 5952498.84 689955.63 MWD+IFR gent IS S S S S S I S S S 4 S I S S S 4 S .8 S i8 S S 1 S S S S S S Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/7/2007 'time: 15:40:41 Page: 4 Field: Prudhoe Bay Co-ordinate(N E) Referenc e: Well: 02-09, True North Site: PB DS 02 Vertical (TV D) Reference: 02-09C Plan 58.8 Well: 02-09 Section (VS) R eference: Well (O.OON,O.OOE,3 2.39Azi) Wellpath: Pla n 02-09C Survey Calculation Method: Minimum Curvature Ub: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S ' E/W DLS MapN MapE TooVCo ft deg deg ft ft ft ft ft degl100ft ft ft 10829.18 91.37 340.06 8913.80 8855.00 3316.62 2482.09 2278.74 0.00 5952526.00 689945.00 02-09C Tg 10869.70 92.67 343.03 8912.37 8853.57 3342.19 2520.50 2265.93 8.00 5952564.07 689931.23 End Dir : 1 10900.00 92.67 343.03 8910.96 8852.16 3361.90 2549.45 2257.09 0.00 5952592.79 689921.67 MWD+IFR 11000.00 92.67 343.03 8906.31 8847.51 3426.96 2644.99 2227.93 0.00 5952687.57 689890.14 MWD+IFR 11100.00 92.67 343.03 8901.66 8842.86 3492.02 2740.54 2198.78 0.00 5952782.35 689858.62 MWD+IFR 11200.00 92.67 343.03 8897.00 8838.20 3557.07 2836.08 2169.62 0.00 5952877.13 689827.09 MWD+IFR 11300.00 92.67 343.03 8892.35 8833.55 3622.13 2931.62 2140.46 0.00 5952971.91 689795.56 MWD+IFR 11400.00 92.67 343.03 8887.69 8828.89 3687.19 3027.16 2111.31 0.00 5953066.69 689764.03 MWD+IFR 11500.00 92.67 343.03 8883.04 8824.24 3752.24 3122.70 2082.15 0.00 5953161.47 689732.50 MWD+IFR 11600.00 92.67 343.03 8878.39 8819.59 3817.30 3218.25 2052.99 0.00 5953256.25 689700.97 MWD+IFR 11612.61 92.67 343.03 8877.80 8819.00 3825.51 3230.29 2049.32 0.00 5953268.20 689697.00 02-09C Tg rent • ~ 9 •~ ~ .~ ~ x Y y o fi„ ~ y4•7y 8~ ~ '~01'~ ~o '3 ~~ ~'3 ~yy t~ ~~{ Y '= 7 d~;C'~~'~'~~~~d ~3 tl'~3+1 s'A~~ ~ gg ~ 3~% ~z ~3~ ~ a.3$ ~ ~ ~ a~~~~~~i~~~yc~= 88~58"3a8 `3 y s a 3 ~-~ 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O ~ - a ~2r~~~~~#~~«.. FAO ~Orrrroo oo o00o co.a ~ -+z ~ ~ ^\ ~ 8'==$~ __33~~: v..n ~i oa Sd~~~^.~3~.. I I I I I I I ~ / ~~ y 9 8'8'2 s'.SFs A^ ~ ~`~ U y ~ w ~.~3~~~~ ... Eogogogooo$ogog ~ v,r ONVir ONVirON~n ~ f-M1. ~ a zx~_,>., ~~~~a~~iS=_'=`-_ i~ ~ [L ~O ~orrrroo oo oo oocac O ~ w y +~ ~ _'.^.„~r.-==--- g ~=a~~ ~ a ~ ~ > ~a~ ~'~~~ ~K~4 ~_.._~ 3 O ~ u .. C O O _ _ 3 ~ L a ~ :J y L 3 ~=~ ~ e O sr ~ ~< ~ U ~ 4 p~v ~~_ 1 .. , 000 ' fl ' v, C ~ r , . N ~ ~ ~.~ Q s ~~ O Fw- .. ~ s a ~N 3 ~ ~ ~ ~ Q ~ ~ ~ ~ z M M N ~"~ 3 ~ ~ y ~ V '; ~ L ~' 3 O ~-~~• 3 _ ~ ~ N J ' ~, '~ 3 - ~ N .; ~~ !! ~~ N O ~ O ~ s r ~ O ~ ~ O ~ O N ~ r s • 0 `D Sperry-Sun Anticollision Report Company: BP Amoco Date: 8/7/2007 Time: 15:40:11 Puge: 1 Field: Prudhoe Bay Reference Sitc: PB DS 02 Co-ordinate(NE) Reference: Welh 02- 09, True North Reference Well: 02-09 Vertical (TVD) Reference: 02-09C Plan 58.8 Reference ~VeUpath: Plan 02-09C Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tlre/ihTeerodis in this fRtdlCipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 6800.00 to 11612.61 ft Scan Method: Trav Cylinder North Maximum Radius: 1 358.41 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/2/2007 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 96.80 6800.00 1 : Camera based gyro multisho (100 .80-10496~`(RO-MS Camera based gyro multishot 6800.00 11612.61 Planned : 02-09C Wp 7.0 V7 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name. ft ft in in' 9165.46 8283.80 7.000 8.500 7" 11612.61 8877.80 4.500 6.125 41/2" Summary <--------- Offset Wellpath =-----> Reference `Offset Ctr-Ctr' Na-Uo Allowable Site - WeR Wellpath MD MD Distance Area Deviation ~~'arning ft ft ft ft ft PB DS 02 02-01 02-01 V2 6805.69 6825.00 922.54 308.61 613.93 Pass: Major Risk PB DS 02 02-01A 02-01A V1 6808.62 6825.00 642.68 146.42 496.26 Pass: Major Risk PB DS 02 02-01 B 02-01 B V1 6807.98 6800.00 618.02 148.30 469.72 Pass: Major Risk PB DS 02 02-09 02-09 V2 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-09 02-09A V3 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-09 02-09AP61 V5 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-09 02-09AP62 V5 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-09 02-096 V4 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-09 02-096P61 V3 6800.80 6800.00 0.00 0.76 -0.75 FAIL: NOERRORS PB DS 02 02-13 02-136 V16 9250.00 9050.00 1186.88 544.03 642.84 Pass: Major Risk PB DS 02 02-29A 02-29A V3 Out of range PB DS 02 02-29A 02-296 V6 Out of range PB DS 02 02-29A 02-29C V3 9925.00 10100.00 1133.20 260.47 872.72 Pass: Major Risk PB DS 02 02-29A 02-29CP61 V1 9803.75 9900.00 1203.76 266.72 937.04 Pass: Major Risk PB DS 02 02-31 02-31 V9 9301.38 8950.00 441.50 175.64 265.86 Pass: Major Risk PB DS 02 02-31A 02-31A V1 9590.40 9375.00 389.90 194.42 195.48 Pass: Major Risk PB DS 02 02-31APB1 02-31APB1 V1 9301.38 8950.00 441.50 175.64 265.86 Pass: Major Risk PB DS 02 02-37 02-37 V3 11597.72 9125.00 541.38 83.60 457.77 Pass: Major Risk PB DS 02 02-37 02-37L1 V3 11597.72 9125.00 541.38 83.62 457.76 Pass: Major Risk PB DS 02 02-38 02-38 V1 11469.91 9375.00 1271.65 242.33 1029.32 Pass: Major Risk PB DS 02 02-38L1 02-38L1 V1 11470.27 9375.00 1272.14 242.35 1029.79 Pass: Major Risk PB DS 05 05-36 05-36A V3 9613.86 12108.00 834.45 663.88 170.57 Pass: Major Risk PB DS 05 OS-36 OS-36AP61 V2 9625.00 11952.00 967.64 610.24 357.40 Pass: Major Risk Site: PB DS 02 Well: 02-01 Rule Assigned: Major Risk Wellpath: 02-01 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD T'VD MD TVD Ref Offset T'FO+AZI TFO-HS Casing/IISDistance Areu Deviation Warning - fit -ft ft fit - - ft - fit deg deg - in - ft ft - ft - - 6805.69 6264.81 6825.00 6619.05 77.65 27.29 281.15 229.32 922.54 308.61 613.93 Pass 6812.80 6270.58 6850.00 6642.65 77.64 27.26 281.13 228.29 935.82 307.89 627.93 Pass 6820.00 6276.37 6875.00 6666.26 77.64 27.22 281.11 227.27 949.43 307.20 642.23 Pass 6859.92 6308.55 6900.00 6689.87 77.79 27.74 280.63 228.18 963.00 308.95 654.05 Pass 6900.98 6342.01 6925.00 6713.49 77.93 28.25 280.17 229.12 976.13 310.82 665.31 Pass 6918.46 6356.36 6950.00 6737.10 77.84 28.47 280.17 228.08 989.11 310.85 678.26 Pass 6935.92 6370.76 6975.00 6760.72 77.75 28.69 280.19 227.04 1002.18 310.87 691.31 Pass 6953.35 6385.19 7000.00 6784.35 77.67 28.91 280.22 226.01 1015.34 310.88 704.46 Pass 6970.75 6399.64 7025.00 6807.97 77.58 29.13 280.27 224.97 1028.58 310.88 717.70 Pass 6988.11 6414.12 7050.00 6831.60 77.49 29.35 280.33 223.93 1041.90 310.86 731.03 Pass Alaska Department of Natural sources Land Administration System Page 1 of 2 r-:: , ~::,~ ~ ~,~s. ~:~cr~~ _ ~~rarch Stag Gabins ~t~.tr~ ~~ C~ a~Ca ~~ ~c~Se ~ ~r File Type: Aug File Number: „ _ ,,.28308 ~ ~ Printable Case Fife_Summary See Township, Range, Section and Acreage? ~` Yes ~ No New Search j L AS Menu I Case Abstract I Case Detail I Land Abstract Iilr: Al)L 2'~30~ ~''! Search for Status Plat Updates :~~ ~,f 10-'1 T2U07 Customer: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANACER- ALASKA ANCHORAGE AK 995196612 Cuse Tlhe: 7~4 O1L & GAS LEASE COMP 1%ile Location: DOG DIV OIL AND GAS Case Stabs: 35 ISS/APPRV/ACTV/ AUTH Totul Acres: 2560.000 DNR Uf~it: 780 OlL AND GAS Status Date: 09/ 14/1965 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DFV OIL AND GAS Last Trausactio~r Date: 12/04/2006 Case Subtype: ~~-~ NORTH SLOPE Last Ti~uusaction: AA-NRB ASSIGNMENT APPROVED Meridian. U Tou~r~ship: 01 IN R~m~=~ : O l ~C ~~~~c~~i<~jr.~ ~ ~ S~~~ctiof~ Aci°es: 6 kU Search Pia~s 1lleridl~m.~ U Ibwns'hip: Ol IN Rc~ti«c'' U I ~~ E. ~'<~c/i~,it ~ ~(~ Me~~idr~m. U ToN~rtship: O1 1N l~arr~~rc.~ 1) I -~L ,Sc~c~iuir: 35 NI~r<<licrr~: U Tinrn~ht~~~ (ll ll~~ R~rn;~~. (ll~l: Scctiori.~ _iG Legal Description 0~ -?~-196 * ~` ~S_=1LE NOTICE LEGAL DESCRIPTION C1-1-129 11NI~E UM2~,26,3~,362~60.00 U- 3- 7 ~Ci~ fit" Last updated on 10/17/2007. ti'~~ction :Acres: 640 Section Acres: 640 S'c~c~tir~~i : is r~~s: 640 http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=283 08... 10/ 17/2007 Page 1 of 1 Maunder, Thomas E (DOA) From: Peltier, Travis M [Travis.Peltier@bp.com] Sent: Thursday, October 18, 2007 2:38 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 02-09C Attachments: 02-09C Permit to drill.doc Tom, Good catch. I forgot to update that part of the permit when I changed the 7" casing TOC to 3000'. Changes are in both intermediate (lead & tail slurry) and production (+2 more bbls Class G) cement programs. The yield on the class G is 1.17 and the lite Crete is 3.26. The rest of the document remains the same. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 18, 2007 2:15 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: DS 02-09C Travis, I am reviewing the permit application for this welt and have a question ... 1. is the 1.62 yield correct for the 7" cement? 1.62 seems a little high fora 15.8 ppg slurry. Thanks in advance, Tom Maunder, PE AOGCC 10/19/2007 RE: 02-09C Sundry • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, September 28, 2007 4:27 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: RE: 02-09C Sundry Travis, have no objections. Tom Maunder, PE AOGCC oa-c~~, c~ From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Friday, September 28, 2007 11:06 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: 02-09C Sundry Tom, ~`~~'~~~ This new procedure looks to address your concerns from the previous procedure. The cement will be squeezed, and the tubing test follows the P&A guidelines for 0.25psi/ft to the casing shoe (8400' TVD). Please look it over and let me know if this is acceptable with the state. -Travis Peltier PS Have a great weekend. 02-09C_O erations Summer Current Status: o CIBP at 10690' MD. o CMIT - IAxOA -Passed to 3000 psi (3/19/07) 0 1 joint of 5-1/2" tubing corroded 63% @ 4,375' MD (wall penetration only] (3/5/06) o Fluid in cellar (fresh water) (12/13/05) Pre Rig Operations 1. SLICK: Pull POGLV at 3944' MD. 2. CO{L: Drift tubing through GLM at 7080' MD to CIBP at 10,690', if possible. 3. COIL: Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. 11/23/2007 RE: 02-09C Sundry ~ • Page 2 of 3 Volume of 2-718" firom 10,690' to 8724': 0.0058 bpfi, 1966' = 11.4 bbls Volume of 4-1/2" from 8724' to 8639`: 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 1000 psitf operations allow. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. SBHP: 3300 psi SBHT; 190 °F 4. COIL: Freeze protect tubing with Diesel to 2200' TVD. 5. Test tubing to 2,125 psi (reduced for tubular corrosion). Test IA and OA to 2000 psi. Pressure tests are required for competent barrier for rig operations. If test faits due to tubing issue, contact ODE. 6. Bleed casing and annulus pressures to zero. 7. SLICK: Drift to TOC. Be aware of GLM at 7080'. 8. Function tubing and easing LDS. Repair/replace as required. 9. Test tubing packoff to 5000 psi. Test 9-5/8" casing packoff to 3800 psi (80°f° of collapse resistance 47# L$0). 10. Set a BPV. Remove well house and flow line. Level pad as necessary From: Maunder, Thomas E (DOA) [mailtp..tom.m~under<aalaska.gc?v] Sent: Monday, September 24, 2007 5:06 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); aogcc prudhoe_bay@admin,state.ak.us Subject: RE: 02-09C Sundry Travis, Sorry I am late in my reply. Yes, it is appropriate to rearrange the procedural steps as you propose. You will likely have to allow time for the cement to set prior to the pressure test unless you plan to employ some sort of retainer. Although you don't say a squeeze is necessary, it may be appropriate to bump the cement with a little pressure. That should insure that there are no voids. With the possible tubing compromise is it advisable to test above the cement to 3500 psi? If the tubing fails, then the 9-5/8" and possibly 13-3/8" casing could be exposed to pressures higher than you might desire. Please have the rig supervisor contact the Inspector for possible witness of the plug pressure test. Call or message with any questions. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC From: Peltier, Travis M [rr~z ~ 4~ r~°}f9, r~34 ~~,~;,~~;] Sent: Monday, September 24, 2007 4:50 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: FW: 02-09C Sundry i nm in ~s~ fr-s t':_:.r F?'1 ~ ,r,p i-~~r ~P`, fiz~T:~G~ ;5s-,. (}?A! ihifli.(~C'! rs~ ~r n~f \ftfli . .. rl f? s3r~~a~F e ~.~1a3 l.:r Cijr° i( i/C?l.: rE C~~if°;] !~!3l! T From: Peltier, Travis M Sent: Friday, September 21, 2007 9:55 AM 11 /23/2007 RE: 02-09C Sundry ~ • Page 3 of 3 To: 'tom_maunder@admin.state.ak.us' Cc: Hobbs, Greg S (ANC) Subject: 02-09C Sundry Tom, I am looking to change my order of operations for the Pre-Rig work listed on the Sundry Application for 02-09C (see pages 4 and 6 of attached Sundry). Upon reviewing the Sundry's pre-rig ops and the current schematic for 02-09B, there is no isolation from the top perfs to successfully test the tubing to 3500 psi. I would like to cement the perfs up to 8639' and then test the tubing integrity rather than test the tubing and cement the perfs (see below). Please let me know if this is acceptable. -Travis Peltier (907)564-4511 Current Status: ^ CIBP at 10690` MD. ^ CMIT - IAxOA -Passed to 3000 psi (3/19107) ^ 1 joint of 5-1/2° tubing corroded 63°!0 @ 4,375` [watt penetration only) (3!5/06} ^ Fluid in cellar (fresh water} (12/13/05} Pre Ria Operations 1. SLICK: Pull POGLM at 3944' MD. (FORMERi Y 2;~,a} 2 COIL: Drift tubing through POGt_M at 7080' MD to CIBP at 10,690', if possible. 3. COIL: Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-112" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls ff unable to tag 10,690' due to fill, adjust cement to adjust for tagged bottom. Squeeze pressure is not required. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. 4. Test tubing to 3500 psi. Test IA and OA to 2000 psi. {FORMERLY ~ l Pressure tests are required for competent barrier for rig operations. 5. SLICK: Drift to TOC. Drift tubing to top of POGLM at 7080' for upcoming jet cut. 6. E-LINE: Jet cut 5-1/2" tubing in the middle of the first full joint above the POGLM at 7080'. 7. Circulate well to seawater through the cut until returns are clean. 8. Bleed casing and annulus pressures to zero. Freeze protect with Diesel to 2200' TVD. 9. Function tubing and casing LDS. Repair/replace as required. 10. Test 9-5l8" casing packoff to 500 psi. 11. Set a BPV. Remove well house and flow line. Level pad as necessary. 11 /23/2007 t TRANSMITTAL LETTER CHECKLIST WELL NAME /~.l~L~ Ov~-O~' PTD# 0?0~~.~90 Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50• - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (,name of well) until after (Campanx,Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. lCompany Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 ~ ~ ^~ ~ ~ ~ ~ ~ ~ ~ ~, ~ a ; ; ~ ~~ , ~ o d , o ~ ~ ~ ~ ~, ~ , ~ , ~'~ ~ = `o; f6; C ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O• ~ N. ~ N, C a L J' d N. p O~ f9. C~ ~ O N' O ~ ~ ~ N 4 o, `~ E O ~ > O' N. 3 ° L. ~ ~ a. a> o ~ E' 'C' c' a , , ~ ~ ~ ~ ~ , N' v. O. f0. ~ f6. - 4 d ~ ~ ~ ~ OA , ~ ~~ ; 3' ~ ' N' ; 3 a; a Ol c' ul. c, Or V, C C. C' ~ ~ ~~ ~ y. N. o - w' a' -° m' O' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ C' ~~ N O. Z Z, , O, ~ M~ ~ ~ N~ CD. ~ ~ ~ ~ ~ ~ ~ ~ ~~ O. p. O' . . 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'c. a, ;° . , ~ ~; ;° ~+ m; Q; ~~ _ Q. ~' ~; 3 3; a a~ ~ ro' a, E. a~ o . a~ '~ `~ 'v ~ c. 3 m ~; ti, ~ M. ~ ° L o o ° y ~, ~, a~ 4 d ° ~ m 3 i ~ o o 3 ~ ~ ~ ~ ° ~ ~ o w V o O O a Q a o. a w 'v. m a~ a, , a~' > a ~ a' a~ fl, a. ~' ~ a. ° o , .. ~ ~ o c' ~~ . 'o' ~ o. o . ~ Q a~ o' . Y' ° -°o o ~' E' a~, ~ °' m E o. rn r . c, j o , a. m a y ~ m a ~ , L d a Q d N Q ~ N , o, N Q ~ o. U C ~ N O- ~ ~~ ~ x - a , N ~ a ~ ~ C U • , i >; C. N ~~ c O, ot3 ' v. . . ~, E. ca' O, . O o1 a~' (6' d N, ~~ 4 ,v_~, f6' y, !~~ <a , . ~~~ .' 'c, m of d ca' co ~ ~ m. m~ N' m , m~, o m, of ' p' . ~ >, ~ -O N 3' 2. ~~ -o~ O ~ t ~, °~ . ~' o. ' ~ n O C ~ p i ~ > C Y N Q ' d ~ N O a N _ N ~ J t6' 1'j. , a. a a U. N, C ~, L, L, -O, L, ~, ~ ~ U ~, O, O, >, ~ C L. N ~ ." N~ O O N U U L' C' ~ a C j(~\ L N' E' N' ~ N O. L, G C. ~ , ~, ~ j W (6. O U ~ ~ U ~ ~ ,~ - ~ a ~ O, (6. U C, N. . O. O U N, C " ~ f- I ~ ~~ , V, V, C o, °, °, U• ° ~, . •a~, ~ ~ O U' m m U' ~ , . ' U• o -' o, o i , , ~ ~ ~, ~, ~, o, •3 ~ p~ , ~, , ~ ~~ ~, v` ~~ -c, ~ , . Q ui ~ -, C. '3, ~ .m V, ~~ a •~' ~ ~ ~ ~._ d J 00 E' a~ ~ .$ ~, ~ ~ `.t, a ' a> a>, ~ ~ c ~ 3~ ad , c. c. `f4t ~ ~ ' ' ~' ' 'vc a°i ` asi ~ ;c ' d d o, ' a a cLi ~, :°. N m. c. ~ -~~ Y >, o. a~ c, ~ v ° d a~ a~ m j - o, o, ° ~ ~ ~ m a ca a, o L, O O ai a~, m, . o, a~ o, D w Q = O .- N M V' ~O CO I~ _ W O) O N M V ~ CO I~ W 6~ O N M d' u7 O n M O O ~ N M_V' ~O (D h 00 O) ~ A N N N N N N N N N N M M M M M M M M M M V f- O _ O O ~~ r2 C w N w _ON w N U C ~ w Q ate- Q ~~ D r N ~ fL6 O ~ C • O O O p 'N O y N ~ p N J J i# C G (n ~ G A 01 O Q (n C,1 ~ a a a s w a ~ I ~ a d Well History File APPENDIX • Information of detailed nature that is nat particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information- 01 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. ~ r 2-09c.tapx Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 29 07:51:10 2008 Reel Header Service name .............LISTPE Date . ...................08/04/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/04/29 0rigin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: 02-09C API NUMBER: 500292015303 OPERATOR: BP Exploration Alska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 28-APR-08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: Mw0005194551 Mw0005194551 Mw0005194551 LOGGING ENGINEER: GEOFF SAMONS GEOFF SAMONS SHAWN POLAK OPERATOR WITNESS: BILL DECKER BILL DECKER BILL DECKER MWD RUN 5 MAD RUN 5 MAD RUN 5 JOB NUMBER: Mw0005194551 Mw0005194551 Mw0005194551 LOGGING ENGINEER: SHAWN POLAK SHAWN POLAK SHAWN POLAK OPERATOR WITNESS: BILL DECKER BILL DECKER BILL DECKER SURFACE LOCATION SECTION: 36 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 4064 FEL: 4308 FWL: Page 1 a~~ ~a9 ~r~~~ ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 2-09c.tapx 57.11 28.61 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3522.0 6.125 7.000 9030.0 • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 4644'MD/4476'TVD IN THE 2-09B WELLBORE. NO DATA ARE INCLUDED FOR THIS RUN. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 4,5 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC RESISTIVITY - PHASE 4 (EWR4), AND AT-BIT INCLINATION (ABI). MWD RUN 5 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD PASS DATA WERE ACQUIRED OVER TWO INTERVALS IN THE PRODUCTION ZONE. THESE DATASETS WERE MERGED AND ARE PRESENTED SEPARATELY. 6. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP) DATED 1 APRIL 2008, AS AUTHORIZED BY PRIYA MARAJ (BP). THIS MWD LOG IS THE PDCL FOR 2-09C. 7. MWD RUNS 1-5 REPRESENT WELL 2-09C WITH API# 50-U29-20153-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11471'MD/8872'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 ~ r 2-09c.tapx SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4-8.8 PPG MUD SALINITY: 3800-18000 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4350.0 11408.0 ROP 4681.5 11471.0 RPS 8974.0 11415.0 FET 8974.0 11415.0 RPM 8974.0 11415.0 RPX 8974.0 11415.0 RPD 8974.0 11415.0 NPHI 9989.5 11379.5 FONT 9989.5 11379.5 NCNT 9989.5 11379.5 DRHO 10003.0 11395.0 RHOB 10003.0 11395.0 PEF 10003.0 11395.0 Page 3 U BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED 2-09c.tapx DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 4350.0 4767.0 MWD 3 4767.0 9030.0 MWD 4 9030.0 10080.0 MwD 5 10080.0 11471.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 RoP MWD FPH 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4350 11471 7910.5 14243 4350 11471 FONT MWD CP30 279.38 938.67 612.818 2781 9989.5 11379.5 NCNT MWD CP30 18767.4 34226.2 28463.8 2781 9989.5 11379.5 RHOB MWD G/CC 1.862 3.047 2.44281 2785 10003 11395 DRHO MWD G/CC -0.201 0.695 0.0771788 2785 10003 11395 RPD MWD OHMM 0.65 2000 117.965 4883 8974 11415 RPM MWD OHMM 0.67 2000 107.999 4883 8974 11415 RPS MWD OHMM 0.74 849.67 59.5256 4883 8974 11415 RPX MWD OHMM 0.74 763.29 62.4375 4883 8974 11415 FET MWD HR 0.25 64.27 4.13646 4883 8974 11415 GR MWD API 5.15 501.27 92.5972 14117 4350 11408 PEF MwD B/E 0.94 6.07 2.2632 2785 10003 11395 ROP MWD FPH 0.19 854.34 156.209 13580 4681.5 11471 Page 4 ~ ~ 2-09c.tapx NPHI MwD Pu-s 17.59 34.07 24.1028 2781 9989.5 11379.5 First Reading For Entire File..........4350 Last Reading For Entire File...........11471 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 9628.0 10490.5 FONT 9628.0 10490.5 NCNT 9628.0 10490.5 RHOB 9642.5 10506.0 DRHO 9642.5 10506.0 PEF 9642.5 10506.0 GR 9655.5 10516.0 RPD 9662.5 10525.5 RPM 9662.5 10525.5 RPS 9662.5 10525.5 RPx 9662.5 10525.5 FET 9662.5 10525.5 T 9719.0 10579.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MwD 5 1 9628.0 9900.0 wD 5 3 9900.5 10579.0 $ REMARKS: MERGED MAD PASS. Data Format specification Record Page 5 2-09c.tapx Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9628 10579 10103.5 1903 9628 10579 FCNT MAD CP30 318.24 868.4 556.474 1201 9628 10490.5 NCNT MAD CP30 18917.4 33770.4 27529 1201 9628 10490.5 RHOB MAD G/CC 2.007 2.816 2.34846 1209 9642.5 10506 DRHO MAD G/CC -0.108 0.289 0.0644239 1209 9642.5 10506 RPD MAD OHMM 15.25 249.16 85.0813 1212 9662.5 10525.5 RPM MAD OHMM 14.9 273.67 82.7301 1212 9662.5 10525.5 RPS MAD OHMM 15.11 238.49 69.6001 . 1212 9662.5 10525.5 RPX MAD OHMM 16.3 473.23 81.0637 1212 9662.5 10525.5 FET MAD HR 30.25 95.5 53.9937 1212 9662.5 10525.5 GR MAD API 14.46 128.98 42.8262 1203 9655.5 10516 PEF MAD B/E 1.09 6.24 2.52262 1209 9642.5 10506 RAT MAD FPH 0.01 12097.8 285.812 1202 9719 10579 NPHI MAD Pu-s 19.13 34.76 25.4689 1201 9628 10490.5 First Reading For Entire File..........9628 Last Reading For Entire File...........10579 File Trailer service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF Page 6 File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD 2-09c.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4350.0 ROP 4681.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 4714.5 4767.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 7 28-NOV-07 Insite 74.11 Memory 4767.0 4350.0 4767.0 36.0 36.0 TOOL NUMBER 134745 8.500 3522.0 Fresh water Gel 9.30 58.0 9.5 900 8.0 .000 .0 .000 81.0 .000 .0 .000 .0 2-09c.tapx HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 ~_I Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4350 4767 4558.5 835 4350 4767 GR MWD020 API 23.69 120.1 61.8842 730 4350 4714.5 ROP MWD020 FPH 9.92 854.34 131.687 172 4681.5 4767 First Reading For Entire File..........4350 Last Reading For Entire File...........4767 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 Page 8 2-09c.tapx RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4715.0 8980.5 ROP 4767.5 9030.0 LOG HEADER DATA DATE LOGGED: O1-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9030.0 TOP LOG INTERVAL (FT): 4767.0 BOTTOM LOG INTERVAL (FT): 9030.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25,9 MAXIMUM ANGLE: 35.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3522.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel .MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 50.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 141.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Page 9 2-09c.tapx Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD030 API 4 1 68 4 2 ROP MwD030 FPH 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4715 9030 6872.5 8631 4715 9030 GR MWD030 API 5.15 401.76 112.784 8532 4715 8980.5 ROP MWD030 FPH 0.89 492.04 188.961 8526 4767.5 9030 First Reading For Entire File..........4715 Last Reading For Entire File...........9030 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......sTSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8974.0 10024.0 FET 8974.0 10024.0 RPM 8974.0 10024.0 RPD 8974.0 10024.0 RPS 8974.0 10024.0 GR 8981.0 10017.0 Page 10 2-09c.tapx ROP 9030.5 10080.0 LOG HEADER DATA DATE LOGGED: 06-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10080.0 TOP LOG INTERVAL (FT): 9030.0 BOTTOM LOG INTERVAL (FT): 10080.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.5 MAXIMUM ANGLE: 35.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232605 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9030.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 45.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.810 69.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.070 122.0 MUD FILTRATE AT MT: 1.450 69.0 MUD CAKE AT MT: 1.600 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Page 11 • 2-09c.tapx Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8974 10080 9527 2213 8974 10080 RPD MWD040 OHMM 0.65 2000 147.164 2101 8974 10024 RPM MWD040 OHMM 0.67 2000 149.06 2101 8974 10024 RPS MWD040 OHMM 0.74 849.67 59.5746 2101 8974 10024 RPX MWD040 OHMM 0.74 324.25 48.0693 2101 8974 10024 FET MWD040 HR 0.5 64.27 5.52976 2101 8974 10024 GR MWD040 API 12.01 501.27 45.993 2073 8981 10017 RoP MWD040 FPH 0.22 433.28 73.0601 2100 9030.5 10080 First Reading For Entire File..........8974 Last Reading For Entire File...........10080 File Trailer Service name... .......STSLI6.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 9989.5 11379.5 NCNT 9989.5 11379.5 NPHI 9989.5 11379.5 Page 12 ! • 2-09c.tapx PEF 10003.0 11395.0 DRHO 10003.0 11395.0 RHOB 10003.0 11395.0 GR 10017.5 11408.0 RPD 10024.5 11415.0 FET 10024.5 11415.0 RPX 10024.5 11415.0 RPS 10024.5 11415.0 RPM 10024.5 11415.0 ROP 10080.5 11471.0 LOG HEADER DATA DATE LOGGED: 09-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11471.0 TOP LOG INTERVAL (FT): 10080.0 BOTTOM LOG INTERVAL (FT): 11471.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.4 MAXIMUM ANGLE: 95.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record TOOL NUMBER 232605 1844674407370955 223565 183652 6.125 9030.0 Fresh water Gel 8.50 43.0 9.1 3650 7.0 1.520 65.6 .830 126.0 1.420 62.0 .980 66.7 Page 13 • 2-09c.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .IIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MwD050 CP30 4 1 68 4 2 NCNT MwD050 CP30 4 1 68 8 3 RHOB MwD050 G/CC 4 1 68 12 4 DRHO MWD050 G/CC 4 1 68 16 5 RPD MwD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MwD050 OHMM 4 1 68 28 8 RPX MwD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MwD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 RoP MwD050 FPH 4 1 68 48 13 NPHI MWD050 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9989.5 11471 10730.3 2964 9989.5 11471 FCNT MWD050 CP30 279.38 938.67 612.818 2781 9989.5 11379.5 NCNT MWD050 CP30 18767.4 34226.2 28463.8 2781 9989.5 11379.5 RHOB MwD050 G/CC 1.862 3.047 2.44281 2785 10003 11395 DRHO MWD050 G/CC -0.201 0.695 0.0771788 2785 10003 11395 RPD MWD050 OHMM 7.43 2000 95.913 2782 10024.5 11415 RPM MWD050 OHMM 6.92 1716.15 76.9897 2782 10024.5 11415 RPS MWD050 OHMM 6.63 302.06 59.4886 2782 10024.5 11415 RPX MWD050 OHMM 6.78 763.29 73.2885 2782 10024.5 11415 FET MwD050 HR 0.25 36.24 3.08423 2782 10024.5 11415 GR MWD050 API 15.82 164.32 73.4737 2782 10017.5 11408 PEF MwD050 B/E 0.94 6.07 2.2632 2785 10003 11395 ROP MWD050 FPH 0.19 412.02 120.114 2782 10080.5 11471 NPHI MwD050 Pu-S 17.59 34.07 24.1028 2781 9989.5 11379.5 First Reading For Entire File..........9989.5 Last Reading For Entire File...........11471 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.007 Physical EOF Page 14 i ~ 2-09c.tapx File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9628.0 9831.0 NCNT 9628.0 9831.0 FCNT 9628.0 9831.0 PEF 9642.5 9846.5 DRHO 9642.5 9846.5 RHOB 9642.5 9846.5 GR 9655.5 9859.5 FET 9662.5 9866.5 RPD 9662.5 9866.5 RPM 9662.5 9866.5 RPS 9662.5 9866.5 RPX 9662.5 9866.5 RAT 9719.0 9900.0 LOG HEADER DATA DATE LOGGED: 09-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9900.0 TOP LOG INTERVAL (FT): 9628.0 BOTTOM LOG INTERVAL (FT): 9900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.4 MAXIMUM ANGLE: 95.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232605 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 223565 ALD Azimuthal L itho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9030.0 BOREHOLE CONDITIONS Page 15 • 2-09c.tapx MUD TYPE: Fresh Wa ter Gel MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 43.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 3650 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.520 65.6 MUD AT MAX CIRCULATING TERMPERATURE: .830 126.0 MUD FILTRATE AT MT: 1.420 62.0 MUD CAKE AT MT: .980 66.7 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MAD051 CP30 4 1 68 4 2 NCNT MAD051 CP30 4 1 68 8 3 RHOB MAD051 G/CC 4 1 68 12 4 DRHO MAD051 G/CC 4 1 68 16 5 RPD MAD051 OHMM 4 1 68 20 6 RPM MAD051 OHMM 4 1 68 24 7 RPS MAD051 OHMM 4 1 68 28 8 RPX MAD051 OHMM 4 1 68 32 9 FET MAD051 HR 4 1 68 36 10 GR MAD051 API 4 1 68 40 11 PEF MAD051 B/E 4 1 68 44 12 RAT MAD051 FPH 4 1 68 48 13 NPHI MADO51 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9628 9900 9764 545 9628 9900 FONT MAD051 CP30 330.18 726.99 547.441 407 9628 9831 NCNT MAD051 CP30 19538.2 31209.8 26981.9 407 9628 9831 RHOB MAD051 G/CC 2.09 2.711 2.27729 409 9642.5 9846.5 DRHO MAD051 G/CC -0.059 0.173 0.044912 409 9642.5 9846.5 RPD MAD051 OHMM 25.03 114.44 68.9724 409 9662.5 9866.5 RPM MAD051 OHMM 20.91 110.41 57.742 409 9662.5 9866.5 RPS MAD051 OHMM 18.25 87.22 40.2489 409 9662.5 9866.5 Page 16 2-09c.tapx RPX MAD051 OHMM 16.78 76.96 34.3669 409 9662.5 9866.5 FET MAD051 HR 39.72 50.72 45.107 409 9662.5 9866.5 GR MAD051 API 14.46 85.18 30.9813 409 9655.5 9859.5 PEF MAD051 B/E 1.43 4.92 2.31286 409 9642.5 9846.5 RAT MAD051 FPH 0.01 12097.8 410.744 363 9719 9900 NPHI MAD051 PU-S 20.84 32.58 25.1761 407 9628 9831 First Reading For Entire File..........9628 Last Reading For Entire File...........9900 File Trailer Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5L26.007 comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 3 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9831.5 10490.5 NCNT 9831.5 10490.5 FCNT 9831.5 10490.5 DRHO 9847.0 10506.0 PEF 9847.0 10506.0 RHOB 9847.0 10506.0 GR 9860.0 10516.0 RPx 9867.0 10525.5 RPS 9867.0 10525.5 RPD 9867.0 10525.5 RPM 9867.0 10525.5 FET 9867.0 10525.5 T 9900.5 10579.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE Page 17 09-DEC-07 r1 ~..J SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD 2-09c.tapx Insite 74.11 Memory 10579.0 9900.5 10579.0 85.4 95.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .liN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 TOOL NUMBER 232605 1844674407370955 223565 183652 6.125 9030.0 Fresh water Gel 8.50 43.0 9.1 3650 7.0 1.520 65.6 .830 126.0 1.420 62.0 .980 66.7 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MAD053 CP30 4 1 68 4 2 NCNT MAD053 CP30 4 1 68 8 3 Page 18 2-09c.tapx RHOS MAD053 G/CC 4 1 68 12 4 DRHO MAD053 G/CC 4 1 68 16 5 RPD MAD053 OHMM 4 1 68 20 6 RPM MAD053 OHMM 4 1 68 24 7 RPS MAD053 OHMM 4 1 68 28 8 RPX MAD053 OHMM 4 1 68 32 9 FET MAD053 HR 4 1 68 36 10 GR MAD053 API 4 1 68 40 11 PEF MAD053 B/E 4 1 68 44 12 RAT MAD053 FPH 4 1 68 48 13 NPHI MAD053 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9831.5 10579 10205.3 1496 9831.5 10579 FCNT MAD053 CP30 318.24 868.4 561.104 794 9831.5 10490.5 NCNT MAD053 CP30 18917.4 33770.4 27809.4 794 9831.5 10490.5 RHOS MAD053 G/CC 2.007 2.816 2.38484 800 9847 10506 DRHO MAD053 G/CC -0.108 0.289 0.0743994 800 9847 10506 RPD MAD053 OHMM 15.25 249.16 93.2862 803 9867 10525.5 RPM MAD053 OHMM 14.9 273.67 95.4575 803 9867 10525.5 RPS MAD053 OHMM 15.11 238.49 84.5498 803 9867 10525.5 RPX MAD053 OHMM 16.3 473.23 104.848 803 9867 10525.5 FET MAD053 HR 30.25 95.5 58.52 803 9867 10525.5 GR MAD053 API 15.97 128.98 48.9277 794 9860 10516 PEF MAD053 B/E 1.09 6.24 2.62986 800 9847 10506 RAT MAD053 FPH 0.01 1798.79 231.76 839 9900.5 10579 NPHI MAD053 PU-S 19.13 34.76 25.619 794 9831.5 10490.5 First Reading For Entire File..........9831.5 Last Reading For Entire File...........10579 File Trailer Service name... .......STSLI6.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/29 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/04/29 Origin ...................STS scientific Technical Services Page 19 r: Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File 2-09c.tapx writing Library. Page 20 • scientific Technical services