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Home My WebLink About202-216Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-113 202216 500292312500 24 12/31/2023 i BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~.~`'~~~~~~~r F`!~' ~'j a~~ 7dC~~,~ ~ bp ~~~~f~~~ OCT A 5 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~alca Oil & Gas Cons. Go~r~um~a~inn pnchorape ~,b~- ~. ~ ~ 1~ ~ ~ I 3 Enclosed please find mu(tiple copies of a spreadsheet with a list of wells from GPB V- 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 e~ernal 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA t7 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 v-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970490 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830t00 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-20~ 2012220 5002s23o54000o SC leak NA 4 NA 9o.s 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V403 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310U00 NA 2 NA t8.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30l2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ 2080200 50029233830000 NA 1.75 NA ~b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 . . '" MICROFilMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc I Ó t"'lv~ cÀvÐ Ù b DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022160 Well Name/No. PRUDHOE BAY UN BORE V-113 Operator BP EXPLORATION (ALASKA) INC S f7 ú-L ;¡)),.(.\., " d' V ..{ API No. 50-029-23125-00-00 MD 8555 ....--- TVD 7041 /' Completion Date 2/18/2003 ----- Completion Status 1-01l Current Status 1-01l UIC N -- ..----- REQUIRED INFORMATION Mud log No Samples No --- -,. Directional surv¿---Yesj _.----- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, PEX, BHOC Sonic Well Log Information: (data taken from logs Portion of Master Well Data Maint) o~ Logl Electr Data Digital Dataset Log Log Run Interval OH/ -' ~~~ed/Frmt Number Name Scale Media No Start Stop CH Received Comments - . D C LA1497 See Notes 1 110 8550 Open 1/21/2003 GR and ROP5 Data ~g c....-Oens ity 25 Col 2751 8466 Open 1/21/2003 ~ U11duction/Resistivity 25 Col 2751 8500 Open 1/21/2003 Rpt Directional Survey 0 8555 Open 12/19/2002 ~g c..st> n ic 25 Col 2751 8484 Open 1/21/2003 ~ Gamma Ray ivfb 25 Col 108 8501 Open 1/21/2003 ~/D ~ctional Survey 0 8555 Open 12/19/2002 CkÓg l.ßee Notes 2 Col 2751 8466 Open 1/21/2003 Platform Express, Borehole Profile - HCAl ~ c.&e Notes 25 Col 2751 8500 Open 1/21/2003 Platform Express. Triple Combo - TCOM vÆÍ> C d>498 See Notes 2545 8518 Open 1/21/2003 Main and Repeat PEX, 'ì V· 1) AIT, SHC log --~ :1:69' Gamma Ray 25 Col 108 8501 Open 1/21/2003 --- 1!69 ~ Neutron 25 Col 2751 8466 Open 1/21/2003 ~ ~ssure Blu 800 8422 Case 2/28/2003 --- -- -----. Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2022160 Well Name/No. PRUDHOE BAY UN BORE V-113 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23125-00-00 MD 8555 TVD 7041 Completion Date 2/18/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? (j, / N £ ¿ ~ \.. l,riDJ-f o-vv~ Chips Received? ~ Analysis Y ~ Received? Daily History Received? ß/N (JyN Formation Tops Comments: _~r' '- . ----. ---~- ~ Date: J Ò (fl~YL /ù.,~ r- .--------- Compliance Reviewed By: 3 t, MM).. (\ ~ \- CJM ì-t'vu.'~, )'(, c¡ - Y v:'A.t ~ ~il C.o V'> Q~'I.~ ç d , --- ) / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: IPERFS / FRAC 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 645'FNL, 1847'FEL,Sec. 11,T11N, R11E,UM At top of productive interval 4595' FNL,561' FEL, Sec. 03, T11N, R11E,UM At effective depth 4591' FNL,565'FEL, Sec. 03,T11N, R11E, UM At total depth 4513' FNL,639'FEL, Sec. 03,T11N, R11E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Length 112' 2726' Surface Production 8516' Perforation depth: Operation shutdown_ Pull tubing _ Stimulate _X Alter casing _ 5. Type of Well: Development _X Exploratory_ Stratigraphic_ SeNice_ Plugging _ Perforate _X Repair well _ Other 6. Datum elevation (OF or KB feet) RKB 82 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number (asp's 590456,5969881) V-113 ~9, Permit number / approval number (asp's 586446, 5971163) 202-216/303-037 10. API number (asp's 586442, 5971167) (asp's 586345, 5971264) 8555 feet 7041 feet 50-029-23125-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool Plugs (measured) Reversed Circulate @ 8066' ctm (02/13/2003) 8066 feet 6571 feet Junk (measured) Size Cemented Measured Depth True Vertical Depth 20" 260 sx ArcticSet (Aprox) 138' 138' 7-5/8" 271 bbls Permafrost 'L', 2752' 2495' 197 sx Class 'G' 5-1/2" x 3-1/2" 62 bbls SilicaLite, 182 sx 8542' 7028' Class 'G'. measured Open Perfs 8048' - 8102' true vertical Open Perfs 6554' - 6606' Tubing (size, grade, and measured depth) 3-1/2" 9.2#, L-80 TBG @ 7797'. RECEIVE[) MAY 05 2003 Alaska 0;) & Ga13 Con~. OJmmi3Skm Anchorage Packers & SSSV (type & measured depth) BKR LOC SEAL Assy @ 7797'. Top of BKR PBR @ 7800'. BTM of 3-1/2" BKR SEAL Assy @ 7816'. 3-1/2" HES X Nipple @ 2341' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Prior to well operation SHUT-IN Subsequent to operation 03/06/2003 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A;i~ Æ ..J~ Title, Techica' Assistan. DeWayne R. Schnorr IRBDMS Sf-I.. MAY Form 10-404 Rev 06/15/88 · 3484 Tubinç¡ Pressure 4788 16. Status of well classification as: 362 367 Suspended _ Service Date April 08, 2003 Prepared by DeWayne R. Schnorr 564-5174 Ú iUH1 . ORIGI~AL SUBM'T IN DUPLICATE ~ ') ) V-113 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/03/2003 NEW WELL POST: JEWELRY LOG--DEPTH CONTROL; PERFORATING; STATIC BOTTOM HOLE PRESSURE SURVEY 02/03/2003 NEW WELL POST: PERFORATING 02/08/2003 FRACTURING: FRACTURING 02/11/2003 FRACTURING: FILL CLEAN OUT 02/12/2003 FRACTURING: FILL CLEAN OUT 02/13/2003 NEW WELL POST: FILL CLEAN OUT 02/17/2003 NEW WELL POST: GAS LIFT--FOR RATE 02/18/2003 NEW WELL POST: GAS LIFT--FOR RATE 02/2S/2003 NEW WELL POST: HOT OIL TREATMENT 04/07/2003 TESTEVENT --- BOPD: 2,382, BWPD: 0, MCFPD: 6,407, AL Rate: 2,741 EVENT SUMMARY 02/03/03 JEWELRY LOG I PERFORATED 80481-81021 WITH 2.S" POWERFLOW BH 2506 6 SPF, EH 0.66", PENE 4.8". CORRELATE TO SWS JEWELRY LOG DATED 3-FEB- 2003, REFERENCED TO SWS PEX-TCOM LOG DATED 1S-DEC-2002. LOG FROM TD 843S1 TO 6400' GR/CCUTEMP @SO FPM. PRESSURE STOP IN LUBRICATOR 383 PSI, 82861 MD/67001 SS = 3092.1 PSI, 81811 MD/66001 SS = 3050.2 PSI. 81811 MD/66001 SS = 3049.1 PSI, TWO MRTs RUN ON TOOLS, BOTH READ 160 DEGF. 80771 MD/65001 SS = 300S.8 PSI, «< TD 843S1 »> «< WELL SHUT-IN »> 02/03/03 JEWELRY LOG THEN PERF INTERVAL 80481-81021 WITH 2.S" 2S06 PF BH HMX, 1S0 PSI WHP, NO CHANGE IN PRESSURE, RBIH TO PERFORM SBHPS. 02/08/03 FRAC'D ICI SAND PERFS 80481-81021 WITH YF125LG SYSTEM AND 203.6K# OF 16/20 CLlTE. EXTENDED 10 PPGA STAGE WITH AN ADDITIONAL 67 BBLS SLURRY, SIO TO 7705 PSI WITH 46 BBLS GW FLUSH AWAY (DIESEL DID NOT MAKE IT TO TREE). PLACED 223.8# PROP BEHIND PIPE LEAVING 7K# PROP IN CASING, ESTIMATED TOS IS 60001. SIO OCCURED WITH 237 BBLS OF 10 PPGA IN PERFS. MAX TREATING PRESSURE --- 770S PSI. AVERAGE TREATING PRESSURE --- S042 PSI. LOADTO RECOVER --- 1470 BBLS. ALL TREESAVER CUPS RECOVERED. WELL IS NOT FREEZE PROTECTED, HEATERS APPLIED TO TREE. 02/11/03 CTU #S, POST FRAC FCO. MIRU. 02/12/03 PERFORM BOP TEST. RIH W/2.S" DJN & JET ICE FROM SURFACE TO - 13001 CTM. NO ICE FROM 1300' ON DOWN. TAG TOP OF SAND @ 71401 CTM. POOH. RIH W/2.S" BD NOZZLE. BEGIN REVERSING FROM 71001. PUMPING SWEEPS OF FLOPRO DOWN BACKSIDE. REVERSE DOWN TO 77S0'. Page 1 ) ) V-113 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/13/03 CONTINUE REVERSING FROM 77501 TO 80001 WI FLOPRO SWEEPS. CIRC BOTTOMS UP. REVERSE TO 80661 (CTM). LOOSING RETURNS. CLEAR COIL. DROP BALL, JET GLMIS WI HEC. JET GLMIS WI WATER, CHASE OUT OF HOLE @ 50 %. FREEZE PROTECT TO 3000' WI NEAT METH. FREEZE PROTECT SURFACE LINES & STAND BY DUE TO WEATHER. (-40 DEGREES F) 02/17/03 WELL SHUT IN ON ARRIVAL «< SSV TRIPPED »> SET 3-1/2 XC-SUB- PULL DGLV FROM STA# 1. 02/18/03 PULL DGLVIS STA# 2 & 4. SET LGLV STA# 4,2, & 1. PULL C-SUB. TURN WELL OVER TO DSO. HOT OIL (DIESEL) I.A. - PUMPED 104 BBLS DIESEL @ 180 DEG F DOWN I.A TO 02/25/03 ASSIST APC TEST UNIT. UNLOADED 20 BBLS NEAT INTO TEST UNIT TANK. RDMO. 04/07/03 TESTEVENT --- BOPD: 2,382, BWPD: 0, MCFPD: 6,407, AL Rate: 2,741 FLUIDS PUMPED BBLS 3 PRESSURE TEST LUBRICATOR TO 3000 PSI W/1 BBL OF DIESEL (3 TESTS) 77 NEAT METHANOL 185 60/40 METHANOL WATER 234 DIESEL 1317 1% EXTRA SLICK KCL WATER 1470 FRESH WATER 65 FLOPRO 35 FLOPRO (150,000 LSRV) 42 HEC WITH BREAKER 3428 TOTAL INITIAL PERFS 02103/2003 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2.5" HSD POWERFLOW BH 2506, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 80481 - 81021 Page 2 '" to STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) ~'I.:'...~,~VJ~¡..I,''''''~'''\I':'''...¡' ~".' 1. Status of Well :r:~':'~:~;~'~/¡\l Classification of Service Well iii Oil 0 Gas 0 Suspended 0 Abandoned 0 S~rviç~.., ··I";~~~'~'" 2. Name of Operator i '.\:.". "':J. ;~:: "'~~"',~ 7 Permit Number :: c. ,'" "i\I!:,:.",f.r40~ W;,~''1':l;' . BP Exploration (Alaska) Inc. ; ,"2--¿i.(td:~'ftt'~I'!~''''''''''··''''··''' 202-216 3. Address .¡:~ \¡I!~;g;~-u 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 !::..",...Lf'~".,..,.. 50-029-23125-00 4. Location of well at surface q.." "",...., 9. Unit or Lease Name 4635' NSL, 1847' WEL, SEC. 11, T11 N, R11 E, UM X = 590457, Y = 5969881 Prudhoe Bay Unit At top of productive interval 683' NSL, 559' WEL, SEC. 03, T11 N, R11 E, UM X = 586448, Y = 5971162 10. Well Number At total depth 786' NSL, 660' WEL, SEC. 03, T11 N, R11 E, UM X = 586345, Y = 5971264 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool RKB = 82' ADL 02~241 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband* 15. Water depth, if offshore 16. No. of Completions 12/8/2002 12/14/2002 l,i,li:' ~ ~~.3 <. NIAMSL One 17. Total Depth (MD+TVD) 18. Plug Back d~Pth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8555 7041 FT 8443' 6933 Fr iii Yes 0 No (Nipple) 2341' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, PEX, BHC Sonic .?3. CASING SIZE 3411 X 20" 7-5/8" 5-1/2" x 3-1/2" V-113 WT. PER FT. 91.5# 29.7# 15.5# / 9.2# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 109' 42" 27' 2752' 9-7/8" 26' 8542' 6-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 366 sx PF 'L', 200 sx Class 'G' 148 sx Class 'G', 184 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 8048' - 8102' 6554' - 6606' SIZE 3-1/2", 9.2#, L-80 TUBING RECORD DEPTH SET (MD) 7816' PACKER SET (MD) N/A 25. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4375' Freeze Protected with 130 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 25, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 3/8/2003 4 TEST PERIOD 4,050 4,559 -0- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 326 24-HoUR RATE ?8. CHOKE SIZE 1760 OIL GRAVITY-API (CORR) GAS-OIL RATIO 1,126 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Sidewall Core summary is attached. Form 10-407 Rev. 07-01-80 MAR 1 L 2003 -- ~~&-aOil&GasCons.__n ~~ R B OM S B Fl '~ I 2 ª~tlln Duplicate ,j ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 3301' 2881' Ugnu M Sands 4836' 4022' Schrader Bluff N Sands 5163' 4266' Schrader Bluff 0 Sands 5370' 4423' Base Schrader I Top Colville 5838' 4775' HRZ 7718' 6242' Kalubik 7940' 6451' Kuparuk D 8039' 6546' Kuparuk C 8048' 6554' Kuparuk B 8172' 6673' Kuparuk A RECEIVED MAR 1 ¿ 2003 Alaska Oil 8, (~a9G1JßS Qr ;cð&" Summary of Daily Drilling Reports and Post-Rig Work, Sidewall Core Summary, ~ .aUllOOlun 8300' 6796' Miluveach 8377' 6869' 31. List of Attachments: 32. I ~erebY certify that the fO~Oi~9 is true and correct to the best of my knowledge Signed TerrieHubble /f0l\N...t ~ ~ Title Technical Assistant Date Ol:j·, I· O~ V -113 202-216 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Neil Magee, 564-5119 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) Sidewall Core Record for V-113 (Borealis) December 15, 2002 Run 1 of 2 Description Core Measured Bullet Core Core Visual Petroleum Observable Number Depth Shot? Recovered? Length Rock Type Stain Odor 1 4526 yes yes 1.75" ss none faint 2 4510 yes yes 1.75" ss none faint 3 4491 yes yes 1.75" ss none faint 4 4455 yes yes 1.75" ss none faint 5 4433 yes yes 1.75" sltst none' faint 6 4411 yes yes 1.5" ss none faint 7 4324 yes yes 1.5" sltst none faint 8 4315 yes yes 1.75" sltst none faint 9 4296 yes yes 1.75" ss none faint 10 4288 yes yes 1.75" ss none faint 11 4260 yes yes 1.75" sltst none faint 12 4251 yes yes 1.75" sltst none faint 13 4241 yes yes 1.75" ss none faint 14 4216 yes yes 1.75" ss none faint 15 4197 yes yes 1.75" ss none faint 16 4181 yes yes 1.75" ss none faint 17 4169 yes yes 1.5" ss none faint 18 4153 yes yes 1.5" sltst none faint 19 4143 yes yes 1.75" ss none faint 20 4130 yes yes 1.5" ss none faint 21 4117 yes yes 1.5" sltst none faint 22 4105 yes yes 1.5" ss none faint 23 4089 yes yes 1.75" ss none faint 24 4079 yes yes 1.5" ss none faint 25 4066 yes yes 1.75" ss none faint 26 4051 yes yes 1.75" ss none faint 27 4037 yes yes 1.75" ss none faint 28 4027 yes yes 1.75" ss mod faint 29 4017 yes yes 1.5" ss mod faint 30 3996 yes yes 1.5" ss faint faint 31 3979 yes yes 1.75" ss mod faint 32 3966 yes yes 1.5" sltst faint faint 33 3948 yes yes 1.5" ss mod faint 34 3929 yes yes 1.75 " broken ss w/coaJ none faint 35 3900 yes yes 1" broken ss none faint 36 3895 yes yes 1.5" ss none faint 37 3879 yes yes 1.75" ss none faint 38 3866 yes yes 1.75" ss none faint 39 3854 yes yes 1" broken ss wi tr coaJ none faint 40 3845 yes yes 1" ss none faint 41 3838 yes yes 1.5" ss mod faint 42 3789 yes yes 1" broken ss none faint 43 3776 yes yes 1.5" ss mod faint 44 3761 yes yes 1.5" broken ss none faint 45 3742 yes yes 1.5" ss none faint ) ) Sidewall Core Record fOf V-113 (Borealis) December 15,2002 Run 2 of 2 Description Core Measured Bullet Core Core Visual Petroleum Observable Numbef Depth Shot? Recovered? Length Rock Type Stain Odor 1 3727 yes yes 1.25" sltst none faint 2 3714 yes yes 1.5" ss mod faint 3 3707 yes yes 1" broken ss none faint 4 3697 yes yes 1.75" ss faint faint 5 3687 yes yes 1.25" ss none faint 6 3677 yes yes 1.4" ss none faint 7 3667 yes yes 1.5" ss mod faint 8 3657 yes yes 1.6" ss none faint 9 3649 yes no 10 3639 yes yes 1.75" ss none faint 11 3631 yes yes 1.75" broken ss none faint 12 3625 yes yes 1.5" sltst faint faint 13 3619 yes yes 1.6" ss mod faint 14 3611 yes no 15 3601 yes yes 1.25" broken ss w/coal none faint 16 3586 yes yes 1.75" ss faint faint 17 3580 yes yes 1.75" ss mod faint 18 3566 yes no 19 3555 yes yes 1.5" ss mod faint 20 3550 yes yes 1.5" broken ss faint faint 21 3463 yes yes 1.25" ss mod faint 22 3447 yes yes 1.25" broken ss faint faint 23 3431 yes yes 1.75" ss faint faint 24 3417 yes yes 1.5" clay none faint 25 3379 yes no 26 3363 yes yes 1.75" ss mod faint 27 3355 yes yes 1.5" ss good live faint 28 3345 yes yes 1.5" broken ss good live faint 29 3337 yes yes 1 " ss good live faint 30 3179 yes no 31 3174 yes no 32 3154 yes no 33 3114 yes yes 1.25" broken ss faint faint 34 3101 yes yes 1.25" ss none faint 35 3095 yes yes 1.6" ss none faint 36 3065 yes yes .5" ss none faint 37 2980 no no 38 2970 yes yes 1.25" ss none faint 39 2964 yes yes 1.5" ss faint faint 40 2957 no no 41 2947 yes yes 1.5" ss faint faint 42 2939 yes yes 1.5" ss faint faint 43 2924 no no 44 2914 yes yes 1.25" broken ss none faint 45 2904 yes yes 1.5" ss none faint Legal Name: Common Name: Test Date 12/11/2002 LOT V-113 V-113 Test Type Test Depth (TMD) 2,752.0 (ft) BP Leak-Off Test Summary Test Depth (TVD) 2,495.0 (ft) AMW 9.70 (ppg) Surface.·PresSure Leak.OffPresSul"e(BHP} 620 (psi) 1,877 (psi) EMW 14.48 (ppg) -..' _/ Printed: 12/26/2002 10: 18:04 AM , , ) ) BP Operations Summary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-113 V-113 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/5/2002 Rig Release: 12/18/2002 Rig Number: 9ES Spud Date: 12/8/2002 End: 12/18/2002 Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2002 00:00 - 05:00 5.00 RIGU P PRE Move rig, pit and pump module and mechanic shop from V-03 to V-113. Move camp. Accept rig at 05:00 hrs 12/8/2002 05:00 - 14:00 9.00 RIGU P PRE Nipple up riser on 20" diverter. Take on water and start mixing spud mud. 14:00 - 16:30 2.50 RIGU P PRE Load pipe shed and prepare tools. 16:30 - 17:30 1.00 RIGU P PRE Pick up drill collars and jars stand in derrick. 17:30 - 18:30 1.00 RIGU P PRE Function test diverter bag and 16" diverter line knife valve. Witness of test waived by John Crisp of AOGCC. 18:30 - 19:00 0.50 RIGU P PRE Prespud meeting with all rig personnel. 19:00 - 20:00 1.00 DRILL P SURF Make up bit and BHA. Test and orient MWD. Fill hole and check for leaks. 20:00 - 22:30 2.50 DRILL P SURF Spud well. Drill 9 7/8" hole to 355'. Start drilling with water, drill first 5' and confirm no cement in returns convert to spud mud. Maintain high vis mud 22:30 - 23:00 0.50 DRILL P SURF POH 2 stands and replace with drilling jars and HWDP. 23:00 - 00:00 1.00 DRILL P SURF Drill 9 7/8" hole to 405'. WOB 35K, TO RPM 80, MM RPM 96, GPM 600, PSI 1 000. Maintain 300 vis mud. 12/9/2002 00:00 - 08:30 8.50 DRILL P SURF Drill 9 7/8" hole to 1561'. WOB 35K, TO RPM 80, MM RPM 104, GPM 650, PSI 2500. Maintain 300 vis mud. Kick off well at 449'. Build angle, slide 1/2 of every stand drilled. AST=4 ART=2.6 08:30 - 09:00 0.50 DRILL P SURF Circulate bottoms up to clean hole prior to trip. 09:00 - 09:30 0.50 DRILL P SURF POH to BHA. Intermittent tight spots, max over pull 30K. 09:30 - 10:30 1.00 DRILL P SURF POH and stand back BHA. Change bit. 10:30 - 11 :30 1.00 DRILL P SURF RIH with new bit and BHA. 11 :30 - 12:00 0.50 DRILL P SURF RIH with drill pipe to TO. No fill 12:00 - 17:00 5.00 DRILL P SURF Drill 9 7/8" hole to 2762'. WOB 35K, TO RPM 80, MM RPM 104, GPM 650, PSI 3150. Maintain 300 vis mud. Slides yielding 3-6 deg/100' AST=1.52 ART=1.02 17:00 - 17:30 0.50 DRILL P SURF Circulate hole clean prior to trip. 17:30 - 20:30 3.00 DRILL P SURF POH to 700'. Well swabbing, pump and back ream from bottom to 1250'. POH clean to 700' 20:30 - 22:00 1.50 DRILL P SURF RIH to 2060'. Wash and ream from 2060' to bottom. 22:00 - 23:00 1.00 DRILL P SURF Circulate and condition mud to clean hole. Pump around 55 bbl sweep with 20 Ibs/bbl wallnut shell. 23:00 - 00:00 1.00 DRILL P SURF POH to run 7 5/8" casing. Pull off bottom with no excessive drag and no swabbing. 12/1 012002 00:00 - 00:30 0.50 DRILL P SURF POH, standing back 4" DP. 00:30 - 03:00 2.50 DRILL P SURF Stand back HWDP, UD BHA # 2. 03:00 - 05:30 2.50 CASE P SURF M/U Landing Jt. , Make Dummy run, change bails, M/U fill-up tool, RlU 7 5/8" casing equipment. 05:30 - 09:00 3.50 CASE P SURF Run 66 Jts, 7 5/8" Casing as per program. Shoe @ 2752'. 09:00 - 09:30 0.50 CASE P SURF RID Fill-up Tool, M/U Hanger & Land Same. M/U Cement Head & Line. 09:30 - 11 :30 2.00 CEMT P SURF Stage up pumps to 8 BPM @ 550 psi. Circ. & Cond Mud for Cement Job. FV = 44, PV = 22, YP = 12. 11:30 -13:30 2.00 CEMT P SURF Switch to HOWCO. Pump 15 Bbls Water, Test lines to 3500 Printed: 12/26/2002 10: 18: 11 AM · . ) -) BP Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-113 V-113 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/5/2002 Rig Release: 12/18/2002 Rig Number: 9ES Spud Date: 12/8/2002 End: 12/18/2002 Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2002 11 :30 - 13:30 2.00 CEMT P SURF psi., Drop bottom plug, Mix & pump 50 Bbls, 10.6 ppg, Alpha spacer, Mix & Pump 271 Bbls, 10.7 ppg., Permafrost "L" Lead Slurry, Mix & pump 41 Bbls. 15.8 ppg., Premium "G", Tail Slurry. Drop top plug and chase with 1 0 Bbls. Water. Switch to Rig Pumps and displace wi 114 Bbls Mud. Reciprocate Casing throughout job. Pump Plug wi 1500 psi. Check Floats - OK. CIP @ 13:15 Hrs. 23 Bbls good Cmt to surface. 13:30 - 15:30 2.00 CEMT P SURF RID Cement Head. Flush stack, Flow line & Knife Valve. LID landing Jt. RID casing Equip.Clear floor. cia Bails. 15:30 - 17:00 1.50 DIVRTR P SURF N/D Diverter & Line, remove from cellar. 17:00 - 17:30 0.50 WHSUR P SURF N/U Speed Head. Test Metal/Metal seal to 1000 psi. 17:30 - 19:30 2.00 BOPSURP SURF N/U 13 5/8", 5000 psi BOP & Equipment. 19:30 - 23:00 3.50 BOPSURP SURF R/U test equip. & Test BOPE - 250 I 4000 psi, Annular 250 I 3500 psi. Witness of test waived by John Crisp, AOGCC. 23:00 - 23:30 0.50 BOPSURP SURF Install Wear Bushing. 23:30 - 00:00 0.50 DRILL P PROD1 Bring BHA # 3 to floor. 12/11/2002 00:00 - 04:30 4.50 DRILL P PROD1 P/U 126 Jts. 4" DP from shed & stand back in derrick. 04:30 - 06:30 2.00 DRILL P PROD1 M/U BHA #3 , Orient & RIH past Tam collar to 1065'. 06:30 - 07:00 0.50 DRILL P PROD1 Fill pipe, Test MWD, Close bag and test Tam Collar wi 1000 psi 07:00 - 08:30 1.50 DRILL P PROD1 Cut & Slip Drlg. Line 50 ft., Service Top Drive. 08:30 - 09:30 1.00 DRILL P PROD1 RIH, P/U DP to 2510'. 09:30 - 10:30 1.00 DRILL P PROD1 Break Circulation. Test 7 5/8" Casing to 3500 psi for 30 Minutes 10:30 -11:00 0.50 DRILL P PROD1 Wash down & tag cement @ 2656' 11 :00 - 12:00 1.00 DRILL P PROD1 Drill Cement to Float Collar @ 2665', drill Shoe Track and clean out rathole to 2762'. 12:00 - 12:30 0.50 DRILL P PROD1 Drill 20' of new hole to 2782'. ART = 0.22 Hrs. 12:30 - 13:00 0.50 DRILL P PROD1 Displace hole wi new 9.7 ppg. LSND Mud. 13:00 - 14:00 1.00 DRILL P PROD1 Perform LOT. Leak Off @ 620 psi. wi 9.7 ppg mud = EMW of 14.48 ppg. Obtain ECD Benchmark readings. 14:00 - 00:00 10.00 DRILL P PROD1 Drill form 2782' to 4374'. 330 GPM @ 2510 psi. TO = 4100 RPM = 60 - 80 Calc ECD = 11.25 ppg. - Drlg ECD = 11.7ppg. to 12.3 ppg. Circulating HI-VIS Sweeps every 200 - 300 ft. Backreaming each stand @ 110 RPM. ART = 3.33 Hrs. AST = 1.25 Hrs. 12/12/2002 00:00 - 00:00 24.00 DRILL P PROD1 Drill from 4374' to 6894'. Backream every stand @ 110 RPM. La - HI Vis sweeps every 300 ft. ECD averaging 0.5 ppg. over calculated while drilling. Drilling @ 6894: 330 GPM @ 3400 psi. TO = 7600 WOB = 10 to 25K. P/U = 157K, ON = 94K, ROT = 117K AST = 6.72 Hrs. ART = 8.02 Hrs 12/13/2002 00:00 - 15:30 15.50 DRILL P PROD1 Drill from 6894' to 7700'.330 GPM @ 3300 psi. TO = 8000 P/U = 172K, ON = 101K, ROT = 128K WOB = 10 to 25K. Pumping HI-VIS Sweeps every 300'. Drilling ECD averaging 0.5 ppg. over calculated. Fault crossed @ 7594' MD - Estimated 168 ft Throw. Started weighting up with spike fluid while drilling after crossing fault. Stopped drilling @ 7700' to complete weight-up. 15:30 - 16:00 0.50 DRILL P PROD1 Complete Weight Up - 10.1 ppg all around. 16:00 - 00:00 8.00 DRILL P PROD1 Drill from 7700' to 8200'. Drilling parameters same. TO up to 8500. P/U = 180K, ON = 111 K, ROT = 140K AST = 5.6 Hrs. ART = 11.1 Hrs. ( From 6894' to 8200') Printed: 12/26/2002 10: 18: 11 AM ") ) BP Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-113 V-113 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/5/2002 Rig Release: 12/18/2002 Rig Number: 9ES Spud Date: 12/8/2002 End: 12/18/2002 Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2002 00:00 - 04:00 4.00 DRILL P PROD1 Drill from 8200' to 8555'. TD as per Geologist. Backream each Stand. 330 GPM @ 3420 psi. TQ = 8000 WOB 20 to 25K. P/U = 191 K, DN = 113K, ROT = 143K. ART = 3.2 Hrs. 04:00 - 06:30 2.50 DRILL P PROD1 Circulate HI -VIS Sweep. ECD = 0.4 ppg. over calculated Circulate second Sweep - HI-VIS Weighted, ECD = 0.29 ppg over. 06:30 - 09:30 3.00 DRILL P PROD1 POH to Shoe @ 2752, No Problems. 09:30 - 10:00 0.50 DRILL P PROD1 Circ. Bottoms Up at Shoe 10:00 - 11 :00 1.00 DRILL P PROD1 Service Top Drive,Drawworks & Crown 11 :00 - 13:30 2.50 DRILL P PROD1 RIH to 8480' - No Problems. 13:30-16:00 2.50 DRILL P PROD1 Wash last stand to bottom. Circulate Sweep. Spot Logging Pill. ECD = 0.25 over calculated. 16:00 - 20:00 4.00 DRILL P PROD1 POH to HWDP. Pulled 25K over @ 8400 & 8250 - wiped once - OK. 20:00 - 22:00 2.00 DRILL P PROD1 Stand back HWDP. LID BHA. Clear & Clean Floor. 22:00 - 00:00 2.00 EVAL P PROD1 PJSM wI SWS. R/U Logging Tools. M/U PEX I BHCS & RIH. 12/15/2002 00:00 - 07:00 7.00 EVAL P PROD1 Log PEX I BHCS from 8555' to 2752'. POH LID Tools. 07:00 - 16:00 9.00 EVAL P PROD1 Make 2 Runs of 45 SWC's each. Taking samples from Ugnu & Schrader. 4 - Empty, 3 - Lost, 3 - Misfires, 80 - recovered. RID SWS. 16:00 - 17:00 1.00 CASE P PROD1 M/U & RIH w/6 3/4" C/O Assy. 17:00 - 18:00 1.00 CASE P PROD1 RIH to Csg Shoe @ 2750'. 18:00 - 18:30 0.50 CASE P PROD1 CBU, 330 GPM 18:30 - 20:00 1.50 CASE P PROD1 RIH to 5600', breaking circulation every 10 stands. 20:00 - 20:30 0.50 CASE P PROD1 CBU, 330 GPM. 20:30 - 22:00 1.50 CASE P PROD1 RIH to 8487, breaking circulation every 10 stands. 22:00 - 00:00 2.00 CASE P PROD1 Wash last stand to bottom - No Fill. Circulate HI-VIS Sweep, 330 GPM @ 2340 psi. , 110 RPM. Monitor Well. Pump Dry Job. 12/16/2002 00:00 - 02:00 2.00 CASE P PROD1 POH, Laying Down DPto 5832', Intermittent drag thru Kuparuk - 10 to 15K over - wipe through -OK. 02:00 - 03:00 1.00 CASE P PROD1 Spot "Steel Seal" Pill across Schrader & Ugnu. 03:00 - 07:00 4.00 CASE P PROD1 Continue POH, LID, to HWDP. 07:00 - 08:30 1.50 CASE P PROD1 LID BHA #4. Clear & clean Floor. 08:30 - 09:30 1.00 CASE P COMP Pull Wear Bushing. Jet wash Stack & Wellhead. Make dummy run wI Hanger & Landing Jt. 09:30 - 10:30 1.00 CASE P COMP Rig Up to run Production Casing. 10:30 - 12:30 2.00 CASE P COMP PJSM. M/U 3.5" Shoe Track, RIH, Check floats - OK. Continue RIH wI 3.5" Prod. Csg. 12:30-13:30 1.00 CASE P COMP RID 3.5" Equip, RlU 5.5" Equip & Fill Up Tool. 13:30 - 17:00 3.50 CASE P COMP Run 5.5" Casing to Shoe @ 2750', Running speed - 1 min. per Jt., Filling every Jt, breaking circulation every 5 Jts & Circulating for 15 minutes every 15 Jts. Full returns, correct displacement & No Losses. 17:00 - 17:30 0.50 CASE P COMP Break circ., stage up pumps to 5 BPM @ 575 psi. Circulate 1.5 times annular volume. 17:30 - 23:00 5.50 CASE P COMP Cont. running 5.5" Csg to 4800'. Same parameters. 23:00 - 00:00 1.00 CASE P COMP Break circ., stage up pumps to 5 BPM. @ 860 psi. Circulate 1.5 times annular volume. 12/17/2002 00:00 - 05:30 5.50 CASE P COMP Continue RIH wI 5.5" Casing to 7660'. Fill every Jt, break circ. every 5 Jts., Circ. for 15 minutes every 15 Jts. 10 BBls short on displacement at this point. Printed: 12/26/2002 10: 1 B: 11 AM ') ') Page 4 of 5 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-113 V-113 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From- To Hours Task Code NPT Phase 12/17/2002 05:30 - 07:00 1.50 CASE P COMP 07:00 - 09:00 2.00 CASE P COMP 09:00 - 09:30 0.50 CEMT P COMP 09:30 - 10:30 1.00 CEMT P COMP 10:30 - 13:00 2.50 CEMT P COMP 13:00 - 13:30 0.50 CEMT P COMP 13:30 - 14:00 0.50 WHSUR P COMP 14:00 - 14:30 0.50 CASE P COMP 14:30 - 16:00 1.50 RUNCOrvP COMP 16:00 - 00:00 8.00 RUNCOrvP COMP 12/18/2002 00:00 - 05:00 5.00 RUNCOrvP COMP 05:00 - 05:30 0.50 RUNCOrvP COMP 05:30 - 09:30 4.00 RUNCOrvP COMP 09:30 - 10:30 1.00 RUNCOrvP COMP 10:30-11:00 0.50 RUNCOrvP COMP 11:00-12:30 1.50 RUNCOrvP COMP 12:30 - 13:30 1.00 RUNCOrvP COMP 13:30 -15:00 1.50 RUNCOrvP COMP 15:00 - 16:00 1.00 WHSUR P COMP 16:00 - 17:30 1.50 BOPSUR P COMP 17:30 - 19:00 1.50 WHSUR P COMP 19:00 - 19:30 0.50 WHSUR P COMP 19:30 - 20:30 1.00 WHSUR P COMP 20:30 - 23:00 2.50 CHEM P COMP 23:00 - 23:30 0.50 WHSUR P COMP Start: 12/5/2002 Rig Release: 12/18/2002 Rig Number: 9ES Spud Date: 12/8/2002 End: 12/18/2002 Description of Operations Circulate 1.5 Times annular capacity (210) Bbls. 4 BPM @ 895 psi. Lost 25 Bbls Circulating. Shut down pumps - Well breathed back 16 BBls. Then Stable. Complete running 189 Jts 5.5" Casing. M/U Hanger & Landing Jt Land String. LID Fill up Tool. R/U Cement Head & Lines. Stage pumps up to 5 BPM @ 1100 psi. Reciprocate Pipe - 170K Up & 80K Down. Initially losing 15 bbls. I Hr while staging up pumps. No losses @ 5 BPM. PJSM wi HOWCO Switch to HOWCO. Pump 5 Bbls. 3% KCL water & test lines to 4000 psi. Pump 25 Bbls, 11.1 ppg. ALPHA Spacer. Pump 62 Bbls, 12.5 ppg. HOWCO, SilicaLite Slurry, followed by 38 Bbls., 15.8 ppg, " Premium" Slurry. Flush lines, drop Combo Plug and switch to Rig Pumps. Displace with 192 bbls filtered seawater. Did not see plug go through XO. Bumped plug wi 3000 psi. Held for 5 Minutes. Bled off - Floats OK. Annulus full & stable. Reciprocated until beginning displacement - unable to P/U w 300K. No Mud losses throughout Job- 100% Returns RID Cement Head, LID Landing Jt., Drain Stack. Install Pack Off, R.I.L.D.S., Test to 5000 psi -OK. RID & clear floor of all Casing equipment. R/U Tubing running equipment. Make Dummy run wi Hanger & landing Jt. Run 3.5", 9.3#, L-80, TC-II Completion tubing & acces. , utilizing Torque-Turn. Continue running 3 1/2" tubing. Torque turn & MU to 2300 ft Ibs. Test casing to 3500 psi - 10 min. Good test. Finish running tubing & simultaneously freeze protect OA with 40 bbl diesel to 2250' TVD. Sting seal assembly into SBR and run in to no-go. Work out space out pups. PU and MU same. PU last jt of tubing. MU tubing hanger & landing joint. Land tubing & verify spaceout. Pick back up to floor with hanger. Reverse in dirt magnet followed by clean seawater sweep then corrosion inhibited seawater. Circ at 4 BPM - 850 psi. Land Tubing Hanger final time. R.I.L.D.S. & torque down. LID Landing Jt. Pressure Tubing to 4000 psi. Chart & hold for 30 min. Bleed tbg to 2500 psi. Pressure annulus to 4000 psi. Chart & hold for 30 Min. Both tests good. Bleed annulus then tubing to "0" . Pressure annulus to 2950 psi to shear DCK. Blow down lines, drain stack. Install TWC & test from below to 2800 psi. NID BOPE & Secure. N/U Adapter Flange & Tree. Test Adapter Flange, P/O & Tree to 5000 psi. - OK. RIU DSM. Pull TWC wi lubricator. Reverse 90 Bbls diesel down annulus, displacing seawater. Allow diesel to U-Tube - Freeze protecting tubing and annulus to 4375'. Install BPV & test to 1000 psi. - OK. Printed: 1212612002 10:18:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP Operations Summary Report V-113 V-113 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/5/2002 Rig Release: 12/18/2002 Rig Number: 9ES From - To Hours Task Code NPT Phase 12/18/2002 23:30 - 00:00 0.50 WHSUR P Page 5 of 5 Spud Date: 12/8/2002 End: 12/18/2002 Description·of Operations CaMP Secure cellar & Complete cleaning pits. RIG RELEASED FROM V-113 @ 23:59 HRS 12/18/2002. Printed: 12/26/2002 10:18:11 AM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well.....................: V-113 API number...............: 50-029-23125-00 Engineer. . . . . . . . . . . . . . . . .: E. Roux RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS. . . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.50 ft KB above permanent.......: 82.00 ft DF above permanent.......: 82.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 288.05 degrees [(c)2002 Anadrill IDEAL ID6 lC_10] 14-Dec-2002 08:08:36 Spud date. . . . . . . . . . . . . . . . : Last survey date. . . . . . . . . : Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 08-Dec-02 14-Dec-02 92 0.00 ft 8555.00 ft '--' ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date.. ..........: 08-Dec-2002 Magnetic field strength..: 1149.72 HCNT Magnetic dec (+E/W-).....: 25.85 degrees Magnetic dip.............: 80.76 degrees ----- MWD survey Reference Reference G.... ..........: Reference H........ ......: Reference Dip......... ...: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1149.72 HCNT 80.77 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.73 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.73 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)...... ..: No degree: 0.00 ---' ANADRILL SCHLUMBERGER Survey Report 14-Dec-2002 08:08:36 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Az imuth Course TVD Vertical Disp1 Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 199.31 0.43 270.27 199.31 199.31 0.71 0.00 -0.75 0.75 270.27 0.22 MWD Incl. Only 3 292.92 0.19 270.27 93.61 292.92 1.19 0.01 -1.25 1.25 270.27 0.26 MWD IFR MSA - 4 384.94 0.30 231.63 92.02 384.94 1.47 -0.14 -1.60 1.60 264.88 0.21 MWD IFR MSA 5 476.81 0.72 259.72 91.87 476.80 2.11 -0.40 -2.35 2.39 260.46 0.52 MWD IFR MSA 6 569.21 1.92 286.30 92.40 569.18 4.17 -0.06 -4.41 4.41 269.16 1.42 MWD IFR MSA - 7 661.45 3.27 297.92 92.24 661.32 8.31 1.60 -8.22 8.37 281.03 1.56 MWD IFR MSA - - 8 753.30 5.10 304.60 91.85 752.92 14.80 5.15 -13.89 14.82 290.33 2.06 MWD IFR MSA - 9 845.31 7.19 310.41 92.01 844.40 24.05 11.20 -21.64 24.37 297.36 2.37 MWD IFR MSA - 10 938.77 7.86 308.19 93.46 937.05 35.46 18.94 -31.12 36.43 301.33 0.78 MWD IFR MSA 11 1032.96 9.64 301.63 94.19 1030.15 49.17 27.06 -42.90 50.72 302.25 2.16 MWD IFR MSA - 12 1125.08 12.34 299.27 92.12 1120.57 66.33 35.92 -58.06 68.27 301.75 2.97 MWD IFR MSA - 13 1220.28 15.44 300.25 95.20 1212.97 88.70 47.28 -77.88 91.11 301.26 3.27 MWD IFR MSA 14 1312.46 17.62 301.16 92.18 1301.34 114.28 60.69 -100.42 117.33 301.14 2.38 MWD IFR MSA - 15 1405.32 18.61 301.65 92.86 1389.60 142.38 75.73 -125.06 146.21 301.20 1.08 MWD IFR MSA 16 1499.03 20.14 299.13 93.71 1478.00 172.74 91.43 -151.89 177.28 301.05 1.86 MWD IFR MSA - 17 1592.69 23.09 292.14 93.66 1565.08 206.90 106.21 -182.99 211.58 300.13 4.18 MWD IFR MSA 18 1686.87 23.93 289.91 94.18 1651.44 244.41 119.67 -218.06 248.74 298.76 1.30 MWD IFR MSA - 19 1779.38 26.90 291.27 92.51 1734.99 284.07 133.66 -255.21 288.09 297.64 3.27 MWD IFR MSA - 20 1871.58 30.08 289.99 92.20 1816.01 328.00 149.13 -296.37 331.78 296.71 3.51 MWD IFR MSA 21 1964.37 32.66 286.80 92.79 1895.24 376.28 164.32 -342.21 379.61 295.65 3.31 MWD IFR MSA - 22 2057.79 35.72 285.55 93.42 1972.50 428.74 178.92 -392.62 431.47 294.50 3.36 MWD IFR MSA ---' 23 2150.58 38.23 285.11 92.79 2046.63 484.48 193.67 -446.44 486.64 293.45 2.72 MWD IFR MSA - 24 2243.34 39.82 286.06 92.76 2118.69 542.83 209.36 -502.70 544.55 292.61 1.83 MWD IFR MSA 25 2336.03 42.55 286.00 92.69 2188.44 603.82 226.22 -561.35 605.22 291.95 2.95 MWD IFR MSA 26 2429.54 42.29 286.22 93.51 2257.47 666.86 243.72 -621.96 668.00 291.40 0.32 MWD IFR MSA - 27 2523.79 41.98 286.56 94.25 2327.36 730.07 261.56 -682.62 731.01 290.97 0.41 MWD IFR MSA - 28 2617.10 41.85 286.64 93.31 2396.80 792.38 279.37 -742.35 793.18 290.62 0.15 MWD IFR MSA - 29 2701.61 43.51 284.72 84.51 2458.93 849.61 294.84 -797.51 850.26 290.29 2.50 MWD IFR MSA - 30 2827.47 44.38 284.96 125.86 2549.55 936.82 317.21 -881.93 937.24 289.78 0.70 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 14-Dec-2002 08:08:36 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) ( ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2921.55 45.57 283.43 94.08 2616.10 1003.16 333.50 -946.40 1003.44 289.41 1.71 MWD IFR MSA 32 3015.37 47.93 283.56 93.82 2680.38 1071.27 349.45 -1012.84 1071.43 289.04 2.52 MWD IFR MSA - 33 3107.82 46.43 284.14 92.45 2743.22 1138.90 365.68 -1078.68 1138.98 288.73 1.69 MWD IFR MSA - 34 3200.87 44.70 282.12 93.05 2808.36 1205.09 380.79 -1143.37 1205.11 288.42 2.42 MWD IFR MSA - 35 3293.80 42.04 282.06 92.93 2875.91 1268.55 394.15 -1205.77 1268.55 288.10 2.86 MWD IFR MSA - 36 3386.78 42.78 282.15 92.98 2944.56 1330.92 407.30 -1267.08 1330.93 287.82 0.80 MWD IFR MSA - 37 3480.85 41.18 284.57 94.07 3014.49 1393.62 421.82 -1328.29 1393.66 287.62 2.42 MWD IFR MSA _/ 38 3572.80 40.68 287.20 91.95 3083.97 1453.80 438.30 -1386.22 1453.86 287.55 1.95 MWD IFR MSA - 39 3667.21 41.62 286.91 94.41 3155.05 1515.92 456.52 -1445.61 1515.98 287.53 1.02 MWD IFR MSA 40 3760.45 44.08 285.90 93.24 3223.41 1579.30 474.41 -1506.44 1579.37 287.48 2.74 MWD IFR MSA - 41 3853.77 41.97 286.60 93.32 3291.63 1642.93 492.22 -1567.57 1643.03 287.43 2.32 MWD IFR MSA - 42 3945.84 42.57 285.99 92.07 3359.76 1704.83 509.59 -1627.01 1704.95 287.39 0.79 MWD IFR MSA - 43 4039.40 44.28 285.09 93.56 3427.71 1769.08 526.81 -1688.97 1769.22 287.32 1.94 MWD IFR MSA - 44 4133.00 42.22 284.92 93.60 3495.88 1833.12 543.42 -1750.91 1833.30 287.24 2.20 MWD IFR MSA - 45 4226.22 40.52 282.68 93.22 3565.84 1894.55 558.13 -1810.72 1894.79 287.13 2.43 MWD IFR MSA 46 4320.58 41.12 281.99 94.36 3637.26 1955.91 571.31 -1870.97 1956.26 286.98 0.80 MWD IFR MSA 47 4413.33 40.80 285.30 92.75 3707.31 2016.52 585.64 -1930.04 2016.94 286.88 2.36 MWD IFR MSA - 48 4507.15 42.22 284.62 93.82 3777.56 2078.60 601.68 -1990.11 2079.08 286.82 1.59 MWD IFR MSA - 49 4600.14 41.36 285.19 92.99 3846.89 2140.48 617.62 -2050.00 2141.01 286.77 1.01 MWD IFR MSA - 50 4693.62 43.03 285.63 93.48 3916.15 2203.19 634.31 -2110.52 2203.78 286.73 1.81 MWD IFR MSA - 51 4787.34 40.87 286.05 93.72 3985.84 2265.79 651.40 -2170.79 2266.42 286.70 2.32 MWD IFR MSA - 52 4879.77 42.06 284.93 92.43 4055.11 2326.93 667.74 -2229.77 2327.61 286.67 1.52 MWD IFR MSA ~ - 53 4972.14 42.67 288.62 92.37 4123.37 2389.14 685.71 -2289.34 2389.83 286.67 2.77 MWD IFR MSA - 54 5065.88 40.80 290.11 93.74 4193.32 2451.52 706.38 -2348.21 2452.16 286.74 2.26 MWD IFR MSA 55 5159.11 42.71 289.90 93.23 4262.86 2513.56 727.62 -2406.55 2514.14 286.82 2.05 MWD IFR MSA - 56 5252.43 41.32 291.14 93.32 4332.20 2575.96 749.51 -2465.05 2576.47 286.91 1.73 MWD IFR MSA - 57 5346.24 38.16 291.48 93.81 4404.32 2635.83 771.29 -2520.91 2636.27 287.01 3.38 MWD IFR MSA - 58 5438.40 39.20 289.83 92.16 4476.27 2693.36 791.60 -2574.81 2693.74 287.09 1.59 MWD IFR MSA 59 5530.89 41.09 288.54 92.49 4546.97 2752.98 811.18 -2631.12 2753.33 287.13 2.23 MWD IFR MSA - 60 5623.73 41.71 289.35 92.84 4616.61 2814.37 831.12 -2689.19 2814.70 287.17 0.88 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 14-Dec-2002 08:08:36 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5717.64 42.98 289.08 93.91 4686.02 2877.61 851.93 -2748.93 2877.91 287.22 1.37 MWD IFR MSA - 62 5811.38 41.84 288.33 93.74 4755.23 2940.82 872.21 -2808.80 2941.11 287.25 1.33 MWD IFR MSA - 63 5905.13 42.28 288.64 93.75 4824.83 3003.63 892.12 -2868.37 3003.90 287.28 0.52 MWD IFR MSA 64 5998.72 43.46 286.81 93.59 4893.42 3067.29 911.50 -2929.01 3067.56 287.29 1.83 MWD IFR MSA - 65 6092.64 43.53 285.04 93.92 4961.56 3131.88 929.23 -2991.17 3132.19 287.26 1.30 MWD IFR MSA 66 6186.31 41.75 283.65 93.67 5030.46 3195.20 944.96 -3052.64 3195.55 287.20 2.15 MWD IFR MSA - 67 6280.09 41.98 281.21 93.78 5100.31 3257.47 958.43 -3113.75 3257.91 287.11 1.75 MWD IFR MSA - --- 68 6373.37 42.78 286.54 93.28 5169.24 3320.14 973.52 -3174.74 3320.65 287.05 3.94 MWD IFR·MSA - 69 6466.90 43.36 291.52 93.53 5237.58 3383.95 994.34 -3235.07 3384.44 287.09 3.69 MWD IFR MSA - 70 6561.30 41.52 296.05 94.40 5307.26 3447.31 1019.98 -3293.35 3447.68 287.21 3.78 MWD IFR MSA - 71 6653.93 41.99 295.16 92.63 5376.36 3508.46 1046.64 -3348.98 3508.72 287.36 0.82 MWD IFR MSA - 72 6746.81 42.18 296.04 92.88 5445.29 3570.17 1073.53 -3405.11 3570.33 287.50 0.67 MWD IFR MSA 73 6839.41 42.90 296.03 92.60 5513.52 3632.17 1101.01 -3461.37 3632.26 287.65 0.78 MWD IFR MSA - 74 6932.81 42.13 294.42 93.40 5582.37 3694.78 1127.92 -3518.46 3694.83 287.77 1.43 MWD IFR MSA - 75 7025.67 40.64 290.13 92.86 5652.05 3755.97 1151.21 -3575.23 3756.00 287.85 3.45 MWD IFR MSA 76 7119.35 39.16 284.70 93.68 5723.94 3816.01 1169.22 -3632.50 3816.04 287.84 4.04 MWD IFR MSA 77 7213.01 37.02 284.99 93.66 5797.65 3873.70 1184.02 -3688.35 3873.73 287.80 2.29 MWD IFR MSA - 78 7307.13 30.93 283.67 94.12 5875.67 3926.16 1197.07 -3739.27 3926.21 287.75 6.52 MWD IFR MSA - 79 7400.18 28.99 289.43 93.05 5956.30 3972.56 1210.23 -3783.79 3972.62 287.74 3.73 MWD IFR MSA - 80 7493.27 26.39 293.45 93.09 6038.73 4015.72 1225.97 -3824.05 4015.76 287.78 3.44 MWD IFR MSA - 81 7586.39 25.80 291.61 93.12 6122.35 4056.55 1241.67 -3861.88 4056.58 287.82 1.08 MWD IFR MSA 82 7679.81 23.93 297.76 93.42 6207.13 4095.52 1257.99 -3897.55 4095.54 287.89 3.41 MWD IFR MSA ~ - 83 7772.49 21.46 303.05 92.68 6292.63 4130.44 1275.99 -3928.40 4130.44 287.99 3.45 MWD IFR MSA - 84 7863.22 19.49 306.53 90.73 6377.63 4160.83 1294.06 -3954.48 4160.83 288.12 2.55 MWD IFR MSA - 85 7957.45 17.07 309.63 94.23 6467.10 4188.60 1312.24 -3977.77 4188.63 288.26 2.77 MWD IFR MSA - 86 8050.57 15.05 317.71 93.12 6556.59 4211.82 1329.90 -3996.43 4211.90 288.41 3.23 MWD IFR MSA - 87 8145.22 16.66 318.59 94.65 6647.64 4234.19 1349.17 -4013.68 4234.37 288.58 1.72 MWD IFR MSA - 88 8239.00 17.44 317.67 93.78 6737.30 4257.98 1369.64 -4032.03 4258.31 288.76 0.88 MWD IFR MSA - 89 8330.73 17.06 315.05 91.73 6824.90 4281.92 1389.33 -4050.80 4282.43 288.93 0.94 MWD IFR MSA - 90 8425.68 15.76 313.77 94.95 6915.98 4305.95 1408.10 -4069.95 4306.65 289.08 1.42 MWD IFR MSA - ANADRILL SCHLUMBERGER Survey Report 14-Dec-2002 08:08:36 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8499.80 14.98 311.44 74.12 6987.45 4323.81 1421.41 -4084.40 4324.66 289.19 1.34 MWD IFR MSA 92 8555.00 14.98 311.44 55.20 7040.77 4336.91 1430.85 -4095.09 4337.87 289.26 0.00 Projected to TD [(c)2002 Anadrill IDEAL ID6 1C_10] ,-/ ~/ õ V-113 Schlumberuer Survey Report - Geodetic Report Date: 14-Dec-02 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 289.300° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 11 Structure / Slot: V-Pad/V-113 TVD Reference Datum: KB Well: V·113 TVD Reference Elevation: 82.000 ft relative to MSL Borehole: V·113 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWUAPI#: 500292312500 Magnetic Declination: +25.716° Survey Name I Date: V -113 / December 14, 2002 Total Field Strength: 57508.486 nT Tort I AHD I DDII ERD ratio: 170.924° / 4373.59 ft /5.958/0.621 Magnetic Dip: 80.772° / Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: December 17, 2002 - Location LatlLong: N 701938.831, W 1491559.064 Magnetic Declination Model: BGGM 2002 Location Grid NlE Y/X: N 5969880.670 ftUS, E 590456.760 ftUE North Reference: T rue North Grid Convergence Angle: +0.69077917° Total Corr Mag North -> True North: +25.716° Grid Scale Factor: 0.99990930 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.0 0.00 0.00 0.00 0.00 5969880.67 590456.76 N 70 19 3B.831 W 149 1559.064 199.31 0.43 270.3 199.31 0.71 0.00 -0.75 0.22 5969880.66 590456.01 N 70 19 38.831 W 149 1559.086 292.92 0.19 270.3 292.92 1.19 0.01 -1.25 0.26 5969880.66 590455.51 N 701938.831 W 149 1559.101 384.94 0.30 231.6 384.94 1.46 -0.14 -1.60 0.21 5969880.51 590455.17 N 701938.829 W 149 1559.111 476.81 0.72 259.7 476.80 2.09 -0.40 -2.35 0.52 5969880.25 590454.41 N 701938.827 W 1491559.133 569.21 1.92 286.3 569.18 4.14 -0.06 -4.41 1.42 5969880.55 590452.35 N 701938.830 W 149 1559.193 661 .45 3.27 297.9 661 .32 8.28 1.60 -8.22 1.56 5969882.17 590448.52 N 70 19 38.846 W 149 15 59.304 753.30 5.10 304.6 752.92 14.81 5.15 -13.89 2.06 5969885.65 590442.81 N 701938.881 W 149 1559.470 845.31 7.19 310.4 844.40 24.13 11.20 -21.64 2.37 5969891.61 590434.98 N 701938.941 W 149 1559.696 --- 938.77 7.86 308.2 937.05 35.63 18.94 -31 .12 0.78 5969899.24 590425.42 N 701939.017 W 1491559.973 1032.96 9.64 301.6 1030.15 49.43 27.06 -42.90 2.16 5969907.21 590413.54 N 701939.097 W149160.316 1125.08 12.34 299.3 1120.57 66.67 35.92 -58.06 2.97 5969915.89 590398.28 N 70 19 39.184 W 149 160.759 1220.28 15.44 300.3 1212.97 89.13 47.28 -77.88 3.27 5969927.01 590378.32 N 70 19 39.296 W 149 16 1.338 1312.46 17.62 301.2 1301.34 114.84 60.69 -100.42 2.38 5969940.13 590355.62 N 70 19 39.428 W 149 16 1.996 1405.32 18.61 301.6 1389.60 143.07 75.73 -125.06 1.08 5969954.88 590330.80 N 70 19 39.576 W 149162.715 1499.03 20.14 299.1 1478.00 173.57 91.43 -151.89 1.86 5969970.26 590303.80 N 70 19 39.730 W 149 163.498 1592.69 23.09 292.1 1565.08 207.81 106.21 -182.99 4.18 5969984.66 590272.52 N 70 19 39.875 W 149 164.406 1686.87 23.93 289.9 1651.44 245.36 119.67 -218.06 1.30 5969997.70 590237.29 N 70 19 40.008 W 149 165.430 V-113 ASP Final Surveys.xls Page 1 of 4 12/17/2002-12:16 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVD vSec N/-S E/-W OLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1779.38 26.90 291.3 1734.99 285.05 133.66 -255.21 3.27 5970011.23 590199.98 N 70 1940.145 W 149166.514 1871.58 30.08 290.0 1816.01 329.01 149.13 -296.37 3.51 5970026.20 590158.64 N 70 19 40.297 W 149167.716 1964.37 32.66 286.8 1895.24 377.28 164.32 -342.21 3.31 5970040.84 590112.63 N 70 1940.447 W 149 169.054 2057.79 35.72 285.5 1972.50 429.69 178.92 -392.62 3.36 5970054.83 590062.05 N 701940.590 W 149 1610.526 2150.58 38.23 285.1 2046.63 485.36 193.67 -446.44 2.72 5970068.92 590008.06 N 701940.735 W 149 1612.097 2243.34 39.82 286.1 2118.69 543.64 209.36 -502.70 1.83 5970083.94 589951.62 N 70 1940.890 W 149 16 13.739 2336.03 42.55 286.0 2188.44 604.57 226.22 -561.35 2.95 5970100.08 589892.77 N 70 1941.055 W 1491615.452 2429.54 42.29 286.2 2257.47 667.55 243.72 -621.96 0.32 5970116.85 589831.97 N 70 1941.227 W 1491617.221 2523.79 41.98 286.6 2327.36 730.70 261.56 -682.62 0.41 5970133.96 589771 .10 N 70 1941.403 W 149 1618.992 2617.1 0 41.85 286.6 2396.80 792.97 279.37 -742.35 0.15 5970151.04 589711.16 N 70 1941.578 W 1491620.736 ~ 2701.61 43.51 284.7 2458.93 850.13 294.84 -797.51 2.50 5970165.84 589655.83 N 70 1941.730 W 1491622.346 2827.4 7 44.38 285.0 2549.55 937.21 317.21 -881.93 0.70 5970187.19 589571 .15 N701941.950 W1491624.811 2921.55 45.57 283.4 2616.10 1003.44 333.50 -946.40 1.71 5970202.71 589506.50 N 70 19 42.11 0 W 149 16 26.693 3015.37 47.93 283.6 2680.38 1071.42 349.45 -1012.84 2.52 5970217.85 589439.87 N 70 19 42.267 W 149 16 28.632 3107.82 46.43 284.1 2743.22 1138.92 365.68 -1078.68 1.69 5970233.28 589373.85 N 70 19 42.426 W 149 16 30.554 3200.87 44.70 282.1 2808.36 1204.97 380.79 -1143.37 2.42 5970247.61 589308.99 N 70 19 42.575 W 149 16 32.443 3293.80 42.04 282.1 2875.91 1268.28 394.15 -1205.77 2.86 5970260.22 589246.44 N 701942.706 W 1491634.265 3386.78 42.78 282.1 2944.56 1330.49 407.30 -1267.08 0.80 5970272.63 589184.98 N 70 19 42.835 W 149 16 36.055 3480.85 41.18 284.6 3014.49 1393.06 421.82 -1328.29 2.42 5970286.41 589123.60 N 701942.978 W 1491637.842 3572.80 40.68 287.2 3083.97 1453.18 438.30 -1386.22 1.95 5970302.18 589065.49 N 701943.140 W 1491639.533 3667.21 41.62 286.9 3155.06 1515.26 456.52 -1445.61 1.02 5970319.68 589005.88 N701943.319 W1491641.267 3760.45 44.08 285.9 3223.41 1578.58 474.41 -1506.44 2.74 5970336.84 588944.85 N 70 19 43.495 W 149 16 43.043 3853.77 41.97 286.6 3291.63 1642.16 492.22 -1567.57 2.32 5970353.91 588883.52 N 70 19 43.670 W 149 16 44.828 3945.84 42.57 286.0 3359.76 1704.00 509.59 -1627.01 0.79 5970370.57 588823.88· N 70 19 43.841 W 149 16 46.563 4039.40 44.28 285.1 3427.71 1768.17 526.81 -1688.97 1.94 5970387.04 588761.72- N 701944.010 W 149 1648.372 4133.00 42.22 284.9 3495.88 1832.12 543.42 -1750.91 2.20 5970402.89 588699.59 N 701944.173 W 1491650.180 -~ 4226.22 40.52 282.7 3565.84 1893.44 558.13 -1810.73 2.42 5970416.88 588639.60 N 701944.318 W 1491651.927 4320.58 41.12 282.0 3637.25 1954.66 571.31 -1870.99 0.80 5970429.33 588579.20 N 70 1944.447 W 1491653.686 4413.33 40.80 285.3 3707.30 2015.15 585.64 -1930.05 2.36 5970442.95 588519.96 N 701944.588 W 149 1655.411 4507.15 42.22 284.6 3777.55 2077.15 601.69 -1990.13 1.59 5970458.27 588459.71 N 701944.746 W 1491657.165 4600.14 41.36 285.2 3846.88 2138.93 617.62 -2050.01 1.01 5970473.48 588399.64 N 701944.902 W 149 1658.913 4693.62 43.03 285.6 3916.14 2201.57 634.31 -2110.53 1.81 5970489.43 588338.93 N 701945.066 W 149 170.680 4787.34 40.87 286.0 3985.83 2264.10 651 .41 -2170.80 2.32 5970505.80 588278.46 N 70 19 45.234 W 149 172.440 4879.77 42.06 284.9 4055.10 2325.17 667.74 -2229.78 1.52 5970521.42 588219.30 N 70 19 45.395 W 149174.162 4972.14 42.67 288.6 4123.36 2387.33 685.71 -2289.35 2.77 5970538.67 588159.52 N 70 19 45.571 W 149 175.901 V-113 ASP Final Surveys.xls Page 2 of 4 12/17/2002-12:16 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ·S E/·W DLS Northing Easting Latitude Longitude (ft) (") (0) (ft) (ft) (ft) (ft) (0/100ft) (ftU5) (ftU5) 5065.88 40.80 290.1 4193.31 2449.73 706.39 -2348.22 2.26 5970558.63 588100.41 N 70 1945.774 W 149 177.620 5159.11 42.71 289.9 4262.85 2511.80 727.62 -2406.56 2.05 5970579.16 588041 .83 N 701945.983 W 149 179.323 5252.43 41.32 291.1 4332.19 2574.25 749.51 -2465.06 1.73 5970600.34 587983.07 N 701946.198 W 1491711.031 5346.24 38.16 291.5 4404.31 2634.18 771.30 -2520.93 3.38 5970621.45 587926.95 N 701946.412 W 149 1712.663 5438.40 39.20 289.8 4476.26 2691 .75 791 .60 -2574.82 1.59 5970641 .1 0 587872.82 N 701946.612 W 1491714.236 5530.89 41.09 288.5 4546.96 2751.38 811.18 -2631.14 2.23 5970660.00 587816.28 N 701946.804 W 149 17 15.881 5623.73 41.71 289.4 4616.60 2812.77 831.12 -2689.20 0.88 5970679.23 587757.98 N 701947.000 W 149 17 17.576 5717.64 42.98 289.1 4686.01 2876.03 851.94 -2748.94 1.37 5970699.33 587698.01 N 701947.204 W 149 1719.320 5811.38 41.84 288.3 4755.22 2939.24 872.21 -2808.82 1.33 5970718.88 587637.89 N 701947.404 W 1491721.069 5905.13 42.28 288.6 4824.82 3002.04 892.13 -2868.38 0.52 5970738.07 587578.10 N 701947.599 W 1491722.808 .~ 5998.72 43.46 286.8 4893.41 3065.68 911.50 -2929.03 1.83 5970756.71 587517.23 N 701947.790 W 1491724.579 6092.64 43.53 285.0 4961.55 3130.21 929.23 -2991.18 1.30 5970773.69 587454.87 N 70 19 47.964 W 149 17 26.394 6186.31 41.75 283.6 5030.45 3193.42 944.97 -3052.65 2.15 5970788.68 587393.22 N 70 19 48.118 W 149 17 28.188 6280.09 41.98 281.2 5100.30 3255.54 958.43 -3113.76 1.75 5970801.41 587331.96 N 70 19 48.250 W 149 17 29.973 6373.37 42.78 286.5 5169.23 3318.09 973.52 -3174.75 3.94 5970815.76 587270.80 N 701948.399 W 1491731.753 6466.90 43.36 291.5 5237.57 3381.92 994.35 -3235.08 3.69 5970835.85 587210.23 N 701948.603 W 1491733.515 6561.30 41.52 296.0 5307.25 3445.39 1019.98 -3293.36 3.78 5970860.78 587151.65 N 701948.855 W 149 1735.217 6653.93 41.99 295.2 5376.35 3506.71 1046.64 -3348.99 0.82 5970886.76 587095.71 N 70 19 49.117 W 149 17 36.841 6746.81 42.18 296.0 5445.28 3568.58 1073.54 -3405.13 0.67 5970912.98 587039.26 N 701949.381 W 1491738.481 6839.41 42.90 296.0 5513.51 3630.76 1101.02 -3461.38 0.78 5970939.78 586982.68 N 701949.651 W 149 1740.124 6932.81 42.13 294.4 5582.36 3693.53 1127.92 -3518.47 1.43 5970965.99 586925.27 N 70 1949.916 W 1491741.791 7025.67 40.64 290.1 5652.04 3754.81 1151.21 -3575.24 3.45 5970988.59 586868.23 N 70 19 50.144 W 149 17 43.448 7119.35 39.16 284.7 5723.93 3814.81 1169.22 -3632.51 4.04 5971005.91 586810.75 N 701950.321 W 1491745.121 7213.01 37.02 285.0 5797.64 3872.41 1184.02 -3688.36 2.29 5971020.03 586754.7~ N 701950.467 W 1491746.752 7307.13 30.93 283.7 5875.66 3924.79 1197.08 -3739.28 6.52 5971032.47 586703.66 N 70 19 50.595 W 149 17 48.239 7400.18 28.99 289.4 5956.29 3971.15 1210.23 -3783.80 3.73 5971045.09 586659.00 N 701950.724 W 149 1749.539 .~ 7493.27 26.39 293.5 6038.72 4014.36 1225.97 -3824.06 3.44 5971060.34 586618.55 N 701950.878 W 1491750.714 7586.39 25.80 291.6 6122.34 4055.25 1241.67 -3861.89 1.08 5971075.58 586580.54 N 701951.033 W 149 1751.819 7679.81 23.93 297.8 6207.12 4094.31 1257.99 -3897.56 3.41 5971091.47 586544.68 N 701951.193 W 149 1752.861 7772.49 21.46 303.0 6292.62 4129.38 1276.00 -3928.42 3.45 5971109.10 586513.61 N 701951.370 W 1491753.762 7863.22 19.49 306.5 6377.62 4159.96 1294.06 -3954.49 2.55 5971126.84 586487.32 N 701951.547 W 1491754.524 7957.45 17.07 309.6 6467.09 4187.95 1312.24 -3977.78 2.77 5971144.74 586463.82 N 701951.726 W 149 1755.204 8050.57 15.05 317.7 6556.58 4211.40 1329.90 -3996.45 3.23 5971162.18 586444.94 N 70 1951.900 W 1491755.749 8145.22 16.66 318.6 6647.63 4234.05 1349.17 -4013.69 1.72 5971181.23 586427.47 N 70 19 52.089 W 149 17 56.253 8239.00 17.44 317.7 6737.29 4258.14 1369.64 -4032.05 0.88 5971201.48 586408.87 N 70 1952.290 W 1491756.789 V-113 ASP Final Surveys.xls Page 3 of 4 12/17/2002-12:16 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec NI-S E/-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8330.73 17.06 315.0 6824.89 4282.35 1389.33 -4050.81 0.94 5971220.94 586389.87 N 70 19 52.484 W 149 1757.337 8425.68 15.76 313.8 6915.97 4306.63 1408.11 -4069.96 1.42 5971239.48 586370.50 N 70 19 52.668 W 149 17 57.897 8499.80 14.98 311.4 6987.44 4324.67 1421.41 -4084.41 1.34 5971252.61 586355.89 N 70 1952.799 W 149 1758.319 8555.00 14.98 311.4 7040.76 4337.88 1430.85 -4095.11 0.00 5971261.92 586345.08 N 70 19 52.892 W 149 17 58.631 , j - --- V-113 ASP Final Surveys.xls Page 4 of 4 12/17/2002-12:16 PM Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well V-113 ~O~ "óJJlf' E-103 dol-e;)aO Job # Log Description SBHP SURVEY SBHP SURVEY PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED FEB 28 2003 AlaaIœ Oii & Gas Cons. Commiseion Anchorage 02104103 01/26/03 02119/03 NO. 2676 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Midnight Sun Date BL Sepia Color CD -/ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth R~~ úOo~ ~ ') ') \f-I~A- z...11Þ/O 3 ,.,..,I/Q 2.("(03. ø~ 2(?/ð3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Size Cemented Measured Depth True vertical Depth 20" 260 sx Arctic Set (Aprox) 138' 138' 7-5/8" 271 bbls Permafrost 'L', 2752' 2495' 197 sx Class 'G' 5-1/2" x 3-1/2" 62 bbls SilicaLite, 182 sx 8542' 7028' Class 'G'. 1. Type of reques/.: . Abandon_ Suspend_ FRAC Alter casing _ Repair well - Change approved program _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 645' FNL, 1847' FEL, Sec. 11, T11 N, R11 E, UM At top of productive interval 4595' FNL, 561' FEL, SEC 03, T11N, R11E, UM At effective depth 4513'FNL,639'FEL,Sec.03,T11N, R11E,UM At total depth 4513' FNL, 639' FEL, Sec 03 T11N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Length 112' 2726' Surface Production 8516' Perforation depth: Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service_ (asp's 590456, 5969881) (asp's 586446, 5971163) (asp's 586367,5971244) (asp's 586345, 5971264) 8555 feet 7041 feet 8443 feet 6933 feet Plugs (measured) Junk (measured) measured Open Perfs 8048' - 8102' true vertical Open Perfs 6554' - 6606' Tubing (size, grade, and measured depth 3-1/2",9.2#, L-80 TBG @ 7797'. Re-enter suspended well _ Time extension Stimulate _X Variance Periorate 6. Datum elevation (DF or KB feet) RKB 82.0 feet 7.UnnorPropertyname Other Prudhoe Bay Unit 8. Well number V-113 /' 9. Permit numbe~proval number 202-216 10. API number 50-029-23125-00 11. Field / Pool Prudhoe Bay Field I Borealis Pool RECE~\fED í:.-~ F- !t=~ l'ì 5 0¿ 0 0 3 "_' .I __. \.. Alaska Oil & Gas Cons. Gmmnissicm Anchorage Packers & SSSV (type & measured depth) BKR LOC SEAL Assy @ 7797'. Top of BKR PBR @ 7800'. BTM of 3-1/2" BKR SEAL ASSY @ 7816'. 3-1/2" HES X Nipple @ 2341' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch 14. Estimated date for commencing operation / 15. Status of well classification as: February, 2003 16. If proposal was verbally approved Oil _X Gas Suspended _ Name of approver 17. I hereby certify that the foregoing is true a Service ~ .'V Questions? Call Bruce Smith, (907) 564-5093. Title: Borealis Development Petroleum Engineer Date February 04, 2003 Prepared by DeWayne R. Schnorr 564·5174 Signed Bruce Smith FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance Mechanical Integrity Test X Subsequen.!.!orm required 10- l./-o t.f Approved by order of the Commission ORIGINAL SIGNED BY M L. Ijm RBO~1S BFL Form 10-403 Rev 06/15/88 · ""-"', I'¡ ,'\ 1 "\ ,¡ , \. ...' t.: . Approval no. 3CJ3-037 Commissioner ,s/1f6 Date r::-cr¡ I r ""''''1'1 SUBMIT IN TRIPLICATE bp February 04, 2003 ') ") ... ,\If.,II. .....~ ~~. .~; ¡~. .",.~\\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for V-113 Fracture Stimulation Program BP Exploration Alaska, Inc. proposes to fracture stimulate well V-113. Attached is the Fracturing procedure, which consists of 1500 bbls of water for /' diagnostics and fracturing with 200 Mlbs of 16/20 Carbo Lite proppant. See pump schedule for details. The pump schedule is subject to change; fluid and proppant volumes should be adequate to address any contingencies. The procedure includes the following major steps: The procedure includes the following major steps: Category NOB STEP Description S 1500 1 Pull and dummy GLV. o 1500 2 MIT IA /' o 1500 3 Perform Data Frac & Frac. Shut-in. C 1500 4 FCO. Freeze protect. Shut-in. S 1500 5 InstaIlGLV's. T 1500 6 Frac, Flowback, HOT tubing, Simultaneously POP. T 1500 7 Mobile Test Separator Test schedule. Last Test: Max Deviation: Perf Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S value: Reference Log: BHT & BHP: New Completion, never tested 44° @ 6093' MD 17° @ 8181' MD 2.813" X Nipple 8443' MD New Well New Well o ppm 12/02 Schlumberger PEX estimated 158° F & 3050 psia @ 6600' TVDSS ) ) 1. Slickline a) Perforate and run static survey from prior programs before moving to this program. /' b) Report well conditions. WHP, WHT, lA, OA. Production rate. Freeze Protect wellbore and flowline. c) Pull and dummy gas lift valves. d) Service Tree 2. Fracture Treatment a) Load Frac tanks with - 100 of seawater; - 1500 bbls are required (excluding tank bottoms). b) RU the tree-saver/isolation tool for 3Y2 "- 9.3 #/ft. tubing (see attached tubing detail). PT backside to 4000 psi and maintain 3500 psi throughout treatment (set inner annulus pop-off at 4000 psi). Note this well has a 10' floating seal assembly and maintenance of 2500 psi on IA is required to stay in the PBR. Pressure test treating lines to 8500 psi. Set Nitrogen pop-off valve at 7500 psig. Set pump trips afterwards to 7500 psi. This well is expected to treat at ± 7000 psi. It is recommended that 4 pumps be on location (1 backup). /' c) Breaker tests will be performed on fluids prior to frac. The breaker schedule will be designed to ensure fluid stability at end of pump time with complete break with-in one hour of shut down. A minimum of 100 cp @ 100 sec^-1 is required at shut down. d) Begin pumping Data Frac, initial rate will be 5 bpm while displacing wellbore fluid, after spotting Data Frac fluid a few feet above top perf increase rate to 25 bpm and displace data frac. Shut down for ISIP, monitor for closure time, calculate efficiency and re-design frac schedule as necessary (Pad size, fluid loss additive, etc.) e) Additional diagnostic tests may be performed after data frac analysis. Consult with engineer before proceeding with frac. f) Re-establish injection, when add rates are lined out start counting PAD. Pump the proppant schedule as detailed in the attached pump schedule. Flush with linear fluid. Switch to diesel flush if at all possible for freeze protect. (34 bbls), switch back to linear fluid. g) Bleed off excess annulus pressure. Rig down Service Company. 3. Post Fracture a) Perform CTU fill cleanout to original PBTD (-8443' corr) 1 Perform an overbalanced pressure fill clean-out, circulating gel and sand to a tank. A connection to a flowline will not be available. 2 Use filtered seawater to clean-out. If gel sweeps are required to clean-out, have lab verify that breaker loading is adequate to break polymer & mix water at 150° F. 3 Freeze protect to 3000' with neat MEOH. b) Slickline to install gas lift design to lift from bottom. c) Shut-in pending frac flowback. ) ) 4. Frac Flowback a) As soon as possible flowback through portable flow-back separator: 1 For analog Kuparuk frac flowback, see L-11 0 & L-107 well files. 2 Kuparuk wells tend to hydrate-off, HOT oillA with 100 bbls of hot diesel followed by 20 bbls of neat MEOH. Kick off well simultaneouslv with POP well. 3 Expect FWHTs of 50 - 60°F and watercuts of 100% to begin with. Treat gas lift with methanol to prevent freezing. Attempt to quantify returned proppant flushed to tank. . 4 Unload the well with 0.5 MMSCFGPD. 5 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T to 1 MMSCFGPD. 6 Conduct 4 hour well tests. If after 12 hours, solids are <0.1 %, then increase GL T to 1.8 MMSCFGPD. 7 Do not surge well to flowback proppant. Surging could cause formation failure and sand production. 8 Continue producing to the flowback separator until the gel load has been recovered or watercut <10% and the solids production <0.1 %. g Schedule wellbore for Pad Separator test. b) Place well on production at gas lift rate of 1.8 MMSCFPD, Place well on normal 15 day AOGCC required testing schedule. c) Service tree. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @BP.com Sincerely, j ~ '-J /~ Bruce W. Smith GPB Borealis Development Engineer ) TREE = 3-118"5M CIIN W 8..LHEAD = 11" FMC Ä'C'iÜAiÒR; w.'".'"."w·'"·..····¡;j'Ä· KB. ELEV = B2 .0' B F. ELEV = 56.43' KOP = 500' 'Max "Aiïgi~;;; . ·····44·@600¿' ·ÖatUmMD··;;;····· 'ï:>äfuiïïïVD;;;'" ..... 17-513" GSG, 29.7#, S-95/L.:-I3IJ', ID = 6.eT~" H "ll52' µ Minimum ID = 2.813" @ 2341' 3 -112" H ES XN NIPPL E f3-1/2" lBG, 92#. L·BO, TC-Il .0007 bpf, ID = 2.992" H 7797' 5-1fl" eSG, 15.5#. L-BO, D = 4.Q50" 1-1 779':1 1& 1/2" X3-112" XO, ID = 3.000" H 7820' PERF ORA TION SIJ MW\ RY RB=' LQ G: ANGLE AT TOP PffiF: Note: Refer to Production DB for histarical perf data SIZ E SPF INTER\! AL Dp nIS qz DA TE PB 1D H 8443' 3-1f2" eSG, 9.2#. L-BO, D = 2.002" H 8542' DA TE REV BY C OMUENTS 12/1GIO:2 DAV/KK ORIGINAL CQMPLETION V-113 - - ~ ~ 965' I 2341' I . ~ ) SAFE TV NOTE S: H7-518" TAM PORT COLLAR, ID = 6.875" 1 H3-1f2" HES X NIP, ID = 2.813" I GA S LIFT tv1A. ND R8..S ST tvD TVD DE\! TYPE VLV LATCH PORT DATE L 4 4126 3491 42 KBG2-) DMY BTM 0 12/181D2 3 5478 45D7 40 KBG2-9 DMY BTM 0 12/181D2 :2 68D7 5400 43 KBO,:2-9 DMY BTM 0 12/181D2 1 7718 6242 23 KBa.2-Q DCK-2 BTM 12/18102 I I 1773' H3-1I2" BKR CMD SUDING SLV, ID = 2.813" 17m' 7800' 7816' 78441' 7861' 8119' HSKR Lor; 5EALASSY.ID =3.00" I H TOP OF BKR PBR, ID = 4.0D" I IjBTM DF 3-112" BKR SEið.LASSY.ID =3.1)0" H3-1f2" HES X NIP, ID = 2.813" I H3-1f2" HES X NIP, ID = 2.813" I HpUPJTW/ RA TAG 1 . 8233' HpUPJTW/ RA TAG I ~ DATE REV BY C0M\48'HS PRUDHOE BAY UNrr WEli.: V-113 PERWlT NQ: 2022160 API No: 50- 021}.. 23125- OD SEe 11, T11N, R11E. 4634' FSL& 1846' FEL BP 6<pler:tien (Alaskal 1/15/2003 Schlumbel'ger NO. 2809 Alaska Data and Consulting Services Company: Alaska Oil & Gas Cons Comm 3940 Arctic Blvd, Suite 300 Attn: Lisa Weepie Anchorage, AK 99503-5711 333 West 7th Ave, Suite 100 ATTN: Sherrie Anchorage, AK 99501 Field: Borealis ,-. Well Job# Log Description Date BL Color CD W-212 aO;:)....() CD [0 23001 SCMT 12/10/02 2 V-113 ~Od-d(o 22538 OH EDIT GR & RaPS DATA 12/14/02 1 V-113 J, 22538 MD IMPULSE-GR 12/14/02 1 V-113 22538 TVD IMPULSE-GR 12/14/02 1 L-110 a 0 1- I d 3 22400 RST -SIGMA 07/24/02 1 1 V-113 dO;=}- dllo 22537 OH EDIT PEX,AIT,BHC LOG 12/15/02 1 V-113 .. 22537 PEX-AIT 12/15/02 1 V-113 22537 PEX-DEN/NEUTRON 12/15/02 1 V-113 22537 PEX-TRIPLE COMBO 12/15/02 1 V-113 22537 PEX-BOREHOLE PROFILE 12/15/02 1 V-113 '-/' 22537 BHC 12/15/02 1 V-109 aoa-~o~ 22500 OH EDIT MWD GRlRESISTIVITYIDEN/NEUTRON 11/06/02 V-109 22500 MD VISION RESISTIVITY 11/06/02 1 V-109 22500 TVD VISION RESISTIVITY 11/06/02 1 V-109 22500 MD VISION DEN/NEUTRON 11/06/02 1 ~, V-109 22500 MD VISION RESISTIVITY BOREHOLE PROFILE 11/06/02 1 V-109 V 22500 MD VISION SERVICE BOREHOLE PROFILE 11/06/02 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Sherrie Re~Y.___~IMor~ Date Delivered: JAN 21 2003 .4Jatka en & Gas Cons. Commiseion ~ · -¡~) ) aCB-~/ttJ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-113 Date Dispatche 1 6- Dec-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys 2 RECE\' JED DEC 1 <) 2002 A1a~ O'ì & Gas COns. eommia8\On Anchorage Received By: d (t Wo (->"^ ') Please sign and return to: Anadrill L WD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1 Dec '97 V-II3 Drilling Program- Change of surfa...tting depth an d additional SWC program rl,.vè-21(P Subject: V-II3 Drilling Program- Change of surface casing setting depth an d additional SWC program Date: Tue, 26 Nov 2002 13:19:40 -0600 From: "Magee, D Neil" <MageeDN@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> ) Winton, There has been a change to the approved program which will require the surface casing setting depth to be raised to the SV-1 sand horizon rather than the proposed SV-3 in well V-113. There are no drilling or pressure issues associated with this change and an adequate formation integrity to drill the reservoir section is anticipated based on offset wells in the area. This change is to allow the running of SWC's in the SV-1/Ugnu as a part of the production hole logging program to aid in the identification of a potential water source at V-Pad. Regards, Neil Magee Alaska Drilling & Wells 907 564-5119 Office 907 564-4040 Fax 907 240-8038 Cell ) ~ ~7fÆC? ~ ; ~ !I. .1: L II! I J GÍ ~~!Æ~&!Æ TONY KNOWLES, GOVERNOR AI1ASKA. OIL AND GAS CONSERVATION COltDlISSION 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay UnitV-113 BP Exploration (Alaska) Inc. Permit No: 202-216 Surface Location: 4635' NSL, 1847' WEL, SEC. 11, T11N, RIlE, UM Bottomhole Location: 731' NSL, 793' WEL, SEC. 03, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this;¿¡,r day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W G A- tI / to ( 0',- 12. Distance to nearest property line 13. Distance to nearest well ADL 028240,793' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 500' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade COUDlina 34" x 2011 91.5# H-40 Weld 7 -5/811 29.7# L-80 BTC 5-1/211 15.5# L-80 BTC-M 3-1/211 9.2# L-80 IBT-M Hole 4211 9-7/811 6-3/411 6-3/411 J"' STATE OF ALASKA } ALASKn ·"IL AND GAS CONSERVATION COMfvll6SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 82' Prudhoe Bay Field I Borealis 6. Property Designation Pool (Undefined) ADL 028241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number , V-113 (' 9. Approximate spud d~' 12/05/02 Amount $200,000.00 / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8559' M D I 7007' TVD 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 42 0 Maximum surface 2709 psig, At total depth (TVD) 6700' I 3379 psig Setting Depth TaD Bottom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 3027' 27121 Surface Surface 7789' 6290' 7789' 6290' 8559' 7007' 11. Type Bond (See 20 AAC 25.025) ... 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4635' NSL, 1847' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 672' NSL, 607' WEL, SEC. 03, T11 N, R11 E, UM At total depth 731' NSL, 793' WEL, SEC. 03, T11 N, R11 E, UM Number 2S100302630-277 Lenath 80' 3027' 7789' 770' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 325 sx PF IL', 200 sx Class 'G' 5-1/211 x 3-1/211 Cement Listed Below 146 sx Class 'G', 190 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner true vertical R&@BIVED OCT 30 2002 rooRa 011/& Gas Gons. Commission Anchorage Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program o Drilling Flui Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Neil M ee,564-5119 Prepared By NameINumber: Terrie Hubble, 564-4628 21. ~~:~::y ::~; ~ ro:~ t1!xrrecl to th~ b;;:eO: ;;n;r:;~:'~n~i",e,er 1 Date. .,. I <) _ ~ ~ _ O:L ",\.;~ÇoI:nrriI..~qiU_~Ø9i"\\I;;::.i:,:",.\);,,:,~:,: ,':: ,~'" ,-,:', ,.,', ::;, Permit Number' API Number Approval Date See cover letter ~ 2. - 2/ b 50- 0 2. 7'-- .2..3 / Z :;;- 11/2-1 /0 ~ for other reQuirements Conditions of Approval: Samples Required 0 Yes g No Mud Log Required 0 Yes [8 No Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:Rs-~ 60 f E fc 'Iot/?t? f5l. Approved By ~/¿?- ~ Form 10-401 Rev. 12-01-85 Commissioner ~ ., ~ r' \ÿ Ð'::¡~~ by order of the commission Date 1(/2-(/0 t- Submit In Triplicate V-II3 Pennit to Drill- Diverter Waiver Application ) Subject: V-113 Permit to Drill- Diverter Waiver Application Date: Mon, 18 Nov 2002 12:41:08 -0600 From: "Magee, D Neil" <MageeDN@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Crane, Lowell R" <CraneLR@BP.com> Winton, We would like to retract our request for a diverter waiver on our upcoming V-113 well. We have reviewed our diverter installation on V-113 relative to nearby production modules, and found that there are no proximity issues that would prevent use from installing a diverter line. Regards, Neil Magee Alaska Drilling & Wells 907 564-5119 Office 907 564-4040 Fax 907 240-8038 Cell " ) "tAt!. bp ~~~ ~~. ~.- -..-.. .....I~ .~.....~ ·'j'·'I\- ". ) cK vJ__ 1_ \\l\\.t' '" JA'~V-- vJ; ~r To: Winton Aubert, AOGCC Date: OCt. 25,2002 From: Neil Magee Subject: Dispensation for 20 AAC 25.035 (c) on V-113 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the Borealis/Kuparuk wells at L-pad or V -pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All of the Borealis Development were drilled to the shale underlying the SVl sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±200' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. V-I03 is planned to reach a 9.5 ppg mud weight before TD at -2,778' TVDss. This request is being made based on V-Pad data submitted regarding mud weight, surface open hole logging in the Borealis development (PEX/Dipole sonic), and a meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, 'f1JWì0~ Neil Magee GPB Rotary Drilling Engineer 564-5119 ) I Well Name: V-113 ) Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): 1 Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 590,456.76' Y = 5,969,880.67' 46351 FSL, 1847'FEL,Sec. 11, T11N,R11E X = 586,400' Y = 5,971,150' 672'FSL,607'FEL,Sec.03, T11N, R11E X = 586,213.55' Y = 5,971,207.28' 731'FSL, 793'FEL,Sec.03, T11N, R11E I AFE Number: I BRD5M41 071 / I Estimated Start Date: 112/5/2002 I I MD: 18559' I TVD: 17007' 1 I Rig: I Nabors 9ES / I Operating days to complete: 114.0 I BF/MS: 153.5' 1 I RKB: 182.0' I Well Design (conventional, slim hole, etc.): I Microbore (Iongstring) 1 Objective: I Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-3027'): Initial below Permafrost interval TO Densitv (ppg) 8.5 - 9.2 9.0 - 9.5 9.5 max / Viscositv (seconds) 250-300 200 150-200 Upper Interval Top of HRZ 4-7 10.1 / 3-7 V-113 Drilling Program Outline Fresh Water Surface Hole Mud Yield Point (lb/100fe) 50 - 70 30 - 45 20 - 35 27 -32 1 0-1 5 6 %" Intermediate 1 Production Hole (3027' - 8559'): Interval Density Tau 0 YP PV (ppg) 9.7 17-25 1 0-15 Tau 0 APIFL PH (mls/30min) >20 15-20 8.5 - 9.5 >15 <8 8.5 - 9.5 >15 <8 8.5 - 9.5 Fresh Water LSND pH API HTHP Filtrate Filtrate 8.5-9.5 6-10 8.5-9.5 4-6 <10 by HRZ ) ) Hydraulics: Surface Hole: 97/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1812' 550 4" 17.5# 130 1600 10.2 N/A 18,18,18,16 .942 1812' -3027' 600 4" 17.5# 150 2600 10.4 N/A 18,18,18,16 .942 Production Hole: 6 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3027' -8559' 330 4" 17.5# 210 1700 - 2500 11.1 N/A 5X12 .552 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110' -3027' Surface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport particularly in sliding mode 210 60 500 9.5 Acceptable 250 60 600 9.5 Acceptable 300 60 700 9.5 Acceptable 250 90 500 9.5 Acceptable 315 90 600 9.5 Acceptable 300 90 700 9.5 Acceptable 2797'-5742' To Base ROP's greater than 400'/hr must be Schrader accompanied by a GPM of 330 and fully reamed connections to maintain minimum hole cleaning requirements 250 80 330 9.7 Marginal 250 100 330 9.7 Acceptable 300 80 330 9.7 Marginal/Poor 300 100 330 9.7 Marginal/Manageable 400 80 330 9.7 Very Poor 400 100 330 9.7 Poor 5742'-TD Base ROP's greater than 200'/hr must be Schrader accompanied by maximum pump rates toTD and fully reamed connections to maintain minimum hole cleaning requirements 150 80 330 10.1 Acceptable 200 80 330 10.1 Marginal V-113 Drilling Program Outline Directional: Ver. Anadrill P5 Slot SC KOP: 500' Maximum Hole AnQle: Close Approach Wells: Survey Program: LOQQinQ PrOQram: Surface Production Hole Formation Markers: Formation Tops SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (Na sands) WS1 (Oa sands) Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TMLV (Miluveach) TD Criteria V-113 Drilling Program Outline ) ) 42 degree~ at 2371' MD All Wells Pass Major Risk Criteria V-109 - 31' Ctr-Ctr to 500' MD Standard MWD surveys (IFR+MSA Correction) Drilling: MWD / GR Open Hole: Cased Hole: None Drilling: MWD / GR / PWD Open Hole: e-line PEX/BHC Sonic Cased Hole: SCMT after rig departure TVDss 245' 1535' 1660' 1685' 2045' 2215' 2530' 2850' 3180' 3640' 3960' 4200' 4355' 4650' 5025' 5630' 6120' 6285' 6325' 6390' 6410' 6560' 6700' 6785' Estimated Pore Pressure Not Hydrocarbon Bearing, 8.5 ppg Not Hydrocarbon Bearing, 8.5 ppg Not Hydrocarbon Bearing, 8.5 ppg / Hydrocarbon Bearing, 8.9 ppg Possibly Hydrocarbon Bearing, 9.8 ppg \ V, \ ---- 150' below Miluveach top ) ) CasingITubing PrOQram: Hole Csgl WtlFt Gr;cte Conn Length Top Btm Size Tbg O.D. I MDrrVD MDrrVD bkb 42" Insulated 91.5# H-40 WLD 80' GL 110/110 34"x20" 9-7/8" 7 5/8" 29.7# L-80 BTC 3027' GL 3027'/2712' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 7789' GL 7789'/6290' 6-3/4" 3-1 /2" 9.2# L-80 IBT-mod 770' 7789'/6290' 8559'/7007' Tubing 3-1/2" 9.2# L-80 IBT-mod 7789' GL 7789'/6290' InteQrity TestinJ.:l: Test Point Depth Test Type EMW / Surface Casing Shoe 20' min from LOT 12.8 ppg (minimum for a surface shoe 25bbl kick tolerance) Cement Calculations: The following surface cement calculations are based upon a single stage job The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader Ma sands with 1000 psi ultimate compressive strength and covering the entire Kuparuk interval with 2000 psi/24 hours compressive strength cement. Casinq Size 17-5/8" Surface I Basis: Lead: Based on 1812' of annulus in the permafrost @ 2500/0 excess and 463' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOC: At -2277' MD ~ L/~ Total Cement Volume: Lead 241 bbl I 1352fe I ~sks of Halliburton Permafrost L at 10.7 ppg and 4.15_~k. Tail 41 bbl I 230 fe 1.2J!r"sks of Halliburton Premium 'G' at 15.8 ppg and 1 W5cf/sk. Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOC 500' MD above the top of the Schrader Bluff Ma formation + 300/0 excess and base of cement 500' MD above top of Kuparuk formation. Tail: Based on TOC 500' MD above top of Kuparuk formation + 30% excess + 90' shoe track volume. /~~; Total Cement Volume: Lead 61 bbl I 342fe 1~4 . ks of Halliburton Premium 'G' at 12.5 ppg and 2.34 c l Tail 39 bbl I 218 fe I 99'''sks of Halliburton Premium 'G' (KUP Latex Design) '5.8 ppg and 1.15 cf/sk. V -113 Drilling Program Outline ') -) Well Control: / Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future frac job considerations, the BOP equipment will be tested to 4000 psi / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 9.7 ppg .EMW, 3379 psi @ 6700' TVDss - KUP-A 2709 ~i @ surface (based on 3379 psi at TKUP and a full column of gas @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. H2S: · H2S has not been recorded on V-Pad wells. As a precaution Standard Operating Procedures for H2S should be followed at all times. V-113 Drilling Program Outline ) ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed October 2002. 1. Weld a FMC landing for the FMC Ultra Slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. V-109 well house should not have to be removed for the rig move. Rig Operations: 1. MIRU Nabors 9E~n Slot SC. "'.~') 2. Nipple up diverter spool and riser. (A diverte~t has been made in the drilling application.) PI{~~> DP as required and stand back in derrick. ,.;" 3. MU 9 7/8" drilling assembly with MWD/LWD (see page 4) and directionally drill surface hole to approximately 100' TVD below the SV1 sands (see Anadrill directional plan). An intermediate bit trip to surface will be performed prior t~xiting the Permafrost. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A Tam port collar will be run as a contingency on the chance that cement returns are not seen at the surface. 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4000 psi. / 6. MU 6-3/4" drilling assembly with MWD/LWD (see page 4) and RIH to float collar. Test the 7-5/8" casing to 3500 psi for 30 minutes. ,- 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 7- 5/8" shoe and perform Leak Off Test. ¡""'" 8. Drill to ±200' above the HRZ, ensure mud is in good condition at 9.7 to 9.8 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' of rat hole into the Miluveach formation. 9. Perform open hole logging program. PEX/BHCSonic (e-line conveyed). If the logging run is unsuccessful on the first e-line attempt, the logs are to be run on drill pipe. 1 O. Condition hole for running longstring and POOH. This step may be done when pulling the drill pipe out after reaching TD at the Company Representatives discretion. 11. Run and cement the tapered production casing as required from TD to 500' above the Schrader Ma sands./'Displace the casing with filtered seawater during cementing operations and freeze protect the 5 ¥2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 518" shoe. Record on chart and submit to town.) 12. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. 5?irculate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 13. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 14. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to reach the lower GLM. 15. Rig down and move off. V-113 Drilling Program Outline ') ") V-113 Drilling Program Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location will be V-109. V-113 will be -30' wellhead to wellhead. The well is expected to be on production and will require a surface shut-in during move in. ~ Check landing ring height on V-113, the BOP nipple up may need review. Reference RPs .:. IlDrilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" OperaUonalSpecifics · The surface conductor was set in October 2002. See the attached As-Built for the V-113 location on V-Pad. · Post the Drilling Permit with Summary of Drilling Hazards in doghouse prior to spud. · Diverter is required while drilling surface hole. Notify AOGCC 24 hours advance for Diverter and BOP function test witness if diverter waiver was not approved. . Review the V-Pad data sheet & post in doghouse & field office. ,\I. . ,\ ..·'-.-_-_-.L'--;-.-:::.-:~,._._:._:x:._..,,__.-._._J~._._::I~-._._._._ 'AI:..\": Job 2: Drillina Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by V-113 in the surface interval. "" Drilling Close Approach: The nearest well is V-109 which will have a center-center distance of approximately 30' at the surface. A gyro will be required until the interference from V-1 09 has dissipated. ~ A limited amount of gas hydrates have been observed on the surface holes drilled on V-Pad from the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. uPrudhoe Bay Directional Guidelines" .:. uWell Control Operations Station Bill" Job 3: Install Suñace Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone and 30% excess below the permafrost. A 7-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation should cement to surface not be achieved. V-113 Drilling Program Outline ') '\ .) ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 300/0 excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. UCasing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. uHalliburton Cement Program" .:. uSurface Casing Port Collar Procedure" mfflmw.wm;¡.;·mmm!;;¡mm.-}}!!!m~mm~mmmmmmmmmmmmm~u~m~ß;m.-!mmmmmm;.m¡.mmm;mmmmmmÞÞ,,"'fø¡~p;m¡m'¡1Mfflffl;;;~mmmmmmmmmm'¡mmmmmmmmmmmmmmmm,!;,~¡.mm;;.pmmmm»mmmmmm;mmmJmmmmmmmmmmm~¡,,-mm;J;';;;;¡'~"';'¡;"~;¡""',",...""^",,,,;';!iiw,m;;m!¡;...,;.h~~m..........,iWmmmm;¡.mA. Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been estimated to be 9.7 ppg due to production in the area. Assuming gauge hole, a fracture gr:¡di .A-r~ 12.8 ppg at the surface casing shoe, 9.7 ppg mud in the hole the kick tolerance i ..~Is. An accurate LOT will be required as well as heightened awareness for kick dete on. Contact Drilling Manager if LOT is less than 12.8 ppg. ~ Two faults are expected to be penetrated by V-113 in the production hole. The first in the lower part of the Schrader 0 sands at 4750' TVD. This fault is very small, less than 50' of throw and is not expected to be an issue for lost circulation. The second fault near the base of the Colville at -6010' TVD is more substantial. The throw is estimated @ -150' and is considered a risk for loss circulation. It is feasible however that losses may be encountered when running the production casing string if adequate precautions are not taken including running speed, staging in and optimal mud properties. ~ V-Pad development wells have kick tolerances in the 35-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There are no "Close Approach" issues with the production hole interval of V-113. ~ During the drilling of the Kuparuk reservoir do not add LCM (including Walnut sweeps, Barofibre) other than Baracarb for losses <50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses, >50 BPH may include the use of Barofibre to arrest losses. See modified LCM Decision Chart in Baroid Mud Program. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uShale Drilling- Kingak & HRZ" V-113 Drilling Program Outline ) ') Job 8: LOQ Production Hole Hazards and Contingencies );> Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. );> If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y'2" x 3 V2" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" i'llnmlm"lln_-;:~lm_'n_ -\I\:t,.111111u,:mlmlllnllllualn:':I.II'I,nl:'.I.--ln-- .\.--1-- .nm. _nmm__I__IL-- _~mr:-.--I. -:1;,- ,:III1:O:II::W·;; ;:11111 'Im_ _Lr:'I_I:II11II:-nlt:m:,:--,-:" 1_ .1'11_,:,-..omllllU:lln-mIU:--:I. _1_ .m,:mna!1!IUnnllUlllI'I'UU'--:'.'. _1_ .l!lmlualll,--ml'lumlllml'I".-\.;-;;III--" Job 9: Case & Cement Production Hole Hazards and Contingencies );> The 5-1/2" casing will be cemented to 500' above the top of the Schrader Bluff Ma sands with a single stage-two slurry cement. Due to the small annular spacing, a two stage job is not an option. Getting casing to bottom while maintaining returns is a critical operation. );> Considerable losses during the running and cementing of the production casing has occurred on L and V-Pad. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition, a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. );> Ensure the upper production cement has reached at least a 7)BC thickening value prior to freeze protecting. After freeze protecting the 7 -5/8) x 5-1 12m' casing outer annulus with dead crude to 2200' MD, 2092'TVD, the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) );> Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Loss of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. );> The well will be under-balanced after displacing the cement with sea-water. Verify that the floats / are holding before continuing operations and hold pressure on the well if they are not holding. / );> The X- Nipples, with I.D. of 2.813" is the tightest tolerance for the Weatherford Dual- Plug system, (tapered cement plugs to be used in the 5 %" X 3 %" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been milled down to an 0.0. of 2.5". Caliper to confirm, prior to use. ~' Note: Based on ongoing studies relating to wiper plug failures, drop the top and bottom plug together prior to displacement of cement. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" V-113 Drilling Program Outline ) ') Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be under-balanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. uCompletion Design and Running" .:. llFreeze Protection of Inner Annulus" Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Standard practices apply. .:. Freeze Protection of Inner Annulus. !llIIW,m¡:w¡- ,I: _.1_ ,1II1,mmm,I',Cml,ll,Ullllm,"II,mUl¡U,IIII,llIIllllmm,IIIII,'I,I,"IIIIÞ,I,'II,IIII:III,I,:LI!III,II,:;¡mamC::,.IlU,I,W:;I,I:':,II,.IIIII,,II¡I¡-:¡,,lllltl',II'HU,~',r"I"mll.l,:m,:mmIIJ,n,U-JJJJmmIlJWII'I/lJmmlJI:IJI:JWIUIIWI'IUI:~~IIIJIIIIIIIUAmllllllllm"III~III¡mIIlUJJIIIIIIII;IIIIUI~mm ¡_··'M'~,I.IIIIIUIIIIU'''·''·~I,'I,I_lt;l_ -,-·-W·~·""'J",I'\IIIII'I:_I- ,mmmu V-113 Drilling Program Outline TREE = 3-1/8" 5M CrN . WELLHEA D = 11" FMC ^ÃëTÜÃTÕR-;-W·"~"^""-'^""^ÑÃ 'REra:E\i^';;;"-'""""'""""8:2':¿; 'B'F:'ËCË\T,;;;,,"w^""''''''''''''''''5à:'50; 'Rõp·';;''''·'''-''-''··'''·''''''''·''''''''''''"·''''·''''''''"'''''', "'fV1ã'X^Anglè = 'Baturn'..MÖ';;;..'····,"'''"·,·w.,..,''''',,...,'' Õatum ·rlDw;--~~'--_.''''- ) , 17-5/8" CSG, 29.7#, S-95, ID = 6.875" 1 3027' Possibly L-80 surfacE~ casing 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 1-1 7789' 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 1-1 7789' 15-1/2" X 3-112" CSG XO, ID = 3.000" 1-1 7789' ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE None PBID 1-1 13-1/2" CSG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1-1 DA TE REV BY COMMENTS 10/25/02 nm Proposed Corrpletion 8469' 8559' V -1 07 J ~ ')~AFETY NOTES: 1000' 1-17-5/8" TAM Collar, ID = 6.875" I I I 2200' 1-13-1/2" HES 'X' NIP, ID = 2.813" I ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LA TCH PORT DATE l 3 3500 KBG2-9 DV BTM 3.5x1 2 4500 KBG2-9 DV BTM 3.5x1 1 tbd KBG2-9 DCK-3 BTM 3.5x1 / I I 1-13-1/2" BKR CMD SLIDING SLY, ID = 2.813" 1 ~ ¡--i \ I r I 1 1 I 1-1 BKR LOC SEA L ASSY, ID = 3.00" 1 1-1 TOP OF BKR PBR, ID = 4.00" I I~ BTM OF 3-1/2" BKR SEAL ASSY, ID = 3.00" 1-13-1/2" HES X NIP, ID = 2.813" I 1-13-1/2" HESXNIP,'D=2.813" I ~} ~~ -1PUPJTW 1 RA TAG 1 jt I I above TKUPB ----¡ ~ -1PUPJTW 1 RA TAG 2jt I I above TKUPA DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: V-113 ÆRMIT No: API No: SEC 11, T11 N, R11 E, 4634' FSL & 1846' FEL BP Exploration (Alaska) ) \ J V-113 Well ,Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1814'MD and near the TO hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · A majority of the V-Pad development wells will have "kick tolerances" in the 35-50 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.7 pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · V-113 will cross a fault in the Schrader 0 sands at 5670' -4750' TVD (+/-150'). The estimated throw of the fault is approximately 50'. Loss circulation is considered a minor risk. A second fault will be crossed at 7200' -6010' TVD (+/-150'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. · Under no circumstances add any LCM (including Walnut sweeps, Barofibre) other than Baracarb during the drilling of the production hole section without prior discussions with the Drilling Supervisor. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies õ V-113 Proposed Well Profile - Geodetic Report Minimum Curvature / Lubinski 288.052° N 0.000 ft. E 0.000 ft KB 82.0 ft relative to MSL 55.000 ft relative to MSL 25.734 ° 57507.753 nT 80.772° Noverrnber30, 2002 BGGM 2002 True North +25.734° Well Head Schlumberger Survey 1 DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Report Date: Client: Field: Structure 1 Slot: Well: Borehole: UWUAPI#: Survey Name 1 Date: Tort 1 AHD 1 DDII ERD ratio: Grid Coordinate System: Location LaULong: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: October 21. 2002 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) 3/02 ~:~~~/PlanV-113 d 10/2 V-113 APprove 50029 V-113 (P5) / October 21, 2002 64.956° /4453.28 ft /5.548 10.63E NAD27 Alaska State Planes, Zone 4, US Feel N 70.32745298, W 149.26640672 N 5969880.670 ftUS, E 590456.760 ftUS +0.69077917° 0.99990930 I KBE G1 KOP Crv 1/100 Crv 1.75/100 Station ID Crv 2.5/100 SV6 SV5 SV4 V-113 (P5) report.xls '---/ Grid Coordinates Geographic Coordinates MD I Incl I Azim I TVD I VSec I NJ·S I E}·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 0.00 0.00 320.00 0.00 0.00 0.00 0.00 0.00 5969880.67 590456.76 N 70.32745298 W 149.26640672 327.00 0.00 320.00 327.00 0.00 0.00 0.00 0.00 5969880.67 590456.76 N 70.32745298 W 149.26640672 500.00 0.00 320.00 500.00 0.00 0.00 0.00 0.00 5969880.67 590456.76 N 70.32745298 W 149.26640672 600.00 1.00 320.00 599.99 0.74 0.67 -0.56 1.00 5969881.33 590456.19 N 70.32745481 W 149.26641126 700.00 2.75 320.00 699.94 3.52 3.17 -2.66 1.75 5969883.81 590454.06 N 70.32746164 W 149.26642829 800.00 4.50 320.00 799.73 8.88 8.02 -6.73 1.75 5969888.61 590449.93 N 70.32747489 W 149.26646129 900.00 6.25 320.00 899.29 16.83 15.19 -12.75 1.75 5969895.70 590443.83 N 70.32749448 W 149.26651010 958.13 7.46 313.24 957.00 22.93 20.20 -17.53 2.50 5969900.66 590438.99 N 70.32750817 W 149.26654886 1000.00 8.38 309.61 998.47 28.23 24.01 -21.86 2.50 5969904.41 590434.61 N 70.32751858 W 149.26658398 1100.00 10.67 303.52 1097.09 43.93 33.77 -35.20 2.50 5969914.01 590421.16 N 70.32754524 W 149.26669215 1200.00 13.04 299.60 1194.95 63.91 44.46 -52.73 2.50 5969924.49 590403.50 N 70.32757444 W 149.26683430 1300.00 15.45 296.87 1291.87 88.13 56.05 -74.43 2.50 5969935.81 590381.67 N 70.32760610 W 149.26701026 1400.00 17.88 294.86 1387.67 116.54 68.53 -100.24 2.50 5969947.98 590355.71 N 70.32764020 W 149.26721956 1500.00 20.33 293.33 1482.15 149.09 81.87 -130.13 2.50 5969960.96 590325.66 N 70.32767664 W 149.26746194 1600.00 22.79 292.11 1575.15 185.72 96.04 -164.03 2.50 5969974.72 590291.60 N 70.32771535 W 149.26773683 1645.59 23.92 291.63 1617.00 203.75 102.77 -180.80 2.50 5969981.24 590274.75 N 70.32773374 W 149.26787282 1700.00 25.26 291.12 1666.48 226.35 111.02 -201.88 2.50 5969989.24 590253.58 N 70.32775627 W 149.26804376 1784.25 27.34 290.41 1742.00 263.63 124.24 -236.79 2.50 5970002.03 590218.51 N 70.32779239 W 149.26832685 Page 1 of 3 10/23/2002-10:46 AM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim TVD I VSec N/-S EJ-W DLS Northing Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1800.00 27.73 290.29 1755.97 270.91 126.77 -243.62 2.50 5970004.48 590211.65 N 70.32779930 W 149.26838223 Base Perm 1812.48 28.04 290.20 1767.00 276.74 128.79 -249.09 2.50 5970006.44 590206.16 N 70.32780481 W 149.26842659 1900.00 30.21 289.59 1843.45 319.31 143.28 -289.15 2.50 5970020.44 590165.93 N 70.32784440 W 149.26875144 2000.00 32.69 288.99 1928.75 371.47 160.50 -338.39 2.50 5970037.06 590116.49 N 70.32789143 W 149.26915074 2100.00 35.17 288.46 2011.72 427.28 178.41 -391.25 2.50 5970054.33 590063.42 N 70.32794036 W 149.26957939 2200.00 37.66 287.99 2092.19 486.63 196.97 -447.63 2.50 5970072.21 590006.83 N 70.32799105 W 149.27003659 SV3 2244.30 38.76 287.80 2127.00 514.03 205.39 -473.70 2.50 5970080.32 589980.66 N 70.32801405 W 149.27024800 2300.00 40.14 287.58 2170.01 549.42 216.14 -507.42 2.50 5970090.66 589946.82 N 70.32804341 W 149.27052144 End Crv 2371.44 41.92 287.31 2223.90 596.32 230.19 -552.16 2.50 5970104.17 589901.92 N 70.32808179 W 149.27088425 ~' SV2 2469.68 41.92 287.31 2297.00 661.94 249.72 -614.82 0.00 5970122.94 589839.03 N 70.32813513 W 149.27139238 SV1 2893.02 41.92 287.31 2612.00 944.74 333.84 -884.84 0.00 5970203.79 589568.04 N 70.32836486 W 149.27358210 7-5/8" Csg pt 3027.41 41.92 287.31 2712.00 1034.51 360.55 -970.56 0.00 5970229.46 589482.01 N 70.32843780 W 149.27427725 UG4A 3323.07 41.92 287.31 2932.00 1232.02 419.31 -1159.15 0.00 5970285.94 589292.75 N 70.32859826 W 149.27580665 UG3 3766.57 41.92 287.31 3262.00 1528.29 507.44 -1442.02 0.00 5970370.64 589008.86 N 70.32883889 W 149.27810067 UG1 4384.77 41.92 287.31 3722.00 1941.26 630.29 -1836.34 0.00 5970488.72 588613.13 N 70.32917427 W 149.28129863 Ma 4814.83 41.92 287.31 4042.00 2228.55 715.76 -2110.64 0.00 5970570.87 588337.84 N 70.32940757 W 149.28352328 Na 5137.37 41.92 287.31 4282.00 2444.01 779.85 -2316.37 0.00 5970632.47 588131.37 N 70.32958249 W 149.28519184 Oa 5345.67 41.92 287.31 4437.00 2583.16 821.25 -2449.24 0.00 5970672.26 587998.02 N 70.32969548 W 149.28626949 Obf Base 5742.13 41.92 287.31 4732.00 2848.00 900.03 -2702.11 0.00 5970747.98 587744.25 N 70.32991046 W 149.28832043 CM2 6246.1 0 41.92 287.31 5107.00 3184.67 1000.19 -3023.56 0.00 5970844.25 587421.64 N 70.33018375 W 149.29092767 CM1 7059.17 41.92 287.31 5712.00 3727.82 1161.76 -3542.17 0.00 5970999.54 586901.17 N 70.33062453 W 149.29513420 Drp 3.5/100 7363.18 41.92 287.31 5938.21 3930.90 1222.18 -3736.08 0.00 5971057.61 586706.56 N 70.33078933 W 149.29670708 7400.00 40.63 287.32 5965.88 3955.19 1229.41 -3759.27 ~3.50 5971064.56 586683.29 N 70.33080905 W 149.29689519 7500.00 37.13 287.36 6043.71 4017.94 1248.11 -3819.17 3.50 5971082.53 586623.18 N 70.33086006 W 149.29738106 7600.00 33.63 287.42 6125.23 4075.83 1265.41 -3874.42 3.50 5971099.16 586567.73 N 70.33090724 W 149.29782923 Top HRZ 7690.58 30.46 287.47 6202.00 4123.88 1279.82 -3920.26 3.50 5971113.02 586521.72 N 70.33094655 W 149.29820106 - 7700.00 30.13 287.48 6210.14 4128.63 1281.24 -3924.80 3.50 5971114.38 586517.16 N 70.33095042 W 149.29823789 7800.00 26.63 287.56 6298.10 4176.16 1295.55 -3970.12 3.50 5971128.15 586471.68 N 70.33098945 W 149.29860551 Base HRZ 7876.21 23.96 287.63 6367.00 4208.72 1305.39 -4001.16 3.50 5971137.61 586440.53 N 70.33101628 W 149.29885729 7900.00 23.13 287.65 6388.81 4218.22 1308.27 -4010.21 3.50 5971140.38 586431.44 N 70.33102414 W 149.29893070 K-1 7919.73 22.44 287.68 6407.00 4225.86 1310.59 -4017.50 3.50 5971142.61 586424.13 N 70.33103047 W 149.29898984 End Drp / Target 7989.46 20.00 287.77 6472.00 4251.10 1318.27 -4041.54 3.50 5971150.00 586400.00 N 70.33105141 W 149.29918484 Top Kuparuk 7989.48 20.00 287.77 6472.01 4251.10 1318.27 -4041.54 0.00 5971150.00 586400.00 N 70.33105141 W 149.29918484 KupC 8010.75 20.00 287.77 6492.00 4258.38 1320.49 -4048.47 0.00 5971152.14 586393.04 N 70.33105747 W 149.29924106 LCU / Kup B 8170.38 20.00 287.77 6642.00 4312.97 1337.15 -4100.46 0.00 5971168.17 586340.86 N 70.33110290 W 149.29966279 V-113 (P5) report.xls Page 2 of 3 10/23/2002-10:46 AM Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim I TVD I VSec I N/·S EI·W I DlS Northing I Easting latitude I longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KupA 8319.36 20.00 287.77 6782.00 4363.93 1352.70 -4148.98 0.00 5971183.13 586292.16 N 70.33114531 W 149.30005637 TMLV 8409.83 20.00 287.77 6867.01 4394.87 1362.15 -4178.45 0.00 5971192.22 586262.58 N 70.33117108 W 149.30029542 TD 8559.82 20.00 287.77 7007.95 4446.17 1377.80 -4227.30 0.00 5971207.28 586213.55 N 70.33121376 W 149.30069169 Leqal Description: Surface: 4634 FSL 1847 FEL S11 T11 N R11 E UM Target: 672 FSL 607 FEL S3 T11 N R11 E UM BHL: 731 FSL 793 FEL S3 T11N R11E UM Northina ey} rftUSl 5969880.67 5971150.00 5971207.29 Eastinq eX} rftUSl 590456.76 586400.00 586213.55 .~ ~-' V-113 (P5) report.xls Page 30f3 10/23/2002-10:46 AM ) ') 'I =: "I VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: V-1l3 (P5) Field: Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 288.05 deg Date: October 21, 2002 Schlumberger 0---..-1..- l(OP-crltLoo 500 MD s'oo TVD A 0.00' 32000'8Z o departuro -- ----------- Cry 1.75/100 9/ .-- 600 MD 600 TVD ~ . 1.00' 320.00' 8Z 1 departure Cry 2.5/100 1 000 ...;.....=_..:?..:::::..._=~_:::::.....:::::~~~:r~:~._:::::.....=:::.-.:::::-:::::'...':::::'''''::::'sV6:-o'.iiM6:;~ji:;yvß::_··:::::....:::::...·.:::::~..·=_..:...::.....::::-..::::::·...~:::~·..:~~: ....:::::......::::..-:::::.....::~.:.....:::::..... 17 departure I I -..---..-..1-..........-....-......-..--.... ------ -------------- G1 327 MD 327 TVD : : :: ~ : : : : : ~:1~~22;1V;. : J¡':: ::~: ::~:~: : ;f¡',;!I~;16;MI;.1'ï;r; : : : : : 41.92' 287.31' 8Z 2000 _.................-..................-... ............................. ...............§.!1§.9.~J?!!r!~.r!!........................._........:......_.....................-..................................................-................................-........-..........-.-.......................-.........-.......... -ŠV12893 MÕ ~312 'I'VE! ..- 7:¡¡¡a" ëï.g pi ..... ...... sv:i' :?Ï44 M() :1.1'2ì' ;\iÒ·.... 3027 MD 2712 TVD - 4f92'-287"]1'šž -sV'i 2470 MÕ 2297 TVD - / 1035 departure ",-... ...... Q) - ~~ 8~ o Q) 3000 -:. :':':.. ~,];!\?4z" j;j~,;j..i;¡j).. i¡þ;¡.j3i:li·:·: ..."-:: . ..::~.. ...:" ~.8 1______ c: CO IJG3 3767 MD 3Z62 TVD ;~ I ,-",0 I o 1 t ~ rJGI 4381; MD 3ï2:? TV!) I o m 4000 ~....::::....·:::t:..·..:::::....·::::.....:::.....:::::.....:::::..·..:::::.....:::.....:::::.....::::::....:::::.....:::::.....:::::.....:::::.....::::¡...:::::....:::..................................................................:::::.....::::::........................................-....................................................... ro ~ 1M" 4815 MD 4042 TVD I .2 iB +,~ 1:'1:~rr.,,(i428Trv) -j to:: 1'----- ....! Q) ~~~~~ I > ~ I ! 2 W ":òt,fBas;;"'s7ïi2'MÕ"4732 ÑD ..... ..... ..... ..... ....¡ ..... ..... I- 5000 _.......................................................... .........=.....=.....=.....:=.....:=. .j.. fM26246MDs1Õ7iŸb - I I ! I i i:M1;"O§ MD :;i~~ iV() - i -------------------- - _. __ .__ - _. - - - - - - __ __ - ··b __ _ __, _ _ _ ~ ~)I~ ;n~&~ ~ ~ ~ ~ ~ ................................-.......... i -I - 6000 -.... I J______ i I I I .................................... ........¡....... ¡ I ¡:~:.;~;~ù.l~,~6;;~;() ~ ~ ~. .... ..... .... .... d ..¡ro~1';'r:'U"ru< 3'f,ICnv,7ZTVDi ¡(up c·-801';i·MÕ..~9;rTVëï , , ¡LCU: r::!j) 8 a17~1D SIô4::- TVO: ------ Drp 3.51100 7363 MD 5938 TVD 41.92' 287.31' 8Z ~31ë1epa-¡¡ure i ......1 .. ............................... ]'Up':::A ~13~D 0:e~IvD= : TMLV ~.... 10 MD ~E¡3';" n'D -' _. End Drp I Target ..... ...... "'/ 7989 MD 6472 TVD L= = 2000' 28777' 8Z _1' ~~ ~ .~'œ~~" _. _ \_ _ m/csgPt \ t> 8560 MD 7008 TVD . t).. 20 00' 287 77' 8Z 4446 departure ,'.- ··..1 ..... .... ._i -' .-.¡ .~-; 0 þ,... - 7000 - .....-... ....-----.... .......................................M.... ..... ........................ ................. I o I 1000 I 2000 I 3000 I 4000 Vertical Section Departure at 288.05 deg from (0.0, 0.0). (1 in = 1000 feet) I 1000 -1000 -------.-.- "Crv 1.751100 . 600 Me 600 TVD i 1.00' 320.00' az 1 N 1W ~ KOP Cry 11100 500 MD 500 ND 0.00' 320.00' az ON OE .~ o --·-0 I -1000 EAST »> ¡ , -2000 , ¡ , I -3000 «< WEST ! i I t -4000 I -5000 . 7-518" Csg PI TVD ~ 3027 MD 271~ az ¡ ~ 41.92" 287.31 HOld J i 361 N 971 W ~/rnlJth 2,D "> . '-+-7 L_~'oL;-?7°-- i ; i.~ End dry ~::~~~~.._·_-_·_..··t·_..··__·_...._-_·- 1000 230 ~ 552W ...--.....-....!.-.....--....-................- 2000 ~ -- True North Mag Dec ( E 25.734° 3000 1000 I Schlumberger o I .--+-------- ---------1 -1000 ---..... I I- ::> o en V V V 1000 _·--·--..·..-..·..-··--·...·-1-- ; I ! j I i I I I o -.........._........._......._.._......._~._...- j ! ¡ End Drp lTa'get i .! 7989 Me 6472 ND i ¡ 20.00" 287.77' az ! TO I Csg Pt . ¡ 1318 N 4042 W Drp 3.5I1Øo 8560 MD 7008 TVDiW' . 7363MD! 5938TVD 20.00' 287.77' az i... .. 41.92" ~7.31' az 1378 N 42Il W! 1222 N r36 W .; ¡ v ! I I ! ! -3000 I -4000 I j --., I -1000 I -2000 I , ¡ BP Exploration Alaska V-l13 (PS) Prudhoe Bay Unit - WOA V-Pad 1 in = 1000 ft 21-0ct-2002 Client: Well: Field: Structure: Scale: Date: PLAN VIEW ----··-····r---·------- i ! i I ! -5000 , ¡ 2000 _......-.--..--m.... ^ ^ ^ I I- 0:: o Z 3000 -.........................-......... O.......................:;.....i.....................................bP >:~~ ~ , v,';_~_ o1.h ) ) Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 3940 Arctic Blvd, Site 300 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Wednesday, October 23, 2002 Neil Magee BP Exploration Alaska Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Prudhoe Bay V-113 (P5) Nabors 9ES Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type CB_GYRO_SS MWD+IFR+MS Start Depth 28.50'md 1000.00'md End Depth 1000.00'md 10,799.65'md Close Approach Analysis results: ! Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillinç¡ Aids to be provided: A drilling map, with any offset wells on the plan view, and a traveling cylinder, will be provided. Checked by: Scott Delapp 10/23/02 ,) ) Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 8559.82 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/18/2002 Validated: No Planned From To Survey ft ft 28.50 1000.00 Planned: Plan #5 V1 1000.00 8559.82 Planned: Plan #5 V1 Version: 4 Toolcode Tool Name CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points 3027.41 2712.00 8559.82 7007.96 7.625 5.500 9.875 6.750 7-5/8" 5 1/2" Summary PB V Pad Plan V-03 (N-W) Plan V-03 V4 Plan: Pia 945.12 950.00 384.57 18.35 366.22 Pass: Major Risk PB V Pad Plan V-109 (S-E) Plan V-109 V1 Plan: PI 500.61 500.00 31.40 10.51 20.91 Pass: Major Risk PB V Pad V-100 V-100 V7 643.82 650.00 324.75 11.74 313.01 Pass: Major Risk PB V Pad V-101 V-101 V7 1882.48 1850.00 167.04 33.58 133.53 Pass: Major Risk PB V Pad V-102 V-102 V5 499.84 500.00 223.93 10.98 212.95 Pass: Major Risk PB V Pad V-103 (N-S) V-103 V6 349.47 350.00 335.27 7.25 328.02 Pass: Major Risk PB V Pad V-104 V-104 V13 1163.41 1150.00 170.50 20.85 149.70 Pass: Major Risk PB V Pad V-105 V-105 V13 1041.68 1050.00 249.48 18.58 230.91 Pass: Major Risk PB V Pad V-106 V-106 V10 549.60 550.00 311.54 9.94 301.60 Pass: Major Risk PB V Pad V-107 (N-J) V-107 V5 1147.38 1150.00 165.05 19.80 145.26 Pass: Major Risk PB V Pad V-108 V-108 V7 1235.73 1200.00 184.21 23.14 161.70 Pass: Major Risk PB V Pad V-201 V-201 V8 961.57 950.00 225.86 18.08 207.84 Pass: Major Risk Field: Prudhoe Bay Site: PB V Pad Well: Plan V-113 (S-C) Wellpath: Plan V-113 ____106 ~' ~. t. -, T........ 1:)................ (TfO+AZI) ¡.... ",,- I. cmn ...........'1_ +E/-W ft 281.81 318.20 -176.51 -172.89 ) Well: V-I08,Plan V-I13 (S-C) Based on: Planned Program Vertical Depth: 6390.00 ft below Mean Sea Level Local +N/-S: 1318.27 ft Local +E/-W: -4041.53 ft Longitude: 149°17'57.065W Northing ft 5971300.00 5971000.00 5971025.00 5971325.00 Easting ft 586680.00 586720.00 586225.00 586225.00 Polygon 1 2 3 4 Site: PB V Pad Drilling Target Conf.: 99% Description: Map Northing: 5971150.00 ft Map Easting : 586400.00 ft Latitude: 70° 19'51. 785N +N/-S ft 146.63 -153.86 -122.89 177.11 ) Target: V -113 Kup Tgt 1500 1500 14-00 1300 -------- 1200 1100 / / 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 ~ (Y) N 0 0- m I LD Ln ~ -3- -3- -3- -+ (î) (î) (Y) (î) (Y) 0 o ~ I I I I I I I I I ~ ~ ·p'~ ~ t-£T'IAJ.IDð.lõTiR 120D.4\Y$,.-,-__~· .. ...-:^-~ ~~.:.:.~~~·:::.:.::::·s:::::s::~ :\:}'/::' ~~.~.:.~>:~:::; =:\:;= :\~; :.:.:\ .. .~:j1~~ ::'....... 'UR' ...... ...... .....1 t~~,~t-rr {%::j¡~~~'::;~:;;:;;:::;;€J II· 20 ? ~ 2 b II· I: 0 ~ ~ 20 3 B ~ 5 I: 0 0 B ~ L. ~ ~ II· AMOUNT SEPT. 20, 2002 ****$100.00***** DATE 56-389 --¡:j'2 No. H 207126 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND. OHIO CONSOLIDATED COMMERCIAL ACCOUNT RE€E_ VED OCT J02002 Alaska on& Gas Goæ. CommissIon Anchora ~e H NET VENDOR DISCOUNT CHECK NO. H207126 DATE 9/20/02 V,\\3 GROSS ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7th AVE, STE 100 ANCHORAGE, AI< 99501 8 13·-· r;!]" 1'" IdU', ,If/I~J .,""1' oP'.'" I'fl, . . IIí f f ! ' ."f f./.. I " _. . .. .... lIU" tUtt): 'lUlU .","- uu. TOTAL ~ TO THE ORDER OF PAY BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. PERMIT TO DRILL FEE DESCRIPTION 9/20/02 INV# CK091602H INVOICE / CREDIT MEMO DATE H 207126 ') ) { TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME/.ð'4'. t/ -)/-..5 PTD# bo/ _ - ..2 / .h CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce 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. All dry ditch sample sets submitted to the 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. WELL PERMIT CHECKLIST COMPANY N)( WELL NAME./".&c. t/ - )! 3 PROGRAM: Exp _ Dev L Redrll _ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL ¡Ç LJóJ,3o INIT CLASS /)::,1/ /-ð.:/ GEOL AREA J-1'-J UNIT# //b""Ç';"'j ON/OFF SHORE....Q!J ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . f) N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \Y N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_». 'U( A- (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. N ~ LJ it . W' Q //0 ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N") '/. ~ 16. Surface casing protects all known USDWs. . . . . . . N k- 17. CMT vol adequate to circulate on conductor & surf csg. (j) R kd/(6~ 4JA!J'U (V'(..J'PÇ( 18. CMT vol adequate to tie-in long string to surf csg. . . . Y ~ 19. CMT will cover all known productive horizons. . . . . , ~- N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . - N "I { 'IE <; 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . _ N /'-f1Jl., PO v S 22. If a re-drill, has a 10-403 for abandonment been approved. . . ¥=-N-. ,..Jlft- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . Ii2 N 24. If diverter required, does it meet regulations. . . . . . . . . . ~ N 25, Drillin,g flU,id program schematic & equip list adequate. . . . . IN MW1/ MIJJ 10. ( P P Î 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 27. BOPE press rating appropriate; test to i./-OOO psig. N JIl.1 ç, f? 1.. 7 0 c¡ f S ¿' . A- / I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \J-IG ' Ii UJ 0 l.- 29. Work will occur without operation shutdown. . . . . . . . . . . .. N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y t!P , 31. Mechanical condition of wells within AOR verified. . . . . . . . ¥----N- Ail ~ cYJN ){ AJ.4. RESERVOIR ENGINEERING APPR DATE ,ttL /~z APPR DATE (Service Well Only) GEOLOGY APPR DATE ,(fc /d4~7 (Explorat6rY bnly) 32. 33. 34. 35. 36. Permit can be issued wlo hydrogen sulfide measures. . , . . Data presented on potential overpressure zones. . . . . . . . Seismic analysis of shallow gas zones. . . . . . . . . . . . . Seabed condition survey (if off-shore). . . . . .. ...... Contact namelphone for weekly progress reports. ...... GEOLOGY: RPg#. UIC ENGINEER PETROLEUM ENGINEERING: TEM JDH JBR Rev: 10/15/02 SFD_ / MJW WGA G:\geology\perm its\checklist.doc COMMISSIONER: COT I t/z-r 10 2- DTS JJ)ecrjò '( MLB II/%J /~¿. Comments" nstructions: