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199-130
COSSEaVAT ON TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 2000 Paul Mazzolini Exploration Drilling Team Leader Phillips Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Location Clearance, Some NPRA Wells Dear Mr. Mazzolini: On August 2, 2000 our inspector Lou Grimaldi accompanied your representatives, Lee Gooding and RiCk Overstreet, on final location clearance inspections of some North Slope wells. Mr. Grimaldi concluded that the wells listed below met the requirements for Location Clearance. Well Name Nanuk #2 Clover #A Meltwater North # 1 Meltwater North #2 & 2A PTD No'. 200-030 200-007 "'~200-012 '"'-,o 199/130 & 200-031 The Location Clearance inspections showed the locations were in compliance with 20 AAC 25.170 Onshore Location Clearance and therefore the Commission requires no further work on subject wells, however Phillips Alaska, Inc. remains liable if problems with the wells occur in the future. Sincerely, L-lc-4pans.doc Blair E. Wondzell, ~ - Sr. Petroleum Engineer CANNED JUN 1 2 2003 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lernke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Directional survey data DATE: 08/01/2000 Ak. Oil & Gas Conservation Comm. ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 Transmitted herewith is the following: -.- Transmittal of directional survey data for 4 1999-2000 North Slope Exploration wells: Permit 200-012 Meltwater North 1; Sperry Sun Job # AKMM90251 Permit' 200-031 Meltwater North 2A; Sperry Sun Job # AKMMg0261 Permit 199-130 Meltwater North 2; Sperry Sun Job # AKMM90232 Permit 200-030 Nanuk 2; Sperry Sun JOb # AKMM0002 , CC: Mark McDermott Sharon AIIsup-Drake Approved for transmittal by: Sandra Lemke. R E ¢ E IV E D Receipt: O~>'~Z~ Return receipt to: {~ Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99,501 Date: AUG 0 3 2000 Alaska 0ii & Gas Cons. Commissior~ Anchorage Prepared by: Sandra D. Lemke Phillips Alaska IT Geoscience Group ARCO ALASKA INC. 700 G STREET ANCHORAGE, AK 99510 907-276-1215 To: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Lori Taylor Date: May 02, 2000 From: Mark Myers ATO 1446 ARCO Alaska Inc. P.O.Box 100360 Anchorage, Alaska 99510-0360 Enclosed is the final data for Meltwater North #2 (AP1 # 501032032100) as listed below. 1 notebook: Epoch Final Well Report Includes lpaper copy each Formation log (mudlog) MD and Drilling Dynamics log - 2", 136 - 6300'. 1 sepia Epoch Formation Log (mudlog) 2" 136 - 6300' Upon receipt, please sign and return to: Thank You Received by: Catherine Worley ATO 1355 P.O. Box 100360 Anchorage, AK 99510. ARCO ALASKA INC. MELTWATER NORTH NO,, 2 FINAL WELL REPORT Section 16, T8N-R7E, UM North Slope Borough, Alaska RECEIVED MAY 04 2000 A/aska Oil & Gas Cons. Cornmi,ssion Anchorage EPOCH WELL SERVICES INC. ARCO ALASKA INC. MELTWATER NORTH NO. 2 FINAL WELL REPORT 136' to 6300' 216100 to 2115/00 Prepared By: JOHN MORRIS AND LEES BROWNE EPOCH WELL SERVICES INC. ARCO ALASKA, INC. MELTWATER NORTH NO. 2 WELL RESUME OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE: CONTRACTOR: RIG NUMBER: RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY REPS: MUD COMPANY: MUD TYPES: CASING DATA: HOLE SIZE: MUDLOGGING SERVICES: TYPE UNIT: UNIT NUMBER: LOGGING GEOLOGISTS: SAMPLE TECHNICIANS: LWD I MWD: COREING COMPANIES: ARCO ALASKA INC. MELTWATER NORTH NO. 2 SEC. 16, T8N-R7E, UM WILDCAT 2034' FNL, 293' FWL 250' AMSL (KB) 222' AMSL (PAD) NORTH SLOPE BOROUGH ALASKA 50-103-20321-00 FEBRUARY 6, 2000 6300' FEBRUARY 15, 2000 DOYON DRILLING INC. 141 SCR DIESEL-ELECTRIC (2) EMSCO FB1600 MARK MYERS MIKE WHITELEY, DEARL GLADDEN BAROID DRILLING FLUIDS INC. SPUD MUD TO 2070' LSND TO 6300' 9 518" AT 2059' 12 114" TO 2070' 8 112" TO 6300' EPOCH WELL SERVICES INC. DML I RIGWATCH I FID GAS DETECTION MLOA1 (RIG ROOM INSTALLATION) JOHN MORRIS, LEES BROWNE DAVE ROSCOE, ISAAC STOTTS SPERRY SUN INTEQ I CORE LABORATORIES ARCO ALASKA INC. MELTWATER NORTH NO. 2 DALLY ACTIVITY 2~6~00 MOVED RIG FROM WEST SACK PAD TO MELTWATER NORTH #2 PAD. RIG UP AND N/U DIVERTER. HELD PRE SPUD MEETING. CALIBRATE GAS ALARMS. TEST DIVERTER AND GAS ALARMS. MAKE UP BHA #1. DRILL 12 N" SURFACE HOLE FROM 105'-790'. 2/7/00 DRILL TO 2070'. TOP OF WEST SAK AT 1250'. BASE PERMAFROST AT 1390'. GAS SHOW FROM WEST SAK SAND AT 1760' (20') 1700 UNITS. BASE WEST SAK AT 1960'. PUMP SWEEP AROUND AND ClRC HOLE CLEAN FOR SHORT TRIP. OBSERVE WELL. MAKE WIPER TRIP TO 370'--NO PROBLEMS. SLM--NO CORRECTION. SWEEP HOLE. ClRC CLEAN. HAD 240 UNITS TRIP GAS. DROPPED SURVEY. OBSERVED WELL. POOH TO RUN SURFACE CSG. NO PROBLEMS. LID BHA, DOWN LOAD FRT'S. CHECK SHOT GOOD. CLEAR RIG FLOOR. RIG UP CASERS. PJSM. 2/8/00 RUN 9 5/8" 53.5~ L0=-80 BTC CASING. FILL EVERY JOINT. TOP OFF AFTER EVERY 5 JOINTS. BREAK CIRC AT 1000'. RAN 48 JOINTS TOTAL. M/U HANGER. P/U LANDING JOINT. M/U CEMENT HEAD. LANDED WITH 115K UP WT, 112K DOWN WT. CIRC AND CONDINTION. RECIP PIPE AND CONDITION FOR CEMENT. PUMP RATE AT 6 BPM INITIAL, WOR UP TO 9.5 BPM FINAL. CIRC TOTAL 5800 STROKES (586 BBL). HELD PJFSM WITH RIGH CREW AND ALL CONTRACTORS. CEMENT CASING--IN PLACE AT 10:00 AM. HELT 1000 PSI/5 MIN.--FLOATS HELD. RID CEMENT HEAD, LANDING JOINT AND CASING TOOLS. N/D DIVERTER SYSTEM. N/U CASING HEAD, ADAPTER AND TUBING SPOOL. TEST CASING HEAD SEALS TO 1000 PSImOK. N/U 13 3/8" 5000 PSI BOPE. RIU TO TEST BOPE, SET TEST PLUG. AOGCC REP JOHN SPAULDING WITNESSES TEST. TOP PIPE RAMS FAILED. REPAIR AND REPLACE SEAL AND WEAR PLATE. ATTEMPT TO RESTEST UPPER PIPE RAMS. 2/9/00 PJSM--TEST BOPS. CONTINUE TESTING BOPE--OK--WlTNESSED BY JOHN SPAULDING OF AOGCC. PULL TEST PLUG. INSSTALL WEAR BUSHING. M/U BHA #2, ORIENT TOOLS, SHALLOW TEST MWD, TIH, TAG CEMENT AT 1955'. ClRC ANC COND FOR CASING TEST. TEST CASING TO 2500 PSI FOR 30 MIN. ALL OK. DRILL CEMENT, PLUGS, FC, CEMENT AND FS + 20' NOW HOLE TO 2090'. ClRC AND COND FOR LOT. CHANG OVER TO LSND 9.6 PPG MUD. RIU AND PERFORM FIT TO EMW OF 16 PPG. DRILL TO 2588'. 2/10/00 PJSM--PLANNING OPERATIONS. DRILL TO 3305'. PUMP SWEEPS ASNEEDED. DRIL TO 3676'. PUMP SWEEP, CBU, MONITOR WELL--OK. WIPER TRIP TO SHOE. HOLE IN GOOD SHAPE. DRILL TO 4110'. 2/11/00 PJSM. SERVICE RIG. DRILL TO 5007', PJSM. DRILL TO 5316'. CBU, MONITOR HOLE-- STATIC. WIPER TRIP TO 3875'--NO PROBLEMS. PUMP SWEEP, ClRC AND COND MUD FOR TRIP. PULL 5 STANDS--MONITOR WELL--OK. PUMP DRY JOB. TOH TO CASING SHOE. MONITOR WELL--OK. TOH, WOR BHA, SERVICE MWD, BEGIN P/U ROTARY DRILLING ASSEMBLY. 2/12~00 SERVICE RIG. PJSM. P/U BHA #3--ROTARY ASSEMBLY--TIH, BREAK ClR AT 2070' AND 3750'. TIGHT SPOTS AT 4625' TO 4750'. KELLY UP AND PUMP THROUGH THIS ZONE OK, CLEAN. PUMP CHECK SUKRVEY FOR SPERRY AT 5274' AND 5310'. ROTARY DRILL TO 5447'. BREAK IN BIT. PUMP SWEEP AT 5320', WORK ROP UP TO 28' TO 30' PER HOURS. DRILL TO 5680'. 2/13100 SERVICE RIG. DRILL 5680' TO 5726'. DRILL BREAD AT 5720' UP TO 124 FT/HR. P/U STRING TO ROT. STOP PUMP. WELL APPEARS TO HAVE FLOW. SHUT IN WELL. NOTIFY RIG SUPV AND TOOLPUSHER. WELL SHUT IN. TAKE 15 MIN SHUT IN "NO PSI" CSG OR DP. OPEN CHOKE. NO FLUID RETURN. OPEN ANNULAR. NO FLOW. WELL STATIC. CBU. 240 UNITS BOTTOMS UP GAS. NO MUD WT CUT. DRILL TO 5735'. CBU. GAS AT BOTTOMS UP 540 UNITS. WIPE HOLE 15 STANDS. CBU. BOTTOMS UP GAS 82 UNITS. POOH--SLM. LAY DOWN BHA, DOWN LOAD MWD. CLEAN TOOLS OFF FLOOR. M/U CORE BARRELL. P/U CORE ASSY TO CUT 90' CORE. RIH TO SHOE, BREAK CIRC. CUT DRILL LINE. RIH TO 5465'--TIGHT SPOT. WASH AND REAM 5442' TO 5522'. RIH. WASH AND REAM 5658' TO 5735'. CBU. DROP BALL. SPACE OUT WITH 5' PUP. CORE 5735' TO 5826'. CBU. OBSERVE WELL--STATIC. PUMP DRY JOB. PULL 5 STDSmWELL STATIC. POOH AT 90 SEC/STD. 2/14~00 LAY DOWN AND PROCESS CORE. 90.2' RECOVERY. M/U CORE ASSY #2. RIH AND CBU. BOTTOMS UP GAS 14.6 UNITS. CORE 5826' TO 5894'. CBU--WELL STATIC--PUMP DRY JOB. POOH 5 STDS--WELL STATIC--POOH AT 90 SEC/STD. AT 900' REDUCE RATE TO 3 MIN/STD, AT 300' REDUCE RATE TO 6 MIN/STD. LAY DOWN INNER BARRELS. LAY DOWN CORE ASSY. M/U BHA #5. ORIENT TOOLS. UPLOAD MWD. RIH, BREAK ClRC AT 2000' AND 4100'. CONTINUE RIH. 2/15~00 RIH TO 5701'. MAKE MAD PASS FOR SPERRY/SUN FROM 5701' TO 5894'. DRILL 5894' TO 6300' MD (6132' TVD). WELL TAKING A SMALL AMOUNT OF FLUID WHILL DRILLING (10-18 BPH.) AFTER PUMPS ARE STOPPED, FLUID FLOWS BACK AND SLOWLY DECREASES TO ZERO. BREATHING SLIGHTLY. SURVEY, CBU. WIPE'HOLE TO 5360'--NO PROBLEM. P/U KELLY, WASH AND REAM 6260' TO 6300'. PUMP SWEEP. CBU. CONDITIN MUD FOR LOGGGING. CONTINUE ClRC SWEEP FROM HOLE. OPSERVE WELL--PUMP DRY JOB. POOH 10 STANDS--MONITOR WELL--OK. POOH TO SHOE--MONITOR WELL--OK. POOH TO BHA. DAILY RIG ACTIVITY BREAKDOWN ARCO ALASKA, INC. MELTWATER NORTH NO. 2 ACTIVITY AND HOURS tu 0 ,,~ m [u m m x m 0 , _, ~ => e - -' "' DATE DAY FEe s o ~os '' '?0' " 2000; ~ , ,, , ? 2 2,070.~.',00 '~:~.0 e.o~.~ :~.~ :~,,..0 "8 3 ,,o'ro 0 ' :~.0 ' 9 '4' :,,s~2 s22 ~.0 3.02.s" .~0.0 o.s ~,,,.'.0 , , , 10 5 4,110151821.52.00.5 24.0 ~ ,~, , , , 11 6 6,316 1206 16.0 6.5 1.5 24.0 ,, , .... ,, ~2 ? s,eso3e4 ~9.5 ~.~ 0.5 o.s 24.0 ................. 13 s s,s2e ~4e 4..0 13.5 3.~ ~.~ 1.5 2,4..0 ........ "d' ~ ~.~94 es 6.5 ~.5 2.0 24.0 ,, , r 15 10 6,300 406 5.0 7.0 2.5 2.5 0.5 6.5 24.0 ,,, 17 12 .... i iql 18 13 19 i4 i , i 20 15 i i i i i i i i i i ii 2,t .t6 ~ i i lull 22 17' · ................. 24 19 26 20 I ~ i i iiui 26 21 i i ii i i 27 22 i i i i ii i I II ii 28 23 i i i 29 24 1 '2~ .............. I ii I I 2 26 ,,, i .3 2? i i ii · 4 28 i i ii i ii $" 29 6 3O II I I I I I I I CUMM TOTAL HOURS 101.0 60.0 18.0 3.0 2.0 29.0 11.0 0.0 .5 9.5 240.0 II I I I I I I I I I I I II I III TRIP/WIPE/BHA 25% CIRCULATE 8% RIG UTILIZATION CHART ARCO ALASKA INC. MELTWATER NORTH NO. 2 REAM/OPENHOLE RIG/TEST BOPE suRv~1% 12°,6 CASING/CEMENT 5% WIRE UNE LOGS DRILLING 41% 3°,6 OTHER 4% 0 1000 2O00 3OOO 4000 5OO0 6OO0 7OO0 ARCO ALASKA INC. MELTWATER NORTH NO. 2 DALLY DRILLING PROGRESS 9 5/8" IG 10 DAYS 2o PLAN ACTUAL BIT RECORD ARGO ALASKA INC. MELTWATER NORTH NO. 2 BIT SIZE MAKE AND SERIAL JETS DEPTH FOOTAGE ON AVG DRILUNG PARAMETERS NO. BTM WOB BIT RPM PUMP PRES DULL GRADE TYPE NUMBER IN OUT TOTAL HOURS ROP low-high~avg lowJfigh~vg Iow-high~vg I 12.25 HTC MSDSH J232W 3X15 105 2070 1965 9.5 206.8 2-43-21 8-100-73 1565-2729-1890 2-2-ER-A E-8-NO-TD 2 8.5 HYC DS70FGV 20627 6X 11 2070 5316 3246 23.8 136.4 2-25-9 0-88-57 1212-2525-1953 3-1-CT-N X-1-NO-BHA 3 8.5 HTC AT J050 V29CL 3X 15 5316 5735 419 16.8 24.9 7-35-33 17-103-94 1443-2437-1982 1-1-NCAA E-1-NO~CP , 4 8.5 HTC ARC412 1901876 .77 TFA 5735 5826 91 1.5 60.7 3-31-7 0-91-85 567-894-664 1-1-NO-A X-1-NO-CP 4R1 8.5 HTCARC412 1901876 .77 TFA 5826 5894 68 3.5 19.4 2-15-4 0-91-83 567-716-665 7-1-BT-N X-I-NO-PR 2R1 8.5 HYC DS70FGV 20627 6 X 11 5894 6300 406 8.8 46.2 2-12-7 17-86-77 640-2716-2364 6-2-CT-N X-1-ER-TD DAILY MUD REPORTS ARCO ALASKA, INC. MELTWATER NORTH NO. 2 Mud Data Provided By: BAROID WATER BASE MUD OIL ~WATER DATE DEPTH MW FV PV YP GELS FL CAKE SOL % % SD MBT Ph Cl- CA 2~6/00 970 10.1 102 20 33 22/58 11.0 2.0 10 0 90 0.5 27.5 9.1 700.0 52 2/7/00 2070 10.2 76 26 22 11/36 6.5 2.0 12 0 88 0.5 20 9.1 500.0 40 2/8/00 2070 10.2 48 24 10 3/4 6.2 2.0 13 0 87 0.5 20 9.0 500.0 36 2/9/00 2425 9.6 45 16 16 5/12 6.6 2.0 6 0 94 TR 12.5 10.2 300.0 20 2/10/00 4110 9.6 45 16 15 5/12 6.0 2.0 6 0 94 TR 17.5 9.8 200.0 28 , 2/11/00 5316 9.6 45 15 13 5/13 5.8 2.0 6 1 93 TR 17.5 9.4 150.0 32 2/12/00 5585 9.60 43 16 16 3/8 4.4 2.0 5 1.0 94 TR 15 9.4 300.0 40 2/13/00 5826 9.6 45 16 14 4/7 4.4 2.0 6 2 92 TR 15 9.0 250.0 32 , , 2/14/00 5894 9.6 46 19 14 4/9 4.3 2.0 6 2 92 TR 15 9.1 300.0 40 2/15t00 6300 9.6 44 18 13 4/7 4.3 2.0 7 1 92 TR 15 9.2 300.0 32 SURVEY RECORD ARCO ALASl~, INC MELTWATER NORTH NO. 2 i MEASURED HOLE VERTICAL COORDINATES DOG LEG , DEPTH TVD ANGLEAZlMUTH SECTION N {+~ S l'! E {+} W (-) SEVERITYI 165.43' 165.42' 0.28 26.23 -0.04 0.04 0.18 0.17 292.94 292.94 0.32 1.67 0.04 1.00 0.33 0.10 404.35 40~.35 0.12 342.76 0.21 1.42 0.31 0.19 441.91 441.91 0.19 340.48 0.27 1.51 0.27 0.19 , , , , , 533.40 533.40 0.12 5.47 0.39 1.74 0.23 0.10 662.10 662.10 0.19 9.46 0.46 2.08 0.28 0.06 760.27 760.26 '0'.30 340.97. 0.66 2.48 ' 0.22 '0116 819.32 819.31 0.31 329.30 0.88 2.76 0.09 0.11 922.89 922.88 0.43 357.26 1.25 3.39 -0.07 0.21 1013.98 1013.97 0.39 341.26 1.58 4.03 -0.18 0.13 1106.39 t106.38 0.46 345.21 1.99 4.68 -0.38 0.09 ,, , , 1198.56 1198.55 0.44 346.62 2.40 5.38 -0.55 0.03 1291.38 1291.36'0.52 332.37 '2.91"' 6.10 " ~0.83 '0.'15 ..... 1384.52 1384.49 0.64 344.01 3.53 6.98 -1.17 0.18 1486.71 1486.68 0.65 350.41 4.16 8.10 -1.42 0.07 ' '1568.71 ' 1568.6'7 0'.~4 354.60 4'.62~ 9.08 -1.55 ~ 0.12 ' 1661.05 1661.01 0,76 343.49 5.25 10.26 -1.78 0.16 '1754.27" 1754'.'22 0.'19 276.00 '5.77 10.87 "-2.i'1 ' '0.~6 1847.27 1847.22 0.19 243.06 6.02 10.81 -2.40 0.12 1940.'47 1940.42 0.26. 227.36 6.22" 10.60 '2.69 0.09 .... 1999.91 1999.86 0.38 246.36 6.43 10.43 -2.97 0.28 2115.19 2115.14 0.38 261.79 7.04 ..... 10.22 ....~3.~1 ' "0.09 2146.77 2146.72 0.29 247.96 7.19 10.10 -3.88 0.39 2208.89 2208.84 0.48 257.15 7.52 10.06 -4.28 0.33 2240.05 2239.99 0.63 267.75 7.79 10.03 -,4.58 0158 2271.56 2271.50 1.94 290.61 8.48 10.21 -5.25 4.38 2301.70 2301.61 2.79 288.72 9.73 10.62 -6.43 2.85 '2331'.99 2331.8~' 4'.50 290.86' 1i.~6 "'11.28 ' '-8.'24 '"5.66 ' 2425.39 2424.69 7.77 292.72 '~1'.64' 15.0':~ ........ -1":~149' 3.51 2518.77 2516.99 9.66 290.52 35.78 20.21 -30.66 2.05 2612.26 2608.87 11.56 288.58 52.99 25.95 -46.89 2.07 ,' 2674.88 2670.1~ 12.02 286.05 65.77 29.75 -59.10 1.10 2734.61 2728.40 13.72 282.99 78.99 33.06 -71.98 3.06 "'2797115 2788.79 16.'39 280.~' '95.04 36.33 -87.88 4.39' '2888.75 2875.82 19.9'3 282.28 123.22 ' 42.00 -11'5.85 3.91 2951.98 2935.10 20.80 282.49 145.01 46.72 -137.34 1.39 3045.27 3021.49 23.54 '28~.89" 180.04 56.03 -171.'25 3,66'" 3106.65 3077.51 24175 294.41 205.11 65.11 -194.62 4.77 3199.56 3161.51 25.85 293.16 244.74 81.12 -230.95 1.31 3292.08 3244.24 27.32 291.13 286.12 96.71 -269.30 1.87 i [ I i iiii I i i i i iii i i i i SURVEY RECORD ARCO ALASKA, INC. MELTWATER NORTH NO. 2 MEASURED HOLE VERTICAL COORDINATES DOG LEG DEPTH TVD ANGLEAZIMUTkt SECTION N (+) S (-) E (+) W (-) SEVERITY i 3386.48 3328.18 27.14 291.09 329131 112.26 -309.60 0.20 , , , , , , 3477.73 3409.50 26.83 291.58 370.71 127.33 -348.16 0.41 '355'2.98 34'76.71 26.73 '291.40 404.54 139.75 -379.64 '0.21 ~ , 3560.12 3483.09 26.59 291.49 407.75 140.93 -382.62 0.21 ,, , , 3664.12 3576.12 26.51 291.53 454.22 157.97 ~25.87 0.08 3757.01 3659.29 26.41 291.50 495.60 173.15 ~64.37 0.11 3852.31 3744.61 26.49' 288.98 '538.04 187.~3' -504.19 1.18 3942.41 :3825.25 26.49 288.34 578.21 200.69 -542.26 0.32 4038'.21' '39il.50 25.13' 287.8~ 619.88 213.65 -581.90 1.44 4128.90 3994.30 23.01 289.14 656.84 225.37 -6t6.98 2.41 4221.78 4080.70 20.02' ~.86.73 ''6~0.86 235.90 -649136 ' 3.35 4311.19 :4165.42 17.21 286.44 719.33 244.05 -676.70 3.15 4407.40 '4257.94 14.6'1 287'.35 7'45.64 ~ 251.70 -701.93 '2.~1 4502.29 4349.88 14.03 286.32 769.07 258.50 -724.40 0.66 4591.66 ~4436.64 13.75 285.41 790.46 264.37 -745.04' '0.40" "4684.24"4526159 13'.60' 286.,43 '812.28 270.37 -766.09 "0.'30 4746.33 4586.94 13.60 2'86.97 826.85 274.57' -780.07' 0.20"' '4840.04 4678.36 11'178 '287.27 '847.40 280.63 -7~9.75 1.94"' 4936.26 :4772.97 9.13 288.58 864.85 285.98 -816.37 2.76 ~'5026.52' 4862.33' 7.04 287.48 8'77.53 ' '289192 -828.44 " 2.33 5118.52 495'3.8~ '4172 288.33 886.95 2'92.81 -837.41 .... 2.53' .... 5211'191 " '~046.94 " '4.26 2'91'.67 894.25 29~.3'0' '~844.2~ '0.5~ 5226.82 5061.81 4.35 292.50 895.37 295.72 -845.31 0.77 "5308.32 5143.09 '4.05 294'.80' 901.33" '298. il "-8,50.78 ....0.43 5402.61 5237.15 4.08 296.02 907.99 300.98 -856.82 0.10 5496.51 '5330.81 4,05 297.65 914.60 303.98 -862.76 0.13 ' '5589.'76" 5423.82 4~.i9 "29'7.63 921.25 '307.09 '" -'868.69 ' 0.16 '568(3.87 "5514.69 ',4.12 '297.45 927.79'"' 310. i4" '-874.54 " 0.08 5776.30 5609.86 4.32 299.61 934.74 313.49 -880.71 0.27 5895.11 5728.33 '4.30 300.44~ '943.55' 31~.96 -888.44 0.06 5992.54 582',5.5'04.15 300.'97 950.61 ..... 321.63 -894.6i "0.16" 6084.89 5917'.61 41'11 301.42 957.14 ' 325.07 -900.30 '0.05 6'179.21 60il.70 3'.98 '301.44 963.68 32'8.54 -905.98 0.14 6231.05 6063.41 '3.93 '304.55 96~.16 330.49 '-'908.98 "0.42 ' 6300.00 6132.20 3.93 30'1144 "971.78 .... 33'3.06 -912.94 ' 0.31 i i i i i I i i I ARCO Alaska, Inc. ~( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Anchorage, Alaska 99501 Subject: Meltwater North #2 and #2A (Permit 199-130/300-048 and 200-31) Completion Report Dear Mr.' ARCO Alaska, Inc., as operator of the Meltwater North #2 and #2A exploration wells, submits the enclosed sepias to be included with the "Well Completion Report" (form 407) sent earlier. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PAM/TJB/skad RECEIVED APR 24 2000 Alaska 0il & Gas Cons. Commission Anchorage Core Chip Descriptions - Core 1 Meltwater North #2 ORIGINAL 65% - analcine pseudomorphic replacement of very fine - upper fine gr. sandstone; strongly 5733 light grayvolcanic glass, 15% - quartz, 15% - friable; moderately sorted; subangular bright yellow fair to good petroliferous sedimentary rock fragments, 5% - carbonaceous fragments grains 65% - analcine pseudomorphic replacement of upper fine gr sandstone interbedded strongly 5739 light grayvolcanic glass, 15% - quartz, 15% - with 4cm long siltstone rip-up clasts; yellow fair to good petroliferous sedimentary rock fragments, 5% - minor calcite cement; moderately carbonaceous fragments sorted; subangular grains 65% - analcine pseudomorphic replacement of upper fine gr sandstone interbedded strongly volcanic glass, 15% - quartz, 15% - with 4cm long siltstone rip-up clasts, yellow fair to good petroliferous 5742 light graysedimentary rock fragments, 5% - minor calcite cement; moderately carbonaceous fragments sorted; subangular grains laminated siltstone, very indurated; spotty light 5745 dark gray moderately sorted; subangular grains yellow 65% - analcine pseudomorphic replacement of upper fine to loWer very fine gr. strongly 5748 light grayvolcanic glass, 15% - quartz, 15% - sandstone interbedded with siltstone bright yellow fair to good petroliferous sedimentary rock fragments, 5% - rip-up clasts, friable; moderately carbonaceous fragments sorted; subangular grains siltstone, indurated; moderately sorted; spotty light 5751 dark gray subangular grains yellow 65% - analcine pseudomorphic replacement of very fine - lower medium gr. strongly volcanic glass, 15% - quartz, 15% - sandstone; siltstone rip-up clasts; fair to good petroliferous 5754 light graysedimentary rock fragments, 5% - subangular sand, moderately sorted carbonaceous fragments laminated carbonaceous siltstone; spotty light 5759.3 dark gray indurated; subangular sand, yellow moderately sorted 65% - analcine pseudomorphic replacement of argillaceous lower very fine gr spotty light 5762 medium volcanic glass, 15% - quartz, 15% - sandstone, indurated; subangular poor gray sedimentary rock fragments, 5% - ~- sand, moderately sorted yellow Carbonaceous fragments ~ 65% - analcine pseudomorphic replacement of upper fine gr sandstone, good sorting, volcanic glass, 15% - quartz, 15% - strongly 5765 light graysedimentary rock fragments, 5%- subangular grains, friable; moderately bright yellow fair to good 3etroliferous carbonaceous fragments sorted; subangular grains Page 1 4/12/00 Core Chip Descriptions - Core 1 Meltwater North #2 Porosity r odor 65% - analcine pseudomorphic replacement of lower - upper very fine gr sandstone; strongly 5768 light grayvolcanic glass, 15% - quartz, 15% - well sorted, subangular grains; bright yellow good petroliferous sedimentary rock fragments, 5% - moderately sorted; subangular grains carbonaceous fragments 65% - analcine pseudomorphic replacement of argillaceous very fine gr. sandstone, spotty light volcanic glass, 15% - quartz, 15% - indurated; moderately sorted; poor 5771 dark gray sedimentary rock fragments, 5% - yellow carbonaceous fragments subangular grains spotty light 5774 dark gray siltstone, indurated yellow 65% - analcine pseudomorphic replacement of argillaceous very fine gr sandstone 5777 dark gray volcanic glass, 15% - quartz, 15% - with thin wispy carbonaceous spotty light poor sedimentary rock fragments, 5% - laminations, friable; moderately sorted; yellow carbonaceous fragments subangular grains lower medium to upper very fine - 65% - analcine pseudomorphic replacement of lower med gr sandstone; upper portion spotty light fair volcanic glass, 15% - quartz, 15% - has wispy carbonaceous laminations; yellow 5780 light graysedimentary rock fragments, 5% - friable; moderately sorted; subangular carbonaceous fragments grains, very thin graded beds 65% - analcine pseudom°rphic replacement of upper very fine - lower medium gr sandstone with wispy carbonaceous spotty light fair medium volcanic glass, 15% - quartz, 15% - laminations; moderately sorted; yellow 5783 gray sedimentary rock fragments, 5% - subangular grains, very thinly bedded carbonaceous fragments beds 65% - analcine pseudomorphic replacement of argillaceous lower very fine gr spotty light volcanic glass, 15% - quartz, 15% - sandstone; moderately sorted; poor 5786 dark gray sedimentary rock fragments, 5% - yellow carbonaceous fragments subangular grains laminated, argillaceous siltstone; spotty light 5790 dark gray moderately sorted; subangular grains yellow poor 65% - analcine pseudomorphic replacement of argillaceous lower very fine gr volcanic glass, 15% - quartz, 15% - sandstone with millimeter scale graded spotty light 5793 dark gray sedimentary rock fragments, 5% - bedsl moderately sorted; subangular yellow poor carbonaceous fragments ~lrains Page 2 4/12/00 Core Chip Descriptions - Core 1 Meltwater North #2 Porosib/ I Odor 65% - analcine pseudomorphic replacement of upper to lower very fine gr sandstone volcanic glass, 15% - quartz, 15% - with small amounts of calcite cement; spotty light fair to poor 5796 light graysedimentary rock fragments, 5% - yellow carbonaceous fragments moderately sorted; subangular grains 65% - analcine pseudomorphic replacement of 5799 dark gray volcanic glass, 15% - quartz, 15% - argillaceous siltstone, indurated; spotty light poor sedimentary rock fragments, 5% - moderately sorted; subangular grains yellow carbonaceous fragments !65% - analcine pseudomorphic replacement of lower to upper very fine gr sandstone; 5802 medium volcanic glass, 15% - quartz, 15% - somewhat friable; moderately sorted; bright yellow fair gray sedimentary rock fragments, 5% - carbonaceous fragments subangular grains 65% analcine pseudomorphic replacement of argillaceous very fine gr sandstone; 5805 dark gray volcanic glass, 15% - quartz, 15% - indurated; moderately sorted; very spotty sedimentary rock fragments, 5% - carbonaceous fragments subangular grains argillaceous siltstone interbedded with millimeter thick beds of very fine gr 5808 dark gray sandstone; moderately sorted; none subangular grains 65% - analcine pseudomorphic replacement of argillaceous lower very fine gr spotty light poor 5811 dark gray volcanic glass, 15% - quartz, 15% - sandstone; indurated; moderately yellow sedimentary rock fragments, 5% - sorted; subangular grains carbonaceous fragments ~ 65% - analcine pseudomorphic replacement of volcanic glass, 15% - quartz, 15% - argillaceous very fine gr sandstone; spotty light poor 5814 dark gray sedimentary rock fragments, 5% - moderately sorted; subangular grains yellow carbonaceous fragments 5821 dark argillaceous siltstone, high indurated, none brown moderately sorted, subangular grains laminated argillaceoUs siltstone with wispy carbonaceous material 5824 dark gray interbeds, moderately sorted, none subangular grains Page 3 4/12/00 Core Chip Descriptions - Core 1 Meltwater North #2 Porosity I Odor siltstone, highly indurated, moderately none 5825.5 dark gray sorted, subangular grains medium lamianted coarse siltstone, moderately 5827 gray sorted, subangular grains none 65% - analcine pseudomorphic replacement of argillaceous very fine sandstone, 5830 medium volcanic glass, 15% - quartz, 15% - indurated, moderately sorted, very spotty poor gray sedimentary rock fragments, 5% - subangular grains carbonaceous fragments medium coarse siltstone, indurated, moderately none 5833 gray sorted, subangular grains 65% - analcine pseudomorphic replacement of upper very fine sandstone, no 5836 medium volcanic glass, 15% - quartz, 15% - carbonate cement, moderately sorted, none poor gray sedimentary rock fragments, 5% - subangular grains carbonaceous fragments 65% - analcine pseudomorphic replacement of medium volcanic glass, 15% - quartz, 15% - argillaceous lower very fine sandstone, 5839 gray sedimentary rock fragments, 5% - moderately sorted, subangular grains none poor carbonaceous fragments medium coarse siltstone, indurated, moderately very spotty, 5842 gray sorted, subangular grains light yellow argillaceous siltstone, moderately none 5845 dark gray l sorted, subangular grains 65% - analcine pseudomorphic replacement of very fine sandstone with minor 5848 medium volcanic glass, 15% - quartz, 15% - carbonate cement, moderately sorted, none poor gray sedimentary rock fragments, 5% - subangular grains carbonaceous fragments medium siltstone, indurated, moderately sorted, spotty 5851 gray subangular grains medium siltSonte, indurated, moderately sorted, spotty weak 5854 gray subangular grains yellow 65% - analcine pseudomorphic replacement of lower fine sandstone with zeoloite or volcanic glass, 15% - quartz, 15% - kaolinite cement, indurated, moderately spotty yellow poor 5854.6 light graysedimentary rock fragments, 5% - sorted, subangular carbonaceous fragments Page 4 4/12/00 Core Chip Descriptions - Core 1 Meltwater North #2 I I J Visible Odor Depth (feet) Color Ljthology Textural Description Fluorescence Porosib/ mediUm siltstone, moderately sorted, none 5859.2 gray subangular medium siltstone, moderately' sorted, none 5861 gray subangular 65% - analcine pseudomorphic replacement of upper very fine sandstone with volcanic glass, 15% - quartz, 15% - kaolinite or zeolite cement, indurated, weak spotty poor 5864 light graysedimentary rock fragments, 5% - moderately sorted, subangular grains carbonaceous fragments 65% - analcine pseudomorphic replacement of upper very fine sandstone with minor spotty poor volcanic glass, 15% - quartz, 15% - kaolinite or zeolite cement, indurated, yellow 5867 light graysedimentary rock fragments, 5% - moderately sorted, subangular grains carbonaceous fragments argillaceous siltstone, fissile, none 5870 dark gray moderately sorted, subangular grains argillaceous siltStone, moderately minor spotty 5873 dark gray sorted, subangular grains yellow silty mudstone, moderately sorted, none 5876 dark gray subangular grains silty mudstone, moderately sorted, none 5879 dark gray subangular grains silty mudstone, moderately sorted, none 5882 dark gray subangular grains silty mudstone, moderately sorted, none 5885 dark gray subangular grains laminated siltstone with coarser gr. 5889 dark gray Interbeds, moderately sorted, none subangular grains Page 5 RECEIVED APR 24 2000 Ala~k~ Oil & G~ Cons. C0mmis~ior~ Anch0r~e 4/12/OO ARCO ALASKA, INC. Meltwater North #2 CL File No.: 571' PRELIMINARY CORE ANALYSIS RESULTS 28 5758.1 4.9 18.1 35.3 40.9 0.86 76.2 2.63 Sst tan slty carb incl m stn yel-grn flu D. Stark 29 5759.1 34. 19.3 40.5 41.4 0.98 81.9 2.67 Sst tan vf-fgr slty carb incl rn stn yel-grn flu D. Stark 30 5760.1 18. 17.4 33.3 42.7 0.78 76.0 2.64 Sst tan vf-fgr slty sh incl carb incl rn stn yel-grn flu D. Stark RECEIVED APR ~4 ~000 AJa~k~l Oil & Gas Cons. Commission Anchorage RECEIVED APR 24 2000 Ata~ka 0ii & Gas Cons. Cornmissio~ Anchorage :lesults Page 2 Page 4 4/12/00 RECEIVED ARCO ALASKA, INC. Meltwater North #2 APR 24 2.000 Alaska 0il & Gas Cons. Commission Anchorage PRELIMINARY CORE ANALYSIS RESULTS CL File No.: 571' 1 5730.1 1.1 20.6 13.3 70.0 0.19 83.3 2.73 2 5731.1 0.19 19.5 11.5 71.2 0.16 82.7 2.68 3 5732.1 0.32 20.3 9.6 73.4 0.13 83.0 2.74 4 5733.1 2.1 18.3 15.8 65.3 0.24 81.1 2.67 5 5734.1 2.1 19.5 28.6 49.7 0.58 78.3 2.69 6 5735.2 5.1 19.9 29.3 56.8 0.52 86.0 2.70 7 5736.2 2.3 20.2 26.0 56.3 0.46 82.3 2.70 8 5737.4 22. 20.6 36.9 40.8 0.90 77.8 2.68 9 5738.1 0.030 14.5 0.0 95.7 0.00 95.7 2.69 10 5739.2 18. 18.4 30.1 45.4 0.66 75.5 2.67 11 5740.2 2.7 14.7 9.8 69.1 0.14 79.0 2.57 12 5741.1 4.9 16.1 35.0 52.9 0.66 87.9 2.67 13 5742.2 2.5 20.5 26.5 50.8 0.52 77.3 2.68 14 5743.1 20. 20.6 27.2' 53.4 0.51 80.6 2.71 15 . 5744.1 51. 20.1 49.4 35.7 1.39 85.1 2.68 16 5745.5 0.023 13.1 0.0 75.3 0.00 75.3 2.66 17 5746.1 0.15 13.4 0.0 94.5 0.00 94.5 2.67 18 5747.2 0.09 16.4 0.0 89.1 0.00 89.1 2.66 19 5748.1 1.2 16.5 16.1 70.7 0.23 86.8 2.62 20 5749.1 2.1 14.1 27.3 42.1 0.65 69.4 2.66 21 5751.3 0.99 12.6 0.0 88.5 0.00 88.5 2.53 22 5752.1 0.008 8.5 4.3 75.3 0.06 79.6 2.64 23 5753.1 0.20 13.8 3.3 80.8 0.04 84.1 2.61 24 5754.1 0,56 16.6 0.0 48.7 0.00 48.7 2.61 25 5755.1 0.51 17.3 14.9 65.3 0.23 80.3 2.61 26 5756.1 0.012 13.1 0.0 94.5 0.00 94.5 2.70 27 5757.1 85. 21.6 49.9 32.7 1.53 82.7 2.70 Sst It tan vslty mica It stn yel-grn flu D. Stark Sst It tan vfgr vslty sh incl mica It stn yel-grn fluD. Stark Sst It tan vfgr vslty mica It stn yel-grn flu D. Stark Sst It tan vfgr slty mica It stn yel-grn flu 13. Stark Sst It tan vfgr slty mica It stn yel-grn flu D. Stark Sst It tan vfgr slty mica It stn yel-grn flu D. Stark Sst It tan vfgr slty mica It stn yel-grn flu D. Stark Sst It tan vfgr slty sh incl mica It stn yel-grn flu D. Stark Sh gry slty no stn no flu D. Stark Sst It tan vf-fgr slty sh incl mica It stn yel-grn flu D. Stark Sst It tan vfgr vslty Ig sh lams mica It stn yel-grn flu D. Stark Sst tan vfgr vslty sh lam mica It stn yel-grn flu D. Stark Sst It tan vfgr vslty sh strks mica It stn yel-grn flu D. Stark Sst It tan vfgr slty sh incl mica It stn yel-grn flu D. Stark Sst tan vfgr slty m stn yel flu D. Stark Sit gry vfgr sdy shly no stn no flu D. Stark Sltst gry vfgr sdy shly no stn no flu D. Stark Sst gry-lt tan vfgr vslty It strk stn yel-grn flu D. Stark Sst It tan vfgr vslty sh strk It stn yel-grn flu D. Stark Sst tan vfgr slty m stn yel flu D. Stark Sst gry-lt tan vfgr vslty vshly It strk stn gld flu D. Stark Sst gry-lt tan vfgr vslty It sptd stn yel-grn flu D. Stark Sst gry-lt tan vfgr vslty sh lams It strk stn yel-grn fk D. Stark Sst tan vfgr vslty sh incl mica It stn yel-grn flu D. Stark Sst It tan vfgr vslty carb strks mica It stn yel-grn flu D. Stark Sh gry vfgr sdy strk slty no stn no flu D. Stark Sh tan vfgr slty cht incl m stn yel flu/Fractured D. Stark RECEIVED APR 24 2000 ~a~a Oil& Gas o~s. Anchora~je Results Page I Page 3 4/t 2/00 PLUGGI",'~G & LOC3.TION State cf Alaska ALA8~ OiL & GA~ C~S~TION C~HMISSION Well }tame . Lcc~Cicn ! 03 - 20 3 ~ ~ -o o Revlaw the well file, Well hear Harker 'pos= or place: Loca:£cn Clearance: an~.' c~.~: on pluq~.nq, well hea~ ~ o3-- ~o3 ,zI -o 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 24, 2000 Mr. Robert Christenson Commissioner · State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Meltwater North #2 (Permit 199-130/300-048) Completion Report Dear Mr. Commissioner: ARCO Alaska, INC., as operator of the Meltwater North #2 exploration well, submits the enclosed "Well Completion Report" (form 407). Other attachments to the completion report include the directional survey, geologic tops, report of daily well operations, memo for Abnormal Pressure, time and mud weight chart and as-built. We will send under separate cover the core description, the logs, the sepia of the mud logs and other well data and reports. We have already sent over the cuttings samples. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PAM/TJB/skad RECEIVED APR 05 000 AJaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned I~1 Service r'"l 2. Name of Operator . .~.--.,.,.,..,.,~., 7. Permit Number ARCO Alaska, Inc. ~, ~.'3'CATIC)I'~,.~,,,...~_ ~ 199-130 / 300-048 3. Address -,-;.r.,j~-~.:.~ I,' 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~u~~ 50-103-20321-00 2099' FNL, 454' FWL, Sec. 16, T8N, R7E, UM (ASP: 447689, 5867751) . Exploration NPRA A tTop Producing Interval :! ,~_ ~./~_..~ 10. Well Number 1789' FNL, 419' FEL, Sec. 17, T8N, R7E, UM (ASP: 446817.1,5868066.8) Meltwater North #2 A tTota, Depthi~ ,~..~ .... .: 11. Field and Pool 1766' FNL, 458' FEL, Sec. 17, T8N, R7E, UM (ASP: 446778.5, 5868090.6) i ................... , ........... 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Exploration RKB 28 feetI ADL 373112 ALK 4711 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Comp'ietions February 6, 2000 February 15, 2000 February 20, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost YES [] No [~I N/A feetMD 1390' 6300' MD / 6132' TVD 6300' MD / 6132' TVD 22. Type Electric or Other Logs Run Resistivity/G R, Neutron/Density/AIT/GR, Magnetic Resonance L 2.3. OASlNG, LINER AND dEMENTING RECORD SETTING DEPTH MD OASING 81ZE WT. PER FT. GRADE TOP Bo-FrOM HOLE 81ZE OEMENTING REOORDI AMOUNT PULLED 16" 62.5# L-80 Surface 105' 20" 200 cf 9.625" 53.5# L-80 Surface 2059' 12.25" 392 sx AS III LW & 230 sx Class G Plug 1: top of cement plug @ 5493' Plug 2: Mechanical retainer @ 2009', TOC @ 1952' Plug 3: top of cement plug @ 111' 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) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug 1:64 bb115.8 # Class G Plug 2:17 bbls 15.8 ppg Class G Plug #3:17.4 bblAS I 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) None Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL 'CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVERRECEIVED Os 0oo Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. ~, 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Geologic Markers: RECEIVED Refer to attachment APR 0 5 000 Alaska Oil & Gas Cons. Commission Anchorage Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Geologic Tops, Abnormal Pressure memo, time and mud weight chart, as-built 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 Signed~"~~_ ~~ Title Exploration/Tarn Team Leader Date t fj~ Paul Mazzolini INSTRUCTIONS Prepared by Sharon Al/sup-Drake 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 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 Geologic Tops Meltwater North #2 Measured Depth TVDSS Depth Base Prmfrost 1390 1140 Top W. Sak 1250 1000 Base W. Sak 1960 1710 C-80 2448 2198 :C-40 (K-S) 3430 3116 Top Cairn 5447 5031 Top Bermuda 5710 5294 Mid Bermuda 5820 5397 Base Bermuda/Top C-35 5920 5500 Base C-35 5930 5564 TD 63OO 5882 RECEIVED APR 0 5 2000 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: Internal Correspondence 3~20~00 Abnormal Pressure in Melt~vater North #2 & #1 From/Location: Telephone: To/Location: T.J. Brassfield 265-6377 Sharon AIIsup-Drake As requested from the DNR for data submittal on the Meltwater North #2 & #1 wells, there were no abnormally pressured zones encountered while drilling these wells. Please find attached the mud weight graphs plotted by depth for both of the wells. Any questions, please call me at 265-6377 or Paul Mazzolini at 263-4603. Tom Brassfield Staff Drilling Enginee~ CC: MWN #1 & #2 Well Files ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED APR 0 5 2000 Alaska 0ii & Gas Cons. Commission Anchorage ILl DRILLING TIME AND MUD WEIGHT CURVE Meltwater North #2 0 -~' 16" set @ 105' ~ 4000 i D~k~ee: ___!_ i._ ~ : _~__ ; __ ~ ~ ~ . : : ; ; . ~ Core 8-1/2" ~Log Hole, Temporarily Suspend 6000 :_ : : .... ' --~ : ;-- ~ :--% ; - ;-- ~ ; ; -; : : -: ~ Release Rig for Test to MWN _ _~ z _ · , . ~ _ : · : _ : _ ; : ' - .. : , . ~ : . . 7OOO Spud 1630 hrs 2/6/00 0 5 10 15 20 25 TIME TO DRILL (DAYS) #1 + Depth ' ~-':~-'Mud Weight 10.8 : 10.6 10.4 10.2 10 9.8 9.2 9 8.8 8.6 8.4 3O 8.2 35 Rig Release 1700 hrs 2/21/00 prepared by TJB 2/11/00 Date: 03/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:MELTWATER NORTH #2 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD:02/06/00 START COMP: RIG:DOYON 141 BLOCK: FINAL: WI: 0% SECURITY:3 API NUMBER: 50-103-20321-00 02/06/00 (D1) TD/TVD: 970/970 SUPV:MIKE WHITELEY MW: 10.1 VISC: 102 PV/YP: 20/33 (970) DRILLING AHEAD AT 1700' APIWL: 11.0 Moved rig from West Sak pad starting 10:00 hrs 2/4/2000, complete rig on Meltwater location ~ 10:00 hfs 2/5/2000. Start NU diverter. Accepted rig ~ 0000 hrs 2/6/2000. Held pre-spud safety, enviro, compliance meeting. Function test diverter. Shallow gas drill. Drill 12.25" surface hole from 105' to 790' 02/07/00 (D2) MW: 10.2 VISC: 76 PV/YP: 26/22 APIWL: 6.5 TD/TVD: 2070/2069 (1100) CIRC AND CONDITION MUD WITH CSG ON BTM AT 2059' FOR CE SUPV:MIKE WHITELEY Drilled from 970'-2070' TD. Pump sweep around and circ hole clean for short trip. Made wiper trip to 370', no problems. Sweep hole. Circ clean. Had 240 units trip gas. POOH. PJSM. 02/08/00 (D3) MW: 9.6 VISC: 48 PV/YP: 24/10 APIWL: 6.2 TD/TVD: 2070/2069 ( 0) ATTEMPT TO RE-TEST TOP PIPE RAMS SUPV:DEARL W. GLADDEN PJSM. Run 9-5/8" casing. PJSM. Pump cement. Floats held. N/D diverter. N/U casing head. N/U BOP and test. Top pipe rams failed, repair and replace seal and wear plate. Attempt to re-test upper pipe rams. 02/09/00 (D4) MW: 9.6 VISC: 45 PV/YP: 16/16 APIWL: 6.6 TD/TVD: 2592/2588 ( 522) DRILLING 8.5" HOLE @ 2965' SUPV:DEARL W. GLADDEN PJSM. Test BOPs. OK. Tag cement @ 1955'. Circ and cond for casing test. Test casing to 2500 psi. Drill cement, plugs, FC, cement and float shoe + 20' new to TD 2090'. Circ and condition for LOT, change over to LSND mud. Perform FIT to EMW 16.0 ppg. Drill from 2090' to 2592' 02/10/00 (D5) MW: 9.6 VISC: 45 PV/YP: 16/15 APIWL: 6.0 TD/TVD: 4110/3986 (1518) DRLG 8.5" HOLE ~ 4530' SUPV:DEARL W. GLADDEN PJSM. Drilling from 2592' to 3305' Pump sweeps. Drilling from 3305' to 3676' Pump sweep, CBU, monitor well static. Wiper trip to shoe, hole good shape, no problems. Drilling from 3676' to 4110' RECEIVED APR O5 2000 A~aska Oil a Gas Cons. Commission Anchorage Date: 03/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/11/00 (D6) MW: 9.6 VISC: 45 PV/YP: 15/13 APIWL: 5.8 TD/TVD: 5316/5150 (1206) DRILLING W/ ROTARY ASSY @ 5320' SUPV:DEARL W. GLADDEN PJSM. Drilling from 4110' to 5007' Pump sweeps as needed. PJSM. Drilling from 5007' to 5316'. CBU, monitor well, static. Wiper trip to 3875', no problems, Pump sweep, circ & condition mud. Pull 5 stds, monitor well, static. Pump dry job. TOH t/shoe. Monitor well, static. 02/12/00 (D7) MW: 9.6 VISC: 43 PV/YP: 16/16 APIWL: 4.4 TD/TVD: 5680/5514 ( 364) CIRCU & CONDITION 8 CORE POINT 5735' SUPV:DEARL W. GLADDEN Service rig, PJSM. TIH w/ BHA #3. Break circ @ 2070' & 3750' Tight spots @ 4625', 4750'. Rotary drilling from 5316' to 5680' 02/13/00 (D8) MW: 9.6 VISC: 45 PV/YP: 16/14 APIWL: 4.4 TD/TVD: 5826/5659 ( 146) P/U CORE ASSY #2 SUPV:DEARL W. GLADDEN PJSM. Continue drilling from 5680' to 5726'. Well appears to have flow. Shut in well. Well static, CBU. Drilling from 5726' to 5735'. CBU. Wiper trip to 3506'. CBU. PSJM. P/U core assembly. Wash & ream from 5442' to 5522' TIH. Wash & ream from 5658'-5735'. CBU. Core from 5735' to 5826' CBU. 02/14/00 (D9) MW: 9.6 VISC: 46 PV/YP: 19/14 APIWL: 4.3 TD/TVD: 5894/5727 ( 68) DRLG 8.5 HLOE ~ 6001' SUPV:DEARL W. GLADDEN PJSM. L/D and process core. TIH with core assy #2. Break circ ~ 2070' and 4200'. CBU, gas to surface 14.6 units. Core 5826'-5894'. PJSM. CBU, well static. TOH. PJSM. L/D inner barrels and core assy. TIH with BHA #5. Break circ 2000' & 4100' 02/15/00 (D10) MW: 9.6 VISC: 44 PV/YP: 18/13 APIWL: 4.3 TD/TVD: 6300/6132 ( 406) WASH & REAM TIGHT HOLE @ 5938' SUPV:DEARL W. GLADDEN Make MAD pass 5701' to 5894' Drilling from 5894' to 6300' MD. Well taking a small amount of fluid while drilling. Breathing slightly. CBU. Wiper trip to 5360', no problem. Wash & ream from 6260' to 6300'. Pump sweep. CBU. Run #1 platform express. 02/16/00 (Dll) TD/TVD: 6300/6132 ( SUPV:DEARL W. GLADDEN RECEIVED APR 0 5 : o00 AJaska Oit & Gas Cons. Commission Anchorage MW: 9.7 VISC: 44 PV/YP: 16/11 0) TIH W/HO APIWL: 4.0 Had tight spot ~ 5700', could not log to TD. Logged from 5900' to 5700' Log would not go back down, sticking. TIH, tight ~ 5938' MD. Wash & ream from 5901' to 6300'. Circu hole clean. Pump dry job. Observe well. TOH. Tight spot ~ 3213'. Run #2, RFT, tools stopped ~ 3042'. Attempt to work tools down unsuccessful. Date: 03/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 02/17/00 (D12) MW: 9.6 VISC: 44 PV/YP: 18/13 APIWL: 4.3 TD/TVD: 6300/6132 ( 0) TOH - L/D BHA SUPV:DEARL W. GLADDEN Continue to test BOPs, had 2 valve failures. Replace kill line HCR with manual valve. Test manual valve installed on kill line 250/5000 psi, OK. TIH with HO & assy. Tight ~ 3057', Ream from 3057' to 3070'. TIH. Small tight spot @ 4936' Wash and ream 4920'-4969' Wash & ream 5849' to 5990'. Wash and ream to bttm ~ 6300'. Run #1, RFT. Tools stopped ~ 3045', made several attempts to work by, no success. P/U DSI log, tools stopped in the same place 3045'. Tried several configuration of tools and centrilizers. No success. 02/18/00 (D13) MW: 9.6 VISC: 44 PV/YP: 14/12 APIWL: 4.3 TD/TVD: 6300/6132 ( 0) ON STANDBY FOR WEATHER - ROAD BLOWN IN SUPV:DEARL W. GLADDEN PJSM. TIH TAG Bridge @ 3042' Wash & ream. Ream 3042' to 3112'. Pump dry job. Tag bridge ~ 3115'. TOH. PJSM. TIH w/5" DP & cement stinger, tight ~ 4030'. TIH to 4130', CBU. TIH to 6300' 02/19/00 (D14) MW: 9.6 VISC: 46 PV/YP: 17/15 APIWL: 4.4 TD/TVD: 6300/6132 ( 0) TOH L/D 5"DP SUPV:DEARL W. GLADDEN Circ & recip pipe @ 6300'. Rig on weather stand down ice road blown in. No outside work until weather improves. Phase 3 weather conditions. 02/20/00 (D15) MW: 0.0 VISC: 46 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6300/6132 ( 0) SECURE WELL - CLEAN PITS SUPV:DEARL W. GLADDEN Circ & recip pipe. PJSM. Lay bttm balanced plug. Pump cement. No cement to surface. CBU. Set retainer. Pump plug, down squeeze cement under retainer to P&A. SPot hi vis pill. Safety meeting. Spot top plug, pump cement. N/D BOPs. 02/21/00 (D16) MW: 0.0 VISC: 46 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6300/6132 ( 0) RIG ON STANDBY W/ FULL CREWS SUPV:DEARL W. GLADDEN N/U tbg adapter and master valve. Test adpt flange to 5000 psi, OK. Displace well to diesel to 111' (TOC plug). Set 2 way choke and test master valve flange to 3500 psi, OK. Pull 2 way choke, This is a temporary suspension of this well. PJSM. Clean pits. Release rig ~ 1700 hrs. 2/21/00. RECEIVED ,APR 0 ~aska Oil & Gas Cons. Commission Anchorage "1 ]2/0.3/~l~ MRT AJR PER~i . ,,:~- j:~ .:-,-.,-~~.1'~;- .. 1 COORDINATES SHO~ ARE ALASKA STATE PLANE ' '' ~ . {~~, ~'~ ZONE 4, NAD 27 . ~ : - :~.~) ' ' 2. ALL ELEVATIONS ARE B.P.M.S.L.. /; 1 ! HER[aY ~RTIFY.~ATI AU PR~[RLY MEL~A~R NOR~ ~2 REGIS~RED AND LICEN~D TO PRACTICE RECEIVED LAND SUR~NG LOCATED WITHIN PROTRACTED ALA~A AND ~AT ~lS P~T REPRE~NTS s~c. ~ T~. ~ U.~T .~.~. APR 0 5 ~000 LONG. = 15e' 25' e6.8e6" DIMENSI~S AND O~ER DETAILS ARE Y = 5,867,751.12 ~a~a~i&GasC~s. Commission CORRECT AS ~ FEaRUARY e3, 2eee. x = 447,689.e9 ~r~e ~.~..' ~...L.. ~' F.w.L. LOUNSBU~Y RIG PAD ELEV. '= 222.1'~~{/.~ A ASSOCIATES, INC. O.G. ELEV. = 218.6' ~'~-E~NEE~ P~NNE~ SURVEYO~ ~ MEL~A~R NOR~ 2 ARCO Alaska, Inc. co..uc o SubsiOiory of Atlontic Richfield Compony AS-BUILT LK6elD32~ 2/03/00 CEArM1XX-601D32~ 1 OF1 Arco Alaska Inc. North Slope Alaska Alaska State Plane 4 Meltwater North Meltwater North #2 Surveyed: 15 February, 2000 SURVEY REPORT 28 February, 2000 Your Ref: API-501032032100 Surface Coordinates: 5867751.12 N, 447689.09 E (70° 02' 57.8761" N, Kelly Bushing: 250.63ft above Mean Sea Level 150° 25' 06.8054" W) RECEIVED APR 05 ~000 -~a ~ & Gas Cons. Commiss~ DRILLING Survey Ref: svy9040 Sperry-Sun Drilling Services Survey Report for Meltwater North #2 Your Ref: API-501032032100 Surveyed: 15 February, 2000 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth fit) Vertical Depth (ft) 0.00 0.000 0.000 -250.63 0.00 165.43 0.280 26.230 -85.20 165.43 292.94 0.320 1.670 42.31 292.94 404.35 0.120 342.760 153.72 404.35 441.91 0.190 340.480 191.28 441.91 533.40 0.120 5.470 282.77 533.40 662.10 0.190 9.460 411.47 662.10 760.27 0.300 340.970 509.63 760.26 819.32 0.310 329.300 568.68 819.31 922.89 0.430 357.260 672.25 922.88 1013.98 0.390 341.260 763.34 1013.97 1106.39 0.460 345.210 855.75 1106.38 1198.56 0.440 346.620 947.91 1198.54 1291.38 0.520 332.370 1040.73 1291.36 1384.52 0.640 344.010 1133.87 1384.50 1486.71 0.650 350.410 1236.05 1486.68 1568.71 0.740 354.600 1318.04 1568.67 1661.05 0.760 343.490 1410.38 1661.01 1754.27 0.190 276.000 1503.59 1754.22 1847.27 0.190 243.060 1596.59 1847.22 1940.47 0.260 227.360 1689.79 1940.42 1999.91 0.380 246.360 1749.23 1999.86 2115.19 0.380 261.790 1864.51 2115.14 2146.77 0.290 247.960 1896.09 2146.72 2208.89 0.480 257.150 1958.21 2208.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 0.36 N 0.18 E 1.00 N 0.33 E 1.42 N 0.30 E 1.52 N 0.27 E 1.76 N 0.23 E 2.10 N 0.28 E 2.50 N 0.22 E 2.79 N 0.09 E 3.42 N 0.08 W 4.05 N 0.19 W 4,71 N 0.39 W 5.41 N 0.56 W 6.13 N 0.84 W 7.00 N 1.18 W 8.12 N 1.43 W 9.11 N 1.56 W 10.29 N 1.79 W 10.90 N 2.12 W 10.85 N 2.41 W 10.63 N 2.71 W 10.46 N 2.99 W 10.25 N 3.71 W 10.21 N 3.89 W 10.09 N 4.29 W 28 February, 2000 - 8:45 -2- 5867751.12 N 447689.09 E 5867751.48 N 447689.27 E 5867752.12 N 447689,42 E 5867752.54 N 447689.40 E 5867752.63 N 447689.37 E 5867752.87 N 447689.33 E 5867753.22 N 447689.38 E 5867753.62 N 447689.33 E 5867753.91 N 447689.20 E 5867754.54 N 447689.04 E 5867755.17 N 447688.93 E 5867755.83 N 447688.74 E 5867756.53 N 447688.56 E 5867757.25 N 447688.29 E 5867758.13 N 447687.96 E 5867759.25 N 447687.71E 5867760.24 N 447687.59 E 5867761.42 N 447687.37 E 5867762.03 N 447687.04 E 5867761.98 N 447686.75 E 5867761.77 N 447686.46 E 5867761.60 N 447686.18 E 5867761.40 N 447685.45 E 5867761.36 N 447685.27 E 5867761.24 N 447684.87 E RECEIVED Dogleg Rate (°ll00ft) 0.169 0.105 0.189 0.187 0.105 0.055 0.164 0.106 0.206 0.133 0.082 0.025 0.154 0.180 0.071 0.126 0.159 0.761 0.116 0.099 0.267 0.089 0.381 0.321 Alaska State Plane 4 Meltwater North Vertical Section (ft) Comment o.oo -o.o4 0.03 0.20 0,27 0.39 0.46 0.65 0.87 1.24 1.57 1.98 2.38 2.89 3.51 4.13 4.59 5.21 5.73 5.98 6.18 6,39 7.00 7.15 7.49 Continued.,. DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for Meltwater North #2 Your Ref: AP1-$01032032100 Surveyed: 15 February, 2000 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2240.05 0.630 267.750 1989.36 2239.99 2271.56 1.940 290.610 2020.87 2271.50 2301.70 2.790 288.720 2050.98 2301.61 2331.99 4.500 290.860 2081.21 2331.84 2425.39 7.770 292.720 2174.06 2424.69 2518.77 9.660 290.520 2266.36 2516.99 2612.26 11.560 288.580 2358.25 2608.88 2674.88 12.020 286.050 2419.55 2670.18 2734.61 13.720 282.990 2477.77 2728.40 2797.15 16.390 280.470 2538.16 2788.79 2888.75 19.930 282.280 262~19 2875.82 2951.98 20.800 282.490 2684.46 2935.09 3045.27 23.540 287.890 2770.86 3021.49 3106.65 24.750 294.410 2826.88 3077.51 3199.56 25.850 293.160 2910.87 3161.50 3292.08 27.320 291.130 2993.61 3244.24 3386.48 27.140 291.090 3077.55 3328.18 3477.73 26.830 291.580 3158.86 3409.49 3560.12 26.590 291.490 3232.46 3483.09 3664.12 26.510 291.530 3325.50 3576.13 3757.01 26.410 291.500 3408.66 3659.29 3852.31 26.490 288.980 3493.98 3744.61 3942.41 26.490 288.340 3574.62 3825.25 4038.21 25.130 287.870 3660.86 3911.49 4128.90 23.010 289.140 3743.66 3994.29 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10.06 N 4.59W 5867761.21N 447684.57 E 10.24 N 5.26W 5867761.39 N 447683.90 E 10.65 N 6.43W 5867761.82 N 447682.73 E 11.31 N 8.24W 5867762.49 N 447680.93 E 15.06 N 17.49W 5867766.30 N 447671.70 E 20.24 N 30.65W 5867771.57 N 447658.58 E 25.98 N 46.88W 5867777.42 N 447642.39 E 29.78 N 59.09W 5867781.30 N 447630.20 E 33.09 N 71.97W 5867784.70 N 447617.34 E 36.36 N 87.88W 5867788.08 N 447601.46 E 42.03 N 115.85W 5867793.95 N 447573.53 E 46.75 N 137.35W 5867798.81N 447552.07 E 56.06 N 171.26W 5867808.35 N 447518.22 E 65.14 N 194.63W 5867817.59 N 447494.92 E 81.14 N 230.96W 5867833.85 N 447458.69 E 96.73 N 269.31W 5867849.70 N 447420.45 E 112.29 N 309.61W 5867865.53 N 447380.26 E 127.35 N 348.17W 5867880.86 N 447341.80 E 140.94 N 382.62W 5867894.69 N 447307.45 E 157.99 N 425.87W 5867912.03 N 447264.31E 173.17 N 464.38W 5867927.47 N 447225.91E 187.85 N 504.19W 5867942.43 N 447186.20 E 200.71N 542.27W 5867955.54 N 447148.21E 213.67 N 581.91W 5867968.78 N 447108.66 E 225.39 N 616.99W 5867980.74 N 447073.66 E 28 February, 2000 - 8:45 -3- RECEIVED APR 0 5 2000 Dogleg Rate (°/100ft) 0.581 4.384 2.832 5.662 3.507 2.055 2.068 1.105 3.065 4.395 3.913 1.381 3.657 4.768 1.316 1.868 0.192 0.418 0.295 0.079 0.109 1.181 0.317 1.436 2.406 Alaska State Plane 4 Meltwater North Vertical Section (ft) Comment 7.76 8.45 9.69 11.62 21.59 35.73 52.94 65.72 78.95 95.02 123.24 145.05 180.10 205.16 244.78 286.15 329.34 370.73 407.75 454.22 495.60 538.04 578.21 619.90 656.87 Continued... AJa~a 0ii & Gas Cons. C0mmissh3n Anch0ra~e DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for Meltwater North #2 Your Ref: API-501032032100 Surveyed: 15 February, 2000 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4221.78 20.020 286.730 3830.06 4080.69 4311.19 17.210 286.440 3914.79 4165.42 4407.40 14.610 287.350 4007.31 4257.94 4502.29 14.030 286.320 4099.25 4349.88 4591.66 13.750 285.410 4186.00 4436.63 4684.24 13,600 286.430 4275.96 4526.59 4746.33 13.600 286.970 4336.31 4586.94 4840.04 11,780 287.270 4427.73 4678.36 4936.26 9.130 288.580 4522.34 4772.97 5026.52 7.040 287.480 4611.70 4862.33 5118.52 4.720 288.330 4703.21 4953.84 5211.91 4.260 291,670 4796.31 5046.94 5226.82 4.350 292,500 4811.18 5061.81 5308.32 4,050 294,800 4892.46 5143.09 5402.61 4,080 296.020 4986.51 5237.14 5496.51 4,050 297.650 5080.18 5330.81 5589.76 4.190 297.630 5173.19 5423.82 5680.87 4.120 297,450 5264.06 5514.69 5776.30 4.320 299.610 5359.23 5609.86 5895.11 4.300 300.440 5477.70 5728.33 5992.54 4.150 300,970 5574.87 5825.50 6084.89 4.110 301.420 5666.98 5917.61 6179.21 3.980 301,440 5761.06 6011.69 6231.05 3.930 304,550 5812.78 6063.41 6300.00 3,930 304,550 5881.57 6132.20 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 235.92 N 649,37W 244.08 N 676.72W 251.72 N 701.96W 258.52 N 724.42W 264.39 N 745.06W 270.39 N 766.10W 274.59 N 780.09W 280.64N 799.76W 285.99 N 816.38W 289.94 N 828.44W 292.82 N 837.42W 295.31N 844.29W 295.73 N 845.32W 298.12 N 850.79W 300.99 N 856.83W 303.99 N 862.77W 307.10 N 868.70W 310.15 N 874.56W 313.51N 880.72W 317.98 N 888.45W 321.64N 894.63W 325.09 N 900.32W 328.56 N 905.99W 330.50 N 908.99W 333.18 N 912.88W 28 February, 2000 - 8:45 -4- Alaska State Plane 4 Meltwater North Dogleg Rate (°/100ft) Vertical Section (ft) Comment 5867991.50 N 447041.35 E 3.356 5867999.84 N 447014.06 E 3,145 5868007.66 N 446988.88 E 2.715 5868014.61N 446966.46 E 0,668 5868020.62 N 446945.87 E 0.397 5868026.77 N 446924.86 E 0,307 5868031.06 N 446910.91 E 0.205 5868037.25 N 446891.27 E 1.943 5868042.71 N 446874.69 E 2,765 5868046.74 N 446862.66 E 2.322 5868049.68 N 446853.70 E 2.523 5868052.22 N 446846.85 E 0,566 5868052.65 N 446845.82 E 0.734 5868055.08 N 446840.36 E 0.422 5868057.99 N 446834.35 E 0.097 5868061.03 N 446828.43 E 0.127 5868064.18 N 446822.52 E 0,150 5868067.27 N 446816.68 E 0,078 5868070.67 N 446810.54 E 0.268 5868075.19 N 446802.84 E 0.055 5868078.90 N 446796.69 E 0,159 5868082.38 N 446791.03 E 0.056 5868085.89 N 446785.37 E 0.138 5868087.86 N 446782.39 E 0.425 5868090.56 N 446778.52 E 0.000 R.F. CEIVED 690,9O 719.39 745.72 769.15 790.55 812.38 826.95 847.51 864.96 877.64 887.06 894.37 895.49 901.44 908.10 914.70 921.35 927.89 934.83 943.63 950.68 957.21 963.73 967.21 971.79 Projected Survey APR 0 5 2000 ~ & ~ Cons. Comm~s~ Continued.., DrillQuest 1.05,04e Sperry-Sun Drilling Services Survey Report for Meltwater North #2 Your Ref: API-501032032100 Surveyed: 15 February, 2000 Arco Alaska Inc. North Slope Alaska Alaska State Plane 4 Meltwater North All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.037° (06-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 290.027° (True). Based upon Minimum Curvature type calculationsl at a Measured Depth of 6300.00ft., The Bottom Hole Displacement is 971.79ft., in the' Direction of 290.051° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 6300.00 6132.20 333.18 N 912.88 W Projected Survey RECEIVED APR 05 20OO Ata~a OiJ & 6as C.,m~. ~~ Continued... 28 February, 2000 - 8:45 - 5- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for Meltwater North #2 Your Ref: API-501032032100 Surveyed: 15 February, 2000 Arco Alaska Inc. North Slope Alaska Alaska State Plane 4 Meltwater North Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 6300.00 6132.20 Survey Tool Description MWD Magnetic RECEIVED · . APR 0,5 200o 28 February, 2000 - 8:45 - 6- DrillQuest 1.05.04e SAMPLE TRANSMITTAL TO: OIL & GAS CONSERVATION COMMISION 3001 PORCUPINE ANCHORAGE, AK. DATE: MARCH 23, 2000 AIR BILL: DROP-OFF AFT: ABV00-03-23-01 CHARGE CODE: OPERATOR: AAI NAME: MELTWATER #1 MELTWATER#2 MELTWATER#2 S.T. A SAMPLE TYPE: DRY DITCH SAMPLES SENT: MELTWATER NORTH #1 501032032600 MELTWATER NORTH #2 501032032100 MELTWATER NORTH #2 S.T. A 501032032101 APl NO: NUMBER OF BOXES: 60' TO 6,122' 120' TO 6,300' 2,070' TO 7,349' ~yBX. ~E~ l 6 BX.~F~ 7 BX. ~'$~ L,(~ ~ ~ SENT BY: D. L. PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: aogcc ARCO BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 ATTN: DAN PRZYWOJSKI ABV100 DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill No. 1991300 Well Name/No. MELTWATER NORTH 2 3/21/2002 Operator ARCO ALASKA INC APl No. 50-103-20321-00-00 MD 6300 TVD 6132 Completion Date 2/20/2000~/ Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log NO~ ~ Samples Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name T · ~/ PEX-AIT/MCFL c/L/ MUD FCORE CHIP DESCRI INAL WELL RPT ~'/ DGPJEWR-MD . .~'/PRELIM CORE ANAL /~ PEX-SS'I'VD CMR L PEX-DT/CNP ~ DIR SRVY ~/ DGR/EWR-TVD (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Interval Run OH / No Start Stop CH Received Dataset Number Comments 25 2 25 25 25 25 25 FINAL FINAL FINAL FINAL FINAL FINAL FINAL 1890 6032 OH 136 6300 OH O O 5733 5889 OH 136 6300 OH 100 6300 OH I 5760 OH 1890 6032 OH 5385 5941 OH 1890 6032 OH 0 6300 OH 100 6080 OH 3/14~2000 4~24~2000 3114~2000 3/21/2000 4~24~2000 5~4~2000 3121 ~2000 4~24~2000 311412000 311412000 3/14/2000 8~3~2000 3/21/2000 EPOCH 09453/1890-6032 09511b,'r'~'100_6247 EPOCH 2/6/00 THRU STARK 5730..1 SPERRY -. L . _ - Well Cores/Samples Information: Name Cuttings Core Chips Start 120 Interval Stop 63OO Sent Received Dataset Number Comments 1023 L,/ 1023 . . _ ADDITIONAL INFO/~ATION Well Cored? ,.~ N Chips Received? ~)N Analysis Received? ~/N Daily History Received? ~ N Formation Tops Receuived? ~ N DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Permit to Drill No. 1991300 Well Name/No. MELTWATER NORTH 2 Operator ARCO ALASKA INC MD 63OO TVD 6132 Completion Date 2/20/2000 Completion Status P&A Current Stares P&A APINo. 50-103-20321-00-00 UIC N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska March 16, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs Meltwater North #2, AK-MM-90232 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 Meltwater North 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20321-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20321-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia RECEIVED .'gJaska Oil & Gas Cons. Commissior, Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 16, 2000 Meltwater North #2, AK-MM-90232 1 LDWG formatted Disc with verification listing. API#: 50-103-20321-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING A~D RETURNING A COPY OF THE TRANSMITTAl' LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Alaska Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company 3/] 3/O0 Schlumberger NO. 121266 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Exploration (KRU) Color Well Job # Log Description Date BL Sepia Print CD MELTWATER NORTH #2 20084 PEX-AIT~,~ 000215 I 1 MELTWATER NORTH #2 20084 PEX-DEN/Ci~iL POROSITY 000215 I 1 MELTWATER NORTH #2 20084 CMR 000215 I 1 MELTWATER NORTH #2 20084 PEX-SSTVD 000215 I 1 MELTWATER NORTH #2 2008~' CMR TOTAL POROSITY (FILE 16 & 17) 000215 I each MELTWATER NORTH #2 20084 AIT/PEX/CMR ,~__~'~ 000215 1 ,! - / 126' !\/I: !h , MAR 1 4 2000 SIG . ~ DATE: Naska 0il & Gas C0n~. ~0mm~ssi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Customer Project ,Field Structure Wellhead Profile (ft) 0.000 165.430 292.940 404.350 441.910 533.400 662.100 760.270 819.320 922.890 1013.980 1106.390 1198.560 1291.380 1384.520 1486.710 1568.710 1661.050 1754.270 1847.270 1940.470 1999.910 2115.190 2146.770 2208.890 2240.050 2271.560 2301.700 2331.990 2425.390 2518.770 Incl. Deg. 0.000 0.280 0.320 0.120 0.190 0.120 0.190 0.300 0.310 0.430 0.390 0.460 0.440 0.520 0.640 0.650 0.740 0.760 0.190 0.190 0.260 0.380 0.380 0.290 0.480 0.630 1.940 2.790 4.500 7.770 9.660 Arco Alaska Inc. Alaska State Plane 4 North Slope Alaska Meltwater North Meltwater North #2 Meltwater North #2 Azim. Deg. Sub-Sea (a) 0.000 26.230 1.670 342.760 340.480 5.470 9.460 340.970 329.300 357.260 341.260 345.210 346.620 332.370 344.010 350.410 354.600 343.490 276.000 243.060 227.360 246.360 261.790 247.960 257.150 267.750 290.610 288.720 290.860 292.720 290.520 -250.630 -85.201 42.308 153.717 191.277 282.766 411.466 509.635 568.684 672.252 763.340 855.747 947.914 1040.731 1133.866 1236.050 1318.044 1410.376 1503.593 1596.592 1689.792 1749.231 1864.508 1896.088 1958.206 1989.365 2020.866 2050.980 2081.208 2174.061 2266.358 Creation Date Profile Type Your Ref Job Number Kelly Bushing Elev. Print Date TVD Local N Coord Local E Coord Global E Coord (it) (it) (ft) (ft) 0.000 0.363 0.998 1.420 1.517 1.755 2.100 2.503 2.787 3.416 4.051 4.707 5.409 6.129 7.004 8.124 9.110 10.290 10.899 10.846 10.632 10.462 10.254 10.209 10.092 10.057 10.238 10.653 11.312 15.057 20.241 0.000 165.429 292.938 404.347 441.907 533.396 662.096 760.265 819.314 922.882 1013.970 1106.377 1198.544 1291.361 1384.496 1486.680 1568.674 1661.006 1754.223 1847.222 1940.422 1999.861 2115.138 2146.718 2208.836 2239.995 2271.496 2301.610 2331.838 2424.691 2516.988 0.000 447689.090 0.179 447689.271 0.327 447689.424 0.301 447689.401 0.269 447689.369 0.227 447689.329 0.275 447689.380 0.218 447689.325 0.086 447689.195 -0.076 447689.038 -0.191 447688.926 -0.387 447688.735 -0.564 447688.564 -0.841 447688.291 -1.181 447687.957 -1.434 447687.711 -1.562 447687.591 -1.792 447687.369 -2.121 447687.044 -2.412 447686.752 -2.705 447686.458 -2.985 447686.177 -3.714 447685.447 -3.892 447685.269 -4.291 447684.868 -4.589 447684.570 -5.262 447683.899 -6.434 447682.729 -8.243 447680.925 -17.493 447671.701 -30.654 447658.576 2/28/2000 i el ci' I '~o O API-501032032100 AKMM90232 Global N Coord Dogleg Vertical Section (It) (°/lOOfl) (ft) 5867751.120 0.000 0.000 5867751.481 0.169 -0.040 5867752.116 0.105 0.030 5867752.538 0.189 0.200 5867752.635 0.187 0.270 5867752.873 0.105 0.390 5867753.218 0.055 0.460 5867753.622 0.164 0.650 5867753.906 0.106 0.870 5867754.536 0.206 1.240 5867755.172 0.133 1.570 5867755.830 0.082 1.980 5867756.533 0.025 2.380 5867757.255 0.154 2.890 5867758.132 0.180 3.510 5867759.254 0.071 4.130 5867760.240 0.126 4.590 5867761.423 0.159 5.210 5867762.034 0.761 5.730 5867761.982 0.116 5.980 5867761.771 0.099 6.180 5867761.602 0.267 6.390 5867761.399 0.089 7.000 5867761.356 0.381 7.150 5867761.242 0.321 7.490 5867761.208 0.581 7.760 5867761.393 4.384 8.450 5867761.816 2.832 9.690 5867762.489 5.662 11.620 5867766.296 3.507 21.590 5867771.571 2.055 35.730 2612.260 11.560 2674.880 12.020 2734.610 13.720 2797.150 16.390 2888.750 19.930 2951.980 20.800 3045.270 23.540 3106.650 24.750 3199.560 25.850 3292.080 27.320 3386.480 27.140 3477.730 26.830 3560.120 26.590 3664.120 26.510 3757.010 26.410 3852.310 26.490 3942.410 26.490 4038.210 25.130 4128.900 23.010 4221.780 20.020 4311.190 17.210 4407.400 14.610 4502.290 14.030 4591.660 13.750 4684.240 13.600 4746.330 13.600 4840.040 11.780 4936.260 9.130 5026.520 7.040 5118.520 4.720 5211.910 4.260 5226.820 4.350 5308.320 4.050 5402.610 4.080 5496.510 4.050 5589.760 4.190 5680.870 4.120 5776.300 4.320 5895.110 4.300 5992.540 4.150 6084.890 4.110 288.580 2358.246 2608.876 286.050 2419.545 2670.175 282.990 2477.773 2728.403 280.470 2538.162 2788.792 282.280 2625.186 2875.816 282.490 2684.463 2935.093 287.890 2770.857 3021.487 294.410 2826.876 3077.506 293.160 2910.874 3161.504 291.130 2993.611 3244.241 291.090 3077.550 3328.180 291.580 3158.865 3409.495 291.490 3232.463 3483.093 291.530 3325.496 3576.126 291.500 3408.655 3659.285 288.980 3493.982 3744.612 288.340 3574.623 3825.253 287.870 3660.864 3911.494 289.140 3743.665 3994.295 286.730 3830.065 4080.695 286.440 3914.789 4165.419 287.350 4007.305 4257.935 286.320 4099.247 4349.877 285.410 4186.004 4436.634 286.430 4275.959 4526.589 286.970 4336.308 4586.938 287.270 4427.725 4678.355 288.580 4522.340 4772.970 287.480 4611.698 4862.328 288.330 4703.207 4953.837 291.670 4796.311 5046.941 292.500 4811.179 5061.809 294.800 4892.460 5143.090 296.020 4986.513 5237.143 297.650 5080.176 5330.806 297.630 5173.185 5423.815 297.450 5264.056 5514.686 299.610 5359.227 5609.857 300.440 5477.701 5728.331 300.970 5574.866 5825.496 301.420 5666.977 5917.607 25.976 29.778 33.090 36.361 42.032 46.752 56.060 65.137 81.142 96.729 112.286 127.349 140.943 157.987 173.167 187.848 200.706 213.671 225.393 235.924 244.075 251.723 258.524 264.390 270.393 274.588 280.644 285.993 289.937 292.821 295.310 295.731 298.121 300.989 303.994 307.102 310.154 313.510 317.978 321.642 325.087 -46.881 -59.095 -71.975 -87.881 -115.854 -137.345 -171.256 -194.626 -230.960 -269.312 -309.607 -348.175 -382.622 -425.870 -464.375 -504.195 -542.270 -581.912 -616.990 -649.373 -676.721 -701.959 -724.421 -745.056 -766.103 -780.088 -799.761 -816.379 -828.444 -837.416 -844.287 -845.324 -850.792 -856.829 -862.769 -868.704 -874.557 -880.724 -888.454 -894.626 -900.316 447642.388 447630.201 447617.344 447601.460 447573.528 447552.069 447518.223 447494.916 447458.692 447420.449 447380.261 447341.798 447307.445 447264.315 447225.915 447186.197 447148.211 447108.659 447073.663 447041.353 447014.061 446988.876 446966.462 446945.867 446924.861 446910.906 446891.275 446874.694 446862.656 446853.704 446846.851 446845.816 446840.365 446834.348 446828.429 446822.516 446816.683 446810.540 4468O2.840 446796.693 446791.028 5867777.417 5867781.303 5867784.704 5867788.084 5867793.947 5867798.814 5867808.355 5867817.592 5867833.846 5867849.696 5867865.530 5867880.857 5867894.687 5867912.028 5867927.471 5867942.425 5867955.545 5867968.782 5867980.745 5867991.498 5867999.836 5868007.657 5868014.612 5868020.620 5868026.767 5868031.058 5868037.249 5868042.712 5868046.739 5868049.685 5868052.221 5868052.649 5868055.076 5868057.986 5868061.031 5868064.180 5868067.272 5868070.670 5868075.191 5868078.898 5868082.382 2.068 1.105 3.065 4.395 3.913 1.381 3.657 4.768 1.316 1.868 0.192 0.418 0.295 0.079 0.109 1.181 0.317 1.436 2.406 3.356 3.145 2.715 0.668 0.397 0.307 0.205 1.943 2.765 2.322 2.523 0.566 0.734 0.422 0.097 0.127 0.150 0.078 0.268 0.055 0.159 0.056 52.940 65.720 78.950 95.020 123.240 145.050 180.100 205.160 244.780 286.150 329.340 370.730 407.750 454.220 495.600 538.040 578.210 619.900 656.870 690.900 719.390 745.720 769.150 790.550 812.380 826.950 847.510 864.960 877.640 887.060 894.370 895.490 901.440 908.100 914.700 921.350 927.890 934.830 943.630 950.680 957.210 6179.210 6231.050 6300.000 3.980 3.930 3.930 301.440 304.550 304.550 5761.062 5812.778 5881.566 6011.692 6063.408 6132.196 328.557 330.502 333.183 -905.993 -908.991 -912.883 446785.375 446782.39O 446778.516 5868085.890 5868087.856 5868090.563 0.138 0.425 0.000 963.730 967.210 971.790 LEAK-OFF TEST 800 psi 700 psi 600 psi "' 500 psi ~. 400 psi i ~ 300 psi 200 psi 100 psi 0 psi 0.0 min 2.0 min 4.0 min 6.0 min 8.0 min 10.0 min 12.0 min SHUT IN TIME CASING TEST and FORMATION INTEGRITYTEST Well Name: MWN#2 Date: 2/9/00 SuPervisor: Dearl W. Gladden Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 53.5~ L-80 BTC Casing Setting Depth: 2,059' TMD 2,058' TVD Hole Depth: 2,090' TMD 2,089' TVD Mud Weight: 9.6 ppg Length of Open Hole: 31' EMW = Leak-off Press. ~- Mud Weight 700 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,o89' EMW = 16.0 ppg Pump output = 0.1010 bps Fluid Pumped = 0.8 bbl Fluid Returned 0.0 2,800 psi 2,700 psi 2,600 psl 2,500 psi 2,400 psi 2,300 psi i 2,200 psi 2,100 psi · 2,000 psi 1,900 psi 1,800 psi - 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 pSI 1,100 psi 1,000 psi 900 psi 800 psi 700 pSI !' 600 psi -- LEAK-OFF TEST 500 psi 400 psi ~ CASING TEST ~oo psi LOT SHUT IN TIME 200 psl ~oo ps~ ~ CASING TEST SHUT IN TIME o ps~ -- rIME LINE 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 50 32 541 36 58 40 42 44 46 48 50 5t 51~ st/( s'~ stl¢ sl~ sr.X stl( 51;~ st~ sti( st1( St.l¢ sl:~ stl( stl( Stk Sl;k S'~ Stl~ St~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................ ] i 6stks i 000psi = 8stks i 700 psi 1 ............... ~ ............... i ................. ' CASING TEST DATA MINUTES FOR CSG 'lEST STROKES PRESSURE ............... l .... .... i 6stks i 675 psi ............... ~ ................ f ................. i 8stks ! 850psi i ! ............... ............... ............... i 18stks i 2,275 psi ............... l ................ t ................. I I ................ + ............... t ................. ~ ............ --f- .............. I ................. ," ............... ~ ................ t ................. ! i SHUT IN TIME ! SHUT IN PRESSURE I' ............... i ................ r ................ ~ i 0.0min i i 2,550 psi i ................ ) 2.0min i j 2,545 psi ) I ' }- ............... t ................ I' ................. SHUT IN TIME i SHUT IN PRESSURE i 3.0min i i 2,540psi j ............... i----76'6';;; .... ................ FqT~'Ji~i--T ............... i'"'~,~iFg, T'" F--Fj;~",;;i~"-j ................ J"~-;~'~'~;~-~'-i 2.0rain ~ A 625 psi i 6.0min ~ [ 2,535 psi i 3.0min ~ i 600 psi 4.0 min i i 600 psi 5.0min i i 590 psi i. ............... .~- ............... ~ ................. -4 ~__~:.o..~j_.__I ............... j_._._s~.o_._..;L~ 7.0min ! [ 575 psi , ............... ,~ 9.Omin j j 570 psi ............... · i" ............... -i .................'~ 10.0rain i i 545 psi ~. ............... .~_ ............... ,a .................,.~ 7.0min = i 2,530 psi i 8.o mini [ 2,530 psi i 9.0 rain i i 2,525 psi i ................ ~ ................ ; ................. ~ 10.0 minl i 2,525psi l ............... I ................ ; ................. I 15.0 min i i 2,525 psi i ................ 25.0 minl i 2,525 psi! ............... ~ ................ ~ ................. t 30.0 mini i 2,525 psi ! NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST 2,555 psi 2,550 psi 2,545 psi 2,540 psi 2,535 psi 2,530 psi 2,525 psi 2,520 psi 0.0 min 5.0 min 10.0 min 15.0 min 20.0 min 25.0 min 30.0 min 35.0 min SHUT IN TIME Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation Commissio~ 3001 Porcupine Drive Anchorage, Alaska 99501 Date: 2~Fe~0 Well Name: Arco Alaska Inc. Meltwater North #2 · Number of Samples: 157 Contact: Mark Myers Description of Material: Core Chip Samples Depths: 5730-5888 Sent By: Received By: Core Laboratories RECEIVE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon Suspend X Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging __ Time extension Stimulate Change approved program m Pull tubing_ Variance m P~-rforate __ -- Other _ 2. Name of Operator 5. l-ype of Well: 6. Datum elevation (DF or KB) Development __ ARCO Alaska, Inc. Exploratory X 28' RKB Pad 222' feet 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Exploration 4. Location of well at surface 8. Well number 2099' FNL, 454' FWL, Sec. 16, T8N, R7E, UM .'Meltwater North #2 At top of productive interval 9. Permit number 1789' FNL, 419' FEL, Sec. 17, T8N, R7E, UM 199-130 At effective depth 10. APl number 50-103-20321-00 At total depth 11. Field/Pool 1766' FNL, 458' FEL, Sec. 17, T8N, R7E, UM Tarn Exploration 12. Present well condition summary Total Depth: measured 6300 feet Plugs (measured) (See attached proposal) (approx) true vertical 6132 feet Effective depth: measured 6300 feet Junk (measured) (approx) true vertical 6132 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 77' 16" 200 cf 105' 105' Surface 2031' 9.625" 392 sx AS III LW & 2059' 2059' Intermediate 230 sx Class G Production Liner Perforation depth: measured N/A N/A RECEIVED N/A Tubing (size, grade, and measured depth) [~';l~'B ~2, ~000 0 ~ / G//I~,[ NIA Packers and SSSV (type and measured depth) NIA 13. Attachments Description summary of proposal X Detailed operation program BOP sketch Contact Paul Mazzolini at 263-4603 or Tom Brassfield @ 265-6377with any questions. LOT test, sua~ cement details and cas~ detail sheets 14. Estimated date for commencing operation 15. Status of well classification as: 2/18/00,, Oil Gas Suspended X 16. If proposal was verbally approved--,,,,-- .~. ~ta~,~ I Name of approver Tom Maunder 2118100 Date approved I Service 17. I he ~by certify that the foregoing is true and correct to the best of my knoWledge. , Title Exploration/Tarn Team Leader .Date ,~ ~ ~,~ ~-~ Signed ~(AR"COMMISSION USE ONLY '"- - Conditions of approval: Notify Commission so representative may witness IApproval N Plug integrity .~ BOP Test Location clearance ~_..t . I ~'~' Mechanical In[egrity Test _ Subsequen-['form require 10- t,4,1;::>~"~- oO~'~ Approved by the order of the Commission R~b~_.rl'_ N Christenson . .~ missioner Date ' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1. . Meltwater North #2 Temporary Suspension CONFIDENTIAL ;v. 2/18~00 REASON for temporary suspension' ARCO and Partners would like to preserve the option of sidetracking the MWN #2 wellbore to a different bottom hole location this winter season after drilling the Meltwater North #1 well. This would help to delineate the Bermuda formation and provide additional reservoir information for future development. The MWN #2 wellbore ?ill b_e plugged and abandoned this year before the ice roads/pa~l's ~o-out and tundra -travel is revoked. Notif~ AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 3. Mobilize and rig up D/S for well suspension operation. . . , . Spot a balanced cement plug #1from TD @ 63000'MD to 5500'MD (approx. 200' above top of the Bermuda interval @5711' MD). This plug can be laid in two sections as needed. Total interval is approx. 800' in length. Will not need to tag the plug, as we are setting the plug from TD of the well. By the down squeeze method through a retainer set 50' minimum above the shoe (or approx. 2009') pump cement plug #2 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 150' below (50' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Weight test retainer before pumping cement. Not required to tag the plug. Leave 9.7 ppg mud above and below the plug.(Weight of mud needed to TD the hole) Optional: we might elect to spot a balanced plug per AOGCC regulations across the casing shoe set at 2059' MD which could also act as the kick-off plug if we elect to sidetrack. Spot a 200' surface balanced cement plug from 300' MD to 100' MD per the AOGCC regulations 20 AAC 25.110 (d). Run 90' of 3-1/2" tubing below the tubing hanger and land in the tubing head. Nipple up tubing head adapter and with master valve. Move rig off location. 8. A Sundry would be filled at a later date to permanently P&A the wellbore per AOGCC regulations. TJB 2/18/00 File:MWN #2 ~a~Drr~~n g i nee r' Blair Wondzell ~ TJB 2/18/00 RECEIVED FEB 22 2000 Ala aOil&Gas Cons. n MWN #2 Ex Revised 2/18/00 by TJB WELLBORE SCHEMATIC Temporary Suspension CONFIDENTIAL 16" Conductor ~_ 200' Cmt Plu.q L~, 85 sacks Arctic Set 1 300' MD to 100' MD Slurry Volume Slurry Weight Slurry Yield Thickening Time Port Collar ~1000' MD 132.6 cu-fl 15.7 ppg 0.93 cu-ft/sk 2.2 - 2.8 hours 12-1/4" Hole 9-5/8" Surface Cas_i~.q ~ ~ 2059' MD Cemented with 392 sx AS3 Lite, 230 sx G 8-1/2" Hole OH Caliper Io,q used to Calculate Cement Volumes 9.7 ppg Mud between plugs TD at 6300' MD 200' Cmt Plu.q @ 1959'-2159' MD ,~-(50'above and 150' below Ret. 2009') 800' Cmt Pluq @ -~-6300'-5500' MD Set in 2 Plugs 100 sacks Class G cement + 0.2% D46 AntiFoam + 0.3% D65 Dispersant + 0.5% S1 CaCI2 Accel.+ 0.4% D167 20 Sacks above retainer (rounded from 17) 80 sacks below retainer (rounded from 79) Slurry Volume (11.5" OH on Caliper log) 112 cu-ft Slurry Weight Slurry Yield Thickening Time 70 degF 15.8 ppg 1.16 cu-ft/sk 3.5 - 4.5 hours (tested 4:38) RECEIVED 22 2000 Alaaka Oil & Gas Cons. commiae 305 sacks Class G cement + 0.2% D46 AntiFoam + 0.27% D65 Dispersant + 0.19 % D800 Retarder + 0.25% D167 FLAC Slurry Volume based on 9" hole 353 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.16 cu-ft/sk 4.0 - 4.5 hours Thickening Time, 130 degF BHCT (tested 4:04) Tom Maunder <tom_maunder~admin.state.ak.us> on 0211812000 12:57:52 PM To: A©GCC North Sope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Tom J Brassfield/AAI/ARCO, Paul Mazzolini/AAI/ARCO cc: Subject: Re: Meltwater North #2 Temporary Suspension Tom and Paul, Looks good to me as well. You have approval to abandon as proposed below and in the referenced drawing. I will forward a copy of the drawing to the Inspector on the North Slope. Please notify him of the timing so he can witness 1 or all of the plugs. Thanks. If you need to get hold of me over the weekend home # is 345-0850 or cell phone 244-1567. Tom Maunder Blair Wondzell wrote: > Tom B, > This program looks ok to me, but I will leave it to Tom M. to give the verbal approval since I leave > on vacation tomarrow morning and he will be tracking the operation. > Good Luck, Blair > > Tom J Brassfield wrote: > > > Blair, here are the revised procedures for the temporary suspension of the MWN > > #2 wellbore. Changes include: > > Added 200' surface plug per AOGCC regulations > > Bottom plug will be 800' long or 200' above top of the Bermuda. > > Will hang-off 90' of tubing below the wellhead to assist with final P&A if > > rig does not return. > > > > Would like to receive a verbal to proceed ahead with the temporary suspension > > today with plans to send over the Sundry on Tuesday (Monday is a holiday). Any > > questions or comments, please call me at 265-6377. Wil fax a copy of the revised > > VISIO drawing to your office. > > Thanks, Tom > > > > (See attached file: MWN2 Agency Temp Susp by TJB 2 18 00.rtf)(See attached file: > > MWN2 Temp Susp Vi by TJB 2 18 00.vsd) > > > > ........................................................................ > > Name: MWN2 Agency Temp Susp by TJB 2 18 00.rtf > > MWN2 Agency Temp Susp by TJB 2 18 00.rtf Type: Rich Text Format ( appl icat ion/rt f ) RECEIVED Encoding: base64 Description: Rich Text Format > > > > > > > 00 .vsd Ala aOil & Gas C ns. Com Name: MWN2 Temp Susp Vi by TJB 2 18 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ DATE' February 20, 2000 Chairman THRU: Blair Wondzell, ,~-~'~.,~.~__ ,:~ P. I. Supervisor ~-~- FROM' John Crisp, SUBJECT: Petroleum Inspector Surface Cement Plug Meltwater North #2 AAI Exploratory Well PTD 199-130 February 20. 2000: I witnessed the cementing of the surface cement plug on AAI's Meltwater North #2 Exploratory Well. Work performed by Doyon Rig 141. I witnessed RIH w/3 ¼" tubing to a depth of 296'. A balanced 15.8 ppg. Arctic Set 1 cement plug was pumped in quantity to cover 200' of the inside diameter of the surface casing. 3 % "tubing was POOH to WOC for 4 hours. After 4 hour setting time I witnessed RIH w/3 %" tubing to a solid cement plug @ 111'. SUMMARY:. I witnessed the surface plug on AAI's Meltwater North #2 for temporary suspension. Tested surface plug w/tubing weight for integrity. Attachments: none cc; CONFIDENTIAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman THRU: DATE: Blair Wondzell, P. I. Supervisor ~.~c, FROM: John Crisp, SUBJECT: Petroleum Inspector February 20, 2000 Surface Casing Shoe Plug Meltwater North #2 AAI Exploratory Well PTD 199-130 February 207 2000: I traveled to Arco Alaska Inc. Meltwater North #2 Exploratory well to witness the placement of the cement retainer & the cementing of the uncased to cased portions of the wellbore on Meltwater North #2. Doyon Rig 141 is performing work on this well. I witnessed the Baker N-1 cement retainer set 50' from the surface casing shoe. A volume of cement was pumped thru the cement retainer that was sufficient to extend from the retainer to 102' below the surface casing shoe. I witnessed a volume of cement placed from top of retainer to 52' above the retainer. The surface casing & the cement retainer were then tested to 1500 psi. for 30 minutes. SUMMARY: I witnessed the RIH & setting of cement retainer effectively segregating uncased & cased portions of the wellbore on Meltwater North #2. I witnessed the volumes of cement pumped & the placement of cement for this segregation plug. Tested segregation plug to 1500 psi. for 30 minutes. Attachments: none cc; CONFIDENTIAL Csg. Shoe Cmt.doc MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ Chairman Blair Wondzell, 4~~ P. I. Supervisor ,2..~0too FROM: John Crisp~~ ~ SUBJECT: Petroleum ~spector DATE: February 17, 2000 Bop Test Doyon 141 Meltwater North #2 PTD 199-130 February 177 2000: I traveled to Arco Alaska Inc. Meltwater North #2 Exploratory well being drilled by Doyon Rig 141 & witnessed the weekly BOP test on this well. The test lasted 6 hours with 3 failures. The visual alarm for the Iow level H2S gas detector failed to function properly, this was repaired immediately. Hydraulic valve on kill line leaked & was replaced. The #1 valve on the choke manifold would not hold test pressure & was replaced. The AOGCC BOPE test report is attached for reference. SUMMARY: I witnessed the weekly BOP test on Doyon 141 drilling Meltwater North #2 Exploratory well for AAI. Tested BOPs on Doyon 141.3 failures witnessed. Test time 6 hours. Attachments: BOP Doyon 141 2-17-00jc cc;. CONFIDENTIAL BOP Doyon 141 2-17-00jc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Rig No, Operator: Arco Alaska Inc. Well Name: Meltwater North #2 Casing Size: 9 5/8" Set @ 2059' Test: Initial Weekly x Other '/4'/ PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA DATE: 2/'/7/00 '/99'/30 Rig Ph.# 263-3'/'/0 Dearl Gladden Pat Krupa '/6 T. 8N R. 7E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan, Test Press. P/F 25O/25OO P '/ 250/5,000 P I 250/5,000 P '/ 250/5,000 P 1 250/5,000 P 2 250/5,000 P/F 1 25O/5, OOO P MUD SYSTEM: Visual Alarm Trip Tank OK YES Pit Level Indicators OK YES Flow Indicator OK YES Math Gas Detector OK Tested H2S Gas Detector OK Tested FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan Pressure P/F '/ 25O/5, OOO P '/ 250/5,000 P 1 250/5, 000 P I 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F '/4 250/5, 000 P 28 250/5,000 P I YES Functioned Functioned YES ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,'/00 I P '/,900 P minutes 32 3 minutes 8 X Remote: 5 Btls. @ 2250 ave. Psig. sec. sec. X ;', ..... ~ · .' .. TEST RESULTS .... Number of Failures: //3./ ,Test Time: 6.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within~ all repaired days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Low level H2S visual a/arm was not functioning properly, minor repair performed immediately. #1 valve in choke manifold would not hold test pressure, repaired immediately. ~ydraulic actuated valve on kill line leaked, replaced immediately, lAII repairs tested OK. Rig & Location in good condition. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File Inspe c- ~t-~ L (Rev.~2/~4) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp 141 2-17-00jc MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~) DATE: February 9, 2000 Chairman THRU: Blair Wondzell SUBJECT: P. I. Supervisor FROM: John H Spaulding~,~--~ Petroleum InspectOr Leak Off Test ARCO Meltwater N. 2 Wildcat well PTD: 199-130 February 097 2000' I traveled this date to ARCO's wildcat well Meltwater North #2 to witness the leak off test on the surface casing. The leak off test report form is attached for reference. As noted on the LOT charts, the casing test and LOT tracked quite well. SUMMARY: I witnessed the Leak Off Test on ARCO's Meltwater North #2. Attachment: LOT Charts CONFIDENTIAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,'~' DATE: Chairman February 9, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor ~[c~ ('~ FROM: John H Spaulding~ Petroleum InspeCt'or BOPE Test ARCO / Doyon 141 Meltwater N. #2 Wildcat PTD: 199-130 February 9, 2000: I traveled to ARCO's Meltwater North # 2 wildcat well to witness the BOPE test on Doyon rig 141. The AOGCC BOPE Test report form is attached for reference. As noted on the report form 1 failure was observed when the top set of 3.5" pipe rams failed. These rams were replaced with variable bore rams and tested ok. Testing was completed with no further delays. SUMMARY: I witnessed the BOPE test on; Doyon 141, 20 components, 1 failure, 8hrs. Attachment: bope doyon 141 2-9-00 js CONFIDENTIAL t STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: ARCO Well Name: Meltwater North #2 Casing Size: 9 5/8" Set @ Test: Initial Weekly Rig No. 141 PTD # 199-130 Rep.: Rig Rep.: 2,059 Location: Sec. 16 T. Other DATE: 2/9/00 Rig Ph.# 1-907-263-3110 Dead Gladden Pat Krupa 8N R. 7E Meridian MISC. INSPECTIONS: Location Gen.: ok Well Sign Housekeeping: ok (Gen) Drl. Rig PTD On Location yes Hazard Sec. Standing Order Posted yes .. yes ok yes TEST DATA FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F I 250/5,000 P 1 250/5,000 P I 25O/5, OOO P 1 25O/5, OOO P BOP STACK: Quan. Test Press. P/F Annular Preventer 1 250/2500 P Pipe Rams 1 250/5,000 P Lower Pipe Rams 1 250/5,000 P Blind Rams 1 250/5,000 P Choke Ln. Valves 1 250/5,000 P HCR Valves 2 250/5,000 P Kill Line Valves I 250/5,000 P ~ Check Valve NA 250/5,000 MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual Alarm CHOKE MANIFOLD: No. Valves 14 No. Flanges 33 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 25O/5, OOO P 250/5,000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: M aster: Nitgn. Btl's: 5 @ 2100 avg Umiat 3,300 P 1,800 P minutes 31 sec. minutes 13 sec. X Remote: X Psig. · /" ....... "" ..... i TESTRE~ULTS~'- .... [8.0 ,,l%urs. Num'l~er of valves tested 20 RePair or Replacement of'Failed Number of Failures: '/ ,Test Time: L'da sY~. Notify the Inspector and follow with Written or Faxed verification to Equipment will be made within the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Upper Pipe rams failed and were changed to variable bore rams and tested ok. The mud system and ALL gas detectors were inspected 2 days earlier on the diverter function test. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~ DATE: Chairman February 6, 2000 THRU: Blair Wondzell,~-~~'/-°° SUBJECT: P. I. Supervisor FROM: John H Spauldin~f~'~ Petroleum Inspeq~6r Diverter Function Test ARCO / Doyon 141 Meltwater N # 2 Wildcat PTD 199-130 February 6, 2000: I traveled to ARCO's Meltwater North # 2 wildcat well to witness the diverter function test on Doyon Rig 141. The AOGCC Diverter Function test report form is attached for reference. No failure were noted and all gas detectors were function tested at this time. SUMMARY: I witnessed the Diverter Function test on; Doyon 141, 2 hour test time Attachment: diverter doyon 141 2-6-00 js CONFIDENTIAL Drlg Contractor: Operator: Well Name: Location: Sec. ~' STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COM '~o$1ON Diverter Systems Inspection Report Doyon ARCO Meltwater N. //2 16 T. 8N R. Operation: Rig No. Development 141 PTD D ate: Exploratory: 1 99-130 Rig Ph. # Mike Whitely Oper. Rep.: Rig Rep.: 7E 2~6~00 X 263-3110 Jim Willingham Merdian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: na (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: yes ok na 20 in. yes yes 16f in. 75 ' ft. na yes yes na ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 31 50 1800 min. 39 3 min. 43 5@2150avg. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Light Alarm ok ok ok ok ok ok Light Alarm ok ok ok ok GAS DETECTORS: Methane Hydrogen Sulfide: psig psig sec. sec. psig DIvERTER. SCHEMATIC Pipe Shed 76" vent line 5' from rig IPits & Motors Wind Direction Shop Camp Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c- Oper/Rep c- Database c - Trip Rpt File c- Inspector AOGCC REP.: OPERATOR REP.: Diverter Doyon 141 2-6-00 js John H. Spaulding Mike Whitely DVTRINSP.XLT (REV. 1/94) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPlMISSION Paul Mazzolini Exploration/Tam Drilling Tcam Lcadcr ARCO Alaska. Inc. P O Box 100360 Anchoragc. AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-75~,2 ae~ ExploratoD: Meltwater North #2 ARCO Alaska. Inc. Permit No:_ .199-13() ,qg~, d<-'4 ' ,q(A..T, . /~' /_)cz:, ;7-6~.'-_~'r'"--- _ _.' . /..~-' :-~ ~ /..~L~ Sur. Loc. '.?,j30'T4-FNL,~FWL, SEC. 16, T08N, R07E, UM Btlnhole Loc. 1788'FNL, 408'FEL. SEC. 17, T08N. R07E. UM Dear Mr. Mazzolini' Encloscd is the approvcd application for permit to drill the above rcfercnccd well. Thc permit to drill does not exempt you from obtaining additional pcrmits rcquircd bv law from other govcrnmcntal agcncics, and docs not authorizc conducting drilling operations until all othcr rcquircd pcrmitting dctcrnfinations arc madc. A weekly status rcport is required from the time thc wcll is spudded until it is suspended or plugged and abandoned. The report should bc a gcncralizcd synopsis of thc week's activitics and is cxclusivclv for thc Commission's internal usc. Annular disposal of drilling wastes will not be approvcd for this well until sufficient data is submitted to ensure that thc rcquircmcnts of 20 AAC 25.080 arc met. Annular disposal of drilling waste will bc contingcnt on obtaining a well cemented surface casing confirmed bra valid Formation intcgrity Test (FIT). Cementing records. FIT data, and anv CQLs nmst be submittcd to thc Commission on form 10- 403 prior to thc start of disposal operations. All d~ ditch sample scts submittcd to thc Commission must bc in no greater than 30' sample intervals from bclow thc permafrost or from whcrc samplcs arc first caught and 10' samplc intcrvals through target zones· Blew'out prcvcntion equipment (BOPE) must be tested in accordancc with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test pcrformcd bcfore drilling below thc surfacc casing shoc must be given so that a representative of the Commission may witness the test. Notice mav be given bv contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. Robcrt N. Christcnson, P.E. Chair BY ORDER OF TH, E~_OMMISSION DATED this[ ~'~- day of January, 2000 dl f' l:,ncl osurcs CC: l)cpanmcnt of Fish &(.}ame. l.{abita! Section w/o encl. Department o1" l;;m.'ironmental Conservation w.o encl. ARCO Alaska, Inc. Post Office~,.~ .100360 Anchorage, Alaska 99510-0360 January 7, 2000 Steve Davies, Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Meltwater North #2 Permit To Drill Dear Steve: This letter is in response to your request for additional clarification regarding pore pressure predictions for the proposed ARCO Meltwater North Number 2 well. Per our telephone conversations 1/5/00 regarding the pore pressure prediction plots from the seismic data for Meltwater North #2, we have corrected the depth scale to match the text in the original report. We have also marked base of permafrost on the depth seismic cross section. The colored anomaly which occurs directly underneath 850 feet below MSL is believed to correspond to a velocity inversion associated with base of permafrost. (This is a commonly observed effect associated with predictive pore pressure analysis on the North Slope and is not normally indicative of abnormal pressure). The half pound increase at 2000' TVD on the fracture gradient plot is not believed to be indicative of abnormal pressure based on surrounding wells. We have investigated all of the surrounding offset data from the nearest wells and we see this inversion on some of the seismic plots but have not seen abnormal pressures while drilling. For example, the Meltwater South #1 well had a similar response, but nothing was seen while drilling. As we mentioned to you in our phone conversation(s), we will be including a discussion of the potential for shallow gas hazards at this location in the well plan. Also, we are required by our internal SOP's to hold a spud meeting with the crews prior to spudding the well and this potential will be addressed. Proper precautionary drilling and tripping techniques Will be enforced. The 10 ppg planned drilling mud weight for this interval will also exceed the predicted pore pressure prediction of approximately 9.6 ppg. As you requested we are submitting the pore pressure plots with the appropriate titles. If we can be of any additional assistance, please feel free to call Tom at 265-6377 or Monte Mabry at 265-1653. Sincerely, T~o~m Brassfield Monte Mabry Senior Staff Geophysicist ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JAN lO 2000 Nasla 0il & Gas Cons. Commissio Anchorage Pore Pressure and 12/24/98 Ray Wydrinski Fracture Gradient Pre-drill Project: Meltwater Well Meltwater North #2 NCTL:: 165_45S DEPTH (Datum set to RKB, 280 fl above MSL) -220 4(-/ 61) 80 I00 120 140 160 NCTL In'tcrcep~ at GL = 16(I.78,1 lx~garithmic Slope: -4.5e-05 · Casing Depth + Repeat Formation Test Production Pressure [] Lx~st Circulation Zones "- Stuck Pipe Ix~cation Frcefi)rm Kick/Flow Drill Stem Test [] Leak-off Test - Formation Top Sidetrack I_x~cation Meltwater #1 (IL5265, CDP 10465) ,, ............. ~ ...... "'.:--~-7 .................. · , o . , , . o !~ t LOT ( i'om Cirr ue ~! LOT 'from W{ If'button ~fl) -- , . .. o . , __ ,, 8 9 10 !1 12 13 14 15 16 17 18 19 20 PPG FEET 20~ 300(I 6(XX) 898(} 0 i 95_ 45.'qPI I:. 0 t MSL 0.0 I~,L~S u j-~dl'i/'/L:i[rost 1000.0 2000.0 J O00. 0 E P T t-I 4ooo.o (ft) 5000.0 70OO.0 8000.0 ~000.0- 12/21/98 Flay Wydrinski Scale ' Vertical 1' -- 614 msec, Horizontal 1 in = 8?' cdp Project: Meltwater Cross ,qection' !15265 0 500' 1000' I I I Scale I 1 I 1 I I I I 1 I I I I I I I 1 I I I ! I 1 I I I I I 1 1 I I t t I I I I t I I I I r) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o o 0 0 0 0 0 o 0 0 0 0 0 o (] 0 u (I (} () (! ~) ~} (1 I I I t I t 2 2 2 2 2 2 3 3 3 '3 3 3 4 4 4 4 4 4 5 5 5 5 5 5 5 6 6 ,5 6 6 6 7 7 7 '? 7 7 ~ x 2 3 4 6 8 9 I 2 4 6 7 9 0 2 4 5 7 8 0 2 3 5 6 8 0 I 3 4 6 8 9 I 2 .1 6 7 9 0 2 4 5 7 8 () 1 0.0_0 1 I I I ! I I 1 I I 1 1 I I I I I I 1 5 I 1 I I I 1 I I I I t 0 I I 1 1 0 I t I I 3 ppg MSL 200.0- 400.0- 600.0- 800.0- 1200 T 1400.0- I M 1 E (ms) 1800 2000 2200 2400, 2600.( 2800.0 3000.0 3200.~ 3400.1 3500.0 oor) 10,~r) 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 28, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill ARCO Meltwater North #2 Surface Location: 2034' FNL, 293' FWL, Sec. 16, TSN, R7E, UM or ASP4, NAD 27 coordinates of X=447528 & Y=5867817 Target & BHL: 1788' FNL, 408' FEL, Sec. 17, TSN, R7E, UM CONFIDENTIAL Dear Commissioner Christenson: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the Meltwater North #2, located approximately 10 miles south of the Kuparuk River Unit's 2N Pad. This well will be accessed via ice road originating near 2N Pad, drilled using Doyon Rig #141, tested and permanently abandoned prior to spring breakup. Attached is the information required by 20 ACC 25.005 (c) for your review. There are no shallow hazards expected at Meltwater North #2 (see attached graphs). The nearest offset wells indicate no overpressured intervals or lost circulation zones. There will be no reserve pit for this well. Waste drilling mud will be hauled to a KRU Class II disposal well. If a production casing string is set in this well ARCO requests that Meltwater North #2 be permitted for annular disposal of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As in the past ARCO would submit a 10-403 Form to the Commission with the appropriate technical information. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating, as is the usual case while drilling wells in and near the Kuparuk River Field. If you have any questions or require any further information, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, ~ Paul Mazzolini Drilling Team Leader Exploration/Tarn Team Leader Attachments cc: Meltwater North #2 Well File RECEIVED D£C 9 t999 A/aska Oil & Gas Cons. Commission Anchorage ARCO Alaska Inc, is a subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill rm lb Type of Well Exploratory X Stratigraphic Test F~. Developm~-nt Oil Re-Entry r- Deepen F~ service ~ Development Gas r-~ Single Zone Multiple Zone X .. 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 222' feet 3. Address 6. Property Designation Tarn Expl. P. O. Box 100360, Anchorage, AK 99510-0360 ADL 373112 ALK 4711 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ASP4, NAD27 coordinates X=447528 & Y=5867817 or N/A Statewide 2034' FNL, 293' FWL, Sec. 16, T8N, R7E, UM At top of productive interval (@ TARGET ) 8. Well number Number 1788' FNL, 408' FEL, Sec. 17, T8N, R7E, UM Meltwater North #2 #U-630610 At total depth 9. Approximate spud date Amount 1788' FNL, 408' FEL, Sec. 17, T8N, R7E, UM 1/15/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Cirque #2 MD 6418' 408' @ TD feet 5.3 Miles feet 5583 TVD 6300' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 2500' feet Maximum hole angle 23° Maximum surface 1302 psig At total depth (TVD) 3472 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 118' 118' +/- 200cf 12W' 9-5/8" 53.5 L-80 BTC 2272' 28' 28' 2300' 2300' 450 sx AS3 plus 340 sx Cl G PPf 8Y2" 7" 29 ppf L-80 BTC-M 6390' 28' 28' 6418' 6300' 350 sx Cl 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 Measured depth True Vertical depth !~i!tcuU?~rRECEIVED Intermediate Production Liner DEC 29 1999 Perforation depth: measured true vertical0il & Gas Cons. Commission 20. Attachments Filing fee X Property plat [] BOP Sketch X '~'n'c;;n""~erter Sketch X Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis ~' Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge 1 Signed / (~,.~,~.,~. Title Exploration/Tarn Drilling Team Date ,~_'~ ~ /~ .-~ ~ ['?~ ,~(O"~'z,~', Leader i'7_. ¢(.2 C6mmission Use Only Permit NumbererS., /.~,~ I AP, nu~r~.:~ 50- -- .,2,,~_.~,~ / ¢ O IAppr°val date/_ I~, _ ~ I See cover letter for b~.ther requirements Conditions of approval Samples required [~ Yes E~ No Mud Io~l required [~ Yes bJ No Hydrogen sulfide measures p[~ Yes ['-~ No ~ Directional survey required [~ Yes F/ No Required working pressure for BO E~ 2M E~ 3M 5M [." 10M [-] 15M Other: ORIGINAL $16NED BY by order of Approved by Robert N. Chnstenson Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE ARCO Meltwater North #2 . . . . . 10. 11. 12. 13. 14. Move in and rig up Doyon #141 over pre-installed 16" conductor casing. Install diverter system. Drill 12-1/4" hole to 9-5~8" surface casing point (2300' MD) according to directional plan. Run and cement 9-5/8" 53.5 ppf L-80 BTC Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 9-5/8" casing at approx. 1000' TMD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top .lob may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. Install and test BOPE to 5,000 psi. Test casing to 2,500 psi. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. These test results must demonstrate that the integrity of the casing shoe will be sufficient to contain the anticipated wellbore pressures. Drill 8-1/2" hole to TD (6418' MD), coring as necessary, according to directional plan (if applicable). Run open hole evaluation logs. If the well is to be tested, run 7", 29 ppf L-80, BTC-M production casing. Go to step 10. Pressure test casing to 3500 psi. If the well will not be tested, P&A it per AOGCC regulations. Go to step 14 Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test to 5,000 psi. Shut in and secure well. RDMO Doyon #141. Hook up well for flow testing to surface tanks. Produced fluids to be trucked to Kuparuk production facilities. Test zones as appropriate. When complete, plug and abandon the well as per AOGCC regulations. Thoroughly clean location and block off access ice road. TJB 12/22/99 LEAK OFF TEST PROCEDURE Meltwater North #2 After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in l-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. ARCO Meltwater North #2 PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (4) DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of Meltwater North #2. ............................................................................. C;4"§fi~'~""S'~ffi'i:i~'"D'~"iS'(t'i ................................................................................................................ P~F~ .................................................................................................................................................................. Casing Fracture Pressure Pore ASP Drilling Size Gradient Gradient Pressure ................... "f6"' .................. i ........................... ff"~"8'"'~DT'"~'"~"8'""MD ......................................... 1"~'":'0'"'¢'¢'~ ............. [ ............... 8';'5'"'~'~"¢ ............... ~ .................. 52'"'~'i ................................................. N'IA' ............................ ............ 9:'5/8'" ........... ~ .................... '23'0'0'""~DT'23'0'0'""MD ..................... ~ ............. 1'3';0'"'¢'~ ............ '[ ............... 9':"0'"'~'~ ............... ~ ............. ~"0'7'8'"'~'~i ................................ '1"3'0'2""~i .................. Expected Maximum Mud Weights: 12ol/4" Surface Hole to 2300' TVD / 2300' MD: 10.0 ppg 8-1/2" Production Hole to 6300' TVD / 6418' MD: 11.2 ppg Procedure for calculating Anticipated Surface Pressure (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)-0.11] D Where: ASP = FG = 0.052 = 0.11 = D= Anticipated Surface Pressure in psi Fracture Gradient at the casing seat in lb/gal Conversion factor from lb/gal to psi/ft Gas gradient in psi/ft True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP-(0.11 x D) Where: FPP - Formation Pore Pressure at the next casing point -1- Meltwater North #2 PRESSURE INFORMATION AND CASING DESIGN ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11] D = [(11 x 0.052) - 0.11] x 118 = 54 psi OR ASP =Fppo(0.11xD) = 1076- (0.11 x 2300) = 825 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x0.052)-0.11]D = [(13.0 x 0.052) - 0.11] x 2300' = 1302 psi OR ASP =FPP-(0.11xD) = 3472 - (0.11 x 6300) = 2779 psi Casing Performance Properties ....................................................... i ................................................................. i ................................................................................................................................................................................................... i ......................................................................... T~'i~'§'il~'"S'[i;~'~'~t'l~ ........... i i Internal . Siz,e.. i Weight i Grade . Connection Yield j Collapse ..................... '~1'6 ..................... i .......... 6275'8'"'jS"lS'f .......... T ..................... B' ...................... i ............................. PEB ..................................................................................................... Cb"fi"Eb"gtb"FC~7if'¢ ....................................................................... .............. 9:578" .............. ~ .............. 53";5'"'i5i5'f ............. i ............... E'"'8'0 ............... i ............................. BTC .......................................... 7;'9'30'"'i5'§i ........... i ........... 6';'620'"'i5§'i ............ i'"'"'~f28'6'"M'"'"?2;~'~;'"'M'''''', 'iiiiii',iiiiii'.i',iiiiii;....,'.'.i'.'.i'.ii'.'.ii'.ii',i'.i',ii',ii i17 ! iiiiii','.iii '.ii i'.2,,.'i,,..iiiii19 ppiii',i'.i'. '.i .f.i iiiiii;ii i'.iiii'.ii i'.i'.iiiiiiii'.i i..iE~80'.iiill i...'.ii...'.'.'.ii i'.iii iiiii i'll i ii ifll ill iiiiiiiiiii i.....'.BTi......~i;ii..i'.'..ii'.i'.iiii',iiii'.'.ii-I~I ii ifil'ii iii'.ii'.iiii..18,'i6011'.ii i.i '...i i..i i iiiii'.'.ii'.iiiiiiiiiiiiiiil;Psl '.'.'.iiiiiiii...'.iii..17' 0201..iii..i',iiiiiii'.iiiiiiiiiiiiiiiiiipsl Casing Setting Depth Rationale 16"-118' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8"-2300' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 7"-6300' TVD RKB Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into the ~lettwater North #2 approved annulus or hauled to the nearest permitted Class II disposal well. The cement rinsate will not be injected down the dedicated disposal well but will be recycled or held for the Meltwater North #2 open annulus or injected down another Kuparuk well open annulus. The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The I'¢leltwater North #2 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. -2- Meltwater North #2 PRESSURE INFORMATION AND CASING DESIGN We request that Meltwater North #2 be permitted for annular pumping of fluids (if production casing is set) occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 50' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by' Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2300') + 1,500 psi Max Pressure = 2935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the casing performance properties above. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). -3- ARCO Meltwater North #2 PRESSURE ANALYSIS AND PREDICTION (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the ARCO Meltwater North #2 well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells Ruby State #1, Cirque #2, and Meltwater South #1. Attached are the following: Mud weight versus depth graph for these wells. Seismic analysis for Meltwater North #2. Pore pressure, frac pressure and anticipated mud weight graph. DRILLING FLUIDS PROGRAIV[' ARCO Meltwater North #2 ['""D~'5'~i't~' ........................................................................................................................................................ ~"0 ................................................................................ 8:6:'1'"1:'2 ............................ ['""PV ........................................................................................................................................................................ 20':26 ............................................................................... ~"6:20 ................................... ['"'Y'P .......................................................................................................................................................................... ~"5':2'5 ................................................................................ ~5:20 ["Vi~'b'5'~'it~ ........................................................................................................................................ 50':70 .............................................................................. 30:~0 .................................... ['""lh'iti'~l'"G'~l ........................................................................................................................................ 5:"1"5 ......................................................................................... 4:6 .......................................... ?'"'~"0':M'i'~":'"'G'~I .......................................................................................................................... ~'5':~'0 ...................................................................................... 6:8 .......................................... ['""A'P'I'""F'iI't'~' ............................................................................................................................ 1'0':~"2 ................................................................................... 8:'1"0 ........................................ ~'""~'R ........................................................................................................................................................................ g':'5:'~"0 ............................................................................ 9:5:~0 %' Soli'd~ ................................ : ................... ~ 10% ............................ 4:7% .......... .................................................................................................................................................... ¢, .................................................................................................................... [ ...................................................................................................... ing Fluid System: 3 - Derrick FIo-Line Cleaners Pioneer Model S2-t2 Desander Tri-FIo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (wi visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers Drilling Area Risks: Examination of the three nearest offset wells, Ruby State #1, Cirque #2, and Meltwater South #1 reveal no subsurface hazards such as abnormal pressure or lost circulation zones. For the well, MWN #2, seismic analysis is plotted and pore pressure and fracture gradient curves derived.. Again, no indications of abnormal pressure or weak formations were seen particularly at shallow depths. The mud weights planned for MWN #2 are conservatively based on those used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this well with specific regards to the potential shallow gas hazards which have been encountered in the Tarn wells ten (10) miles to the north and in other exploration activities. The 9-5/8" surface casing shoe will be tested to a maximum 16 ppg EMW formation integrity test or leak-off (whichever is least) after drilling 20 feet of new formation. MELTWATER SOUTH OFFSET WELLS - MUD WEIGHT AT DEPTH 10.7 10.5 10.3 10.1 9.9 ' 9.7 9.5 '9.3 8.9 8.7 -8.5 t i i i i i i i i i : I I .. I I I I I I I II I I I I I I I I I I I I I I I - i I I ! I I I I I I I I I I I I I I I I I I I I I I _._ I ~ I _ .~L -- - - I I I I ........ _1 ..... .......... - ! I I I I I I II I II I I I ! 1 ~ I I ! I I I I I / ! - ' ' I I I I I I I I I I I I I ~ I I I' . I I I ; .... .4- -I-- ........... I ...... -I- ....... .~1- . . .-~ .......... -I-- ' l-- .... .-I ...... '~' ..... 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I I I 0 1000 2000 : 3000 4000 5000 6000 7000 8000 9000 Vertical Depth (feet) _ prepared by Steve McKeever January 7, 1998 lOOO 4OOO 7ooo 1OOOO ~Mud"-e-' Depthwe ght I 116" set @ 108'I DRILLING TIME AND MUD WEIGHT CURVE MWS #1 ~--:--? -:--:-,---:--';--: .... ~ .... ?--:--: .... ~--:--:--' ..... ,__:__,._,_ .... :__,__,.__, ..... ,__,.__,__:__ 0-5/8 set @ 2~8 i .............. "-'--"'"" :_~i ;~:~\_~.._:__ :...: ......-:- - ':~:-~- - ,"~'~- -',~. ,._,_....-..-,. ,,-.,,.,-,.,~,-~.:-'~' .:,,,,.,,,?,,.;,_,~,,.~v,.~?,-,~, .... ~ :.. :...:.. :. .... :._ _:__ ~__: ..... :__ :.._:__ :._: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .-, .... - :~.,~.- -,.:.-,~.-,-.-,: -, _,~,_ ,~:_-,.~,.: - -,- -: - -,- - ,- .... ,.. _,_ _,. _ _, ..... ,__.._.,..,._ ~ :/i- - i - - -i- - i - -i- - i .... 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L _ _~ _ _ L _ _' ..... ' _ _ '. _ _' _ _ L _ _ 0 5 10 15 20 25 30 35 Spud 1/25/99 TIME TO DRILL (DAYS) Rig Release 2/11/g9 10.8 10.6 10.4 10.2 10 9.8 9.6 9.4 9.2 8.8 8.6 8.4 8.2 prepared by TJB 5/24/99 '1 ARCO Exploration -,nd Produc§on Technology Date: Subject: From: Telephone: To: Internal Correspondence January 18, 1999 Pore Pressure Prediction for Meltwater #1; ~2, #4, #6 and #6R Seismic In-Lines 5120, 5265____, 5336, 5812, 5823 and one traverse line R. Wydrinski PRC-Dl139 5094325 M. Mabry ATO-1486 J. Trantham ATO-1204 This memo is to review the pore pressure prediction for above Meltwater wells. These wells are normal pressure with no apparent shallow hazard problems. Due to the seismic reference point was 500' above Mean Sea Level, the depths on the seismic pore pressure plots with depth are about 500' too shallow. Seismic ProceSsing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velodty field that is used as input. This velocity field is generated by picking velocities at every fourth CDP location with an automated high resolution velocity analysis program (UHCI process developed by AEPT). This process produces a very accurate and densely sampled velodty field to cover each CDP location. The RMS velodties that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. From'pore pressure prediction studies done in Alpine and Tarn areas, the following procedure was used for the pressure prediction: 1) A Normal Compaction Trend Line (NCTL) was determined for each seismic line. The slope of this line was 4.5* with an intercept of ranging from 160 to 173. The variation for the intercept is due to .ground level or formation top changes. 2) A comparison was made between the NCTL and the Seismic Integrated Travel Time (rrr). This difference is AAT. 3) From the Alpine and Tarn study, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is: PP = C2 * AAT2 + C1 * AAT + CO where C2 = -2.5769 e-04; C1 = .119231; CO = 8.94231 4) The fracture gradient was determined using the Eaton Method where the inputs are the bulk density (used from Cirque #2) and Poisons Ratio (from a West Cameron model). Seismic IL5265 Meltwater #1 (CDP 10465) or/~/~TM ~'°~' ~e, ~t,~J~ )~do,~ Figure #1 is the pore pressure prediction across Seismic Inline 5265 with depth. The warmer the colors, the higher the mud weight (or pore pressure). Figure ~2 is the pore pressure plot with time. Figure #3 is a plot of the pore pressure at the Meltwater location ( CDP 10465 ). The left track is the Integrated Travel Time (black curve) and the Normal Compaction Trend Line (NCTL, red line). The right track has the pore pressure prediction (blue curve) and the fracture gradient (red curve). Labeled are the Leak Off Tests from Wolfbutton #1 and Cirque #2. There is good agreement with the LOT and the fracture gradient. Due to the reference point of the seismic was not at Mean Sea Level (MSL), the seismic pore pressure prediction with depth (Figure #1) is 500' shallower than the prediction at Meltwater #1 (Figure #3). There is no apparent shallow hazard at this location. Seismic IL~336 Meltwater ~2 (CDP 10427) Figure #4 is the pore pressure prediction across Seismic Inline 5336 with depth. Figure #5 is the pore pressure with time. Figure #6 is the pore pressure prediction at CDP 10428, which is the location of Meltwater #2. The presentation is the same as in Meltwater #1. The fracture gradient comparison with the LOTs from Cirque ~2 and Wolfbutton #1 are in good agreement. The seismic pore pressure with depth is 500' shallower than Meltwater #2 (Figure #6), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. .Seismic IL5120 Meltwater/t4 (CDP 10578) Figure #7 is the predicted pore pressure for Seismic Inline 5120 with depth. Figure #8 is the pore pressure with time. Figure ~V9 is the pore pressure for Meltwater #4 at CDP 10578. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The seismic pore pressure with depth is 500' shallower than Meltwater #4 (Figure #9), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Seismic IL5~2~ Meltwater #6R (CDP 10461) Figure #10 is the predicted pore pressure for Seismic Inline 5823 with depth. Figure #11 is the pore pressure with time. Figure #12 is the pore pressure for Meltwater #6R at CDP 10461. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The seismic pore pressure with depth is 500' shallower than Meltwater #6R (Figure #12), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Seismic Traverse Line .Meltwater #6 (CDP 10499) Figure #13 is the predicted pore pressure for this Traverse Line with depth. The borehole trajectory shows the surface location at CDP 10499 and the bottom hole location at 10478. The well does not appear to encounter any apparent shallow hazards. Figure #14 is the pore pressure with time. Figure #15 is the pore pressure for Meltwater #6 at CDP 10499. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The'seismic pore pressure prediction with depth is 500' shallower than the prediction at Meltwater #6. This is due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. .~onclusions: 1. There are no apparent shallow hazards for Meltwater #1, #2, #4, #6R and #6. 2) The seismic reference point is 500' above Mean Sea Level. This caused the seismic plots in depth to be 500' too shallow. 3) There is good agreement between the know Leak Off Tests and the calculated fracture gradient. 4) The slope and intercept for the Normal Compaction Trend Line from the Alpine and Tam study is the same as this Meltwater study. If there are any further questions, please call me at the above number. Ray Wydrinski ,! ,! ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill 12/24/98 Ray Wydrinski Project: Meltwater Well Meltwater North #2 NCTL:' 165_45S Well Name Updated 1/06/2000 DEPTH (l;iamm set to RKB, 280 fl above MSL) -22O Meltwater #1 (1L$265, CDP 10465) FEET -220 1000 2OOO 7OOO 7O0O 8OOO 8980 40 60 80 100 I20 140 160 NCTL latereept at GL = 160.781 Logarithmic Slope = -4.5e-05 k Casing Depth .. ~ Kick l Flow + Repeat Formation Test I,[ Drill Ste~n Test A Production Press~ El Leak~ffT~ ~ Lost Circulation Zones -- Formation Top -'- Stuck Pipe Location % Sidetrack Location Z Freeform 8 9 10 I1 12 I3 14 15 16 17 18 PPG --0-- 165_45sPLE__pPG c 16~_43WC_~ (Sonic NCTL: 165_45S, Poisaon Model: ~CAMERON) 8980 19 20 00010601C00 ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill 12/21/98 Ray Wydrinski Sc. Ne :Vertical 1'= 1753 ft, Horizontal I in = 87 cdp Project: Meltwater Cross Section: 115265 Depths Updated 1/06/2000 Meltwater North #2 c~ooo o oo oo o oo oo o oo oo o oo o o o oc oo o oo oo o oo oo ! ! ] ~. ! I 22 2 22 2.3 3 ~ ~ .33 4 '44 4 4 4 55 5 ~ 5 55 66 6 6 6 6(~!. 2 34 6 89 12 4 67 9(.) 2 ~i ~ 78 0 23 5 6 lg 0 t 3 '~ 6 89 ! 2 4' 6 7 9 . MSL Base Permafrost 1000 D E P T H 4000.0- (ft) 500' 1000' I I Scale 00010601A00 ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill 12/21/98 Ray Wydrinski Scale :Vertical 1' = 614 msec, Horizontal I in = 87 cdp Project: Meltwater Cross Section: 115265 Depths Updated 1/06/2000 0 500' 1000' Meltwater North #2 ~ ~ ~ j ~ Scale 1 I I -I ] -1 -1"! 1 .1 t' 1 ! ';t . ;I ;!:; I 1 ~ 1 I ' i l' t ':i-1 I 1 t I 1 1 1 I- 1 1 ! i 1 I 1 ! I ] ] 0 O0 0 O0 O0 0 O0~. 0:0-:-:'0 O.O: '0-0 0 O0 'o 0 0 0.0 O0 o O0 O0 O- 0 0 O0 O. 0 0 O0 0 0 CDP- t't I 1 ' I 1 2 2 2 2 2~ 2.37~:. 3 -33:-~ 33 "~t '4 4 ' 4 4 4 5:5 -5 5 5- $ 5 .6 6 6 6 6 6 7 .7 7 7 7 7 8 8 2 3.4 -6-'.-89 '~::2 4.i 6-7~: :9---.0;!i~!2-:--it-;: .~-~:8 -~0 ---2.3. ;'-5:-6 ~ ..0-1, 34 6 89 . t 2 4~ :6 7 -90 2 4 5 7 8 0'1 1. MSL 400 1200.0' T 1400.0' I M E (ms) 1800.0- ppg' :-'8.00 !8-50 :950 I0.00 t0.50 11.50 i3.~ 4.50 ]5.50 16~00 --16.50 't7.00 ~7;50 3500.0 00010601 BOO ARCO Alaska, Inc. Doyon 141 Diverter Schematic Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 6" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-518" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE L__] w/hydraulic actuator / DSA 13-5/8" 5,000 psi WP x 11" 5,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator L~~-~ CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L_] ~ w/two 3" 5M psi WP outlets I ] SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams Meltwater North I MIRU I Depth vs Time Build Ice Road I Spud I 0~ ........... -7000 .............. ; ......... :-i ......... : ...................... : .................... o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o Days MWN Time-Cost Graph.xls, Time Chart jt 12/22/99 NOTES '-q~, ~:., · ~ 1. COORDINA~S SHO~ ARE ALASKA STATE PLANE ' , 4 2. ALL ELEVATIONS ARE B.P.~.S.L.. , ': 4. DA~ OF SURLY: 2/~5/2~, FB. L ~-~2, Pg. 55. , ,. ~--~ ~, / ~ I H~R~BY C~RTIFY THAT I A. PR~RLY MEL~A~R NOR~ ~2 REGIS~R~D AND LImNeD TO PRACTIC[ LAND SUR~NG IN' ~E STA~ OF SEC. 16 T~. 8'N., RGE. 7 E.~~~V~ A SURLY OON~ BY M~ OR UNO~R MY UMIAT MERIDIAN DIRECT SUP~RVISI~ AND ~AT ALL LONG. = 15~' 25' ~6.8~6' :.~ 1 5 coR.~CT Y = 5,867,751.12 X 447,689.e9 I~&~ = ~ WI~ WllilI~ RIG PAD ELEV. = 222.1' ~/~ · ASSOCIATES, INC. O.G. ELEV. = 218.6' ~'~-E~NEE~ P~NNE~ SURVEYO~ ~ MEL~A~R NOR~ 2 ARCO Alaska, Inc. ~ EXPLORATORY ~LL CONDUCTOR Subsidiary of Atlantic Richfield Compan~ AS-BUILT LK6~lD32~ 2/~3/~ CEA-M1XX-6~l D32~ 3aa BOO 900 1200 . 1500- 1800 2100 2400 r- 2700 3OOO 0 '1~ 5300 Q) 3600 I 390O 4200 4500 4800 5100 _ _ 5700 - - 6000 - _ 6300 - _ 6600 - RKB Elevation: 250' es · e t ~p ~es[r~fkr°~ot nd, Base West Sak Sands C-BO 9 5/8 Casing Pt tARCO Alaska, Structure: blelfwafer North ~2 Field: Exploration Begin Angle Drop BLS: 1.50 dog per 100 ft T/ Cairn - End Drop Top Bermuda B/Bermuda / T/C35 Base C-35 TO- 7 Casing Pt II1C. Well: IdWN#2 Location: North Slope, Alaska <- West (feet) 700 650 560 490 420 550 280 210 140 70 0 70 I I t I t I t ! I I I ! I I I I I t I I I ~ I Base W~ KOP 2.50 BLS: 2.50 deb per 100 ft. 5.00 7.50 10.00 12.50 15.00 17.50 20.00 22.50 EOC 0-40 22.50 21.00 19.50 18.00 15.50 15,00 15.50 12.00 10.50 g,o0 7.50 6.00 4.50 5.00 1.50 550 280 /X I 210 Z 0 -140 70 v PROFILE COMMENT DATA ..... Paint ..... MD Inc Oir TVO North Eo~ V. Sect Dog/lO0 Bass Permafrost 1150.00 0.00 290.03 1150,00 0-00 0-00 O.O0 O.O0 Top West 5~k .Sands 1200.00 0.00 290.03 1200,00 0.00 0.00 0.00 Base West Sak Sands 1700.00 0.00 290.03 1700.00 O.iX) 0.00 0.00 0.00 '9 0/8 CasIng P~ 2300.00 O.O0 290,03 2300.00 0.00 0.00 0-00 lC-BO 2425.00 0.00 290,03 2~.25,000.00 0.00 0.00 KOP 2500.00 0.00 290.03 2500,00 0-00 0.00 0.00 0.00 ~'OC ;5417.7722,94 290.03 5595.~4 62.11 -170.55 181.-~2 2.5fl =-40 3533.49 22.94 290.03 3500.00 77.57 -212.73 226.43 O.O~ Begin Anglo Drop 4088.32 22.94 290.03 4010,93 151.66 -415.94 442.72 O.Og I*/Cairn - End Drop 5617.94 O.O0 290.03 55(X).00255.18 -699.85 744.92 1.50 rap Bermuda 5797.94 0.00 290.03 5680.00 255.18 -699.85 744.92 0.00 rat - I~Id Bermuda5952.93 0.00 290.03 5834.99 255.18 -699.85 744.92 0-00 B/asrmuda / T/ C356127.94 0,00 290.03 8010.00 255.15 -699.85 744.92 O.O0 Base C-35 6202,94 0-00 290.03 6085.00 255.18 -699.85 744.92 O.O0 rD - 7 Casing Pt. 6417.94, , 0.00 290.0,363(30.00255.16 -699.85 744.92 0.00 __ Tat - Mid Bermuda - ! i ~ i -7--- i i ~ ~ i i 300 O 500 500 go0 1200 Vertical Section (feet) -> Azimuth 290.03 with reference 0.00 N, 0.00 E from slat ~I ALPINE DISBURSEMENT ACCOUNT CHECK 249005880 P.O. Box 103240 : .. :...:: :'- ' -- ,,:' .i "-- ::. ::- -: Anchorage, AK 9951.0-3240 '~: ' '" ' : '":' '" -'"' ':"":"' ' ' ' · .'-" ~:". ' ~ .... ~NOVEMBER- 17; 1999 pAy TO THE STATE OF ALASKA,-. ..-...-.'-...-. ORDER OF:' ALASKA OIL. &:GAS:CONSERVATION CO~i 'i."-':.i'!'~ .:.....i;/ !..:':;"-:'-'..: ~::.-.-::' .::..-;!-" .."' -' 3001 PoRCUpINE DRIVE -' " " :' ~-; -;:'V~i~'Al~r~R 90'DA~/s ':'~, ' . EXACTLY .*;*********.100 DOLLARS -~D O0 :CENTs $*********** 100.00 . The Fir§t National Bank of'Chicago-07'10 TRACE . : :- ...::. -. 'i! : . . ' NUMBER: 249005880 ' ':' ' ' 0990337 0 q'qO.3 3 ?"" ,' i~qO0 5P, P,O,' ~:OEt~'-qo~, ar, WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION DATE /z..¢/5 ¢7 ENGINEERING COMPANY ~ WELL NAME/~.~-,/'/'~/~' PR/~OGRAM: exp v'/dev__ redrll- sen/__ wellbore seg __ann. disposal para req_ INIT CLASS L'~T'_"'X/~ &~/?r-/_¢--~,")L GEOL AREA ~---~(b. UNIT# .-'1/~/~_ ON/OFF SHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. N JDATE~/tr~° 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ..... - ..... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .S'~i~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY R DATE _. /z ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Seismic analyms of shallow gas zones N ~. · ·' . ............ ~ ~..'. /~ .'. ~ ~ ~ ~ ,~ ~ ~ .,~¢~o,-~,~.~o. II 33. Seabed condition su~ey 0f off-shore) ............. ~ ~ N ~ ~ ~ 1~ ~ ~/~ ~Xl/~ s~ ~ ~'1, ~, ~..a_ ~. . Con, o, n me,.,one .,o,,e.s ,epo.. 35. With p~op~ oeme,ting re~o~d~, thi, Ca. ~.~~ ~~~¢~t ', (A) w,, oonta~n waste in ~ su,aUe ~eoeiv~.g zone; ....... ~N &tV~*~k ~ ~*~~'"~~ ~ '*~O. [[ (B) will not contaminate freshwater; or cause drilling waste . . . to surface; (C) will not impair mechanical integrity of the well used for disposal; ~ N ~ ¢ ~v6D ~ o~S . (D) will not damage producing formation or impair recovew from a ~ N pool; and (E) will not circumvent 20 ~C 25.252 or 20 ~C 25,412. ~N , , , GEOLO~ ¢ ENGINEERIN~ ~ LUJ¢/Annular COMMISSION: Comments/Instructions: TEM'¢ ~.',- . ' RNC , c:\msoffice\wordian\diana\checklist (rev. 09~27~99) >. Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Mar 13 12:53:07 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Tape Header Service name ............. LISTPE Date ..................... 00/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific jqq. i%o Technical Services Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MM-90232 J. MARTIN M. WHITELY MWD RUN 4 AK-MM-90232 JUSTIN PANTE MSL 0) MELTWATER NORTH %2 501032032100 ARCO ALASKA, INC. Sperry Sun 13-MAR-00 RECEIVED MAR 2 1 '2000 Alaska Oil & Gas Cons. Commission Anchorage MWD RUN 2 AK-MM-90232 S.HUIBAN MWD RUN 3 AK-MM-90232 JUSTIN PANTE 16 08N 07E 2099 454 250.63 249.13 222.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.125 16.000 108.0 8.500 9.625 2059.0 8.500 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISED NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS , AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE- 4 (EWR4). 3. GAMMA RAY AND RESISTIVITY DATA IN THE CORED INTERVAL 5735'MD, 5569'TVD TO 5891'MD, 5724'TVD IS FROM A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED PRIOR TO MWD RUN 4. 4. DIGITAL DATA IS DEPTH CORRECTED TO THE PDC GR LOG OF 02/15/00 WITH KBE OF 250.6' A.M.S.L. 5. LDWG RUN NUMBER REFERENCES 10, 20, 30 AND 40 CORRESPOND TO MWD RUN NUMBERS 1-4. 6. MWD RUNS 1-4 REPRESENT WELL MELTWATER NORTH %2 WITH API % 50-103-20321-00. THIS WELL REACHED A TOTAL DEPTH OF 6300'MD, 6132'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 89.5 6255.0 RPD 100.0 6257.0 RPM 100.0 6257.0 RPS 100.0 6257.0 RPX 100.0 6257.0 GR 100.0 6247.0 ROP 144.0 6302.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 100.0 1892. 1894. 1896. 1910. 1931. 1977. 1984. 1988. 2009. 2036 2062 2073 2078 2091 2113 2119 2123 2130 2148 2153 2156 2182 2200 2202 2203 2205 2208 2211 2225 2239 2247 2267 2269. 2279. 2288. 2301. 2305. 2307 2318 2324 2338 2339 2343 2346 2354 2358. 2362. 2364. 2365. 2373. 2386. GR 98. 0 1890. 0 1893. 5 1895. 5 1909. 5 1931. 5 1977. 5 1982. 5 1987. 5 2007. 5 2034 5 2061 0 2071 0 2076 5 2090 0 2111 0 2117 5 2121 5 2128 5 2146 0 2151. 5 2154. 0 2180. 0 2198. 9 2199. 0 2201. 5 2203. 0 2205. 5 2209. 5 2223. 0 2237 0 2244 5 2266 5 2267 5 2277 5 2286 0 2300 5 2304 0 2305 0 2317. 0 2323. 0 2338. 5 2339. 5 2341. 5 2344. 5 2352. 5 2358 0 2361 5 2364 0 2365 5 2372 5 2385 EQUIVALENT UNSHIFTED DEPTH 2401.0 2404.5 2406.5 2408.5 2414.5 2419.5 2426.0 2429.5 2439.5 2443.0 2447.5 2454.0 2459.0 2473.5 2477.0 2482.5 2512.0 2517.0 2524.5 2533.0 2538.0 2540.0 2542.5 2552.5 2559.5 2562.5 2570.0 2577 5 2581 5 2587 5 2595 0 2599 0 2604 0 2606 5 2610 5 2615 5 2618.5 2632.5 2641.0 2642.5 2649 0 2654 5 2660 0 2663 0 2665 5 2670 5 2683 0 2699 5 2703 0 2708 5 2716 0 2722 5 2726 5 2732 5 2735 0 2759 0 2763 0 2775 0 2782 5 2793 5 2798 0 2802 5 2808 0 2819 0 2823.0 2828.5 2398.5 2402.0 2404.5 2407.0 2413.0 2420.0 2424.5 2427.5 2438.5 2441.5 2446.0 2454.0 2458.0 2472.5 2476.5 2482.0 2511.5 2516.5 2524 0 2533 0 2537 5 2539 0 2541 0 2552 0 2559 5 2562 0 2569 5 2577 0 2581 0 2587 0 2594 5 2598 5 2603 5 2606 0 2610 0 2614 5 2617 0 2631 0 2639 5 2645 5 2655 5 2662 5 2668 0 2670 0 2670 5 2674 5 2683 0 2699 5 2702 0 2707 0 2714 5 2721 0 2728 0 2731.5 2734.0 2758.0 2762.0 2774.0 2781 5 2792 5 2797 0 2801 5 2807 0 2818 5 2822 0 2827 5 2840 2843 2851 2854 2862 2864 2869 2881 2883 2888 2894 2899 2904 2908 2915 2917 2924 2939 2962 2966 2978 2984 2992 2996 3000 3014 3015 3022 3024 3036 3040 3049 3057 3063 3065 3079 3093 3098 3101 3102 3104 3110 3114 3118 3120 3123 3127 3130 3137 3139 3141 3145 3153 3157 3160 3166 3172 3177 3182 3187 3196 3203 3209 3210 3212 3217 .0 .5 .0 .5 .5 .5 .5 .0 .5 .5 .5 .5 .0 .5 .0 .0 .5 .5 .5 .0 .0 .5 0 0 5 5 5 0 0 5 5 0 5 0 0 5 0 5 0 5 5 0 .5 .5 .5 .0 .0 .0 .0 .5 0 5 0 5 5 0 5 5 5 0 0 0 0 5 0 0 2839.0 2842.5 2850.0 2853.0 2861.0 2864.0 2868.5 2880.0 2883.5 2888.0 2892.0 2897.0 2901.5 2906.5 2913.0 2915 5 2922 5 2938 5 2962 0 2965 5 2977 0 2983.0 2990.5 2994.0 2999.5 3013.5 3014.5 3021.0 3023 0 3035 5 3039 5 3048 0 3056 5 3062 0 3065 0 3079 0 3093 0 3098 5 3101 0 3102 0 3104 0 3109 0 3114 5 3118 0 3120 0 3122 5 3126 5 3129 5 3136 5 3138 0 3140.5 3144.5 3151.0 3156.0 3159.0 3165.0 3171.5 3176.5 3181.5 3186.5 3194.5 3201.5 3207.5 3209.0 3210.5 3215.5 3221.0 3223.0 3225.5 3229.0 3232.5 3238.5 3240.5 3243.5 3247.0 3249.5 3253.5 3261.5 3265.0 3267.0 3269.5 3275.5 3279.5 3281.5 3284.5 3290.5 3293.0 3295.5 3302.0 3304.0 3309.0 3312.0 3327.0 3329.5 3332.5 3356.5 3361.5 3364.0 3373.0 3380.0 3411 0 3415 5 3420 5 3424 0 3431 5 3436 0 3447 0 3460 0 3469 0 3478 0 3487 5 3514 5 3517.0 3530.0 3539.0 3542.5 3550.5 3552.5 3562.5 3567.0 3580.0 358?.0 3592.5 3592.7 3602.5 3611.0 3611.3 3637.0 3656.0 3658.0 3665.5 3671.5 3219 5 3221 5 3224 0 3227 5 3231 0 3237 0 3239 0 3241 0 3243 5 3248 5 3252 0 3260 5 3264 0 3266 0 3268.5 3275 5 3279 0 3281 0 3284 0 3291 0 3293 5 3295 5 3301 5 3303 5 3308 5 3311 5 3326 0 3329 0 3332 0 3356 0 3361 0 3363 5 3372 5 3379 5 3410 5 3415 0 3420 0 3423 5 3431.0 3435.5 3446 5 3459 5 3468 5 3477 0 3486 5 3513 5 3515 5 3529 0 3539.0 3542.5 3550.5 3552.0 3563.5 3567.0 3579.0 3586.0 3591.0 3592.5 3601.0 3609 0 3610 0 3635 5 3656 5 3658 5 3666 0 3671 5 3675.0 3695.0 3717.0 3734.5 3767.5 3769.0 3810.0 3817.5 3820.5 3829.5 3867.0 3880.5 3897.0 3950.5 3955.0 3961.5 3986.5 3997.5 4003.5 4016.0 4044.0 4147.0 4227.5 4231.0 4257.0 4260.5 4278.0 4282.0 4292.5 4296.0 4321.0 4327.0 4345.0 4364.5 4387.5 4394.5 4421.5 4423.0 4424.0 4433.5 4442.0 4451.5 4456.0 4459.5 4471.0 4475.5 4494.5 4515.5 4520.5 4557.5 4561.5 4574.0 4580.0 4585.5 4590.0 4594.5 4606.5 4610.0 4625.5 4636.0 4649.5 4669.0 4676.0 4679.0 4680.0 4697.5 3677.0 3696.5 3718.5 3736.0 3769.0 3770.5 3811.5 3819.0 3822.0 3831 0 3868 0 3881 0 3897 0 3955 0 3958 5 3965.5 3990 5 4000 5 4007 0 4020 0 4047 5 4148 5 4227 5 4233 0 4260 0 4263 5 4281 0 4285 0 4294 5 4298 0 4323 5 4330 5 4346 0 4365 5 4389.5 4396 0 4423 0 4424 5 4426 5 4435 5 4444 5 4453 5 4458 0 4461 5 4473 0 4477 5 4497 0 4518 0 4523 0 4559.5 4563 0 4576 5 4582 5 4586 5 4591 5 4596 0 4608 0 4611 5 4627 0 4637 0 4650 5 4671 0 4677 5 4681 0 4682 5 4698 0 4707 5 4712 5 4715 0 4717 0 4725 5 4726 5 4737.0 4738.5 4768.5 4788.5 4828.5 4843.0 4863.0 4864.0 4866 5 4871 5 4876 5 4899 5 4917 0 4928 0 4968 0 4979 5 5001 5 5008 5 5013 0 5022 0 5028 0 5034 5 5036 0 5042 5 5055 0 5069 5 5074 0 5083 5 5092 5 5098 5 5103 5 5113 0 5116 5 5143 0 5148 5 5149 0 5151 0 5157 0 5170 5 5174 0 5211.0 5215.5 5227.5 5237.0 5262.5 5268.5 5284.0 5288.5 5302 5 5313 5 5321 0 5334 0 5336 5 5352 5 5360 0 5363.0 5374.5 5403.5 5407.0 5415.5 4708.0 4713.5 4715.5 4717.5 4725.5 4727.0 4737.5 4739.0 4770.5 4791.0 4831.0 4844.5 4863.5 4865.5 4867.0 4872.0 4877.0 4900.5 4918.0 4929.0 4969.0 4980.5 5002.5 5010.0 5015.0 5023.5 5029.0 5035.5 5038.0 5044.0 5058.0 5072.0 5078.0 5087.0 5095.0 5101 5 5106 5 5116 0 5120 0 5146 0 5150 5 5151.5 5152.5 5159.0 5171.5 5175.5 5213.0 5217.5 5229.0 5239.0 5264.5 5268.0 5283.0 5288.0 5303.0 5315.0 5322.5 5338.0 5340.0 5354 5 5361 5 5364 5 5376 0 5405 0 5408 5 5417.0 5416 5423 5426 5430 5445 5454 5468 5480 5487 5497 5501 5515 5529 5533 5547 5549 5550 5551 5556 5563 5574 5593 5603 5658 5663 5667 5679 5681 5685 5708 5711 5715 5718 5722 5730 5738 5746 5750 5751 5755 5759 5768 5776 5787 5792 5813 5816 5823 5829 5834 5858 5862 5874 5877 5897 5912 5918 5926 5934 5938 5948 5956 5970 5976 5981 5984 .5 .5 .0 .5 5 5 0 5 0 0 0 .5 .5 0 5 0 5 0 0 5 5 0 5 .0 5 0 0 0 0 5 5 5 0 0 0 .5 0 0 0 0 5 5 5 0 0 0 0 5 .0 .5 0 5 0 0 0 0 5 5 0 5 0 0 5 5 5 5 5418.0 5426.5 5428.5 5432.5 5446.0 5456.0 5472.0 5483.0 5488.0 5498.5 5503.5 5517.5 5531.5 5535.0 5549.0 5550.0 5552.0 5553.0 5557.0 5566.0 5577.0 5595.0 5606.5 5660.5 5666 0 5669 5 5681 5 5683 5 5687 5 5710 0 5712 5 5716 0 5719 0 5722.5 5730.0 5737.5 5745.0 5750.0 5751.0 5755 5 5758 5 5768 0 5775 0 5787 5 5792 5 5813 5 5817 5 5823.5 5827.5 5831.0 5860 0 5865 5 5876 0 5878 0 5897 0 5912 0 5917 5 5927 0 5934 0 5938 0 5947 5 5954 0 5970 5 5976 0 5980.5 5983.0 5990.0 5987.5 6001.0 5999.5 6007.0 6005.0 6302.0 6300.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 10 MWD 20 MWD 30 MWD 40 $ # REMARKS: MERGED MAIN PASS. $ MERGE TOP 89.5 2070.0 5318.0 5735.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 2070.0 5318.0 5735.0 6300.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 89.5 6302 ROP MWD FT/H 0 5546.56 GR MWD API 15.14 240.34 RPX MWD OHMM 0.82 2000 RPS MWD OHMM 0.8 2000 RPM MWD OHMM 0.79 2000 RPD MWD OHMM 0.85 2000 FET MWD HOUR 0.1539 54.1208 Mean Nsam 3195.75 12426 222.47 12317 110.01 12295 14.1472 12286 20.6703 12286 39.6532 12286 84.9881 12286 1.27984 12303 First Reading 89.5 144 100 100 100 100 100 89.5 Last Reading 6302 6302 6247 6257 6257 6257 6257 6255 First Reading For Entire File .......... 89.5 Last Reading For Entire File ........... 6302 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 89.5 RPM 98.0 GR 98.0 RPS 98.0 RPD 98.0 RPX 98.0 ROP 142.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: STOP DEPTH 2020.5 2020 5 2028 5 2020 5 2020 5 2020 5 2069 5 07-FEB-00 Insite 65.30 Memory 2070.0 .0 .8 TOOL NUMBER PB01426CGR8 PB01426CGR8 12.125 108.0 SPUD 10.10 102.0 9.1 7OO 11.0 3.500 2.800 65.0 83.0 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 65.0 65.0 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR Min Max Mean Nsam 89.5 2069.5 1079.5 3961 20.7 5546.56 366.744 3856 15.14 126.62 71.1816 3862 2.11 2000 30.9266 3817 2.07 2000 54.329 3817 2.22 2000 113.188 3817 2.38 2000 219.53 3817 0.1539 1.2121 0.545095 3834 First Reading 89.5 142 98 98 98 98 98 89.5 Last Reading 2069 5 2069 5 2028 5 2020 5 2020 5 2020 5 2020 5 2020 5 First Reading For Entire File .......... 89.5 Last Reading For Entire File ........... 2069.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 2021.0 5271.5 RPS 2021.0 5271.5 FET 2021.0 5271.5 RPX 2021.0 5271.5 RPD 2021.0 5271.5 GR 2029.0 5261.5 ROP 2070.0 5318.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: il-FEB-00 Insite 65.30 Memory 5316.0 .3 27.3 TOOL NUMBER PB01417HGVR6 PB01417HGVR6 12.125 2059.0 LSND 9.60 45.0 9.8 200 6.2 3.100 1.860 3.100 3.400 66.0 114.8 66.0 66.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 i ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min Max Mean Nsam 2021 5318 3669.5 6595 4.36 2850.69 169.922 6497 35.32 240.34 125.223 6466 0.82 2000 6.96542 6502 0.8 2000 5.73681 6502 0.79 2000 7.08204 6502 0.85 2000 30.7528 6502 0.2651 54.1208 1.48916 6502 First Reading 2021 2070 2029 2021 2021 2021 2021 2021 Last Reading 5318 5318 5261 5 5271 5 5271 5 5271 5 5271 5 5271 5 First Reading For Entire File .......... 2021 Last Reading For Entire File ........... 5318 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5262.0 5709.5 RPX 5272.0 5720.0 RPS 5272.0 5720.0 RPM 5272.0 5720.0 FET 5272.0 5720.0 RPD 5272.0 5720.0 ROP 5318.5 5734.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 12-FEB-00 Insite 65.30 Memory 5735.0 4.1 4.2 TOOL NUMBER PB01417HGVR6 PB01417HGVR6 12.125 LSND 9.60 43.0 9.4 3OO 4.4 3.100 1.800 3.100 3.300 69.0 111.6 69.0 69.0 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min DEPT FT 5262 ROP MWD030 FT/H 0 GR MWD030 API 85.06 RPX MWD030 OHMM 1.05 RPS MWD030 OHMM 1.09 RPM MWD030 OHMM 1.11 RPD MWD030 OHMM 1.19 FET MWD030 HOUR 0.2849 Max 5734. 131 9 181 1 33 2 21 1 18 0 16 9 14.877 Mean 5498.25 28.1131 140.157 4.87173 4.37914 4.31746 4.43187 2.04821 Nsam 946 833 896 897 897 897 897 897 First Reading 5262 5318.5 5262 5272 5272 5272 5272 5272 Last Reading 5734.5 5734.5 5709.5 5720 5720 5720 5720 5720 First Reading For Entire File .......... 5262 Last Reading For Entire File ........... 5734.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 5710.0 5720 5 5720 5 5720 5 5720 5 5720 5 5736 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : STOP DEPTH 6245 0 6255 0 6255 0 6255 0 6255 0 6255 0 6300 0 15-FEB-00 Insite 65.30 Memory 6300.1 3.9 4.3 TOOL NUMBER PB01417HGVR6 PB01417HGVR6 12.125 LSND 9.60 46.0 9.1 3OO 4.3 2.400 116.600 1.920 1.940 68.0 101.1 68.0 68.0 EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 5710 6300 ROP MWD040 FT/H 0 886.84 GR MWD040 API 70.31 196.96 RPX MWD040 OHMM 1.67 20.12 RPS MWD040 OHMM 1.66 14.61 RPM MWD040 OHMM 1.65 14.48 RPD MWD040 OHMM 1.69 15.91 FET MWD040 HOUR 0.2967 48.5166 First Last Mean Nsam Reading Reading 6005 1181 5710 6300 173.958 1128 5736.5 6300 132.103 1071 5710 6245 5.84673 1070 5720.5 6255 5.13085 1070 5720.5 6255 5.0392 1070' 5720.5 6255 5.22765 1070 5720.5 6255 1.99644 1070 5720.5 6255 First Reading For Entire File .......... 5710 Last Reading For Entire File ........... 6300 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/03/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
