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Home My WebLink About207-087~ ~ Image Project Weli History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~,Q ~- Q~~ Well History File Identi~er Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III (IIIII I) II III III RES AN DIGI AL DATA Color Items: Diskettes, No. ~ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ( Maria ~ Date: Project Proofing OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: D ~ /s/ 1 BY: Maria Date: ~/ ~ ~S~ ~ ~~' ^ Scann~ng Preparat~on x 30 =`~ ~ + _~ = TOTAL PAGES ~ ~~ 1~ ~ D t Q (Count does not include cover ~S~ sheet) BY: Maria a e: Production Scanning I I) I I' lll III II I I II I Stage 1 Page Count from Scanned File: ~(Count does fi P i include cover sheet) ~ YES NO on repara ng Page Count Matches Number in Scann BY: Maria Date:' ~ ~. v ~ l q : ~S~ ~~ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ II I II'lII I I) II I I III Scanning is complete at this point unless rescanning is required. ReScanned ~II ~I~~IIIIIII ~I III BY: Maria Date: ~S~ Comments about this file: Quality Checked ilI I'lll III II'I I I 10/6l2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA APR ZO13 . A OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS fAOGCC 1. Operations Abandon U Repair Well U Plug Perforations 11 Perforate LJ Other U Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2 Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development p Exploratory ❑ 207 -087 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20448 -03 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028308 PBU 02 -16C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: . Total Depth measured 13604 feet Plugs measured None feet true vertical SS97 feet Junk measured None feet Effective Depth measured 13169 feet Packer measured See Attachment feet true vertical 8915.17 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 68 20" 94# H -40 30 - 98 30 - 98 1530 520 Surface 3001 13 -3/8" 72# N -80 28 - 3029 28 - 2674.94 4930 2670 Intermediate None None None None None None Production 9423 9 -5/8" 47# L -80 27 - 9450 27 - 7446.99 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11192 - 11197 feet 11750 - 11950 feet 12250 - 12730 feet 12840 - 13120 feet True Vertical depth 8891.7 - 8893.28 feet 8908.75 - 8901.53 feet 8914.93 - 8926.02 feet 8925 27 - 8916.35 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUL 0 8 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 483 43980 30 -750 1153 Subsequent to operation: 460 43267 30 -750 1203 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorE Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Ell Gas ❑ WDSPUJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summer BP. Printed Name Nita Summerhays i Title Petrotechnical Data Technician Signatur. jl 9% s r,,, . cr - Phone 564 -4035 Date 4/24/2013 RSDMS A' : q- !' /13 T �� Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028308 ACTIVITYDATE I SUMMARY T /I /0= 2422/11/62 Temp =S /I MIT -IA to 2500 PSI PASSED, MIT -OA to 2000 PSI PASSED (Eval liner top gas) Pumped 2 bbls MEOH & 17 bbls 70* crude for IA test. 1st 15 min IAP lost 128 & 2nd 15 min IAP lost 39 for a total IAP loss of 167 in 30 min. Bled back — 6.5 bbls. Pumped 2 bbls MEOH & 10.1 bbls 70* crude for OA test. 1st 15 min OAP lost 146 & 2nd 15 min OAP lost 42 for a total OAP loss of 186 in 30 min. Bled back - 4 bbls. 9/20/2012 FWHP's= 2423/578/213 DSO notified upon departure SWV,SSV,MV =S /I IAV,OAV =OTG T /I /O = 2474680/500 Temp = Online Freeze protect TBG and F/L for SSL. Pumped 10 bbls Neat Methanol folloed by 57 bbls crude and 5 bbls Neat Methanol down Flowline to freeze protect. Pumped 5 bbls Neat Methanol and 38 bbls Dead Crude down TBG to freeze protect. Well S/I notified DSO upon departure. FWHP = 2098/701/502 SV /W /SSV = C M =0 4/1/2013 IA/OA = OTG ** *WELL FLOWING ON ARRIVAL ** *(profile mod) PULLED BKR KB PATCH FROM 7331' SLM ** *LOST 2 ELEMENTS * ** DRIFT W/ 3.805" GAUGE RING, 3.50" WIRE GRAB RECOVERED 1/2 ELEMENT PULLED 4 -1/2" x 2 -7/8" NIPPLE REDUCER FROM 10734' SLM, 10754' MD DRIFTED TO LINER TO W/ 3.805" GAUGE RING, 3.50" WIRE GRAB 4/1/2013 ** *JOB CONTINUED ON 4/2/13 WSR * ** T /I /0= 2400/907/44 Temp =S1 Assist S -Line (Eval liner top gas) Spear in to TBG w/5 bbls of meth followed by 200 bbls of 120* crude to load Pumped 7 bbls of crude to set lower LTP. Pumped 9 bbls crude to set upper LTP. SSL in control of well upon departure. 4/2/2013 IA OA OTG. FWHPS= 0/530/50 ** *JOB CON TINUED FROM 4/1/13 WSR ** *(profile mod) RAN 40 ARM CALIPER FROM 10,760' SLM TO SURFACE RAN 2.45" LIB. TAG TOP OF LINER @ 10,827' SLM, 10,842' MD BRUSHED LINER @ 10,827, SLM SET 35 KB LINER TOP PACKER (OAL= 26.14') @ 10, 822' MD (TOP OF LTP) SET 45 KB LINER TOP PACKER (OAL= 13.06') @ 10,783' MD (TOP OF LTP) 4/2/2013 ** *JOB CONTINUED ON 4/3/13, WSR * ** ** *JOB CONTINUED FROM 4/2/13 WSR ** *(profile mod) INSPECTED DPU TOOLS RIGGED DOWN 4/3/2013 ** *JOB COMPLETE, WELL TURNED OVER TO DSO * ** FLUIDS PUMPED BBLS 122.1 CRUDE 29 METH 2 DIESEL 116 OIL 269.1 TOTAL Casing / Tubing Attachment ADL0028308 Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 20" 94# H-40 30 - 98 30 - 98 1530 520 LINER 845 7 -5/8" 29.7# NT -80S 8454 - 9299 6615.34 - 7316.28 6890 4790 LINER 1655 7" 29# 13CR80 9299 - 10954 7316.28 - 8791.79 8160 7020 LINER 50 3 -1/2" 8.81# L -80 10790 - 10840 8670.79 - 8711.84 LINER 467 3- 3/16" 6.2# L -80 10840 - 11307 8711.84 - 8915.3 LINER 2501 2 -3/8" 4.7# L -80 10843 - 13344 8714.17 - 8907.17 11200 11780 PRODUCTION 9423 9 -5/8" 47# L -80 27 - 9450 27 - 7446.99 6870 4760 • SURFACE 3001 13 -3/8" 72# N -80 28 - 3029 28 - 2674.94 4930 2670 TUBING 5 5 -1/2" 17# L -80 24 - 29 24 - 29 7740 6280 TUBING 10893 4 -1/2" 12.6# L -80 29 - 10922 29 - 8771.17 8430 7500 • 1 • • Packers and SSV's Attachment ADL0028308 SW Name Type MD TVD Depscription 02 -16C PACKER 9270 7232.75 4 -1/2" Baker PBR Assembly 02 -16C PACKER 10766 8591.15 7" Baker SABL -3 Packer 02 -16C PACKER 10783 8605.97 3 -1/2" Baker 45 KB Packer 02 -16C PACKER 10822 8638.77 KB Liner Top Packer TREE= GRAY GR4 2 /WELLHEAD = GRAY SA. NOTES: WELL ANGLE >70° 0 11180'. ACTUATOR = AXELSON 02-1 6 i -NTI KB. ELE '64' BF. ELEV = KOP= ) I 29' H5 -1/2" X 4 -1/2" XO 1 Max Angle = 95" i; [ tum kin= 11093' I 1-i 98 I Datum TVD = 8800' SS I 2103' I- 4-112" CAM TRDP -4A SSSV NP, O = 3.812" 1 5-1/2" TBG, 17 #, L -80, .0232 bpf, D = 4.892" H 29' • GAS LFT MANDRELS 13 -3/8" CSG, 72#, N-80, O = 12.347" 3029' , , ST MD 1VD DEV TYPE VLV LATCH PORT DATE 1 3597 3055 48 TGPD DMY RK 0 11/04/08 L 2 6942 5443 39 TGFO DMY RK 0 11/04/08 3 9100 7148 33 TM'DX OM' BK 0 10/02/93 4 9206 7237 32 TM'DX DMY BK 0 10/02/93 I TOP OF 7-5/8" LN2 -TACK H 8454' I jr I 9270' H4 -112" BAKER PBR I 17 -5/8" LNI -TBK, 29.7 #, NT-80, .0459 bpf, O = 8.875' H 9299' ` MILLOUT WINDOW (02 -16A) 9450' - 9500' I TOP OF CBu1BJT' H 9306' I i r 1 95/8" CSG, 47 #, L -80, D= 8.681" H 9450' i 1. 10764' H 4-1/2" PARKER SWS P P, D = 3.812" I 145 KB LTP, 13= 2.39" (04/02/13) H 10783' I 10766' Hr BAKER SABL -3 R(R 1 Minimum ID =1.81" rLD 10822' Q r ' 10790' 3-1/2" BKRDEFLOYMBYTSLEEVE, D =3.00" I 35 KB LTP i� % 10790' I LEST TOP OF I 35 KB LTP D =1.81" (04102/13) 1 10022' , 1 10810' H 3-1/ " HES X NP D = 2.813" I I3-UT LIAR, 8.81 #, L -80, .0087 bpf, D = 2.990" 10840' II : =' = Vi 10840' H3-112" X 3- 3/16" XO, D = 2.786" I ' ;',1 r . 1 10842' H2-3/8" BKR DEPLOY RENT SLEEVE, D = 2.25" 1 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958' H 10922' 1 i 11 ' * 1 1� • , 10842' 1—I EST ■ T OF CEMENT I 444 ■.• 441 *4 41 4 1 1 1 MILLOUT WINDOW (02 -169) 10954' - 10962' 444 4* 17" LN2, 29//, NT-80, D = 6.184" H 10954' 4.1.i; 44 13 -3/16" LPIR 6.2#, L -80, .0076bpf, D= 2.80" H 1130T PH2FOWATDN SUMMARY 1 I MILLOUT WINDOW (02-16C) 11307' - 11313' REF LOG: MCNJGR LOG 08/28/07 i ANG1EAT TOP FERF:93° 7 11750' Note: Refer to Roduction DB for historical pert data SIZE SPF NTB2VAL Opn/Sqz SHOT SQZ 1.56" 6 11192 - 11197 S 08/26107 08/27/07 1.56" 6 11750 - 11950 0 08/29/07 1.56" 6 12250 - 12730 0 08/29/07 1.56" 6 12840 - 13120 0 08/29/07 1 13169' ( {2 -3/8" CBP(08/26/07) I I PBTD I 13169' 12-3/8" LNR, 4.7 ", L-80, STL, .0039bpf, D =1.92" H 13344' I ■ TD 13604' 1 DATE REV BY OOM ENTS DATE REV BY COMMENTS PR DHOE BAY UNIT 07/2780 PARKER ORIGINAL COMPLETION 12/09/08 SEWISV SET NP REDUCER WELL 02 -16C 09/1287 AUDI 13 WO 02/03/09 RRDISV SET PATCH (01/01/09) PERMT No: 2070870 10/31193 N2ES SIDETRACK (02 -16A) 05/30/12 MSS/JMD MAX ANGLE CORRECTION AR No: 50-029- 20448.03 10/03/04 NORDIC1 CTD SIDETRACK (02 -16B) 04/11/13 SWC/JMD RA.. PATC3111\1 RED/SET 45&35 KB SEC 36, T11N, R14E, 332 Fa & 80T FOIL 08/30107 NDRDIC1 CID SIDETRACK (02 -16C) 11/10(08 GJF /SV GLV C/O (11/04/08) BP Exploration (Alaska) c 1. 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] `241 4/i (13 Sent: Thursday, April 18, 2013 12:47 PM l To: Regg, James B (DOA); Schwartz, Guy L (DOA); 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 Cc: AK, D &C DHD Well Integrity Engineer; Grey, Leighton (CH2M Hill) Subject: NOT OPERABLE: Producer 02 -16C (PTD #2070870) Unsuccessful Gas Mitigation All, Producer 02 -16C (PTD #2070870) was brought online to evaluate whether resetting LTPs would reduce gas production. The resets were unsuccessful in gas mitigation, and at this time the well is to be shut in and made Not Operable. Regards, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator SCANNED Jul 0 8 2013 SW C 'rs CarganizatIon WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator PBP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, April 05, 2013 10:11 AM 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 tells Opt Engr; G GPB FS1 Drillsites; G GPB FS1 DS; AK, OPS FS1 DS2 Operator; AK, D &C Wireline Operations Team Le. AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; olt, Ryan P Subject: UNDER EVALUATION: Producer 02 -16C (PTD #2070870) Evaluatior for Gas Shutoff All, Producer 02 -16C (PTD #2070870) has known TxIA communication. A tubing patch was pulled on 04/01/2013 in order to set liner top packers to shut off gas from a potentially leaking li r lap. We have permission from the AOGCC to flow the well Under Evaluation for 14 days. The well is reclassified as der Evaluation, and can be placed on production for evaluation. Please call with any questions. Thank you, Jack Disbrow 1 P61.A. 02 -«C Regg, James B (DOA) 70 8 7a From: Regg, James B (DOA) Sent: Thursday, April 04, 2013 5:05 PM e /� 14,1 i T 'AK, D &C Well Integrity Coordinator' " ( Cc: Schwartz, Guy L (DOA) Subject: RE: Producer 02 -16C (PTD #2070870) Permission to Evaluate For Gas Shut Off As discussed by phone, PBU 02 -16C is approved to be temporarily flowed without the tubing patch to evaluate if the liner top packers (recently set) are effectively shutting off gas. You estimate flowing the well in this configuration up to 2 weeks to evaluate. Contact me if additional time is necessary. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SCANNED JUL 1 0 2013 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator Cabp.com] Sent: Thursday, April 04, 2013 4:48 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Producer 02 -16C (PTD #2070870) Permission to Evaluate For Gas Shut Off All, Producer 02 -16C (PTD #2070870) is a natural flow producer that has known TxIA communication which has been repaired with a tubing patch. The well has been producing large amounts of gas, and BP suspects the liner lap is leaking. Two liner top packers have been set in an attempt to reduce gas production. In order to run the liner top packers, the patch was pulled. The well is currently shut in and ready to place on production to evaluate the gas shut off. A passing MIT -IA and MIT -OA were performed prior to pulling the patch. The tests are included for reference. Proposed plan forward: BP would like permission from the AOGCC to flow the well Under Evaluation for two weeks without the tubing patch with the intent of determining if the liner top packers have reduced the amount g as tF1e well produces` Gas lift will not be used to flow the well. If the liner top packers are successful in shutting off the excess gas, the tubing patch will be reset and a MITIA will be performed to confirm competent barriers. Thank you for your consideration, Jack Disbrow BP Alaska - Well Integrity Coordinator GW Global Webs Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator Pbp.com 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 e, • '1116 3 21 August 22, 201188 Cent sta Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ' SF.7 2 0 2.0 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 ( lb - 7 - 0 ( 3g Dear Mr. Maunder, Q a- I b 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 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 . . _ ,. 5 -, _v ..~ j~'._ __. ,~IRRR.~ ~. M1 { M~. ~ ~} 4~. ~~~ t ,~ x ~.F~ .-b:....... ''~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Driil 2070870 Well Name/No. PRUDHOE BAY UNIT 02-16C Operator BP EXPLORATION (ALAS!(A) INC API No. 50-029-20448-03-00 MD 13604 ND 8897 Completion Date 8/30/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES, GR / CCL / CNL Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / pe meairrm~ rvumc~r Name Log Cement Evaluation D D Asc Directional Survey Rpt Directional Survey "ED D Asc Directional Survey pt Directional Survey D C Las 15618 Gamma Ray ED C Las 15619 Gamma Ray Log Neutron ED C lis 15892 Neutron D C Pds 17206 Leak LIS Verification ED C Lis 17543 Gamma Ray Log Gamma Ray og Gamma Ray ( Log See Notes JliAltl IYICUIq ry0 JWR JLOF7 Vfl RCliC1VtlU 1iV111111C11W 25 Coi 1 10701 13240 Case 9/14/2007 MCBL, GR< CCL, VDL 25- Aug-2007 0 13604 Open 9/25/2007 0 13604 Open 9/25/2007 0 12808 Open 9/25/2007 PB 1 0 12808 Open 9/25/2007 PB 1 10915 13604 Open 10/26/2007 LAS, GR, ROP w/PDF graphics 10915 12808 Open 10/26/2007 LAS, GR, ROP w/PDF graphics 5 Blu 1 10680 13152 Open 1/22/2008 MCNL, GR, CCL, CNL 28- Aug-2007 10675 13163 Open 1/22/2008 LIS Veri, GR, CNT 0 10785 Case 11/28/2008 LDL, WLD, UMT, CCL, . Temp 8-Nov-2008 10916 13602 Open 2/4/2009 LIS Veri, GR, ROP 10916 13602 Open 2/4/2009 LIS Veri, GR, ROP 25 Col 11307 13604 Open 2!4/2009 MD GR 22-Aug-2008 25 Col 11307 13604 Open 2/4/2009 TVD GR 22-Aug-2008 ,'~~~ Col 10910 13602 Open 2/4/2009 Depth Shift Monitor Plot ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070870 Well Name/No. PRUDHOE BAY UNIT 02-16C M 13604 ND 8897 Completion Date 8/30/2007 R LIS Verification D C Lis 17569 Gamma Ray ~g Gamma Ray Cog Gamma Ray ~oa See Notes Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~~ Chips Received? ~ Analysis ~'N Received? Operator BP EXPLORATION (ALASK~y INC API No. 50-029-20448-03-00 Completion Status 1-OIL Current Status 1-OIL UIC N 10916 12812 Case 2/6/2009 P61 LIS Veri, GR, ROP 10916 12812 Open 2/6/2009 PB1 LIS Veri, GR, ROP 25 Col 11307 12808 Open 2/6/2009 PB1 MD GR 18-Aug-2007 25 Col 11307 12808 Open 2/6/2009 PB1 ND GR 18-Aug-2007 ~ ~,* y Coi 10916 13602 Open 2/6/2009 P61 Depth Shift Monitor Plot ~ Sent Received Dai~y History Received? Formation Tops Sample Set Number Comments N Comments: i ~J ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 02-16CPB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 1506411 Sent by: Terri Tuminello Date: 02/OS-0 ~~ ~~ ~ ~~'' ,.e~ ~,3 "- , ._ Received by: ~ Date: ,~ ,, ,, y ~ 3,i ~ yi~ a1 ?-+~ 3 tJV.i . ~ ~,~ ~.i'~ rn~ :,i.,~m ~.':~~. PLEASE ACKNOWLEDGE RECEIPT BY ~ ~ ~1~~~,~~TURNING OR FAXING YOUR COPY ~ FAX: (907) 267-6623 Baker Hughes INTEQ (~~ 7260 Homer Drive ~~R Anchorage, Alaska 99518 ~ ~~y ~ ~ ~ ~~~ ~ Direct: (907) 267-6612 '~d II~CTEQ ~ FAX: (907) 267-6623 ~ ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 02-16C Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 1506411 Sent by: Terri Tuminello Date: ~ ;~ ~~~~. ,~~, .. /~ '3 -~ ',~~ ;?~-s:~ 'a ~ ;. .. ,~ : Received by: ( v Date: ~ ~ ~ ;° :~, „ !~ ~{, ~?~ PLEASE ACKNOWLEDGE RECEIPT B ~ ~ ~ ~ ~~ ~ ~~ ~~~~~ ~ ~ RNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~i 7260 Homer Drive ~ _f~ '~ ~~~ Anchorage, Alaska 99518 ~~ `r ~ D'uect: (907) 267-6612 ~ /~~~3 I NT EQ FAX: (907) 267-6623 ' ~ ~/ ~~ BAKER NV6HE5 ~ Bal~er Atlas PRINT DISTRIBUTION LIST FIELD PRUDHOE BAY UNIT DATE THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO #: 1506411 CUMYANY t3Y ~XYLUIZAI'IUN (ALASKA) 1N(: WELL NAME 02-16C C:UUN'l Y NUK'1'H SLUY~ 13U1ZUUCiH STATE ALASKA 2/3/2009 Copies of Copies Digital Copies of Copies Digi[al Each l.og of Fiim Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DNISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE_ AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Comoleted Bv: '~~ i ~ ` 3 s ~ ~a ~ ~ .~ ~.~ . ~-~ ~ ~ ~ ~ ~;Y;7 ~d' ~ ~D"~-O~~ ~ re °-, il. '' ~ i~ ,) ~ ~ ~'. ~~. ~f~ ~,~~~-~;~~~~~~ ~,:~~~ :z~ :~~a.~ -;~ Page t of 1 ~' ~~ ~ STATE OF ALASKA /~ ALAS~OIL AND GAS CONSERVATION COM~If~I~ ZOO~ REPORT OF SUNDRY WELI~~~~,~IC~NS r_ _ 1. Operations Abandon ~ Repair Well Q, Plug Perforations ~ Stimulat ` TUBING PATCH , Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver h~f~re Extension ~ Change Approved Program ~ Operat. Shutdown ~ PerForate ~ Re-enter Suspended Well ~ 2. Operator BP E3cploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~elopment ~~ Exploratory ~ 2o~-os~o - 3. Address: P.O. Box 196612 St-'8t1g1"BphiC ~~ Service [~ 6. API Number: Anchorage, AK 99519-6612 50-029-20448-03-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 58.76 KB - PBU 02-16C - 8. Property Designation: 10. Field/Pooi(s): ADLO-028308 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13604 - feet Plugs (measured) None true vertical 8897.25 - feet Junk (measured) None Effective Depth measured 13169 - feet true vertical 8915.17 - feet Casing Length Size MD ND Burst Collapse Conductor 98 20" 94# H-40 SURFACE - 98 SURFACE - 98 1530 520 Surface 3029 13-3/8" 72# N-80 SURFACE - 3029 SURFACE - 2676 5380 2670 Production 9450 9-5/8" 47# L-80 SURFACE - 9450 SURFACE - 7447 6870 4760 Liner 2500 7-5/8"X7" 29.7/29# 8454 - 10954 6616 - 8792 6890/8160 4790/7020 Liner 517 3-1/2x3-3/16x2-7/81-8010790 - 11307 8671 - 8915 Liner 2501 2-3/8" 4.7# L-80 10843 - 13344 8714 - 8907 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 SURFACE - 29' 4-1/2" 12.6# L-80 29' - 10922' 3.7" OD BAKER SINGLE SET CHROME PATCF 7345' - 7365' Packers and SSSV (type and measured depth) 7" BAKER SABL-3 PKR 10766' BAKER 45 PKR 7345' BAKER 45 PKR 7365' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ . t~ ~~~ ~~,4k~ ~ Q ~~`~Q ` Treatment descriptions including volumes used and final pressure: 4 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 775 34244 22 1080 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ DeV~2lopment ~~ Se11ACe ~ Daily Report of Well Operations X 16. Well Status after proposed woric: Oil ~- Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~` 17. I hereby certify that the foregoing is true and coRect to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 1/8/2009 ~ 02-16C 207-087 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-16C 8/26/07 PER 11,192. 11,197. 8,891.7 8,893.28 02-16C 8/27/07 SQZ 11,192. 11,197. 8,891.7 8,893.28 02-16C 8/29/07 BPS 13,169. 13,604. 8,915.17 8,897.25 02-16C 8/29/07 PER 11,750. 11,950. 8,908.75 8,901.53 02-16C 8/29/07 PER 12,250. 12,730. 8,914.93 8,926.02 02-16C 8/29/07 PER 12,840. 13,120. 8,925.27 8,916.35 02-16C 12/9/08 BPS 10,741. 11,192. 8,627.98 8,891.7 02-16C 12/31/08 STO 7,345. 7,365. 5,753.06 5,768.27 02-16C 1/5/09 BPP 10,741. 11,192. 8,627.98 8,891.7 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n U ~ ~ • 02-16C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY `~~~~ACTIVITYD ~ ~ ~ ~ ~ ~ , ~ ~: ~,~~~ ~ . , ~ ~ . ~ ~. _ i 12/7/2008!""'` WELL S/I ON ARRIVAL *"" (pre patch) . ~ ~PULLED PRONG & 4 1/2" PX PLUG PLUG BODY FROM 10730' SLM ; DRIFT TBG W/ 20' x 3.70" DMY PATCH TO 7600' SLM, TBG IS CLEAR iTWO ATTEMPTS TO SET 4-1/2" NIPPLE REDUCER IN SWS NIP fa~ ! 10754' MD ~"''''JOB CONT ON 12/8/08'*" ~~.~~~~~~_~~~ 12/8/2008~ JOB CONT. FROM 12/7/08***.~~~~~~~ ~~~._~~~~~ ~SET 4 1/2" x 2 7/8" NIP REDUCER IN X NIP @ 10754' MD iATTEMPTED TO SET 2 7/8" XX PLUG IN NIP RED, LOST SPANG ~ACTION ~DROPPED CUTTER BAR AND RECOVERED @ 10724' SLM ~ ~ FISHED TOOLSTRING FROM 10726' SLM ~ """'JOB CONT ON 12/9/08""` ~ _..________.____ ~__~ t-~ _~ ~~ ______ ___ , 12/9/2008~*"*JOB CONT. FROM 12/08/08**'' (pre patch) ~~~~ ~ ~SET 2-7/8" XX PLUG IN NIPPLE REDUCER @ 10754' MD ~ ~**"WELL TURNED OVER TO DSO**" ~ ~ ~ ____..._ ___.--12/9/2008;T/I/0-1650/350/500 CMIT Tx ~ ~~~~ ~ ~~~ ~ - IA to 3000 psi INCOMPLETE. Pumped 49.7 ; ~bbls crude down IA to reach test pressure. First test 1st 15 min lost 0/450 re-~ ~pressured w/1.3 crude. Second test 1st 15 min lost 0/350 re-pressured ( ~ ~w/1.8 bbls crude. Third test 1st 15 min TBG gained 170 psi IA lost 370 psi. ~ ~Started to bleed well head pressure off. Bled back aprox.20 bbls till we got ~ gas. Bleed qas to neiqhborinq well until FS1 lost power and job was ?canceled. Will return at later time to finish job. Final VVHP's=1200/400/500. ~ DSO notified of valve positions upon departure swab shut wing shut ssv shut master open IA open OA open. ~ i ~ ~~_____.~_~_.~~.~~~~. ~ ~_..~,~ ~.~__,.~~.e.~em~ .._..... . ~v~a.~.~~a~ ~~a~n~~~___~ _~.~~~ 12/11/2008~T/I/0=1200/300/500 CMIT TxIA to 3500 psi (Patch TBG/Liner) MI, RU to ~ IA, Standby for transport. "''''Continued on 12-12-08 WSR**" __ _ _ . ~ ...m.a~.. _...__. ___ _~ W__ ~~ ~.________~_ ___ __ , 12/12/2008~'`*~'Continued from 12-11-08 WSR*** CMIT TxIA to 3000 psi *"'*PASSED ~ ~ ;Per WIC*""* (Patch TBG/Liner) Bled TBG from 1280 psi to 260 psi (Gas) to = ;production on well #28. Pumped 17.1 bbls crude down IA to pressure up to ~ ~2500 psi (TBG did not track) IA lost 140 psi in 15 min & 10 psi in 2nd 15 :min. Passed MIT on IA. Bleed IAP. Pumped 44 bbls crude down TBG to `bring TxIA to test preesure. On 3rd test, TxIA lost 20/0 psi in 1 st 15 min, ~ ~0/30 psi in 2nd 15 min & 20/10 psi in 3rd 15 min. Call PE. Inconclusive. 'Bleed TxIAP. Notify DSO of results. FWHP's=350/250/500 '"''*Tags ~ ~hung. SV, WV, SSV closed. MV open. IA & OA open to gauges""* , ~ ~ ~ ~ 12/19/2008~MACHINING COST FOR GETTING 02-16C 45 KB PATCH READY FOR E- i LINE JOB. 45 KB PATCH IS ASSEMBLED AND READY. ~ ~ ~_ --- - ' --~ ~_ ___ -- -- ~----- ~ ~ ~ 12/29/2008 ~ T/I/O = SSV/250/500. Temp = SI. OA FL (OA FL campaign). OA FL @ 105' (7 bbls). SV, WV & SSV=C. MV=O. IA & OA=OTG~NOVP.W ~ ~ 12/31/2008 """WELL SHUT-IN ON ARRIVAL*"* ' (E-LINE SET PATCH). INITIAL T/I/O = 750/200/500. RIH WITH BAKER 4- ~ ~ 1/2" TUBING PATCH WITH BAKER 45 "KB" STRADDLE PACKERS. ~ APPEARS BAKER 10 SETTING TOOL PARTIALLY STROKED. PATCH PARTIALLY SET. INTENTIONALLY BREAK WEAKPOINT IN ORDER TO POOH. OVERALL LENGTH OF PATCH IS 26.52'. ELINE TOOLS OVERALL LENGTH IS 8.4'. TOP ELEMENT SET AT 7345', BOTTOM ELEMENT AT 7365' (20'). WLEG LOCATED 6' BELOW BOTTOM ELEMENT, AT 7371'. MINIMUM ID THROUGH PATCH IS 2.45". RIG DOWN. WELL SI ON DEPARTURE. FINAL T/I/O = 500/250/500 PSI. ~ ***JOB NOT COMPLETE"'" ; 1/3/2009 ***WELL SHUT IN ON ARRIVAL""'" TRAVEL FROM L-116 TO DS2 START RIGGING UP ~ ~MECHANICAL ISSUES, TRAVEL TO SHOP ~ ~ START MAINT TICKET AT 0300 ~ ~ . ~ ~"""WELL TURNED OVER TO DSO*"" _.__ _ ~ _ 1/4/2009 """ WELL SHUT IN ON ARRIVAL "** RIH W/ 3.60" BELL GUIDE & 2" JDC ~ E """JOB CONT. ON 1/5/08*** , ~mm~~ 1/5/2009 **'`JOB CONT. FROM 1/4/09**" ~ ~ ~~ ~ FISHED E-LINE TOOLSTRING FROM 7324' SLM MIT-IA 3000# TO VERIFY PATCH IS HOLDING PASS j ; PULLED 2-7/8" XX PLUG FROM 10743' SLM ' ~ ""*WELL TURNED OVER TO DSO*** FLUIDS PUMPED BBLS 12 diesel 114 CRUDE 2 METH 128 Total OPERABLE: 02-16C (PTD #2070870} Passing MITIA post patch Page 1 of 2 . " • ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIltntegrityEngineer@BP.com] Sent: Tuesday, January 06, 2009 8:40 AM ' 1~~ `~ ~'7~~~~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Aspelund, Roger E Cc: Rico Hernandez, Claudia; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 02-16C (PTD #2070870) Passing MITIA post patch AI I, Well 02-16C (PTD #2070870) had a tubing patch placed in the welf on 12/31/08. Foflov~ring the patch placement, the wefl passed an MITIA ta 3000 psi on 01/05l09:-Tfie p~ing pressure test has restared 2 barriers #o the well and has been ree{ass~ ie-'fi" d as Operable. Operatians may bring the wefl online at their discretion. Please contact me with any questions or comments. Thank you, Taylor WelEman fil(ing in for Anna DubelAndrea Hughes OfFice: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Wel~ Integrity Engineer Sent: Thursday, November 13, 2008 7:12 AM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Rico Hernandez, Claudia; GPB, EOC Specialists; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Aspelund, Roger E Cc: Winslow, Jack L.; NSU, ADW WeII Integrity Engineer Subject: NOT OPERABLE: 02-16C (PTD #2070870) TxIA communication AI I, Well 02-16C {PTQ #207Q870) was secured with a dawnhole pl~g on 11/12108 as proven by a passing CMIT-Tx{A. The decision to secure the well was made after a leak detect log confirmed a tubing leak at 7350' M~ on 11/08If?8. The weEl has been reciassified as Not Operabie unti! the (eak has been repaired. Piease call with any questians or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /7/2009 OPERABLE: 02-16C (PTD #2070870) Passing MITIA post patch Page 2 of 2 i ~ey ~ ~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, October 26, 2008 8:05 PM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSi OTL; GPB, FSi DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Rico Hernandez, Claudia; GPB, EOC Specialists; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Aspelund, Roger E Cc: Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 02-16C (PTD #2070870) TxIA communication Hi ail, Well 02-16C (PTD 2070870) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2100/800 psi on 10/25/08. Due to the constraint of not being able to bleed pressure down to the production system due to the drillsite shut-down, the diagnostic work took more days to complete. A TIFL was conducted on 10/25/08 and initially passed. Overnight the wellhead pressure increased to SSV/2380/750 confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL - FAILED 2. Slickline: Dummy off gas lift valves 3. Fullbore: MITIA to 3000 psi A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna ~u6e, ~'.~. Well Integrity Coorclinator GPB Wells ~roup Phone; {907) 659-5102 Pager: (907} 659-510Q x9154 1 /7/2009 r ~- ~E~L ~~~ T/~,~~~lill/TT.4L ProActive Diagnostic Services, ]Cnc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection[Caliper/ M'R) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmitta) letter to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1] Leak Detection - WLD 0&Nov-08 02-16C 1 Color Log / EDE 50-029-20448-03 2] ~ ~~~~ ~ ' ~ ~ _. ~ Signed : Date : Print Name: 1~'~n~ ~~~-i uo _ Y Vlra~ ~~,,, _ PROACTIVE DIAGNOSTIC SERVICES, MC., 130 W. INTERNATIONAL AIRPORT RD SUffE C, ANCHORA~3E, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAI~ :~cisas~et~araqeCa~rvaemor4tlflq cff~s WEBSRE : W/W fit.~ei777a3YV4~t~.CS3¢73 C:~Doclunetns and Settings\Owner~Desktop\Trar~smit_Conoco.doc~c ~ NOT OPERABLE: 02-16C (PTD~ 70870) TxIA communication Page 1 of 2 ! i ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, November 13, 2008 7:12 AM ,\~~ ~~ ~~~'~'~ To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Weli Operations Supervisor; GPB, Wells Opt Eng; Rico Hernandez, Claudia; GPB, EOC Specialists; Regg, James B(DOA); Maunder, Thomas E(DOA); Aspelund, Roger E Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 02-16C (PTD #2070870) TxIA communication All, / Wefl OZ-16C {PTD #207Q870) was secured with a downhole lu on 11/12/08 as proven by a passing CMIT-TxIA. The decision to secure the well was made after a eaK detect log confirmed a tubin leak ak 7350' MD on~T~08. The weEl has been reclassified as Na# Operable until the feak has een repaired. Please call wrth any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, October 26, 2008 8:05 PM To: GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Rico Hernandez, Claudia; GPB, EOC Specialists; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Aspelund, Roger E Cc: Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 02-16C (PTD #2070870) TxIA communication Hi all, Well 02-16C (PTD 2070870) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2100/800 psi on 10/25/08. Due to t e constraint of not beinq able to bleed pressure down to ti~e production system due to the drillsite shut-down, the diagnostic work took more days to complete. A TIFL was conducted on 10/25/08 and initially passed. Overnight the wellhead pressure increased to SSV/2380/750 confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL - FAILED 2. Slickline: Dummy off gas lift valves 3. Fullbore: MITIA to 3000 psi A TIO plot and wellbore schematic have been included for reference. 11/28/2008 NOT OPERABLE: 02-16C (PTD~ 70870) TxIA communication Page 2 of 2 ~ Please call with any questions. Thank you, ,/~nna ~u6e, ~'. E. Wetl Integrity Coordinator GPB Wells Group Phone: (9p7} 659-5'i 02 Pager: (907) 659-5'f 4l0 x1154 11/28/2008 a,ooa ^^• I, . ~,aoo ; 2,aao 1,000 0 7rzsnaos ~o._Z6-2~c~~ ........................~~~ 8M 0~408 8~2~l2008 ~~~ ~z-~cP c p~ 2~~ - ~-7 ~ i~ -~ oa~ c~o~. 00~ 9M 0l2008 9~25~2048 10~10~2008 10~26~008 1111 Q~2008 -~- Tbg ! TREE = GRAY GEN 2 ` ~ s ~ aIC~~~~~C~4 29° (-~ 5-1t2" X 4-1/2" XO 5-1i2" TBG, 17#, ~-&Q, .0232 bpf, ID = 4.892" 2J' 13-3I8" CSG, 72#, N-$0, ID = 12.347" -( 3029' TOP OF 7-5(8" LNR-TIEBACK ~-~ 8454• 7-51$" LNR-T&K, 29.7#, NT-$Q, .Q459 bpf, ID = 6.$75" 9299' TOP OF 7" LNR 9299' TOP OF CEMENT 9306~ 9-5(8" CSG, 47#, L-$0, ID = 8.881" ~450~ Minimum 1~ =1.995" a~ 10,849' 2~3i$" LINER 3-1l2" LNf2, 8.81#. L-80, .0087 bpf, ID = 2.990" 'IQ$4Q' 4-1l2" TBL~, 12.6#; L-80, .0152 bp$, ED = 3.95$" 1 OQ~~' 1(I949' 2ND MECH WHIPSTOCK wlRA TAG M IliOUi W INOOW 90954' - 199G2' ~ ~ 2'I fl3' --~ 4-112" CAM TRDP-4A SSSV NIP, ID = 3.812" ~ GA5 LIFI" MANDF2ELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3597 3056 48 TGPD QMY RK 0 49/14(07 2 6941 5444 39 TGPD DMY RK 0 09114(07 3 9100 7148 33 TMPQX DMY BK 0 10/03/04 4 9205 7237 32 TMPdX Dfv1Y BK 0 1 d143/04 9270~ ~--{4-1/2" BAKER PP:R 10754° ~-14-1/2" PARKER SWS NIP, ID = 3.812" ~ 10766' 7" BAKER SABL-3 PKR 10790' 3-~r2° BKR DEPLOY SLV, ia = s.oo° ~ o7sa' EST TClP OF CE(viENT 10810~ 3-1/2" HES X NIP, ID = 2.&13" 10840' a-~~2° X 3-3/16° xo, ia = 2.~ss~~ 1(19(}9' 4-1;2" PARKER SWS NIP, 3D = 3.812" {BENIND 10922" 4-112" TBG TAIL WLEG (BENIND PtPE} ~~,.a ~f 9 La W...~~ Z§PIX~L.Xid~'W ...... ~ 8 w~LdA ° ~ {xJ~I.~~ ... . .. °~~~~~` ~i~~ ts` ~-~~r&" LFn~~3' '~Cl~~~" Ccs~ ~f <~ r~t°~ ......._._.._ ~z~oRaT~aN sun~~w~zY RFs LOG: SWS MCNUGR LOG OF 08(2$/07 ANGLEAT TOP PERF: 93 Deg ~ 11,750' Note: Refer ta Praduction DB for histarica! perf da#a SEZE SPF INTERVAL OpnlSqz DATE 9.58" 6 1 i 750 - 1195Q C3~r; G~3(~3C1t~J7 3.56" 8 12250 - 12734 (~~;a7i (~~f3t}i~17 1.~6" 6 12840 -'t 3120 C;~rj El3t;~J?€l7 ~.>s° s aE~s2-~~~sa ~=r~r±:l~~=>.~~ ~~~J:~~%er 2" 6 1119fl - 11210 ~?~~ ;iz~{ >€~r G~?2?ff~d 2" 6 1131 Q- 11350 3'~T;i .; ;>yz uz~f2 ~''+}7 PBTD 13593' 2-7l8" LNR, 6.16#, L-&0, .0058 bpf, ID = 2.441 ° 13628` TD 136$5` ~1~3~ -~ ~ 3~ 69" ~ ~"~3 °i ~~(~~` 9'~~~r' ~r~~Y~€~€~k~r'~,?~~a ~x~r~t~?~~ 11'733" ~-~f~s~ t~tt~, s.z~, L-at~, .oo'~s ~~t, ~D=2.~ 11733' s-~11 s~~ x L-7rs~~ XO JC3INT, €~ = z.aao" 11,770' WFD CIBF (06l15/06T DATE REV BY COMMENT5 DATE REV BY C(7MMENTS Q6/80 QRIGINAL COMPLETBQN 06115!06 SCS!PJC SET C[BP c~,i7 11770° 10/31t93 SIDET'RAGK{Q2-16A} 10,!03,!06 vJ81PAv PERF 14143/04 BN1cNilTLH CTD SDTRC9{ {02-168) Q5/Q9/47 RDWlPJC WAfVER SFTY NOTE QELET~ED ET 0$(30105 JRRiTLH 2Q" CSG ADDED 08f30(47 G. S. CT[3 HORIZONTAL SIDETRACK 09110f05 BiNc'WTLH FfNA~ DRLG CORRECTIONS O~Ji14JQ7 TAIPJC GLV C/O 01110106 EZLr'PJC WANERS~IY NOTE(12t05) PRUDHflE BAY UNIT WELL: 02-16C PERMIT No: ~2Q7C870 APt No: 50-Q29-20448-03 SEC 38, T11 N, R34E, 45&9.95 FEL & 1417.31' FNL BP Explaration {Alaska} 01 /18/08 ~ ~ ~?~i~~~~~~a~~pi~ NO. 4560 Alaska Data & Co~sulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 AIa5k8 Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Wgll Joh # 1_nn DPSrrinfinn nata RI C~,1.,. rtn L-219 11966240 MDT ~~-- (~, 12/22/07 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LOL (-( 12I31I07 1 V-211 12021135 MEM INJECTION PROFILE ~~( ~- (~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE V 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL 01/02/08 1 P2-16 11975750 INJECTION PROFILE 12/31/U7 1 F32 11970707 LDL ~} - 01/04(08 1 15-04B 12005202 MEM CEMENT BOND LOG 12/28/07 1 G-31A 11962778 SCMT j - C 01/07/08 1 S-26 11978425 USIT 12/29/07 1 02-16C 17628793 MCNL ~ '~- ~ 08/28/07 1 1 G-04B 11628765 MCNL - c 3~ 04/06/07 1 1 K-02D 11209613 MCNI ~ ~. 07/21/O6 1 1 17-07B 11649940 MCNL - ?~l / 02/17/07 1 1 L2-28 11975742 RST = '- 12~05107 1 1 Z-06 11968821 RST ~ - 12113/07 1 1 r~~-a,C q~,-~rvvvvLtUUt KtGtIY 1 tSY JIIiNINIa~ANU Kt I UKIVING VIVp I:UYY tAl:Fi IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~~~ ~, ~ ' ~^ t#~° ~ n ~~~~ ~"~~~,~ 900 E. Benson Bivd. ~ `` ~ ~ '~ ~ -. < ' ~~~~~"~ `' ~~ ~~ P. . Anchorage, Alaska 99508 Date DeVivered: ~;a`~~~'~ '~, ~" 1_~~~~~ ,~:xt {,s,.~~, _ a i ~ : ~ y , `.1; » t -. ~,. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: ~~ ~ ~ ~a ~~ Date 10-12-2007 Transmitta( Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Deliverv Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following welis: 02-12B ab~-r,.s~r4!t_!5"6!~_._.. 02-16C._~~=(~ ~ _~~ts.~ot.~_--- ._.__._ 02-16CPB1 aD ~-G$~__~.lSb!`} _ _ _. 02-18~1 IVn ~~3~ S 4' oZ.,g ~ ~.o `!SY -Q ~ y~.~ .,~.. , J_ _ .._ . _ _ -- - 04-01 A ~p~ 03.5_ ~`1S~~G-_.------- 15-16B ~7O(o - ~33--~_~6ai______. 15-16BP61 ~~-p~-3 ~~~__--___. 15-16BPB~ a~~~~ ts~a3 18-27D ~-~DS= ~3 r s~`i-----_____ 18-27DP61 _ ~0_~_13~._(_~~~_:___ _ ___----_ a-a2A___~-13~ __ iS~a_6 _ _ _.__ . _---- G-24A c?6G_.O~a--1-~-~~--___ G-24AP61 ~lo~--~~-_. is~`?~-~._..__~~.___ P2-11 A ~Q(,~ -vo~f~ _l.S.~.a_`-'l-.____.__.__._._.___ P2-11APB1 _2-CUca--oa_~__~1~6~.Q_ ,_.____~..~~. P2-36A ~~~_-~~2.a.._1ST3/.._ ..__.... P2-37A a05-0S~- _ .1~1_.~~Gr3.a P2-37AP61 _.,J:b,a -_Q~~..--~.~6~--r--.-.. -102 _ _ ---- .._....~~.~.. ~~ l~PZ'tt ~r~-~~`~-2335~-~~ -102PB ' Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Atm: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 t,~~ ~; ~"j _ ~~ y? - ~ ~ ~ ~ ~-: ~~ ~ ~"~a ~ ;~. ~ ,~~-, . u,, ti .~ ~~ ~ , , ~:~~_. Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. PO Box t96612 Anchorage, AK 995 1 9-66 1 2 STATE OF ALASKA /O%~'o~ ALAS~L AND GAS CONSERVATION COM~SION OCT 2 2 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LO~ :.,f~,~~ ~i! ~x Gas Cons. Gommissian Anrhnr9no 1 a. Well Status: ~ Oi{ ^ Gas ^ Plugged ^ Abandoned ^ Suspended sawc zs.,os Zonnc zs.~,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Weli Ciass: ~ Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab .• ,a~ 8/30/2007 12. Permit to Drill Number 207-087 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded / 8/15/2007 13. API Number 50-029-20448-03-00 ' 4a. Location of Well (Govemmental Section): Surface: 4 48' FSL 807' FWL 7. Date T.D. Reached 8/21/2007 14. Well Name and Number: PBU 02-16C ` , 9 , SEC. 36, T11N, R14E, UM Top of Productive Horizon: 3324' FSL, 4048' FEL, SEC. 26, T11 N, R14E, UM 8• KB (ft above MSL): 58.76'~ Ground (ft MSL): 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2968' FSL, 2325' FEL, SEC. 26, T11N, R14E, UM 9. Plug Back Depth (MD+ND) 13169 8915 PO°~ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687542 y- 5950868 Zone- ASP4 10. Total Depth (MD+T1/D) 13604 8897 16. Property Designation: ADL 028308 TPI: x- 682595 y- 5954403 Zone- ASP4 Total Depth: x- 684327 y- 5954089 Zone- ASP4 11. SSSV Depth (MD+1'~/D) None 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No bmi le roni nd rin ed inf rm i n er 2 AA 25. 5 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (App~ox.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AA 25.0711: MWD DIR / GR / RES, GR ! CCL / CNL l~%if/L~O/~/ C° //, ..~6 "~~ ~9/6 7'Yb 22• CASING, LINER AND CEMENTING RECORD ` ~ ~aSiNa " ~ ~ ~~. SFrrtr~ DE~rH aro ? SErru~c D Et~r~i z'+ro ''~ ` ~ Hot.~ ; < ~ ' ~~ ~ A-~cwri~': ~ ~ Wf'. PEf~ FT: ' GRADE TQP `Bd7TOM `~TOP ` BO'tTE)AA .. ., SIZE ' ' CEhAEMTING FZECdRD 'PULIEd' ; " rf , , " P 1-3/ " 7# N- rf c ' urf 67 ' 17-1/ " 00 x F nd 4 x PF' ' -5/ " 47# L-80 / S00-95 rfa 94 ' urfa 7447' -1/4" 1 6 sx CI s' x PF '' 7- /" x" # T- / 13 r 4' 1' 79 ' 9-5ie" = e-~~" s I s' a-irz° x 3-3/16° X z-~ia° 8.81# / 62# / 6.16# L- 0 107 0' ' 71' 8 1' a-vs~~ x s-~ra~~ 145 x CI '' 2- /" 4.7# L- 1 43' 1 ' 8714' 7' 5 x Cla s'' 23. Open to production or inject ion? ~ Yes ^ No ,:. - , t : 24. ` Tuei~ R~coR~ !f Yes, IISt @8CI1 IRt@iVBI Op@R (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10922' 10766' MD TVD MD ND 11750' - 11950' 8909' - 8902' 12250' - 12730' 8915' - 8926' ~~. ' : ~q~i p,: Fss~~~ Cc~~ac ~uEEZ~~"E'cC .. : `•. 'I ZH4O~ -'I $'I ZO' 8925' - 8916~ DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 13169' Set CIBP 11192' - 11197' 2-3/8" Cement Squeeze with 8 Bbls 'G' 2150' Freeze Protect with MeOH 26. PRODUCTION TEST Date First Production: September 30, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date of Test: 10/16/2007 Hours Tested: $ PROOUCrioN FoR TEST PERIOD Oll-BBL: 434 GAS-MCF: 8,369 WATER-BBL: -0- CHOKE SIZE: 44 GAS-OIL RATIO: 19,054 Flow Tubing Press. 958 Casing Press: 750 Cn~cuwreo 24-HOUR RATE• OtL-BBL: 1,302 GAS-MCf: 24,808 WATER-BBL: -0- OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No Sidewal l Core s Ac uired? 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 descriptians, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~M~~.~r~ar~ None ~ '~;;~ Form 10-407 Revised OZ/2007 CONTINUED ON REVERSE SIDE fi~` ~'~ ~~~ c~ ~~oo~ OR1GlNAL ~ ZS. GE(2LOGIC MARKERS ~LIST ALL FORMATIONS AND ERS ENCOUNTERED~: 29. FORMATION TESTS NAME ND Well Test D 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. Kicked off in Zone 1A 11182' 8888' None (From 02-166) Top TDF i Zone 1A (Inverted) 13367' 8906' Formation at Total Depth (Name): Zone 1 B 13367' 8906' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Si d , `~/~ /~ gne Title Drilling Technologist Date Terrie Hubble / PBU 02-16C 207-087 Prepared ey Name~lvumber. Teirie Hubble, 564-4628 Well Number P rmit No. / A rov I N. Drilling Engineer: Sean MCLaughlin, 564-4694 IN3TRUCTIONS GeNeRnt: This form is designed for submitting a complete and correct weil 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. ITeM 1a: Class~cation of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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. Iren~ 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 1reM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND 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. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing interoals 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). I~~ 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of interoals cored and the corresponding formations, and a brief description in this box. Submft detailed description and analytical laboratory information required by 20 AAC 25.071. Ir~e~ 28: Provide a listi~g of intervals tested and the corresponding Eosmation, and a brief summary in this box. Submit detaifed tes4 and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Onry ~ ~ BP: EXPLORATION Page 1 of 15 : t?perations Summary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hou~s ~ask Cc~de NPT Phase~ DescriptFan of C~p~rations . 8/12/2007 12:30 - 19:45 7.25 MOB P PRE ~ Park rig on G pad, clean up location. C/O breaker in SCR room. Work on rig pits with welder. 19:45 - 20:00 0.25 MOB P PRE PRE-RIG MOVE SAFETY MEETING. Review procedure, hazards and mitigation for rig move to DS 02-16C with Security, Nordic and SWS personnel. 20:00 - 00:~0 4.00 MOB P PRE ~ Move rig on West dock road to DS 02-16c. 8/13/2007 00:00 - 03:45 3J5 MOB P PRE ! Move rig to DS 02-16C. 03:45 - 04:00 0.25 MOB P PRE i SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 04:00 - 04:30 0.50 MOB P PRE Back rig over well and set down rig. Accept Rig 0430 8/13/07 04:30 - 07:00 2.50 RIGU P PRE i Rig up trailers and tanks. I BJSM. Pick up 2" E-Coil off of Veco trailer. i Prep E-coii reel to pull coil to injecter head. ' 07:00 - 09:30 2.50 BOPSU P PRE ~ N/U BOPE 09:30 - 17:00 7.50 BOPSU P . Pressure and function test BOPE. Test witness waived by PRE I ~ I i AOGCC inspecter, Jeff Jones. Greased tree vavles and rig valves to get good tests. ! Rig up Tiger tank, berm and hardiine. Press test hardline. 17:00 - 18:00 1.00 BOPSU P PRE i Grease CT injecter. 18:00 - 18:45 0.75 BOPSU P PRE ~ Wait on BPV crew. 18:45 - 19:00 0.25 BOPSU P PRE PJSM for pu lubricator. Testing lubricator. 19:00 - 20:30 1.50 BOPSU P PRE RU lubricator . Test 250 psi low 1000 psi hi. OK pull BPV. Well I on vac. RD Lubricator. 20:30 - 20:50 0.33 RIGU P PRE i PJSM for stabbing coil. 20:50 - 21:30 0.67 RIGU P PRE PU injector. RU to pull test grapple in e-coil. Pull test OK. Pull coil across 21:30 - 21:45 0.25 RIGU P PRE PJSM for slack management. 21:45 - 22:45 1.00 RIGU P PRE Stab onto weil. Circulate coil to fill with KCL 43 bbl to fill. Cut ~ 14' wire. Seal E line. 22:45 - 00:00 1.25 RIGU P PRE Reverse circulate to manage slack. 2.8 bpm @ 2424 psi. POP off well.Cut 40' coil. Install Kindal connector and pull test. OK. 8/14/2007 00:00 - 01:30 1.50 RIGU P PRE Head up E-coil. Tested at 52 ohms, PT to 4000 psi. 01:30 - 02:00 0.50 WHIP P WEXIT PU whipstock install pip tags, 02:00 - 02:30 0.50 WHIP P WEXIT Circulate across the top of well. 16 bbl to fill. 02:30 - 02:45 0.25 WHIP P WEXIT ~ PJSM with crew for PU of WS. 02:45 - 03:30 0.75 WH~P P WEXIT PU Whipstock. MU Baker eline tools. 03:30 - 06:30 3.00 WHIP P WEXIT RIH with WS. I Circ. out fluid in tubing to Tiger tank. 06:30 - 07:10 0.67 WHIP P WEXIT i Log GR tie-in to PDC log RA tag at 10,960', of 02-16B. -17' ~ I correction. ~ Tied-in depth is corrected to top of whipstock tray. 07:10 - 07:25 0.25 W HiP P W EXIT RIH to 11,306' top of whipstock. Orient TF to 90LOHS. Stop 1 ft high to allow for piston effect when setting whipstock with 3500 psi. 07:25 - 07:40 0.25 WHIP P WEXIT I Top of Whipstock at 11,307', Circ 20 bbl at 2 bpm. Close i EDC. Press up slow. Sheared at 3100 psi and set whipstock, Set down 3K on whipstock. OK. Clean pick up off whipstock at 29K, circ at 2 bpm, 2000 psi ~, . - . . w i e circ a pm, psi, gas in re urns, sen ~,~~ ~ returns to tiger tank. ~ Circ 100 bbis to tiger tank. Keep returns and circ at 1 bpm. Printed: 9/10/2007 2:51:45 PM ~ ~ BP EXPLORATION Page 2 af ~~ : ~peratic~ns Summary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 ' Date From - To Hours Task C~ide lVPT Phase Deseriptian of Operatians 8/14/2007 ~ 07:40 - 10:10 2.50 WHIP P WEXIT POH. Flow check at surface. 10:10 - 10:20 0.17 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA to window milling BHA. 10:20 - 10:45 0.42 STWHIP P W EXIT UO BTT whipstock running tools and BHI DGS. I M/U Window milling BHA #2 with, 2.74" NCC Diamond Window speed mill, and string mill, BTf extreme motor, BHI Coiltrak and CTC. OAL = 38.19'. 10:45 - 13:00 2.25 STWHIP P WEXIT RIH with window milling BHA #2, circ at 0.2 bpm, 100 psi, Keep 4500 psi on SSSV control line. Start on fluid swap to 2# Biozan while RIH. 13:00 - 22:30 ~ 9.50 STWHIP P WEXIT Tag top of whipstock at 1~,326'. Correct CTD to 11307'. -19' CTD. ~ Mill window to 11313' at ifph with 1.4 bpm, 2650 psi, 1.9K WOB, After 2# bio surface to surface. 29K up,1.5 bpm @ 2750 ~ psi FS, dril4ed 10' of new formation to 11323', back reamed and reamed through window and hole severaTtimes, with and I without pumps, OK ' 22:30 - 23:15 0.75 STWHIP P WEXIT Attempt to open EDC, failed, displacing CT to new Flo-Pro mud at 1.45 bpm, 2794psi 23:15 - 00:00 0.75 STWHIP P WEXIT POH, displacing weil to new Flo-Pro Mud, present depth 880~' 8/15/2007 00:00 - 01:45 1.75 STWHIP P WEXIT POH to Milling BHA #2 01:45 - 02:00 0.25 STWHIP P WEXIT PJSM on LD and handling BHA 02:00 - 02:45 I 0.75 STWHIP P WEXIT POH, LD Baker miliing BHA, 2.74 go, 2.73 nogo on both mills, ~ offload to ground, LD EDC and DPS subs 02:45 - 04:15 1.50 DRILL P PROD1 Baker replaced EDC and DPS subs, Test, MU Drlg BHA #3 with a 3" x 2.70" HCC BC bit, 2.6 deg X-treme Mtr, HOT, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LQC, UQC, SLB Dipple CTC, stab injector, Surface test tools 04:15 - 06:20 2.08 DRILL P PROD1 RIH with Drlg BHA #3 06:20 - 06:35 0.25 DRILL P PROD1 Log tie-in correction -3.5' MWD depth. 06:35 - 06:45 0.17 DRILL P PROD1 R~H tag at 11325'. 06:45 - 09:00 2.25 DRILL P PROD1 Drill buiid 1.56/1.56 bpm @ 3320 psi, 2840 psi FS, 2.1 K WOB, 56 ROP, Drill to 11450. 09:00 - 09:48 0.80 DRILL P PROD1 Wiper to window 09:48 - 10:25 0.62 DRILL P PROD1 Mad pass for 10,900' to 11,325' .@.3 bpm 700 fUhr. 10:25 - 17:45 7.33 DRILL P PROD1 Drill build 1.28/128 bpm @ 2750 psi. 2.9K WOB, 42 ROP, Drill at 1.59 / 1.59 bpm @ 3250 psi, 3190 psi FS, 4K WOB, 6.0 ROP.Brok out of shale at 11525. Drill 17:45 - 18:15 0.50 DRILL P PROD1 Wiper trip below window, no problems 18:15 - 19:50 1.58 DRILL P PROD1 Drill to 11695', TF 79L, 1.46l1.45 bprri @ 3375 psi. 1.2K WOB, 100 - 80fph ROP, PVT 325bb1s, IA 269psi, OA 265psi 19:50 - 22:45 2.92 DRILL P PROD1 POH to Drlg BHA #3, PJSM on handling and LD BHA #3, Brk out injector and UQC, std bk injector 22:45 - 23:00 0.25 DRILL P PROD1 POH, LD Drlg BHA #3 23:00 - 00:00 1.00 DRILL P PROD1 Back up software from last run, reconfigure Rib Steer BHA #4 and installed new software to support ribsteer run 8/16/2007 00:00 - 01:00 1.00 DRILL P PROD1 Continue install of new software to support ribsteer run. MU Drlg BHA #4 with 3" x 2.70" HCC BC bit, Rib Steer Mtr, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LQC, UQC, and SLB Dipple CTC. 01:00 - 01:20 0.33 DRILL P PROD1 RU BHA #4 and injector. 01:20 - 04:50 3.50 DRILL P PROD1 RIH with BHA #4 to btm, tie-in with +1.5 for CT correction, Printed: 9/10/2007 2:51:45 PM ~ ~ 8/16/2007 101:20 - 04:50 1 3.501 DRILL I P 04:50 - 05:15 I 0.421 DRILL I P 05:15 - 06:00 I OJ51 DRILL ~ N PROD1 PROD1 DFAL IPRODI 06:00 - 07:45 1.75 ~ DRILL I N DFAL PROD1 07:45 - 09:00 1.25' DRILL ', N DFAL PROD1 09:00 - 11:30 2.50 DRILL N DFAL PROD1 11:30 - 11:45 0.25 i DRILL N DFAL PROD1 11:45 - 12:00 0.25' DRILL i N DFAL PROD1 12:00 - 14:45 2.75 DRILL I N DFAL PROD1 14:45 - 16:00 1.25 DRILL N DFAL PROD1 16:00 - 16:45 0.75 DRILL N DFAL PROD1 16:45 - 19:30 2.75 DRILL N 19:30 - 21:25 1.92 DRILL P 21:25 - 22:00 0.58 DRILL P 22:00 - 23:30 I 1.501 DRILL I P 23:30 - 00:00 0.50 DRILL P 8/17/2007 00:00 - 00:20 0.33 DRILL P 00:20 - 02:45 2.42, DR{LL P 02:45 - 03:50 1.08I DRILL P 03:50 - 06:45 2.92I DRILL P 06:45 - 07:25 0.67 DRILL P 07:25 - 07:35 0.17 DRILL P 07:35 - 08:05 0.50 ~ DRILL P DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 slight bobble going through window, sat down at 11515', PU, shut down pumps, slide thru with no problems Drill to 11717' with TF at 146L, 1.49bpm, 3365psi, WOB 1k, ROP 93fph, FS at 2975psi, 1.45bpm, AP 4500psi, BP 5161 psi, PVT 318bb1s, IA 131 psi, OA 149psi, mtr stalled out, PU off btm, reduce pump rate to .62bpm at 3692psi, shut down pumps, backsurge pressure through choke attempting to remove obstruction, still pumping at .62bpm with 3650psi POH above window inside 4 1/2" production tbg to 10717' with .26bpm, 2715psi, tight spot at 11510' (40deg), shut down pumps, open EDC, circ at 1.90bpm, 3300psi, back surge pressure thru choke, and RIH aggressively to 10730', repeating process, closed EDC, still experiencing high pressure while pumping at low rate POH to troubleshooting ribsteer mtr and bit. Swap out motor. Rib steer motor locked up. Bit green. RIH w/ BHA #5 Log tie-in. No Correction BHI -16' SLB . Both counters zero at surface. RIH no problem thru window. and tag at 11716.4' Attempt to start driliing 3100 psi, FS+2900 psi. Pressuring up to 3600 psi.PU blead off thru Baker choke. Attempt to circulate .2 bpm Pressuring up. PU above window. Down hole pressure 600 psi out of balance . POH to 10500', Open EDC. POH Rib steer motor locked up. LD Rib steer motor and bit. Upload software, MU lateral Drig Assy #6 with rerun HCC BC bit, .5 deg mtr, HOT, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LQC, UQC, SLB Dipple CTC, Stab Injector RIH to btm, tie-in with corrections of -8' Baker and -23.5' SLB Drill to 11851' with TF at 77-120L, 1.54bpm, 3398psi, WOB 1.3k, ROP 59-100fph, FS at 3130psi, 1.48bpm, AP 4510psi, BP 5094psi, ECD 9.85ppg, PVT 326bb1s, tA 88psi, OA 109psi Wiper trip to below window, no hole problems, RBIH, Dn Wt 11.6k, set down once at 11549', Drill to 12000' with TF at 114 - 167L, 1.50bpm, 3242psi, WOB 1.2k, ROP 83-147fph, FS at 3130psi, 1.48bpm, AP 4552psi, BP 5201 psi, ECD 9.88ppg, PVT 316bb1s, IA 203psi, OA 190psi Wiper trip to below window Finish wiper trip, RBIH to btm Driil to 12082' with TF at 114L, 1.50bpm, 3387psi, WOB 1.4k, ROP 147 -40fph, FS at 3130psi, 1.48bpm, AP 4552psi, BP 5201 psi, ECD 9.88ppg, PVT 316bb1s, IA 203psi, OA 190psi, ROP and motor work dropped off in shale transition. W iper trip io window, RBIH, and set down at 12082 ft Drill to 12294' with TF at 90-67L, 1.50bpm, 3340psi, WOB 1.Ok, ROP 46-108fph, FS at 3130psi, 1.48bpm, AP 4593psi, BP 5123psi, ECD 9.88ppg, PVT 316bb1s, IA 353psi, OA 361 psi, Coil stacking out. Worked coil up and down, broke out of shale at 12086'. W iper to window Log tie -in No correction MWD and -.6' correction SLB. W iper to bottom. Printed: 9/10/2007 2:51:45 PM . ~ _ _ _ _ _ _ _ BP EXPLQRATION' Page 4 af 15' Operations Sumrnary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORD{C 1 Rig Number: N1 i i r ~ i ~ ~ uace r~uiu - iu nvurra ra~n ~,vuC ivr i 8/17/2007 08:05 - 11:20 3.25 DRILL ~ i P 1120 - 12:10 0.83 DRILL i P 12:10 - 14:20 2.17 DRILL P 14:20 - 15:30 1.17~ DRILL P 15:30 - 15:50 0.33 DRILL ~ P 15:50 - 17:50 i 2.00 ~ DRILL i P 17:50 - 18:00 0.17 DRILL P I 18:00 - 18:30 0.50 DRILL P 18:30 - 22:45 4.25 DRILL P 22:45 - 23:30 ~ 0.75 ~ DRILL I I P ' 23:30 - 00:00 0.50 DRILL P 8/18/2007 00:00 - 03:00 3.00 DRILL ~ P 03:00 - 05:40 2.67 DRILL P 05:40 - 07:00 1.33 DRILL P 07:00 - 09:45 2.75 DRILL P 09:45 - 10:35 0.83 DRILL P 10:35 - 10:45 0.17 DRILL P 10:45 - 11:30 0.75 DRILL P 11:30 - 13:00 1.50 DRILL P 13:15 - 15:40 2.42 DRILL P 15:40 - 17:30 1.83 DRILL C 17:30 - 21:00 3.50 DRILL C 21:00 - 21:10 0.17 DRILL C i 1"F!IdJC VC~iiII~.1ttUI~:1 lll V~ICIdIIVfI`5 PROD1 Directionally dril~ 1.47.1.47 bpm @ 3230 psi, 3130 psi FS, 2.5K WOB, ROP 73 , BP 5296 psi, 4590 psi annular pressure, ECD 10.0 ppg. Swap to new mud. Drill to 12330' PROD1 Wiper to window to allow Geo time to consult with Anch. Decide to change direction and drill up due to uncertainty of formation. Decided more motor bend would be beneficial in the search out the pay zone. PROD1 POH for more motor bend. PROD1 Change out motor PROD1 Conducted the McLaughlin Encoder Preformance Test. 100 reveloution of the wheel yielded the following: 100.01' SLB Encoder 99.86' BHI Encoder PROD1 RIH to 10980' PROD1 Tie - in fog. Correction =+2.5'. BHI correction. PROD1 RIH to Btm , no hole problems, Dn wt 11.1 k, Up wt 31.1 k PROD1 Drill to 12445' with TF at 12L-127R, 1.55/1.53bpm, 3153psi, WOB 2.3-1.7k, ROP 40-72fph, FS at 2875psi, 1.54bpm, AP 4375psi, BP 4997psi, ECD 9.51 ppg, PVT 328bb1s, IA 137psi, OA 142psi PROD1 W iper trip to window, Up wt 31 k, 10k over puil at 12100', 5-7k overpulls at 11490'-11480' PROD1 RBIH to Btm, Dn wt 10.8k at 11330', ratty hole at 11510' to 11520', set down at 12380', PU, worked past ratty hole to btm at 12445' PROD1 Drill to 12475' with TF at 49-139R, 1.55l1.53bpm, 3153psi, WOB 2k, ROP 60fph, FS at 3032psi, 1.54bpm, AP 4397psi, BP 5079psi, ECD 9.56ppg, PVT 315bb1s, IA 255psi, OA 245psi, Stacking weight and staAing frequently at 12454 ft. PROD1 Drill to 12548' with TF at 135L-100R, 1.53bpm, 2940psi, WOB 1.6k, ROP 11- 70fph, FS at 2800psi, 1.50bpm, AP 4423psi, BP 4910psi, ECD 9.63ppg, PVT 313bb1s, !A 291 psi, OA 280psi. At 12475 ft pumped 30 bbl pill of LoTorq (55 gal), when pill rounded bit ROP increased from 19 to 70fph PROD1 Wiper Trip to below window at 1 i330', Up wt off btm 30 - 34K, formation ratty to 12380', set down at 11525 PROD1 Drilling at 1.62/1.62 bpm @ 3450 psi 3000 psi = FS, W0B=2.8K, ROP 10-70, AP 4436psi, BP 5279 psi, ECD 9.7pP9, PROD1 W iper to above window to 10970'. PROD1 Tie-in {og correction zero correction BHI (-.6' SLB) PROD1 Wiper to TD. Set down 12485.Pu went right thru. Good trip. PROD1 Drilling at 1.58.1.58 bpm at 3414 psi, 3050 psi FS, Drill to 12808. Geo calling for open hole sidetrack. Have faulied up into zone 1 B. PROD1 POH to PU billet for OH sidetrack Q 12150'. PROD1 LD Bit grade 1,1. PU aluminum billet setting sleeve and Baker model 10 setting tool. PROD1 RIH to 12161', PU Wt 33.5k at 26fph, Dn Wt 13k at 21fph, tie-in pass at 10495', correction of +4' baker, -12' SLB, set down once at 11050', inside 3 3/16" PROD1 Orient TF to 145L, Pressure up to 2500psi, set anchor, continued pressuring up to 3300psi, sheared off AI billet, Printed: 9/10f2007 2~51:45 PM ~ ~ BP' EXPLORATIQN Page 5 of 15 Qperations Summary Repart Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8(31/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From°- Tc~ Hours Task Code NPT Phase ~~scriptior~ 4f Operatigns 8/18/2007 21:00 - 21:10 0.17 DRILL C PROD1 slacked off 3k down, PU to 33k free I ~ Top Of AL Billet at 12150' 21:10 - 23:30 2.33 DRILL C PROD1 23:30 - 00:00 0.50 DRILL X SFAL i PROD1 8/19/2007 00:00 - 00:30 0.50 DRILL X SFAL I PROD1 00:30 - 00:45 0.25 DRILL C PROD1 00:45 - 02:00 1.25 DRILL C PROD1 02:00 - 02:30 0.50 DRILL C PROD1 02:30 - 02:50 0.33 DRILL ~ C PROD1 02:50 - 04:30 1.67 DRILL C I PROD1 04:30 - 04:40 0.17 DRILL C ~ PROD1 04:40 - 05:15 0.58 DRILL C PROD1 05:15 - 07:15 2.00 DRILL C PROD1 07:15 - 16:30 9.25 DRILL C PROD1 16:30 - 1820 1.83' ~ DRILL C ~ PROD1 18:20 - 20:40 2.33 DRILL C PROD1 20:40 - 21:15 0.58 DRILL C PROD1 21:15 - 21:50 0.58 DRILL C PRODi 21:50 - 22:40 0.83 DRILL C PROD1 22:40 - 00:00 1.33 DRILL C PROD1 8/20/2007 00:00 - 00:30 0.50 DRILL C PROD1 00:30 - 00:45 025 DRILL C PROD1 00:45 - 01:00 0.25 DRILL C PROD1 01:00 - 01:20 0.33 DRILL C PROD1 01:20 - 03:15 1.92 DRILL C PROD1 ~ POH to Baker #10 J Hyd setting tool, std back injector while { holding PJSM for handling and LD BHA ~ Hydraulic hose on tugger failed, secured and clean up of fluid with absorbent, placed in oily waste bag for disposal, approximately one gal leaked on floor, reported leak to X5700. Hydraulic hose on tugger failed, secured and clean up of fluid, approximately one gal leaked on floor, Replaced new hydraulic hosefortugger POH, std back coiltrak tools, LD and offload Baker setting tool MU kick off BHA #9 with 1.7 deg mtr, HCC STR 324 PDC bit to ~ coilktrak BHA #9, PJSM on stabbing injector, PU, stabbed ~ injector ~ RIH with kick oft BHA #9 I Injector oring on Otis quick connect leaking. Reseated and lubricated oring after stopping RIH, bleeding off pressure, and opening 2 in. Injector MU and 2 in valve closed. Continue RIH with kick off BHA#9 Tie-in log correction zero correction BHI (+1 ft SLB) RIH to 12150' Develop 30' trough from t2115' to top of A1 Billet at 12150', TF at 148L, FS at 1.48bpm, 2933psi. Made three passes. Time drili off WS face 12,151.8' @ 6 min per .1ft.1.48/1.46 bpm Q 2860 psi. Time drill to 12153. Stacking Pump 10 bbl lub pill ~ no resuits. Drilling 1.5 / 1.5 bpm @ 3400 psi, FS= 3130 psi WOB 1.4K. Enhanced scale MWD shows a 30 fph stringer at 12150. Slow drilling 3-8 fUhr. Drill to 12170. Near bit inclination 1 degree less than previous hole. Back ream from 12160 to 12141with 210 Degree TF, with 165 degree TF, & with 255 degree TF. RIH dry tag 12167' POH to kickoff BHA #9, std back injector Blow down BHA, EDC left open, closed EDC, Blow down BHA, POH, LD kickoff BHA #9 Change out BHA components do to high hours while performing weekly function test of BOP's,adjust mtr to .80 bend, change out bit, service LQC PU lateral drlg BHA #10 with 3" x 2.70" HCC BC bit, .8 deg X-treme Mtr, HOT, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LQC, orient mwd, serviced UQC, MU UQC, SLB Dippie CTC, stab injector, Surface test toois RIH with lateral drlg BHA #10 RIH with lateral drlg BHA #10 Tie-in log correction; zero correction BHI, -1 ft SLB WHP increased from 10 to 140 psi. Stopped RIH, pumps shut off, and opened the choke. Back flushed the choke manifold and aluminum chunks came out on the shaker. WHP back to 10 psi. RIH to 12161 ft. Drili to 12350 ft with TF at 90L-90R, 1.52bpm, 3285psi, WOB 1.3k, ROP 66-132fph, FS at 2830psi, 1.50bpm, AP 4483psi, BP 5099psi, ECD 9.75ppg, PVT 293bb1s, IA 153psi, OA Printed: 9/10/2007 2:51:45 PM , ~ ~ ' BP' EXPL~RATION ` Pac~e 6 ot ~ 5' Opera~ians S~mmary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task C€~de NPT Phase Description vf.C3perations 8/20/2007 01:20 - 03:15 1.92 DRILL C PROD1 151 psi. 03:15 - 04:00 0.75 DRILL C PROD1 Wiper Trip to below window at 11330' 04:00 - 05:30 1.50 DRILL C PROD1 Drill to 12500' with TF at 90R-109L, 1.49bpm, 3376psi, WOB 0.90-2.Ok, ROP 126-132fph, FS at 2830psi, 1.48bpm, AP 4518psi, BP 5215psi, ECD 9.83 ppg, PVT 295 bbls, IA 236psi, I ; 05:30 - 06:30 1.00 DRILL C PROD1 OA 226psi. Wiper Trip to below window at 11330', UP wt off btm 31.1k ~ 06:30 - 08:00 1.50 DRILL C PROD1 ~ Directionally drill 1.4/1.4 bpm at 3350, FS 2950 psi, ROP 122, i WOB 1.2K, AP 4550 psi, BP 5207, ECD 9.9, Drill to 12650' 08:00 - 08:45 0.75 DRILL C PROD1 ~ W iper to window. 08:45 - 08:50 0.08 DRILL C PROD1 ~ Tie-in correction +6' 08:50 - 09:30 0.67 DRILL C PROD1 Wiper to borrom. Ciean trip. 09:30 - 12:50 3.33 DRILL C PROD1 Directionally drill 1.47/1.47 bpm at 3300, FS= 2950 psi, ROP 110, W OB 1 K, AP 4580 psi, BP 5207, ECD 9.96, Drill to 12798. Swap to new mud. 12:50 - 14:00 1.17 DRILL C PROD1 Wiper to window. Bauble at 11530 14:00 - 15:35 1.58 DRILL P PROD1 Directionally drill 1.51/1.51 bpm at 3300, FS= 2800 psi, ROP 15-70, WOB 2.6K, AP 4380 psi, BP 4870, ECD 9.5, Drill to 12849 15:35 - 15:40 0.08 DRILL P PROD1 Short wiper to 12,750'. 15:40 - 1725 1.75 DRILL P PROD1 Directionally drill 1.51/1.51 bpm at 3100, FS= 2800 psi, ROP I 60-90, WOB .7K, AP 4440 psi, BP 4920, ECD 9.63, Drili to i i 12950'. 17:25 - 19:00 1.58 DRILL P PROD1 W iper to window, hole clean, RBIH, Dn Wt at 11.1 k, slight bobble at 12530', ratty formatiom fl 11810 to 11840' 19:00 - 21:00 2.00 DRILL P PROD1 Drill to 13102', TF at 104R-90L, 1.51/1.51 bpm @ 3100, FS= 3000 psi, ROP 132, WOB 1.3K, AP 4443 psi, BP 5100psi, ECD 9.65, PVT 305bb1s, IA 320psi, OA 343psi, stacking wt at 13020' 21:00 - 22:35 1.58 DRILL P PROD1 Wiper to 10800', inside 4 1/2" tbg, Up wt off btm 32k, hole clean, tie-in correction for Baker +4', SLB +4.3' 22:35 - 23:30 0.92 DRILL P PROD1 RBIH, Dn wt at 12.6k, no hole problems 23:30 - 00:00 0.50 DRILL P PROD1 Drill to 13150', TF at 56-149L, 1.45/1.42 bpm at 3220psi, FS 2878 psi, ROP 110-51, WOB 1.1K, AP 4513 psi, BP 5161psi, ECD 9.82, PVT 296bb1s, IA 338psi, OA 367psi 8/21/2007 00:00 - 04:10 4.17 DR~LL P PROD1 Drill to 13245', TF at 15-128L, 1.45/1.44 bpm at 2882psi, FS ~ 2878 psi, ROP 110-51, WOB 1.1K, AP 4513 psi, BP 5161psi, ~ ECD 9.82, PVT 296bbis, IA 338psi, OA 367psi, stacking wt at i 12154' with -7.6k, pumped 15 bbl of 3 percent lo-torq pill, once pill rounded corner Dn wt at 2.2k, ROP increased from 11 - 80fph, drilled to 13164', started stacking wt once pill finished rounding corner with -8k, Pumped additional 30 bbl piil of 3 percent lo-torq pill, same results while pill lasted, driiled to i 13202', ROP 85-50fph, stacking wt to -6 to -8k 04:10 - 05:15 1.08 DRILL P PROD1 Wiper trip to window. 05:15 - 07:15 2.00 DRILL P PROD1 POH to RU agitator. 07:15 - 08:55 1.67 DRILL P PROD1 Tag at surface. Lay out BHA and PU agitator. 08:55 - 11:00 2.08 DRI~L P PROD1 RIH BHA #11 with agitator. to 10950'. 11:00 - 11:10 0.17 DRILL P PROD1 Tie - in log correction +12'. 11:10 - 12:10 1.00 DRILL P PROD1 RIH set down at 12770 nd 12806 multiply times ,12880. On bottom at 13239 ft. 12:10 - 12:20 0.17 DRILL P PROD1 Drill to 13250, TF 95-155L, 1.43/1.41 bpm at 3800 psi, FS 3500, ROP 93, WOB 2.11k, AP 4575 psi, BP 5763, ECD 9.94, Printed: 9/10/2007 2:51:45 PM . ~ ~ BP; EXPL~RAT40N Page 7 ofi 15 : Operatians Sumt~ary Report Legal Well Name: 02-16 Common Well Name: 02-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 7/7/1980 Start: 8/12/2007 End: 8/30/2007 Rig Release: 8/31/2007 Rig Number: N1 , 8l21/2007 12:10 - 12:20 0.17 DRILL P 12:20 - 12:35 0.25 DRILL P ,12:35 - 13:00 0.42 DRILL P i 3:00 - i 6:00 I 3.00' DRILL P 16:00 - 17:10 ' 1.17 DRILL P 17:10 - 18:05 0.92 DRILL P 18:05 - 19:15 I 1.171 DRILL I P 19:30 - 20:15 ! 0.751 DRILL I P 20:15 - 20:30 0.25 DRILL P 20:30 - 21:15 0.75 DRILL P 21:15 - 22:00 0.75 ~ DRILL P 22:00 - 23:45 1.75 DRILL P 23:45 - 00:00 0.25 DRILL P 8/22l2007 00:00 - 01:00 1.00 DR{LL P 01:00 - 01:15 0.25 DRILL P 01:15 - 04:00 2.75 DRILL P 04:00 - 05:00 1.00 DRILL P 05:00 - 06:30 1.50 CASE P 06:30 - 06:45 0.25 CASE P 06:45 - 07:15 0.50 CASE P 07:15 - 08:00 0.75 CASE P Q8:00 - ~8:15 0.25 CASE P 08:15 - 10:30 225 CASE P 10:30 - 13:15 2.75 CASE P 13:15 - 13:45 0.50 CASE P PROD1 PVT 289 bbf, IA 234 psi, OA 303 psi. PROD1 PU to 12580 ft, ratty formation thru shales from 11820' to 11775' PROD1 RIH to btm, Ream through shale sections from 11780' to 11840', PROD1 Drill to 13400', TF 92R, 1.43/1.41 bpm at 3800 psi, FS 3500, ROP 70- 112fph, WOB 2.38k, AP 4544 psi, BP 5789, ECD 9.88ppg, PVT 285 bbl, IA 298psi, OA 344psi, stacking wt from -4 to -8k, motor work with 2.86k WOB PROD1 Wiper trip to below window at 11330', ratty formation with 10k overpulls intermittently between 12840' to 11770' PROD1 RIH to Btm, set down at 11751', PU, shut down pumps, RIH to 12796', work thru ratty hole with pumps to 12900', continued to RIH thru ratty formation from 12980' to 13400', pumped 30 bbl, 3 percent lo-torq pili timed to reach bit at TD PROD1 Drill to 13486', TF 112L, 1.58bpm at 4450 psi, FS 3700 at 1.43bpm, ROP 162fph, WOB 2.19k, AP 4632 psi, BP 6181psi, ECD 10.10ppg, PVT 279bb1, IA 398psi, OA 454psi, stacking wt with -2k, motor work good. Diff sticking at 13486'. PROD1 Driil to 13540', TF 135R, 1.50/1.50 bpm at 4025 psi, ROP 150 fph, WOB 1.56k, AP 4612 psi, BP 5969 psi, ECD 10.05ppg, PVT 277 bbl, lA 441 psi, OA 474 psi PROD1 Stacking wt with -4k, motor work good. Short wiper to 13500', pumped 30 bbl 3 percent lo-torq pill timed to reach bit at TD. PROD1 Diff. stuck at 13540'. overpull 70k. Pumped Lo-Torq pill, worked pipe free. PROD1 Drill to TD at 13600', TF 105R, 1.50/1.47 bpm at 3980 psi, ROP 100 fph, WOB 1.69k, AP 4559 psi, BP 5766 psi, ECD 9.93ppg, PVT 272 bbl, IA 447psi, OA 487 psi, stacking wt with -8k. PROD1 Wiper trip from TD up to tubing tail at 10,800' at 1530'/hr. overpull 55k at 13380' PROD1 Log tie in pass, make +10' correction. PROD1 RIH to tag TD after tie in to GR depth control. Set down 4x at 12800'. PU and run through. Tag TD at 13604'. PROD1 Circulate 45 bbl liner pill w/ 4% Lo-Torq, 12 ppb Kla-Gard, 2 ppb aipine beads. PROD1 POOH while continuing to pump liner pill around. PJSM for lowering extra 2-3/8" BHI tools down beaver slide. PROD1 PJSM for L/D BHA. Lay out Drilling BHA. Bit graded at 1,1,1, pilot was rung-out. RUNPRD PJSM, Pickle reel, circ 10 bbl bleach, 40 bbl rig water, 15 bbl inhibitor and 6 bbl MEOH. RUNPRD PJSM on blow down procedure with N2 RUNPRD RU N2 unit, Test lines to 4000psi, blow down CT with N2, take returns to tiger tank RUNPRD RD N2 unit while N2 bled down RUNPRD PJSM on pul{ CT across pipeshed securing to reel RUNPRD Cut off CTC, head up internal CTC, pull test, pull across pipeshed, secure to reel, RD down hard line RUNPRD PJSM on reel swap, swap out 2" e-coii to 2" e-free coil, install internal grapple, pull test, pull across pipeshed, stab injector RUNPRD Cut off internal CTC, dress off CT, weld on CTC, Pull test Printed: 9/10/2007 2:51:45 PM • ~ BP. Operatior Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: ~ 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 i i _ i i 8/22/2007 13:45 - 14:00 0.25 CASE I' 14:00 - 16:00 2.00 CASE P l ~ ~ 16:00 - 23:00 7.00 i CASE II P I ~ '~ ~I I i 23:00 - 00:00 1.00 CASE I P 8/23/2007 00:00 - 05:00 5.00 CASE i P STUC I 12:45 - 13:00 0.25) CASE N STUC 05:00 - 08:45 3.75I CASE P I 08:45 - 10:20 1.58 CASE P i 10:20 - 12:45 2.42 ~ CASE N 13:00 - 14:00 14:00 - 14:15 14:15 - 16:45 16:45 - 20:30 1.00 CASE N STUC 0.25 CASE N STUC 2.50I CASE I N I STUC 3J5 i CEMT I P Pag Spud Date: 7/7/1980 Start: 8/12/2007 End: 8/30/2007 Rig Release: 8/31 /2007 Rig Number: N1 RUNPRD PJSM on RU handling tools and run 2 3/8" liner RUNPRD RU 2 3/8" handling tools, slips and elevators, switch around supply and return hydraulic lines which were installed backwards, PU Baker tools to rig floor, while RU hardline and filling CT with mud RUNPRD PJSM. PU shoe track and 1 joint of 2 3/8" liner with cementralizer foliowed by 77 jts of 2 3!8" 4.6#, L-80, STL with cementralizers, 3' 2-3/8" pup jt and 2.60" OD BOT deployment sleeve, OAL 2501.21', MU torque 800-1100ftibs. note tong dyes slipping, changed out tong dyes, no spare jaws. RUNPRD Fill coil with mud, pressure test C7C and inner reel valve, RU dart catcher, pump dart, dart landed at 42.0 bbls, calculated volume was 41.5 bbls, RD dart catcher, recovered dart, stand back injector RUNPRD Stab injector. RIH with 2 3/8" Liner Assy BHA #12 to 11000', up wt 35k, dn wt 15k, continue to RIH, set dn multiple times at 12830'. RIH fast to get past. Set down at 13040', 6x at 13170', 4x at 13350'. PU and work through. Tagging hard at 13380'. Hard to RIH when pumps are on. Have to shut down pumps to get to 13380'. Shut in backside and pressured up to 500 psi, no progress. Ordered 100 bbl Flo-Pro pill with 5% LoTorq. Circ at 13362', 0.73/0.69 bpm at 1800psi. RUNPRD Ordered 100 bbl Flo-Pro pill with 5percent LoTorq. Circ at 13362', 0.73/0.69 bpm at 1800psi. wait on pill. Pipe stuck at 13362' RUNPRD Pumped 50 bbls of 5 percent lo-torq Flo-Pro pill at .68/.68bpm, 1780psi, attempt to free liner as pill rounded corner, PVT 254bb1s, worked pipe free with 70k, UP wt 27 -29k, and Dn wt 12-10k differed from earlier Up and pn wts of 35k and 15k respectively RUNPRD POH to BHA #12, up wt at 11350', 28k at 100fph, Up wt at 11000', 25k at 100fph, Std bk injector RUNPRD POH LD, offload Baker running tool and liner wiper plug, running tool ripped out of GS profile on deployment sleeve, running tool dogs did not shear, left deployment sleeve and liner assy in hole at 13360', top of deployment sleeve at 10858' RUNPRD Sent in running tool to be inspeced and redressed at Baker RUNPRD PU redressed Baker running tool(LBRT) with iiner wiper plug BHA #13, ball seat was removed and dogs on running tool were in the released position RUNPRD RIH with LBRT BHA #13 to 10650' (inside 4 1/2" tbg), Up wt 29.8k, Dn wt 12.1 k at 25fph, 1.05 bpm, 1512 psi, continue RIH to 10825' (inside 3 3/16" liner), Up wt 30.1 k, Dn wt 13k at 25fph, 1.06bpm, 1490psi, RIH, stung in deployment sleeve at 10863' with pressure increasing to 2117psi, siack off with 10k down, PU to verify free movement of running tool, OK, slacked back off with 10k dn on deployment sleeve RUNPRD Displace well to 2 percent double slick KCL at 1.59/153bpm, 2600psi. Meanwhile R/U SLB cementers. Mix 30bbls of 2ppb biozan KCL fluid. Function test pump 1, 1.53 bpm, 1.38 bpm returns. 10% loss with KCL. Function test pump 2, 1.57 bpm, 1.43 bpm returns. Printed: 9/10/2007 2:51:45 PM ~ ~ ~ BP'~'I EXPLORATIaN Page 9 of ~ 5' Operations Summary Repart. Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 _ I _: f : I-` I- ~ = I I' 8/23/2007 20:30 - 20:45 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. 20:45 - 21:15 0.50 CEMT P RUNPRD Batch mix cement. Cement at wt at 2100 hrs. ~ i Press test cement line with 5000 psi. 21:15 - 23:30 2.25 CEMT P RUNPRD Stage 12 bbis, 15.8 PPG, G, Cement. 1.25 bpm, 3000 psi, ~ I 1.10 bpm returns. ~ stop pump, clean cement line. Insert dart. Zero in/out totalizers. Press up to 1000 psi. Launch dart. ~ Displace cement / Dart with 5 bbls 2# Biozan. Swap to KCI 10 bbl displ, 1.78 bpm, 3600 psi, 1.61 bpm returns 20 bbl displ, 1.65 bpm, 3625 psi, 1.55 bpm returns, pump 25 bbls 2# Biozan 30 bbi displ, 1.70 bpm, 3700 psi, 1.56 bpm returns 37 bbl disp, 1.46 bpm, 2600 psi, 1.19 bpm returns 39.1 bbl cement at shoe. Zero out totalizer. l Dart landed on LW P at 42.3 bbl. Sheared at 4000 psi. i~ i 44 bbl displ, 0.11 bpm, 4600 psi, 0.01 bpm returns I ( 45 bbl dispi, 0.3 bpm, 4800 psi, 0.01 bpm returns, pressure , getting too high I Swap to SLB cementers pumps, bypass rig micromotions, zero ~i cementer totalizers ', Coil burst pressure for 2" coil is 11800 psi ~. pressured up to 6300 psi, pressure dropped to 33~0 psi 48 bbls away, 0.5 bpm, 3600 psi 49.5 bbls displ, 0.75 bpm, 3800 psi 50.5 bbls displ, 0.8 bpm, 3800 psi 51.4 bbls displ, 0.8 bpm, 3800 psi 53.4 bbls displ, 0.8 bpm, 2200 psi pumped totai of 53.4 bbls, 2 bbls excess of calculated displ 5.8 bbl on return totalizer. Discuss with town. Pump 1 extra bbl, 0.3 bpm, 2000 psi total 54.4 bbl displ, plug never bumped, pumped 3 bbls excess of calculated dispi Seals in depioyment sleeve holding pressure 23:30 - 00:00 0.50 CEMT P RUNPRD Pull out of deployment sleeve at 27K up wt. Lay 1 bbls biozan at top of liner POH while replacing coil voidage. 0.7 bpm, 95 fpm. 8/24/2007 00:00 - 01:45 1.75 CEMT P RUNPRD Continue POOH after liner cmt job 01:45 - 02:00 025 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for Lay out BHA and RIH with cleanout BHA. 02:00 - 02:30 0.50 CEMT P RUNPRD UO LBRT BHA. recovered 100% 02:30 - 05:15 2.75 CEMT P RUNPRD M/U Liner Cleanout BHA #14, 1.875" Diamond Parbolic HCC mill, motor, cire sub, hyd disconnect and 86 jts of 1" CSH workstring. OAL of BHA = 2,636.66'. 05:15 - 07:00 i.75 CEMT P RUNPRD RIH with cleanout BHA #14 to 10863', Up wt 26k, Dn wt 12.6k, at 10765' 07:00 - 13:45 6.75 CEMT P i RUNPRD RIH, tagged at 11886', Up wt 28k, Dn wt 14.3k, wash down ( through 2 3/8" liner with 1.08bpm, 3065psi to 11927', sweep ~ hole with 10 bbl bio pill every 300' with a 200' wiper trip, continued RIH at 600fph to 12998', tagged up, wash Dn f/ 12998' - 13007', stalling out repeatedly- with 1.1 bpm, 2300psi, i RIH to 13290', motor work below, stalling out mtr, new PBTD at Printed: 9/10/2007 2:51:45 PM ` ~ ~ _ __ ' BP EXPLORATION Page f 0 ofi 15' C-pe~atiuns Summary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 ' Date Fr4m - Ta Hours Tas#c Code NPT Phase C}e~criptipn ~f C7perations 8/24/2007 07:00 - 13:45 6.75 CEMT P RUNPRD 13290, no cement in returns, treated total circ volume with .6 percent safe fube Top of deployment sleeve at -10863' 13:45 - 15:00 1.25 CEMT P RUNPRD Load and drop 1/2" steel ball, pumped 20bbls of Bio pill, ball did not land on seat 15:00 - 18:10 3.17 CEMT P RUNPRD POH to BHA #14, pumped 20 bbl biozan pill off btm, Up wt 31.5k, 1.2bpm, 2500psi, Continued POH, pumped second bio I pill of 30 bbis at 10900' while POH, recovered pilis, no cement in returns 18:10 - 19:30 1.33 CEMT P RUNPRD I P/U injector. Break connection to check for ball at surface. Ball did not appear to land on seat. Load second 1/2" steel ball and circ. Saw no indication that ball landed. 19:30 - 21:45 2.25 CEMT P RUNPRD ~ S/B injector. UO cleanout BHA #14. S/B 43 stnds 1" CSH. j Recovered both balls in cire sub. Cire sub was open. 21:45 - 22:30 0.75 CEMT P RUNPRD i Jet stack with swizzle stick. 22:30 - 22:45 0.25 EVAL P LOWERI I SAFETY MEETING. Review procedure, hazards and I mitigation for M/U and RIH with logging BHA. 22:45 - 00:00 125 EVAL P LOWERI ' M/U Logging BHA #15, bull nose, Memory SCMT/GR/CCL logging tools, ported sub, hyd disconnect, 86 jts of 1" CSH workstring, hyd disconnect. OAL of BHA = 2,655.88'. 8/25/2007 00:00 - 00:45 0.75 EVAL P LOW ER1 Continue M/U logging BHA #15. Stab injector. 00:45 - 02:00 1.25 EVAL N DPRB LOWERI RIH with logging BHA at 100 fUmin, 0.30/0.68 bpm, 242 psi. Tag GLM #2 at 6925' CTM. Increase pump rate. Unable to work past. 02:00 - 03:00 1.00 EVAL N DPRB LOW ER1 POOH with logging BHA to change BHA configuration. 03:00 - 03:15 0.25 EVAL N DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for UD logging BHA. 03:15 - 05:15 2.00 EVAL N DPRB LOW ER1 S/B CSH, VO logging BHA #15. 100% BHA recovered. Logging tools seams to be working fine. 05:15 - 06:30 1.25 EVAL N DPRB LOW ER1 SLB to dowload data and verify tool is working properly. 06:30 - 06:45 0.25 EVAL N DPRB LOW ER1 PJSM with crew on handling and running logging tools 06:45 - 09:00 2.25 EVAL N DPRB LOW ER1 MU Logging BHA #15 with SLB SCMT tools, 43 stds of 1" CSH, MHA, CTC, stab injector i 09:00 - 10:00 1.00 EVAL P LOW ER1 RIH with Iogging BHA #15 to 6925', Dn Wt 7k, no problems passing GLM at 6925' 10:00 - 11:30 1.50 EVAL P LOWERI RIH with logging BHA #15 to 13240', Top of Liner PU wt 31k, Dn Wt 12.1k at 10790', flag EOP at 10580.5' 11:30 - t3:05 1.58 EVAL P LOWERI Log up with GR-SCMT at 30fpm from 13240' to 10700' 13:05 - 13:45 0.67 EVAL P LOWERI RIH to logging depth at 13240' 13:45 - 15:15 1.50 EVAL P LOWERI Repeat Logging pass up with GR-SCMT at 30fpm from 13240' to 10700', started pumping perf pill 15:15 - 16:00 0.75 EVAL P LOWERI RIH to 13240' with Perf pill exiting nozzle 16:00 - 18:45 2.75 EVAL P LO~lVER1 POH to BHA #15, lay in perf pill across line 18:45 - 19:00 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for VD logging BHA. 19:00 - 21:00 2.00 EVAL P LOWERI S/B CSH, UO logging BHA #15. 21:00 - 22:30 1.50 EVAL P LOWERI SLB to dowload CBL data. PJSM, Test liner lap to 2000psi, IA at 55psi, OA at 48psi, pressure bled off 200psi in 2 minutes, liner lap failed 2 mins 1761 psi 5 mins 1516 psi Printed: 9/10/2007 2:51:45 PM ` ~ ~ ~P' EXPLORATIaN Page 11 of 15 Uperati.ons Summary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To Hours Task Code NPT Phase ' Description of C~pe~afians 8/25/2007 22:30 - 00:00 1.50 EVAL N WAIT LOWERI Send results to town and discuss. +21' correction on logs. 8/26/2007 00:00 - 01:00 1.00 EVAL N WAIT LOW ER1 Discuss CBL results w/ town. Decide to set 2-3/8" CIBP and ( perform cement top squeeze above liner top. 01:00 - 02:30 1.50 EVAL N WAIT LOW ER1 Wait for Baker to bring 2-3/8" CIBP and running tools. I 02:30 - 02:45 0.25 REMCM N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and ' ~ mitigation for M/U and RIH with 2-3/8" CIBP BHA 02:45 - 05:00 2.25 REMCM N DPRB RUNPRD M/U Bridge Plug BHA #17 w/ 42 stnds CSH, #5 J Setting Tool, ; 05 00 - 08 00 3 00 REMCM N DPRB RUNPRD 2-3/8" CIBP. Overall BHA length 2571.59' / CIBP BHA #17 t t th f 13261 2' RIH d d : : . o correc . w e ep o ~ 08:00 - 10:15 2.25 REMCM N DPRB RUNPRD Drop 1/2" AI ball, circ 20bb1 12.oppg NaBr pill followed by 8.5 ! KCL water at .7bpm, 2736psi, reduced rate after pumping 20 bbls to .21 bpm at 601 - 300psi, Ball landed after pumping ; 40.3bbls, sheared and set CIBP at 13261' with 1700psi, PU 50' I with Pu wt at 35k, RIH, tagged at 13261', slack off 2k, ok, PU, I flagged EOP at 10689' corrected j 10:15 - 11:05 0.83 REMCM N DPRB RUNPRD POH to 10500', inside 4 1/2" tbg tail, .32/.07bpm, 400psi, 65fpm, layed in 12 ppg Biozan NABr pill inside liner I 11:05 - 12:00 0.92 REMCM N DPRB RUNPRD RU test recorder, iine up choke manifold, tested CIBP, liner lap I I , to 2000psi, test twice with similiar results i 12:00 - 13:40 1.67 REMC i 13:40 - 13:50 0.17 REMC i 13:50 - 16:00 i 2.17 REMC ~ 16:00 - 16:30 0.50 REMC 16:30 - 17:30 1.00 REMC 17:30 - 18:15 0.75 REMC 18:15 - 18:30 0.25 REMC 18:30 - 23:00 4.50 REMC 23:00 - 23:30 0.50 REMC 23:30 - 23:45 0.25 REMC i I 23:45 - 00:00 0.25 REMC 8/27/2007 i 00:00 - 01:30 1.50 REMC ISIP 1963psi 5min 1700psi 10min 1500psi Repeat test ISIP 2000psi 5min 1700psi DPRB RUNPRD POH to BHA #17, brk out injector and CTC DPRB RUNPRD Bull plug CT, tested to 4000psi, ok DPRB RUNPRD POH with BHA #17, LD Baker MHA, std back 42 stds of f", LD Baker # 5 J setting tool DPRB RUNPRD PJSM on handling and running squeeze gun, PU squeeze gun, handling equipment to rig floor DPRB RUNPRD MU 1.56" squeeze gun BHA #18 with hyd disconnect, knuckle Jt swivel, x-o, 7 stds of 1" CSH, x-o, hyd disconnect, lockable swivel, check valve, 2.62" nogo x-o, CTC, all 1" CSH connections were checked, stabbed injector DPRB RUNPRD RIH with squeeze gun BHA #18. Up wt 32k, dn wt 14k. Tag no-go on deployment sleeve at 11311'. Correct to bottom shot at 11291.5'. -19.5' correction. DPRB RUNPRD PU 94.5', bottom shots positioned at 11197'. DPRB RUNPRD Drop 1/2" AL ball. Circ ball, 0.41/0.38 bpm at 286 psi. No indication that ball landed on seat after 60 bbls. Load and drop 2nd ball, 1/2" Steel. Ball landed on seat at 33.3 bbis DPRB RUNPRD Pressured up to 3400 psi. Good indication that shots fired. P/U above iiner top to 10800'. DPRB RUNPRD S/I backside. Perform injectivity test. 1/2 bpm, 1700 psi 3/4 bpm, 1846 psi 1 bpm, 1945psi, dropped to 1813psi DPRB RUNPRD POOH with BHA #18. DPRB RUNPRD POOH with tubing punch BHA #18. Printed: 9/10/2007 2:51:45 PM ~ ~ BP`: ~XPLQRATION'' Page ~2 of 15' Opera~tic~ns Sumrr~ary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 ilr.#...:. F C..'~....... T.: 1 Ll....~~.. 1 T..::~~..G 1/~....1.. 1 A11'fT 1 A4....~.. I~; ... [1...~.....:..~s:..~~~.~. ..l /1...~~~:....~.i:...,,~~... .. . 8/27/2007 01:30 - 01:45 0.25 ( REMCM N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for UD tubing punch BHA. 01:45 - 02:30 0.75 REMCM N DPRB RUNPRD Stand back 7 stnds CSH. UD tubing punch BHA #18. ASF 02:30 - 03:15 ; 0.75 REMCMT N DPRB RUNPRD PJSM. M/U cmt squeeze BHA #19. hyd disconnoct, 7 stnds i ~ i ~ CSH, 1.8" OD cmt nozzle. Overall BHA length = 431.27' ' ' 03:15 - 05:15 2.00 REMCM N DPRB RUNPRD RIH w/ cmt squeeze BHA #19 to 11279 , tag on no-go. -15 correction Up wt 11 k Ibs, dn wt 14k 05:15 - 06:00 0.75 REMCM N DPRB RUNPRD PUH to 10822', perform injectivity test 1 bpm, 1725 psi 06:00 - 06:30 0.50 REMCM N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping cmt sqeeze 06:30 - 07:30 1.00 REMCM N DPRB RUNPRD Primed up cmt pumps, Batch mix 8 bbls of 15.8ppg CL "G" w/ additives, POH to position cmt nozzle at 10321' 07:30 - 09:00 ; 1.50 REMCM ~ N DPRB RUNPRD Pump 2.5 bbls of water, test lines to 5000psi, pump 8 bbls of cmt slurry at 1.1 bpm, 1161 psi, 28bbls of Biozan at i 1.50/1.50bpm, 2058 - 2241 psi, shut in well after 25bbis pumped, reduce pump rate to 1 bpm, 1850 shut in psi, 5 bbls of KCL at 1.03bpm, 1846 shut in psi, cmt exiting nozzle with 3900 circ psi, 1780 shut in psi , 16.5 bbls of KCL pump, cmt out of i CT pressure fell from 4000psi to 3590 circ psi, 1740 shut in psi, left .50 bbls of cement inside 2 3/8" above top perforation at I 11192' - 11063' Pumped Shut in Pressure Pumping ISIP 51.1 bbis cmt at perfs 1827psi 55 bbls 2175psi 58 bbls 2443psi 2125psi waited 5 mins 2087psi 58.5 bbls 2334psi 2065psi CIP at 08:36 hrs on 8/27/07 09:00 - 11:00 2.00 REMCM N DPRB RUNPRD POH to cement squeeze BHA # 19 11:00 - 12:00 1.00 REMCM N DPRB RUNPRD POH with cement squeeze BHA # 19, STd bk injector, 7 stds of 1" CSH, LD cement nozzle and MHA 12:00 - 17:40 5.67 BOPSU N DPRB RUNPRD PJSM on RU, testing BOP's, RU, Test BOP's, all rams, surface valves and lines to 250 -3500 psi, annular to 250 - 2500 psi, choke manifold valves to 250 - 2500psi. 17:40 - 18:15 0.58 REMCM N DPRB RUNPRD PJSM, Test Squeeze Perfs/Liner Lap against CIBP at 13261' back to surface with 2000psi, first 15 min lost 162psi, last 15 min lost 18psi, totai lost 180psi ISIP 1990psi 5min 1864psi 10min 1853psi 15min 1838psi 20min 1831psi 25min 1824psi 30min 1820psi 18:15 - 19:00 0.75 REMCM N DPRB RUNPRD Break hardlines in reelhouse and check for cmt buildup. Lines j look okay. M/U and PT lines and inner reel valve to 500 and Printed: 9/10/2007 2:51:45 PM ~ ~ BP EXPLOR/~710N ` Page ~ 3 of 15' Opera#ions Sumrnary Rept~rt Legai Weli Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 ~ate ' From - To Hours Task Cade NPT Phase ' Description of Qperatians 8/27/2007 18:15 - 19:00 0.75 REMCM N DPRB RUNPRD 4000 psi. 19:00 - i9:15 0.25 REMCM N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and ~ I mitigation for M/U and RIH 1.69" cleanout BHA. 19:15 - 21:15 2.00 REMCM7 N ~ DPRB RUNPRD M/U cmt cieanout BHA #20, hyd dis, 86 jnts CSH, hyd dis, circ ~ sub, motor, 1.875" D331 Mill. Overall BHA length = 2636.66' 21:15 - 23:00 1.75 REMCMt N DPRB RUNPRD RIH w/ cmt cleanout BHA #20. Increase pump rate to 1.12/1.35 bpm at 3550 psi at 10000' 23:00 - 00:00 1.00 REMCM N DPRB RUNPRD Slow to 15 fUmin in liner. 1.19/1.19 bpm @ 3970psi. Cmt stringer at 11075', 11105'. Wash thru. dn wt 12k, up wt 30k. ' Cmt stringer @ 11142'. ', 8/28/2007 00:00 - 03:45 3.75 REMCM N j DPRB RUNPRD Hard cmt at 11158'. Pump 10 bbl 2# biozan sweep every I 20-30 bbls. mill at 1.12/1.12 bpm, 3980 psi, 20-50 ft/hr. i Multiple stalis. ROP increased to 75 fUhr at 11200'. Cleanout ; to 11240'. 03:45 - 05:45 2.00 REMCM N DPRB RUNPRD Circ bottoms up. Wash up to TOL and back to 11240' while pumping sweeps. 120/1.18 bpm, 3800 psi, 10 fUmirr. PU and wash through top of 2-3/8" Inr, slow to 5 fUmin, PU into 4-1/2" tbg and wash through top of 3-1l2" Inr. PU to 10675', returns i ~ cleaned up. ' 05:45 - 07:15 1.50 REMCMt N DPRB RUNPRD S/I backside. PT Liner Lap with 2000psi, first 15 min lost ', ~ 454psi, last 15 min lost 220psi, total lost 674psi ~!i 2nd test, line up to pump thru the kill line, Brk circ, PT Squeeze Perfs/Liner Lap to 1943psi, lost 337psi in 10 mins, Inspected all surface line for leaks, no leaks, pressire test surface lines to j 2000psi, ok ~ I 1 st Test 2nd Test ~ ISIP 2073 psi 1890 psi 5min 1886 psi 1633 psi 10min 1721 psi 1553 psi 15min 1619 psi 25min 1454 psi 30min 1399 psi 07:15 - 08:00 0.75 REMCM N DPRB RUNPRD RIH, tagged at 11241', mtr stalled, PU, waiting on orders 08:00 - 09:30 1.50 REMCM N WAIT RUNPRD Discuss plan forward with Anchorage office 09:30 - 13:30 4.00 REMCM N DPRB RUNPRD RIH, cleanout to 13146', drill cmt at 11241' - 11255', tag at 12143', twice, wash through. RIH to 13181'. Tagged hard (CIBP?). painted EOP flag at 10509', started pumping perf pill at 12600' 13:30 - 17:30 4.00 REMCM N DPRB RUNPRD POH to cleanout BHA #20, lay in perf pill across 2 3/8" liner._ 17:30 - 19:00 1.50 REMCM N DPRB RUNPRD Crew Change. S/B injector. Drop 1/2" steel ball. Cire sub sheared at 4000 psi. 19:00 - 19:15 0.25 REMCM N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for UD cmt cleanout BHA. 19:15 - 21:15 2.00 REMCM N DPRB RUNPRD S/B 43 stnds CSH. UD cmt cleanout BHA #20. 21:15 - 21:30 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for MU MCNL logging BHA. 21:30 - 23:15 1.75 EVAL P ~ LOWERI M/U iogging BHA #21, 84 jnts CSH, ported XO, MCNL/GR/CCL logging toois, SLB thru-tubing guide. Overall BHA length = 2627.26' 23:15 - 00:00 0.75 EVAL ! P LOW ER1 Stab injector. RIH w/ logging BHA #21. 8/29/2007 00:00 - 00:45 0.75 EVAL ~ P ~ LOWERI RIH w/ logging BHA #21 to 10700'. Printed: 9/10/2007 2:51:45 PM ~ ~ - _- _ _-- B'P EXPLORATION Page 14 of 15 Q~erations Summary Repc~r~ Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30l2007 Contractor Name: NORDIC CALISTA Rig Refease: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 ' Date From - Tr~ Hours Task Code NPT Phase ' Description af Qperations 8/29/2007 00:45 - 02:15 1.50 EVAL P LOW ER1 Log down at 30 fpm from 10700'. 1.19/1.28 bpm, 2760 psi. Tag 2x at 13183'. Dn wt 13.5k, Up wt 33k. 02:15 - 03:00 0.75 EVAL P LOW ER1 Log up at 60 fpm from 13183'. Lay in 10 bbl perf pill. Flag coil ~ at 11627'. EOP flag at 9000' uncorrected. Log up to 10700' 03:00 - 04:30 1.50 EVAL P i LOWERI ! POOH w/ logging BHA #21. 04:30 - 06:15 1.75 EVAL P ~ LOWERI PJSM. Standback 84 jnts 1" CSH and layout logging BHA #21. 06:15 - 07:45 1.50 EVAL P I LOWERI Jet stack with swizzle stick. ~ Fax'd MCNL/GR log to town. No change in perforating program. PBTD from log was 13,169'. 07:45 - 08:00 0.25 PERFO P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for running SWS perf guns and 1" CSH workstring. 08:00 - 10:30 2.50 PERFO P LOW ER1 Run SWS, 1.56" Power jet pert guns loaded with 6 SPF as per program. 65 guns total. 10:30 - 13:00 2.50 PERFO P LOWERI ' RIH with BTT Hyd disc, XO and 42 stds of 1" CSH. ~ M/U Hyd disc, swivel and check valves. BHA OAL = 3989.6'. 13:00 - 15:15 225 PERFO P ! LOWERI RIH with Perforating BHA #22 with SWS 1.56" Power Jet perf i guns. Circ. at min. rate while RIH. Full returns. Up wt above top of liner at 10,800' was 30K. RIH to Flag at 9000' EOP, 12,989.6' CTD, saw flag at 12,990.5'. very close to flag depth, which was uncorrected ', , depth from last trip. Fiag depth is secondary depth control. ', ~ PBTD is primary depth control. No correction. Up wt = 32.3K. ', ~ ~ RIH and tag PBTD at 13,188' Down depth. Pick up at 13,180' and correct depth to 13,169'. (-11'). , Tag bottom again at 13,175'. Pick up clean at 13,169'. Coil depth is on depth with corrected PBTD. 15:15 - 16:30 1.25 PERFO P LOWERI Pump 7 bbi new FloPro perf pill, insert 1/2" AL Ball, Zero in totalizer. Displace ball with 7 bbls FloPro and swap to KCL water. Position bottom perf shot at 13,123' and Pump 1.1 bpm at 3150 psi. I I Slow pump to 0.6 bpm, 1200 psi at 31 bbls. Ball on seat at I 43.5 bbls. Pull coil at 3 fpm. ' Fired guns on depth with bottom shot at 13,120' when firing head sheared at 3700 psi. Good shot detection with SWS. 16:30 - 18:45 2.25 PERFO P LOW ER1 POH to above 2-3/8" liner top. Flow Check, okay. POOH to surface 18:45 - 19:00 0.25 PERFO P LOWERI Pinholed coil 300' from surface. Flow Check, okay. 19:00 - 19:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and , mitigation for laying out 1" CSH workstring. 19:15 - 20:30 1.25 PERFO P i LOWERI Flush 1" CSH w/ fresh water. KICK WHILE TRIP DRILL, 19:30 20:30 - 00:00 3.50 PERFO P LOWERI UO 1" CSH in singles. Load CSH from pipeshed onto trailer. 8/30/2007 00:00 - 00:45 0.75 PERFO P LOW ER1 UO 1" CSH in singies. Load CSH from pipeshed onto trailer. 00:45 - 01:00 0.25 PERFO P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS perf guns. 01:00 - 04:30 3.50 PERFO P LOWERI Layout SWS, 1.56" Powerjet perf guns. 65 guns total. ASF. Load out of pipeshed. 04:30 - 06:00 1.50 PERFO N SFAL LOWERI PJSM. Cut coil for pinhole. Pinhole was -25' below a i ~ butt-weld. Cut a total of 375' of coil. Cut double mule shoe. Printed: 9/10/2007 2:51:45 PM ~ ! • 'LORATION Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+COMPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALiSTA Rig Release: 8/3i/2007 Rig Name: NORDIC 1 Rig Number: N1 i ` Date ~From - To Haurs Task Code NPT Phase Description c~# U{~erations 8/30/2007 I06:00 - 09:30 3.50 WHSUR P POST Stab injector. Could not get past swab valve with coil. M/U ' ~ CTC and nozzle. RIH to freeze protect with MeOH to 2150'. I POH. I09:30 - 09:45 025 WHSUR P POST SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV using a lubricator. ! 09:45 - 12:00 2.25 W HSUR P POST Press test lubricator. Set BPV. Well was dead prior to settting ~ ~ BPV. R/D lubricator. I~ 12:00 - 12:15 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and mitigation for Pickle procedure for coil. ' 12:15 - 13:00 0.75 W HSUR P POST Pump 15 bbi Bleach, 40 bbl fresh water, 15 bbl inhibitor and 5 bbl MEOH. ~ 13:00 - 13:15 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and mitigation for blowing coil down with N2. I 13:15 - 15:00 1 J5 WHSUR P POST Pump N2 at 1800 cfm for 10 min. Blowdown reel and take ~, returns to tiger tank thru choke. ', Change out pack off and brass for 2-3/8" CT CVean rig pits for rig move and rig pit inspection. ~i 15:00 - 15:15 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and i mitigation for pulling coil stub to reel. 15:15 - 16:45 1.50 WHSUR P POST Install internal grapple on coil. Puil test and pull coil stub to reel. Install crossbar on reel to secure coil. Secure with a chain to provide doubie energy isolation. , 16:45 - 19:00 2.25 WHSUR P POST Continue cleaning pits for rig move and rig pit inspection. Prep to C/O rams in BOP stack for 2-3/8" coil. ~ 19:00 - 19:15 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and I mitigation for lowering reel onto Veco trailer. 19:15 - 20:00 0.75 WHSUR P POST Open bombay door. Lower E-free reel onto trailer and 4 point ~; secure reel on trailer. 20:00 - 00:00 4.00 WHSUR P POST C/O rams in BOP stack for 2-3/8" coil. Finish cleaning rig pits for rig move and rig pit inspection. N(D BOPE. N/U tree cap and press test to 3500 psi. I RIG RELEASE AT 2400 HRS, 08/30/2007. ~ TOTAL OF 17 DAYS AND 19.5 HOURS FROM RIG ACCEPT ~ TO RELEASE. ALL FURTHER RIG INFORMATION WILL BE IN DIMS, WELL i G-09B Printed: 9/10/2007 2:51:45 PM ~ f, ~ ~ • ~ ~ F ~w BP Alaska Baker Hughes INTEQ Survey Report /"° BAKER Wu~sf~s ~.. ~...,L ___- ____..__-- ._.__.- _.__-__ -_.. FYeld: Prudhoe Bay ~ North Slope ~ UNITED STATES ; Map System:US State P1ane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level _ ____ _ _ - _-- - Site: PB DS 02 TR-11-14 UNITED STATES : North Slope Site Position: Northing: 5948800.37 fl From: Map Easting: 687638.44 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft _ - _- - _ - -- -- -- --_ _ -__ _-- , Well: 02-16 ~' 02-16 ~ Well Position: +N!-S 2069.25 ft Northing: 5950667.74 ft +E/-W ~4.63 ft Easring : 687542.26 ft i Position Uncertainty: 0.00 ft _- _._ __ _---- ------ --- ---_ _-- Wellpath: 02-16C Cnrrent Datum: 39 : 16 9/10/1993 00:00 Height 58.76 ft Magnetic Data: 8l20l2007 Field Streagth: 57662 nT Vertical Section: Depth From (TVD) +N/-S ft ft --- __ _ _ - - ._ . - -- 28.76 0.00 - - - -_ _ - -- -- Survey Program for DeSnitive Wellpath Date: 8~20/2007 Validated: No Actual From To Survey ft ft ~ 94.76 9394.76 1: Camera based gyro muttisho ~ 9394.76 10947.47 MWD (9394.7Cr11933.00) (1) I 10949.00 11274.31 MWD (10949.00-13685.00) (2) 11307.35 12124.61 MWD (11307.35-12808.00) (3) I12150.00 13604.00 MWD (12150.00-13604.00) 1--- -- _ -- --- _ -- AnnotaHoa 12124.61 8905.43 TIP 12150.00 8906.79 KOP 13604.00 8897.25 TD Survey: MWD Company: Baker Hughes INTEQ ~ TooL• MWD;MWD - Standard Map Zone: Coordinate 5ystem: Geomagnetic Model: Latitude: Longitude: 1 North Reference: Grid Convergence: Alaska, Zo~e 4 Well Centre bggm2007 70 15 53.847 N 48 28 58.060 W True 1.43 deg Slot Name: Latitude: 70 16 14.199 N Lon~tude: 148 28 59.359 W - _.. -- -- Drilled From: -- -_ _ ___ 02-16CP61 Tie-on Depth: 12124.61 ft Above System Datum: Mean Sea Level Declination: 23.73 deg Mag Dip Angle: 80.91 deg +E/-W Directioa ft ---- _--- deg - -.__ __ 0.00 316.47 Version: 1 Toolcode Tool Name CB-GYRO-MS Camera based gyro multishot MWD MWD - Standard MWD MWD - Standard MWD MWD - Standard MWD MWD - Standard Start Date: Engineer: Tied-to: - ___ __ 8/20/2007 From: Definitive Path a.U7- D~? . \ , • • BP Alaska s~~~~ Baker Hughes INTEQ Survey Report 1NTEQ s~~ey 12124.61 87.57 100.79 8905.43 8846.67 3220.78 ~588.OA 5953973.01 682875.67 5495.13 0.00 MWD 12150.00 86.27 99.08 8906.79 8848.03 3216.41 ~563.07 5953969.26 682900.74 5474.75 8.45 MWD 12181.10 84.69 96.98 8909.24 8850.48 3212.08 ~532.37 5953965.68 682931.53 5450.47 8.43 MWD 12215.70 84.46 93.33 8912.51 8853.75 3208.98 ~4498.07 5953963.45 682965.90 5424.60 10.52 MWD 12247.58 87.27 89.38 8914.81 8856.05 3208.23 -4466.29 5953963.50 682997.68 5402.17 15.18 MWD 12254.09 89.60 85.81 8915.81 8857.05 3209.76 ~429.84 5953965.94 683034.09 5378.17 11.67 MWD 12316.66 90.83 84.95 8915.69 8856.93 3212.39 ~397.37 5953969.37 683066.47 5357.71 4.61 MWD 12346.78 89.51 88.27 8915.60 8856.84 3214.17 ~367.31 5953971.90 683096.48 5338.30 11.86 MWD 12378.00 88.37 92.65 8916.18 8857.42 3213.92 ~336.11 5953972.42 683127.68 5316.62 14,49 MWD 12408.88 88.28 97.83 8917.08 8858.32 3211.10 -4305.38 5953970.37 683158.47 5293.41 16.77 MWD 12439.17 89.97 102.65 8917.54 8858.78 3205.72 ~275.59 5953965.73 683188.38 5268.99 16.86 MWD 12469.51 89.94 103.03 8917.57 8858.81 3198.97 ~246.00 5953959.73 683218.12 5243.73 1.26 MWD 12497.71 89.11 102.05 8917.80 8859.04 3192.85 -4218.48 5953954.30 683245.79 5220.33 4.55 MWD 12527.43 88.68 99.41 8918.37 8859.61 3187.32 ~189.29 5953949.50 883275.11 5196.21 9.00 MWD 12560.19 88.46 96.17 8919.19 8860.43 3182.88 ~156.84 5953945.87 683307.65 5170.65 9.91 MWD 12589.98 88.59 92.72 8919.96 8861.20 3180.57 -4127.16 5953944.30 683337.38 5148.53 11.59 MWD 12620.60 88.22 88.53 8920.81 8862.05 3180.24 ~096.56 5953944.73 683367.98 5127.21 13.73 MWD 12650.69 87.82 85.64 8921.85 8863.09 3181.77 ~066.53 5953947.00 683397.96 5107.63 9.69 MWD 12683.38 86.62 82.32 8923.44 8864.68 3185.19 -4034.06 595395124 683430.33 5087.75 10.79 MWD 12713.40 86.87 79.01 8925.14 8866.38 3190.05 -4004.49 5953956.83 683459.77 5070.91 11.04 MWD 12744.24 87.33 75.64 8926.70 8867.94 3196.81 -3974.45 5953964.34 683489.63 5055.11 11.01 MWD 12774.29 89.85 75.25 8927.44 8868.68 3204.36 -3945.37 5953972.61 683518.51 5040.56 8.49 MWD 12805.37 92.33 78.37 8926.85 8868.09 3211.45 -3915.12 5953980.45 683548.57 5024.87 12.82 MWD 12835.61 92.83 82.40 8925.49 8866.73 3216.49 -3885.34 5953986.23 683578.21 5008.01 13.42 MWD 12866.32 94.79 86.91 8923.45 8864.69 3219.35 -3854.84 5953989.85 653608.63 4989.07 15.98 MWD 12898.26 93.41 90.58 8921.16 8862.40 3220.05 -3823.00 5953991.34 683640.44 4967.65 12.25 MWD 12931.18 90.92 93.54 8919.92 8861.16 3218.86 -3790.13 5953990.97 683673.33 4944.15 11.74 MWD 12961.09 91.78 98.05 8919.21 886Q.45 3215.84 -3760.39 5953988.70 683703.13 4921.48 15.35 MWD 12991.81 92.18 102.82 8918.15 8859.39 3210.29 -3730.20 5953983.89 683733.45 4896.65 15.57 MWD 13020.77 91.60 100.78 891720 8858.44 3204.37 -3701.87 5953978.68 683761.92 4872.85 7.32 MWD 13053.47 90.77 98.23 8916.52 8857.76 3198.97 -3669.63 5953974.09 68379428 4846.73 8.20 MWD 13083.31 89.82 95.27 8916.37 8857.61 3195.46 -3640.00 5953971.32 683823.98 4823.78 10.42 MWD 13113.05 90.12 92.53 8916.38 8857.62 3193.44 -3610.34 5953970.04 683853.69 4801.88 927 MWD 13146.44 91.54 89.64 8915.90 8857.14 3192.81 -3576.96 5953970.24 683887.07 4778.43 9.64 MWD 13189.80 92.76 86.04 8914.27 8855.51 3194.44 -3533.67 5953972.95 683930.31 4749.80 8.76 MWD 13216.71 91.20 81.91 8913.36 8854.60 3197.20 -3507.53 5953976.36 683956.37 4733.79 16.77 MWD 13254.92 92.96 79.93 8911.95 8853.19 3203.32 -346923 5953983.43 683994.50 4711.85 6.82 MWD 13286.99 93.01 83.82 8910.28 8851.52 3207.84 -3437.53 5953988.74 684026.07 4693.30 12.17 MWD 13319.11 93.16 80.75 8908.55 8849.79 3212.15 -3405.75 5953993.84 684057.73 4674.53 9.56 MWD 13353.38 9323 75.86 8906.64 8847.88 3219.08 -3372.26 5954001.60 684091.04 4656.48 14.25 MWD 13387.61 93.84 71.33 8904.53 8845.77 3228.73 -3339.49 5954012.06 684123.56 4640.91 13.33 MWD 13420.77 93.01 65.39 8902.55 8843.79 3240.93 -3308.74 5954025.03 684153.99 4628.57 18.06 MWD 13461.11 92.43 66.52 8900.63 8841.87 3257.35 -3271.94 5954042.36 684190.37 4615.13 3.15 MWD 13494.96 91.63 69.50 8899.43 8840.67 3270.01 -3240.58 5954055.50 684221.41 4602.71 9.11 MWD 13525.84 91.07 74.83 8898.71 8839.95 3279.47 -3211.20 5954065.98 684250.54 4589.33 17.35 MWD 13604.00 91.07 74.83 8897.25 8838.49 3299.92 -3135.78 5954088.30 684325.42 4552.20 0.00 MWD ~ • CJ , BP Alaska Baker Hughes INTEQ 5urvey Report • ~~~~$ 1NTEQ Fietd: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarice 1866) Coord'watc System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 -- ----- __ _--- ---- Site: PB DS 02 - - - - - - TR-11-14 UNITED STATES : North Slope Site Position: Northing: 5948800.37 ft Latilude: 70 15 53.847 N From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Gronnd Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-16 -- Slot Name: - - -- _ _ 02-16 Well Position: +N/-S 2069.25 ft Northing: 5950867.74 ft Latitude: 70 16 14.199 N +E/-W ~4.63 ft Easting : 687542.26 ft Longitade: 148 28 59.359 W I Position Uncertainty: 0.00 ft --- -------- __ _ ; Wellpath: 02-16CP61 _ _ __. _ _ Drilled From: _ _ 02-16B ~ Tie-on Depth: 11274.31 fl ' Current Datum: 39 : 16 9/10/1993 00:00 Height 58.76 ft Above System Datum: Mean Sea Lev ' Magnetic Data: 6/13/2007 Declination: 23.84 C ~ Field Strength: 57658 nT Mag Dip Angle: 80.91 c ~ Vertical Section: Depth From (TVD) +N1-S +E/-W Direction ft ft ft deg -- _ _ _- - 28.76 - -- -- 0 00 -- - -- - 0 00 309.15 Survey Program for Definitive Wellpath Date: 8/20/2007 Validated: No Version: 3 Actual From To Survey Toolcode ft ft 94.76 9394.76 _- 1: Camera based gyro muttisho - -__ - ---- CB-GYRO-MS 9394.76 10947.47 MWD (9394.76-11933.00) (1) MWD 10949.00 11274.31 MWD (10949.00-13685.00) (2) MWD 11307.35 12808.00 MWD (11307.35-12808.00) MWD Annotation 17274.31 8911.33 TIP ~ 11307.35 8915.33 KOP 112808.00 8894.74 TD , _ _ . _ -- - - ---------- - _ _ _ _ _ i Survey: MWD Start Date: Company: Baker Hughes INTEQ Engineer: ~Tool: MWD;MWD - Standard Tied-to: Tool Name __ __ _-_ --- _ Camera based gyro multishot MWD - Standard MWD - Standard MWD - Standard _ _ __ _ 8/18/2007 From: Definitive Path ~~~- od'~ r ~ • • _ BP Alaska Baker Hughes INTEQ Survey Report BAKER 4WG~iEg ~.. _ ~,~ Survey 11274.31 81.76 255.11 8911.33 8852.57 3645.71 -4948.22 5954388.81 682505.04 6139.03 0.00 MWD 11307.35 84.34 248.11 8915.33 8856.57 3635.37 ~i979.31 5954377.69 682474.21 6156.62 22.43 MWD 11331.28 84.90 243.09 8917.58 8858.82 3625.53 -5001.00 5954367.32 682452.77 6167.22 21.02 MWD 11351.57 87.70 238.84 8918.89 8860.13 3615.70 -5018.70 5954357.05 682435.33 6174.74 25.05 MWD 11380.25 90.28 232.86 8919.39 8860.63 3599.62 -5042.42 5954340.38 682412.02 6182.97 22.70 MWD 11412.69 91.04 219.20 8919.02 886026 3577.15 -5065.71 5954317.34 682389.30 6186.85 42.17 MWD 11442.72 91.63 205.79 8918.31 8859.55 3551.88 -5081.80 5954291.69 682373.84 6183.38 44.69 MWD 11474.36 89.54 194.24 8917.99 8859.23 3522.21 -5092.61 5954261.75 682363.77 6173.02 37.09 MWD 11504.16 93.90 182.21 8917.09 8858.33 3492.79 -5096.87 5954232.24 68236025 6157.75 42.97 MWD 11536.01 91.01 169.86 8915.72 8856.96 3461.11 -5094.67 5954200.63 682363.24 6136.04 39.78 MWD 11566.45 90.80 158.27 8915.24 8856.48 3431.89 -5086.32 5954171.63 682372.31 6111.12 38.08 MWD 11596.43 92.95 148.59 8914.26 8855.50 3405.13 ~072.94 5954145.20 682386.35 6053.84 33.06 MWD 11626.11 92.40 137.01 8912.87 8854.11 3381.55 ~055.05 5954122.08 682404.83 6055.08 39.02 MWD 11653.03 90.83 126.26 8912.11 8853.35 3363.70 -5034.96 5954104.74 682425.35 6028.24 40.34 MWD 11690.34 9120 115.75 8911.44 8852.68 3344.51 -5003.03 5954086.35 682457.74 5991.36 28.18 MWD 11720.91 93.13 113.20 8910.29 8851.53 3331.86 ~t975.23 5954074.40 682485.85 5961.81 10.46 MWD 11750.79 92.92 111.51 8908.71 8849.95 3320.57 ~947.64 5954063.74 682513.72 5933.25 5.69 MWD 11781.77 91.07 110.07 8907.63 8848.87 3309.52 ~918.70 5954053.48 682542.92 5903.87 7.57 MWD 11814.60 91.90 108.59 8906.78 8848.02 3298.66 ~887.73 5954043.39 682574.15 5872.99 5.17 MWD 11844.74 92.52 106.99 8905.62 8846.86 3289.46 ~859.05 5954034.91 682603.05 5844.95 5.69 MWD 11875.42 92.49 106.21 8904.28 8845.52 3280.70 ~829.68 5954026.88 682632.63 5816.64 2.54 MWD 11904.98 92.33 105.53 8903.04 8844.28 3272.62 ~801.27 5954019.52 68266122 5789.51 2.36 MWD 11936.93 91,75 104.84 8901.90 8843.14 3264.26 ~770.46 5954011.93 68269224 5760.34 2.82 MWD 11966.59 91,14 104.60 8901.15 8842.39 3256.73 -4741.78 5954005.11 682721.09 5733.34 2.21 MWD 12001.24 89.82 104.16 8900.86 8842.10 3248.12 ~708.22 5953997.34 682754.85 5701.88 4.02 MWD 12032.32 88,59 103.70 8901.29 8842.53 3240.64 1t678.05 5953990.62 682785.19 5673.77 4.23 MWD 12065.15 87,33 103.36 8902.46 8843.70 3232.97 -4646.16 5953983.74 682817.27 5644.19 3.98 MWD 12094.55 86.83 101.62 8903.96 8845.20 3226.62 ~t617.49 5953978.11 682846.08 5617.95 6.15 MWD 12124.61 87.57 100.79 8905.43 8846.67 3220.78 -4588.04 5953973.01 682875.67 5591.43 3.70 MWD 12155.85 88.00 98.66 8906.63 8847.87 3215.51 ~557.27 5953968.50 682906.55 5564.24 6.95 MWD 12192.06 89.66 98.04 8907.37 8848.61 3210.25 ~521.46 5953964.14 682942.49 5533.15 4.89 MWD 12222.23 90.52 96.64 8907.33 8848.57 3206.40 ~491.53 5953961.03 682972.50 5507.51 5.45 MWD 12257.12 89.48 95.10 8907.33 8848.57 3202.83 ~456.83 5953958.33 68300728 5478.34 5.33 MWD 12285.82 89.45 93.08 8907.59 8848.83 3200.78 ~428.20 5953957.00 683035.94 5454.86 7.04 MWD 12315.82 88.62 91.26 8908.10 8849.34 3199.65 -4398.23 5953956.61 683065.93 5430.90 6.67 MWD 12363.33 89.42 89.85 8908.91 8850.15 3199.19 ~350.73 5953957.33 683113.43 5393.77 3.41 MWD 12393.03 93.75 92.15 8908.09 8849.33 3198.67 ~321.06 5953957.56 683143.10 5370.43 16.51 MWD 12423.25 94.89 96.03 8905.81 8847.05 3196.52 ~291.01 5953956.16 683173.20 5345.77 13.35 MWD 12453.91 92.33 100.42 8903.88 8845.12 3792.14 ~260.73 5953952.54 683203.57 5379.53 16.55 MWD 12484.86 92.21 104.45 8902.66 8843.90 3185.49 ~230.54 5953946.63 683233.92 5291.92 13.02 MWD 12517.70 92.86 103.70 8901.20 8842.44 3177.51 ~198.72 5953939.45 683265.93 5262.20 3.02 MWD 12545.58 91,47 101.83 8900.15 8841.39 3171.35 -4171.55 5953933.97 683293.24 5237.25 8.35 MWD 12573.54 93.01 99.55 8899.06 8840.30 3166.17 r{144.10 5953929.48 683320.81 5212.69 9.83 MWD 12603.34 93.66 95.10 8897.32 8838.56 3162.38 -4114.60 5953926.42 683350.39 5187.42 15.07 MWD 12632.78 92.42 91.26 8895.76 8837.00 3160.75 ~085.25 5953925.52 683379.77 5163.63 13.69 MWD 12663.57 92.15 87.76 8894.53 8835.77 3161.01 -d054.49 5953926.55 683410.51 5139.94 11.39 MWD 12693.79 91.69 84.18 8893.52 8834.76 3163.13 ~024.37 5953929.43 683440.57 5117.93 11.94 MWD 12723.45 9021 81.31 8893.03 883427 3166.88 -3994.95 5953933.90 683469.88 5097.48 10.89 MWD 12753.33 89.26 77.44 8893.17 8834.41 3172.39 -3965.59 5953940.14 683499.09 5078.19 13.34 MWD 12781.77 88.03 75.18 8893.84 8835.08 3179.11 -3937.97 5953947.55 683526.54 5061.02 9.05 MWD 12808.00 88.03 75.18 8894.74 8835.98 3185.82 -3912.63 5953954.89 683551.70 5045.60 0.00 MWD ~ ~ INTEQ To Whom It May Concern: ~~.. BAKER NUGI~IES 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 September 20, 2007 Please ~nd enclosed directional survey data for the following wells: E-11BL1PB1 E-19B E-11BL1PB2 E-11BL1 E-11BL1-01 G-25BPB 1 02-16CPB 1 G-25B 02-16C OS-28BPB 1 OS-28B Enclosed for each well is: 2ea copies of directional survey reports 1 ea 3. 5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. ~ ~ ri l ,~ ~ ; RECEIVED BY: ,~~~;-A4~~°~ _.'.; ' , State of Alaska AOGCC DATE: ~ ~ ~..,~~= ~.~~ °;`~ ;~ Cc: State of Alaska, AOGCC ~~? - ~ ~ ~ 09/10/07 ~~~I~~~~~~~s~ NO. 4406 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken A77N: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job # loa Descriotion Date BL Color CD 17-14 N/A JEWELRY/SBHP 08H7/07 MPC-10 11767137 MEM INJ PROFILE - ~ 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG Q8l15/07 1 P230 11686776 PRODUCTION PROFILE ~ 9 - ' 08/25/07 1 L131 71865639 LDL ' 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE ~ '~( - 08/17107 1 17-03A N/A JEWELRY/SBHP 08/77/07 1 C-26 11824342 LDL - L, " 08/22/07 1 15-07C 11594517 SBHP SURVEY -- ('~ 08/23/07 1 D-04B 11591451 SBHP SURVEY 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE j 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE 08/19/07 1 09-44 11855501 SBHP/JEWELRY -~ 08/16/07 1 09-23 11824337 SBHP/JEWELRY 08/16/07 1 2-521S-41 11846807 PRODUCTION PROFILE - 08/18/07 1 F-08A 11638646 USIT -~ 06/28/07 1 02-16C 11628790 SCMT 08I24/07 1 L2-32 11695060 RST 'a' ~ 05/23/07 1 1 L5-09 11492259 RST ~ ~ 11/11/06 1 1 02-12B 11767132 MCNL 06/21/07 1 1 18-096 11366500 MCNL ~ ~ 10/23/06 1 1 G-14A 11485777 MCNL t~ ~'j .- ~ L 17/27/06 1 1 05-20B 10942220 MCNL ~~ 06/26/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNINC~/~p ~ T~il~iQaONE COPY EACH TO: BP Exploration (Alaska) Inc. ~~ ~ ~ ~~ ~ ~~~ xL_,,, k_-~~~ Petrotechnical Data Center LR2-1 ~ ~^ ~ -° 900 E. Benson Bivd Anchorage, Alaska 99508 ~ ~ ~ ,~I._~ Date Delivered: '+ i 3 ~.~9`, t~Oi1~;. ~c~k r~~,~~.. ~~ ~ ~~{,~ ~ Alaska Data & Consulting Senrices 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth j Received by: ' i ~ ~ ~ ~ ~ ~ ~ ~ SARAH PALIN, GOVERNOR ~s$A Duj ~i`D ~s 333 W. 7thAVENUE, SUITE 100 C011TSERQATI011T COrII~'II5SIOIQ ANCHORAGE,ALASKA 99501•3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-16C BP Exploration (Alaska) Inc. Permit No: 207-087 Surface Location: 4948' NSL, 807' EWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 4967' NSL, 52' WEL, SEC. 27, T11N, R14E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) ~9-3607 (pager). rman DATED this ?D day of June, 2007 cc: Department of Fish 8b Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~,~1, ~ -2b -~7 ,~ ~r-o~ STATE OF ALASKA ~~ J~ T~ ALAS~IL AND GAS CONSERVATION COMMI~N ZOO~ PERMIT TO DRILL ~~ ~ ~gaxk~a ~~~ ~ ~ . jv~ ~S GOns. Commission 20 AAC 25.005 Anchnra~~ 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Expioratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ~ Development Oil ^ Singie Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single WeN Bond No. 6194193 11. Wel1 Name and Number: PBU 02-16C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13550 TVD 8851 ss 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4948' NSL 807' EWL SEC 36 T11 N R14E UM 7. Property Designation: ADL 028308 Pool , , . , , , Top of Productive Horizon: 3311' NSL, 3976' WEL, SEC. 26, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 10, 2007 Total Depth: 4967' NSL, 52' WEL, SEC. 27, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 32500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687542 y-5950868 Zone-ASP4 10. KB Elevation (Height above GL): 58.76' feet 15. Distance to Nearest Well Within Pool: 616' 16. Deviated Wells: Kickoff Depth: 11300 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3280 Surface: 2400 1. asi P ram: S' . catio ns To - Se in h- ttom anti of " ~ c:f. r sa , Hole Casin We+ ht Grade Cou lin Len th MD TVD MD ND includin sta e data 3" 2-3/8" 4.7# L-80 STL 2450' 11100' 8802' 13550' 8851' 48 sx Class 'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) ; Total Depth MD (ft): 13685 Total Depth ND (ft): 8864 Plugs (measured): 11770 Effective Depth MD (ft): 11770 Effective Depth TVD (ft): 8925 Junk (measured): None Casing Length ize Cement Vo{urne M D Conductor / Structural gg' 20" 431 sx Permafrost 98' 98' Surface 3029' 13-3/8" 2500 sx Fondu 400 sx PF 'C' 3029' 2676' Intermediate 9450' 9-5/8" 1965 sx Class'G' 300 sx Permafrost'C' 9450' 7447' Production Liner 1655' 7" 380 sx Class 'G' 9299' - 10954' 7316' - 8792' Liner Tieback 845' 7-5/8" Uncemented 8454' - 9299' 6616' - 7316' Liner 2g3g' 3-1/2" x 33/16° X z-~~s° 145 sx Clas 'G' 10790' - 13 28 8671' - 8872' Perforation Depth MD (ft): 11190' - 13300' Perforation Depth TVD (ft): 8891' - 8894' 20. Attachments ~ Filing Fee, $100 ~ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4694 Printed Name an McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature /~~ Phone 564-4694 Date ~ Sondra Stewman, 564-4750 Commission Use ~nl Permit To Drill Number~ O O~ a API Number: 50-029-20448-03-00 Permit Approv See cover letter for Date: • other re u+rements 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 ~No Mud Log Req'd: ~ Yes dNo HZS Measures: Q Yes ^ No Di ctional Survey Req'd: Yes ^ No Other: ~~~~i~ ~~ "~~ Date ~~~S~O~ APPROVED BY THE COMMISSION , COMMISSIONER Form 10-401 Revised 12l2005 ~~' ~~ `~~j,~~ Submit In Duplicate (1 R 1(; ~° ~ ~ bp To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin, CTD Engineer Date: June 18, 2007 Re: Prudhoe Bay 02-16C Permit to Drill Request u The sidetrack, 02-16C, is scheduled to be drilled by Nordic 1 around August l0th, 2007. The plan calls for a slimhole lateral with a solid liner and 1000 ft of perforations ln Zone lA. Pre-Rig Work: 1. O MIT-IA, and OA. (Done on 4/18/07) 2. S Run caliper log (Done on 4/15/07) 3. C Dummy W S(15' x 2.625") drift to 11,400' 4. O Set BPV ~~ ~~ , 5. O AC-LDS; AC-PPPOT-IC, T 6. O Test MV, SV, WV 7. O Bleed gas lift and production flowlines down to, zero and blind flange ~ 8. O Remove wellhouse, level pad The pre CTD work is slated to begin on July 15th, 2007. Rig Work: 1. MIlZU and test BOPE to 250 psi low and 3500 psi high, Pull BPV 2. Set 3-3/16"monobore packer whipstock @ 11,300. 3. Mi112.74" window at 11,300' and 10' of openhole. Swap the well to Flo-Pro. 4. Drill Build: 3" OH, 350' (40 deg/100 planned) 5. Drill Lateral: 3" OH, 1,900' horizontal (12 deg/100 planned) - include resistivity 6. Run 2 3/8" solid liner leaving TOL at 11,100. 7. Pump primary cement job to TOL, 10 bbl of 15.8 ppg cmt planned 8. Run CO assembly 9. Run MCNL/GR/CCL log 10. Test liner lap to 2000 psi. 11. Perforate, planned 1000ft. 12. If needed, set LTP at 10,740 13. Freeze protect well, Set BPV, RDMO Post-Rig Work 1. Pull BPV 2. Install well house. Hook up flow line. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" ~ ~ Casing Program: • 2 3/8", 4.7# , L-80, STL connection Solid liner -11,100' - 13550' MD • A minimum of 10 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 11,100 ft (TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 92 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 32,500' (North) • Distance to nearest well within pool - 616' ft to 02-30B Anticollision Summary • 02-30B - 616' ctr-ctr, Status: Well shut-in waiting on RWO • 07-33A - 661' ctr-ctr, Status: P&A'd • 07-33APB1 - 681' ctr-ctr, Status: P&A'd Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on DS 2 is 100 ppm on 02-29A • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3,280 psi at 8,800'ss (7.2 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2400 psi. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE _ ~ GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. E1EV = ~58.8' BF. ~EV = KOP = 10949 Max Angle = 102 @ 1361B Datum MD = 11093' 20" CONDUCTOR 9$' , Datum TV D= 8800' SS 5-1/2" TBG, 17#, ~-80, .0232 bpf, ID = 4.892" 29 13-318" CSG, 72#, N-80, ID = 12.347" 3029~ LTOP OF 7-5t8" LNR-TIEBACK ~~ 7-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, ID = 6.875" 9299~ TOPOF7"LNR 9299~ TOP OF CETAENT 9306~ 9-5/8" CSG, 47#, ~-80, ID = 8.681" 9450~ Minimum ID = 2.440" @ 11733' 3~3/16" X 2-7/8" SUB XO JOINT 3-1/2" LNR, 8.81#. L-80, .0087 bpf, ID = 2.990" 1084C 4-1i2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10922 10949~ H 2ND MECH WHIPSTOCK w(RA TAG 7" LNR, 29#, NT-80, ID = 6.184" ~--~ 11305~ PERFORAT~N SUMMA RY REF IOG: CNL LOG ON 10/02/04 ANGLEATTOPPERF:71 @ 11190' Note: Refer to Production DB for historical perf data SiZE SPF INTERVAL Opn/Sqz DATE 2" 6 11190 - 11210 O 10/03(06 2" 6 11310 - 11350 O 10/02/04 2" 6 11370 - 11535 O 10/02/04 2" 6 11920 - 12320 C 10/02/04 2" 6 12560 - 12735 C 10/02/04 2" 6 12950 - 13200 C 10/02/04 2" 6 13270 - 13300 C 10l02/04 ORIGiNAL WELBORE NOT O ~ -~ ~ ~ SHOWN. 2J' -15-1/2" X 4-1/2" XO ~ 2103~ 4-112" CAM TRDP-4A SSSV NIP, ID = 3.812" GAS LIFT MANDREIS ~ ST MD TVD DEV NPE VLV LATCH PORT DATE 1 3597 3056 48 TGPD DMY RK 0 08/12/05 2 6941 5444 39 TGPD DMY RK 0 08/12/05 3 9100 7148 33 TMPDX DMY BK 0 10/03/04 4 9205 7237 32 TMPDX DMY BK 0 10/03l04 9270~ I"I4-1/2" BAKER PBR ~ 0754~ -14-1/2" PARKER SWS NIP, ID = 3.812" 10766~ 7" BAKER SABL-3 PKR 10790~ 3-1/2" BKR DEPIOY SLV, ID = 3.00" 10790~ --~EST TOP OF CEM ~ 10810~ 3-1 /2" HES X NIP, ID = 2.813" 10840~ 3-112" X 3-3/16" XO, ID = 2.786" 10909~ 4-1/2" PARKER SWS NIP, ID = 3.812" (BEHIND PIP~ 10922~ 4-1/2" TBG TAIL WLEG (BEHIND PIPE~ MILLOUT WIiJDOW 10954' - 10962' 3-3/16" X 2-7l8" XO JOINT, ID = 2.440" 11770' ~ WFD CIBP (O6/15l06) ~ 3-3/16" LNR, 6.2#, L-80, 11733~ .0076 bpf, ID = 2.80" PBTD --C, 2-7l8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~ I~ 13685' DATE ftEV BY COMMENTS DATE REV BY COMMENTS 06/80 ORIGINAL COMPLETION 05/17/06 JDlPJC MIN ID CORRECTION 10/31/93 SIDETRACK (02-16A) 05130/06 DTM WEILHEAD CORRECTIONS 10/03l04 BMcM/TLH CTD SDTRCK (02-166) 06/15/O6 SCS/PJC SET CIBP @ 11770' O8/30/05 JRA/TLH 20" CSG ADDED 10/03/06 GJB/PAG PERF 09/10/05 BMcNVTLH FINAL DRLG CORRECTIONS 05/09/07 RDW/PJC WAIVER SFTY NOTE DELETED 01/10/06 EZL/PJC WANERSFTY NOTE(12/18/05) PRUDHOE BAY UNIT WEIL: 02-16B PERMff No: ~2041570 API No: 50-029-20448-02 SEC 36, T11 N, R14E, 4589.95' FE~ 8~ 1417.31' FNL BP F~cploration (Alaska) ~~= GRAY G~2 WEILHEAD= GRAY ACTUATOR = AXEISON KB. ElEV = 58.8' BF. ELEV = KOP = 10949 Max Angle = Datum MD = 102 (c~ 13618 11093' 20" CONDUCTOR Datum N D= 8800' SS 5-1l2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 13-3/8" CSG, 72#, 1~80, D= 12.347" TOP OF 7-5/8" LNR-TIEBACK ~~ 7-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, ID = 6.875" 9299~ TOP OF 7" LNR 9299~ TOP OF CEMENT 9306~ 9-5/8" CSG, 47#, L-80, ID = 8.681" 9450~ Minimum ID = 2.440" @ 11733' 3-3116" X 2-7/8" SUB XO JOINT ~3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" 11 10s~w 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10922' 10949~ 2ND Iv~CH WHIPSTOCK w/RA TAG MILIOUTWINpOW 1095{'-10863' 7" LNR, 29p. NT-80, ID = 6 184" PERFORATION SUWqNARY REF LOG: CNL LOG ON 10/02/04 ANGLE AT TOP PERF: 71 @ 11190' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 11190 - 11210 s~~iated proposed 2" 6 11310-11350 sr%!ated proposed 2" 6 11370 - 11535 ~solated proposed 2" 6 11920 - 12320 isolated proposed 2" 6 12560 - 12735 isolated proposed 2" 6 12950 - 13200 isolated proposed 2" 6 13270 - 13300 isolated p Lr°iv 6.16#, L-80, .0058 bpf, ID = 2.441" ST MD TV D DEV TY PE V LV LATCH PORT DATE 1 3597 3056 48 TGPO DMY RK 0 08/12/05 2 6941 5444 39 TGPD DMY RK 0 08/12/05 3 9100 7148 33 TMPDX DMY BK 0 10/03/04 4 9205 7237 32 TMPDX DMY BK 0 10/03l04 1/2" 10740' 1Liner Top Packer 10754~ ~~4-1/2" PARKER SWS N~, ~= 3.812„ 10766' ~-~7" BAKER SABL-3 PKR 10790~ ~~3-1/2" BKR DEPLOY SLV, ID= 3.00" 10790' ~ EST TOP OF CEMENT ~ 10810~ 3-1/2" HES X NIP, ID = 2.813" 10840' 3-1 /2" X 3-3/16" XO, ID = 2.786" 10909~ ~-~4-1/2" PARKER SWS NIP, D= 3.812" 10922' 1~4-1/2" TBG TAIL WLEG (BEFIIND PIPI 11100' 2-318" ~_Inei 21100' ~ ~ement - and perfed I 13550' I 1 1300' ~vlech Pa _ : ;s 11733~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 1~2.8" 11733' 3-3/16" x 2-~i8" XO JONT, ID = 2.440" 11770' WFD CIBP (O6/15/O6) DATE REV BY COMMENTS DATE REV BY COMMENTS 06180 ORIGINAL COMPLETION 05/17/O6 JD/PJC MIN ~ CORRECTION 10131/93 SIDETRACK (02-16A) 05l30l06 DTM WELLHEAD CORRECTIONS 10103/04 BMcMITLH CTD SDTRCK (02-16B) 06/15/06 SCS/PJC SET CIBP @ 11770' 08/30/05 JR,4/TLH 20" CSG ADDED 10/03/O6 GJB/PAG PERF 09/10/05 BMcMITLH FINAL DRLG CORRECTIONS 05/09/07 RDW/PJC WANER SFTY NOTE DEIETED 01/10/06 QL/PJC WANER SFIY NOTE (12/18/05) PRUDHOE BAY UNff WELL: 02-16B PERMff No: `2041570 API No: 50-029-20448-02 SEC 36, T1 t N, R14E, 4589.95' FE18 1417.31' FNL BP Exploration (Alaska) 0~~~ ~~ SHOWN. Proposed CTD Sidetrack ORIGINAL W ELBORE NOT 29' ~~5-1/2" X 4-t/2" XO -1/2" CAMTROP-4A S GAS LIFf MANDRELS • ~ ~ bp BP Alaska s~~ Baker Hughes INTEQ Plannmg Report 1NTEQ fiompeey; BP Amoco Date: 6/14/2007 Tiroe: 09:55:54 Page: . 1 Field: Prudhoe Bay Ca-ordi~te(PiE) Refeeencs: WeB: 02=16, True-Notth Site: PB DS b2 Vertic9l(TVD) Retereece: 39 : 16 9110f1993` 00:00 58.8 WeU: 02-16 Sectioa (VS) Reference: WeN (O.OON,0.08E,110.OOAzij Welipat6: Plan 3, 02 16C SarveyCalcalatios MeWod: ' Minimum Curvature Db: Ocade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datnm: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Modei: bggm2006 Site: PB DS 02 TR-11-14 UNITED STATES : North Slope Site Position: Nort6ing: 5948800 .37 ft I.etitude: 70 15 53.847 N From: Map Eastieg: 687638 .44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft NoN6 Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-16 Slot Name: 02-16 Well Position: +N/-S 2069.25 ft Northing: 5950867 .74 ft Latitude: 70 16 14.199 N +FJ-W -44.63 ft Easting : 687542 .26 ft Longitude: 148 28 59.359 W Position tincertainty: 0.00 ft Wellpath: Plan 3, 02-16C Drilled From: 02-16B Tic-on Depth: 11 274.31 ft Current Datum: 39 : 16 9/10/1993 00 :00 Height 58.76 ft Above System Datum: Mean Sea Level Magnetic Data: 6/13/2007 Declinatioo: 24.00 deg Field Strength: 57669 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.76 0.00 0.00 110.00 Plan: Plan #3 Date Composed: 6l13/2007 Copy Lamars Plan 3 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map c._ Latitnde ---> ~-- Loogitude --> Name Description T'VD +NJ-S +E/-W Northing Easting Deg Min Sec De~ Mio Sec Dip. Dir. ft ft ft R ft 02-16C Polygon 58.76 3725.50 -5091.32 5954465.00 682360.00 70 16 50.822 N 148 31 27.648 W -Polygon 1 55.76 3725.50 -5091.32 5954465.00 682360.Q0 70 16 50.822 N 148 31 27.648 W -Polygon 2 58.76 3587.01 -5354.87 5954320.00 682100.00 70 16 49.458 N 148 31 35.321 W -Polygon 3 58.76 3374.82 -5270.13 5954110.00 682190.00 70 16 47.372 N 148 31 32.848 W -Polygon 4 58.76 3007.00 -4158.88 5953770.00 683310.00 70 16 43.761 N 148 31 0.478 W -Polygon 5 58.76 3078.05 -3196.75 5953865.00 684270.00 70 16 44.464 N 148 30 32.459 W -Palygon 6 58.76 3346.64 -2734.89 5954145.00 684725.00 70 16 47.108 N 148 30 19.011 W -Polygon 7 58.76 3383.57 -3614.29 5954160.00 683845.00 70 16 47.467 N 148 30 44.623 W -Polygon 8 58.76 3246.69 -4142.90 5954010.00 683320.00 70 16 46.118 N 148 31 0.017 W 02-16C Fauk 1 58.76 3347.55 -5580.92 5954074.99 681880.00 70 16 47.101 N 148 31 41.900 W -Polygon 1 58.76 3347.55 -5580.92 5954074.99 681880.00 70 16 47.101 N 148 31 41.900 W -Polygon 2 58.76 3008.21 -4609.02 5953759.99 682860.00 70 16 43.770 N 148 31 13.587 W 02-16C Fauk 3 58.76 3397.80 -3784.00 5954170.00 683675.00 70 16 47.606 N 148 30 49.566 W -Polygon 1 58.76 3397.80 -3784.00 5954170.00 683675.00 70 16 47.606 N 148 30 49.566 W -Polygon 2 58.76 3160.24 -3684.88 5953935.00 683780.00 70 16 45.271 N 148 30 46.676 W -Polygon 3 58.76 2876.82 -3551.90 5953655.00 683920.00 70 16 42.484 N 148 30 42.799 W -Polygon 4 58.76 3160.24 -3684.88 5953935.00 683780.00 70 16 45.271 N 148 30 46.676 W 02-16C Fault 4 58.76 336728 -4164.90 5954130.00 683295.00 70 16 47.304 N 148 31 0.659 W -Polygon 1 58.76 3367.28 -4164.90 5954130.00 683295.00 70 16 47.304 N 148 31 0.659 W -Polygon 2 58.76 3887.71 -3371.64 5954670.00 684075.00 70 16 52.427 N 148 30 37.563 W 02-16C Fauft 2 58.76 4004.76 -5659.57 5954729.89 681785.00 70 16 53.564 N 148 31 44.205 W -Polygon 1 58.76 4004.76 -5659.57 5954729.99 681785.00 70 16 53.564 N 148 31 44.205 W -Polygon 2 58.76 3363.56 -5420.46 5954094.99 682040.00 70 16 47.260 N 148 31 37.227 W ~ ~ bp BP Alaska ~~ ~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amocp Date: 6/14l2007 Time: 09:55:54 Psge: 2 FieW: Prudhoe $ay Co-ordiaate(NE) Refereaee: We~: 02-f 6, Tnte North Sitc: PB DS 02 Vertical (TVD) Reterenee: 39 : 16 ~10/1993 OO:QO 5$s8 WeU: d2-76 Sectioa (VS) Refereace: V1lefl (O.OON,O.OOE,110.OOAzi) Welipath: Plan 3; 02- 16C Burvey CakalatioA Met6od: Minimum Cuevature Db: Orade Targets Map A~p <-- I.atitnde _.a a.- Lpsgitdde .> Name Description 'CVD +lYf•S +E/-W Nort6ieg Essting Deg Mia Sec Dea Mi~ ' Sec Dip. Dir. ft ft ft ft ft 02-16C Fauit 5 58.76 2323.30 -4020.86 5953090.00 683465.00 70 16 37.038 N 148 30 56.448 W -Polygon 1 58.76 2323.30 -4020.86 5953090.00 683465.00 70 16 37.038 N 148 30 56.448 W -Polygon 2 58.76 3231.93 -2547.68 5954035.00 684915.00 70 16 45.980 N 148 30 13.557 W 02-16C Target 4 8908.76 3145.66 -3180.06 5953933.00 684285.00 70 16 45.129 N 148 30 31.974 W 02-16C Target 2 8909.76 3213.33 -4008.68 5953980.00 683455.00 70 16 45.791 N 148 30 56.107 W 02-16C Target 3 8915.76 3207.82 -3506.63 5953987.00 683957.00 70 16 45.739 N 148 30 41.485 W 02-16C Target 1 8919.76 3303.54 -4898.76 5954048.00 682563.00 70 16 46.673 N 148 31 22.031 W Annotation MD 't'VD ft ft 11274.31 8911.33 TIP 11300.00 8914.52 KOP 11320.00 8916.82 End of 9 Deg/100' DLS 11340.00 8919.31 4 11358.89 8920.48 5 11508.89 8920.48 6 11648.89 8920.48 End of 40 Deg/100' DLS 11798.89 8920.48 8 11998.89 8918.82 9 12273.89 8914.57 10 12573.89 8910.73 11 12723.89 8909.87 12 12823.89 8910.75 13 13123.89 8915.76 14 13223.89 8916.46 15 13348.89 8914.72 16 13550.00 0.00 TD Plan Secfion Information NID Incl Azim TVD +N/-S +E/-W DLS Build Turn fiF0 Target ft deg deg ft ft ft deg/100ft deg/100tt deg/1dOft deg 11274.31 81.76 255.11 8911.33 3645.71 -4948.22 0.00 0.00 0.00 0.00 11300.00 83.98 252.~3 8914.52 3638.65 -4972.71 12.62 8.64 -9.26 313.08 11320.00 82.82 251.34 8976.82 3632.53 -4991.61 9.00 -5.78 -6.95 230.00 11340.00 82.90 243.28 8919.31 3624.88 -5009.90 40.00 0.35 -40.31 270.00 11358.89 90.00 240.70 8920.48 3616.03 -5026.53 40.00 37.61 -13.65 340.00 11508.89 90.00 180.70 8920.48 3492.86 -5099.66 40.00 0.00 -40.00 270.00 11648.89 90.00 124.70 8920.48 3373.35 -5037.98 40.00 0.00 -40.00 270.00 11798.89 90.00 106.70 8920.48 3308.57 -4903.37 12.00 0.00 -12.00 270.00 11998.89 90.94 82.72 8918.82 3292.26 -4705.51 12.00 0.47 -11.99 272.30 12273.89 90.78 115.72 8914.57 3248.82 -4437.83 12.00 -0.05 12.00 90.00 12573.89 90.63 79.72 8910.73 3209.18 -4145.44 12.00 -0.05 -12.00 270.00 12723.89 90.02 97.71 8909.87 3212.54 -3996.09 12.00 -0.41 11.99 91.90 12823.89 88.98 109.66 8910.75 3188.92 -3899.11 12.00 -1.04 11.96 95.00 13123.89 89.17 73.66 8915.76 3180.37 -3604.19 12.00 0.07 -12.00 270.00 13223.89 90.02 85.63 8916.46 3198.31 -3506.00 12.00 0.85 11.97 86.00 13348.89 91.57 100.55 8914.72 3191.59 -3381.55 12.00 1.24 11.94 84.00 13550.00 91.43 76.41 8909.36 3196.88 -3182.07 12.00 -0.07 -12.00 270.00 ~ ~ bp BP Alaska s~ ~ ~ Baker Hughes INTEQ Planning Report 1NTE Q Compaey: BP Amoco Date: 6/14/2007 Time: 09:55:54 P~Ee: 3 Fieid: Prudhoe Bay Co-ordisate(NE) Refensee: WeR: d2-16, True Nwth Site: PB DS 02 Vertica l (TVD) Rcference: 39 : 1 6 9/t0/1993 00:00 58.8 We1L• 02-16 Sectioo (VS) Refereoce: WeU (O.OON,OAOE,110.OOAai) Weilpath: Plan 3, 02-16C Snrvey C~kulation Met6od: Minimum Curvature ` Ab: Q[ade Survey NID Incl Aziro SS TVD N/S E/W MapN MapE DLS VS TFO : Tool ft deg dey ft ft ft ft ft deg/100ft ` ft deg 11275.00 81.82 255.05 8852.67 3645.54 -4948.88 5954388.62 682504.38 0.00 -5897.27 0.00 MWD 11300.00 83.98 252.73 8855.76 3638.65 -4972.71 5954381.14 682480.73 12.62 -5917.31 313.09 MWD 11320.00 82.82 251.34 8858.06 3632.53 -4991.61 5954374.54 682461.99 9.00 -5932.97 230.00 MWD 11325.00 82.83 249.32 8858.68 3630.86 -4996.28 5954372.76 682457.37 40.00 -5936.79 270.00 MWD 11340.00 82.90 243.28 8860.55 3624.88 -5009.90 5954366.44 682443.90 40.00 -5947.55 270.25 MWD 11350.00 86.66 241.91 8861.46 3620.29 -5018.74 5954361.64 682435.18 40.00 -5954.28 340.QU MWD 11358.89 90.00 240.70 8861.72 3616.03 -5026.53 5954357.18 682427.49 40.00 -5960.15 340.12 MWD 11375.00 90.00 234.26 8861.72 3607.37 -5040.11 5954348.19 682414.14 40.00 -5969.95 270.00 MWD 11400.00 90.00 224.26 8861.72 3591.07 -5059.02 5954331.43 682395.63 40.00 -5982.15 270.00 MWD 11425.00 90.00 214.26 8861.72 3571.74 -5074.82 5954311.71 682380.32 40.00 -5990.38 270.00 MWD 11450.00 90.00 204.26 8861.72 3549.96 -5087.03 5954289.63 682368.66 40.00 -5994.40 270.00 MWD 11475,00 90.00 194.26 8861.72 3526.39 -5095.26 5954265.86 682361.02 40.00 -5994.07 270.00 MWD 11500,00 90.00 184.26 8861.72 3501.74 -5099.28 5954241.13 682357.62 40.00 -5989.42 270.00 MWD 11508.89 90.00 1$0.70 8861.72 3492.86 -5099.66 5954232.24 682357.46 40.00 -5986.74 270.00 MWD 11525,00 90.00 174.26 8861.72 3476.78 -5098.95 5954216.18 682358.57 40.00 -5980.58 270.00 MWD 11550.00 90.00 164.26 8861.72 3452.25 -5094.30 5954191.77 682363.83 40.00 -5967.81 270.00 MWD 11575.00 90.00 154.26 8861.72 3428.90 -5085.45 5954168.65 682373.25 40.00 -5951.52 270.00 MWD 11600.00 90.00 144.26 8861.72 3407.44 -5072.69 5954147.52 682386.55 40.00 -5932.18 270.00 MWD 11625.00 90.00 134.26 8861.72 3388.52 -5056.39 5954129.01 682403.31 40.00 -5910.40 270.00 MWD 11648.89 90.00 124.70 8861.72 3373.35 -5037.98 5954114.31 682422.10 40.00 -5887.90 270.00 MWD 11650.00 90.00 124.57 8861.72 3372.72 -5037.06 5954113.70 682423.03 12.00 -5886.83 270.00 MWD 11675.00 90.00 121.57 8861.72 3359.08 -5016.11 5954100.59 682444.31 12.00 -5862.48 270.00 MWD 11700.00 90.00 118.57 8861.72 3346.55 -4994.48 5954088.61 682466.24 12.00 -5837.87 270.00 MWD 11725.00 9D.00 115.57 8861.72 3335.18 -4972.22 5954077.79 682488.78 12.00 -5813.06 270.00 MWD 11750.00 90.00 112.57 8861.72 3324.99 -4949.40 5954068.17 682511.85 12.00 -5788.12 270.00 MWD 11775.00 90.00 109.57 8861.72 3316.00 -4926.07 5954059.77 682535.39 12.00 -5763.13 270.00 MWD 11798.89 90.00 106.70 8861.72 3308.57 -4903.37 5954052.90 682558.27 12.00 -5739.26 270.00 MWD 11800.00 90.01 106.57 8861.72 3308.25 -4902.31 5954052.61 682559.34 12.00 -5738.15 272.30 MWD 11825.00 90.13 103.57 8861.69 3301.75 -4878.17 5954046.72 682583.63 12.00 -5713.24 272.30 MWD 11850.00 90.25 100.57 8861.61 3296.52 -4853.72 5954042.10 682608.19 12.00 -5688.49 272.30 MWD 11875.00 90.36 97.5~ 8861.47 3292.58 -4829.04 5954038.78 682632.97 12.00 -5663.94 272.29 MWD 11900.00 90.48 94.58 8861.29 3289.93 -4804.18 5954036.75 682657.88 12.00 -5639.68 272.27 MWD 11925.00 90.60 91.58 8861.05 3288.59 -4779.22 5954036.03 682682.86 12.00 -5615.77 272.25 MWD 11950.00 90.72 88.58 8860.76 3288.56 -4754.23 5954036.62 682707.85 12.00 -5592.27 272.22 MWD 11975.00 90.83 85.58 8860.43 3289.83 -4729.27 5954038.51 682732.77 12.00 -5569.25 272.19 MWD 11998.89 90.94 82.72 8860.06 3292.26 -4705.51 5954041.54 682756.4& 12.Q0 -5547.75 272.15 MWD 12000.00 90.94 82.85 8860.04 3292.40 -4704.41 5954041.71 682757.56 12.00 -5546.76 90.00 MWD 12025.00 90.93 85.85 8859.63 3294.86 -4679.53 5954044.78 682782.36 12.00 -5524.23 90.00 MWD 12050.00 90.93 88.85 8859.23 3296.02 -4654.57 5954046.56 682807.29 12.00 -5501.17 90.05 MWD 12075.00 90.92 91.85 8858.82 3295.87 -4629.57 5954047.03 682832.28 12.00 -5477.63 90.10 MWD 12100.00 90.91 94.85 8858.42 3294.40 -4604.62 5954046.19 682857.26 12.00 -5453.68 90.15 MWD 12125.00 90.90 97.85 8858.02 3291.64 -4579.78 5954Q44.05 682882.96 12.00 -5429.39 90.20 MWD 12150.00 90.89 100.85 8857.63 3287.58 -4555.12 5954040.60 682906.91 12.00 -5404.83 90.24 MWD 12175.00 90.87 103.85 8857.25 3282.23 -4530.70 5954035.86 682931.45 12.00 -5380.06 90.29 MWD 12200.00 90.85 106.85 8856.87 3275.61 -4506.60 5954029.85 682955.71 12.00 -5355.15 90.34 MWD 12225.00 90.83 109.85 8856.50 3267.74 -4482.88 5954022.57 682979.62 12.00 -5330.16 90.38 MWD 12250.00 90.81 112.85 8856.15 3258.64 -4459.60 5954014.05 683003.12 12.00 -5305.17 90.43 MWD 12273.89 90.78 115.72 8855.81 3248.82 -4437.83 5954004.78 683025.13 12.00 -5281.36 90.47 MWD 12275.00 90.78 115.59 8855.80 3248.34 -4436.83 5954004.32 683026.14 12.00 -5280.25 270.00 MWD 12300.00 90.78 112.59 8855.46 3238.13 -4414.01 5953994.69 683049.20 12.00 -5255.32 270.00 MWD 12325.00 90.78 109.59 8855.12 3229.14 -4390.69 5953986.28 683072.74 12.00 -5230.33 269.96 MWD 12350.00 90.77 106.59 8854.78 3221.38 -4366.93 5953979.12 683096.68 12.00 -5205.35 269.92 MWD 12375.00 90.77 103.59 8854.44 3214.88 -4342.80 5953973.22 683120.97 12.00 -5180.45 269.88 MWD ~ ~ b BP Alaska s~ ~ ~ p Baker Hughes INTEQ Planning Report 1NTEQ Coropaoy: BP Amoco Date: 6/14l2007 Time: 09:55:54 PAge: 4 Field: Prudhoe Bay Co-ordi~ate(NE) Refereece: WeU: 02-16~ Trve North Site: PB OS 02 VerticAl (TVD) Referena: ' 39 : 1 6 9/10/4993 Q0:00 58:8 Well: ' Q2- 16' Sectioa (VS) Referencec WeN {O.OON,O.QOE,110.OOAzi) WeOpath; Plan 3, 02-16C Survey Gakulation Method: ; Minimum Curvature Db: Orade Survey NID Incl Azim SS'TVD N/S F./W MnpN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100k ft deg' 12400.00 90.76 100.59 8854.11 3209.64 -4318.35 5953968.59 683145.53 12.00 -5155.69 269.84 MWD 12425.00 90.75 97.59 8853.78 3205.70 -4293.67 5953965.26 683170.30 12.00 -5131.15 269.80 MWD 12450.00 90.73 94.59 8853.46 3203.05 -4268.82 5953963.23 683195.21 12.00 -5106.88 269.76 MWD 12475.00 90.72 91.59 8853.14 3201.70 -4243.86 5953962.51 683220.20 12.00 -5082.97 269.72 MWD 12500.00 90.~0 88.59 8852.83 3201.66 -4218.87 5953963.09 683245.18 12.00 -5059.47 269.68 MWD 12525.00 90.68 85.59 8852.53 3202.93 -4193.90 5953964.99 683270.10 12.00 -5036.45 269.64 MWD 12550.00 90.66 82.59 8852.24 3205.51 -4168.04 5953968.18 683294.89 12.00 -5013.96 269.61 MWD 12573.89 90.63 79.72 8851.97 3209.18 -4145.44 5953972.44 683318.40 12.00 -4993.04 269.57 MWD 12575.00 90.63 79.85 8851.96 3209.38 -4144.35 5953972.67 683319.48 12.00 -4992.08 91.90 MWD 12600.00 90.53 82.85 8851.71 3213.14 -4119.63 5953977.04 683344.09 12.00 -4970.15 91.90 MWD 12625.00 90.43 85.85 8851.50 3215.60 -4094.76 5953980.12 683368.90 12.00 -4947.61 91.93 MWD 12650.00 90.32 88.85 8851.33 3216.76 -4069.79 5953981.90 683393.83 12.00 -4924.55 91.96 MWD 12675.00 90.22 91.85 8851.21 3216.61 -4044.79 5953982.37 683418.82 12.00 -4901.01 91.98 MWD 12700.00 90.12 94.84 8851.14 3215.15 -4019.84 5953981.53 683443.80 12.00 -4877.06 91.99 MWD 12723.89 90.02 97.71 8851.11 3212.54 -3996.09 5953979.52 683467.60 12.00 -4853.85 92.00 MWD 12725.00 90.00 97.84 8851.11 3212.39 -3994.99 5953979.39 683468.70 12.00 -4852.77 95.00 MWD 12750.00 89.74 100.83 8851.17 3208.33 -3970.33 5953975.95 683493.46 12.00 -4828.20 95.00 MWD 12775.00 89.48 103.82 8851.34 3203.00 -3945.91 5953971.23 683518.01 72.00 -4803.43 94.99 MWD 12800.00 89.22 106.81 8851.62 3196.39 -3921.80 5953965.23 683542.27 12.00 -4778.52 94.97 MWD 12823.89 88.98 109.66 8851.99 3188.92 -3899.11 5953958.33 683565.13 12.00 -4754.64 94.94 MWD 12825.00 88.98 109.53 8852.01 3188.55 -3898.07 5953957.98 683566.19 12.00 -4753.53 270.00 MWD 12850.00 88.98 106.53 8852.46 3180.81 -3874.30 5953950.84 683590.14 12.00 -4728.56 270.00 MWD 12875.00 88.98 103.53 8852.90 3174.33 -3850.16 5953944.96 683614.43 12.00 -4703.66 270.06 MWD 12900.00 88.99 100.53 8853.35 3169.12 -3825.72 5953940.36 683638.99 12.00 -4678.91 270.11 MWD 12925.00 89.00 97.53 8853.78 3165.20 -3801.04 5953937.06 683663.76 12.00 -4654.37 270.16 MWD 12950.00 89.01 94.53 8854.22 3162.58 -3776.18 5953935.05 683688.68 12.00 -4630.11 270.21 MWD 12975.00 89.03 91.53 8854.64 3161.26 -3751.22 5953934.35 683713.66 12.00 -4606.21 270.27 MWD 13000.00 89.05 88.53 8855.06 3161.24 -3726.23 5953934.97 683738.64 12.00 -4582.72 270.32 MWD 13025.00 89.07 85.53 8855.48 3162.54 -3701.27 5953936.88 683763.56 12.00 -4559.71 270.37 MWD 13050.00 89.09 82.53 8855.88 3165.14 -3676.41 5953940.10 683788.35 12.00 -4537.24 270.42 MWD 13075.00 89.12 79.53 885627 3169.04 -3651.72 5953944.61 683812.93 12.00 -4515.37 270.47 MWD 13100.00 89.14 76.53 8856.65 3174.22 -3627.27 5953950.41 683837.24 12.00 -4494.17 270.51 MWD 13123.89 89.17 73.66 8857.00 3180.37 -3604.19 5953957.12 683860.16 12.00 -4474.58 270.56 MWD 13125.00 89.18 73.79 8857.02 3180.68 -3603.13 5953957.46 683861.22 12.00 -4473.69 86.00 MWD 13150.00 89.39 76.79 8857.33 3187.03 -3578.95 5953964.41 683885.23 12.00 -4453.14 86.00 MWD 13175.00 89.60 79.78 8857.55 3192.10 -3554.47 5953970.09 683909.56 12.00 -4431.88 85.96 MWD 13200.00 89.82 82.77 8857.67 3195.90 -3529.77 5953974.50 683934.17 12.00 -4409.96 85.93 MWD 13223.89 90.02 85.63 8857.70 3198.31 -3506.00 5953977.51 683957.86 12.00 -4388.45 85.92 MWD 13225.00 90.04 85.76 8857.70 3198.39 -3504.90 5953977.62 683958.97 12.00 -4387.44 84.00 MWD 13250.00 90.35 88.75 8857.62 3199.59 -3479.93 5953979.44 683983.90 12.00 -4364.39 84.00 MWD 13275.00 90.66 91.73 8857.40 3199.49 -3454.93 5953979.95 684008.89 12.00 -4340.86 84.01 MWD 13300.00 90.97 94.71 8857.04 3198.08 -3429.98 5953979.17 684033.87 12.00 -4316.93 84.04 MWD 13325.00 91.28 97.70 8856.55 3195.38 -3405.13 5953977.09 684058.77 12.00 -4292.66 84.08 MWD 13348.89 91.57 100.55 8855.96 3191.59 -3381.55 5953973.89 684082.44 12.00 -426921 84.14 MWD 13350.00 91.57 100.42 8855.93 3191.39 -3380.46 5953973.72 684083.53 12.00 -4268.11 270.00 MWD 13375.00 91.57 97.42 885524 3187.52 -3355.78 5953970.46 684108.30 12.00 -4243.59 270.00 MWD 13400.00 91.56 94.42 8854.56 3184.s4 -3330.92 5953968.51 684133.21 12.00 -4219.36 269.91 MWD 13425.00 91.55 91.41 8853.88 3183.67 -3305.97 5953967.86 684158.19 12.00 -4195.47 269.83 MWD 13450.00 91.54 88.41 8853.20 3183.71 -3280.98 5953968.52 684183.17 12.00 -4172.00 269.75 MWD 13475.00 91.52 85.41 8852.54 3185.05 -3256.03 5953970.48 684208.08 12.00 -4149.02 269.67 MWD 13500.00 91.49 82.41 8851.88 3187.70 -3231.18 5953973.75 684232.85 12.00 -4126.57 269.59 MWD 13525.00 91.47 79.41 8851.24 3191,65 -3206.50 5953978.31 684257.42 12.00 -4104.74 269.51 MWD ~J ~_JJ b BP Alaska s~ ~ ~ p Baker Hughes INTEQ Planning Report 1NTEQ Companys BP Amoco Date: 6/14/2007 Time: 09:55:54 Page: 5 Ficld: ' Prudhoe Bay Co-ordioate(NE) Referertce: ` WeB: 02-16, True Nordt Site: PB DS 02 VerEical (TVD) Refereece: ` 39 : 16 9/90/1993 ~0:00 58.8 Well: 02-16 Sectioe (VS) Refereace: WeN (O.OON,O.OOE,)10.40Azi) Weilpath: Plarr 3, 02-16G Survey Caleulation Met6od: Minimum Curvatute Db: Qrade Survey NID Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tooi- ft deg deg ft ft ft ft ft deg/100$ ft deg 13550.00 91.43 76.41 8850.60 3196.88 -3182.07 5953984.15 684281.71 12.00 -4083.56 269.43 2 3/8" ^ • ~~~ g~b b F ! s{ ~ ! Ag~ ~ ~ ~ ~~a~ ~ ~ ~~m~ ~, osos oooa~ I Q. ~ ~ a w € a ~ ~ -C ~s y 3 Y ? ~~ ~ ~ `~~~~ ~ i ~ !~ ; a; ~ ~ v=°~~ Q ~p~~~A~ ~=~~ = t r:rrE a -='~ m ~1 3' i~ i =~~'s`~ ~; ~ ~ : ~~~a]$ ~~ §~ 3 3 3 i~~~y^~~~~ffiaaJ ~ s ~i~: TT ~ y ~ 1 ~~~~~~~ ; 3 Z:i...a...._cr.:e ~ g .lxl:eie ;~i _.......sswaue ~,3: er .::_._=?:~..----- $ a° ~ Y i F t ;- ,~~~ ~ ~fi 'F~;1j~ T:~ ~ EtG ~ - { ~ , I ~ ~j 1; ~r ~ ~:-,.~, .~. .,~, „~. ..~. _. [waw~l aew i.~w.n .~+a ...y.~ ~ ~ ~ bp BP Alaska Anticollision Report ~i%~ s~~s INTEQ Coropsay: BP Amoca Date: 6/14/2007 Time: 10:26:22 Pa~e: 1 Fietd: Pnadhoe Bay Re~'ereace Site: PB DS 02 Co-ordirate(NE) Retereece: We~: 02-16, True North Refereace We1L• ' 02-16 Vertical (TVD) Refer~ence: 39 : 16 9/10/i993 00: 00 58.5 Reknaee Wellpath: Plan 3, 02-16C Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ot reference - T6ere are "Ri~~eells io this~e111Ypal Plan 8 PLANNED PROGRAM Interpolation Met6od: MD Interval: 100.00 ft Error Model: ISCWSA Eltipse Depth Range: 11274.31 to 13550.00 ft Scan Met6od: Trav Cylinder North Maaimum Radius: 2500.00 ft Error Surface: Ellipse + Casing Sarvey Program for Definitive Wellpath Date: 6/13/2007 Validated: No Versioo: 0 Planaed From To Survey Toolcode Tool N ame ft ft 94.76 9394.76 1: Camera based gyro muftisho CB-GYRO-MS Camera based gyro multishot 9640.52 10949.00 MWD (9394.76-11933.00) (1) MWD MWD - Standard 10949.00 11274.31 MWD (1 0949.00-13685.00) (2) MWD MWD - Standard 11274.31 f 3550.00 Planned: Plan #3 V2 MWD MWD - Standard Casing Points MD 1'VD Diaroeter Holc Siu Name 8 ft in irr 13550.00 8909.36 2.375 3.125 2 3/8" Sommary < Ofiset Weilpat6 ---% Refereece OtiseC Ctr-Ctr No-Go Allowable Site WeII Wetipat6 MD MD Distaoce Area ' Deviatian Warniag ft ft ft ft ft PB DS 02 02-16 02-16 V7 12134.33 10700.00 553.161016.35 -463.19 FAIL: Major Risk PB DS 02 02-16 02-16A V6 14127.46 11400.00 208.91 1953.13 -1744.21 FAIL: Major Risk PB DS 02 02-16 02-166 V13 12068.00 10900.00 318.091055.32 -737.23 FAIL: Major Risk PB DS 02 02-28 02-28 V3 13525.00 10216.76 1402.90 598.47 804.43 Pass: Major Risk PB DS 02 02-28 02-28A V3 13550.00 10200.00 1226.17 572.20 653.97 Pass: Major Risk PB DS 02 02-28 02-28AL1 V7 13390.22 10900.00 761.67 746.68 14.99 Pass: Major Risk PB DS 02 02-30 02-30 V3 Out of range PB DS 02 02-30 02-30A V1 13300.00 11000.00 1291.81 745.64 546.18 Pass: Major Risk PB DS 02 02-30 ~02-306 V3 13321.60 11600.00 615.69 753.53 -137.84 FAiL: Major Risk F-- PB DS 02 02-30 02-30BPB1 V2 13316.41 11738.96 953.85 769.04 184.81 Pass: Major Risk PB DS 02 02-30A 02-30A V2 13300.00 11000.00 1291.30 745.34 545.96 Pass: Major Risk PB DS 02 02-30A 02-306 VO Plan: 02-306 13325.00 11700.00 784.83 770.02 14.81 Pass: Major Risk PB DS 07 07-33 07-33 V4 11610.00 11207.76 1158.98 836.32 322.67 Pass: Major Risk PB DS 07 07-33 ~ 07-33A V1 12436.31 12759.76 661.31 796.95 -135.64 FAIL: Major Risk E-- PB DS 07 07-33 -'1 07-33AP61 V5 12350.00 12538.76 681.13 849.46 -168.33 FAII: Major Risk ~ PB DS 07 07-33 07-33APB2 V1 11648.89 11500.00 941.20 864.17 77.03 Pass: Major Risk PB DS 07 07-33 07-336 V5 11610.00 10900.00 1332.09 833.85 498.24 Pass: Major Risk PB DS 15 15-38 15-38A V13 11520.00 14134.71 1254.58 688.01 566.57 Pass: Major Risk PB DS 15 15-42 Plan#2 15-428 V1 Plan: 11283.43 1 t000.00 2008.78 631.73 1377.05 Pass: Major Risk Site: PB DS 02 Well: 02-16 Rule Assigoed: Major Risk Wellpath: 02-16 V7 Inter-Site Error: 0.00 ft Refercnce Offset Semi-Major Aais Ctr-Ctr No-Go AOowabie MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglFI~ist9nce Area Deviation Warni~g ft ft ft ft ft ft deg deg in ft ft ft 12982.80 8913.54 8300.00 6492.78 197.98 170.50 100.64 10.05 9.625 2458.83 239.87 2218.96 Pass 12958.85 8913.13 8400.00 6572.26 205.23 179.10 102.84 9.37 9.625 2372.90 236.84 2136.06 Pass 12932.65 8912.68 8500.00 6652.15 212.58 187.99 105.33 8.72 9.625 2287.33 233.65 2053.68 Pass 12904.75 8912.19 8600.00 6732.71 219.74 196.84 108.05 8.09 9.625 2201.74 230.01 1971.73 Pass 12875.39 8911.67 8700.00 6874.17 226.50 205.42 110.97 7.49 9.625 2115.88 226.00 1889.88 Pass 12844.43 8911.12 8800.00 6896.64 232.61 213.62 114.14 6.94 9.625 2029.69 222.19 1807.50 Pass 12803.98 8910.43 8900.00 6979.81 232.72 216.44 113.79 6.51 9.625 1943.36 216.95 1726.41 Pass 12753.08 8909.94 9000.00 7063.46 222.05 209.28 107.20 6.01 9.625 1856.69 206.86 1649.83 Pass 12703.59 8909.89 9100.00 7147.46 209.28 199.77 100.53 5.25 9.625 1769.87 193.87 1576.00 Pass 12655.89 8910.06 9200.00 7231.95 194.84 188.26 93.81 4.26 9.625 1682.77 178.80 1503.97 Pass 12616.42 8910.32 9300.00 7317.14 181.46 177.31 87.87 3.05 9.625 1595.49 166.14 1429.35 Pass 12583.60 8910.63 9400.00 7403.25 169.41 167.26 82.54 1.66 1508.09 157.44 1350.65 Pass 12554.86 8910.95 9500.00 7489.85 172.90 172.36 82.14 0.14 1421.19 153.50 1267.69 Pass ~ ~ Alaska Department of Natural Resources Land Administration System Page 1 of 2 ~ ~ Stat~ Cabins ~~tu ~ ' ~! 5 mm~~ ,.~,.~.~ File Type: ADL ~ File Number: 283~8 = - Printable C..ase Fil.e_Summary See Township, Range, Section and Acreage? ~~, ,~~~~ ,. ~ Yes ~ No f~° ~ r~~~~ ~ ~ Last updated on 06121/2007. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28308&... 6/21 /2007 ~ ~ ! IfJi IYONVfIqI UOffl~ f1fOJ1~O Anchorage, AK 99501 MEMO t J~ ~ 1 ~ I O ~~ ~~ ~:i25200060~:99i4622?i556~~' 0341 Terri L. Hubble 89-6/1252 341 BP Exploration AK Inc. ~~Mastercard Check° PO Box 196612 MB 7-5 _~~ Anchorage, AK 99519 DATE ~ ~__J ~'RA~YSidII~'T'AL L~~'TER CI~~CKL~ST ~/ELL cYAI'~IE ~/,~~ Q~.,~ ~ P'tD# ~D ~O~ ~ Development Service E~ploratory St ` Yon-Conventiona[ Wet! ratigraphic Z'est ~ Circte Appropriate Letter / paragraphs to be Inctud~d ia Traasmitta! Letter CHECK V~'HAT APPLIES AUU-UYS (OPTIOtiS} T'EXT FOR APPROV4L LETTER ~ MtiLTt LATER.AL i rhe permit i; for a new well6oce se me t f i ' g n o ex sting j(If fa.st two deg We[ t ~ its in I ;~P[ number are ; P~~~t NO' . APj No. 50- . ; between 60-69) Production shouid continue to be reported as a function of the ~ ~ original 4Pt number stated a6ove. ~ PILOT E[OLE j ; in accordacice with 2p A.4C 25.OU~ ~~ (~, all record.s, da.ta and Io~s ~ ; a:cquired for the pilot hole must be i cteacly differentiated in both ~ ; ~'etl name ( PE~ and API ~umber ~ i i~~~- - -____} from records, data and to~s ~ , acquired for wel! ~ ~ SPAClNG ~ EXCEPTION The perrrtit is approved subject to feit! compliance with 20 AAC ~ ! ~ 2~.0». Approval to perforate and ~roduce / iniect is contingent ? I upoa issua f i nce o a conservation oe~ler approving a spacing j ; exceptton. ' ~ liability of any protest to the spacing exceptior~ rhac r~ay occurs ~e i ; DRY DCtCH ~ ~``~i~ drr' ditch sample sets submitted to th -~ i SA!1~IPLE ~ e ommission must be in ; no greater thar~ 30 sample intervals from below~ the pecmafrost or ; f ~ ~ rom where samptes are fint caught and IO' sample intervals ; through target aones. ~ i i~o "Conventiona! ~ j Piease note the fotlowing specia! coadition of rhis i producrion or production testi f t o ~r~ Z i ' ng o coa[ bed metharte is not a w ~ ~ for (ciame of we11) untt( after (Cocnaanv Name) has designed d i ~ ~ implemeated a water well testing program to provide basetine data ; on water quality and u ti I q an ry. ~Comaartv 1Vame) must concact the ~ Commission to obtain advance a rova! f pp o i such water welf testing ! ' _P~oBrattt. 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U ¢¢ ~ ~ Well History File APPE~IDIX Iniormation of detailed nature that is not panicula~iy geRnane to the Weii PeRnitting Process but is part of the history file. To improve the readability of the We~l History file and to simpl~fy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronotogically _ organize this category of information. ~ ~ tapescan.txt **** REEL HEADER **** MWD 09/O1/30 BHI 01 LIS Customer Format Tape ~~*~ TAPE HEADER **** MWD 07/08/22 1506411 O1 2.375" CTK ^** LIS COMMENT RECORD **~' !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~Version znformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well znformation Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 10916.0000: Starting De pth SroP.FT 13602.5000: Ending Dept h STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 02-16C FLD . FIELD: Prudhoe Bay Unit ~oc . LOCATION: 70 deg 16' 14.2"N 148 deg 28' S9.36"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375~~ CTK DATE. LOG DATE: 22 AUg 2007 API . API NUMBER: 500292044803 ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 36 . TOWN.N T11N . RANG. R13E . PDAT. MSL . EPD .F O . LMF . DF . FAPD.F 58.76 . DMF . DF . EKB .F O . EDF .F 58.76 . EGL .F O . Page 1 ~escription section Township rtange Permanent Datum Elevation Of Perm. Datum ~og Measured from Feet Above Perm. Datum ~rilling Measured From Elevation of Kelly Bushing Elevation of ~errick Floor Elevation of Ground ~evel ~c~--o~s ~ r~-~4~' ~3 C~ CASE.F N/A OS1 . DIRECTIONAL ~ tapescan.txt . Casing ~epth . Other Services Line ~rtemarks (1) ,411 depths are Measured ~epths (MD) unless otherwise noted. (2) ,411 depths are Bit ~epths unless otherwise noted. (3) All True vertical ~epths (TV~ss) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the ,4dvantage surface system to lo~ this well.. (6) Tools ran in the string included Casing Collar ~ocator, an Electrical ~isconnect and Circulating sub, a ~rilling Performance sub (Inner and outer ~ownhole Pressure, vibration and ~ownhole weight on Bit), a ~irectional and Gamma sub, and a Hydraulic orientin~ sub with a Near Bit Inclination sensor. (7) ~ata presented here is final and has been depth adjusted to a Primary oepth Control (P~C)log provided by schlumberger CH GR CNL dated 28 Aug 2007 per poug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 02-16e through a milled window in a 3 1/2 inch liner. Top of window 11307 ft.MD (8856.6 ft.NDSS) Bottom of window 11312 ft.M~ (8857.0 ft.7v~s5) (9) Tied to 02-166 at 11274 feet M~ (8852.57 feet TV~ss). (10) The open Hole side Track from 02-16CPg1 was off of an aluminum billet set at 121500 ft. MD (8848 ft TVDSS). (11) The interval from 13574 feet to 13604 feet MD (8839.0 feet to 8838.6 feet TVD55) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJaVG -> Rate of Penetration, feet/hour Tv~ss -> True vertical oepth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, 10925.6, 10926.6, 10941.5, 10942.1, 10944.4, 10945, 10950.2, 10949.6, 10958.1, 10957.9, 10961, 10960.8, 10967.8, 10967, 10975.3, 10974.9, 10985.6, 10985, 11005.9, 11004.7, 11026.4, 11025.4, 11034.1, 11031.8, 11048.4, 11047.4, 11057.5, 11054.2, 11064.8, 11063.5, 11075.4, 11073.9, 11083.9, 11083.4, 11102.3, 11101.5, 11104.2, 11103.3, 11108.7, 11108.5, 11118.3, 11118.3, 11121.2, 11121.6, 11130.9, 11129.9, 11137.1, 11136.3, 11141.9, 11141.3, 11147.5, 11146.6, 11154.3, 11153.9, 11166.1, 11164.7, 11167.8, 11167.6, 11177.7, 11178.4, DISPLACEMENT 1.03711 0.62207 0.62207 -0.621094 -0.207031 -0.208008 -0.830078 -0.414062 -0.62207 -1.24414 -1.03711 -2.28027 -1.03613 -3.31641 -1.24414 -1.45117 -0.414062 -0.829102 -0.829102 -0.208008 0 0.414062 -1.03711 -0.829102 -0.62207 -0.829102 -0.415039 -1.45117 -0.208008 0.621094 Page 2 . 11183.1, 11182.3, 11205.2, 11204.8, 11209.1, 11210, 11214.1, 11213.9, 11217, 11217.4, 11223.4, 11224.9, 11231.7, 11231.1, 11237.3, 11235.9, 11247.1, 11244, 11253.7, 11253.7, 11259.7, 11259.5, 11265.5, 11266.5, 11275, 11275.9, 11282.9, 11281.9, 11285.8, 11285.6, 11296.3, 11295.9, 11298.6, 11300.2, 11302.5, 11302.3, 11303.3, 11304.6, 11311.6, 11311.6, 11314.7, 11314.9, 11340.9, 11340.9, 11353.3, 11352, 11360.1, 11359.7, 11364.1, 11363.4, 11370.5, 11370.7, 11376.3, 11376.9, 11403.9, 11404.3, 11409.2, 11408.4, 11434.9, 11433.9, 11438.4, 11436.7, 11442.5, 11442.1, 11454.9, 11452.7, 11470.8, 11469.8, 11509.4, 11510.2, 11525.4, 11523.5, 11562.3, 11560.4, 11568.7, 11567.9, 11581.2, 11581, 11582.4, 11582.8, 11584.5, 11584.5, 11601.5, 11601.5, 11606.2, 11606.4, 11608.5, 11608.5, 11643.4, 11642.6, 11647, 11645.5, 11656.1, 11654, 11664.2, 11662.7, 11670, 11668.9, 11708.9, 11704.2, 11714.5, 11711.6, 11723.2, 11722.2, 11725.9, 11725.7, 11732.1, 11731.7, 11737.6, 11737.4, 11767.8, 11768.7, 11827.7, 11824.8, 11839.9, 11839.3, 11869.6, 11868.9, 11896.1, 11894.8, 11914, 11913.7, 11921.6, 11919.3, 11925.1, 11922.7, tapescan.txt ! -0.829102 ! -0.415039 ! 0.829102 ! -0.208008 ! 0.415039 ! 1.45117 ! -0.62207 ! -1.45117 ! -3.10938 i p ! -0.207031 ! 1.03613 ! 0.829102 ! -1.03613 ! -0.207031 ! -0.414062 ! 1.6582 ! -0.207031 ! 1.24316 i p ! 0.208008 i p ! -1.24414 ! -0.415039 ! -0.62207 ! 0.207031 ! 0.621094 ! 0.415039 ! -0.829102 ! -1.03613 ! -1.6582 ! -0.414062 ! -2.28027 ! -1.03613 ! 0.829102 ! -1.86523 ! -1.86621 ! -0.829102 ! -0.207031 ! 0.415039 i p i p ! 0.207031 i p ! -0.829102 ! -1.4502 ! -2.07227 ! -1.45117 ! -1.03711 ! -4.76758 ! -2.90234 ! -1.03711 ! -0.207031 ! -0.414062 ! -0.207031 ! 0.829102 ! -2.90234 ! -0.62207 ! -0.62207 ! -1.24316 ! -0.207031 ! -2.28027 ! -2.4873 • Page 3 . tapescan.txt 11951.1, 11950.2, ! -0.829102 11956.9, 11955.2, ! -1.6582 11963.1, 11961.3, ! -1.86523 12002.1, 12000.6, ! -1.45117 12019.2, 12016.1, ! -3.10938 12025.8, 12022.1, ! -3.73145 12030.2, 12026, ! -4.14551 12032, 12027.7, ! -4.35352 12037.8, 12036, ! -1.86621 12058.8, 12055.5, ! -3.31641 12063.8, 12061.1, ! -2.69434 12070.2, 12070.6, ! 0.415039 12072.7, 12072, ! -0.62207 12076.6, 12074.9, ! -1.6582 12078.9, 12077.4, ! -1.45117 12082.8, 12082.2, ! -0.62207 12129.6, 12129.8, ! 0.207031 12146.1, 12149.2, ! 3.10938 12156.7, 12159.8, ! 3.10938 12164.4, 12164.8, ! 0.415039 12171.3, 12171.3, ! 0 12176.6, 12177.9, ! 1.24414 12191.4, 12193.2, ! 1.86621 12199.7, 12201.5, ! 1.86523 12206.7, 12206.5, ! -0.207031 12218.5, 12217.9, ! -0.621094 12226.6, 12230.1, ! 3.52441 12232.6, 12234.1, ! 1.45117 12244.2, 12247.5, ! 3.31641 12285.1, 12287, ! 1.86523 12292.8, 12294.9, ! 2.07324 12299.2, 12303.4, ! 4.14648 12325.9, 12327.1, ! 1.24414 12332.3, 12334, ! 1.6582 12335.2, 12337.5, ! 2.28027 12342.9, 12345.1, ! 2.28027 12346.8, 12346.8, ! 0 12351.2, 12353, ! 1.86523 12361.9, 12363.6, ! 1.6582 12367.1, 12367.5, ! 0.414062 12371.1, 12372.9, ! 1.86523 12374.6, 12376.7, ! 2.07227 12387.9, 12391.2, ! 3.31641 12390.8, 12393.5, ! 2.69531 12408.6, 12408.8, ! 0.207031 12415.9, 12416.5, ! 0.62207 12419.8, 12421.1, ! 1.24414 12423.1, 12424.4, ! 1.24316 12426, 12427.1, ! 1.03711 12491.7, 12493, ! 1.24316 12511.8, 12511.4, ! -0.415039 12521.3, 12521.9, ! 0.62207 12526.2, 12525.4, ! -0.829102 12534.7, 12534.5, ! -0.207031 12563.3, 12565, ! 1.6582 12590.3, 12590.3, ! 0 12592.1, 12594.4, ! 2.28027 12596.9, 12597.3, ! 0.415039 12605.4, 12603.3, ! -2.07324 12607.7, 12606.2, ! -1.45117 12623.4, 12622.8, ! -0.62207 12629.7, 12628.6, ! -1.03613 12640, 12639.8, ! -0.208008 Page 4 ~ ~ 12649.6, 12650.4, 12652.9, 12653.1, 12654.9, 12655.9, 12660.7, 12661.1, 12670, 12671.5, 12704.2, 12705.9, 12712.3, 12711.7, 12715.8, 12715.6, 12745.8, 12741.4, 12749.9, 12745.4, 12751, 12746.8, 12754.7, 12751, 12756.3, 12752.4, 12758.2, 12754.1, 12760.3, 12756.5, 12764.6, 12763, 12766.9, 12765, 12771.6, 12768.7, 12792.7, 12789.4, 12795.2, 12791.5, 12798.7, 12796.9, 12810.5, 12807, 12816.1, 12811.4, 12818.6, 12814.7, 12819.9, 12817, 12823.8, 12820.1, 12827.5, 12824, 12829.4, 12825.7, 12838.5, 12832.9, 12841.6, 12837.1, 12873.9, 12869.1, 12877.6, 12872.5, 12880.7, 12876.4, 12886.5, 12882.2, 12892.6, 12890.9, 12897.7, 12896.5, 12926.2, 12923.5, 12935.3, 12931.6, 12939.7, 12936.1, 12963.1, 12959.3, 13051.6, 13051.2, 13063.8, 13060.1, 13071.9, 13068.4, 13131.5, 13130.5, 13141.9, 13140, 13146.2, 13144, 13152.7, 13149.6, 13155.2, 13153.5, EOZ END ! BASE CURVE: GROH, Tape subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MwD .001 tapescan.txt 0.829102 0.208008 1.03711 0.415039 1.45117 1.6582 -0.62207 -0.207031 -4.35352 -4.56055 -4.14648 -3.73047 -3.93945 -4.14551 -3.73145 -1.6582 -1.86523 -2.90234 -3.31738 -3.73145 -1.86621 -3.52441 -4.76758 -3.93945 -2.90234 -3.73047 -3.52344 -3.73145 -5.59766 -4.56055 -4.76758 -5.18262 -4.35254 -4.35352 -1.6582 -1.24414 -2.69434 -3.73145 -3.52441 -3.73145 -0.414062 -3.73047 -3.52441 -1.03613 -1.86523 -2.28027 -3.10938 -1.6582 OFFSET CURVE: GRAX 277 records... 10 bytes 132 bytes ~J Page 5 ~ ~ tapescan.txt 1024 *** LIS COMMENT RECORD **~ !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary ~epth Control (P~C)log provided by sclumberger CH GR CNL dated 28 aug 2007 per poug Stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) ~ata record type is: 0 Datum Frame Size is: 12 bytes ~og~ing direction is down (value= 255) optical l.o~ Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] n-umber of frames per record is: 84 one depth per frame (value= 0) oatum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 1 Size Length 4 4 4 4 8 Total Data Records: 64 Tape File Start Depth = Tape File End Depth = Tape File ~evel Spacing = Tape File Depth Units = ~*** FILE TRAILER **** Tape subfile: 2 73 Minimum record length: 54 Maximum record length: 4124 10916.000000 13602.500000 0.500000 feet records... bytes bytes ~*** FILE HEADER *~** MWD .001 Page 6 t ~ ~ tapescan.txt 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field Mw~ data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes ~og~ing direction is down (value= 255) optical ~o~ Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] tvumber of frames per record is: 84 One depth per frame (value= 0) ~atum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 1 Size ~ength 4 4 4 4 8 Total oata rtecords: 129 Tape File Start Depth = Tape File End Depth = Tape File ~evel Spacing = Tape File ~epth Units = **** FILE TRAILER **** Tape subfile: 3 138 Minimum record length: 18 Maximum record length: 4124 10916.000000 13604.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD 07/08/22 1506411 Ol Page 7 , ~ tapescan.txt *~** REEL TRAILER **** MWD 09/Ol/30 BHI O1 Tape subfile: 4 Minimum record length: Maximum record length: 0 Tape Subfile 1 is type: ~IS 0 Tape Subfile 2 is type: ~IS 2 records... 132 bytes 132 bytes DEPTH GR ROP 10916.0000 -999.2500 -999.2500 10916.5000 10.3000 -999.2500 11000.0000 24.3000 -999.2500 11100.0000 31.0301 -999.2500 11200.0000 44.9037 -999.2500 11300.0000 157.6608 -999.2500 11400.0000 80.5690 71.2034 11500.0000 139.5822 60.7658 11600.0000 67.1000 108.0000 11700.0000 64.3153 89.6673 11800.0000 55.9835 101.1119 11900.0000 39.9888 136.2520 12000.0000 46.8247 132.7366 12100.0000 57.0415 102.9575 12200.0000 85.3010 135.3801 12300.0000 74.4733 126.9603 12400.0000 77.0829 129.8238 12500.0000 76.1012 115.6374 12600.0000 79.8354 107.5035 12700.0000 58.2727 106.5966 12800.0000 201.8131 47.2883 12900.0000 72.8211 132.2843 13000.0000 50.5544 126.1693 13100.0000 58.1469 104.8734 13200.0000 118.9576 21.7395 13300.0000 119.6816 92.0225 13400.0000 113.4605 141.3961 13500.0000 45.4018 157.0129 13600.0000 -999.2500 59.0572 13602.5000 -999.2500 52.5000 Tape File Start ~epth = 10916.000000 Tape File End Depth = 13602.500000 Tape File Level Spacing = 0.500000 Tape File oepth units = feet • 0 Page 8 n C ~ • tapescan.txt Tape Subfile 3 is type: ~zs DEPTH GR ROP 10916.0000 11.2000 -999.2500 10916.2500 11.8000 -999.2500 11000.0000 24.3000 -999.2500 11100.0000 33.2000 -999.2500 11200.0000 48.4000 -999.2500 11300.0000 133.8000 -999.2500 11400.0000 81.0000 70.6000 11500.0000 142.0000 41.7000 11600.0000 67.1000 108.0000 11700.0000 54.8000 93.0000 11800.0000 57.1000 101.2000 11900.0000 45.6000 134.1000 12000.0000 44.6000 160.4000 12100.0000 56.2000 104.4000 12200.0000 85.8000 134.5000 12300.0000 67.3000 134.2000 12400.0000 87.6000 130.3000 12500.0000 76.7000 116.4000 12600.0000 81.3000 108.0000 12700.0000 58.4000 106.9000 12800.0000 207.2000 57.8000 12900.0000 70.7000 131.9000 13000.0000 52.5000 121.4000 13100.0000 55.2000 48.0000 13200.0000 121.9000 19.9000 13300.0000 118.9000 74.0000 13400.0000 93.9000 111.3000 13500.0000 45.4000 139.3000 13600.0000 -999.2500 68.3000 13604.0000 -999.2500 52.5000 Tape File Start oepth = 10916.000000 Tape File End oepth = 13604.000000 Tape File ~evel Spacing = 0.250000 Tape File ~epth units = feet 0 Tape Subfile 4 is type: LIS Page 9 ~ tapescan.txt **** REEL HEADER **** MWD 09/02/03 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 07/08/22 1506411 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~version znformation ~ VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~well znformation Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 10916.0000: Starting Depth STOP.FT 12812.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 02-16CPB1 FLD . FIELD: Prudhoe Bay Unit ~oC . LOCATION: 70 deg 16' 14.2"N 148 deg 28' S9.36"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375~~ CTK DATE. LOG DATE: 22 AUg 2007 API . API NUMBER: 500292044870 ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 36 . TOWN.N T11N . RANG. R13E . PDAT. MSL . EPD .F 0 . LMF . DF . FAPD.F 58.76 . DMF . DF . EKB .F O . EDF .F 58.76 . EGL .F O . page 1 ~escription Section Township Range Permanent Datum Elevation Of Perm. Datum ~og Measured from Feet Above Perm. Datum ~rilling Measured From Elevation of Kelly Bushing Elevation of ~errick Floor Elevation of ~round ~evel ~v~- _p~ ~- ~~ ~-~69 ~ ~ tapescan.txt CASE.F N/A . Casing Depth OS1 . DIRECTIONAL . Other Services Line 1 ~Remarks (1) All depths are Measured ~epths (MD) unless otherwise noted. (2) ,411 depths are Bit oepths unless otherwise noted. (3) All True vertical ~epths (TVDSS) are subsea corrected. (4) ,411 Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lo~ this well.. (6) Tools ran in the string included casing collar ~ocator, an Electrical ~isconnect and circulating sub, a orilling Performance sub (rnner and outer oownhole Pressure, vibration and ~ownhole weight on Bit), a ~irectional and Gamma sub, and a Hydraulic Orientin~ sub with a Near Bit Inclination sensor. (7) ~ata presented here is final and has been depth adjusted to a Primary ~epth Control (POC)log provided from 02-16C Mw~ data dated 22 Aug 2007 per poug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 02-166 through a milled window in a 3 1/2 inch liner. Top of window 11307 ft.MO (8856.6 ft.TVOSS) Bottom of window 11312 ft.M~ (8857.0 ft.TV~ss) (9) Tied to 02-16g at 11274 feet MD (8852.57 feet Tv~ss). (10) The interval from 12787 feet to 12809 feet MD (8836.0 feet to 8836.0 feet Tv~ss) was not logged due to sensor to bit offset at well T~. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP.~4VG -> Rate of Penetration, feet/hour -rv~ss -> True vertical ~epth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, 10925.6, 10926.6, 10941.5, 10942.1, 10944.4, 10945, 10950.2, 10949.6, 10958.1, 10957.9, 10961, 10960.8, 10967.8, 10967, 10975.3, 10974.9, 10985.6, 10985, 11005.9, 11004.7, 11026.4, 11025.4, 11034.1, 11031.8, 11048.4, 11047.4, 11057.5, 11054.2, 11064.8, 11063.5, 11075.4, 11073.9, 11083.9, 11083.4, 11102.3, 11101.5, 11104.2, 11103.3, 11108.7, 11108.5, 11118.3, 11118.3, 11121.2, 11121.6, 11130.9, 11129.9, 11137.1, 11136.3, 11141.9, 11141.3, 11143.7, 11143.1, 11146.4, 11145.4, 11147.5, 11146.6, 11154.3, 11153.9, 11166.1, 11164.7, 11167.8, 11167.6, 11177.7, 11178.4, DISPLACEMENT 1.03711 0.62207 0.62207 -0.621094 -0.207031 -0.208008 -0.830078 -0.414062 -0.62207 -1.24414 -1.03711 -2.28027 -1.03613 -3.31641 -1.24414 -1.45117 -0.414062 -0.829102 -0.829102 -0.208008 0.414062 -1.03711 -0.829102 -0.62207 -0.62207 -1.03613 -0.829102 -0.415039 -1.45117 -0.208008 0.621094 Page 2 ~ ~ 11183.1, 11182.3, 11205.2, 11204.8, 11209.1, 11210, 11214.1, 11213.9, 11217, 11217.4, 11223.4, 11224.9, 11231.7, 11231.1, 11237.3, 11235.9, 11240, 11238.2, 11247.1, 11244, 11253.7, 11253.7, 11256, 11256, 11259.7, 11259.5, 11265.5, 11266.5, 11270.7, 11271.5, 11275, 11275.9, 11282.9, 11281.9, 11285.8, 11285.6, 11296.3, 11295.9, 11298.6, 11300.2, 11302.5, 11302.3, 11303.3, 11304.6, 11311.6, 11311.6, 11314.7, 11314.9, 11340.9, 11340.9, 11353.3, 11352, 11356, 11354.8, 11360.1, 11359.7, 11364.1, 11363.4, 11370.5, 11370.7, 11376.3, 11376.9, 11398.9, 11399.7, 11403.9, 11404.3, 11409.2, 11408.4, 11427.9, 11426.4, 11434.9, 11433.9, 11438.4, 11436.7, 11442.5, 11442.1, 11454.9, 11452.7, 11458.8, 11456.7, 11462.9, 11461.5, 11470.8, 11469.8, 11482.8, 11481.9, 11495.4, 11495.6, 11501.8, 11502.4, 11509.4, 11510.2, 11516.5, 11515.9, 11525.4, 11523.5, 11540.6, 11538.5, 11548, 11545.6, 11554.7, 11552.8, 11562.3, 11560.4, 11568.7, 11567.9, 11572.2, 11571.6, 11575.8, 11575.1, 11581.2, 11581, 11582.4, 11582.8, 11584.5, 11584.5, 11601.5, 11601.5, 11606.2, 11606.4, 11608.5, 11608.5, 11619.9, 11619.3, 11632.8, 11632.1, i 0 tapescan.txt -0.829102 -0.415039 0.829102 -0.208008 0.415039 1.45117 -0.62207 -1.45117 -1.86523 -3.10938 0 -0.207031 1.03613 0.829102 0.829102 -1.03613 -0.207031 -0.414062 1.6582 -0.207031 1.24316 0 0.208008 0 -1.24414 -1.24316 -0.415039 -0.62207 0.207031 0.621094 0.829102 0.415039 -0.829102 -1.45117 -1.03613 -1.6582 -0.414062 -2.28027 -2.07324 -1.45117 -1.03613 -0.829102 0.207031 0.621094 0.829102 -0.62207 -1.86523 -2.07227 -2.4873 -1.86621 -1.86621 -0.829102 -0.621094 -0.62207 -0.207031 0.415039 0 0 0.207031 0 -0.621094 -0.62207 ~ Page 3 ~ ~ 11636.9, 11635.9, 11643.4, 11642.6, 11647, 11645.5, 11656.1, 11654, 11664.2, 11662.7, 11670, 11668.9, 11695, 11691.2, 11708.9, 11704.2, 11714.5, 11711.6, 11718.7, 11716.4, 11723.2, 11722.2, 11725.9, 11725.7, 11732.1, 11731.7, 11737.6, 11737.4, 11755.1, 11755.5, 11767.8, 11768.7, 11784.1, 11783.9, 11816.5, 11814.3, 11827.7, 11824.8, 11839.9, 11839.3, 11869.6, 11868.9, 11891.9, 11890.6, 11896.1, 11894.8, 11914, 11913.7, 11921.6, 11919.3, 11925.1, 11922.7, 11932.3, 11930, 11951.1, 11950.2, 11956.9, 11955.2, 11963.1, 11961.3, 11978, 11976.4, 12002.1, 12000.6, 12019.2, 12016.1, 12025.8, 12022.1, 12030.2, 12026, 12032, 12027.7, 12037.8, 12036, 12047.6, 12044.7, 12058.8, 12055.5, 12063.8, 12061.1, 12068.3, 12067.1, 12070.2, 12070.6, 12072.7, 12072, 12076.6, 12074.9, 12078.9, 12077.4, 12082.8, 12082.2, 12102.5, 12102.1, 12125.1, 12125.1, 12129.6, 12129.8, 12146.1, 12149.2, EOZ END ! BASE CURVE: GROH, Tape subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 tapescan.txt -1.03711 -0.829102 -1.4502 -2.07227 -1.45117 -1.03711 -3.73145 -4.76758 -2.90234 -2.28027 -1.03711 -0.207031 -0.414062 -0.207031 0.414062 0.829102 -0.207031 -2.28027 -2.90234 -0.62207 -0.62207 -1.24316 -1.24316 -0.207031 -2.28027 -2.4873 -2.28027 -0.829102 -1.6582 -1.86523 -1.6582 -1.45117 -3.10938 -3.73145 -4.14551 -4.35352 -1.86621 -2.90234 -3.31641 -2.69434 -1.24414 0.415039 -0.62207 -1.6582 -1.45117 -0.62207 -0.414062 0 0.207031 3.10938 OFFSET CURVE: GRAX 216 records... 10 bytes 132 bytes Page 4 ~ tapescan.txt 1024 ~ ~** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC)log provided from 02-16C Mw~ data dated 28 aug 2007 per ~oug Stoner with BP Exploration (,4laska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 ~atum Frame Size is: 12 bytes ~ogyin9 direction is down (value= 255) Optical Lo~ Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) ~atum specification elock sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 1 Size ~ength 4 4 4 4 8 Total oata rtecords: 46 Tape File start ~epth = 10916.000000 Tape File End Depth = 12812.000000 Tape File ~evel Spacing = 0.500000 Tape File ~epth units = feet **** FILE TRAILER **** Tape Subfile: 2 55 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 Page 5 ~ tapescan.txt 1024 ~ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field Mw~ data. * FORMAT RECORD (TYPE# 64) ~ata record type is: 0 Datum Frame Size is: 12 bytes ~og~ing direction is down (value= 255) optical ~og ~epth scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) ~atum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth z~: F 2 Curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total ~ata Records: 91 1 size ~ength 4 4 4 4 8 Tape File Start ~epth = 10915.000000 Tape File End Depth = 12808.750000 Tape File ~evel Spacing = 0.250000 Tape File ~epth units = feet **** FILE TRAILER **** Tape Subfile: 3 100 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/08/22 1506411 O1 Page 6 ~ tapescan.txt ~*** REEL TRAILER **** MWD 09/02/03 BHI Ol Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: ~IS DEPTH GR ROP 10916.0000 -999.2500 -999.2500 10916.5000 9.8000 -999.2500 11000.0000 24.3000 -999.2500 11100.0000 31.0301 -999.2500 11200.0000 44.9037 -999.2500 11300.0000 157.6608 -999.2500 11400.0000 80.8474 70.9168 11500.0000 138.5958 67.0324 11600.0000 67.1000 108.0000 11700.0000 64.7641 89.1447 11800.0000 56.1571 101.0964 11900.0000 39.6072 136.2520 12000.0000 47.8039 132.7197 12100.0000 57.3585 102.3772 12200.0000 44.0385 110.1936 12300.0000 174.8633 11.5707 12400.0000 133.0035 63.5994 12500.0000 136.9869 53.5184 12600.0000 181.2408 41.3410 12700.0000 83.4977 74.0799 12800.0000 -999.2500 78.1172 12812.0000 -999.2500 33.2738 Tape File Start ~epth = 10916.000000 Tape File End ~epth = 12812.000000 Tape File ~evel Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP 10915.0000 -999.2500 -999.2500 10915.2500 -999.2500 -999.2500 Page 7 ~ ~ ~ tapescan.txt 11000.0000 24.3000 -999.2500 11100.0000 33.2000 -999.2500 11200.0000 48.4000 -999.2500 11300.0000 133.8000 -999.2500 11400.0000 79.1000 70.6000 11500.0000 141.9000 41.7000 11600.0000 67.1000 108.0000 11700.0000 54.9000 93.0000 11800.0000 58.8000 101.2000 11900.0000 44.1000 134.1000 12000.0000 44.5000 160.4000 12100.0000 56.6000 104.4000 12200.0000 49.2000 113.8000 12300.0000 154.6000 78.7000 12400.0000 131.1000 68.6000 12500.0000 123.4000 50.7000 12600.0000 155.6000 69.7000 12700.0000 89.6000 99.2000 12800.0000 -999.2500 133.1000 12808.7500 -999.2500 162.5000 Tape File Start ~epth = 10915.000000 Tape File End Depth = 12808.750000 Tape File ~evel Spacing = 0.250000 Tape File oepth units = feet 0 Tape Subfile 4 is type: LIS Page 8