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205-110
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-91 MILNE PT UNIT F-91 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/11/2025 F-91 50-029-23271-00-00 205-110-0 W SPT 6371 2051100 1593 1239 1243 1240 1239 216 354 331 318 4YRTST P Adam Earl 10/24/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT F-91 Inspection Date: Tubing OA Packer Depth 340 1921 1873 1864IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE251025193050 BBL Pumped:2.3 BBL Returned:2.3 Thursday, December 11, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, November 1, 2021 ! � Jrl � � G�r.'Zl P.I. Supervisor 1� SUBJECT: Mechanical Integrity Tests Mlcorp Alaska, LLC F-91 FROM: Bob Noble MILNE PT UNIT F-91 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT F-91 API Well Number 50-029-23271-00-00 Inspector Name: Bob Noble Permit Number: 205-110-0 Inspection Date: 10/25/2021 Irisp Num: mitRCN2 11025170335 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F-91 Type Inj w "TVD 6371 Tubing 1572 1574 1575 1574 PTD 2051100 Type Test SPT Test psi 1593 IA 505 2025 1982 1973 " BBL Pumped: 22 BBL Returned: 22 OA 188 370 354 " 35T Interval 1 4YRTST P/F P Notes: Monday, November 1, 2021 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,October 25,2017 Jim Regg P.I.Supervisor 1<seo SUBJECT: Mechanical Integrity Tests ` �`?f HILCORP ALASKA LLC F-91 FROM: Jeff Jones MILNE PT UNIT F-91 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT F-91 API Well Number 50-029-23271-00-00 Inspector Name: Jeff Jones Permit Number: 205-110-0 Inspection Date: 10/21/2017 Insp Num: mitJJ171025084522 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ___-- F-91 Type Ill] W 'TVD 6371 Tubing 1755 . 1758 . 1756 1755 PTD 2051100 Type Test SPT Test psi 1593 - IA 423 2510 1 2474 - 2465 BBL Pumped: 3 BBL Returned: 3 OA 192 " I 436 - 423 419 Interval 4YRTST P/F P v Notes: 1 well inspected,no exceptions noted. SCANNED r Lb 2 0 ircj 1 Wednesday,October 25,2017 Page 1 of 1 STATE OF ALASKA AILKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair WellL Plug Perforations U Perforate U OtherLI Brightwater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wet] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ " 205 -110 -0 3. Address: P.O. Box 196612 StratigraphiC Service El 6. API Number: Anchorage, AK 99519 -6612 5(- 029 - 23271 -00 -00 7. Property Designation ease Number): . 9 8. Well Name and Number: _ 01 ADL0355018 38g2,35 to 1,4 KUP MPF -91 9. Logs (List logs and submit ele ronic and printed data per 20AAC25.071): 10. Field/Pool(s): _ To Be Submitted MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 13045 feet Plugs measured None feet true vertical 7329.21 feet Junk measured None feet Effective Depth measured 13002 feet Packer measured See Attachment feet true vertical 7298.67 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20" 94# H-40 35 - 114 -10.51 - 114 1530 520 Surface 7059 10 -3/4" 45.5# L -80 34 - 7093 -11.51 - 4551.59 5210 2480 Intermediate None None None None None None Production 12146 7 -5/8" 29.7# L -80 33 - 12179 -12.51 - 6734.37 6890 .. I V E D Liner None None None None None " None OCT 042012 Perforation depth Measured depth 12706 - 12718 feet 12726 - 12747 feet 12756 - 12810 feet /f ®® ��a,� °' True Vertical depth 7091.4 - 7099.81 feet 7105.42 - 7120.18 feet 7126.52 - 7164.18 feet G `* Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 32 - 11529 -13.51 - 6386.08 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None Norte None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 3 2013, 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: _ Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG el GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact Nita Summerhays Email Nita.Summerhayst BP.com Printed Name Ni - Summerh- s Title Petrotechnical Data Technician �,irr Signatilr Phone 564-4035 Date 10/4/2012 7.e !a' 7 1 Z RBDMS OCT 0 8 2011( x' 3R1GINAL ..e° (0j�� Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0355018 g., `. SUMMARY • = • I I 1 .1 emp =' o :rig a er * eservoir weep o• Standby, Well injecting at to high of a pressure to pump. 8/29/2012 ** *Continue to next WSR * ** T /1/0 = 2001/200/150 ** *Continued WSR from 08 -29- 2012 * ** Temp =Hot ( Brghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 92 gal. EC9360A (Surfactant) Average of 8.36 gph for 24 hrs. Pumped a total of 92 gal. since start of project. Pumped 528 gal. EC9398A ( Polymer) Average of 48 gph for 24 hrs. Pumped a total of 528 gal. since start of project 8/30/2012 ** *Continued on WSR 08/31/2012 * ** [1110 = 2045/150/200 Onfinued - WSR from 08 -30- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 261 gal. EC9360A (Surfactant) Average of 10.875 gph for 24 hrs. Pumped a total of 353 gal. since start of project. Pumped 1188 gal. EC9398A ( Polymer) Average of 49.5 gph for 24 hrs. Pumped a total of 1716 gal. since start of project 8/31/2012 ** *Continued on WSR 09/01/2012 * ** Ill /O = 2113/150/200 ***Continued WSR from 08 -31- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 260 gal. EC9360A (Surfactant) Average of 10.8 gph for 24 hrs. Pumped a total of 613 gal. since start of project. Pumped 1108 gal. EC9398A ( Polymer) Average of 46.16 gph for 24 hrs. Pumped a total of 2824 gal. since start of project 9/1/2012 ** *Continued on WSR 09/02/2012 * ** T /1 /0 = 2135 /150 /200 ***Continued WSR from 09- 01- 2012* ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 240 gal. EC9360A (Surfactant) Average of 10 gph for 24 hrs. Pumped a total of 853 gal. since start of project. Pumped 1276 gal. EC9398A ( Polymer) Average of 53.2 gph for 24 hrs. Pumped a total of 4100 gal. since start of project 9/2/2012 ** *Continued on WSR 09/03/2012 * ** T /1/0 = 2142/150/200 * * *Continued from 09 -02- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 242 gal. EC9360A (Surfactant) Average of 10.08 gph for 24 hrs. Pumped a total of 1095 gal. since start of project. Pumped 1216 gal. EC9398A ( Polymer) Average of 50.6 gph for 24 hrs. Pumped a total of 5316 gal. since start of project 9/3/2012 ** *Continued on WSR 09/04/2012 * ** • Daily Report of Well Operations ADL0355018 T /I /O = 1258/150/200 * * *ConninuedWSR from 09 -03- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Pumped 272 gal. EC9360A (Surfactant) Average of 11.3 gph for 24 hrs. Pumped a total of 1367 gal. since start of project. Pumped 1213 gal. EC9398A ( Polymer) Average of 50.5 gph for 24 hrs. Pumped a total of 6529 gal. since start of project ** *Continued on WSR 09/05/2012 * ** 9/4/2012 T /1 /0 = 2027/150/200 * * *Confinued WSR from 09 -04- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2000 bwpd. Reduced injection rate to 1500 bwpd at 1400 hrs. Pumped 218 gal. EC9360A (Surfactant) Average of 9 gph for 24 hrs. Pumped a total of 1585 gal. since start of project. Pumped 1143 gal. EC9398A ( Polymer) Average of 47 gph for 24 hrs. Pumped a total of 7672 gal. since start of project. 9/5/2012 ** *Continued on WSR 09 -06- 2012 * ** T /1 /0 = 1989/150/200 * ** Continued WSR from 09 -05- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 1500 bwpd. Pumped 232 gal. EC9360A (Surfactant) Average of 9.6 gph for 24 hrs. Pumped a total of 1817 gal. since start of project. Pumped 968 gal. EC9398A ( Polymer) Average of 40.3 gph for 24 hrs. Pumped a total of 8640 gal. since start of project. 9/6/2012 ** *Continued on WSR 09 -07- 2012 * ** 171/0 = 1992/150/190 ** *Continued WSR from 09 -06- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 1500 bwpd. Pumped 227 gal. EC9360A (Surfactant) Average of 9.4 gph for 24 hrs. Pumped a total of 2044 gal. since start of project. Pumped 957 gal. EC9398A ( Polymer) Average of 39.8 gph for 24 hrs. Pumped a total of 9597 gal. since start of project. 9/7/2012 ** *Continued on WSR 09 -08- 2012 * ** T /1 /0 = 1995/150/190 ***Continued WSR from 09 -07- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 1500 bwpd. Pumped 197 gal. EC9360A (Surfactant) Average of 8.2 gph for 24 hrs. Pumped a total of 2241 gal. since start of project. Pumped 963 gal. EC9398A ( Polymer) Average of 40.1 gph for 24 hrs. Pumped a total of 10560 gal. since start of project 9/8/2012 ** *Continued on WSR 09 -09- 2012 * ** • • Daily Report of Well Operations ADL0355018 T /I /O = 2000/150/190 ** *Continued WSR from 09- 08- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 1500 bwpd. Pumped 208 gal. EC9360A (Surfactant) Average of 8.6 gph for 24 hrs. Pumped a total of 2449 gal. since start of project. Pumped 853 gal. EC9398A ( Polymer) Average of 35.5 gph for 24 hrs. Pumped a total of 11413 gal. since start of project. 9/9/2012 ** *Continued on WSR 09 -10- 2012 * ** 171/0 = 2000/150/190 * * *(;onfinuedWSR from 09 -09- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 1500 bwpd. Pumped 229 gal. EC9360A (Surfactant) Average of 9.5 gph for 24 hrs. Pumped a total of 2678 gal. since start of project. Pumped 887 gal. EC9398A ( Polymer) Average of 36.9 gph for 24 hrs. Pumped a total of 12300 gal. since start of project. 9/10/2012 ** *Continued on WSR 09 -11- 2012 * ** T /I /O = 2005/150/190 ** *Continued WSR from 09 -10- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 1500 bwpd. Pumped 191 gal. EC9360A (Surfactant) Average of 7.9 gph for 24 hrs. Pumped a total of 2869 gal. since start of project. Pumped 701 gal. EC9398A ( Polymer) Average of 41 gph for 24 hrs. Pumped a total of 13001 gal. since start of project. Job Completed, Rig down in Progress 9/11/2012 FWHP = 2020/150/190 SV= CLOSED SSV, WV, MV =OPEN IA,OA =OTG FLUIDS PUMPED BBLS 2 DIESEL 2 METH 4 TOTAL FLUIDS PUMPED GALS 2869 EC -9360A SURFACTANT 13001 EC -9398A POLYMER 15870 TOTAL . • Perforation Attachment ADL0355018 SW Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base TVD Depth Top ND Depth Base MPF -91 11/6/2008 APF _ 12706 12718 7091.4 7099.81 MPF -91 11/6/2008 APF 12726 12747 7105.42 7120.18 MPF -91 10/29/2005 PER 12756 12810 7126.52 7164.18 BPS OH OPEN HOLE BRIDGE PLUG SET FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0355018 SW Name Type MD TVD Depscription MPF -91 PACKER 11371 6276.19 4 -1/2" Baker S -3 Perm Packer MPF -91 PACKER 11492 6325.33 4 -1/2" Baker S -3 Perm Packer MPF -91 PACKER 12033 6591.08 5 -1/2" BAKER ZXP PACKER Tree: 4 1/16" - 5M FM* M P U F -91 i OrB. elev. = 45.18' (Doyon -14 Wellhead:11" 5M FMC Gen. 5 Orig. GL. elev.= 11.5' w/ 11" x 4.5" FMC Tbg. Hng. w/ Orig. DF. elev. = 33.68' (Doyon -14) 4.5" TC -II & 4" CIW "H" BPV profile 20" 91.1 ppf, H 114' Well required to have a SSSV installed. 10.75 Howco "ES Cementer" @ 2,517' MCX I 4.5' HES X- Nipple (3.813 ") 2,992' I 10.75 ", 45.5 ppf, L -80 BTC 7,093' me surface casing KOP O @ 350' Max. hole angle = 60 to 68 deg. f/ 3,500' to 11,780' Hole angle through perfs. = 45 deg. 7 -5/8" 29.7 ppf, L -80, Btc -Mod csg. ( Drift ID = 6.875 ", Cap. = 0.0459 bpf) 4.5' HES X - Nipple (3.813 ") 1 11,309' 4.5 ", 12.6 #,L - TC -II tubing ( Drift ID = 3.958" , Cap. = .0152 bpf) 1r=ii 7 -5/8 "x 4.5" Baker S -3 Perm. Pkr. \ J I 11,371' 4.5' HES X - Nipple ( 3.813 ") I 11,458' 6.40" od. Unique Overshot 5' long I 11,479' I Btm. 4' off packer 7 -5/8 "x 4.5" Baker S -3 Perm. Pkr. 11,492' 4.5' HES XN - Nipple ( 3.725 No -Go ") 1 11,516' WLEG / W/NoGo I 11,529' 12,093' — 7 -5/8 x 5.5" Baker Tie Back Sly. 12,022' Weatherford 7-5/8" float collar I 7 -5/8 x 5.5" Baker ZXP liner Pkr. 12,033' Weatherford 7 -5/8" casing shoe' 12,179' A - • 7 -5/8 x 5.5" Baker HMC liner Hng. 12,039' Perforation Summary Ref log: sws scMr 10/18/05 Size SPF Interval (TVD) 2.5" 6 12706' - 12718' 7091' - 7100' 2.5" 6 12726' - 12747' 7105' - 7120' 2.5" 6 12756' - 12810' 7127' - 7164' Baker 4.5" Landing Collar 12,960' HES 4.5" Float Collar 13,002' HES 4.5" Casing shoe 13,045' 2.5" HSD 2506 PJ HMX 6 SPF GR -CCL, 10/29/05 DATE REV. BY COMMENTS MILNE POINT UNIT 09/30/05 MDO Drilled and Cased by Doyon - 14 WELL F API NO: 50 -029- 23271 -00 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 SLANNEV) FI`"F ', "'LUI Mr. Tom Maunder Alaska Oil and Gas Conservation Commission J 11° 333 West 7 Avenue �0 Anchorage, Alaska 99501 I Subject: Corrosion Inhibitor Treatments of MPF -Pad �n Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad 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) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft nal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF -06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 WA 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top lob MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 WA 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 WA 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 N/A 12 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 ----›► MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 • MEMORANDUM To: Jim Regg ~ ~ ~ 1((3i,~f U`~ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 18, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-91 MILNE PT lJNIT KR F-91 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: MILNE PT UNIT KR F-91 Insp Num: mitLG091107043755 Rel Insp Num: API Well Number: 50-029-23271-00-00 Permit Number: 205-110-0 Inspector Name: Lou Grimaldi Inspection Date: 11/6/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. VVell F-91 ~Typelnj W'~ TVD -j ---- ---- - I b322 '~ IA ~ - -- -- 90 2300 226 2255 --- -~ - -- ± ~ P.T.Di 2051100 iTypeTest SP~est pSl ~ ~580 .i OA i 450 19~ i 440 ~ 430 _ 4YRTST P Interval -------- P/F - ----- TUbin ~ -------g ~ 1800 i 1800 ----! ----- ~- 1800 ~ 1800 -------! -------!--- ~---- NOtes: 3.3 Bbl's pumped. Good test. ~~~ ~ Wednesday, November 18, 2009 Page 1 of 1 2°t ~4~.~ao? DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051100 Well Name/No. MILNE PT UNIT KR F-91 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23271-00-00 MD 13045 TVD 7329 Completion Date 10/29/2005 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR/CASANDRA, PWD, RES, GYRO (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log! Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~O D Asc Directional Survey 0 13045 Open 9/26/2005 IIFR t~D D Asc Directional Survey 0 13045 Open 9/26/2005 MWD D Lis 13333 Induction/Resistivity 171 13004 Open 10/26/2005 GR EWR4 PWD GP Log Cement Evaluation 5 Blu 1 11250 12960 Case 11/21/2005 Slim Cement Mapping Tool Primary Depth Control Log ~ 18-Oct-2005 ~'~D C Lis 13368 Gamma Ray 11226 12972 Case 11/21/2005 GR CCL + PDS Graphics ~D C Pdf 13893 Rate of Penetration 1-4 114 13045 Case 5/10/2006 ROP DGR EWR 22-Aug- 2005 ~D C Pdf 13893 Induction/Resistivity 1-4 114 7329 Case 5/10/2006 DGR EWR 22-Aug-2005 C Lis 13893 InductionlResistivity 171 13011 5/10/2006 GR, ROP ,.ED: ~C Las 14524 Induction/Resistivity 12453 12927 Open 3/22/2007 LAS Warmback Temperature 2 Blu 1 11911 12941 Case 6/11/2007 Mem Temp Survey, LEE CCL, GR, Pres, Temp 9- Mar-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051100 Well Name/No. MILNE PT UNIT KR F-91 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23271-00-00 MD 13045 ND 7329 Completion Date 10129/2005 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? N V Chips Received? Y~T~N-- Formation Tops ~/ N Analysis ~`t#- Received? Comments: Compliance Reviewed By: Date: ,~ Sehlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I( ~, I~~~ ~fl 1 t I _ ~ t~;,;,~~ n~~ I~..9 `ii .{i ~Ull~ `~h~' ~~a ('~JEftlYll~~6t~!~ i ,.,, new ..~~,. NO.4290 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~*e Ri rr.tnr rn 06/07/07 LS-23 11733320 PRODUCTION PROFILE 04/30107 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04129!07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-08A 11686747 LDL 05120/07 1 G-05 11773110 LDL 05113107 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05!08107 1 V-03 11628770 MEM LDL 04/30107 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08107 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE 05122/07 1 04-10 11594498 LDL 05/19107 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02107 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A NIA LDL 05109/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04130/07 1 P1-16 11594494 INJECTION PROFILE 05!01107 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EAGFt TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Date Delivered: UZC ~p~j ~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~'•~ ~ ~ Uf,o~LL LOG ~-~ Tl4~4/~~lt/I/~1'~4L ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hale/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper / MTTJ The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 S Fax: (907j 245-8952 1 ] EDE Disk MPF - 91 i Warmback Passes 2) 3) 4J 5J r..J TL-~US -l l C~ ~ i ~-(5~`~ 6J 7J 9 /' /~ Signed : -- Print Name: CI _U r ; ~ ~-i I,t ~ ~,-,, ~~~ :,~ l.C ~ ~,, 1 O-Mar-07 - ~ ~~: m ~ ~ ~~ Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL : PDSt~~ICWORAGE(Q~MEE~®RYS °'4.G.COM WEBSITE : W!ItfW.ilflEMORYLOG.i.OM D:\Ivfastei_Copy_00_PDSANC-20~a\Z_Word\Distribution\TransmittaL_Sheets\Tiaru~mit_Onginal.doc ~ 3~s93 ao5 =rra WELL LOG TRANSMITTAL To: State of Alaska April 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-91, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPF-91: LAS Data & Digital Log Images: 50-029-23271-00 ~'rrs~o~ C_XJV_ t3~R3 gas =rr6 1 CD Rom ` ~~~~~E~ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COM~ION MAR 2 4 Z006WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & has Cons. Commission Revision: 03/24/06, Start Injection ia. Well Statu Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 2oAAC 2s.+os 2aAAC 2s.i~o ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/29/2005 12. Permit to Drill Number 205-110 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/22/2005 13. API Number 50-029-23271-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/5/2005 14. Well Name and Number: MPF-91i 2211 FSL, 2853 FEL, SEC. 06, T13N, R10E, UM ~ Top of Productive Horizon: 2739' FSL, 108' FEL, SEC. 35, T14N, R09E, UM S. KB Elevation (ft): 45.51 15. Field /Pool(s): Milne Point Unit / Kuparuk River Sands Tatal Depth: 2861' FSL, 283' FEL, SEC. 35, T14N, R09E, UM 9. Plug Back Depth (MD+TVD) 13002 + 7299 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541708. y- 6035662 ~ Zone- ASP4 10. Total Depth (MD+TVD) ~ 13045 + 7329 ~ Ft 16. Property Designation: ADL 355018' TPI: x- 533984 y- 6041430 Zone- ASP4 Total Depth: x- 533809 Y- 6041551 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: ~`----------"- -----~----- -""-------"---- 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: MWD , GR , IFR/CASANDRA , PWD , RES , GYRO 2. ASING, LINER AND EMENTING RECORD CASI-a~ No PT}- MD eTrn~ PrH Tvo Hp~ uNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 7093' 35' 4552' 13-1 /2" 79 sx AS Lite, 442 sx Class 'G' 7-518" 29.7# L-80 33' 12179' 33' 6734' 9-7/8" 15 sx Class 'G' 4-1/2" 9.2# L-80 12022' 13045' 6630' 7329' 6-3/4" 165 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24, TUBING REEORQ Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 4-1/2", 12.6#, L-80 11529' 11371' & 11492' MD TVD MD TVD 12756' - 12810' 7127 - 7164' 25. ` ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 104 Bbls Hot Oil 26. PRODUCTION TEST Date First Production: November 2, 2005 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None @, ..... ~@C~ii , ~ , Lif k, ~~•~ °~ 2~~6 ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~~ r 28. GEOLOGIC MARKERS 29' . ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". THRZ 11991' 6611' None BHRZ 12124' 6696' KLG M 12240' 6778' TKUD 12462' 6930' TKUA 12692' 7082' TKA3 12703' 7089' TKA2 12722' 7103' TKA1 12752' 7124' TMLV 12834' 7181' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si ned g Sondra ewman Title Technical Assistant Date l "~ y-(~ MPF-911 205-110 Prepared ByName/Number.• Sondra Stewman, 564-4750 Well Number Permit No. / A fOVal NO. Dril-ing Engineer: Skip Coyner 564-4395 INSTRUCTIONS GeNERa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. heM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-ln, or Other (explain). IreM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only r~C:3ANICAL INTEGRITY RPORT - BUD u--=-= " ~I3>'o~ OPER ~ FIELD ~+P ~~`t~ ~c5~c~~ -~G r~~I~:.C. - ~IS_O`~ i,~LL Nut~ER ~`'~,P~-'~~ ,,,~ LL DATr_ TD : ~~j©y~~.. ~`(~'I'VD ; PBTD : 1~?•ID ~~TVD Casi^g: '1~~~r Shoe: ~2l'1~ MD ~v~,3y"TVD; LV: ~~ ?~ ~~ T4`i ..:,e.: ~/ Shoe : 130~-5 '~ r(~~ T`TD ; I'CP : I~ba~?•t.D ~~~C,1 ~";D -•`ID'- v ~1I~.-P2CKE'.~ 1~3 11 ~ TV1~ Cet c~ 1~sa~ ole S_~e ~~~~- and ~~L~~, Perks \~~-~ _ to ~a~~~ ~- _-'~= C'r'.~?~ _r~y INTEGRITY _ a a..RT # ~ rnnuius Press Test• ~~ 15 rain ~0 min Cor,:~ents '-'~'CHpNICr1, INTEGRTTY - PART #Z ~----~3ybb~5~(05 bh~s Cement Volumes :~ Amt. Liner ~(~SS CsQ 315gy DV ~~ • recaQcocc,~ V c~a~c C~,t Jol to convey o(e(r~=s 1 ^/~\~~,,T-` ~;p ~~ \1 `7~['~ l~C\ ~lC «r } `,~ ~ J T1 ~l\ S C . ~..~T~~ IRA R- Jle~. r M.~e1 _ _~eoretical TCC ~ ~Zo~, S Cement Bond Log (Yes or No)~~_; In AOGCC File CBL Evaluation, gone above perfs C~~. - Producti-an Log: Tp~e CONCLJS ~ Ot~S Part #1: Part T 2 : M,~,.., S , Evaluation -~ ~Stx~ ~ -~, ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMNI~"310N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 4~~ V ~~ ~,~~~~~ ~~~ ~>IIs Cnns. GotnrrNSSion Anfhorage ia. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/29!2005 i 12. Permit to Drill Number 205-110 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612. 6. Date Spudded 8/22/2005, 13. API Number 50- 029-23271-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/5/2005 ~ 14. Well Name and Number: MPF-91 i 2211 FSL, 2853 FEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 2739' FSL, 108' FEL, SEC. 35, T14N, R09E, UM g, KB Elevation (ft): 45.51 15. Field /Pool(s): Milne Point Unit / Kuparuk River Sands Total Depth: 2861' FSL, 283' FEL, SEC. 35, T14N, R09E, UM 9. Plug Back Depth (MD+TVD) 13002 + 7299 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541708 4` y- 6035662 ° Zone- ASP4 10. Total Depth (MD+TVD) .13045 + 7329 ~ Ft 16. Property Designation: ADL 355018 TPI: x-_ 533984 y- 6041430_ Zone- ASP4 Total Depth: x- 533809 ~ Y- 6041551 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: " ~--""- ----~~--~-._"""----- ---~"~""""---- f f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness o Perma rost 1800' (Approx.) 21. Logs Run: MWD , GR , IFR/CASANDRA , PWD , RES , GYRO 2. CASING, LINER AND CEMENTING ECORD CASING ETTING EPTH MD ETTINO EPTH ND OLE MOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM ~IZE CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 7093' 35' 4552' 13-1/2" 79 sx AS Lite, 442 sx Class 'G' 7-5/8" 29.7# L-80 33' 12179' 33' 6734' 9-7/8" 315 sx Class 'G' 4-1/2" 9.2# L-80 12022' 13045' 6630' 7329' 6-3/4" 165 sx Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING. RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 5PF 4-1/2", 12.6#, L-80 11529' 11371' 8~ 11492' MD TVD MD TVD 12756' - 12810' 7127 - 7164' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protected with 104 Bbls Hot Oil 26• PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". - - - None S ~F~ Ntl~ ;? 9 200 ~ ~ ~ ~: ~~; ,:-r~ Form 10-407 Revised 12/2003 £} CONTINUED ON REVERSE SIDE r~ 28.. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD ND and attach detailed supporting data as necessary. If no tests were conducted, state "None". THRZ 11991' 6611' None BHRZ 12124' 6696' KLGM 12240' 6778' TKUD 12462' 6930' TKUA 12692' 7082' TKA3 12703' 7089' TKA2 12722' 7103' TKA1 12752' 7124' TMLV 12834' 7181' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, a Well Servicre Report and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. II ~~ Signed Son a Stewma Title Technical Assistant Date i - ~ ~ ~ V MPF-9i i 205-110 Prepared ey NamelNumber: Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Skip Coyner, 564-4395 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 18: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: 4 1/16" - 5M FMC Wellhead: 11" 5M FMC 5 w/ 11" x 4.5" FMC Tbg. Hng. w/ 4.5" TC-II & 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 114' ~ 10.75 Howco "ES Cementer" @ 2,5' 110.75", 45.5 ppf, L-80 BTC 7,093' m surface casing KOP @ 350' Max. hole angle = 60 to 68 deg. f/ 3,500' to 11,780` Hole angle through perfs. = 45 de. Ori. elev. = 45.18' (Doyon-1 Ori .elev.= 11.5' Orig. DF. elev. = 33.68` (Doyon-14) 5' HES X-Nipple (3.813") 2,992` 7-5/8" 29.7 ppf, L-80, Btc-Mod csg. ( Drift ID = 6.875", Cap. = 0.0459 b IES X -Nipple (3.813") 11,309' 4.5", 12.6#,L-80 TC-II tubing ( Drift ID = 3.958" ,Cap. _ .0152 bpi x 4.5" Baker S-3 Perm. Pkr. 11,371' iES X -Nipple (3.813") 11,458` od. Unique Overshot 5' long 11,479' Btm. 4' off packer x 4.5" Baker S-3 Perm. Pkr. 11,492' IES XN -Nipple (3.725 No-Go") 11,516` WLEG / W/NoGo 11,529' Weatherford 7-5/8" float collar 12,0' Weatherford 7-5/8" casing shoe 12,1 Perforation Summary Ref log: sws scnnT 1o/laios i/8 x 5.5" Baker Tie Back Slv. 12,022' i/8 x 5.5" Baker ZXP liner Pkr. 12,033' i!8 x 5.5" Baker HMC liner Hng. 12,039' Size SPF Interval (T~ 2.5" 6 12756' - 12810' 7127' - 4.5" Landing Collar 12,960` ,5" Float Collar 13,002` 2.5'° HSD 2506 PJ HMX 6 SPF GR-CCL, 10/29/05 .5" Casing shoe 13,045` DATE REV. BY COMMENTS 09/30/05 MDO Drilled and Cased by Doyon - 14 MILNE POINT UNIT WELL F-91 i API NO: 50-029-23271-00 M P U F-91 i .7 BP EXPLORATION Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Start: 8/21/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 9/21/2005 Rig Name: DOYON 14 Rig Number: Date ', From - To Hours ~, Task Code NPT '~ Phase 8/21/2005 18:00 - 19:00 1.00 MOB P PRE 19:00 - 20:00 1.00 MOB P PRE 20:00 - 21:00 1.00 MOB P PRE 21:00 - 23:00 2.00 MOB P PRE 23;00 - 00:00 i 1.00 ~ RIGU P PRE 8/22/2005 ~ 00:00 - 02:00 2.00! RIGU P PRE 02:00 - 03:00 ~ 1.00 ~ DRILL ~ P ~ ~ SURF 03:00 - 08:00 5.00 DRILL P SURF 08:00 - 09:00 1.00 DRILL P SURF 09:00 - 10:30 1.50, DRILL P SURF 10:30 - 11:00 0.50 DRILL P SURF 11:00 - 11:30 0.501 DRILL P SURF 11:30 - 12:00 0.50 DRILL P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30 - 14:00 1.50 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 00:00 9.50 DRILL P SURF 8/23/2005 00:00 - 13:00 13.00 DRILL P SURF 13:00 - 14:00 1.00 DRILL P SURF 14:00 - 15:30 1.50 DRILL P SURF 15:30 - 16:30 1.00 DRILL P SURF 16:30 - 17:30 1.00 DRILL P SURF 17:30 - 00:00 6.50 DRILL P SURF 8/24/2005 ~ 00:00 - 06:00 ~ 6.00 ~ DRILL ~ P ~ ~ SURF 06:00 - 07:30 1.50 DRILL P SURF 07:30 - 10:00 2.50 DRILL P SURF 10:00 - 12:00 2.00 DRILL P SURF 12:00 - 14:30 2.50 DRILL P SURF 14:30 - 15:30 1.00 DRILL P SURF 15:30 - 17:30 2.00 DRILL P SURF 17:30 - 00:00 6.50 DRILL P SURF 8/25/2005 00:00 - 16:00 16.00 DRILL P SURF 16:00 - 17:00 1.00 DRILL P SURF 17:00 - 00:00 7.00 DRILL P SURF 00:00 - 09:30 f 9.501 DRILL I P I I SURF 09:30 - 11:30 2.00 CASE P SURF 11:30 - 15:00 3.50 CASE P SURF 15:00 - 16:00 1.00 CASE P SURF 16:00 - 20:00 4.00 CASE P SURF 20:00 - 00:00 4.00 CASE P SURF 8/27/2005 00:00 - 01:00 1.00 CASE P SURF Page 1 of 10 Spud Date: 8/22/2005 End: Description of Operations PJSM, Skid rig floor. move off MPF-89 PJSM, Pickup and move mats to MPF-91 PJSM, Spot rig over MPF-91 PJSM, Skid rig floor, hook up service lines,air,steam,h2o, spot rock washer PJSM, Nipple up, Drilling Nipple, Rig accept @ 23:00 hrs 8/21 /2005 PJSM, Nipple up riser and flow lines, Pre-spud derrick inspection PJSM, Prep. Drill pipe handling equipment, from 4.5 to 5", load pipe shed with pipe and strap same. PJSM, Picking up Drill pipe 1x1, standing in derrick PJSM, Pickup HWDP and stand in derrick PJSM, Mobilize BHA, pickup bit, motor, float,stab. X-over, prep for drill out ice plug Pre-Spud meeting with crew Evacuate rig due to unexplained gas smell on rig floor, Check well houses on location for leaks Spud well, drill out ice plug, drill 112 to 221' ~" POH P/U Dm,Tm hang off subs,UBHO, orient same, P/U flex do RIH to 221, run Gyro Drill 221 to 820' with 380 gpm, 1000 psi, 80 rpms, Run Gyros to 820', AST 4.27, ART 1.73, ADT 6, TO 4K Drill 820' to 2319' with 600 gpm, 2200 psi, 80 rpms Circ. two bottoms up with 600 gpm, 2020 psi, 80 rpms Pump out to HWDP with full drilling rate Circ. out clay balls, unplug flow line to rockwasher Rih wash fast stand to bottom. Drill 2319' to 3069' with 600 gpm, 2200 psi, 80 rpms AST 6.19 ART 5.81, ADT 12, Tq 6K Drill 3069' to 3729' with 600 gpm, 2200 psi, 80 rpms ,AST 2.67, ART 1.45, ADT 4.12 Circ, Two bottom up with 600 gpm, 2200 psi, 80 rpms Pump out to HWDP with full drilling rate Stand back BHA, lay down MWD Pickup BHA #3, Upload MWD, suface test MWD Slip and cut drilling line, service topdrive RIH, wash last stand to bottom Drill 3729' to 4488' with 600 gpm, 2400 psi, 100 rpms AST 1.43, ART 2.9, ADT 4.33, TQ 10K Drill 4488' to 6081' with 650 gpm, 2900 psi, 100 rpms Replace Swivel packing Drill 6081' to 6550' with 650 gpm, 3150 psi, 100 rpms, AST 3.62, ART 12.5, ADT 15.4, Tq 13K Dril! 6550' to 7104' with 650 gpm, 3150 psi, 100 rpms, AST .94, ART 5.98, ADT 6.38 Circ, two bottoms up with 680 gpm., 3100 psi, 100 rpms Pump out to 3400' with full drilling rate, no problems Rih, wash last stand to bottom Circ, three bottoms up with 680 gpm, 3100 psi, 100 rpms Pump out to 1003', with full drilling rate, Pumping out to HWDP, With full drilling rate, Standing back Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ', ' From - To ' Hours ~ Task ~ Code' NPT - - 8/27l2005 - 00:00 - 01:00 1.00 _- CASE - P 01:00 - 02:00 1.00 CASE P 02:00 - 04:00 2.00 CASE P 04:00 - 13:00 9.00 CASE P 13:00 - 13:30 13:30 - 16:00 0.50 CASE P 2.50 CASE P 16:00 - 20:30 20:30 - 22:30 22:30 - 00:00 8/28/2005 ~ 00:00 - 01:30 01:30 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 14:00 4.501 CEMT I P 2.00 CEMT P 1.50 CEMT P 1.50 CEMT P 2.00 CASE P 1.50 CASE P 1.00 CASE P 3.00 CASE P 1.50 CASE P 3.50 CASE P Start: 8/21 /2005 Rig Release: 9/21/2005 Rig Number: Phase SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF 14:00 - 15:00 1.00 CASE P SURF 15:00 - 16:00 1.00 CASE P SURF 16:00 - 18:00 2.00 CASE P SURF 18:00 - 19:30 1.50 CEMT P SURF 19:30 - 22:00 2.50 CASE P SURF 22:00 - 23:30 1.50 CASE P SURF 23:30 - 00:00 0.50 CASE P SURF 8/29/2005 00:00 - 01:00 1.00 CASE P SURF 01:00 - 01:30 0.50 CASE P SURF 01:30 - 02:00 0.50 CASE P SURF Page 2 of 10 Spud Date: 8/22/2005 End: Description of Operations HWDP Laying down BHA Clear floor, Rig up to pickup 10 3/4 csg, PJSM Picking up 165 jts 10 3/4 45.5# L-80 btc csg, shoe 7092, float 7048, landing collar 7005,cementer 2517 Lay down franks tool, rig up cement head Circ with 2 to 7.5 bbls min 350 psi, reduce mud to 65 vis, 23 yield point, 9.4, PJSM Cement with Schlumberger stage #1, with 10 bbls water, test lines 3500 psi, 20 bbls CW 100, 50 bbls mud push mixed @ 10.1, drop bottom plug 348 sxs Artic set light, yield 4.44, 275 bbls mixed C~3 10.7, tail with 240 sxs Class G yield 1.17, 49.8 bbls mixed @ 15.8, drop top plug, kicked out with 30 bbls water, displace with 401 bbls mud, 50 bbls water, 193 bbls mud, bump plug with 1900 psi, float held, job was mixed and displace with 7.5 bbls min., full returns thru out job Load head with closing plug, pressure up to 2510 psi on csg, cementer open, Circ. 7 bbls min, 150 psi to condition hole for stage #2, PJSM Cement with Schlumberger Stage #2, with 20 bbls CW100, with 2 gals dye, 50 bbls mud push mixed ~ 10.1, 431 sxs Arctic set light 340 bbls yield 4.44 mixed @ 10.7, tail 202 sxs Class G 1.17 yield 42.1 bbls mixed @ 15.8, drop closing plug, Kicked out with 30 bbls water., mixed and pumped 7 bbls min., fu11 returns Displace with rig, 212 bbls mud, 7 bbls min. 700 psi, bump closing plug with 1250 psi, shut down bled off pressure, cementer closed, 230 bbls good cement to surface, full returns thru out job. R/d cement equipment, Flush stack, flow lines, lay down landing jt. Nipple down, Drilling nipple Nipple up FMC Gen 5 head, test metal to metal seals 1000 psi for 10 min. Nipple up BOPS Rig up to test Bops, Mobilize 4 and 5" handling eguipment to floor Test Bops and manifold to 250-4000 psi ,for 5 min per test, Hydrill 250-2500 psi 5 min per test, the right to witness test was wavier by Jeff Jones AOGCC, install wear ring, test was witness by WSL Mobilize Bha, Change out bales Pickup clean out Bha #3 Picking up 4' pipe out of shed to 2517 Drill ES cementer@ 2517, wash and ream to 2657', 60 rpms, 10K bit wt 420 gpm, 550 psi Picking up 4" pipe to 4867' Change out handing equipment, Picking up 5" pipe 4867 to 6552' Slip and cut drilling line, service topdrive Finish cut and slip drill line, service top drive Rih to 7000' Circ. Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Page 3 of 10 ~ Operations Summary Report Legal Well Name: MPF-91 Common W ell Name: MPF-91 Spud Date: 8/22/2005 Event Nam e: DRILL+C OMPLE TE Start : 8/21/2005 End: Contractor Name: DOYON DRILLIN G fNC . Rig Release: 9/21/2005 Rig Name: DOYON 14 Rig Number: Date ~~ I From - To Hours Task i Code I, NPT ~ Phase Description of Operations ~ - -- 8/29/2005 02:00 - 03:00 1.00 CASE P --_ SURF - _ - - Test csg. with 2000 psi for 30 min. record on chart, test witness by WSL 03:00 - 05:30 2.50 CEMT P SURF Drill landing collar @ 7005, cement, float 7048, cement and shoe @ 7092, drill 20 ft of new hole to 7124 with 75 rpms, 410 gpm, 1600 psi, 10 -15 bit wt., Tq 10-12k 05:30 - 09:00 3.50 CASE P SURF Circ. and displace well with new LSD 9.0 mud 09:00 - 10:00 1.00 DRILL P INT1 Fit, with MD 7124, TVD 4561, MWT 9.0, 710 Psi=12.0 EMWT, good test 10:00 - 13:00 3.00 DRILL P INT1 Slug pipe, POH 13:00 - 13:30 0.50 DRILL P INT1 Stand back HWDP,Lay down BHA 13:30 - 17:00 3.50 DRILL P INT1 Clear floor, Pickup BHA #4 17:00 - 21:30 4.50 DRILL P INT1 RIH, to 7124 21:30 - 00:00 2.50 DRILL P INT1 Drilling 7124 to 7392' with 600 gpm, 2700 psi, 150 rpms, AST ~ 1.2, ART .64, ADT 1.84, Tq 11 k, base line ECD 9.4 8/30/2005 00:00 - 00:00 24.00 DRILL P INT1 Directional drilling from 7392 to 9490 - WOB 10 / 12 -RPM 170 -TOon8-Off6-GPM625-PP on3510-Off3500-PU 170- SO 130 -ROT 150 -ECD 9.8 8/31/2005 00:00 - 05:00 5.00 DRILL P INT1 Directional Drill from 9490' to 9750' at short trip depth - WOB 10/12-RPM170-TQon8-off6-GPM625-PPon3480- off 3480 - PU 175 - SO 135 -ROT 152 -ECD 9.91 05:00 - 07:00 2.00 DRILL P INT1 CBU 2 X -GPM 625 - PP 3450 -RPM 150 - TO 6 off - 07:00 - 09:00 2.00 DRILL P INTi Pump out of hole f/ 9750 - 7090' @ 575 gpm 09:00 - 10:00 1.00 DRILL P INT1 CBU 1x @ 600 gpm 3150 psi - 120 rpm - Clayballs observed upon bottoms up. 10:00 - 11:00 1.00 DRILL P INT1 Cut drlg line -Service Top Drive. 11:00 - 12:00 1.00 DRILL P INT1 RIH f/ 7092' to 9750' -wash down last stand -fill pipe C~3 8952' 12:00 - 00:00 12.00 DRILL P INT1 Drilling f/ 9750 to 10990' - WOB 10-12 -RPM 160 - Tq on 11 Off 8- 585 gpm - PP on 3560 -Off 3580 - PU 195 - SO 135 - ROT 160 -ECD 10.5 9/1/2005 00:00 - 01:00 1.00 DRILL P INT1 CBU 1X C~3 600 gpm 3600 psi - 150 rpm -Due to ECD increse 10.69 & packing off on connection 01:00 - 12:00 11.00 DRILL P INT1 Directional drilling 9 7/8" hole f/ 10990' to 12,191'. WOB 15 - RPM 160-Tgon 13-off9-585 gpm-PP on 3700-off 3700- P.U. 210 - S.O. 140 -ROT 172 -ECD 10.5 12:00 - 15:00 3.00 CASE P INT1 Condition mud &cbu 3x - 550 gpm @3440 psi - 160 rpm - Flow check 15:00 - 17:30 2.50 CASE P INT1 Pump out from 12191' to 9500' -Pump at drlg rate 17:30 - 18:30 1.00 CASE P INT1 RIH f19500 to 12191'. 18:30 - 22:30 4.00 CASE P INT1 Condition mud &cbu 3x- w/ 550 gpm - 3440 psi -RPM 150 - Shakers loaded with sand. 22:30 - 00:00 1.50 CASE P INT1 Pump out from 12191 to 10,588 -Pump at drlg rate. 9/2/2005 00:00 - 03:00 3.00 CASE INTi Pump out from 10,588' to 7050' -inside shoe -Pump at drlg rate 03:00 -04:30 1.50 CASE INT1 Flow check -CBU 2 x C~? 550 gpm - 3200 psi -RPM 110 - Shakers loaded with sand. 04:30 - 07;30 3.00 CASE INT1 Flow check -Pump Dry Job - POH From 7062' to 5855' - LD 9 stands 5" dp - Con't POH with 4" DP to BHA 725' 07:30 - 11:00 3.50 CASE INTi L.D. G. rmr, hwdp, Dc's -Download MWD - LD MWD - Geo-Pilot -Bit 11:00 - 12:00 1.00 CASE INTi Clear floor -Pull wear ring -install test plug 12:00 - 13:30 1.50 CASE INTi PJSM -change rams to 7 5/8" -Test doors to 250 low - 1500 high 13:30 - 14:30 1.00 CASE INTi R.U. to run 7 5/8" casing Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-91 Common WeII Name: MPF-91 Event Name: DRILL+COMPLETE Start: 8/21/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 9/21/2005 Rig Name: DOYON 14 Rig Number: Date ~ From - To ~ Hours I Task ! Code ~ NPT Phase 9/2/2005 14:30 - 21:30 -_ __ 7.00 (( _- 1 CASE ~ INTi 21:30 - 22:30 1.00 CASE INTi 22:30 - 00:00 1.50 CASE INT1 9/3/2005 00:00 -04:00 4.00 CASE P INT1 04:00 - 07:00 ! 3.001 CASE I P I I INTi 07:00 - 08:00 I 1.001 CEMT I P I I INT1 08:00 - 09:30 I 1.501 CASE I P I I INT1 09:30 - 10:00 0.50 CASE P INT1 10:00 - 11:00 1.00 CASE P INT1 11:00 - 12:00 1.00 CASE P INT1 12:00 - 14:00 2.00 CASE P INT1 14:00 - 15:30 1.50 CASE P INT1 15:30 - 16:30 1.00 CASE P INT1 16:30 - 23:00 6.50 CASE P INT1 23:00 - 00:00 1.00 CASE P INT1 9/4/2005 00:00 - 02:30 2.50 CASE P INT1 02:30 - 10:30 8.00 CASE P INT1 10:30 - 11:30 1.00 CASE P INT1 11:30 - 13:00 1.50 CASE P INT1 13:00 - 14:00 1.00 CASE P INT1 14:00 - 15:00 1.00 DRILL P INT1 15:00 - 16:30 1.50 CASE P INT1 16:30 - 18:30 2.00 CASE P INT1 18:30 - 19:00 0.50 DRILL P INT1 19:00 - 20:00 1.00 CASE P INT1 20:00 - 00:00 4.001 DRILL P PRODi Page 4 of 10 Spud Date: 8/22/2005 End: Description of Operations Run 7 5/8" 29.7# BTC-Mod casing to 7075' (10 3/4' shoe 7092' ) Circulate one casg volume Con't Run 7 5/8" casg from 7075' to 8600' Continue run 7 5/8" 29# casing into open hole -Break circ. every 1500' -Ran 295 jts. of 7 5/8" 29.7# BTC-M L-80/S95 casing. PU landing joint w/ hanger. Broke circulation and washed landing joint to landing ring. Slowly raise pump rate from 2 bpm to 7.5 bpm - Circ. casing vol. (559 bbls) 294 gpm 730 psi- Reciprocate casing - PU 290 - SO 150. After circulating casing volume. Rigged down casing fill up tool and made up Schlumberger cementing head. Circulated additional casing volume (559 bbls). Pumped 5 bbls of water, test lines to 3500 psi, pump 5 bbls of water, pumped 20 bbls of CW-100 and 30 bbls of 10.8 ppg Mud Push. Dropped bottom plug. Mixed and pumped 65 bbls (305 sxs) of Premium cement w/ .2% BWOC D-046 antifoam + .3% BWOC D-065 dispersant + .35% BWOC D-167 Fluid loss + .06% BWOC Retarder. Cement mixed in a 15.8 ppg slurry with a yield of 1.16 cft/sx. Kicked out top plug with 30 bbls water. Displace cement with rig pumps at 7.5 bpm (initial circulating rate 430 psi and final circulation rate 830 psi at 30 spm). Reciproc~t oi~e with 30' strokes throughout entire job with full returns. Bumped the plug with 1600 psi at 0915 hrs. Held pressure 5 minutes. Bled off pressure and check floats. Float held. LD cement head -Flush ROPE w/ H2O - LD landing jt. Install 10 3/4" x 7 5/8" packoff - RILD -Test to 5000 psi f/ 10 min. Change rams to 2 7/8" x 5" var. - LD casing equip. Change out saver sub dies & bell guide on top drive. PU test jt. - RU test equip. -Test top rams to 250 low - 4000 high - RD test equip -Install wear ring -Clear floor PJSM - Cut drlg. line -Service rig -Install bales & elevators. PJSM - Ld 5" DP f/ derrick. Clear floor, change over to 4" handling equip. -Pull BHA to rig floor. PU BHA -Surface test MW D - 245 gpm 810 psi. PU 4" DP f/ pipeshed -Fill pipe every 1000' RIH w/ DP f/ derrick to 12060'. CBU - R&R DP - 40 rpm, 9k tq. - 300 gpm 3400 psi RU & test csg to 3500 psi f/ 30 min. - OK Drill FC @ 12092 -Drill Shoe @ 12179 -Clean out rat hole to 12191'. CBU - 280 gpm, 2380 psi. - R&R DP 50 rpm PJSM -Change over to 11.0 ppg LSND mud - 300 gpm 3140 psi Obtain SPR -Drill 20' of new hole to 12211'. Pull to 7 5/8" shoe at 12179' -Perform FrI.T. - 11.0 ppg - 1050 psi - 12179' MD, 6743' TVD - EMr W = 14.0 ppg D.D. f/ 12211' to 12362 - P.U 205 - SO 100 -Rot. 135 - Tq. on Printed: 9/26/2005 9:39:56 AM r~ BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task ~ Code 9/4/2005 20:00 - 00:00 -- 4.00 DRILL P 9/5/2005 00:00 - 14:30 14.50 DRILL P I f 4:30 - f 6:00 1.50 CASE P 16:00 - 17:30 1.50 CASE P 17:30 - 18:00 0.50 CASE P 18:00 - 19:00 1.00 CASE P 19:00 - 21:00 2.00 CASE P 21:00 - 22:00 1.00 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 23:30 0.50 CASE P 23:30 - 00:00 0.50 CASE P 9/6/2005 00:00 - 04:00 4.00 CASE P 04:00 - 05:30 1.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 08:00 1.50 CASE P 08:00 - 08:30 0.50 CASE P 08:30 - 15:00 6.50 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 17:00 1.50 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 20:00 2.50 CASE P 20:00 - 21:00 1.00 CEMT P 21:00 - 22:00 I 1.001 CASE I P 22:00 - 23:00 I 1.00 I CASE I P 23:00 - 00:00 I 1.001 CASE I P 9/7/2005 100:00 - 03:00 I 3.001 CASE I P 03:00 - 04:00 1.00 CASE P 04:00 - 10:00. 6.00 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 11:30 0.50 CASE P 11:30 - 12:00 0.50 BUNCO 12:00 - 12:30 0.50 BUNCO Spud Date: 8/22/2005 Start: 8/21/2005 End: Rig Release: 9/21/2005 Rig Number: NPT Phase Description of Operations PRODi 10 -Off 10 - 300 gpm - 3380 psi on - 3220 off PRODi DD f/ 12362 to 13045' - 6 3/4" TD - WOB 10 to 12 -RPM 80 - TOon14-off10-GPM296-PPon 3780-off 3490-PU210 - SO 100 -ROT 138 PROD1 CBU 1x - 290 gpm, 3390 psi - R&R DP @ 80 rpm PROD1 Pump out of hole f/ 13,045' to inside 7 5/8" shoe at 12,179' - 275 gpm, 3010 psi PROD1 Monitor well f/ 30 min. -Well static PROD1 RIH f/12177' to 13045' -Ream/wash f! 12728' to 13045' PROD1 CBU 2 X -GPM 296 - PP 3200 -RPM 80 - TO 10 -Bottoms up mud gas cut to 10.6 ppg from 11 ppg -Shakers clean PROD1 Pump out to shoe from 13045' to 12170' -GPM 275 - 3000 psi PROD1 CBU 1 X -Shakers clean - PROD1 Monitor Well F/30 mins -Well static -Pump dry job PROD1 POH from 12170' to 11,960 PROD1 POH f/ 11,960 to BHA PROD1 LD BHA PROD1 Clear floor PROD1 Rig up to run 4 1/2" 12.6# L-80 IBT Casing Liner PROD1 Run 24 jts. of 4 1/2" casing - 7 5/8" x 5 1/2" HMC liner hanger & ZXP packer PROD1 Circ. casing volume 210 gpm 210 psi - PU 55k - SO 55k PROD1 Run liner on 4" DP to 7 5/8" shoe at 12179 -Fill every 20 stands. PROD1 CBU 1 x - 210 gpm C~3 1200 psi - PU 185 - SO 105 PROD1 Cont. RIH to 13045 - PU 205 - SO 105 PROD1 RU cement head -Tag bottom PROD1 CBU - 210 gpm @ 1380 psi PROD1 PJSM -Turn over to Schlumberger -Pump 5 bbls H2O -Test lines to 4500 psi - 10 bbls CW 100 chem. wash - 20 bbls 12 ppg mud push - 43.5 bbls 15.8# Class G cement C~ 4 bpm. -Flush lines w/fresh H2O -Drop dart -Pump 20 bbl 9.3 ppg viscosified brine - Reciprocate pipe during entire operation PROD1 Displace w/ rig pumps 122 bb sl 11.0 ppg mud With 930stks pumped, started packing off -Work pipe free w/ full circ. -Set down 1' off bottom -Bump plug at 1197 stks -Press. to 3500 psi to set hanger -Rot. 20 turns to right to release hanger. Press. to 1000 psi - PU to press drop to 200 psi. Pump 25 bbls mud @ 10 bpm -Rotate down -Set 70k down while rotating - Observe ZXP set. PU to up weight PROD1 Circulate cement out - 380 gpm 3230 psi. 10 bbls +- contaminated cement back. PROD1 PJSM -Lay down cement head -Flush lines - RU to displace well w/ seawater. PROD1 Pump 20 bbls high visc. Sweep - 70 bbls H2O - 30 bbls High visc. sweep -Displace well w/ 960 bbls seawater -Flow check well 30 mins -Well static PROD1 Cut drlg. line -Service rig PROD1 LD 4" DP PROD1 POH, stand back 40 stands 4" DP in derrick PROD1 LD Baker running tool RUNCMP Pull wear ring RUNCMP Test casing to 3500 psi f/ 30 min - OK Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name:. DOYON 14 Date ~ From - To ~ Hours Task I Code ' NPT 9/7/2005 12:30 - 14:00 i 1.50 BUNCO 14:00 - 16:00 2.00 BUNCO 16:00 - 00:00 8.00 BUNCO 9/8/2005 00:00 - 05:00 5.00 BUNCO 05:00 - 05:30 0.50 RU 05:30 - 13:00 7.50 RU 13:00 - 13:30 0.50 RU 13:30 - 14:30 1.00 RU 14:30 - 16:00 1.50 RU 16:00 - 17:30 ~ 1.50 ~ RU 17:30 - 21:30 I 4.001 RU 21:30 - 22:00 I 0.50 I R 22:00 - 00:00 I 2.00 9/9/2005 00:00 - 01:00 1.00 R 01:00 - 02:30 1.50 R 02:30 - 04:00 ~ 1.50 04:00 - 05:00 I 1.00 05:00 - 05:30 0.50 R 05:30 - 09:30 4.00 R 09:30 - 10:00 0.50 R 10:00 - 10:30 0.50 R 10:30 - 12:00 1.50 R 12:00 - 13:00 1.00 R 13:00 - 00:00 11.00 R 9/10/2005 00:00 - 01:30 1.50 R 01:30 - 10:30 I 9.00 10:30 - 13:00 I 2.50 13:00 - 16:00 3.00 16:00 - 18:00 2.00 18:00 - 19:00 I i .00 19:00 - 00:00 I 5.00 Start: 8/21 /2005 Rig Release: 9/21/2005 Rig Number: I Page 6 of 10 Spud Date: 8/22/2005 End: Phase Description of Operations RUNCMP Change out saver sub to 4 1/2" IF RUNCMP RU completion running equip. RUNCMP PJSM -Run 4 1/2" 12.6# L-80 TCII tubing RUNCMP Run 4 1/2" 12.6# L-80 TCII completion to 5796' String took wt - Work string set down 25K - No Movement - PU 105 SO 85 DPRB RUNCMP RU to lay down 4 1/2" Completion DPRB RUNCMP Lay down 4 1/2" TC 11 completion string DPRB RUNCMP Lay Down & inspect Baker Packer (No visible damage ) DPRB RUNCMP Clear floor of tubing equip. -Change bales DPRB RUNCMP PJSM - C/O dies - Beli guide -savor sub to 4" - RU bails - Install wear ring DPRB RUNCMP Moblize BHA - MU BHA -Bit -Bit sub - 6.75" string mill - Collars -Jar DPRB RUNCMP RIH with clean out string from 196' to 5801.' -Taking weight 2k to 3k - Con't RIH to 5813' - PU to 5780 - No overpull -Run through 5813 to 6175' - (No issues) - PU 115 - SO 97 DPRB RUNCMP Break Circulation -Pump Hi-Vis sweep 28 bbls -GPM 650 - PP 3050 -RPM f 00 - TO 3 -lot of cutting balls -cuttings -mush - some cement back -Most of the residue came back before sweep around DPRB RUNCMP Con't RIH from 6175' to 9886' - (Hit stringer C~ 8873' set 20K fell off) - PU to 8850' no overpull -Run through 8873 no issues - Con't RIH DPRB RUNCMP Con't RIH from 9886' to 11318' - Taking weight (stringers) DPRB RUNCMP Wash /Ream from 11318' to 12022' -GPM 550 PP 3770 - RPM 120 - TO 5 DPRB RUNCMP Circulate 2 Hi-Vis sweeps -GPM 570 - PP 3820 - R&R DP - RPM120-T05-PU-170-SO-115-ROT-140 DPRB RUNCMP Pump 3rd sweep -Displace with clean 8.5 ppg seawater - 550 GPM DPRB RUNCMP Flush lines -Clean possum belly DPRB RUNCMP POH w/ 4" DP DPRB RUNCMP LD BHA DPRB RUNCMP Pull wear ring -Clear rig floor DPRB RUNCMP Change out savor sub on top drive from 4" HT 38 to 4 1/2" IF DPRB RUNCMP RU tubing to run 4 1/2" TC11 Completion DPRB RUNCMP Run 4 1/2" TC11 completion Joints ran 127 - @ 4427' DPRB RUNCMP Run 4 1/2" completion trom Jt # 127 C~3 4427' to Jt # 140 5800' RUNCMP Con't Run 4 1/2" TC11 Completion from Jt # 141 @ 5841' to 10,093'(jt.# 244) -Taking wt. Set 15k down & fell through - PU 1 jt taking wt at 10,134'( jt.# 245) -Set down 15k & fell through - PU 1 Jt. Taking wt. at 10,176' (jt. # 246) -WLEG depth - Would not go PU to 190k (50k over) & pulled free. DPRB RUNCMP POH slow laying down tubing. PU 140 - SO 97. Layed down 21 jts. & pulling tight -Pulled free w/ 210k (70k over) DPRB RUNCMP PJSM - RU &circ. w/ 3 bpm 250 psi -Pump 1 bbl tube sweep. DPRB RUNCMP LD 4 jts.to 9162' WLEG depth -Pulling tight - 280k (140k over ). Attempt to circ. w/ no success. DPRB RUNCMP PU 10' pup jt. - PU to 280k. No movement up or down. Drop ball & rod. Press. to 3500 psi to set packer. WLEG depth = 9162' -Top packer @ 9126' (221 jts. in hole ). DPRB RUNCMP Wait on Schlumberger E-Line to run Chemical cutter Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Start: 8/21/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 9/21/2005 Rig Name: DOYON 14 Rig Number: Date ', From - To Hours Task Code' NPT Phase 9/11/2005 00:00 - 01:30 1.50 RUNC 01:30 - 02:30 1.00 RUNC 02:30 - 04:00 1.50 RUNC 04:00 - 05:00 ~ 1.00 05:00 - 08:30 I 3.50 08:30 - 10:00 1.50 10:00 - 13:00 3.00 13:00 - 13:30 0.50 R 13:30 - 00:00 10.50 R 9/12/2005 00:00 - 01:30 1.50 CLEAN ~ N 01:30 - 02:30 1.00 CLEAN N 02:30 - 07:30 5.00 BOPSU N 07:30 - 08:00 0.50 BOPSU N 08:00 - 08:30 0.50 CLEAN N 08:30 - 10:00 1.50 CLEAN N 10:00 - 13:00 3.00 CLEAN N 13:00 - 19:00 6.00 CLEAN N 19:00 - 21:30 I 2.501 CLEAN I N 21:30 - 23:00 I 1.501 CLEAN I N 23:00 - 00:00 1.00 CLEAN N 9/13/2005 00:00 - 00:30 0.50 CLEAN N 00:30 - 04:00 3.50 CLEAN N 04:00 - 05:00 1.00 CLEAN N 05:00 - 06:00 1.00 CLEAN N 06:00 - 09:30 3.50 CLEAN N 09:30 - 10:30 1.00 CLEAN N 10:30 - 17:00 I 6.501 CLEAN I N Spud Date: 8/22/2005 End: Description of Operations DPRB RUNCMP Spot Schlumberger & rig up at beaver slide DPRB RUNCMP PJSM - PU 140k on string & set slips - RU Schlumberger DPRB RUNCMP RIH w/ chem. cutter on W.L. to 262' -Hit bridge - POH to X -Nipple -Stuck chemical cutter in X-Nipple -Pulling to 3800 w/ wireline w/ no success. DPRB RUNCMP Bolt "T" bar on wireline & pull free with blocks (3k overpull) - Tools came out complete. Small gouge on firing head. Inspected chemical cutter found two alien head screws missing from centralizers DPRB RUNCMP Moblize gauge ring -junk basket - to make drift run for X-nipples and tubing DPRB RUNCMP Run 3.7" drift /junk basket on E-line to 9163' WLM - POH DPRB RUNCMP Run Chemical cutter on E-line to 9124' WLM -Fire cutter - tubing cut - POH -Left bottom centralizer in hole on top of ball and rod (21 inches long) - RD Schlumberger DPRB RUNCMP PJSM - RU to lay down tubing DPRB RUNCMP LD 4 1/2" TC11 tubing -Recovered 221 jts. - 2 X nipples - 4 i pup jts. & cut pup jt. (7.60' ). Estimated top of fish @ 9124'. DPRB CLEAN Change saver sub to 4" HT38 DPRB CLEAN Slip & cut drlg. line -Service Rig DPRB CLEAN RU to test BOPE And Related Equipment -Test BOPE - Annular 250 low, 2500 high 5 min ea. -Test choke manifold, BOP stack & related valves to 250 low, 4000 high 5 min. ea. - Test Top drive upper & lower IBOP & floor valves to 250 low, 4000 high 5 min. ea. - WSL witnessed all test -The Right To Witness The BOP Test Was Waived By AOGCC Inspector John Spaulding -Rig Down Testing Equipment DPRB CLEAN Install Short Wear Bushing And Energize Lock Down Studs DPRB CLEAN Install Short Bales On Top Drive -Mobilize BHA To Rig Floor DPRB CLEAN Pick Up Packer Milling Assembly - 12 Each 4 3/4" Steel Drill Collars - 6 Each 4" HWDP = 595.04 DPRB CLEAN RIH With Milling Assembly From 595' To 9,135' DPRB CLEAN Break circulation -Mill packer -GPM 318 - PP 1150 -RPM 60 - T02.5-PU145-S0118-ROT 128 DPRB CLEAN Push packer to 12000' -Tail pipe 12036' - TOL 12026' -From 9300 to 10100' -Push taking 10 to 20K in spots -from 10100 to 11400' taking 10 to 40K in spots -From 11400 to 11560' free - From 11560 to 11570 taking 30 to 40K - trom 11570 to 12000' free DPRB CLEAN Circulate Hi-Vis sweep -GPM 318 - 1170 psi - On bottoms up + - 90% fine metal 10% cement DPRB CLEAN PJSM - POH from 12036' to 10,762' DPRB CLEAN Service rig DPRB CLEAN POH w14" DP f! 10,762'. DPRB CLEAN LD milling BHA -Clean junk baskets -Recovered 2.5 Gallons Of Metal DPRB CLEAN PU fishing BHA DPRB CLEAN RIH to 11910' DPRB CLEAN Break circ. 64 spm 1440 psi, P/U 167k, S/O 125k, slow pump to 26spm 640 psi, sting in to PKR, psi increase confirm spear in packer, pull free with 175K, drop ball to circ sub, pull two stands, pump circ sub open with 33 spm 790 psi, pump dry job DPRB CLEAN POH with packer Printed: 9/26/2005 9:39:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 'From - To 9/13/2005 17:00 - 18:00 18:00 - 20:30 Page 8 of 10 MPF-91 MPF-91 Spud Date: 8/22/2005 DRILL+COMPLETE Start: 8/21/2005 End: DOYON DRILLING INC. Rig Release: 9/21/2005 DOYON 14 Rig Number: Hours Task Code' NPT Phase Description of Operations 1.00 CLEAN N 2.50 CLEAN N 20:30 - 21:00 0.50 CLEAN N 21:00 - 22:30 1.50 CLEAN N 22:30 - 00:00 1.50 CLEAN N 9/14/2005 00:00 - 01:00 1.00 CLEAN N 01:00 - 02:30 1.50 CLEAN N 02:30 - 04:00 1.50 CLEAN N 04:00 - 05:30 ~ 1.50 ~ CLEAN ~ N 05:30 - 07:00 1.50 CLEAN N 07:00 - 08:30 1.50 CLEAN N 08:30 - 09:00 0.50 CLEAN N 09:00 - 10:30 1.50 CLEAN N 10:30 - 11:00 0.50 CLEAN N 11:00 - 12:30 1.50 CLEAN N 12:30 - 13:00 0.50 CLEAN N 13:00 - 14:00 1.00 CLEAN N 14:00 - 20:30 6.50 CLEAN N 20:30 - 00:00 3.50 CLEAN N 9/15/2005 00:00 - 00:30 0.50 CLEAN N 00:30 - 02:00 1.50 CLEAN N 02:00 - 03:00 1.00 CLEAN N 03:00 - 06:30 3.50 CLEAN N 06:30 - 07:30 1.00 CLEAN N 07:30 - 09:00 1.50 CLEAN N 09:00 - 00:00 15.00 CLEAN N 9/16/2005 100:00 - 10:00 I 10.00 I CLEAN I N 10:00 - 14:00 I 4.00 14:00 - 23:30 ~ 9.50 23:30 - 00:00 I 0.50 9/17/2005 100:00 - 00:30 I 0.50 00:30 - 01:00 I 0.50 01:00 - 05:30 I 4.50 DPRB CLEAN PJSM, laying down packer and tail pipe assm. DPRB CLEAN PJSM, Picking up 3 3/4 junk mill,bit sub,29 jts 2 7/8 Pac drill pipe, xo subs,2 boot baskets,? 5/8 casing scraper, bit sub, bumper sub, Jars,circ sub,xo,12 4 3/4 DC,6 4" hw pipe DPRB CLEAN Break circ. thru 2 7/8" pac dp - 46 spm (200 gpm) 480 psi DPRB CLEAN Cont. PU BHA DPRB CLEAN RIH w14" DP DPRB CLEAN Continue RIH to 9000' DPRB CLEAN Slip & cut drlg. line -Service rig DPRB CLEAN Continue RIH to 12,000' -Obtain parameters -Continue RIH to 12,941' (7 5/8" casing scraper at 12,021' ). DPRB CLEAN CBU 2x - 91 spm, 3400 psi - PU 170 - SO 120 -Reciprocate pipe 90' DPRB CLEAN POH so 7 5/8 Csg scraper is @ 9000' DPRB CLEAN RIH to 12941' DPRB CLEAN Circ one bottoms up with 9 bbls min. 3300 psi, recipocate pipe DPRB CLEAN Displace well with 35 bbls hi- vis sweep, 100 bbls h2o, 500 bbls sea water, 8 bbls min 3800 psi, recipocate pipe DPRB CLEAN POH to 11960' DPRB CLEAN Displace well with 35 bbl hi-vis sweep, 450 bbls Sea water, 95 spm 3900 psi, recipocate pipe DPRB CLEAN PJSM, Test csg with 3500 psi, good test DPRB CLEAN POH, with 13 stands and stand in derrick, total of 30 stands in derrick DPRB CLEAN PJSM, POH, laying down pipe DPRB CLEAN LD Cleanout BHA DPRB CLEAN Clear rig floor DPRB CLEAN Rig up Schlumberger slick line unit, PJSM DPRB CLEAN Schlumberger oil jars not working proper, replace same DPRB CLEAN Run 6.75 gauge ring, junk basket DPRB CLEAN Rig down Schlumerger slick line unit DPRB CLEAN Rig up to run Tubing, PJSM DPRB CLEAN Picking up, 4.5 12.6# L-80 TC-II tubing, using Torque-Turn and Compensator and stabbing guide, testing tubing with 4000 psi for ten min. every 2000', total picked up 126 jts DPRB CLEAN Picking up, 4.5 12.6# L-80 TC-II tubing, using Torque-Turn and Compensator and stabbing guide, testing tubing with 4000 psi for ten min. every 2000', RIH To 9,162' RUNCMP Continue to RIH from 9,162' picking up, 4.5 12.6# L-80 TC-II tubing, using Torque-Turn and Compensator and stabbing guide, testing tubing with 4,000 psi for ten min. every 2000'. Taking weight at 1.1,406' WLEG depth. PU-145k - SO 100k. RUNCMP PJSM - RU slickline -RIH & retrieve Doyon 16 plug f/ X-nipple # 2 - POH w/ same -RIH & retrieve RHC-M plug f/ XN-nipple. RD slickline RUNCMP RU & reverse circ. 2.5 bpm 100 psi.- Pump 60 bbl. "screen clean" pill DPRB RUNCMP Continue pump "screen clean" pill w! 2.5 bpm 100 psi. Pressure inc. due to packing off (390 psi ). DPRB RUNCMP Work pipe free w/ 145k up - 100k down. RIH w/ 2 jts. to 11,489' WLEG depth. Taking weight. Pu to 155k - SO to 95k. DPRB RUNCMP RU & attempt to rev. circ. -Packed off. Work pipe free on down stroke- SO 100k. Rev. circ. w/ 2.5 bpm 100-300 psi. Printed: 9/26/2005 9:39:56 AM C7 BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: MPF-91 Common Well Name: MPF-91 Event Name: DRILL+COMPLETE Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 8/21 /2005 9/21 /2005 Spud Date: 8/22/2005 End: Date I From - To ~ Hours Task Code I NPT Phase Description of Operations 9/17/2005 05:30 - 09:00 3.50 BUNCO DPRB RUNCMP RIH from 11489' to 11528' set down on first 7 5/8 collar, rig up to rev. circ, pumped 2.5 bbls min. 150 psi for 10 bbs, attempt to lower pipe, 155k pick up, 100k s/o, stiA setting down in collar, pumped 3 bbls min 240 psi for 20 bbls, worked pipe 165k p/u 100k s/o, still setting down in collar, attempt to circ packed off, p/u to 145k sting wt. attempt to circ still packed off, slacked off to 100k string wt., picked up to 170k, slacked off to 100k, p/u to pipe movement, attempt to circ, still packed off, p/u 200k, slack off 105k saw movement of pipe, slacked of to 98k, p/u 150k, attempt to circ, still packed-off, p/u to 245k, s/o 98k no pipe movement, P/u 285k, s/o 98k, attempt to rev. circ 3500 psi, still packed off, pumped down long way with 2700 psi still packed off 09:00 - 10:00 1.00 BUNCO DPRB RUNCMP Rig up slick line unit 10:00 - 14:30 4.50 BUNCO DPRB RUNCMP RIH with RHC pug set in XN nipple, pressure up to 3500 psi for 15 min. to set packer C~ 11492' 14:30 - 15:30 1.00 BUNCO DPRB RUNCMP POH with slick line and RHC plug, rig down slick line unit 15:30 - 00:00 8.50 BUNCO DPRB RUNCMP Spot Schlumberger E-line truck, and rig up to run chemical cutter, PJSM -RIH w/Chem. cutter to 3750'-Could not get down. POH-Add weight bars -RIH -Could not get past 4046' - POH - PU weight bars & rollers -RIH -Spot cutter at 11,485' W LM (8' above pkr. ). Fire cutter -Good indication of firing. Log up -Pipe appears to have moved up hole + - 2'. 9/18/2005 00:00 - 01:30 1.50 BUNCO DPRB RUNCMP POH w/ chem. cutter - RD Schlumberger. 01:30 - 07:30 6.00 BUNCO DPRB RUNCMP RU to rev. circ. -Pull to ensure pipe free- PU 140k 4' above cut-Rev. circ 35 bbls HV sweep @ 3.5 bpm - 135 bbls. hot diesel @ 1.5 bpm, 150 psi - 180 bbls. HV sweep ~ 3.5 bpm - 100 deg. seawater to surface C~ 8- 10 bpm. Returns showed very dark dirty diesel back- HV sweeps to thick to observe any cuttings on shakers. 07:30 - 08:30 1.00 BUNCO DPRB RUNCMP RD circ. head-RU compensator tubing equip. 08:30 - 00:00 15.50 BUNCO DPRB RUNCMP LD 4 1/2" TCII tubing- Recovered 278 jts- 2 "x"nipples- 4 pup jts + cut (2.13') Break out cut jt.- Insert into Unique O.S. to ensure fit. OK. 9/19/2005 00:00 - 00:30 0.50 BUNCO DPRB RUNCMP RD compensator & tubing equipment 00:30 - 01:30 1.00 BUNCO DPRB RUNCMP Cut drlg. line -Service rig 01:30 - 02:00 0.50 BUNCO DPRB RUNCMP RU compensator & torque turn equipment. 02:00 - 03:00 1.00 BUNCO DPRB RUNCMP PJSM - PU Unique overshot & tailpipe assembly- Baker 7 5/8" x 4 1/2" Premier packer w/ pups - 1 jt. 4 1/2" TCII tubing - "x"nipple & pups w/ Doyon 16 plug -attempt to Test to 4000 psi 03:00 - 06:00 3.00 BUNCO DPRB RUNCMP Lay down 1 jt and X nipple, repair D-16 plug 06:00 - 00:00 18.00 BUNCO DPRB RUNCMP RUN 4 1/2" TCII completion using torque turn & compensator - Test to 4000 psi every 2000' (50 jts. ). 9/20/2005 00:00 - 02:00 2.00 BUNCO DPRB RUNCMP RUN 4 1!2" TCII completion using torque turn & compensator - Test to 4000 psi every 2000' (50 jts. ). total 250 jts.Joint # 246, 10,243' set down with 5k down wt., PU to 140k (15k over ). Slack off w/ no issues. PU 125k - SO 100k. Test 250 jts to 4000 psi. 02:00 - 07:00 5.00 BUNCO DPRB RUNCMP PJSM, RU slickline to pull D-16 plug @ 10,231'., big chunk of rubber hung up in D-16 plug 07:00 - 08:00 1.00 BUNCO DPRB RUNCMP PJSM, attempt to rev. circ. bbls min. pressure up to 400 psi , bleed off, work pipe 130k up, i00k slo, attempt to rev. circ Printed: 9/26/2005 9:39:56 AM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: MPF-91 Common W ell Name: MPF-91 Spud Date: 8/22/2005 Event Nam e: DRILL+C OMPLE TE Start : 8/21/2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 9/21/2005 Rig Name: DOYON 14 Rig Number: Date From- To Hours I Task Code I NPT Phase '! Description of Operations 9/20/2005 07:00 - 08:00 1.00 BUNCO DPRB ~ RUNCMP pressure up to 500 psi, bleed off, work pipe p/u 130k s/o 100k, rig up circ long way 1 bbl min 90 psi, rig up to rev circ. 3 bbls min. 150 psi, circ bottoms up, saw nothing on bottoms up. 08:00 - 10:00 2.00 BUNCO DPRB RUNCMP PJSM, Pickup 4 1/2" TCII completion using torque turn & compensator, total 276 jts 11484' tag up at top of cut jt. 10:00 - 10:30 0.50 BUNCO DPRB RUNCMP PJSM, Rig up to rev circ. pressure up to 480 psi., rig up to circ long way, 1 bbl min. 90 psi 10:30 - 15:00 4.50 BUNCO DPRB RUNCMP PJSM, Rig up Schlumberger slick line to pull RHCM plug C~3 11454' 15:00 - 16:30 1.50 BUNCO DPRB RUNCMP PJSM, Rev. circ 3 bbls min. 150 psi, saw nothing on bottoms up 16:30 - 17:00 0.50 BUNCO DPRB RUNCMP PJSM, Broke circulation down the tubing at 2 bpm at 60 psi. Up weight 142K Down weight 104K Slacked off on string and set down on tubing stump. Picked up 3' and slack off and swallowed stump with unique overshot. Sheared off brass shear pins with 8K down weight. Slacked off additional 2' and stack out 10K on packer at 11492'. Picked up 3' for space out. 17:00 - 18:30 1.50 BUNCO RUNCMP PJSM, Laid out joint # 276 and made up tubing hanger and landing joint. Broke circulation at 2 bpm at 60 psi and slacked off over stump. Pressure increased to 200 psi. Shut down pump and slacked off and landed hanger. Bottom of Unique Overshot 4' above top of packer. Ran in lock down screws. 18:30 - 21:00 2.50 BUNCO RUNCMP PJSM, Rig up Schlumberger slick line, set plug in X nipple C~3 3,000, pull slick line from well 21:00 - 21:30 0.50 BUNCO RUNCMP PJSM, Rig up and test top 3,000 ft of tubing and space out jt, to 4,000 psi for 10 min. with annulus valve open, good test 21:30 - 22:30 1.00 BUNCO RUNCMP PJSM, Rig up Schlumberger slick line, pull plug in X nipple C«2 3,000 22:30 - 23:30 1.00 BUNCO RUNCMP PJSM, lay down landing jt., set TWC, test to 1000 psi for 10 min. 23:30 - 00:00 0.50 BUNCO RUNCMP PJSM, Clear floor of Tubing handling equip. 9/21/2005 00:00 - 01:30 1.50 BUNCO RUNCMP PJSM, Nipple down BOPS 01:30 - 03:30 2.00 BUNCO RUNCMP PJSM, Nipple up FMC 11 "X 4 1/1 6 5000# adapter, CIW 4 1/16 5000# tree test adapter to 5000psi for ten min., shell test tree 5000 psi for ten min. 03:30 - 05:30 2.00 BUNCO RUNCMP PJSM, Remove TWC, rig up to reverse Circ., Rev. circ 232 bbls sea water treated with corrosion inhibitor C~3 3 bbls min 700 psi 05:30 - 08:00 2.50 BUNCO RUNCMP PJSM, Freeze protect with hot oil truck, pump 104 bbls down annulus and let U-Tube to tubing, 1.9 bbls/min. 800 psi 08:00 - 13:30 5.50 BUNCO RUNCMP PJSM, Rig up Schlumberger slick line unit and run and set RHC plug in lower X nipple @ 11457', Rig down slick line unit 13:30 - 17:00 3.50 BUNCO RUNCMP PJSM, Drop ball and rod, let fall to 11457', pressure up and set packer with 4000 psi, record pressure for 30 min., bleed Tubing pressure to 2000 psi, test annulus to 3500 psi for 30 min. 17:00 - 18:00 1.00 BUNCO RUNCMP Install BPV and Secure well, Rig release @ 1800 hrs 9/21/2005 Printed: 9/26/2005 9:39:56 AM WELL SERVICE REPORT • • WELL JOB SCOPE UNIT M P F-91 RWO CAPITAL SWS 2150 DATE DAILY WORK DAY SUPV 10/29/2005 PERFORATING HO FFMAN AFE KEY PERSON NIGHT SUPV MKD337447 SWS-AVANT UNKNOWN MIN ID DEPTH TTL SIZE 3.75 " 11516 FT 4.5 " CORRELATED TO SWS SCMT LOG DATED 18-OCT-2005 AS PER PAD ENGINEER PERFORATED 12756 - 12810 FT Init Tb IA OA -> 0 0 0 TIME COMMENT 07:00 DRIVE TO F PAD 07:30 PJSM WITH SLICKLINE. MIRU. MAKE UP DUMMY GUN AND PRESSURE TEST TO 3000 PSI. 09:18 GOOD TEST. BREAK OFF AND MAKE UP HEAD, HOT CHECK TOOL. GOOD TEST. POWER DOWN EQUIPMENT AND MAKE UP MH22/EQF56/ROLLERS/UPCT/SECURE HEAD/20 FT OF 2.5" 2506 PJ HMX GUN/ROLLERS. 10:22 _ _ RIH WITH 36 FT TOOL STRING. REQUIRED PERF INTERVAL IS 12790 - 12810 FT. CCL TO TOP SHOT IS 3.3 FT. REQUIRED CCL STOP DEPTH IS 12786.7 FT. 12:02 ON BOTTOM. DID NOT TAG TD. LOG CORRELATION PASS TO TIE INTO SWS SCMT LOG DATED 18-OCT- 2005 FOR TIE IN AS PER PAD ENGINEER 12:27 LOGGED UP INTO POSITION. T/I/O BEFORE SHOOTING 0/0/0. SHOT GUN. GOOD INDICATION OF FIRING. POOH. NO IMMEDIATE CHANGE iN PRESSURES. 14:00 ON SURFACE. ALL SHOTS SPENT. BREAK OFF SPENT GUN AND TEST FIRE THROUGH TOOLS STRING. GOOD TEST. POWER DOWN UNIT AND MAKE UP NEW HEAD WITH GUN #6758 . CCL TO TOP SHOT IS 3.3 FT. REQUIRED PERF INTERVAL IS 12770 - 12790 FT. REQUIRED CCL STOP DEPTH IS 12766.7 FT. 14:46 RIH WITH NEW STRING. ~~ ~ ~~- ~~ ~~ ~~~~ 15:58 _ __ __ _ _ ON BOTTOM. CORRELATING TO LOG. LOGGED INTO POSITION WITH CCL AT 12766.7 FT. T/I/O = 0/0/0. SHOT GUN. GOOD INDICATION OF FIRING. NO IMMEDIATE CHANGE IN PRESSURE. POOH. 17:45 ON SURFACE. ALL SHOTS. BREAK OFF SPENT GUN AND CHANGEOUT UPCT WITH CCL. TEST FIRE THROUGH TOOL, GOOD TEST. POWER DOWN UNIT AND MAKE UP 14 FT GUN #6765. 18:08 _ RIH. REQUIRED PERF INTERVAL IS 12756-12770 FT. CCL TO TOP SHOT= 9.3 FT. REQUIRED CCL STOP DEPTH = 12746.7 FT 19:24 ON BOTTOM. CORRELATING TO TIE IN LOG. LOG INTO POSITION. 20:11 ON DEPTH WITH CCL AT 12746.7 FT. T/I/O = 0/0/0. SHOT GUN. GOOD INDICATION OF FIRING. NO IMMEDIATE CHANGE IN PRESSURE. POOH, 21:13 ON SURFACE. ALL SHOTS SPENT. RDMO. ~ 22:30 DRIVE TO BASE ~ Final Tb IA OA -> 0 0 0 FLUID SUMMARY 1 bbl diesel for pressure test ~~~~~ SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL SCHLUMBERGER ~ _ $23,681 $60,032 WAREHOUSE $0 $5,586 LITTLE RED ~~ _ $0 $3,913 TOTAL FIELD ESTIMATE: $23,681 .$69,530 Printed: 9/26/2005 9:39:49 AM ,, v' ~ --~ Halliburton Sperry-Sun Milne Point Unit BPXA MPF-97 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Survey Report 14 September, 2005 Your Ref: API 500292327100 y Surface Coordinates: 6035662.34 N, 541708.15E (70° 30' 30.0576" N, 149° 39' 31.4802" V-~ Grid Coordinate Sysfem: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.51ft above Mean Sea Level DRI.L..LING SERVFCES A Halliburton Company Survey Ref: svy1543 • f 1 ~J Halliburton Sperry-Sun Survey Report for MPF-91 Your Ref: API 500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 BPXA Milne Point Unif Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -45.51 0.00 0.00 N 0.00 E ~ 6035662.34 N 541708.15 E - ~ 0.00 CB-SS-GYRO - Wellnav Gyro 81.00 0.640 90.570 35.49 81.00 0.00 N 0.45E 6035662.34 N 541708.60E 0.790 -0.36 168.00 0.660 106.320 122.48 167.99 0.15 S 1.42E 6035662.20 N 541709.57E 0.206 -1.22 256.00 0.710 3.910 210.48 255.99 0.25 N 1.94E 6035662.60 N 541710.09E 1.214 -1.40 358.00 1.900 323.180 312.45 357,96 2.24 N 0.97E 6035664.58 N 541709.11E 1.410 0.57 437.00 4.290 297.030 391.33 436.84 4.63 N 2.45 W 6035666.95 N 541705.68E 3.439 4.74 525.00 5.260 292.850 479.03 524.54 7.69 N 9.09 W 6035669.98 N 541699.01E 1.170 11.89 614.00 7.340 297.160 567.49 613.00 11.87 N 17.91 W 6035674.11 N 541690.17E 2.395 21.45 709.00 10.210 298.670 661.37 706.88 18.68 N 30.70 W 6035680.85 N 541677.34E 3.031 35.76 804.00 13.330 297.180 754.36 799.87 27.72 N 47.84 W 6035689.80 N 541660.16E 3.299 54.89 MWD+IIFR+MS 835.65 13.470 296.220 785.14 830.65 31.02 N 54.39 W 6035693.05 N 541653.59E 0.831 62.10 932.38 18.090 307.280 878.22 923.73 45.10 N 76.46 W 6035707.01 N 541631.44E 5.679 88.21 1027.07 21.090 308.980 967.42 1012.93 64.73 N 101.41 W 6035726.50 N 541606.38E 3.225 119.94 1122.51 20.120 309.650 1056.76 1102.27 86.01 N 127.40 W 6035747.63 N 541580.27E 1.046 153.50 1218.90 19.230 310.110 1147.52 1193.03 106.81 N 152.30 W 6035768.30 N 541555.25E 0.937 185.91 1312.31 22.250 307.420 1234.87 1280.38 127.47 N 178.12 W 6035788.81 N 541529.32E 3.389 218.97 1407.63 24.890 307.070 1322.23 1367.74 150.54 N 208.46 W 6035811.70 N 541498.85E 2.773 257.08 1501.02 23.140 306.730 1407.53 1453.04 173.36 N 238.85 W 6035834.36 N 541468.33E 1.880 295.08 1595.15 22.200 303.950 1494.39 1539.90 194.35 N 268.43 W 6035855.18 N 541438.63E 1.514 331.34 1689.43 22.090 302.730 1581.72 1627.23 213.88 N 298.12 W 6035874.55 N 541408.84E 0.502 366.80 1786.25 21.320 301.820 1671.67 1717.18 233.01 N 328.39 W 6035893.50 N 541378.46E 0.868 402.49 1881.09 20.080 303.070 1760.39 1805.90 250.98 N 356.68 W 6035911.32 N 541350.06E 1.388 435.90 1976.79 19.600 299.850 1850.41 1895.92 267.94 N 384.37 W 6035928.11 N 541322.28E 1.247 468.22 2071.58 23.610 296.770 1938.52 1984.03 284.41 N 415.12 W 6035944.41 N 541291.44E 4.395 502.68 2166.92 23.240 296.740 2026.01 2071.52 301.47 N 448.97 W 6035961.28 N 541257.50E 0.388 539.98 2262.11 24.950 297.300 2112.90 2158.41 319.13 N 483.58 W 6035978.75 N 541222.78E 1.812 578.25 2352.53 26.790 294.930 2194.26 2239.77 336.47 N 519.01 W 6035995.89 N 541187.26E 2.334 616.98 2449.74 30.360 291.500 2279.62 2325.13 354.71 N 561.75 W 6036013.89 N 541144.42E 4.040 662.09 2544.51 34.250 292.350 2359.70 2405.21 373.64 N' 608.72 W 6036032.56 N 541097.34E 4.132 710.98 2637.12 37.530 292.060 2434.72 2480.23 394.15 N 658.98 W 6036052.78 N 541046.97E 3.546 763.46 2730.79 37.670 293.170 2508.94 2554.45 416.13 N 711.73 W 6036074.46 N 540994.09E 0.738 818.81 2826.26 38.590 295.310 2584.04 2629.55 440.33 N 765.47 W 6036098.37 N 540940.22E 1.686 876.29 2919.72 40.660 298.440 2656.03 2701.54 467.30 N 818.61 W 6036125.04 N 540886.93E 3.076 934.95 3015.01 42.560 300.660 2727.27 2772.78 498.52 N 873.63 W 6036155.95 N 540831.73E 2.523 997.69 3108.85 45.580 300.920 2794.69 2840.20 531.93 N 929.69 W 6036189.05 N 540775.49E 3.224 1062.56 14 September, 2005 - 15:31 Page 2 of 7 DrillQuesf 3.03,06.008 Halliburton Sperry-Sun Survey Report for MPF-91 Your Ref.• AP1500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Milne Point Unit Measured Depth (ft) 3205.83 3298.16 3392.15 3486.50 3579.61 3674.79 3762.74 3856.85 3951.43 4046.31 4139.18 4231.63 4323.46 4419.55 4512.47 4603.43 4698.04 4790.89 4885.30 4977.07 5072.45 5166.34 5259.05 5354.93 5450.65 5542.83 5637.28 5731.58 5826.90 5919.25 6013.71 6109.71 6201.20 6298.55 6393.39 Incl 48.850 52.100 56.360 59.410 63.910 65.380 66.100 65.680 66.060 66.990 66.860 65.540 66.520 66.690 66.740 66.480 66.170 65.910 65.960 66.100 65.900 65.040 65.900 65.310 64.510 65.980 66.790 65.790 64.080 64.490 65.900 66.120 65.740 65.580 66.230 True Azim 304.230 305.420 306.500 308.410 309.320 310.970 310.970 311.040 309.070 307.470 307.510 307.380 305.170 305.110 305.600 305.120 304.810 304.560 305.980 307.320 307.050 306.470 307.290 308.110 308.370 309.030 311.270 311.160 311.880 310.100 309.730 309.930 309.370 308.560 308.270 Sub-Sea Depth (ft) 2860.56 2919.32 2974.25 3024.40 3068.59 3109.35 3145.49 3183.93 3222.60 3260.39 3296.79 3334.10 3371.41 3409.56 3446.30 3482.41 3520.40 3558.10 3596.60 3633.89 3672.68 3711.66 3750.15 3789.75 3830.34 3868.94 3906.78 3944.70 3985.08 4025.15 4064.78 4103.81 4141.13 4181.25 4219.97 Vertical Depth (ft) 2906.07 2964.83 3019.76 3069.91 3114.10 3154.86 3191.00 3229.44 3268.11 3305.90 3342.30 3379.61 3416.92 3455.07 3491.81 3527.92 3565.91 3603.61 3642.11 3679.40 3718.19 3757.17 3795.66 3835.26 3875.85 3914.45 3952.29 3990.21 4030.59 4070.66 4110.29 4149.32 4186.64 4226.76 4265.48 Local Coordinates Northings Eastings (ft) (ft) 570.28 N 989.62 W 610.96 N 1048.06 W 655.75 N 1109.76 W 704.36 N 1173.17 W 755.77 N 1236.96 W 811.23 N 1302.69 W 863.80 N 1363.24 W 920.16 N 1428.06 W 975.70 N 1494.13 W 1029.60 N 1562.45 W 1081.60 N 1630.24 W 1133.03 N 1697.40 W 1182.67 N 1765.04 W 1233.43 N 1837.16 W 1282.81 N 1906.77 W 1331.13 N 1974.86 W 1380.78 N 2045.86 W 1429.07 N 2115.63 W 1478.84 N 2186.01 W 1528.90 N 2253.29 W 1581.56 N 2322.71 W 1632.68 N 2391.13 W 1683.30 N 2458.60 W 1736.69 N 2527.69 W 1790.35 N 2595.77 W 1842.69 N 2661.10 W 1898.49 N 2727.24 W 1955.38 N 2792.18 W 2012.61 N 2856.83 W 2067.18 N 2919.63 W 2122.19 N 2985.40 W 2178.37 N 3052.75 W 2231.67 N 3117.07 W 2287.45 N 3186.03 W 2341.24 N 3253.87 W Global Coordinates Northings Eastings (ft) (ft) 6036227.06 N 540715.35 E 6036267.41 N 540656.68 E 6036311.85 N 540594.72 E 6036360.10 N 540531.04 E 6036411.16 N 540466.97 E 6036466.24 N 540400.92 E 6036518.48 N 540340.09 E 6036574.47 N 540274.95 E 6036629.64 N 540208.57 E 6036683.15 N 540139.94 E 6036734.77 N 540071.86 E 6036785.82 N 540004.42 E 6036835.08 N 539936.49 E 6036885.43 N 539864.09 E 6036934.43 N 539794.21 E 6036982.36 N 539725.85 E 6037031.62 N 539654.57 E 6037079.51 N 539584.53 E 6037128.89 N 539513.87 E 6037178.56 N 539446.31 E 6037230.84 N 539376.60 E 6037281.57 N 539307.89 E 6037331.81 N 539240.14 E 6037384.82 N 539170.75 E 6037438.09 N 539102.37 E 6037490.06 N 539036.75 E 6037545.49 N 538970.30 E 6037602.01 N 538905.03 E 6037658.87 N 538840.06 E 6037713.09 N 538776.96 E 6037767.74 N 538710.88 E 6037823.54 N 538643.21 E 6037876.48 N 538578.60 E 6037931.87 N 538509.32 E 6037985.28 N 538441.19 E Dogleg Rate (°/100ft) 4.200 3.658 4.627 3.659 4.909 2.200 0.819 0.451 1.943 1.831 0.145 1.434 2.444 0.186 0.487 0.562 0.444 0.373 1.374 1.343 0.333 1.075 1.228 0.993 0.871 1.722 2.336 1.066 1.920 1.792 1.534 0.298 0.696 0.776 0.740 Vertical Section 1133.50 1204.65 1280.88 1360.78 1442.66 1528.54 1608.53 1694.22 1780.41 1867.42 1952.85 2037.44 2121.33 2209.47 2294.79 2378.24 2464.83 2549.61 2635.77 2719.62 2806.76 2892.17 2976.51 3063.82 3150.49 3234.16 3320.56 3406.67 3492.74 3575.74 3661.38 3748.98 3832.43 3921.07 4007.62 Comment BPXA • 14 September, 2005 - 15:31 Page 3 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for MPF-91 Your Ref: AP1500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Milne Point Unii Measured Depth (ft) 6483.21 6575.57 6670.26 6764.08 6858.42 6952.35 7038.09 7170.88 7266.90 7360.49 7456.37 7549.35 7645.54 7739.07 7832.83 7929.46 8025.47 8119.99 8215.65 8311.07 8404.71 8498.23 8592.77 8685.86 8778.28 8873.25 8967.86 9063.75 9156.35 9253.46 9347.69 9440.33 9535.07 9627.90 9723.64 Incl 66.140 66.130 65.640 65.400 65.330 66.400 66.040 64.340 64.870 65.540 65.670 65.610 65.950 66.620 66.560 66.090 64.670 62.950 62.360 62.050 61.340 63.310 63.480 65.140 65.830 66.080 65.620 66.040 66.040 65.820 66.090 69.240 69.230 67.710 65.440 True Azim. 308.450 306.820 306.220 306.080 305.990 306.400 306.150 306.080 307.420 309.080 311.020 312.890 312.600 312.030 310.210 308.520 308.410 308.450 308.920 309.580 309.760 310.310 310.950 310.060 309.350 307.530 307.210 306.840 306.790 306.880 306.460 305.020 306.530 307.050 307.540 Sub-Sea Depth (ft) 4256.24 4293.61 4332.29 4371.17 4410.49 4448.90 4483.47 4539.19 4580.37 4619.62 4659.23 4697.58 4737.04 4774.66 4811.91 4850.72 4890.71 4932.43 4976.37 5020.86 5065.27 5108.70 5151.04 5191.39 5229.74 5268.44 5307.15 5346.41 5384.01 5423.62 5462.01 5497.22 5530.81 5564.87 5602.93 Vertical Depth (ft) 4301.75 4339.12 4377.80 4416.68 4456.00 4494.41 4528.98 4584.70 4625.88 4665.13 4704.74 4743.09 4782.55 4820.17 4857.42 4896.23 4936.22 4977.94 5021.88 5066.37 5110.78 5154.21 5196.55 5236.90 5275.25 5313.95 5352.66 5391.92 5429.52 5469.13 5507.52 5542.73 5576.32 5610.38 5648.44 Local Coordinates Northings Eastings (ft) (ft) 2392.24 N 3318.30 W 2443.81 N 3385.19 W 2495.25 N 3454.64 W 2545.62 N 3523.59 W 2596.06 N 3592.94 W 2646.68 N 3662.11 W 2693.11 N 3725.36 W 2764.15 N 3822.73 W 2816.05 N 3892.23 W 2868.65 N 3958.95 W 2924.83 N 4025.78 W 2981.45 N 4088.77 W 3040.99 N 4153.19 W 3098.64 N 4216.51 W 3155.22 N 4281.33 W 3211.35 N 4349.74 W 3265.64 N 4418.08 W 3318.36 N 4484.52 W 3371.47 N 4550.85 W 3424.87 N 4616.22 W 3477.50 N 4679.68 W 3530.78 N 4743.08 W 3585.82 N 4807.23 W 3640.30 N 4871.02 W 3694.02 N 4935.71 W 3747.93 N 5003.64 W 3800.33 N 5072.25 W 3853.01 N 5142.09 W 3903.72 N 5209.84 W 3956.87 N 5280.80 W 4008.26 N 5349.82 W 4058.30 N 5419.37 W 4110.08 N 5491.24 W 4161,80 N 5560.39 W 4215.02 N 5630.28 W Global Coordinates Northings Eastings (ft) (ft) 6038035.91 N 538376.47 E 6038087.11 N 538309.29 E 6038138.15 N 538239.55 E 6038188.13 N 538170.32 E 6038238.19 N 538100.70 E 6038288.42 N 538031.24 E 6038334.49 N 537967.72 E 6038404.98 N 537869.96 E 6038456.49 N 537800.17 E 6038508.71 N 537733.16 E 6038564.52 N 537666.01 E 6038620.79 N 537602.70 E 6038679.97 N 537537.95 E 6038737.26 N 537474.30 E 6038793.47 N 537409.17 E 6038849.22 N 537340.45 E 6038903.12 N 537271.80 E 6038955.47 N 537205.07 E 6039008.20 N 537138.44 E 6039061.24 N 537072.78 E 6039113.51 N 537009.02 E 6039166.43 N 536945.32 E 6039221.11 N 536880.86 E 6039275.23 N 536816.77 E 6039328.59 N 536751.78 E 6039382.12 N 536683.55 E 6039434.13 N 536614.65 E 6039486.42 N 536544.51 E 6039536.74 N 536476.48 E 6039589.50 N 536405.21 E 6039640.50 N 536335.91 E 6039690.15 N 536266.08 E 6039741.53 N 536193.92 E 6039792.85 N 536124.48 E 6039845.68 N 536054.29 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 0.209 4089.77 1.614 4174.22 0.776 4260.65 0.290 4346.02 0.114 4431.76 1.207 4517.47 0.497 4595.93 1.281 4716,44 1.376 4803.18 1.762 4888.12 1.84$ 4975.31 1.833 5059.69 0.448 5146.98 0.908 5232.24 1.782 5318.06 1.674 5406.48 1.483 5493.73 1.820 5578.52 0.756 5663.45 0.693 5747.80 0.777 5830.15 2.170 5912.86 0.631 5997.22 1.980 6080.95 1.023 6164.94 1.770 6251.64 0.576 6337.97 0.562 6425.45 0.049 6510.07 0.242 6598.74 0.498 6684.79 3.692 6770.44 1.490 6859.00 1.718 6945.35 2.417 7033.19 C7 14 September, 2005 - 15:31 Page 4 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-91 Your Ref: API 500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Milne Point Unit Measured Depth (ft) 9814.05 9907.91 10001.93 10096.67 10188.76 10281.65 10375.38 10468.36 10561.74 10655.01 10749.03 10840.10 10934.25 11027.99 11122.98 11216.69 11309.04 11403.91 11500.04 11593.25 11687.32 11781.55 11876.89 11971.79 12065.49 12161.00 12234.65 12281.73 12324.29 12378.09 12423.36 12473.06 12518.60 12568.87 12614.24 Incl. 65.540 64.470 65.120 65.630 65.970 66.300 66.470 66.500 66.520 65.890 65.220 65.260 65.360 66.080 66.420 66.640 66.710 66.150 65.740 65.150 63.170 60.520 58.000 54.540 49.830 45.230 44.180 43.630 44.990 48.510 49.610 49.760 48.830 49.710 49.670 True Azim. 307.300 307.170 306.510 306.810 307.000 306.710 306.420 306.320 306.380 307.280 307.060 306.980 307.340 307.170 308.000 308.330 309.850 310.090 310.960 311.080 311.270 310.040 308.190 306.520 304.930 304.100 305.720 305.310 306.710 305.560 307.800 307.730 307.300 308.120 308.240 Sub-Sea Depth (ft) 5640.44 5680.10 5720.14 5759.61 5797.36 5834.94 5872.49 5909.59 5946.81 5984.44 6023.35 6061.49 6100.82 6139.36 6177.62 6214.94 6251.51 6289.45 6328.63 6367.36 6408.36 6452.82 6501.56 6554.25 6611.68 6676.15 6728.50 6762.42 6792.88 6829.73 6859.40 6891.55 6921.25 6954.06 6983.41 Vertical Depth (ft) 5685.95 5725.61 5765.65 5805.12 5842.87 5880.45 5918.00 5955.10 5992.32 6029.95 6068.86 6107.00 6146.33 6184.87 6223.13 6260.45 6297.02 6334.96 6374.14 6412:87 6453.87 6498.33 6547.07 6599.76 6657.19 6721.66 6774.01 6807.93 6838.39 6875.24 6904.91 6937.06 6966.76 6999.57 7028.92 Local Coordinates Northings Eastings (ft) (ft) 4265.01 N 5695.61 W 4316.48 N 5763.34 W 4367.48 N 5831.42 W 4418.91 N 5900.51 W 4469.35 N 5967.67 W 4520.30 N 6035.65 W 4571.46 N 6104.62 W 4622.02 N 6173.27 W 4672.78 N 6242.25 W 4723.93 N 6310.56 W 4775.65 N 6378.76 W 4825.44 N 6444.79 W 4877.11 N 6512.96 W 4928.84 N 6580.98 W 4981.87 N 6649.88 W 5034.98 N 6717.46 W 5088.45 N 6783.27 W 5144.31 N 6849.92 W 5201.35 N 6916.64 W 5256.99 N 6980.60 W 5312.73 N 7044.33 W 5366.86 N 7107.34 W 5418.56 N 7170.90 W 5466.45 N 7233.61 W 5509.69 N 7293.67 W 5549.61 N 7351.69 W 5579.25 N 7394.18 W 5598.22 N 7420.75 W 5615.70 N 7444.79 W 5638.80 N 7476.44 W 5659.22 N 7503.86 W 5682.43 N 7533.82 W 5703.46 N 7561.20 W 5726.76 N 7591.34 W 5748.14 N 7618.53 W Global Coordinates Northings Eastings (ft) (ft) 6039895.30 N 535988.68 E 6039946.39 N 535920.67 E 6039997.01 N 535852.30 E 6040048.05 N 535782.92 E 6040098.11 N 535715.48 E 6040148.68 N 535647.22 E 6040199.45 N 535577.95 E 6040249.62 N 535509.02 E 6040300.00 N 535439.76 E 6040350.77 N 535371.17 E 6040402.10 N 535302.67 E 6040451.52 N 535236.37 E 6040502.80 N 535167.91 E 6040554.15 N 535099.60 E 6040606.79 N 535030.41 E 6040659.53 N 534962.53 E 6040712.63 N 534896.41 E 6040768.11 N 534829.46 E 6040824.77 N 534762.42 E 6040880.05 N 534698.14 E 6040935.43 N 534634.10 E 6040989.21 N 534570.79 E 6041040.55 N 534506.94 E 6041088.09 N 534443.96 E 6041130.99 N 534383.66 E 6041170.59 N 534325.42 E 6041199.99 N 534282.77 E 6041218.81 N 534256.09 E 6041236.15 N 534231.94 E 6041259.07 N 534200.16 E 6041279.34 N 534172.63 E 6041302.38 N 534142.54 E 6041323.25 N 534115.04 E 6041346.39 N 534084.78 E 6041367.62 N 534057.46 E Dogleg Rate (°/100ft) 0.266 1.147 0.939 0.610 0.414 0.456 0.337 0.104 0.063 1.112 0.744 0.091 0.363 0.786 0.876 0.399 1.513 0.634 0.930 0.644 2.113 3.039 3.125 3,929 5.202 4.859 2.104 1.315 3.936 6.725 4.458 0.320 2.164 2.143 0.220 Vertical Section 7115.46 7200.52 7285.59 7371.71 7455.71 7540.66 7626.53 7711.79 7797.42 7882.76 7968.35 8051.05 8136.59 8222.04 8308.98 8394.92 8479.66 8566.50 8654.12 8738.69 8823.13 8906.03 8987.91 9066.82 9140.80 9211.16 9262.93 9295.57 9325.29 9364.47 9398.66 9436.55 9471.07 9509.16 9543.75 Comment BPXA • 14 September, 2005 - 15:31 Page 5 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-91 Your Ref: APl 500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 12665.48 46.280 307.350 7017.70 7063.21 5771.47 N 7648.60 W 6041390.78 N 534027.26E 6.740 12710.38 45.500 306.080 7048.96 7094.47 5790.75 N 7674.44 W 6041409.91 N 534001.32E 2.672 12762.30 45.190 306.590 7085.45 7130.96 5812.63 N 7704.19 W 6041431.62 N 533971.44E 0.919 12807.54 46.440 305.820 7116.98 7162.49 5831.79 N 7730.37 W 6041450.63 N 533945.16E 3.021 12856.44 46.010 306.130 7150.81 7196.32 5852.53 N 7758.95 W 6041471.21 N 533916.47E 0.991 12953.58 45.080 307.500 7218.84 7264.35 5894.07 N 7814.46 W 6041512.44 N 533860.72E 1.389 12983.35 44.760 307.420 7239.92 7285.43 5906.86 N 7831.14 W 6041525.14 N 533843.96E 1.092 - 13045.00 44.760 307.420 7283.70 7329.21 - 5933.24 N 7865.62 W - 6041551.32 N 533809.34 E - 0.000 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Aiaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 307.020° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13045.OOft., The Bottom Hole Displacement is 9852.48ft., in the Direction of 307.028° (True). n...,.,........... i.. Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 13045.00 7329.21 5933.24 N 7865.62 W Projected Survey BPXA Vertical Section Comment 9581.81 9614.04 9650.97 9683.41 9718.71 9788.05 . 9809.07 9852.48 Projected Survey 14 September, 2005 - 15:31 Page 6 of 7 Dri/IQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-91 Your Ref: API 500292327100 Job No. AKZZ3896973, Surveyed: 5 September, 2005 Milne Point Unit Survey tool program for MPF-91 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 804.00 804.00 799.87 13045.00 Vertical Depth (ft) Survey Tool Description 799.87 CB-SS-GYRO - Wellnav Gyro 7329.21 MWD+IIFR+MS BPXA • • 14 September, 2005 - 15:31 Page 7 of 7 Dri!lQuest 3.03.06.008 Halliburton Sperry-Sun Milne Point Unit BPXA MPF-91 (mwd) Job No. AKMW3896973, Surveyed: 5 September, 2005 Survey Report 74 September, 2005 Your Ref: API 500292327100 Surface Coordinates: 6035662.34 N, 541708.15E (70° 30' 30.0576" N, 149° 39' 31.4802" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.51ft above Mean Sea Level DRA~:I_I111G sERwICES Survey Ref:svy1544 A Halliburton Company • • Halliburton Sperry-Sun Survey Report for MPF-91 (mwd) Your Ref: API 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -45.51 0.00 0.00 N 0.00E 6035662.34 N 541708.15E 0.00 CB-SS-GYRO - WeIINav 81.00 0.640 90.570 35.49 81.00 0.00 N 0.45E 6035662.34 N 541708.60E 0.790 -0.36 168.00 0.660 106.320 122.48 167.99 0.15 S 1.42E 6035662.20 N 541709.57E 0.206 -1.22 256.00 0.710 3.910 210.48 255.99 0.25 N 1.94E 6035662.60 N 541710.09E 1.214 -1.40 358.00 1.900 323.180 312.45 357.96 2.24 N 0.97E 6035664.58 N 541709.11E 1.410 0.57 437.00 4.290 297.030 391.33 436.84 4.63 N 2.45 W 6035666.95 N 541705.68E 3.439 4.74 525.00 5.260 292.850 479.03 524.54 7.69 N 9.09 W 6035669.98 N 541699.01E 1.170 11.89 614.00 7.340 297.160 567.49 613.00 11.87 N 17.91 W 6035674.11 N 541690.17E 2.395 21.45 709.00 10.210 298.670 661.37 706.88 18.68 N 30.70 W 6035680.85 N 541677.34E 3.031 35.76 804.00 13.330 297.180 754.36 799.87 27.72 N 47.84 W 6035689.80 N 541660.16E 3.299 54.89 MWD Magnetic 835.65 13.780 297.230 785.12 830.63 31.12 N 54.43 W 6035693.15 N 541653.54E 1.422 62.20 932.38 18.420 307.590 878.05 923.56 45.72 N 76.80 W 6035707.63 N 541631.09E 5.624 88.85 1027.07 21.420 309.280 967.07 1012.58 65.80 N 102.05 W 6035727.56 N 541605.73E 3.226 121.09 1122.51 20.450 310.740 1056.21 1101.72 87.71 N 128.17 W 6035749.33 N 541579.49E 1.154 155.15 1218.90 19.560 310.390 1146.78 1192.29 109.16 N 153.22 W 6035770.64 N 541554.32E 0.932 188.06 1312.31 22.590 307.350 1233.94 1279.45 130.18 N 179.40 W 6035791.51 N 541528.02E 3.447 221.62 1407.63 25.220 307.420 1321.07 1366.58 153.63 N 210.09 W 6035814.79 N 541497.20E 2.759 260.24 1501.02 23.480 306.970 1406.15 1451.66 176.91 N 240.75 W 6035837.90 N 541466.41E 1.874 298.74 1595.15 22.530 303.590 1492.80 1538.31 198.17 N 270.76 W 6035858.99 N 541436.28E 1.728 335.50 1689.43 22.420 302.740 1579.92 1625.43 217.89 N 300.93 W 6035878.53 N 541406.00E 0.364 371.46 1786.25 21.650 301.810 1669.66 1715.17 237.29 N 331.64 W 6035897.76 N 541375.18E 0.873 407.66 1881.09 20.410 303.000 1758.19 1803.70 255.51 N 360.38 W 6035915.83 N 541346.35E 1.383 441.58 1976.79 19.920 300.090 1848.02 1893.53 272.78 N 388.48 W 6035932.93 N 541318.15E 1.166 474.41 2071.58 23.950 297.100 1935.94 1981.45 289.64 N 419.59 W 6035949.62 N 541286.94E 4.410 509.40 2166.92 23.570 297.360 2023.19 2068.70 307.22 N 453.75 W 6035967.01 N 541252.69E 0.413 547.26 2262.11 25.290 297.300 2109.86 2155.37 325.29 N 488.72 W 6035984.89 N 541217.61E 1.807 586.06 2352.53 27.130 295.370 2190.98 2236.49 342.99 N 524.51 W 6036002.38 N 541181.72E 2.242 625.30 2449.74 30.720 292.000 2276.05 2321.56 361.79 N 567.58 W 6036020.94 N 541138.55E 4.055 671.00 2544.51 34.620 293.020 2355.82 2401.33 381.40 N 614.82 W 6036040.28 N 541091.20E 4.156 720.52 2637.12 37.900 292.980 2430.48 2475.99 402.79 N 665.23 W 6036061.39 N 541040.67E 3.542 773.66 2730.79 38.030 293.740 2504.33 2549.84 425.64 N 718.13 W 6036083.94 N 540987.64E 0.518 829.65 2826.26 38.950 296.610 2579.06 2624.57 450.93 N 771.89 W 6036108.92 N 540933.74E 2.104 887.79 2919.72 41.030 300.810 2650.68 2696.19 479.80 N 824.51 W 6036137.51 N 540880.96E 3.645 947.20 3015.01 42.900 302.400 2721.53 2767.04 513.21 N 878.77 W 6036170.60 N 540826.52E 2.257 1010.63 3108.85 45.940 302.360 2788.54 2834.05 548.38 N 934.23 W 6036205.46 N 540770.86E 3.240 1076.09 • • 14 September, 2005 - 15:28 Page 2 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-91 (mwd) Your Ref: API 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 Milne Poinf Unit Measured Depth (ft) 3205.83 3298.16 3392.15 3486.50 3579.61 3674.79 3762.74 3856.85 3951.43 4046.31 4139.18 4231.63 4323.46 4419.55 4512.47 4603.43 4698.04 4790.89 4885.30 4977.07 5072.45 5166.34 5259.05 5354.93 5450.65 5542.83 5637.28 5731.58 5826.90 5919.25 6013.71 6109.71 6201.20 6298.55 6393.39 Incl 49.230 52.450 56.720 59.770 64.270 65.760 66.220 65.810 66.180 67.100 66.980 65.690 66.650 66.850 66.860 66.570 66.310 66.040 66.050 66.240 66.030 65.140 66.020 65.430 64.600 66.100 66.910 65.910 64.190 64.590 66.040 66.230 65.820 65.680 66.360 True Azim. 307.010 307.130 310.140 309.730 308.410 311.010 312.770 311.790 309.930 311.080 309.700 309.130 306.460 308.140 308.390 306.550 306.430 305.360 305.800 306.330 304.170 306.150 307.030 306.080 305.960 312.400 313.940 312.390 312.940 312.070 310.050 310.560 310.300 311.450 312.670 Sub-Sea Depth (ft) 2853.97 2912.26 2966.73 3016.38 3060.05 3100.26 3136.05 3174.30 3212.78 3250.40 3286.63 3323.74 3360.85 3398.78 3435.30 3471.26 3509.08 3546.59 3584.92 3622.03 3660.62 3699.44 3737.76 3777.18 3817.61 3856.09 3893.75 3931.49 3971.69 4011.61 4051.06 4089.90 4127.08 4167.06 4205.61 Vertical Depth {ft) 2899.48 2957.77 3012.24 3061.89 3105.56 3145.77 3181.56 3219.81 3258.29 3295.91 3332.14 3369.25 3406.36 3444.29 3480.81 3516.77 3554.59 3592.10 3630.43 3667.54 3706.13 3744.95 3783.27 3822.69 3863.12 3901.60 3939.26 3977.00 4017.20 4057.12 4096.57 4135.41 4172.59 4212.57 4251.12 Local Coordinates Northings Eastings (ft) (ft) 589.16 N 993.02 W 632.31 N 1050.13 W 680.15 N 1109.91 W 731.64 N 1171.42 W 783.44 N 1235.25 W 838.56 N 1301.61 W 892.20 N 1361.41 W 950.04 N 1425.02 W 1006.56 N 1490.37 W 1063.14 N 1556.59 W 1118.55 N 1621.72 W 1172.31 N 1687.13 W 1223.78 N 1753.51 W 1277.28 N 1823.73 W 1330.19 N 1890.82 W 1381.02 N 1957.13 W 1432.59 N 2026,85 W 1482.39 N 2095.65 W 1532.59 N 2165.82 W 1582.00 N 2233.67 W 1632.34 N 2304.89 W 1681.56 N 2374.79 W 1731.88 N 2442.56 W 1783.94 N 2512.77 W 1834.96 N 2582.94 W 1887.87 N 2647.82 W 1947.13 N 2710.99 W 2006.25 N 2774.02 W 2064.82 N 2837.57 W 2121.09 N 2898.96 W 2177.45 N 2963.67 W 2234.24 N 3030.63 W 2288.45 N 3094.26 W 2346.54 N 3161.37 W 2404.59 N 3225.70 W Global Coordinates Northings Eastings {ft) (ft) 6036245. 91 N 540711. 84 E 6036288. 74 N 540654. 48 E 6036336. 25 N 540594. 44 E 6036387. 39 N 540532. 64 E 6036438. 83 N 540468. 52 E 6036493. 58 N 540401. 86 E 6036546. 88 N 540341. 75 E 6036604. 37 N 540277. 81 E 6036660. 52 N 540212. 16 E 6036716. 72 N 540145. 61 E 6036771. 77 N 540080. 18 E 6036825. 16 N 540014. 46 E 6036876. 25 N 539947. 80 E 6036929. 36 N 539877. 27 E 6036981. 89 N 539809. 89 E 6037032. 35 N 539743. 30 E 6037083. 53 N 539673. 29 E 6037132. 94 N 539604. 21 E 6037182. 74 N 539533. 76 E 6037231 .77 N 539465. 64 E 6037281 .71 N 539394. 13 E 6037330 .54 N 539323. 96 E 6037380 .48 N 539255. 90 E 6037432. 14 N 539185. 40 E 6037482 .77 N 539114. 95 E 6037535 .32 N 539049. 77 E 6037594 .22 N 538986 .27 E 6037652 ,99 N 538922. 91 E 6037711 .20 N 538859 .04 E 6037767 .12 N 538797 .33 E 6037823 .11 N 538732 .30 E 6037879 .53 N 538665 .03 E 6037933 .38 N 538601 .09 E 6037991 .09 N 538533 .65 E 6038048 .78 N 538469 .00 E BPXA Dogleg Vertical Rate Section Comment {°/100ft) 4.901 1147.58 3.489 1219.16 5.239 1295.70 3.254 1375.81 4.992 1457.96 2.929 1544.13 1.901 1624.17 1.046 1709, 79 1.839 1795.99 1.476 1882.93 1.374 1968.29 1.505 2052.89 2.858 2136.87 1.620 2225.16 0.248 2310.58 1.885 2394.12 0.298 2480,84 1.094 2565.76 0.426 2652.01 0.567 2735.93 2.083 2823.11 2.141 2908.55 1.284 2992.96 1.093 3080.36 0.875 3167.11 6.554 3250.76 1.724 3336.88 1.842 3422.80 1.879 3508.80 0.954 3591.69 2.476 3677.30 0.525 3764.95 0.518 3848.40 1.087 3936.95 1.377 4023.27 • • 14 September, 2005 - 15:28 Page 3 of 7 Dri1/Quest 3.03.06.008. Halliburton Sperry-Sun Survey Report for MPF-91 (mwd) Your Ref: API 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 Milne F'oint Unix Measured Depth (ft) 6483.21 6515.57 6670.26 6764.08 6858.42 69:52.35 7038.09 7170.88 7266.90 7360.49 7456.37 7549.35 7645.54 7739.07 7832.83 7929.46 8025.47 8119.99 8215.65 8311.07 8404.71 8498.23 8592.77 8685.86 8778.28 8873.25 8967.86 9063.75 9156.35 9253.46 9347.69 9440.33 9535.07 9627.90 9723.64 Incl. 66.230 66.220 65.760 65.490 65.420 66.500 66.160 64.340 64.880 65.550 65.680 65.620 65.960 66.640 66.570 66.100 64.670 62.960 62.370 62.060 61.350 63.320 63.490 65.160 65.840 66.100 65.630 66.050 66.050 65.830 66.110 69.250 69.240 67.720 65.440 True Azim. 311.250 308.520 306.830 306.980 306.960 307.050 307.260 306.280 307.330 309.690 311.990 314.770 313.510 313.020 310.680 308.880 309.040 309.710 309.970 310.160 310.250 311.790 311.270 310.010 310.260 309.230 308.880 308.430 308.130 306.980 306.630 306.460 306.820 307.010 304.590 Sub-Sea Depth (ft) 4241.72 4278.96 4317.49 4356.21 4395.40 4433.67 4468.09 4523.68 4564.85 4604.09 4643.68 4682.03 4721.47 4759.07 4796.30 4835.09 4875.08 4916.79 4960.71 5005.19 5049.58 5093.00 5135.32 5175.66 5213.98 5252.66 5291.34 5330.59 5368.18 5407.77 5446.14 5481.32 5514.89 5548.94 5587.00 Vertical Depth (ft) 4287.23 4324.47 4363.00 4401.72 4440.91 4479.18 4513.60 4569.19 4610.36 4649.60 4689.19 4727.54 4766.98 4804.58 4841.81 4880.60 4920.59 4962.30 5006.22 5050.70 5095.09 5138.51 5180.83 5221.17 5259.49 5298.17 5336.85 5376.10 5413.69 5453.28 5491.65 5526.83 5560.40 5594.45 5632.51 Local Coordinates Northings Eastings (ft) (ft) 2459.57 N 3286.86 W 2513.77 N 3351.71 W 2566.63 N 3420.16 W 2617.95 N 3488.50 W 2669.55 N 3557.06 W 2721.19 N 3625.56 W 2768.61 N 3688.15 W 2840.80 N 3784.74 W 2892.77 N 3854.19 W 2945,68 N 3920.67 W 3002.78 N 3986.73 W 3060.95 N 4048.29 W 3122.04 N 4111.25 W 3180.74 N 4173.61 W 3238.15 N 4237.70 W 3294.77 N 4305.71 W 3349.66 N 4373.58 W 3403.46 N 4439.15 W 3457.90 N 4504.40 W 3512.24 N 4569.01 W 3565.46 N 4631.98 W 3619.83 N 4694.46 W 3675.87 N 4757.74 W 3730.51 N 4821.41 W 3784.72 N 4885.70 W 3840.18 N 4952.40 W 3894.58 N 5019.44 W 3949.22 N 5087.76 W 4001.65 N 5154.20 W 4055.70 N 5224.49 W 4107.26 N 5293.40 W 4158.28 N 5362.24 W 4211.15 N 5433.33 W 4263.02 N 5502.37 W 4314.41 N 5573.61 W Global Coordinates Northings Eastings (ft) (ft) 6038103.42 N 538407.53 E 6038157.25 N 538342.38 E 6038209.73 N 538273.63 E 6038260.66 N 538205.01 E 6038311.88 N 538136.16 E 6038363.13 N 538067.37 E 6038410.20 N 538004.51 E 6038481.85 N 537907.52 E 6038533.43 N 537837.78 E 6038585.96 N 537771.00 E 6038642.69 N 537704.62 E 6038700.51 N 537642.74 E 6038761.25 N 537579.44 E 6038819.60 N 537516.75 E 6038876.64 N 537452.33 E 6038932.89 N 537384.00 E 6038987.39 N 537315.83 E 6039040.82 N 537249.96 E 6039094.89 N 537184.41 E 6039148.87 N 537119.50 E 6039201.74 N 537056.23 E 6039255.75 N 536993.44 E 6039311.44 N 536929.84 E 6039365.72 N 536865.87 E 6039419.57 N 536801.27 E 6039474.65 N 536734.27 E 6039528.67 N 536666.92 E 6039582.94 N 536598.29 E 6039634.99 N 536531.57 E 6039688.64 N 536460.97 E 6039739.81 N 536391.77 E 6039790.45 N 536322.65 E 6039842.92 N 536251.26 E 6039894.40 N 536181.93 E 6039945.39 N 536110.41 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 1.455 4105.20 2.705 4189.61 1.701 4276.10 0.323 4361.55 0.077 4447.37 1.153 4533.15 0.456 4611.68 1.526 4732.26 1.137 4819.00 2.399 4903.93 2.189 4991.06 2.725 5075.24 1.246 5162.29 0.871 5247.42 2.292 5333.16 1.774 5421.56 1.497 5508.79 1.918 5593.53 0.662 5678.41 0.370 5762.71 0.763 5845.03 2.562 5927.65 0.524 6011.92 2.169 6095.65 0.776 6179.62 1.028 6266.26 0.601 6352.55 0.613 6440.00 0.296 6524.61 1.105 6613.28 0.451 6699.34 3.394 6785.02 0.355 6873.61 1.648 6959.97 3.324 7047.79 • • 14 September, 2005 - 15:28 Page 4 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for MPF-91 (mwd) Your Ref: APl 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 Milne Point Unii Measured Depth (ft) 9814.05 9907.91 10001.93 10096.67 10188.76 10281.65 10375.38 10468.36 10561.74 10655.01 10749.03 10840.10 10934.25 11027.99 11122.98 11216.69 11309.04 11403.91 11500.04 11593.25 11687.32 11781.55 11876.89 11971.79 12065.49 12161.00 12234.65 12281.73 12324.29 12378.09 12423.36 12473.06 12518.60 12568.87 12614.24 Incl. 64.540 64.480 65.140 65.640 65.980 66.320 66.480 66.510 66.530 65.900 65.230 65.270 65.370 66.100 66.440 66.650 66.720 66.160 65.750 65.160 63.170 60.520 57.990 54.530 49.820 45.210 44.180 43.630 44.990 48.510 49.610 49.760 48.830 49.710 49.670 True Azim. 307.110 306.140 308.320 308.230 307.680 306.620 307.450 306.810 308.190 309.130 309.000 308.930 308.780 308,420 307.940 306.770 310.140 307.260 311.530 311.530 312.410 310.080 308.550 306.810 305.720 304.760 306.070 305.630 307.480 306.370 307.360 308.130 307.550 308.380 308.480 Sub-Sea Depth (ft) 5625.23 5665.62 5705.64 5745.10 5782.83 5820.39 5857.92 5895.00 5932.21 5969.82 6008.72 6046.84 6086.16 6124,68 6162.91 6200.21 6236.77 6274.69 6313.88 6352.60 6393.59 6438.05 6486.79 6539.50 6596.94 6661.43 6713.79 6747.71 6778.16 6815.02 6844.69 6876.84 6906.54 6939.34 6968.69 Vertical Depth (ft) 5670.74 5711.13 5751.15 5790.61 5828.34 5865.90 5903.43 5940.51 5977.72 6015.33 6054.23 6092.35 6131.67 6170,19 6208.42 6245.72 6282.28 6320.20 6359.39 6398.11 6439.10 6483.56 6532.30 6585.01 6642.45 6706.94 6759.30 6793.22 6823.67 6860.53 6890.20 6922.35 6952.05 6984.85 7014.20 Local Coordinates Northings Eastings (ft) (ft) 4362.39 N 5640.01 W 4412.93 N 5708.01 W 4464.40 N 5775.74 W 4517.76 N 5843.36 W 4569.42 N 5909.59 W 4620.73 N 5977.31 W 4672.46 N 6045.87 W 4723.93 N 6113.85 W 4776.06 N 6181.80 W 4829.38 N 6248.44 W 4883.32 N 6314.90 W 4935.33 N 6379.21 W 4989.00 N 6445.83 W 5042.32 N 6512.62 W 5096.07 N 6580.97 W 5148.23 N 6649.31 W 5200.96 N 6715.71 W 5255.33 N 6783.56 W 5311.02 N 6851.39 W 5367.24 N 6914.86 W 5423.85 N 6977.81 W 5478.63 N 7040.25 W 5530.55 N 7103.63 W 5578.79 N 7166.06 W 5622.58 N 7225.70 W 5663.23 N 7283.20 W 5693.24 N 7325.42 W 5712.36 N 7351.88 W 5730.07 N 7375.75 W 5753.60 N 7407.08 W 5774.11 N 7434.44 W 5797.31 N 7464.40 W 5818.49 N 7491.66 W 5841.93 N 7521.70 W 5863.43 N 7548.80 W Global Coordinates Northings Eastin gs (ft) (ft) 6039992. 99 N 536043. 73 E 6040043. 15 N 535975. 46 E 6040094. 24 N 535907. 44 E 6040147. 22 N 535839. 52 E 6040198. 51 N 535772. 99 E 6040249. 43 N 535704. 99 E 6040300. 78 N 535636. 14 E 6040351. 86 N 535567. 87 E 6040403. 62 N 535499. 63 E 6040456. 56 N 535432. 69 E 6040510. 13 N 535365. 93 E 6040561. 78 N 535301. 33 E 6040615. 07 N 535234. 41 E 6040668. 01 N 535167. 32 E 6040721. 38 N 535098. 67 E 6040773. 15 N 535030. 04 E 6040825. 51 N 534963. 35 E 6040879. 50 N 534895. 19 E 6040934. 81 N 534827. 05 E 6040990. 67 N 534763. 26 E 6041046. 93 N 534700. 00 E 6041101. 35 N 534637. 25 E 6041152. 92 N 534573. 58 E 6041200. 81 N 534510. 88 E 6041244. 26 N 534450. 99 E 6041284. 58 N 534393. 27 E 6041314. 36 N 534350. 88 E 6041333 .33 N 534324. 32 E 6041350 .91 N 534300. 34 E 6041374 .26 N 534268. 88 E 6041394 .62 N 534241. 41 E 6041417 .65 N 534211. 32 E 6041438 .68 N 534183. 93 E 6041461 .94 N 534153. 77 E 6041483 .29 N 534126. 55 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 2.715 7129.69 0.935 7214.41 2.212 7299.49 0.535 7385.60 0.658 7469.59 1.106 7554.55 0.829 7640.44 0.632 7725.70 1.356 7811.34 1.143 7896.65 0.724 7982.20 0.082 8064.85 0.180 8150.36 0.854 6235.79 0.585 8322.73 1.167 8408.69 3.352 8493.46 2.845 8580.37 4.079 8668.05 0.633 8752.58 2.277 8836.93 3.558 8919.76 2.991 9001.63 3.952 9080.52 5.110 9154.50 4.883 9224.88 1.876 9276.66 1.336 9309.30 4.408 9339.03 6.713 9378.21 2.938 9412.40 1.219 9450.29 2.259 9484.81 2.152 9522.90 0.190 9557.49 • • 14 September, 2005 - 15:28 Page 5 of 7 DrillQuest 3.03.06.008 Halliburfon Sperry-Sun Survey Report for MPF-91 (mwd) Your Ref: AP! 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 Milne Point Unit Measured .True Sub-Sea Vertical Local Coord inates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12665.48 46.280 307.470 7002.99 7048.50 5886.86 N 7578.79 W 6041506.55 N 534096.42 E 12710.38 45.500 306.140 7034.24 7079.75 5906.17 N 7604.60 W 6041525.72 N 534070.51 E 12762.30 45.190 306.770 7070.73 7116.24 5928.12 N 7634.31 W 6041547.50 N 534040.68 E 12807.54 46.440 306.040 7102.27 7147.78 5947.37 N 7660.42 W 6041566.60 N 534014.46 E 12856.44 46.010 306.600 7136.10 7181.61 5968.28 N 7688.87 W 6041587.35 N 533985.89 E 12953.58 45.080 308.000 7204.13 7249.64 6010.29 N 7744.03 W 6041629.05 N 533930.50 E 12983.35 44.760 307.700 7225.21 7270.72 6023.19 N 7760.62 W 6041641.86 N 533913.83 E 13045.00 44.760 307.700 7268.98 7314.49 6049.73 N 7794.97 W 6041668.21 N 533879.33 E Ail data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 307.020° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13045.OOft., The Bottom Hole Displacement is 9867.16ft., in the Direction of 307.815° (True). Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 13045.00 7314.49 6049.73 N 7794.97 W Projected Survey Dogleg Vertical Rate Section Comment (°/100ft) 6.776 9595.54 2.746 9627.78 1.050 9664.71 2.996 9697.15 1.207 9732.45 1.405 9801.78 1.289 9822.80 0.000 9866.21 Projected Survey BPXA • • 14 September, 2005 - 15:28 Page 6 of 7 DrillQuest 3.03.06.008 Milne Point Unit Halliburton Sperry-Sun Survey Report for MPF-91 (mwd) Your Ref: API 500292327100 Job No. AKMW3896973, Surveyed: 5 September, 2005 Survey tool program for MPF-91 (mwd) From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 804.00 804.00 799.87 13045.00 Vertical Depth Survey Tool Description (ft) 799.87 CB-SS-GYRO - WeIINav 7314.49 MWD Magnetic BPXA • 14 September, 2005 - 15:28 Page 7 of 7 DrillQuest 3.03.06.008 • • 16-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPF-91 Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 13,045.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchoragge, AK 99518 Date U ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a,~ ~ -1 l ~ • • 16-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-91 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 13,045.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date~~_ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ ~ -~tc~ 10/28/05 Schiumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth weu i,.ti ~ ~~ ~...,, yt.„~,;~.~ s~ ~ Slug ~~~, to ~~,3.~;ll~y ~_ NO. 3511 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. MPF-91 11090718 SCMT (PDC-GR) Q ~ 10/18/05 .. 1v, 1 F-346 10913019 OH LDWG EDIT PEX-AIT-DSI-POR-TCOM-MSGT 04/20/05 1 F-34B 10913019 PEX-AIT 04/20/05 1 F-346 10913019 PEX-POROSITY 04/20/05 1 F-346 10913019 PEX-TCOM 04/20/05 1 F-346 10913019 MSCT 04/20/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~` ~~- Date Delivered: ~~ ~~ ~ ~~ ~ 1~i=~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ ~ ~ ~~ ~~ >~5 .~~ ~_ c~3 i • ~_/ ~ ) MEMORANDUM • Toy Jim Regg cj P.I. Supervisor ~'~j ~ ~ ~ rUS FROtit: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 09, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-91 MILNE PT LJN1T KR F-91 Src: Inspector NON-CONFIDENTIAL ~~{~~ Reviewed By:_ n P.I. Suprv ,-.J#~~- Comm Well Name: MILNE PT UNIT KR F-91 Insp Num: mitCS051107141705 Rel Insp Num API Well Number Permit Number: 50-029-23271-00-00 205-110-0 Inspector Name: Chuck Scheve Inspection Date: 11/7/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ F'91 jType Inj. ~'~' ~ TVD ~ 6322 i IA o ~ zoao ~ 2000 ~ zooo ~ p T 2osnoo ~TypeTest j SPT ~ Test psi j Issos OA o j o ~ o o Interval ~T~- P/F P Tubing z9oo i z9oo ' z9oo ~ z9oo Notes Wednesday, November 09, 2005 Page 1 of 1 r. _ ,,.. . _. ^~~ WELL LOG TRANSNIITTAL To: State of Alaska October 24, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-91, AK-MW-3896973 1 LIS formatted Disc with verification listing. ~ 3 3 ~ 3 API#: 50-029-23271-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99649-6612 ~~-~.~- ~ Datc: 5 Si~ncd: ~c~~ -i~~ a M • a :~,,~ . ) ~ ~ '`~~~ ~ ~'~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR °~-7~~ O~ ~ ~ 333 W. 7'" AVENUE, SUITE 100 CO1~T5ERQA'1`IO1Q COl-i1~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 8, 2005 Mr. Skip Coyner Drilling Engineer BP Exploration (Alaska) Inc. ACT PO Box 196612 Anchorage, AK 99519 Re: Request for Waiver of Diverter Requirements at 20 AAC 25.035 (c) Milne Point Unit F-89..:~--'~fl Dear Mr. Coyner: We have received your request for exception to the Diverter requirements at 20 AAC 25.035 (c) for Milne Point F-91. In support of this request, you relate information regarding the number of wells drilled on MPU F Pad including the surface hole strata anticipated, structural setting for the Schrader Bluff formation in the area and the absence of any indications of shallow gas (free or hydrate) or over-pressure while drilling prior wells. The majority of wells on F Pad are completed in the Kuparuk River formation with a few wells completed in the Sag River. There are no Schrader Bluff wells and the nearest Schrader injection well is some 3.5 miles to the SE. MPF-91 is the third well planned in the latest drilling campaign. No surface hole drilling problems were encountered on either MPF-89 or MPF-93. The Commission agrees that the record does .not reveal any known problems with natural pressure or shallow gas on F Pad. A possibility does exist for production operations to "induce" shallow hazards if there is a compromise to a well's integrity during normal operations. At this time, the Commission has not been notified that any casing integrity problem exists for any production or injection well on F Pad. MPF-17 is a water injection well presently operating with T x IA communication. Regardless of the past drilling history in the F Pad area, the operator must be prepared to accommodate drilling hazards that may develop over time. Each well should be carefully monitored to detect any developing drilling hazards, and subsequent operations conducted accordingly. Dialogue with Milne Point operations should be ongoing so that any changes in injection well performance are highlighted. ~ ~ ~ / Mr. Skip Coyner August 4, 2005 Page 2 of 2 Your request to waiver for the diverfer requirements for MPF-91 (205-110) is hereby APPROVED. This approval is specifically for MPF-91 f waivers for additional wells on MPF pad are desired, your request should be incl ed ith the Permit to Drill as done here. Please contact Tom Maunder, PF~t~93-1 w any questions. airrr4an cc: Daniel Seamount, Commissioner Cathy Foerster, Commissioner ~ ~ ~ ~~, ,, a ~ ~„ ~ 3 0' a ~ ~a t "~ ~ ~ ~ ~ ,~ j ~ ~ r ~„ ~ ± "?~ ~ ~ ~ '~, w ' FRANK H. MURKOWSKI, GOVERNOR '~ ~ a ALASSA OIL A1QD GAS ~ ~` 333 W. 7T" AVENUE, SUITE 100 COI~TSERQA'I`IO1Q CO1~iISSIOIQ ~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPF-91 BP Exploration (Alaska) Inc. Permit No: 205-110 Surface Location: 2211' FSL, 2853' FEL, SEC. 06, T13N, R10E, UM Bottomhole Location: 2861' FSL, 285' FEL, SEC. 35, T14N, R09E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Com >pector at (907) 659- 3607 (pager). DATED this~day of August, 2005 cc: Department of Fish 8~ Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ t~ °'~`l ALASKA OIL AND GAS CONSERVATION COn~MISSION PERMIT TO DRILL q~~~k ~~; ~~~ 20 AAC 25.005 ~'~rt.~ ~;,. 1a. Type of work ®Dnll ^Redrill ^ Re-Entry 1b. Current Well Gass ^ Exploratory ^ Developm pp#~ Multip ^ Stratigraphic Test ®Service ^ Development Gas Single Zone " 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: MPF-91 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 13038 ' T~/p 7314 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of We11 (Governmental Section): Surface: 2211' FSL 2853' FEL SEC. 06 T13N R10E UM ~ 7. Property Designation: ADL 355018 Sands , , , , , Top of Productive Horizon: 2602' FSL, 5232' FEL, SEC. 36, T14N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 15, 2005 Total Depth: 2861' FSL, 285' FEL, SEC. 35, T14N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 5330' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541708 ~ y- 6035662 'Zone- ASP4 10. KB Elevation Planned (Height above GL): 47 feet 15. Distance to Nearest well Within Pool 1115' from MPF-46 16. Deviated Wells: Kickoff Depth: 300 'feet Maximum Hole Angle: 65.6 % de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4000 i Surface: 3306 1 asing rogram: Size Specifications Setting Depth To Bottom uantrty'o ement c.f. or sacks. Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 92# H-40 Welded 80' 34' 34' 114' 114' 60 sx Arctic Set A rox. 13-1 /2" 10-3/4" 45.5# L-80 BTC 7048' 30' 30' 7078' 4546' 97 sx AS Lite, 443 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 12223' 30' 30' 12253' 6791' 305 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT-M 938' 12100' 6688' 13038' 7314' 165 sx Class 'G' '19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD t P Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 to the best of my knowledge. Contact Skip Coyner, 564-4395 Printed Name Dan Kara Title Senior Drilling Engineer Prepared ey Name/Number: Si nature - Phone 564-5667 Date 7 ~ o S Teme Hubble, 564-4628 Commission Use Only Permit To Drill Number: 2C~.S //d API Number: 50_ O ~- 2 3Z'7/- GNU Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples R fired ^ Yes ,~No Mud Log Required ^ Yes ~'No Hydrog u de Measures ~~.Y_es [] No Directional Survey Required 'Yes ^ No \ Other: L.1O ~; ~ ~ -E aS ~~~r~I~~J , Q1v~C'~t` v~Ci~ v~„r~ a~~~. a--S~C~3 ~ ~,~~`~ ) APPROVED BY A roved THE COMMISSION Date Form 10-401 Revised Od>«2964 ~_ ~Subr~t In Duplicate ~~ ! iii-..+ 1 1 M 1 i) ~rt, July 14~', 2005 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Exception to 20 AAC 25.035 (c) Request for Variance to 20 AAC 25.035 (e)(10)C MPU F-Pad /MPF-91 Mr. Maunder: BP Exploration (Alaska) Inc. ("BP") hereby requests an exception to 20 AAC 25.035(c) in accordance with 20 AAC 25.035(h)(2) allowing Doyon 14 to drill the surface hole without using a diverter. The requested exception pertains to the drilling of MPF-91, a Kuparuk A sand injector. The MPF-91 well plan includes 10-3/4" surface casing to be set through the Schrader Bluff sands. It is this hole section for which this exception is requested. Recently BP successfully drilled and cased the same hole section in MPF-93 without a diverter. The surface hole section in MPF-93 was drilled with 9.3 ppg mud and there were no indications of gas or other "flow to surface" hazards in MPF-93, thus confirming the continued benign nature of this hole section as drilled from MPU F Pad. The only potential hydrocarbon bearing zone in this hole section is the Schrader Bluff "O" sands. The Schrader Bluff "O" sands that underlie F-Pad are low on structure, and in most cases, water bearing. Any potential oil bearing sands in this hole section would not be capable of flow to surface. Additionally, the nearest Schrader Bluff injection well, MPJ-15i, is located 3.5 miles away and it's surrounded by producers (see attached map). Additionally, BP Exploration (Alaska) Inc. ("BP") hereby requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." If you have any questions or require any additional information, please contact the undersigned at 564-4395, or Dan Kara at 564-5803. Sincerely, Skip yner Drilling Engineer BPXA /ACT • • Top Schrader Time-Structure Map with current Schrader Bluff injectors r F-Pad is 3.5 miles nearest Schrader Bluff injector MPJ-15i ~ ~ ~ • by Well Name: MPF-91 Kuparuk A Sand Injector Drilling and Completion Plan Summary T e of Well: Ku aruk A Sand In'ector ~ Surface Location: 2211' FSL and 2853' FEL - Section 6 T13N R10E UM ' , , , E = 541,708' N = 6,035,662' Top Kuparuk D at 12,471' MD 2602' FSL and 48' FWL Section 36, T14N, R9E UM E = 534,141' N = 6,041,294' Z = 6916' TVD T/Kuparuk A at 12,688' MD 2701' FSL and 80' FEL Section 35, T14N, R9E UM E = 534,013' N = 6,041,392' Z = 7081' TVD BHL at 13,038' MD 2861' FSL and 285' FEL Section 35, T14N, R9E UM E = 533,807' N = 6,041,551' Z = 7314' TVD Distance to Pro a line 5,330' Distance to nearest well 1,115' from MPF-46 AFE Number: Ri Do on 14 Estimated Start Date: 8/15/2005 ~ Ri da s to com fete: 19.5 MD: 13,038' TVD: 7,314' Max Inc: 65.6° KOP: 300' KBE: 47' Well Desi n: "S-Curve", Ku aruk A sand, In'ector with Intermediate Casin Ob'ective: Ku aruk A Sand • Mud Program: 13-1/2" Surface Hole 0' - 7078' • LSND Densi PV YP HTHP H API Filtrate LG Solids 8.6-9.3 10-20 25-30 10-11 9.0-9.5 <6 <15 9-7/8" Intermediate Hole (7078' -12253'): LSND Densi PV YP HTHP H API Filtrate LG Solids 8.8-9.6 10-20 20-30 10- 11 9.0-9.5 <6 < 15 6-3/4" Kuparuk Section (12253' -13038'): LSND Densi PV YP HTHP H API Filtrate LG Solids 9.0-10.5 8-15 20-28 10-11 9.0-9.5 <6 <10 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Recommended Bit Program: BHA Hole Size Depth (MQ) Footage Bit Type TFA GPM 1 13.50 in Surf - 7,078' 7,078' MXC1 .75 - .90 450 - 650 2 9.875 in 7,078' -12,253' 5,175' PDC .50 - .75 400 - 550 3 6.75 in 12,253' - 13,038' 785' HCM-5052 .30 - .50 250 - 300 Casing/Tubing Program Hole Size Csg / Tb O.D. Wt/Ft Grade CPLG Length Top MD / TVD Bottom MD / TVD 42" 20" 92# H-40 Welded 80' 34' 114' / 114' 13.5" 10.75" 45.5# L-80 BTC 7,048' 30' 7,078' / 4,546' 9.875" 7.625" 29.7# L-80 BTC-M 12,223' 30' 12,253' / 6,791' 6.75" 4.5" 12.6# L-80 IBT-M 938' 12,100'/6,688' 13,038' / 7,314' Evaluation Program: 13-1/2" Section Open Hole: MWD/GR IFR/CASANDRA S er InSite G ro as needed 9-7/8" Section Open Hole: MWD/GR/RES/PWD IFR/CASANDRA S er InSite 6-3/4" Section Open Hole: MWD/GR/RES IFRlCASANDRA S er InSite 2 dement Program: i~ Casin Size 10-3/4", 45.5, L-80, BTC Surface Casin at 7,078' MD Excess from B/Permafrost to Surface = 150% over gaug ole. Use Basis / 2-Stage 30% excess below the B/Permafrost (1963' MD). 85' Shoe Track. H-ES cementer at 2500' MD. Stage I 10 bbl water Total Cement Wash & Spacer 20 bbl CW 100 Volume: 260.4 bbl 5 udPu h '~ 210.5 bbl, 2 66.4 sx of Arctic et L ' 0.7 ppg and Led 4.44 ft3/sx 8 bbl mix d at 15.8 lb/gal & 1.17 Tail ft3/sx Stage II Wash & 10 bbl water ~~ ~ ~~ votal Cement Spacer 20 bbl CW 100 olume: 382.7 bbl 50 bbl of MudP h p~. Lead 340.6 bbl, 431 x of Arctic Set Late: 10.7 ppg and 4.44 ft3/sx 42.1 bbl, 2 sx "G" mixed at 15.8 lb/gal & 1.17 Tail ft3/sx --~ Casin Size 7-5/8", 29.7#, L-80 TC-M Intermediate Casin at 3' M Basis Top of cement to a 1000' MD above the shoe: % excess. Shoe Joint = 12 ft OC = 13,038' MD Total Cement Volume: 63.1 bbl Wash & Spacer 5- I water, 25 bbl CW 100 4 bbl of MudPush Tail 3.1 bbl, 304.5 sx "G" mixed at 15.8 Ib/ al & 1.20 ft /sx Tem BHST =150°F from Schlumber er Chart Liner Size 4-1/2" 12.6#, L-80, IBT-M Production Liner: 12,100' to 13,038' MD Basis Top cement to be 100' above the TOL. Liner Lap > 150'. O Hole excess = 40°~°. Shoe Joint = 125 ft. TOC = 12,000' MD Total Cement Volume: 35.3 bbl W sh & acer 5-bbl water, 20 bbl CW 100 20 bbl of MudPush ail 35.3 bbl, 165 sx "G" mixed at 15.8 Ib/ al & 1.20 ft3/sx Tem BHST =174°F from Schlumber er Chart Well Control: ~rmediate/P~oduction hole: ~1~•1 ~4''~~ • Maxim m possible BHP: 4,000 psi at 6,936' TVD (Kuparuk D) • Maxi um surface pressure: 3,306 psi at (Based on a full column of gas at 0.1 psi/ft) • Pla ed BOP test pressure: 4,000 psi • B Test Interval: Not to exceed 14 days • I tegrity tests: FIT to 11.3 Ib/gal 20' below the 10-3/4" shoe. ick tolerance: 66-bbl with 9.5 Ib/gal mud at below the 10-3/4" shoe. • Planned completion fluid: Brine with diesel cap. 3 • Cement Program: C. Casin Size 10-3/4", 45.5, L-80, BTC Surface Casin at 7,078' MD Excess from /Permafrost to SurFace = 150°!° over gauge hole. Use Basis / 2-Stage 30% excess below the B/Permafrost (1963' MD). 85' Shoe Track. H-ES cementer at 2500' MD. Stage I Wash & 10 bbl water r~V ~SG~ $~~„ `~ Total Cement 20 bbl CW 1 Volume: 325 bbl a o MudPush Lead 275 bbl, 348 sx of Arctic Set Lite: 10.7 p and 4.44 ft3lsx Tail . _ 49.8 bbl, 240 sx "G" mixed at 15.8 l~al & 1.17 ft /sx Stage II Wash & 10 bbl water Total Cement Spacer 20 bbl CW 100 Volume: 382.7 bbl 50 bbl of MudPush Lead 340.6 bbl, 431 sx of Arctic Set Lite: 10.7 and 4.44 ft3/sx Tail _ _ 42.1 bbl, 203 sx "G" mixed at 15.81blgal & 1.17 ft /sx _ Casin Size 7-5/8", 29.7#, L-80, BTC-M Intermediate Casin at 12,253' MD Basis Top of cement to be 1000' MD above the shoe: 50°I° excess. Shoe Joint = 125 ft TOC = 13 ' MD Total Cement Volume: 63.1 bbl Wash & Spacer 5-bbl water, 25 bbl CW 100 1353 ~' 40 bbl of MudPush Tail 63.1 bbl, 304.5 sx "G" mixed at 15.8 Ib/ al & 1.20 ft3/sx Temp BHST =150°F from Schlumber~c er Chart Liner Size 4-1/2", 12.6#, L-80, IBT-M Production Liner: 12,100' to 13,038' MD Basis Top of cement to be 100' above the TOL. Liner Lap > 150'. en ole excess = 40°/Q. Shoe Joint = 125 ft. TOC = 12,000' MD Total Cement Volume: 35.3 bbl Wash & Spacer 5-bbl water, 20 bbl CW 100 20 bbl of MudPush Tail 35.3 bbl, 165 sx "G" mixed at 15.8 Ib/ al & 1.20 ft3/sx Tem BHST =174°F from Schlumber er Chart Well Control: _ Intermediate/Production hole: ~ ,,' ` _t;~~ ~~ ~~~ • Maximum possible BHP: 4,000 psi at 6,936' TVD (Kuparuk D) • Maximum surface pressure: 3,306 psi at (Based on a full column of gas at 0.1 psi/ft) • Planned BOP test pressure: 4,000 psi • BOP Test Interval: Not to exceed 14 days • Integrity tests: FIT to 11.3 Ib/gal 20' below the 10-3/4" shoe. Kick tolerance: 66-bbl with 9.5 Ib/gal mud at below the 10-3/4" shoe. • Planned completion fluid: Brine with diesel cap. Formation Markers: Formation Tops MD TVD Pore Pressure EMW ft (ft) psi Ib/ al BPRF 1,963' 1,876' 8.3 TUZC 4,365' 3,426' 1,468 8.3 T/SB-NB Sand 5,745' 3,996' 1,715 8.3 ~~ ~ ~~~ 3 Formation Marke'ii~s: Formation Tops MD ft TVD (ft) Pore Pressure si EMW Ib1 al BPRF 1,963' 1,876' 8.3 TUZC 4,365' 3,426' 1,468 8.3 T/SB-NB Sand 5,745' 3,996' 1,715 8.3 T/Schrader Bluff "OA" 6,060' 4,126' 1,772 8.3 Deepest SB Sand 6,739' 4,406' 1,893 8.3 T/HRZ 12,044' 6,651' B/HRZ 12,156' 6,726' 2,900 8.3 KLGM 12,283' 6,811' 2,937 8.3 T/Kuparuk D 12,471' 6,936' 3,000 - 4,000 8.3 -11.1 T/Kuparuk A3 12,695' 7,086' 1,830 5.0 - T/Kuparuk A2 12,710' 7,096' 1,833 5.0 T/Kuparuk Ai 12,748' 7,121' 1,800 - 2,300 5.0 - 6.2 T/Miluveach 12,839' 7,182' 3,098 8.3 ' Drilling Hazards & Contingencies: • Hydrates have not been reported on any of the F-Pad wells and are not expected in MPF-91. • Tight hole and stuck pipe due to gravel beds, reactive clays and poor hole cleaning have all occurred in F Pad wells. Lost Circulation • Losses are likely while drilling the 6-3/4" hole through the Kuparuk. • Losses are also possible while running and cementing the surface casing. Expected Pressures • The Schrader Bluff sands are expected to be normally pressured: 8.3 ppg. ' • The Kuparuk A & B sands are depleted down to ±5 ppg EMW, however, the Kuparuk Dsand could require > 11ppg EMW. - Pad Data Sheet ~~`~ • Please Read the MPF-Pad Data Sheet thoroughly. Hole Breathing • Based upon the recently drilled MPF-93, the lower Colville and/or Kalubik may "breath". • Flow checks should be done to differentiate between breathing and flowing. Hydrocarbons • Hydrocarbons may be encountered in the Ugnu through the Schrader Bluff sands, and will be encountered in the Kuparuk sands. Faults • This well path should not intersect any faults although it parallels several faults. Anti-collision Issues • MPF-91 passes the Major Risk Criteria, however, gyro surveys will be required for close approach issues and magnetic interference down to ± 1000 ft MD. 4 Hydrogen Sulfide • MPF Pad is not designated as an H2S Pad, however, low concentrations of H2S have been detected from Kuparuk wells on the pad: MPF-88i 7 ppm 9/2003 MPF-30i 32 ppm 9/2003 The highest concentration of H2S on MPF: MPF-53 47 ppm 912003 Distance to Nearest Property • MPF-91 is 5,330 ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool • MPF-91 is 1,115 ft from the nearest Kuparuk sand penetration in MPF-46. DRILL & COMPLETION PROCEDURE Pre-Riq Oaerations 1. The 20" conductor will be installed pre-rig. 2. Secure waiver from AOGCC for diverter variance Drillin 1. MIRT. PUDP, etc. 2. Drill 13.5" surface hole through all of the Schrader Bluff sands. 3. Run and cement 10.75" surface casing. 4. Install wellhead and NU/Test BOPE. 5. Drill 9.875" intermediate hole to the Kalubik/Kuparuk D. ~ 6. Run and cement 7-5/8" intermediate casing. 7. Drill 6-3/4" hole through the Kuparuk sands and into the Miluveach.' 8. Run and cement a 4.5" liner with HGR, ZXP &PBR. 9. Displace the well with kill weight brine. LDDP. 10. Run a 4-1/2" injection completion and sting into the PBR (or run a PKR). 11. ND BOP/NU Tree. 12. Freeze Protect. 13. RD & MO Doyon 14. Post-Riq• 1. RU SLU. Drift & Tag run to PBTD. RD SLU. 2. RU E-Line. Perforate Kuparuk sand(s) as directed (based on LWD's). RD E-Line. 3. Clean up the wellbore by swabbing, flowing or with CTU. 4. Put the well on injection. 5 -~ F- 91 -~ F- 85 •- F- 83 • F- 8~J ^ 79 ^ 78 ^ 74 ^ 70 ^ 66 ^ 62 ^ 58 ^ 54 ^ 50 ^ 48 ^ 42 ^ 38 ^ 34 ^ 30 ^ 26 ^ 22 ^ 18 ^ 14 ^ 10 ^s ^ 2 ^ 77 ^ 73 ^ 69 ^ 65 ^ 61 ^ 57 ^ 53 ^ 49 ^ 45 ^ 41 ^ 37 ^ 33 ^ 29 ^ 2s ^ 21 ^ 17 ^ 13 ^ 9 ^ 5 ^ 1 SIMPSON LAGOON a 6 F PAD 5 4 ~ ~, 35'19'21" a ~~O o - N - a I a ~ ~}' L PAD ~~7 t~'8 g _N_ Q Q 1 s~ 1 ~ 6 ~~ ~~ VICINITY MAP N.T.S. NOTES 1. DATES OF SURVEY: DECEMBER 21, 1997. 2. REFERENCE FIELD BOOK: MP97-09 (PGS. 23-24). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 1927. 5. PAD SCALE FACTOR IS 0.99990199. fi.-kiORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS F-1 SOUTH AND F-2 NORTH. ~P~~ OF q *~°~ TH ~ °°~~ ~~°°° S'CEPHEN STOLL °~,o ~ %T~~°~ 6726-S °°~J~~`` ~~'~ROFESS I ONA~ LP~~ F PAD ~ LEGEND -~ AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE [ HEREBY CERTIFY THAT [ AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 21, 1997. 1 nCATF(1 WtTHiN PRnTRACTFfI CFf OfR T 7~ N R ~a F IIAIIAT ucornrnnl nl ncvn WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSIT[ON(D.DD) BOX ELEV. OFFSETS F-80 Y=6,(435,392.88 N=10,045.06 70'30'7.418" ' ' " 70.5076161' 10 8' 1,943' FSL X= 541,517.49 E= 4,775.25 149 39 37.141 149.6603169' 3,046' FEL F-83 Y=6,035,466.40 N=10,134.86 70'30'28.138" ' ' " 70.5078161' 1' 11 2,016' FSL X= 541,569.03 E= 4,774.81 149 39 35.610 149.6598917' . 2 994 FEL F-85 Y=6,035,515.44 N=10,194.91 70'30'28.618" ' " 70.5079494' 11 1 2,065' FSL X= 541,603.69 E= 4 774.73 149'39 34.581 149.6596058' ' 2,959' FEL F-91 Y=6,035,662.34 N=10,375.18 70'30'30.058" ' " 70.5083494' 11 4' 2 211' FSL X= 541,708.15 E= 4,775.03 149'39 31.480 149.6587444' . 2,853' FEL r. uvuc,~ JACOBS cNEacEO.O'HANLEY : • BP EXPLORATION 0 0 oArE: 12 22/97 DRAWING: MPUFAB MILNE POINT UNIT F-PAD SHEET: ~~~~ J08 NO: tl1~UC~ AS-BUILT CONDUCTORS ~ SCALE: ~ z rsse,EO von urrarwAnoN JJ LaN °""~'~ "° "° *^"'°'~ WELLS F-80, F-83, F-85 dt F-91 t °` 1 N0, OAtE 11EVIStON BY CNK xioia.z ww 1" 200' t .~ -4-••~;~a~.. ,~ ~.. ., ~ ~~'.: ~:~~ BP EXPLORATION `~~ ~ MPF-91 Field: Milne Point Kuparuk A Sand ENG: s. coyner Pad: F-Pad Injector RIG: Doyon 14 RKB: 47 H DIR / LWD OH FORM DEPTH HOLE CASING MUD INFO MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 125' 30" Welded, Insul 20" x 11" 5K MWD/GR NONE Gyro as needed Staae 11 150% Excess Base Permafrost 1,963' 1,876' 341 bbls, 431 sx of In Permafrost 24.0° ASL at 4.44 cf/sx H-ES Cementer 2,500' 2,365' ~ I 42.1 bbls, 203 sx TOC I Stage I 2,500' 2,365' ~ Class G + CaCl2 65.6° Surtace Csp Test Csg to r 10-3/4" 2000 psl r I 45.5# TUZC 4,365' 3,426' L-80, BT Int. Yield 10 psi Stage Collasp 2470 psi 275 bbls, 348 sx of T/Schrader Bluff 5,745' 3,996' ASL at 4.44 cflsx 5°1o Excess 49.8 bbls, 240 sx Class G + CaCl2 B/Schrader Bluff 6.739' 4.4nG' 85 ft Shoe Track Casing Point 7.076' 4.546' 65.6° 13.5" MWD/GR/RES NONE PWD IFR/Cas 65.6° Inter. Casing Cement Slurry 50% Excess 7-518" 63.1 bbls, 305 sx 29.71bs/ft 15.8 ppg L-80, BTC-M 1.16 ft3/sx Top of Cement 11,253' 6,269' Int. Yield 6890 psi Class "G" Collaspse 4790 psi Test Csg to Start Drop 11,616' 6,419' 65.6° 3500 psi 1 End Drop 12,044' 6,651' 48.1° Top/LNR/ZXP/PBR 12,103' 6,744' Casing Point 12.253' 6.791' 48.1° ~ 9.57 ~' BlColville MWD/GR/RES KLGM 13,697 7,032' Liner Liner Cement Top / Kuparuk D 12,471' 6,936' 4-1/2" , 12.6#, L80 35.3 bbl, 165 sx Test LNR to Top / Kuparuk A 12,688' 7,081' Class G, 15.8# 3500 psi IFR/Cas 40% Excess Liner Point 13,037' 1,314' 48.1° 6.75" Miluveach [10/04/04] MPF-91 Revised Well Plan Schematic.xls I Field: Milne Point KUPBrLI~(A Sand ENG: S. Coyner Pad: F-Pad injector RIG: Doyon 14 RKB: 47 ft DIR / LWD OH FORM DEPTH HOLE CASING MUD INFO MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 125' 30' Welded, Insul 20" x 11° 5K MWD/GR NONE Gyro as needed Stage 11 150°h Excess Base Permafrost 1,963' 1,876' 341 bbls, 431 sx of In Permafrost 24.0° ~ -~~~~ ASL at 4.44 cf/sx H-ES Cementer 2,500' 2,365' ~ ~: ~ 42.1 bbls, 203 sx Class G + CaCl2 65.6° ; Surface Csa Test Csg to 10-3/4° 2000 psi TOC /Stage 1 4,078' 3,307' ; ; 45.5# TUZC 4,365' 3,426' L-80, BTC Ei~C Int. Yield 521 psi to e Collaspse 2 0 psi 210 bbls, sx of T/Schrader Bluff 5,745' 3,996' ASL .44 cf/sx 30% xcess bbls, 240 sx ~~'' ~ Class G + CaC12 B/Schrader Bluff 6,739' 4,406' ,: 85 ft Shoe Track Casing Point 7,078' : 4,546' • , ` 65.6° 13.5" MWD/GR/RES NONE PW D IFR/Cas 65.6° Inter. Casino Cement Slurrv 50% Excess 7-5/8" 63.1 bbls, 305 sx 29.7 Ibs/ft 15.8 PP9 L-80, BTC-M 1.16 ft3/sx Top of Cement 11,253' 6,269' Int. Yield 6890 psi Class "G" CoNaspse 4790 psi Test Csg to Start Drop 11,616' 6,419' 65.6° 3500 psi End Drop 12,044' 6,651' 48.1° Top/LNR2XP/PBR 12,103' 6,744' Casing.Point 12,253' 6,791' ~ 48.1° ' 9.875" B/Colville MWD/GR/RES KLGM 13,697' 7,032' Liner Liner Cement Top / Kuparuk D 12,471' 6,936' 4-1/2" , 12.6#, L80 35.3 bbl, 165 sx Test LNR to Class G, 15.8# 500 psi Top / Kuparuk A 12,688' 7,081' 3 IFR/Cas 40% Excess Liner Point 13,037' 7,31.4' 48.1° 6.75" Mlluveach [10/04/04] MPF-91 Well Plan Schematic.xls ~~ BP EXPL A I OR T ON M PF-91 Field: Milne Point Kuparuk A Sand Injector ENG: S. Coyner Pad: F-Pad With Contingency Liners RIG: Doyon 14 r RKB: 47 ft DIR 1 LWD OH FORM DE PTH HOLE CASING MUD INFO MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 125' 30" Welded, Insul 20" x 11" 5K MWD/GR NONE Gyro as needed Staae 11 150% Excess Base Permafrost 1,963' 1,876' 341 bbls, 431 sx of In Permafrost ~ 24.0° ASL at 4.44 cf/sx H-ES Cementer 2,500' 2,365' [` i 42.1 bbls, 203 sx Class G + CaCl2 65.6° ; Surface Csa Test Csg to 10-3/4" 2000 psi TOC !Stage 1 4,078' 3,307 ; ; 45.5# ~'~,'~ TUZC 4,365' 3,426' L-80, BTC S~ ~~ Int. Yield 521 psi e 1 CoNaspse 70 psi 2i0 bbls, 266 of T/Schrader Bluff 5,745' 3,996' ASL at 4. cf/sx 3 ° Excess 49.8 s, 240 sx i G G + CaCl2 B/Schrader Bluff 6,739' 4,406' j 5 ft Shoe Track Casing Point 7,078' 4,54fi' 65.6° 13.5' \~ MWD/GR/RES NONE PW D ~`` 65.6° Inter. Casina Cement Slurrv 50% Excess 7-5/8" 63.1 bbls, 305 sx 29.7 Ibslft 15.8 Ppg Top of Cement 11,253' 6,269' L-80, BTC-M 1.16 ft3/sx Test Csg to Int. Yield 6890 psi Class `G" 3500 Psi Start Drop 11,616' 6,419' 65.6° Collaspse 4790 psi Top/LNR/ZXP 11,953' 6,656' End Drop 12,044' 6,651' 48.1° Top/LNR2XP 12,103' 6,690' Casing'Point " 12;253' 6,791' { 48.1° 9.875' B/Colvitle MWD/GR/RES KGLM 12,283' 6,811' Drilling Liner Test LNR to IFR/Cas Liner Cement 3500 pai Top / Kuparuk D 12,471' 6,936' 16.9 bbl, 83 sx 100% Excess Class G, 15.8# Drilling Liner 12,600' 7,022' 6.75 Kup D / B MWD/GR/RES Prod Liner Top f Kuparuk A 12,688' 7,081' 3-112° , 9.2#, L80 Test LNR to 48.1 ° 3500 psi Liner Cement 100% Excess IFR/Cas 22.4 bbl, 109 sx Production Liner 13,03T 7,314' 4.75' Class G, 15.8# Miluveach [10/04/04] MPF-91 Well Plan Schematic.xls COMPANY DETAIL9 REFERENCE INFORMATION SURVEY PROGRAM Plan: MPF-91 WPO7 (Plan MPF-91/MPF-91) I BP Amoco Coadvum (N~) Re(en:rce: Well Cede: Plan MPFAI. Trve N°M Venial (TVD)Re( :34J~11./45.70 DePth Fm Deph To Slavry/Plan Tool Created By: Digital Busixss Chem User Dal<: 6/22/2005 tl' C akulanoo Mednd: Mmmmn Cimanue Senkn iVSl Ref Sla-(O.OON,O.ODE) J1J0 1199.10 Pkened: MPFAI WP03 VI9 CB-0YR0.S5 Checked: Dele: • Erm System: ISCWSA Measamd Deqn Rd :34J-11.4 45.]0 Sun Medd: Tnr Cylinder North GkuWuo Merhod Mmurum Cusamie 1199.10 I11B7.6D Ph~eed MPFAI WPm VI9 MWD-IFR-MS Ertor Sur( Ell~tkal-Casv~ Reviewed: Dare: Wamiog Metlnd: RWes Based WELL DET.4RS CASING DETAILS N,n>: -Ni-S -FJ-W Nonhmg Esamg Ladode Langinde Slm No. TVD MD Name Size Plan MPFAI Sti62.02 9919.01 rN56b234 541708.15 ]0%070.OS8N 149°3971.180W W.4 I 4545.70 7077.73 10 3!4" 10.750 TARGET DETAILS 2 6790.70 12253.31 7 5/8" 7.625 " Name TVD +N/-S +E/-W Northing Fasting Shape 3 7313.80 13037.00 41/2 4.500 MPF-9l TI wp02 6790.70 5574.92 -7407.67 6041195.04 534270.02 Circle (Radius: 150) MPF-91 T2 wp02 7180.70 5841.88 -7751.21 6041460.04 533925.02 Point - ? - ~ ~ Start Dv L5/100' :300' MD, 300TVD i--+ Start Dir 2.5/100':500'MD, 499.91'TVD Q0 SECTION DETAILS j~! '~~ Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target ~ Start Dir 3/100' :620' MD, 619.53TVD ~ I .I ~ ~ ~' End Dir :1220' MD, 1196.7 TVD 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 • 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 14 3 500.00 3.00 302.00 499.9] 2.77 -4.44 1.50 302.00 5.21 ' t 4 620.00 6.00 302.00 619.53 7.76 -12.42 2.50 0.00 14.59 Start Dir 4/100':2372.32'MD,2249.4'TVD ISOIl ~ ~ ~ ~ 5 1220.00 24.00 302.00 1196.70 89.72 -143.58 3.00 0.00 168.65 ' ! 6 2372.32 24.00 302.00 2249.40 338.09 -541.05 0.00 0.00 635.55 PRF ~ 7 2580.32 29.00 287.00 2435.69 375.31 -625.29 4.00 299.87 72522 _ _ 2000 ~ 8 3564.57 65.62 308.08 3095.43 735.83 -1230.26 4.00 31.10 1425.32 \ ~ o- ~, End Dir : 3564.57 MD, 3095.43' TVD 9 11615.99 65.62 308.08 6419.13 5259.05 -7002.51 0.00 0.00 8757.43 ' ~ 10 12053.31 48.13 307.85 6657.20 5483.54 -7290.08 4.00 -179.42 9122.19 ~+~ ' ~ ll 12253.31 48.13 307.85 6790.70 5574.92 -7407.67 0.00 0.00 9271.10 MPF-91 TI wp02 2 ~ ~ 12 12837.60 48.13 307.85 7180.70 5841.88 -7751.21 0.00 0.00 9706.13 MPF-91 T2 7vp02 !-~i ~ ~ - 13 13037.60 48.13 307.85 7314.20 5933.27 -7868.81 0.00 0.00 9855.04 28 ; ~ 3000 ~~ j i - ~ FORMATION TOP DETAILS ~~ ~ ~~ ~ ~ - _ ~35pp No. TVDPath MDPath Formation c a "' i 140~~ ~ ~ _ 1 1875.70 1963.26 BPRF g '_ - - i ,~ ~ ~. ~ 2 3425.70 4364.61 TUZC ? ~ ~ ' 3 3995.70 5745.40 SBFI-NB s i- ---- ~ ~ fpp0 - ~ ~ ~ 4 4125.70 6060.31 OA y • ~ - : _ - 0 5 4405.70 6738.59 BASE DEEPEST SBF SAND } 55 0 ~. ~ ' 6 6650.70 12043.53 THRZ 42 - - -----~~_~~ ~ 6 ~ ~ ~ ~- 7 6725.70 12155.93 BHRZ ~ ~ ~ ~ ~~ - ~ ~ 8 6810.70 12283.28 KLGM ~ ~- SB~I~IB .6500 '\~ - . ~ 9 6935.70 12470.55 TKUD > ~ ~ _ ~ ; 10 7080.70 12687.78 TKUA 2 I 3~ I ~ I ~ I I 7085.70 12695.27 TKA3 [- _ ,_ "- _. _- .-. - 7500. - 4 - - _ 12 7095.70 12710.25 TKA2 _. t 4ND BASE DEEP ST SBF i 1 S 1 13 7120.70 12747.71 TKAI ' 8000 I4 0.00 -0.60 TMLV F ~, .. 4~ -- - - ~ ~ ~ 8500 .,,,,~„ "~ Start Dv 4/100' :11615.99' MD, 6419.13'7 VD End Dir :12053.31' MD, 6657.2' TVD /_ MPF-91 TI wp02 7 5/8" MPF-91 T2 wp02 ~- MPF-91 Total Depth :13037.6' MD, 7314.2' TVD 4 1/2" dPF-91 WP03 I 7000 8400 9800 11200 1 Vertical Section at 307.02° [1400R/iD] ~ ~{ I COMPANY DETARS BP Amoco REFERENCE INFORMATION Co-oNi~we (71EI Ref Wdl Crntre: Rm MPFA I. Teue Nall SURVEY PROGRAM l7cpW Em Depth To Sully/Plan Tool Plan: MPF-91 WP03 (Plan MPF-91/MPF-91) Crcehd By: Digital BuameSa Chart User Dale: 6/22/2005 CalcuWion Mehod: Mmhrum Curvaaue E S ISCWSA Vernal ITVDI Re( :34.3-11.415.]0 Section lVS/Rdererice: Sbt~ (O.OON.O.OOE) M d D h f 1 3- 1 45 ]0 3030 1199.40 Pla,uad: MPFAI WPQI V21 CB-GYR0.S5 9 Checked: Dale: tta ymem: Scau Method: Tav CyliMa North eaeura eg Re ererce: 4. 1 .4 . Calahron Method Mminmm Cavutae 9.40 1303].6D Plara>cd: MPFAI WP03 V21 MWD-IFR-MS 11 Ertor SuRxe: Eaipacal-Crime Wamvmg Mehod: Rub Bnaad WELL DETAaS Name ~N/-S -E/-W Nwtbmg Easv,g WRUde Lotgiade Sla CASING DETAILS plan MPFAI 5662.02 9919.01 6(6566231 541706.15 70°30'30.OSBN 149%9'31.480W WA No. TVD MD Name Siu TARGET DETAILS 1 4545.70 7077.73 10 3/4" 10.750 Name TVD +N/-S +E/-W Northing Fasting Shape 2 6790.70 12253.31 7 5/8" 7.625 3 7313.80 13037.00 4 I/2" 4.500 MPF-91 Faultl 6095.70 2099.02 -7317.19 6037720.04 534380.00 Polygon MPF-91 Tl wp02 6790.70 5574.92 -7407.67 6041195.04 534270.02 Circle (Radius: 150) ~. MPF-91 T2 wp02 7180.70 5841.88 -7751.21 6041460.04 533925.02 Point ' i ' ' MPF-91 Faultl 7185.70 5425.62 -9313.73 6041035.05 532365.02 Polygon Total Depth 13037.6 MD, 7314.2 - MPF-91 Fault3 7185.70 4610.94 -7608.1 I 6040230.04 534075.02 Polygon i M~ 91 P03 . ! r } - - I I ~ i MPF-9I i 2 wp02 - t I - t - SECTION DETAILS ~ ~ ~ ~ j I I i 1 1~[P~'- 1 1 wp02 - ~ - j- - - j ~~, Sac MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec target I I 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 60 4 1/2 ~ d E 1? 053 3 1' MD 6657 I ' TVD ! i 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 p Ir :: , . . , -- 3 500.00 3.00 302.00 499.91 2.77 -4.44 1.50 302.00 5.21 ~ i i 4 620.00 6.00 302.00 619.53 7.76 -12.42 2.50 0.00 14.59 ~~ ~ I i ~ ' 5 1220.00 24.0(1 302.00 1196.70 89.72 -143.58 3.00 0.00 168.65 PF 91 ' 70 I f ~ ~ I i 6 2372.32 24.00 302.0(1 2249.40 338.09 -54!.05 0.00 0.00 635.55 ' ~ ~, i j ~ • lpir 4/ IOQ' : 11615. ~- 6469 ' Mp 3 I ! 7 2580.32 29.00 287.00 2435.69 375.31 -625.29 4.00 299.87 725.22 l I ~ , . , ~ I i g 3564.57 65.62 308.08 3095.43 735.83 -1230.26 4.00 31.10 1425.32 7 5/8" i 500 ~ I. I I ' 1 : i I l 9 11615.99 65.62 308.08 6419.13 5259.05 -7002.51 0.00 0.00 8757.43 , I i 10 12053.31 48.13 307.85 6657.20 5483.54 -7290.08 4.00 -179.42 9122.19 ~, ' ~, i ! i I I ' ~ ! 11 12253.31 48.13 307.85 6790.70 5574.92 -7407.67 0.00 0.00 9271.10 MPF-91 TI wp02 , 12 12837 60 48 13 307 85 7180 70 5841 88 -7751 21 0 00 0 00 9706 13 MPF-91 T2 wp02 48 ' i : i ! . . . . . . . . . 13 13037.60 48.13 307.85 7314.20 5933.27 -7868.61 0.00 0.00 9855.04 - i MPF 1 Fault 3 ~' ' -- -- --- _ -- I - I ~ , I I f ¢Oq0 ~ I -- { ' I ' FORMATION TOP DETAII.S I ~ ~ ~. - i . I, ' - - 1 ~ I i i i ~ - - -- _. ~ ~ No. TVDPath MDPath Formation I ~ ~ ._ - i ' ' , I 1875.70 1963.26 BPRF $ __ I 5500 ~ i l i ~ ~ ~ ~ I i ~ 2 3425.70 4364.61 TUZC i ` ' ~ ' ~ I 3 3995.70 5745.40 SBFI- NB ~ ~~ ~ ~ ~ ~ ~ ~ I ~ ~ I ~ ~ 4 4125.70 6060.31 OA , S 4405.70 6738.59 BASE DEEPEST SBF SAND e 6 6650.70 12043.53 THRZ c _ _-- .-- +- - - - I I 1 I I _ ~ i ~ 7 6725.70 12155.93 BHRZ ~ i t- ' I i I I I i ~ ~ t 8 6810.70 12283.28 k.LGM .. - -- -r -- 5 ! ~ I - ~ ~ I ~ - 9 6935.70 12470.55 TKUD -- -- ---. ..- - - --- -- - - i { ~ j y I ~ '. i -- ~ -- - - - i ~ ~ i ~ - ~ - ---. I i I 10 7080.70 12687.78 TKUA l -_ - - - --- ', I ` ~~ ~ ~ ~. , I ~ _- I ~ I 1 7085.70 12695.27 TKA3 y i - -- _. : _ 1 1 ~ ,, I I ~ 12 7095.70 12710.25 TKA2 712 1274 __ _ - I ] _ I 10 3 , Y4' ~ - - ( I i I -- f ~ I I . ~ ! I 14 0.00 0.60 TMLV 1 West(-)/East(+) [1200Win] Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/22/2005 Time: 14:25:43 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-91, True North Site: M Pt F Pad Vertical {TVD) Reference: 34.3+11.4 45.7 Well: Plan MPF-91 Section (VS) Reference: Well (O.OON,O.OOE,307.02Azi) Wellpath: MPF-91 Survey Calcufa6on Method: Minimum Curvature Db: OraGe Ptan: MPF-91 WP03 Date Composed: 3!30/2005 Version: 19 Principal: Yes Tied-to: From: Definitive Path Fietd: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Geomagnetic Model: Well CenVe bggm2005 Site: M Pt F Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6029958.49 ft Latitude: 70 29 34.438 N From: Map Easting: 531814.44 ft Longitude: 149 44 23.616 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.25 deg Well: Plan MPF-91 Slot Name: Babe Injector Well Position: +N/-S 5662.02 ft Northing: 6035662.34 ft Latitude: 70 30 30.058 N +E/-W 9919.01 ft Easting : 541708.15 ft ~ Longitude: 149 39 31.480 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 7077.73 4545.70 10.750 13.500 103/4" 12253.31 6790.70 7.625 9.875 7 518" 13037.00 7313.80 4.500 6.750 41/2" Formations MD TVD Formations Lithology Dip Angle Dtp Direction ft ft deg deg 1963.26 1875.70 BPRF 0.00 0.00 4364.61 3425.70 TUZC 0.00 0.00 5745.40 3995.70 SBF1-NB 0.00 0.00 6060.31 4125.70 OA 0.00 0.00 6736.59 4405.70 BASE DEEPEST SBF SAND 0.00 0.00 12043.53 6650.70 THRZ 0.00 0.00 12155.93 6725.70 BHRZ 0.00 0.00 12283.28 6810.70 KLGM 0.00 O.QO 12470.55 6935.70 TKUD 0.00 0.00 12687.78 7080.70 TKUA 0.00 0.00 12695.27 7085.70 TKA3 0.00 0.00 12710.25 7095.70 TKA2 0.00 0.00 12747.71 7120.70 TKA1 0.00 0.00 0.00 TMLV 0.00 0.00 Targets Map Map <-- LaNtude --> <--- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPF-91 T1 wp02 6790.70 5574.92 -7407.67 6041195.04 534270.02 70 31 24.849 N 149 43 9.815 W -Circle (Radius: 150) -Plan hit target MPF-91 T2 wp02 7180.70 5841.88 -7751.21 6041460.04 533925. 02 70 31 27.471 N 149 43 19.949 W -Plan hit target • Sperry-Sun BP Planning Report Company: B P Amoco Drxte: 6/22/2005 Time: 14:25:43 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-91, True North Site: M Pt F Pad Vertical (TVD) Reference: 34.3+11.4 45.7 Wett: Plan MPF-91 Section (VS) Reference: Well (O.OON,O.OOE,307.02Azi) Wellpath: MPF-91 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Inc( Azim TVD +N/-S +FJ-W DLS Bnild Turn TFO Target ft deg deg ft ft ft dey/100ft deg/100ft deg/100ft deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 3.00 302.00 499.91 2.77 -4.44 1.50 1.50 0.00 302.00 620.00 6.00 302.00 619.53 7.76 -12.42 2.50 2.50 0.00 0.00 1220.00 24.00 302.00 1196.70 89.72 -143.58 3.00 3.00 0.00 0.00 2372.32 24.00 302.00 2249.40 336.09 -541.05 0.00 0.00 0.00 0.00 2580.32 29.00 287.00 2435.69 375.31 -625.29 4.00 2.40 -7.21 299.87 3564.57 65.62 308.08 3095.43 735.83 -1230.26 4.00 3.72 2.14 31.10 11615.99 65.62 308.08 6419.13 5259.05 -7002.51 0.00 0.00 0.00 0.00 12053.31 48.13 307.85 6657.20 5483.54 -7290.08 4.00 -4.00 -0.05 -179.42 12253.31 48.13 307.85 6790.70 5574.92 -7407.67 0.00 0.00 0.00 0.00 MPF-91 T1 wp02 12837.60 48.13 307.85 7180.70 5841.88 -7751.21 0.00 0.00 0.00 0.00 MPF-91 T2 wp02 13037.60 48.13 307.85 7314.20 5933.27 -7868.81 0.00 0.00 0.00 0.00 Survey MD lncl Azim TVD Sys TVD N/S E/R' DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 34.30 0.00 0.00 34.30 -11.40 0.00 0.00 0.00 6035662.34 541708.15 CB-GYRO-SS 100.00 0.00 0.00 100.00 54.30 0.00 0.00 0.00 6035662.34 541708.15 CB-GYRO-SS 200.00 0.00 0.00 200.00 154.30 0.00 0.00 0.00 6035662.34 541708.15 CB-GYRO-SS 300.00 0.00 0.00 300.00 254.30 0.00 0.00 0.00 6035662.34 541708.15 Start Dir 1.5/1 400.00 1.50 302.00 399.99 354.29 0.69 -1.11 1.50 6035663.03 541707.04 CB-GYRO-SS 500.00 3.00 302.00 499.91 454.21 2.77 -4.44 1.50 6035665.09 541703.70 Start Dir 2.5/1 600.00 5.50 302.00 599.63 553.93 6.70 -10.72 2.50 6035668.98 541697.39 CB-GYRO-SS 620.00 6.00 302.00 619.53 573.83 7.76 -12.42 2.50 6035670.03 541695.68 Start Dir 3/100 700.00 8.40 302.00 698.89 653.19 13.08 -20.93 3.00 6035675.30 541687.15 CB-GYRO-SS 800.00 11.40 302.00 797.39 751.69 22.19 -35.50 3.00 6035684.32 547672.53 CB-GYRO-SS 900.00 14.40 302.00 894.85 849.15 34.01 -54.43 3.00 6035696.05 541653.53 CB-GYRO-SS 1000.00 17.40 302.00 991.02 945.32 48.53 -77.67 3.00 6035710.43 541630.22 CB-GYRO-SS 1100.00 20.40 302.00 1085.61 1039.91 65.69 -105.13 3.00 6035727.44 541602.66 CB-GYRO-SS 1200.00 23.40 302.00 1178.39 1132.69 85.46 -136.76 3.00 6035747.02 541570.93 MWD+IFR+MS 1220.00 24.00 302.00 1196.70 1151.00 89.72 -143.58 3.00 6035751.24 541564.09 End Dir :1220 1300.00 24.00 302.00 1269.78 1224.08 106.96 -171.17 0.00 6035768.33 541536.40 MWD+IFR+MS 1400.00 24.00 302.00 1361.14 1315.44 128.51 -205.66 0.00 6035789.68 541501.79 MWD+IFR+MS 1500.00 24.00 302.00 1452.49 1406.79 150.07 -240.16 0.00 6035811.04 541467.18 MWD+IFR+MS 1600.00 24.00 302.00 1543.85 1498.15 171.62 -274.65 0.00 6035832.40 541432.57 MWD+IFR+MS 1700.00 24.00 302.00 1635.20 1589.50 193.17 -309.14 0.00 6035853.76 541397.96 MWD+IFR+MS 1800.00 24.00 302.00 1726.56 1680.86 214.73 -343.64 0.00 6035875.11 541363.35 MWD+IFR+MS 1900.00 24.00 302.00 1817.91 1772.21 236.28 -378.13 0.00 6035896.47 541328.74 MWD+IFR+MS 1963.26 24.00 302.00 1875.70 1830.00 249.92 -399.95 0.00 6035909.98 541306.84 BPRF 2000.00 24.00 302.00 1909.27 1863.57 257.84 -412.62 0.00 6035917.83 541294.13 MWD+IFR+MS 2100.00 24.00 302.00 2000.62 1954.92 279.39 -447.12 0.40 6035939.19 541259.52 MWD+tFR+MS 2200.00 24.00 302.00 2()91.97 2046.27 300.94 -481.61 0.00 6035960.55 541224.91 MWD+IFR+MS 2300.00 24.00 302.00 2183.33 2137.63 322.50 -516.10 0.00 6035981.90 541190.29 MWD+IFR+MS 2372.32 24.00 302.00 2249.40 2203.70 338.09 -541.05 0.00 6035997.35 541165.26 Start Dir 4/100 2400.00 24.57 299.69 2274.63 2228.93 343.92 -550.82 4.00 6036003.13 541155.46 MWD+IFR+MS 2500.00 26.89 292.17 2364.73 2319.03 362.76 -589.84 4.00 6036021.74 541116.34 MWD+IFR+MS 2580.32 29.00 287.00 2435.69 2389.99 375.31 -625.29 4.00 6036034.09 541080.83 MWD+IFR+MS 2600.00 29.68 287.82 2452.85 2407.15 378.19 -634.49 4.00 6036036.93 541071.61 MWD+IFR+MS 2700.00 33.18 291.52 2538.17 2492.47 395.81 -683.53 4.00 6036054.27 541022.47 MWD+IFR+MS 2800.00 36.78 294.57 2620.10 2574.40 418.31 -736.24 4.00 6036076.47 540969.65 MWD+IFR+MS 2900.00 40.44 297.15 2698.23 2652.53 445.57 -792.35 4.00 6036103.41 540913.39 MWD+IFR+MS 3000.00 44.16 299.37 2772.16 2726.48 477.47 -851.59 4.00 6036134.97 540853.98 MWD+IFR+MS 3100.00 47.91 301.30 2841.60 2795.90 513.84 -913.67 4.00 6036170.99 540791.70 MWD+IFR+MS 3200.00 51.68 303.02 2906.15 2860.45 554.51 -978.29 4.00 6036211.29 540726.86 MWD+IFR+MS • Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/22/2005 Time: 14:25:43 Page: 3 ~e1d: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-91, True North Site: M Pt F Pad Vertic al (TVA) Reference: 34.3+11.4 45.7 Well: Plan MPF-91 Section (VS) Reference: Well (O.OON,O.OOE,307.02Azi) ~ Wcllpath: MPF-91 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S )!:/VV DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft deg/100ft ft ft 3300.00 55.49 304.57 2965.50 2919.80 599.28 -1045.14 4.00 6036255.69 540659.77 MWD+IFR+MS 3400.00 59.30 305.98 3019.38 2973.68 647.94 -1113.88 4.00 6036303.95 540590.76 MWD+IFR+MS 3500.00 63.14 307.29 3067.51 3021.81 700.24 -1184.19 4.00 6036355.85 540520.16 MWD+IFR+MS 3564.57 65.62 308.08 3095.43 3049.73 735.83 -1230.26 4.00 6036391.18 540473.90 End Dir :3564 3600.00 65.62 308.08 3110.06 3064.36 755.74 -1255.66 0.00 6036410.94 540448.39 MWD+IFR+MS 3700.00 65.62 308.08 3151.34 3105.64 811.92 -1327.35 0.00 6036466.71 540376.39 MWD+IFR+MS 3800.00 65.62 308.08 3192.62 3146.92 868.10 -1399.04 0.00 6036522.48 540304.39 MWD+IFR+MS 3900.00 65.62 308.08 3233.90 3188.20 924.27 -1470.74 0.00 603657825 540232.39 MWD+IFR+MS 4000.00 65.62 308.08 3275.18 3229.48 980.45 -1542.43 0.00 6036634.02 540160.39 MWD+IFR+MS 4100.00 65.62 308.08 3316.46 3270.76 1036.63 -1614.12 0.00 6036689.79 540088.39 MWD+IFR+MS 4200.00 65.62 308.08 3357.75 3312.05 1092.81 -1685.81 0.00 6036745.56 540016.39 MWD+IFR+MS 4300.00 65.62 308.08 3399.03 3353.33 1148.99 -1757.50 0.00 6036801.33 539944.39 MWD+IFR+MS 4364.61 65.62 308.08 3425.70 3380.00 1185.29 -1603.83 0.00 6036837.37 539897.87 TUZC 4400.00 65.62 308.08 3440.31 3394.61 1205.17 -1829.20 0.00 6036857.10 539872.39 MWD+IFR+MS 4500.00 65.62 308.08 3481.59 3435.89 1261.35 -1900.89 0.00 6036912.87 539800.40 MWD+IFR+MS 4600.00 65.62 308.08 3522.87 3477.17 1317.53 -1972.58 0.00 6036968.64 539728.40 MWD+IFR+MS 4700.00 65.62 308.08 3564.15 3518.45 1373.71 -2044.27 0.00 6037024.41 539656.40 MWD+IFR+MS 4800.00 65.62 308.08 3605.43 3559.73 1429.89 -2115.97 0.00 6037080.18 539584.40 MWD+IFR+MS 4900.00 65.62 308.08 3646.71 3601.01 1486.07 -2187.66 0.00 6037135.95 539512.40 MWD+IFR+MS 5000.00 65.62 308.08 3687.99 3642.29 1542.24 -2259.35 0.00 6037191.72 539440.40 MWD+IFR+MS 5100.00 65.62 308.08 3729.27 3683.57 1598.42 -2331.04 0.00 6037247.49 539368.40 MWD+IFR+MS 5200.00 65.62 308.08 3770.55 3724.85 1654.60 -2402.74 0.00 6037303.26 539296.40 MWD+IFR+MS 5300.00 65.62 308.08 3811.84 3766.14 1710.78 -2474.43 0.00 6037359.04 539224.40 MWD+IFR+MS 5400.00 65.62 308.08 3853.12 3807.42 1766.96 -2546.12 0.00 6037414.81 539152.40 MWD+IFR+MS 5500.00 65.62 308.08 3894.40 3848.70 1823.14 -2617.81 0.00 6037470.58 539080.40 MWD+IFR+MS 5600.00 65.62 308.08 3935.68 3889.98 1879.32 -2689.51 0.00 6037526.35 539008.40 MWD+IFR+MS 5700.00 65.62 308.08 3976.96 3931.26 1935.50 -2761.20 0.00 6037582.12 538936.40 MWD+IFR+MS 5745.40 65.62 308.08 3995.70 3950.00 1961.00 -2793.75 0.00 6037607.43 538903.71 SBF1-NB 5800.00 65.62 308.08 4018.24 3972.54 1991.68 -2832.89 0.00 6037637.89 538864.40 MWD+IFR+MS 5900.00 65.62 308.08 4059.52 4013.82 2047.86 -2904.58 0.00 6037693.66 538792.40 MWD+IFR+MS 6000.00 65.62 308.08 4100.80 4055.10 2104.04 -2976.28 0.00 6037749.43 538720.40 MWD+IFR+MS 6060.31 65.62 308.08 4125.70 4080.00 2137.92 -3019.52 0.00 6037783.06 538676.97 OA 6100.00 65.62 308.08 4142.08 4096.38 2160.21 -3047.97 0.00 603780520 538648.40 MWD+IFR+MS 6200.00 65.62 308.08 4183.36 4137.66 2216.39 -3119.66 0.00 6037860.97 538576.40 MWD+IFR+MS 6300.00 65.62 308.08 4224.64 4178.94 2272.57 -3191.35 0.00 6037916.74 538504.40 MWD+IFR+MS 6400.00 65.62 308.08 4265.93 4220.23 2328.75 -3263.04 0.00 6037972.51 538432.40 MWD+IFR+MS 6500.00 65.62 308.08 4307.21 4261.51 2384.93 -3334.74 0.00 6038028.28 538360.40 MWD+IFR+MS 6600.00 65.62 308.08 4348.49 4302.79 2441.11 -3406.43 0.00 6038084.05 538288.40 MWD+-FR+MS 6700.00 65.62 308.08 4389.77 4344.07 2497.29 -3478.12 0.00 6038139.82 538216.40 MWD+IFR+MS 6738.59 65.62 308.08 4405.70 4360.00 2518.97 -3505.79 0.00 6038161.34 538188.62 BASE DEEPE 6800.00 65.62 308.08 4431.05 4385.35 2553.47 -3549.81 0.00 6038195.59 538144.40 MWD+IFR+MS 6900.00 65.62 308.08 4472.33 4426.63 2609.65 -3621.51 0.00 6038251.36 538072.40 MWD+IFR+MS 7000.00 65.62 308.08 4513.61 4467.91 2665.83 -3693.20 0.00 6038307.13 538000.40 MWD+IFR+MS 7077.73 65.62 308.08 4545.70 4500.00 2709.50 -3748.93 0.00 6038350.48 537944.44 10 3/4" 7100.00 65.62 308.08 4554.89 4509.19 2722.01 -3764.89 0.00 6038362.90 537928.40 MWD+IFR+MS 7200.00 65.62 308.08 4596.17 4550.47 2778.18 -3836.58 0.00 6038418.67 537856.41 MWD+IFR+MS 7300.00 65.62 308.08 4637.45 4591.75 2834.36 -3908.28 0.00 6038474.44 537784.41 MWD+IFR+MS 7400.00 65.62 308.08 4678.73 4633.03 2890.54 -3979.97 0.00 6038530.21 537712.41 MWD+IFR+MS 7500.00 65.62 308.08 4720.02 4674.32 2946.72 -4051.66 0.00 6038585.98 537640.41 MWD+IFR+MS 7600.00 65.62 308.08 4761.30 4715.60 3002.90 -4123.35 0.00 6038641.75 537568.41 MWD+IFR+MS 7700.00 65.62 308.08 4802.58 4756.88 3059.08 -4195.05 0.00 6038697.52 537496.41 MWD+IFR+MS 7800.00 65.62 308.08 4843.86 4798.16 3115.26 -4266.74 0.00 6038753.29 537424.41 MWD+IFR+MS >B Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/2212005 Time: 14:25:43 Page: 4 Field: Mil ne Point Co-ordinate(NE) Reference: Well: Plan MPF -91, True North Sitc: M Pt F Pad Vertical (TVD) Reference: 34.3+11.4 45.7 Well: Plan MPF-91 Section (VS) Reference: Well (O.OON,O.OOE,307.02Azi) Wellpath: MPF-91 Survey Calculation Methud: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD Sys TVD N!S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 7900.00 65.62 308.08 4885.14 4839.44 3171.44 -4338.43 0.00 6038809.06 537352.41 MWD+IFR+MS 8000.00 65.62 308.08 4926.42 4880.72 3227.62 -4410.12 0.00 6038864.83 537280.41 MWD+IFR+MS 8100.00 65.62 308.08 4967.70 4922.00 3283.80 -4481.82 0.00 6038920.60 537208.41 MWD+IFR+MS 8200.00 65.62 308.08 5008.98 4963.28 3339.98 -4553.51 0.00 6038976.37 537136.41 MWD+IFR+MS 8300.00 65.62 308.08 5050.26 5004.56 3396.15 -4625.20 0.00 6039032.14 537064.41 MWD+IFR+MS 8400.00 65.62 308.08 5091.54 5045.84 3452.33 -4696.89 0.00 6039087.91 536992.41 MWD+IFR+MS 8500.00 65.62 308.08 5132.82 5087.12 3508.51 -4768.59 0.00 6039143.68 536920.41 MWD+IFR+MS 8600.00 65.62 308.08 5174.11 5128.41 3564.69 -4840.28 0.00 6039199.45 536848.41 MWD+IFR+MS 8700.00 65.62 308.08 5215.39 5169.69 3620.87 -4911.97 0.00 6039255.22 536776.41 MWD+IFR+MS 8800.00 65.62 308.08 5256.67 5210.97 3677.05 -4983.66 0.00 6039310.99 536704.41 MWD+IFR+MS 8900.00 65.62 308.08 5297.95 5252.25 3733.23 -5055.35 0.00 6039366.76 536632.41 MWD+IFR+MS 9000.00 65.62 308.08 5339.23 5293.53 3789.41 -5127.05 0.00 6039422.53 536560.41 MWD+IFR+MS 9100.00 65.62 308.08 5380.51 5334.61 3845.59 -5198.74 0.00 6039478.30 536488.41 MWD+IFR+MS 9200.00 65.62 308.08 5421.79 5376.09 3901.77 -5270.43 0.00 6039534.07 536416.41 MWD+IFR+MS 9300.00 65.62 308.08 5463.07 5417.37 3957.95 -5342.12 0.00 6039589.84 536344.41 MWD+IFR+MS 9400.00 65.62 308.08 5504.35 5458.65 4014.12 -5413.82 0.00 6039645.61 536272.41 MWD+IFR+MS 9500.00 65.62 308.08 5545.63 5499.93 4070.30 -5485.51 0.00 6039701.38 536200.41 MWD+IFR+MS 9600.00 65.62 308.08 5586.91 5541.21 4126.48 -5557.20 0.00 6039757.15 536128.41 MWD+IFR+MS 9700.00 65.62 308.08 5628.19 5582.49 4182.66 -5628.89 0.00 6039812.92 536056.41 MWD+IFR+MS 9800.00 65.62 308.08 5669.48 5623.78 4238.84 -5700.59 0.00 6039868.69 535984.41 MWD+IFR+MS 9900.00 65.62 308.08 5710.76 5665.06 4295.02 -5772.28 0.00 6039924.46 535912.42 MWD+IFR+MS 10000.00 65.62 308.08 5752.04 5706.34 4351.20 -5843.97 0.00 6039980.23 535840.42 MWD+IFR+MS 10100.00 65.62 308.08 5793.32 5747.62 4407.38 -5915.66 0.00 6040036.00 535768.42 MWD+IFR+MS 10200.00 65.62 308.08 5834.60 5788.90 4463.56 -5987.36 0.00 6040091.77 535696.42 MWD+IFR+MS 10300.00 65.62 308.08 5875.88 5830.18 4519.74 -6059.05 0.00 6040147.54 535624.42 MWD+IFR+MS 10400.00 65.62 308.08 5917.16 5871.46 4575.91 -6130.74 0.00 6040203.31 535552.42 MWD+IFR+MS 10500.00 65.62 .308.08 5958.44 5912.74 4632.09 -6202.43 0.00 6040259.09 535480.42 MWD+IFR+MS 10600.00 65.62 308.08 5999.72 5954.02 4688.27 -6274.13 0.00 6040314.86 535408.42 MWD+IFR+MS 10700.00 65.62 308.08 6041.00 5995.30 4744.45 -6345.82 0.00 6040370.63 535336.42 MWD+IFR+MS 10800.00 65.62 308.08 6082.28 6036.58 4800.63 -6417.51 0.00 6040426.40 535264.42 MWD+IFR+MS 10900.00 65.62 308.08 6123.57 6077.87 4856.81 -6489.20 0.00 6040482.17 535192.42 MWD+IFR+MS 11000.00 65.62 308.08 6164.85 6119.15 4912.99 -6560.89 0.00 6040537.94 535120:42 MWD+IFR+MS 11100.00 65.62 308.08 6206.13 6160.43 4969.17 -6632.59 0.00 6040593.71 535048.42 MWD+IFR+MS 11200.00 65.62 308.08 6247.41 6201.71 5025.35 -6704.28 0.00 6040649.48 534976.42 MWD+IFR+MS 11300.00 65.62 308.08 6288.69 6242.99 5081.53 -6775.97 0.00 6040705.25 534904.42 MWD+IFR+MS 11400.00 65.62 308.08 6329.97 6284.27 5137.71 -6847.66 0.00 6040761.02 534832.42 MWD+IFR+MS 11500.00 65.62 308.08 6371.25 6325.55 5193.88 X919.36 0.00 6040816.79 534760.42 MWD+IFR+MS 11600.00 65.62 308.08 6412.53 6366.83 5250.06 -6991.05 0.00 6040872.56 534688.42 MWD+IFR+MS 11615.99 65.62 308.08 6419.13 6373.43 5259.05 -7002.51 0.00 6040881.48 534676.91 Start Dir 4/100 11700.00 62.26 308.04 6456.04 6410.34 5305.57 -7061.92 4.00 6040927.66 534617.24 MWD+IFR+MS 11800.00 58.26 308.00 6505.63 6459.93 5359.04 -7130.31 4.00 6040980.74 534548.56 MWD+IFR+MS 11900.00 54.26 307.94 6561.17 6515.47 5410.19 -7195.85 4.00 6041031.52 534482.74 MWD+IFR+MS 12000.00 50.26 307.88 6622.36 6576.66 5458.77 -7258.23 4.00 6041079.74 534420.10 MWD+IFR+MS 12043.53 48.52 307.86 6650.70 6605.00 5479.06 -7284.31 4.00 6041099.88 534393.91 THRZ 12053.31 48.13 307.85 6657.20 6611.50 5483.54 -7290.08 4.00 6041104.33 534388.11 End Dir :1205 12100.00 48.13 307.85 6688.37 6642.67 5504.87 -7317.53 0.00 6041125.51 534360.55 MWD+IFR+MS 12155.93 48.13 307.85 6725.70 6680.00 5530.43 -7350.42 0.00 6041150.87 534327.52 BHRZ 12200.00 48.13 307.85 6755.11 6709.41 5550.56 -7376.33 0.00 6041170.86 534301.50 MWD+IFR+MS 12253.31 48.13 307.85 6790.70 6745.00 5574.92 -7407.67 0.00 6041195.04 534270.02 MPF-91 T1 wp 12283.28 48.13 307.85 6810.70 6765.00 5588.61 -7425.29 0.00 6041208.63 534252.33 KLGM 12300.00 48.13 307.85 6821.86 6776.16 5596.25 -7435.12 0.00 6041216.22 534242.45 MWD+IFR+MS 12400.00 48.13 307.85 6888.61 6842.91 5641.95 -7493.92 0.00 6041261.57 534183.41 MWD+IFR+MS 12470.55 48.13 307.85 6935.70 6890.00 5674.18 -7535.40 0.00 6041293.57 534141.75 TKUD Sperry-sun BP Planning Report Company: BP Amoco Date: 6/22!2005 Time: 14:25:43 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: WeN: Plan MPF-91, True North Site: M Pt F Pad Vertic al (TVD) Reference: 34.3+11.4 45.7 Wetl: Plan MPF-91 Section (VS) Reference: Wel1(O.OON,O.OOE,307.02Azi) Welipath: MPF-91 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 12500.00 48.13 307.85 6955.36 6909.66 5687.64 -7552.72 0.00 6041306.93 534124.36 MWD+IFR+MS 12600.00 48.13 307.85 7022.11 6976.41 5733.33 -7611.51 0.00 6041352.28 534065.31 MWD+IFR+MS 12687.78 48.13 307.85 7080.70 7035.00 5773.43 -7663.13 0.00 6041392.09 534013.48 TKUA 12695.27 48.13 307.85 7085.70 7040.00 5776.86 -7667.53 0.00 6041395.49 534009.06 TKA3 12700.00 48.13 307.85 7088.86 7043.16 5779.02 -7670.31 0.00 6041397.64 534006.27 MWD+IFR+MS 12710.25 48.13 307.85 7095.70 7050.00 5783.70 -7676.34 0.00 6041402.29 534000.21 TKA2 12747.71 48.13 307.85 7120.70 7075.00 5800.81 -7698.36 0.00 6041419.27 533978.10 TKA1 12800.00 48.13 307.85 7155.60 7109.90 5824.71 -7729.11 0.00 6041442.99 533947,22 MWD+IFR+MS 12837.60 48.13 307.85 7180.70 7135.00 5841.88 -7751.21 0.00 6041460.04 533925.02 MPF-91 T2 12900.00 48.13 307.85 7222.35 7176.65 5870.40 -7787.90 0.00 6041488.35 533888.18 MWD+IFR+MS 13000.00 48.13 307.85 7289.10 7243.40 5916.09 -7846.70 0.00 6041533.70 533829.13 MWD+IFR+MS 13037.00 48.13 307.85 7313.80 7268.10 5932.99 -7868.45 0.00 6041550.48 533807.28 41/2" 13037.60 48.13 307.85 7314.20 7268.50 5933.27 -7868.81 0.00 6041550.75 533806.93 MWD+IFR+MS weu oErnas .`WTILOLLISION SETTINGS coMPnNY oErARS SURVEY PROGRAM Nine -t1' S -E-W' Nuthu~ Eames Istiu~ Long~nde Sid Interpolation MethodMD Interval: 2$.00 aP nmoro ~n Fm ~ To SuMym~ Tool Plan xlPf-9i 566202 991V01 6073613 _N Syl]08.15 ](P3070038N 149°79'31 d80W Nn Depth Range From: 34.30 To: 13037.60 CalcuWpo McOed Mm®vv Clvveme 3430 1199.10 Piamcd: MPF91 WP03 V19 C&GYRCI-SS Maximum Range: 1500.33 Re(erellce: Plan: MPF-91 WP03 Four Sysem: ISCWSn 1199.ao 1303760 Plam d: MPFAI WPol V19 MWD~IFR-Ms Scan McWod: Tnv Cyliab Naeth Eemr Surfi: Ell~eival-Casing Wamuig Meehod Rules Baud {$ >5 l3 0 3 5 :olour To MD 500 - 1000 -_- 1500 - 2000 2500 3000 -- 3500 4000 - 4500 5000 5500 6000 7000 8000 9000 10000 10500 11000 - 11500 12000 MPF-91 R Ref. Uanm 31J~11.4 43.70fl VSecu99 Orgm Sunma Argle S .Fl-W Foam TVD 67.02° 0.00 0.00 3430 MPf ~91 NI`~~; me Aa TVD -ws .E/-w IXp TF~ce vSec tugtt 00 0.00 M30 0.00 0.00 0.00 Q00 0.00 00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 00 302.00 499.91 2.77 A.14 130 302.00 311 00 302.00 61953 7.16 -12.42 2.50 0.00 1439 00 302.00 119670 89.72 -14358 S.OD 0.00 168.65 00 102.00 2249.40 338.09 -541.03 0.00 0.00 613.35 ~r.00 26'!.00 2435.69 3]531 42519 /.00 29981 72312 B 356457 65.62 308.06 3095.43 735$3 -113016 O.OD 71.10 142532 9 1161599 65.62 308.06 6119.13 5259.05 -700231 0.00 0.00 8757.0 10 1205331 48.13 307.85 663710 518354 -7290.08 0.00 -IA.Q 9122.19 I I 1225331 08.17 30'!.85 6790.70 SS]d.92 -700/67 0.00 0.00 9271.10 61PF'91 TI svp02 i2 13 12H3760 48.13 307.85 1303760 48.13 307.85 7180.70 771110 5641.88 593317 -773111 -7868$1 0.00 0.00 O.OD 0.00 9706.0 MPF91 tt a'P02 9855.04 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in] • Sperry-Sun Anticollision Report Company: BP Amoco Date: 6/22/2005 Time: 14:12:10 Page: 1 Field: Milne Point Reference Site: M Pt F Pad Co-ordinate(NE) Reference: Well: Pla n MPF-91, Tru6 North Reference Well: Plan MPF-91 Vertical (TVD) Reference: 34.3+11.4 45.7 Reference WeUpath: MPF-91 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.30 to 13037.60 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.33 ft Error Surface: Ellipse + Casing Survey Program for Definitive WeUpath Date: 3/30/2005 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 34.30 1199.40 Planned: MPF-91 WP03 V19 CB-GYRO-SS Camera based gyro single shots 1199.40 13037.60 Planned: MPF-91 WP03 V19 MWD+IFR +MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 7077.73 4545.70 10.750 13.500 10314" 12253.31 6790.70 7.625 9.875 7 5/8" 13037.00 7313.80 4.500 6.750 41/2" Summary < Offset WeUpath ~ 1eference Offset Ctr-Ctr No-Go Allowable Site Well WeUpath MD MD Distance Area Deviation Waroing ft ft ft ft ft M Pt F Pad MPF-01 MPF-01 V1 3510.73 3950.00 454.13 89.13 365.01 Pass: Major Risk M Pt F Pad MPF-O6 MPF-O6 V1 3036.88 3200.00 306.66 78.29 228.37 Pass: Major Risk M Pt F Pad MPF-10 MPF-10 V1 3012.42 3250.00 105.91 71.69 34.22 Pass: Major Risk M Pt F Pad MPF-13 MPF-13 V7 346.17 350.00 440.54 7.13 433.41 Pass: Major Risk M Pt F Pad MPF-14 MPF-14 V1 8281.23 8950.00 816.41 462.62 353.79 Pass: Major Risk M Pt F Pad MPF-18 MPF-18 V1 2645.26 2850.00 155.91 56.18 99.72 Pass: Major Risk M Pt F Pad MPF-22 MPF-22 V3 2381.21 2550.00 345.29 48.33 296.96 Pass: Major Risk M Pt F Pad MPF-25 MPF-25 V1 2828.37 3200.00 414.78 60.19 354.59 Pass: Major Risk M Pt F Pad MPF-30 MPF-30 V1 347.34 350.00 279.96 6.43 273.53 Pass: Major Risk M Pt F Pad MPF-38 MPF-38 V4 347.28 350.00 250.36 7.04 243.32 Pass: Major Risk M Pt F Pad MPF-42 MPF-42 V6 580.68 600.00 236.72 11.80 224.92 Pass: Major Risk M Pt F Pad MPF-46 MPF-46 V4 3513.86 3800.00 204.07 28.44 175.62 Pass: Minor 1!200 M Pt F Pad MPF-50 MPF-50 V6 347.21 350.00 227.27 7.43 219.84 Pass: Major Risk M Pt F Pad MPF-54 MPF-54 V3 441.61 450.00 226.52 7.98 218.54 Pass: Major Risk M Pt F Pad MPF-58 MPF-58 V1 937.06 1000.00 231.47 20.14 211.33 Pass: Major Risk M Pt F Pad MPF-62 MPF-62 V1 394.35 400.00 237.32 7.95 229.37 Pass: Major Risk M Pt F Pad MPF-79 MPF-79 V3 2750.24 2750.00 229.23 63.82 165.41 Pass: Major Risk M Pt F Pad MPF-79PB1 MPF-79PB1 V6 2749.93 2750.00 228.01 63.90 164.11 Pass: Major Risk M Pt F Pad MPF-82 MPF-82 V4 551.00 550.00 270.87 9.95 260.92 Pass: Major Risk M Pt F Pad MPF-82 MPF-82P61 V9 551.00 550.00 270.87 9.79 261.08 Pass: Major Risk M Pt F Pad MPF-83 MPF-83 V9 650.16 650.00 236.75 11.49 225.26 Pass: Major Risk M Pt F Pad MPF-84 MPF-84 V19 651.14 650.00 212.63 14.44 198.19 Pass: Major Risk M Pt F Pad MPF-84 MPF-84A V10 651.14 650.00 212.63 14.23 198.41 Pass: Major Risk M Pt F Pad MPF-84 MPF-84AP61 V3 651.14 650.00 212.63 14.49 198.14 Pass: Major Risk M Pt F Pad MPF-84 MPF-84B V6 651.14 650.00 212.63 14.33 198.30 Pass: Major Risk M Pt F Pad MPF-85 MPF-85 V28 2847.90 2900.00 169.78 72.44 97.34 Pass: Major Risk M Pt F Pad MPF-86 MPF-86 V18 2672.96 2700.00 97.17 66.41 30.76 Pass: Major Risk M Pt F Pad MPF-87 MPF-87 V11 698.98 700.00 123.05 15.27 107.78 Pass: Major Risk M Pt F Pad MPF-87 MPF-87A V3 698.98 700.00 123.05 15.27 107.78 Pass: Major Risk M Pt F Pad MPF-88 MPF-88 V3 949.96 950.00 41.66 18.16 23.50 Pass: Major Risk M Pt F Pad MPF-90 MPF-90 V1 898.72 900.00 22.76 17.12 5.64 Pass: Major Risk M Pt F Pad MPF-90 MPF-90PB1 V31 898.72 900.00 22.76 17.12 5.64 Pass: Major Risk M Pt F Pad MPF-92 MPF-92 V15 349.95 350.00 31.50 7.36 24.14 Pass: Major Risk M Pt F Pad MPF-94 MPF-94 V17 449.74 450.00 90.00 8.58 81.42 Pass: Major Risk M Pt F Pad MPF-95 MPF-95 V16 399.74 400.00 121.76 9.16 112.59 Pass: Major Risk M Pt F Pad Plan MPF-89 MPF-89 V3 Plan: MPF-89 794.80 800.00 49.20 17.99 31.21 Pass: Major Risk M Pt F Pad Plan MPF-93 MPF-93 Vf Plan: MPF-93 399.90 400.00 61.52 10.11 51.41 Pass: Major Risk M Pt F Pad Plan Phelps MPF-Phelps V2 Plan: Ph 399.74 400.00 151.09 9.77 141.32 Pass: Major Risk 46 00 W 149 4 AIPU F-i9 Ta4N, R9E, UM IPU F-85 P Q 4 - 4 4 ~D 149 MPU F-18 U F-4S \ Area of Review _ os ~ ,_; Cement ~; I~PU F_9 t ti ~` MPU F-14 ~~ o° ~ ~ MPU L-28 ~., ^d MPU F-86 MPU F~ 1 ~,p„ d_,~. 149 40 ~~ W 36 ~~~.lpu F-ez L-1 MPU F-91 Proposed 1-WINJ F-5 2051100 I Confidential wells are red SFD 7/20/2005 I.IP U 7 MPU F-84B 14 MPU F-09 ~` ~~ N - 530,004 4 &~0 AIPU F-83 L-28.4 ,000 ~i, MPU 09 fFei ~ 0 1,flflfl 2,000 3,flflfl 4,flflfl -lo I /I \~iooo~.,4~ sS r.4y-oa'~ i b~.~, ~ ~ ~~~~ ~ , ~~ ~. `tS~~4~~~ MPU F-91 ` MPU F-Ol ~~~. 1~~3v - ~~~u~ '^O P~t~~ '\ C tio~O,` ~`~ SS __, ~~~~ ~~ MPF-91 10-401 /Application for Permi~to Drill • Subject: MPF-91 10-401 /Application for Permit to Drill From: "Coyner, Skip (NATCHIQ)" <coyns0@BP.com> Date: Tue, 02 Aug 2005 10:24:01 -0800 To: tom_maunder@admin.state.ak.us CC: "Kara, Danny T" <KaraDT@BP.com>, "Johnson, David A. (Fairweather)" <john23@BP.com> Please make the following changes to the 10-401 package for the captioned well. • Increase the lead cement on Stage I of the surface casing to 275 bbl (348 sx) • The total volume of Stage I is now 325 bbl • Excess from the shoe to the H-ES cementer is 7.5% As such, the cement job is in compliance. 5~~ ~~ ~°~~~ np~ Revisions are attached: Thank you «MPF-91 Revised Well Plan Schematic.xls» «MPF-91 Revised Permit Data Sheet.doc» Skip ~'oyner 907-564-4395 BPXA 907-748-3689 cell Content-Description: MPF-91 Revised Well Plan Schematic.xls MPF-91 Revised Well Plan Schematic.xls !„ Content-Type: application{vnd.ms-excel '' Content-Encoding: base64 'P Content-Description• MPF-91 Revised Permit Data Sheet.doc MPF-91 Revised Permit Data Sheet.doc .Content-Type: application/msword Content-Encoding: base64 1 of 1 8/2/2005 2:12 PM RE: MPF-89 Cement Volumes - 10 3!4" Surface Casing. • Subject: RE: MPF-89 Cement Volumes - 10 3/4" Surface Casing. From: "Johnson, David A. (Fairweather)" <john23@BP.com> Date: Mon, O1 Aug 2005 10:15:07 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: "Johnson, Frederick C" <Frederick.Johnson@BP.com>, "Kara, Danny T" <KaraDT@BP.com>, Skip Coyner <Skip.Coyner@asrcenergy.com> Tom, Thanks. I will keep you informed on how the job went. Dave From: Thomas Maunder [maiito:tom_maunder@admin.state.ak.us] Sent: Monday, August 01, 2005 10:06 AM To: Johnson, David A. (Fairweather) Cc: Johnson, Frederick C; Kara, Danny T; Skip Coyner Subject: Re: MPF-89 Cement Volumes - 10 3J4" Surface Casing. David, It would appear that you are incorporating what cementing history is available from F pad and others in order to meet the regulatory requirements. You have "deepened" the stage tool depth which could make the difference avoiding lost circulation. Unfortunately, you will only know when you pump the job. Based on the information you have provided, you plan is acceptable. Please keep me advised regarding how the operation goes. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tam. For the 1st stage, MPF-88 pumped 40% volume excess from the shoe at 7859' to the ES cementer at 1935', lost returns (volume not recorded) and had 50 BBLS of cement to surface on the 1st stage displacement. They were unable to reciprocate the casing and obviously the Dement channeling was extreme. The 2nd stage cement was pumped with out initially circulating and the dye marked spacer was seen in returns while still mixing cement. Feasibly the 2nd stage cement filled the ohannel fram the stage Dollar up. This well had a +!- 64° degree angle vs. 70° on MPF-93 anal the prcaposed £i7° on MPI~-89. The casing for MPF-93 was stuck off bottom at 7925' with the ES cementer at 2509'. Assuming some channeling, the cement volume on the 1st stage cement was +1- 551ess than theoretical. Circulation was lost shortly before bumping the plug so additional cement would not have helped. No cement or spacer was seen from the 1st stage cement job indicating little channeling problems. It is doubtful that they will be able to reciprocate casing on the 1st stage for MPF-89. ~lVe could increase the cement volume slightly but I would prefer not to pump more than 1 Q to 15% max. e should reach casing point sometime tomorrow morning. Dave From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, July 29, 2005 3:59 PM To: Johnson, David A. (Fairweather) 1 of 3 8/3!2005 1:26 PM RE: MPF-89 Cement Volumes - 10 3/4" Surface Casing. • Cc: Johnson, Frederick C; Kara, Danny T; Skip Coyner Subject: Re: MPF-89 Cement Volumes - 10 3/4" Surface Casing. David, et al, I understand your desire to minimize potential problems and meet the regulatory requirements. The two examples you give cover both ends of the spectrum. What was the performance on MPF-93?? I looked in the records at MPF-88 and their experience was not good at all, although it appears that a very large volume of cement was pumped on the first stage. On that basis, it is not too much of a surprise that MPF-88 had problems. I looked back on some of the wells I planned on F pad in late 1998 and 30% XS was what was used below the stage tool. We only have the DEAP summary reports in our file which don't give a lot of detail. I don't remember any problems at that time. Your math is correct that the planned volume is 7% XS of the total interval. Optimizing the cementing volume to avoid problems is prudent planning. It is probable that when you open the stage tool, that you will circulate up your preflush or spacer. That will give a good indication of where the cement top is. Is it planned to reciprocate the casing on the 1st stage?? Before I close my comments here, I'd like to have the answers to the questions I have posed. Thanks, Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, MPF-89 will probably be running surface casing on August 5th. The intent of the cement design on MPF-89 is not to leave an uncemented section but to avoid lost returns while initiating circulation through the ES oementer. The volume from the shoe fio the ES cementer is 7°la excess instead of the normal 30°la excess below permafrost used on single stage cement jobs. The worst Dees scenario would be fio lose the ability to circulate cement to surface on the 2nd stage. We are hoping to have minimum cement volume above the stage collar. MPC-42 used 5°!o excess volume on the 1st stage and recovered thick contaminated mud and 20 BBLS of cement. They did minor have problems during the initial circulation for the 2nd stage. MPC-43 used 1 °l° excess, did not recover any cement but also lost 200 BBLS of fluid while displacing the 1st stage cement. This was probably due fio the length of the sectian. W lt D th E aximum 1st Stage Volume % Excess e ep Cementer Angle Calculated Pumped Recovered Pumped ecov C-42 5807 1902 47.5 260.7 274 20 5°In 7°1 C-43 9361 1985 68.5 485.6 491 0 1 °l0 0°l Note: C-43 lost 200 BBLS while cerr~enting 1st stags Dave From: Thomas Maunder [mailtoaom maunder@admin.state.ak.us] Sent: Thursday, July 28, 2005 7:09 AM To: Johnson, David A. (Fairweather) Cc: Johnson, Frederick C; Kara, Danny T; Skip Coyner Subject: Re: MPF-89 Cement Volumes - 10 3/4" Surface Casing. David, 2 of 3 8/3/2005 1:26 PM RE: MPF-84 Cement Volumes - 10 314" Surface Casing. When do you anticipate cementing the surface casing on this well?? As I pointed out to Skip on MPF-91 regarding similar cement design, the plans being proposed are a combination of the surface and intermediate casing cementing requirements. If it is BP's intent to have an uncemented section of the surface casing, then a letter should be submitted requesting the variance according to the requirements of 20 AAC 25.030 (g). Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, We have redesigned the cement volumes on MPF-89 for the 1st stage cement on the 10 314" surtace casing.. The total volume has been reduced to 279.5 BBLS lead and tail. The reduction was made to insure that we did not get to much cement and cement contaminated mud above the ES Cementer at 2800' and reduce the possibility of losing circulation while circulating thru the ES Cementer for the 2nd stage. Due to the casing being set at 67 degrees there is a higher chance of cement channeling. This total cement volume will be 7% over gauge hole volume from the shoe to the ES Cementer at 2800'. If the hole volume runs 30% excess as is normally calculated, the cement top would be at 3500' assuming no channeling. This is +/- 667' above the TUZC. The 15.8 ppg tail cement was increased from 50 BBLS to 92 BBLS. The second stage cement has remained unchanged. A new well plan schematic is attached. Casing Size 10-3l4", 45.5, L-80, BTC Surface Casing at 6,726' MD 1st Stage - 6726' MD to 3500' MD w/ 30% Excess. Tail cement = 1000' MD Basis Use 30°I° excess below the Base of the Permafrost. Note: This is +/-17 BBLS (7% excess) over gauge volume to ES Cementer at 2800' Total Cement Volume: 338 bbl Wash 10 bbl water 20 bbl CW 100 Spacer 50 bbl of MudPush Lead 187.5 bbl, 237 sk of Arctic Set Lite: 10.7 ppg and 4.44 ft3/sx Tail 92 bbl, 441 sk "G" mixed at 15.8 Ib/gal & 1.17 ft3/sx Temp Casing Point BHST 80° F (estimated by Dowell) Casing Size 10-3/4", 45.5, L-80, BTC Surface Casing at 6,726' MD 2nd Stage - 2800' MD to Surface Basis Excess from Base of the Permafrost to Surface = 150% over gauge hole. Use 30% excess below the Base of the Permafrost. Tail cement = 500' MD. Total Cement Volume: 399 bbl Wash 10-bbl water 20 bbl CW 100 Spacer 50 bbl of MudPush Lead 357 bbl, 452 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft3/sx Tail 42 bbl, 202 sx "G" mixed at 15.8 Ib/gal & 1.17 ft3/sx Dave Office: 564-4171 Cell: 632-5806 «MPF-89 Well Plan Schematic.ZlP» 3 of 3 8/3/2005 1:26 PM RE: MPF-91 • Subject: RE: MPF-91 From: "Coyner, Skip (NATCHIQ)" <coyns0@BP.com> Date: Fri, 22 Jul 2005 10:06:13 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> Sorry, try this one. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell • -----Original Message----- From: Thomas Maunder [mailto:tom maurder~admin.state.ak.us] Sent: Friday, July 22, 2005 10:03 AM To: Coyner, Skip (NATCHIQ) Subject: Re: MPF-91 Skip, It appears that you sent the MPF-93 drawing and not MPF-91. With regard to not cementing to the stage tool, your comment is correct for intermediate cementing. This is the surface casing. As I read the reps, sufficient cement must be used to fill the annulus from the shoe to surface. I don't remember looking at any other proposed surface stage job that was proposed like this. Are you aware of other jobs that were similarly proposed?? If this is what you intend, you need to make a request for relief according to 20 AAC 25.030 (g). Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote: 1. We did run GR/RES across the Schrader Bluff and there is ± 5' of probable viscous oil in the OA. Perhaps a slight show of oil in the very top of the NB & NC sands. All else is water. We saw no indications of hydrocarbons. - 2. Stage 1 of the surface casing job is intended only to cover the known hydrocarbon bearing zones in the field, which is what we normally do when cementing intermediate casing into or through the Schrader Bluff: Top of TUZC - 500'. There is an error in the schematic. It has been corrected Stage I TOC should be: 3865' MD / 3220' TVD. The correct volumes for stage I should be: 228.6 bbl (289 sx) Lead & 49.8 bbl (240 sx) Tail. 3. The planned TOC for the 7-5/8" intermediate casing is TD - 1000' _ 11253' MD. The planned excess is 50%. The shoe track is 125'. Cement volume = 63.1 bbl (305 sx). 4. The maximum possible BHP of 4000 psi was measured in MPF-46i this year. MPF-91 is fault separated from MPF-46i, however, the two wells are relatively close toge er. So, we e ieve that the 4000 psi BHP is verb unlikely but it is possible. We believe that the MPF-91 BHP will be on the order of 2000 - 3000 psi based upon offset producers in the same fault block. The 10.5 ppg mud weight in the program will control virgin pressure in the Kuparuk if found. We do not expect over-pressure in this fault block. We do expect severe depletion. 1 of 2 8/3/2005 1:21 PM RE: MPF-91 • ~ If we do have over-pressure in the Kalubik or upper Kuparuk sands, we will need to set a contingency drilling liner before drilling the depleted Kuparuk A sands. The primary plan is to drill the entire Kuparuk section without the drilling liner if possible. Let me know if you need any further data or clarifications. I appologize for the errors in the original submission. A corrected schematic is attached. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell -----Original Message----- From: Thomas Maunder [mailto:tom maunder~~?ad.min.state.a.k,us Sent: Thursday, July 21, 2005 4:22 PM To: Coyner, Skip (NATCHIQ) Cc: Kara, Danny T Subject: MPF-91 Skip, I am reviewing the permit application and have a couple of questions. 1. In your request for diverter waiver you cite the mud weight used on MPF-93 and that no gas was seen. You also discuss that the only maybe/potential hydrocarbon interval is the O sand, but that it is usually water bearing. I suspect that there was no Res in the LWD (same as here). Was there any drilling indication of hydrocarbon in the O sand?? We did run GR/RES across the Schrader Bluff and there are hydrocarbons albeit viscous. 2. On your the first stage of your surface job, it would appear that your cement volume is less than one would calculate using your basis. I presume that you intend to bring the first stage above the stage collar. My gage calculation of the 13-1/2" x 10.75" annulus from 7078 - 2500 is just under 297 bbls. Your program (or programme) only shows 260.3 bbls planned. On your "sketch sheet" I see that the planned TOC for stage 1 is 4078'. Why the open interval?? I do not remember any other stage jobs that have been proposed the "included" an open interval between the 1st stage TOC and the stage tool. 3. I think there is a mistype on the planned TOC for your 7-5/8" and the XS I calculate based on your stated volume is 70%. 4. On page 3 the maximum BHP is listed as 4000 psi @ 6936' TVD (-11.1 EMW) On page 2, the highest MW listed in the table at the top of the page is 10.5 ppg. Please reconcile these. Also, according to your email you had pressure in the A sand on MPF-93. Is similar pressure possible in the A sand at this location?? I see you have included a 2nd well drawing with a drilling liner. I presume this is the contingency if high pressure is encountered. Thanks in advance, Tom Maunder, PE AOGCC ''MPF-91 Well Plan Schematic.xls Content-Description: MPF-91 Well Plan Schematic.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 2 of 2 8/3/2005 1:21 PM TER`RIE L HUB~LE BP EXPLORATION AK INC "haste .. PO BOX 196612 MB 7-5 as-si~25z 2'12 ANCHORAGE, qK 89519-6612 rcard Check DATE ~~ ~~ PAY TO THE .ORDER OF C s /~~ .~~ First`Nationa Bank Alaska Anchorage,' AK 99501 MEMO ~= i 25 200060:99 i4rn6 2 27u~ 1556n• 0 2.1.2 •s • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSpMITTAL LEGT~TER WELL NAME ~/- ~ ~~ < PTD# 2d ~~ ^ ! /~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIT) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PIT) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). SPACING The permit is approved subject. to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT KR F-91 Program SER Well bon; seg ^ PTD#:2051100 Company BP EXPLORATION (ALASI(A) INC Initial ClasslType SER I PEND GeoArea 890 Unit 11328 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached-__,- -__-__-_-__-__,-_-_.__-__--_--__--- Yes- ------------- - - - - 2 Lease number appropriate-_.-_-__-_.-.-_.__-._.---____----_,-_ Yes_ ____-Surface location inApL25509,productivejnten!al&TDinA0L35501.8,_--_._------------------ 3 Uniquewell-name and number-__-_________________________________ Yes- .-._...-_-._ 4 Well located ln_a-defined_pool_ - - - - - , - - - - - _ _ - Yes - - - . _MILNE POINT, KUPARUK R(VER OIL, 525100, governed by Conservation Orde[ No. 432C , _ _ - _ - - - - 5 UVell located proper distance from dritling unit boundary- - - - - - - - - - - - -- - Yes - - Conservation Order No. 4320 contains no spacing restrictions with respecitp drilling unit boundarie&.. - - . 6 Well located proper distance_from other wells- - - - - - - - - - - - - - - - - - Yes - - - - . -Conservation Order No. 4320 has no inter!cell-spaeing_restrictions, - _ _ _ - - _ _ _ - _ _ . _ - - - 7 Sufficient acreage available in_drilling unit_ - - _ - _ _ - - _ _ - _ - _ - - - - Yes - Conservation Order No. 4320 has no interwell spacing_restr_ictions, Wellbore will_ be-more than 500' from 8 If_deviated, is-wellbore plat-included _ - _ - _ - _ - _ . Yes - _ - - - _ an-external property line where-ownership gr_Iandownership changes. - - 9 Ope[atoronlyaffectedparty------------------- ------------------ Yes- ----------- -----.- - - - - - - 10 Ope[atorhasappropriate-bondinforce- -- - -- ------- ---- --- -- Yes ------- -- ------ -- -- - ---- ------ -~--- ------- - --- -- ----~- 11 Pe[mit_canbei_ss~edwithoutconservafionorder_______________________---- ,Yes_ _-_--____-____ - - - Appr Date 12 Pe[mitcanbeissuedwithoutadministrativ_e_app[oval-_-_-_-.________________ Yes_ ____-_-___-_,_-__-_--__--_---__,_----_---___--__-,_ - - -- - --------- SFD 7/20/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauthorized by Injection Order# (put1O# in_comments)-(For_ Yes - - Area Injection Order No._ 10B- - - - - - - - - - - - - - - - - - - - - - - - - - - _ . - _ , 15 All wells-within 1l4.mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - . _ - - - MPU F-79, MPU F-46 _ _ _ - - _ . , . _ _ _ _ _ _ , _ _ _ _ _ . - - _ ------------------------------ 16 Pre-produced injector; duration ofpre-production less than_ 3 months. (Far service well only) - No_ - _ - - - 17 ACMP Finding of Consistency_has been issued_forthis project- _ _ - . - NA- _ - - - Engineering 18 Conductor string-provided________ _____________________________ __ Yes. __-_-_--_-__-_____-- 19 Surface casing-protects all_known-USDWS - - - - - - - - - - - - - - - Yes . - - - Surface casing will be cemented below Schrader Bluff.- Anyshallowerzones_will be_isolated. - _ - _ 20 CMT-vol_ adequate_to circul_ate_o_n cond_uctor_& surf_csg - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ - _ _ - _ 1st stage cement volume X10% X$ of annulus_ v_olume._ Intent is to circulate to_stage tool. - _ - _ - _ - _ _ - - _ - - - 21 CMT-vol-adeguate_to tie-in long string to surf csg_ - - . No_ . _ - - No h drocarbon_ zones known in this holes_ection.- - - - 22 CMT,will coyer all knownproductiye horizon_s_ - - - - _ _ - Yes . - _ Liner planned to be_ cemented, - _ _ - - - _ , 23 Casingdes~nsadequatefo[C,TB&_permafr_ost-___-_---._- ------------ Yes. -----------------,----------------,-- -- ------_--- ,-- ------- - --- 24 Adequate tankage_o_r reserve pit .. - _ .. - Yes . - . - Rig is_equipped with steel-pits.. No resflrve-pitplanred, All waste to approved disposal wells._ . - - - 25 Ifa_re-drill,has.a_1.0.403fcr abandonment been approved______ __________-__ NA-_ __-_---____--___--___---_,__--__. 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ .Proximity analysis performed, Traveling cylinder path_ealculated. Close approaches_identifed.- Gyros planned.- - _ 27 If diverter required, does it meet regulations_ - _ NA_ . _ - _ BP has-applied for tlivertetwaiver.-Noshallow-problems have been reported a# F pad, Waiver recommended. - Appr Date 28 Drilling fluid_program schematic & equip list adequate_ , - - - - - - . _ - Yes - - - 5.0 EMW expected_in Kup. _BHL believed fault separated from 11.1 EMW. -Potential haza[d_noted._ - - - _ TEM 8/4/2005 29 BOPES, do they meet_regu_lotion - - - - Yes - - - - - - - - - `(~t~,J~ ~ 30 BOPE_press rating appropriate; test to-(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ _ - . _ - Calculated_MASt? based Qn 11,tEMW 3306_psi. 4000 psi BOP test planned.. _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ - _ _ -y ,`,`~Ii 31 Choke_manifoldcomplieswlAPI_RP-53 (May84)_-_,__-_-____-_-____-- Yes- ___________________ -______-_-_-------___--_ 32 Work will occur without operation shutdown---------------__,_-_-_--__, Yes_ -__-__-_- - - - - - - 33 Is presence_of H2S gasprobable_ - - - - - - - Yes - - _ , - - - Minor_H2S-reported at F_pad._ Mud should p[eclude H2S on-rig, Rig_has sensors and alarms._ . 34 Mechanical condition of we11s within AOR verified GFo[service well only) _ . - Yes - - , - MPF-46 MIT II acceptable. MPF-79-& P61 penetrate Kuparuk beyond 1/4 mile.- PB acceptable. - . - - - - Geology 35 Permit_can be issued wlo_ hydrogen_ sulfide measures - _ - - - - _ . _ No_ - _ - _ H2S ha_s been measured in_quantities_exceeding 20 ppm from MPU F-Pad, - . - - , - - - - - 36 Data_presented on_ potential overpressure zones - _ - - - - _ . - _ - _ - - Yes - _ - - Expected pressure is 8.3 ppg-EMW to Kup, maybe up_to 11.1 ppg _in Kup D, then depleted to_5.0 in t<up reservoir_ Appr Date SFD 7120!2005 37 Seismic analysis of shallow gas-zones - - _ , - - - . - - . - . NA_ - - . will be drilled withmud-weights_ranging:from 8,6-to 10.5 pp. Pressure dis us ed-in Drilling Haz a/r ds.//- _ - _ - - _ _ - ~~ ° ~ ` 38 Seabed condition survey (if pff-shore) _ _ NA_ - _ I ~y-1Kar 1 ~ 2 t l~7G.~? ~~ / ~/ _ and Contengencies section. _~R,7~w- ~. jj r 39 -Contact namelphone for weekly progress,reports [exploratory only]_ - _ NA ' ~f /~k~ T ' ~°Q'~td ~F'F"7 ~ y~ " ~yp~ - ~ Geologic Engineering Public D t D D /'C~~ d~+C.~-~~7~C.~Q.dt.e,(,, ~+p uv /~/pi - ~/~ .6 ~ Commissioner: a ate e: Commissioner: ate Commissioner ` _ r, ,fF~ ~ e~~~ ~ ~/f ~Grh~ /1. p • • ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify Tending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. s Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 24 13:15:48 2005 Reel Header Service name .............LISTPE Date .....................05/10/24 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/10/24 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • ~-~333 ~ ,~~<<~ O Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-91 API NUMBER: 500292327100 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-OCT-05 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AKMW3896973 AKMW3896973 AKMW3896973 LOGGING ENGINEER: C. ZAWADZKI C.A.DEMOSKI C.A.DEMOSKI OPERATOR WITNESS: D. GREEN E. VAUGHN E. VAUGHN MWD RUN 4 JOB NUMBER: AKMW3896973 LOGGING ENGINEER: C.A. DEMOSKI OPERATOR WITNESS: E. VAUGHN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 6 13N l0E 2211 2853 45.51 11.40 OPEN HOLE CASING DRILLERS • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 114.0 9.875 10.750 7092.0 6.750 7.625 12179.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUN 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND GEOPILOT ROTARY-STEERABLE BHA (GP) . 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPF-91 ON 18 OCTOBER 2005. THESE PDC DATA WERE PROVIDED TO SDS BY D.DORTCH (SAIC/BP) ON 19 OCTOBER 2005, AS AUTHORIZED BY MIKIE WEEKS (BP GEOSCIENTIST) LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 4 REPRESENT WELL MPF-91 WITH API#: 50-029-23271-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13045'MD/7329'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 • # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 171.5 13004.0 ROP 211.5 13052.0 FET 3674.5 13011.0 RPD 3674.5 13011.0 RPM 3674.5 13011.0 RPS 3674.5 13011.0 RPX 3674.5 13011.0 s BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH - -------- BASELINE DEPTH GR 171.5 177.5 11288.0 11294.0 11315.0 11322.0 11375.5 11379.5 11398.5 11401.5 11475.5 11484.5 11501.0 11512.5 11534.0 11541.5 11684.0 11690.5 11786.0 11787.5 11834.0 11832.5 11881.0 11887.5 11895.0 11902.5 11908.0 11915.5 11917.5 11926.0 11924.0 11930.0 11927.5 11934.5 11943.5 11949.0 11953.0 11959.5 11955.5 11963.0 11960.5 11966.5 11979.5 11988.5 11985.0 11992.5 11993.0 12002.0 12000.0 12007.0 12027.5 12036.0 12049.5 12058.5 12052.0 12060.0 12058.5 12066.0 12075.0 12085.0 12095.5 12099.5 12120.5 12121.0 12179.5 12178.0 12194.5 12193.0 12236.5 12236.5 12250.0 12253.0 12268.5 12270.0 12343.5 12346.5 12363.0 12365.5 12372.5 12372.0 12385.5 12383.5 12396.5 12398.0 12410.5 12408.0 12415.0 12413.5 12426.5 12421.0 12437.0 12435.0 12467.0 12464.5 12470.5 12467.0 12473.5 12470.5 12486.0 12483.5 12495.5 12493.5 12508.0 12505.5 12541.0 12538.0 12556.5 12553.5 12568.5 12566.0 12588.0 12586.5 12597.5 12596.5 12617.0 12615.0 12628.0 12625.5 12636.0 12634.0 12671.5 12669.0 12680.0 12677.0 12708.0 12705.5 12714.5 12713.0 12737.0 12735.5 12748.0 12748.0 12756.0 12757.0 12765.0 12766.0 12774.0 12772.5 12776.5 12774.5 12780.0 12777.0 12782.0 12779.0 12793.5 12791.0 12804.0 12801.5 12835.5 12830.5 12914.5 12908.5 12964.5 12957.5 13052.0 13045.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 177.5 MWD 2 3729.0 MWD 3 7104.0 MWD 4 12191.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3729.0 7104.0 12191.0 13045.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel L` DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 171.5 13052 6611.75 25762 171.5 13052 ROP MWD FT/H 0.4 2683.1 187.29 25682 211.5 13052 GR MWD API 18.52 243.66 86.5537 25666 171.5 13004 RPX MWD OHMM 0.15 2000 7.81823 18674 RPS MWD OHMM 0.06 2000 8.26551 18674 RPM MWD OHMM 0.06 2000 13.9072 18674 RPD MWD OHMM 0.02 2000 11.2011 18674 FET MWD HOUR 0.12 84.62 1.77515 18674 First Reading For Entire File..........171.5 Last Reading For Entire File...........13052 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER •674.5 13011 3674.5 13011 3674.5 13011 3674.5 13011 3674.5 13011 FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 177.5 3688.5 ROP 217.5 3729.0 LOG HEADER DATA DATE LOGGED: 24-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3729.0 TOP LOG INTERVAL (FT) 114.0 BOTTOM LOG INTERVAL (FT) 3729.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 65.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 . DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Native/Spud Mud 9.30 110.0 8.0 900 10.2 .000 .0 .000 80.6 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 177.5 3729 1953.25 7104 177.5 3729 ROP MWDO10 FT/H 3.2 2683.1 201.572 7024 217.5 3729 GR MWDO10 API 18.52 127.35 66.2157 7023 177.5 3688.5 First Reading For Entire File..........177.5 Last Reading For Entire File...........3729 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • • File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 3680.5 7055.5 RPD 3680.5 7055.5 RPS 3680.5 7055.5 RPX 3680.5 7055.5 FET 3680.5 7055.5 GR 3689.0 7063.0 ROP 3729.5 7104.0 LOG HEADER DATA DATE LOGGED: 26-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7104.0 TOP LOG INTERVAL (FT) 3729.0 BOTTOM LOG INTERVAL (FT) 7104.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.1 MAXIMUM ANGLE: 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 85.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.240 105.6 MUD FILTRATE AT MT: 4.000 72.0 MUD CAKE AT MT: 4.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3680.5 7104 5392.25 6848 3680.5 7104 ROP MWD020 FT/H 0.4 5 03.65 175.415 6750 3729.5 7104 GR MWD020 API 27.45 1 25.34 77.4207 6749 3689 7063 RPX MWD020 OHMM 0.9 17.7 3.01965 6751 3680.5 7055.5 RPS MWD020 OHMM 0.86 22.6 3.14957 6751 3680.5 7055.5 RPM MWD020 OHMM 0.62 22.88 3.26033 6751 3680.5 7055.5 RPD MWD020 OHMM 0.63 22.73 3.34264 6751 3680.5 7055.5 FET MWD020 HOUR 0.12 61.97 1.49548 6751 3680.5 7055.5 First Reading For Entire File..........3680.5 Last Reading For Entire File...........7104 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 • File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7056.0 12149.0 RPD 7056.0 12149.0 RPM 7056.0 12149.0 RPS 7056.0 12149.0 RPX 7056.0 12149.0 GR 7063.5 12156.5 ROP 7104.5 12191.0 LOG HEADER DATA DATE LOGGED: O1-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12191.0 TOP LOG INTERVAL (FT) 7104.0 BOTTOM LOG INTERVAL (FT) 12191.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAXIMUM ANGLE: 69.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 9.875 7092.0 Fresh Water Gel 9.20 50.0 8.0 400 5.2 4.000 74.0 2.170 141.8 6.000 64.0 3.500 74.0 REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel r ~J DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7056 12191 9623.5 10271 7056 12191 ROP MWD030 FT/H 2.78 4 46.14 200.588 10174 7104.5 12191 GR MWD030 API 43.4 2 43.66 102.436 10187 7063.5 12156.5 RPX MWD030 OHMM 0.55 2000 11.6318 10187 7056 12149 RPS MWD030 OHMM 0.34 2000 12.2594 10187 7056 12149 RPM MWD030 OHMM 0.28 2000 12.176 10187 7056 12149 RPD MWD030 OHMM 0.31 2000 15.6461 10187 7056 12149 FET MWD030 HOUR 0.13 84.62 1.41054 10187 7056 12149 First Reading For Entire File..........7056 Last Reading For Entire File...........12191 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for e ach bit run in separate fil'€s. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 12149.5 13004.0 RPM 12149.5 13004.0 RPS 12149.5 13004.0 RPX 12149.5 13004.0 FET 12149.5 13004.0 GR 12157.0 12997.0 ROP 12191.5 13045.0 LOG HEADER DATA DATE LOGGED: 05-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13045.0 TOP LOG INTERVAL (FT) 12191.0 BOTTOM LOG INTERVAL (FT) 13045.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.6 MAXIMUM ANGLE: 49.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 12179.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY {LBJG) 11.00 MUD VISCOSITY (S) 68.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 640 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.500 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.740 143.6 MUD FILTRATE AT MT: 2.600 68.0 MUD CAKE AT MT: 5.500 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet • Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel 5~ DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12149.5 13045 12597.3 1792 12149.5 13045 ROP MWD040 FT/H 1.02 271.01 98.0412 1708 12191.5 13045 GR MWD040 API 33.42 182.97 111.336 1681 12157 12997 RPX MWD040 OHMM 0.15 32.48 4.06263 1710 12149.5 13004 RPS MWD040 OHMM 0.06 405.48 4.68953 1710 12149.5 13004 RPM MWD040 OHMM 0.06 2000 65.0037 1710 12149.5 13004 RPD MWD040 OHMM 0.02 2000 15.8114 1710 12149.5 13004 FET MWD040 HOUR 0.28 80.53 4.97544 1710 12149.5 13004 First Reading For Entire File..........12149.5 Last Reading For Entire File...........13045 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/10/24 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................05/10/24 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF • • End Of LIS File
