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Home My WebLink About192-147 ~-~ coVER t-IA~ Olq OK BE:FORE c:LOgi~X~IL~I-DOC PERMIT DATA .OGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 01/10/95 RUN DATE_RECVD 92-147 407 92-147 DWOP 92-147 SURVEY R COMP DATE:02/07/93 R 01/21/-02/07/93 R 8070-8909 MWD ANADRILL 03/31/93 03/31/93 03/31/93 Are dry ditch samples required? yes ~ And received? Was the well cored? yes (no) Analysis & description received? Are well tests required? yes ~n0~ Received? yes~no"~ Well is in compliance~~ Initial yes yes ~ STATE OF ALASKA '"' /'")., ALASK,-, OIL AND GAS CONSERVATION C WELL COMPLETION OR RECOMP LETION · ~.,~ 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEt, a3ED [] ABANDONED I'~ x SERVICE [] Plu~oed back for [edrill "' Y 2. Name of Operator 7. Permit Number BP Exploration 92-147 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20855-01 4. Location of well at surface 9. Unit or Lease Name 3670' NSL, 4695' WEL, SEC. 6, T11N, R13E i-L--OC-~'rl~)~-~~ Prudhoe Bay Unit ..... ~ ¥~IFIED 10. Well Number At Top Producing Interval M-leA (32-1-11-12) N/A ![,~rf~, 11. Field and Pool At Total Depth ~1 Prudhoe Bay Fieid/Prudhoe Bay Pool 2032' SNL, 2227' WEL, SEC. 1, T 11N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.16' J ADL 28260 12. Daie Spudded !13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1/26/93 2/3/93 2/7/93! N/Aeet MSL I .Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD'. 19. Directional Survey J20. Depth where SSSV set ~21. Thickness of Permafrost 9266' MD/8830' TVD 7704' MD/7378' TVD YES [~ NO []! N/Aeel MD ~ 1900' (Approx.) 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RE-COF~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8 72# L-80 Surface 2726' 17-1/2" 4140 cufl AS il 9-5/8 47# L-80 Surface 8228' 12-1/4" 1191 cufl Class "G" 7 29# 13CR80 7867' 9167' 8-1/2" 236 cufl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 'SIZE DEPTH SET (MD) PACKER SET (MD) Not perforated None None 26. ACID, FRACTURE, CEMENT SQUI=FTF. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7704'-7840' 56 cu ft Class "G"-squeezed to 400 psi 8887'-9156' 56 cu ft Class "G"-squeezed to 400 psi Top @ 9156' 449 cu ft Class "G"squeezed to 400 psi 7840'& 9156' Bridge plugS 27. PRODUCTION TEST D~,te First Production IMethod of Operation (Flowing, gas lift, etc.) " Not on production I N/A Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF !WATER-BBL CHOKESIZE ~GAS-OIL RATIO ri'EST PERIOD I Flow Tubing casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL 'GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~- /'"'"~ 30. GEOLOGIC MARKEI:~. N=iMATION TESTS NAME Include interval tested, pressure data, all lluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag River 9020' 8625' Top Sadlerochit 9165' 8746' ,! ECE V£D Alaska Uil & Ga~; Cor~s. (JornmissJo~ 31. LIST OF ATTACHMENTS 32. I hereby certify that lhe foregoing is true and correct to lhe best of my knowledge 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATION PAGE: 1 WELL: M-18A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/20/93 05:00 SPUD: 02/07/93 04:00 RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 01/21/93 (1) TD: 0 PB: 0 01/22/93 (2) TD: 0 PB: 8275 CIRC. BTMS. UP MW: 0.0 NaCl MOVE RIG TO M-18A, SPOT & SHIM RIG, R/U ON TREE TO CIRC WELL, ATTEMPT TO PULL BPV, ACTUATOR CLOSED ON TREE, PUMP OPEN, PULL BPV, CIRC WELL, TOOK 27 BBLS SEAWATER TO FILL HOLE, CIRC FREEZE PROTECTION, SET TWC, N/D TREE & ADAPTOR FLANGE, N/U BOPE, TEST BOPE, PULL TWC, M/U LNDG JT, PULL TBG FREE, PULL TBG HGR TO FLOOR, CBU RIH W/9-5/8" SECTION MILL MW: 0.0 WBM CBU UNTIL WELL STABLE, PULL 5-1/2" TBG, M/U BRIDGE PLUG, RIH, SET 8 8275', POH FOR SECTION MILL, RIH W/SECTION MILL 01/23/93 (3) TD: 0 PB: 8275 01/24/93 (4) TD: 0 PB: 8275 01/25/93 (5) TD: 0 PB: 8275 MILLING SECTION 9-5/8" CSG MW: 0.0 WBM RIH W/SECTION MILL, SLIP & CUT DRLG LINE, CIRC & CONDITION MILLING FLUID, RIG REPAIR, REPAIR FLUID END ON MUD PUMP, CIRC/COND MUD, RAISE VIS &YP FOR MILLING SECTION, LOCATE SECTION MILL @ 8067', MAKE CUT OUT IN 9-5/8" CSG, MILLING SECTION 9-5/8" CSG FROM 8067'-8100' MILLING CSG MW: 0.0 WBM MILL SECTION FROM 8098'-8101', CBU, JET FLOW LINE, ATTEMPT TO MAKE CONNECTION, BLADES WILL NOT CLOSE ON MILL, WORK MILL AGAINST STUMP 8 8067' ATTEMPTING TO CLOSE BLADES, L/D 15' DP, MAKE CONNECTION, MILL CSG F/8101'-8117', PUMP HI-LO VIS SWEEP, CBU TO CLEAN OPEN HOLE SECTION, ATTEMPT TO TRIP-BLADES WILL NOT CLOSE ON MILL, WORK MILL AGAINST STUMP 88067', WORK PIPE, MILL ON CSG ATTEMPTING TO WEAR OUT BLADES, PUMP HI-LO VIS SWEEP,MILLING CSG ATTEMPTING TO CLOSE BLADES 8 8160' INSTALL NEW PACKOFF & SPOOL MW: 0.0 WBM FLOW LINE PLUGGED, C/O, MILL SECTION CSG ATTEMPTING TO CLOSE BLADES, SLOWED PUMP RATE TO 35 SPM, PULL UP INTO CSG 8 8067', PUMP HI-LO VIS SWEEP TO CLEAN HOLE, POH W/SECTION MILL, L/D SAME, RIH OPEN ENDED MULE SHOE ON 5" DP, TAG STUMP 8 8162', WASH DOWN F/8162' TO 8217', BATCH MIX CMT, PUMP 31 BBLS CMT,ATTEMPT TO SQUEEZE, RAMS & HYDRIL WILL NOT HOLD PRESSURE, POH W/MULE SHOE CLEAN OUT STACK-METAL SHAVINGS, N/D BOPE & TBG SPOOL, INSTALL NEW PACKOFF & TBG SPOOL, TEST TO 3500 PSI :~tiask~ Oil & Gas Coils. A~chorage WELL : M-i~A OPERATION: RIG : DOYON 16 PAGE: 2 01/26/93 (6) TD: 8130' ( 0) 01/27/93 (7) TD: 8236' ( 106) 01/28/93 (8) TD: 8755' ( 519) KICKOFF WELL WITH DYNADRILL MW: 9.9 VIS: 57 N/U BOPE. TEST BOPE. SET WEAR RING. RIH TO DRILLPIPE. RIH BREAK CIRC EVERY 1000' TO CLEAR DRILLPIPE. RIH TO 7855'. DRILL FIRM CMT FROM 7855' TO 8072'. OREIENT & KICKOFF WELL WITH STEERABLE DRILLING ASSEMBY @ 8190'. DRILLING NEW HOLE OUT OF SECTION @ 2300 HRS ON 1/25/93. DRILLING MW: 9.8 VIS: 53 KICKED OFF CMT PLUG, SLID 8115'-8228'. PULL UP INTO 9-5/8" CSG, REPAIR BEARINGS ON DYNAMATIC, REPLACE CRACKED BRAKE BAND, CUT/SLIP DRLG LINE, RIH TO 8228', SLIDE F/8228'-8236' DRILLING MW: 9.8 VIS: 49 DRILLED & SURVEYED F/8239'-8875' HOLE IN GOOD SHAPE , 01/29/93 ( 9) TD: 8974' ( 219) 01/30/93 (10) TD: 9121'( 147) 01/31/93 (11) TD: 9170' ( 49) 02/01/93 (12) TD: 9214' ( 44) RIH W/PACKED BHA MW: 9.8 VIS: 57 DRILLED 8755'-8820', CBU, ST TO CSG, NO DRAG, REAMED LAST 30' TO BTM, 20' OF FILL, DRLD TO 8974', PUMPED HI VIS SWEEP, NO INCREASE IN RECOVERY, DROPPED SINGLE SHOT, SLUG PIPE, POH, L/D MOTOR & MWD, P/U PACKED BHA & NEW BIT, CUT/SLIP DRLG LINE, RIH, BREAK CIRC @ 8067' DRILLING MW: 9.9 VIS: 61 PULL 11 STDS INTO CSG, CIRC ONE DP VOL, RIH, TAG TIGHT HOLE @ 8822'. HOLE PACKING OFF, REAMED 8622'-8974', HARD SHALE PIECES @ SURF. DRLD 8974'-9060', BEGAN LOOSING MUD @ 60 BBLS/HR, CIRC @ 30 SPM WORK PIPE, DRLD REMAINING SAG RIVER F/9060'-9080', CIRC & SPOT 70BBL LCM PILL ACROSS SAG RIVER, POH TO CSG, RIH, DRLD 9080'-9090', CIRC SLOWLY WHILE LCM PILL RETURNING TO SURF, DRLD 9090'-9121' REAMING TO BOTTOM MW: 9.7 VIS: 44 DRLD 9121'-9163', NO MUD LOSSES, LOST RTNS @ 9163', MIX & PUMP 70 BBL CSG PILL, LOST 394 BBLS MUD, POH 14 STDS TO CSG, OBSERVE WELL 2 HRS, NO LOSSES, RIH TO 9029', REAM TO 9168', HARD FILL @ 9168', BROKE THRY & IMMEDIATELY LOST FULL RTNS, POH TO SHOE, WELL STABLE, SPOT PILL, RIH TO 9100', CUT MUD WT TO 9.7PPG, WASH 9100'-9163', HARD FILL @ 9158', DRLD 9163'-9170', LOST 450 BBLS MUD WHILE REAMING, SHUT DOWN WHEN PIT LEVEL REACHED 100 BBLS, POH TO CSG, SHIP MUD TO RIG, FILL PITS & STORAGE TANK, MIXED PILL, REAMNED TO BTM, TAGGED HARD FILL @ 9150', LOOSING 1-1/2 BPM RIH W/7"LINER MW: 9.5 VIS: 43 DRLD 9170'-9214', INITIALLY LOOSINGI-1/4 BPM, WITH RATE INCREASING TO 2-1/2BPM, SPOT PILL ON BTM, POH TO 9-5/8" SHOE TO REFILL MUD PITS, CONTINUED TO LOOSE MUD @ 2BPM IN CSG, REFILL PITS, RIH TO 9200', POH TO SHOE, POH, L/D BHA, CLEAR FLOOR, R/U TORQUE TURN, P/U 7" LINER A~chorage WELL : M-I~A OPERATION: RIG : DOYON 16 PAGE: 3 02/02/93 (13) TD: 9214' ( 0) 02/03/93 (14) TD: 9266' ( 52) 02/04/93 (15) TD: 9266' ( 0) 02/05/93 (16) TD: 9266' ( 0) 02/06/93 (17) TD: 9266' ( 0) 02/07/93 (18) TD: 9266' ( 0) PU 6" BHA MW: 9.5 VIS: 0 P/U 7" CR LINER & HGR, FILL LINER, RIH, PUMP 200 SX "G" CMT, REVS OUT SEAWATER, NO CMT OR SPACER, POH, L/D DP, INSTALL VBR'S IN TOP RAM. TEST BOP, P/U 6" BHA & 45 JTS 3-1/2" DP. EFC IS RAISED DUE TO EXTRA RIG DAYS INCREMENTAL MUD COSTS & LOST CIRCULATION PROBLEMS. POH MW: 8.6 VIS: 39 RIH PICKING UP 3-1/2" DRILL PIPE FROM PIPE SHED, RIH TAG LINER TOP @ 7860', RIH W/5" DRILLPIPE, TAG LANDING COLLAR @ 9120'. WASH & REAM FROM 9167' TO 9214'. DRILL 6" OPEN HOLE FROM 9214' TO 9266'. PUMP CMT PLUG MW: 8.6 VIS: 40 POH, BRK OFF BIT, STAND BACK BHA, M/U 7" CMT RETAINER, RIH, SET @ 9156', STAB INTO RETAINER, EST CIRC, PUMP 40 BBLS CMT, HESITATION SQUEEZE TO 500 PSI, CIRC & CON MUD FOR DRLG, STING INTO RET. WOULD NOT HOLD 200 PSI, R/U CMTRS, PUMP 40 BBLS CMY, DISP. SURE FILL THIXOTROPIC CMT W/RIG PUMP USING DRILL MUD RIH W/6" BIT MW: 8.6 VIS: 40 SQZ CMT BELOW 7" RETAINER W/600 PSI, PULL OUT OF RETAINER, CBU, NO CMT TO SURFACE, WOC & CIRC, STING INTO RETAINER, ATTEMPT TO TEST CMT SQZ W/200 PSI, WILL NOT HOLD PRESSURE, FLUID PUMPING AWAY @ 1.5 BPM, CIRC, R/U CMTRS TO P & A WELL, BATCH MIX CMT, PUMP 5 BBLS H20, PUMP 10 BBLS CMT, POH, L/D DRLG ASSMB. M/U 6" BIT RIH TO TAG CMT PLUG WOW MW: 8.6 VIS: 0 RIH W/6"BIT @ 8700', CIRC & WOC, POLISH OFF CMT PLUG F/8863'-8887', PRESSURE TEST CMT PLUG W/1500 PSI, CBU, POH, SLOW DUE TO HIGH WINDS & BLOWING SNOW ZERO VISIBILITY, WAITING ON WEATHER RELEASE RIG @ 04:00 2/7 MW: 8.6 VIS: 0 RIH W/9-5/8" BRIDGE PLUG, SET @ 7840', CMT W/10 BBLS CMT, EST CMT TOP @ 7704', DISPLACE WELL W/136 BBLS DIESEL, POH, L/D DP, PULL WEAR RING, TOP OFF WELL W/DIESEL, M/U TBG HGR & LAND IN WELLHEAD, N/U TREE, FILL TREE W/DIESEL, PUMP OUT CELLAR & PITS, SECURE WELLHEAD, RELEASE RIG 02/07/93 04:00 SIGNATURE: (drilling'superintendent) DATE: MIC OFILMEI ; / / ***~******* SURV:Y PROGRAM COW'ANY PRUDHOE BAY DR!LLIN~ WELL NAME M-!SA LOCATION 1 F'itl WOA LOCATION 2 PRL~HOE BA¥~ AE MA~i.~ric DECLI~4TiO~ DATE: 26-JAN-~ W~L NUM£~ 0 ~=.. HE,'-"f: L~:ATION: LA.,,.,v-o) DEP(E/-W) 0~00 AZI~]TH FROM E~TARY TABLE TO TARGD IS 252,52 TIE iN POiNT(TiP) MB~]~P DEPTH TRUE VERT DEPTH INCLI~TIC~:~ AZIM{FrH LATITLE~E(N/-S) DEPARTURE(E/-W) 8070,00 7745.00 ~I~ -!969.00 MEASUF~D INTERVAL VERTICAL DEPTH DEPTH ,~ Tt ft 6070.00 0,0 ~=~S ~n 8509,37 31,~ 8i7~,1~ 7ARGE? STAT!P4 AZIMUTH LATITUDE ~C~t~ INCLN~ N/-S ft d~ de9 ft I9~,9L 3.i7 273.2~ -369.00 2n4~.15~ ~ 15,22 267,28 -~:.,,~'~, 37 2057,56 17.94 267.01 -~, ~ ~367.27 i9,38 265,~5 -3~.94 ~077.81 20.49 266.10 _~o ~ DEPARTL~:E DtSPLACEMENi at E/-W ft ft ~""" ~' 20C3,2~ -2023,23 ~'~' -zwl,20 ~74.16 -205~,!7 AZIHUTH deg 259,39 259,71 ~O 77 259,83 T C ~/ lOOft 0,00 3.61 4.31 4.92 8726.5~, ~ ~ ~1.~ 8374.3i =~,~ 22,59 262,43 -371.97 2124,10 24,9~ 261.4i -375,52 2i37,A? 26,26 ~:~ ~'~ -377 ~I~1 :' ~ (~,' ~A~ A~ -379.78 2179.80 ~ ~^ o~ ,~ -383.49 -2083,78 2116.72 £59,88 -2!06.i~ 2!41 ~ -2135,13 2167,$2 259,?2 -2164.57 2198.27 259.95 4,17 4.25 2.90 86!8,06 30,6 8849.12 31,1 8879,~ 890~,75 30.1 PROJ£C~D SL$:L~Y 8974.00 64.S 8454,8? 2194.58 30,04 262,89 -385,28 6481,65 ~10,07 30,90 263,05 -~.7,20 8507.63 2225,83 32.37 ~i~ ~l _~.: ~ 8532,89 2242.02 33.56 261.36 -391,73 -2i':15,13 2229.02 260.00 -2210,~? 2245,01 -2~7.~0 226I.[~' 260.02 2277,i3 33~60 zoo-"",40 -37,05 ~'-2262.34 2296.92 2,:',0,05 3°83 2,79 5,31 4,02 1. Type of Request: ' STATE OF ALASKA ~ - AI_~,.,KA OIL AND GAS CONSERVATION COMMISL,...,~I -' /,~'~ .. APPLICATION FOR SUNDRY APPROVALSo Abandon )~ ~l-~t uspend Operation Shutdown xx Re-enter suspended well__ Alter casin~ ' Repair well __ Plugging Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance Perforate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration Development xx Exploratory 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1611'SNL, 195'EWL, SEC. 6, T11N, R13E At top of productive interval N/A At effective depth N/A At total depth 2032' SNL, 2227' WEL, SEC. 1, T11N, R12E M-18A (32-1-11-12) 9. Permit number 92-14 7 10. APl number 50- 029-20855-01 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9266 feet 8787 feet 8887 feet 8537 feet Casing Length Size Structural Conductor 110' 20" Surface 2699' 13-3/8" Intermediate Production 8913' 9-5/8" Liner 1300' 7" Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented 8 cu yds 4140 cu ft 1321 cuft 200 sx Class "G" Measured depth True vertical depth 137' 137' 8228' 7867'-9167' 7487'-7695' feet 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 2/5/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed,~'~ ~ Title Driling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- E.O~ Original S~gned By Approved by order of the Commission fh~id W- Johr~ston Form 10-403 Rev 06/15/88 ..... (~0mmissioner Date SUBMIT IN TRIPLICATE M-18A OPERATIONAL SHUTDOWN WELL SUMMARY The following operations summarize the operational shutdown of well M-18A. The listed well operations are in compliance to MMS- regulations as set forth in 20 ACC 25.072. Comments: Prior to the operational shutdown in well M-18A 80 bbls of cement had been displaced below an EZSV positioned at 9156' md. Open hole below the 7" 29# 13Cr80 shoe at 9167 is 8-1/2" to 9214' md and 6" from 9214' md to 9266' md. 1. RIH w/drill pipe, locate into EZSV @ 9156' md, spot 10 bbls of class "G" neat cement on top of EZSV. Estimate cement top at 8887' md. 2. Pressure test and weight test cement plug. Notify AOGCC representative for witnessing of cement plug tests. 3. Displace well to 8.6 filtered seawater. POOH and L/D drill pipe. 4. P/U 9-5/8" 47# bridge plug, RIH and position bridge plug +/- 25' above 7" tieback extension located at 7867' md. Spot 10 bbls of class "G" neat cement on top of 9-S/8" bridge plug. Verify plug hardness with 10,000#. 5. Displace top 600' of well to diesel to freeze protect. Freeze protect 13-3/8" x 9-S/8" annulus. 6. ND BOPE, NU dryhole tree. 7. Release rig. The M-18 wellbore has future utility in that an alternate target is being evaluated for a future sidetrack. Ail neccessary permitting will be forthcoming once the well planning phase is complete. M-18&CMT.XLS State: Well: Field: State Permit PRLIDI-IOE BAY 92.14,7 Work Sheet: Date: ,44. ,4,/~e~ Ceftin/l,"ol~e C.8/c~Yation,~. 12/21/92 Casing T.~e Casing Size Casing Length Hole Diameter Cement- Sacks Cement- Yield Cement- Eubic R Cement- Cubic it Cement-Sacks Cement- Yield Cement- Cubic ft Cement- Cubic ft Cement- Sacks Cement- Yield -Inches - Feet -Inches 111 111 111 112 112 112 112 113 113 Cement- Cubic ft 113 Cement- Cubic It 113 Cement- Cubic ft / Vd Cement - Fill Factor Conducto~ 0.000 O. OOO 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DiV/O! Surface 0.000 0.0OD 0.000 0.000 0.000 0.00O 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/O! Liner 7.000 1,792.000 8.50O 350.000 1.180 413.000 413.000 0.000 0.000 0.000 0.000 413.000 1.817 CaCmg Type Casing Size Ca~'mg Depth Hole Diameter Cement- Sacks Cemer, t - Yield Cement- Cubic Cement- Cubic it Cement-Sacks Cement- Yield Cement- Cubic ft Cement- Cubic ft Cement-Sacks Cement- Yield Cement- Cubic It Cement- Cubic ft Cement- Cubic It /Vol Cement-intefYal Irt Top o~ Cement- Feet -Inches - Feet -Inches 111 Itl 112 112 112 ~I2 113 113 ~I3 Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 11DIV/O! I~DIV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! ~DIV/OI P~oduction 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O( I~DIV/O! Messured [-~ep'th Printed 12/21/92 M-18~,CSG.XLS State: Alaska Borough: Well: M-18A Field: Prudhoe Bay St. Perm ~ 92-147 Date 12/21/92 Engr: M. Minder Casing Interval Interval Size Bottom Descriptionescriptionescription Tension Top Length 1A 7 9191 7590 1792 2A 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 26 13CR-80 FOX 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 619 7B 8B 9B 1 OB Mud Hydrolytic Wieght Gradient ppg psi/ft 9.7 0.504 0.0 0.000 · 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 Maximum Minimum Pressure Cataloged psi 2821 0 0 0 0 0 0 0 0 0 Yield BDF 7240 2.6 0 #DIViO! 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIVI0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DNIO! 1C 2C 3C 4C 5C 6C 7C 8C 9C Tension Strength K/Lbs 46.592 0 0 0 0 0 0 0 0 K/Lbs TDF 604 12L 96 0 #DIVIO! 0 #DNIO! 0 #DIVI0! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 4636 0 0 0 0 0 0 0 0 Resist. CDF 5410 1.167 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIVKI! 0 #DIV/O.I 0 #DIV/O! 0 #DIV/O! Paoe 1 WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7,542 December 31, 1992 Bill Kirton Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P. O. Box 1966112 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-18A BP Exploration (Alaska), Inc. Permit No. 92-147 Sur. Loc. 1611'SNL, 195'EWL, Sec. 6, TllN, R13E, UM Btmnhole Loc. 2180'SNL, 2459'WEL, Sec. 1, TllN, R12E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~hnsto~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work 'Drill [] RedrillElllb. Type of well. Exploratory[] Stratigraphic Test[] Development Oil[] Re-Entry [] DeepenDI service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration RKB = 55.16'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28260 ¢. Location of well at surf-ace ~ 7. Unit or property Name 11 Type Bond(... 20 ,~c 25.0~5) 1611'$NL, 195'EWL, SEC. 6, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2101' SNL, 2207' WEL, SEC. 1, T11N, R12E M-18A (32-1-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 2180' SNL, 2459' TEL, SEC. 1, T11N, R12E 1/21/93 $200,000.00 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 28277-2180'feet No close proximity feet 2560 9707' MD/9191' TV~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2}) Kickoff depth ~oTofeet Maximum hole an~lle 3~.7 o Maximum surface 3330psig At total depth (TVD) 8800'/4390pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD . (include stage data) 8-1/2" 7" 26t/ 13CR/ NSCC/ i792' 7915' 7590' 9707' 9191' 350 sx Class "G" L-80 Fox ~,LI V i19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summaryDEC1 81992 Total depth: measured 9555feet Plugs (measured) Alaska 0ii & Gas Cons. C0mm. iss|, true vertical BKB 9229 feet Anch0rag~ Effective depth: measured 9360feet Junk (measured) fill@ 9360'(1/91) true vertical BKB 9034 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 30" 8 cu yds ' 137' 137' S u rface 2699' 13-3/8" 4140 cu ft 2726' 2636' Intermediate 8913' 9-5/8" 1321 cu fi 8940' 8614' Production Liner 1115' 7" 292 cu ft 8440'-9555' 8114'-9229' Perforation depth' measured 9077'-9126' Squeezed: 9126'-9183', 9194'-9214', 12112'-12182' true vertical subsea 8696'-8745' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby ~,rti!y~!_h. at/the foregoing is true and correct to the best of my knowledge Si(:jned/~//~ Title Drilling Engineer Supervisor ~'~/,/~/? ~- Date Commission Use Only Permit Number IAPI number IApproval date _ See cover letter ~,2_,-/,'~x7 150-C:>2...'~--2.0 ~'~5'-c~/ I ,/,,,~-_~//---~.__f_or other requirements Conditions of approval SampleS required ~l Ye~No Mud log required ~,Yes ~ No'~ Hydrogen sulfide measures [] Yes i~ No Directiona.~,l survey required [] Yes [] No Required working pressure for BOPE 1-'] 2M; r-13M; ]~i~M; 1-110M; [-]15M' Other: Original Sioned By by order of Approved by David W. Johnston Commissioner' zne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicat OBJECTIVE: The major goal of this sidetrack is to replace M18 with a well that accelerates oil production and reduces inefficient water production. This will not access additional reserves, therefore the sidetrack will be expensed. M18 currently produces 7000 bwpd and 700 bopd. The high water production is due to a propped fracture which extends into the base of Zone 4. The sidetracked is expected to have an initial rate of 3000 bopd at 0% watercut. CURRENT STATUS: Well M18 was drilled in 1982 as a Sohio tract well and was not unitized until 16th March 1988. Initial perforations were added on 27th April 1988 and resulted in an initial flow rate of 9800 bopd with 0% watercut. The gross fluid rate stabilized at approximately 4500 bpd with a 15% watercut. On 18th November 1988 a bullhead mud acid treatment stimulation was performed. This resulted in a short term gain in gross fluid rate ( 5500 bpd) and a watercut of 25%. Over the next 2 years no significant well work was performed. By October 1990 the gross fluid rate had declined to 3600 bpd at a watercut of 52%. A full suite production Icg run in February 1990 indicates a small channel below the bottom perforations and high water production from the bottom 75 feet of perforations. A coil tubing unit (CTU) cement squeeze was performed in November 1990. The objective was to shut off the water production and reperforate the top 50 feet of Zone 4 in preparation for a fracture treatment.. After reperforation the well returned to production at a gross fluid rate of 2000 bpd at a 19% watercut. The well was fractured on 15th November 1990.and was the first fracture treatment performed on M-Pad. The design assumed vertical containment of the fracture above a small shale at 9126' md. The post fracture flow rate was approximately 9500 bpd at a 55% watercut. The watercut was very similar to the pre-squeeze watercut, which indicates that the fracture treatment stimulated all of Zone 4. A flowmeter survey performed in March 1991 indicates that the squeeze perforations are holding and that the fracture extends down to the base of Zone 4. In March 1992 M18 was shut in due to high water production and fluid production constraints at GC-2. The well returned to production in August 1992 at a watercut of 90%. This well will continue to be shut in periodically whenever GC-2 is subject to total fluid production constraints. The well is currently believed to be producing 8000 bfpd at a 91% watercut. PERMITTING: The attached sundry notice covers the plugback of the original well and the drilling permit covers the proposed drilling program. R E DEC 1 ~ 199~ ~!l~ .~ ~as Cons. M18-A AFE SUMMARY PROCEDURE 1 1 3. 4. 5. 6. 6a. 7. 1 gl 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 8300' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU BOP's. Test BOP's to 5000 psi. Pull two-way check valve. Pull and lay down ~-1/2" tubing. RIH w/9-5/{~" bridge plug and set at 8275' MD. Spot an 18 ppg pill on bottom. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 806~' MD. RIH with open-ended DP. Mix and pump 1§0 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. Replace intermediate packoff if necessary. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" packed hole assembly to total depth of 9707' MD / 9191' TVD or 150' MD below the OOW¢ at-9011'$$ TVD. RU wireline and lOg with the DLL/GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 26# 13CR FOX x 7" 26# L-80 NSC(3 standard liner assembly to TD with liner top packer/hanger and tie-back extension w/+/- 150' lap. Crossover from 13CR to L-80 at 8035'MD. Cement liner with 350sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RIH with 5-1/2" 17# NS(3C L-80 xo to 4-1/2" 12.6# NSCT L-80 completion string w/7" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at 8015' MD based on 100' below 7"liner tie-back extension. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 6" 5M CIW tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. RU wireline and perforate. M18-A PRELIMINARY WELL PLAN WELL: M18-A SIDETRACK PBU APl No.: 50-029-20855-00 (on the original M18 well) LOCATION: Surface: 1611' FNL, 195' FWL, Sec. 6, T11N, R13E Target: 2101' FNL, 2207' FEL, Sec. 1, T11N, R12E @ 8740' ssTVD BHL: 2180' FNL, 2549' FEL, Sec. 1, T11 N, R12E @ 9136' ssTVD ESTIMATED START: 21 January, 1993 OPR. DAYS TO COMPLETE: 16 CONTRACTOR: Doyon Rig #16 DIRECTIONAL: Kickoff at 8070' MD. (30.53 degree angle drop and 40.76 degree west turn.) WELLBORE: Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR 110' 110' N/A 13-3/8" SHOE 2634' 2724' N/A KOP 7745' 8070' 9.7 TOP SAG RIVER 8640' 9045' 9.7 TOP SHUBLIK 8679' 9092' 9.7 TOP SADLEROCHIT 8744' 9170' 9.7 TOTAL DEPTH 9191' 9707' 9.7 LOGGING PROGRAM: 8-1/2" Hole: DLL / GR / BHCS / SP NOTE: Open hole CNL sonde will not be picked up. MUD PROGRAM: The milling/drilling fluid program will consist of a 9.3 - 9.8 ppg XCD polymer / KCI water based mud. DEPTH DENSITY PV YP INT 10 MIN FL (TVDI (PPG1 (CP) (#/FT)GEL GEL cc/30min 7745' 9.7 10 10 5 7 8 to to to to to to to 9191' 9.8 16 18 10 15 5 OIL SOLIDS MUD (%) (%) TYPE 0 5 Water to to Base 0 7 Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.7 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 3550 psi/8600' ss TVD. 3600 psi/8800' ss TVD. Overbalance Sag River: 700 psi. Overbalance Top Sadlerochit: 860 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING 7" 26# 13CR-80 FOX DEPTH BUR~T COLLAPSE TENSILE 7915' - 9707' MD 7240 psi 5410 psi 604 klbs CEMENT 7" LINER: CALCULATIONS: Measured Depth: Basis: 7915'MD (Hanger)- 9707'MD (Shoe) 40% open hole excess, 40' shoe joints, 150' liner lap and 200' excess above liner with DP. Total Cement Vol: 415 cu ft or 350 sxs of Class G blend @ 1.18 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 NSCT (0'- 7955' MD) MUD & DOYON RIG #16 SOLIDS CONTROL EQUIPMENT i m m m _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console DEC 1 t~ !99~ Alaska Ull & Gas Guns. Anchorage G~AT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Pax 349-2487 DIRECTION~L WELL PLAN for PRUDHOE BAY DRILLING Well ......... : M-ISA (P3) Field ........ : PRUDHOE BAY M-p;tD Computation..: MINIMUM CURVATURE Prepared ..... : 12/09/92 Section at...: 252.82 KB elevation.= 55.10 LEGAL DESCRIPTION Surface ...... : 1611 FNL 195 FWL S06 TllN R13E UM Tie-in ....... : 1979 FNL 1774 FEL S01 TllN R12E UM Target ....... : 2101 FNL 2207 FEL S01 TllN R12E UM BHL .... ...... : 2180 FNL 2459 FEL S01 TllN R12E UM X ASP ZONE 4 Y 629005.59 5974759.72 627043.00 5974357.43 626612.19 5974229.00 626361.84 5974145.47 PROPOSED WELL PROFILE ~mmmmmmm~ .... STATION IDENTIFICATION TIE-IN TJE MEAS INCLN DEPTH ANGLE --- 8070 3.17 8100 4.12 8157 6.23 8200 7.80 8300 11.69 V~RT-D~PTHS SECT BKB SUB-S DIST 7745 7690 1989 7775 7720 1991 7832 7777 7875 7819 2000 7973 7918 2017 DIRECTION REL-COORDINATES DL/ AZIMUTH 2g~.28 281.57 272.41 265.56 259.95 FROM-WELLHEAD 100 369 S 1969 W <TIE 368 S 1971 W 4.0 268 $ 1976 W 3.9 ~6~ S 1981 W 4.0 370 S 1998 W 4.0 TJD 8347 13.55 8400 15.63 8500 19.60 8600 23.58 8700 27.56 8019 7964 2027 8070 8015 2041 8166 8110 2071 8259 8203 2108 8349 8294 2151 258.62 257.12 255.42 254.27 2~3.44 372 S 2008 W 4.0 375 $ 2021 W 4.0 382 S 2051 W 4.0 392 S 20R6 W 4.0 404 $ 2128 W .4.0 TJC TJB ~ND OF CURVE SAG RIVER 8702 27.62 8800 31.55 8848 33.46 8854 33.70 9045 33.70 8350 8295 2i51 8436 8381 2200 8476 8421 2226 8481 8426 2229 8640 8585 2335 253.43 2~2.80 252.$5 252.52 252.52 404 S 2128 W 4.0 418 $ 2175 W 4.0 426 S 2199 W 4.0 427 S 2203 W 4.0 459 $ 2304 W 0.0 SHUBLIK GOO TSAD ~.4 TARGET OWe 9092 33.70 8679 8624 2361 9170 33.70 8744 8689 2404 9170 33.70 8744 8689 2404 9231 33.70 8795 8740 2439 9291 33.70 8845 8790 2472 252.52 252.52 252.52 252.52 252.52 467 S 2329 W 0.0 480 S 2370 W 0.0 480 $ 2370 W 0.0 490 S 2402 W 0.0 500 S 2434 W 0.0 TSAD 13 TSAD Z2 HOT OOWC TD 9360 33.70 9416 33.70 9501 33.70 9557 33.70 9707 33.70 8902 8847 2510 8949 8894 2541 9019 8964 2588 9066 9011 2619 9191 9136 2702 252.52 252.52 252.$2 252.52 252.52 511 S 2470 W 0.0 521 S 2500 W 0.0 535 $ 2545 W 0.0 544 S 2575 W 0.0 569 $ 2654 W 0.0 TOTAL P. 02 PRUi~HOE i iLii ~ III ,,1 BAY_DRILLING M-i 8A (P3) VERTICAL SECTION VIEW Section at: 252.52 TVD Scale.' J inch = 300 feet Dep Scale.' J inch = :300 feet Drawn · !1/26/92 Great Lan¢ OJpectYonaY £rY]Ylng Marker Identification MD BKB SECTN INCLN A) TIE-IN 8070 7745 lgBg 3.i7 B) ENO OF CURVE 8854 848! ~229 33.70 C) TARGET g23J 8795 243q 33,70 D) TD 9707 9193 2702 33,70 J 800 J 950 2 ! O0 2250 2400 Section Oepantune [61.J~ (c) ~2 NJOA BI.~ 4:~6 PM ~ 2550 8700 2B50 RECE Iv LD OEO 1 8 199t A)aska Oil & Gas Cons. comll~lSSl~.~ Anchorage ~O'd qW±O± Id1 I I IlL i i i. i _ iiii i iiiii ii i ' · <- 1~¥3 ' iS3~ -> Og~ 0 OG~ 009 OGL O00T 09~; OOgI 09~[ 0002 Oc~ 0092 i, i . m I Ill 06P ~ $g6I $ 6BE 0108 SIN le imm i i 30HOnWd Ol lO 139B¥1 13 3Al:tn3 :lO 01,13 (Gl NI-3II (V uo!1~3~ ~lluapl aa4ueN i i im '~i DOYON 16 13 5/8" 5,000 psi Stack 10.15 4.5 5.02 RKB HYDRIL I I i fLO 12.40 Variable 3.5"x 6" Pipe Ram R 15.40 17.60 1.02 1.80 GROUND LEVEL 2.35 0.25 Variable 4.5"x 7L" Pipe Ram MUD CROSS 20.70 Blind Ram TBG SPOOL SPOOL ~ BASE ~ FLG 24.85 25.10 ,~..~S~ OIL ,~ID ~S C, ONSERVATION COMMISSION FOR SUNDRY APPROVALS OperalJon Shutdown _ Re-enter suspended well Plugging x 'Time extension . Stimulate .. '" Pull tubing ." Variance~ Perforate ~ Oth~; x Plug back for redrill 2. Name of Operator BP Exploration, Alaska 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1609' SNL, 196' EWL, Sec. 06, T11N, R13E At top of productive interval 1955'SNL, 1801' WEL, Sec. 01, T11N, R12E At effective depth 1942'SNL, 1808' WEL, Sec. 01, T11N, R12E At total depth 1941'SNL, 1809' WEL, Sec. 01, T11N, R12E 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (s Packers 5. Type of Well: Development x Exploratory StralJgraphic __ Service 13. Attachments 9555 feet BKB 9229 feet 14. Estimated date December22, 1992 Plugs (measured) -- ~ Junk (meas~red) 6. Datum elevation (DF or KB) KB =, 55.16 feet 7. Unit or Property name Prudhoe Bay Unit , 8. Well number M-18 (32-01-11-12) 9. Permit number 82-181 10. APl number 50- 029-2O855 i 1. Field/Pool Prudhoe Oil Pool measured 9512 feet true vertical BKB 9186 feet _,--,-, 't R '~- L Length Size Cemen~ Measured de~3th. "aS Cu0t~'~'~cai(J~tepth 272~ f37 '~913 n :,o ~-~,o { ~ ./~ 132~ ~ 8940 measured ~-91~6' ( ~d: 91~6~91~t 919419214'~ ~ / and moasuro~doPth) ~-~/~ ~7~ L-80 ~B Mod B~r, ss 'w~ 4-~/~ t~ip~ to (,~an~m~~epth" ' ' / ) ; ~ '; VN a t1920 ' Description program __ ~P sketch __ / of well classification as: Oil x Gas Suspended __ 16. if proposal was verball' Name of approver :e approved Service 17. ! hereby certify that the foregoing is true and correct to of my knowledge. S i~ned ~_,~~ ~/_~ .... Title PBU Drilling Engineering7 Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test__ Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the CommissiOn Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ITEM (1) Fee (2) Loc ...... ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE ..... '[2 tl~ru Company /~ (3) Admin/~ ' ~ [9 thru [10 & 13] (5) BOPE 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed ..................... · .............. Is lease ngrnber appropriate .......................................... ~ Does well have a unique name & ng~nber ................................ '~ I s conductor st r ing provided ......................................... ~ Lease & Well YES NO ! ! [14 thru 22] Wi l to 16. Is 17. Wi 1 18. Wil 19. Wi 1 20. Is 21. Is /~-~Z-e~-~ 23. Is [23 thru 28] 24. 25. 26 27. 28. 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. enough cement used to circulate on conductor & surface ............ 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. a diverter System required ........................................ RE.HARKS Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of.~.~~ BOPE attached Does BOPE have sufficient pressure rating -- test to ,5'~:~oO psig. Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other .,/-~. L t~ [29 thru 31] (7) Contact .[32] (8) Addl ,~..~.~ 9eo 1 ogy' DWJ ~ , rev 12/92 ena i ne'--r i n ' ~. ~ BEW JDH LG~L~ 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Add i t i ona l requ i rements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Add i t i onal remarks' UM MERIDIA~J' SM TYPE' Exp/Dev Redr i 1 1 Inj Rev 0 -rZ -~0 u~-~