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Home My WebLink About196-133KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶǇ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶǇƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt>>ED W/η ^Zs/KZZη &/>ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^dηϭ ϭͲϭϰ ϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϭͲĞĐͲϮϱ Ϭ ϭϮ ϭͲϭϯϬ ϱϬͲϬϮϵͲϮϮϴϭϱͲϬϬ ϵϭϬϰϳϰϬϵϵ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϳͲEŽǀͲϮϱ Ϭ ϭϯ ϭͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϮϭͲEŽǀͲϮϱ Ϭ ϭϰ ϭͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϯͲEŽǀͲϮϱ Ϭ ϭϱ ϭͲϬϰ ϱϬͲϬϮϵͲϮϬϰϳϴͲϬϬ ϵϭϬϰϯϮϭϱϰ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϵͲEŽǀͲϮϱ Ϭ ϭϲ ϭͲϭϴ ϱϬͲϬϮϵͲϮϬϵϬϰͲϬϬ ϵϭϬϰϳϰϮϯϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϵͲĞĐͲϮϱ Ϭ ϭϳ ϭ'ͲϭϮ ϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϱͲĞĐͲϮϱ Ϭ ϭϴ ϯͲϭϴ ϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϵͲEŽǀͲϮϱ Ϭ ϭϵ ϯ<ͲϬϯ ϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϲͲEŽǀͲϮϱ Ϭ ϭϭϬ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ >ĞĂŬĞƚĞĐƚ>ŽŐ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭW>^<EKt>'Z/Wdz^/'E/E'EZdhZE/E'KWzK&d,dZE^D/dd>>ddZdKd,ddEd/KEK&͗&ĂŶŶǇ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗199-089197-183180-056180-057183-016183-132196-133186-103197-076T41200T41201T41202T41202T41203T41204T41205T41206T41207T41208Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:38:53 -09'00'196-133ϴϯͲϭϴϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮϵͲEŽǀͲϮϱϬϭ By Meredith Guhl at 1:44 pm, Jul 19, 2022 Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this document Location: your signing location here Date: 2022.07.19 12:14:06-08'00' Foxit PDF Editor Version: 11.2.1 DTTMSTART JOBTYP SUMMARYOPS 3/8/2022 SUPPORT OTHER OPERATIONS TAG TD @ 8562' RKB (33' SHORT OF CTD TARGET DEPTH OF 8595' RKB) & MEASURE BHP @ 8450' RKB. IN PROGRESS. 3/9/2022 SUPPORT OTHER OPERATIONS DRIFT W/ 15' X 2.625" DMY WHIPSTOCK & TAG @ 8536' RKB (59' SHORT OF CTD TARGET DEPTH); BRUSH n' FLUSH W/ 2.72" GAUGE RING THRU D-NIPPLE @ 8248' RKB; SET 2.75" D-CSV @ 8248' RKB (MITT TO 2500 PASSED); REPLACED OV IN KIND @ 8195' RKB & MITT TO 2500 PSI (PASS); PULLED CSV @ 8248' RKB. JOB COMPLETE. 4/5/2022 SUPPORT OTHER OPERATIONS RIH WITH LEFT HANDED MOTOR AND MILL. TAG NIPPLE AT 8,249'. PAINT FLAG. MILL OUT D-NIPPLE TO 2.80".MILLED NIPPLE BACK REAMED AND DRY DRIFTED THRU NIPPLE 4/6/2022 SUPPORT OTHER OPERATIONS SET BAKER EZ COMPOSITE PLUG AT 8,420' RKB. LAY IN CEMENT FROM 8,420' TO 8,290'. PERFORM INJECTIVITY TEST WITH A FULL COLUMN OF SEAWATER 0.5 BPM = 890 PSI, 1.0 BPM = 1050 PSI, 1.5 BPM = 1245 PSI. ESTABLISH 1:1 RETURNS AT TRIP TANK. LAY IN CEMENT FROM 8420' TO 8,200' INJECT CEMENT INTO PERFS. PERFORM 3 HESITATIONS WITH CEMENT IN COIL GET 200 PSI PRESSURE BUMP. LAY IN REMAINING CEMENT. PERFORM 2 HESITATIONS TO GET 600 PSI PRESSURE BUMP. DROP BALL AND CIRCULATE DOWN TO NOZZLE. GET 750 PSI SQUEEZE PRESSURE. CLEAN DOWN TO 8,280'. 4/9/2022 SUPPORT OTHER OPERATIONS RIH AND TAG CEMENT AT 8,287' RKB. MILL CEMENT FROM 8,287'- 8,420'. MILL COMPOSITE PLUG AT 8,420' RKB. TAG AT 8,536' RKB. CLEANOUT TO HARD TAG AT 8,611' FREEZE PROTECT WELL W / DIESEL. ****JOB COMPLETE**** 4/10/2022 SUPPORT OTHER OPERATIONS TIE INTO GLM @ 8195' RKB FOR C/F (METAL CHUNKS IN TRAY OF KOT); DRIFT W/ 2.625" BAKER DMY WHIPSTOCK & TAG HARD @ 8545' RKB (TOOLS FOULED WITH METAL & SCALE--SEE ATTACHMENTS); DRIFT W/ 2.5" BAILER W/ 2.65" BOTTOM & TAG @ SAME (UNABLE TO MAKE HOLE W/ SMALL AMOUNT OF METAL IN BAILER). UNABLE TO REACH DEPTH TO SET WHIPSTOCK; JOB SUSPENDED FOR PLAN FORWARD. 4/12/2022 SUPPORT OTHER OPERATIONS TAG @ 8545' RKB W/ 10' x 2.5'' PUMP BAILER W/ 2.65'' BOTTOM (NO RETURNS). RAN 10' x 2.5'' PUMP BAILER TO TAG @ 8624' RKB. RAN BARBELL 2.74'' LIB TO TAG OBSTRUCTION @ 8545' RKB (OBTAIN PICTURE OF 2.58'' SEMI CIRCLE). IN PROGRESS. 4/13/2022 SUPPORT OTHER OPERATIONS DRIFT W/ 5' x 2.625'' & TAG @ 8545' RKB (UNABLE TO WORK PAST). DRIFT W/ 20' x 1.875'' (RIGID) & 2.25'' CENTRALIZER TO TAG @ 8625' RKB. READY FOR E-LINE. 4/17/2022 SUPPORT OTHER OPERATIONS GYRO ENTIRE WELLBORE FROM TAG DEPTH OF 8630' RKB TO SURFACE. JOB COMPLETE, READY FOR CALIPER. 4/18/2022 SUPPORT OTHER OPERATIONS LOG READ CASED HOLE 24-ARM CALIPER FROM 8610' TO SURFACE, CORRELATED TO K1 GAMMA RAY MARKER AT 8220' . JOB COMPLETE. 3A-18 Summary of Operations Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: Corrected RKB 3A-18 cjkenne Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed Norther Solutions LTP 6/22/2022 3A-18 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 45.0 Set Depth (ftKB) 121.0 Set Depth (TVD) 121.0 Wt/Len (lb 62.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.5 Set Depth (ftKB) 4,277.4 Set Depth (TVD) 3,300.8 Wt/Len (lb 29.70 Grade L-80 Top Connection BTC Casing Description PRODUCTION 5.5x3.5" @8261' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.9 Set Depth (ftKB) 8,795.0 Set Depth (TVD) 6,386.5 Wt/Len (lb 15.50 Grade L-80 Top Connection LTCMOD Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String 3 1/2 ID (in) 2.99 Top (ftKB) 37.0 Set Depth (ft 8,273.7 Set Depth (TVD 5,957.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 37.0 37.0 0.00 HANGER 3.500 8.000 FMC GEN IV 500.4 500.2 4.36 NIPPLE 2.812 4.500 CAMCO DS 3,265.1 2,643.3 51.29 GAS LIFT 2.900 4.750 BST ATX 4,757.1 3,606.4 51.31 GAS LIFT 2.900 4.750 BST ATX 5,938.0 4,383.5 49.41 GAS LIFT 2.900 4.750 BST ATX 6,896.4 5,032.4 46.52 GAS LIFT 2.900 4.750 BST ATX 7,650.3 5,530.1 50.08 GAS LIFT 2.900 4.750 BST ATX 8,195.5 5,897.6 40.70 GAS LIFT 2.900 4.750 BST ATX 8,248.8 5,938.5 38.95 NIPPLE 2.800 4.520 CAMCO D (MILLED TO 2.80" ON 4/5/22) 8,256.0 5,944.1 38.68 LOCATOR 3.500 4.000 BAKER GBH-22 8,256.9 5,944.8 38.65 SEAL ASSY 3.500 4.000 BAKER Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,352.0 6,020.3 36.64 PACKER Northern Solutions Mono-Pack Liner Top Patcher w/ 1.78" RX nipple (11.28' OAL) 6/22/2022 1.780 8,485.0 6,127.5 35.53 WHIPSTOCK BOT 3.5" mono XL tray 5/28/2022 1.000 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,265.1 2,643.3 51.29 1 GAS LIFT GLV T-1 0.156 1,287.0 9/21/2010 2 4,757.1 3,606.4 51.31 1 GAS LIFT DMY T-1 0.000 0.0 9/15/1996 3 5,938.0 4,383.5 49.41 1 GAS LIFT GLV T-1 0.156 1,287.0 9/21/2010 4 6,896.4 5,032.4 46.52 1 GAS LIFT DMY Broke 0.000 0.0 9/15/1996 5 7,650.3 5,530.1 50.08 1 GAS LIFT GLV T-1 0.250 1,437.0 8/27/2001 6 8,195.5 5,897.6 40.70 1 GAS LIFT OV T-1 0.250 0.0 3/9/2022 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,392.0 8,402.0 6,052.4 6,060.4 C-1, 3A-18 4/26/2009 6.0 APERF 2 1/8" Phase PEJ, 45° phase 8,536.0 8,566.0 6,169.2 6,193.8 A-3, A-2, 3A-18 10/31/1996 2.0 IPERF 180° phase, 2 1/2" HC 8,568.0 8,596.0 6,195.5 6,218.6 A-2, 3A-18 10/17/2005 6.0 APERF 2 1/8" Spiron Jet, 45° phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,392.0 8,402.0 6,052.4 6,060.4 Cement Squeeze Cemented off C-Sand 4/6/2022 3A-18, 7/15/2022 2:30:23 PM Vertical schematic (actual) L1-01; 8,358.8-11,694.0 PRODUCTION 5.5x3.5" @8261'; 38.9-8,795.0 WHIPSTOCK; 8,641.0 APERF; 8,568.0-8,596.0 IPERF; 8,536.0-8,566.0 L1; 8,286.2-11,680.0 WHIPSTOCK; 8,485.0 Cement Squeeze; 8,392.0 ftKB APERF; 8,392.0-8,402.0 PACKER; 8,352.0 GAS LIFT; 8,195.5 GAS LIFT; 7,650.3 GAS LIFT; 6,896.4 GAS LIFT; 5,938.0 GAS LIFT; 4,757.1 SURFACE; 40.5-4,277.4 GAS LIFT; 3,265.1 NIPPLE; 500.4 CONDUCTOR; 45.0-121.0 KUP PROD KB-Grd (ft) RR Date 9/15/1996 Other Elev 3A-18 ... TD Act Btm (ftKB) 8,795.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292269200 Wellbore Status PROD Max Angle & MD Incl (°) 53.03 MD (ftKB) 3,000.00 WELLNAME WELLBORE3A-18 Annotation Last WO: End DateH2S (ppm) 110 Date 10/25/2019 Comment SSSV: NIPPLE Casing Strings Casing Description L1 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,286.2 Set Depth (ftKB) 11,680.0 Set Depth (TVD) 6,277.8 Wt/Len (lb 4.60 Grade L-80 Top Connection STL 3A-18L1, 7/15/2022 2:30:24 PM Vertical schematic (actual) L1; 8,286.2-11,680.0 PRODUCTION 5.5x3.5" @8261'; 38.9-8,795.0 L1-01; 8,358.8-11,694.0 WHIPSTOCK; 8,485.0 APERF; 8,392.0-8,402.0 Cement Squeeze; 8,392.0 ftKB PACKER; 8,352.0 GAS LIFT; 8,195.5 GAS LIFT; 7,650.3 GAS LIFT; 6,896.4 GAS LIFT; 5,938.0 GAS LIFT; 4,757.1 SURFACE; 40.5-4,277.4 GAS LIFT; 3,265.1 NIPPLE; 500.4 CONDUCTOR; 45.0-121.0 KUP PROD KB-Grd (ft) RR Date 9/15/1996 Other Elev 3A-18L1 ... TD Act Btm (ftKB) 12,420.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292269260 Wellbore Status PROD Max Angle & MD Incl (°) 100.18 MD (ftKB) 9,299.64 WELLNAME WELLBORE3A-18 Annotation End DateH2S (ppm) 110 Date 10/25/2019 Comment Casing Strings Casing Description L1-01 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,358.8 Set Depth (ftKB) 11,694.0 Set Depth (TVD) Wt/Len (lb 4.60 Grade L-80 Top Connection ST-L 3A-18L1-01, 7/15/2022 2:30:24 PM Vertical schematic (actual) L1-01; 8,358.8-11,694.0 PRODUCTION 5.5x3.5" @8261'; 38.9-8,795.0 WHIPSTOCK; 8,641.0 APERF; 8,568.0-8,596.0 IPERF; 8,536.0-8,566.0 L1; 8,286.2-11,680.0 WHIPSTOCK; 8,485.0 Cement Squeeze; 8,392.0 ftKB APERF; 8,392.0-8,402.0 PACKER; 8,352.0 GAS LIFT; 8,195.5 GAS LIFT; 7,650.3 GAS LIFT; 6,896.4 GAS LIFT; 5,938.0 GAS LIFT; 4,757.1 SURFACE; 40.5-4,277.4 GAS LIFT; 3,265.1 NIPPLE; 500.4 CONDUCTOR; 45.0-121.0 KUP PROD KB-Grd (ft) RR Date 9/15/1996 Other Elev 3A-18L1-01 ... TD Act Btm (ftKB) 12,420.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292269261 Wellbore Status PROD Max Angle & MD Incl (°) 95.75 MD (ftKB) 9,321.39 WELLNAME WELLBORE3A-18 Annotation End DateH2S (ppm) 110 Date 10/25/2019 Comment 3A-18 Final CTD Schematic3-1/2" 9.3# L-80 EUE 8rd Tubing to surfaceDS-Nipple @ 500' RKB (ID = 2.812")3-1/2" gas lift mandrels @ 3265', 4757', 5938', 6896', 7650', 8196' RKBD-Nipple @ 8249' RKB (2.75" ID) Milled to 2.80" pre-CTDBaker GBH-22 Locator @ 8256' RKB (ID = 3.5")Baker Seal Assembly @ 8257' RKB (ID = 3.5")7-5/8" 29.7# L-80 shoe @ 4277' MD5.5" 15.5# L-80 XO to 3.5" @ 8261' MD3-1/2" 9.3# L-80 shoe @ 8795' MDA-sand perfs 8536' -8596' MDKOP @ 8484' MD16" 62# H-40 shoe @ 121' MDModified by SJG 6/22/2022C-sand perfs (sqz'd)8392' - 8402' MD3A-18L1 TD= 12,426' MD2-3/8" slotted liner from TD up tobillet @ 8641' MD3A-18L1-01 TD= 11,694' MD2-3/8" slotted liner from TD up toswell packer @ 8494' MD, solid liner from swell packer up to LTP @8358' MDSolid liner section from 9856' to 9549' MD3A-18L1PB1 TD= 9563' MDTop of Billet @ 8910' MDFailed billet pushed down to 9073' MD3A-18L1PB2TD= 11,482' MDTop of Billet @ 10,160' MD3A-18L1-01PB1TD= 10,100' MDTop of Billet @ 9230' MD C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-04-18_22014_KRU_3A-18_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22014 KRU 3A-18 50-029-22692-00 Caliper Survey w/ Log Data 18-Apr-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 196-133 T36486 Kayla Junke Digitally signed by Kayla Junke Date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y Samantha Carlisle at 1:49 pm, Mar 03, 2022 'LJLWDOO\VLJQHGE\-DPHV-2KOLQJHU '1& 8628 &RQRFR3KLOOLSV2 :HOOV&RLOHG7XELQJ 'UOOLQJ&1 -DPHV-2KOLQJHU( -DPHV-2KOLQJHU#FRSFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ -DPHV- 2KOLQJHU '/%'65 ; 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O Lj iC7ad Z O O C O Y E 0) w ryJ mE N yup Z y • w 1011/1•11 C q p NNNNMO M IP v u ^ 3 I 1 1 1 1 1as a s • ~ ~~~~~r~~~ STATE OF ALASKA iu~qy 2~ ZQ09 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~,1~I~,Sr,;, Q, ~~n rawri ~,..~__~_ . 1. Operations Pertormed: AbandOn ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Ot~ChOCe~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate Q. Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drili Number: ConocoPhillips Alaska, 111C. Development ^ Exploratory ^ 196-133 /• 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22692-00 ` 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' • 3A-18 • 8. Property Designation: 10. Field/Pool(s): ADL 25632 . Kuparuk River Field / Kuparuk River Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 8795' • feet true vertical 6368' . feet Plugs (measured) Effective Depth measured 8731' feet Junk (measured) true vertical 6314' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4236' 7-5/8" 4277' 3287' PRODUCTION 8240' 5-1/2" 8281' 5968' PRODUCTION 514' 3-1/2" 8795' 6368' ~ Perforation depth: Measured depth: 8392'-8402', 8536'-8566', 8568'-8596' ' ' ' ' ~± ~ ~ ~'~~3 R ~•. J'"~~~'~~`~~L+: J4,Ji ' ' ~~ true vertical depth: 6026 -6034 , 6148 -6174 , 6175 -6199 r ~ Tubing (size, grade, and measured depth) 3.5", L-80, 8274' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 150 ' 815 158 -- 119 Subsequent to operation 260 , 1142 405 -- 130 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^' ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ' Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer / Signature ~~~ ,_„ Phone: 265-6471 ~9 Date ~~~~ P ared b Sharon 1/su - rak 263-4612 / ..--~' /F/'"'~-~ 2.- ~ G' . /, d ~ ~1.~,. .J J? '~1 ~, ~QO~ ~ ~ ~ ~ ,~ ~ Form 10-404 Revised 04/2006 Submit Original Only ~~~~~ .~T~a. ."_.~ ~~1~~~ ~~ I ~ CoraocoPF~i!lips ;' ~ `+ti~!!~E {fi~'. coNOUCroR, 12t NIPPlE.500 GAS LIFT, 3,265 SURFACE. a.2n GAS LIFT, 4.757 ' ~ KU P - 3A-18 s Max Angle 8 MD TD Field Nama Wall Status jProd/Inj Type Incl (°) ~ MD (ftKB) Act Btm (ftKB) KUPARUK RIVER UNIT I PROD 52.84 I 3,058J6 8,795.0 ~H25(ppm) i EndDate Date ~~~MnWation KB-Grd(it) RigReleaseDat 725 l 1lV2009 ~LastWO~ ~ I I 9/15/1996 iepth (RKB) ~'~End Date Mnofation End Date I 8.563A ~ 426/2009 Rev Reason: TAG, PERFORATIONS I 4/26/2009 IS ' Siring OD i String ID Set Dapih Set Depth (ND) String Wt String ~ ' (in) I (in) ~ Top (ftKB) (HKB) (HKB) ~ Qbs/fl) G2tle $tring TopThn ' i6 15.062 0.0 121.0 121.0 6250 H-00 75/8' 6JW 0.0 4,277.0 3,287.1 29J0 L-80 51/2I 4.825 0.0 8,281.0 5,931.1 15.50 L-80 .cription Comment Run LE Camco'DS' Landmg Nipple NO GO 9/15/1 LIFT BST/AXTl1/GLV/T1L756/1302/ Comment: STA 1~ 8/28l. .._ .__ .-_ .__. LIFT BST/AXT/1/DMY/T7///CommencSTA2 9/i511 LIFT BST/AXTl1/GLV/T1/.188l1336/ Comment STA 3 8/27/. UFT BST/AXT/1/DMY/T1U/Comment:STA4 9/1511 'D' Lantling Nipple GAS LIFT. 5.938 GAS LIFT, 6.896 GAS LIFf, 7,650 GAS LIFT. 8,195 NIPPLE,8,249 PBR.8.456 LOCATOR, 8.25] TfL.8.2]0 PRO~UCTION, 8,481 APERF, 8,392-8,002 IP~3F. 8.536-8.566 APERF, ____ B,Sfi8~8,596 PRODUCTION, _ B,I95 ~ TD, 8,795 IS ~ SIotS . _.- _.- __. . . . __ .. . ... __ _ . sna , roa Rvol e~m (rvol I oens (ftKB~~ (ftKB) (kK6) Zone Date (z~~~~ Type Comme~A 8 402 6 025.5 6,034.0 C-1, 3A-18 4126/2009 6.0 APERF 2 1/8" PHASE PEJ, 45 deg phase ~ 8,566 6,148.0 6,173.5 A3, A-2, 3A-18 10131/7996 2.0 IPERF iS0 deg phase, 2 1/2" HC 8,596 6,1752 6,199.0 A-2, 3A-18 10/17/2005 6.0 APERF 2 1/8" Spiron Jet, 45 deg phase 3A-18 Well Work Summary DATE SUMMARY 4l23/09 DRIFTED TBG TO 8543' WLM 10' x 2-1/8" WITH 2.25" CENTRALIZE~BOVE AND BELOW. READY FOR E/L. 4/26/09 STATIC BOTTOMHOLE PRESSURE SURVEY AND PERFORATION. SHOT 2 1/8" 45 DEGREE PHASED POWER ENERJET GUNS FROM 8392'-8402'. STATIC PRESSURE AT 8560' WAS 1996 PSI, PRESSURE AT 8437' WAS 1980 PSI. FLUID LEVEL WHILE RUNNING IN HOLE WAS AT 8527'. TAGGED TD AT 8563'. BOTTOM 8' OF TOOL WAS COVERED WITH UNIDENTIFIED SUBSTANCE AFTER TAGGING BOTTOM. 05/12/09 il~r~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ t, ATTN: Beth `:a~ti~,~t~~'ii~.r ~~'~, ~ ~~lu`~ A ~ AY ~ ~ 2009 al~s~~ C~ii ~ ~~s Cs• ~~T9~issi0r~ s~r~ch~r~~~ NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY - 6 '- 04/26/09 1 1 3C-08 6146-00033 GLS $ = / 04/21/09 1 1 2M-25 8146-00034 GR/TEMP LOG /9 (- - 04/22/09 1 1 1 R-19A AYS4-00065 _ SBHP SURVEY -'r G `~ 3 fo 04/23/09 1 1 3G-13 AYS4-00067 ` SBHP SURVEY - 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 6146-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-08 B14B-00037 SBHP SURVEY - 04/24/09 1 1 3M-25A B14B-00040 SBHP SURVEY - 3 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY 04/27/09 1 1 2Z-07 8146-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A B14B-00044 SBHP SURVEY ~-_ ~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 604C-00037 PRODUCTION PROFILE p 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY 05/09/09 1 1 1 J-120 604C-00043 GLS - ~ 0 0 05/08/09 1 1 31-11 604C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. u • ~~~ ConocoPhillips Alaska P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 • ~~~ .. fit I- ~ p • ~ ~ G ~; r M ~~6~1~~ ~1~ ~~ ~c•-t5, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~,1~~ ~~ ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, PerryKlein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 ~' We{{ Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 185-237 16' 2.50 25" 3/27/2009 5.95 4/6!2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 26, 2005 -",,", E' ~I'-'I(' t·:' , ,""""(,..,,, I ,.\I;I¡;:rQ' ocr 2 7 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Oil & Gas Cems. Commission Anchorage Subject: Report of Sundry Well Operations for 3A-18 (APD 196-133) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation activity on the Kuparuk well 3A-18. If you have any questions regarding this matter, please contact me at 263-4574. ,.;t Sincerely, );/, do-~ M. Mooney Wells Group Team Leader CP AI Drilling and Wells StJANNlEfJ NO \1 0 1 2005 MM/skad RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 8 Z005 REPORT OF SUNDRY WELL OPERA TION¡§ßIc.a Oil & G11S Com;. fÀmm~sicn Abandon D Repair Well D Plug Perforations 0 Stimulate D Other And¡;Jage Alter Casing 0 Pull Tubing D Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program D Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 196-1331 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22692-00 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 41' 3A-18 8. Property Designation: 10. Field/Pool(s): ADL 25632, ALK 2565 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: ) ) STATE OF ALASKA measured 8795' feet true vertical 6368' feet measured 8572' feet true vertical feet Length Size MD 80' 16" 121' 4236' 7-5/8" 4277' 8240' 5-1/2" 8281' 514' 3-1/2" 8795' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3287' 5968' 6368' Measured depth: 8536'-8566',8568'-8596' true vertical depth: 6164'-6187',6177'-6201' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8274' MD. Packers & SSSV (type & measured depth) no packer SSSV= Cameo 'OS' Landing Nipple @ 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBOMS 8Ft nC:'2 8 2005 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1059 232 1269 211 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 288 304 Casinç¡ Pressure Tubinç¡ Pressure 143 142 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X WDSPL 0 Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Signalure 4J 11/4 Form 10-404 Revised 04/2004 --- Wells Group Team Leader Date It' ~ 7/1,) ç Prepared bY /;f:;;on¿AIISUP-Drake 263-4612 Title Phone t,.)t\IGINAL Submit Original Only ) 3A-18 Well Events Summary Date Summary 10/17/05 SHOT 28' 2-1/8" POWERSPIRAL ENERJET FROM 8568'-8596'. GUNS LOADED WITH RDX, 6 SPF 45 DEG PHASED. TAGGED BOTTOM AT 8572' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: THRU: FROM: SUBJECT: Julie Heusser, Commissioner Tom Maunder, ~)~v~o.~~ P. I. Supervisor xj c~%-' o \ Chuck Scheve; Petroleum Inspector January 7, 2001 Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sunday, JanUarY 7, 2001 I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety Valve System Test Reports indicate I Witnessed the -testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure observed. The surface safety valve on well 3A-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test procedure and was a pleasure to. Work with The wellhOuses on these two pads were very clean and all related equipment appeared to be in gOod condition.. summarY: I witnessed the semi annual SVS testing at 3^ & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components' KRU 3B Pad, 6 wells, 12 components, 19 wellhouSe inspections I failure 0 failures Attachment: svS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad 1-7-0.1 CS X UnclaSsified COnfidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupan~ / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well ' Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3A-01 1851860 64 70 50! P P OIL 3A-03 1852060 ' 3A-05 1852210 64 70 50 P P OIL 3A-08 1852240 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810 64 70 40 .P P OIL 3A-16 1852840 64 70 70 P P OIL 3A-17 1961320 ~ 3A-18 1961330 64 70 50 P P OIL Wells: 8 Remarks: CompOnents: 16 Failures: 1 Failure Rate: 6.3% [] 90 oar . Surface Safety ValVe on well 3A-08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve - Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip ,i,Code Code Code,, Passed GAS or CYCLE 3B-03 1850600 64 70 60 P P OIL 3B-04 1850610 64 70 50 p p OIL 3B-0~ ' 1850760! 64 70 50 P P OIL 3B-08 1850870I 3B-09 1851130 64 70 70 P P OIL 3B-11 1851150 64~ 70 50 P P OIL 3B-13 1850230 3B-14 1850240 ' Wells: 6 Components: 12 FailUres: 0 Failure Rate: moo Day Remarks: Good Test ...... p~,~ 1 ,,~'1 SVS KRU 3B Pad 1-7-01 CS.xls ON OR BCFOP,¢ ANLIARY 03 200[ W c:l~ar,Ml:a,ld.poc P E RM I T DATA Geological Materials Inventory T DATA PLUS Page: 1 Date: 09/15/98 RUN RECVD 96-133 USIT ~/350-3845 FINAL 10/07/96 96-133 96-133 96-133 96-133 CBT CBL ARC 5 7523 10-407 DAILY WELL OPS Are dry ditch samples required? yes ~__~And received? Was the well cored? yes ~Analysis & description received? Are well tests required? )~es ~eceived? ~ Well is in compliance ~ Initial COMMENTS FINAL 10/07/96 FINAL 11/08/96 FINAL 11/15/96 1 11/15/96 J~ 4~o /2/A~q~/ /~/%/ yes"--n--fi~ STATE OF ALASKA · ALASr',~ OIL AND GAS CONSERVATION U~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i~'"Staius of Well '" classificati°n of SerVice Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-133 3. Address ......... 8. APl Numbe~' P. O. Box 100360, Anchorage, AK 99510 50-029-22692 4. Location of well at surface 9. Unit or Lease Name 904' FSL, 849' FEb, Sec. 7, T12N, R9E, UM ~' ~':/?'~" -':-;-'~"'~' t~' Kuparuk River Unit 323' FNL, 843' FEb, Sec. 17, T12N, R9E, UM i 3A-18 At total depth ! ~ii ¢ '~'l. Field and Poo, 425' FNL, 633' FEb, Sec. 17, T12N, R9E, UM ...... Kuparuk River · i5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designatiod-and Serial No. Rig RKB 41', Pad 41'I ADb 25632, ALK 2565 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 12. Date Spudded iI I N/A MSLI One 9/3/96 i 9/12/96 10/31/96 ... 17. Total Depth (MD+TVD)118. Plug BaCk Depth (MD+TVD)Iig. Directional Su~veyl20. Depth where SSSV set J21. Thickness of Permafrosl 8795 6368 F-q 8731 6314 FT~ __l~Ye.s f-IN° I N/A MD.! 1465' (Approx.) 22. Type Electric or Other. Logs Run ARC5/GR, GR/CCL/SLTJ 23. C. ASlNG, LINER AND CEMENTING RECORD cASING I .... .S__E___.'Er_i'_N_.G ___D _E__P__T___H_ ...... HoLE .... ...... SIZE_ . VV-I-.___P___ER FT_: ...... GF~__DE _ ~ TOP BO-FrOM__. SI_Z__E_ .... __C_EME__N_TIN_G___REc~____P,D 16" 62.5¢ H-40 Surf. 121' 24" 193 sx AS I 7.625" 29.7¢ L-80 Surf. 4277' 9.875" 1170 sx AS III, 380 sx Class G -fi .... ii~, ........ 5.5 X3.5 I 15.5#/9.3# L-80 Surf. 8795' 6.75" lgb--~x Clas~-~ ...................................... 24~ perfOrations open to Production (MD+TVD of Top and Bottom 1251 TuBiNG REcoRD '" and interval, size and number) SIZE .......... DEi~;~H SiT (MD) '" PACKER ~=T 3.5" 8274' MD TVD MD TVD ............................ 8536'-8566' 6164'-6187' 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTM INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ....... 8-~36--8566'- ' - i 76867# pr~ppar~ in '~'orm'~.tior~ .... _ ....... 27. PRODUCTION TEST Date First Pr'oduction iMeth°d of Operation (Flowing, gas lift, etc.) '" 11/13/96 ! Flowing Date of Test jHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO 12/5/96! 8 TEST PERIOD° 461 ...... 311 ............. ?_9_ ...... 136 .......... j ...................... _6._7._6_ ...................... ;F-f~w--Tub-~-~jiOa~i~---Pi'-~-~-b-~ C-~L-~OL-~b-; ..... OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 19~ 780 24-HOUR RATE 1383 935 417 =24° ....... . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED DEC 2 4 1996 Naska 011 & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. . Geologic Mar~'; 30. ' ' Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 8380' 6026' Bottom Kuparuk C 8412' 6051' Top Kuparuk A 8520' 6138' Bottom Kuparuk A 8670' 6262' Freeze protected annulus 31 ."List ~f Attachments ............ Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge __Signed ~~~ ...... Title ~) 17..[ LL-, kJ ~ ~'I~ ~ I tg __~:~P-.. ...... Date ! _'~//_~ !? (:, ...... Prepared By Name/Number: ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 RECEIVED DEC 2 4 1995 N~ka 011 & eaa ~na. Commis~ton Anchorage Date- 11/14/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page' 1 WELL:3A-18 RIG:PARKER 245 WELL ID: AK8613 TYPE: -- AFC: AK8613 AFC EST/UL:$ 1085M/ 1260M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT BLOCK: SPUD:09/03/96 START COMP' FINAL: WI- 0% SECURITY'0 API NUMBER: 50-029-22692-00 09/03/96 (D 1) TD' 2675' (2675) SUPV: DCL DAILY:$ 09/04/96 (D 2) TD' 4287' (1612) SUPV' DCL DAILY'$ 09/05/96 (D 3) TD' 4287' ( 0) SUPV:DCL DAILY:$ 09/06/96 (D 4) TD' 4287' ( 0) SUPV:DCL DAILY: $ 09/07/96 (D 5) TD: 4287' ( 0) SUPV: DCL DAILY: $ 09/08/96 (D 6) TD: 5155' (868) SUPV: DCL DAILY' $ MW: 9.1 rISC: 56 PV/YP: 20/19 APIWL: 7.2 DRILLING @ 3800' Move rig from 3A-t7 to 3A-18. Function test diverter. Drill 9-7/8" hole from 121' to 2675' 124,836 CUM:$ 124,836 ETD:$ 0 EFC:$ 1,209,836 MW: 9.2 ViSC: 48 PV/YP: 18/14 APIWL: 7.4 RIH W/7-5/8" CSG Drill 9-7/8" hole from 2675' to 4287' POH. Hole swabbing. Back ream from 3600' to HWDP at 1288' No problems. RIH to TD. No tight hole or fill. RIH w/7-5/8" casing. 84,223 CUM:$ 209,059 ETD:$ 0 EFC:$ 1,294,059 MW: 0.0 VISC: 38 PV/YP: 11/ 8 APIWL: 7.4 STAND BY FOR SCHLUMBERGER Held pre-job safety meeting. RIH w/7-5/8" csg to tight spot at 1645' Washed from 1635' to 1700' No problems. RIH w/7-5/8" casing. Pump cement. Lost returns 71 bbls into displacement. Did not bump plug. CIP @ 1045. Attempt to break LJ. Hanger 2" above landing ring. PU diverter, hanger had settled down on landing ring. RIH w/top job pipe to 156'. POH. No indications of cement. RIH w/l" CS hydril pipe. Tagged and plugged pipe at 185' 235' and 326' No indication of cement. Work pipe to 50~' No indication of cement. 118,724 CUM:$ 327,783 ETD:$ 0 EFC:$ 1,412,783 MW: 0.0 rISC: 38 PV/YP: 11/ 8 APIWL: 7.4 STAND BY FOR SCHLUMBERGER Kuparuk river bridge washed out. Wait on bridge. NU diverter. Fill and check for leaks. Standby for bridge outage. 137,221 CUM:$ 465,004 ETD:$ 0 EFC:$ 1,550,004 MW' 8.4 VISC' 0 PV/YP' 0/ 0 APIWL' 0.0 TEST BOP Run USIT/CBT from 3850' to 350' Run and work pipe to 555' Extremely tight. 106,409 CUM-$ 571,413 ETD:$ 0 EFC:$ 1,656,413 MW: 8.8 VISC: 44 PV/YP: 11/17 APIWL: 12.6 DRILLING AT 6000' Finish top job. Pumped 60 bbls cement. NU BOPE. Test BOPE to 200/3000 psi. Drill cement, float equip., and 10' new formation to 4298' Perform LOT. Drill 30' new hole to 4328' Perform LOT %2. Drill from 4328' to 5155' Problems with packing off due to clay. Circ hi vis sweep. 97,592 CUM:$ 669,005 ETD:$ 0 EFC:$ 1,754,005 Date: 11/14/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/09/96 (D 7) TD: 7511' (2356) SUPV:DCL DAILY:$ 09/10/96 (D 8) TD: 8000' (489) SUPV: DCL DAILY:$ 09/11/96 (D 9) TD: 8308' (308) SUPV:DCL DAILY:$ 09/12/96 (D 10) TD: 8795' (487) SUPV:DCL DAILY: $ 09/13/96 (D 11} TD: 8795' ( 0} SUPV: DCL DAILY:$ 09/14/96 (D 12) TD: 8795' ( 0) SUPV:DCL DAILY: $ 09/15/96 (D 13) TD: 8795' ( 0} SUPV: DCL DAILY:$ MW: 8.9 VISC: 38 PV/YP: 9/ 6 APIWL: 7.8 DRILLING AT 7786' Drilling from 5155' to 6868' Packing off at 6868' Work pipe. Drilling from 6868' to 6957' Circ hi vis sweep. Ream to bottom. No problems. Drilling from 6957' to 7511' 80,865 CUM:$ 749,870 ETD:$ 0 EFC:$ 1,834,870 MW: 12.6 VISC: 43 PV/YP: 25/20 APIWL: 6.2 DRILLING Drilling from 7511' to 8000' Performed FIT. Pump pill. POH. RIH w/BHA %3 to 8000' No problems. 108,623 CUM:$ 858,493 ETD:$ 0 EFC:$ 1,943,493 MW: 12.6 rISC: 48 PV/YP: 28/22 APIWL: 4.0 DRILLING AT 8430' Wt up mud to 12.7 ppg. Rotary drilling from 8000' to 8308'. Circulate and condition mud to reduce viscosity. No problems. 84,930 CUM:$ 943,423 ETD:$ 0 EFC:$ 2,028,423 MW: 12.6 VISC: 50 PV/YP: 26/20 APIWL: 3.8 POH W/DP TO RUN CSG Rotary drilling from 8308' to 8565' Gas cut mud to surface. Monitor well - static. Work pipe. CBU. No gas. Rotary drilling from 8565' to 8619' Circ out gas cut mud. Rotary drilling from 8619' to 8795' Monitor well. Circ and condition mud for short trip. 81,169 CUM:$ 1,024,592 ETD:$ 0 EFC:$ 2,109,592 MW: 12.6 rISC: 53 PV/YP: 30/22 APIWL: 4.0 CEMENT CSG Circ and condition mud. Monitor well at shoe. Held pre-job safety meeting. RIH w/3.5" and 5.5" casing to 3100' Circ and condition mud. RIH w/5.5" casing. 72,238 CUM:$ 1,096,830 ETD:$ 0 EFC:$ 2,181,830 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TEST CSG TO 3500 PSI RIH w/5.5'~ csg to 8795' Break circ slowly. Reciprocate pipe. Lost all returns after 200 bbls mud pump. Pump cement. Bumped plug. Floats did not hold. Cut off 7" csg. ND BOPE. Test to 3000 psi. NU BOPE. Set test plug. RU to run tubing. Held pre-job safety meeting. RIH w/3.5~ completion equipment. 278,264 CUM:$ 1,375,094 ETD:$ 0 EFC:$ 2,460,094 MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish RIH w/3.5" completion. Test casing to 3500 psi for 30 min. Test tubing and annulus to 3500 psi. ND BOPE. NU tree adapter and master valve. Test adapter to 5000 psi. Freeze protect annulus. Rig release at 2400 hrs. 9/15/96. 80,037 CUM:$ 1,455,131 ETD:$ 0 EFC:$ 2,540,131 End of WellSummary for Well:AK8613 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3A-18(W4-6)) WELL JOB SCOPE 3A-18 PERFORATE, PERF SUPPORT DATE DAILY WORK 10/31/96 SLT-J WELL LOG AND INITIAL A SAND PERF DAY OPERATION COMPLETE I SUCCESSFUL 4 NO I YES Initial Tbg Press IFinalTbgPress IlnitiallnnerAnn 0 PSI 1300 PSI 800 PSI DAILY SUMMARY JOB NUMBER 0919961042.1 UNIT NUMBER KEY PERSON SUPERVISOR S. DECKERT JORDAN Final Inner/~nn I Initial Outer Ann ] Final' Outer Ann 800 PSI 250 PSI 250 PSI SLT-J WEll. LOG AND INITIAL A SAND PERFS AT 8536'-8566' INTERVAL COMPLETE. TIME LOG ENTRY 08:30 MIRU SWS E-LINE UNIT. PT BOP/LUB OK. 0 WHP 10:00 RIH W/SLT-J; CCL; GAMMA RAY. TIE INTO GR-RES LOG DATED 09/03/96.LOGGED 8556'-8205'. TD LOGGER 8722'- TOOL STRING 32' 13:30 RIH W/2.5" CARRIER GUN X 10'; GAMMA RAY; 6' WB.MAINTAIN 1250 WHP. PERF 8556'-8566'. WHP DROP TO 1000.POOH. ALL SHOTS FIRED. 16:30 RIH W/2.5" CARRIER GUN X 20'; GAMMA RAY. PERF 8536'-8556'. POOH. ALL SHOTS FIRED. RD SWS. WHP 1300. RECEIVED DEC 2 4 199~ Alaska 011 & Gas Cons. Commission Anchorage PAGE NO, ********* ANADRILL ********** ********* SCHLUMBERGER ********** ::::::*** ********** AFE: Al( 8613 APl: 50-029-22692-00 *********** SURVEY PROGRAM *********** COMPANY A~O ALASEA~ INC, WELL NAMB 3A-18 LOCATION ! IO]PARU~ LOCATION 2 ALASEA MAGNETIC DECLINATION GRID CONVERGENCE At~LE 0.00 DATE: 13-S~'-76 ELL NUMBER 18 WELl. EEAD LOCATION: LAT(N/-S) 0.00 D£P(~-W) 0.00 AZIMUTH ~]M R~]TARY TABLE TO TAli~ IS 103,03 TIE IN I~]IHT(TIP) : M~SURED D~?H 121.00 T1EgJE VE~ DBC'TH 121.00 INCLINATION 0.00 AZIMUTH 0o00 LATITUDE(H/-S) 0,00 D~ARTURE(E/-W) 0o00 PAGE NO. ******~-~**** ANAl)RILL ************** SUR~EY CALCULATIONS *******.****** CIRCULAR ARC METHOD******** 3A-18 M~SUF'<EI)INTEEt~qLUF. F~ICAI. DEPTH DEPTH ft ft ft 121,00 0.0 121,00 286,17 165,2 286,17 379.02 ?2,8 378.98 468,,85 89,8 468,69 560,85 92.0 560,32 TARGET STATION AZIMUTH LATITUI)E SECTION INCLN, N/-S ft deg deg ft 0,00 O.OO 0.00 0,00 1,20 0.96 I~,53 -0,93 3.60 2.15 94.14 -1,59 8,03 3,75 83.38 -1.37 15,44 6,35 76,99 0,12 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft deg 0.00 0,00 0,00 1.02 1.38 13'2,53 3,33 3.69 115.47 7,93 8.05 ~,79 15.~ 15.88 89.5'5 DLS deg/ 10Oft 0.00 0.58 1.64 1,88 2,89 653.23 740.78 8;36,84 929.08 1020.11 92,4 651,61 87.6 736,98 96.1 829.62 92.2 918,12 91,0 1005,01 27,81 i1.04 74,44 3,65 45.22 14,54 78.99 8.00 68,77 16.15 82,91 11,96 93,45 16,61 86,45 14,25 119,67 18,07 89,78 15,21 29.39 29.62 82.92 48.26 48.92 80.59 4,16 73.36 74.33 80.74 1,99 99,24 100.28 81.77 1,19 126.35 127.26 83,13 1.94 1111.36 1203.54 1295.63 I386.22 1478,76 91,3 1090.78 92.2 1175,11 92.1 1256,61 90.6 1335,09 ?2.5 1414.39 150,16 21,81 92,35 14,28 186,92 25,77' 95,67 11,29 22~,50 29,70 97.69 6,26 2_74,54 30.23 97,29 0,36 321.99 31.82 97,11 -5.62 1~.43 158.08 84.82 4.31 194.47 194,80 86.66 4,41 237.02 237,10 88.49 4.39 281,~ 281,~ 89,92 0,63 329.20 329.25 90.98 1.72 1572,72 1665.53 17~.78 1850,49 1942,23 94.0 1493,54 ?2.8 1569,87 93.3 I643.89 91.7 1714,01 91.7 1782,09 372,35 33.37 97,16 -I1.90 424.90 35,97 98.09 -18,92 481,41 38.94 98,71 -27.21 540,35 41+31 98.86 -36,24 601,72 42.86 100.15 -46.40 379.43 379,62 91,80 1.65 431.75 432.17 92,51 2,85 487.84 488.60 92,19 3.21 546.24 547.44 93.80 2.59 606,8,8 608.65 94,37 1.93 2036,33 2131,04 ~23,31 2S02.20 2780,73 94,1 1849.28 94,7 1913,35 ~,3 1972,87 278,9 2152,88 278,5 2336.33 667.53 46.00 101.30 -58.~ 737,25 48,86 102,54 -73.09 807.75 50,80 103.I2 -88,75 1020.74 48.80 101.96 -135.05 12~.31 48.81 I~,~ -182.20 671.59 674.15 94,99 3.44 739.82 743.42 95,64 3.17 808.56 813.42 96,26 2.16 1016.47 1025.40 97,57 0.78 1220,~ 1234,18 98,49 0,56 3058,77 3336,07 3607.75 3887,59 4202.18 278,0 2.511,93 277,3 2683,01 2.73,7 2859,99 ~.8 3038,78 314,6 323?,06 1445,69 52.84 105,60 -237.40 1~,80 50.97 1~,~ -~3,30 1872.45 48,44 lOS,OS -345,71 208,4.94 51.44 105.12 -401,04 2327,36 49,47 105,18 -46~{,42 1428.96 1448.55 ~,43 1639.89 1665,92 100,14 1841.93 1874.09 100.63 2047,23 2086,14 101,08 2281.39 2328,18 101.51 1.51 0.80 1,08 0.62 4411,32 4690.37 4968.69 5241.62 5516,75 209.1 3373.95 279.1 3550.70 278.3 3728.13 272.9 3?06,49 275,1 4069,90 2487,10 50,20 104,38 -505,19 2.703,02 51.20 102.22 -5~,83 ~17,41 49,60 105,03 -~5,28 3123,95 48.80 101,52 -652,74 332%01 47.60 104,33 %98.56 2435,92 2487,76 101.72 2646,05 2703,60 101.84 2854.44 2917.91 101,97 ~55,~ 3124,40 102,06 ~5,33 3329,44 102,11 0,45 0,70 0,97 1,02 0.88 5791,13 6158,40 6435.04 6710,98 6985.35 2.7'4.4 4272.86 367,3 4515,06 276,6 4701,45 275,9 4890,45 274,4 ~077,60 ~32.86 48,80 1~.96 -758,90 :3807,79 48.70 106,44 -045,13 4012,08 46.60 102,22 -895.83 4212.86 47.00 108,55 -949.18 4413.03 47.00 105.03 -1007,I2 3450.60 3533.07 102.40 1.59 3712,84 3807,8I 102,82 0,72 3910,80 4012,09 102,90 1,36 4104,54 4212,86 DEC 2 4 1996 Naska Oil & Gms Gon~, commls~ion Anc~rage ~)EY C~qLCUI.ATI~ MEASUR~ IH'I'EI~JAL VERTI~ TARGET STATION AZI~JTH LATITUDE DEPARTURE DISPLACEIt~T at AZIMUTH DLS DEF~H DEPTH SECTIOH INCLN, N/-S E/-W deg/. ft ft ft ft deg deg ft ft ft deg lOOft 7262.74 277.4 5262,66 4619.40 49,30 106,44 -1063.20 4495.44 4619.45 103.31 0.91 7444.33 181.6 5380.02 47~.90 50.20 102.22 -1097.45 4629.67 4757.97 103.34 1.84 7631.43 187,1 5300.18 4901,20 49,90 99.41 -1124.37 4770.53 4901,24 103,26 1,16 7910.91 279.5 .5483.54 5111.40 48.10 97.30 -1153.06 4979.18 5111.40 103,06 0.86 8735,00 824.1 6317.18 5628.58 31.75 I21,69 -I309.91 5474.20 ~628,74 I03.46 2,72 T~ FIh~qL ~ IS A PRCk~CTIDN TD T~DEPIt~, 8795.00 60,0 6368.20 5658,49 31.75 121.69 -1326.50 5501,06 5658,73 103,56 0,00 SEPTEMBER 6, 1996 To: DWJ Fm: TAB BW BC Well File 3A-18 96-133 Jack H. 09/09/96 9:23 AM During the p.m. of 9/5, Bobby Foster called from the NS regarding surface casing cement operations on KRU 3A-18. He indicated that returns were lost during the cement job and that he had been told that cement was" at the bottom of the conductor". He indicated he would be stopping at the rig to get more details and monitor the progress of diagnostic and remedial operations. At the time of his call ARCO was planning to run 1" pipe into the hole and attempt to sample fluids and find the TOC behind the 7 5/8" csg.. Cement Job Summary: (Design - 230% excess lead, 30% excess tail) Pumped 391 bbls of lead - Lost Circulation. Pumped 15 bbls lead - no returns Pumped 72 bbls tail - no returns Displaced with 196 bbls - no returns except for a short period Note: The well design is a basic monobore production well with 20" conductor, 7 5/8" surface csg and a 3.5" x 5.5" combination liner/casing string. 9/5 5:50 PM. Denise Petrash, AAI, called to report that 1" pipe had been run to 100'+ with no indication of cement. AAI was finding more pipe to be able to run to approximately 100'. I was asked to approve a top j ob from the depth of the 1" pipe (whether or not there was cement indicated?). I indicated they should run pipe and find TOC, if not then they could log TOC. My intent was to have a factual TOC before recommending any action by AOGCC. 6:15 PM. Spoke to Bobby F. at Parker Rig 245 and we agreed that AAI should find TOC regardless before approval of any remedial action. 9/6 8:00 am. Bobby called and indicated that 1" pipe had been run to 461' with no indications of cement. Circulated 40 Bbls of fresh water at that point. Returns were 9.2 to 8.6 ppg mud and water. One pH measurement spiked at 12 with others 7+ range. Mud was 7-7.5 pH. No cement was evident. Bobby was asked if they could go ahead with a top job at that point. He laughed and said no (were they serious?). He stated that ARCO had ordered a USIT and CBL log from service company. 9/6 11:20 am. B.F. called to say that Kuparuk R. bridge had washed out and there would be no logs run until a unit was able to cross Kuparuk River. Later in the afternoon, Mike Zhangi, AAI, called to indicate that AR~.CO might fly a logging unit in to run logs. 9/7 6:00 PM. Bobby called to say CET and USIT logs had been. He indicated the logging engineer interpreted cement to 750' +/- and possibly higher. 6:30 PM. I spoke with Mike Zhangi who discussed Schlumberger's analysis of CET/USIT logs. The "G" tail cement was as high as 2885' (W. Sak sand. at 3300'), lead cement showed compressive strength development up to 750' with indications of lead as high as 510' but with little compressive strength indicated. Mike proposed runni,ng 1" pipe to 720' and doing a cement job from there. He felt there may be some risk to sticking below 500' and reserved judgment to stop and cement below that point if pipe started to stick. I .agreed with that plan and informed Bobby F. so he could witness and make any onsite decisions. 9/8 9:30 am. Bobby reported that the 1" pipe was run to 550' where it stopped and then pumped and circulated to 562' where it stopped again A cement job was performed at 562' by pumping 40 bbls. fresh water followed by 60 bbls ASIII, 12.1 ppg., cement. Cement appeared at surface with 51 bbls. away. He expected that a leakoff test would be done later Sunday afternoon. ARCO KRU 3A-18 IWELL PERMIT WORK SHEET IINPUT AREA 7/291961 hole csg csg csg csg csg top top bot bot size size wt. grd t&c Igth md tvd md tvd AKR3A18.XLS design mud cmt, cfr grd, ppg 24 16 62.5 h40 w 80 41 41 121 121 200 9 9.875 7.625 29.7 180 Itc 4226 41 41 4267 3302 2588 10 6.75 5.5 15.5 180 Itcmod 8241 41 41 8282 5950 119.5 9.6 6.75 3.5 9.3 180 eue8rd 547 8282 5950 8829 6369 99 11 I Input Pressure/Depth Max whp, psi bhp, psi tvd, ft 1955 3300 6369 grd.,psi/ff 0.21 default 0.10 csg size csg wt. Input Csg Paramenters csg grd csg t&c 16 62.5 h40 w 7.625 29.7 180 Itc 5.5 15.5 180 Itcmod 3.5 9.3 180 eue8rd coll. burst yeild pres. pres. stgth 670 1640 614 479O 689O 721 4990 7000 298 10540 10160 207 I Design Factors Using Various Assumptions I. Worst Case Design: Evacuated Pipe/Evacuated Annulus + 100K# overpull max coll. max burst wt yield csg coll. mud design burst fm design yeild of csg design size pres. press factor pres. press factor stgth +100k# factor 16 670 57 11.8 1640 63 26.2 614 105 5.8 7.625 4790 1717 2.8 6890 1711 4.0 721 226 3.2 5.5 4990 2970 1.7 7000 3083 2.3 298 228 1.3 3.5 10540 3643 2.9 10160 3300 3.1 207 105 2.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I1. Practical Case: Formation Pressure at Shoe- gas to surface wi mud in or outside casing. No overpull mud coll. max(res) burst max(mud) burst wt yield csg coll. less gas design burst surface design surface design yeild of csg design size pres. press factor pres. press factor press factor stgth +Ok# factor 16 670 45 15.0 1640 1955 0.8 57 29.0 614 5 122.8 7.625 4790 1387 3.5 6890 1955 3.5 1615 4.3 721 126 5.7 5.5 4990 2375 2.1 7000 1955 3.6 2658 2.6 298 128 2.3 3.5 10540 3006 3.5 10160 1955 5.2 3235 3.1 207 5 40.7 0 0 0 0 0 0 0 0 0 0 0 0 0 0 III. Cement Volumes and Heights Surf csg Surf csg csg csg ann cmt ht of csg/Inr top of w.r.t. Est'd cmt cmt size shoe vol,cfi vol,cfi cmt length cmt g.I. Fillup collapse collapse 16 121 140 200 115 80 -6 below 1.4 dif¢l pres cdf 7.625 4267 908 2588 12049 4226 7782 above 2.9 540 8.9 5.5 8282 688 120 1431 8241 -6851 below 0.2 3.5 8829 99 99 545 547 -8284 below 1.0 0 0 0 0 0 0 0 0 F ge 1 11/12/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10566 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape .3A-18 ~-.'-I?~ '~-~5~.,°'p 96289 ARC5 960912 I I I SIGNED: ~___~~_~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 11/6/96 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10543 Company: Alaska Oil & Gas Cons Comm Attn- Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 12 X- 13 -~ c[ _ I'7 ~J PRODUCTION PROFILE 9 61 0 0 8 I 1 3A-17 ~'~-1~. CBL 961029 I 1 3A-18 c~ (.o--1 i57'¢ CBL 961031 I 1 3J-19 ~f.¢ - I~ ~ CBL 961101 I 1 1 E-19 ~'~ - O t ~ INJECTION PROFILE 9 61 01 9 I 1 · SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: , .CEIVED t~OV 0 8 1996 An~orage 10/3/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10437 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1Q-2A c~ ~--_ Iflq CBT 960806 I 1 1Y-13 ~- ~t~- INJECTION PROFILE 960820 I 1 , , 1Y-25 'c~<~ - ©'~ PRODUCTION PROFILE. W/DEFT 960821 I 1 ..... 2X-12A ~- i--i~ GAS LIFT SURVEY 960810 I I .... 2 X- 17 c~ ~' - I ~ t PRODUCTION PROFILE 96 081 0 I I _ 3A-!s °i G, - t,~---~ USIT 960907 I 1 _. 3A-18 ~ CBT 960907 I 1 , , 3G-25X ~(~ - ~ :~(~ CBT 960809 I I _., .,- ., SIGNED: ~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ DATE: Chairmarf ~ THRU: FILE NO: Blair Wondzell, P. I. Supervisor'~ FROM: Bobby Foste'-r,~-'~/.-"~ SUBJECT: Petroleum Inspector September 5, 1996 GCXIIEDD.DOC Surface Csg. Cemt. Job KRU - Well 3A-18 PTD # 96-0133 Thursday, September 5,1996: ! traveled this date to ARCO's KRU well 3A-18 after being contacted by Daryl Gladden, Parker Rig Manager, to informed me of a upcoming BOPE test. I arrived at the rig at 11:15 AM and met with Donnie Lutrick, ARCO drilling foreman, and he informed me that while they were cementing the surface casing returns had been lost and cement did not circulate to surface. I discussed the cement job with Donnie and he informed me that 40 bbls. of fresh water had been pumped followed by 404 bbis. Of lead cement at 12.1 lb/gal, followed by 75 bbls. of 15.8 tail and the casing was displaced with 196 bbls. of 9.2 lbs.(weight used to drill hole) of mud. Circulation was lost after pumping the 40 bbls of fresh water and 361 +- bbis. of lead cement. Donnie said that when circulation was lost the casing was reciprocated up and circulation was regained for just a minute and the pipe would not go back down on the fluted hanger. He said no returns were received from this point during the job. We went to the rig and attempted to tag the cement using 116' of 1" pipe and found on cement. Donnie ordered 350' of 1 ' pipe and that was run in the hole for a total of 461' The pipe had to be run several times due to hanging up in the open hole. Samples of the mud and walt cake were made during all of these runs. The highest weight mud was 9.2 lbs./gal and the highest Ph was 11.5 and this was obtained at approximately 125'. After the 1~ pipe was run to 461' Donnie decided to circulate with fresh water. Dowell was rigged up and pumped 40 bbls of fresh water down the 1 ~ pipe at a rate of 1.3 bbls/min at 500 psig. No cement was received at surface and the highest mud weight was 9.2lbs/gal and the lightest 8.7. At this point it was decided to run a Schlumberger CBL and a USIT ( Ultra Sconic Imaging Tool) to find the top of cement. .Saturday, September 7, 1996: Due to the Kuparuk river washing the road out between Prudhoe and Kuparuk the logging was delayed for several hours. A temporary bridge was installed and the logging began at approximately 10:00 AM. Donnie contacted me at 2:00 PM informing me that the logging would be completed by 3:00 PM. I arrived at the rig and we looked at the logs. The top of the cement seemed to be between 700 and 800'. The logs were faxed to Anchorage and reviewed by ARCO personnel. They contacted Jack Hartz and he called me on the slope and informed me that if l agreed, they could pump cement down a 1" pipe to complete the job if the pipe could be run in the hole at least 550'. ! went back to the rig and the pipe was run to a depth of 550'. The pipe hung up and they tied in Dowell and broke circulation with 10 bbls of fresh water. The pipe was then run to 561' and hung up again. Circulation was established but the pipe could not be worked any deeper and 50 bbls of fresh water was pumped followed by 60 bbls of 12.1# ARCTIC Set 3 cement. Good cement returns were observed at the surface after pumping 51 bbls. i departed the location at this point and returned to Deadhorse. ! contacted Donnie this morning and he said the BOPE test went OK and he would do the LOT this afternoon. He also said that all of the 1" pipe had been pulled out of the hole with no problems. I called Jack Hartz and gave him as up date on the progress of the job. Sunday, September 8, 1996: ! received a call from Donnie this date informing me that he was ready to do the LOT. i arrived at the rig and witnessed 2 LOT. The first test was performed after 10' of new formation had been drilled and the hole had been circulated clean. The second LOT was performed after drilling another 20' of formation and the hole circulated clean. The results of these test are attached to this report. SUMMARY: I witnessed the remedial work performed by ARCO on KRU well 3A-18 on the surface casing cement job and the LOT. Attachments: LOT Results furnished by ARCO X Unclassified Classified Unclassified with Document Removed CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: KRU 3A-18 Date: 9/8/96 Donald Lutrick 7 5/8, 29.7#, L-80, BTC MOD Casing Size and Description' Casing Setting Depth: Mud Weight: 8.5 4277' TMD 3288' TVD PPg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT #2 = 940 psi / (0.052 x 3321 ft) + 8.4 ppg = 13.84 ppg Fluid Pumped = 2.21 bbls. Fluid bled back = 2.0 Hole Depth (md)= 4328 Pump output = .085 bps 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 8OO 7OO 6O0 5OO 4OO 3OO 2OO 100 0 . + CASING ~ST STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: K R U 3A - 18 Date: 9/8/96 Donald Lutrick 7 5/8, 29.7#, L-80, BTC MOD Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 4277' TMD 3288' TVD ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT #1 -- 1090 psi / (0.052 x 3301 ft) + 8.4 ppg = 14.7 ppg Fluid Pumped = 2.21 bbls. Fluid bled back = 2.0 Hole Depth (md)= 4298 Pump output = .085 bps 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 7OO 600 500 400 300 200 100 0 LEAK-OFF TEST CASING TEST STROKES , '-.? i , /~_~.?~ .... /'--: ./ . ' ~ t ~' 'i ! ! ."-- ii' .... - .-i7 o~/ ! .-~-~-.L./_:_' ........ / / .. · . ~.'- .: : ..[_CC, C?;- . ' '"" x.." .. · >.%-. -.~ .. .. . · · .. TONY KNOWLE$, GOVERNOR July 30, 1996 ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Drlg Engr Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3A-18 ARCO Alaska, Inc. 96-133 904'FSL, 849'FEL, Sec 07, T12N, R09E, UM 394'FNL, 571'FEL, Sec 17, T12N, R09E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~--hnston - Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept offish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type el Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry F'~ Deepen D Service r~ Development Gas r-~ Single Zone X Multiple Zone 2. Name o! Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 41' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora(:je, AK 99510-0360 ADL 25632, ALK 2565 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 904' FSL, 849' FEL, Sec. 7, T12N, R9E, UM Kuparuk River Unit Statewide Al top of pmduclive interval ({~ TARGET ) 8. Well number Number 308' FNL, 893' FEL, Sec. 17, T12N, R9E, UM 3A-18 #U-630610 At total depth 9. Approximate spud date Amount 394' FNL, 571' FEL, Sec. 17, T12N, RgE, UM 8/1 4/96 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number o! acres in property 15. Proposed depth (MD and TVD) property line 3 A- 1 6 8829 MD 308 @ tarc~et feet 15.8' @ 20' feet 2448 6369 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 49.2° ~umsu,ace 1955 psig At total depth (TVD) 3300 18. Casing program Settinc,! Depth size Specifications Top Bottom Quant~ of cemenl Hole Casir~l We~ht Grade Couplin~l Length MD TVD MD TVD /include sta~e datat 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875' 7.625' 29.7# L-80 LTC 4226' 41' 41' 4267' 3302' 1150 Sx Arcticset III & HF-ERW 330 Sx Class G 6.75" 5.5' 15.5# L-80 LTCMOC 8241' 41' 41' 8282' 5950' HF-ERW 190 Sx Class G 6.75' 3.5' 9.3# L-80 EUE8rdM 547' 8282' 5950' 8829' 6369' Top 500' above Kuparuk 19. To be completed for Red~ll, 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 ~ru~V~e. rtical depth Structural ~. ~ ~r" ': I ~. Conductor ~-~ i- ; Surface Intermediate i (,.. Production d11; / ;~ !j,~i Liner , Perforation depth: measured ~1n,.,t~.'~ 0~1 ~-~ ~"'''' r,-,:-,o C~r. rrl~';~SSt0FI true vertical " .... ~'~i 20. Altachments Filing lee X Properly plat [-] BOP Sketch X Diverter Sketch X Ddlling program X Ddlling fluid program X Time vs depth plot ~ Refraction analysis [~] Seabed report r~ 20 AAC 25.050 requirements X 21. i~hereby certify that the foregoing is true and correct to the best el my knowledge Signed, ~y~~J ~/_,~ Ap ~~~r_~ ~/~' "~ ~'~CommissionTitleuse Onl~/Drill Site Develop. Supv. Date ~/~f./ Permc~r~.~,.~, ~ ]-- I Approval date...~ I See cover letter lor ~ 50-~ ~_...c~_ ,~_ ~_..~' ~; ~ ~) ~ /~ other requirements Con(Jitions el approval Samples required [] Yes J~a No Mud iogrequired [-1 Yes ~ No Hydrogen sulfidemeasures i~ Yes D No Directional surveyrequired ~ Yes D No Required working pressure for BOPE 2M ~ 3M Q 5M Q 1OM [-1 15M O~her:Original Signed By David W. Johnston Approved by Gommissioner the commission Date Form 10-401 Rev. 7~24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3A-18 . . . . . . . . . 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,267')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test,~"~ I._... '~ ~ ~.~.~""~'~ ~A~Z. .... Drill 6-3/4" hole to total depth (8,829') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3A-18 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-4O 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillina Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,955 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3A-18 is 3A-16. As designed, the minimum distance between the two wells would be 15.8' @ 20'. Drillin~ Area Risks- Risks in the 3A-18 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2' casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to~['-ill,,g~avel?~e',ds.~..~, i~., ~.. ~- ...... ANNULAR PUMPING OPERATIONS WELL KRU 3A-18 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3A-18 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3A-18 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. 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 3A surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3560 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7,625 29,7 L-80 3 LTC 4790 4072 6890 5857 5.500 15,5 L-80 3 LTC-M 4990 4 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, [ nc. Pad 3A Well : 18 slot #18 Kuparuk River Unit North SLope, ALaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T by Baker Hughes INTEQ Your ref : 18 Version Our ref : prop1616 License : Date printed : 19-Jul-96 Date created : 30-Apr-96 Last revised : 19-Ju[-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n?O 24 4.812,w149 55 52.391 SLot Location is nTO 24 13.702,w149 56 17.268 SLot Grid coordinates are N 5~7285.109, E 507600.716 SLot Local coordinates are 904.00 N 849.00 W Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North. Report is Limited to clearances Less than 200 DECREASZNG CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.&* Object weL Lpath CLosest approach with 3-D Minimua Distance method Last revised Distance M.D. Diverging from M.D.. PGNS <O-8475'>,,4,Pad 3A 30-Apr-96 354.9 220.0 220.0 PGHS <O-8391)'>,,3,Pad 3A 30-Apr-96 389.5 220.0 220.0 PGNS <O-?630'>,,13,Pad 3A 2-Jan-92 90.2 20.0 325.0 PGNS <O-8024'>,,12,Pad 3A 2-Jan-92 116.0 20.0 1~25.0 PGNS <O-7350'>,,11,Pad 3A 2-Jan-92 140.5 160.0 160.0 Pt;NS <0-?000'>,, lO,Pad 3A ' 2-Jan-92 165.5 220.0 220.0 MHS <0-6400'>,,WS-23,Pad 3A 2-Jan-92 187.9 425.0 425.0 PGIIS <O-?120'>,,8,Pad 3A 2-Jan-92 265.7 160.0 160.0 PMSS <O-7275'>,,7,Pad 3A 2-Jan-92 290.8 300.0 300.0 PGMS <0-7680'>,,6,Pad 3A 2-Jan-92 315.6 20.0 20.0 PGMS <O-8(xSO,>,,5,Pad 3A 2-Jan-92 339.9 325.0 325.0 PGNS <0-8690'>,,2,Pad 3A 2-Jan-92 414.4 160.0 160.0 PGMS <O-9600'>,,1,Pad 3A 2-Jan-g2 440.7 140.0 140.0 PGMS <O-9155'>,,16,Pad 3A 2-Jan-92 15.8 20.0 20.0 PGMS <O-8160'>,,15,Pad 3A 2-Jan-92 40.5 20.0 20.0 PGMS <O-7855'>,,14,Pad 3A 2-Jan-92 64.7 375.0 375.0 17 Version #4,,17, Pad 3A 19-Jut-96 249.4 300.0 300.0 C,~ed W ~o.. For: D PETRASH Date plot'ted: 22-Jui-95 Plot Reference i~ 18 V~r~on C~ordJcmte~ are in feet refer~rnce True Vertical Depths ~RKB (Parer 1~2~5). 450 o JSURFACE LOCATION: ! 904' FSL, 849' FEL SEC. 7, T12N, RgE 450 45O 900 1350 1800 2250 2700 '-~ 3150 0 -I-- Q) 3600 4050 I V 4500 4950 5400 5850 63OO 6750 450 AR C O ALASKA, Inc. Structure : Pad SA Well: 18 Field : Kuparuk River Unit Location : North Slope, Alaska S 76.97 DEG E 5375'(T0 TARGET) ***Plane of Proposal**- East (feet) -> 4-50 900 1550 1800 2250 2700 5150 5600 4050 4500 4950 5400 5850 I I I I I I I I I I I I I I I I t I I I f I I I I RK8 ELEVATION: 82' ~ TARGET LOCATION: 508' FNL, 895' FEL SEC. 17, T12N, RgE TARGET TVD=5972 TMD=8310 DEP=5375 SOUTH 1212 EAST 5236 KOP '1¥D=300 TMD=300 DEP:O 6.00 DLS: 3.00 deg per 100 ft 12.00 18,00 BEGIN TURN TO TARGI-I-~ 22.75 TVD=953 TMD=967 DEP=g7 27.43 32.52 37.86 B/ PERMAFROST TVD=1582 TMD=1683 DEP=420 43.34 48.92 EOC TVD=1891 TMD--2109 OEP--711 T/ UGNU SNDS TV0=1992 TMD=2265 DEP=827 T/ W SAK SNDS TVD=2682 TMD=3318 DEP=1625 MAXIMUM ANGLE 49.17 DEC B/ W SAK SNDS '1'VD=3102 TMD=3961 DEP=2111 7 5/8" CSG PT TVD=3302 TMD=4267 DEP=2542 BEGIN ANGLE DROP TVD=5646 TMD=7851 DEP=5053 B/ HRZ TVD=5797 TMD=8075 DEP=5215 TARGET - T/ UNIT D (EOD) TVD=5972 TMD=8310 DEP=5375 v UN,T c WD:6OO4 TM0:8352 DEP:5402 T/ UNIT B TVD=6024 TMD=8378 OEP--5419 T/ UNIT A TVD=6101 TMD=8478 DEP:5483 'T/ A3 INTERVAL TVD=6127 TMD=8512 DEP=5505 TARGET ANGLE B/KUP SNDS TVD=6216 TM0=8629 DEP=5580 40 DEG ~']~ - ~ z/~" cst ~,T TV]~-~a~ T~D=~Z~ i t i I i i i i i i ! i I I I i I i i i i i J i i 0 450 go0 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 Verficol Section (feet) -> Azimuth 105.05 with reference 0.00 N, 0.00 E from slot #18 45O 450 9OO 1550 1800 JTD LOCATION: J 394' FNL, 571' FEL SEC. 17, T12N, R9E 48.20 DLS: 2.00 deg per 100 ft 44.20 40.20 6v~"~ 3~/~ xo 'rvr~ - $q5o I I i 5850 6300 Created by janes For: D PETRASH Dote plotted : 22-Ju1-96 Plot Reference is 18 Version ~J6. I Coordinates are in feet reference slat ~18. ITrue Vertical Depths ~RKR (Porker ARCO ALASKA,. Inc. Structure : Pad 3A Well: 18 Field : Kuparuk River Unit Location : North Slope, Alaska 100 ~ 20 0 2O I V 40 East (feet) -> 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 300 320 340 ,360 2700 I I I I I I I I I I I I I ~00 100 5OO % 11oo 1300 1aa I I i I I I I I [ I I I I I I I I PROPOSED ;o ' ' ' ;o ' '~ ' ~' ' 'o ............................ 0 4 0 8 1 O0 120 140 160 1 80 200 220 240 260 280 300 320 340 360 East (feet) -> loo 8O 6O 4O 20 (./) o (- 0 20 _+. I 40 V 80 100 120 20" r~UPARUK RIVER UNI~ DIVERTER SCHEMATIC 5 ! ] 5 4 3 2) O I DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' CONDUCTOR 2. SLIP~N WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20' - 2000 PSI DRILLING SPOOL WITH TWO 10' OUTLETS. 5. 10' HCR BALL VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER ..... - ...... ,¢ ~-~ ~'~ EDF3/10/92 I ,6 , I 5 4 I I 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3030 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"-5000 PSI ANNULAR 13 5/8" 5000 PSI STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. Fill BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 30(X) PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8, OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS, TEST BO'I-I'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9, OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUll OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OFTHE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BETESTED TO 5000 PSI HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. · WELL PERMIT CHECKLIST COMPANY/Z X- '_, ' WELL NA'ME/~,~..~ .'~ "/<~ PROGRAM: exp [] dev~ redd, [] serv [] wellbore seg [] ann. disposal para req ~ ADMiNiSTRA¥10N .............................................. 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 drlg 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. ........ ENGINEERING Y N YN .Y N Y N Y N Y N Y N N 14. Conductor string provided .................. .~-/N 15. Surface casing protects ail known USDWs ......... /~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . (~f,/N 17. CMT vol adequate to tie-in long s~ng to surf csg ...... ~ 18. CMT will cover all known productive horizons ......... ~ N 19. Casing designs adequate for C, T, B & permafrost. ..... (~ .N 20. Adequate tankage or reserve pit. ............... ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~ 22. Adequate wellbore separation proposed ............ (~ N 23. 24. REMARKS If diverter required, is it adequate. (~ N Ddlling fluid program schematic & ~=~:l'uip ii-~t ~le;:l;;~t~ .' .' .' .',.J) N 25. BOPEs adequate ....................... ~ N 26. BOPE press ruling adequate; test to ~~ psig.'~ N 27. Choke manifold complies w/APl RP-53 (May 84) ....... (~.PN ~3~-'-~ 28. Work will occur without operation shutdown .......... /~ N 29. Is presence of H2S gas probable ............... ~ N GEOLOGY 30. Permit can be issued w,o hydrogen sulfide measures ..... Y N/,/~ ...~ 31. Dam presented on potential overpressure zones ....... .Y.~., 32. Seismic analysis of shallow gas zones ............. ~_ N 33. ~ condition survey (if off-shore) ............ ~ N 34. Contact name/phone for weekly progress reports .... ,Z.. Y N iexp~oratary only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN TAB~ Comments/Instructions: HOW/lib - A~OR~list rev 4/96 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. i'~0V 1 5 1996 . ~,.,.si~.8 Oil & Gas Cons. * O~e/ * ~v_asKA couPlinG C~VTER * * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3A-18 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22692-00 REFERENCE NO : 96289 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-NOV-1996 11:06 PAGE: **** REEL HEADER **** SERVICE NANiE : EDIT DATE : 96/11/11 ORIGIN . FLIC REEL NAME : 96289 CONTINUATION # PREVIOUS REEL : COM~zFal~r : ARCO ALASKA INC., KUPARUK 3A-18, API #50-029-22692-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 96/11/11 ORIGIN · FLIC TAPE NAME : 96289 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 3A-18, API #50-029-22692-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN1 96289 MILTON LUTRICK SECTION: TOWNSHIP: ~GE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3A-18 500292269200 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES Il-NOV-96 BIT RUN 2 BIT RUN 3 .................. 7 12N 9E 736 227 82.00 82.00 41.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6. 750 7. 625 4277.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-NOV-1996 11:06 3RD STRING PRODUCTION STRING Well drilled 03-SEP through 12-SEP-96 with ARC5 only. Ail data was collected in a single bit run. Log was depth shifted to SWS CBT logged 31-0CT-96. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 96/11/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lVTJMBER: 1 EDITED~RGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8789.0 7835.0 BASELINE DEPTH 88888.0 8710.5 8703.5 8695.5 8671.0 8669.0 8665.0 8654.5 8646.0 8620.0 8617.0 8613.5 8602.0 8593.5 8590.5 8582.0 8579.5 8571.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 88882.5 8705.0 8698.5 8692.0 8665.5 8664.0 8660.5 8649.5 8640.5 8615.5 8611.0 8609.0 8598.5 8589.0 8586.0 8577.0 8575.0 8567.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-NOV-1996 11:06 PAGE: 8557 8544 853 6 8531 8526 8522 8506 5 8495 5 8474 0 8467 0 8446 0 8436 5 8435.0 8429.0 8422.0 8412.0 8406.5 8399.0 8387.5 8383.0 8376.5 8370.5 8361.0 8350.5 8338.5 8327.5 8318.5 83OO. 0 8292.5 8290.0 8285.5 8277.5 8272.5 8261.0 825 6.5 8246.5 8241.0 8232.0 8222.0 8209.0 7840.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 8552.5 8539.5 8532.0 8527.0 8521.5 8518.0 8501.5 8490.0 8467.5 8461.0 8441.0 8432.0 8429.5 8424.0 8417.0 8407.5 84 O1.0 8393.5 8382.5 8378.0 8373.0 8366.5 8356.0 8345.5 8333.0 8322.0 8313.5 8294.0 8286.0 8283.5 8280.0 8271.0 8266.5 8254.0 8247.5 8240.5 8235.0 8227.0 8216.0 8203.0 7834.0 BIT RUN NO. MERGE TOP MERGE BASE The depth adjustments shown above reflect the MWD GR to the CBT GRCH logged by SWS. Ail other MWD curves were carried with the GR. The log was depth shifted to SWS CBT GRCH logged 31-0CT-96 $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-NOV-1996 11:06 PAGE: 4 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 619197 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR 619197 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 619197 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 619197 O0 000 O0 0 1 1 1 4 68 0000000000 RPXJfMWD OH~ 619197 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OP2V~f619197 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OHMM619197 O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~q 619197 O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~M 619197 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8788.500' ROP.MWD 21.064 FET.MWD -999.250 GR.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD -999.250 RPD.MWD -999.250 DEPT. 8500.000 ROP.MWD 26.400 FET.MWD 1.544 GR.MWD 64.540 RPXX.MWD 5.090 RPX.MWD 5.088 RPS.MWD 5.063 RPM. MWD 4.931 RPD.MWD 4.725 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 8000. 000 ROP.MWD RPXX. MWD 2. 602 RPX. MWD R PD . MWD 2. 570 DEPT. 7835.000 ROP.MWD RPXX.MWD -999.250 RPX.MWD RPD.MWD -999.250 il-NOV-1996 11:06 15.469 FET.MWD 2.696 RPS.MWD 2.692 2.735 -999.250 FET.MWD 3.764 -999.250 RPS.MWD -999.250 GR. MWD RPM. MWD GR. MWD RPM.MWD PAGE: 153.995 2.675 114.245 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 96/11/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 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: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8794.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~iE): TDDRILLER (FT): STOP DEPTH 7840.0 12-SEP-96 IDEAL 4.0 4.0 MEMORY 8795.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-NOV-1996 11:06 PAGE: TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 7840.0 8795.0 75 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 31.0 40.0 TOOL NUMBER ARC5 475 6. 750 4277.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.60 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1.570 MUD AT MA~ CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.540 MUD CAKE AT (MT): 1. 590 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *******LWDRUNI******* INTERVAL DRILLED 8000' - 8795' DISTANCE TO BIT: GR=33.2', RES=30.1' $ LIS FORMAT DATA 72.0 72.0 72.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-NOV-1996 11:06 PAGE: 7 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619197 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR 619197 O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR 619197 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 OAPI 619197 O0 000 O0 0 2 1 1 4 68 0000000000 RPSLXLW1 Ot~4~I619197 O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OI~OI 619197 O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OH~f4619197 O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 OH~ff4 619197 O0 000 O0 0 2 1 1 4 68 0000000000 RPD LW1 OFAVk4 619197 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8794. 500 ROP. LW1 21. 064 FET. LW1 1. 617 GR. LW1 RPXX. LW1 3.171 RPX. LW1 3.217 RPS.LW1 3.140 RPM. LWl RPD. LW1 2.946 DEPT. 8500. 000 ROP. LW1 32. 459 FET. LW1 1 . 606 GR. LW1 RPXX. LW1 6.611 RPX. LW1 6.519 RPS.LW1 6.370 RPM. LW1 RPD. LW1 5. 523 DEPT. 8000. 000 ROP. LW1 17. 522 FET. LW1 2. 642 GR. LW1 RPXX.LW1 2. 630 RPX. LW1 2. 721 RPS.LW1 2. 762 RPM. LW1 RPD. LW1 2. 615 74. 342 3. 015 61. 189 5. 995 281. 935 2. 711 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-NOV-1996 11:06 PAGE: DEPT. 7840. 000 ROP. LW1 RPXX. LW1 1000. O00 RPX. LW1 RPD. LW1 86. 035 180. 000 FET.LW1 O. 000 1000. 000 RPS.LW1 1000. 000 GR. LW1 RPM. LW1 40.386 1000.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 96/11/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/11/11 ORIGIN · FLIC TAPE NAME : 96289 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC., KUPARUK 3A-18, API #50-029-22692-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/11/11 ORIGIN · FLIC REEL NAME : 96289 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC., KUPARUK 3A-18, API #50-029-22692-00