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Home My WebLink About180-065 STATE OF ALASKA ALA. .OIL AND GAS CONSERVATION COMM. SON REPORT OF SUNDRY WELL OPERATIONS c41_p-d ' 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other 0 Patches Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 180-065 RECEIVED 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20100-01 n F r. 19 2014 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-05RD AOG CC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G Oil&Hemlock Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,660 feet Plugs measured 9,758 feet true vertical 10,043 feet Junk measured 10,522 feet Effective Depth measured 10,522 feet Packer measured See Schematic feet true vertical 9,908 feet true vertical See Schematic feet Casing Length Size MD ND Burst Collapse Structural Conductor 407' 33" 407' 407' Surface 2,505' 13-3/8" 2,505' 2,505' 3,090 psi 1,540 psi Intermediate Production 10,608' 9-5/8" 10,608' 9,987' 6,330 psi 3,810 psi Liner Perforation depth Measured depth See Schematic feet SCANNED vV.l;\' F! 1 '1L True Vertical depth See Schematic feet U:„, Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 9,298'(MD) 8,790'(ND) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 62 94 168 620 186 Subsequent to operation: 32 151 123 560 140 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 2 Gas ❑ WDSPL❑ GSTOR El WINJ El WAG ❑ GINJ El SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-454 Contact Dan Marlowe Email dmarlowe(a hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature 4f�,,,4 �`- � (� 0,,i, 4., e (907)283-1329 Date 12/19/2014 vl Form 10-404 Revised 10/2012 C�*' ' Z 7` Submit Original Only /� 2�� RBDMS,1t JAN - 4 2015 Dolly Varden SCHEMATIC Well No: D-5RD Haeorp Alaska,LHLC Completion: 12/23/97 CASING DETAIL T / RKB = 41' SIZE WT GRADE CONN ID TOP BTM. 1 ) 2 33" Surface 407' Patch 45'-a8' ; 13-3/8" 61 J-55 12.51 Surface 2,505' Patch 62'-75' b 43.5 N-80 BTC 8.755 Surface 1,277' 9-5/8" 47 N-80 BTC 8.681 1,277' 8,199' 47 P-110 BTC 8.681 8,199' 10,608' �/1 _3_ TUBING DETAIL 3-1/2" 9.2 L-80 Butt. 2.992 41' 9,298' JEWELRY DETAIL NO. Depth ID OD Item 1 41' 3.95 11 Cameron,Type'F',3-1/2"Tubing Hanger 2 41.60' 2.987 4.5 Crossover,4-1/2"Seal Lock Pin x 3-1/2"Buttress Pin 33L 1 3 327' 2.813 4.33 SSSV S. 2,440' 2.867 5.968 PTRO 1180 GLM 14,122' 2.867 5.968 PTRO 1175 GLM 5,307' 2.867 5.968 PTRO 1175 GLM II 6,236' 2.867 5.968 PTRO 1175 GLM 13-3/8" 4 6,702' 2.867 5.968 PTRO 1170 GLM L4 7,223' 2.867 5.968 PTRO 1165 GLM 7,710' 2.867 5.968 PTRO 1160 GLM 8,198' 2.867 5.968 PTRO 1155 GLM Howco ' 8,686' 2.867 5.968 PTRO 1150 GLM Stage Collar @ 6,545 [ 111 9,200' 2.867 5.968 PTRO(3/8"Port)Orifice GLM 5 9,298' 2.97 3.97 HES, No-Go Seal Assembly,10.74',Molded 6 II WM 4 8.13 HES,9-5/8",36#-59 ,4#,'BWD'Permanent Packer 7 9,303' 4 5.02 HES,Seal Bore Extension, 7.17'Long in 8 9,311' 2.992 5.7 HES,Tubing Adapter 5� 9 9,326' 2.813 3.97 HES,'X'Nipple,2.813 10 9,342' 2.992 6 Wire Line Re-entry Guide 9,758' A - HES,9-5/8",47#,EZSV,with Plug Kit Installed 6 +.,��I I' WLM Drilled HES,9-5/8",47#,EZSV, Pushed to BTM 7 B DPM 12/21/97 g I 9,785' 4 7.125 Brown,PBR. II 9,801' 6.5 7.75 Brown,CH Seal Anchor 9 III 9,802' 8.218 4.75 Brown,'3H'Hydraulic Set Packer w/Millout 10 G Zone Extension IV 9,824' 3.725 5.25 Otis,'XN,(3.813"Profile) V 9,836' 4 5.187 Brown,Shear Sub/Entry Guide A B I ( ] OPEN PERFORATION DETAIL II .♦, Btm Top Zone Top(MD) (MD) (TVD) Btm(ND) Amt spf Comments Date III <<,t t.A G-1 9,420' 9,430' 8,896' 8,906' 10' 6' 2-1/2"Gun 08/23/14 G-2 9,457' 9,482' 8,934' 8,956' 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/6/1998 G-3 9,522' 9,547' 8,993' 9,015' 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 9,552' 9,612' 9,020' 9,074' 60' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 IV x G-4 _ 9,657' 9,672' 9,114' 9,128' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 / \ G-5 9,708' 9,723' 9,161' 9,174' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 V B-1 SEE SECOND PAGE FOR ISOLATED PERFORATION DETAIL Fill Tagged @ 10,522' 8-4 12/89 B-4 B Slickline/Fish/Fill Information: EZSV @ , r =, 11/19/14: Installed Pack-Off patch (3' long)45'to 48'. 10,522' 11/19/14: Installed Pack-Off patch (13' long)62'to 75'. Z �; 9-5/8" 10/16/14:SCSSV Assembly @ 9,410'. ETD=9,758'WLM, PBTD=10,522',TD= 10,660' MAX HOLE ANGLE=27.57°@ 8,700' Revised By:JLL 12/19/14 Dolly Varden . 11 SCHEMATIC Well No: D-5RD Hilcorp Alaska,LLC Completion: 12/23/97 ISOLATED PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments HB-1 9,925' 9,970' 9,358' 9,299' 45.00 8.00 Isolated 10,069' 10,078' 9,490' 9,498' 9.00 4.00 Isolated HB-3 10,090' 10,100' 9,509' 9,518' 10.00 4.00 Isolated 10,150' 10,182' 9,564' 9,594' 32.00 4.00 Isolated HB-4 10,220' 10,265' 9,629' 9,670' 45.00 4.00 Isolated 10,286' 10,306' 9,689' 9,708' 20.00 4.00 Isolated HB-5 ' 10,320' 10,370' 9,721' 9,767' 50.00 4.00 Isolated Revised By:JLL 12/19/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 08/22/14-Friday R/U slickline equipment. R/U on well, pressure tested lubricator to 250 psi low/1500 psi high. Equipment tested good. RIH w/3" GS pulling tool, latched and pulled top AA tubing stop @ 5'wlm. POOH. Recovered AA stop. RIH w/same, latched and pulled packoff assembly @ 6'wlm. POOH. Recovered patch. RIH w/same, latched and pulled bottom AD-2 tubing stop, POOH. Recovered AD-2 stop. RIH w/2.70"gauge ring, tagged @ 9,702'wlm, unable to work past. POOH. RIH w/1.75"x 8' pump bailer,worked bailer @ 9,707'wlm. POOH. (note: 9748' MD)OOH. Recovered very small amount of scale. Changed to flapper bottom. RIH w/same w/flapper bottom,worked bailer @ 9,707'-9,708'wlm. POOH. Recovered 1 cup of scale. RIH w/same,worked bailer 9,707'-9,708'wlm. POOH. Recovered 2 cups of scale. Received word to lay down lubricator, secure well. 08/23/14-Saturday R/U ELINE,TEST LUBRICATOR TO 250 LOW 2500 HIGH. RIH WITH 2-1/2" GUN 6 SPF, LOG GUN ON DEPTH AND FIRE SAME, PERFORATING FROM 9,420'-9,430'. POOH AND R/D E-LINE.ALL SHOT FIRED. 08/28/14-Thursday Safety meeting with production and JSA reviews. Rig Up slickline-P.T. LUB and WLV to 2500 PSI-GOOD. RIH w/3" GS w/3" AD-2 Stop to 16'WLM. Set AD-2 Stop. POOH. RIH w/3" GS w/Weatherford Packoff w/spacer pipe w/weatherford packoff to 2'WLM (top)set patch. POOH. RIH w/3" GS w/AA stop to 2'WLM,set, POOH.OOH, rig down. Return well to production. 09/08/14-Monday PERMIT-JSA-WIRELINE MEETING W/PROD. RIG UP SLICKLINE. PRESS TEST LUB AND WLV-GOOD(250 PSI LOW- 1500 PSI HIHG). RIH W/3" GS TO 2' WLM -LATCH AND PULL A STOP. POOH. RIH W/SAME TO 2'W/M. LATCH AND PULL PACKOFF, SPACER, PACKOFF. POOH. RIH W/SAME TO 16'WLM. LATCH AND PULL AD-2 STOP. POOH. RIH W/2.80" G. RING TO 400' WLM. NO OBSTRUCTION. POOH. RIH W/3" B/L BRUSH TO 341'KB. BRUSH SSSV LN FOR 30 MIN. POOH. RIH WI 3"X-LINE W/FXE SSSV(WEATHERFORD SN-13026-R)TO 300'KB. PURGE CONTROL LINE. CONT TO 341'KB-SET VALVE. MAKE SEVERAL ATTEMPTS TO PRESSURE UP CONTROL LINE.WILL NOT PRESSURE UP. SHEAR OFF X-LINE. POOH. RIH W/3" GS AND PRONG TO SAME. LATCH,JAR UP BY HAND FOR 1 HR,SHEAR OFF. POOH. ADD STEM. RIH W/SAME TO SAME.JAR, UP 1 HR BY HAND-SHEAR OFF. POOH. ADD STEM (20'TOTAL)AND 01. RIH W/SAME. HIT 20 500 TO 700#OJ LICKS,SHEAR OFF. POOH. CUT 50'WIRE. RIH WI SAME TO SAME. HIT 30 1000#JAR LICKS,SHEAR OFF. POOH. OOH, LAY DOWN LUB. SECURE WELL FOR NIGHT. 09/09/14-Tuesday Morning safety meeting.Stand by for crew c/o and crane. RIH w/3" GS to 341'KB. Latch, Hit 40 100#Jar Licks,shear off. POOH-cut 50'of wire. Re-head add long stroke oil jars. RIH w/same to 337'KB. Hit 40 1200#jar licks,shear. POOH,cut 50' of wire. RIH w/same to 335'KB. Hit 40 1500#jar licks,shear. POOH, cut 50'of wire. RIH w/same to 332'KB. Hit 40 1600# jar licks,shear. POOH, cut 50'of wire. Lay down lub for crane work.Stand by. RIH w/same to 329'KB. Hit 40 1600#jar licks, shear. POOH, cut 50'of wire. RIH w/same to 327'KB. Hit 40 1600#jar licks, shear. POOH. OOH,secure well. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 09/10/14-Wednesday ATTEND MORNING MEETING. OBTAIN PERMITS. COMPLETE JSA. RIG UP W/L. RIH WI 3"GS WI 5'SPEAR TO 328.5' KB LATCH WT(40 OJ LICKS AT 1500 LBS)TO 324.6' K. SHEAR OFF, POOH. CUT 25'WIRE RE HEAD. RIH WI SAME TO 325' KB WT(40 OJ LICKS)TO 321.9' KB. SHEAR OFF, POOH. CUT WIRE REHEAD. RIH WI SAME TO 323' KB WT(40 OJ LICKS)TO 320'KB.SHEAR, POOH. CUT RE-HEAD. RIH W/SAME TO 320' KB WT(50 OJ LICKS AT 1500LBS)TO 314' KB.SHEAR, POOH. REHEAD. RIH WI SAME TO 314' KB WT(50 OJ LICKS)TO 311' KB.SHEAR, POOH. REHEAD. RIH WI SAME TO 311'KB WT( 50 01 LICKS)TO 307' KB.SHEAR, POOH. LAY DOWN LUB. STANDBY FOR.160 UNIT. RIG UP.160 UNIT. RIH WI 3"GS TO 307' KB WT(3400LB OJ LICKS)TO 303' KB,CAME FREE. POOH. OOH WI GS. DOGS PARTIALLY ROLLED-WI SMALL METAL PIECES FROM FISHING NECK. LAY DOWN TOOLSTRING CUT 25'WIRE REHEAD. RIH WI 3" PR TO 303' KB WT(3500LB OJ LICKS) CAME FREE POOH. OOH WI PR W SMALL PIECES OF FISHING NECK OF SSSV. RIG DOWN W/L SECURE WELL. 09/11/14-Thursday ATTEND MORNING SAFETY MEETING. OBTAIN PERMIT. COMPLETE JSA. RIG UP W/L. RIH WI BOWEN SPEAR TO LATCH FISHING NECK TO 300' KB WT PULL 500LB OVER CAME FREE. POOH. RUN GAUGE RING TO SWALLOW GRAPPLE TO 300' POOH.OOH, NO GRAPPLE. STANDBY FOR TOOLS. DUMP 14 GALLONS OF 15%HCL ACID INTO WELL-LET SOAK FOR 1.5 HOURS. PUMP WATER INTO WELL FOR 10 MIN TO RINSE ACID. RIH W/BOWEN SPEAR W/1.51 GRAPPLE TO 300' KB WT COULD NOT LATCH POOH. RIH WI BOWEN SPEAR W/1.43 GRAPPLE TO 300' KB WT COULD NOT LATCH POOH. RIH WI 2.5" LIB TO 300' KB WT POOH.OOH W/TWO MARKS ON SIDE OF LIB. CLEAN FACE. RIH W/2' LIB TO 300' KB WT POOH.OOH WI IMPRESSION OF EXPANDER MANDREL. CONT.ON NEXT DAY. 09/12/14-Friday CONT FROM PREVIOUS DAY. RIH W/3"JDC WI SPEAR TO LATCH FISHING NECK TO 300' KB WT 800LB OVER PULL CAME FREE SEVERAL TIMES. POOH. RIH W/3"JDC W/SPEAR TO LATCH PACKING MANDREL TO 300' KB COULD NOT LATCH. RIH W/3" PR TO 300' KB WT COULDN'T LATCH -SHEAR. POOH. RIH W/BAIT SUB W/1.77"SPEAR TO 300' KB SET SPEAR. POOH. RIH W/3" PR TO 300' KB LATCH BAIT SUB. POOH. OOH W/BAIT SUB NO GRAPPEL. LAY DOWN LUB-SECURE WELL. ATTEND MORNING MEETING. OBTAIN PERMIT. COMPLETE JSA. DUMP 10 GALLON 15%HCL ACID-SOAK 1.5 HOUR. CHASE W/WATERFLOOD. RIH WI 2.65" CENTRALIZER W/2.25" MAGNET TO 300' KB WT. POOH. OOH WI PIECE OF SCALE. RIH W/BOWEN SPEAR WI 2" GRAPPEL TO 300' KB WT(2X1200LB 0 J LICKS)CAME FREE. POOH.OOH WI SPEAR WITH METAL MARKS ON NOSE. RIH W/2.85" GAUGE RING TO 200'KB WT TO 278' KB FALL TO 300' KB. POOH, RIH W/RELEASABLE SPEAR TO 300' KB WT COULD NOT LATCH POOH. RIH W/2.70 BLIND BOX BEAT DOWN FOR 30 MIN, POOH. RIH W/RELEASABLE SPEAR TO 300' KB WT FRICTION BITES NO LATCH POOH. RIH WI PR SPEAR TO 300' KB WT FRICTION BITES NO LATCH POOH. RIH WI 1"X3' PRONG BEAT DOWN FOR 30 MINS POOH. HEAVY METAL MARKS ON TIP. RIH WI PR SPEAR TO 300' KB WT FRICTION BITES NO LATCH. POOH. RIH W/1.5"X5' PRONG WT FOR 30 MIN. POOH, METAL MARKS ON PRONG. RIH W/BOWEN SPEAR TO 300' KB WT COULD NOT LATCH POOH.STANDBY FOR SPEAR. SPEAR ARRIVES,TOO LARGE TO FIT INSIDE TUBING. MODIFY BOWEN SPEAR TO ACCEPT GRAPPEL. RIH W/MODIFIED BOWEN SPEAR TO 300' KB WT TO LATCH. COULD NOT LATCH POOH. RIG DOWN W/L. SECURE WELL. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 09/13/14-Saturday E-line rig up. RIH with side view camera, arrive at point of interest, 270 ft.good pics, record top 50 ft, pull in to lubricator and begin pumping water. Continue recording top 50 ft. POOH. RDMO. 09/17/14-Wednesday ATTEND MORNING SAFETY MEETING. COMPLETE JSA.OBTAIN PERMIT TO WORK. RIG UP W/L. PRESSURE TEST LUB TO 2000PSI-GOOD. RIG W/PR STYLE FISHING TOOL TO 278' KB LATCH WT(5 OJ LICKS AT 3400LBS)COME FREE. POOH-OOH W/PR MISSING TWO DOGS. RIH W/2" MAGNET TO 278' KB WT POOH.OOH W/PIECES OF SCALE NO DOGS. RIH WI 2.25 magnet to 278' KB WT POOH.OOH W/DOGS FROM PR. RIH WI KINLEY POWER JARS TO 278' KB WT POOH.OOH W/FIRED POWER JARS. PREPARE KINLEY POWER JARS FOR SECOND USE. RIH W/KINLEY POWER JARS TO 278' KB WT POOH. OOH WI FIRED POWER JARS. NO NOTICEABLE MOVEMENT ON EITHER SHOTS. RIH W/3"JDC W/RELEASABLE SPEAR TO 278' KB WT (3 OJ LICK AT 3000 LB) COME FREE. POOH. RIH W/3" PR W/SERRATED DOGS TO 278' KB COULD NOT LATCH, POOH. LAY DOWN LUB. STANDBY FOR TOOLS FOR E-LINE. 09/18/14-Thursday RIG UP SLICKLINE TOOLSTRING ON E-LINE. RIH WI BOWEN OVERSHOT W/ 1"GRAPPLE TO 277' KB WT TO LATCH. WT W/ SPANGS AND OIL JARS FOR 1 HOUR.TOOLSTRING STARTED MOVING AT 2,600 LBS POOH TO 92' KB. PULL OUT OF ROPE SOCKET. RIG UP 0.160 W/L. RIH W/BOWEN OVER SHOT WI 1" GRAPPLE TO 277' KB WT TO LATCH POOH. OOH W/BOTH TOOLSTRINGS. INITIAL E-LINE TS W/DOWNWARD JUNK SHOT EXPANDED TO 3.02".SECOND SLICKLINE TS LATCHED AND PULLED OUT OF ROPE SOCKET CLEAN. RIG DOWN W/L.SECURE WELL.CLEAN AREA. 10/07/14-Tuesday Off load coil tubing equiment from boat and start rigging up same. BOP testing,witness waived by Jim Regg 10/07/14 at 10:37 by Jim Regg. 10/08/14-Wednesday OFF LOAD COIL TBG EQUIPMENT FROM BOAT AND START RIGGING UP SAME. BOP testing witness waived by Jim Regg 10/07/14 at 10:37. 10/09/14-Thursday PJSM &Work permits& Hot work Permits. Start up all equipment.Check oils& Fuel Up. Finish Testing BOP's with Water Flood 250 low 2500 psi high. PJSM. Make Stabbing Coil into inj. Make up lubricator&tools. Make up to Well& Pressure Test Stack to 2500 psi. RIH,Tag Fish @ 284'Coil Tubing MD. Milled down to 286.6'. Cont milling down on Fish @ 290'. POOH.Close Swab.Shut down for the night. 10/10/14-Friday Morning Safety Meeting. Rig up coil.Test lubricator to 2500 psi. RIH,tagged up at 286.7',started milling with carbide mill, not making any hole. POOH. Changed out mill to HC mill. RIH to continue milling f/286.7 ft, milled to 287.2 ft CTM. Pooh, secured well for night. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 10/11/14-Saturday TEST STACK 250 PSI LOW AND 2500 PSI HIGH.GOOD TEST. BLEED OFF TO 100 PSI AND OPEN WELL,42 PSI ON WELL.START TIH WITH DIAMOND MILL. DRY TAG AT 287.4'.START PUMPING .75 BBLS PER MIN. 101 PSI ON WELL AND 717 PSI, CIRCULATE PRESSURE,START MILLING ON LOCK. DOWNHOLE MOTOR STALLING, PICK UP WHEN SETTING 5 K DOWN. CONSTANTLY HAVING TO PICK UP TO CONTINUE MILLING. POOH. 3620#DOWN CIRCULATE RATE .8 BBLS PER MIN AT 1006 PSI. OUT OF HOLE AND SHUT WELL IN FOR NIGHT. 10/12/14-Sunday HOLD SAFETY MEETING WITH CREW AND SERVICE EQUIPMENT. CHECK MILL,95%OF DIAMOND BUTTONS ARE GONE. LAY OUT MILL AND MAKE UP CARBIDE 5 BLADE MILL.TEST LUB TO 250/2500 PSI,GOOD TEST. BLED OFF TO 100 PSI.OPEN WELL TO 100 PSI ON WELL.START TIH. TAG UP AT 286.9'CTM.START MILLING ON FISH CIRCULATING AT.8BBL/MIN 899 PSI CIRCULATING PRESSURE AND 105 PSI ON WELLHEAD. KEPT STALLING OUT. PICK UP HAVING SOME DRAG. POOH TO INSPECT MILL. OUT OF HOLE. EVERYTHING LOOKS GREAT.SOME WEAR ON O.D. OF THE MILL.TEST LUB 250/2500 PSI. GOOD TEST. BLEED OFF TO 100 PSI OPEN WELL 110 PSI.TIH WITH MILL. TAG FISH AT 286.9 CTM. CONTINUE MILLING ON FISH,STALLING OUT CONSTANTLY HAVING TO PICK UP 5'TO RELEASE DRAG SETTING DOWN BETWEEN 500#-1000#. DECIDED TO POOH. FINAL DEPTH 287.3 CTM. OUT OF HOLE AND RIG DOWN TO COIL TUBING BOPS AND START RIGGING UP SLICKLINE. PRESSURE TEST LUB TO 250/2500 PSI, GOOD TEST.TIH WITH 2.5" MAGNET TO 306'SLM. POOH,SHUT IN WELL. RECOVERED 2 OZ OF METAL. MAKE 3 RUNS WITH 1.5" MAGNET WITH A 2.5 OD.CENTERLIZER ABOVE TAG 306'SLM AND POOH WITH NO METAL. MAKE UP 2.77" LIB AND TIH TO 306'TAG POOH AND LAY DOWN LUB. FOUND ON LIB WHAT LOOKS LIKE THE TANG ON THE SPEAR GRAPPLE LOOKING UP. 10/13/14-Monday HOLD SAFETY MEETING WITH CREW.SERVICE EQUIPMENT. MAKE UP 1.70" FLAT BOTTOM MILL.TEST LUB TO 250/2500 PSI.GOOD TEST. BLED OFF TO 100 PSI AND START IN HOLE. TAG UP AT 292', BREAK CIRCULATION AT.70 BPM AT 840 PSI 291.8.START MILLING THE ID OF X LOCK. BROKE THRU AT 292.5'. PICK UP AND SHUT DOWN PUMP. SLACK OFF TO 295', POOH. OUT OF HOLE AND CHANGE OUT MILLS TO 2-13/16"TAPERED MILL.TEST LUB TO 250/2500 PSI,GOOD TEST. BLED OFF TO 100 PSI OPEN WELL AND TIH TO 332',TAG HARD. POOH WITH MILL. RIG DOWN COIL TUBING IN PREPARATION FOR SLICKLINE IN THE MORNING. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 10/14/14-Tuesday HOLD SAFETY MEETING WITH CREW AND START RIGGING UP SLICKLINE.TIH WITH 1-1/4" LIB,TAG 348'SLM. POOH. LAY OUT LIB. LIB SHOWS OBSTRUCTION AT OPENING OF X LOCK. MAKE UP BOWEN 1.75 SPEAR GRAPPLE AND TIH WITH SAME. TAG FISH AT 348'WORK SPANG JARS TO LATCH FISH,ONLY GETTING 400#OVERPULL THEN FALLING OFF. POOH. OUT OF HOLE. FOUND BOTTOM BULLNOSE DAMAGED. RIG UP COIL TO GO MILL OUT ID. PRESSURE TEST LUB TO 250/2500 PSI, GOOD TEST. BLEED OFF TO 100 PSI AND OPEN WELL.TIH WITH 1.70 MILL. TAG AT 330.8'START MILLING, MILLED DOWN TO 331.8', MOTOR STALLED. POOH TO CHECK MOTOR. OUT OF HOLE. MOTOR FROZE UP. RIG DOWN COIL AND RIG UP SLICKLINE. RUNNING MAGNET,GETTING LOTS OF DEBRIS AND SHAVINGS. RUN LIB, FOUND THAT ID IS STILL BLOCKED AND WE ARE DOWN TO THE LOCKS. MAKE UP SPEAR AND TIH TO TRY TO LATCH FISH. NO GOOD. PICKING UP 200#OVERPULL AND SLIPPING OFF. 10/15/14-Wednesday HOLD SAFETY MEETING WITH CREW AND SERVICE EQUIPMENT. START TESTING BOPS WHICH WAS WAIVED AS PER MR. JIM REGG WITH AOGCC ON 10-13-14 09: 34AM, 250 LOW AND 2500 HIGH TEST. RIG UP COIL TUBING. MAKE UP TOOLS 1.70 OD MILL TO CLEAN OUT ID OF LOCK. PRESSURE TEST LUB 2500 PSI,GOOD TEST. BLEED OFF TO 100 PSI.OPEN WELL AND TIH TO FISH.TAG FISH AT 334.1 CTM.START MILLING,AT 6PM STARTED SPUDDING ON FISH, FISH FELL 7"TO 334.9'. POOH AND RIG DOWN COIL TUBING. START RIGGING UP SLICKLINE. TIH WITH 1.8", 1.75"GRAPPLES ONLY ABLE TO GET FRICTION BITES. MAKE UP AND RUN IN HOLE WITH A 1.35"SWEDGE.TAG FISH AND WORK SPANGS ON FISH. FISH FELL DOWN HOLE TO 348'. POOH. MAKE UP 1.75 SPEAR AND TIH TO 348'.TRY TO LATCH FISH AND FISH FELL DOWN HOLE.TIH AND TAG FISH AT 5,217'SLM.TRY TO LATCH FISH, BIT NO GOOD. POOH. GOT HUNG UP AT 4,340'SLM.ABLE TO WORK FREE. CONTINUE POOH. GOT HUNG UP AGAIN AT 4,151'. LOST ALL SPANG ACTION. BUILD UP WELL PRESSURE AND TRY TO FLOW WELL WITH GAS LIFT AT 700 PSI. PULL BIND ON STRING, NO GOOD. WORK SLICKLINE WHILE PUMPING 1 BPM AT 700 PSI TOTAL PUMP 37 BBLS, NO GOOD.WAIT ON CUTTER BARS. 10/16/14-Thursday HOLD SAFETY MEETING ABOUT DROPPING CUTTER BAR. DROP CUTTER BAR,CUT WIRE AND POOH WITH WIRE. GOT ALL WIRE BACK. MAKE UP NEW TOOL STRING. MAKE UP 2.5 EARTH MAGNET.TIH AND TAG 4,173', FELL THRU,TAG 4,207' FELL THRU, POOH. FOUND METAL SHAVING. MAKE UP 2"JDC AND TIH TO 4,220' LATCH CUTTER POOH. MAKE UP AND TIH WITH 2.5 MAGNET TO 5,283'TAG TOOL STRING. POOH AND FOUND METAL SHAVINGS.TIH WITH 2.67" FLUTED CENTERLIZER AND 2" .5 JDC LATCH AND POOH.TOOL STRING FREE. OUT OF HOLE. HAD 2/3 OF EXPANDER MANDREL STUCK ON ROPE SOCKET.TIH WITH 2.67" FLUTED CENTERLIZER AND 2.5" MAGNET AND TIH TO 5,301',TAG POOH. FOUND SHAVING ON MAGNET. MAKE UP AND RUN 2.5 JDC AND LATCH BOWEN SPEAR AND TRY TO LATCH FISH. FRICTION BITE. PULL FREE AND POOH WITH BOWEN SPEAR AND LAY DOWN SAME. MAKE UP AND RUN IN 2.67" FLUTED CENTERLIZER AND 2.25 BRUSH TO 5,301'.SPANGED ONE TIME, FISH FELL THRU X-NIPPLE AT 9,326'. POOH. TIH WITH 2.5" PR SPEAR TO 9,326'TRY TO LATCH 2 TIMES. FISH FELL OUTSIDE THE TUBING TO 9,410'. DO NOT TAG. POOH AND RIG DOWN SLICKLINE. RIG UP COIL TUBING.TIH TO 2,500'START BLOWING COIL DRY.START RIGGING DOWN COIL. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 10/17/14-Friday HOLD SAFETY MEETING.WAIT ON CRANE WHILE BACK LOADING COIL TUBING. RIG UP LUB AND 1000 PSI, GOOD TEST. TIH WITH 3-1/2" BRUSH.WORK BRUSH FROM 330'-360' POOH. RIG DOWN LUB FOR BOAT. RIH W/3"X-LINE W/2.81"X LOCK WITHOUT PACKING TO 348' KB-SET LOCK-POOH. RIH W/CHECK SET TOOL TO SAME-JAR DOWN-POOH. OOH, PIN SHEARED.GOOD SET. RIH W/3"GS TO 348'KB-LATCH AND PULL-POOH.OOH W/LOCK. RIH W/3"X-LINE W/2.81 PLUG BODY TO SAME-SET POOH. RIH W/2 1/2 JUC W/EQ PRONG TO SAME-SET. P/T TUBING TO 1,000 PSI,WOULD NOT HOLD. RIH W/2 1/2"JUC TO 348' KB LATCH W/TOOL, POOH. OOH NO PRONG PIN. RIH W/2 1/2"JDC TO SAME, LATCH WI TOOL POOH. OOH, NO PRONG, PIN SHEARED. RIH WI 2 1/2"JDC WI OIL JARS TO 348' LATCH WI TOOL POOH. OOH WI PRONG. RIH W/3" GS TO SAME LATCH AND PULL PLUG. RIG DOWN SLICKLINE SECURE WELL FOR NIGHT. RETURN TO PRODUCTION. 10/18/14-Saturday TGSM. MOVE EQUIPMENT. GATHER TOOLS NO LONGER NEEDED AND SENT TO SHOP ON BOAT. STAND BY FOR CRANE (WORKING W/DRILLING). RIH WI DUAL PRESS TEMP GAUGES TO 41'KB, STOP 5 MIN, CONT IN HOLE AT 30 FPM TO 370' KB. CONT AT 60 FPM TO 9,600' KB,STOP FOR 10 MIN, POOH AT 60 FPM STOPPING 50' BELOW AND 50'ABOVE EACH GLM. SLOW TO 30 FPM AT 370' KB. OOH W/GAUGES. DOWNLOAD DATA. GOOD. LAY DOWN SECURE WELL FOR NIGHT. GATHER DATA CHARTS AND SPYDER RECORDER. 10/19/14-Sunday TGSM. RIG UP. STAND BY FOR CHOPPER WI VALVES.S/I AND EQUALIZE TUBING AND CASING. RIH WI 3 1/2 DAINELS KOT W/1 5/8 JDS TO 5,307' KB. LOCATE, HAD TO WORK TOOLS TO GET GOOD LATCH. HIT 5 JARS AT 1200#CAME FREE, POOH. OOH W/#3 GLV.VALVE LATCH WAS BENT. RIH WI SAME TO 4,122' KB. LOCATE, LATCH AND PULL. POOH. OOH W/ #2 GLV. RIH WI SAME TO 2,440' KB. LOCATE, LATCH AND PULL. POOH. OOH W/#1 GLV. RIH WI SAME WI RK W/#1 GLV (PTRO 1180#)TO 2,440' KB. SET, POOH. RIH WI SAME WI#2 GLV(PTRO 1175#)TO 4,122' KB. SET, POOH. RIH WI SAME WI#3 GLV(PTRO 1175#)TO 5,307'KB. SET, POOH. HAVE PROD FLOW WELL.WELL FLOWING GOOD. S/I PROD. RIH W/3" X-LINE AND PRONG WI BXE SSSV TO 315' KB. PURGE LINE. CONT TO 348' KB SET SSSV. PRESS UP CONTROL LINE,GOOD. SHEAR OFF. POOH. CLOSURE TEST FAIL. RIH WI DD HOLE FINDER TO 70' KB SET.WOULD NOT PRESSURE UP. POOH WI HOLE FINDER. RIH WI 3" GS WI AD2 STOP TO 57' KB,SET, POOH. RIH WI SAME WI WEATHFORD PO WI SPACER WI WEATHFORD PO(14')TO 43.5'KB,SET, POOH. RIH W/SAME WI A STOP TO 43' KB,SET, POOH. CLOSURE TEST PASSED ON SSSV. RIG DOWN SLICKLINE. 11/04/14-Tuesday(Previously unreported) ATTEND MORNING SAFETY MEETING. STANDBY FOR XOVER TO ARRIVE ON MORNING FLIGHT. RIG UP SLICKLINE. P/T LUB AND WLV TO 2500 PSI, GOOD. RIH/W 3"GS TO 43' KB. LATCH W/T. POOH W/3 1/2"A STOP. RIH W/SAME TO 43.5' KB. LATCH W/T. POOH WI 14' PATCH. UPPER ELEMENT MISSING. RIH WI SAME TO 57' KB. W/T SHEAR. POOH, REPIN. RIH WI SAME TO SAME WIT. LATCH. BEAT UP 30 MINS,CAME FREE. POOH W/AD-2 STOP. RIH W/3"GS WI PRONG TO 315' KB. LATCH W/T. POOH WI SSSV. PACKING DAMAGED. PULL SSSV APART. INSIDE SEALS RIPPED&SEAT SCARRED.SSSV BAD. RIH WI 3"OM-1 KOT WI 1 5/8"JDS TO 6,243' KB.SET DOWN W/T. LATCH WIT. POOH WI GLV STATION 4. REBUILD KOT. RIH WI 3"OM-1 KOT WI 1 5/8"JDS TO 9,200' KB. LATCH W/T. POOH WI#10 ORIFICE. RIH W/SAME TO 8,686' KB. LOCATE W/T.CANNOT STAY LATCHED. POOH. OOH SWAP SLICKLINE UNITS. CLEAN AND SECURE AREA AND WELL. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-05RD 50-733-20100-01 180-065 8/22/14 11/19/14 Daily Operations: 11/05/14-Wednesday MORNING SAFETY MEETING.JSA-PERMIT. RIG UP. RIH WI 3 1/2 OM-1 WI 1 5/8 JDS TO 8,685' KB. LOCATE, LATCH AND PULL, POOH WI VALVE. RIH WI SAME TO 6,702' KB. SET DOWN AND LATCH#5 GLV. POOH WI VALVE. RIH WI SAME TO 8,198' KB. LOCATE, LATCH AND PULL, POOH WI VALVE. RIH W/SAME TO 7,710' KB. LOCATE, LATCH AND PULL, POOH WI VALVE. RIH WI SAME TO 7,223' KB. LOCATE, LATCH AND PULL, POOH W/VALVE. RIH W/SAME WI RK RUN TOOL W/#4 GLV(PTRO 1175#)TO 6,236' KB. SET VALVE. POOH. RIH W/SAME WI#5 GLV(PTRO 1170#)TO 6,702'KB. SET VALVE. POOH. RIH W/SAME W/#6 GLV(PTRO 1165#)TO 7,223'KB. LOCATE, SET DOWN,TRY TO SET VALVE.VALVE WOULD NOT STAY IN POCKET. POOH WI VALVE.ADD K JAR AND CHANGE TO LONG SPANGS. RIH W/SAME WI#6 GLV(PTRO 1165#)TO 7,223'KB. LOCATE,SET DOWN, SET VALVE. POOH WI KOT. LAY DOWN. SECURE WELL FOR NIGHT. 11/06/14-Thursday ATTEND MORNING MEETING.JSA-PERMIT. RIG UP SLICKLINE. RIH W/3 1/2"OM-1 KOT WI RK RT WI#7 GLV(PTRO 1160)TO 7,710' KB. LOCATE WIT. SET VALVE. RIH WI SAME WI GLV#8 (PTRO 1155)TO 8,798' KB. LOCATE W/T.SET VALVE. 11/07/14-Friday CONTINUE RUN FROM PRIOR DAY WITH GLV#9. RIH W/3 1/2" OM-1 KOT WI RK RT/W GL ORFICE (3/8" PORT)TO 9,200' KB.SET ORFICE, POOH. LAY DOWN LUB SECURE AND CLEAN AREA AND WELL. PIN UP SSSV. RIG UP SLICKLINE. RIH W/3 1/2"XLINE R/T W/PRONG WI SSSV TO 327' KB W/T, SET. HAVE PRODUCTION TEST. GOOD.SHEAR OFF, POOH. REDRESS PACKOFF'S THEN MAKE UP PATCH 14' LONG. RIH W/3" GS W/3 1/2"AD-2 STOP TO 17'WIT. SET,SHEAR, POOH. RIH WI SAME WI PATCH 14' LONG TO 3'WIT.SET, SHEAR, POOH. RIH WI SAME W/3 1/2"A STOP TO 3'WIT. SET, SHEAR, POOH. RIG DOWN CLEAN AND SECURE AREA. 11/13/14-Thursday JSA/TGSM. RIG UP ON D-5, P/T 2000 PSI (GOOD). RIH W/3 1/2 GS TO 2WL WIT, NO LATCH, POOH.ADD KJ. RIH WI 3 1/2 GS TO 2WL W/T, LATCH, POOH W A-STOP. RIH W/3 1/2 GS TO 4WL, LATCH PATCH, POOH WI PATCH. RIH W/3 1/2 GS TO 17WL, LATCH AD-2 STOP, POOH W/STOP. RIG DOWN W/L. 11/14/14-Friday SAFETY MEETING. PERMIT AND JSA. RIG UP. RUN IN HOLE WITH CALIPER TO 320FT W/L. PULL OUT OF HOLE WITH CALIPER /LOGGING UP. RIG DOWN. START ANALYZING CALIPER LOG. 11/19/14-Wednesday RIG UP P/T 2500 PSI. GOOD. RIH W/PRONG TO 344' KB W/T. KNOCK OUT KOBES. POOH. RIH W/3 1/2 GS TO 342' KB W/T. PULL A-STOP. POOH. RIH W/3 1/2 GS TO 344' KB W/T. PULL W-PACK OFF PLUG. POOH. RIH W/3 1/2 AD2-STOP ON GS TO 75' KB.SET AD2-STOP. POOH. RIH W/12'5" PATCH W/W-PACK OFF ON GS TO 62' KB W/T.SET PATCH. POOH. RIH W/13'5" PATCH W/W-PACK OFF ON GS TO 48' KB WIT. CANT SET PATCH. POOH. POOH REBUILD W-PACK OFF. RIH W/13'5" PATCH W/W-PACK OFF ON GS TO 48' KB,SET. POOH. RIH W/3 1/2 A-STOP TO 45' KB POOH. OOH STAND BY FOR TEST. TEST GOOD. RIG DOWN. XHVZE Ima~Oroject Well History File CoverOge This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J ~_-~_ ~ Well History File Identifier Organizing ~o,~ RESCAN · ~'~' Color items: DIGITAL DATA [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT~MARIA WINDY OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ¢/?. O(~ IS/ Project Proofing ~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation ? x 30 = ~-/~/0 BY: BEVERLY RoB~SHERYL MARIA WINDY Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES IF NO IN STAGE '~ , PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNIRG I$ COMPLETE AT THIS POINT UNLESS SPECIAL A'i'TENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS/ General Notes or Comments about this file: Quality Checked 12/10102Rev3N OTScanned.wpd fly o OF 4,� THE STATE a:16 Gat. f rz ,= 333 west Seventh Avenue :21i/ GOVERNOR SEAN PARNELL Anchorage, Alaska 99501 3572 ✓� hart ; Jain. 907.279. 433 SCNNNEV JUL 2 9 2014 Dan Marlowe Operations Engineer I (� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools, TBU D-05RD Sundry Number: 314-188 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /9. ev) 44—Cathy P. ' oerster 141-ay - Chair / DATED this 4 day of April, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ' 14y 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations 0 Perforate 9 Pull Tubing 9 Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. Run G/L Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory 0 Development 0 N 180-065• 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99516 50-733-20100-01 W 7.If perforating: 8.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes 0 No 9 , Trading Bay Unit/D-05RD. 9.Property Designation(Lease Number): 10.Field/Pool(s): P1y3 ADL0018729 McArthur River Field/Middle Kenai G Oil Pool r I4tret..6 k 04 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,660 • 10,043 . 10,522 • 9,908 - 9,758 . 10,522 ' Casing Length Size MD TVD Burst Collapse Structural Conductor 407' 33" 407' 407' Surface 2,505' 13-3/8" 2,505' 2,505' Intermediate Production 10,608' 9-5/8" 10,608' 9,987' 6,330 psi 3,810 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic - See Schematic 3-1/2" 9.2#/L-80 9,298 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Schematic See Schematic- 12.Attachments: Description Summary of Proposal 9 ' 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 , Exploratory ❑ Stratigraphic 0 Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/1/2014 Oil 9. Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature :;g.... riabehre.-- Phone (907)283-1329 Date 3/25/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test Lr7 Mechanical Integrity Test- 0 Location Clearance ❑ Other: eV 25Y QS L f�v!egTe7;-S t RBDMS° MAY 1 0 2014 Spacing Exception Required? Yes ❑ No [l Subsequent Form Required: /p - V O eY f APPROVED BY / Approved by: 9-t �ALejCOMMISSIONER THE COMMISSION Date: 4__76 _/eL— lil l'i PIO -5/14411 r. . `i i1 Submit Form and Form 10-403(Revised 1 012) App / dRic^n idAr Lmonths from the date of approval. Attachments in Duplicate Well Work Prognosis Well: D-05rd xi!carp Alaska,LLC Date: 03/25/14 Well Name: Trading Bay Unit D-05rd API Number: 50-733-20100-01 Current Status: Producer(Gas Lift) Leg: Leg#A-2 (NW corner) Estimated Start Date: 06/01/2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 180-065 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office:907-777-8420 Cell: 985-867-0665 Current Bottom Hole Pressure: -3,191 psi @ 9,053'TVD 0.35 psi/ft at mid pert of G-zone Maximum Expected BHP: -3,300 psi @ 9,053'TVD 0.36 psi/ft at mid perf of G-zone Max.Allowable Surface Pressure: -0 Psi static using 0.435 psi/ft SW gradient to surface Brief Well Summary The D-05RD was initially completed in 1980 as a Hemlock producer and was converted to G-zone only in 1997 after 2.3mmbo cumulative production and final rate of 30bopd at 92%water-cut. Initial G-zone rate was 140bopd at 50% water-cut. Despite the low initial rate, no additional reperforating or stimulation work was performed and the well was shut-in in 2004 at a 10bopd rate and 80%water-cut. In 2012, production was re-started with a new gas-lift design and 40- 60 bopd rates with a 60-80%water-cut and mid-perf FBHP of 960psig. A Tubing Patch was installed in 2012 from 47'-61'to isolate a casing by tubing leak Procedure: 1. At least one day prior to rig move, stop lift gas to well and bleed down tubing and casing. 2. Skid rig and RU HAK Rig 1 over D-05rd well slot. 3. RU slick-line, RIH and set plug inside seal assembly. �Y 4. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 5. RU E-line and cut tubing in the middle of the first full joint of tubing just above the packer(-9,275'). 6. RD E-line. Circulate FIW to ensure tubing and casing are full. POOH laying down tubing and GLMs. 7. Scrape 9-5/8" casing to -9,275'. 8. RIH and wash over tubing stub to packer top. Circulate well clean and swap out fluids to clean FIW. 9. Pressure test casing to 2,500 psi and chart. POOH with same.- 10. POOH 200' and PU storm packer. RIH and set same at 200' and hang off string. Pressure test to 1500 psi and chart. Release from storm packer, POOH. Replace tub' d. AT: 11-‘11. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. Retest all flange breaks to 2,500 psi. 12. MU Overshot assembly and latch onto the tubing stub/seal assembly. 13. POOH, LD cut tubing joint and seal assembly. 14. Burn over and retrieve production packer. 15. RIH w/E-Line caliper log to 9,400'. 16. RIH and clean out to HES EZSV at 9,758' 17. Re-perforate G-Zone/ 18. POOH to top perf circulate gun gas to ensure well is static, POOH laying down guns. 19. PU, RIH with packer and seal bore extension and set at^'9,300'. 20. POOH laying down work string. •. • Well Work Prognosis Well: D-05rd Hilcorp Alaska,LLC C Date: 03/25/14 21. PU and RIH with Gas lift Completion 22. ND BOP, NU wellhead and test. 23. Turn well over to production. 24. Conduct a no-flow test within 2 weeks after stabilized flow and water cut is achieved. 7 NnT ‘eR Attachments: G, SSSS 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. New Wellhead Diagram Dolly Varden .. ti SCHEMATIC Well No: D-5RD Hilcorp Alaska,LLC Completion: 12/23/97 CASING DETAIL RKB = 41' SIZE WT GRADE CONN ID TOP BTM. 1 2 33" Surface 407' a 13-3/8" 61 J-55 12.51 Surface 2,505' 43.5 N-80 BTC 8.755 Surface 1,277' 9-5/8" 47 N-80 BTC 8.681 1,277' 8,199' 47 P-110 BTC 8.681 8,199' 10,608' 3 TUBING DETAIL 11 3-1/2" 9.2 L-80 Butt. 2.992 41' 9,298' JEWELRY DETAIL NO. Depth ID OD Item 1 41' 3.95 11 Cameron,Type'F',3-1/2"Tubing Hanger ' 2 41.60' 2.987 4.5 Crossover,4-1/2"Seal Lock Pin x 3-1/2"Buttress 33" Pin 3 341' 2.813 4.33 HES,'XXO' SSSV(2.813 I.D.),HES SSSV Installed 2,427' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK 4,109' _ 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK_ II 5,285' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK 13-3/8" 6,243' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK 4 I 6,702' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK 4 7,226' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK III 7,718' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK Howco 8,207' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK Stage Collar L 8,697' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK @ 6,545' I 9,216' 2.867 5.968 McMurry Maccco,3-1/2"SMO-2 GLM,1-1/2",RK 5 9,298' 2.97 3.97 HES, No-Go Seal Assembly,10.74',Molded 6 9,300' LM 4 8.13 HES,9-5/8",36#-59,4#,'BWD'Permanent Packer 7 9,303' 4 5.02 HES,Seal Bore Extension, 7.17'Long 8 9,311' 2.992 5.7 HES,Tubing Adapter 5 \ 9 9,326' 2.813 3.97 HES,'X'Nipple,2.813 y s 10 9,342' 2.992 6 Wire Line Re-entry Guide ♦'�►+t *t 9,758' 6 ��Ai I I::* A WLM - HES,9-5/8",47#,EZSV,with Plug Kit Installed i 7 : 9,797' Drilled HES,9-5/8",47#,EZSV, Pushed to BTM 8MID B - - DPM 12/21/97 _ I • 9,785' 4 7.125 Brown,PBR. 9 G 2 II 9,801' 6.5 7.75 Brown,CH Seal Anchor 10 - G 3 Brown,'3H'Hydraulic Set Packer w/Millout G-4 III 9,802' 8.218 4.75 Extension b G-4 IV 9,824' 3.725 5.25 Otis,'XN,(3.813"Profile) A G-5 V 9,836' 4 5.187 Brown,Shear Sub/Entry Guide B OPN PERFORATION DETAIL IIin Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date Ill 4 G-2 9,457' 9,482' _ 8,934' 8,956' 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/6/1998 .��.A! i- -- G-3 9,522' 9,547' 8,993' _ 9,015' _ 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 MI 9,552' 9,612' 9,020' 9,074' 60' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 G-4 119,657' 9,672' 9,114' 9,128' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 G-5 9,708' 9,723' 9,161' 9,174' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 IV SEE SECOND PAGE FOR ISOLATED PERFORATION DETAIL V Bi Fill Tagged @ 10,522' B-4 12/89 - B-4 Slickline/Fish/Fill Information: EZSV @ B-5 a. 8/11/12: Installed Weatherford Pack-Off patch(14' long)47'to 61'. 10,522' b. 8/11/12:2.72"GR tagged up at 9,736'. \ -5/8" ETD=9,758'WLM, PBTD=10,522',TD= 10,660' MAX HOLE ANGLE=27.57°@ 8,700' Revised By:TDF 10/21/2012 Dolly Varden , H SCHEMATIC Well No: D-5RD Hilcorp Alaska,LLC Completion: 12/23/97 ISOLATED PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments HB-1 9,925' 9,970' 9,358' 9,299' 45.00 8.00 Isolated 10,069' 10,078' 9,490' 9,498' 9.00 4.00 Isolated HB-3 10,090' 10,100' 9,509' 9,518' 10.00 4.00 Isolated 10,150' 10,182' 9,564' 9,594' 32.00 4.00 Isolated HB-4 10,220' 10,265' 9,629' 9,670' 45.00 4.00 Isolated 10,286' 10,306' 9,689' 9,708' 20.00 4.00 Isolated H B-5 10,320' 10,370' 9,721' 9,767' 50.00 4.00 Isolated Revised By:TDF 10/21/2012 Dolly Varden ~ 111 PROPOSED Well No: D-5RD HilcorpAlaska,LLC Completion: Future CASING DETAIL RKB = 41' SIZE WT GRADE CONN ID TOP BTM. 1 33" Surface 407' 13- 61 J-55 12.51 Surface 2,505' 3/8" I 43.5 N-80 BTC 8.755 Surface 1,277' 9- 47 N-80 BTC 8.681 1,277' 8,199' 5/8" 47 P-110 BTC 8.681 8,199' 10,608' 2 I TUBING DETAIL 3-1/2" 9.2# L-80 Supermax 2.992 Surf ±9,340' JEWELRY DETAIL NO. Depth ID OD Item 1 41' 3.95 11 3-1/2"Tubing Hanger 33L 2 ±350' SSSV ±2,100' Priority IPOR-1/IPOC-1/PPOR-1 GLV ±3,709' Priority IPOR-1/IPOC-1/PPOR-1 GLV • ±4,940' Priority IPOR-1/IPOC-1/PPOR-1 GLV 13-3/8 ' ±5,849' Priority IPOR-1/IPOC-1/PPOR-1 GLV 3 3 ±6,500' Priority IPOR-1/IPOC-1/PPOR-1 GLV ±7,056' Priority IPOR-1/IPOC-1/PPOR-1 GLV ±7,603' Priority IPOR-1/IPOC-1/PPOR-1 GLV Howco - - ±8,142' Priority IPOR-1/IPOC-1/PPOR-1 GLV Stage Collar ±8,696' PriorityPPOR-1 GLV @ 6,545' - - IPOR-1 IPOC-1/ / ±9,254' Priority ORIFICE-1 4 ±9,300' Packer III 5 ±9,330' X-Nipple 6 ±9,340' WLEG I A 9,758' M - HES,9 5/8",47#,EZSV,with Plug Kit Installed B 9,797' Drilled HES,9-5/8",47#,EZSV, Pushed to BTM UMWDPM 12/21/97 4 " _ P I 9,785' 4 7.125 Brown,PBR. • II 9,801' 6.5 7.75 Brown,CH Seal Anchor 5 III 9,802' 8.218 4.75 Brown,'3H'Hydraulic Set Packer w/Millout 6 = Extension IV 9,824' 3.725 5.25 Otis,'XN,(3.813"Profile) G 2 V 9,836' 4 5.187 Brown,Shear Sub/Entry Guide If G-3 G4 aG-4 A G-5 B OPEN PERFORATION DETAIL Top Btm Top Btm 1 II Zone Amt spf Comments Date (MD) (MD) (TVD) (TVD) Ill "` IV G-2 9,457' 9,482' 8,934' 8,956' 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/6/1998 G-2 ±9,469' ±9,481' ±8,945' ±8,956' 12' Future ‘.. G-3 9,522' 9,547' 8,993' 9,015' 25' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 G-3 ±9,534' ±9,543' ±9,003' ±9,011' 9' Future IV 9,552' 9,612' 9,020' 9,074' 60' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 AIL ±9,563' ±9,569' ±9,030' ±9,035' 6' Future G-4 ±9,576' ±9,588' ±9,041' ±9,052' 12' Future V B-1 9,657' 9,672' 9,114' 9,128' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 Fill Tagged G-5 9,708' 9,723' 9,161' 9,174' 15' 6' 2-1/2",Ultra Jet,60 Deg. 1/5/1998 @ 10,522' B-4 SEE SECOND PAGE FOR ISOLATED PERFORATION DETAIL 12/89 B-4 EZSV @ B 5 10,522' Slickline/Fish/Fill Information: a. 8/11/12:2.72"GR tagged up at 9,736'. - -5/8" ETD=9,758'WLM, PBTD=10,522',TD= 10,660' MAX HOLE ANGLE=27.57°@ 8,700' Revised By:JLL 03/24/14 Dolly Varden , isi PROPOSED Well No: D-5RD HilcoraAlaska,LLC Completion: Future ISOLATED PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments HB-1 9,925' 9,970' 9,358' 9,299' 45.00 8.00 Isolated 10,069' 10,078' 9,490' 9,498' 9.00 4.00 Isolated HB-3 10,090' 10,100' 9,509' 9,518' 10.00 4.00 Isolated 10,150' 10,182' 9,564' 9,594' 32.00 4.00 Isolated HB-4 10,220' 10,265' 9,629' 9,670' 45.00 4.00 Isolated 10,286' 10,306' 9,689' 9,708' 20.00 4.00 Isolated H B-5 10,320' 10,370' 9,721' 9,767' 50.00 4.00 Isolated Revised By:JLL 03/24/14 , ill Doily Varden Platform D-05rd Current 03/20/2014 Hileorp Alarka,HA Dolly Varden D-5rd 13 3/8 X 9 5/8 X 41/2 Tubing hanger,CIW-AP- FBB, 11 X 4%ASL lift and susp,w/4"type H BPV profile,7"EN,'/4" non continuous control line BHTA,CIW,w/internal knockup cap,41/16 5M FE .k ,1 21 `cam it 4� sr y Valve,swab,CIW-F , 3 h) °� 3� Q 4 1/16 5M FE, HWO, EE ��`y\f a: 4�s ' trim 0 o , ") J Aftm�� ., °Ve � y I (:(7.0,40 Tree, Block,CIW-F, 11 5M X 4 , an r» 1/16 5M run X 3 1/8 5M ' ' ..� ` Q US � wing,double master,wing ®® Oi m valve, EE trim prepped for 7" E" 08 FBB type hanger neck,w/%z control line exit r 63j Void test good \� 250/5000 \ / 1/18/2012 1111 Lfl 1 1 Tubing head,CIW-AP, 13 0— —e 5/8 3M X 11 5M,w/2-2 1/16 5M SSO,X-bottom :1110 1t1 Valve,CIW-F,2 1/16 5M FE, prep, � � � HWO,AA 1%VR profile ■■Ilr' iJll.-6. L.6,e, Void test Bad in Does not pressure up Iin 1/18/2012 Casing head,CIW-WF, 1111 el 13 5/8 3M X 13 3/8" ,„ I lei Valve,CIW-F,2 1/16 3M, casing thread, _ / ), HWO,AA I w/2-2 1/16 5M EFO = +� �!' �I'`° ■ • ...ill Doily Varden Platform D-05rd Proposed 03/20/2014 Harm?Moan,IAA Dolly Varden Tubing hanger,SME-CL,11 X D-05RD 3'A EUE lift and susp,w/3" 13 3/8 X 9 5/8 X 3 1/2 Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I III a w ,.l obi Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim ,411 _ i•, Valve,Wing,WKM-M,31/8 Valve,Wing,WKM-M,2 1/16 5M FE,w/15"OMNI SM FE,HWO,DD trim o _ _ = operator,DD trim 11 I < _ Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim II III IMF IINIF Valve,Master,WKM-M, 1,� 3 1/8 5M FE,HWO,DD trim .1. III X2 IMP Control line '�_ " 111 hm Lax Tubing head,S-8,13 5/8 3M i,I ilat x 115M,w/2-2 1/16 5M SSO,w/BG bottom - II d _ lit * w/1-2 1/16 5M WKM-M valves I ' �'/41lII ' j 11 1L.iat 'I+ Casing head,CIW-WF, Valve,CIW-F,2 1/16 5M FE, 13 5/8 3M X 13 3/8 casing III 1III HWO,AAtrim thread bottom,w/2-2 1/16 = 2 _ h = SM EFO �(♦�� 0 ' it •,-I.; . 11 Dolly Varden Platform 2014 BOP Stack(HAK#1) Hilrnrp AlaPkr.l.r.c: 01/10/2014 Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack . . Ill III iii it iii iii iii ii AM AniniIIMII :.. ..- 3.42' Shaffer ill til Iii Ill III t 111111111111 Ell 4.54' . =r' CU+ ®_ 0 ill Ill Ill Ill Ill M ill iII III III til 2.00' IlPI: i E�� -lii �ni iii tit ill � ' ,� Kill Side Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line 21/16 5M w/HCR and Unibolt line connection lil til Ili Ili lit connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE tit tit tit til lit III III III III III 3.00' Spacer spool 115M FE X 115M FE lit lit at lit lit STATE OF ALASKA RECEIVED AOKA OIL AND GAS CONSERVATION COMMON MAY 17 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other EAOG CC Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extensiorn ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other G Re -enter Suspended WeIII ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development O Exploratory ❑ 180.065 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20100 -01 --^ o 7. Property Designation (Lease Number): t 8. Well Name and lumber: Trading Bay Unit / ADL0018729 Dolly Varden / D -5RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River / Middle Kenai G Pool 11. Present Well Condition Summary: Total Depth measured 10,660 feet Plugs measured 9,758 feet true vertical 10,043 feet Junk measured 10,522 feet Effective Depth measured 10,522 feet Packer measured 9,300/9802 feet true vertical 9,908 feet true vertical 8,792/9,246 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 407 33" Surface 2,505' 13 -3/8" 2,505' 2,505' Intermediate Production 10,608' 9 -5/8" 10,608' 9,987' 6,330 psi 3,810 psi Liner Perforation depth Measured depth 9,457- 9,482; 9,522 - 9,547; 9,552- 9,612; 9,657- 9,672; 9,708 -9,723 feet True Vertical depth 8,934 - 8,956; 8,993- 9,015; 9,020- 9,074; 9,114- 9,128; 9,161 -9,174 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" N -80 9,836' (MD) 9,277 (TVD) HES, 'BWD' Perm. Pkr / 9,300' (MD) & 8,792' (TVD) / Brown '3H' Hydraulic Packer / 9,802' (MD) & 9,246' (TVD) Packers and SSSV (type, measured and true vertical depth) HES, SSSV / 341' (MD) & 341' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 163 873 4129 920 150 Subsequent to operation: 195 659 3701 900 170 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 151 — Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil GI Gas ❑ WDSF❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLU❑ 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: Contact Ted Kramer Printed Name Ted Kramer Title Sr. Operations Engineer Signature f, Phone 907- 777 -8420 Date 5/16/2012 I RBDMS MAY 17 2012 r0)'` ott /g"z Form 10-404 Revised 11/2011 40 171 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -05RD 507332010001 180065 4/12/12 4/25/12 4/12/2012 RU slick line and test lubricator to 250 psi low /2,500 psi high. RIH with 3 1/2" GS to 43' KB and pull Stop. POOH. RIH to 44' KB, latch up and pull pack -off assembly. POOH with same. RIH to 59' KB, latch AD -2 and pull to Stop. Rig down. 4/13/2012 No operations to report. 4/14/2012 No operations to report. 4/15/2012 No operations to report. 4/16/2012 Test BOP's 250 psi low /3,000 psi high. Rig up unit on well. Nipple up BHA and test coil. RIH and find hydrates up high. Work through same and continue to RIH. 4/17/2012 RIH and started tubing acid job, complete procedure. POOH and RD. i tj a a Q �Q� 7 4/18/2012 , No operations to report. 4/19/2012 RU slickline - PT lubricator to 250 psi low / 2,500 psi high. RIH with 3 1/2" GS with AD -2 stop to 100' KB. Sheared. POOH. RIH with 3 1/2" GS to 100' KB latch, pulled up to 59' KB and set, POOH. RIH with 3 -1/2" GS with upper pack off with spacer & lower pack off (15' patch) to 44' KB set. POOH. RIH with AD2 stop to 43' KB and set. POOH. Rig down. 4/24/2012 Rig up 5/L - PT lubricator to 250 pis low/ 2,500 psi high. RIH w/3.5" GS to 44' KB pull A -Stop. RIH w /same to 45' KB pull patch pipe. POOH. RIH w /same to 59' KB, pull AD2 -Stop. RIH w/2.75" GR to 9,742' KB, tag fill, POOH. RIH w /Daniels KOT, sit down @ 141' KB, tool tripped, POOH. RIH w /Daniels KOT two times, sit down @ 141' KB, wouldn't fall through, POOH. Secure well, shut down for the night. 4/25/2012 RIH with 2.75" GR and then 1.80" GR could not get below 137' KB. GR full of ice. Dumped 10 gal. methanol down tubing. RIH w/2.6" Star bit, work tool fell to 144' KB. POOH. Dumped 30 gal methanol. RIH w /same to 144' KB, work tool fell to 148' KB. POOH. Dumped 20 gal methanol down tubing. RIH w /same to 144' KB, work tool fell through to 5,000' KB. POOH. RIH w /Daniels KOT & heavy duty 1 -5/8" JDC to 4,109' KB, latched and pulled valve. RIH to 2,427' KB, latched and pulled valve. RIH and set valves @ 4,109' KB and 2,427' KB. RIH w/3.5" GS & AD2 stop, set stop @ 59' KB, POOH. RIH and set upper and lower pack -off. RIH w/3.5" GS & A stop to 44' KB, set stop, POOH. RD well and secure area. "" • 0 Dolly Varden ALASKA DRILLING Well No. D -5RD UNOCAL 76 Actual Completion 12/23/97 CASING AND TUBING DETAIL RKB = 41' SIZE WT GRADE CONN ID TOP BTM. 1 l 1 2 33" Surface 407' 13 -3/8" 61 J -55 12.51 Surface 2,505' - 9 -5/8" 43.5 , 47 N -80 &P -110 BTC 8.681 Surface 10,608' Tubing 3 -1/2" 9.2 L -80 Butt. 2.992 41' 9,298' 3 JEWELRY DETAIL NO. Depth ID OD Item 1 41' 3.950 11.00 Cameron, Type `F', 3 -1/2" Tubing Hanger 2 41.60' 2.987 4.500 Crossover, 4 -1/2" Seal Lock Pin x 3-1/2" Buttress Pin 4 3 341' 2.813 4.330 HES, `XXO' SSSV (2.813 I.D.), HES SSSV Installed 4 2,427' 2.867 5.968 McMurry Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 4,109' 2.867 5.968 McMurry Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 5,285' 2.867 5.968 McMurry Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK L. 6,243' 2.867 5.968 McMuny Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 6,702' 2.867 5.968 McMurry Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 7,226' 2.867 5.968 McMuny Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 7,718' 2.867 5.968 McMuny Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 8,207' 2.867 5.968 McMuny Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 8,697' 2.867 5.968 McMurry Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK L ' 9,216' 2.867 5.968 McMuny Maccco, 3 -1/2" SMO -2 GLM , 1 -1/2 ", RK 5 9,298' 2.970 3.970 HES, No-Go Seal Assembly, 10.74', Molded 6 9,300' WLM 4.00 8.130 HES, 9 -5/8 ", 36 #- 59,4 #, `BWD' Permanent Packer 7 9,303' 4.00 5.020 HES, Seal Bore Extension, 7.17' Long Howco -I 8 9,311' 2.992 5.700 HES, Tubing Adapter Stage Collar 9 9,326' 2.813 3.970 HES, `X' Nipple, 2.813 @ 6,545' 10 9,342' 2.992 6.00 Wire Line Reentry Guide A 9,758' WLM - - HES, 9 -5/8 ", 47# , EZSV, with Plug Kit Installed I. B 9,797' DPM - - Drilled HES, 9 -5/8 ", 47 #, EZSV, Pushed to BTM 12/21/97 I 9,785' 4.00 7.125 Brown, PBR. II 9,801' 6.50 7.75 Brown, CH Seal Anchor 5 III 9,802' 8.218 4.75 Brown, `3H' Hydraulic Set Packer w/ Millout Extension IV 9,824' 3.725 5.25 Otis, `XN, (3.813" Profile) V 9,836' 4.00 5.187 Brown, Shear Sub/Entry Guide 6 V' 1 t► . . 7 Slickline/Fish/Fill Information: 8 a. 8/25/07: 1.30" Swedge tagged up at 9740'. 9 M _ G_2 b. 4/20/12: Installed Daniels Pack -Off w/ 1.50" ID from 45' - 54'. G -3 G -4 10 G -4 PERFORATION HISTORY a _ G - Interval Accum. A Date Zone Top Btm Amt spf Comments B - woo �� 1/6/98 G -2 9,457' 9,482' 25' 6' 2 - 1/2 ", Ultra Jet, 60 Deg. 1 1/5/98 G -3 9,522' 9,547' 25' 6' 2 - 1/2 ", Ultra Jet, 60 Deg. • II � • r �� ■ 1/5/98 G-4 9,552' 9,612' 60' 6' 2 - 1/2 ", Ultra Jet, 60 Deg. i : 1/5/98 G-4 9,657' 9,672' 15' 6' 2 - 1/2 ", Ultra Jet, 60 Deg. 1/5/98 G -5 9,708' 9,723' 15' 6' 2 - 1/2 ", Ultra Jet, 60 Deg. A Above Perforations Added after Workover HB -1 9,925' 9,970' 45' 8.00 Isolated III HB -3 10,069' 10,078' 9' 4.00 Isolated B - HB -3 10,090' 10,100' 10' 4.00 Isolated IV HB-4 10,150' 10,182' 32' 4.00 Isolated Fill Tagged - B - HB-4 10,220' 10,265' 45' 4.00 Isolated @ 10 B - HB -5 10,286' 10,306' 20' 4.00 Isolated HB -5 10,320' 10,370' 50' 4.00 Isolated B -5 EZSV @ / ETD = 9,758' WLM, PBTD = 10,522', TD = 10,660' 1 0,522' MAX HOLE ANGLE = 27.57° @ 8,700' O:\Alaska\Fields\McArthur River\Dolly Varden \1.0 Wells\D -05RD \Schematics\D -05RD Schematic 05.04.2012.doc Revised: 5/04/2012 DRAWN BY: TDF • Regg, James B (DOA) S f ��8a3�. S From: Regg, James B (DOA) Sent: Friday, March 23, 2012 9:23 AM ,rz 3f , To: Tom Fouts - (C); Michael Dunn Cc: Larry Greenstein; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: Request: D -26RD as the first well in the coil program at Dolly You are correct; Conservation Order 351A published a sundry matrix delineating which Cook Inlet fields and operations require sundry approvals. Trading Bay Unit, McArthur River field is included in CO 351A. Provide a 10 -404 upon completion of work on D -05RD and D -04RD. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 " AL Anchorage, AK 99501 907 - 793 -1236 From Tom Fouts - (C) [mailto:tfoutsCahilcorp.com] Sent: Friday, March 23, 2012 7:16 AM To: Schwartz, Guy L (DOA); Michael Dunn; Regg, James B (DOA) Cc: Larry Greenstein; DOA AOGCC Prudhoe Bay Subject: RE: Request: D -26RD as the first well in the coil program at Dolly Hello Guy, I'm a little confused, in response to your email below I have attached the second page of the AOGCC Sundry Matrix and circled the two points of interest. My interpretation is, since D -05RD and D -04RD are both Development [Production] Wells, It appears we would be required to submit a 10 -404 only. I would be in agreement with your statement below if these two wells were Service [Injection} Wells. I would appreciate your stance on this issue upon review this document. Thanks, Tom Fouts 1 Construction Manager kiiicorp Alaska, I,I,C tfoutsOhilcorp.com Direct: (907) 777 -8390 Mobile: (907) 351 -5749 From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz(aalaska.gov] Sent: Thursday, March 22, 2012 3:23 PM To: Michael Dunn; Regg, James B (DOA) Cc: Larry Greenstein; Tom Fouts - (C); DOA AOGCC Prudhoe Bay Subject: RE: Request: D -26RD as the first well in the coil program at Dolly Mike, Thanks for the list of upcoming Coil tubing wellwork. You may move onto D -26RD with CT and start the upcoming work program. 1 believe the D -05RD and D -04RD will require 403 sundries as you are stimulating the reservoir. ( per 20 AAC 25.280(a)(2)) . 1 • Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Michael Dunn [mailto:mdunn ©hilcorp.com] Sent: Thursday, March 22, 2012 3:02 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Larry Greenstein; Tom Fouts - (C) Subject: Request: D -26RD as the first well in the coil program at Dolly Guy and Jim, We have begun moving coiled tubing equipment to the Dolly platform. The well order and one -line description of the coil work we are planning is as follows: 1. D -26RD — CT CO of the horizontal slotted liner. Lift with N2. No acid. 2. D -28 — Fish slickline tools that have been stuck since 2001. Acid may be pumped to dissolve scale around tools. 3. D -07 — Fish a stuck perforated catcher sub. Pump acid, jar on same. If no luck, mill up sub and catch same. 4. D -05RD — Coiled tubing clean out and acid stimulation of a producer. 404 required. 5. D -04RD — Coiled tubing clean out and acid stimulation of a producer. Polymer sweeps needed. 404 required. 6. D -14RD — CT clean out fill over perfs. May require acid and xylene to loosen fill. Polymer sweeps needed. Wash perfs with acid. Would like the option (permission) to put acid behind the perfs on this injector. 403 to be submitted tomorrow. 7. D -24ARD - CT clean out fill over perfs. May require acid and xylene to loosen fill. Wash perfs with acid. Would like the option (permission) to put acid behind the perfs on this injector. 403 required. Application to be re- submitted tomorrow. As I mentioned to Guy on the phone, I guessed incorrectly 2 weeks ago when the 403 was submitted for D -24ARD when I thought we would go to that well first. Due to the ship loading issues at the Christy Lee, and not having the usual tankage at Trading Bay Facility to handle clean out returns (particularly with polymer), we have determined it is best to delay the jobs that may require polymer sweeps to the tail end of the program, when tankage space will be available. This e -mail is requesting permission to rig -up on D -26RD first. The BOP test and site inspection would be performed are on this well. BOP testing notification was while we i; provided by John Lee to Jim Regg earlier today. p Thanks for your help. Mike Dunn 1 Reservoir Engineer Hilcorp Alaska, LLC mdunnfthilcorp.com Office: (907) 777- 8382 Mobile: (907) 351 -4 191 2 ALASRA OIL AND GAS CONSERVATION COI~L~ISSION July 27, 2000 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE (907) 279-14,33 FAX' (907) 276-7542 Chris Meyers/Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification MRF Wells D-5RD and D-11 Gentleman: On June 30,2000, our inspector Lou Grimaldi witnessed "no-flow" tests on UNOCAL's McArthur River Field TBU wells D-SRD and D-11. Prior to his arrival, both wells had been routed to the "Well Clean" tank, which is about 2 psig back pressure. Both wells were bled down when Lou arrived and had been routed to the tanks for the previous 24 hours. He observed both wells and recorded gas rates far below the "no- flow" limit of 900 scf/hr. He noted rates of 190 to 200 scl/hr on D-5 and 180 to 200 scf/hr on D-11. Neither well had any fluid production. He recommended that "no-flow" status be given to both wells. McArthur River Field TBU wells D-SRD (180-065) and D-11 (168-073) meet the criteria of a "no-flow" performance test and as such, are considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A) they are not required to have a fail-safe automatic SSSV: however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Sincerely, Blair E. Wondzell/ Sr. Petroleum Engineer cc: Bill Smith (UNOCAL's Dolly Varden Foreman) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Dan Seamount, ~ DATE: Chairman ,c~/./ Blair Wondzell, J~~ P. I. Supervisor Lou Grimaldi~ ~ SUBJECT: Petroleum Insl~ctor June 30,2000 No Flow Verification Unocal, Dolly Varden McArthur River Field D-5 ~,D PTD~I~ D-11 PTD#168-073 NON-CONFIDENTIAL Friday, June 30, 2000; I traveled to Unocal's Dolly Varden platform to verify the No- Flow status of wells D-5 and D-11 in the McArthur river field. I had been in contact with Greg checking on the wells status. I arrived to find both wells routed to the "Well Clean" tank which is the lowest back-pressure separator (approx. 2 psi) available on the platform. These wells had been open to well clean for twenty-four hours, bled down and both had negligible pressure on there production casing. 0800; D-5 & 11 flowing to well clean tank @ 1 psi, no fluid produced. Shut in flowlines D-5 0920; checked pressure I psi. 0950; pressure @ I psi establish rate at 200 scf/h 1025; pressure @ I psi rate a 190 scf/h D-11 0925; checked pressure I psi. 0955; pressure @ 1.5 psi, establish rate at 200 scf/h 1030; pressure @ 1 psi rate at <180 scf/h. Note: 180 scf/hour is the lowest rate the flow meter could read. Both wells had no fluid production and slight gas flow but were below our 900 SCF/hour maximum. I recommend these wells be granted No-Flow status. Summary: I verified the No-Flow conditions on Unocal's wells D-5 and D-11 in the McArthur River Field, Both wells passed. Cc; Bill Smith (Unocal Dolly Varden foreman) No Flow TBU UNOCAL D-5 D-11 6-30-00 LG MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, ~0~.~. Commissioner · Blair Wondzell, P. I. Supervisor FROM: John Crisp? ~ 43. SUBJECT: Petroleum Iml~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. - 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON-CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Varde Separator psi: LPS 110 HPS 6/22/00 Well Data " Pilots SV SSV Well Type Well Permit Separ Set L/P Test Test Test Oil, WAG, ClNJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 'D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80: 80 P P OIL 1820410 110 80 80 P P OIL 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820, 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL iD-32 1700370 110 80 75 P P P OIL 'D-40RD 1820830 110 80! 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110~ 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 90 Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Pit. 6-22-00jc 1 STATE OF ALASKA (' ALASKA O AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I Operabons performed Operabon shutdown Sbmulate Plugging Perforate X Pull tubing X Alter casing Repair well. Other 2 Name of Operator 5 Type of Well 6 Datum elevation (DF or KB) UNOCAL Development X 106' KB ABOVE MSL feet 3 Address Exploratory 7 Umt or Property name Strabgraph~c PO BOX 190247 Anchorage, AK 99519 Service Trading Bay Unit 4 Locabon of well at surface 8 Well number 751' FSL, 1,127' FWL, Sec 6-8N-13W-SM D-Srd At top of producbve ~nterval 9,460' MD 9 Permit number 2,016' FSL, 1,616' FEL, Sec 6-8N-13W-SM 80-65 At effecbve depth 10,523' MD 10 APl number 2,165' FSL, 1,212' FEL, Sec 6-8N-13W-SM 50-733-20100-01 At total depth 10,660' MD 11 Reid/Pool 2,182' FSL, 1,165' FEL, Sec 6-8N-13W-SM McArthur R~verF~eld/Hemlock 12 Present well cond~bon summary Total depth measured 10,660' feet Plugs (measured) HES EZSV W/plug k~t ~nstalled @ 9,758' WLM true vertical 10,043' feet HES EZSV pushed to BTM @ 9,797' DPM Effective depth measured 9,758' feet Junk (measured) Junked Retainer @ 10,523' true vertical 9,194' feet Casing Length S~ze Cemented Measured depth True vertmal depth Structural 407' 33" 407' 407' Conductor Surface 2,505' 13-3/8" 2,505' 2,504' Intermediate Production 1 O, 608' 9-5/8" 1,195 sx 1 O, 608' 9,983' L~ner Perforation depth measured See Attached true vertmal Tubing (s~ze, grade, and measured depth) 3-1/2" L-80 @ 9,342' M D ~ ,~'. ~ ~ ~,, Packers and SSSV (type and measured depth) HES "BWD" Perm Pkr @ 9300' W/HES "XXO" SSSV @ 341' Brown '3H' Hydraulic Packer @ 9,802' M D 13 St~mulabon or cement squeeze summary , Intervals treated (measured) ORIGINAL Treatment description including volumes used and final pressure 14 Representatwe Dadv Average Production or Injection Data Od-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 12/3/97 26 144 249 870 115 Subsequent to operation 1/8/98 175 18 137 705 110 15 Attachments Cop~es of Logs and Surveys run Dady Report of Well Operabons X Od X Gas Suspended Serwce 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned ,~~ O~l ~ Dale Haines T,tle Drilling Manager Date 2/2511998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE TBU Well D-5RD Perforations EXISTING PERFORATIONS: Bench Measured Depth True Vertical Depth HB-1 9,925' - 9,970' 9,354' - 9,395' HB-3 10,069' - 10,078' 9,485'- 9,497' HB-3 10,090'- 10,100' 9,505' - 9,514' HB-4 10,150'- 10,182' 9,560'- 9,589' HB-4 10,220' - 10,265' 9,624' - 9,666' HB-5 10,286' - 10,306' 9,685' - 9,703' HB-5 10,320' - 10,370' 9,716' - 9,763' NEW PERFORATIONS: 1/6/98 Zone G-2 Perforated "G" Zone W/2-1/2" Hollow Carrier Guns, 6HPF, 60 Phase Interval MD Feet Interval TV 9,460' - 9,485' 25' 8,929' - 8,951' G-3 9,525'- 9,550' 25' 8,987' - 9,010' G-4 9,555' - 9,615' 60' 9,014'- 9,068' G-4 9,660' - 9,675' 15' 9,109' - 9,123' G-5 9,710'- 9,725' 15' 9,155' - 9,169' Workover Summary McArthur River Unit, Dolly Varden D-5rd 12/15/97 -1/6/98 DAY 1 (12/15/97) SKID RIG TO D-5RD. SET BPV, NIPPLE DOWN TREE, NIPPLE UP BOPE, RIG UP HYDRAULIC WORKOVER UNIT (HWO). DAY 2 (12/16197) CONT. RIG UP OF UNIT. SET TWO WAY CHECKS. TEST BOPE. VALVES ON CHOKE LEAKING. THAW OUT SAME. DOUBLE GATE DOORS LEAKING. TIGHTEN DOORS. TEST TEST O.K. PULL TWO WAY CHECKS. SET BPV'S. CONT. RIG UP OF UNIT AND WIND WALLS. DAY 3 (12/17197) COMPLETE RIG UP OF UNIT. ENGAGE TUBING HANGER AND PULL SEALS FROM PACKER. CIRCULATE WELL W/FILTERED INLET WATER. POOH WITH 4-1/2" COMPLETION. DAY 4 (12/18/97) COMPLETE POOH WITH 4-1/2" COMPLETION, 100% RECOVERY. RIG UP SCHLUMBERGER E-LINE UNIT. RIH WITH JUNK BASKET AND 8.25" GAGE RING TO 9,721' UNABLE TO GET DEEPER. POOH. PICK UP HALLIBURTON 9-5/8" EZSV. RIH. STUCK IN DV COLLAR AT 6,543'. UNABLE TO WORK FREE. SET EZSV AT 6,535'. POOH WITH E- LINE. DAY 5 (12/19/97) TEST 9-5/8" CASING TO 1,500PSI FOR 15 MIN. TEST OK. MAKE UP 8-1/2" BIT, RIH ON 4- 1/2" TUBING. DAY 6 (12/20/97) CONT. RIH. TAG EZSV AT 6,577'. DRILL EZSV. DAY 7 (12/21/97) PUSH EZSV TO 9,797' DPM. POOH DAY e (12/22/97) CONT. POOH WITH TUBING AND BHA NO. 1. RIG UP SCHLUMBERGER E-LINE. RIH WITH JUNK BASKET AND 8.12" GAGE RING. SET DOWN AT 9,767'. POOH. MAKE UP, RIH WITH HALLIBURTON 9-5/8" EZSV. SET AT 9,758'. POOH. PICK UP, RIH WITH HALLIBURTON 9- 5/8" 'BWD' PERMANENT PRODUCTION PACKER AND TAIL PIPE. DAY 9 (12/23/97) RIH AND SET PACKER AT 9,300' ELM. POOH. PU 3-1/2" GAS LIFT COMPLETION. RIH. PREP TO SPACE OUT. DAY 10 (12/24/97) SPACE OUT TUBING, MAKE UP CONTROL LINE TO TUBING HANGER. SLACK OFF, STING INTO PACKER AND LAND TUBING. PRESSURE TEST TUBING STRING TO 500PSI FOR 15 MIN. GOOD TEST. PICK UP HWU WITH RIG. INSTALL TREE. TEST HANGER AND TREE. TEST GOOD. RELEASE WELL TO PRODUCTION AT 1800 HRS. DAY 11 (1/4/98) SKID RIG OVER D-5RD. RIG UP SLICK LINE. PULL DUMMY SSSV. RIG, DOWN SLICKLINE. RIG UP SCHLUMBERGER E-LINE. ATTEMT TO RUN GUN NO. 1 UNABLE TO GET DEEPER THAN 100'. FOUND ICE HOLDING GUNS IN LUBRICATOR. THAW SAME. RIH WITH GUN NO. 1 DAY 12 (1/5/98) TIE IN AND PERFORATE G ZONE FROM 9,723'- 9,708' WITH 2-1/2" HOLLOW CARRIERS, 60 DEG. PHASING, 6 SPF. POOH. RIH WITH GUN RUN NO. 2. PERFORATE G, ZONE 9,582' - 9,612'. POOH. RIH WITH GUN RUN NO.3. PERFORATE G ZONE 9,657'- 9,672'. POOH. RIH WITH GUN NO. 4. PERFORATE G ZONE FROM 9,552' - 9,582'. POOH. RIH WITH G,UN RUN NO. 5. PERFORATE G ZONE 9,522' - 9,547'. POOH. RIH WITH GUN RUN NO. 6 DAY 13 (1/6/98) PRFORATE G ZONE 9,457' - 9,482'. POOH. RD. RELEASE WELL TO PRODUCTION. A B I II IH D-5Actdraw.doc Dolly Varden Well No, 5rd Actual Completion 12/23/97 RKB = 4t~ CASING AND TUBING DETAIL SIZE WI' G, RADE CONN 1D TOP BTM~ JEWELRY DE'IYkiL ~N'O~ _~D_el~h ID OD Item 10 IV 13-1 B -4 B-4 B-5 PERFOI~TtON HISTORY 1/5/98 G-4 9 552' 9 6 2' 6 ' I/5/98 £;-4 9,657' 9,672' 15' 6' 1/5/98 . G5 9,708' , 9,72Y 1~~ 6' [2-1/2",UltraJet,(,ODe~ [ IIB-I 9,92Y 6,970' ~5' 8.00 Isolated ItB-3 10,069' 10,078~ 9' 4.00 Isolated HB-3 0,090' 0,l ))' t0' 4.00 l~la~ed ttB-4 I0, I50' 10.182' 32' 4.00 ~:t~d lib 4 I0,220' 10,265' 45' 4,00 Isolated llB-5 l(~,~86~ ]0,306' ? ~,00 fB-5 ] 1().30()~ 1 ~70' ~0' 4,00 ~) a ed ETD = 9,758' WLM, PBTD = 10,522% TD = 10,660~ MAX HOLE ANGLE = 27.57° DRAWN BY: tcb O~ STATE OF ALASKA ~ ALASKA LAND GAS CONSERVATION uMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon: Suspend: X Operation shutdown' Re-enter suspended well. Alter casing: Repair ~ell Plugging: ' Time extension. . Sbmula[~: Change approved p'"-"~ogram: Pull tubing: X Variance: Perforatel X Other: Name of Operator 5 Type of well' 6 Datum elevabon (DF or KB) UNOCAL Development' X 106' KB ABOVE MSL feet Address Exploratory: 7 Umt or Property name Strabgraph~c. PO BOX 190247 Anchorage, AK. 99519 Service' Trading Bay Unit Location of well at surface Leg A-2, Cond. 9, Dolly Varden Platform 8. Well number 751' FSL, 1,127' FWL, Sec. 6.SN-13W-SM D-Srd At top of productive ~nterval 9 Permit number 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM 80-65 At effecbve depth 10 APl number 2,120' FSL, 3,720' FWL, Sec. 6.SN-13W-SM 50.733-20100-01 At total depth 11 F~eld/Pool 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM McArthur RiverField I Hemlock 12 Present well condition summaryORIGINAL Total depth' measured 10,660' feet Plugs (measured) None true vertical t0,043' feet Effecbve depth measured 10,523' feet Junk (measured) Junked Retainer @ 10,523' true vemcal 9,908' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,505' 13-3/8" 2,505' 2,505' Intermediate Production 10,608' 9-5/8" 1,195 sx 10,608' 9,987' L~ner Perforation depth: measured See AttachedRECEIVED true verbcal 1997 Tubing (size, grade, and measured depth) 4-1/2" N-80 @ 9,836' M.D. Packers and SSSV (type and measured depth) ,l~J~ 0i! & GaS COilS, Anchorage Brown '3H' Hydraulic Packer @ 9,802' M.D.; Otis Series 10 Flapper SSSV @ 321' 13 Attachements Descnpt~on summary of proposal. X Detaded operations program. X BOP sketch X 14 Esbmated date for commencing operabon 15 Status of well classificabon as. 12/1/1997 16 If proposal well verbally approved' Od X Gas. Suspended: Name of approver Date approved Service. 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed Dale Haip. e$ T~tle Drilling Manager Date' FOP, COMMISSION USE ONLY Condit, ons of approval Notify Commission so representat've may w'tness [Approv>? Plug ~ntegnty BOP Test ~ Location clearance Uechamcal Integn~ Test Subsequent form required 10- ~ ~ ~ .O~le6 C___,~O~j Ur~gmal Signed By Approved by order of the Commissioner David W. Johnston Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Corporation ( P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCALe) Dale A. Haines Dnllmg Manager Tuesday, November 18, 1997 Mr. David Johnston Commissioner Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1392 Dear Mr. Johnston Enclosed is an application for Sundry Approval (Form 10-403) to suspend the Hemlock formation and re-complete the G-zone in Dolly Varden Platform Well No. D-5rd. The timing to begin the work is approximately December 2, 1997. If you should have any questions regarding this request please contact Tim Brandenburg at 263-7657. Thank you for your attention to this matter. Sincerely, Dale Haines Drilling Manager RECEIVED NOV ~.4 199i' Alaska 0it & Gas Cons. C0mmissigll Anchoraoe ¢ Dolly Varden D-5rd Actual Perforations Measured Depth True Vertical Depth Date Zone Top Btm Top Btm Amt Comments H B- 1 9,925' 9,970' 9,357' 9,399' 45' HB-3 10,069' 10,078' 9,486' 9,494' 9' HB-3 10,090' 10,100' 9,505' 9,514' 10' HB-4 10,150' 10,182' 9,564' 9,593' 32' HB-4 10,220' 10,265' 9,629' 9,657' 45' .... HB-5 10,286' 10,306' 9,685' 9,704' 20' ,,, HB-5 10,320' 10,370' 9,720' 9,766' 50' 211' ( Dolly Varden Platfrom Well D-5rd It ydraulic Workover Procedure Objective: It is proposed to workover and recomplete DVP well D-5rd as a G-Zone oil producer. The well is currently completed in the Hemlock formation, The workover will require suspension of the Hemlock by setting an F. ZSV, pulling of the tubing with the HWO, Setting a IF. ZSV on E-Line, and running a 3-112" gas lift completion with the HWO. The G-Zone will be perforated through tubing In an under balance state. The workover will be complicated with NORM. Prep Well for Workover 1. Displace well to FIW. Circulate untd returns are clean. SBHP = 3,700 psi at 9,450' 'I'VD MOB and RU HWO Note: 1, , . , Contact AOGCC 24 hours prior to testing BOPE (2;'9-1433) Hold safety meeting with crews and discuss the presenco of H2S and the use of Fresh Air Breathing Systems and the Unocal Alaska H2S Contingency Plan for Hydraulic Pulling Units. RU and circulating system per attached layout. Secure ali lines with chains Pressure test circulating system to choke to $,000 psi. Pressure test down stream of choke to 2,500 psi. Set 4-1/2" nominal Cameron Type "H" BPV in profile. Load out HWO eqmpment to platform, Lay out surface eqmpment per attached lay out plan. RU and circulating system per attached layout. Secure all lines with chains. Pressure test circulating system to choke to §,000 psi. Pressure test down stream of choke to 2,500 psi. ND production tree and flowline. Have production check for H25. Ensure that SCBA's are available for all hands working in the wellhead room. Have Cameron Service Rep. Verify that all pressure has been bled from all lines and all voids associated with the tree, seal flange, tubing hanger and tubing spool immediatley prior to removal. Blind flange flowlines per UNOCAL lock out tag procedure. Inpect tubing hanger top, Veri~ the lift thread type and condition. Plug all pods in hanger. NU BOP's, BOP's to be configured with 2-7/8" x §-~/2" Variable rams in the top cavity and bl~nds in the bottom RU HWO unit and associated equipment. Rig up Secorp's Cascade fresh air breathing system Ensure all safeguards are met for a safe operation with adequate fall protection and sp,ll prevention. Check stack bolts once per tour and ensure bolts remain prope,~,~~ V E D Conduct Pre Job or "Pre Spud" Inspection as per Unocal Alaska Drilling policy. 25 199 ' ~,nchorage Doily 5.doc 1 I/I 8/07 g/g 'd 8L[L'0N 'd~J0O qVOONn ~d6t'g L66L 'gg'AON UNOCAL ) Doily Varden Platfrom Well D-5rd Hydraulic Workover Procedure l_ Workover: Accept Rig: , Hold Pre-well safety meeting, Bnef crews on safety and enwronmental concerns, handling of NORM pipe, and Slip hazards of slick decks. Accept HWO unit. 9. Pull BPV and set two-way check valve. 10. Pressure test BOP Iow / high to 250 psi/ 5000 psi. Pull two way check valve. Complete Unocal Alaska BOPE Checklist and Contract Toolpusher's BOPE Checklist and fax to office. Pull Completion: 11. Measure up 4-1/2" landing joint and engage hanger, Back out hanger hold down screws. PU hanger assembly and monitor well. 12, Shear release seals from Packer. Monitor well and circulate FIW as required to clear any residual gas. The pipe may have BaSO4 scale. The tubing will be checked for NORM with a LUDLUM Monitor. Norm pipe to be properly marked and handled in accordance with UNOCAL's NORM pipe handling procedures, (Attached to end of procedure) 13. POOH laying down 4-1/2" 12 6#, tubing stnng. Note: there is a stage collar located at 6,545'. Them is no mention of the tool's I.D. Set EZSV: 14, RU E-Line unit. MU 9-5/8", 47#, HES EZSV (the EZSV will NOT be dressed with a bridge plug kit), E-4 Setting tool, GR, & CCL. RIH and set CIBP at 9,875' CBL Dresser Atlas dated 7/28180. POOH with Setting tool. 15. Pressure test 9-5/8" and EZSV to 1,500 psi for 15 minutes. Run New Completion Packer on E-Line: 16. RU E-Line unit GPJCCL. MU Halllburton's 9-5/8" x 4" WD permanent packer with ~,~l~,iiev assembly on Bakers Mode, 20 Seffing tool. R E E D - Wire Line R-e Enby Guide, 3-1/2' Buttress Pup, 15', $-1/2', 9.2#, L-SO, Buttress SC Tubing ~0V - x- Nipple, 3-1/2" Buttress Box x Pin - Pup, 15', 3-1/2", 9.20, L-80. Buflress SC Tubing Bor~~l,l,~ GaS Cons. O0;ntia~10n - 9-5/8". 360 - 59.4#, 'BWD' Permanent Packer with 8' Seal °'"" Anchorage 17. RIH and set packer at 9,300' CBL Dresser Atlas Dated 7-28-80. POOH & RD E-Line unit. Dolly 5,doc t 1/18/97 ~/8 'd 8LtL'ON 'd~J03 'lV3ONrl ~d6~r'~ I66[ 'G~'^oN UNOCALe Dolly Varden Platfrom Well D-5rd Hydraulic Workover Procedure Run New Completion 18 PU the completion as noted below. Pipe dope pin connections only using a paint brush with Lead Free Modified. - 10' Molded seal assembly vath spacer rings - No-Go seal shoulder - 3-1/2" Completion with 10 ea. SMO-2 McMurry Macco 1-1/2' GLV's per Gas Lift design . HES, 'XXO' SCSSV profile nipple, 3-112" Buttress Box x Pin (w~th SCSSV installed). - 8 Joints 3-1/2", 9 2#, L-80, Buttress SC Tubing - Space Out Pups Joints 3-1/2", 9,2#, L-80, Buttress SC Tubing - Cameron 11" DCB tubing hanger. 19. RIH with assembly torquing connections to make up marks on buttress connections Rabbit all 3-112" tubing joints with a 2,875' bunny, Control line to be banded 2 X's on pup joint on SCSSV and 1 per joint to surface, 20, 2'!. Maintain 5,000 psi on control l~ne while RIH with SC$SV. Stab seal assembly in packer while slowly c~rculating, note pressure increase. PU and space out for neutral string weight with seals fully engaged. Make up hanger assembly. Make 3 wraps around 3-1/2" tubing with control line prior to making up control line to the hanger. Make up landing joint in top of hanger and tie in control line to the top of the hanger. Pressure control Dne to 6,000 ps~ to open valve, RIH and land completion. Engage hold down screws. Test hanger body seals to 5,000 psi. RD & Release HWO: 22, Set BPV's. RD HWO unit ND BOP's. 23. NU Tree. Pull BPV's and set 2 way checks. Pressure test tree to 5,000 pst. Pull 2-way checks, 24. Release HWO. 25. NU flowlines, gas lift header lines and pressure test. RU two pin recorder. 26 Open flowline to production and route well to test separator. Unload water m tubing and casing to production by slowly stacking gas to castng. Do not exceed 1 BPM to prevent flow cutting GLV's. Unload 645 bbts fluid from tubing and casing with gas lift. 27. 28- With well lifting off bottom orifice, SI tubing and stack 1,000 ps~ on tubing. SI lift gas at header. RU E-Line unit. Pressure test to 2500 p$~. Establish Safeguards for handling perforating guns. MU 2-'I/2" HC, 6-SPF, 60-Phase guns as noted below. RIH and perforate the following interval. Note initial pressure increase from perforating. SI well while RIH and POOH with perforating guns. Tie in to Dresser Atlas CRL dated 7/28/80. R E C E IV E D G-5: 9,708'- 9,723' CBL '15' 2-1/2", HC, 6 HPF, 60-PhaseWell S! NOV 2 5 '~99~' NOTE INCREASE IN SITP. Dolly 5,doc ~//~ 'd SLLL'ON 'd~03 'I¥30NFI Naska 011 & Gas Cons. C0mmi~sl0n Anchorage 11/i8/97 ~d6~'~ /.66[ UNOCALe G-4: 9,657' - 9,672' CBL G-4: 9,552'- 9,615' CBL G-3: 9,522'- 9,547' CBL G-2: 9,457'- 9,482' CBL Dolly Varden Platfrom Well D-5rd Hydraulic Workover Procedure 15' 2-1/2", HC, 6 HPF, 60-Phase Well Flowing 60' 2-1/2", HC, 6 HPF, 60-Phase Well Flowing 25' 2-1/2', HC, 6 HPF, 60-Phase Well Flowing 25' 2-1/2", HC, 6 HPF, 60-Phase Well Flowing 29. RD E-line Allow well to clean up ~n group separator for 24 hours obtaining WC's every 4 hours, RECEIVED NOV 25 199i' Alaska 011 & Gas Cons. Comml~ Anchorage Dolly 5.doc §/cj 'd 8LLL'ON 'd~JO3 "I¥30Nn 11/18/97 Dd6'r'Z L66L 'cjz'AoN e Dolly Varden Well No. 5rd Proposed Completion II RKB = 4F SIZE WT CASING AND TUBING DETAIL GR,M) E CONN ID TOP BTM, 33" 133/8" 9 5/8" Tubing 43.5 , 47 9.2 Surlhce J-55 t2.51 Surface L-80 Butt. 2.992 41' 407' 2.505' !).3(//3' D~ ~oLh 41' 3.50' 9,300' 9.30T 9312' 9.34Y 9S74' 9.802' ID JEWELRY DETAIL OD Item B-1 B-4 PERFORATION ttlSTORY laterval Accim~. Date Zone Top Btm Ami spf Comments (]~2 9,460' 9.485' 25' 6 holx~scd : c;-% 2~P'. 9d50' 25' ,_6' ??~,~a [ Gzl 9 555' 9 6 5' 60' 6' fh'opsed G~ 9,660' 9,675' 15' C i Pmtmsed IIB-3 10D90' 0A(0' 10' 4.00 HB4 10, I50' 10 182' 32' 4.00 HBq 10.220' 10.250' [ 30' 4.00 PBTD = 10,526' TD = t0,660' MAX HOLE ANGLE = 27.57° Cc0 8,7{}0' D-5propdraw.doc DI%~WN BY: ~cb REVISED: 11/16/97 Dolly Varden Well No. 5rd Actual Completion 12/29/89 RKB = 41~ CASING AND TUBING DETAIL SIZE V~I' GRADE CONN ID TOP BTM. 33" Surihce 9-5/8" 43.5,47 N 80 &P-t 10 BTC 8.681 Surface Tubing 4.1/2" 12,6 L-80 AB Mc×t. Burl 3.958 41' 9.836' JEWELRY DETAIL NO. !~p~l! ID OD ltem 4 PERFOI~L4TION HISTORY Date Zone Top B~m Amt { spf Present Condition HBA : 9,92Y 9,970' 45' 8 00 HBo3 10,069' 10,078' 9' 4.00 HB-3 10.090' I0,100' 10' 4.00 HB-5 10286' 10,306' 20' [ 40) fIB-5 10,320' 10,370' 50' 4.00 8 -- B~I PBTD = 10~526~ TD = 1{k660~ MAX HOLE ANGLE = 27.57° @ 8,700~ D-5draw,doc I)RAWN BY: ~cb RI~ViSED: 11/116/97 UNOCAL ) Dolly Varden Platfrom Well D-5rd Hydraulic Workover Procedure 1997 NORM RIG & PIPE YARD SURVEY AND EXPOSURE MINIMIZATION PLAN The following procedures apply to workover operations that include the removal of production tubular equipment from wells that produce water along with oil or gas. RIG SITE: 1. During rig activation and prior to opening well, pipe rack, rig floor, mud circulating p~ts, shale shaker, and x-mas tree will be surveyed using a Gamma survey instrument. Survey is to be conducted under direction of Unocal IH person, by individuals having completed Unocal accredited survey training, using Unocal supplied or contracted equipment. A like survey will be conducted prior to deactivation. Equipment registering NORM readings above 50 micro R/hr will be cleaned prior to further use or demob. 2. Contract Toolpusher will conduct and document pre-job safety meebng with rig crews and effected support vendors prior to pulling production tubing In addition to eqmpment safe operabng procedures the following will be d~scussed. 2.1. Absolutely no open food or drink will be allowed on rig floor while tubing and ancillary equipment is being removed from the well. 2.2. R~g crews will wear hardhats, safety eyewear with side shields, shcker suits, work gloves, hearing protection and safety footwear while pulling completion equipment. 2.3. Hardhats, slicker suits and gloves will be removed and workers will thoroughly wash their face and hands prior to smoking or eating. 2.4.On Unocal platforms, footwear will be changed prior to entering crew quarters. 2.5.Clothing will be washed prior to reuse or removal from Iocabon. 2.6. Should pipe need to be hot tapped to remove trapped pressure, workers exposed to cuttings dust will wear at a minimum, half-face respirators with cartridges approved for radioncide dust. 3. Recovered tubulars and equipment will be laid out on pipe rack and receive a bulk "protectors on" ends survey with a Gamma type instrument (Gamma survey penetrates steel). Instrument standoff will not exceed 1/2" at a maximum survey speed of one foot per second. 3.1. Survey results will be noted on morning report. 3.2. Prior to transport, rig personnel will not~fy designated Unocal Environment representative of all well equipment that surveyed positive, noting weight, O.D., I.D., estimated scale thickness (absence of scale is possible indication of false posibve) and total footage. 3.3 Recovered producbon equipment will not leave location prior to job specific written sh~pping instructions from the Environmental representative. 3.4. Equipment will be properly manifested and placarded. PIPE INSECTION YARD: 1 Pipe yard has established 6-10 micro R/hr. as background. AI_}I used tubulars entenng yard are surveyed w~th Gamma ~nstrument. The tubular ends are surveyed on the float with protectors on, in a designated staging area. 2. When survey reads nothing over background, tubulars are handled as per Unocal 'job order'. 3. When survey reads twice or more background, tubing is taken to designated area. 3.1. Each joint ~s rolled out for isolabon and receives end survey with protectors on, then segregated: 3.1.1. Less than twice background. 3.1.2. More than twice background. 3.1.3.Over 50 micro R/hr. 4. Tubing that comes in designated to junk automatically receives handling as per 3.1. 5. Tubing that comes in for inspecbon meebng requirements of #2 but fails Unocal "15% inspection", receives survey as per 3.1. Ima\word60\busumt\97NORM-RIG&YARD doc Dolly 5.doc 11/20/97 Well D-5rd HYDRAULIC WORKOVER PLATFORM DOLLY VARDEN FILL DRILLING SPOOL 13 5/8" 5M x 13 5/8" 5M WITH 4 1/16" 5M OUTLETS ANNULAR PREVENTER HYDRIL "GK" 15 5/8" 5M DOUBLE GATE "NL" SHAFFER 13 5/8" 5M 2 7/8" x 5" VARIABLE RAMS IN TOP BLINDS IN BOTTOM RISER 13 5/8" 5M ADAPTER SPOOL 13 5/8" 5M x 11" 5M GENERAL CIRG_~ATING SYSTEM HYDRAULIC WORKOVERS PLATFORM DOLLY VARDEN PANEL LINE DSR CHOKE F-I % 10 PRODUCIION ~/8'. 5M HOSE ~" HOSE FROM PLATFORM PiTS # FILL HOSE I I I 4" REI1JRN 2", 5M KELLY HOSE /\ 6' SUCTION 50 BBL. ± TRIP TANK I© 0 01 OPI TRIPLEX MUD PUMP 6' EQUAL 50 BBL. ~' RETURN (TO PLAT PITS) GRAVITY 2", 5M 1502 HIGH PRESSURE CIRCU~ ,TING PLATFORM DOLLY SYSTEM VARDEN FOR HWC CHOKE MAN. ;] 1/8" PANIC LINE 5", 5M FLANGE X 2', 5M 1502 UNION TO PRODUCTION 2', 5M HOSE w/1502 UNION ARMORED HOSE HYD CHOKE I. I FILL I-I-! L[1 FLOW LINEq FUNE 135/8",5M ,~ / ANNULAR AND DOUBLE C.~ATE 3", 5M i~,, s~ UmON 4",~D5M I MANUAL CHOKE KELLY UNE %,%. x,, ~ 2', 5M LOTORC 2', 5M STEEL 2" 502 w/1502 TEE UNION FROM PUMP OVERHEAD VIEW HYD CHOKE TO PRODUCTION J~ J ~ I FROM WELL 113" GAUGE VALVE AT 90 DEGREES TO PITS TO PRODUCTION SIDE VIEW FROM WELL J TO PITS ,.3 1/16" 5M CHOKE MANIFOLD PLATFORM DOLLY VARDEN Unocal Energy Resf es Division Unocal Corporation '~ 909 West 9th Avenue, PO Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL October 5, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: Dolly Varden Platform Well D-$RD APl Number 50-733-20100-01 On July 28, 1995 the following intervals were perforated in Well D-5RD: BENCH TOP (MD) BOTTOM (MD) FEET HB3 10,069 10,078 HB3 10,090 10,100 HB4 10,151 10,181 HB4 10,220 10,265 HB5 10,286 10,306 HB5 10,320 10,324 9 10 3O 45 2O 4 TOTAL 118 Attachment Very truly yours, STATE OF ALASKA ALAS,,A OIL AND GAS CONSERVATION [. JMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X Pull tubing ~ Alter casing__ Repair well __ Pull tubing __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Devaopment X F_xr4omto~y 106' KB above MSL feet 3. Address StraUgraph~ __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Service~ Trading Bay Unit 4. Location of well at surface Leg A-2 Cond. #9 Dolly Varden Platform 8. Well number 751' FSL, 1,127' FWL, Sec. 6-SN-13W-SM D-SRD At top of productive interval 9. Permit number/approval number 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM 80-65/e~-'I.¢~-~tt'-Oq~ At effective depth 10. APl number 2,120' FSL, 3,720' FWL, Sec. 6-8N- 13W-SM 50-733-20100-01 At total depth 11. Field/Pool 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM Hemlock 12. Present well condition summary Total depth: measured 10,660' feet Plugs (measured) None true vertical 10,043' feet Effective depth: measured 10,523' feet Junk (measured) Junked Retainer @ 10,523' true vertical 9,908' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,505' 13-3/8" 2,505' 2,505' Intermediate Production 10,608' 9-5/8" 1,195 sx 10,608' 9,987' Liner Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt Tbg to 9,836' Packers and SSSV (type and measured depth) Baker SB-3 Pkr. w/192-47 Model EBH-22 @ 9,960' 13. Stimulation or coment squoezo summa~ ~. Intervals treated (measured) OCT 1995 Treatment description including volumes used and final pressure A_t~Ya O~t & Gas Cons. C0mmissi0t~ 14. Representative Daily Average Production or Injection Data Anct~0rage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 16/14/95 96 152 331 883 130 Subsequent to operationl~ 113 307 417 1171 140 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X Gas ~ Suspended _ Service 17. I hereby cel;;t~fy that ~e,,fc~egcipg is tr~e,~nd correct to the best of my knowledge. Signed ~.~~~ Title Drilling Manager Date [~l .~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Well D-5RD BENCH MD TVD B1 9,925 9,970 9,357 9,399 B4 10,150 10,182 9,564 9,593 B4 10,220 10,250 9,629 9,657 B5 10,320 10,370 9,720 9,766 HB3 10,069 10,078 9,486 9,494 HB3 10,090 10,100 9,505 9,514 HB4 10,151 10,181 9,561 9,588 HB4 10,220 10,265 9,624 9,665 HB5 10,286 10,306 9,685 9,704 HB5 10,320 10,324 9, 717 9,720 Unocal Energy Resource~~' ,ision Unocal Corporahon ~. 909 West 9th Avenue, P.O Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Alaska DOCUMENT TRANSMITTAL August 24, 1994 TO: Larry Grant FROM: Vince LeMieux 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS 1 Blueline and sepia each for the following wells: TRADING BAY UNIT ~ ~-(? 0 M-31 M-31 .~-.~M-31 -5RD Continuous Gyro Cement Evaluation Log Cement Bond Log Production & Injection Profile RECEIVED S EP 2. $1994 Alaska 0il & Gas Cons. Commission Anchorage 7106194 7/05/94 7105/94 8/13/94 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL TO: DEBRA CHILDERS CiO UNOCAL P.O. BOX 196247, ANCHORAGE, AK 99519 RECEIVED B ~ DATED: / ALASKA OIL AND GAS CONSERVATION COM ~o,51ON REPORT OF SUNDRY WELL OPERATIONS Operations Performed Operations Shutdown Stimulate Plugging Perforate X Pull Tubingm Alter Casing ~ Repair Well~ Other ~ 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 196247 Anchorage, AK 99519 5 Type of Well Development Exploratory Stratlgraphlc Service 4 Location of well at surface 751' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive interval 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM At effectwe depth 2,120' FSL, 3,720' FWL, Sec.6-8N-13W-SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM Leg A-2 Cond. #9 Dolly Varden Platform 12 Present well condition summary Total Depth measured true vertical 10,660' feet 10,043' feet Plugs (measured) 6 Datum elevation (DF or KB) 106' KB above MSL 7 unit or Property name Trading Bay Unit 8 Well number D-5RD 9 Permit number/approval number 80-65 / 91-163 10 APl number 50- 733-201 00-01 11 F~eld/Pool Hemlock None feet Effective depth measured true verbcal 1 0, 5 2 3' feet 9,908' feet Junk (measured) Junked Retainer @ 10,523' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth measured true vertical Length 2,505' 10,608' Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, N-80 Tbg. to 9,836' Packers and SSSV (type and measured depth) S~ze Cemented Measured depth 13-3/8" 9-5/8" 1,195 sx B-1 9,925' - 9,970' MD B-4 10,150'- 10,182' MD B-4 10,220' - 10,250' MD B-5 10,320' - 10,370' MD 2,505' 10,608' 9,357' - 9,399' 9,564' - 9,593' 9,629' - 9,657' 9,720' - 9,766' Brown 3H Hydralic Pkr w/Millout Ext. @9,802'; Otis Series 10 Flapper SCSSV @ 321' stimulation or cement squeeze summary True vertical depth 2,505' 9,987' TVD TVD TVD TVD Intervals treated (measured) Treatment description ~nclud~ng volumes used and final pressure ,, ~, - 4 t994 ~ ,.,~ & 0:~s Cons. C0mmissi( 14 Representative Daily Average Production or Inlect~on Data Od-Bbl Gas-Mcr Water-Bbl Casing Pressure ' 119/91 "\~ j~ Prior to well operation //5 164 229 84 700 Subsequent to operabon (. 6/8/91 ~ 637~ 349 446 760 Tubing Pressure 110 120 15 Attachments Cop~es of Log and Surveys run Dady Report of Well Operations X 16 Status of well classification as O~1 X Gas Suspended Service -- 17 I hereby ~l~fY that the foregoing ~s true and correct to the best of my knowledge SUBMIT IN DUPLICATE~7 Form 10-404 Rev 06/15/88 DAILY WELL OPERATIONS D-5RD 5/20/91 Held safety meeting. Pressure tested lub to 2500 psi. Good test. RIH w/ 3-3/8" HC, 6 SPF, 60° phase guns. Unable to pass GLM #9 0 9,700'. POOH w/ 20' gun. RIH w/ 3-1/8" CCL & 20' weight. POOH. RIH w/ 20' 2-1/8", 6 SPF, 0° phase Dyna strip gun. Flowed well to obtain underbalance and perforated the following interval: HB-4 10,150' - 10,170' DIL Fired RD. Test well production. 6/6/91 PT lub to 2500 psi Good. RIH w/ 2-1/8", .20.5 g, 6 SPF, 0° offset Dyna strip guns. Flowed well ~o obtain underbalance and perforated the following intervals: RUN #1 HB-1 9,940' - 9,970' Fired RUN #2 HB-1 9,925' - 9,940' Fired RD. Return well to production. H: \wp\l~E L LOPS\D5RD Alaska I~ Domestic ~-roduct~on Marathon Oil Company February 16, 1994 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Well D-5RD Sundry Application Dear Mr. Wondzell: Attached please find engineering calculations to support Marathon's conclusion that Well D-5RD is not capable of flowing unassisted. Please note the following: Hemlock reservoir pressure and present oil/water cuts will support a maximum fluid level of 767 feet from surface. Anticipated G-Zone reservoir pressure is lower than the Hemlock pressure. Assuming best case G-Zone production (550 BFPD, 25% water cut) the commingled production will support a maximum fluid level of 340 feet from surface. G-Zone alone, with 0% water cut would be incapable of flowing to surface (maximum fluid level of 740.feet from surface). Please note that our proposed procedure includes Hemlock reservoir pressure measurement (step #5) to confirm that the pressure does not exceed 3700 psi. A "no-flow" test can also be conducted at that time, and G-Zone perforating will be contingent upon successfully passing this no-flow test. We would prefer not to conduct a no-flow test following the G-Zone perforation because of the fact that the G-Zone is known to have lower pressure than the Hemlock (if Hemlock will not flow, neither will the G-Zone), and because of the resultant cross flow that could damage the newly opened interval. If you need additional information, please advise. ~d~on C.Sincerely' ~bete~~ Operations Engineering Supervisor RECEIVED FEB 2 2 1994 uLl & Gas Cons. Commission Anchorage LCI/cah Enclosure H \WP\Sundry\WellD-SRD A subsidiary of USX Corporation Enwronmentally aware for the long run Subject File Page No / By ~'. of / Date ........... H..~.~/~. DA'rum ,/go = r. ,,.,Is3 ! I ECEIVEL Anchorage Alaska I(' )n Domesbc r'roducbon Marathon Oil Company P O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 10, 1994 Mrs. Lynne Goard UNOCAL P. O. Box 196247 Anchorage, Alaska 99519 RE: D-SRD 1 1 FEB 199q Dear Mrs. Goard: Enclosed for further handling is the AOGCC "Application for Sundry Approval" form for Well D-5RD. Please submit the attached letter with the D-5RD Sundry as requested by AOGCC. It would be appreciated if the signed Sundry application with cover letter would be couriered to the AOGCC to ensure time to review and approve the Sundry. Should you have any questions regarding any application or report, please call Mr. Ed Oberts at 564-6436. ~. C. Ib e 1 eS~~ t'Operations Engineering Supervisor LCI/EVO/cah Enclosures H'\wp\Sundry RECEIVED FEB 1 6 1994 Ataska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporahon Enwronmentally aware for the long run Alaska Region Dear Blair: Unocal North Americar~lf Oil & Gas Division ~, Unocal Corporabon P O Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) February 14, 1994 ~. Blair Wonzell ~ O&G Conservation 3001 Porcupine Drive ~chorage, DOLLY VARDEN PLATFORM WELL D5RD Attached please find an "Application for Sundry Approval" with an accompanying letter from Marathon for the adding of perforations to well D-5RD on the Dolly Varden Platform. The proposed perforations are located above the current production packer. While this is not a customary production technique, this well, including the proposed zone, are not capable of natural flow to the surface. Production will be continued using gas lift as the artificial lift mechanism. Since the zones completed, and proposed for completion, are not capable of flow, and the adding of these perforations will add more economic life to this completion I support Marathon's proposed perforating program in this well. Sincerely, G. Russell Schmidt Drilling Manager Unocal - Alaska Business Unit Attachment GRS / 1 eg RECEIVED FEB 1 6 1994 Oil & Gas Cons. Commission Anchorage Alaska I(' ~n Domesbc ~roducbon Marathon Oil Company February 10, 1994 P O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Dolly Varden Platform Well D-5rd Dear Blair: Attached is a Sundry application for TBU Well D-5rd, Dolly Varden Platform, Cook Inlet, Alaska. Well D-5rd is presently producing 433 BFPD, 70% WC, 130 BOPD from Hemlock Benches 1, 4, & 5. The objective of the proposed work is to increase oil production economically from the well and allow G zone reserves to be produced that would otherwise not be recovered using the existing completion. This Sundry application proposes to perforate the G zone from 9462' to 9614' (which is above the production packer) and commingle production with the Hemlock. This work can be accomplished at an estimated cost of $35,000 vs. pulling the well and setting the packer up hole at an average historical cost of between $700,000 and $1,000,000. Following the work, the well would remain on gas lift. There would not be any loss of Hemlock reserves as a result of this work and production from the Hemlock is expected to remain at 130 BOPD. Reservoir pressure in the Hemlock and G zone is estimated to be 3700 psi and 3000 psi, respectively; therefore the well is not capable of unassisted fl~l¢..w? Cement bond across, below, and above the G interval appears to be good bas~l on a cement evaluation log run 12-21-89. Please call me if you require additional information regarding this proposal. Sinc,~ly, ~ Operations Engineering Supervisor RECEIVED LCl/JDM/cah · t'hr~ $4a4em, e~-t-. FEB 1 6 1994 oil & 6a$ Cons. Commissio,, Anchorage A subsidiary of USX Corporabon Enwronmentally aware for the long run Mr. Blair Wondzell February 10, 1994 Page Two Attachments: Application for Sundry Approval, Form 403 Procedure Current Wellbore diagram Wellbore diagram with proposed G zone interval identified Electric line lubricator and BOPE proposal H:\WP\Sundry\D-5rd RECEIVED FEB 1 6 1994 Alaska Otl& Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COM o$1ON APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon ~ Suspend m Operation shutdown ~ Re-enter suspended well__ ~.~,~'' Alter casing Repair well Plugging Time extension Stimulate Change approv'"-~ program__ -- Pull Tubing m~ Variance__ P~rforate ~ Othe-'~" !2 Name of Operator 5 Type of Well: 6 Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development X 106' KB above MSL Exploratory ~ 3 Address Strabgraphlc -- 7 UnR or Property name P.O. Box 196247 Achorage, AK Service Z Trading Bay Unit 4 Location of well at surface Leg A-2 Cond. ~9 Dolly Varden Platform 8 Well number 751' FSL, 1,127' FWL, Sec. 6-8N-13W-SM D-5RD At top of productwe interval RECEIVED 9 PermR number/approval number 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM 80-65 At effectwe depth 10 APl number 2,120' FSL, 3,720' FWL, Sec.6-8N-13W-SM FEB 1 6 1994 50- 733-20100-01 At total depth AIAS~(~ Oil & Gas Cons. Commission ~ Field/Pool 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM ~nchora@e Hemlock 12 Present well cond~lon summary Total Depth measured 1 0,660' feet Plugs (measured) None true vertical 10,043' feet Effectwe depth: measured 10,523' feet Junk (measured) Junked Retainer (~ 10,523' true vertical 9,908' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,505' 13-3~8" 2,505' 2,505' Intermediate Production 10,608' 9-5/8" 1,195 sx 10,608' 9,987' Liner Perforation depth' measured B-1 ~ 9,925' - 9,970' MD 9,357' - 9,399' TVD B-4 10,150'- 10,182' MD 9,564'- 9,593' TVD B-4 10,220' - 10,250' MD 9,629' - 9,657' TVD true vertical B-5 10,320' - 10,370' MD 9,720' - 9,766' TVD Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, N-80 Tbg. to 9,836' Packers and SSSV (type and measured depth) Brown 3H Hydralic Pkr w/Millout Ext. ~9,802°; Otis Series 10 Flapper SCSSV (~ 321' 13 Attachments Descnption summary of proposal ~ Detailed operabons program __ BOP sketch X.~ Estimated date of commencing operation 15 Staffs of well classification as February 17, 1994 If proposal was verbally approved O~1 X.~ Gas~ Suspended ~ Service Name of approver Date approved 17 Ihereby(~ll ~atthefo~,3)o~g,s~u~nd~thebestofmyknq~dge~,~.Lg.(..tlk~C.... ["~A,~/~C.~-g..~ ~.~/~__..~ [ S~gned /O~ ~/V~"x~./~ TRle -©per~.!o.q~_ I:_n_glneering $,_,per,:!~er~ Date FOR COMMISSION USE ONLY Cond,t,ons of approval Not,fy Comm,ss,on so representat,ve may w~tness JApproval No I Plug Jntegr~y ~ BOP Test~ Location clearance ~ .- .. Mechanical Integrity Test ~ Subsequent form required 10- 5/O"r -~oproved Copy Returned Original Signed By Approved by order of the Commlslon David W. J0hnsto_n Comm,ssloner Date -'~/j~./~j~ Form 10-403 Rev 06/15/88 SUBMIT IN TR TBU Well D-Srd Objective: Perforate and produce G zone above the packer, commingle production wi th Hemlock. 1. Hold safety meeting with personnel. SI well. RU wireline unit on well. Hook up communications equipment in wireline unit. MU 3.70" GR on standard tool string. Pressure test lubricator and BOPE to 2500 psi. 2. Lock open TR SCSSV with auxiliary pump. Monitor pressure to ensure no bleed off occurs. 3. Ensure csg and tbg pressure is equalized. RIH with 3.70" GR, tag fill. POOH. 4. MU 4 1/2" kickover tool on tool string. RIH and pull GLV #10 at 9256' TM. POOH. MU and RIH with new GLV #10, a 3/8" orifice GLV. Set in GLM #10. POOH. MU IB on kickover tool. RIH and hit down in pocket of GLM #10. POOH. Check impression to ensure valve is in the pocket. 5. MU Amerada pressure gauge and RIH. Obtain SBHP at 10,026' WLM. POOH. RD wireline unit. 6. Unload well to orifice. Keep well producing until ready to RIH with perforating guns. Check gas lift chart & tbg/csg psi to ensure the well is lifting efficiently. 7. RU E-Line unit. HU communications equipment in wireline unit. Pressure test lubricator and BOPE to 2500 psi. SI well. RIH with 3 3/8", 6spf, 60 degree phasing, 41B 22 gram charges and perforate the G zone(80' total). Perforating runs 2 & 3 will be under a near "balanced condition". Run # Interval ~ Footage Comments I 9584 - 9614~G-4)~ 30 select fire gun 2 9564 - 9584 (G-4), 20 select fire gun 9534 - 9544 (G-3) 10 3 -P9462 - 9482 (G-2) , 20 8. POOH. RD E-line unit. Return well to production. Obtain well tests. H: \WP\Sundry\D- 5 RECEIVED FEB 1 6 1994 Alaska Oil & Gas Cons. Commislton Anchorage MARATHON OIL COMPANY TRADING BAY UNIT WELL D-5RD Compie'ted 12/30/89 L j J-55 ] ] ] ] ] ] ] ;/47#, : B- B- . B- B- 33' Conductor @ 407'. 13-3/8' 61# @ 2505' 9-5/8' 43 N-80/P-110 All measurements are RKB to top oF equipment 41' CI~/ Type 'F' Tbs Hngr. 321' Otis series 'lO' Flapper SCSSV (3,813 X profile) Comoletion String, 0'-9836' 4.5' 12.6# L-80 AB Mod Butt Tbs (3,958 ID). Gas LiFt Mandrels are 4.5' Otis RL w/AB Mod Butt couplings. Valves are GLESCO 1.5' w/RA latches, 2362 #1 16/64 Port 4094 #2 16/64 Port 5322 #3 20/64 Port 6325 #4 20/64 Port 6784 #5 24/64 Port 7259 #6 24/64 Port 7763 #7 24/64 Port 8245 #8 28/64 Port 8752 #9 28/64 Port 9256 #10 28/64 Port 9730 #11 28/64 OriFice 9785'-9801' 9801' Brown Type PBR w/external re~rieving threads, S/A pinned w/GGK# shear. CH-Anchor Type seal assembly. 9802'-9808' Brown '3H' hydraulic set packer. w/mlllOUt ext, 9813' X-over (7,3875 DB x 3,958 ID), 9824' Otis 'XN' nipple (3.813 profile x 3.785 NoGo). 9836' Brown shearout/entry sub, (Fracture stimulated 18/89) PERFORATIONS_ B-1 9925'-9970' 8 SPF 60' Phasing 12/24/89 B-4 10150'-10182' 4 SPF 120° PhasinQ 18/17/87 10820'-10850' 4 SPF 180' Phaslng 18/16/87 B-5 10380'-10370' 4 SPF 120° Phas;nQ 18/17/87 10522' Togged Fill 12/89 10523' Junked retainer PBTD @ 10526' TD @ 10660' RECEIVED 1994 ,~ ,,,~ .... ~ Gas Cons. Commission Revision ]]ate, 1/11/90 Anchorage Revised By, VHR/rms Reason: Recompletion Previous Revision: 1/89 33' Conductor @ 407', - ( Completed 12/30/89 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-5RD PROPOSED All measurements are RKB to top oF equipment. 41' CIW Type 'F' Tbg Hngr, 321' Otls series '10' Fl~pper SCSSV (3.813 X proF,le) ComPletion String: 0'-9836' 4.5' 12,6# L-80 AB Mod Butt Tbg (3.958 I])), 13-3/8' 61# J-55 @ 2505' G~s LIFt Mandrels couplings. Valves ~re 45' Otis RL w/AB Mod Butt are GLESCO 1.5' w/RA latches, 8362 #1 16/64 Port 4094 #2 16/64 Port 5322 #3 20/64 Port 6325 #4 80/64 Port 6784 #5 84/64 Port 7259 #6 24/64 Port 7763 #7 84/64 Port 8245 #8 28/64 Port 8758 #9 88/64 Port 9256 #10 3/8' OriFice 9730 #11 28/64 OriFice 9-5/8' 43,5/47~ N-80/P-iIO Proposed G-Zone Perforations G-2 9462' - 9482' G-3 9534' - 9544' G-4 9564' - 9614' 9785'-9801' Brown Type PBR w/externat retrieving threads, S/A pinned w/GGK# shear. 9801' CH-Anchor Type seal ~ssembly, 9802'-9808' Brown '3H' hydr~ulic set packer, W/MillOUt ext, 9813' X-over (7.3875 OD x 3.958 ID). 9824' Otis 'XN' nipple (3,813 profile x 3,725 NoGo), 9836' Brown shearout/entry sub. B-1 (Fracture stimulated 18/89) B-4 B-4 PERFORATIONS B-1 9925'-9970' 8 SPF B-4 10150'-10182' 4 SPF 10220'-10250' 4 SPF B-5 10380'-10370' 4 SPF 60° Phasing 120' Phasing 120' Phasing 120° Phasing 12/24/89 18/17/87 18/16/87 12/17/87 RECEIVED B-5 FE{3 16 1994 10588' Togged ¢lll 18/89 10583' Junked retainer PBT]) @ 10586' TD @ 10660' Gas Cons. Commission Anchorage Revision DCte: 2/10/94 Revised By.' JDM/evo Re~son' Proposed Previous Revlslon: 1/11/90 ('UOLLY VARDEN PL(~TFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) - LUBRICATOR MANUALLY OPERATED BOP 4 ~1/.-1.6'-'. 5000 psi CHISTMAS TREE POSITIVE CHOKE RECEIVED FEE] I 6--1994 A~aska Oil & Gas Cons. Commission Anchorage --.-- 2' 5000 pal _-- 2" 3000 pal 13 3/8' CASING ALA .,~ OIL AND GAS CONSERVATION COM . REPORT OF SUNDRY WELL OPEI TIONS 10perabons Performed: Operations Shutdown Stmmulate Plugging Pull Tubing __ Alter Casing m Repair Well__ 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 196247 Anchorage, AK 99519 5 Type of Well: Development Exploratory Stratigraphlc Servmce Perforate X "~G'~' 6 Datum elevation (DF or KB) I 106' KB above MSL 17. Unit or Property name Trading Bay Unit 4 Location of well at surface Leg A-2 Cond. ~J Dolly Varden Platform 751' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of producbve mterval 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM At effecbve depth 2,120' FSL, 3,720' FWL, Sec.6-8N-13W-SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM 8 Well number D-5RD ,, 9. Permit number/approval number 80-65 / 93-235 10 APl number 50- 733-20100-01 11 F~eld/Pool Hemlock 12 Present well cond~bon summary Total Depth measured true verbcal 1 0,660' feet Plugs (measured) 1 0,043' feet None Effecbve depth measured true verbcal 10,523' feet Junk (measured) 9,908' feet Junked Retainer @ 10,523' 13 Casing Structural Conductor Surface Intermedmte Producbon bner Perforabon depth measured true verbcal Length S~ze Cemented Measured depth 2,505' 13-3/8" 2,505' 10,608' 9-5/8" 1,195 SX 10,608' Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, N-80 Tbg. to 9,836' Packers and SSSV (type and measured depth) B-1 9,925'- 9,970' MD 9,357'- B-4 10,150'- 10,182' MD 9,564'- B-4 10,220' - 10,250' MD 9,629' B-5 10,320' - 10,370' MD 9,720' Brown 3H Hydralic Pkr w/Millout Ext. @9,802'; Otis Series 10 Flapper SCSSV @ 321' Sbmulabon or cement squeeze summary Intervals treated (measured) Treatment descnpbon includ~ng volumes used and final pressure True vertical depth 9,399' TVD 9,593' TVD 9,657' TVD 9,766' TVD 2,505' 9,987' RECEIVE[, DEC t 7 ig ,;b AlaSka, ~il & ~as t~on~ uumrmsslon 14 Representative Dally Average Producbon or Inlecbon Data '*-t ~lCJlorag8 O~l-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operabon 160 ~ 206 359 / Subsequent to operabon 192 173 333 870 130 860 130 ! 15 Attachments J 16 Status of well class~ficabon as I Cop~es of Log and Surveys run Da~ly Report of Well Operabons X O~1 X Gas Suspended __ -- 171 hereb~j~ertlfy~ the foregoing IsI.,u~ithe best of my knowledge Signed ~/0~, Form 10-404 Rev 06/15/88 Service SUBMIT IN DUPLICAT~ ( DAILY WELL OPERATIONS D-5RD ..9.//19-20/93 RU E-line. PT lub to 2500 psi. Good. RIH w~ 1-11/16" pivot §un, 4 SPF, 180° phase. Flowed well to obtain underbalance and peri=orated the i=ollowing: RUN BENCH DEPTH (DIL) RESULT I HB-1 9,940' - 9,955' Fired 2 HB-1 9,925' - 9,940' Fired RD. Returned well to production. H: \wp\WEL LOPS\D5RD RECEIVE[ DEC 1 7 19 UiI & Gas Cons Anchorage STATE OF ALASKA COM~,,,~SION ALA_~., OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation shutdown Re-enter suspended well '//"~ Alter casing __ Repair well__ uP~ngging __ : Tc;~me extens,on ..~.~rforate X St,mulao~'th.~. (~/.,,~ Change approved program__ Pull T g .... rian ~'~../~.,~ 5 Type of Well' 6 Datum elevation (DF or KB) Development X 106' KB above MSL ~et Type of Request 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 196247 Anchorage, AK 99519 Exploratory Strafigraph~c Service 4 Location of well at surface 751' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productwe interval 2,087' FSL, 3,542' FWL, Sec. 6-8N-13W-SM At effective depth 2,120' FSL, 3,720' FWL, Sec.6-8N-13W-SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6-8N-13W-SM Leg A-2 Cond. ~9 Dolly Varden Platform RECEIVED s E P -- Alas.la Oil & Gas Con.~ 12 Present well condi~on summary Total Depth' measured true vertical 10,660' feet 10,043' feet /tnch0ra; .......... Plugs (measured) 7 UnR or Property name Trading Bay Unit 8 Well number D-5RD 9 PermR number/approval number 80-65 10 APl number 50- 733-201 00-01 11 F~eld/Pool ~n.~lemlock None Effective depth, measured true vertical 10,523' feet 9,908' feet Junk (measured) Casing Length Structural Conductor Surface 2,505' Intermediate Production 10,608' L~ner Junked Retainer @ 10,523' Perforabon depth measured true verbcal Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, N-80 Tbg. to 9,836' Packers and SSSV (type and measured depth) Size Cemented Measured depth True verbcal depth 13-3/8" 2,505' 2,505' 9-5/8" 1,195 SX 10,608' 9,987' 9,357'- 9,399' TVD 9,564'- 9,593' TVD 9,629'- 9,657' TVD 9,720'- 9,766' TVD B-1 9,925' - 9,970' MD B-4 10,150'- 10,182' MD B-4 10,220' - 10,250' MD B-5 10,320' - 10,370' MD Brown 3H Hydralic Pkr w/Millout Ext. @9,802'; Otis Series 10 Flapper SCSSV @ 321' 13 Attachments Descnpbon summary of proposal X Detmled operations program BOP sketch X Estimated date of commenmng operabon Sept. 2, 1993 If proposal was verbally approved Blair Wondzell Name of approver 9/1/93 Date approved 15 Stabs of well clasmficabon as OII X Gas Service Suspended 17 I hereby cer~v t~at t,~ foregoi~g,4s tr~ a, Rd corr te~.~ the best of my knowledge S,gned .~ /~L~ ~ T,tle5 [t. LL[~k~(-~ FOR COMMISSION USE ONLY Conditions of approval Nobly Comm~smon so representabve may wRness Plug ~ntegnty_ BOP Test__ Location clearance__ Mechanmal Integrity Test __ Subsequent form required 10- Approved by order of the Comm~s~on Original S~gned By David W. Johnston Approved Copy Returned commissioner JApproval N o~ ._~_ .~_~,.,___ Date SUBMIT I~ TRIPLICAT'E~ Form 10-403 Rev 06/15/88 PERFORATION PROCEDURE NELL D-5RD lo e Be Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #77 over D-5RD. RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, complete the perforating checklist. Complete the perforating checklist again when POOH w/ gun at 1,000'. SI well. RIH w/ 1-11/16" pivot perforating guns, 4 SPF and perforate the following intervals underbalanced (well flowing): RUN BENCH INTERVAL (DIL) FOOTAGE i HB #1 9,940' - 9,955' 15' 2 HB #1 9,925' - 9,940' 15' e POOH w/ well SI. RD E-Line unit. Return well to production and obtain a 24-hour well test w/ 4WC's following cleanup. H: \wp\WLPRO\DSRD RECEIVED SEP - ) 199) Als-ejl~ Oil & Ga~ Anchorage MARATHON OIL CF]MPANY TRADING BAY UNIT ~ELL D-SRO 33' Conductor" 8 407' Completed 18/30/89 AlE measurements ore RKB to top oF equ,pment 41' CI~/ Type 'F' Tbg Hngr 3Bl' Ot,s set,es 'lO' Ftapper SCSSV (3813 X pro~,te) Comptet,on Str,ng 0'-9836' 45' 126~ L-80 AB Mod Butt Tbg (3958 ID) 13-3/8' 6]~ J-55 @ 2505' Gas L,f't Mandmets ore 45' Ot,s RL w/AB Mod Butt coupt,ngs Vatves are GLESCO 1 5' w/RA torches 2362 #1 16/64 Port 4094 ~2 16/64 Port 5322 ~3 20/64 Port 6325 ~4 20/64 Port 6784 ~5 24/64 Port 7259 ~6 24/64 Port 7763 ~7 24/64 Port 8845 ~8 88/64 Port 8758 ~9 88/64 Port 9856 ~10 88/64 Port 9730 ~11 88/64 Or,Pice 9-5/8' 43,5/47~, N-80/P-110 9785'-9801' Brown Type PBR w/externaL retr,ev,ng threads, S/A p,nned w/66K~ shear 9801' CH-Anchom Type seat assembly 9802'-9808' Brown '3H' hydr~ut,c set packer w/miUout ext, 9813' 9884' 9836' X-over (7,3875 OD x 3,958 ID) Otis 'XN' topple (3,813 pmoPiLe x 3,725 NoGo), Brown sheorout/entry sub, B-1 (Froctume st,mutated 12/89) B-4 B-4 PERFORATIONS B-1 9925'-9970' 8 SPF 60° Phas,ng 12/24/89 B-4 10150'-10182' 4 SPF 120° Phas,n9 12/17/87 10220'-10250' 4 SPF 120° Phas,n9 18/16/87 B-5 10320'-I0370' 4 SPF 120° Phas,ng 12/17/87 RECEIVED B-5 i0522' Tagged ¢,U 12/89 10523' Junked reta,ner PBTD @ 10526' TD e 10660' SEP- Alas Oil & Gas Cons. Commissio~ Anchorag~ Rev,s,on Date 1/11/90 Rev,sed By VHR/rms Reason' RecompLet,on Prev,ous Rev,s,on, i/89 ( ~)OLLY VARDEN P( ~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) ,. RICATOR 4-11.-1.6~ 5000 CHISTMAS TREE POSITIVE CHOKE RECEIVED s E P - ~ 199~ Alaska OJ] & Gas Cons. Oor~miss~o*' ;Anchorage ---- 2' 5000 psi ' ~...- 2' 3000 psi 13 3/8' CASING ALASKA OIL AND GAS CONSERVATION COM~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA gg501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. , To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversati~ concerning the subject, it had been__explained to me that either ARCO or Marathon had been the ~1~-operator on the majority of the work proposed; however, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem in the future will be appreciated. We would also appreciate notification of any canceled work so that the corresponding Application on file can be marked accordingly. -. _ Sincerely, · Statistical Technician r~ p~inted on recycled I~aper b y C,~3. . . · Well Permit No. No. . ,. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit Description Perforate 2-91 Perforate 5-91 Workove~ 4~91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 67-71 G-6 82-33 G-17 78-3 G-19 69-17 G-21 72-42 G-27 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 3/15-91, 91-086 10-30-91, 91-325 4-21-92, 92-093 11-1-91, 91-331 11-10-92, 92-238 4-21-92, 92-094 6-17-93, 93-154 4-21-92, 92-95 1-6-93, 92-203 · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this wel~ Perf. 10-19-91 Perf 4-92 Perforate Temp. log 10-15-92 Perf 4-92 Coil tubing cleanout Perforate Convert to inj. Production profile Perforate 2/90 Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 Perforate 2/90 G. Bush - G. Bush G. Bush G. Bush , G. Bush G. Bush RJ' Schn~dt . G ~Bus h R Schmidt G. Bush R. Roberts R. Roberts G. Bush G. Bush R. Roberts Unocal North Ameri( Oil & Gas Division % Unocal Corpora, on 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Regmn UNOCAL P,E£EIV£D APR 2 0 1993 Alaska Oil & Gas Cons. Commission AnGhorage DOCUMENT TRANSMITTAL April 16, 1993 TO: Larry Grant FROM' Kirk Kiloh LOCATION: 30Ol PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL , · TRANSMI'ITING AS FOLLOWS TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below 7 7-'~-- -- D-7RD ~-2% -D-17RD (,9-q5' -- D-20 Perforating Record Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 q'l-il D-28 D-43RD D-47 G-1RD M-3 M-7 Completion Record Perforating Record Perforating Record Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool 6-20-92 11-21-92 11-25-92 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 M-28 Perforating Depth Control 8-12-92 M-29 Tubing Patch Record 11-13-92 PLEASE ACKNOWLk'YOGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOC~ TRA~SB4ITrAL. THANK YOU DATED: 10pe~ahons pedormed 2 Name of Operator ( STATE OF ALASKA AL~c~KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL 3 Address P. O. Box 190247 Anchorage: Al( 4 Locabon of well at surface Leg A-2 Cond. #9 Operahon shutdown __ Stimulate __ Plugging __ Perforate _.._X Pull tubing ....... Alter casing __ Repair well __ Other __ 5 Type of Well Development ~ i o r) Exploratory __ Strat~graphm ~ Cj q _1::[ () Serwce __ Dolly Varden Platform 6 Datum elevation (DF or KB) 1~,1 VD .~k,..~,,,.~ MCI Trad~nn Rmu IIn;~ ,,_ 8 Well number feet 751' FSLz 1.127' FWL, Sec. 6- 8N- 13W- SM At top of product~ ve mtbrva/ 2,087' FSL, 3,542' FWL, Sec. 6 - 8N - 13W - SM At effecbve depth 2,120' FSL, 3,720' FWL, Sec. 6 - 8N - 13W - SM At total depth 12 Present well condition summary Total depth measured 10,660 ' true vertical 10,043' Effective depth measured true vertical 10,523 ' 9,908' Camng Length S~ze Structural Conductor Sudace Intermediate 2,505' 13-3/8" Production 10,608' 9-5/8" Liner Perforabon depth measured true vertical Tubing (s~ze, grade, and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented ~-~'~n,t number/approval number ~]Y%~ffnum6er 50- ~_~n~ nn_n~ None 1,195 sx Junked Measured depth Retainer ~ 10,523' True vertical depth Bench I 9,925' Bench 4 10,150' Bench 4 10,220' Bench 5 10,320' 2,505' 2,505' 10,608' 9,987' - 9,970' MD 9,357' - 9,3gg' TVD - 10,182' MD 9,564' - 9,593' I'VD - 10,250' MD 9,629' - 9,657' TVD - 10,370' MD 9,720' - 9,766' I'VD 13 14 4-!/2",. 12.6#, N-80 Tubino [a 9 836' MD Packers and SSSV (tyCe and measured d~,pth) I~,nt.,n 2U k,,~l,~,,1;,~ .-,I ..... /~; .... ~ ~..... ~n nnn;. Stimulation or cement squeeze summa y Intervals treated (measured) Treatment descnptlon ~nclud~ng volumes used and hnal pressure NOV - 6 1992 Representative Oa,ly Average Production or InJection Data Anchor .... OlI-Bbl Gas-Md Water-Bbl Casing Pressure a'~eb ng Pressure Pnor to well operation Subsequent to operation 278 193 320 680 60 269 ~ 275 375 760 50 , 15 Attachments Copies of Logs and Surveys run __ Dady Report of Well Operations __ 17 I hereby certdy that the foregoing is true and correct to the best of my knowledge. ..S,gned .. 0_-~..~ ~'... '~~~ . T,tle %,-, ~,~ ,,,.-~ Form 10-404 Rev /88 ~ 16 Status of well classification as Od X Gas_ Suspended_ Service suBMIT ;'N DU PucATE'"~ DAILY WELL OPERATIONS D-5RD 10/17/92 Hold operational/safety meting. RU E-line unit and lubricator on well. Pressure test lubricator & BOPE to 2500 psi w/ wt. bars in lubricator. Test good. Lock out SCSSV w/ aux. pump at 4000 psi - monitor. Establish CBO. 10/18/92 RIHo Open well to flow to obtain underbalanceo Correlate and perforate with 2- 1/8" phased (45°) enerjet perf gun, 6SPF. Run #1 HB-1 9,945' - 9,965' Misfired Run #2 HB-1 9,945' - 9,965' Fired Run #3 HB-1 9,925' - 9,945' Fired Turn well over to production. H: \wp\~ELLOPS\DSRD RECEIVED NOV - 6 1992 Alaska Oil & Gas Coas. ~ommission Anchorage 33' Conductor @ 407'. MARatHON OIL COMPANY TRADING BAY UNIT WELL D-SRO Cof~etecl 12/30/89 All ~eaS~rf~entS are RKB to to;) oF eClU~ent. 41' ~l' Ot;s ser~s '10' flopper $C$SV ¢~13 x peoFae) 0'-t~3~' 4.5' 12~l L-80 AB Hod Butt Th9 (~958 ID). 13-3/8° 611 J-55 9 2505' Gas LiFt Mandrels ore 4.5' Otis RL e/AB Hod Butt caul:Xmas. Valves ore GLESC~ 1.5' u/RA latches. 2:~)~ II 16/64 Port 4~4 ~ 16/64 538~ ~3 ~0/64 6~ 14 ~0/64 P~t 6784 15 ~4/64 Port 7~59 g6 ~4/64 P~t 7763 B7 ~4/64 Port ~45 N8 ~8/64 Port 87~ i9 ~8/64 Port ~ BIO ~8/~4 Port 9~ Ill ~8/64 ~iFice 9-5/8' 43.5/47l, N-BO/P-IlO 9785'-9801' Bro.m Type PBR ./external retr~v~9 threads, $/A p~med w/66KB shear. 9801' CH-Anchor Type seat assenbly. 9808'-9808' Bro~n '3H' hydrauUc set pecker. w/~llout ext 9813' X-over (7.~7~ OD x ~8 ID). ~' otis 'XN' ~e (1813 peo;~e x 3.7~ 9836' Bro~ s~orout/efltry s~. B-I (Fracture st~ulated I;/89) B-4 B-! B-4 B-4 B-5 9985'-9970' 8 SPT 60' Phas~;) 12/24/89 10150'-10188' 4 SPT 120' Phasm9 12/17/87 10;80'-IOL~uO' 4 SPT leO' PhaSe9 12/16/87 10~'-10370' 4 ~ 120' ~s~ 12/17/87 CEIVED iO~E° Toooed F;U 12/89 1057.3' Junked reta~er PBTD 9 10526' TD e 10660' NOV - 6 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage Rev~ Date: 1/il/90 Re~sed By, VHR/PnS Reos~ Pre~ Rev;~ 1/89 ALASKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1 TVDe Of ReQuest Abanaot~ __ Suspend __ Ooerat~onsnutdown ~ Alter casing __ Repair we, __ Plugging __ %me extensIon __ Change aporoveO orogram __ Pull tu~ng __ Var,ance __ Pedorat~ 2 Name of Operator i 5 Type of Well Development __X UNOCAL (Marathon 0il Co - Sub 0pera~or) Ex~oratorv 3 Address ! Strabgrapmc P. O. Box 190247 Anchoraoe,.AK# 995)~9 Ser~qce__ 4 Locat,on of well at sudace Leg A-2 Cond 9 Dolly Varden Platform Re-enter susoenOeCl we~l __ Z[;mula[e __ Other 6 Datum elevation (DF or KB) 106' KB above HSL 7 Umt or Property name Trading) Bay Unit 8 Well number feet 751' FSL, 1,127' FWL, Sec. 6- 8N- 13W- SM At top of productive ~nterval 2,087' FSL, 3,542' FWL, Sec. 6 - 8N - 13W - SM At effective depth 2,120' FSL, 3,720' FWL, Sec. 6- 8N- 13W- SH At total depth 2,187' FSL, 3,806' FWL, Sec. 6- 8N- 13W- SH 12 Present well condition summary Total deptn measureO true vertical 10,660 ' feet Plugs (measured) 10,043' feet 9 Permit numDer 10 APl number so--733-20100_01 11 F~etd/Pool Hemlock None Effect,ve depth measured 10,523 ' true vert,cal 9,908 ' Casing Length Structural Conductor Sudace 2,505' Intermediate Production 10,608 ' bner Perforabon depth measured true vertical Tubing (s~ze. grade, and measured depth) feet Junk (measured) feet Junked Retainer ~ 10,523' S~ze Cemented Measured depth True verbcal depth 13-3/8" 2,505' 2,505' 9-5/8" 1,195 sx 10,608' 9,987' Bench i 9,925' - 9,970' MD Bench 4 10,150' - 10,182' MD Bench 4 10,220' - 10,250' MD Bench 5 10,320' - 10,370' MD 9,357' - 9,399' TVD 9,564' - 9,593' TVD 9,629' - 9,657' TVD 9,720' - 9,766' TVD 4-1/2", 12.6#, N-80 Tubing ~ 9,836' MD Packers and SSSV (type and measured depth) Brown 3H hydraulic pkr w/millout ext,,69~802'/ Otis Series 10 Flapper SCSSV e 321' 13 Attachments Descnptlon summary of proposal/.2_~ De~lecl operations program __ BOP sketch X~ 14 Esbrnated date for commencing operation 10/17/92 1 lS. Status of wetl class, f,cat~ ~:~ ~ i V E D 16 If proposal was v,erbally approved Il Od X Gas __ Suspended __ [,like Hinuer 10/16/92 I OCT ~ ? 199 Nameof approver Date approved Service '~'--'L-_ _"~ "_. "__. ~. ............. ;.,_.~n' 1Z I hereby certify that the f~re(~e~ is true anO correct to the best of my knowledge. Anchorage [./ >1 ' . ,.- ("'] FOR COMM!$$1ON USE ONLY CondmonUof approval: Not~fy Commission so r~presentatmve may witness Plug mtegnty ~ BOP Test ._. Locatmon clearance ~ Mechamcal Integnty Test ~ Subsequent form required 10- z/c)"// Approved by order of the Commmsaon Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY RUSSELl- A. DOUGLASS ( PERFORATZON PROCEDURE HELL D-5RD le e e Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #77 over D-SRD. RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication black-out. Re-establish the communication black-out when guns are g 1000' when POOH. SI well. RIH w/ 2-1/8" phased enerjets, 6 SPF and perforate the following intervals underbalanced. R.UN BENCH INTERVAL (DIL) FOOTAGE I HB #1 g,945' - g,965' 20' 2 HB #1 g,g25' - 9,g45' ~ 20' 6, POOH w/ well SI. RD E-Line unit. Return well to production and obtain a 24-hour well test w/ 4WC's following cleanup. H:\wp\WLPRO\DSRD OCT 2 ? 1992 Oil & Gas Cons. (~ommission ,Zinchorage MARATHON OIL COMPANY TRADING BAY UNIT V£LL D-SRO 33' Conduct; @ 407'. 13-3/8' 61m e 2505' cJ-~/8' 43.~}/4711 N-80/P-IIO are RKB to top oF eclu~N~ent. 41' CIV Type 'r' Tbg Hngr. 3~1' 01;S set~s '10' Flapper $C$$V C3.813 x proFae) -- 0'-~° 4~° 12~ L-80 ~!~ ~ Butt Coflp(eted 12/30/89 Gas LiFt Mandrels ore 4.5' Otis RL u/AB Hod Butt co~p~wgs. Valves are CM.[$CO I~' u/RA latcheT, 2362 Il 16/64 4~4 N2 16/64 P~t ~322 N3 ~0/64 63~ 14 20/64 P~t 6784 ~ 24/64 7259 N6 ~4/64 P~ 7763 H7 24/64 ~45 N8 ;8/64 97~ gll 28/64 ~iFiCe z j J-55 J J J J ] ] , , 71, B-I , !1-4 10522' TagOed Fit 12/89 10523' Junked reta~er PBTD e 10526' TD @ 10660' RevJs~fl Date, !/11/90 Reused By, VHP./rns Reoso~ RecoPq~etKM Pre~cus Re~,s~ 1/89 12/24/89 12/17/87 12/16/87 12/17/87 B-! 99L~o-9970· 8 SPF 60' Phase0 B-4 I0150'-10182' 4 spt 120' lO, use0 10220'-10~ 4 SPF 120' PhQs~O B-5 10320'-10370' 4 SPt 120' Phase9 9836' Brave shearout/entry sLd~ CFroct~u-e stmulated 12/89) 9813' 9824' X-over C7.3875 OD x :~9~8 ID). Otis 'XN' WlN)le C:~813 profde x 3.7L~ NoGo). 9785'-9801' Broum Type PBR u/external retrwvi~G) tl~'eGdL S/A pruned u/MKI s~or. CH-~h~ Type seat osse~y. 9~'-~08' Dro~ '3H' hy~Gu(C set packer. w/Mt~t ex~ ( .)OLLY VARDEN PI~ ,TFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 3 1/8' 5000 psi CHISTMAS TREE POSITIVE CHOKE RECEIVED OCT 2 7 1992 Naska Oil & Gas Cons. 6omm'tssior~ N~chorage ----- 2' 5000 pal 2' 3ooo psi 13 3/8' CASING WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE (907) 279-1433 TELECOPY (907) 276-7542 AUGUST 3, 1992 GARY BUSH UNION OIL COMPANY OF CALIFORNIA P O BOX 190247 ANCHORAGE, ALASKA 99519 DEAR MR. BUSH, OUR FILES INDICATE THAT UNION OIL COMPANY OF CALIFORNIA IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING WELL FILES FOR MISSING 404 SUNDRY WELL OPERATION FORMS. SEVERAL 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT EITHER BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR COMPLETED WORK OR A NOTE STATING THAT THE 403 APPROVAL NUMBER IS VOID. THE APPROVAL NUMBER IS ON THE SIGNED COPY OF THE 403 THAT AOGCC SENT BACK TO THE OPERATOR. WELLNAME PERMIT 403 APPROVAL # TRADING BAY UNIT D-5RD TRADING BAY UNIT D-12RD GRANITE PT ST 17568 8 TRADING BAY UNIT K-3RD 80-0065 91-163/7-514 80-0082 92-054 80-0084 91-87 80-0144 90-081 PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THE PROPER FORM IN A TIMELY MANNER. IF THERE IS SOMEONE ON YOUR STAFF THAT I COULD CONTACT PLEASE GIVE ME THERE NAME AND PHONE NUMBER. THIS IS GOING TO BE AN ON GOING PROCESS JUST LIKE THE PLUG AND ABANDON WELLS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandor~ __ Suspend__ Alter casing __ Repair well __ Change approved program __ 2 Name of Operator f 5 Type of Well .... .,[__~ Development X UNOCAL (Marathon 0i 1 Co - Sub Ul:)~rd~,ur/ Exploratory Z 3 Address I Strattgraph~c __ P. O. Box 190247 Anchora~le, A~ 995]9 Serv,ce__ 4 Locabon of well at sudace Leg A-Z Cond. 9 Doll.y Varden Plat. tom Operation shutdown __ Re-enter suspended well __ Pluggmg__ T~me extension __ Stimulate __ Pull tubmg__ Variance ~ Perforate L Other __ 751' FSL, 1,127' FWL, Sec. 6- 8N- 13W- SM At top of producbve mterval 2,087' FSL, 3,542' FWL, Sec. 6 - 8N - 13W - SM At effective depth 2,120' FSL, 3,720' FWL, Sec. 6- 8N- 13W- SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6 - 8N - 13W - SM 6 Datum elevabon (DF or KB) 106' KB above NSL 7 Unit or Property name Trading Bay Unit 8 Well number D-.~RD 9 Permit number 80-65 10 APl number so-~33-20100-01 11 Field/Pool Hemlock 12 Present well condition summary Total depth measured true verbcal 10,660 ' feet Plugs(measured) 10,043' feet None Effective depth measured 10,523 ' true vertical 9,908 ' feet Junk (measured) feet true verhcal Junked Retainer ~ 10,523' Casing Length S~ze Cemented Measured depth Structural Conductor Sudace 2,505' 13-3/8" 2,505' Intermediate Production 10,608' 9-5/8" 1,195 sx 10,608' bner Perforabon depthmeasured Bench 1 9,925' - 9,970' ND Bench 4 10,150' - 10,182' ND Bench 4 10,220' - 10,250' ND Bench 5 10,320' - 10,370' ND Tubing (s~ze, grade, and measured depth) True verhcal depth 2,505' 9,987" 9,357' - 9,399' TVD 9,564' - 9,593' TVD 9,629' - 9,657' TVD 9,720' - 9,766' TVD 4-1/2", 12.6#, N-80 Tubing e 9,836' MD Packers and SSSV (type and measured depth) Brown 3H hydraulic pkr w/millout ext 69,802'; Otis Series 10 Flapper SCSSV @ 321' Description summary of proposal _.~ Date approved Detailed operabons program __ BOP sketch 15. Status of well class~hcabo~~j~~L~m~ Service Alaska OJJ & Gas Cons. Commission 13 Attachments 1, 14 Esbmated date for commencmg operabon Nay 21, 1991 16 If proposal was verbally approved Name of approver 17 I hereby c~rbfy that the foregomg ~s true and correct to the best of my knowledge Conditions o.! a~lroval-"r~obfy Commission so representative may w~tness Plug ~ntegnty __ BOP Test __ Location clearance __ /~ Mechanical Integnty Test __ Subsequent form required 10- '"' Date S -2...~ _c:::} .~ IAppr°val N°¢,/_./~' ~ ORIGINAL SIGNED By LONNIE C Approved by order of the Commission Form 10-403 Rev O6/15/88 Approved Cop~ ! R~/t u ?&~ Commissioner feet Date~( ;2~ I .~ l SUBMIT IN TRIPLICATE '~ 1) 2) 3) 4) 5) 4 HB #5 10,320' - 10,340' NOTE: WELL TESTS TO BE EVALUATED PRIOR TO REPERFORATING HB #5. 6) RD E-line unit. docs\oe57\15, doc Attachment #1 WELL D-5RD PROCEDURE Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #77 over D-5RD. RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. RIH with 3-3/8" carrier guns, 6 SPF, 60-Degree phasing and perforate the following intervals underbalance. RUN BENCH INTERVAL (DIL) FOOTAGE 1 HB #4 10,150' - 10,170' 20' *******TEST WELL FOR A MINIMUN OF 24-HOURS FOLLOWING CLEANUP**** 2 HB #1 9,940' - 9,970' 30' 3 HB #1 9,925' - 9,940' 15' *******TEST WELL FOR A MINIMUN OF 24-HOURS FOLLOWING CLEANUP**** 20' RECEIVED UAY 0 t99 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 ~F DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP ,. GREASE HEAD (Hydraulically Activated) LUBRICATOR -- POSITIVE CHOKE 4-1~Ci.6-'. 5000 pSI CHISTMAS TREE RECEIVED MAY ~ 0 t991 Alaska Oil & Gas Cons. Commission Anchorage ---.-- 2' 5000 psi _-- 2' 3000 psi · 13 3/8' CASING 33' Conductor 8 407', Completed 12/30/89 Attachment #3 ( MARATHDN DIL CDMPANY TRADING BAY UNIT WELL D-5RD ALL measurement~ are RKB to top o~ equipment. 41' CI~; Type 'F' TbQ Hngr, 3~1' O~ls series '10' Fl~pper SCSSV (3.813 X pro?lle) Comple~lon 13-3/8' 6]# J-55 @ 2505' Gas LI¢~ Mandrels are 4.5' Otis RL w/AB Mod But~ couplings. Valves are GLESCO 3,5' w/RA latches, 2362 #1 16/64 Pork 4094 #2 t6/64 Port 5322 #3 80/64 Port 6385 #4 20/64 Port 6784 #S 84/64 Port 7259 #6 84/64 Port 7763 #7 24/64 Port 8845 #8 28/64 8758 #9 88/64 Port 9256 #10 88/64 Port 9730 #11 28/64 OriFice 9-5/8' 43.5/47#, N-80/P-110 9785'-9801' Brown Type PBR w/external retrieving threads, $/A pinned w/G6K# shear. 9801' CH-Anchor Type seal ~ssembiy, 9802'-9808' Brown '3H' hydraulic set packer, w/mlllout ~×~c. 9813' X-over (7.3875 OD x 3.958 ID). 9824' Otl~ 'XN' nipple (3,813 profile x 3.725 NoGo). 9836' Brown shearout/entry sub, ])-1 (Fracture s~lmuloted 12/89) B-4 B-4 B-5 PERFDRATIDNS B-1 9925'-9970' 8 SPF B-4 10150'-10188' 4 SPF 108E0'-10850' 4 SPF B-5 10380'-10370' 4 60' Ph~lsln9 12/24/89 180' Phasing 12/17/87 120' Phasing 12/16/87 MAY 0 t99t Alaska Oil & Gas Cons. Commission Anchorage 10528' Tagged Fill 12/89 10523' Junked re%alner PBTll 8 10586' TI] 8 )0660' Revision Date, 1/11/90 Revised By, VHR/rms Reason, Recompletlon Previous Revision, 1/89 ( STATE OF ALASKA ( 0 F~ I G i N A L ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed Operation shutdown __ Stimulate ~ plUggtng ~ Perforate .._X. Pull tubing ~ Alter caang ~ Repar well ~ Other 2 Name of Operator ~ 5. Type of Well UNOCA[ (:Harathon ....... / , Development :X" Hll ~:n - ~,n IJn~_v'ator] Exploratory__ 3 Address ' ! Strat~graphlc ~ P. 0. Box 190247 Anchoraqe, AK 99519 Ser, ce~ 4. Locatlon ot we# at surface Leg A-2 Cond. #9 Dolly Varden Platform 751' FSL, 1.127' FWL Sec. 6- 8N- 13W- SM top of productive interval ' 2,087' FSL, 3,542' FWL, Sec. 6- 8N- 13W- SM At effective depth 2,120' FSL, 3,720' FWL, Sec. 6- 8N- 13W- SN At total depth 2f187' FSL, 3,806' FWLf Sec.. 6- 8N- 13W- SH 12. Present well condition summary Total depth measured 6. Datum elevation (DF or KI~) lCJfi' KR ahnv~ M~I 7 Unit or Property name Tradinq Bay Unit . 8. Well number ~. i~..~t nu~oval number 11-0- AiSi-n~mber ~ 5°-733-2010[t-01 11. Reid/Pool Hemlock 10,660 ' feet Plugs (measured) 10,043' feet None true vertical Effective depth measured 10,523 ' feet true vertical feet 9,908' Casing Length Structural Conductor Surface Intermediate 2,505' 13 - 3/8" 2,505' Producbon 10,608' 9-5/8" 1,195 sx 10,608' Liner Junk (measured) Junked Retainer e 10,523' Perforation depth measured Size Cemented Measured depth Bench i 9,925' - 9,970' MD 9,357' -9,399' TVD trueveracal Bench 4 10,150' - 10,182' MD 9,564' -9,593' TVD Bench 4 10,220' - 10,250' MD 9,629' -9,65?' TVD Bench 5 10,320' - 10,370' MD 9,720' -9,766' TVD Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 Tubing e 9,836' MD Packers and SSSV (type and measured depth) Rrnwn :~H hvd~'aul{c_ nlr~, w/milln,t e~t OCI.R~I:;)'? (lf. iR ~r{eR 10 Flannpr' S~.S<:¥ ~1 .~71' · i i 13. Stimulat,on or cement squeeze s~Jmmar~ ' RECEIVED Intervals treated (measured) Treatment descnption includ,ng volumes used and final pressure JAN ! 7 ] 991 , ,, ~!~!.,. 4.~, ,~ ,.~ ,. ,.. ..... 14. Representative D~ily Average Producbon or I~~ ~ uUli~' ~i~uio,~l~/j~ ' ' O,I-Bbl Gas-Md Water-Bbl C~s~~gl8 Tul~ng Pressure Pr,or to well operal]on 12/12/90 121 39 53 710 Subsequent to operat,on 12/30/~0 518 1,55 164 920 15 Attachments 11~ Status of well clasaflcatlon as: Cop~es of Logs and Surveys run ~ i Daily Report of Well Operations X Oil x Gas ~ Suspended ~ 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Service "<J-~ feet True vertical depth 2,505' 9,987' 110 1,~n Date t - ~ ~ -'~ ~ SUBMITIN DUPLICATE Attachment Summary of Daily Well Operations D-5RD 12/11/90 RU Schlumberger. PU CET tool. 12/12/90 Good PT, held 2500 psi. RIH w/ CET tool string. Tool set down to 9,720'. Could not work deeper. POOH. Take out upper tool centralizer. RIH, working tools to gg50'. CET quit working. POOH. 12/13/90 LD tools. RIH w/ working CET string. Run two full passes over required interval. Caliper showing - 6" ID across HB-1 (avg~scale thickness = 1.3"). POOH. LD CET MU first gun loaded 15', 6 SPF e 60v phasing, 3-3/8" OD, 22 gm Hyperjet II charges. PU & RIH. Tie gun in and perforate HB-1 from ggss' - 9970' DIL. POOH. RIH w/ gun #2. Perforate HB-1 from gg25'-gg55' DIL. POOH. RD E-line. Flow well to separator. \docs\dvp\d5rd.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon__ Suspend__ Alter casmg __ Repair well __ Change approved program __ 2 Name of Operator. . ! 5 Type of Well UNOCAL (Marathon Oil Co - Sub Operal:or) Devel.opment~X ! Exploratory __ Addr~.ss 0. Box 190247, _t_ Strat,graph,c 3 Anchorage, AK 9..9.5~9 . ?.e.,rv,ce-- 4 Locatlon of well at surface cc51 r~-~_ ~..,J,mu. ~ uuml.y YalUCl, rmo~.mu, mmt 751' FSL, 1,127' FWL, Sec. 6- 8N- 13W- SM At top of producbve mterval 2,087' FSL, 3,542' FWL, Sec. 6 - 8N - 13W - SM At effecWe depth 2,120' FSL, 3,720' FWL, Sec. 6 - 8N - 13W - SM Attot~l,df§~p, FSL, 3,806' FWL, Sec. 6- 8N- 13W- SM Operabon shutdown __ Re-enter suspended well __ Plugging __ T~me extension __ ~tlmulate __ Pull tubmg __ Vanance __ Pedorate ~ Other __ 12 Present well condlbon summary Total depth measured true verbcal Casmg Length Structural Conductor Sudace 2,505' Intermediate Production 10,608' LineF Perforabon depth measured 6 Datum elevabon (DF or KB) 106' KB above MSL .~ Un~,t pr Pro,~erty n, am,e. raalng uay unl~: 8 Well number D-SRD 9 Permit number 80-65 Bench I 9,925' - 9,970' MD Bench 4 10,150' - 10,182' MD truevertlcal Bench 4 10,220' - 10,250' MD Bench 5 10,320' - 10,370' MD ~blng (s~ze, grade, and measured depth) 4-1/2", 12.6#, N-80 Tubing 0 9,836' MD Junked Retainer ~ 10,523' True vertical depth 2,505' 9,987' BOP sketch Date )Approval No Date SUBMI'r IN TRIPLICATE 9,357' - 9,399' TVD 9,564' - 9,593' TVD 9,629' - 9,657' TVD 9,720' - 9,766' TVD Packers and.$$SV (type aqd. measpred d~pthl urown J~nyoraullC pKr w/mlllout ext ~9,802'; Otis Series 10 Flapper SCSSV ~ 321' 13 Attachments ¢ 1 ", Descnpbon summary of proposal #2 Detailed operabons program __ 14 Esbmated date for commencing operabon December 1!, 19°0 16 If proposal was verbally approved Russell Douglass Name of approver 12/7/90 Date approved 15 Status of well classlflcabon as. Od .X_ Gas ~ Suspended Service 17 I hereby.c.ert,fy that the foregoing ~s true and correct to the best of my knowledge S,gned ( idL,.~ ~, ~,..~U.. T,tle -~ ,~ FOR COMMIS~ON USE ~LY Conditions of~pr~l Not~fy Commission so representabve may witness Plug ~ntegnty __ BOP Test __ L(x:atton clearance --'1'~4c' Mechanical Integnty Test __ Sub~quent form required 10- Approved Copy ORIGINAL SIGNED BY /~,Rje~t~_.~..turn d LONNIE C. SMITH Approved by order of the Commiss~on ~ .(5.Y~~(J Commissioner Form 10-403 Rev 06/15/88 Effechve depth measured 10,523 ' feet Junk (measured) true verbcal 9,908' feet ~.~gCt~l~ ~,0 S~ze Measured depth [3-3/8" , 2,505' 9-5/8" ~ 1~ sx 10,608' 10,660' None feet Plugs (measured) 10,0 4 3' feet 11. Field/Pool Hell ock 10 APl number 5o-733- 20100-01 1) 2) 3) 4) 6) NOTE: Attachment #1 Wel 1 D-5RD Reperforation Procedure Well should be SI. RU E-Ling unit. Pressure test lubricator and BOPE to 2500 PSI. RIH with CET log. Log from about 10,400' up into tbg tail to at least g,730'. POOH w/ CET. RIH with 3-3/8" hollow carrier, 6 SPF, 60o phasing, 22 gram charges and perforate the following intervals underbalanced. RUN BENCH INTERVAL DIL FOOTAGE i I 9,955' - 9,970' 15' 2 I g,g25' - g,g55' 30' Test well after cleanup for 12-24 hours. 3 4 10,220' - 10,250' 30' 4 3 10,150' - 10,182' 32' RD E-line. Flow well to group separator for 24 hours prior to placing well in test. Maximum anticipated FBHP is 4200 psi. \docs\oe54\7.doc Attachment #2 (,~OLLY VARDEN PL[. rFORM Wireline Lubricator w/Associated BOPE , - GREASE HEAD (Hydraulically Activated) · LUBRICATOR MANUALLY OPERATED BOP 4.1/~-1.6~ 5000 pal CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 psi _-- 2' 3000 psi .... 13 3/8' CASING DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. CONDUCTOR LEG ~/A-1: LAT : 60048, 28.272" LONG :151°37' 57.620" 6, T8N~ R13W "Y" COORD. "X" COORD. WELL # FSL ,,, 2,490,836.22 208,461.20 757.5 1 2 3 4 5 6 7 8 9 lO ll 12 LEG ~A- 2' 1 2 3 4 5 6 7 8 9 10 ll 12 LEG #B-l' LAT = 60°48' 27.485" LONG =151°37' 57.564" 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842,79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' D-32 762.9 .2,490,837.76 208,467.60 D-40 759.2 2,490,833.28 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 ° D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD & 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 2,490,756.22 208,462. O0 677.5 1 2 3 4' 5 6 7 8 9 10 ll 12 LEG #B-2: 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 674.8 (Reserved for Compressors) FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 121D.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 ll31.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 1219.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Unocal North Americ~ Oil & Gas Division ~ Unocal Corporation P O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Gar~ S. (Bush Regi%nal Drilling Manager GSB/lew APR 2 197 Unooal North America~ Oil & Gas Division ~ Unocal Corporation ~ P O Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Enwronmental Affairs Alaska Region March 20, 1990 Ms. Joan Miller Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REPLACEMENT FOR 10-407 SUBMITTED FOR DOLLY VARDEN PLATFORM WELL D-5RD Dear Ms. Miller: Per our telephone conversation of March 13, 1990 please replace the 10-407 submitted to you on March 1, 1990 with the enclosed 10-404 for the above referenced well. The attachments sent with the 10- 407 should be attached to the 10-404. If you have any questions concerning the above, please call me at 276-7600. Sincerely, Donna M. Secretary da Enclosure REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operation shutdown ~ Stimulate __ Plugging __ Pull tul~ng X__. Alter casing __ Repair well __ 2 Name of Operator ! 5 Type of Well UNOCAL (Narathnn (~i] Cc~ - ~llh (~n~r'a'J'or)/ Development__~X , Exploratory __ 3 Address ' ! Strabgraphlc __ P. 0. Box 190247 Anchoraqe, AK 99~.9 Serv,ce__ 4 Locat~on of well at surface Leg A-2 Cond. //9 Dolly Varden Platform 751' FSL, 1,127' FWL, Sec. 6 At top of productive ~nterval 2,087' FSL, 3,542' FWL, Sec. At effectwe depth 2,120' FSL, 3,720' FWL, Sec. At total depth 2,187' FSL, 3,806' FWL, Sec. 12 Present well condition summary Total depth measured true vertical - 8N - 13W - SM 6 - 8N - 13W - SM 6 - 8N - 13W - SM 6 - 8N - 13W - SM 13. Perforate ~ Other __ 6 Datum elevation (DF or KB) 1NR' ER ahnvp Mql 7- On,t o~:~r0pe~ty r~am(~ - Trading Bay Unit 8 Well number 10,660' feet Plugs (measured) 10,043' feet Effective depth measured true vertical 10,523 ' 9,908' Casing Length Structural Conductor Surface Intermediate 2,505 ' Production 10,608' brier Perforation depth measured true vertical feet Junk (measured) feet S~ze Cemented Tubing (raze, grade, and measured depth) 13-3/8" 9-5/8" 1,195 sx Bench I 9,925' Bench 4 10,150' Bench 4 10,220' Bench 5 10,320' ~}~n~t number/approval number 9-984/80-65 10 APl number s°-733-20100-01 11 Reid/Pool Heml oc k 14. None Junked Retainer (a 10,523' Measured depth 4-1/2", 12.6//, N-80 Tubing 0 9 836' Packers and SSSV (type and measured depth) ' Rrnwn ~H hydroxyl-lc nl~r w/m~lln,Jf pYf Stimulat,on - ~'. ~_:_'mm~%; fractured True vertical depth 2,505' 2,505' 10,608' 9,987' - 9,970' MD 9,357' - 10,182' MD 9,564' - 10,250' MD 9,629' - 10,370' MD 9,720' MD - 9,399' TVD - 9,593' TVD - 9,657' TVD - 9,766' TVD raq R~,~~I~~ in Flann~r SCSSV _ca 321' Intervaistreated(measured) 9925' - 99701 (HB #1 ) MAR 2 2 19! 0 3800 Treatment description including volumes used and final press~[~;~(:.~ 0JJ & Gas C0ris, C ~ ~,~ 7400 lbs I~,~uu 20/40 Annh0ra~ Representabve Da~ly Average ProdUCt~°n or~nject~on Data Od-Bbl Gas-Md Water-Bbl Casing Pressure gal YF-140 gal WF-40 Carbo Lite Tubing Pressure feet Prior to well operation 12/8/89 206 939 99 850 120 Subsequent to operation 1/4/90 160 64 480 8.50 160 15 Attachments Copies of Logs and Surveys run __ Dady Report of Well Operations ~ 16 Status of well classification as: Oil .~_ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S, gned ~'~ ,,~~z (~-~Z)T,tle Environmental Form 10-404 Rev 06/15/88 Engineer Date 3/20/90 SUBMIT IN DUPLICATE Attachment #1 Summary of Daily Well Operations D-5RD 12/14/89 Pulled GLV La 9367'. Accept rig La 1200 hrs. 12/13/89. Bled well to production. Displace tbg and csg w/ 3>0 KCl. PU 5" dop. 12/15/89 PU 5" d.p. ¢irc to displace oil. Spot HEC pill. Well still on vacuum. Mixing 30 bbl Bridgesal pill. 12/16/89 Mix 30 bbl LCM pill and spot La 9371'. Monitor well. Close SCSSV and set BPV. ND tree. NU BOPE. 12/17/89 Finish NU BOPE. Test BOPE. Pull tbg free. Circ gas to production. POOH. LD 4-1/2" tbg. 12/18/89 POOH. LD 4-1/2" tbgo Change PR's to 5". MU pkr milling assembly and RIH, PU 5" d.p. 12/19/89 RIH w/ pkr millin9 assembly. Tag La 9778'. Mill pkr 9778'-9781'. POOH. Hung up La 7488'. Work free. POOH. Hung up La 6550'o Pulled loose. POOH. Grapple smooth. RIH w/ grapple and mill shoe. 12/20/89 RIH w/ PRT. Mill pkr. POOH. BHA. Recovered prk. RIH w/ bit and scraper. 12/21/89 RIH w/ bit and scraper to 10,481'. CO fill to 10,522'. POOH. Run CET-CBT 10,522'-8500'. 12/22/89 RIH and set BP on E-line La 10,120 DIL. RIH w/ OEDPo Pump sand pill to scour pipe. Filter ,~u~,. RECEIVED MAR - 2 ]990 AJaska 0i! & Gas Cons. CommissioP Anchorage ( Summary of Daily Operations Dolly Varden Well D-5RD Page 2 12/23/89 Filter brine. POOH. MU TCP assembly. RIH. 12/24/89 RIH w/ TCP assembly. Correlate w/ GR.~ Perf Hemlock B-1 9925'-9970'. RO. POOH. LD guns. RIH w/ pkr. 12/25/89 RIH. Set pkr @ 9831'. Test annulus to 2000 psi. Perform data frac. Run temp log. RIH. Set pkr @ 10,020: Test BP to 4000 psi. Bled to 2250 psi in 15 min. 12/26/89 RO. POOH. Set retainer on wireline (a 10,080' DIL. Tested BOP's. RIH w/ RTTS and set @ 10,020' DPM. 12/27/89 Set RTTS (a 9833' and tested annulus to 2000 psi. Frac'd Hemlock Bench 1. Monitored pressure for 4 hrs. RO gel flush. Ran temp survey. Started POOH. 12/28/89 POOH. LD retrievable pkr and bundle carrier. Picked up bit and boot baskets and RIH. Washed 155' fill. Drld retainer. Displaced fluid in hole w/ clean FIW w/ 3% KCl. Drld bridge plug. RIH to 10,517'. Started CBU. 12/29/89 Fin CBU. POOH. Changed pipe rams and tested same. RU and started running 4-1/2" production tbg. 12/30/89 Fin running production tbg. Set permanent pkr at 9802'. Tested seals and pkr. ND BOP's. NU tree. RELEASED RIG. ~docs~dvp~D5RD RECEIVED MAF - 2 Alaska Oil & Gas Cons. Commissio Anchorage Attachment #2 33' Conductor 4079 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-SRO Completed 12/30/89 Ail measurements are RKO to top of equipment. 41' CIW Type 'F' Tb9 Hngr. 321' Otis series '10' Ft~pper SCSSV (3.B13 X proFIte> Campier;on Stm;ng, 0'-9836' 4.5' 12.6# L-80 AB Mod Butt Tbg (3.950 ID). 13-3/8' 61# J-55 e 25O5' Gas L;?~ Nandrets are ¢.5' Ot;s RL w/AB Mod Butt couptmg$. Valves are GLESCO 1.5' w/RA latches. 2362 ~1 16164 Port ~094 #2 16/64 Port 5322 #3 20/64 Port 6325 #4 20/64 Port 6784 ~5 24/64 Port 7259 If6 2¢/64 7763 ~7 ~4/64 Point 8245 08 28/64 875~ ~9 ~8/64 Port 925~ ~10 28/64 Port 9730 ~II 28/64 9-5/8' 43.5/47#, N-80/P-IIO 9785'-9801' Brown Type PBR w/externa( retr;eving ~hreads, S/A penned w/66K# shear. 9801' CH-Anchor Type seat assembly, 9802'-9808' Brown '3H' hydraulic set pucker. w/mlLlou~ ext. 9813' X-over (7.3875 rid x 3.958 ID). 9824' ntis 'XN' nipple (3.813 profile x 3,725 NoGo). 9836~ Brow. shearout/en~ry sub. B-1 <Frac~cure s~lmuloted 18/89) B-4 B-4 PERFr1RATIr1NS B-1 9925'-9970' 8 SPF B-4 10150'-1018;:" 4 SPF I0220'-10250' 4 SPF B-5 10380'-10370' 4 SPF 60' Phasing 1~0' Ph(~slng 120' Phas~n9 1~0' Ph(~sln9 12/24/89 12/17/87 12/16/87 EIVED B-5 I052~" Togged Fltt 1E/B9 10523' Junked retainer PBTD e I05~6' TI) 8 10660' MAF - 2 ]990 .a/asia Oil & Gas Cons. Commission Anch0mge Revis~on Dote, 1/11/90 Revised By, VHR/rm$ Re.sam Recomplet~on Previous Revislom 1/89 , MEMORA.N Stat of Alaska ALASK~ .. GAS CONSERVATION COMMISSION TO Lonnie C Smith~ DATE December 19, 1989 Commissioner ~ FILE NO D. JFB. 3 TELEPHONE NO THRU Michael T Minder ~1~,~.~ . SUSJECT Sr Petroleum Engineer BOP Test Marathon TBI D-SRD Permit No. 80-65 McArthur Rv Oil Pools FROM John F Boyle Acting Petroleum Inspector Saturday, Dec.ember 16,,,1989: After completing the safety valve retest and MITS ('cove~in Other reports), I stood by for the testing of the BOP system. The test began at 12:30pm and concluded at 8:30pm. As the attached BOP test report shows there were five failures, all of which were repaired and tested satisfactorily. The blind rams could not be tested because of tubing in the hole. After the tubing is pulled, they will be tested. In summary, I witnessed the BOP test on the Dolly Varden on Marathon' s TBU D-SRD. Attachment 02-001A (Rev 8/85) ( STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COMM ! SS I ON BOPE Inspection Report Operator L] AJ 0 C, 4k. / ~l&~,~,'~ k~ ,~ ~ Location: Sec ~ T ~N R ~ M ~ D?] g :o.t?:tr A 0 Location (general) ~ Well sign ~ General housekeeping ~ Rig ~ Reserve pit ~~ Visual Audio MUD SYSTEMS: DATE Trip tank Pit gauge Flow monitor Gas detectors Choke line valves HCR valve Kill line valves Check valve 0 i~ ~£AT3~ep resentati ve Permit # ~0--~ / 3 ~" Casing set ~. ~ ~0~ ACCUMULATOR SYST~: Full charge pressure Press after closure BOPE STACK: Test Pressure Annular preventer ! Pipe rams B1 ~nd rams / ft /SO~ psig Pump incr clos press 200 psig Full charge press attained Controls: Master (~ ~' mi n ~_~ sec psig Remote .0 J~ , Blind switch coverO~- KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Numb.r ~.]~s Number flanges Adjustable chokes Hydraulically operated choke Test pressure Test pressureoO. S Of _;~00 Test pressure~Q Test pressure Test pressure TEST RESULTS: Remarks: Failures ~' Test time ~ hrs Repair or replacement of failed equipment to be made within ~ days and Inspector/Commission office notified. · Distribution: orig - AOGCC c - Operator c - Supervisor Inspector: C.004 (rev 03/17/89) --' "'_..~,_a , -~- , Kill ~n~ . · Choke Val ve~ e -* --:---'"--" ·, ~hoke Atne Hydril Ba9 = . ChoJ~e H~nifold , , Upper Kell~ Cook , ._ ~..-Lower gellM Coak .... __ Che~ Valve B.qdrau,/.l c Lea]cs /~a/~e and ,mote-Operated Cho~e , ._ ' --~:~'"" ~-'- i ' Si~ of ' , AdJ~t~le ~o~e .--.~_ ' : Size ~ Positive Ch~e ' ' ' ' - . , . . ! . . '--':::::: J i c . , Pipe Rams ,., closing Pz'efsuz'e L Closing Time Opentnfl. Pre~ Open~ng Time Annular Sag I clostflg Pressure Clofin~ Time Open/n~ Pz.es~u~'e O?enin~ ~lme ~ltnd Ram;: Cloetn~ ~ Clo~in~ Time Opening RECEIVED .,' DEC i 1989, , <a 011 & 6as Cons. 6om , aig' s Pre~=ure ~ Forem~n STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O lt l G l lV 1. Type of Request. Abandon A Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repar well ~ PluggLn. g ~ Time extension ~ Sbmulate X~ Change approved program __ Pull tubmng ~ Variance __ Perforate X Other 2 Name ot Operator I 5. Type of Well UNOCAL (Marathon 0il Co - Sub Operator) Development_~.X Exploratory 3. Address ! Strabgraph~c P. 0. Box 190247 Anchorage, AK 995~9 Serv,ce~ 4. Locabon of well at surface Leg A-Z [;on(I, i~51 Uol/y Varden Plattorm 751' FSL, 1,127' FWL, Sec. 6- 8N- 13W- SM At top of producbve ~nterval 2,087' FSL, 3,542' FWL, Sec. 6- 8N- 13W- SM At effecbve depth 2,120' FSL, 3,720' FWL, Sec. 6- 8N- 13W- SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6- 8N- 13W- SM 6. Datum elevabon (DF or KB) 106' KB above MSL ,,, 7. Unit or Property name Trading Bay Unit feet 8. Well number 3-BRB g. Permit number 80-65 10. APl number 5o--733-20100-01 11. Reid/Pool Hemlock 12. Present well condition summary Total depth: mea§ured true verbcal 10,660' feet Plugs (measured) 10,043' feet None Effecbve depth measured 10,523 ' true verbcal 9,908' feet Junk (measured) feet Junked Retainer @ 10,523' Casing Length Structural Size Cemented Measured depth Conductor Surface 2,505' 13-3/8" Intermediate Producbon 10,608' 9- 5/8" Liner 1,195 sx True vertical depth PerforatIon depth: measured true vertical TubIng (s~ze, grade, and measured depth) Bench 1 9,925' - 9,970' MD Bench 3 10,150' - 10,182' MD Bench 4 10,220' - 10,250' MD Bench 5 10,320' - 10,370' MD 4-1/2", 12.6#, N-80 Tubing @ 9,830' MD 2,505' 2,505' 10,608' 9,987' 9,357' - 9,399' TVD 9,564' - 9,593' TVD 9,629' - 9,657' TVD 9,720' - 9,766' TVD a S SV(ty e~)~ e uredd th P~e]r~ ~_~ x ~- ~ ~r w~P~B~ @ 9,772' MD; Otis 4-1/2" DC TRBV @ 321' MD 13. Attachments 1, 2 Descnpbon summary of proposal ~ 3&4 14 Esbmated date for commencing operabon m I~ovember 20, i909 ! 16 If proposal was verbally approved Od X__ Gas Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~:7~~,/~~ Title Environmental Engineer y., -- {/- Roy- D. Roberts FOR COMMISSION USEONLY Cond~bons of approval. Notify Commission so representabve may w~tness Plug ~ntegnty __ BOP Test __ Locabon clearance __ Mechanical Integrity Test ~ Subsequent form required 10-_ ~¢ Detailed operations program _,y.. o.s Lrf E iV E [ 15. Status of well class~flcabon as: f':ev -- !989 Suspended ~ ~,., Anchorage Date 11/8/89 Approved by order of the Commmssion ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev O6/15/88 I Approva~ No. 7"' ,~ ..:vc.':~ COP"./ C---0mm,ss, oner Date //-"/'~'"'~;; SUBMIT IN TRIPLICATE (/~' Attachment #1 Well D-SRD Workover Procedure 1. Fill annulus with FIW. Skid rig over D-5RD. Bullhead FIW w/ 3% KC1 down tubing. ND tree, NU and test BOPE and riser. 2. POH laying down 4-1/2" ASL tubing and gas lift mandrels. 3. Retrieve Otis WD packer at 9772'. Make bit and scraper run to top of fill last tagged at 10,420'. 4. Cement squeeze all existing perforations. Clean out and pressure test each set of perforations. Resqueeze any perforations other than Bench 5 that will not pressure test. Clean out to -10,500', circulate hole clean and POH. 5. RIH w/ 8-1/2" bit and scraper to PBTD. Circulate and filter hole clean. POH. 6. Log the minimum with CET-CBL from PBTD. Evaluate need for additional squeeze work to isolate Bench 1 and 5. 7. RIH w/ TCP perforating assembly and perforate Bench 5 w/ 4 SPF. 8. RIH w/ packer to -10,280'. RU fracture pumping equipment. Perform step rate test and datafrac. Run temperature log. Modify frac design based on datafrac resul ts. 9. Fracture treat Bench 5. 10. Plug back to 10,100'. 11. RIH w/ TCP perforating assembly and perforate Bench 1 w/ 4 SPF. 12. RIH w/ packer to -9850'. Perform step rate test and datafrac. Run temperature log. Modify frac design based on datafrac results. 13. Fracture treat Bench 1. RD frac equipment. 14. Clean out to PBTD. RU E-line and run tracer profile from PBTD to -9800' Run GR/ junk basket to PBTD. RECEI ED 15. PU and run 4-1/2" completion equipment. Set packer at -9800'. 16. Land tubing. ND BOPE and NU tree. Release rig. 17. Unload well and test until stabilized production rate is obtained.A~ohoIag~ 18. RU E-line and perforate Hemlock Bench 3 (10,150' to 10,182') and Bench 4 (10,220' to 10,250') through tubing underbalanced. 19. Obtain a production profile after production stabilizes. Note: Maximum anticipated SBHP is 4000 psi. em\docs\afe\5 33" ax-,b:cor @ ~07 13-3/8, 611, 3-5~ @ 25Q5 9-$/8", ~3.~/& ~711, H-eO & P-II0 Proposed Comp]etlon Schematic SCSSV Gas Lift Mandrels w/Gas Lift Valves 13-3/8, 6if, .,T-55 @ 2.f05 I 321 ~f" 0cb IX: ~BY, 3.813" ID . vAia:co Of2--RC vmJ.vm & i~ Licch Bench I ~925 - 9970' Bench 3 10150' - I011~e Bench 4 10220'- 102.~' Bench 5 10320' - 10370' '/"': t: · . Production Packer i 4~', 12.g, H-(JO t~bLn8 ~b Ta) $ X 9-5/8" ltcr v/se&L - 0772 Bench I 9~25 - ~970' Bench 3 10150* - !0182° Bench 4 1022.0'- 10250' Bench5 1~20'- 10370' 6775 " 7381 " 7908 8317 8719 " 9092 N 9371 4~ HurLs ~TD umndreb, ~) - 3.833" ~678 2~/64" or3I. flm 9728 OcJj XA . 9774 1~e~co~ 9798 ~ Attachment #3 MARATHON OIL COMPAN~ DOLLY VARDEN PLATFORM BOP STACK Flowline U 13 S/8'x SOO0 I)'1 Annular Prevenler o o ..._._--------- Clamp Connecior _ r'J Pipe Ram, J-1 /13 5/8' 5000 pal Double Rama KilILIne3°SOOOpll ) ah9 m C-'/- Ch°k'Cine3'SOOOpal Drill Deck I:1~ ..oo,....,o REC£1VEi) - Caalnghead (~) 3' Howco LO Torque SO00 pal Valve All Flanges ere 3" SO00 CHOKE MANIFOLD 3' Vent Line Remote AdJusJeble Choke Slop Cock Valve (To Be Left Open) Manual I 1/2" Manual Choke Bull Plug 2' Blind Flange 6" lo Shaker Rig Floor Choke Une 3" 5000 Attachment #4 ~.OLLY VARDEN PL[i rFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP 4.1/fl.6-'. 5000 psi CHISTMAS TREE GREASE HEAD (Hydraulically Activated) - , BRICATOR , R[CEtVED POSITIVE CHOKE ~ 2' 5000 psi ...--. 2' 3000 psi 13 3/8' CASING REPORT OF SUNDRY WELL OPERATIONS I Operahons performed: Operahon shutdown [] Shmulate [] Plugging [] Alter Casing [] Other [] 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P. O. Box 190247 Anchorage, AK 99519 4. Locahon of well at surface Leg A-2 Cond. ¢f9 Dolly Varden Platfor~ 751' FSL, 1,127' FWL, Sec. 6 - 8N - 13W- SM At top of produchve ~nterval 2,087' FSL, 3,542' FWL, Sec. 6- 8N- 13W- SM At effechve depth 2,120' FSL, 3,720' FWL, Sec. 6 - 8N - 13W- SM At total depth 2,187' FSL, 3,806' FWL, Sec. 6 - 8N- 13W- SM Perforate J~ Pull tubing [] 5. Datum elevahon (DF or KB) 106' KB above MSL Feet 6. Unit or Property name Trading Bay Unit 7 Well number D-5RD 8. Approval number 7-908 9. APl number 50-- 733-20100-01 10 Pool Hemlock 11. Present well condition summary Total depth measured true vertical 10,660' feet Plugs (measured) 10,043' feet None Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,505' Intermediate Produchon 10,608 ' L~ner Perforation depth' measured true vertical Tubing (size, grade and measured depth) 10,523' feet 9,908' feet Size 13-3/8" 9-5/8" Junk (measured) Junked Retainer @ 10,523' Cemented Measured depth True Vertical depth 2,505' 2,505' 1,195 sx 10,608' 9,987' Bench 1 9,925' - 9,970' MD 9,357' Bench 4 10,150' - 10,182' MD 9,564' Bench 4 10,220' - 10,250' MD 9,629' Bench 5 10,320' - 10,370' MD 9,720' - 9,399' TVD - 9,593' TVD - 9,657' TVD - 9,766' TVD 4-1/2", 12.6#, N-80 Tubing @ 9,830' MD Packers and SSSV (type and measured depth) Otis WD-5 x 9-5/8" Pkr w/SBE @ 9,772' MD; Otis 4-1/2" DC TRBV @ 321' 12. St,mulat,on or cement squeeze summary R ~ ~, Intervals treated (measured) Treatment description including volumes used and final pressure 13 Representative Da~ly Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operahon 12/2/87 192 136 99 Subsequent to operation 12/18/87 401 51 602 735 psi 930 psi 130 psi 120 psi 14 Attachmentgx Da~ly Report of Well Operahons [~ Cop~es of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,_. S,gn~Roy D. Roberts T~tle Environmental Engineer Date 1/18/88 Form 10-404 Rev. 12-1-85 Submit ~n Duplicate (~,~._~ Attachment #1 TBU Well D-5RD Daily Summary of Well Operations 12115187 RU slickline, PT lubricator. RIH w/3.47 gauge ring to 9720' and cut medium scale to tbg tail. RIH to 10,427' , tag bottom, POOH. RIH w/BHP inst. and take FBHP survey @ 10,026. POOH. RD. 12116187 RU wireline, PT lubricator. RIH w/CCL, 3-1/8" through tubing guns, 4 SPF, 0° phasing. Correlate and perf Bench 4 from 10,220' - 10,250' DIL. POOH, RD, put well in test. 12117187 RU wireline, PT lubricator. Made five perforating runs using same guns as above. 1st run: perfed Bench 5 from 10,345' - 10,370' DIL; 2nd run: perfed Bench 5 from 10,320' - 10,345' DIL; 3rd run: perfed Bench 4 from 10,150' - 10,182' DIL; 4th run: perfed Bench 1 from 9,950' - 9,970' DIL; 5th run: perfed Bench 1 from 9,925' - 9,950' DIL. POOH, RD. NEF/em/61A/Sundr3 STATE OF ALASKA CO~,MISSION ALI,,,~A OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 'r. Type of Request: Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter camng [] T~me extension [] Change approved program [] Plugging [] Shmulate [] Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Operator U~OCAL (Harathon Oil Company - Sub Operator 3. Address P. O. Box 190247 Anchorage, AK 99519 4 Location of well at surface Leg A-2 uond. #9 Dolly varden Placfo~ 751' FSL, 1,127' FWL, Sec. 6 - 8N - 13W- SM At top of produchve ~nterval 2,087' FSL, 3,542' FWL, Sec. 6- 8N- 13W- SM At effechve depth 2,120' FSL, 3,720' FWL, Sec. 6 - 8N - 13W - SM At total depth 2,187' FSL, 3,806' FWL, Sec, 6 - 8N - 13W - SM 5 Datum elevation (DF or KB) 106 ' KB above MSL 6 Unit or Property name Trading Bay Unit 7. Well number D-5RD 8. Permit number 80-65 9. APl number 50-- 733-20100-01 10. Pool Hemlock feet 11 Present well condition summary Total depth, measured true vertical 10,660' feet Plugs (measured) 10,043' feet Nome Effective depth' measured 10,523' true vertical 9,908 ' Casing Length Size Structural Conductor Surface 2,505' 13-3/8" Intermediate Production 10,608" 9-5/8" L~ner Perforation depth, measured true vertical feet Junk (measured) Junked Retainer @ 10,523' feet Cem~ E I ~ EI~asured depth True Vert,cal. depth "' ~ -,~_~ . A*- Ot~' kt~s~ Oil & Gas Cons. c0mmts~°5 '-- ~-- 2, 505~ 1, l~C~age 10,608' 9,987' Bench 1 9,925' - 9,970' MD 9,357' Bench 4 10,150' - 10,182' MD 9,564' Bench 5 10,320' - 10,370' MD 9,720' - 9,399' TVD - 9,593' TVD - 9,766' TVD ~bing(s~ze, grade and measured depth) 4-1/2", 12.6#, N-80 Tubin~ @ 9,830' MD Packers and SSSV(type and measure~depth) Otis WD-5 x 9-5/8" Pkr w/SBE @ 9,772' MD; Otis 4-1/2" DC TRBV @ 321' MD 12 AttachmentiF 1 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13 Estimated date for commencing operation November 1987 14 If proposal was verbally approved Name of approver Date approved 15 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned /~'~~,~~ Title Environmental Enqineer ~/'Roy D. RoDents bA Commission Use Only Cond~hons of approval Notify commission so representative may witness I Approval [] Plug ~ntegmy [] BOP Test [] Location clearanceI Date 11/20/87 Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Ii --. ,_ _ . _.. __ommlssloner by order of the commission Date Form 10-403 Rev 12-1-85 Submit ~n triplicat~ Attachment #1 Well D-SR~ Procedure 1. RU Otis WL and PT to 2500 psi. 2. RIH with 3.50" gauge ring and cut scale as necessary. 3. Tag bottom and POH. 4. Make up dual Amerada bombs. 5. RIH and stabilize well. 6. Measure FBHP at 10,026' (9450' TVD). 7. POH and RD Otis. 8. RU E-line and PT to 2500 psi. 9. Perforate the following zones underbalanced or flowing and test as indicated. Ail runs will be with 3 1/8", 4 SPF, 120° phasing, through tubing guns. Run Interval(DIL) Feet Zone 1 10,220' - 10,250' 30 B4 Stabilize well and test for 24 hours 2 10,345' - 10,370' 25 B5 3 10,320' - 10,345' 25 B5 4 - o, s2' 5 9,950' - 9,970' 20 BI 6 9,925' - 9,950 25 Bi NOV 2 QigS7 10. RD E-line. ~ska 0il & Gas ConS. commission Anchorage 11. RU Otis and PT lub. to 2500 psi. 12. RIH with dual Amerada gauges and stabilize well. 13. Measure FBHP at 10,026' (9450'TVD). 14. POH RD Otis. Otis will read pressure charts, then send data and chart to Rose Hamlin in Anchorage Office. Data will also be sent to Bill Browne in Nikiski. 15. Test well for at least 24 hours. NEF/em/61/Sundr3 .~ STATE OF ALASKA ALASK ~IL AND GAS CONSERVATION COMM( .ION REPORT OF SUNDRY WELL OPERATIONS 1. Operahons performed: Operahon shutdown [] Stimulate ~ Plugging ~, Perforate ~ Pull tubing AIterCas~ng ~ Other [] 2. Name of Operator D~OCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Locahon of wellatsurface 751' FSL, 1,127' FWL, Sec. 6 - 8N - 13W - SM Attop ofproduchve~nterval 2,087' FSL, 3,542' FWL, Sec. 6 - 8N - 13W - SM Ateffechve depth 2,120' FSL, 3,720' FWL, Sec. 6 - 8N - 13W - SM Attotaldepth 2,187' FSL, 3,806' ~L, Sec. 6 - 8N - 13W - SM 11. Present well condition summary Total depth: measured true verhcal Effechve depth: measured true vertical Casing Length Structural Conductor 407' Surface 2,505 ' Intermediate Produchon 10,608 ' L~ner Perforation depth: measured 5 Datum elevation (DF or KB) KB 106 6. Unit or Property name Trading Bay Unit 7. Well number 8 Approval number 9. APl number 50-- 733-20100-01 Feet 10. Pool Hemlock 10,660' feet 10,043' feet 10,526' feet 9,910' feet Plugs (measured) Junk (measured) S~ze Cemented 33" 13 3/8" 9 5/8" 1,915 sx Measured depth 407' 2,505' 10,608' See Attachment #1 true vert~cal Tubing (s~ze, grade and measured depth) 4 1/2", N-80 @ 9,830' Packers and SSSV (type and measured depth) 12. Stimulahon or cement squeeze summary WD - 5 Packer @ TRRV (a 32] ' Intervals treated (measured) Treatment descnphon ~nclud~ng volumes used and hnal pressure 9,772' True Vertical depth 13. 407' 2,505' 9,987' Prior to well operation Subsequent to operahon Naslm 0ii & bas ~3ol]s. G0mm[s$[0Q Anchorage Representahve Daily Average Produchon or Injechon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 169 54 80 760 100 466 149 289 980 120 Date 6/6/86 14. Attachments Attachment #2 B~i~Report of Well Operahons ~ Cop~es of Logs and Surveys Run [] 15. I hereby cerhfy that the foregoing ~s true and correct to the best of my knowledgeL~'% J~''- R~ D. Roberts Title Environmental Engineer S~gned Form 10-404 Rev. 12-1-85 Submit ~n Duplicate Attachment #1 WELL D-5RD PERFORATIONS Hemlock Bench 1 Bench 4 Bench 5 MD 9,925' - 9,970' DIL 10,150' - 10,182' DIL 10,320' - 10,370' DIL TVD 9,357' - 9,399' 9,564' - 9,593' 9,720' - 9,766' WJL/092/em/LAV Attachment #2 WELL D-5RD The well was perforated on April 18 and 19, 1986, with 3 1/8" guns, 0° phasing, 4-HPF, under draw down as follows: i. Rig up lubricator and test to 2500 psi. 2. RIH and perf: B-5 10,320' - 10,370' DIL. B-1 9,925'- 9,970' DIL. B-4 10,150' - 10,182' DIL. 3. Return well to production. Note: Tagged Fill @ 10,489' WLM before perforating. WJL/em/091/LAV I. Im>=al Oil & Gas Bi~isie~ ~ Unocal Corlx~atK~ ~· RO. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) En~ronn~ntal Group Alaska ~ April 8, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: SUNDRY NOTICES AND REPORTS ON WELLS DOLLY VARDEN PLATFORM Attached for your approval are two (2) copies each of Form 10-403 for wells D-3RD2; D-SRD and D-43RD. Upon approval, please return one copy of each Notice to the undersigned. Very truly yours, Environmental Engineer cwl 00280 cc: Trading Bay Unit Participants RECEIVED APR 0 Alaska Oil & Gas C~ns, Commission Anch0ra~e ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2 Name of Operator Unocal* 3 Address P.O. Box 6247 Anchorage, AK 99502 4 Location of Well Surface: Leg A-2, Cond. #9, Dolly Varden Platform 751' FSL, 1127' FWL, Sec. 6-8N-13W-SM 7 Permit No 80-65 8 APl Number 50733-20100-0 9 Unit or Lease Name Trading Bay Unit 10 Well Number 11 F,eld and Pool 5 Elevation m feet (~nd~cate KB, DF, etc ) I 6 Lease Demgnat~on and Semal No 106' KB Above MSLI ADL 18729 McArthur River Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casmg [] Perforations [] AItermg Casmg Stimulate [] Abandon [] St~mulat,on [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubmg [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertment detads and g~ve pernnent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) PERFORATE TBU WELL D-5RD It is Marathon's intention to perforate the well with 3 3/8" guns, 4 SPF, 0° phasing, under drawdown. · Be Rig up WL and lubricator, pressure test to 2500 psi. RIH and perforate Benches 1 & 5; 9,925' - 9,970' DIL B-1 10,320' - 10,370' DIL B-5 Flow test the well. RIH and perforate B-4; 10,150' - 10,182' DIL. Return the well to production. Perforating operations are expected to begin April 10, 1986. [CEIVED APRO 9 lgB - Sub Operator * Marathon Oil Company ~~ ~,~m~ ~__~_~~ ~,~ .... ~,, ~ r, ,s Cons. C0mmissi0n r~ F~ No. ~_~Dr~:...~] ~./~ .-~?ch0rage 14 I herebyz:~ert,f.~)th_~_ h~e for_~..o~ng ~s true Signed ~)7D'¢~i~~'~'~ The space below for Commission use Conditions of Approval, ff any Approved by. and correct to the best of my knowledge ~"..J-; ~ Er~i~l Enginer 4/8/86 T~tle Date By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Trmpllcate and "Subsequent Reports" ~n Duplicate f STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] Name of Operator Union Oil Co~l_~an~v of Cai if. * Address P.O. Box 6247 Anchorage Alaska 4 Location of Well 99502 Surface: Leg B-I, cond. #2, Dolly Varden platform 6?3' FSL, 1220' FWL, Sec. 6-SN-13W-SM 7 Perm,t No 82-20 8. APl Number 5o- 733-201q? 9 Un,t or Lease Name Trading Bay Unit 10 Well Number D-6 ~ 11 F,eld and Pool Elevation in feet (indicate KB, DF, etc ) [ 6 Lease Des~gnat,on and Serial No 106' KB above MSL I ADL - 18729 McArthur River Field 12 Check Appropriate Box To Indicate Nature of Notice, Rei3D¥-'L, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations ,r~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~ Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Change of drilling plans. 1) A window was cut in the 9 5/8" csg. at 6652' DPM beginning March 12, 1982. 2) Ran ?", 29#, N-80 But casing to 13,833' OAL. Pumped 1250 sx cl G cmt in first stage. Returns to surface. 3) Pumped 600 sx cl G cmt in second stage through DV collar at ?592'. 4) The well was completed as a Hemlock Injector. RECEIVED MAR--4 !983 Alaska 0il & Gas Cons Commission Anchorage * Marathon Oil Company - Sub operator 14 h~ ?rt If~~f°re~g Is trTd ~ ISlgr e ' · Approved by correct to the best of my knowledge DISTRICT DRLG SUPT By Order of COMMISSIONER the Corem,ss,on T~tle Date 311183 Date ___ -- Submit "Intentions ,n Tr~plmate Form 10-403 and "Subsequent Reports ,n Duphcate Rev 7-1-80 A~. STATE OF ALASKA C~, ALASK oIL AND GAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~[ 2. Name of Operator 7 Permit No. Union Oil Company of C~lifornia* 80-65 3. Address 8 APl Number P. O. Box 6247, Anchorage AK 99502 50- 733-20100-01 OTHER [] 4. Locat,on of Well Surface: Leg A-2, Oond #9, Dolly Varden Platform 2000'FSL, 1500'FEL, Sec. 6-SN-13W-SM 5. Elevation ,n feet (~nd~cate KB, DF, etc ) 106' KB above MSL 12. I 6 Lease Designation and Serml No ADL-18729 9 Umt or Lease Name Trading Bay Unit 10 Well Number 11. F~eld and Pool McArthur River Field Check Appropmate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. {Submit ~n Tmphcate) Perforate [] Alter Camng [] Perforations St,mulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing {Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each complenon ) SUBSEQUENT REPORT OF. (Submit m Dupl,cate) Alter,ng Casing [] Abandonment [] Other [] [] 13. Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On November 20, 1982, the well was perforated with 2-5/8" Slimkone guns, 0° phasing, 4 HPF, under drawdown as follows: Bench #1 9,925 ' - 9,945 ' DIL 9,955'- 9,970' DIL Bench #5 10,320 ' -10,370 ' DIL Tagged PBTD @ 10,469 ' DIL on last run. Production before reperforating: 840 BFPD, 12% BS&W, 739 BOPD, 101 BWPD Production after reperforating: 1512 BFPD, 6.5% BS&W, 1414 BOPD, 98 BWPD * Marathon Oil Company Sub-operator RECEIVED DEC 0 6 ]982 Alaska 0il & (~as Cons. Comntls.~on Anchorage 14 I hereby certify that the foregoing m true and correct to the best of my knowledge S,gne~~.~_.-~ T,t lo _ . ~~-~ ~Z~_~~ ~~-¢-~'-~.~ Date Th e space 'bel'owy/om m ,ss,on use Conditions of Approval, ~f any Approved by By Order of COMMISSIONER the Comm~ss,on Date __ Form 10-403 Rev 7-1-80 Submit "Intentions" m Tr~phcate and "Subsequent Reports" ,n Duphcate STATb. OF ALASK. A ALASK/a OIL AND GAS CONSERVATION~ iMMISSION SUNDR¥,iOTICES AND REI OR1 ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator 7 Permit No Union Oil Company of California* 80-65 3. Address 8 APl Number P.O. Box 6247, Anchorage, AK 99502 50_733-20100-O1 4 Location of Well Leg A-2, Cond #9, Doily Varden Platform - 2000'FSL, 1500'FEL, Sec. 6-8N-13W-SM 5. Elevat,on ~n feet findlcate KB. DF. etc ) 106' KB above MSL 12. I 6 Lease Des~natlon and Serial No ADL- 1 8729 9 Umt or Lease Name Trading Bay Unit 10 Well Number D-5RD 11 Fmld and Pool McArthur River"Field Check Appropriate Box To Indicate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit in Duplicate) Perforate IX] Alter Casing [] Perforations [] Altering Casing [] St,mulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other F-] Pulhng Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubmitted Form 10-407 for eachcomplet~on) 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is Marathon's intention to reperforate Hemlock Benches 1 and 5 with a 2-5/8II Sl imkone gun w/ 4 HPF, 0° phasing. Bench 1 9,925'- 9,945' DIL 9,955'- 9,970' DIL Bench 5 10,3201-10,340' DIL **Bench 4 10,150'-10,170' DIL The October, 1982, production test averages were: 989 BFPD, 13.50% WC, 856 BOPD, 133 BWPD. EECEIVED DECO ! 1.982 Alaska 0d & Gas C0rl5. ~umm/s~i0D Anchorage 14 I hereby cer~ S~gned __ The space below for Commission use ~e f~r_~golng is true and correct to the best of my knowledge. ~j~ c~ m,tle District Enoineer C. H. CASE Date 11/29/82 Conditions of Approval, if any Approved by / · COMMISSIONER the Commission Date /~' - _ _ ~ __ Form 10403 Submit "Intentions" in Triplicate Rev 7-1-80 and "Subsequent Reports" ~n Duphcate ** Bench #4 will be perforated if Benches 1 and 5 do not show a significant increase i n prod uct i on. Subsequent Work 11s.oorted ¢¢'..%¢ ¢ ~/ ~!~ d~ * Marathon Oi Company Sub-operator. ---~ ' ""~'~ 2-~' ~'~'~ /~'-*-- -, ---/z~Z-- [z--2 Do('cument Transmitta~ ~ Umon 0~1 Company of Callfo ,, unl ,n FORM !-2M02 {REV 1 1-72) PRINTE0 IN U S A HAND DELIVER ,:,ATE SUEiMITTEO ACCOUNTING MONTH 7/29/82 '~o John Levorsen F',OM R. C. Warthen Alaska Oil & Gas P.O. Box 6247 ^"r Conservation Commission Anchorage, AK 99502 3001 Porcupine Drive ~~=~ ~-~ 9950~. 2;/ ~ · TELEPHONE NO TRANSMITTING THE FOLLOWING: ii 1 !set Direct£onal Surveys ...... TBU D-5 ~RD., ., · , , ..... ...... ., , ~CD: d- / ..... , , , ~ ..... ~ ~,, . I , ..... ~c.h~ 'ago ~ , ~ , ,, ,,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator 7 Permit No Union Oil Company of California 82-20 3 Address 8 APl Number P.O. Box 6247, Anchorage, AK 99502 50- 733-20147-0/ 4 Location of Well Surface: Leg B-i, Cond #2, Dolly Varden Platform 673' FSL, 1220' FWL, Sec 6-8N-13W-SM Elevation ~n feet (~nd~cate KB, DF, etc ) 106' KB above MSL Lease Designation and Semal No ADL-18729 12 9 Umt or Lease Name Trading Bay Unit 10 Well Number D-6RD 11. F~eld and Pool McArthur River Field Check Appropmate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tmphcate) (Submit m Dupl,cate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tub,ng [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13. Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of start,ng any proposed work~ for Abandonment see 20 AAC 25 105-170) Due to 9-5/8" casing problems below 6950' MD, it is necessary to revise the D-6RD drilling plans. The 8-1/2" hole will now be drilled from a new kickoff point at approximately 6700' MD to the original location at 13,829' MD; 10,350' TVD. Seven inch casing will be run to surface and cemented with approximately 1400 sacks and the well will be completed as a Hemlock injector. Verbal approval for the above procedure was received from J. Trimble on 03-10-82 by D. Stover. *Marathon Oil Company - Sub-Operator o~ ~o~ ~°J~ 14 I h~cert,fy~that~, o~thof and~rr~tt~~thebostofmg kno~lod~o S~gned/t . _ -_ T,tle DIST D~ S~T mission use Con~ of Approval, ~f any Approved Date 3/18/82 o~y Approvedby BY }],~,~[~¥ W. KJJ~.£R COMMISSIONER Returned By Order of the Commlsmon Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate r ' 3000 I MARATHON I1 OMP./~NY i;,' DOLLY ,VARDE, N ~PLATFI3( ;_,_.: .... LEG B.-I CONDUCTOR ":, i ' ' i "' SCALE '1"=1000''' ; ' I , ~' ~ ~MARCH ,9;'.:- 1982 I ' ' 13v ~ BESSE, EPPS ,& POTTS ~ AMER'IC~" 4000 ': - II I ..DIRECTIONAL .DRILLING..,.__:-: .... 5000 ' ' 6000 ~ ' 7000~ ' ~ - ' 8000 ' ' ' ' ' I I ' ' ' I , ,, I ', I ' , ,.; ', i i ,j ; _, t I i,, j . 7 18 :: , ' I.., , j , ., ! I ;, - , ,~... ~, , , , , I, ~ ' , : J '~ ...... ' 48 O ' ' ' T8 , ,j ,t I ' , , ' ~ ' , J , , J ~~.'.KOP (mR.$s~ se~'l . N,,RI3 W,S~. , ~ _.' .... ~ , , . ~ , ~ . , , ~ , , ~ ~ , . , ' ,-' ,I i ~'~ ' , , , :-' , , ~ j ', ~. 0/, i ~ I ', , ~ I ~ . , , , ..... t , J-' , ' I i .-, . ~. ~' - ' ' , ~ ' - ~ ' ' ~ ', ~/ ~ : i ' ' -~--' ' ' ,, ~P ~ :, ~ '~eeo ! I , ', ~ J ~ , , , ~_~ , %r0 (AN~LE ~oOB'~ .T~ l-~'! J ; I ;, ~ ~, ' ' DRoP opEn ,oo' 5000 ~, TVD=486~ ~ 4¢ ' , ....... ~" F --'--F' '-' 7 -~%F:7~ .... ~ '-, .... ' TMD=6700 ~ ~ ' ' j , ' -' , ~ ~ i, ''~ ' '-DE~=3997 ' '0° -t J ' ' ' ' ; ~ ' ,*' ;-t ' -~-EOC! ',;,~ ,-~ ' , , . TVD'= 5248 TMD '= '7243 '- DEP = 4378 : i + .- , . ' ' ' , ' ,. ! ' JO k, , , "L ' ' '~, .... I *-; '~. ' i ' ' s j ~ ' , ' I ' ' ~ , ~ ' ' ' , Ft~ ...... ' t ' ' ~ ' , L , ~ ' ..... ' i ,: , ,,,, ',,,, t,,. [~ii~ ........ t . , J ' , , ~L , I ._L '1 . ' .... : :. I ' ~ ' ' , , -, D~PARTURE,,ALON~ LINE OF SECTION ~ ' j; , ~ [ , . )' ;5~ ~, ; e~O SURFACE 'TO TARGET (S69°45'E) ' , ~ r I ' , r j I Document Transmittal Un,on 0~1 Company of Callforn DATE SUBMITTED ACCOUNTING MONTH HAND DELIVERY 11-18-81 TO FROM Mr. Bill Van Allen R.C. Warthen AT Alaska 0il & Gas Cons. C¢~m~. Pouch 6247 3001 Porcupine Drive Anchorage, Alaska 99502 Anchrua§e, Ai~sk~ TE'EP.ONE NO TRANSMITTING THE FOLLOWING D-5 RD Magnetic tapes- 1 ea. 60703 1 ea. 60702 1 ea 60702A 1 ea.! 60713 PLEASE SIGN AND RETURN 0NI' COPY RECE I VEDAS'? ~"~ DATE'E C E I V E I NOV Alaska 0~1 & Gas C, nn~ AnchoraDe FORM 1-2M02 (REV 11-72) PRINTED IN U $ A A{r~ STATE OF ALASKA ALASK IL AND GAS CONSERVATION C~' JlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator 7 Permit No Union Oil Company of California* 80-65 3 Address 8 APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20100-01 4 Location of Well Dolly Varden Platform, Leg A-2, Conductor #9, 2000'FSL, 1500'FEL, Sec. 6, T8N, R13W, SM 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 106.2'KB Above MSL 12 Lease Demgnatlon and Serial No ADL-18729 A-926 9 Unit or Lease Name Trading Bay Unit 10 Well Number D-bRD 11 F~eld and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other-Data ......... ~ NOTICE OF INTENTION TO' ,.._ SUBSEQUENT REPORT OF ~/2 (Submit m Tnphcate) (Submit m Duplicate) Perforate [] Alter Casing [] ~ Perforat,ons Stimulate [] Abandon r'q Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion Altering Casing Abandonment Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105~170) On January 17, 1981, perforated the following Hemlock intervals under drawdown: Bench 1: 9925' - 9945' 4 HPF DA 3-1/8" Jumbo Jet 120© Phasing Production Test: Before Perfs: 1011 BFPD .8% WC 1003 BOPD After Perfs: 2098 BFPD .3% WC 2092 BOPD 1981, to Tony Swan. Verbal approval received from Russ Douglass on January 15, *Marathon Oil Company - Sub-Operator I ECEIYED FE~ _ 6 I981 .t[laska Oil & Gas C0 , ns. Comrnis$io~ /~chorage 14 I hereby certify that the foregmng ~s true and correct to the best of my knowledge S,gned~t~ t~0~/~,t~ ~, T,tle Dist. Drlg. Supt. Conditions of Approval, ~f any ~ Date 2/5/81 By Order of Approved by. COMMISSIONER the Commmsmon Date Form 10-403 Rev 7-1-80 Submmt "Intentions" in Triplicate and "Subsequent Reports" ~n Duphcate DATE: ~/~ ~,/~-~ ~-.~ DATE $ U B M I '~'"'~ ~' O ACCOU ITO F~OM C. Warthen H. W. Kugler . Alaska 0il & Gas Cons. Cor~. Union 0il Com AT 3001 Porcupine Drive ^TP0 BOX 6247 Anchorage, AK 99504 Anchorage, AK 99502 TELEPHONE NO TRANSMITTING THE FOLLOWING RES ENG 1 ENG DST Neutron Decay Time Lo( Natural Gamma Ray Tool Neutron-CNL 2" LSS DDBHC/GR 2"~ 5" :ased Hole 2", 5" DI-SFL TVD 2" DI-SFL 2"~ 5" uel i ne 5" II FORM 1-2M02 (REV 11-72) PRINTED IN U 5 A *. ~rm No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA el L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP1 NUMERICAL CODE 50-133-20100-01 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 2. NAME OF OPERATOR Union Oil Company of California* ADDRESS OF OPERATOR P. O. Box 6247, Anchoraqe AK 99502 4. LOCATION OF WELL Leg A-2, Cond ~9, Dolly Varden Platform 2000'FSL, 1500'FEL, Sec 6-8N-13W-SM & UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBU D-5RD 10. FIELD AND POOL, OR WIL~AT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO. 80-65 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. AUGUST REPORT OF DRILLING OPERATIONS 08-01 10,660'TD 10,526'PBTD Fin POH w/ OEDP. RU DA. RIH w/ JB & GR 2 times. RIH w/ Halliburton EZSV cmt rtnr on DA WL & set @ 10,197'(DIL). POH. RIH w/ cmt rtnr stinger on DP. Tstd lines to 6000~ & tstd 9-5/8" csg to 2500 psi. PI sqz perfs @ 10,229'-10,230 (DIL) @ 1-1/4 BPM & 2-1/2 BPM @ 3600 psi. Mixed & spotted ' 250 sx CIG cmt w/ 1% CFR-2 & 0.3% Halad-9. Sqzd 125 sx below rtnr to max & FP of 4900 psi. CIP @ 0300 hrs, 08-01-80. Rev 125 sx. POH. 08-02 10,660'TD 10,526'PBTD Fin POH w/ cmt rtnr stinger. Tstd BOPE. RU DA. RIH w/ GR & JB to 9887'. Could not get below 9887'. JB stuck momen- tarily. POH & rec cmt in JB. RD DA. RIH w/ bit & scraper. Circ clean FIW into hole. POH. RU DA. RIH w/ GR & JB to 10,185'. POH. 08-03 10,660'TD 10,526'PBTD Fin POH w/ JB & GR. Rec small pieces of cmt. RIH w/ 4" csg jet & perfd 10,178'-10,179'(DIL) w/ 4 HPF. POH. RIH w/ EZSV rtnr on DA WL & set @ lO,130'(DIL). Unable to pull loose from rtnr. Pulled out of rope socket. POH. RIH w/ OS. Tagged fish @ 10,117'. Latched fish & pulled free. POH. Rec clr loc & setting tool. RIH w/ cmt rtnr stinger on DP. Stabbed into rtnr & tstd csg to 2000~--OK. Tstd Inr to 6000#. PI perfs @ 1BPM @ 4100 psi & 1-1/2 BPM @ ,,.~,~600 psi. Mixed 150 sx C! G cmt w/ 1% CFR-2 & 0.3% Halad 22-A. Sqzd 39 sx below rtnr @ FP of 5100 psi. Rev 111SXo CIP @ 0630 hrs, 08-03-80. Circ to clean DP. 08-04 10,660'TD Circ to clean cmt from DP. POH. LD cmt rtnr stinger. 10,526'PBTD Performed rig maint while WOC. MU BHA & RIH. Drlg cmt rtnr @ 10,130' @ 0700 hrs. I hereby c~n'~f~at the f~~true and correct Dist. Drlg. Supt.DATE 9/8/80 14. NOTE~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. *Marathon Oil Company - Sub-Operator August Report of Drilling Operations Page 2 08-05 10,660'TD lO,526'PBTD 08-06 10,660'TD lO,526'PBTD 08-07 10,660'TD 10,526'PBTD 08-08 10,660'TD 10,526'PBTD 08-09 10,660'TD 10,526'PBTD 08-10 10,660'TD 10,526'PBTD 08-11 10,660'TD 10,526'PBTD 08-12 10,660'TD 10,526'PBTD Fin drlg cmt rtnr @ 10,130'. Drld hd cmt to 10,180'. Tstd csg & sqz to 2000~--OK. Drld 2nd cmt rtnr ~ 10,197' & drld hd cmt to 10,230'. RIH & pushed junk to btm. Rev circ to clean hole. Tstd csg & sqz to 2000#--OK. POH. LD DC's & HWDP. RIH w/ bit & scraper. Circ & clean hole. POH. RU DA. RIH w/ GR & JB. DA set Otis "WD" pkr @ 9772'(DIL). RD DA. RIH w/ DP & POH LD DP. RU to run tbg. RIH w/ prod tbg. Fin running 4-1/2", 12.6#, SL tbg & landed same. ND BOP's. NU Xmas tree & began connecting flow & gas lift lines. Fin NU Xmas tree. RD & prep to move eqpmt to Rig 76. Attempting to GL well. GL well for drawdown. Perfd Hemlock Bench 5 from 10,320' to 10,370' (DIL) w/ 4 HPF. Two hr test: 744 BFPD @ 65% cut. Choke barely open. TP 500 psig. Flow testing D-5RD: Time Flow Rate Cut TP Lift Gas 1300 1128 BFPD 3% 200# 2-1/2 MM 1900 984 BFPD 0.1% 200# 2-1/2 MM 0030 960 BFPD 0.1% 200# 2-1/4 MM 0600 1060 BFPD 0.1% 200# 2-1/4 MM Flow tstd D-5RD: Sep Lift Form Flow Time TP CP Gas Gas Gas (BPD) Cut 1400 160 1050 2200 M 2080 M 120 M 1097 0.1% 2400 150 1060 2199 M 2068 M 131M 1104 0.1% Flow tstd well: 1152 BPD @ 0.1% cut. TP 150~; CP 1050#; Sep Gas 2409; Lift Gas 2213. Released ri§ to D-12RD @ 0700 hrs~ 08-12-80. STATE OF ALASKA (see other in- structions on . OIL AND GAS CONSERVATION COMMITTEE reverse side) 5 APl NUMERICAL CODE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* e LEASE DESIGNATION AND SERIAL NO ADL-1 8729 A-926 la TYPE OF WELL OwIELLL~=~ GAS I---I WELLLJ DRY [-~ Other b TYPE OF COMPLETION NEW WORK DEEP- F-3 PLUG DIFF WELLE] OVERE~ EN I I BACKO RESER BI Other Redriil 2 NAME OF OPERATOR Union Oi I Company of California* 3 ADDRESS OF OPERATOR P. O. Box 6247, Anchoraqe AK 99502 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface Leg A-2, Conductor #9, Dol i¥ Varden Platform 751'FSL, 1127'FWL, Sec 6-8N-13W-SM At top prod interval reported below 2087'FSL, 3542'FWL, Sec 6-8N-13W-SM At total depth 2187'FSL, 3806'FWL, Sec 6-8N-13W-SM 7 IF INDIAN, ALLOTTEE OR TRIBE NAME ---- 8 UNIT, FARM OR LEASE NAME Tradinq Bay Unit f'~ 9 WELL NO ~Jl' D-5RD 10 FIELD AND POOL, OR WILDCAT ~ McArthur River Field '.~'/~v 11 SEC,T, R, M, (BOTTOM HOLE OBJECTIVE) Sec. 6, TSN, R13W, SM 2 PERMIT NO 80-65 13 DATE SPUDDED 114 DATETD REACHED 115' DATE COMP' SUSP' OR ABAND06-0 8-80 07-21-80 08-13-80 !16 ELEVATIONS{DF'RKB'RT'GR'ETC)* 117 ELEV CASINGHEADKB 106' Above MSL 63'MSL 10,660'MD I DEPTH 10 526'MD I HOWMANY* ' 121 ROTARY TOOLS INTERVALS DRILLED BY cABLE TOOLS 1¢/ .¢~A~,'T\/.F1 I q'ql0'TVD I -- All 22 PRdD~LI~N~-IN'I'E~AL(S), OF THIS COMPI:E~i'ON - TOP, BOTTOM, NAME (MD & TVD)* 23 WAS DIP ECTIONAL Top of Hem lock: 9920 ' MD 9349' TVD SURVEY MADE Btm of Hem lock: 10,484'MD 9785'TVD Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN LSS-DDBHC-GR ABL-Si~nature~ ABL-VDL~CNL(CH),, CD¢-CN¢~ DDNLL~ NGT~ Spectroloq. TDQ,Lt TDT~ DIL/SFL/GR, 25 CASING RECORD (Report all strings set in well) 9-5/8" 43.5~/ IN-80 I 1,277' 12-1/4'] 1st Stage: 1250 sx CI .G 9-5/8" 47# In I 8.199' 12-1/4'1 2nd Stage: 685 sx CIG 9-5/8" 47# I P-11nI 10~.608' i 2-1/4'1, [ 28 PERF'~RATIONS OPEN TO PRODUCTION (Interval, size and number) 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) ]AMO_U..NTANOKINDOF MATERIAL .... USED Bench 5: 10,320'-370' DA 3-1/8" gun, Cmt sqzd 2 intervals w/ DA 4" r_~n irt_ ~ HPF 120° Phase, 4 HPF .at flowin~ intel-vals. , 10,178'-1~9 sq'l 39 sx CIG cmt, FP 5100# .......... ~ 10t229'-230' sq, 125 sx CIG cmt~ FP 4900# 30 PRODUCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing. ga5 lift, pumping--size and type of pump) 08- 10-80 I Gas Lift DATE OF TEST IHOURS TESTED ICHOKE SIZE ! PROD'N FOR Ii I ITESTPERIOD 08- 13-80 24 FLOW TUBING CASING PRESSURE ~ CALCULATED OI L--BBL 1 4..ou.RA~_TE PRESS 150 I 1040 31 DISPOSITION OF GAS (Sold, u~ed for fuel, vented, stc Lift Gas and Sales l WE LL STATUS (Producing or .hut-i.) Prod uc i n,q OIL--BBL GAS--MCF WATER--BBL I GAS-OI L RATIO I ~ ~64 I188 I 12 J 561 GAS-~CE.. , .~, r WA.TER--BBL IOILGRAVITY-API (CORR.) ': 'i ') ~' "" ITESTWITNESSED BY ,,. ; - ~- ,IW- F. Stephens~ Jr. 32 LIST OF ATTACHMENTS Wel I Histp4~y, Tubing and Casing Detai Is 33 I hereby certify tl~t tt~ foregoing and attached information is complete and correct as det~'mir;~d from all available records · ,¢ Dist. Drlg. Supt. s,~,E~~~ [- Cz:~//z,,,-_~4.~ T,TLE *(See instructions and Spaces for Additional Data on Reverse Side) *Marathon Oil Company - Sub-Operator DATE 9/8/80 INSTRUCTIONS General Thru form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska Item 16' Indicate which elevation Is used as reference (where not otherwise shown) for depth measurementsg~ven ~n other spaces on thru form and ~n any attachments Items 20, and 22 If thru well ~s completed for separate production from more than one ~nterval zone (multiple com- plet~on), so state ~n ~tem 20, and ~n ~tem 22 show the producing ~nterval, or ~ntervals, top(s), bottom(s) and name(s) (~f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) onthmform, adequately ~dent~hed, for each additional ~nterval to be separately produced, showing the additional data pertinent to such ~nterval Item 26 "Sacks Cement" Attached supplemental records for th~s well should show the details of any multiple stage cementing and the location of the cementing tool Item 28. Submit a separate completion report onthmform for each ~nterval to be separately produced (See~nstruct~on for items 20 and 22 above) ~RY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35 GEOLOGIC MARKERS NAME MEAS DEPTH TRUE VERT DEPT See Item 30 on front See Item 22 ¢~ front CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER Fo~;~ 484 ~v. ~-~3 /.~, ~ DATE August, 9, 1980 M~-.~ATHON OIL COMI~ANY HISTORY OF OIL OR GAS WELL FiELDMcArthur Ri ver WELL NO. D-5RD STATE A I aska LEASE Trading Bay Unit PARISH Kena i Pen i n- COUNTY. sula Borough BLOCK SEC. 6 TWP.. 8N R. 13W M I[ASURI[MENTS TAKEN FROM fToP OF OIL STRING TOP OF ROTARY TABLE GRD. OR MAT. ELi[V., ELI[V., ELEV,.~ ELI[V, __ H~STORV P.I[.ARI[O at L..G. Haywood Secretary TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1980 06-08 06-09 06-10 06-11 06-12 WELL HISTORY - TBU WELL D-5RD (Marathon AFE 4678) 10,250'TD Skidded rig over Well D-5. ND Xmas tree. NU BOPE & tstd. 5,783tPBTD Displ wtr in 9-5/8" csg w/ mud. POH. LD 4-1/2" tbg. RIH w/ bit & scraper to 2825'. Started out of hole. lO,250'TD POH w/ bit & scraper. ND BOPE & remove tbg spool. Tack weld 5,783'PBTD 9-5/8" slips to 9-5/8" csg. Pulled on 9-5/8" csg, could not remove si ips. MU Tri-State mech cutter & RIH to 53' & cut 9-5/8" csg. POH w/ cutter. RIH w/ spear. Engaged spear in cut-off 9-5/8" csg & attempted to pull s lips & 9-5/8" cut-off csg. Heated Bradenhead w/ steam. Still unable to remove slips. RU oil jars, HWDP, accel jars & spear. Engaged cut-off piece of 9-5/8" csg & jarred same out of hole. Rec slips & 9' cut-off jt of 9-5/8" csg. 10,250'TD Tstd BOPE. RU Tri-State spear & Dialog. RIH & ran FPI-- 5,783'PBTD 9-5/8" csg completely free ~ 1500', stuck ~ 1720'. POH & RD Dialog. RIH w/ Tri-State mech cutter & cut 9-5/8" csg ~ 1526'. Extent of blades of csg cutter is 9-7/8". POH. RIH w/ spear & engaged cut-off 9-5/8" csg. POH & rec 34 j ts & 2 pieces of 9-5/8" csg. RIH w/ 8-1/2" bit to csg stub ~ 1526'. Circ & clean dehydrated & contaminated mud from hole. MU spear, Sperry-Sun side entry sub, & RU Dialog. RIH & engaged fish. Ran FPI & worked pipe & free point to 1800'o Stuck @ 1850'. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 1790'. POH. lO,250'TD RIH & engaged spear in 9-5/8" csg @ 1526'. Jarred on fish, 5,783'PBTD then stripped out of fish. Could not re-engage spear. POH. Replaced pack-off rubber. RIH & engaged fish. Jarred 1/2 hr & pulled fish free. POH & LD 6 jts & 2 pieces of 9-5/8" csg. RIH to csg stub w/ 12-1/4" bit for CO. POH. RIH w/ FPI. Could not get inside 9-5/8" csg stub. RIH w/ 8-1/2" bit. Pushed rubber to 2800'. POH. RIH w/ spear & FPI. Worked free point to 1860'. POH. RIH w/ mech cutter & cut 9-5/8" csg & 1868'. POH. R IH w/ spear & jars. I0,250'TD Jarred on fish. String parted. POH. Had BO @ stop sub on 5,783'PBTD spear. RIH & screwed into stop sub. POH. RIH w/ spear. Engaged fish & jarred free. POH. Rec 1 jt + 2 pieces of 9-5/8" csg @ 1997'. POH. RIH w/ spear. Attempted to work to csg stub @ 1868'. POH. RIH w/ 12-1/4" bit & CO dehydrated & heavy mud to 1868'. POH. RIH w/ spear. Engaged fish @ 1868' Jarred fish loose. POH & rec 2 its + 2 pieces of 9-5/8" csg (131.25'). RIH w/ 12-1/4" bit. CO to 1997'. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2215'. POH. R IH w/ spear. Engaged fish & started jarring. Well History - TBU W~II D-5RD Page 2 ' 06-13 06-14 06-15 06-16 06-17 06-18 06-19 06-20 06-21 06-22 06-23 10,250'TD 5,783'PBTD 10,250'TD 5,783'PBTD 10,250'TD 5,783'PBTD 10,250'TD 2,581'TOF 10,250'TD 2,400'PBTD 10,250'TD 2,513'PBTD 2,832'TD 3,684'TD 4,664'TD 5,060'TD 5,501'TD Jarred on fish. Fish moved up hole 8' & stopped. Released spear & POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2028'. POH. RIH w/ spear. Engaged spear & POH. Rec 39.28' of 9-5/8" csg. RIH w/ spear. Engaged spear ~ TOF ~ 2028'. Jarred on fish. Could not move fish. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2120'. RIH w/ spear. Engaged spear & jarred fish loose. POH. Rec 93.31' of 9-5/8" csg. RIH w/ 12-1/4" bit. CO to 2120'. POH. RIH w/ 8-1/2" bit & CO to 2800'. POH. RIH w/ spear. Jarred fish loose & POH. Rec 88.32' of 9-5/8" csg. RIH w/ 8-1/2" bit, 1 std DP, & 12-1/4" reamer. CO 13-3/8" csg to 2215'. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2344'. POHo RIH w/ spear. Jarred fish loose & POH. Rec 124.49' of 9-5/8" csg. RIH w/ mech cutter & cut 9-5/8" csg ~ 2490'. POH. RIH w/ spear. Jarred fish loose & POH. Rec 147.95' of 9-5/8" csg. RIH w/ 12-1/4" bit & CO to stub. POH. RIH w/ 8-1/2" bit. Fin RIH w/ 8-1/2" bit to 2800'. Circ hole clean. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 26~0'. POH. RIH w/ spear. Engaged fish & jarred. Could not move fish. Released spear. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2592'. POH. RIH w/ spear. Jarred on fish & moved csg up hole 9'. Spear stripped out--could not re-engage. POH & redressed spear & RIH. Jarred on fish & pulled fish free. POH. Rec 101.51' of 9-5/8" csg. RIH w/ spear. Jarred on fish 30 min. Fish moved up hole 8'. Spear stripped out--POH. Redressed & repaired spear. RIH w/ spear & engaged fish. Jarred on fish ~?~5_8]].. Fish would not move. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2650'. POH. RIH w/ spear. Jarred on fish 2-hrs--no movement. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2611'. POH. RIH w/ spear. Jarred on fish. On 9th jar, appeared that fish pulled free. POH--no rec. Redressed spear & RIH. Jarred on fish 5 hrs--no movement. POH. LD Tri-State tools & DC's. RIH w/ 12-1/4" bit to 2581'. CBU & POH. RIH w/ 8-1/2" bit to 2830'. CBU & POH. RIH w/ OEDP. Halliburton set 175 sx CIG cmt plug (1% CFR-2 & 2% CaCI2) from 2676'-2400'. CIP ~ 2000 hrs, 06-16-80. LD DP from derrick. Tstd BOPE. Cut & slipped drlg line. Have open hole section from 2505'-2581' in which to KO wellbore. LD DP from derrick. Mixed mud & serviced rig. PU Monel DC's & HWDP. RIH. Tagged cmt ~2435'.~ Drld cmt to 2465'. Tstd 13-3/8" csg to 1000 psig--OK.- Drld cmt from 2465'-2513'. Tstd 13-3/8" shoe to 14.6 ppg MW equiv. POH to PU DD. ' Fin POH w/ 12-1/4" bit. RIH w/ DD to 2496'. RU Eastman gyro. Oriented tool face~~. RU Sperry-Sun steering tool DD ]2-1/4" hole fro_m~?5~f~)2749'. POH. RIH w/ 12-1/4" b~t~ '" Reamed from 2513'~. Drld to 2832'. Drld & surv 12-1/4" hole from 2832'-3267'. POH &N LD 23 jts DP. MU locked BHA assy &-RIH. Drld 3267'-3413'. Secured rig for 1 hr while prod crew extinguished fire behind CB #2 bldg. Resumed drlg & directional ly drld hole to 3684'. Drld 12-1/4" hole from 3684'-3908'. POH. RIH w/ bit ~4. Drld 12-1/4" hole from 3908'-4664'. POH. RIH w/ bit ~5. Drld 12-1/4" hole from 4664'-4922'. POH. RIH w/ bit #6. Reamed 4881'-4922'. Drld from 4922'-5060'. Drld 5060'-5114'. Repaired swivel. Drld 5114'-5501'. Well History - TBU Well D-5RD Page 3 06-24 06-25 06-26 06-27 06-28 06-29 06-30 07-01 07-02 07-03 07-04 07-05 07-06 07-07 07-08 07-09 07-10 07-11 07-12 07-13 07-14 07-15 07-16 07-17 5,831'TD Drld from 5501'-5515'. POH. RIH w/ bit ~7. Drld 5515'- 5831'. POH. PU DD & RIH to 13-3/8" csg shoe. RU Sperry- Sun steering tool. 6,072'TD Fin RIH to 5831'. RU Sperry-Sun steering tool. DD 5831'- 5906'. POH. Tstd BOPE. RIH w/ bit #9. Reamed 5831'-5906'. Drld 5906'-6072'. 6,471'TD Drld 6072'-6270'. POH. RIH w/ bit #10. Washed 30' to btm. Drld 6270'-6471'. 6,750'TD Surv ~ 6471'. POH. RIH w/ bit ~11. Drld 6471'-6750'. 7,021'TD Drld 6750'-6761'. POH. RIH w/ bit #12. Drld 6761'-7021'. POH. RIH w/ bit #13. 7,371'TD Drld 7021'-7371'. POH. RIH w/ bit #14. 7,585'TD Fin RIH w/ bit #14. Drld 7371'-7547'. POH. RIH w/ bit #15. Drld 7547'-7585'. 7,956'TD Drld 7585'-7838'. POH. RIH w/ bit #16. Drld 7838'-7956'. 8,181'TD Drld 7956'-8029'. POH. RIH w/ bit #17. Drld 8029'-8181'. 8,413'TD Drld 8181'-8291'. POH. Tstd BOPE--rams to 3000~, annlrs to 1500#. RIH w/ bit #18. Drld 8291'-8413'. 8,696'TD Drld 8413'-8621'. POH. PU locked BHA. RIH w/ bit #19. Drld 8621'-8696'. 8,884tTD Drld 8696'-8766'. POH. RIH w/ bit #20. Drld 8766'-8884'. 8,986'TD 'Drld 8884'-8896'. Tripped for bit. Drld 8896'-8969' w/ bit ~21. Tripped for bit. Drld 8969'-8986' w/ bit #22. 9,095'TD Drld 8986'-9087'. POH. RIH w/ bit #23. Drld 9087'-9095'. 9,262'TD Drld 9095'-9185'. POH. RIH w/ bit #24'. Drld to 9262'. Started POH for new bit. 9,391'TD POH. RIH w/ bit #25. DRId 9262'-9391'. 9,485'TD Drld 9391'-9393'. POH. RIH w/ bit #26. Drld to 9485'. POH. RIH w/ bit #27. 9,634 ' TD Drld 9485'-9618'. POH. Tstd BOPE. RIH w/ bit #28 & drld 9618 ' - 9634. 9,840'TD Drld from 9634'-9840'. 10,066'TD Drld from 9840'-10,066'. 10,215'TD Drld 10,066'-10,098'. POH. RIH w/ bit #29. Drld to 10,215'. 10,375'TD Drld from 10,215'-10,375'. 10,481'TD Drld 10,375'-10,481'. POH. RIH w/ bit ~30 to 13-3/8" shoe. Presently chg brake bands on drawworks. 10,620'TD Fin brake repairs. RIH w/ bit #30. Drld 10,481'-10,620'. C&C mud & hole. Made 14-std short trip. C&C mud & hole for logs. ! Well History - TBU Well D-5RD Page 4 07-18 07-19 07-20 07-21 07-22 07-23 07-24 07-25 07-26 07-27 07-28 07-29 10,620'TD C&C mud & hole for logs. POH. RU Schl. Ran DIL log. Ran long spaced Sonic w/ Caliper & GR. Sonic tool stuck w/ btm ~ 7703'. Worked WL in attempt to free tool. 10,620'TD Attempting to work stuck logging tool free. MU fishing tools to strip DFP over WL. RIH to 5351' & tools stopped. Attempted to work by bridge. POH. Added 8-1/2" straight stabilizer & pump out sub to fishing tools. RIH stripping over WL. 10,620'TD RIH stripping over WL. Worked thru bridge ~ 5252' to 5366'. Staged on into hole, C&C mud. Logging tools came free w/ guide on end of DP ~ 7550'. RIH to 7643'. Pul led fish into grapple. Press up on DP & checked WL wt. Had indications that fish was in grapple. Pulled WL out of rope socket w/ blocks. Pulled WL out of DP w/ Schl un it. Dropped bar & opened ¢irc sub. POH. Tight places in hole from 5395' to 5312' and ~ 2610'. Tstd BOPE. lO,660'TD Fin testing BOPE. RIH. Broke circ ~ 6750', 8700', 9900', 10,560'. Hole OK. Drld 10,620'-10,660'. C&C mud & hole for logs. POH. DP stopped moving w/ bit ~ 5676'. Worked bit to 5660'. Pipe free going dwn. 10,660'TD Worked thru tight hole ~ 5660'-5655'. RIH. Washed fill from 10,618'-10,660'. C&C mud. POH. Hole tight ~ 4350'. LD roller reamer, RWP stab, Monel DC's & Monel stabi- Ilzers. Cut & slipped drlg line. RIH w/ 12-1/4" bit, 3 stds, DC's, & 3 stabilizers. No tight spots going in hole. POH--no tight hole. RU to run 9-5/8" csg. lO,660'TD Fin RU to run csg. Ran 9-5/8" csg w/ shoe ~ 10,608', FC ~ 10,526', & DV stage clr @ 6548'. RU HOWCO & started cmtg 1st stage. 10,660'TD Fin cmtg 9-5/8" csg. 1st stage: 900 sx CIG w/ 1/2 gal/ sk Econolite, .3% HR-6L, 1/4 #/sk flocel (13.4 ppg) followed by 350 sx CIG w/ 1% CFR-2, .3% Halad 22-A, 3% KCI, 1/4 ~/sk flocel (15.8 ppg). Bumped plug w/ 1950 psi. CIP ~ 0745 hrs, 07-23-80. 2nd stage: Dropped DV bomb. Opened DV tool w/ 1300 psi. Circ out 50 bbls mud contaminated cmt. Cmtd w/ 685 sx CI G w/ 1/2 gal/sk Econolite, .3% HR-6L, I/4 #/sk flocel (13.4 ppg). Dropped DV closing plug. Closed DV tool w/ 2500 psl. Bled to 1000 psi & held 30 min. PU BOP stack & set slips. LD landing jt. ND BOPE. lnstld tbg spool & tstd same--OK. NU BOPE & tstd. WOC. 10,660'TD WOC. RIH w/ 8-1/2" bit. Tagged cmt ~ 6535'. Tstd csg above 10,526'PBTD DV clr to 2500 psi--OK. Drld cmt & DV clr from 6535'-6548'. Tstd csg & DV clr to 2500 psi--OK. RIH to 10,482' & tagged firm cmt. Drld cmt from 10,482' to FC ~ 10,526'. Circ hole. Displ mud in csg w/ FIW. POH. RU Schl. RIH w/ Density-CNL-NGT log. 10,660'TD Ran NGT-CNL. POH. RIH w/ TDT-K logging tools. Running 10,526'PBTD TDT-K. 10,660'TD Fin TDT-K & POH. RD Schl. RU DA & RIH & ran NLL. POH. RIH 10,526'PBTD w/ GND (Density). Tool failed. POH & repaired tools. 10,660'TD Ran GND log & Spectrolog. RIH w/ CBL logging tool. Tool 10,526'PBTD failed. POH. 10,660'TD DA ran CBL log & Sperry-Sun gyro. RD DA & Sperry-Sun. RIH w/ 10,526'PBTD bit & scraper to 10,526'. Circ & POH. RU DA. RIH w/ JB & GR. Well History - TBU Well D-5RD Page 5 07-30 07-31 08-01 08-02 08-03 08-04 08-05 08-06 08-07 O8-O8 10,660'TD RIH w/ JB & GR to 10,278'. POH w/ drag. Lost drag when tools lO,526'PBTD pulled into lubricator. RIH w/ JB & GR to 3400'. POH--no rec. RD DA. RIH w/ bit & scraper to 10,526'. Rev circ hole w/ FIW. No indication of rubber or junk. POH. RU DA. RIH w/ JB & GR to 10,350'. Did not tag any obstacle. No rec in JB. RIH w/ 4" csg jet & perf for isolation sqz in B4 of Hemlock ~ lO,229'-10,230'(DIL) w/ 4 HPF. POH. RIH w/ Halliburton EZSV cmt rtnr to 10,180'. PU to check clrs & cmt rtnr hung ~ 10,119'. Pulled out of rope socket. 10,660'TD POH w/ DA WL. RIH w/ OS on DP. Tagged rtnr setting tool ~ 10,526'PBTD 10,507'. Worked grapple over fish. Set wt on rtnr, PU & sheared setting slv w/ 30,000# pull. Left rtnr @ 10,522'. POH. Rec clr loc & setting tool. RU DA. RIH w/ JB & GR. Set dwn ~ 6531'. Spudded thru & RIH to btm. Had drag while POHo RD DA. RIH w/ OEDP. Circ & rev circ cmt flakes, rubber, & sd from hole. POH. lO,660'TD Fin POH w/ OEDP. RU DA. RIH w/ JB & GR 2 times. RIH w/ 10,526'PBTD Halliburton EZSV cmt rtnr on DA WL & set ~ 10,197'(DIL). POH. RIH w/ cmt rtnr stinger on DP. Tstd lines to 6000# & tstd 9-5/8" csg to 2500 psi. PI sqz perfs @ 10,229'-10,230 (DIL) ~ 1-1/4 BPM & 2-1/2 BPM ~ 3600 psi. Mixed & spotted 250 sx CIG cmt w/ 1% CFR-2 & 0.3% Halad-9. Sqzd 125 sx below rtnr to max & FP of 4900 psi. CIP ~ 0300 hrs, 08-01-80. Rev 125 s×. POH. 10,660'TD Fin POH w/ cmt rtnr stinger. Tstd BOPE. RU DA. RIH w/ GR & lO,526'PBTD JB to 9887'. Could not get below 9887'. JB stuck momentarily. POH & rec cmt in 'JB. RD DA. RIH w/ bit & scraper. Clrc clean FIW into hole. POH. RU DA. RIH w/ GR & JB to I0,185'. POH. 10,660'TD Fin POH w/ JB & GR. Rec small pieces of cmt. RIH w/ 4" csg lO,526'PBTD jet & perfd 10,178'-10,179'(DIL) w/ 4 HPF. POH. RIH w/ EZSV rtnr on DA WL & set ~ 10,130'(DIL). Unable to pull loose from rtnr. Pul led out of rope socket. POH. RIH w/ OS. Tagged fish @ 10,117'. Latched fish & pulled free. POH. Rec clr loc & setting tool. RIH w/ cmt rtnr stinger on DP. Stabbed into rtnr & tstd csg to 2000#--OK. Tstd Inr to 6000#. PI perfs ~ 1 BPM ~ 4100 psi & 1-1/2 BPM ~ 4600 psi. Mixed 150 sx CIG cmt w/ 1% CFR-2 & 0.3% Ha lad 22-A. Sqzd 39 sx below rtnr @ FP of 5100 psi. Rev 111 sx. CIP ~ 0630 hrs, 08-03-80. Circ to clean DP. 10,660'TD Circ to clean cmt from DP. POH. LD cmt rtnr stinger. 10,526'PBTD Performed rig maint while WOC. MU BHA & RIH. Drlg cmt rtnr ~ 10,130' ~ 0700 hrs. 10,660'TD Fin drlg cmt rtnr @ 10,130'. Drld hd cmt to 10,180'. Tstr csg 10,526'PBTD & sqz to 2000~--OK. Drld 2nd cmt rtnr ~ 10,197' & drld hd cmt to 10,230'. RIH & pushed junk to btm. Rev circ to clean hole. Tstd csg & sqz to 2000#--OK. POH. LD DC's & HWDP. RIH w/ bit & scraper. Circ & clean hole. POH. RU DA. RIH w/ GR & JB. 10,660'TD DA set Otis "WD" pkr ~ 9772'(DIL). RD DA. RIH w/ DP & POH LD 10,526'PBTD DP. RU to run tbg. RIH w/ prod tbg. 10,660'TD Fin running 4-1/2", 12.6#, SL tbg & landed same. ND BOP's. NU 10,526'PBTD Xmas tree & began connecting flow & gas lift lines. 10,660'TD Fin NU Xmas tree. RD & prep to move eqpmt to Rig 76. 10,526'PBTD Attempting to GL well. Well History - TBU Well D-5RD Page 6 08-09 08-10 08-11 08-1-2 10,660'1]] GL well for drawdown. Perfd Hemlock Bench 5 from 10,320' lO,526'PBTD to 10,370' (DIL) w/ 4 HPF. Two hr test: 744 BFPD ~ 65% cut. Choke barely open. TP 500 psig. 10,660'TD Flow testing D-5RD: 10,526tPBTD Time Flow Rate Cut TP Lift Gas 1300 1128 BFPD 3% 200# 2-1/2 MM 1900 984 BFPD 0.1% 200~ 2-1/2 IVlVl 0030 960 BFPD 0.1% 200# 2-1/4 MM 0600 1060 BFPD 0.1% 200# 2-1/4 MM 10,660'TD lO,526tPBTD Flow tstd D-5RD: Sep Lift Form F Iow Time TP CP Gas Gas Gas (BPD) Cut ,, 1400 160 1050 2200 M 2080 M 120 M 1097 O. 1% 2400 150 1060 2199 M 2068 M 131 M 1104 0.1% 10,660'TD Flow tstd well: 1152 BPD ~ 0.1% cut. TP 150#; CP 1050~; 10,526'PBTD Sep Gas 2409; Lift Gas 2213. Released rig to D-12RD ~ 0700 hrst 08-12-80. TUBI,IIG./C~AS i.N(} DETAIL WELL NO.: DATE: I tern Descr | >t | on Set · tl,. ~,,i, i i i v t,.. ,,1 ~,~ ! ii ir~ w,,. ! vi~1 )o :s Size Wt Thread Grade Range Condi tion Length From To , ,, , , ,, , , , , ,i ~ ,, , , , ~ , , , , i , . ., ,, ,, , ,, , , ,, , ,,, ,, , ,, ¢~" Ro~ ~ ~ C~a,/e~ ~ ~. /~ ~~. /oaox8. z ~ i -_marks: 77~ o? ~4.-- /ff,-~ooO ~ .~ TUB I,I,IG./C .AS.. I,N(}... D ET~K.I L. WELL NO.: Z:) --,~q" ,~'~ DATE: ~ ~ BY :__-~{'),kr,t~ ,,. Item Description ;' Set Jts Size Wt Thread .... Grade Range Condition Length From To . . .~ 4~" (Z.c ~s~... ~o ~ ~ ~36...../f .~,~ ~, ~ ~:, , , ~ ,, ., , ,. . . ,,,, , ,, .. .... ., , , ,,,, .... ~ ...... /a F %" IZ. ~ A~ d-Bo ~ ~ ~oe. ~ 7~9~. ~1 7 Yc Remarks: ( TUBI,liG./C.AS.. tNC~ DETAIL , ~ WELL NO.: DATE: ~-~,- Item Descri)tion Set ~f~/'~ - ts Si ze Wt Thread Grade Range Condition L.ength From To ~ +/~" /2. c R~c ~-e~ z ~ , ~. ~c 7~I~ Ca ~. ~4 , .,,, , , , emarks: TUB I,NG./CAS I, NG DETAIL WELL NO. DATE: ~l-d- 80 Item Description Set !:s Size Wt Thread Grade Range Condition Length From To _ ~ ~' ~sz. x Z~ C~s~ o~' .~ ~o~ f7~, 7¢ 7727. ~z / ............ ,,, . , . , , --, , ,, ,, , ,,r, 3,.,_e_,.~cs. b, Eu£ p I I I i I ! ~'.o~o I i I WELL NO.: , DATE: -7//..~ ' ~ BY :./9 ~-/t'-/,.~ ,.-~,~ · Item Description Set ts Si ze Wt Thread Grade Range Condition Length From To ~ ¢¢/~'' ¢...¢..~ ¢¢,,H ,,¢-£c~ .z / ~, [z 4~. ~8 ~.~ i ~o~ ¢~ o ..~o/ P-//o ~ / .... ~ 87, o ~ ~,/?~. ¢~ /~, ~~. ?~ , .... + ~+ "~ "F/~ =/~ c/..¢' ¢~' ~,brd~ A~/Ic~~ ~ ~ ~. cJ¢~ ~, ¢//~ cr~-zz +~2 ~/~ /~o~/ ~ ~o ~.~ ~/~ ~ //~~. ~/~-~o enarks: C?_..~ ,~¢)..~,,~ OJ//--- 270, 000 " · o -: . . · .;- . .., ,t'":',~ .... ', ...... , .... '. ' -'o"- ': ' .: . :'-' >; -',' "' -' - %" ' . ° ~ -'.' · · ~- '.- -' ', ° ".. 'o, ]['-- *. ~, ,~.' a .' " -~ .... . ..- -. .... ; .~- . , .'.: · : . ,. . ..,~ :-.,_ -. : . .- : '...,.; ~o., :_, ! 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'-"-"- 'Re: Our Boss Ghrro. scop~c Survey ?-~_ -. · ~:, ' ': '"' ' ~-' ': :~-'?"-',~":'-:.,.:-<:ob No. ~osS-Z6633 .'-:, ::.'- "::'-. > :'.~:'-..::- '/' -' · . · ' .... - . . :. o · . · . -_ ;. _ o.' :' .. ...'. ~ ~ . , ·-, ' : ."~ ', .~WellD-SRD .- . .... . .... .,- ..... .. - _ , . , ..-. , - - . , '::.; .... . .Trading BayUni~Fxeld. ' .- '.'. -' :' - ::.- "::'- < Cook Inlet,' A!.aska ' ' :' :' '' ' --.' .' :' . '. *.Date of Survey: July 29, 1980 : ;: ;;. .' . . '* '. ' ' '- "-. · Operator= Ki~k Affle~ach . . -.::.: Please fi~_enclosed the ',Orginal" ~nd twenty _three (23) copies :. of our B~ss Gyroscopic Multishot D'.~rectional .S..u~ve~ on the above well ' "' ' ' ' *' ' ~ '- - " '' Thank you for ~ivi~ us this opportunity %o be of service. : ... · . / , . ' ' . : ,.-. , Yours very truly, -. ' . ' ':' SPERRY-SUN, INC. . : . . Ken Broussard District Manager KB/kc Enclosures cc: Mr. Fudge · .. (11 copies) o · JUL ~ 91~82 . ~,nc~)orago · . CONF.}DEN'rlAL MARA~N OIL COMPANY D-SRD TRADING BAY UNIT ,~-'l ,. PAGE 1 DATE OF SURVEY ,JULY 29, 1980 VERTICAL SECTION DIRECTION N-61-48-00-[ COOK INLET BOSS SURWEL TRUE SUB MEASURED VERTICAL SEA DEPTH DEPTH TVD SPERRY-SUN, INC RECORD OF SURVEY COURSE COURSE DOG-LEG INCLINATION DIRECTION SEV DEG MIN DEG"'MIN'' DEG/IO0' BOSS-16633 TOTAL RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EASIy/~EIS T SECTION 0.00 O.OO -106.20 100.00 100.00 -6.20 200.00 200.00 93.80 300.00 299.98 193.78 400,00 399;195 293.75 KELLY BUSHING 0 3 N 76 17 W .05 0 3 S 30 48 E .09 1 27 S 23 11 W 1.42 1 40 S"1'9'47 W 0.00 N 0.00 E 0.0~ .01 N .04 W -.0~ · 06 S .00 E -.03 1,27 S .51 W ,,.,'~,~05 500.00 499.92 393.72 600.00 599.91 493.71 700.00 699.90 593.70 800.00 799.87 693.67 0 53 S 22 36 W .79 0 43 S 28 23 W .19 0 48 S 79 0 63 .65 1 51 S 77 30 W 1.05 5,88 S 2.29 W -4.80 7.14 S 2,89 W -5.92 7.82 S 3.87 W -7.11 8.31 S 6.13 W -9.33 900.00 899.81 793.61 2 3 S 74 23 W .23 9.14 S 9.43 W -12.63 1000.00 999.75 893.55 1100.00 1099.71 993.51 1200.00 1199.69 1093,49 1300,00 1299.68 1193.~8 1400.00 1399.68 1293.48 I 51 S 83 12 W .36 I 25 S 55 53 W 0 54 S 48 47 W O 36 S 56 30 W .32 0 40 S 18 47 W .'4'1 9.81 S 12.75 63 -15.88 10.69 S 15.38 W -18.61 11.90 S 16.99 W -20.60 12.71 S 18.02 W -21.89 13';55 S 18;65 W -22.84 1500,00 1499,67 1393,47 1600,00 1599.66 lq93.46 17DO.D0 1699.66 1593.46 1800.00 1799.66 1693.46 19010.00 lSZ39.65 .... 179'3~145 0 51 S 15 0 E 0 33 'S 16 0 W 0 13 S 25 30 E 0 20 S 20 41 E .12 0"16 S 85 '6'W .48 14.82 S 18.64 W -23.43 16.00 S 18.58 63 -2~93 16.63 S 18.63 W -k .2R 17.07 S 18.45 W -24.33 17'.36 'S 1'8,58 'W -24,58 2000.00 1999.65 1893.45 0 3 21100.00 2099.65 ' 1993;45 0 1I 2200.00 2199.65 2093.45 0 3 2300.00 2299.65 2193.45 0 28 2~00.00 2399.65 2293.45 0 45 2500.00 2499.61 2393.41 2 0 2600.'00 ...... 259'9.30 2493.10 6 7 2700.00 2698.27 2592,07 9 51 2800.00 2796,46 2690.26 11 56 2900';'010 ' ' 2'893,76 2787;56 1~ 37 N 88 47 ~ .22 N 78 47 .i5 N 21 23 E ,2O N 41 12 E ,42 N"53 0 E .3'1 N 25 12 E 1.$8 N 25 42 E , 4.12 N 37 0 E 4.03 N 45 54 E 2,67 N 48-24' E"' 2;74 17.39 S 18.85 W -24.83 17,35 S 19.05,W -24.99 17.31 S , 19.25 W -25.15 16.97 S 18.95 W -24.72 16,27 S 18.1'6 W -23270 14.29 S 16.90 W -21.65 7.92 S 13.85 W -15.94 3.72 N 6.39 W -3,87 17.74 N 6.19 E 13.84 · 5~.~1 N 2~.04 .... E J6.05 MARA3~N OIL COMPANY D-SRD TRADING BAY UNIT . -, PAGE 2 DATE OF SURVEY dULY 29,~ 1980 VERTICAL SECTION DIRECTION N-61-48-OO-E COOK INLET BOSS SURWEL SPERRY-SUN~ INC BOSS-16633 ~ TRUE SUB MEASURED VERTICAL SEA i. DEPTH DEPTH TVO 3000,00 2989,86 2883.66 RECORD OF SURVEY COURSE COURSE DOG-LEG INCLINATION DIRECTION SEV DEG MIN DEG MIN DEG/ioo TOTAL RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST "'SECTION 17 22 N 50 /47 E 2.83 51.13 N 44.04 E 62.9R 3100,00 3084.74 2978.54 3200.00 3178.57'" 3072.37 3300.00 3271.50 3165.30 19 2~ N 50 5 E 2.05 21 3 N 50 17 E 1.65 22 17 N 50 0 E 1.24 71.22 N 68,35 E 93,89 93.35 N 94.90 E 127.75 117.01 N 123,24 E 1('~90 3257.89 3500.00 3456,71 3350.51 22 6 N 5O 35 E .29 22 12 N 50 17 E .15 141,14 N 152.30 E 20U.92 165.15 N 181.37 E 237.88 3600.00 3549.38 3443.18 3700.00 3642.19 3535.99 3800.00 3735.16 3628,96 21 56 N 5O 5 E .28 21 /47 N 50 17 E .17 21 27 N 51, 17 E ' .50 189.20 N 210.23 E 274.6R 213.04 N 238.83 E 311.15 236.33 N 267.37 E 347.31 3900.00 3828.21 3722.0 I ~000.00 3921.36 3815,16 21 32 N 51 12 E .09 4100,00 4014.68 3908,48 /4200.00 4108.23 A002.03 4300.00 /4201.94 /4095.74 21 7 N 51 30 E 21 0 N 51 0 E .21 20 23 N 52 17 E .77 20 29 N 51 0 E .46 20 0 N'"5i 12 'E .49 4400.00 4295.76 4189.56 4500.00 4389,86 4283.66 19 33 N 51 54 E .51 259.26 N 295.94 E 383,33 281,98 N 324,34 E 419,09 304,47 N 352.56 E 454.,41 326.39 N 380.06 E 489.19 348.06 N 407.4z~ E 523.55 3'E~'9", 78 "N 434'.36'"E ...... 557.55 ~90.82 N 460,86 E 590,84 4600.00 4484.11 4377.91 4700.00 q578.22 /4472.02 4800,00 4671,61 4565.41 4900.00 4764.13 4657.93 ' f 5000.00 4856.55 q750.35 5100.00 49~9.09 4842,89 5200,00 5041,66 ~935.46 5300.00' 5134.50 5028.30 5400.00 5227.79 5121.59 19 31 N 51 17 E .21 20 0 N 51 54 E .53 21 52 N 51 42 E 1.87 22 45 N" 51 .... O"E .89 22 11 N 52 5 E .68 22121 N 51 42 E · 22 22 7 N 51 17 E ,28 21 30 N 52 24 E .7/4 20 43 N 52 24"E .78 5500,00 5321,32 5215.12 5600.00 5~t~52'1o 5308,90 5700,00 ' 5509.18 5402.98 5800.00 5603.40 5497.20 5gOd"".'O0 ..... 56g?.,~'7 "5591'.6'7"' 20 43 N 52 54 E 19 55 N 54 42 E 1,02 19 43 N 53 12 E .55 19 25 N 53 5/4 E .38 18 52 ......... N 6'5'' 5"E 411.59 N ~87.06 E 62'"~7~ 432.59 N 513,55 E 65~.01 45~,69 N 541.62 E 692.19 478238'"N 5'712'24"E ....... 729250 ? 302,13 N 601.1/4 E 767.07 525.51"N 630.96 '5 804.40- 5~9.07 N 660,57 E 841,62 572.02 N " 689,78 E 878,21 ~94'200 'N 71'8251 .... E "913.7~ 615,~6 N 7~6,~3 [ 948,67 635,97 N 77~,4~ E 983,0~ 655.92 N ,801.85 E 1016,62 675.81 N - ' 828.78 E 1049,77 .......... 8D6.SU 5 ..... 1'082.~7 .... 692'2'42'"'N DMARA~N-sR OIL COMPANY TRADING BAY UNIT ,,, PAGE 3 'DATE OF SURVEY '~ULY 29, 1980 VERTICAL SECTION DIRECTION N-61-48-O-O-F COOK INLET BOSS SURWEL SPERRY-SUN9 INC BOSS-16633 TRUE MEASURED VERTICAL RECORD OF S SUB COURSE COURSE SEA INCLINATION DIRECTI URVEY DOG-LEG ON SEV TOTAL RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH 6000.00 5792.12 TVD DEG MIN DEG MI 5685.92 20 10 N 68 30 N DEG/iO0 E 1.73 NORTH/SOUTH EAST/WEST SECTION 705.54 N 887.58 E 1115.63 6100.00 5885 6200.00 5978 6300.00 6069 6400,00 6160 · 55 5779.35 21 35 N 69 48 E 1.49 71'8.21 N · 10 5871.90 22 54 N 68 0 E 1.48 731.85 N · 68 5963.48 24 27 N 66 18 E 1.69 747.46 N · 12 6053.92 26 2 N 64 30 E 1,76 765,22 N 920.88 E 1150.97 956.18 E 1188.52 6500.00 6249 · 70 6143.50 26 44 h 63 47 E .77 784.61 N 1071.91 E 1315.47 6600.00 6339.10 6700.00 6428.69 6800;00 6518.56 6252,90 26 31 N 64 5 E ,25 804,29 N 6322,49 26 14 N 63 54 E ,30 823,77 N 6412.36 25 47 N 64 ll E .47 , 842.96 N 1112,17 E 1360.23 1152.10 E 1404.62 1191.52 E 1448.44 6900.00 6608.69 6502.49 25 33 N 64 5 E .24 861.86 N 1230,50 E 1491.71 7000,00 6699,19 6592.99 24 49 N 65 50 E ,95 879,98 N 1268.99 E 1534.20 7100.00 6789,95 6685,75 7200,00 6880.76 6774.56 7300.00 6971.76 6865,56 24 49 N 65 5 E ,17 897,52 N 26 42 N 66 30 E .60 914.69 N 24 17 N 66 35 E ,q2 931,19 N 1307.12 E 1576.10 1345.32 E 1617.87 1383.35 E 1659.15 7400,00 7063.06 6956.86 , 7500,00 7154.77 7048~57 25 53 N 65 18 E .66 947.82 N 23 6 N 66 2q E .90 964.14 N lq20.61 E 1699.88 1456.98 E 1739.64 7600,00 7246,90 7140.70 7700.00 7339.36 7235,16 7800.00 7432.19 7325.99 22 40 N 66 41 E .45 979.61 N 22 6 N 68 18 E .83 994,19 N 21 33 N 68 11 E .55 1007.97 N 1492.65 E 1778,39 1527.82 E 181'~"2~ 1562,35 E 1853,22 7900.00 7525.27 7419.07 21 20 N 67 30 E .33 1021.76 N 1596.21 E 1889.58 8000,00 7618.48 7512.28 8100.00 7711,47 7605.27 8200.00 7803,88 7697,68 8300,00 7895.59 7789,39 21 9 N 6~ 24 E .37 1035.36 N 22 0 N 68 5 E .86 1048.99 N 22 55 N 68 41 E ,94 1063.05 N 24 3 N 68 54 E 1.14 1077.47 N 1629.79 E 1925.60 1665.94'.E 1962.13 1699.45 E 2000.08 1736,60 E 2039,65 84.00,00 7986.47 7880.27 8500.00 8076. Z+5 7970;25 8600,00 8165,52 8059.32 8700,00. 8255,98 8147.78 8800.00, 8342,53 8256.35 8900.00 8431.57 832..5'.37 25 16 N 68 35 E 1.22 1092,59 N 1775.48 E 2081.0~ 26 27 N 69 11 E 1.~1 1108.29 N 1816.17 E 2124.32 27 58 N 68 55 E, 1,21 112~.67 N 1858,58'E 2169.43 27 57 N 68 24 E ,33 1141,76 N 1901,96 E 2215,74 27 25 N 68 ll E ,5A 1158.95 N 1945.12 E 2261,90 26 45 N 68"~'~"E .6'7 1'175,'86 N ~987;'3'9"E' ' '2307.15 ,,>:,ON OIL COMPANY D- 5 R ~i~-' TRADING BAY UNIT PAGE 'DATE OF SURVEY '~'ULY 29, 1980 VERTICAL SECTION DIRECTION COOK INLET BOSS SURWEL TRUE SUB MEASURED VERTICAL SEA DEPTH DEPTH TVD SPERRY-SUN, INC RECORD OF SURVEY COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEV RECTANGULAR COORDINATES DE'G MIN DEG'"M'I'N ...... D'EGZ'I"O0 ..... N'ORTH/SOUTH ...... E'AS"T/W'E'ST BOSS-16653 VERTICAL SE C'i r6,~ 9000,00 8521,27 8415.07 25 42 9100,00 8611.2~ 8505,04 26 q 9200,00 8701,36 8595,16 25 17 9300,00 8791,78 . 8685,58 25 18 9~00,00 8882,10 8775,90 25 31 · 9500.00 8972.38 8866.18 25 26 N 69 48 E 1,27 1191.71 N 2028.63 E N 68 24 E ,71. 1207,28 N 2069,41 E N 69 24 E .90 1222.89 N 2109,83 E N 69 5 E .13. 1238.02 N 2149.78 E N 70 -"0' E ...... .45 1253,02 N 2189.98 E 2350,9g 2437.27 24"~6,~ 25,.. N 69 30 E ,23 1267,90 N 2230.33 E 256~.75 9600.00 9062.58 8956.38 25 4~ 9700,00 9152,93 9046.75 25 0 9800.00 9243.78 9137,58 24 25 N 69 30 E .30 1283.03 N N 69 35 E .73 1298.00 N N 70 41,E .74 " 1312,20 N 2270.78 E 2607,5~ 2310,92 E 2649.99 2350.23 E 2691.35 9900.00 9355,00 9228,80 23 56 , 0000,00 94~6,53 9320.33 23 35 10100.00 9518.16~ 9~11.96 23 38 10200,00 9609.86 ~ 9503.66 23 23 10300,00 9701.77 9595.57 23 10400.00 9794.04 9687.8~ 22 21 N 69 35 E .66 1326.11 N N 70 18 E .~5 N 69 4'8 E ,21 N 6~ 11 E N 69 11 E ,37 N 69 5 E .67 2388.74 E 2731.86 1339,93 N 2426,59 E 2771.74 1353.59 N 2~64,'23 E ' 2811.36 1367.56 N 2501,59 E 2850.90 1381,.56....N ........ 2538.42 E 2889,97 13'9'5,29 N 25'74,'45 E ........ 2928.22 10500.00 9886.68 9780.48 21 5~ 10600,00 9979.~9 9873.29 21 52 10650,00 10025,89 9919,69 21 52 N 68 ~8 E .50 1~08,81 N N 68 48 E 0,00 1422,28 N N 68 48 E 0,00 1429.01 N 2609,57 E 2965,56 2644,30 E 2661.66 E 302 .01 ** THE'CALCULATIONS ARE BASED ON THE TRAPEZO !DAL 'OR AVG.' I~'ONCT'I"ON i~'~""/i,"N'GLES 'METHOD HORIZONTAL DISPLACEMENT : 3021.01 FEET AT NORTH 61 DEG, 46 MIN, EAST (TRUE) SfART OF SURVEY WAS 106,20 FEET ABOVE SEA LEVEL MARA.,~'L.JN OIL COMPANY D-SRD TRADI'NG BAY UNIT DATE OF PAGE 5 SURVEY dULY 29, 1980 CO,OK I NLE T BOSS SURWEL BOSS-16633 TRUE SPERRY-SUN9 INC INTERPOLATED RECORD OF SURVEY MEASURED VERTICAL SUB SEA TRUE TOTAL RECTANGULAR CO'O~DINATES DEP TH DEPTH TVD ELEVA T I ON NORTH/SOUTH EAST/WEST O. O. -106. 106. 1000. 1000. 894, -894. 2000. 2000. 1893. -1893. O. N O. [ lO. s 17, S , ~, 3000. 2990. 2884. -2884. 4000. 3921. 3815, -3815. , 51. N ~4. 282, N 324. 5000, 4857. 4750, -4750. 6000, 5792, 5686. -5686~ 7000. 6699. 6593, -6593. 502. N 601, E 706. N 888. E 880. N 1269. E 8000. 7618. 7512, -7512. 9000. 8521, 8415. -8415, 10000. 9427. 9320. , :'9320. 10650. 10026, 9920. -9920, INTERPOLAT~'D'"C'ooR'[~'I'NXYES "FOR I'E'V'E"R¥" ].'0'0o.00 'FEET-OF MEASUR'ED'-'DEP'TH FROM 0,00 FEET TO 10650.00 FEET 1035. N 1630- 1192. N 2029. 1340. N 2427. E 1429, N 2662, E MARAI"'.,N OIL COMPANY D-SRD' TRADING BAY UNIT COOK INLET "~, . ~ ',~,- PAGE 1 DATE OF SURVEY JULY 29, 1980 · VERTICAL SECTION DIRECTION N-61-q~I-OO-E BOSS SURUEL TRUE SUB MEASURED VERTICAL SEA O"EtSYH DEPTH TVD BOSS-16635 SPERRY-SUN, INC RECORD OF SURVEY COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEV RECTANGULAR COORDINATES VERTICAL D'EG"M'iN DEGI MilN .......DE'G/1D'O .... NORTH/SOUTH ....... EAST'Y~'EST ..... SECTIOG 0.00 0.00 -106.20 100,00 100.00 -6.20 200,00 200.00 93.80 300. O0 299.97 193,77 Ao0,O'o 39'9.93 2'9'$.75 KELLY BUSHING 0.00 N 0.00 E 0.00 0 3 N 76 17 W .05 .02 N .08 W -.06 0 3 S 30 48 E .09 .05 S .0~+ W -.06 1 27 S 23 11 W 1.q2 2.38 S 1.Oq 1 q'O S 1'9"4'7"W .24 5;I12"IS 2'02 W 500.00 499.91 593,71 600,00 599.91 A95.71 700.00 699.90 593.70 800.00 799.84 695.6/+ 900.00 899,78 795.58 1000,00 999,75 893,55 1100.00 1099,70 993.50 0 53 S 22 36 W .79 6.5/+ S 2.61 W -5.39 0 43 s 28 23 u .19 7.64 s 3.21 0 /+8 s 79 0 w , .65 7.91 s 4.58 w -7.77 1 51 S 77 .tO t4 1,05 8,61 S 7,73 W -10,8~ 2 mm3m S 7q .... 23'w .25' 9.57 's ll"lS-w -14.3'7 1 51 S 83 1'2 W .56 9.95 S 14.38 W -17.3F. 1 25 S '55 53 W .88 11.34 S 16.45 W -19.8~. 1200.00 1199.68 ,, 1093.48 1300.00 1299.68 1193,48 1/+O'O'.OO ..... 139'9;67 ....... 129'3.~7 1500.00 1A9~.66 1393.46 1600,00 1599.66 1493.46 1700,00 1699,66 1595.~+6 1800,00 1799,65 1693.45 1900,00 1899'1.1~15 ......1'793'45 0 54 S 48 87 W .54 1~,37 S 17.61 W -21.37 0 56 S 56 30 W .32 12.95 S 18,/+8 W -22.41 0'40 S 18"'87"W ,4'1' 14'-~'05 S 18.86 W' -23.2'6 0 51 ~ 15 0 E .~7 15.48 S 18./+7 W -23.60 0 33 S 16 0 W .47 16.41 S 1B.74 W -~2'7 0 15 S 25 30 E .41 16.75 S 18.58 W -2~.27 0 20 S 20 /+1E .12 17.29 S 18.37 U -24.56 O' I6 S'85' 6"W ,~"8 17;55"S 18,8'3' w -24.7c 2000.00 1999,65 1895.45 .PlO0.O0 2099.65 . 1993,45 2200.00 2199.65 2093.~5 2300.00 2299.65 2193.45 2400.00 2399.64 2295.44 0 3 N 88 47 W .22 17.53 S 18.92 W -24.87 0'11 N 78 47 W .15 17.27 S 19.24 W -25.11 0 5 N 21 23 E .20 17,19 S 19.20 ~t -25.05 0 28 N ~1 12 E .~2. 16.57 S 18.67 W -24.28 '0'45 N '~'5 ' O"E .31 15,79"S 17.62' W -22.99 , 2500.00 2/+99.58 2395,58 2 0 2600.00 2599,0'1 ..... 2492.81 6 7 2700.00 269'(..54 2591.3~ 9 51 2800.00 279~.38 2689.1({ 11 56 "290'0.00 ....... 2'892'1/+ .... 2'/85,94 ............ 14'37 ........ N 25 12 E 1,~8 12.63 S 16,14 N 25 /+2 E 4.12 5.05'"S 11,51 W -11.58 N 37 0 E /+,03 10,65 N " 1.22 W 3.95 N ~5 54 E 2.67 25,02 N 15.6,3 E 23.R4 N'"~'8 .... 2'4"'E ' 2'74 ....... ~1,'78"N ............. ;,-52-;'50' E ' - q'8.5P MARAt,,, N OIL COMP/~NY D-5RD TRADING BAY UNIT PAGE 'DATE OF SURVEY dULY 29, 3.980 VERTICAL SECTION DIRECTION COOK INLET BOSS SURWEL SPERRY-SUN, INC BOSS-16633 TRUE SUB MEASURED VERTICAL SEA RECORD OF SURVEY COURSE COURSE DOG-LEG INCLINATION DIRECTION SEV TOTAL RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 3000.00 2987.58 2881.38 $100.00 3081.90 2975.70 3200.00 3175.23 3069.03 3300.00 3267.76 3161,56 3400,00 3360.41 3254.21 17 22 N 50 47 E 2.83 19 24 N 50 5 E" 2.05 21 3 N 50 17 E 1.65 22 17 N 50 0 E 1.24 22 6 N 5 0 35 E .29 60.65 N 55.63 E 77.68 81.96 N 81.11 E 110.21 104.91 N 108.74 E 145.40 129.28 N 137.79 E 1,'"'~,52 153.i7 N 166.85 E 21~.43 3500.00 3453.00 3346.80 22 12 N 50 17 E .15 177.31 N 195.92 E 256.45 3600.00 3545.76 3439.56 3700.00 3638.62 3532.42 5800.00 3731.70 3625.50 21 56 N 50 5 E .28 21 47 N 50 17 E .17 21 27 N 51 17 E .50 201.27 N 224.57 E 224.98 N 255.12 E 247,85 N 281,66 E 293.03 329.39 365-35 3900.00 3824.72 3718.52 21 32 N 51 12 E .09 4000.00 3918.00 3811.80 21 7 N 51 30 E .43 21 0 N 51 O'E .21 20 23 N 52 17 E .77 20 29 N 51 0 E .46 :~0 0 N'51 ..... i~'2E .49 4100.00 4011.36 3905.16 4200.00 4105.10 3998.90 4300.00 4198.78 4092.58 4400.00 4292.74 4186.54 270.85 N 293.28 N 315.83 337.13 359.16 380;59' 310.26 E 401.42 339.45 E 436.87 N 366.31 E 472.07 N 393.86 E 506.42 N 421.05 E 540.80 N ........ 447'71"'E ......... 574'.41' 4500.00 4386.98 4280.78 4600.00 4481.23 4375,03 19 33 N 51 5~ E · 51 401.23 N · 21 422.13 N 19 31 N 51 17 E 474.04 E 607.38 500.11 E 4700.00 4575.20 4q69.00 4800.00 4668.01 4561.81 4900.00 5000,0O 4760.25 4654.05 4852.85 4746.65 5100.00 4945.34 4839.14 5200.00 5037.98 4931.78 5300.00 5131.02 5024.82 5400.00 5224.56 5118.36 20 0 N 51 54 E 21 52 N 51 42 E 22 43 N 51 0 E 22 11 N 52 5 22 21 N 51 42 22 7 N 51 17 21 30 N 52 24 · 53 4Q3.23 N 1.87 ~ ~66.31 N .89 ~90.62 N 527,03 E 67~.92 556.26 E 710.59 586.27"E 7~8.52 E .68 513.82 N E .22 537;38 N E .28 560.93 N E .74 583.29 N .78 604.87 N 20 43 N 52 2'~ E 616.06 E 785.74 645,90'E 823.17 675.28 E 860.19 704.31 E 896.35 732.34 E 931.25 5500.00 5318,09 5211,89 5600.00 5412.11 5305.9'1 5700,00 5506.25 5400.05 5800.00 5600.56 5~94.36 5'900.00 5'~-9'~'.-1~ ...... 5588'99 19 55 19 43 19 25 1'8152 N 52 5/-t E ,1'8 N 54 42'E 1;02 N 53 12 E ,55 N 53 54 E N ..... i~'5'" 5 E ..... ~'.70 626,21 N 645.90 N 666.11N '685,69 N 69~.'51''N 760,56 E 966,20 788.36 E lb00;00- 815.37 E. 1033.36 842.23 E 1066.29 8?l',b$"E" MARATHON OIL COMPANY O-5RD TRADING B~Y UNIT COOK INLET BOSS SURWEL SPERRY-SUN9 INC . ' PAGE 3 DATE OF SURVEY dULY 29, 1980 VERTICAL SECTION DIRECTION N-61-48-OO-E B0SS-16633 TRUE SUB MEASUREO, VERTICAL SEA RECORD OF SURVEY COURSE COURSE DOG-LEG INCLINATION DIRECTION 'SEV TOTAL RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST SECTIODJ 6000.00 5789.05 5682.85 20 10 N 68 30 E 1.73 711.95 N 905,64 E 1132.P1 6100.00 5882.04 5775.84 6200.00 5974.16 5867.96 6300.00 6065,19 5958,99 21 35 N 69 48 E 1.49 724.65 N 22 54 N 68 0 E 1.48 739.23 N 24 27 N 66 18 E 1,69 755.86 N 938.16 E 1169.24 974,24 E 12~.7~,92 1012,14 E 12 6400.00 6155.05 6048.85 26 2 N 64 30 E 1.76 774.76 N 1051.75 6500,00 6244.36 6138,16 26 44 N 63 47 E .77 794.63 N 1092.11 E 1337.98 6600.00 6333.84 6227.64 6700.00 6423.54 6317.34 6800,00 6515.58 6407.58 26 31 N 64 5 E .25 814.14 N 26 14 N 63 54 E .30 833.58 N 25 47 N 64 11 E .47 852.52 N 1132.27 E 1382.59 1171.96 E 1426.77 1211.12 E 1470.23 6900.00 6605.80 6497.60 25 33 N 64 5 E .24 871.37 N 1249.92 E 1513.32 7000.00 6694.57 6588.57 24 49 N 65 30 E .95 888.77 N 1288.11 E 1555.20 7100.00 6785.$4 6679.14 7200.00 6876.19 6769.99 7300.00 6967.54 6861.14 24 49 N 65 5 E .17 906.45 N 24 42 N 66 30 E .60 923.11 N 24 17 N 66 35 E .42 939.45,N 1326.18 E 1597.11 1364.50 E 1638.75 1402.24 E 1679.73 7400.00 7058.78 6952,58 23 53 N 65 18 E .66 956.37 N 1439.02 E 1720.15 7500.00 7150.76 7044.56 7600.00 7243.03 7136.83 7700.00 7335.69 7229.49 7800.00 7428.70 7322.50 7900.00 7521.85 7415.65 8000.00 7615.11 7508.91 8100.00 , 7707.83 7601.65 8200.00 7799.93 7695.73 8300.00 7891.25 7785.05 23 6 N 66 24 E .90 972.08 N 1474.97 E 22 40 N 66 41 E .45 987.33 N 1510.36 E 22 6 N 68 18 E .83 1001.24 N 21 33 N 68 ll E .55 1014,88 N 21 20 N 67 30 E .33 1028.81 N 17' '65 1545.32 E 1835.03 1579.42 E 1871.5Z 1613.03 E 1907.73 21 9 N 68 24 E .37 1042.09 N 1646.58 22 0 N 68 5 E .86 1056.07 N 1681,33 22 55 N 68 41 E ,gq 1070,22 N 1717,61 24 3 N 68'5~ E 1,14 1084,89 N 1755.63 E 1943.58 E 1980.81 E 2019.47 E 2059.91 8flO0.O0 7981.69 7875.~9 8500.00 807j.22 7965.02 25 16 N 68 35 E 1.22 llO0.qT N 1795.37 26 27 N 69 11 E 1.21 1116.29 N 1837.01 2102.29 2146,47 8600.00 8159.81 8053.61 8700.00 8248.15 8141.95 8800.00 8336.92 8230.72 8900,00 8426.21 8320,01 27 38 N 68 35 E 1.21 1133.22 N 1880.19 27 57 N 68 24 E .33 1150.fl8 N 1923.77 27 25 N 68 11 E .54 1167.59 N 1966,52 26 45 N 68 lll"E .67 1184'.31 N E 2192.52 E 2239.08 E 2284.84 E 2329.57 ~/~ ~-~-<"-~/--~- I L COMPANY D-ERD TRADING BAY UNIT PAGE a 'DATE OF SURVEY OULY 29, 1980 VERTICAL SECTION DIRECTION N-61-qS-dO-E COOK INLET BOSS SURWEL TRUE SUB MEASURED VERTICAL SEA DEPTH DEPTH TVD SPERRY-SUN~ INC RECORD OF SORVEY COURSE COURSE DOG-LEG INCLINATION DIRECTION S[V RE ...... DEG/IO0' "NO BOSS-16633 DE'G MIN DE'G 'MI'N TOTAL CTANGULAR COORDINATES VERTICAL RTH/SOUTH EAST/WEST' SECTION 9000.00 8516.32 8q10.12 25 42 9100.00 8606-15 8499.95 26 4 9200,0Q 8696,57 8590,37 25 17 9300.00 8786.98 8680.78 25 18 9~00,00 8877.23 8771'~03 25'5'1 N 69 4R E 1 · 27 N 68 24 E .71 N 69 24 E .90 N 69 5 E · 13 N'"7'O ........ O' E .45 1199.28 N 2049.00 E 2372.51 1215.46 N 2089.86 E 2416.17 1230.49 N 2129,84 E 2458.50 12~5.74 N 2169.76 E 25P~8q 12'60"4'7"N 2210,24'E ' "25~ .-55 9500.00 8967.53 8861.33 25 26 N 69 30 E .23 1275,51 N 2250.46 E 2586.09 9600.00 9057.62 8951.42 25 44 N 69 30 E .30 9700.00 9148.25 9042.05 25 0 N 69 35 E .73 9800,00 9239,30 9133,10 2~ 25 N 70 41 E 9900.00 9530.71 9224.51 23 56 N 69 $5'E .66 lOOO0.O0 9422.35 9316.15 23 35 N 70 18 E 10100,00 9513.97 9407,77 23 38 N 69 48"E .~1 10200.00 9605.75 ~ 9499.55 23 23 N 69 11 E ,35 10300,00 9697,79 9591.59 23 1 N 69' 11 E .37 10400,00 97'90.28 9684.08 22'2"i N"'6'9 .......5"'E ,67 1290.72 N 2291.13 E 2629.11 1305.46 N 23..50.74 E 2670.9P 1519.12 N 2369.75 E 2711,82 1.5'35'27 N 2'407,77 E" ' 27'52,02 1346.76 N 2445.4~+ E 2791.57 131160.60 N 2483.06 E 2831%2P 1374,70 N 2520,16 E 2870.64 1388.59 N 2556.71 E 2909.42 14-02;16' N 2'592*;23 E ...... 2947,14 10500.00 9883.09 9776.89 21 52 N 68 48 E .50 10600.00 9975.89 9869.69 21 52 N 68 48 E 0.00 10650,00 10022.29 9916.09 21 52 N 68 48 E 0.00 1415.63 N 2626.96 E 2984.10 1~29.10 N 2661.68 E 302,,~"~07 1~35.84 N 2679,04 E 303 55 ** THE C/~LCUEA'TIONS ARE BASED' ON'~THE' TANGENTIAL' OR 'TERMI'N'A'L' ANGER .... M£'THOD ** HORIZONTAL DISPLACEMENT : 3039.55 FEET AT NORTH 61 DEG. 49 MIN. EAST (TRUE) ST4RT' OF SURVEY WAS, 106.20 FEET ABOVE SEA LEVEL MARAI;S~DN OIL COMPANY D-5RD TRADING EA¥ UNIT DATE OF SURVEY ,JULY PAGE 5 29e 1980 COOK INLET BOSS SURWEL BOSS-16633 MEASURED DEPTH TRUE SPERRY-SUNe INC INTERPOLATED RECORD OF SURVEY VERTICAL SUB SEA T'~'UE DEPTH TVD ELEVATION TOTAL RECTANGULAR' 'COORDINATE.< NORTH/SOUTH EAST/WEST O. O, -106, 106, 1000. 1000, 89~. -89~. 2000. 2000, 1893, -1893, $000. 2988, 2881, -2881, 10. S 17. S ~"'" ~,' 61, N 4000, 3918. 3812. -3812. 293. N 338, E 50 60 70 00, 4853, q7~7, -4747. 00. 5789, 5683, -5683, 00. 6695, 6588. -6588. 514, N 616. 712. N 904. 889. N 1288. 8000. 7615. 7509. -7509. 9000, 8516. 8~10. -8410. 1042. N 16q7, E 1199. N 2049, E 100 106 00, 50- 9~22. 9316. -9316, 10022, 9916. -9916, 1347. N 2q45, 1436. N 2679. INTERPOLATED COORDliN~'~F"$''' FOR'I'E~ERY' l'O00e'O0 .... FEE'T '"OF' "MEASORED' DEPTH FROM 0.00 FEET TO 10650.00 FEET .i , spepp -sun d. A. Fouch~ President Mr. Curtis Dowden Marathon Oil Company P. O. Box 2380 An_chorage, Alaska 99502 July 31, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16633 Well D-5RD Trading Bay Unit Field Cook Inlet, Alaska Date of Survey: July 29, 1980 Operator: Kirk Afflerbach Please find enclosed the "Orginal" and twenty three (23) copies of our Boss Gyroscopic Multishot Directional Survey. on the above well. Thank you for giving us this opportunity to be of service._ Yours very truly, KB/kc Enclosures cc: Mr. Fu~(ll copies) SPERRY-SUN, INC. Ken Broussard District Manager JUl. MARATHON OIL COMPANY D-5RD TRADING BAY UNIT SPERRY.-SUN WELL S ,U~. £YING ANCHORAGE, ALASKA COMPUTATION DATE JULY 28, 1980 MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH rn,,mor.. COURSE Dn~J, rm INCLINATION DIRECTION SEVERITY DEG MIN DEGREES DEG/IO0 COMPANY ri,Tr..n=. SURVrV.,JULv ~a_ BOSS GYROSCOPIC SURVEY JOB NUMBER BOSS-16633 ,,~'' Y ~U~ING~,, ELEV. -- 106.~D FT. OPERATOR-KIRK AFFLERBACH -, ' ~ Y~YAI ' RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECTION 0 0.00 -106.20 100 , 100.00 -6.20 200' '200 O0 .... 300 299.98 193.78 400 399.95 293.75 500 ~99.92 600 599,91 493,71 700 699,90 593,70 000 .... 799.87 693.67 900 899.81 793,61 1500 1499.66 1600 1599.66 1800 '. 1799.65 1900".' 1899,65 2100 2099.65 2200 2199,65 ~300 ~299.~5 2400 . 2399.64 2500 2499,61 1000 999.75 893.55 1100 1099.71 9~3.51 1200 1199,69 1093,q9 1300 1299,68 1193,48 lqO0 ' 13-9-9-67 .... 129~3.q7 1393,46 1493,46 i:~ q5 1693,45 1793,45 ..!893~45 1993.~5 2093.45 21_9~,~5 2293,~4 2393,41 " --= .PAQA " 2599.33 2700 2698.35 2592.15 2800 2796,55 2690.35 2900 2893,86 2787.66 0 0 N O. 0 E 0 3 N 76.29 W 0 ..... 3 .... ~..'~n an 1 27 S 23.19 W 1 ~0 S 19.79 W 0 53 S 22,60 W 0 43 S 28.39 U 0 48 $ 79, 0 id 1 ' 51 .......S 'Y7-50 W ....... 2 3 S 74.39 W 1 51 S 83.20 W - 1 25 S 55-.89 0 54 S 48.79 id 0 36 S 56.50 W 0,00 o.bo · 06 ' .01 ....... ,11 .... " ~"'-'0'2 1.~2 i.23 · 24 3.76 .77. 5.°~ · 19 7,14 ,66 11,'05 0', 32 .... · 23 9,16 · 36 9.83 · 53 11,94 · 33 12.75 0- qO-'~ -'S' ~°,-?~ '-"-' 0 51 S 15. 0 E 0 33 S 16. 0 id O 13 S-25.50 E 0 20 ~'m S 20.69 E 0 16 S 85.10 W .... ~42 ......... 13~59" · 48 14.87 .48 . 16.06 41 I~ 70 · 11 17,16 · 50 17,46 0 .3 . 0 11 0 3 O 2R 0 45 2 0 G. 7 ...... N 25.70 E 9 51 N 37. 0 E 11 56 N 45.90 E 14 37 N ~8.A0 E , , N 88,79 .... N 78.79 W .14 17.45 N 21.39 E .21 17.36 N ~1.20 E ,42 17,00,. N 53,'0 E ,31 16,29 N 25.20 E ' 1,37 lq,31 .' _'.4.12 7.92 4,04 3,72 2.67 17,76 2.75 ' 33.35 0.00 0.00 N .05 W -,0~ S ~v, ..... S .55 W -1.06 S 1,54 W -3.13 S 2.33 W S 2,94 W -5,97 S 3,9~ W -7.18 S g,'21 '~ =9.~1' ' S 9,53 W -12,73 S 12-87 W -15,99 S 17.13 W -20.74 S 18.17 W -22,04 ,S --- 1.8..79 '-J 22..99 S 18,79 W -23,59 S 18.72 W -24.09 S 18,58 W -24,49 S 18,72 W ','-24,75 S 19.21 W -25,18 S 19.35 W -25,27 $ 19,06 W -24.83 S 18.25 W -23,79 S 16.98 W -21,73 g . 13.93 W -1~.07 , N 6.46 W -3.93 N 6.13 E 13.80 N 23.00 E 36.0~ 3000 2989.98 2883.78 17 22 N 50,79 E 2.83 51.18 N 44.02 E 62,99 MARATHON OIL COMPANY SPERRY-SUN WELL suFJ'i"~ZYING ANCHORAGE, ALASKA D-5RD TRADING BAY UNIT ALASKA COMPANY ': ~GE 2 DATE .OF SURVEY dULY 29t 1980 COMPUTATIO~ DATE BOSS GYROSCOPIC SURVEY dULY 28t 1980 JOB NUMBER BOSS-16633 KELLY BUSHING ELEV. = 106.20 FT. J TRUE OPERATOR-KIRK SUB-SEA COURSE COURSE DOG-LEG TOTAL AFFLERBACH MEASURED VERTICAL DEPTH DEPTH VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST VERTICAL SECTION 3100 3084.86 5200 5]78.67 3300 3271.60 2978.66 19 24 N 50. 9 E 2.04 71.27 N 68.35 E 3072.47 21 3 N 50.29 E 1.65 93.41 N 94.92 E 5165.40 22 17 N 50. 0 E 1.23 117.08 N 123.27 E 93.93 127.81 163.98-~. 3400 3364.19 3257.99 3500 3456.81 3350.61 3600 3549.48 3Q43.28 3700 36q2.28 3536.08 3800 3735.24 3629.04 3900 3828.29 3722.09 22 6 N 50.59 E ,30 141,21 N 152,33 E 22 12 N 50.29 E .15 165.22 N 181.40 E 21 56 N 50. 9 E .27 189.27 N 210.27 E 21 47 N 50.29 E .1G 213.11 N 238.89 E 21 27 N 51,29 E ,51 236,40 N 267,45 E 21 32 N 51.20 E .11 259.34 N 296.03 E 201.00 237.97 274.78 311.28 347.45' 383.49. 4000 3921.43 3815.23 4100 q014.75 3908.55 4200 4108.29 4002.09 21 7 N 51.50 E .q4 282.07 N 324.44 E 21 0 N 51. 0 E .21 304.56 N 352.47 E 20 23 N 52.29 E .77 326.50 N 380,1g E 419.27 454.61 489.40 4500 4202.00 4095.80 4400 4295.82 4189.62 4500 4389.92 4283.72 20 29 N 51. 0 E .46 20 0 N 51.20 E ,49 19 33 N 51.90 E .50 348.17 N 407.57 E 369.90 N 434.50 '390.94 N . 461.00 E 523.78 557.78 591.08 4600 4484.16 4377,96 4700 4578,26 4472,06 4800 4671.65 4565.45 4900 4764.17 4657.97 5000 4856.59 4750.39 5!00 4949.13 4842.93 19 31 N 51.29 E 20 0 N 51.90 E 21 52 N 51,70 E 22 43 N 51.~0 E 22 11 'N 52.'9 E 22 21 N 51.70 E · 20 411.72 N 487.22 E ;51 432.72 N 513.72 E 1;87 454.82 N 541.80 E · 89 478,52 N 571.42 E ;68 502.27 N 601,33 E · 23 525.66 N 631.16 E 624,01 657,30 692,48 729.79-"~ 767.38 804.72 5200 5041.69 4955.fl9 5300 5134.53 5028.33 5400 5227.81 5121.61 22 7 N 51.29 E 21 30 N 52.40 E 20 43 N 52.40 E .28 .74 .77 549.22 N 660.78 E 572.17 N 689.99 E 594.15 N 718.53 E 8A1.96 878.56 914.10 5500 5521.34 5215.14 5600 5415.10 5308.90 5700. ,, 5.5,0,9.,18 ...... 5 ..02.98 20 43 N 52.90 E 19 55 N 54.70 E 19 43 N 53.20 E · 18 615.62 N 746.67 E 1~02 636.15 N 77~.70 E · 55 656.11 N 802.12 E 949.05 983.45 1017.05 5800 5603.39 5497.19 5900 5697.89 5591.69 6000 5792.1~ 5685.94 19 25 N 53.90 E 18 52 N 65. 9 E 20 10 N 68.50 E .38 ~,71 1;73 676,02 N 829.08 E 692.63 N 857.19 E 705,76 N 887,90 E 1050,22 1082,85 1116.12 6100 5885.56 5779.36 21 35 N 69,80 E 1.49 921,21 E 1151.45 MARATHON OIL COMPANY D-5RD SPERRY-SUN WELL Sd, .EYING COMPANY ANCHORAGEv ALASKA COMPUTATION DATE .AGE 3 DATE OF SURVEY dULY 29~,,1980 BOSS GYROSCOPIC SURVEY TRADING BAY UNIT ALASKA dULY 28, 1980 JOB NUMBER BOSS-16633 KELLY BUSHING ELEV. = 106.20 FT. .TRUE SUB-SEA COURSE COURSE DOG-LEG OPERATOR-KIRK AFFLERBACH TOTAL MEASURED VERTICAL DEPTH DEPTH VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH OEG MIN DEGREES OEG/iO0 NORTH/SOUTH FAST/WEST VERTICAL SECTION 6200 5978.11 630~ 6069.68 6400 6160.12 5871.91 22 54 N 68. 0 E 1.49 732.08 N 956.52 E 5963.48 24 27 N 66.30 E 1,69 747.69 N 993.53 E 6053,92 26 2 N 64.50 E 1,76 765,46 N 1032,30 E 1189,02 1229.01 1271,57'--" 6500 6249.69 6600 6339.08 6700 6428.66 6143,49 26 44 N 63.79 E ,77 784.84 N 1072,29 E 6232.88 26 31 N 64. 9 E .25 804,53 N 1112,57 E 6322.q6 26 14 N 63.90 E ,30 824.01 N 1152,5~ [ 1315,98 1360,78 1405,19 6800 6518.53 6900 6608,65 7000 6699.13 7100 6789.89 7200 6880,69 7300 6971,69 6412.33 25 47 N 64.19 6502.45 25 33 N 64. 9 6592.93 24 49 N 65.50 6683.69 24 49 N 65. 9 E o17 6774.49 24 42 N 66.50 E .60 6865.49 24 17 N 66.59 E .42 843.21 N 862,10 N 880,23 N 897,78 N 914,96 N 931.46 N 1191;96 E 1449,02 1230J95 E 1492,32 1269.~47. E ..........1534,82- 1307,62 E 1576,74 1345,83 E 1618,53 1383,87 [ 1659.8~ 7400 7062,97 7500 7154,67 7600 7246,79 6956.77 23 53 N 65.30 E .66 7048.47 23 6 N 66.40 E .90 ' 7140.59 22 40 N 66.69 E .45 948.09 964.41 '979,90 1421;15 E 1700,57 1457;54 E 1740,35 1493,23 E 1779,11 7700 7339,25 7233,05 7800 7432.07 7325.87 7900 7525,15 7418.95 8000 7618.35 7512.15 8100 7711.33 7605.13 8200 7803.74 7697.54 22 G N 68.30 E .83 21 33 N 68.19 E ,55 21 20 N 67.50 E 21 9 N 68;~0 E .37 22 0 N 68; 9 E .86 22 55 N 68;69 E .94 994.48 1008,26 1022.05 1035,66 1049.29 1063,35 1528;42 E 1817,02 1562,97 E 1853.97 1596;84 E 1890,34 1630,43 E 1926,37''~', 1664.60 E 1962,92 1700,13 E 2000,88 8300 7895.45 7789.25 8400 7986.32 7880.12 8500 8076.29 7970.09 24 3 N 68.90 E 1.14 25 16 N 68;59 E 1.23 26 27 N 69;19 E 1.21 1077.76 1092.89 1108.59 1737.29 E 2040.43 1776.18 E 2081,86 1816,89 E 2125,15 8600 8165,34 8059,14 8700 8253,80 8147.60 8800 8342.35 8236,15 27 38 N 68.59 E i.22 27 57 N 68.q0 E 27 25 N 68.19 E ;53 1124.97 1142.07 1159.25 1859,32 E 2170,28 1902,71 E 2216,60 1945.89 E 2262.77, ...... 8900 8431,37 8325.17 9000 8521.07 8414.87 9100 8611,03 850~,83 26 45 N 68.19 E .67 25 42 N 69180 E 1.27 26 q N 68.q0 E .71 1176.16 1192.01 1207.59 1988.18 E 2308.03 2029.44 E 2351.88 2070,23 E 2395,19 9200 8701.1~ 8594.9~ 25 17 N 69.40 E ,90 1223.20 2110.66 E 2438.20 MARATHON OIL SPERRY-SUN WELL S,~,/EYING COMPANY ANCHORAGE, ALASKA COMPANY PAGE 4 DATE OF SURVEY JULY 29, 1980 D-SRD TRADING ..ALASKA UNIT COMPUTATION DATE JULY 28~ 1980 TRUE SUB-SEA COURSE COURSE DOG-LEG BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16633 KELLY BUSHINGiELEV. = 106.20 OPERATOR-KIRK AFFLERBACH TOTAL FT. MEASURED VERTICAL VERTICAL INCLINATION DIRECTION DEPTH OEPTH DEPTH DEG MIN DEGREES SEVERITY RECTANGULAR COORDINATES DEG/iO0 NORTH/SOUTH EAST/WEST VERTICAL SECTION 9500 8791,55 8685.55 25 18 N 69, 9 E 9400 8881,87 8775.67 25 51 N 70. 0 E 9500 8972,15 8865,95 25 26 N 69,50 E · 15 1258.$4 N 2150.63 E , · 44 1255,33 N 2190.84 E .23 1268.22 N 2231.20 E 2480.57 2525.09 2565.69'"", 9600 9062,54 8956,14 25 44 N 69.50 E 9700 9152,69 9046.49 25 0 N 69.59 E 9~00 9243.52 9137,32 24 25 N 70.69 E 9900 9334.75 9228.55 23 56 N 69.59 E 10000 ' 9426.27 9320.07 23 35 N 70,30 E 10100 9517,89 9411,69 23 38 N 69;80 E · 30 1283.35 N 2271;66 E · 73 1298.32 N 2311;81 E · 74 1312,53 N 2351.14_E · 67 1326.q3 N 2389,67 E .45 13~0;25, N 2~27;53 E · 21 1353.92 N 2465.19 E 2608.49 2650.95 2692.32 2732.85 2772.74, 2812.39' 10200 9609.58 9505,38 23 23 N 69,19 E ,35 1567,90 N 2502,57 E 10300 9701.q9 9595,29 23 1 N 69.19 E .36 1381.89 N 2539,41 E 10~00 9793,74 9687.54 22 21 N 6g, 9 E .67 1395.62 N 2575,46 E 2851.93 2891.01 ~929.27 10500 9886,58 9780,18 21 52 N 68.80 E . ,49 lq09,15 N 2610,61 E 10500 9979.18 ~9872,98 21 52 N 68.80 E ,00 1422,62 N 2645~35 E 10650 10025.58 9919.38 21 52 N 68.80 E .00 1429.36 N , 2662.72 E 2966.63 3003.62 3022.11 HORIZONTAL DISPLACEMENT : 3022.11 FEET AT NORTH, 61 DEG. 46 MIN. EAST AT MD = 10650 THE'CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RA DIUS OF CURVATURE METHOD. MARATHON OIL COMPANY SPERRY-SUN WELL SU.',EYING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY ,,JULY 29, ..~ AGE 5 1980 D-5RD TRADING ALASKA BAY UNIT CO?.PUTAT ION DATE dULY 28, 1980 dOB NUMBER BOSS-16655 KELLY BUSHING ELEV, : 106.20 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF OPERATOR-KIRK MEASURED DEPTH AFFLERBACH MEASURED TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD , VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 0.00 -106.20 0.00 , O.O0 0.00 CORRECTION 1000 999.75 893.55 9.83 S 12.87 W ,25 .25 2000 1999,65 1893.45 17.48 S 19,00 W .35 o10 3000 2989.98 2883.78 51.18 N 44.02 E 10.02 9.67 qO00 3921.43 5815.23 282.07 N 324.44 E 78.57 68.55 5000 4856.59 4750.39 502.27 N 601.33 E 145.41 64.84 6000 5792.14 5685.94 705.76 N 887.90 E' 207,86 64.45 7000 6699.13 6592.93 880.25 N 1269.47 E 300.87 93.00 8000 7618.35 7512.15 1035.66 N 1630,43 E 381.65 80.79 9000 8521.07 8414.87 1192.01N 2029.44 E 478.93 97.28 10000 9q26.27 9320.07 1340,25 N 2427.53 E 573.73 94.80 10650 " 10025.58 ,9919,38 1429.36 N 2662.72 E 624.42 50.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. MARATHON OIL COMPANY SPERRY-SUN WELL Scr~VEYING ANCI4ORAGE, ALASKA COMPANY , PAGE 6 DATE OF SURVEY JULYs29, 1980 D-5RD TRADING __A_L_ BAY UNIT COHPUTATION DATE dULY 28, 1980 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA dOB NUMBER BOSS-16633 KF.]~LY BUSHING ELEV, : 106.20 OPERATOR-KIRK AFFLERBACH DEPTH FT. MEASURED TRUE VERTIC AL SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH O O.O0 DEPTH NORTH/SOUTH EAST/WEST -106.20 0.00 ' 0.00 DIFFERENCE 0,00 CORRECTION 6 6.20 106 106.20 206 ...... 20~-20 306 306.20 406 406.20 ..5.06 ..50.6,.20 606 606.20 706 706,20 806 806.20 906 906.20' 1006 1006,20 1106 1106.20 -100.00 0.00 .1.00,~ 200.00 300.00 400.00 500.00 600.00 700,00 800.00 900.00 1000.00 0.00 · 01 N .... ,05S 1.57 S 5.93 S ...... 5. '~~ 5 S 7.21 S 7,86 S 8,j~7 S 9,22 S 9,86 S 10,81 S 0.00 0.00 · 06 W .00 · 07 W -00 · 61 W .02 1.60 W ,06, 2,..37_W ........... .08 2.98 U .09 4.02 W .10 6.41 W 9,75 W ,19 13.08 W ,25 15.64 W ,29 0.00 .00 .02 .01 .01 .06 .06 1206 1206.20 1306 1306.20 1406 lq06.20 llO0.O0 1200,00 1300.00 12.01 S 17.21 W .31 .02 12.79 S 18.22 W .32 .01 13.67 S 18.82 W .33 .01 1506 1506.20 1606 1606.20 1706 1706.20 1400.00 1500.00 1600.00 1~.97 16.12 16.72 18.76 W ,34 .01 18.7q W ,34 .01 18.76 W .35 .00 MARATHON OIL COMPANY SPERRY-SUN WELL SU EYING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY dULY /,-'~GE 7 29, 1980 D-5RD TRADING BAY ALASKA UNIT COMPUTATION DATE dULY 28, 1980 dOB NUMBER BOSS-16633 KELLY BUSHING ELEV. : 106.20 FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OPERATOR-KIRK DEPTH AFFLERBACH MEASURED TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR COORDI NATES MD-TVD VERTICAL DEPTH 1806 DEPTH 1806,20 DEPTH 1700.00 NORTH/SOUTH EAST/WE 17.20 S 18.57 ST DIFFERENCE CORRECTION W '.'35 .OD 1906 2006 2106 1906.20 2006.20 2106.20 1800.00 17.46 S 18.75 W .35 1900.00 17.48 S 19.01 W .35 2000.00 17.44 S 19.23 W .35 .00 .00 .00 2206 2506 2406 2206.20 2306.20 2406.20 2100.00 2200.00 2500.00 17.36 S 19.35 16.96 S 19.02 16.23 S 18.18 .35 .35 .36 .00 .00 .01 2506 2606 2707 2506.20 2606.20 2706.20 2AO0.O0 14.06 S 16.86 W .40 2500.00 7.23 S 15.57 W .71 2600.00 4.82 N 5.60 W 1.77 .31 1.06 2809 2912 3P16 2806.20 2906.20 5006.20 2700.00 ~2800.00 2900.00 19.21N 7.63 E 35.52 N 25,47 E 54.39 N 47.96 E 3.67 6,56 10.80 1.90 2.89 4.25 5122 3229 3337 3106.20 3206.20 3306.20 3000,00 3100.00 3200.00 76.10 N 74.11 E 100.18 N 105.07 E 126.19 N 134.13 E 16.45 23.30 31;20 5.63 6.87 7.90 3445 3553 3661 3406.20 5506,20 3606.20 3300.00 3400.00 5500.00 152.04 N ~65.52 E 178.08 N 196.88 E 203.89 N 227.79 E 39.14 47.13 54.94 7.95 7.99 7.80 MARATHON OIL COMPANY SPERRY-SUN WELL 'SG'~%'~/£YING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY JULY 29~ PAGE 8 1980 D-SRD TRADING ALASKA BAY UNIT COMPUTATION DATE dULY 28, 1980 dOB NUMBER BOSS-16633 KELLY BUSHING ELEV. = 106,20 FT. INTERPOLATED VALUES FOR EVEN lO0 FEET OF OPERATOR-KIRK SUB-SEA DEPTH AFFLERBACH MEASURED TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH 3768 3876 3983 4090 4197 ~304 4411 DEPTH 3706.20 DEPTH 3600,00 NORTH/SOUTH 229.27 N EAST/WEST 258,54 E 253.88 N 289.23 E 278.40 N 319.84 E 302,,,50 N 349.9~ ..... E 326.02 N 379.57 E 349.15 N 408.79 E 372.26 N 437.45 E 3806.20 5906.20 4006.~0 4106.20 4206.20 4306.20 3700.00 3800.00 4000.00 4100.00 4200.00 DIFFERENCE CORRECTION 70.05 7.46 77.47 7.42 84.64 7,~7 91.57 6.93 ,~' 98,29 6,72 ,.~ 104,85 6.56 4517 4623 4729 4406.20 4506.20 4606.20 ~300.00 4~00,00 4500.00 '594.51 N 465.56 E 416.61 N 495.32 E ~39.00 N 521.72 E 111.08 6.23 117.19 6.11 123.53 6.34 4837 4945, 5053 4706.20 4806.20 ~906.20 A600.O0 4700.00 4800.00 463.41 N 552.68 E ~89.56 N 585.09 E 514.75 N 617,30 E 131.05 7,50 139.35 8.32 147.39 '8-03 5161 5269 5376 5483 5590 5696 5006,20 5106,20 5206.20 4900.00 5000.00 5100.00 540.20 N 649.52 E 565.36 N 681,15 E 589.16 N 712.05 E 5~06.20 5~06.20 5506.20 5200.00 5300.00 5400.00 612.17 N ~42.10 E 6~4.28 N 772.06 E 655.47 N 801.27 E 155.z+9 8.11 163.35 7.86 170.69 7.34 177.62 6.92 184.33 6.71 190,64 6.31 MARATHON OIL SPERRY-SUN WELL SLr-"~EYING COMPAEY ANCHORAGE, ALASKA COMPANY · DATE OF SURVEY dULY 29~ '~"%A G E 9 1980 D-5RD TRADING BAY ALASKA UNIT COMPUTATION DATE dULY 28, 1980 dOB NUMBER BOSS-16633 KELLY BUSHING ELEV. = 106.20 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OPERATOR-KIRK OF SUB-SEA DEPTH AFFLERBACH MEASURED TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH 5802 DEPT 5606. 2O DEPTH 5500.00 NORTH/SOUTH 676.59 N EAST/WEST 829.88 E DIFFERENCE 196.78 CORRECT 6 ION 5908 6014 6_122 6230 6340 6451 5706.20 5806.20 5906.20 6006.20 6106.20 6206.20 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 693.83 N 859.77 E 707.66 N 892.71 E 721.£5 N 928.87 E 736.52 N 967.53 E 754.37 N 1008.74 E 7?5.22 N 1052.67 E 202.58 208,78 2.15,99 224.29 233,92 245.12 5 6 8 9 11 .81 .20 .21 .30 .63 .20, 6563 6674 6786 6306. 6406. 6506. 20 20 20 6200.00 6300.00 6400.00 797.36 N 1097.80 E 819.14 N 1142.57 E 840,62 N 1186.59 E 257.05 268.76 280.11 1.92 1.71 1.35 6897 7007 7117 6606, 6706. 6806. 20 20 20 6500.00 6600.00 6700.00 861.59 N 1229.90 E 881.59 N 1272.44 E 900.96 N 1314.46 E 291.08 301.59 311.77 0.98 0.50 0.19 7228 7337 6906.20 7006.20 7106.20 6800.00 6900.00 7000.00 919.64 N 1356.59 E 937.64 N 1398.17 E 956.05 N 1438.52 E 321.88 331.67 341.06 0.11 9.79 9.39 7555 7664 ,7,7.72., 7206.20 7306.20 7406.20 7100.00 7200.00 7300.00 973.18 N 1477,64 E 989.52 N 1515.95 E 1004.47 N 1553.48 E 349.80 358.13 365.98 ,74 .33 .85 MARATHON OIL COMPANY SPERRY-SUN WELL S~;,VEYING ANCHORAGE, ALASKA COMPANY DATE OF SURVEY JULY 29e PAGE 1980 10 D-5RD TRADING BAY ALASKA UNIT COMPUTATION DATE JULY 28, 1980 JOB NUMBER BOSS-16633 KELLY BUSHING ELEV. : 106.20 FT, OPERATOR-KIRK AFFLERBACH INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH MEASURED TRUE VERTICAL SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH 7879 DEPTH 7506.20 DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 7qO0.O0 1019.22 N 1590,00 E 373.46 CORRECTION 7.48 7986 8202 760 770 7BO 6.20 6.20 6.20 7500.00 1033.92 N 1626,06 E 380.77 7600.00 1048.51 N 1662,67 E 388.26 7700.00 1063.'73 N 1701,09 E 396.~7 7.32 7,49 8.21 8311 8421 8533 7906.20 8006,20 8106,20 7800.00 1079.q? N 17q1.76 E q05.57 7900.00 1096.32 N 1784,93 E 415.79 8000.00 1113.88 N 1830,81 E 427,21 9 10 11 .10 .22 8646 8759 8871 820 83O 6.20 6.20 6.20 8100.00 1132.79 N 1879.26 E 439.93 8200.00 1152.28 N 192~.46 E 453.07 8300.00 1171.45 N 1976.39 F 465.61 . 72 54 8983 9094 9205 8506.20 8606.20 8706.20 8400.00 1189.54 N 2022.72 E 477.30 "8500.00 1206.72 N 2068.03 E 488.43 8600.00 122~.04 N 2112.90 E 499.39 11 11 10 .69 .13 .97 9316 9426 9537 8806.20 8906.20 9006.20 9106.20 8700.00 1240.81 N 2157.10 E 510.00 R800.O0 1257.31 N 2201.75 E 520.76 8900,00 1273.90 N 2246.37 E 531.51 . 61 75 75 9000.00 1290.73 N 2291.41 E 542.47 10.96 9759 9868 9206.20 9306,20 9100.00 1306.92 N 2335.13 E 552.80 9200.00 1322.02 N 2377.79 E 562.57 10,34 9,76 MARATHON OIL COMPANY SPERRY-SUN ~ELL Sv,{VEYING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY dULY 29, PAGE 1980 11 D-5RD TRADING BAY ALASKA COMPUTATION DATE UNIT dULY 28, 1980 dOB NUMBER BOSS-16633 KELLY BUSHING ELEV. : 106.20 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OPERATOR-KIRK AFFLERBACH DEPTH MEASURED TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH 9978 DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 9406.20 9300.00 1337.30,N 2419.28 E 571.90 CORRECTION 9.3q 10087 9506.20 9400.00 1352.15 N 2460.38 E 581.04 10196 9606.20 9500.00 1367.38 N 2501.20 E 590.12 10305 9706.20 9600.00 1382~60 N 2541.28 E 598.92 9.14 9.08 8.80 10413 9806.20 9700.00 1397.45 N 2580.25 E 607.27 10521 9906.20 9800.00 1412.02 N 2618.03 E 615.16 ...... 1~2.9 10006.20 9900.00 1426.55 N 2655.47 E 622.92 8.35 7.89 7.76 10650 10025.58 9919.38 1429.36 N 2662.72 E 624.q2 THE CALCULATION PROCEOUPES USE A LINEAR INTERPOLATION BETWEEN 1.50 THE NEAREST 20 FOOT MD CFROM RADIUS OF CURVATURE} POINTS Document I*ransmittal Umon O~1 Company of Cal~f union TO H. W. Kugler Alaska 0&G Cons. Comm, AT 3001 Porcupine Drive Anchoraqe~ AK 99504 TRANSMITTING THE FOLLOWING: DATE SUBMITTED NO. ~pn~ ~ lqRn J/ FR6M R. C. Warthen Union 0il Company AT PO Box 6247 Anchoraqe, AK 995[ TELEPHONE NO returning of this document ~nsmitta FORM I-2M02 (REV 11-72) PRINTED IN U S A Form No 10~404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union Oil Company of California* AUe .- 8 lett 3 ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502Alaska 4 LOCATION OF WELL Leg A-2, Cond #9, Dolly Varden Platform 2000'FSL, 1500'FEL, Sec 6-8N-13W-SM 5 AP! NUMERICAL CODE 50-133-20100-01 6. LEASE DESIGNATION AND SERIAL NO ADL-18729 A-926 7 IF 1NDIAN'ALOTTEE OR TRIBE NAME m-- 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9 WELL NO. TBU D-5RD fl ,. 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11 SEC T. R M (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO 80-65 13 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS JULY REPORT OF DRILLING OPERATIONS 07-01 7956'TD Drld 7585'-7838'. POH. RIH w/ bit #16. Drld 7838'-7956'. 07-02 8181'TD Drld 7956'-8029'. POH. RIH w/ bit #17. Drld 8029'-8181'. 07-03 8413 ' TD Drld 8181'-8291'. POH. Tstd BOPE--rams to 3000~; annlrs to 1500#. RIH w/ bit ~18. Drld 8291'-8413'. 07-04 8696'TD Drld 8413'-8621'. POH. PU locked BHA. RIH w/ bit #19. Drld 8621'-8696'. 07-05 8884'TD Drld 8696'-8766'. POH. RIH w/ bit ~20. Drld 8766'-8884'. 07-06 8986'TD Drld 8884'-8896'. Tripped for bit. Drld 8896'-8969' w/ bit #21. Tripped for bit. Drld 8969'-8986' w/ bit #22. 07-07 9095'TD Drld 8986'-9087'. POH. RIH w/ bit #23. Drld 9087'-9095'. 07-08 9262'TD Drld 9095'-9185'. POH. RIH w/ bit #24'. Drld 9185'-9262'. Started POH for new bit. 07-09 9391'TD POH. RIH w/ bit #25. Drld 9262'-9391'. 07-10 9485'TD Drld 9391'-9393'. POH. RIH w/ bit #26. Drld 9393'-9485'. RIH w/ bit #27. 07-11 9634 ' TD Drld 9485'-9618'. POH. Tstd BOPE. RIH w/ bit #28 & drld 9618'-9634'. *Marathon 011 Company - Sub-Operator 14. I hereby c that the for~l~l~"~ true and correct ', ' B' 8~6/80 SIGNED~ ~~~~TITLE lsto Brig. Supt. DATE NOT~-'~eport on this form is required for each calendar month, regardless of the status of operat,ons, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise dtrected. July Report of Drilling Operations Page 2 07-12 9840'TD 07-13 10,066'TD Drld from 9634'-9840'. Drld from 9840'-10,066'. 07-14 10,215'TD Drld 10,066'-10,098'. POH. RIH w/ bit #29. Drld to 10,215'. 07-15 10,375'TD Drld from 10,215'-10,375'. 07-16 10,481'TD Drld 10,375'-10,481'. POH. RIH w/ bit #30 to 13-3/8" shoe. Presently chg brake bands on drawworks. 07-17 10,620'TD Fin brake repairs. RIH w/ bit #30. Drld 10,481'-10,620'. C&C mud & hole. Made 14-std short trip. C&C mud & hole for logs. 07-18 10,620'TD C&C mud & hole for logs. POH. RU Schl. Ran DIL log. Ran long spaced Sonic w/ Caliper & GR. Sonic tool stuck w/ btm @ 7703'. Worked WL in attempt to free tool. 07-19 10,620'TD Attempting to work stuck logging tool free. MU fishing tools to strip DFP over WL. RIH to 5351' & tools stopped. Attempted to work by bridge. POH. Added 8-1/2" straight stabilizer & pump out sub to fishing tools. RIH stripping over WL. 07-20 10,620'TD RIH stripping over WL. Worked thru bridge @ 5252' to 5366'. Staged on into hole, C&C mud. Logging too Is came free w/ guide on end of DP @ 7550'. R IH to 7643'. Pulled fish into grapple. Press up on DP & checked WL wt. Had indications that fish was in grapple. Pulled WL out of rope socket w/ blocks. Pulled WL out of DP w/ Schl unit. Dropped bar & opened circ sub. POH. Tight places in hole from 5395' to 5312' and ~ 2610'. Tstd BOPE. 07-21 10,660'TD 07-22 10,660' TD 07-23 10,660'TD Fin testing BOPE. RIH. Broke circ @ 6750', 8700', 9900', 10,560'. Hole OK. Drld 10,620'-10,660'. C&C mud & hole for logs. POH. DP stopped moving w/ bit @ 5676'. Worked bit to 5660'. Pipe free going dwn. Worked thru tight hole ~ 5660'-5655'. RIH. Washed fill from 10,618'-10,660'. C&C mud. POH. Hole tight @ 4350'. LD roller reamer, RWP stab, Monel DC's & Monel stabi- lizers. Cut & slipped drlg line. RIH w/ 12-1/4" bit, 3 stds, DC's, & 3 stabilizers. No tight spots going in hole. POH--no tight hole. RU to run 9-5/8" csg. Fin RU to run csg. Ran 9-5/8" csg w/ shoe ~ 10,608', FC @ 10,526', & DV stage clr @ 6548'. RU HOWCO & started cmtg 1st stage. July'Report of Drilling Operations Page 3 07-24 10,660'TD Fin cmtg 9-5/8" csg. 1st stage: 900 sx CI"~Z l'Z2'~al't' sk Econolite, .3% HR-6L, 1/4 #/sk flocel (13.4 ppg) fol- lowed by 350 sx CIG w/ 1% CFR-2, .3% Halad 22-A, 3% KCI, 1/4 #/sk flocel (15.8 ppg). Bumped plug w/ 1950 psi. CIP @ 0745 hrs, 07-23-80. 2nd stage: Dropped DV bomb. Opened DV tool w/ 1300 psi. Circ out 50 bbls mud contami- nated cmt. Cmtd w/ 685 sx CIG w/ 1/2 gal/sk Econolite, .3% HR-6L, 1/4 #/sk flocel (13.4 ppg). Dropped DV closing plug. Closed DV tool w/ 2500 psi. Bled to 1000 psi & held 30 min. PU BOP stack & set slips. LD landing jt. ND BOPE. Instld tbg spool & tstd same--OK. NU BOPE & tstd. WOC. 07-25 10,660'TD lO,526'PBTD WOC. RIH w/ 8-1/2" bit. Tagged cmt @ 6535'. Tstd csg above DV clr to 2500 psi--OK. Drld cmt & DV clr from 6535'-6548'. Tstd csg & DV clr to 2500 psi--OK. R IH to 10,482' & tagged firm cmt. Drld cmt from 10,482' to FC ~ 10,526'. Circ hole. Displ mud in csg w/ FIW. POH. RU Schl. RIH w/ Density-CNL-NGT log. 07-26 10,660'TD 10,526'PBTD Ran NGT-CNL. POH. RIH w/ TDT-K logging tools. Running TDT-K. 07-27 10,660'TD 10,526'PBTD Fin TDT-K & POH. RD Schl. RU DA & RIH & ran NLL. POH. RIH w/ GND (Density). Tool failed. POH & repaired tools. 07-28 10,660'TD 10,526'PBTD Ran GND log & Spectrolog. RIH w/ CBL logging tool. Tool failed. POH. 07-29 10,660'TD 10,526'PBTD DA ran CBL log & Sperry-Sun gyro. RD DA & Sperry-Sun. RIH w/ bit & scraper to 10,526'. Circ & POH. RU DA. RIH w/ J B & GR. 07-30 10,660'TD 10,526'PBTD RIH w/ JB & GR to 10,278'. POH w/ drag. Lost drag when tools pulled into lubricator. RIH w/ JB & GR to 3400'. POH--no rec. RD DA. RIH w/ bit & scraper to 10,526'. Rev circ hole w/ FIW. No indication of rubber or junk. POH. RU DA. RIH w/ JB & GR to 10,350'. Did not tag any obstacle. No rec in JB. RIH w/ 4" csg jet & perf for isolation sqz in B4 of Hemlock @ lO,229'-10,230'(DIL) w/ 4 HPF. POH. RIH w/ Halliburton EZSV cmt rtnr to 10,180'. PU to check clrs & cmt rtnr hung @ 10,119'. Pulled out of rope socket. 07-31 10,660'TD 10,526'PBTD POH w/ DA WL. RIH w/ OS on DP. Tagged rtnr setting tool @ 10,507'. Worked grapple over fish. Set wt on rtnr, PU & sheared setting sly w/ 30,000~ pull. Left rtnr @ 10,522'. POH. Rec clr loc & setting tool. RU DA. RIH w/ JB & GR. Set dwn @ 6531'. Spudded thru & RIH to btm. Had drag while POH. RD DA. RIH w/ OEDP. Circ & rev circ cmt flakes, rubber, & sd from hole. POH. ~otn~No REV 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchora~le AK 99502 4. LOCATION OF WELL Leg A-2, Cond #9, Dolly Varden PI.atform 2000'FSL, 1500'FEL, Sec 6-8N-13W-SM 5. AP! NUMERICAL CODE 50- 133-20100-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 A-926 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Tradin9 Bay Unit 9. WELL NO. TBU D-5RD 10. FIELD AND H)OL, OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO. 80-65 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. JUNE REPORT OF DRILLING OPERATIONS 06-08 10,250'TD 5,783'PBTD Skidded rig over Well D-5. ND Xmas tree. NU BOPE & tstd. Displ wtr in 9-5/8" csg w/ mud. POH. LD 4-1/2" tbg. RIH w/ bit & scraper to 2825'. 'Started out of hole. 06-09 10,250'TD 5,783'PBTD POH w/ bit & scraper. ND BOPE & remove tbg spool. Tack weld 9-5/8" slips to 9-5/8" csg. Pulled on 9-5/8" csg, could not remove slips. MU Tri-State mech cutter & RIH to 53' & cut 9-5/8" csg. POH w/ cutter. RIH w/ spear. Engaged spear in cut-off 9-5/8" csg & attempted to pull slips & 9-5/8" cut-off csg. Heated Bradenhead w/ steam. Still unable to remove slips. RU oil jars, HWDP, accel jars & spear. Engaged cut-off piece of 9-5/8" csg & jarred same out of hole. Rec slips & 9' cut-off jt of 9-5/8" csg. 06-10 10,250'TD 5,783'PBTD Tstd BOPE. RU Tri-State spear & Dialog. RIH & ran FPI-- 9-5/8" csg completely free @ 1500', stuck @ 1720_'. POH & RD Dialog. RIH w/ Tri-State mech cutter & cut 9-5/8" csg @ 1526'. Extent of blades of csg cutter is 9-7/8". POH. RIH w/ spear & engaged cut-off 9-5/8" csg. POH & rec 34 j ts & 2 pieces of 9-5/8" csg. RIH w/ 8-1/2" bit to csg stub @ 1526'. Circ & clean dehydrated & contaminated mud from hole. MU spear, Sperry-Sun side entry sub, & RU Dialog. RIH & engaged fish. Ran FPI & worked pipe & free point to 1800'. Stuck @ 1850'. POH. RIH w/ mech cutter & cut 9-5/8" csg @ 1790'. POH. *Marathon ?~t-]Company - Sub-Operator 14. I hereby c~rt,fy ~at the,foreg~d~TmJ~ aq~c~rrect ~ Dist Drl Su t - - ~ sm~ , ~ 'iwn~ __: g~ ~ __DATE 7/~8~ oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. June Report of Drilling Operations TBU Well D-5RD Page 2 06-11 10,250'TD 5,783'PBTD 06-12 10,250'TD 5,783'PBTD 06-13 10,250'TD 5,783'PBTD 06-14 10,250'TD 5,783'PBTD 06-15 10,250'TD 5,783'PBTD 1 1 80 RIH & engaged spear in 9-5/8" csg ~ 1526'. Jarred on fish, then stripped out of fish. Could not re-engage spear. POH. Replaced pack-off rubber. RIH & engaged fish. Jarred 1/2 hr & pul led fish free. POH & LD 6~jts & .2.~.pi~eces of 9-5/8" csg. RIH to csg stub w/ 12-1~it for C~)~- POH. R IH w/ FPI. Could not get inside 9-5/8" csg stub. RIH w/ 8-1/2" bit. Pushed rubber to 2800'. POH. RIH w/ spear & FPI. Worked free point to 1860'. POH. RIH w/ mech cutter & cut 9-5/8" csg & 1868'. POH. R IH w/ spear & jars. Jarred on fish. String parted. POH. Had BO @ stop sub on spear. R IH & screwed into stop sub. POH. R IH w/ spear. Engaged fish & jarred free. POH. Rec 1 j~t + 2 pieces of 9-5/8" csg @ 1997'. POH. R IH w/ spear. Attempted to work to csg stub @ 1868'. POH. RIH w/ 12-1/4" bit & CO dehydrated & heavy mud to 1868'. POH. R IH w/ spear. Engaged fish @ 1868'. Jarred fish loose. POH & r~_ec~._.~.,,jt,,s~+~ 2 pieces of 9-5/8" csg (131.25'). RIH w/ 12-1/4" bit. CO to ~199____Z7'. POH. RIH w/ mech cutter & cut 9-5/8" csg @ 2215'. POH. R IH w/ spear. Engaged fish & started jarring. Jarred on fish. Fish moved up hole 8' & stopped. Released spear & POH. RIH w/ mech cutter & cut 9-5/8" csg @ 2028'. POH. RIH w/ spear. Engaged spear & POH. Rec 39.28' of 9-5/8" csg. RIH w/ spear. Engaged spear @~-T7~'~'~"~28'. Jarred on fish. Could not move fish. POH. RIH w/ mech cutter & cut 9-5/8" csg @ 2120'. RIH w/ spear. Engaged spear & jarred fish loose. POH. R~9_Q~_~,~.I' of 9-5/8" csg. RIH w/ 12-1/4" bit. CO to 2120'. POH. RIH w/ 8-1/2" bit & CO to 2800'. POH. RIH w/ spear. Jarred fish loose & POH. Rec 88.32' of 9-5/8" csg. RIH w/ 8-1/2" bit, 1 std DP, & 12-1/4" reamer. CO 13-3/8" csg to 2215'. POH. RIH w/ mech cutter & cut 9-5/8" csg @ 2344'. POH. RIH w/ spear. Jarred fish loose & POH. ~ec~ of 9-5/8" csg. RIH w/ mech cutter & cut 9-5/8" csg @ 2490'. POH. RIH w/ spear. Jarred fish loose & POH. Rec 147.95' of 9-5/8" csg. RIH w/ 12-1/4" bit & CO to stub. POH.---RrlH w/ 8-1/2" bit. Fin RIH w/ 8-1/2" bit to 2800'. Circ hole clean. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2680'. POH. R IH w/ spear. Engaged fish & jarred. Could not move fish. Released spear. POH. RIH w/ mech cutter & cut 9-5/8" csg @ 2592'. POH. RIH w/ spear. Jarred on fish & moved csg up hole 9'. Spear stripped out--could not re-engage. POH & redressed spear & RIH. Jarred on fish & pulled fish free. POH. of 9-5/8" csg. RIH w/ spear. Jarred on fish 30 min. Fish moved up hole 8'. Spear stripped out--POH. Redressed & repaired spear. RIH w/ spear & engaged fish. June Report of Drilling Operations TBU Well D-5RD Page 3 06-16 10,250'TD 2,581'TOF 06-17 10,250'TD 2,400'PBTD 06-18 10,250'TD 2,513'PBTD 06-19 2,832'TD 06-20 3,684'TD 06-21 4,664'TD 06-22 5,060'TD 06-23 5,501'TD 06-24 5,831'TD 06-25 6,072 ' TD Jarred on fish ~ 2581'. Fish would not move. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2650'. POH. RIH w/ spear. Jarred on fish 2 hrs--no movement. POH. RIH w/ mech cutter & cut 9-5/8" csg ~ 2611'. POH. RIH w/ spear. Jarred on fish. On 9th jar, appeared that fish pulled free. POH--no rec. Redressed spear & RIH. Jarred on fish 5 hrs--no movement. Jarred on fish @ 2581'. Fish would not move. Released spear & POH. LD Tri-State tools & DC's. RIH w/ 12-1/4" bit to 2581'. CBU & POH. RIH w/ 8-1/2" bit to 2830'. CBU & POH. RIH w/ OEDP. Halliburton set 175 sx CI G cmt I~ (1% CiR-2 & 2% CaCI ) from 2676'-2400'. CIP ~ 2000 hr~__6-80. 2 LD DP from derrick. Tstd BOPE Cut & slipped drlg line Have open hole section from 2505'-2581' in which to KO wellbore. LD DP from derrick. Mixed mud & serviced rig. PU Monel DC's & HWDP. RIH. Tagged cmt @ 2435'. Drld cmt to 2465'. Tstd 13-3/8" csg to 1000 psig--OK. Drld cmt from 2465'-2513'. Tstd 13-3/8" shoe to 14.6 ppg MW equiv. POH to PU DD. Fin POH w/ 12-1/4" bit. RIH w/ DD to 2496'. RU Eastman gyro. Oriented tool face N55°E. RU Sperry-Sun steering tool. DD 12-1/4" hole from 2513'-2749'. POH. RIH w/ 12-1/4" bit. Reamed from 2513'-2749'. Drld to 2832'. Drld & surv 12-1/4" hole from 2832'-3267'. POH & LD 23 jts DP. MU locked BHA assy & RIH. Drld 3267'-3413'. Secured ~ig for 1 hr w~hile prod crew extinguished fire behind CB ~2 bldg. Resumed drlg & directionally drld hole to 3684'. Drld 12-1/4" hole from 3684'-3908'. POH. RIH w/ bit #4. Drld 12-1/4" hole from 3908'-4664'. POH. RIH w/ bit ~5. Drld 12-1/4" hole from 4664'-4922'. POH. RIH w/ bit #6. Reamed 4881'-4922'. Drld from 4922'-5060'. Drld 5060'-5114'. Repaired swivel. Drld 5114'-5501'. Drld from 5501'-5515'. POH. RIH w/ bit #7. Drld 5515'- 5831'. POH. PU DD & RIH to 13-3/8" csg shoe. RU Sperry- Sun steering tool. Fin RIH to 5831'. RU Sperry-Sun steering tool. DD 5831'- 5906'. POH. Tstd BOPE. RIH w/ bit #9. Reamed 5831'-5906'. Drld 5906'-6072'. June Report of Drilling Operations TBU Well D-5RD Page 4 06-26 6,471'TD 06-27 6,750'TD 06-28 7,021'TD 06-29 7,371'TD 06-30 7,585'TD Drld 6072'-6270'. POH. RIH w/ bit #10. Washed 30' to btm. Drld 6270'-6471'. Surv @ 6471'. POH. RIH w/ bit #11. Drld 6471'-6750'. Drld 6750'-6761'. POH. RIH w/ bit #12. Drld 6761'-7021'. POH. RIH w/ bit ~13. Drld 7021'-7371'. POH. RIH w/ bit ~14. Fin RIH w/ bit ~14. Drld 7371'-7547'. POH. RIH w/ bit ~15. Drld 7547'-7585'. ALASKA OIL AND GAS CONSERVATION COMMISSION June 6, 1980 JAY S. HAMMOND, GOVERNOR ,' 3001 PORCUPINE DRIVE-ANCHORAGE..ALASKA 99501 ADMINISTRATIVE APPROVAL NO. 80.34 Re: Application of Union Oil Company of California, operator of g Bay~o drill, complete and produce the v un~.t D-5RD~well as a part of the pressure main- tenance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on June 4, 1980 and stated that the drilling, completion and production of the Trading Bay Unit D-5RD well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. , 80. ¢ Yours very truly, Kugle~ Commissioner BY THE ORDER OF THE COMMISSION ~une 6, X980 ~r. ~L~ ~. Call.haler Dietri~t Drilling Superintendent ~n~on 0~1 ~~ny o~ ~al~orn~a P. O. Box 6247 ~ohoz~ge~ AI~$~ 99S02 Re: Trading Bay Unit D-SRD Union Oil Company of California ~t~ole ~,~ 2000*FSL~ i$00*FEL~ Soo. 6~ T8N~ RI~ Dear Itt. CaIlender Enclosed is the approved application for ~e~mit to drill the above referenced veil. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shell be sub- mitred for copying except experi~ntal logs, velocity suz~eys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for. the spawning or migration cE anadrc~ous fish. Operations in these areas are sub~ect to AS 16.50.870 and the regulations p~omulgated thereunder (Title Alaska Administrative Code). Prior to conuuencing operations you may be contacted by the Habitat CoordinatorOs office, Department of Fish and Game. Pollution of any waters of the State is prohibited bY AS 46, Chapt~ar 3, Arti'cle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to K~. Jim R. CaIlender Trading Bay Unit D-SRD -2- June 6, 1980 c~umencing operations you may be contacted b~. a representative of the Departsmnt o£ Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Depar~uent 0£ Labor is being notified o£ the issuance of this permit to dril 1. To aid us in scheduling Lteld ~ork, we would appreciate your noti£ying this office within 48 hours after ~he well i8 o~dded. ~ ~uld also like to ~ notifi~ os ~at a repre- sentative o~ the c~iseton ~y ~ present to wanness te.a~g o~ blo~ut pr~enter e~~ent ~fo~e s~a~e casing ~oe ~0 drill~. In the event of suspension or abandonment, please g~ve this o££~ce adequate advance not~fication so that we nay have a ~~~/truly yours, loyle H. Hamilton Chairman o£ .V~D~ Alaska 0~1 &~Bas ~nserv~"t~on Enclosure ce~ Department of Fish & Ga~e, Habitat Seet~on w/o encl. ~r2~nt of ~ro~ntal Conse~at~on w/o/anti. ~ar~nt of ~r~ Sure, ocr, ~r Law C~pl~a.nce D~v~st~ w/o ariel. Porto I0-- 401 , ~ I--I--71 STATE O.F ALASKA SUBMIT IN TRIPL (Other instructions reverse side) OIL AND GAS CONSERVATION COMMITTEE j ERMIf TO DRILL oR DEEPEN TYPE OF WORK RE DRILL TYPE OF WELL OIL ~{-~)( OAS WELL WELL DEEPEN 8lNG. LB [~ MULTIPLE['--] OTHER ZONE ZONE 2 NAME OF' OPERATOR Union Oil C,,o,m,,pany of California* 3 ADDRF_,..~ O~ OPERATOR P. O. Box 6247, Anchoraqe AK 99502 LOCATION OF WELL At surface 751'FSL, 1127'FWL, Sec. 6, T8N, R13W, SM, Leg A-2, Cond 9 At ploposed prod zone 2000'FSL, 1500'FEL, .Sec. 6, T8N, .R13W, .SM DISTANCE IN MILES AND DIRECTION FI~oM NEAREST TOWN OR POST OFFICE* Approximately 21 miles NW of Kenai, Ala,ska BOND INFORMATION TYPE Statew i de Surety, and/or No Un i ted Pac i f i c Insurance Co. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT (Also to nearest dr]g, unit, if any) B-55502 NO. OF ACRES IN LEASE " ~ 3085 1500'FEL 18 DISTANCE FROM PROPOSED LOCATION'* TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, FT 1450' PROPOSED D~TH lO,650'MD 10,063'TVD AP1 #50-733-20100-01 I, 50-133-201 O0 6 I..,F, ASE DI~IGNATION A2CD SERIAL NO, ADL- 18729 A-926 IF IN'D'IAN. AJ, J.,o~rEE OR TRI~E NAME 8 UNIT, FARM OR LEASE NAME Trading Bay Unit 9 WELL NO D-5RD 10 ~IELD AND POOL, OR WILDCAT McArthur River Field il SEC, T, R M (BOTTOM HOLE OBJECTIVE} Seq. 6, T8N, R13W, 68-28 ~,,,o,~t $100 ~ 000 17 NO ACRF~ ASSIGNED TO TH~S WELL 80 20 HOTARY OR CABLE TOOLS Rotary 21 ELEVATIONS (Show whether DF, RT. CH, etc } 99 APPROX DATE WORK WILL. START* KB 106' above MSL June !6; 1980 23 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI)E SE"rTING DEPTH q uant,ty of cement 17-1/4" ! 9.5/8" 43.5# N-go 1750' AoProx 2150 sx in 2 stafles 12-1/4" 9-5/8" 47~. N-go 83QQ ' ....... _ 17-!/4" 9-5/8" a7~ p-1 lq lO,,6~q' .... SEE ATTACHED FOR DESCRIPTION OF PROPOSED PROGRAM. RECEIVED i' 1980 Alaska 0,1 & (, ;, ,, Ancnu~ ag~ *Marathon Oil Company - Sub-Operator IN ABOVE SPACE D~SCRIBE I~ROPOSE*D Pi:M)GRA.M If ~II ~ to dee~n 'give ~ on present ~u~ive zo~ ~d p~ ~W preclusive ~ne J[;_~l ~ ~ arii~ or ~n ~[O~ily. give ~ent ~ on sgbsu~a~ ~t~ ~d mea&~d ~d ~ue yeS,cai dep~ Give bio--ut preventer ~ram 24 I hereby certify that the Foregoing is True ami Correct SIGNED , , , DA~. ~ CONDITIONS OF APPPA)VAI,, IF AN"/': (This space for State ofhce use) SAMPLES AND CORE CHIPS R.EQ~ [] YES ~NO DIREC~TIONAL SURVEY RI~I3~ ~. Y~ D NO IM.U.D , o Y~ I~N° OTHXR R~UIREMENTS A.PI. NIIMIIRICAL CODE - '75J--fl..olo o-oi - .,. D~St. Prig. Supt. approved b~/Hoy~milton *~J~ons ~ R~Ve~ Side --~ ~ ~' ] .... ~ .... title: onal~an ~~~. BY OROEn OF COUMtSS ON .6/4/So 06/06/80 lO00 2ooo 4000 SURFACE TVD = 0 TMD =0 DEP '-0 8o 12· 4000 TM::) KOP TVD: 2505 TMD: 2505 DEP: -3,0 ANG: I° 00' BUILD ANGLE 2°/100' EOC TVD: 3570 TMD: 3601 I DEP: 196 12 MARATHON OIL COMPANY_~ DOLLY VARDEN PLATFORM WELLNO D-SRD LEG A-2 CONDUCTOR 9 $CAI. E I' lO00' JANUARY 16, 1980 BY BESSE , EPPS & POTTS FOR THIBODEAUX DIRECTIONAL DRILLING I Sec. 6,T8 N,R13W I i 27' TARGET TVD: 9:560 TMD: 9886 DEP :2643 T !XD~ :9 I !'- !_~9:9 I I I I 0 I000 20OO TD TVD=10063 TND=10650 DEP= 2943 1500' 3000 5OOO 5000 TMD 6000 7OO0 300 .- £OOCj TMD o iooo AVERAGE ANGLE 23005' 7000 TMD 806,,0 ThUD 9O00 TARGET TVD -- 9:$60 TMD: 9886 tCOOOT~ '~ DEP : 264.~ TD T','D= 100h3 T' ;D= 1 ;)050 ~"'EF= 2c4'5 1 2030 --t 35CD TBU D-5RD Present Completion 33" conductor ~ 407' ,] 13-3/8" 61// J-55 BTC casing @ 2505' _ 9-5/8" 40#, 43.5#, 47# N-80 BTC casing one centralizer per joint on top five joints) Collapsed casing @ 6000' '-'L Cameron 4-1/2" ASL x ASL tubing hanger 158 jts of 4-1/2" 12.6# N-80 ASL tubing 5043' tail of tubing 5783' cement retainer [ DFS 2/26/80 - MARATHON OIL OO.- -- DOLLY VARD£ PLATFORM FIo,ulir,~ Drillint Mipple. (~Vd~il) · · 0 0 ~ · . - . ..... I! ~ ~GIW Swin~-Bolt Olamp ! ~i cre BOP ~ack For Drilling' From $ur a~e O~s~n9 /o ~.u.-- -. · - - - ..... . ........ ,' f ~,I , ~R . il ' Collar IS ~/S' Surface . o ~ KU -1 D-16 D-22 ~ . ¢o , 0 2000' JL. ......... I .... FEET MARATHON 0IL COMPANY ~NCHO~AGE DIVISION TRADING BAY UNIT McARTHUR RIVER FIELD T?P HEMLOCK ~ ,l~'l- I CONTOUR ~NTERVAL : ICO FT · G-28 + G-?? G'32 D-28 -II G-26 0 ~ D~-8rd · 9'5 ~,~ D-14 'O-15, D-9 7 -12td~ G-12 ar D'-2rd D-4 -25 rd D-12 .~,¢D-14rd KU '1 D-22 !! JKU.- D-23 G-16 D-2zJ. A IO' FEET MARATHON OIL COMPANY ANCHORAGE DIVISION TRADING BAY UNIT MoARTHUR RIVER FIELD , .r HEMLOCK BENCh,- I CONTCLJR iNTERVAL ~ TBU WELL D-5RD AFE 4678 .Objective: TBU Well D-5 is an abandoned water injection well. The objective of this redrill is to drill a Hemlock producer to a location with the Hemlock top 2000'FSL, 1500'FEL, Sec. 6, T8N, R13W, SM. Proposed Proceudres: 1. Displace FIW currently in hole w/ 9.5 ppg mud. . Install BP¥, NU BOPE, and test to 5000 psi. Test BOPE weekly thereafter. 3. LD tbg. Recover 9-5/8" casing to 2650'. 4. Lay KO plug from 2650'-2475' (approx 125 sx CIG w/ 2% CaCI2). 5. Drill out to 2515' & conduct formation leak-off test. . RIH w/ directional drlg assy, kick off and drill a 12-1/4" directional hole to TD ~ approx lO,650'MD, 10,063'TVD. 7. Cond hole & run open hole logs. . Run 9-5/8" csg & cmt in 2 stages: 1st Stage: Cmt w/ approx 1000 sx CIG w/ 1/2 gal/sk Econol it. & 0.3% HR-6L (13.4 ppg). 2nd Stage: Cmt w/ approx 750 sx CIG w/ 1/2 gal/sk Econolite & 0.3% HR-6L (13.4 ppg). 9. Test csg to 2500 psi. 10. Run gyro & CBL. Sqzd cmt as necessary for good zone isolation. 11. 12. 13. Set perm pkr above Hemlock Bench 1. Run tbg string w/ GL eqpmt. Perf thru tbg & compl as Hemlock producer. TLS .' I 06-03-80 I~-C4 CR-13 /?e CASING SI DE DESIGN BY_ ~ HYD. GR. II ?:~/£:. M.S.P. IKTERVAL Bottom Top I?So 0 Wt. DESCPiPTiOi{ JEIGH£ T2JSiON ~':rr,r,',,~._,,_.,~,.~ W/ BF _ -top of Grade ~nread U/O B? scctzon TE'.CSiO:~ lbs lbs !OSO lbs TDF COLLAPSE COLLt=°SE PRESS. ~ PZSIST. bottom tenslon DS1 CDF BU?,~ ? I i.T2 R: LAL BDF PRESSURE ! ~'~! -u~4 Yi2LD psi psi PP-~CE PER --. 3075~O ~1~,3o0 /aSA ~I~ ~/~ao , (qz. Ts) '-/? $'o /,0..7, o~z. ,'-t-7 , ) Formulae- Collapse resxstance in tensicn = X (Collapse pressure ratir~) ~urst Pressure = }~P + Depth ( }{yd. Gr. II --.~) ~ (Bouy~ncy Factor) = ~.oo (o.o~.3 x :~ua wr I) Ca!culat~ons: ~//~3o o : O, "t 'Z. / Oo..g'ooo ,x-- --D,I CHECK LIST FOR ~ WELL PERMITS Item A~prove Date (~) Fee ¢/~... &- ~-~ (3) ~lmin. ~~ C-~o~o 1. Is the permit fee attached ......................................... 2. Is w~ll to be located in a defined pool ..... 3. Is a registered survey plat attached ........ 4. Is well located proper distance frcm pr e 5. Is w~ll located proper distance frcm other ~lls e e · · e e e e e e e e ~ · e I e ® · e 6. Is sufficient undedicated acreage available in this pool 7. IS ~11 to be deviated .............................................. 8. Is operator the only affected party ............................. 10. Does operator have a bond in force .................................. 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................. 13. Is conductor string provided ........................................ (4) casg. ~ Lease & Well No. T~ ~ Remarks " ~,,~ ,~ ~f/,'~ 14. Is enough cement used to circulate on conductor and surface ......... ~ 15. Will c~nent tie in surface and intermediate or production strings ... _~ 16. Will cement cover all known productive horizons ..................... ~ _(5) BOPE ~~ 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. 19. Does BOPE have sufficient pressure rating - Test to 300 O psig .. Appr.oval R~c~ded: Geology: EngingeriDg: rev: 03/05/80 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. 11 000000 7777~77777 11 000000 7777777777 1111 O0 O0 77 1111 O0 O0 77 11 O0 0000 77 11 O0 0000 77 11 O0 O0 O0 77 11 O0 O0 O0 77 11 0000 O0 77 11 0000 O0 77 11 O0 O0 77 11 O0 O0 77 111111 000000 77 111111 000000 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 17777177'17 7777777777 77 77 17 77 77 77 77 77 17 77 77 77 606006 000000 7777777777 666666 000000 7777777777 66 O0 O0 77 66 O0 O0 77 66 00 0000 77 66 00 0000 77 6~6~6~66 00 O0 00 77 66666666 O0 O0 00 77 66 Ob 0000 00 77 66 66 0000 00 77 66 bb O0 O0 77 66 66 O0 O0 77 bbbbbb 000000 77 666666 000000 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 oo 0000 O0 O0 O0 O0 O0 000000 000000 333333 333333 33 33 33 33 33 33 33 33 33 33 33 33 33 33 333333 333333 M M h ~ ~ K ~ EELEE N N AAA 11I MM MM 6 K K K K E h N A A 1 M M M L ~ K ~ K E NN N ~ A i M M b KKK ..... KKK EEEE N N N A A 1 M M h K K K ~ E h NN AAAAA 1 M M L K K K K E N N A A i M M LLLLL K K K K EEEEE N N A A 111 *START* USER PCAL [10707,60703] dUB SHIP SEQ. 4541 DAlE 13-8EP-80 07:04:37 MONITOR $w$ KLIOE37 APR-80. ,S~ART* ,START* uSER PCAL [10707,60703] ,)OB SHIP SEO. 4541 DATk 13-SEP-80 07:04:37 MUN/TUK 6~6 ~blO~3/ hP~-80. *6~ART* bSSSSSS$ HH HH SSSSSSSS H~ MM SS HH MH SS HH HH SS HH HH SS HH HH SSSSS$ MHHHHHHHHM SSSSSS HHHMHHHHHH SS HM HH SS HH MH SS HH HH SS HH MM SSSSSSSS HH HH SSSSSSSS HH HH II I1 II II Ii II I1 II ]1 ii ii I1 1I i1 II II 1I II Ii ii II II PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTr OUOOUU TTTT'rTT~rT OOOOO0 TT OO OO TT O0 OO TT OO UU TT OO OO TT OO OO TT O0 O0 TT OO OO TT O0 O0 TT O0 O0 TT O0 O0 TT OOOOOO TT 000000 *START* USER PCAh [10707,607031 JOB SHIP SEO. 4541 MUNITOR ,WS KLlOh37 APR-80. ,START* FIb&: DSkH:SHIP.rO<057>[10707.60703] CRkATED: 13-SEP-80 PRINTED: 13-SEP-80 07:04:5] QUhUE ,wI1CHES: /FibE:~URT /COPIES:I /SPACING:! /LIMIT:J25 /FORMS:NOrMAL OATh 1]-SEP-80 0b:42:02 07:04:~7 6HIPPING 1N$~UCTiUN6 l$$UkD 13-$~P-80 03:30 SHIP TO : CCC, ENTURA, CAL1F., THANKS. BY MLK PCCC VV VV VV VV VV VV V¥ VV VV VV VV VV VV VV VV VV VV EEEEEEEEEE RRRRRRRR ~V EE RR RR VV EE RR RR VV 5E RR RR VV EE RR RR VV EEEEEEEE RRRRRRR~ V¥ EEEEEEEE RRRRRRRR V¥ EE RR RR ¥¥ EE RR RR EE RR RR EE RR RR EEEEEE~EEE RR RR II1II1 IIilli II Ii ii II i1 II II II 1I II Illiii IIIIII YY Y~ ¥¥ YY ~Y YY YY YY YY YY ¥¥ YY YY YY 000000 000000 222222 000000 000000 222222 00 OO 00 O0 22 22 00 O0 O0 O0 22 22 O0 0000 O0 0000 22 O0 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 O0 O0 O0 U0 00 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 O00000 000000 2222222222 000000 000000 2222222222 ,STAhT* USER PCAb [10707.00703] JOB SHIP 8EO. MONITOR SwS KLlOE37 APR-80. *START* flbE: DSKH:¥ERIfY.002<057>[10707.60703] CREATED: PRINTED: 13-SEP-80 07:05:01 QUEUE SWITCHES: /FILE:TORT /CUPIES:I /SPACING:I /LIMIT:125 /FORMS:NORMAL 4541 DATE 13-$EP-80 13-SEP-~0 07:01:20 07:04:37 bls V~$1UN lb.~Oi 79/03/2b SCHbUMBERGER COMPUTING CENTER 10707,60703 REEL HEADER LENGTH: 132 B~TE6 REEL NAME: P.C.A.L. SERVICE NAME: ED1T REEL CONTINUATION NUMBER: 01 PREVIUUS ~EEL NAME: CU~MENTS: bls FURMAI CUSTOMER TAPE DATE: 80/ 9/12 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 60703 DATE: 80/ 9/12 SER¥1CE NAME: EDIT TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: TAPE COSMENTS CASING SIZE=Ii.37 1N. @ 47/LB/F rO 2505 FT. " " = 9.62 IN. ~ 47/LB/P TU 10620 FT. BIT S1ZE=17 iN. 2505 ~T & 12.25 1N 10620 FT. TYPE fLUID iN HULE=SEA wATER/MAX TEMP 162 F flbE HEADER LENGIH: 62 B*TE$ FiLE NAME: ~DIT .001 MAXIMUM PHYSICAL RECORD LENGTH: 1024 BYTES [.'REVIUU$ FiLE NAME: FILE COMMENTS NO rigiD PR1NT$ TO V£RI~'~ RHUB UR CURR DAIA, CUMPANY : MARATHUN OiL CO. Wkbb : TBU O-b RD. ~IELD : MCARTHUR RIVER RANGE : 13W TUWNSH1F : 8N SECTION : b CUUNTi : KENA! DEN$IT~ : 800. DATA ~(JRMAT SPECIfICATiON bENGTH: 490 BYTES kNTR~ BLOCKS: 0 SiZE REP CODE ENTRY 1 ~6 0 DATUM SPkCi~ICATiON B6UCKS: NAME TOOL ONlr APl APl AP1 AP1 FILE SIZE SAM RgP PROCESS INDICATORS 1 DEPT 2 CALl CNL 3 DRHO fDC ~ NPMi CNL 5 R~OB CNL b NRAT CNL ? NCNb CNL B ~CNL CNL 9 POTA 10 THOR 11 URAN 12 6GR ~'1 0 0 0 0 0 4 IN 42 28 t 0 0 4 G/C3 42 44 0 0 0 4 PU 42 68 ] 0 0 4 G/C3 42 35 1 0 0 4 C/C 42 42 1 0 0 4 CPS 42 ]4 92 0 0 4 CPS 42 34 9] 0 0 4 PPM 0 0 0 0 0 4 PPM 0 0 0 0 0 4 PPM 0 0 0 0 0 4 GAPi 0 31 0 0 0 4 1 68 1 68 1 6U 1 68 1 68 I b8 1 08 1 68 I b8 1 68 1 68 1 b8 USER DEFINED OUTPUT ARRAY OUTPOT CALl AT 2 OUIPUT DRHO AT 3 OUTPUT NPHI AT 4 OUTPUT RHOB AT 5 OUTPUT NRAT AT 6 OUTPUT NCNb AT 7 OUTPUT FCNL AT 8 OUTPUT PO1A A1 9 OUTPUT THOR AT ~0 OUTPUT URAN AT 11 OUTPUT SGR AT 12 DEPTH 10530.000 10500.000 104O0.000 10300.000 10200.000 10100o000 10000.000 9900.000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 NNEMONIC CALk NRAT CALl NRAT CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT ThOR CALl NRAT CALl NRAT THOR CALI NRAT THUH CALl NRAT TMU~ CALl NMAT THUR VA 1 LUE 2.250 3.396 9.492 9.172 3.531 9.492 8.852 2.611 2.652 8.852 2.730 1.579 8.906 2.017 1.529 8.883 2.809 3.477 8.836 1.984 1.562 8.813 3.000 1.335 8.813 3.764 3.281 8.930 3.582 4.723 8.813 2.322 1.253 9.000 3.447 4.543 8.969 5.340 0.191 8.977 3.385 4.094 MNEMUNIC DRHO NCNb URAN NCNb URAN DRHO NCNb ORAN DRHU NCNb URAN DRHO NCNb Ui~AN DRHO NCNb URAN DRHU NCNb URAN DBftu NCNb URAN DRHO NCNb URAh DRHU NCNb U~AN DRHO NCNb URAN DRHU NCNb URAN DRHO NCNb Ut<AN DRitO NCNb URAN VALUE -0.574 1338.000 0.658 -0.652 1355.000 0.658 -0.819 1512.000 0.784 -0.628 1712.000 1.449 -0.527 1740.000 1.514 -0.574 1647.000 0.690 -0.026 2256.000 0.708 -0.780 1308.000 1.914 -0.734 1274.000 1.795 -0.608 1275.000 ].262 -0.580 1989.000 I .487 -0.642 1334.000 1.501 -0.993 1013.000 1.974 -0.626 1354.000 2.021 MNEMONIC NPH1 fCNL NPHI fCNL SGR NPHI ECNL ~GR NPHI fCNL NPHI fCNL 5GR NPHI fCNL NPHI FCNL SGR NPHi fCNb SGR NPH1 fCNL NPHI ~CNb 5GR NPHI ~CNG 6GR NPHI ~CNL SGR NPHI fCNL NPM1 fCNL VAbUk 36.328 379.500 61.125 38.770 366.000 01.125 22.021 589.0O0 27.344 24.170 573.000 30.813 22.119 630.000 30.031 25.635 570.000 28.400 12.891 1108.000 22.797 40.039 362.500 33.500 43.018 308.500 41.313 39.740 335.000 58.625 17.578 783.000 28.906 37.256 379.000 46.909 71.717 192.875 18.891 36.133 398.500 49.219 MNEMONIC RHOD POTA RHOB POTA RHOB PUTA POTA RHUB POTA RHUB POTA RHOB POTA RHOO POTA RHOB POTA POTA RHUB PUTA RHOB POTA RHOB POTA RHOB POTA VALUE 2.039 0.010 I .938 0.010 1.780 0.006 2.139 0.008 2.068 0.007 2.156 0.007 2.223 O.OOb 1.903 O.OOb 1.812 0.007 1.781 0.008 2.334 0.006 1.960 0.009 I .336 0.002 1.945 0.010 DEPTH 9200.000 9100.000 9000.000 8900.000 8800.000 8700.000 8600.000 85OO.OOO 8400.000 8300.000 8200.000 8100.000 8000.000 7900.000 MNEMONIC CALl NRAT CALl NRAT THOR CALl NRAT CALl NRAT THOR CALl NRAT THOM CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT CALl NRAT T H O R CALk NRAT THOR CALl NPAT ThOR CALl NRAT CALl NRAT THOR VAL UE .820 .711 .176 .961 .539 .334 .750 .11~ .410 .930 .850 .008 .828 .031 .773 .914 .137 .943 8.789 ].041 2.820 8.953 2.890 1.822 8.953 5.254 2.117 8.820 3.455 3.715 8.820 2.756 0.329 8.922 3.990 4.180 9.000 4.137 3.725 8.953 2.674 1.258 MNEMONIC DRHU NCNb ORAN DRBU NCNb ORAN D~HO NCNb ORAN DRHO NCNL ORAN DRHU NCNb ORAN DRHO NCNb ORAN DRHU NCNb UBAN DRHO NCNb ORAN DRHO NCNb ORAN DBHU NCNb ORAN DBHO NCNb ORAN D~HU NCNb ORAN DRHO NCNb ORAN DRhU NCNb ORAN VAb -0 1343 1 -0 1267 1 -0 1417 2 -0 1245 2 -0 1013 0 -0 1098 2 -0 1589 0 -0 1660 0 -0 1074 -0 1349 2 -0 1575 1 -0 1114 2 -0 1123 2 -0 1886 1 UE .760 .000 .716 .689 .000 .607 .681 .000 .607 .666 .000 .357 .925 .500 .766 .798 .000 .713 .607 .000 .409 .625 .000 .817 .744 .000 .281 .663 .000 .137 .950 .000 .233 .670 ,000 .992 .625 .000 .027 .533 .000 .138 MNkMONIC NPHI fCNb bGR NPHI f'CNL NPH1 fCNb 8GR NPH1 fCNL SGR NPHI FCN6 NPH1 FCNL SGR IIPHl FCNL ~GR NPHi I~'CNL, SGR NPHI I~CNL NPHI fCNL SGR NPHI I~CNL NPHI FCNL SGR NPHi fCNL NPHi VA6 42 333 45 38 354 31 49 ]17 5O 4~ 3O3 47 185 2~ 49 258 51 29 462 30 27 53O 28 7O 202 35 37 ]62 42 24 612 21 47 256 53 49 262 5O 23 ~82 27 UE .041 .750 .063 .965 .500 .219 .414 .500 .000 .029 .250 .594 .lb2 .750 .188 .854 .750 .250 .883 .75O .031 .246 .000 .484 .5OO .119 .402 .250 .219 .658 .5OO .906 .lb8 .500 .003 .854 .750 .lbo .145 .000 .281 MNEMONIC RHOB PuTA RHUB PUTA RHU~ POTA RHOB POTA RHO~ POTA RHOB POmA RHOB PO'£A RHUB POTA RHUB PUTA RHOB POTA ~HOB POTA RHOB POTA RHU~ POTA RHOB POTA VALUE 1.824 0.008 1.81b 0.008 1.81b O.OO8 1.801 0.008 ~.499 O.OOb 1.676 0.009 2.049 0.009 2.090 0.008 1.bO5 0.00'7 1.977 O.OOb 2.117 0.005 1.737 O.OOb 1.821 0.008 2.232 0.008 DEPTH 7800.000 7700.000 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 7000.000 69OO.O00 0800.000 6700.O00 0600.000 0500.000 MNEMONIC CALl NRAT CALl NRAT THOR CALl NRAT THUR CALl NRAT THOR CALl NRAT THDR CALl NRAT CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CAb1 NRAT THUR CAI, I NRAT THOR CALl NRAT THOR CALl NRAT THUH CALl NRAT THUH VAL .9ol .193 .o85 .969 .230 .764 .830 .328 .54] .953 .258 .027 .930 .670 .847 .9]O .12] .340 .922 .453 .870 .953 .152 .555 8.9]0 5.250 4.]52 8.961 2.539 1.925 8.969 4.844 3.285 8.961 2.768 1.036 9.055 4.809 3.085 ~ .930 4.211 4.273 MN EMUN iC DRHu NCNb URAN DRHU NCNb URAN DRHU NCNb URAN DRHO NCNb URAN DRHO NCNb URAN DRHO NCNb URAN DRHO NCNb URAN DRHO NCNb URAN DRHU NCNb ORAN DRHO NCNb URAN DRHU NCNb URAN DRHO NCNb URAN DRHU NCNb DRHO NCNb URAN VALUE -0.585 2210.000 0.648 -0.677 1095.000 1.785 -0.645 1169.000 1.708 -0.718 1007.000 2.273 -O.485 1902.000 0.906 -0.602 1790.000 1.497 -0.595 1423.000 1.645 -0.688 1194.000 2.697 -0.999 i0]1.000 1.345 -U.571 2037.000 0.796 -0.800 1088.000 2.127 -0.493 1794.000 1.429 -0.688 1095.000 2.383 -0.587 1204.000 1.612 MN kMONIC iv PM 1 fCNL ~GR NPHI ~CNL NPH1 f'CNL 8GR NPH1 fCN6 bGR NPH1 fCNL 6GR NPH1 FCNL 6GR NPH1 FCNL SGR NPHI fCNL NPHI FCNb SGR NPHI fCNb SGR NPH 1 fCNh ~GR NPHI FCNL ~GR NPHI fCNb NPHI ~CNL VAbU~ 15.723 984.500 25.612 51.611 271.750 34.500 53.309 251.000 47.688 52.100 227.375 48.959 23.096 682.500 24.188 31.348 564.500 35.219 37.354 414.750 27.781 50.146 282.250 36.003 70.117 201.375 38.531 20.850 771.000 24.438 02.095 220.875 37.438 24.854 598.000 29.984 b2.109 227.375 45.000 51.172 280.250 52.000 MNEMUNIC HHOB PUTA RHUB PUTA RHUB POTA RHOB POTA RHOB POTA RHUO PUTA RHUB POTA RHOB POTA RHUB POTA RHUB POTA PUTA RHUI~ POTA RHUI5 POTA RHOB POTA VALUE 2.357 0.006 1.652 0.004 1.605 0.009 1.491 0.010 2.557 0.005 2.219 0.008 2.082 0.006 1.711 0.003 1.353 0.006 2.320 0.006 1.538 0.005 2.313 0.007 1.679 0.007 1.882 0.011 DI~PTH 6400.000 6300.000 6200.000 6100.000 6000.000 5900.000 5800.000 5700.000 5600.000 5500.000 5400.000 5300.000 5200.000 5100.000 MNEMON CALl NRAT THOR CALl NRAT THOR CALl NRAT CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT THUH CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAI THOR CALl NRAT CALl NRAT THOR IC VAL UE .984 .977 .947 .023 .793 .820 .977 .783 .501 .961 .438 .172 .953 .281 .003 .977 .707 .453 .977 .625 .516 .930 .832 .176 .922 .551 .449 .922 .916 .bi9 .961 .230 .609 .945 .371 .045 .914 .043 .943 .90o .527 .934 MNEMUN DRMO NCNb URAN NCNb URAN DRHO NCNb ORAN DRHO NCNb URAN DRHU NCNb URAN DRHO NCNb URAN DRHO NCNb UIRAN DRHO NCNb ORAN DRHO NCNb ORAN DRHO NCNb URAN DRHO NCNb URAN oRHU NCNL ORAN DRHO NCNb U~AN DRHO NCNb URAN IC VALUE -0.729 1139.000 1.288 -0.696 1139.000 1.273 -0.774 1107.000 1.276 -0.722 1033.000 1.515 -0.717 1150.000 1.311 -0.727 982.500 2.283 -0.534 1440.000 1.294 -0.738 975.000 1.600 -0.690 1095.000 2.008 -0.b48 1292.000 1.442 -0.525 1219.000 2.139 -0.529 1136.000 2.625 -0.585 1160.000 2.010 -0.8]7 959.000 0.896 MNbMONIC NPMI FCNL 6GR NPHi fCNL SGR NPHI ~CNL SGR NPHI FCNL SGR NPHI ~CNb 5GR NPHi FCNL 6GR NPHI ~CNL SGR NPMI fCNb 6GR NPHI FCNL 6GR NPH1 ~CNb SGR NPHi fCNb SGR NPHI fCNL SGR NPH1 fCNL NPHI fCNL SGR VAbU 46. 276. 30. 43. 294. 28. 43. 278. 25. 55. 237. 34. 34. 329. 23. bO. 198. 45. 40. 362. 36. 02. 198. 36. 57. 238. 45. 45. 317. 43. 51. 292. 50. 54. 268. 54. 48. 286. 54. 75. 162. 19. 924 150 172 555 500 281 408 750 5lb 322 J75 815 229 750 531 303 000 219 479 000 938 549 125 688 422 125 15b 801 25O 900 514 750 003 102 000 625 145 250 000 195 250 594 MNEMONIC RHOB POTA RHUB POTA RHUB PUTA RHO~ POTA RHOB POTA RHUB POTA RHOB POTA RHUH POTA RHOB POTA RHOB POTA RHOB POTA RHUB POTA RHOB POTA RHOB POTA VALUE 1.446 0.007 1.511 O.OOb 1.458 0.004 1.527 0.008 1.636 0.004 1.538 0.007 2.113 0.009 1.55b O.OOb 1.790 0.008 2.020 0.010 2.000 0.009 I .900 O.O09 1.898 0.012 1.lb2 0.002 DEPT~ 5000.000 4900.000 4800.000 4700.000 4600.000 4500.000 4400.000 4300.000 4200.000 4100.000 4000.000 3900.000 3800.000 3700.000 MNLN£JN1C CALl NRAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT CALl NRAT THOR CALl NRAT THOR CA6i NRAT TH(JR CALl NRAT THtJH CAbI NRAT TH(]R CALI NHAT 'tHOR CA6i NRAT TH(JR CAbi NRAT THOR CALl NRAT THOH CALl NRAT VA LU . . . . · . . · . . . 945 328 043 898 539 34zi 914 828 809 930 b91 383 883 246 468 891 422 733 883 703 668 867 359 592 898 879 950 867 428 053 844 910 479 820 844 O45 891 560 429 844 469 090 MNEMONIC DRNU NCNL ORAN DRHO NCNb bRAN DRHO NCNL ORAN DRHU NCNb ORAN DRHU NCNL URAN DRHU NCNL URAN DRHO NCNb URAN DRHO NCNb ORAN NCNL ORAN NCNb URAN DRHO NCNL URAN DHhO NCNb bRAN DHHU NCNL UHAN DRhO NCNb [)RAN vALU -0. 1003. 1. -0. 972. 1. -0. 1178. 1. -0. 983. 2. -0. 926. 1. -0. 1521. 1. -0. 1358. 0. -0. 1133. 1. -0. 104b. 1. -0. 1445. 1. -0. 1150· 1. -0. 1448. 1. -0. 1081. 2. -0. 1043. 1. 613 000 410 785 50O 060 000 471 648 500 617 837 000 001 623 000 466 597 000 910 626 000 807 672 000 357 648 000 198 545 000 ]32 484 000 094 579 000 133 583 000 542 NNLNUNIC NPHI fCN6 SG~ NPHI YCNL SGR NPHi FCNL SGR NPHI FCNL 6GR NPHi fCNL SGR NPHi fCNL SGR NPH1 FCNL NPHI ~CNL SGR NPH I I' CHI., SGR NPH1 FCNL bGR NPHI ~CNL SGR NPHI ~CNb SGR NPH1 I~CNh 6Ol~ NPHi ~CN6 SGR VALU 53. 221. 35. 75. 178· 12. 44. 296. 25. 59. 221. 45. 70. 169. 18. 36. 426. 25. 41. 362. 32. 53. 250. 36. b3. 197. 32. 36. 410· 35. 45. 289. 37. 44. 348. 28. 57. 231. 36. 55. 228. 34. 320 250 281 439 125 b33 189 250 250 9bl 875 906 068 000 813 816 250 875 943 250 813 90(0 750 909 379 125 344 914 75O 219 703 5OO 000 482 750 203 715 750 375 95'1 500 813 MNEMONIC RHUB PUTA RHOB POTA ~HOB POTA POTA POTA RHUB POTA RHOB POTA RHOB POTA RHO0 POTA ~HUB POTA RHUB POTA RHOB POTA RHUB POTA POTA VAbUL 1.725 0.007 1.4U/ 0.001 1.763 0.005 l.b5b 0.009 I .258 0.003 2.035 0.006 2.000 0.009 1.807 0.006 1.7bb 0.008 2.104 0.009 2.090 0.009 2.410 0.007 1.814 0.00b 1.739 O.OOb DEPTH 3bO0.OO0 3500.000 3400.000 3300.000 3200.000 3100.000 3000.000 2900.000 2800.000 2700.000 2600.000 2500.000 2400.000 2368.000 MNEMONIC CALl NEAT THOR CALl NRAT THOR CALl NRAT THOR CALl NRAT CALl NRAT THOR CALl NRAT CA6i NRAT THOR CALl NRAT THOR CALl NRAT CALl NRAT THOR CALl NRAT TH[JR CALl NRAT THOR CALl NRAT CALl NRAT TfiUR VAL 8 UE .813 4.953 2.787 8.828 4.055 3.260 8.8O5 5.082 2.520 8.813 4.031 3.852 8.773 4.887 2.758 8.83u 4.582 2.055 8.805 4.988 2.379 8.805 4.406 2.930 8.789 5.863 1.406 8.813 5.277 2.438 8.805 5.664 2.035 8.828 5.242 1.358 8.836 5.113 0.51q 8.773 5.199 1.020 MNi~MUN lC NCNb URAN DRHO NCNb ORAN DRHO NCNb UKAN DRHO NCNb ORAN DRHO NCNb ORAN DRHO NCNb ORAN DRHO NCNb URAN DRHU NCNb URAN DRHO NCNb ORAN DBHO NCNb ORAN DRHO NCNb URAN DRHO NCNb URAN DRHO NCNb URAN DRHO NCNb URAN VALUE -0.748 994.000 1.182 -0.581 1215.000 1.085 -0.566 1039.000 1.513 -O.bO0 1244.000 0.662 -0.719 993.500 1.976 -0.775 1050.000 1.333 -0.800 953.500 1.498 -0.840 959.500 1.331 -0.777 933.500 0.605 -0.757 975.000 2.092 -0.928 930.500 1.271 -0.652 1029.000 1.255 -0.612 1016.500 1.031 -0.893 1043.000 1.111 MNEMONIC NPHI fCNb SGR NPH1 fCNb bGR NPHi FCNb 6GR NPHI FCNb SGR NPHI ~CNL bGR NPHI fCNb 6GR NPHI fCNL SGR 5GR NPHI fCNL NPH1 fCNb NPHI fCNL NPHI ~CNL 6OR fCNb NP~i ~CNL bGR VALUE b~.697 188.250 34.813 48.340 288.000 34.9~9 67.090 182.375 33.4~9 47.900 295.000 35.281 63.525 181.8;5 36.750 58.008 203.500 31.422 65.381 176.250 32.594 54.785 229.500 31.547 81.299 155.625 14.033 70.054 181.750 34.406 77.086 157.875 23.188 69.971 190.875 23.909 67.076 193.250 10.072 69.238 192.000 20.078 MNEMONIC RHO~ POTA RHU~ POTA RHOB POTA RHOB POTA RHUB POTA RHOB POTA POTA RHOB POTA RHOB POTA RHOB POTA ~HUB POTA RHCJB POTA POTA RHUB PUTA VALUE 1.514 0.008 1.811 0.008 1.981 0.005 2.053 0.009 1.562 0.006 1.450 0.007 1.307 O.OOb 1.206 0.005 1.186 0.003 1.30~ 0.005 0.989 0.003 2.086 0.005 1.810 0.00~ 2.025 0.004 SUMMAIq~ OI~ DAI.'A RImCDED$ NUMBER Of RECORDS: 778 LENGTH OF RECORDS: 1014 BYTES LENGTH Of LAST RECURD: 390 BYTES fILE TRAILER LENGTH: 62 ~¥TE$ fILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT fILE NAME: gOF TAPE IRAILkR LENGTH: 112 B~TES TAPE NAME: 60703 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: NEXT TAPE NAME: COMMENTS: 1024 BYTES DATE: 80/ 9/12 11 000000 7777777777 11 000000 7777777777 1111 O0 O0 '17 1111 O0 O0 77 11 O0 0000 77 11 O0 0000 77 11 O0 O0 O0 77 11 O0 O0 O0 77 11 0000 O0 77 11 0000 O0 77 11 00 O0 77 11 O0 O0 77 1i1111 000000 77 llllll 000000 77 000000 000000 O0 OO O0 O0 O0 0000 O0 0000 O0 OO O0 O0 00 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 7'/ 77 77 77 77 77 77 bb6bbb 000000 7177777777 6bbb6b 000000 7777777777 66 O0 O0 77 ~6 O0 O0 77 6~ O0 0000 77 bb 00 0000 77 66666666 O0 O0 O0 77 66066606 O0 O0 00 77 66 66 0000 O0 77 66 66 0000 O0 77 06 66 O0 O0 77 66 66 O0 O0 77 666666 000000 17 000000 00000U 00 00 O0 O0 O0 0000 00 0000 O0 O0 O0 00 00 O0 0000 O0 0000 00 00 O0 O0 O0 000000 000000 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 AAA A A A A A A AAAAA A A A A *START* UfEP PCAb [10707,O0702J dOB SHIP 8kO. 4335 DAI'~ 24-5EP-80 07:25:24 MONITOR SwS KLIOE40 SEP-80. *STAir* *START* USER PCAb [10707,b0702] dOB SHIP SE~. 4335 DATk 24-8EP-80 07:25:24 MONITOR 8hS KL10E40 SEP-80. *START* HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH S~ HH HH SS HH HH S~ HH HH SS HH HH SSS$SSSS HH HH SSSSSSSS HB HH I1 1I ii 11 1I Il II ii II I1 i1 1I ii 1I i1 ii II 11 1I ii 11 PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTI UUOOf}O ~TTTTTTrTT OOOOU~) TT UO OO TT UU OO I'T 00 UO TT O0 O0 TT O0 OO TT OO OO TT OO OD TT OO OO T~ OO OW TT UO OU TT OOOOOO TT tJOOOOO *START* USER PCAD [10707 b0702J ,JOB SHiP S~,~. 4335 OATP- 24-6EP-80 MONITOR SWS KLIO~40 SEP-80.' *START* FILE: DS~H.SHIP.IU<255>[~0707pRANTkD: 24-SEP-80 05:25:4660702] CREATEDI 24-8EP-80 0b:21:45 ~UkUk SWITCHES: /~-ILE:F~RT /COPIES:I /SPACING:I /b]MII':135 /~URMS:NORMAL 0;:25:24 ' S,H1PPING 1NSTRUCrlC{NS ISSUED 24-SKP-80 06:21 SHIP TO : RUSH TI{ PCCC THANKS. Bk ML~ PCCC VV VV EEEEEEkEEE RERRRHRR VV '¥¥ EEEEEEEEEE RRRRR~HH VV V% EL BR HH VV YV EL RR RR VV VV EE PR HR VV VV EL RR RR V¥ VV EEEkEEEE RRRRRRRR VV VV EEEEEEEE RBRRRHRR VV YV EL RR RH VV VV ~E RH HR VV VV EL HH RP VV VV EL HR RP ' VV LEEEEELE~E ~R RR 1II111 illlll 11 11 II II II ii Ii I1 1i 1i 1II1II 1Iilli YY X¥ YY XX YY XY XX YX YX 000000 000000 11 000000 000000 11 O0 O0 O0 O0 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 11 000000 000000 1111 000000 000000 1111 11 11 *START+ USER PCAL L1070/,60702] dUB SHiP SkU. MONITOR SWS KLIOE40 SEP-80. +START+ FILE: DSKh:VERiFY.O01<05?)[10?07 60702] CHEATED: PRINTED: 24-SEP-80 07:2~:O1 QUEUF, S~IlCHES: /['iLk:fORT /COPIE$:I /SPACING:I /LIMII':I]5 /~ORNS:NORMAL 4135 DATE 24-6EP-80 2~-SEP-80 07:25:24 07:20:29 bis VI",B61UN 15,H01 19/0312b SCHLUMBERGER COMPUTING CENTEH 10707,h0702 LENGTH: 132 BYTES REEL NAME: P.C.A.U. SERVICE NAME: EDIT PEEL CONTINUATION NUMBER: O1 PREVIOUS REEL NAME: COMMENTS: ElS FORMAT CUSTOMER TAFE DATE: 80/ 9/24 TAPE HEADER LENGTH: 132 BYTES ~APE NANE: b0702 SERVICE NAME: EDIT TAPk CONTINUATION NUMBER: O1 PREVIOUS TAP~ NAME: C£JMMEN]S: ~Ibg MEADER LENGTH: 62 BYTES ~ILE NAME: EDIT .00! MAXIMUM PHYSICAL RECORD LENGTH: PREV1UUS fiLE NAME: fILE COMMENTS OPEN HOLE DATA TDT DA~A PASS #] COMPANY : MARATHON OlD CO. WE[,L : TBU D-5 RD ~IELD : MCARTHOR RIVER RANGE : ~UWNSHIP : 8N SECTION : b COUNTY : KkNAI STATE : ALASKA DENSITY : 800. DATE: 80/ 9/24 1024 DA[IA ~ORMAT SPECII~ICATll3N LENGIi~ ~ 730 ~TE$ ENTR~ BLUCKS: 0 SIZE REP CUDE ENTRX I bO 0 DATUM SPLC][I~ICATION ~bUCi~S: NAME 'J~OtJJ~ UNIT AP1 API AP1 AP1 1DLPT iT 0 0 0 0 2 8P DIL MV 7 1 0 0 3 ILD Vlh UH~M 7 12 4b 0 4 IbM DIL UHMM 7 12 44 0 5 SFLU DIL UHMM ? 22 1 0 b GR O]b GAPI 7 31 32 0 7 CALl DIL 1N 7 28 ~ 0 8 DT DIL US/P 7 52 32 0 9 GR TDI GAPI 51 31 32 0 10 TAU TDT US 51 41 1 0 11 TRAT TDT C/C 51 42 I 0 12 SIGM 3DT CU 51 40 1 0 13 N1TD ID1 CPS 51 39 I 0 14 N2TD IDI CPS 51 3q 2 0 15 N~rD IDI CPS 51 39 3 0 16 [I~D TDT CPS 51 39 1 0 17 P2TD 1DT CPS 51 39 2 0 18 PiTD TOT CPS 51 39 3 0 USLR DLFINLD OUTPUT ARRAi OUTPiJ~ 8P AT 2 OUTPUT ILD AT OUTPUT ibm AT 4 OUTPUT S~'6U AT 5 OUTPUT GH AT OUTPUT CALJ Al l OUTPUT Dr A1 8 OUTPUT GR AT 9 OUTPUT TAU AT 10 OUTPUT TRAT A~ 11 OUTPUT S~GM AI 12 OUTPUT NIlD AT ourPu~ N2TD AT 14 OUTPUT N3'£D AT 15 OUTPUT ~JTD Al lb OUTPUT P2TD AT 17 ourPu~ F3TD FILL SIZE SAM REP 0 4 1 b8 0 4 1 b8 0 4 1 b8 0 4 I b8 0 4 1 b8 0 4 1 68 0 4 1 t)8 0 4 1 b~ 0 4 1 b8 0 4 1 08 0 4 1 b8 0 4 1 b8 0 4 1 b8 0 4 I b8 0 4 1 t)~ 0 4 I 68 0 4 1 t)~ 0 4 I ~8 Pt~UCES$ INDICATORS DEPTH 10540.000 10500.000 10400.000 10300.000 10200.000 lOlO0.O00 10000.000 9900.000 9800,000 SP TAD N 2'rD i" 3TO GR TAU N2TD [, SP GR TAU N2TD k 3TD SP GR l At} N2TD [' lTD SP GR TAU N2TD ~ 3TO SP GR TAU N2TD ~3TD GR tAU N2TD ~TD SP TAU N2rD P lTD $P GR ALI N2TD ]'rD VAL -40 94 -433 -?0 -4b 59 187 891 66 -58 42 203 750 82 -93 43 251 508 76 -88 39 2Lb 507 bO -85 40 24] 078 69 -107 35 286 499 64 -32 51 1060 79 -28 63 154 1102 83 UE .625 .063 .625 .500 .094 .219 .875 .000 .875 .094 .375 .000 .625 .813 .531 .250 .000 .06{ .625 .906 .000 .000 .938 .125 .156 .125 .000 .125 .125 .156 ,750 .750 .875 .594 .781 .500 .000 .063 .125 .719 .250 .000 .375 MNLMUNIC ILD CALl THAT N]TD ILD CALl IRAT N3TD ILO CAbi IRAT NSTD CALl rRAT NSTD ILD CALl TRAT N3TD ILD CALl TRAr N3TD ILO CALl THAT N3TD ILO CALl THAT NSTD ILO CALl I'RAT N3TD VALUE 8.]59 20.203 2.242 -286,750 4.523 19.188 3.182 322.750 27.469 18.922 2.492 381,000 25.56] 18.563 2,250 377,250 23.781 18.703 2.111 387.000 18,594 18.26o 2,676 463.000 2].781 18.125 1.755 451.250 7,887 lq.031 3.516 558.000 7.664 18.734 3.695 565.000 MNe, MUN lC ILM DT 61GM [lTD IbM DT blGM P lTD OI 6iGM 1IO AbM O£ 61GM P 1Ti) IbM DT $IGM PITD ILM DT 61GM ~ITO DT SlGM ~ITD ibM OT SIGM ~ITD ibM 6IGM ~ITO VALUL 8.008 77,125 -66.313 -234.000 4.391 80,250 24.203 367.000 28.938 00.375 22,359 395.500 23.734 67.250 18.094 355.750 22.547 70.875 17.078 313.750 19.813 75.750 18.703 329.250 21.813 71.750 15.859 329.000 1,809 70.000 27.'197 387,250 8.094 83.750 29,484 ]90,500 MN~MUNIC 6FLU GR N1TD SFLU GR N1TO F2TO SELU GH N1TO P2TO 8~bU GR N1TD ~ 2TO SFLU GR Nifo ~2TO SFLU GR N1TD P2TO 6FLU GR N1TD F2TD SFLU GR NITD ~2TD SFLU GR NITO ~ 2TO VALUE 10.883 -8~.188 -574.000 -103.188 3.930 33.906 1913.000 195,625 40.031 25.891 1693.000 241.875 38.406 25,297 1384.000 204,500 25.250 23.891 1204.500 169.625 31.b~1 25.656 1547.000 196.625 21.547 17.875 1212.000 183.750 b.938 27.266 2314.000 2Z9.375 10.078 33.219 2404.000 20u.500 DE~'rH 9700.000 9600.000 9500.000 9400,000 9300,000 9200,000 9100,000 9000. 000 8900.000 MN F..., M (J N 1C GR TAU N21D P3'ID Gi~ TAU N 2 'I'D J' jTD TAU N2TD ~3TD SP TAU N2TD ~3TD SP GR tAU N2TD G~ TAU N2TD F3TD GR TAU N2TD F~TD GR TAU N2TD ~3TD SP GR TAU N2TD ~3TD VALUE -24.594 90.875 151.250 1133.000 95.188 -b0.875 46.313 265.500 542.000 79.188 -25.500 72.188 162.750 934.000 88.250 -24.125 25.719 171.750 914.000 71.000 -13.797 74.125 150.375 1150.000 94.498 -20.525 71.250 143.750 114{.000 85.000 -26.125 38.500 181.750 859.500 92.175 -18.000 81.06) 1)8.750 120U.O00 85.188 -18.094 80.813 15t.875 tOb/.O00 88.438 MNEMONIC IUD CALl TRAT N3TD CALI T R A T N3TD CALI I'RAT N3TD CALl TRAT N3TD CALl TRAT N3TD IbD CALl TRAT N3TD lbD CALl IRAT N3TD CALl TRAT N3TD 1LD CALl TRAT N3TD VAI..,UE 12.807 18.984 J.597 580.500 19.297 18.531 2.338 532.500 14.008 18.453 3.514 563.500 14.602 19.281 4.070 593.000 9.898 19.297 3.613 647.000 9.719 17.766 3.727 667.500 1.430 18.453 3.074 O71.500 11.375 19.266 3.779 685.000 8.983 18.641 3.691 682.000 MNLMUN lC DT 8IGM ibm 6IGM f'lTO DT 61GM f lTD IbM D~ ~IGM f lTD DT SIGM flTO ILM DT 6iGM f 1TO IbM DT SIGM lTD IbM OT $IGM f lTD DT 6IGM lTD VALUE 13.1~8 71.625 30.078 413.250 20.265 71.625 17.063 321.250 11.992 59.375 27.938 355.250 12.930 132.750 26.469 320.750 9.508 70.025 30.234 421.750 9.~59 71.500 31.625 401.250 b.457 79.125 25.015 368.250 10.625 74.500 32.781 404.750 7.871 75.750 29.9~8 391.250 MNkMUN lC GR NITD P 2TO SF'LU GR NI~D f2TD GR N1TO $~6U GR NII'D F2TD GR N1TD F 2'rD 8FLU GR N1TD F2TO SfLU GR N1TO F2TD 6FLU GR N1TD ~2TO G~ N1TD ~ 2TD VALUL 15.211 52.656 2462.000 219.0oo 22.553 24.531 1280.000 156.375 11.~05 40.781 2055.000 158.750 2000.000 17.219 2003.000 142.500 9.O41 43.000 2490.000 218.625 9.500 38.406 2452.000 200.125 6.391 26.531 1936.000 205.375 9.555 42.938 2b12.000 203.500 7.746 38.063 2340.000 207.750 DLPiN 8800.0O0 8199,500 MNLM(JNIC SP GR TAU N2TD ~TD N2TD VAL -25 44 -99g -999 -999 -25 -999 -999 -999 UL .b25 .969 .250 .250 .25O .b25 .21g .250 .250 .250 NNkMUNiC CALk IRA'r N3TD 1LD CALl TRAT N3TD VALUk lb.484 18.703 -999.250 -999.250 15.539 18.547 -999.250 -999.250 MNkMUNIC IbM DT $IGM ~ITO IbM DT P1TD VAbU~ 14.938 139.000 -999.250 -999.250 13.521 119.250 -999.250 -999.250 MNh~MUN lC SFLU GR N1TD F2TD GR N1TD F2TO VALUL 72.250 -999;250 -999.250 -999.250 49.719 -999.250 -999.250 -999.250 ,SilMMAt~Ii U[' DATA RI:,Ct.IND,.'5 NUMBE~ UI' IqECURD,.S; 249 l, ENGJtt OF' RECU~D,$: 1014 BYTES I,ENC, IIi Ut' LA,ST IRECtJIql): 720 B~TE~ i' ILE TRAILIc, H I~ENG'I It: b2 B Y Ti-,6 i-JIJE NAME: ED.iT ,001 MAXlfqH~ FHY,SiCAL ~ECuiqD LENGTH: NEXT 1~ lbi'. NAME: FiLE HEADEIe {_,EN C, 1' H: 62 FILL NAME: F. DI'I .002 MAXIMUM PHISICAb RECtJRD LENGTH: PRF~VIUUI5 [,iLE NAMi".: l'lLk CUMMENT,S TDT DATA PA6$ TDT DAq_A PAS5 1024 1024 DAIA ["LIRMA1 6P~CIF1CA'I'IUN I,F_,NG 1 It: 850 BYTIc.,S kNTRZ BLOCKS: tYPE 0 SIZE REP CODE ENTHY I b6 0 L)A'[[)M bPECl[' I. CATIIJN 1~6uCK6: NAM~ [INII AP1 AP1 AP1 AP1 1 DgP 1' 2 GR TDT 3 TAt} TDI' 4 'lRAt ID']. 5 $IG~ TDT t~ N II'D q. DT 7 N2TD 8 N J']D 9 ~ l'rD IDT 10 ~2'ID 'IDT 1! I. ~ID 'tD'l 12 GR TDT 1 3 '/'AU 14 rRAI' TDT 1.5 TtG~ 1'Dql 1~ N1TD 17 N2TD TDT 18 N 3TD TDT 19 [' 1I'D TIL)~ 20 1~2rD 1'131 2~ J'.tTD I'DT FT 0 0 0 0 GAPI 5[ 51 ]2 0 US 51 41 I 0 C/C 51 42 1 0 CU 51 40 1 0 Ct'~ 51 30 1 u CPS 51 {9 2 0 CPS 51 39 3 0 CP~ bi 39 1 0 CPS 51 39 2 0 CPS 51 39 3 0 GAP] 51 Jl 32 O US 51 ~1 1 0 C/C 51 42 1 0 CU 51 40 I 0 CPS 51 ~9 1 0 CPb 51 3g 2 0 CPS 51 39 3 0 CP6 51 39 I 0 CPS 51 39 2 0 CPS 51 39 3 0 U,SER [)EB1NED UU3PUT ARRAY UUTP{IT GH AZ 2 OUTPUT TAU AZ OUTPUT I'RAT AT OUTPUT SIGM AT 5 OUTPUT NIlD A~ UUTPU[ N2ID A~ 7 [JUTPU~ N31D A~ 8 OUTPUT ~ITD A~ 9 OUTPUT f21D A2 10 OUTPU~ F$~D A3 OUTPUT G~ A2 12 OUTPUT TAU A7 13 OUTPUT TBA'I A2 OUTPU~ SIGM AT 15 OUTPUT NllD A3 OUTPUT N2TD OUTPUT N]'ID A'[ 18 OUTPUT F1TD OUTPUt E2TD A2 20 OUTPUT fJi'D AI 2! FILL SIZE SAM RkP 0 4 1 b8 0 4 1 b8 0 4 1 bU 0 4 1 b8 0 4 1 08 0 4 1 68 0 4 1 b8 0 4 1 68 0 q 1 ~8 0 4 1 (>8 0 4 1 OB 0 4 1 o8 0 4 1 b8 0 4 1 08 0 4 1 08 0 4 1 OB 0 4 1 68 0 4 1 68 0 4 1 08 0 4 1 68 0 4 1 OB PI, eOCES$ INDiCA'£OR6 to~qo.ooo I 0500. O00 1040O,O0O 10300·000 10200,000 10100.O00 10000,000 9900,000 9800,000 MN GR N1TD ~2TD TRAT N3TD fllTD ~2TD T~AT N1TD ~2TD TRAT N3TD N1TD ~2TO TRAT N]TD GR N1TD ~2TD TRAr N]TD GR NITD P2TD rRAT N3TD N1TD ~2TD TEAT N]TD GR N1TD F2TD T~AT N3TD N1TD ~2TD TRAT N3TD VAL -28 -10 2 850 1998 202 24 1453 197 2 657 26 1180 225 2 bl? UL .250 .469 ,926 .000 .]75 .000 .750 .305 .500 .375 .000 .250 .535 · 000 .500 .000 .375 .211 .500 25.172 480. 000 188.250 2.03q 642.000 31. 1535. 211· 2. 21. 1224. 114. 1· 648. 27. 2093. 198. 3. 700. 2400. 185. 3. 756. 172 O00 125 605 000 797 000 125 774 500 109 000 125 4]0 000 000 000 125 770 500 MNEMUNIC TAU N2TD F3TD $IGM flTD TAU N2TD F3TD $iGM F1TD TAU N2TD $1GM ~ITD TAU N2TD F]TD SIGM ~ITD TAU N2TD F3TD SIGM flTD TAU N2TD F3TD 6IGM F1TD TAU N2TD F3TD $IGM F1TD TAU N2TD F3TD $IGM ~ITD N2TD F3TD SIGM FITD VAUUL -163.250 -62.188 -25.594 23.500 376.500 184.625 895.500 84.938 24.750 365.250 218.125 6]7.000 94.500 22.703 389.750 248.250 598.000 84.750 17.297 331.500 239.500 04{.500 86.563 18.]75 335.500 243.625 68].000 77.250 18.875 330.500 288.000 503.000 84.500 15,063 322.500 171.500 943.500 84.875 20.188 349.250 156.000 1108.000 99.688 29.516 405.750 MNEMUNIC THAT N3TD GR N1TO ~2TO TRAI N3TD GR NITD f2TD TRAT GR N1TD ~2TD TRAI N3TD GR N1TO F2TD TRAT N3rO OR N1TO F'2TD TRAT N3TD GR N1TD ~2TO TRAT N]TO GR NI~D ~2TO TRA~ N]TD GR N1TD F2FD 1RAT N3TD GR NITD ~2TO VAb 1 -161 1913 220 3 503 38 2013 187 2 517 28 1721 241 2 536 27 1270 185 2 566 27 1400 190 2 575 28 1523 196 1 577 20 1076 161 3 6]6 26 2057 208 3 684 37 2450 203 OE .397 .375 .250 .000 .750 .102 .750 .250 .000 .250 .387 .500 .438 .000 .125 .186 .000 .172 .000 .125 .248 .000 .844 .000 .250 .486 .000 .594 .000 .750 .759 .500 .969 .000 .625 .2b0 .000 .375 .000 .250 .842 .000 .000 .125 MNkMONIC $iGM F1TL) TAU N2TD F]TO $IGM F1TD TAU N2TO F3TD SlGM flTD TAU N2TD f 3TD $1GM flTD TAU N2TD f3TD $IGM F1TO TAU N2TD f3TO $IGM F1TD TAU N2TD F3TD 6iGM F'ITD TAU N2TD F3TD F1TO TAU N2TO F3TO $1GM F1TD TAU N2TD F3TO VALUE -27.891 -35.250 19].500 876.0OO 128.500 24·625 383.250 183.750 911.000 92·063 20.844 362.000 200.250 705.500 102.625 18.328 355.250 262.750 538.500 85.500 18·984 337.750 247.500 603.000 91·750 1~.672 346.750 241.000 669.500 90.43~ 15.789 33?.750 302.000 442.750 74.000 2~.516 37;.750 1/3.625 933.500 89.815 29.150 401.000 154.000 11~1.000 104.000 DLP~ 97'00. 000 9600.000 9500,000 9400.000 9300.000 9200.000 9100,000 9000.000 ~qo0,o00 M NI~,MlJN lC N1TD N3TD N1TD P2TD 1RAT N 3TD G~ I'2TD TRAT H3TD GR NIID P2TD TRAT N3TD GH NIAD ~2TD TRAI N]TD N1TD P2TD TRAI N3TD GR NITD P2TD IMAT N3'£0 N1TO f2TO TRAT N]TU bR N1TD P2TD TRAT N3TD VALUL 51.250 2428.000 201.250 3.062 700.000 25.781 1400.000 201.875 2.270 699.500 41.375 2]36.000 214.875 3.691 731.000 18.26o 2104.000 174.500 3.920 720.500 41.406 2534.00O 227.250 3.443 74U.000 43.438 2422.000 215.815 3.029 754.500 27.250 2143.000 223.250 3.162 747.000 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 MN LMUNIC TAU N2TD f3TD SIGM PITD TAU N2TD F3TD SIGM F1TD TAU N2TD ~3TD S1GM ~ITD ~AU N2TD F3TD SiGM ~ITD rAU N2TD ~3TD $1GM ~ITD TAU N2TD P3TD $IGM P1TD TAU N2TD SIGM flTP 2AU N2TD f3TD $IGM PITD TAU N2TD f3TD $IGM flTD VAbUg 151.250 1127.000 96.438 29.625 404.000 245.]?5 028.500 92.563 18.375 351.750 151.625 1070.000 91.438 29.906 404.250 166.000 953.500 74.063 27.391 334.500 149.625 1177.000 94.750 28.953 407.000 148.000 1113.000 93,188 30.891 415.250 174.625 976.500 105.750 25.031 305.500 -999.250 -999.250 -999.250 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -965.250 MN LMUNIC TRAT N3TD bR NlrD P2TD TRAI N3TD GR N1TD ~2TU TRAT ~R N1TD P2TD TRAI N3TD N1TD TRA~ N3~D GR N1TD THAI N3TD GR Nl'ra f2TO TRA£ N3TD NITO 6210 TRAT N3TD GR N1TD k2TD ~RA~ N3I'D G~ NI~D ~2TD VALUL 3.697 677.000 50.563 2330.000 191.125 2.303 671.500 29.150 1459.000 199.000 3.361 693.000 44.375 2360.000 208.250 3.963 703.000 19.906 2137.000 163.125 3.401 716.500 45.563 2290.000 201.625 3.570 695.000 49.125 2398.000 203.025 3.299 742.000 29.719 2005.000 219.000 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 M IV EMUNIC 8IGM F1TD TAU N2TD F3TD 61GM P'ITD TAU N2TD F3TD SIGM PITD TAU N2TD f3TD SlGM F1TD TAU N2TD fJTD 51GM f-lTD TAU N2TD f ~TD 8IGM ~ITD TAU N2TD ~3TD $IGM F1TD tAU N2TD F3TO $1GM flTO TAU N2TD ~3TD $1GM F1TD TAU N2TD F3TD VAI, 30 414 153 107b 105 18 353 247 628 96 29 152 1077 101 27 334 lbo 976 3O 436 157 1042 80 30 413 147 1112 377 181 915 96 -999 -965 -999 -999 -999 -999 -965 -999 -999 -999 U~ .0/8 .750 .500 .000 .313 .531 .000 .375 .000 .313 .984 .500 .000 .000 .063 .391 .000 .000 .500 .375 .391 .500 .000 .000 .250 .719 .500 .250 .000 .031 .500 .b25 .500 .563 .250 .250 .250 .250 .250 .250 .250 .250 .250 .2bO t oo.ooo 8799,500 MNkMUNiC (JR N1TD [" 2'I'D 'IRAT N3TD GR NITD P2TD TRAT -9 -9 -9 -9 -9 -9 -9 -9 -9 -9 ALU 99. 99. 99. 99. 99, 99, 99, 99, 99, 99, 250 25O 25O 250 250 250 250 250 250 250 M N kMUN iC 1. AU N2TD ~3TD $IGM P lTD TAU N2TD ~{TD SIGM ~ITO VAbU -999, -999, -999, -999o -999. -999, -999, -999, -999, -999, 250 250 250 250 250 25O 25O 25O 25O 250 MNkMUNIC iq 3 TD NITD 1~ 2TU U['RA'I ii 3TO N1TO ~ 2TO VAhU~ -999,250 -999,2§0 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999o250 -999,250 MNkMUNIC $1GM ~ITD ~2T~ ~TD ~ITD N2TD VA6UE -999,~50 -999,250 =999,250 =999.2b0 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 5UMMAR~ U[, DA'IA t~C~JRD~S NUM~-H OF I~ECUP. D$: 29l LENGIH UP ~ECu~D$: 1014 I, KNG'I~ (JP LASI' RP.CORO; 174 ~ilES i: ILE Tiaa IL?-B I,~,NG'IH: b2 ~YT~6 PII,E NAME: EDiT .002 MAXIMUM PHYSICAL R~CORD LENGTH: N~XT ~ILE NAMe: fiLE HEADEP L~.NG'IH: 62 BYTES FILE NAME: LD1T .00] MAXIMUM PHYSICAL RECORD LENGTH: PREV1UU6 FILE NAME: PILE COMMENT6 TDI' DATA PA65 #4 TDT DA~A PA66 #5 1024 B2TES I,P,N~'IH: 850 ENTR~ ~LUCKS: 0 $IZh 1 66 CODE DATUM 8?fc,CIi. ICATIU~ ~LUCK,5: UN1T AP1 API AP1 AP1 ~ILk S1ZE SAM HEP PMUCESS INDICATOHS 1 2 GR 1 3 I~AU IDI US 4 TRAY lOT C/C 5 81GM IO'l CU ~ N13D ~DT CPS 8 N~TD TUT CPS 9 ~ITD 1'DI CPS 10 ~2TD IDI CPb 11 F]TD IDT CPS 12 GR 2DI 13 TAU TOT 14 T~AT 15 SIGM IDT CU 16 Nt%D l'O~ CPS 17 N2TD TD~ CPS lB NtrD lOT CP6 19 ~ lTD IUT CP6 20 f~TD 1DT CPS 21 ~3TD TOT CPm OUTPUT UUIPtiT TAU A%' 3 OUTPUT THAT Al 4 OUTPUT $1GM AI 5 OUTPUT N1TD AT DUI'PUT N2JD A~ 7 OUTPUT N3TD AT OUTPUT ~ ]ID A~ 9 OUTPUT F2TD A~ 10 OUTPUT OUTPUT GH A'I 12 OUTPIlT TAU OUTPUT TRAT Aq 14 OUTPIlT SIGM A~' 15 OUTPUt NIID OUTPUT N2TD A1 17 OUTPUt NtID OUTPUT ~I~D A~ 19 OUTPUT ~2TD A~ 20 OUTPUT F]TD A1 21 I~T O 0 0 GAP[ 51 31 51 41 1 51 42 1 51 40 51 39 1 51 51 39 51 39 1 51 51 39 3 GAPI 51 31 32 51 41 1 51 42 1 51 40 1 51 39 1 51 39 2 51 39 ~1 51 39 1 51 39 2 51 39 3 0 0 4 1 b8 0 0 4 I b8 0 0 4 1 bU 0 0 4 1 68 0 0 4 1 6~ 0 0 4 I 08 0 0 4 1 b~ 0 0 4 1 b8 0 0 4 1 b8 0 0 4 1 b8 0 0 4 1 bU 0 0 4 I 68 0 0 ~ 1 08 0 0 4 1 b8 0 0 4 1 68 0 0 4 1 UB 0 0 4 1 b8 0 0 4 1 bU 0 0 4 1 b8 0 0 4 1 o~ 0 0 4 1 08 10~40.000 10500.000 10400.000 10]00.000 10200,OO0 10100.000 10000.000 9400.000 9800.000 MN~MUNIC GR N 1 TU ['2TD 'I [,,< A'I GR N1YD ~2TD 'fRAT NSTD GR N1TD ~2TD TRAf N 3TD GR N1TD ~2TD TRAT NSTD N1TD ~2TD TRAT NSTD N1TD [, 2TD THA3 N3TD N1TD F2TD NS~D GR NITD ~2TD TRAI NSTD G~ N1TD F2TD THAI NSTD VALU~ 91.375 o45.000 64.688 2.129 -772.500 44.781 2018.000 199.875 ].5Ob 615.000 2b.51b 1495.000 207.00O 2.434 b21.500 30.625 1260.000 210.375 2.357 007.500 27.906 1433.000 192.000 2.17o 635.000 ]0.391 143].000 186.000 2.639 b57.000 23.760 1211.000 154.875 1.Sb{ U85.000 32.469 2228.000 208.25O 3.383 705.000 44.844 2370.000 205.375 3.750 750.000 MNkMONIC ~AU N2ID ~STD ~ITD TAU N2TD ~STD 8IGM ~ITD TAU N2TD ~3FO $IGM blTO 1AU N2TD ~3TD SIGM ~ITD 'YAU N2TD ~STD $1GM blTO TAU N2TD F3TD $1GM ~ITD TAU N2TD F3TO 81GM FITD TAU N2TD ~STO 8IGM ~ITD ~AU N2TO ~STD $IGM F1TD VAbUE 133.125 553.000 274.000 -43.281 -315.500 182.375 915.000 89.625 24.953 389.250 215.250 655.500 99.625 21.641 365.500 2b0.500 54].000 79.188 17.281 320.750 242.875 b]5.500 93.125 18.578 332.750 255.5O0 621.000 87.188 17.969 324.000 283.250 499.500 80.688 16.938 347.000 165.750 1017.000 100.625 25.781 358.750 i55.500 1092.O00 92.750 29.609 40b.250 MN kMONIC TRAT N 3'I'O (JR N1TO ~ 2TD TRAT GR THAi NSTO GR N1TD ~2TO TRAi GR N1TO ~2TO NSTD N1TD ~2TD TRA'I NSTD NITD ~2TD NSTD NITO ~2~0 TRA'! NITD ~2TO TRAT GR N1TD ~2TD VALUk 1.206 652.500 -73.938 -840.000 -135.875 3.189 630.500 44.344 2051.000 203.000 2.41b 619.500 30.641 1565.000 207.750 2.225 b30.500 30.1~1 1272.000 18b.250 2.14b 656.500 28.672 1444.000 182.750 2.711 646.500 29.250 1461.000 177.625 1.757 656.000 23.422 1363.000 189.750 ~.525 730.000 34.188 2004.000 196.250 3.600 748.000 4i.31] 24b0.000 204.625 BMONiC $1GM F1TD TAU N2TO ~STO $1GM klTD TAU N2TD FSTD $IGM F1TD TAU N2TO ~STO F1TD 'FAO N2TD FSTD 81GM ~ITD TAU N2TD ~STD F1TO TAU N2TD FSTO $1GM ~ITD TAU N2TO 8IGM F1TO TAU N2TD F3TO 81GM FITD BAU N2TO FSTD VAbUE 34.150 49u.000 -105.125 -584.000 -lbS.000 24.938 373.500 182.250 934.000 9b.938 21.125 337.500 210.125 685.500 101.000 17.453 Jbb.000 2b].250 553.000 94.000 IB.719 332.750 244.750 b17.00u 88.31~ 1;.797 310.750 253.125 b36.500 87.81~ ]21.750 2~8.500 580.000 92.375 2/.438 37b.500 116.375 903.500 Ul.375 29.250 413.250 153.500 113/.000 94.125 DEPTH 9T00.OO0 9600.000 9500.OO0 9400.000 9t00.000 9200.000 9100.000 9000.000 8900.000 MN kMtJNIC GR N1TD ~2TD ]RAT NiTD GR N1TD ~2TI) TRAT N3TD GR NITD P2TD TRAr GH N1TD ~2TD TRAI' N3TD GR N1TD ~2TO TRAT N3TD GR NITD f2TO TRAT N3TO GP N1TD P2TD TRA1 N3TD G~ NITD ~2TD TRAT N3TD GH NITD ~2TD TRAT N3TD YALUk 51.906 2500.000 223.625 3.592 762.500 31.313 1415.000 200.875 2.07b 694.000 43.125 2410.000 200.125 3.650 751.000 22.078 2179.000 171.500 3.969 744.500 45,344 2362.000 217.000 3.691 798.500 45.813 2374.000 199.625 3.629 735,500 29.969 1693.000 178.375 3.225 785.500 -999,250 -799.250 =999.250 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 MN ~MUNIC TAU N2TD P3TD $IGM klTO 1AU N2TD ~3TD 8iGM ~ITD TAU N2ID k3TD $iGM PITD LAU N2TD P3TD SIGM ~ITD TAU N2TD P3TD $1GM ~ITD TAU N2TD f3TO $iGM ~ITD TAU N2TD f3TO SIGM [lTD TAU N2TD ~3TD $iGM ~ITD TAU N2TD f3TD $IGM F1TD VAL 148 1156 10~ ~0 404 249 617 90 18 355 151 lllb 104 29 406 165 99t 80 2b 327 154 1088 99 29 393 149 1096 93 30 399 198 751 88 24 368 -999 -999 -999 -999 -905 -999 -999 -999 -999 -905 V' tJE, .750 .000 .500 .125 .000 .000 .000 .938 .203 .500 .O00 .000 .313 .578 .750 .125 .000 .375 ,609 .000 .000 .000 .188 .422 .750 .375 .000 .750 .203 .750 .815 .500 .625 .906 .500 .250 .250 .250 .250 .250 .25O .250 .250 .250 .250 MNkMUNIC TRAT GR ~ITD P2TO TRAT GR NITD P2TD N3TD GR NITD P2TO TRA~ N]TO GR NITD f2TD IRA1 N]TD GR N1TD ~2TO TRA1 N~TD N1TD TRAI N 3TD GR NlrD ~ 2TO TRAT N3TD GR N1TD ~2TO TRA1 N]TD G~ NiTD P2TD VALUE 3.b54 753.500 51.b88 2448.000 221.375 2.223 692.000 30.578 1427.000 193.125 3.754 738.500 47.119 2350.000 201.875 3.803 745.500 19.B75 2043.000 159.500 3.416 771,000 46.813 236b.000 204.500 3.689 753.000 48.844 2312.000 185.125 2.953 734.500 29.641 1951.000 199.375 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 MNEMUN1C $1GM F1TD TAU N2TD F3TO 81GM ~ lTD TAU N2TO ~ 3TO 8IGM ~'l~O ~AU N2TD ~TD ~ITO TAU N2TO F3TD 81GM f lTD TAU N2TD F 3 TO 81GM ~ITD TAU N2TO F3TO $1GM F1TD N2TD P3TO 8IGM PITD TAU N2TD ~3TO F1TD TAU N2TO P3TD VAbU~ 30.503 405.250 151.000 1127.000 9U.750 18.2bb 346.250 249.875 b07.500 98.b88 30.109 395.750 153.750 107U.O00 100.438 27.547 343.000 170.875 915.500 80.313 29.531 400.750 154.500 10Bb.000 95.625 30.4~B 384.000 150.500 lOb6.O00 98.43U 22.859 330.500 182.b25 885.000 96.b25 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -9~5.250 -999.250 -999.250 -999.250 DI-.FTH 88'~)0. 000 8799.500 ~NENUNIC Gk NITD ~2TO N3TO GR N1TD ~ 2TD I'~Al N3TD VAI.,Uk -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNkMUNIC TAU N2TD 5IGM ~ITD TAU N2TD ~3TD 61GM ~ITD VALU[~: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNkMONiC IRAT N~TD NII'D b2TD IRAT N]TD N1TD VAbUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MN~MUNIC flTU IAU N2TD F3TD TAU N2TD F3TD VAbUk -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ,SUMMAI-<~ D~ DATA ~ECOiqL)8 NUMBi:,~ O~ IAECURD$: 291 bkNGlrt (.1[. RkCUi~DS: 1014 B~TE,S I,kNGT8 tJ~ LA,SI' ~["]Cl..}i,~O: 174 i~ LLE TI~Albi'.R I,ENGI tt: 62 BY TE,S I;ILE NAME: EDiT MAXIMUM PHYSICAL RECUHD LENGTH: N~.XT 1'ILl". NA~aE: TAPE I~AILER LENGTH: 132 BYTE,S TAPE NAME: 60702 SkPVICE NAME: EDIT 'rAPE CUNTINUATiUN NUMBER: 0! NEX'[ 1APE NAME: C(}MMEN'I',S: 1024 BYTE,S DATE: 80/ 9/24 11 000000 7777777777 11 000000 7777777777 1111 O0 O0 77 1111 O0 O0 77 11 00 0000 77 11 O0 0000 77 11 O0 O0 O0 77 11 00 00 00 77 11 0000 00 71 11 0000 00 37 11 O0 O0 77 11 O0 O0 77 111111 000000 77 111111 000000 77 000000 000000 00 00 00 00 O0 0000 00 0000 00 O0 00 00 O0 00 0000 00 0000 00 00 00 O0 O0 000000 000000 7771777777 7777777777 77 77 77 77 77 77 77 17 77 77 77 77 666066 000000 7777777777 666666 000000 7777777777 bb O0 O0 77 66 00 O0 77 6b O0 0000 77 66 O0 0000 77 b6bbbbbb O0 O0 O0 77 6666666b O0 O0 O0 77 6~ bb 0000 00 77 66 b6 0000 00 77 ~b bb O0 O0 77 66 b6 00 00 77 bbObbb 000000 77 bbbb6b 000000 77 000000 000000 00 00 00 O0 00 0000 O0 0000 00 O0 00 O0 00 00 0000 O0 00o0 O0 O0 O0 O0 00 000000 000000 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 M M b k k ~ K EEEEE N N AAA MM MM L K K g K E N N h A M M M b K K g K E NN N A A M M L KKK ..... KKK EEEE N N N A A M M L K g K k E N NN AAAAA i M M b K K K K E N N A A I M M LLLLL k ~ ~ K EkEEE h N A A 1il *START* USER PCAL [10707,b0702] JOB SHIP SRO. 4533 DATE 13-SEP-80 06:52:54 MONITOR S~6 KLlOE37 APR-80. *START* *SIART* UfER PCAL [10707.60702] dOB S~IP SEO. 4533 DATE 13-SEP-80 06:52:54 MONITOr< bwS KLIOE37 APP-80. *START* SSSSSSSS HH HH HH HH SSSSS5 HHHHHHHHHH 5SSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH UH SSSSSSSS HH HH Illiii PPPPPPPP IIIIii PPPPPPPP II PP PP II PP PP 11 PP PP II PP PP II PPPPPPPP II PPPPPPPP I! PP II PP II PP II PP Iiii11 PP IllII! PP TTTTTTTTTT OOUUUO TTTTTTTTTT UOUOUU TT O0 OU TT UO O0 TT DO O0 TT [10 O0 T~ UO UU TT OO OO TT UO UO TT O0 Ou TT [JO UO TT O0 OO TT OUUOOU TT OOUOUU *bTART* USER PCAL [10107,b0702] dOB SHiP 8E~. 4533 DAT~ 13-SEP-80 MUNiTOH SWS KLlOE37 APH-80. *START* FILE: D&~H:SHIP.TU<O57>[lO707.O0702] CREATED: 13-SEP-80 06:0]:30 PRINTED; 13-SEP-80 06:53:07 ~O~Ok SWITCHES: /Flbt:FORT /SPACiNG:I /LIMiT:131 /FORMS:NORMAb 06:52:54 oSe~oqouv ao!s~lU~moo 'suoo se9 ~ !10 mls~i¥ [86[ 8 l AON SHI~ CCC, ENTURAo SHIPPING INSTHUCTIONS l SSt~ED 13-S~,P-BO 03:30 CALI~.o THAH~S. ~¥ MLK PCCC ~9 ~¥ EELLELLEEL RRHRRRR~ YV ¥~ EE~EEEEEEE RRHHRRR~ VV ~V LE ~ RR VV VV EE RR RH VV VV EE H~ RR V~ VV EE ~ RR ~V VV EEEEEEEE RRRRRR~R VV VV EEEEEEEE R~RRkR~ VV V¥ EE HR HR VV ~V EE RR RR vv VV EE ~ RR vv VV ~E H~ fir VV EEEEE~EEE RR RR VV EEEEEEEE~E HR RR IIIIII iIlIIi Ii Ii Ii II I1 Ii II i1 I1 ii IIIiii IIIIII FFb FFF F'FFF FFI~ f FFFF YY YY YY YY YY YY YY YY YY :fY ~Y YY YY YY O00000 000000 222222 000000 000000 222222 O0 O0 O0 O0 22 22 O0 O0 O0 O0 22 22 O0 0000 O0 0000 22 O0 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 O0 O0 O0 O0 O0 O0 22 O00O O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 000000 000000 2222222222 000000 000000 2222222222 *bTART* USER PCAL [10707.b0702J dOB SHIP SEO. MONITOR SW$ KLlOE37 APH-BO. ,START* fiLE: DShB:VERifX.002<057>[10707o60702] CREATED: P~INTED: 13-SEP-80 06:5]:16 OUEUE SWITCHES: /fILE:f'ORT /COPIES:I /SPACING:I /LIMIT:IS1 /FORMS:NORMAL 4533 DATE 13-$EP-80 13-SEP-BO 06:51:36 0b:52:54 VERSION 15.HOI 7910J/2b SCHLUMBERGER COMPUTING CENTER 10707,00702 REEb HEADER LENGTH: 112 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: O! PREVIOUS REEL NAME: CUMMENTS: L1S fURMAT CUSTOMER TAP5 DAIE: 801 9/12 TAPE HEADER LENGTH: 132 b~TES TAPE NAME: 60702 DATE: 80/ 9/12 SERV1CE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREVIOUS TAPE NAME: COMMENTS: TAP~ COMMENTS CASING $1ZR=13.37 iN. 0 47/LB/F TO 2505 FT. " " = 9.62 iN. 0 47/hB/f TO 10620 FT. BiT $IZE=17 IN. 2505 f'T & 12.25 IN 10620 f'T. T~PE FLUID 1N HOLE=SEA WATER/MAX TEMP 162 F fILE HEADER b~NGIH: 62 BYTES fILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: FSEVIOUS fILE NAME: f'ILE COMMENTS PASS #1 Of 5 PASSES CUMPAN¥ : MARATHON OIL CO. WEbL f'IELD RANGE TOWNSHIP S~CTIUN CUUNT~ STATE DENS1T~ : TBU D-5 ~D : MCARTHUR RIVE~ : 13W : 8N : b : KENAI : ALASKA : 800. 1024 BYTES DATA fOrMAT SP~Cif'ICATIUN L~NGTH: 450 b~TEO ENTR~ OLUC~S: T~PE 0 SIZE 1 CODE 66 ENTR~ 0 DATUM ,SP£CIFICAT10H BLOCKS: NAM~ IOUb UNiT AP1 APl AP1 API FiLE SIZE SAM REM PROCESS iNDICAI'O~S 1 DkPT 2 GR TDT 3 TAU 1DT 4 TRAT TDT 5 81GM TDT 6 NllD TOT 7 N2TD ]DT 8 NBTD TDT 9 P1TD TDT lO P2TD TDT 11 ~]TD TOT l..T 0 0 0 0 0 4 GAPI 51 31 32 0 0 4 08 51 41 1 0 0 4 C/C 51 42 1 0 0 4 CU 51 40 1 0 0 4 CPS 51 39 I 0 0 4 CPS 51 ]9 2 0 0 4 CPS 51 ]9 3 0 0 4 CPS 51 39 ! 0 0 4 CPS 51 39 2 0 0 4 CPS 51 39 3 0 0 q 1 68 I b8 I 68 I b8 1 68 1 6B 1 68 USk, l~ DEE INED UUTPUT ARRAY UUTPUT G~ AT 2 OUTPUT ~AU AT 3 OUTPUT TRAT AI 4 OUTPUT SIGM AT 5 OUTPUT N1TD AT 6 OUTPUT N2TD AT 7 OUTPUT N~I'D AT ~ OUTPUT ~1TD AT 9 OUTPUT F2ID AT 10 OUTPUT F3TD AT 11 10533.OO0 10500.000 10400.000 10300.000 10200.000 10lo0.000 lO000.O00 9900.000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 MNEMONIC N1TD ~2TO GR N1TD F2TD GM N1TD ~ 2TO GR N1TD 1" 2TD GR N1TD F2TO GR N1TD ~2TD GR N1TD P2TD GR N1TD ~2TD GR N1TD ~2TD GR N1TD ~2TO GR N1TD ~2TD NITD F2TD N1TD ~2TO GM N1TD F2TD VAL -88 -674 -103 33 1973 195 27 1760 243 28 1453 192 23 1204 169 27 1537 185 17 1168 191 26 2274 221 33 2404 208 52 2442 219 23 1224 153 42 2137 186 17 1972 136 37 2239 203 UE .188 .000 .188 .906 .000 .625 .859 .000 .250 .000 .000 .75O .891 .500 .625 .734 .000 .875 .15b .500 .625 .625 .000 .500 .219 .000 .500 .bSb .000 .000 .188 .000 .75O .188 .000 .125 .266 .000 .500 .813 .000 .500 MNEMONIC TAU N2TD i;3TD N2TD f'3TD TAU N2TD F3TD TAU N2TD f3TO TAU N2TD P3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD f3TD TAU N2TD F3TD VAb -68 -433 -70 187 891 bb 197 781 85 246 633 74 26b 5O7 60 240 675 76 290 484 66 164 1043 79 154 1102 83 151 1133 95 271 515 76 160 979 83 173 892 71 lbO 1029 94 UE .625 .500 .625 .875 .000 .063 .625 .500 .938 .625 .000 .438 .000 .000 .938 .625 .000 .875 .750 .250 .313 .625 .000 .063 .250 .000 .375 .25O .000 .188 .000 .500 .000 .500 .000 .750 .250 .000 .063 .250 .000 .500 MNLMON1C TRAT N3TD TRAT N3TD 1RAT N3TD IRAT N3TD TRAT N3TD TRA2 N3TD TRAT N3TD TRAI N3TD TMAT N 3TO TRAT N3TD %RAT N3TD TRAT N3TD TRAT N3TO 1'RAT N3TD VALUE 2.242 -286.750 3.182 322.750 2.605 388.000 2.459 386.500 2.111 387.000 2.676 458.250 1.755 462.750 3.411 554.500 3.695 565.000 3.697 580.500 2.123 529.000 3.639 574.000 4.121 599.500 3.500 641.500 MNEMONIC $IGM FITD SIGM FITD SIGM F1TD $IGM F1TD SIGM F1TD SIGM FITD SIGM F1TD $IGM FITD SiGM F1TD SIGM FITD $iGM FITD SiGM FITD SIGM Fl'rD SiGM F1TD VALUE -66.313 -234.000 24.203 367.000 23.016 393.500 18.438 350.000 17.078 313.750 18.891 330.250 15.633 337.250 27.625 379.500 29.484 390.500 30.078 413.250 16.781 317.500 28.344 378.250 26.250 313.250 28.3/5 406.750 Db, PTH 9200.000 9100.000 9000.000 8900.000 8870.000 MNBMUNIC N1TD f2TU GR N1TD F2TO N1TD f2TD GR N1TD P2TD GR N1TO P2TD VALUE 38.469 2362.000 198.750 27.188 1973.000 206.750 38.000 2492.000 19b.250 38.125 2227.000 186.125 -999.250 -799.25O -999.250 MNEMUNiC TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD ~3TD VAGUE 150.000 1089.000 86.500 179.750 890.OO0 92.563 144.375 1144.000 80.750 15b.750 1023.500 93.375 -999.250 -999.250 -999.250 MNEMONIC TRA% N3TD THAT N3TD TRAT N3TD TRAT N3TD £RAI N3TD VALUk 3.000 670.500 3.057 688.000 3.b78 058.500 3.088 067.500 -999.250 -999.250 MNEMONIC SIGN F1 TI) SIGN FITD SIGN F1TD SIGN F1TD SIGN F1TD VAbU~ 30.297 391.250 25.297 382.750 31.500 393.250 29.016 376.250 -999.250 -965.250 DATA NUMB~ OF ~CURDS: 145 LENGTH O~ RECORDS: 1018 I~TES GENG'IH t}~ LAST I{ECUBD: bbb BYTES FiL~ TRAILk~ LENGTH: 62 BYTES ~iL~ NAME: EDIT .001 MAXIMUM PHYSICAL R~CORD LENGTH: NEXT ~ILk NAME: 1024 B~TkS ~IbL HEADER LENGTH: 62 BYTES ~iLE NAME: EDiT .002 MAXIMUM PHYSICAL RSCURD LENGTH: PRSVlOUS FILE NAME: ~IL~ COMMENTS PASTS 2 & ] OF 5 PASS TDT 1024 BYTES DATA /'U~MAT SPBClI"ICATION L~NGT~: 850 BYTE6 BLOCKS: TYPE 0 SIZE R~P CODE ENTRY 1 b6 0 DATUM SPECII;ICATiUN BLuelY5: NAML UNIT AP1 AP1 AP1 AP1 FILE 6IZE SAM ~.P PROCESS INDiCAtORS 1 DLPT 2 GR TDT J TAU TOT 4 TRAT TDT 5 blGM TDT b N1TD TDT ? N2TD TDT 8 NBTD rDT 9 [lTD IDT 10 P2TD TDT 11P~TD rDT 12 GR TDT 13 TAU i'DT 14 TRAT TDT lb SIGM TDT lb NITD rDT 17 N2TO TDT 18 N]TO TDT 19 ~ITO TDT 20 ~2TD TDT 21 [3TD TOT ['T 0 0 0 GAP1 51 31 ]:2 US 51 41 1 C/C 51 42 1 CO 51 40 1 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 CPS 51 39 1 C~$ 51 39 2 CPS 51 39 3 GAPI 51 31 32 US 51 41 1 C/C 51 42 1 CU 51 40 1 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 0 0 4 1 68 0 0 4 I 6U 0 0 4 1 08 0 0 4 1 68 0 0 4 1 6U 0 0 4 1 68 0 0 4 1 b8 0 0 4 I 68 0 0 4 1 bO 0 0 4 I o~ 0 0 4 1 08 0 0 4 1 b8 0 0 4 1 68 0 0 4 1 68 0 0 4 1 b8 0 0 4 1 68 0 0 4 1 b8 0 0 4 1 08 0 0 4 1 68 0 0 4 I b8 0 0 4 1 b8 DEFINED OUTPUT ARRAY OUTPUT GR AT 2 OUTPUT TAU AT 3 OUTPUT T~AT AT OUTPUT 61GM AT 5 OUTPUT NITD AT 6 OUTPUT N2TD AT 7 OUTPUT N3TD AI 8 OUTPUT F~TD AT 9 OUTPUT F2ID ~T 10 OUTPUT F3TD AT 11 UUI'PUT GR AT 12 OUTPUT TAU AT OUTPUT T~AT AT 14 OUTPUT $1GM AT 15 OUTPUT N1TD Al lb OUTPUT N2~D AT 17 OUTFUT N3TD AT 18 OUTPUT fITD AT 19 OUTPUT F2TD AT 20 OUTPUT fJ~D AT 21 9100.000 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000.000 8900.000 MN~MUNiC GR N1TO F2TD rRAT N3TD GR N1TO ~2TD TRAT N3TD GR N1TD f2TO T~AT N3TO GR N1TD f2TD TRAT N3TD GR N1TD ~2TO T~AT N3TD GR N1TD F2TO TRAT N3TD N1TD ~2TD TRAT N3TD GR N1TD P2TO TRAT N3TD GR N1TD P2TO TRAT N3TD VALUE 51.250 2428.000 201.250 3.662 7O0.OOO Z5.~13 1460.000 201.875 2.27O 693.500 42.094 2330.000 219.500 3.523 740.500 16.922 2060.000 162.375 3.920 727.500 40.750 2350.000 222.125 3.39b 747.5OO 42.063 2358.0O0 205.b25 3.527 735.000 26.484 2162.000 215.750 3.107 753.000 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 MNEMONIC TAU N2TD F3TD SIGN F1TD IAU N2TD F3TD SIGN ~l~O TAU N2TD F3TD SIGN F1TD TAU N2TD F3TD SIGN flTO TAU N2TD F3TD SIGN flTD TAU N2TD F3TD SIGN F1TD TAU N2TD F3TD SIGM F1TD TAU N2TD f'3TD SIGN flTD TAU N2TD f3TO SIGN flTD VAbUE 151.250 1127.000 95.438 29.625 404.000 245.375 028.500 92.563 18.469 365.250 150.750 1071.000 91.375 30.281 408.500 lb8.500 933.000 70.875 27.875 342.000 157.500 1080.000 93.188 28.344 395.500 152.750 1074.000 94.938 29.375 388.500 174.250 982.500 103.875 25.328 375.250 -999.250 -999.250 -999.250 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -965.250 MNEMONIC TRAT N3TD GR N1TD F2TO TRAT N3TD GR N1TD TRAT N3TD GR N1TD P2TD TRAT N3TO GR N1TD P2TO TRAT N3TD GR N1TD P2TO TRAT N3TD GR NITD P2TD TRAT N3TD GR NITD k2TO TRAT N3TO GR N1TD ~2TD TRAr N3TD GR N1TD P2TD VALUE 3.097 b77.000 50.563 2336.000 197.125 2.186 671.500 28.438 1459.000 208.125 3.469 690.000 43.031 2414.000 205.625 4.020 080.500 17.813 2210.000 173.500 3.457 710.500 42.875 2256.000 211.250 3.420 718.500 45.281 2227.000 178.875 3.127 749.000 30.375 2031.000 223.750 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 MNEMONIC SIGN F1TD TAU N2TD F3TD SIGN F1TD TAU N2TD F3TD S1GM FITD TAU N2TD F3TO SIGN F1TD TAU N2TD F3TO SIGN F1TO TAU N2TD F3TD SiGN F1TD TAU N2TD F3TD SIGN F1TD TAU N2TD F3TO SIGN F1TD TAU N2TD f'3TO SIGN F1TO TAU N2TD F3TD VALUE 30.078 414.750 153.500 1075.000 105.313 18.531 353.000 246.250 626.500 94.750 30.15b 422.500 150.125 1102.000 107.438 27.000 320.750 163.125 1015.000 84.000 28.875 405.750 160.375 1032.000 85.053 29.766 409.000 154.875 1015.000 87.063 26.094 385.000 179.500 933.500 101.375 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -965.250 -999.250 -999.250 -999.250 DEPTH 10533.000 10500.000 10400.000 10300.000 10200.000 10100.000 10000.000 9900.000 9800.000 MNEMUNIC GR NITO f2TO TRAT NSTD GR N1TD P2TD TMAT N3TD GR N1TD ~2TD TRAT N3TD GR N1TD f2TO TRAT N3TD GR N1TD f2TD TRAT N3TD GR NITO ~2TO TRAT N]TD GR N1TD TRAT NSTD GB N1TD F2TO TRAT N]TD GR N1TD f2TO TRAT N3TD VALU~ -2U.563 87.250 -10.469 2.926 850.000 36.375 1998.000 202.750 ].]05 616.500 25.797 1610.000 213.500 2.559 644.500 27.891 1514.000 206.500 2.467 631.000 25.172 1480.000 188.250 2.039 642.000 30.563 1535.000 211.125 2.b05 661.000 21.781 1112.500 168.000 1.691 648.500 28.422 2082.000 2O2.875 3.385 704.000 35.000 2400.000 185.125 3.770 756.500 MN ~MUNIC TAU N2TD F3TD SIGM F1TD TAU N2TD f3TO SIGM ~ITD TAU N2TD F]TD SiGM F1TD TAU N2TD fSTD SiGM P1TD TAU N2TD FJTD SIGM F1TD TAU N2TD F3TD SIGM FITD TAU N2TD F3TD SIGM F1TD TAU N2TD f']TD SIGM ~ITD TAU N2TD F3TD SIGM VAbUE -16].250 -62.188 -25.594 23.500 376.500 184.625 895.500 84.938 24.750 365.250 206.000 716.000 104.125 2].000 391.500 239.125 658.000 91.188 18.56] 338.250 239.500 o4].500 86.50] 18.375 3]5.50O 243.625 683.000 77.250 19.344 337.750 300.750 461.000 79.875 15.063 322.500 171.375 946.000 80.313 26.547 355.500 156.000 1108.000 99.688 29.516 4O5.750 MN kMONIC TRAT N3TD GR NITO ~2TD TRA~ NSTD GR NITD F2TD TRAT N3TD OR N1TD TRAT N]TD GR N1TD TRAT NSTD GR N1TD f2TO TRAT N3TD GR N1TO f2TO TRAT N]TD GR NITD ~2TD TRAT NSTD GB NITD f2TO TRAT N]TD GR N1TD P2TD VAbUE 1.397 -161.375 38.250 1913.000 220.750 3.102 503.750 38.250 2013.000 187.250 2.525 534.500 28.422 1748.000 226.875 2.625 547.000 27.266 1464.000 196.500 2.248 566.000 27.844 1400.000 190.250 2.514 575.000 29.281 1568.000 199.625 1.70J 562.500 21.625 1076.000 161.625 3.313 b39.500 25.656 2114.000 213.b25 3.842 684.000 37.344 2450.000 203.125 MN EMONIC $IGM TAU N2TD F]TD $IGM F1TO TAU N2TD F]TD SIGM F1TD TAU N2TO F'3TD $IGM F1TD TAU N2TD $IGM F1TD TAU N2TD F3TD SIGM F1TD TAU N2TD F3TD $IGM F1TD TAU N2TD F3TD $IGM F1TD TAU N2TD F3TD SIGM F1TD TAU N2TD VAb -27 -35 193 876 128 24 383 183 911 92 22 381 197 780 102 19 353 244 635 85 18 337 247 b03 91 18 346 235 700 93 15 334 302 442 74 26 382 171 960 86 29 401 154 1131 104 UE .891 .250 .500 .000 .500 .625 .250 .750 .000 .Ob] .Ob3 .500 .750 .500 .688 .016 .000 .875 .000 .625 .984 .750 .500 .000 .75O .672 .750 .000 .000 .750 .125 .750 .000 .75O .000 .547 .750 .250 .500 .750 .156 .000 .000 .000 .000 DEPTH 8870.000 NNENUBiC GR NiTD F2TO TRAT N3TD VALU~ -999.250 -799.250 -999.250 -999.250 -999.250 MNEMONIC TAU N2TD f3TD SIGM F1TD VALUE -999.250 -999.250 -999.250 -999.250 -905.250 MNSMONIC TRAT N3TD N1TD ~2TD VALUE -999.250 -999.250 -999.250 -799.250 -999.250 MNEMUN1C S1GM F1TD TAU N2TD f']TD VALUE -999.250 -965.250 -999.250 -999.250 -999.250 SUMMARY UF DATA RECORDS NUMBER OK BECORDS: 278 LENGTH OF RECORDS: 1014 B~TES LENGTH OF LAST RECORD: 258 BYTES F1LE TRAILER LENGTH: 62 BYTES kiLL NAME: EDIT .002 MAXIMUM PHYSICAL R~CORD LENGTH: N~XT ~IL~ NAME: 1024 BYTES KILL HEADER LENGTH: 62 B~TkS ~lLk NAME: EDIT .003 MAX1MUM PHYSICAL RECO~D L~NGTH: PR~,VIUUS FILE NAME: FILE COMMENTS PASS~,S 4 & 5 O~ 5 PASS TDT 1024 BYTES DAI'A fORMAT SPECifiCATION bENGTH: 850 BYTES ENTRX 0 SiZ5 REP CODE ENTRY DATUM SPkC1FICAT1ON ~bOChS: NAML IOOb 10EPT 2 GR TDT 3 TAU TDT 4 THAT IDT b $1GM TDT 6 N1TD £DT ? N2TD TDT 8 N3TD TDT 9 P1TD TDT 10 F2TO TDT 11P3TD TDT 12 GR TDT 13 TAU TDT 14 TRAT TDT 15 SiGM TUT 16 N1TD TDT 17 N2TD TUT 18 N]TD TDT 19 ~ITD TDT 20 F2TD TDT 21 [~TD TDT [INIT AP1 APl APl AP1 FILE SIZE SAM RkF PROCESS 1NDICAfOR$ ~T 0 0 0 GAP1 51 31 32 US 51 41 1 C/C 51 4~ 1 CO 51 40 1 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 GAPI 51 31 32 U~ 51 41 1 C/C 51 42 1 CU 51 40 1 CPS 51 ]9 1 CPS 51 39 2 CPS 51 39 3 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 USLH DLFINLD OUTPUT ARRAY OUTPUT GE AT 2 OUTPUT TAU AT OUIPUT TRAT AT 4 OUTPUT SiGM AT 5 OUTPUT NI~D AT 6 OUTPUT N2fD AT 7 OUTPUT N37D AT OUTPUT FITD AT 9 OUTPUT ~2~D AT 10 OUTPUT FSTD AT 11 OUTPUT GH AT 12 OUTPUT TAU AT 13 UUTPUT TRAT AT 14 OUTPUT SIGM AT 15 OUTPUT N1TD A7 lb OUTPUT N2TD AT 17 OUTPUT N3'ID AT 18 OUTPUT F1TD AT OUTPUT F2TD AT 20 OUTPUT ~3~'D AT 21 0 0 q 1 08 0 0 4 1 68 0 0 4 1 b8 0 0 4 1 08 0 0 4 1 (:,8 0 0 4 1 68 0 0 4 1 68 0 0 4 1 68 0 0 4 1 68 0 0 4 1 68 0 0 4 1 6~ 0 0 4 1 68 0 0 4 1 68 0 0 4 1 08 0 0 4 1 08 0 0 4 1 68 0 0 4 1 68 0 0 4 I 08 0 0 4 1 68 0 0 4 1 68 0 0 4 I 08 10533.000 10500.000 10400.000 10300.000 10200.000 10100.000 10000o000 9900.000 9800.O00 MNkMUNIC GR N1TD F2Tu THAT N3TD GR N1TD f2TD THAT NSTD GR N1TD f2TD THAT N3TD GP N1TD F2TD THAT N3TD Gk N1TO ~2TD THAT N]TD NITD ~2TD THAT N3TD GR N1Tb F2TU THAT N3TD G~ N1TD F2TD THAT N3TD G~ N1TD ~2TO TEAT NSTD VAL 91 645 64 2 -772 44 2018 199 3 b15 27 1495 207 2 b21 29 1491 219 2 632 21 1433 192 2 635 29 1506 188 2 660 24 1211 154 1 666 32 2231 214 714 44 2370 205 756 Uk .375 .000 .688 .129 .500 .781 .000 .875 .566 .000 .938 .000 .000 .486 .500 .297 .000 .250 .578 .000 .906 .000 .000 .176 .000 .734 .000 .375 .639 .000 .406 .000 .875 .863 .000 .469 .000 .250 .375 .000 .844 .000 .375 .750 .000 MNEMONIC TAU N2TD f3TD S1GM flTD TAU N2TD f3TD $IGM F1TD TAU N2TD F3TU $iGM flTD TAU N2TD fSTD SIGM FITD TAU N2TD FSTD SIGM flTD TAU N2TD F3TD SIGM FITD TAU N2TD F3TD S1GM FITD TAU N2TD F3TD S1GM F1TD TAU N2TD F3TD SIGM F1TD VALUE 133.125 553.000 274.000 -43.281 -315.500 182.375 915.000 89.625 24.953 389.250 215.250 655.500 99.625 21.641 365.500 241.750 658.000 81.063 19.000 347.500 242.875 635.500 93.125 18.578 3]2.75O 246.315 662.500 90.250 18.297 326.500 283.250 499.500 86.688 15.969 340.250 165.315 1015.500 99.250 26.609 374.500 155.500 1092.000 92.750 29.609 406.250 MNEMON lC rRAT N3TD GR N1TD f2TO THAT NSTD ~R N1TD F2TD THAT OR N1TD ~2TD THAT NSTD GR N1TD b2TO TRAT NSTD N1TD ~HAT NSTD N1TD r2TD THAT N3TD GR N1TD b 2TD THAI NSTD GR N1TD f2TO TRAT N3TD N1TD b2TO VALUE 1.206 652.500 -73.938 -840.000 -135.875 3.189 630.500 44.344 2051.000 203.000 2.502 619.500 29.~59 1565.000 207.750 2.414 639.000 29.500 1525.000 192.375 2.140 556.500 28.672 1444.000 182.750 2.711 058.500 30.531 1509.000 1U5.625 1.757 b5b. O00 22.734 1225.000 185.025 3.501 721.500 36.156 2132.000 204.875 3.000 748.000 41.313 2460.000 204.625 MNEMONIC SIGM F1TD TAU N2TO FSTD 8IGM F1TD TAU N2TD FSTD 8IGM F1TD TAU N2TD SIGM F1TD TAU N2TD ~STD $IGM F1TD TAU N2TO FSTD S1GM FITD TAU N2TD FSTD SlGM F1TD TAU N2TD FSTD SIGM ~ITD TAU N2TD F]TD SlGM F1TD TAU N2TD VAI, 34 496 -105 -584 -168 24 373 182 934 96 21 337 210 685 101 18 372 239 675 97 18 ]32 244 {)17 88 18 325 248 658 89 16 321 284 509 89 27 368 170 97], 90 29 41] 1137 94 UE .156 .000 .125 .000 .000 .938 .500 .250 .000 .938 .125 .500 .125 .500 .000 .813 .500 .315 .500 .250 .719 .;50 .750 .000 .31:) .453 .250 .625 .500 .313 .047 .750 .750 .750 .31~ .500 .000 .875 .500 .438 .250 .250 .500 .000 .125 DEPTH 9700.000 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000.000 8900.000 NNLMUNIC GR N1TD f2TD TRAT N3TD N1TD f'2TD T~AT N3TD G~ NITD f2TU T~AT N3TD GR N1TO f2TU TRAT N3TD GR NITD F2TO TRAT GR N1TD f2TD TRAT N3TD GR NITD ~'2TD TRAT N3TD GR NITD F2TD TRAT N3TD G~ N1TD ~2TD TRA~ N3TD VALUE 51.906 250O.000 223.625 3.592 762.500 31.313 1378.000 188.125 2.076 686.000 44.500 2450.000 202.025 3.629 761.000 22.125 2176.000 173.375 3.951 728.000 44.750 2462.000 232.625 3.477 785.500 40.438 2374.000 199.025 3.580 762.000 29.313 1572.000 165.750 3.188 801.000 -999.250 -799.250 -999.250 -999.250 -999.250 -999.250 -799.250 -999.250 -999.250 -999.250 MNEMONIC TAU N2TD F3TD SIGM FITD £AU N2TD f3TD SIGM F1TD TAU N2TD F3TD SIGN ~ITD tAU N2TD ~3TD SIGN fl'rD TAU N2TD F3TD SIGM F1TD TAU N2TD F3TD SIGN F1TD TAU N2TD F3TD SIGN flTD TAU N2TD f3TD S1GM FITD TAU N2TD F3TD SIGN F1TD VALUE 148.750 1156.000 103.500 30.125 404.000 252.500 587.500 93.750 18.000 360.500 150.125 1134.000 107.500 29.563 398.500 105.000 999.500 77.003 26.375 322.750 153.000 1134.000 102.375 29.344 408.750 149.375 1096.000 93.750 29.719 397.250 206.750 679.500 90.813 25.703 376.750 -999.250 -999.250 -999.250 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -965.250 MNg. MUNIC fRA~ N3TD NiTD f2TD TRAT N3TD NITD f2TO THAi N3TD N1TD f2TD TRAI N3TD GR NITD P2TD TRAT N~TD GR NITD ~2TD TRAT N3TD GR N1TD ~2TD N3TD GR NITD TRAT N3TD GR N1TD ~2TD TRAT N3TD N1TD f2TD VALU . 753. 51. 2448. 227 . , 685. 31. 1386. 197. . 747. 48. 2334. 202. , 744. 19. 2014. 149. . 803. 47. 2458. 210. . 753. 48. 2322. 183. . 720. 29. 2075. 214. -999. -999. -999. -799. -999. -999. -999. -999. -799. -999. 054 500 688 000 375 188 50O 891 000 75O 023 5OO 406 000 25O 887 500 938 000 000 506 000 750 000 375 b13 000 844 000 875 910 000 041 000 250 250 250 250 250 250 250 250 250 250 250 MNEMONIC S1GM F1TD TAU N2TD F3TD SIGN ~ITD TAU N2TD F3TD $1GM f'ITD TAU N2TD f3TD SIGN f'ITD TAU N2TD F3TD SIGN F1TD TAU N2TD f'iTO SIGN FITD TAU N2TO F3TO SIGN FITD TAU N2TD F3TO SIGN F1TD TAU N2TD F{TD SIGM F1TD ]AU N2TD f'3TD VALUE 30.503 405.250 151.000 1127.000 98.750 18.000 346.500 252.625 588.500 95.375 30.297 405.500 153.750 1070.000 98.625 27.503 356.500 172.375 902.500 77.125 29.719 435.000 154.875 1130.000 104.750 30.438 384.000 153.000 1065.000 99.813 22.000 309.500 177.000 948.500 104.375 -999.250 -965.250 -999.250 -999.250 -999.250 -999.250 -965.250 -999.250 -999.250 -999.250 DkPTH 8870.000 MNkMONIC GH N1TO F2TO TRAT N3TD VALUE -999.250 -799.250 -999.250 -999.250 -999.250 NNkMONIC TAU N2TD F3TD $1GM F1TD VALUE -999.250 -999.250 -999.250 -999.250 -965.250 MNEMONIC TRAT N]TD GR N1TD ~2TD VALUE -999.250 -999.250 -999.250 -799.250 -999.250 MNEMONIC SIGM F1TD TAU N2TD f3TD VALUE -999.250 -965.250 -999.250 -999.250 -999.250 SUMMARY U~ DATA R~CORDS NUMBER Ok RECORDS: 278 LENGTH OE RECORDS: 1014 BYTES LENGIH OF LAST RECORD: 258 BYTES FILE TRAILER LENGTH: 62 BYTES ~ILE NAME: EDIT .003 MAXIMUM PHYSICAL ~ECURD LENGTH: N~XT FILE NAME: , $ .t. * .* , * TAPE TRAILER LENGIH: 132 BYTES TAPE NAME: 60702 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT 1APE NAME: COMMENTS: 1024 BYTES DATE: 80/ 9/12 VV VV k~ RR RR VV ~V EL RP RR VV VV EL BP ~ VV VV Eh RP RR VV VV EEEEEEEE RRRRRRRR VV VV EE RH PR VV VV E;E RR RR VV VV EE RR RR VV VV EE RR ~R VV EEEEEEEEE. E R~ RR VV ~EEEEEEEEE PR RR llIIIl 1Iilli 1i II 1I ii 1I Ii Ii 1i ii i1 Iiiiii IIIIIi YY ¥¥ YY YY 000000 000000 44 44 000000 000000 44 44 O0 O0 O0 O0 44 44 O0 O0 O0 O0 44 44 00 0000 O0 0000 44 44 00 0000 00 0000 44 44 O0 O0 O0 O0 O0 O0 4444444444 00 O0 O0 O0 O0 O0 4444444444 0000 O0 0000 O0 44 0000 00 0000 00 44 O0 O0 oO O0 44 00 O0 O0 00 44 000000 000000 44 000000 000000 44 *STAR'I* USE~ PCAL [10707,60713] dUB ShIP SE~. MUN1T(~R SW8 KLIOE40 S~P-80. ~6TART~ fILE: DS~H:¥ERIf~.O04<05I>[10707 60713] CREATE[): PRINTED: 19-SEP-80 11:1~:42 QUEUE SWITCHES: /flLE:fURT /COPIES:I /SPACING:i /LIMi£:120 /fO~MS:NURMAL 4111 DATE lq-SEP-80 19-SLP-80 1l:10:04 11:1]:1~ 11 000000 11 000000 ~111 O0 O0 1111 O0 O0 ll O0 0000 11 00 0000 11 00 00 00 11 00 00 00 11 0000 00 11 0000 O0 11 00 00 11 00 00 111111 0000o0 111111 000000 777777~797 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000000 000000 00 00 00 00 00 0000 00 0000 00 00 00 00 00 00 0000 O0 0000 oo O0 O0 O0 O0 00oo00 000000 7777:~77777 77 77 77 77 77 77 77 77 77 77 77 77 b6606b 000000 6~6666 000000 66 O0 O0 66 O0 OU 66 O0 0000 60 O0 0000 66666066 00 00 O0 66666666 O0 O0 O0 66 66 0000 O0 66 66 0000 O0 66 66 00 00 66 66 O0 O0 666666 000000 066066 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 11 11 1111 1111 11 ll 11 11 11 11 11 lllllI 111111 33 33 33 333333 333333 33 33 333333 333333 ~3 ~3 33 33 33 M M ~M M~~ M M F, M M M M N N AAA N N A A NN N A A N N N A A N NN AAAAA N N A A N N A A 1 1 1 i I 11I *START* MONITOR *START* MONITOR I.j ;5 E R PCAL [10707,60713] 5bS KLIOE40 S~_,P-80. USER PCAL [10707,60713J dUB S~S KLIOE40 SLP-80. *START* SHiP 8EO. 4111 DAT~ DAf'ts lO-hEP-80 11:13:13 lq-SkP-80 11:13:13 SS h~ H~ SS HH HH SSSSSS HHHHHHHHHH $$SSSS HHHHHHHHHH SS HH HH S~ HH HH SS HH HH SS$SSSSS HH HH SSSSS$SS HH HH II II Ii Ii I1 Ii ii II ii II II I1 II ii II II II II II ii II PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP ,S'IA[~T* USER PCAL [10707,bO713J JOb SHIP SEO. 4111 MONITOR SWS ffLIOEqO SEE'-BO. *START* FILE: DS~.HISHIP '10<057>[10707 607131 C~EATED: 19-SEP-80 P~INfE~: 19-SEP-80 OUEUk SWITCHES: /FILE:~(J~T /COPIES:I /SPACING:I /LIMIT: 120 DAlE ~9-SEP-80 10147:27 11:13:15 $ttlP TO CCC~ ,SNTURA~ S~IPP1NG INSTRUCTIONS 1SSULD 19-$EP-80 08130 CALII~., THANKM. MLK PCCC LIS VE, RSi[JN 15,H01 79101126 SCHLUMBERGER COMPUTING C~NTER 10707,6071] REEL hEADE~ LENGTM: 132 BY2E$ REEL NAME: P.C.A.L. SER¥1Ck NAME: EDiT RLEL C(JNTiNUAIiON NUMBER: O! PPLVIOU6 REEL NAME: COMMENTS: LiS PUR~AT CUSTOMER TAPE DATE: 80/ 9/12 TAPE HEADER LLNGJH: 132 BITES TAPE NAME: 00713 DATE: 80/ 9/12 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREV1OU6 TAPE NAME: COMMENTS: TAPE COMMENTS CASING DRILLEI~=l ]. 37 IN @ 48 LB/b~I @ 2505 BiT 6]ZE:12.25 IN 0 10621 PT TYPE, t'LUID IN HOLL:SPLRSLNL DENS=9.8 LB/G VI8C:53 SEC PH :10 FLUID LO85 : 6.2 Mb RM 2.52 078 [~ RMF 2.23 m. IIF RMC 2.~7 fa 68 MAX I~LCORDED TLMP : i65 P- I)IL PUN #1 LOGGED 16-JUL-00 ~II~E HLADL~ LENGIH: 62 PILE NAME: LD1T .001 MAXIMUM PHX$ICAL RLCURD LENGTH: 1024 PRE¥1UUS FIL~ NAME: ~ILE COMMENTS [,SS NOT S~ECIFI~D AS 8-10 COMPANY : MARATHON ~)IL CO. WELl, : TOO D-5 RD FIELD : MCARTHUR RIVER RANGE : ~]~ TOWNSHIP : 8N SECTION : b CUUNT~ : ~LNAI STATE DENSITY ALASKA 800, DA~IA ~UPMAT SPI~CII~ICAT1ON I,ENG ]~H: '~ 70 {C,N'I R Y i~LUCKS: TYPE 0 $IZr; REP CODE ENTR2 1 b6 0 NAMk I'UOL UNIT AP1 AP1 AP1 AP1 ~'ibk SIZE SAM HkP PROCESS 1NDICATOA6 2 SP 3 ]i~D 4 JLM DIL 5 SfLU 6 GR 7 GR 8 CALI LSS 9 DT LSS fT 0 0 0 0 0 4 MV 7 I 0 0 0 4 UHMM 7 12 46 0 0 4 OflMM 7 ]2 44 0 0 4 OHMM 7 22 I 0 0 4 GAPI 7 31 32 0 0 4 GAP/ 60 31 32 0 0 4 IN 60 28 3 0 0 4 05/~ 60 52 73 0 0 4 I 08 I b8 1 68 1 bB I 68 I 68 I 68 I b8 1 68 USLP DE~INLD OUTPUT ARRAY OUTPilT SP AZ[ 2 OUTPUT ILD AT 3 OUTPUT iLS~ AT 4 OUTPUT Sf LO AZ[' 5 OUTPUT GH AT b OUTPUT GI~ A~[ 7 OUTPUT CAbl AT 8 OUTPiIT DT A'I 9 DE P'I H 8RO0.O00 8700.(}00 8600.000 8500.000 840U.000 8300.000 8200.000 8100.000 8000.000 7900.O00 1800.000 7700.000 7600.000 7500.000 7400. 000 7300.000 7200.000 7100.O00 7000.000 SP GR G~ SP SP SP SP GR SP GR Gk SP G~ 6P GR 6P GR GR tJh IC VAL -25 50 -26 99 -74 53 -80 44 -24 67 -50 -80 ]8 -23 91 -18 86 -46 44 -~8 43 ~7 -~4 91 -10 95 -41 41 -42 57 -44 44 -9 ~2 77 UL .625 .281 .781 .875 .813 .281 ,250 .594 .844 .375 .125 .594 .063 .813 .594 .375 .656 .875 .56~, .531 .56~ .000 .250 .188 .35g ,000 .531 .563 .56.~ .219 .250 .188 .281 .094 ,109 ,~69 .328 .b25 kMONiC GR GR JLD Gi~ ILD GR ILD GR ILD GP ILD GR 1LD GP 1LD l LD 1LD GH iLD ILD iLD G~ ILD iLD 1LD VAbtIE lb.484 44.069 15.352 91.]13 8.484 51.469 7.402 37.344 16.969 53.281 7.691 58.219 9.914 37.]75 8.469 93.125 7.660 83.063 13.773 44.]25 10.078 34.313 6.738 ~1.719 5.777 -999.250 8.422 -999.250 10.047 -999.250 6.301 -999.250 6.270 -999.250 5.023 -999,250 19.953 -999.250 ILM CALl ILM CAL! CALl CALl iLM CAL 1 iLM CALl ILM CALl ILM CALl ILM CALl 1 LM CALl CALl CALl ILM CALl 1LM CALl CALl ILM CALl CALl 1 LM CALZ IL~ CALl VALUE 14.9~8 18.703 8.422 19.150 10.125 18.531 9.078 18.078 15.172 18.750 8.188 17.938 13.758 18.438 8.086 18.719 b.512 18.3~4 18.003 18.206 13.008 18.~22 5.727 19.150 5.Ob4 -999.250 7.b37 -999.250 11.417 -999,250 7.313 -999.250 7.020 -999,250 4.746 -999.250 12,~36 -999.250 VAL 12 l 84 14 lB 11 87 118 11 82 44 ~9 l 19 84 25 ~3 ~2 12 4 84 5 -999 ; -999 13 -999 7 -999 7 -999 4 -999 29 -999 UE ,250 .000 .422 .150 .234 ,500 .b25 .188 .125 .805 .025 .O00 .500 .381 .000 .938 .O00 .469 .375 .219 .b25 .555 .OO0 .703 .250 .958 .db0 .594 .250 .992 .250 .551 .250 .~0! .250 .375 .2b0 DEPTH ]0638°000 10600.000 10500.000 10400.000 10300,000 10200.000 lOl00.O00 10000,000 9900,000 9800,000 9700.000 9600.000 9500.000 9400,000 9300.000 9200,000 9100.000 9000.000 8900.000 SP GR GR GE` SP 5P SP GR SP SP GR SP 6P $P 5P $P ON lC VALUL -49.125 41,250 -51.625 39.281 -40.094 60.938 -58.875 49.469 -93.813 37.156 -88.625 40.250 -85.125 48.375 -107.125 36.469 -32.594 51.750 -28.125 07.688 -24.594 96.250 -60.875 44.063 -25.500 81.250 -24.125 50.25O -13.797 79.750 -20.025 79.250 -26.125 43.719 -18.000 87.125 -18.094 92.563 MNLMONiC GE< GR ILD GR ILD ill) GE` GR iLD IL, D GR iLD IL, D GR OR ii,L) OE` ILL) GE, ILD ILD GR GR VALUE 7.8]2 43.063 9.242 43.063 4.523 59.219 27.469 42.094 25.563 43.531 23.781 39.906 18.594 46.156 23.781 35.156 7.887 51.781 7.664 63.719 12.867 90.875 19.297 46.313 14.008 72.188 14.602 25.719 9.898 74.125 9.719 71.250 7.430 38.500 11.375 81,003 8.383 80.813 MNI~MO CAn CAL CAn CAL CAb ILM CAL ILM CAb ILM CAL iLM CAL CAL ILM CAb CAb 1LM CAb ibm CAb I hM CAb 1 LM CAb ibm CAL CAb 1 I 1 1 1 i 1 1 1 i 1 1 1 I 1 1 1 1 1 VALUL 7.168 10.011 7.758 20.250 4.391 19.188 28.938 18.922 23.734 18.563 22.547 18.703 19.813 18.2bO 21.813 18.125 7.809 19.011 8.094 18.734 13.148 18.984 20.20b 18.531 11.992 18.45] 12,930 19,281 9.508 19.297 9,859 17.706 0.457 18.453 10.o25 19.2~b 7.871 18.O41 MN LMUNIC S~bU ,5FDU DT Sl~ L,U DT 5FbO DT SFLU DT $FbU DT SEbU DT ,SFbU DT SFLU DT 6FDU DT SFLU DT $FhU SFbO DT 6FDU DT Sl~hU SFLU D'£ SFLU DT Si~LO DT SI~bU DT VAb 7 7~ 8O 4O bO b7 ~b 7O 75 71 b 7O 10 8~ 15 71 11 b9 2000 9 9 ;1 ;9 9 74 Uk .453 .000 .172 .250 .930 .250 .0]1 .375 .40b .250 .250 .875 .041 .150 .547 .750 .938 .000 .07~ .750 .211 .b25 .563 .025 .805 .375 .000 .750 .b41 .b25 .bOO .500 .391 .125 .b56 .500 .746 .750 6900.000 6800.000 6700. 000 6600.000 6500.000 6qO0.O00 6300.000 6Y00.O00 6100.000 6000.000 5900.000 5800.000 5700.000 5600.000 5500,000 5400.000 5300.000 5200.000 5;00.000 ~M G~ SP G~ SP GR 8P G[~ SP GR SP SP GR SP SP GR SP GR SP GR SP SP Gk SP SP GI~ G~ SP GR SP SP ONlC VALUk -34.500 43.406 -6.281 86.063 -33.750 52.438 -1.563 19.938 3.703 83.438 -3.281 50.031 4.953 51.531 -6.844 39.250 2.750 56,938 2.281 41.969 18.266 80.125 0.219 53.313 20.000 87.625 20.203 87.750 17.000 77.313 18.469 75.500 19.719 79,188 21.531 86.188 21.000 31.438 EMUN1C ILD GR GR GR iLD GR lbD GR GR ILD GR iLD GR lbD GR ILD ILD 1LD GP, IbD GR ILD GR ILD GR ILD GR ILD GR VALIJE 8.734 -999.250 10.523 -999.250 8.602 -999,250 5,480 -999.250 7.652 -999,250 6.504 -999.250 12.914 -999,250 8.891 -999,250 6.039 -999.250 19.688 -999.250 6.059 -999.250 6.793 -999.250 10.969 -999.250 5.707 -999.250 7.773 -999,250 8,383 -999.250 6.797 -999,250 7,996 -999.250 58.000 -999.250 MN ILM CALl ILM CALl ibm CALl 1 LM CALl 1 LM CALl CALl CALl CALl CALl ILM CALl IbM CALl CALl 1LM CALl CALl IbM CALl IbM CAI, iLM CALl CALl 1 LM CALl VALU~ 9.977 -999.250 8.344 -999.250 10.492 -999.250 4.875 -999,250 7.223 -999.250 6.909 -999.250 12.172 -999.250 8.U25 -999.250 5,699 -999.250 17.706 -99q.250 5.129 -999.250 0.844 -999.250 7.809 -999.250 5.141 -999.250 7.465 -999,250 7.395 -999.250 6.188 -999.250 6.906 -999.250 56.319 -999.250 MN EMUNIC SFLO DT SFL, U DT SFhO Df :5FLU DT SI'LO SFLU DT SFLU O't SFLU DT 8FLU DT 8FLU 8FbU DT SFbU SFbU S~bO DT 8FbU 8FbO DT S~bO DT SFLU UT VAbOk 12.83o -999.250 1~.398 -999.250 18.484 -999.250 5.734 -999.250 b.371 -999.250 1.0~b -999,250 12.523 -999.250 8.031 -999.250 5.594 -999.250 ~0.313 -999,250 4.b80 -999.250 0.355 -999.250 10.112 -999.250 5.04~ -999.250 0.855 -999.250 0.832 -999.250 5.5J5 -999.250 b.~63 -999.250 29.234 -999.250 5000.000 4900.000 4800.000 4700.000 1600.000 4500.000 4400.000 ¢)00. 000 4200. 000 4100,000 4000.000 3900.000 5800.000 3700.000 3b00.000 3500.000 3400.000 3300.000 3200,000 6P GR SP SP SP SP SP SP SP SP SP G~ SP VALUf 25,000 b0.15b 26.969 20.141 -15.750 35,188 43.469 86,625 42,250 32,031 35.469 38.031 43,781 47,625 50.b25 67.815 56.750 52,750 24,766 59.063 45,688 65.500 39.000 41.969 51.219 57,063 52,719 59,313 54.219 55.281 58,750 54,563 57,250 58.813 52.719 51,909 58,719 61.063 MNEMUNIC GR 1LD G~ ILD GR GR GR ILD GR GR GP GR GR GR ILD GR GR iLD GR 1LD GR ILD G~ ILD GP GR VALU£ 5,074 -999,250 45,969 -999,250 ],906 -999,250 12,828 -999,250 19,578 -999,250 8.469 -999,250 9,328 -999,250 7,891 -999,250 4,219 -999,250 5,742 -999.250 6,789 -999,250 3,736 -999,250 3,908 -999.250 5,484 -999.250 6,852 -999,250 6,965 -999,250 6.105 -999,250 5,434 -999,250 4.883 -999,250 MNEMON 1C CALl 1LM CAL 1 CALl CALl CALl ILM CALl CALl CALl C ALI CALl 1LM CALl ILM CALl 1LM CALl CALl CALI CALl 1LM CAL 1 CALl CALl VALUE 4.125 -999,250 53.250 -999.250 4,465 -999,250 9,83b -999,250 ~2,852 -999,250 8,039 -999,250 8.102 -999,250 b,914 -999,250 3.811 -999,250 b.469 -999,250 5,875 -999,250 4,5O0 -999,250 3.543 -999,250 4.703 -999,250 5,79/ -999,250 b.859 -999,250 5,078 -999,250 5.535 -999,250 4.227 -999,250 MN~.MONIC SFLU DT SFLU SFLU DT SFI.U Si~ LU DT SFLU DT 5FbO DT SFbU DT fit~bU SFbU DT S~LU DT SFLU DT SFLU DT Si~ bU DT SFbU DT SFbU DT ,5i; bU D'.r SFLU 8FLU Df VALUE 3.840 -999,250 -999,250 o.1~4 -999,250 12.b88 -999,250 23.391 -999.250 ~,411 -999.250 b,64~ -999,2b0 O.lb~ -999,250 13.125 -999,250 7,512 -999,250 0,055 -999,250 5.211 -999.250 3.520 -999,250 4,000 -999,250 4,379 -999,250 5.5~2 -999.250 4.609 -999,250 5.508 -999,250 3,826 -999,250 ]100.000 3000.000 2900,000 2800.000 2700.000 2600.000 2500.000 2480.000 8P G~ SP SP SP SP SP SP SP GR VAL 50 5~ 50 53 ~0 5~ 19 45 57 38 -984 -999 UE .469 .125 .688 .750 .406 .719 .625 .000 .594 .750 .781 .500 .b88 .250 .250 MN kMONIC 1LD G~ ILD GR ILD GR ILD GR GR ILD GR ILD GR VA -99 -99 -99 2 -99 -99 1 -99 2OO -99 -99 -99 5.246 9.250 4.914 9.250 5.434 9.250 4.078 9.250 4.484 9.250 1.063 9.250 0.000 9,250 9.250 9.250 MNkM(JN ] C ILM CALl ibm CALl iLM CALl ILM CALl 1LM CALl CALl CALl CALl VALUk 5.813 -999.250 4.188 -999.250 4.013 -999.250 23.078 -999.250 4.172 -999.250 7.;19 -999.250 1.074 -999.250 -999,250 -999.250 MNkMUNIC SFbO DT SFi,U OT SFLU DT Sl~bU DT SFLU DT SFLU DT SFbU DI' 8FbU UT v AbUI~ 5.852 -999.250 ~.177 -999.250 ~.]lb -999.250 ]2.156 -999.250 3.813 -999.250 11.359 -999.2b0 O.lb7 -999.250 -999.250 -999.250 SUMMA~ O~ OA~A ~ECU~D$ NUMBE~ [3F PkCO~DS: 58] I,ENGTH OF RECORDS: 1014 BITES LENGTH OF LAST RECURD: 762 BY~E~ PiLE ]'RAILER LENGTtt: 62 ~ ILF. NAME: EDIT .001 MAXIMUM PH~t$1CAL HECORD LENGTH: NEXT Elbe NAME: 1024 BYTES ']?APL 3kA1LLP I.kNGTB: 112 t~¥TES TAPE NAME: 60713 SLPVICE NAME: EDiT TAPE CONTINUATION NUMBEI~: 0! NEXT TAPE NAME,: DATE: 80/ 9/12