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Home My WebLink About188-140Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (.o.e) [] w~o-Sided or items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: I ~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) ~ Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI PAGES: [~ (at the time of scanning) SCANNED BY; BEVERLY BREN ~HERYL MARIA LOWELL DATE: ~/~~ ReScanned (done) RESCANNED BY:~ BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COMI\. _ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Repair Well❑ Plug Perforations El Perforate fj Other 0 Complete Performed: Alter Casing El Pull Tubings Stimulate-Frac 0 Waiver 0 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❑ 188-140 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service p 6.API Number: Anchorage, AK 99503 50-733-20150-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL00118729 • Trading Bay Unit D-45 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured , 10,415 feet Plugs measured None feet E C I V ED true vertical 10,108 feet Junk measured None feet VIAY 0 8 2014 Effective Depth measured • 10,340 feet Packer measured 9,036 feet j'h true vertical 10,039 feet true vertical 8,867 feet / OGCC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,492' 13-3/8" 2,492' 2,490 3,090 psi 1,540 psi Production 10,399' 9-5/8" 10,399' 10,094' 6,330 psi 3,810 psi Liner Perforation depth Measured depth See Schematic feet {� True Vertical depth See Schematic feet SAWED JUL 1 6 201q 4 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 9,058'(MD) 8,887'(TVD) Packers and SSSV(type,measured and true vertical depth) Tri-Point Stim-Top Pkr 9,036'(MD) 8,867"(TVD SSSV-N/A 12.Stimulation or cement squeeze summary: p Intervals treated(measured): RBDM MAY 15 2014 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: 0 0 0 174 200 Subsequent to operation: 0 0 0 168 45 14.Attachments: 15.Well Class after work: A Copies of Logs and Surveys Run Exploratory❑ Development 0 Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: 4 Oil 0 Gas ❑ WDSPL❑ GSTOR El WINJ ❑, WAG El GINJ❑ 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: 314-057 Contact Dan Marlowe Email dmarlowe(a hilcorp.com Printed Name Dan Marlowe/� / Title Operations Engineer Signature _- anU `7"2—_ O-- "6-- '1-7 /yJ 7h<<l�z•-#.- hone (907)283-1329 Date 5/8/2014 Form 10-404 Revised 10/2012 1,(y g.23M /� Submit Original Only McArthur River Field, TBU , ii SCHEMATIC Well: D-45 Hico�ni„Ako.I.i,c Completed: 04/08/2014 RKB to TBG Head=41' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 61# K-55 Surf 2,406' 13-3/8" 68# N-80 2,406' 2,407' ., 61# K-55 2,407' 2,490' 68# N-80 2,490' 2,492' A 43.5# N-80 Surf 3,425' 9-5/8" 47# N-80&P-110 3,425' 8,423' 53.5# C-75&P-110 8,423' 10,399' Tubing: 4-1/2" 12.6# L-80,Polycore BTC 4.00" Surf 9,058' JEWELRY DETAIL NO. Depth(MD} ID Item 1 40.6' Tbg Hanger • 2 9,036' 4.00" Tri-Point Stim-Top Production Packer 3 9,049' 2.813" X Nipple 4 9,059' 4.00" WLEG Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Date Status G-1 9,205' 9,245' 9,019' 9,055' 40 6 7/10/1998 Open G-1 9,211' 9,238' 9,025' 9,049' 27 5 04/05/14 Open G-2 9,252' 9,278' 9,061' 9,084' 26 5 04/05/14 Open G-2 9,255' 9,285' 9,064' 9,091' 30 6 7/10/1998 Open phi G-3 9,312' 9,338' 9,115' 9,138' 26 5 04/05/14 Open G-3 9,325' 9,345' 9,126' 9,144' 20 6 7/10/1998 Open ._, G-4 9,355' 9,442' 9,153' 9,230' 87 5 04/05/14 Open X G-5 9,500' 9,520' 9,282' 9,299' 20 5 04/05/14 Open G-5 9,505' 9,525' 9,286' 9,304' 20 6 7/10/1998 Open ' G-5 9,534' 9,555' 9,312' 9,331' 21 5 04/05/14 Open G-5 9,535' 9,560' 9,313' 9,335' 25 6 7/10/1998 Open HE G-1 G-5 9,594' 9,599' 9,365' 9,370' 5 5 04/05/14 Open G-2 G-6 9,626' 9,640' 9,393' 9,406' 14 5 04/05/14 Open __0-3 G-7 9,682' 9,701' 9,443' 9,460' 19 5 04/05/14 Open H-1 9,716' 9,759' 9,473' 9,512' 43 5 04/05/14 Open - 0-4 H-1 9,730' 9,762' 9,486' 9,514' 32 5 6/3/1989 Open =- 0-5 H-2 9,778' 9,873' 9,529' 9,614' 95 5 04/05/14 Open =0-6 H-3 9,900' 9,977' 9,638' 9,707' 77 5 04/05/14 Open - G-7 H-4 9,977' 10,064' 9,707' 9,786' 87 5 04/05/14 Open = B-1 H-4 9,982' 10,070' 9,712' 9,791' 88 5 6/3/1989 Open = B-2 H-5 10,092' 10,200' 9,811' 9,910' 108 5 04/05/14 Open = B-3 H-6 10,230' 10,284' 9,937' 9,987' 54 5 04/05/14 Open B-4 B-5 = B-6 Wil a Updated by: JLL 05/08/14 Plug Back Depth=10,340'MD TD=10,415'MD' Max Hole Angle= 27° Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 Daily Operations: 03/15/14-Saturday Rigging up. 03/16/14-Sunday Rigging up. Rig up slick line to pull tbg patch. 03/17/14- Monday RIH w/slickline w/3" GS tool to 1,877'. Pooh w/AA stop. Retrieve both sections of tbg patch &the A2 Stop. Made a run w/2.80 ga to 9,131' WLM. Pooh. Rig down slick line. Set BPV, N/D tree and remove same. Prep head and remove old studs from head. Install riser spool, choke and kill lines and HCR valves. Install Double BOP's and Hydril. Install accumulator lines &function same. 03/18/14-Tuesday Rig up 3.5 test equipment, pull BPV and install 2 way check m/up test jt and fill stack w/water.Attempt to test pipe rams to high pressure of 3000 psi, had leak on well head,tighten same, retest pipe rams to 250 psi low and 3000 psi high. Continue testing BOP's and related surface equipment to 250 psi low and 3000 psi high.Test made w/water held each test for 5 minutes. BOP testing complete. All valves tested to 250 psi low and 3000 psi high. Witness was waived by Jim 601" Regg on 16 Mar 2014. Rig down test equip. Prepare landing joint. Pull 2 way check. Hang sheave in derrick. Wireline prepping to RIH. Attempt to pull hanger loose, no pipe movement. Staged up to 120k hook load, worked pipe up and down several times. Hanger came loose at 120k hook load. Static hook load 65k, pick up string+/-5. PU wt 83k. Circulate hole. Could not circulate at 1/2 bpm pressure was 450 psi and climbing. Rig down hose. Pull hanger to rig floor. At+/- 15' weight fell to 78k. It appears seals came out of packer. Pipe u-tubed when seals dumped.Shut TIW. After closing TIW fluid on annulus dropped. Open TIW. Monitor well. Well stable. Pull hanger to rig floor. Break out hanger. Install TIW onto 3 1/2 DSS HTC tubing. Shut in well. Rig down wireline. Rig up to circulate. Circulate hole at 22 bbls gas alarm in pump house went off. Shut down pump.Shut in well. Monitor until gas units dissipate. Circulate hole at 1 bpm taking returns through gas buster. 03/19/14-Wednesday Circ &condition fluid at 1.5 bpm at 42 psi. Had H2S gas alarm.Secure well. Mustered, had tool box meeting, vented pump room. Rig up return line to production. Circ at 1.5 bpm at 160 psi taking return thru production weighting fluid to 8.8 ppg. Pump total of 492 bbls.At 492 bbls had clear fluid back at return line. Circ&condition fluid pumping at 4 bpm, getting a dirty gray colored fluid back at shaker. Open well tbg, u-tbg mix at 20 bbls 9.0 ppg slug and pump same. Monitor well (well static). POOH laying down 3.5" 9.3 DSS-HTC production tbg. Swap out hyd tongs due to a broken roller.Tbg u-tbg. Cir down tbg w/53 bbls total. Shut down pump-well static. Continue laying down 3.5" 9.3# DSS-HTC. Continue laying 3.5" 9.3# DSS-HTC. Total laid down = 200 jts. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 03/20/14-Thursday Service rig & held JSA. Continue POOH laying down 295 jts (9,109 ft) of 3.5" 9.3# L-80 PL, DSS-HTC production tbg. Had full recovery of seals. R/D 2" BJ tongs and rig up 3"tongs. Clean floor. P/u BHA from deck. Make up BHA= Rotary wash pipe shoe, 8-1/8" x 6.025", bushing, oil jar, (4) 6-1/2" drill collars, ACC jars= 154.28'. Make up x/overs and change out dies on power tongs. P/up 3.5" PH-6 workstring. 200 jts picked up at rpt time = 6,200 ft+/-. 03/21/14- Friday Grease &service rig. Held JSA prejob meeting. Continue picking up 3.5" PH-6 workstring from V-door and strapping same. Tag,.Packer at_9,101' dpm. Nipple up pack off head and spot power swivel power pack behind rig and route hyd hoses. Reverse circ 1 tbg volume. Tagged packer, burning on pack w/2k wob, at 60 rpm,torq 4/5k pumping at 3.5 bpm 340 psi. Made total of 19 inches. L/D 1 jts of tbg, well u-tbg, mix and pump 5 bbls of 9.2 #slug & monitor well. R/D power swivel. POOH. 59 pound of metal f/ magnets. "0" fluid loss. 03/22/14-Saturday Grease & service rig. Held JSA. POOH w/3.5" PH6. Swap out BHA handling equipment. Break off shoe. 5-3/4" piece of the packer was broke off in shoe. Make up 8-118" burning shoe & BHA. RIH w/same. TIH w/3.5" PH 6 workstring to 9,101' dpm. Rigging up power swivel and pack off. Reverse circ btm up at 3 bpm 290 psi ( had no gas ). Burning over packer at 9,102.7' dpm w/ 60 t/80 rpm, torq 2500 to 5200 ft/lbs, wob 2/10k. Could not make any hole. Attempt to dry drill. Spudded on same, tried various combinations of weight and rpm w/ pump rate changes, with no success. Rig down power swivel and pack off. Blowed down lines. POOH w/3.5" PH 6 workstring to look at shoe. 03/23/14-Sunday Grease & service rig. Held JSA. POOH w/ 3.5" workstring. POOH w/ BHA. Change burning shoe. Had a piece of metal ring stuck in shoe like a protector. Inside of shoe worn. RIH w/workstring. Rig up packoff and power swivel. Reverse circ, at 3 bpm, 260 psi milling on packer at 60 rpm, torq 2 t/5200k, wob 2/12 k. Continue to mill on packer. Swivel packing leaking. Call for spare swivel. Rig up same. Continue to mill over packer. Have a total of 5 inches this milling run. Metal recovered 23 lbs. "0" losses. 03/24/14- Monday Milling on packer f/9,102.5 to 9,103.93.w/60 t/80 rpm, 2500 to 5200 ft lbs of torque, w/ 5 to 15 wob, pumping f/ 1 bpm to 4 bpm w/50 psi to 300 psi. At rpt time 9,103.93. Packer broke free, push packer to 9,116 ft w/ no problems. Circ Btm/ up. Change out x/over sub on power swivel & lay down same. POOH w/3.5" PH-6. POOH w/ BHA burning shoe assembly. Making up spear BHA. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 03/25/14-Tuesday Review JSA w/crew& service. P/u & M/u spear assembly. RIH w/3.5" Ph-6 workstring& BHA to 9,116' dpm. Continue in hole picking up singles off the deck,tagging at fish 10,164' dpm, w/5k dn. Push fish down to 10,187' setting 20k dn on same. P/u with 2k extra over pick up weight, check well -well static. POOH laying down 10 jts. Continue POOH w/work string. POOH & lay down spear assembly. Had no recovery on fish. Rigging up 3.5" test equipment.Testing Bop's and related surface equipment to 250 low and 3000 psi high, held each test 5 minutes. Witness of test waived by Jim Regg, AOGCC.Test made w/water.All good test. Rig down 3.5" test equipment. Rigging up to test w/4.5" test equipment. 03/26/14-Wednesday Review JSA w/crew. Rigging up to test bops w/4.5 pipe.Test VBR rams& annular w/4.5 pipe to 250 low and 3000 psi high. Rig down test assembly. Slip and cut drill line 108'. Brk down spear assembly. Make up 8-1/8 overshot w/6" grapple. TIH w/ BHA on 3.5 work string. Continue trip in hole w/3.5 PH-6 workstring. Trouble shoot system. Continue TIH PH6 workstring. Continue TIH picking up 7 jts 3.5 ph-6 work string. R/u power swivel & pack off. Wash down Tag at 10,188' dpm. Cont. washing down to 10,207' dpm. Attempt to make connection, pipe u-tubing. Continue to circ until 8.8 ppg around. Wash down f/ 10,207' dmp at 2 bpm 120 psi. Tag top of fish at 10,217'.Work over top of fish, did not have a increase in pump pressure, could see when we went over top of fish, set 20k down on fish, only had 2k increase in pick up wt. Rig down power swivel. 03/27/14-Thursday Held JSA& pre job meeting. R/d pack off head. Pooh w/3.5 drill pipe to 8,968 ft. Pooh f/8,968 ft.Work BHA. Picking up BHA.Trip in hole w/3.5 work string. Rigging up power swivel and pack off. Wash down, latch fish at 10,217 ft. P/u to 170k,jar one time at 170k, fish came free. Had 3 k over pull on fish and pipe plugged, laying down power swivel. 03/28/14- Friday Review JSA WI crew& service rig. R/d power swivel & pack off.Attempt to Pooh- pipe stuck-work same free max pull 160, work same down pipe came free. Rig up TIW valve and circ hose attempt to rupture disc, pressure up to 4k no success. Rig down lines and rig up mud bucket. Pooh w/wet string. At stand 115 out(7,318) pipe started pulling dry. Pooh w/ BHA. Lay down fish had full recovery of tail pipe assembly. P/u BHA Mill and scrapper assembly( 8-3/8 mill, bit sub, (4) 6-1/2 drill collars x/over= 138.78'). RIH w/Scrapper assembly. P/u scrapper assembly at 1,008' dpm. Trip in hole w/workstring tagging obstruction at 9,252' work back up thru same. Pull one stand, lay down two jts, rig up power swivel. 03/29/14-Saturday Held JSA. Laid out 2 jts of 3.5 ph-6 & RIH w/ 1 stand out of derrick. Rig up power swivel & pack off. Reverse circ at 340 psi, 3 bpm, reaming tight spot at 9,187' dpm.Tag again at 9,190' dpm, wash and ream to 9,197'. Made connection and wash down to 9,250'.Attempt to lay out power swivel -fluid u-tubing, continue to reverse circ until fluid was 8.8 ppg in & out. R/d power swivel and pack off.TIH to 10,175 ft without any problems. Rig up power swivel and pack off. Wash down f/ 10,175'to 10,317' dpm. Reverse circ at 2 bpm, 180 psi, circ a tbg volume every 1/2 jt at 3 bpm, 350 psi,getting a large amount of sand back at shakers. Sand color from black to brown. No loss of fluids to well. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 03/30/14-Sunday Reverse circ at 10,317' at 3 bpm 490 psi, working pipe until returns clean. Rig down & lay out power swivel. Rig down pack off. Lay out 1 jt. Made 15 std wiper trip f/ 10,317'to 9,385'. Rig up and reverse circ at 3 bpm 430 psi. Dump and clean suction tanks. Building fluid in suction pit. Displace well with clean 8.8 ppg fluid at 2 bpm, 240 psi. Pump total of 710 bbls plus suction tank volume 100 bbls= 810 bbls. Rig down pump lines and monitor well ( well static). Pooh to scrapper. Continue to pooh, lay down BHA. 03/31/14- Monday Service rig& held JSA. Lay out mill assembly. Clean & clear floor of pipe handling equipment. Make up RTTS tool &trip on hole to 9,051' dpm at 100 f/m. Space out and set RTTS at 9,051' dpm w/20k do wt. Pressure test 9-5/8 csg to 2500 psi on chart for 30 minutes,first test the pressure bleed f/2550 psi to 2360. Check surface equipment and reset RTTS AT 9,010'. Pressure test csg to 2550 psi for 30 minutes on chart pressure bleed f/2550 to 2450 in 30 minutes. Pooh w/3.5 ph-6 w/string. Lay out RTTS tool &x/overs. Make up mule shoe and TIH w/30 stds 3.5 ph-6 work string. Pick up RTTS tool and remove slips and run in hole w/3 std on top of tool. 04/01/14-Tuesday Attempt to test the storm valve & RTTS tool to 1500 psi on chart, pressure bleed to 950 psi in 11 minutes. Contact Mr. Bob Noble w/AOGCC, who postpond the tbg spool change out until we get the pressure test on storm valve, pressured up to 1500 psi again. Bleed down to 1200 psi in 7 minutes, pull one stand attempt to test to 1500 psi at 120'. Bleed down to 1200 psi in 15 minutes. Called out for back up RTTS set same at 180' press bleed f/ 1500 psi to 950 psi in 11 minutes. Attempted to test again. Pressure bleed f/ 1500 psi- press bleed to 750 in 15 minutes. RIH to 627', had returns on the work string. Pooh & lay down RTTS. Pooh w/work string. RIH T/ 1,251', press bleed 150 psi in 15 minutes. RIH to 1,873'. Press bleed down 50 PSI. Pooh to 627' unable to get test. Pooh w/work string. 04/02/14-Wednesday Attempted to get the RTTS tool and by pass to test to 1500 psi at 940, 627, & 752 ft. appeared to not be enough wt to close the by pass. POOH, lay down RTTS tool. Packed well head w/valve grease.TIH w/30 stds ph-6 workstring. M/u RTTS and by pass.TIH TO 317 FT, set RTTS and pressure up on RTTS and bypass to 1500 psi in 500 psi increments for 15 minutes (good test). POOH and set RTTS tool at 192' dpm.Test RTTS and csg to 1500 psi for 15 minutes(good test ). Pooh w/3.5 workstring& lay down, by pass and make up RTTS&storm valve set same at 192'dpm. POOH w/3.5 work string and stringer. Pressure up to 1500 psi on storm valve and 9-5/8 csg to 1500 psi for 30 minutes (Good Test). Drain stack, making ready to nipple down tbg spool. Check the 13-3/8 x 9-5/8 annulus to verify 30 psi reading change gauge pressure reading 110 psi, bleed pressure to "0" monitor same, pressure increased to 30 psi in 7 minutes, shut down water flood on well 9-15 to see if feeding the 13-3/8 x 9-5/8 annulus on D-45 pressure stabilized at 45 psi in 30 minutes. Rig up 2" line to the 13-3/8 x 9-5/8 annulus monitor pressure build up in 30 minutes intervals pressure stabilizing at 31 psi getting 8.6 ppg fluid back. Monitor pressure for one hr. pressure increased to 20 psi, bleed to '0' in 20 seconds. Monitor pressure, pressure build up f/0 to 22 psi in two hrs. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 04/03/14-Thursday CONT BLEEDING OFF 13-518 CSG TO PROD WELL CLEAN TANK AND WEIGHING RETURNS (8.5PPG). MONITOR CSG. CSG STATIC. BLEED OF ACCUMULATOR, REMOVE WING VALVES AND KOOMEY LINES FROM STACK. REMOVE FLOOR PLATES FROM RIG FLOOR AND RIG UP BLOCK ON STACK TO PULL SAME, WHILE NIPPLING DOWN 13-5/8" X11"TBG SPOOL. HELD PJSM W/ALL ESSENTIAL PERSONNEL PRIOR TO PICKING UP ON STACK AND BREAKING SEAL ON TBG HEAD. PICK UP ON STACK PULL TBG SPOOL FREE. LAND TBG SPOOL AND NIPPLE DOWN RISER FROM SAME. P/U BOP STACK APPROX 6' AND REMOVE TBG SPOOL. ASSIST CAMERON REP PREP CSG HGR SPOOL AND INSTALL NEW TBG SPOOL. LAND BOP STACK AND RISERS. INSTALL WING VALVES ON STACK. M/U KOOMEY LINES AND N/U 11" X 5M BOPS AND TBG SPOOL. CONT' TO N/U 11"X5M BOPS, WING VALVES, 9-5/8" TBG SPOOL, & RISER. INSTALL POLLUTION PANS ON BOPS. CHECKED PRE- CHARGE ON NITROGEN BOTTLES ON KOOMEY UNIT. ASSIST CAMERON REP PACK SECONDARY P-SEALS IN TBG SPOOL& TEST SAME TO 3000 PSI FOR 30 MINS.ASSIST CAMERON REP PACK VOID W/GRAPHITE PLASTIC PACKING TO 3000 PSI. OFF- LOAD &STRAPPED 4-1/2" PRODUCTION TBG. INSTALL 1502 FLANGE ON CSG VALVE & R/U 2" DRAIN HOSE ON SAME. PRESSURE UP ACCUMALATOR & BOPS FUNCTIONED SAME. F/U STACK& R/U TO TEST TBG SPOOL.TESTED TBG SPOOL TO 1500 PSI FOR 30 MINS ON CHART DATED 4-3-2014 AS PER HILCORP PROCEDURE. P/U 3-1/2" TEST ASSY& M/U SAME. RIH & SET TEST PLUG. R/U TEST EQUIP. GREASED/WORK ALL VALVES ON CHOKE, CIRC., &S/P MANIFOLDS F/U ALL SURFACE LINES & PRESSURED UP ON BOPS, SAFETY VALVES, & MANIFOLDS CHECKING FOR LEAKS. PERFORMED GENERAL HOUSEKEEPING AROUND RIG. 04/04/14- Friday CONT GENERAL HOUSE KEEPING WHILE WAITING ON AOGCC REP BOB NOBLE TO ARRIVE & WITNESS BOP TEST.TEST 11" X 5M BOPS RAMS, ANNULAR &SURFACE EQUIPMENT TO 250 LOW/3000 HIGH ON CHART FOR 5 MINS.TEST FROM REMOTE AND FUNCTION MAIN. TEST DONE WITH 3-1/2"TBG. R/D 3-1/2" TEST ASSY AND M/U 4-1/2"TEST ASSY. LAND 4- 1/2" TEST ASSY. &TEST RAMS AND ANNULAR TO 250 PSI LOW/3000 PSI HIGH ON CHART FOR 5 MINS. BOB NOBLE WITH AOGCC WITNESSED TESTING. HAD A TOTAL OF 3 FAIL/ PASS. R/D TEST EQUIPMENT& PULL TEST PLUG. RIH WITH 3-1/2" PH-6 LATCH RTTS PACKER AND STORM VALVE, OPENED VALVE, MONITORED WELL( WELL STATIC) & POOH WITH SAME. RIH WITH WEAR BUSHING AND SET SAME IN WELL HEAD. HELD SAFETY MEETING JSA ON PU & MU TCP GUNS & EQUIPMENT. PU & MU FAST FIRE GUAGE CARRIER AND GUAGES, (52) 4-1/2-SSPF TCP GUNS, FIRING HEAD 1 JT 2-7/8" TBG, & R/A TAG SUB, RIH WITH TCP ASSY& 3-1/2" PH-6 WORK STRING. 04/05/14-Saturday SERVICE RIG AND SAFETY CHECK. CONT TIH W/TCP ASSY AND 3-1/2" PH6 SLOWLY TO 10,280' DPM DRIFTING WORKSTRING OUT OF DERRICK. REVIEW JSA ON RIGGING UP E-LINE. ASSIST PRIORITY R/U E-LINE EQUIPMENT AND HANG SHEAVE IN DERRICK. M/U 1-11/16" GAMMA RAY & 1-11/16" WEIGHT BAR. TEST LUBRICATOR TO 2500 PSI. RIH W/E-LINE TO 9,058' ELM AND CORRELATE GUNS ON DEPTH. GUNS 23'TOO SHALLOW. POOH W/E-LINE. R/D LUBRICATOR &SPACE OUT GUNS ON DEPTH. M/U LUBRICATOR AND RIH W/E-LINE TO 9,082' ELM AND CORRELATE GUNS ON DEPTH.TOP SHOT @ 9,211', BTM @10,284'. POOH W/E-LINE AND R/D SAME. DROPPED 1.75" BAR & FIRED GUNS. PUMP 13 BBLS DOWN BACKSIDE UNTIL HOLE FULL. MONIORED WELL& ESTABLISHED A FLUID LOSS RATE OF 2 BPM. POOH 1100' (17 STNDS) MONITORED WELL WHILE ASSISTING PRODUCTION. CONT TO MONITOR WELL ( -2 BPH). POOH W/3-1/2" DP &TCP GUN ASSY. B/O & L/O TCP GUNS, TOTAL FLUID LOSS = 20 BBLS. i Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-45 50-733-20150-01 188-140 3/15/14 4/8/14 04/06/14 -Sunday SERVICE RIG. CONT POOH W/TCP GUNS AND LAYDOWN SAME (ALL SHOTS FIRED). REMOVE ALL HANDLING TOOLS FROM RIG FLOOR FOR TCP ASSEMBLY. WASH AND CLEAN RIG FLOOR AND PREP SAME TO TIH W/4-1/2" PRODUCTION TBG. M/U 9-5/8" PRODUCTION PACKER AS PER TRI-POINT REP. P/U 4-1/2" PRODUCTION OUT OF V-DOOR AND RIH W/SAME. STRAP AND RABBIT EACH JT. CONT. P/U 4-1/2" PRODUCTION OUT OF V-DOOR AND TIH SAME. CONT. P/U 4-1/2" PRODUCTION OUT OF V-DOOR AND TIH SAME. Depth At 06:00 = 9000', FLUID LOSS= 48 BBLS TOTAL FLUID LOSS = 68 BBLS. 04/07/14- Monday SERVICE RIG AND CONTINUE IN HOLE WITH 4-1/2" INJECTION STRING. P/U HANGER AND LANDING JT AND LAND SAME. CONNECT KELLY HOSE TO LANDING JT. R/U RETURN HOSE FROM CSG.VALVE TO RIG TANKS. CIRCULATE 8.8 INHIBITED FLUID AROUND @ 2 bpm 40 PSI TOTAL PUMPED = 620 BBLS. HELD PJSM W/ESSEINTIAL PERSONNEL ON RIIGING UP EXPRO SLICK LINE UNIT AND EQUIPMENT AND SPOT SAME IN PLACE. R/U EXPRO SLICKLINE AND P/U LUBRICATOR. P/U 2.82" G/R & RIH W/SAME TO 9,028' SLM. POOH & P/U 2.81" PX PLUG & RIH TO 9,032' SLM & SET SAME. P/U 2.82" G/R & RIH W/SAME TO 9,028' SLM. POOH & P/U 2.81" PX PLUG & RIH TO 9,032' SLM &SET SAME. R/U CIRC EQUIP TO PUMP DWN TBG AND SET PKR. WITH 3500 PSI. R/U CIRC EQUIP TO PUMP DWN BACK-SIDE. L/U AND TESTED PKR&CASING TO 2500 PSI, FO_R 30 MINS ON CHART. P/U SB R/R TOOL AND RIH WITH SLICK LINE TO PULL PLUG PRONG. Fluid loss = 50 bbls Total losses 108 bbls. 04/08/14-Tuesday EXPRO SLICK LINE CONT RUN IN HOLE WITH 3" GS RETRIEVING TOOL TO 9,032' SLM. LATCH "PX" PLUG & POOH WITH SAME. R/D SLICK LINE LUBRICATOR AND ALL EXPRO EQUIPMENT. B/O AND L/0 LANDING JT.ASSIST CAMERON REP INSTALL BPV. R/D WEATHERFORD TONGS AND REMOVE FROM RIG FLOOR. N/D 11" X 5M BOPS AND RISERS. INSTALL PRODUCTION TREE AND N/U SAME. TEST VOID TO 5000 PSI "OK". PULL BPV AND INSTALL 2-WAY CHECK, BODY TEST TREE TO 3500 PSI. TURNED WELL OVER TO PRODUCTION @ 18:00 HRS. 'a.OU�gy ��z..._a..�...�..qqqqry --�.,-r..�,�_.�. .�.<.-....ga ,.ns�-mss • e' y� [��y IAT fc ,n C ' ittA r COVERNOR SEAN � 333 West Seventh Avenue z_1 R N F I.I Anc.horace Alaska 09501 3572 Main 907.279 12,33 «, � Dan Marlowe g�r / �O Operations Engineer 1- Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-45 Sundry Number: 314-057 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, /))41-e-,) Cathy P. Foerster Chair 51- DATED DATED this,31 day of January, 2014. Encl. RECEIVED STATE OF ALASKA JAN 2 312014 ALASKA OIL AND GAS CONSERVATION COMMISSION 0.—C l /f e APPLICATION FOR SUNDRY APPROVALS /`J GC 20 AAC 25.280 AO GC Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ ' Pull Tubing❑ . Time Extension❑ Operations Shutdown El Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Camdete • 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development ❑ 188-140 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service 0 ' 6.API Number. Anchorage,AK 99503 50-733-20150-01 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A / Will planned perforations require a spacing exception? Yes El No 0 / Trading Bay Unit-D-45• 9.Property Designation(Lease Number): 10.Field/Pool(s): , ADL00118729 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,415 • 10,108 • 10,340 10,039 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,492' 13-3/8" 2,492' 2,490' 3,090 psi 1,540 psi Production 10,399' 9-5/8" 10,399' 10,094' 6,330 psi 3,810 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.3#N-80 9,124' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Otis BDW Packer&SSSV-N/A 9,109'(MD)/8,933'(ND) /SSSV-N/A 12.Attachments: Description Summary of Proposal (] • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 ' Exploratory ❑ Stratigraphic❑ Development❑ Service 11 • 14.Estimated Date for 15.Well Status after proposed work: 3/1/2014 Commencing Operations: Oil El Gas ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ [] • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ 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 Pho (907)283-1329 Date 1/23/2014 " / / 2 ,17.I-1- - 01 r-1 : . COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ `-f- bl-1 Plug Integrity ❑ BOP Test LH// Mechanical Integrity Test V Location Clearance ❑ Other: 7( go40 fS SOP P 7 - F ABDM MAY U 9 2014 Spacing Exception Required? Yes ❑ No Il Subsequent Form Required: /O —y d / / APPROVED BY Approved by: p a, COMMISSIONER THE COMMISSION Date: /—3/_. N 01 eilz ti2.7111 ,40.0, /, 7207 7 Submit Form and Form 10-403(Revised 10/2012) ApprogiliGh1.41Alimonths from the date of approval. Attachments in Duplicate • Well Work Prognosis Well: D-45 Hilcorp Alaska,LLC Date: 01/24/2014 Well Name: D-45 API Number: 50-733-20150-01 Current Status: Injector Leg: Leg#A-2 (NW corner) Estimated Start Date: March 01, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 188-140 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 AFE Number: The well is currently injecting at 3400 psi. When the well is shut-in, the pressure falls off rapidly and fluid level stabilizes just below the surface. The estimated pressures shown below are consistent with previous shut-in pressures, and observations of surrounding wells. Current BHP: —3950 psi @ 9450'TVD/9690'MD 0.42 psi/ft,(8.1 ppg)mid perf of GZ&HK Max.Expected BHP: —3950 psi @ 9450'ND 0.42 psi/ft.(8.1 ppg)Recomplete same zones Max.Possible SP: 0 psi Using 0.435psi/ft SW gradient to surface Brief Well Summary (? l lk On November 1, 2012 the casing pressure spiked from 130 psi to over 500 psi and was shut-in immediately. The well was taking about 1000 bwipd before it was shut-in. A hole was found between 1875' and 1880' and on 3/26/13 a patch was installed from 1857' — 1884' that tested good. The well was placed back on injection on April 1, 2013 and is currently injecting about 800 bwipd at 3400 psi TP and 200 psi CP. The tubing is plastic coated but is likely to have scale and corrosion. It is estimated that 3500 bwpd can be injected into the G-zone and Hemlock once all fill is cleaned out, zones are re-perforated, tubing is replaced, and injection is resumed at full header pressure. ✓ Notes Regarding Current Wellbore Condition • Communication between tubing and the tubing by casing annulus isolated with tubing patch at 1,857' Procedure: • 1. Skid rig and RU HAK Rig 1 over D-45. 2. RU slick-line and remove the patch at 1,857' ' 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 3,000psi HIGH. • 4. RU E-line.Cut tubing in middle of first full joint above seals. POOH and RD E-line. • 5. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 6. POOH, LD tubing. 7. RIH latch onto tubing stub, release and POOH with seals and tail-pipe. 8. Mill and retrieve injection packer. 9. Clean out fill to a PBD of 10,340'.Circulate with FIW to clean wellbore. POOH — 10. PU retrievable test packer and RIH to 9,050'. Set packer, test casing to ^'2,500 psi and chart for 30 minutes. • Well Work Prognosis Well: D-45 Hileorp Alaska,LLC Date: 01/24/2014 11. 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 tubing head. --''74;54- A-1( )P///. 12. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. 13. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 14. After detonation,circulate perf gas, confirm well is static, POOH. 15. PU injection packer and 4-1/2" plastic lined tubing. RIH, with packer at ±9,050' within at 200' of top perforation. 16. Spot 1-2%by volume Packer fluid on backside. 17. Land the tubing hanger and set packer. 18. Conduct WO MIT, pressure test annulus to^'2500 psi and chart for 30 minutes. 19. Set BPV. NU tree,test same. 20. Place well on injection. Well is expected to take between 2,000 and 4,000 bwpd at full header pressure and new perforations. 21. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. "- Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack Arthur River Field,TBU 111 SCHEMATIC Well: D-45 As Completed: 6/5/1989 Ililrorp Alaska,LLC CASING DETAIL Size Wt Grade Conn ID Top Btm 1 61# K-55 Surf 2,406' 13-3/8" 68# N-80 2,406' 2,407' 2 61# K-55 2,407' 2,490' Immo X 3 68# N-80 2,490' 2,492' 4 nommi 43.5# N-80 Surf 3,425' 9-5/8" 47# N-80,P-HO 3,425' 8,423' 53.58 C-75,P-110 8,423' 10,399' TUBING DETAIL -- -.\ 3-1/2" 9.3# N-80 DSS-HTC 2.92" Surf 9,124' L JEWELRY DETAIL Patch installed 1,857'-1,884' No Depth ID Item 1 40.6' 3.5" Cameron FBB S/S Tbg Hanger 2 318' 2.88" Flow Coupling BxP IPC w/TK69 3 324' 2.813" Otis X Nipple 4 325' 2.88" Flow Coupling BxP IPC w/TK69 5 Otis Straight Slot Locator w/seal ext and seal 9,109' 2.99" mandrels w/16.7'seals 5 6 9,109' 4.00" Otis BWD Packer w/SBE and millout ext. 6 7 9,124' 2.99" Muleshoe 7 8 9,137' 2.99" 8RDx3.5"ETC PXP Crossover 9 9,169' 2.813" Otis XN Nipple w/2.75"NoGo XO 8 10 9,170' 2.99" Otis W/L Entry Guide 1 ;a. 41 9 10 mom amir PERFORATION DETAIL Zone Interval(MD) Interval(TVD) Date G-1 9,205' 9,245' 9,019' 9,055' 7/10/1998 G-2 9,255' 9,285' 9,064' 9,091' 7/10/1998 G-3 9,325' 9,345' 9,126' 9,144' 7/10/1998 G-4 9,355' 9,375' 9,153' 9,190' 7/10/1998 0-5 9,505' 9,525' 9,286' 9,304' 7/10/1998 .N. 0-5 9,535' 9,560' 9,313' 9,335' 7/10/1998 B-1 9,716' 9,730' 9,473' 9,486' 11/18/1989 -'` B-1 9,730' 9,762' 9,486' 9,514' 6/3/1989 5/3/00:2.70" B-2 9,781' 9,783' 9,531' 9,533' Squeezed GR tagged up at 10,294' - B-2 9,886' 9,888' 9,626' 9,627' Squeezed l - B-3 9,900' 9,914' 9,638' 9,651' 6/3/1989 B-3 9,944' 9,976' 9,678' 9,706' 6/3/1989 i B-4 9,982' 10,070' 9,712' 9,791' 6/3/1989 / , B-5 10,092' 10,146' 9,811' 9,860' 6/3/1989 PBTD=10,340' TD=10,415' B-5 10,156' 10,176' 9,870' 9,888' 6/3/1989 i McArthur River Field, TBU PROPOSED Well: D-45 Il v%I k Completed: Future ttemF RKBtoTBGHead=41' CASING AND TUBING DETAIL i SIZE WT GRADE CONN ID TOP BTM. 61# K-55 Surf 2,406' 13-3/8" 68# N-80 2,406 2,407' 61# _ K-55 2,407' 2,490' 68# N-80 2,490' 2,492' A \ 43.5# N-80 Surf 3,425' 9-5/8" 47# N-80&P-110 3,425' 8,423' 53.54 _ C-75&P-110 8,423' 10,399' $ Tubing: 4-1/2" 13.55 L-80,Polycore BTC 3.40" Surf ±9,128' JEWELRY DETAIL NO. Depth(MD1 Depth ID Item f TVD 1 40.6' Tbg Hanger 2 ±9,050' Tri-Point Stim-Top Production Packer A I. 3 ±9,097' X Nipple 4 ±9,128' WLEG Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Date Status G-1 9,205' 9,245' 9,019' 9,055' 40 6 7/10/1998 Open G-1 ±9,211' ±9,238' ±9,025' ±9,049' Future G-2 ±9,252' ±9,278' ±9,061' ±9,084' Future G-2 9,255' 9,285' 9,064' 9,091' 30 6 7/10/1998 Open i G-3 ±9,312' ±9,338' ±9,115' ±9,138' Future G-3 9,325' 9,345' 9,126' 9,144' 20 6 7/10/1998 Open G-4 9,355' 9,375' 9,153' 9,190' 20 6 7/10/1998 Open 2 Sgi G-4 ±9,355' ±9,442' ±9,153' ±9,230' Future 3 U G-5 ±9,500' ±9,520' ±9,282' ±9,299' Future >i G-5 9,505' 9,525' 9,286' 9,304' 20 6 7/10/1998 Open 4 • �� G-5 ±9,534' ±9,555' ±9,312' ±9,331' Future G-1 G-5 9,535' 9,560' 9,313' 9,335' 25 6 7/10/1998 Open - G-5 ±9,594' ±9,599' ±9,365' ±9,370' Future -G-2 . G-6 ±9,626' ±9,640' ±9,393' ±9,406' Future G-3 G-7 ±9,682' ±9,701' ±9,443' ±9,460' Future G-4 H-1 9,716' 9,730' 9,473' 9,486' 14 4 11/18/1989 Open G-5 H-1 ±9,716' ±9,759' ±9,473' ±9,512' Future H-1 9,730' 9,762' 9,486' 9,514' 32 5 6/3/1989 Open =G-6 = 0-7 H-2 ±9,778' ±9,873' ±9,529' ±9,614' Future - H-2 9,781' 9,783' 9,531' 9,533' 2 4 05/31/1989 Squeezed B-1 = H-2 9,886' 9,888' 9,626' 9,627' 2 4 05/29/1989 Squeezed T B 2 H-3 9,900' 9,914' 9,638' 9,651' 14 5 6/3/1989 Open B-3 H-3 ±9,900' ±9,977' ±9,638' ±9,707' Future H-3 9,944' 9,976' 9,678' 9,706' 32 5 6/3/1989 Open _- H-4 ±9,977' ±10,064' ±9,707' ±9,786' Future e-4 H-4 9,982' 10,070' 9,712' 9,791' 88 5 6/3/1989 Open H-5 10,092' 10,146' 9,811' 9,860' 54 5 6/3/1989 Open -B-5 H-5 ±10,092' ±10,200' ±9,811' ±9,910' Future - g{ H-S 10,156' 10,176' 9,870' 9,888' 20 5 6/3/1989 Open �. . Ht H-6 ±10,230' ±10,284' ±9,937' ±9,987' Future '�i Updated by: DEM 01/07/14 Plug Back Depth=10,340'MD TD=10,415'MD' Max Hole Angle= 27° Dolly Varden Platform D-45 Current 07/9/2013 Hilrurp Alaska.1.l.(. Dolly Varden D-45 Tubing hanger,CIW-AP- 133/8X95/8X31/2 FBB,11X3%28rdlift and 3%2 DSS-HTC susp,w/3" type H BPV profile, 6 1/4"EN,SS material BHTA,CIW,3 1/8 5M FE X External Acme knockup aw11111P in - .I 411 .1 riIMMINOi, •I VOA II.. Valve,swab,WKM-M, e ') p 3 1/8 5M FE,HWO, 4)( o 4) T-26 1111 NMI 1111 .. Tee,stdd,3 1/8 5M X 1 h� 3 1/8 5M Aii15 �` r`. ,, , Valve,master,WKM-M, ,4, ft . 3 1/8 5M FE,HWO,T-26 =, ,% Ilir ...0.Th- III Valve,master,WKM-M, 'L. .$a 3 1/8 5M FE,HWO,T-26 ,," opo Adapter,CIW-FBB, 11 5M FE X 1.. ... f$1 3 1/8 5M,prepped for 6 1/4" 1 extended neck Tubing head,CIW-AP, �� ° _■a1033 a 13 5/8 3M X 11 5M,w/2- . 6 2 1/16 5M SSO,X-bottom III fill Valve,CIW-F,2 1/16 5M FE, pfep, � g n HWO,AA 1Y2 VR profile ili it*" ,l III Casing head,Vetco CWC, j; 13 5/8 3M X 13 3/8" „ i ,I, Valve,Gray,2 1/16 3M, casing thread, : r• .:t . HWO,AA w/2-21/165M EFO �� 111 11 l 11 Dolly Varden Platform D-45 Proposed Hilrarp Abz+k■.I I( 07/9/2013 Dolly Varden D-45 Tubing hanger,SME-CL,11 X 133/8X95/8X41/2 4%:EUElift and 4YzTC-2 susp,w/4"Type H 8PV profile,2-3/8 CCL,6 extended neck,17-4PH stainless steel BHTA,Bowen,41/16 5M X 7"-5 SA Bowen Union Full Stainless Steel I III f I., Valve,Swab,WKM-M, 41/16 5M FE,HWO,FF trim • Valve,Wing,WKM-M, ~"' 3 1/8 5M FE,w/15"Safeco operator,FF Stee Full Stainless Steel 0 tot owl Valve,Master,WKM-M, 41/16 5M FE,HWO,FF trim �• O 111 Adapter,Seaboard,11 5M FE X 4 1/16 5M,w/6'/4 pocket, momm�� + ■ o= 2-1/2 CCL exits,Full Stainless s■ l' Steel ev) Tubing head,S-8,13 5/8 3M EEP jI I ! > x115M,w/2-21/165M 7 1_ SSO,w/BG bottom L w/1 21/165M WKM Mma Ii ° �`-�°�i -- valves `' 1111: 15-,110 -1 Valve,Gray,2 1/16 3M, •I• HWO,AA Casing head,Vetco CWC, ■ 13 5/8 3M X 13 3/8" 111 I l l casing thread, _ _ - = w/2-2 1/16 5M EFO ��I�� I-si II' 1II I �• • r • r H Dolly Varden Platform 2014 BOP Stack(HAK#1) 01/10/2014 Hilrarp:Maika.l.id. Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack . 1 iii1.i11.ilsi 1.111.111.11.1 3.42' Shaffer 11"5M it it iI III II 111 111 111 1111 i_1 co4.54' _ -iiia I. _ ��, ...: iik II III Mill iiiir A ;1I11n•1!i•1�1 iv, . 2.00' :I,1IQIlf l ° i l{'' II:: 1I'I, •111 111 Ill l i l 111 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 I '" l' �' �' connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE 1r1 1 ii 11 i1 1n 1111nnr i tit 3.00' Spacer spool 11 5M FE X 11 5M FE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 13,2013 3 cl- ( J t ., P.I.Supervisor SUBJECT: Mechanical Integrity Tests 1-IILCORP ALASKA LLC D-45 FROM: Lou Grimaldi TRADING BAY UNIT D-45 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT D-45 API Well Number 50-733-20150-01-00 Inspector Name: Lou Grimaldi Permit Number: 188-140-0 Inspection Date: 4/9/2013 Insp Num: mitLGl30409142259 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well D-45 Type Inj W 'TVD 8933 - IA 155 2300 2285 2280 - PTD 1881400 ' Type Test SPT Test psi' 2233.25 ' OA 105 118 121 122 Interval ,, 'OTHER P ✓ Tubing 3400 3400 3400 3400 P/F Notes: Initital test post-patch installation.Good stable test.Watertlood used which resulted in inability to measure test fluid(water)in/out. 1/2"hose with 3400 supply resulted in<10 minutes to pressure up IA from 150->2300 psi. SCANNED FEB 2 0 2014 Thursday,June 13,2013 Page 1 of 1 • RECEIVED , STATE OF ALASKA APR 19 2013 ASKA OIL AND GAS CONSERVATION COMMISSION 1 REPORT OF SUNDRY WELL OPERATIONS AOGCO 1 1. Operations Abandon ❑ Repair Well El Plug Perforations ❑ Perforate ❑ Other 0 Install Patch Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wel ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 188 -140 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99503 50- 733 - 20150 -01 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL00118729 .. Trading Bay Unit D -45 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,415 feet Plugs measured None feet true vertical 10,108 feet Junk measured None feet Effective Depth measured 10,340 feet Packer measured 9,109 feet true vertical 10,039 feet true vertical 8,933 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,492' 13 -3/8" 2,492' 2,490 3,090 psi 1,540 psi Production 10,399' 9 -5/8" 10,399' 10,094' 6,330 psi 3,810 psi Liner Perforation depth Measured depth See Schematic feet SCANNED APR 2 4 2013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# / N -80 9,124' (MD) 8,947' (TVD) Packers and SSSV (type, measured and true vertical depth) Otis BDW Pkr 9,109,,(M9) 8,933' (TVD^ SSSV - N/A 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: 0 0 0 200 250 Subsequent to operation: 0 0 1050 200 3400 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 ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ 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: Contact Ted Kramer Email tkramer aV hilcorq.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature '</, ] co 6 ' Phone (907) 777 -8420 Date 4/16/2013 @DMS APR 2 2 2013 -4d'1, ` 23 ' 3 Submit Original Only Form 10-404 Revised 10/201 �/� 9 Y v 1 • • • Hilcorp Alaska, LLC RECEIVED Post Office Box 244027 {� Anchorage, AK 99524 -4027 APR 19 2013 3800 Centerpoint Drive Suite 100 AOGCC Anchorage, AK 99503 Phone: 907 /777 -8300 April 19, 2013 Fax: 907/777-8301 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Ste. 100 Anchorage, Alaska 99501 Re: Dolly Varden Well 45 Submission of form 10 -404 Dear Mr. Schwartz: Attached please find the information you requested in your e-mail dated 4/16/2013 (10- 404, background summary on the wells integrity problem, daily work summaries of the work performed in efforts to find the leak). In response to your statement that, "The Commission will consider whether any enforcement actions will be forthcoming. ", Hilcorp offers the following in mitigation: 1.) Hilcorp was in communication with the AOGCC regarding the setting of this patch. This is evidenced by the following emails (attached): a. From Hilcorp Lead operator Jon Loomis to James Regg, Phoebe Brooks and AOGCC Prudhoe Bay, on March 27, 2013 at 11:26 AM (Attached email #1) informing the Commission that a patch had been set in D -45 and asking to return the well to injection to stabilize the well so that a State Witnessed MITA could be performed. b. From Hilcorp Lead operator Jon Loomis to Jim Regg, AOGCC Prudhoe Bay, and Phoebe Brooks on April 8, 2013 at 3:57 PM (Attached e -mail # 2), informing the Commission that the D -45 Well was now stabilized and that it was ready for a Commission Witnessed MITA. c. From Hilcorp Operations Engineer Ted Kramer on April 16, 2013 at 11:22 AM ( Attached e-mail #3) to Guy Schwartz at AOGCC self - reporting that the patch had been placed in the well without a 10 -403 form being filed. Hilcorp takes the Alaska Oil and Gas Commission's Sundry process very seriously. In an effort to insure that this does not happen again in the future, the need to secure an approved Sundry (10 -403) before setting a tubing patch in an injection well was discussed in our Monthly Foreman's meeting so that all of the Hilcorp offshore Cook Inlet Platforms are now aware of this rule. • • Mr. Guy Schwartz April 18, 2013 Page 2 of 2 Hilcorp has a Sundry Matrix that we follow to determine which sundry form is needed to be filed to match the various work flows performed. We in the office are very aware of this matrix and consult it daily when preparing well work. However, a gap surfaced with this job in that the work was planned and lead in the field by platform personnel. Although our field personnel are technically adept at performing this type of repair, they were not aware that this particular job needed a 10 -403 prior to performing the work. Having the matrix on the platform will give the platform personnel the tool they need to make that determination. This matrix is currently being revised to reflect some reporting changes that took place in February 2013. We expect to have this Matrix completed by next Friday (April 26, 2013). Hilcorp proposes that once this matrix revision is complete, we send it to the AOGCC for approval after which we intend to distribute it to our field supervisors and lead operators that perform well work and diagnostics. Hilcorp feels that getting this information in the hands of the field supervisors performing the work will prevent this oversight from happening in the future. Sincerely, HILCORP ALASKA, LLC Ted E. Kramer Sr. Operations Engineer n 0 • Trading Bay Unit SCHEMATIC well: D -45 Completed: 6/5/1989 Hi!carp Alaska, LLC CASING AND TUBING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 61# K -55 Surf 2,406' 13-3/8" 68# N -80 2,406' 2,407' 61# K -55 2,407' 2,490' 2 68# N -80 2,490' 2,492' 3 43.5# N -80 Surf 3,425' 4 9 -5/8" 47# N -80 & P -110 3,425' 8,423' 53.5# C -75 & P -110 8,423' 10,399' Tubing: I 3 -1/2" 9.3# N -80 Surf 9,124' JEWELRY DETAIL NO. Depth ID Item Z. 1 41' 3.5" Cameron FBB 5/5 Tbg Hanger Patch installed 2 318' Flow Coupling BxP IPC w/TK69 1,857'- 1,884' Si- S 3 324' 2.813" Otis X Nipple 4 325' Flow Coupling BxP IPC w/TK69 ?Arc • 5 9,109' Otis Straight Slot Locator w /seal ext and seal mandrels w/16.7' seals re iiriti 6 9,109' 4.0" Otis BWD Packer w /SBE and millout ext. 7 9,124' 2.99" Muleshoe 8 9,137' 4.5" 8RDx3.5" ETC PXP Crossover 5 9 9,169' 2.813" Otis XN Nipple w/2.75" NoGo 1r :,: 6 i l l 10 9,170' 2.99" Otis W/L Entry Guide 7 8 Perforation Detail ®1 9 10 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Now G -1 9,205' 9,245' 9,019' 9,055' 7/10/1998 G -2 9,255' 9,285' 9,064' 9,091' 7/10/1998 G -3 9,325' 9,345' 9,126' 9,144' 7/10/1998 G -4 9,355' 9,375' 9,153' 9,190' 7/10/1998 G -5 9,505' 9,525' 9,286' 9,304' 7/10/1998 G -5 9,535' 9,560' 9,313' 9,335' 7/10/1998 B -1 9,716' 9,730' 9,473' 9,486' 11/18/1989 \ B -1 9,730' 9,762' 9,486' 9,514' 6/3/1989 9,781' 9,783' 9,531' 9,533' Squeezed 5/3/00: 9,886' 9,888' 9,626' 9,627' Squeezed 2.70" GR = B -3 9,900' 9,914' 9,638' 9,651' 6/3/1989 tagged up _ at 10,294' - B -3 9,944' 9,976' 9,678' 9,706' 6/3/1989 B -4 9,982' 10,070' 9,712' 9,791' 6/3/1989 B -5 10,092' 10,146' 9,811' 9,860' 6/3/1989 B -5 10,156' 10,176' 9,870' 9,888' 6/3/1989 PBTD = 10,340' TD = 10,415' Updated by: J1104 -16-13 • • DoIIv Varden Well Number 45 Well Integrity Summary October 31, 2012 — Well developed tubing to production casing communication and the well was shut in. November 22, 2012 - A spinner Survey was ran in the well to attempt to locate the leak. Survey results were inconclusive. February 20, 2013 - A D & D hole finder was ran I the well and worked up the tubing pressure testing above it until the leak was located. March 26, 2013 - A tubing straddle patch was ran in the well isolating the leak from 1,871 to 1857'. March 27, 2013 AOGCC was notified that the patch was set and permission was requested to place the well on injection to stabilize for a State Witnessed MITA test. April 1, 2013 Phoebe Brooks of AOGCC issued MIT TBU D -45 Report showing a test result "P" for D -45. April 8, 2013 Hilcorp Notified the commission that the well was stable and ready to have a State Witnessed MIT test Performed. April 9, 2013 State witnessed MIT conducted witnessed by Lou Grimaldi. April 10, 2013 Notification submitted to the AOGCC by Larry Greenstein of Hilcorp of the witnessed MIT test. April 16, 2013 Notification submitted to the AOGCC by Hilcorp employee Ted Kramer that the patch was set without a 10 -403 form being filed. . • Hilcorp Alaska, LLC Ililiurp Alaska,LL4: Well Operations Summary Well Name API Number IWell Permit Number Start Date End Date D -45 50- 733 - 20150 -01 188 -140 11/22/2012 3/26/2013 Daily Operations: 11/22/12 - Thursday Rig up. Pressure test lubricator to 3,500 psi. RIH w/ 2.70" GR to 10,237 KB and tag fill. Pooh. Program spinner and gauge. Standby for returns on casing before running survey. RIH w /spinner & tri gauge to 10,000' KB for 30 minutes. Stop and POOH. Secure equipment and shut down for night. 01/20/13 - Sunday Rig up. Pressure test lubricator and WLV - test good. RIH w/2.75" braided line brush to 1,000' KB three times. RIH w /spinner gauge to 10,000' KB for 30 minutes. Stop and POOH. Rig down. 02/20/13 - Wednesday Rig up. Pressure test lubricator and WLV - test good. RIH w/ 2 -1/2" JDC w/ D &D hole finder to 100' KB, set finder and have production set up on it. Tubing held, pin sheared when trying to pull finder. POOH. RIH w 2 -1/2" JDC to 100' KB latch and pull finder. POOH, have finder. RIH w 2 -1/2" JDC W D &D hole finder to 5,000' KB and set. Have production test tubing, didn't hold. Pull up to 4,500' KB, same results. Pull up to 4,000' KB, same results. Pull up to 3,500' KB same results. I u Pull up to 3,000' KB, same results. Pull up to 2,500' KB, same results. Pull up to 2,000" KB, same results. Pull up to 2,000' KB, same results. Pull up to 1,500' KB tubing held. POOH. RIH w/ same to 2,0000' KB, set finder. Have production test tubing, didn't hold. Pull up to 1,950' KB, same results. Pull up to 1,9000' KB, same results. Pull up to 1,850' KB tubing held. POOH. RIH w /same to 1,900' KB make stops every five feet tubing held at 1,875' and didn't at 1,880' KB so the hole is between that five feet. POOH. Rig down. 03/26/13 - Tuesday Rig up. Pressure test lubricator and WLV's - test good. RIH w/ 3" GS w/ AD -2 stop to 1,884' KB, set stop. POOH. RIH w/ 3" GS w /bottom pack off to 1,871' KB set bottom pack off. POOH. RIH w/ 3" GS w/ top pack off to 1,859' KB, set top pack off. POOH. RIH w/ 3" GS w/ A -slip stop to 1,857" KB set stop. POOH. L/D lubricator and secure well. • • Ted Kramer From: Jon Loomis Sent: Monday, April 01, 2013 10:01 AM To: John Lee Cc: Christy Anderson Subject: FW: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Attachments: MIT TBU D -45 03- 27- 13.xls Original Message From: Brooks, Phoebe L (DOA) [ mailto :ohoebe.brooks@alaska.gov] Sent: Monday, April 01, 2013 9:59 AM To: Jon Loomis Cc: Regg, James B (DOA) Subject: RE: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jon, Attached is a revised report for MIT TBU D -45 03 -27 -13 removing the D -34A data and adding test result "P" for D -45. Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 - 276 -7542 Original Message From: Jon Loomis [mailto:iloomisPhilcorp.com] , Sent: Wednesday, March 27, 2013 11:26 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Christy Anderson; John Lee; Larry Greenstein Subject: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jim, We have set a patch @ 1884' -24' in length on D -45 Water Injector. We have completed an in house MIT (see attachment). We would like to return this well to injection and get it stable for a State witnessed MIT. Thank you, Mike Loomis 1 • • Lead Operator Dolly Varden Platform 907 - 776 -6840 2 • - Ted Kramer From: Jon Loomis Sent: Monday, April 08, 2013 3:57 PM To: jim.regg @alaska.gov; doa.aogcc.prudhoe.bay @alaska.gov; phoebe.brooks @alaska.gov Cc: Christy Anderson; John Lee; Larry Greenstein Subject: Dolly Varden D -45 State Witnessed MIT request Jim, D -45 has been back on water injection for the last 10 days and is stable. We would like to schedule a State witnessed MIT. Tuesday and Thursday work best for scheduling but we can accommodate your schedule. Thanks, Mike Loomis 1 • • Lead Operator Dolly Varden Platform 907 - 776 -6840 2 i • Ted Kramer From: Ted Kramer Sent: Tuesday, April 16, 2013 11:22 AM To: Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov) Cc: Juanita Lovett Subject: Dolly D -45 Sundry Attachments: MIT TBU D -45 03- 27- 13.xls Guy, I am writing to let you know that a tubing patch was ran in the above well on March 27, 2013. My concern is that as of February, there was a revision of the through tubing rules which required a 10 -403 for setting a tubing patch. We have been hunting this tubing leak since November of 2012. After several attempts to locate it, we found it and set the patch. During the course of time it took to locate the leak, the need for a Sundry reverted back to needing one for this type of work. As you can see from the paper trail below, all notification steps were taken in letting the AOGCC know what was happening and that a patch was being set, just that a 10 -403 was not filed prior to setting the patch. I am asking for guidance on what we need to do to bring this well into compliance. If we need to shut this injector in and file a sundry, Hilcorp is prepared to do that. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 Original Message From: Christy Anderson Sent: Tuesday, April 16, 2013 7:53 AM To: Ted Kramer Subject: FW: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). See below. Christy D. Anderson Lead Operator Dolly Varden Platform 776 -6840 cnderson@ hilcorp.com 1 i a • • Original Message From: Jon Loomis Sent: Monday, April 01, 2013 10:01 AM To: John Lee Cc: Christy Anderson Subject: FW: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Original Message From: Brooks, Phoebe L (DOA) [ mailto :phoebe.brooksPalaska.gov] Sent: Monday, April 01, 2013 9:59 AM To: Jon Loomis Cc: Regg, James B (DOA) Subject: RE: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jon, Attached is a revised report for MIT TBU D -45 03 -27 -13 removing the D -34A data and adding test result "P" for D -45. Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 - 276 -7542 Original Message From: Jon Loomis [mailto: jloomis@hilcorp.com] Sent: Wednesday, March 27, 2013 11:26 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Christy Anderson; John Lee; Larry Greenstein Subject: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jim, We have set a patch @ 1884' -24' in length on 0 -45 Water Injector. We have completed an in house MIT (see attachment). We would like to return this well to injection and get it stable for a State witnessed MIT. Thank you, Mike Loomis Lead Operator Dolly Varden Platform 2 • • 907 - 776 -6840 3 Regg, James B (DOA) From: Jon Loomis [jloomis @hilcorp.com] Sent: Thursday, March 28, 2013 10:14 AM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jim, We are hoping to get to that well later in the week or next week. We are currently on wells in A -2 well room, once we get done with that well room we will move on to A -1 and test D -34. Thanks, Mike Loomis Original Message SCANNED From: Regg, James B (DOA) [mailto:iim.regg(Balaska.gov] JUL �1 Sent: Thursday, March 28, 2013 10:11 AM To: Jon Loomis Cc: Wallace, Chris D (DOA) Subject: RE: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). OK to put on injection. What's up with D -34A (listed but no test data)? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Jon Loomis [mailto:jloomis@hilcorp.com] Sent: Wednesday, March 27, 2013 11:26 AM To: Regg, James .B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Christy Anderson; John Lee; Larry Greenstein Subject: Emailing: Copy of MIT_Dolly_xx -xx -xx (D -45). Jim, We have set a patch @ 1884' -24' in length on D -45 Water Injector. We have completed an in house MIT (see attachment). We would like to return this well to injection and get it stable for a State witnessed MIT. Thank you, Mike Loomis Lead Operator Dolly Varden Platform 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reogCialaska.aov: doa. aogcc.prudhoe.bay(dialaska.aov; phoebe.brooksCNalaska.aov OPERATOR: Hilcorp Alaska, LLC FIELD / UNIT / PAD: McArthur River/Trading Bay Unit/Dolly Varden Platforrr DATE: 03/27/13 OPERATOR REP: Mike Loomis AOGCC REP: Pfcker Depth Pretest Initial 15 ' . 30 Min. 45 Min. 60 Min. Well D -34A Type Inj. _I -TVD 8,779' Tubing Interva P.T.D. 1790110 T st P Test psi 2195 Casing P/F Notes: Post ' ne work to repair tbg x csg comm Well D -45 Type Inj. N " TVD 8,933' ' Tubing 250 300 300 300 300 300 Interval p P.T.D. 1881400 " Type test P - Test psi 2233 ` Casing 0 2,250 2,250 - 2,250" 2,250 ' 2,250 - P/F P I Notes: Post wireline work to repair tbg x csg comm OA 75 98 98 98 , 98 98 Patch installed 3/27/2013 @ 1884' 24' long Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey 0 = Other (describe in notes) W = Water D = Differential Temperature Test Form 10 (Revised 02/2012) Copy of MIT_Dolly_xx- xx- xx.xls MEMORANDUM • To: Jim Regg ~~~ ~'j,3'i~°o P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 23, 2008 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-45 TRADING BAY UNIT D-45 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~P/=- Comm Well Name: TRADING BAY UNIT D-45 Insp Num: mitLG080913063634 Rel Insp Num: API Well Number 50-73 3-20 1 50-0 1-00 Permit Number: 188-140-0 ~ Inspector Name: Lou Grimaldi Inspection Date: 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j D-as Type Inj. W TVD ~ 8931 j IA I 0 2340 '~ i 2320 ~ 2320 P.T. 1881400 TypeTest sPT Test psi 2340 QA I 15 15 15 15 Interval 4YRTST p/r, F Tubing ~ zsoo j zsoo ~ zaoo ~ zsoo NOtes• Good test. Observed pretest conditions for I S minutes "OK". Well pressured up with water flood, checked before hand for fluid to surface in IA. ~1!~~E~ ~ ~ ~~~~r Tuesday, September 23, 2008 Page t of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'Í/4./.. q/...,I P.I. Supervisor ~~>fl (I ';{M- DATE: Monday, September 13, 2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 0-45 TRADING BAY UNIT 0-45 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :JßR- Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT 0-45 API Well Number: 50-733-20150-01-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40908 I 6430 I Permit Number: 188-140-0 Inspection Date: 9/3/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 0-45 Type Inj. s TVD 8930 IA 280 2310 2300 2300 P.T. 1881400 TypeTest SPT Test psi 2232.5 OA 10 10 10 10 Interval 4YRTST P/F p Tubing 2800 2800 2800 2800 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Monday, September 13, 2004 Page I of I THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE ,OCTO.BER 24,, 2000 P M C:LORI~IFILM.DOC L A T E R IA L THIS MA E E E W UNDER R K E R STATE OF ALASKA 0 R ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS IG 1. Operations performed: ODerat,on snutclown ~ Ptugging m Pull tubing m Alter casing ~ ReDa,r well ~ 2. Same of Ooerator / 5. Type of Well: . UNOCAL (Marathon Oil Company- Sub O~erato Er~E~n 3. Address .... 1 Straagra~ic .._. P. 0. Box 190247 Anchorage, AK YYb:[~ . Ser,,ce_.L 4. Location of well at surface Leg A-2 Cond. #12 Do]].y Varden Platform St~nmate X Perforate__ O~her ~ 6. Daturnelev{~tion (DF.9.r. KB) 106' KB aDove M3L .~1 Unltor ProJ3ertv raalng Bay un~ 8. Well number ' 1 ' - At~pr[~C,,vei.t~l FWL, Sec. 6 8N- 13W- SM 1.100' FSL 2 354' FWL, Sec. 6- 8N- 13W- SM At eM~ctlve cleptn w At total depth 1.17R' FSI. 2,631' FWL, Sec. 12. Present welt concli~ion summary Total depth: measured true verticai 6 - 8N - 13W - SM , 10,415 ' feet Plugs (measured) 10,108' feet Eftect~ve depth: measured feet Junk (measured) true vertical 10,340 ' feet 10,039' Casing Length Size Cemented Structural Conductor Surface Intermediate 2,492' 13-3/8" 2,405 sx Production Liner 10,399' 9-5/8" 2,920 sx Perforauon depth' measureO See Attachment #1 9. Permit number/approval number 88-140 10. APt number 5o-. 733-20150-01 11. Field/Pool Ri v.er/Heml ~r~¥ None Measured depth 2,492' 10,399' True vertical depth 2,489' 10,093' true veracat feet 13. Tubing (s~ze, grade, and measured depth) 3-1/2"w 9.3#, N-80 DSS-HTC tbg. to 9,124' MD PacKers and SSSV (type and measurecl depth) ... 9-5/~" nf~ Run Pkr w/ SBE (4.0" ID) 0 9,109' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment clescriptlon including volumes usecl and final pressure REEEiVED r-v £ I ~ ~.. Alas[fa 0il .& Gas Cons. Commission ;Anchorage 14. Representative Daily Average Producaon or In~ect~on Data Oil-Bbl Gas-Md Water-Bbl Camng Pressure Tubing Pressure Prior to welt operation Subsequent to operation 15. Attacl3ments Copies of Logs and Surveys run .,.,_ Daily Report of Well Operations A~ 1360 2160 ~ 16. Status of well claSaficat~on as: Oil __ Gas ~ Suspended ~ 1Z I herel3y certify that the foregoing is true and correct to me ~est ct my I(nowleOge. Se~ce 3650 3800 Water Injection B-1 B-3 B-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals M__~D 9,716' - 9,730' 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' TVQ 9,473' - 9,486' 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' RECEIVED DEC 2 2 1992 Alaska Oil & Gas Cons. Commission Anchorage DAILY WELL OPERATIONS D-45 11/25/92 Hold safety meeting. RU of chicksan to well. Pressure test to 4000 psi. Good test. Pump 1000 gallons 12-1/24 Sodium Hypochlorite at 1BPM, 3800 psi w/ 1/2 ppg Benzoic acid flakes diverter. Displace w/ 141 bbls FIW at 0.9 BPM, 3800 psi. Rate declined slowly during last 60 bbls pumped to end at 0.6 BPM, 3800 psi. SD pump. Displacement completed. Allow sodium hypochlorite to soak and heat up. 11/26/g2 Pressure test lines to 4000 psi. OK. Open well, TJP = 1000. Start pumping treatment as follows; 3/4*BPM 3800 psi. 2000 gal 154 HC1 10 bbl diverter pill 2000 gal 154 HC1 10 bbl diverter pill 2000 gal 154 HC1 Displace treatment w/ 150 bbls FIW w/ 6 gal/ 1000 gal clay stabilizer. Final rate I BPM, 3800 psi. SD pump. Displacement complete. RD off wellhead. Place well on injection. H: \wp\WELLOPOS\D-/,5 REEEiV£D DEC ~ ~ 199 Alaska Oil & Gas Cons. Commission Anchorage " "~ STATE OF A~KA A LAbK,A OIL AND GAS CONSERVATION COMMISSION - APPLICATION FOR SUNDRY APPROVAL , , -/ I Operation shutdown __ Re-enter suspended woll -- v ~ / Plugging __ Time exlens,on __ Stimulate ~ 4¢' ~. Pull tubing _-- Variance __ Pedorate __ Other __ /~/' 6. Datum elevation (DF or 1. Type of Request: Abandon ~ Suspend ~ Alter casing __ Repair well ~ Change approved program 2. Name of Operator I 5. Type of Well: | D. eve4opment ~ ,,.,,.,,..., /..__.~..... .' ~ r .......... ~:~b ~t,~erator)Exploratory-- ~. Ad~r~s~. k,.,u, u ~., .... 0 ....... r.~,,.z " ] Stratigraphic_ Service X Tradinq Bay Unit P. 0. Box 190247 A~¢hnr~g~. Al( qqGl~ 4. Location of well at sudace Leg A-2 Cond. #12 Dolly Varden AttoT~5~f'proF~tive~mJr~' EWE, Sec. 6- 8N- 13W- SM 00' FL , · Ate~,vedept~ ' 2 354' FWL, Sec 6 -8N - 13W- SM Platform At total depth 1.178' FSL: 2.631' FWL, Sec. 6 - 8N - 13W - SM 12. Present well condition summary Total depth: measured 10,415 ' feet Plugs (measured) true vertical 10,108 ~ feet Effective depth: measured 10,340 ' feet true vertical 10,039 ' feet Casing Length Size Structural Conductor Surface Intermediate 2,492' 13-3/8" Production Liner 10,399' 9-5/8" Perforation depth: measured See Junk (measured) Cemented 2,405 sx 2,920 sx Attachment #1 true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 DSS-HTC tbg. Packers and SSSV (type and measured depth) 9-5/8" Otis BWD 13. Attachments ]OR_' kR nhnv~ M~I 7. Unit or Property name 8. Well number n /ir; ~. P~"Cmit number 88- ] zt0 10. APl number 5o- 7~)3-20150-01 11. Field/Pool McArthur River/Hemlock Pool None Measured depth True vertical depth 2,492' 2,489' 10,399' 10,093' RE6EiVED DEC - 7 1992 to g, 124' MD Alaska 0il & Gas Cons. Commission Anch0rag~ Pkr w/ SBE (4,0" ID) @ 9,109' FID Description summary of proposal ~ Detailed operations program ~ BOP sketchX.._ feet 14. Estimated date for commencing operation /15. Status of well classification as: 11/30/92 16. If proposal was verbally approved Oil ~ Gas Name of approver Date approved Service ~a~ n j ect i o n 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. ~ "-" T, tle %'~,\~, ' Signed (,.~.~ ~ . ~ ~,, ' ,~.. ~ ,"t ' ~ -- '-- FOR CO&' .... IS$1ON U_~,u.-ONLY ~ ,., Cond t,ons of a r~v;l:'~otify Commission so representative ma~'~tness Plug ~ntegrm~ __ _ BOP Test __ ~ion cleara ce ~ M~hanical Integri~ Test __ Su~quent form r~uired 10- 7 Form 10-~ R~ ~5/88 SUBMIT IN TRIPLICATE B-1 Attachment #1 current ~er~orated intervals 9,716' . 9,730' 9,730' ' 9'76~" 9,900' . 9,9!q' 9,9AA' . 9,976' 9,9B2' . 10,070' 10,092' . 10,1~$' 10,156' ' 10,176' 9,~,73, . 9,AB6' 9,~,B6' - 9,51~,' . 9,651' 9,63B' 9,?06' 9,67B' 9,71z' - 9,791' 9,Bll' . 9,B60' 9,B69' ' 9,888' RECEIVED D EO - ? 199~ Alaska Oil & Gas Cons. Commission Anchorag~ WELL D-45 PROCEDURE Acidize Water Injection Well · · · Hold safety/operational meeting with pumping service company. MSDS. Review SI injection to well. Monitor SITP. RU pumping equipment on wellhead. Pressure test lines to 4000 psi. Pump treatment as follows: a) b) c) d) e) f) g) h) i) J) Pump 1000 gallons (24 bbls) 12-1/24 Sodium Hypochlorite at 1-2 BPM or 3800 psi max. Add 1/2 #/gal Benzoic acid flakes (TLC-80) diverter to the Sodium Hypochlorite (continuous). Displace Sodium Hypochlorite with 141 bbls FIW. Allow fluid to heat up for 12 hours. Pump on additional 5 bbls every 4 hours during the 12 hour heatup period to agitate the treatment. Pump 2000 gallons 154 HCl w/ 2 gal/lO00 gal HAI-85M, 20 lbs/lO00 gal Ferchek A and 2 gal/lO00 gal Losurf 300 additives at 1-2 BPM or maximum 3800 psi. Pump 10 bbl diverter pill w/ 500 #'s Benzoic acid flakes and 1 gal/lO00 gallon Losurf 300 mixed in FIW. Pump 2000 gallons 154 HCl w/ additives. Pump 10 bbl diverter pill. Pump 2000 gallons 154 HCl w/ additives. Displace treatment w/ 150 bbls FIW w/ 6 gal/lO00 gal clay stabilizer. RD Halliburton lines. Return to injection immediately. H: \wp\WLPRO\D45 · ~Jaska Oil & ~a$ Oorl8. commission Anchorago MARATHON 12 ?~',~S F1MPA N Y TRADfNG B. UNiT WELL D-45 Csg Cmt Sqz Per~s 9.781'-9783' & 9886'9888' DIL CompLeted 6/5/89 A(L measurements ape RKO to top oF equipmenT, 41' Cameron FOB Stc~in[ess TIo9 Hngr 3.5' 8RD Top x DSS-HTC Bottom. 318' FLow CPt9 (3,885' 0]3) BxP [PC w/TK69, 324' Otis 'X'Nipp(e (.2,813" ID), 325' Flow Cplg (3,885~ OD) BxP [PC w/TK69. Comp[etlon String: 0'-9184' 3.5S 9,3~ N-80 Tb9, tPC w/TK69. (Tbg is Condi"cion ~]) 9-5/8' Csg 43.5~ N-80 to 3,425'; 47~ N-80 & P-110 to 8,423'; 53.5~ C-75 & P-IlO to RECEIVED DEC - 7 992 Alaska {2ii & Was Cons. Anchorage 9109' 9109' 9124' 9137' 9169' 9170' B-i Otis Straight Slot Locator w/sea( ext and sea[ mondre(s w/[6,7' seals, Otis BWD Packer (4.0' ID> w/gSE and miLLou~c ext <4.0~ II:)), Mu[eshoe (2,99" ID), 4,5' 8RDx3,5~ BTC PxP Crossover. Otis "XN~ Nipple (2,813" ID) w/2,75~ NoGo. Otis ~/L Entmy guide (~.99' ID), B-3 B-4 PERFORATIONS B-1 9716'-9730' B-! 9730'-9762' B-3 9900'-99114' B-3 9944'-9976' ]3-4 9982'-]0,070' B-5 10,092'-10,146' B-5 10,156'-10,176' 4 SPF 0" Phasing [1/18/89 5 SPF 60° Phasing 6/3/89 Avg devlot;on through perFs = 26° B-5 B-5 PBTD @ 10,340' TD e 10,415' Revision Date: 4/90 Revised By: JCM/neF Reason: New Previous Revision: N/A Dec, 9, 1998 8'55AM UN~CAL£~.~,, CORP:J~~~/UNOCALe No,3258 p, I Mike Mlnder PO Box 196247 AnohoreQe, AK 99~1g E~,3,,762g Offloe 263,.7864 Fey To: Blair Wondzell Fax: 276-7542 Fr~n: Mike Mlnder Oate: 12/3/98 Fie: Documentation New (Et zone) Pag#: Perfe in Doily Varden D-29rd & D- 45. CC". 3 including 1his cover sheet Pleme Canmmn~ Plmm Reply PI#M Fleqm~ · · · · remr* "G" Zone perforetiom in Doi~Varden Wde D-2grd&D-4,6couldbe it Is ~e we inadvertently fa~ed to no~ you. A summa~ d the Ion Is provided for your ~o~. PleMe lei us ~ what additional Irfom'mtim you may Miko Mlnder DEC -':! !998 ~ & Gas Cons. Commissa3n Dec. 9, 1998 8'55AM WELL: TYPE: UPDATED: U~CAL CORP. · DOLLY VARDEN PLATFORM · APl # 50-733-20150-01 WELL HISTORY D-45 "G" Zoffte & HEMLOCK INJECTOR 7110/98 No,~Zb~ 6'8 -/z~O -- 7/10/98 Perforate "G" Zone W/2-1/2" Hollow Carder Guns, 6HPF, 60° Phase. Zone Interval Feet G - 1 9,205' - 9,560' 40' G - 2 9,255' - 9,285' 30' G - 3 9,325'- 9,345' 20' G - 4 9,355' - 9,375' 20' G - 5 9,505' - 9,525' 20' G - 5 9,535'- 9,560' 25._.~' TOTAL 155' DEC - 9 1998 Memorandum ~/"~\ '/-% UNOCAL ' TO: BLAIR WONDZELL FROM: KIRK KILOH Transmitting one (1) Blueline and Sepia copy of Cement Bond/Evaluation Logs of each of the following wells: G-22 6-22-75 rVCAT G-40 ~ 'F 3-16-90~'3-~%90 K- 15RD ~~-6-797 10-8-89 D-45 5-28-89 RECEIVED DEC 1 B 1990 Alaska 011 & Gas Cons. Cemmlssion FORM 1-0C03 (REV, 8-85) PRINTED IN U.S.A. STATE OF ALASKA REPORT OF SUNDRY WELL OPERATI O S' 1. Operations performed: Operation shutdown -- Stimulate -- Plugging -- Perforate ~ Pull tubing __ Alter casing ~ Repair well ~ Other 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company, Sub n~eratn~'~evel°pment~ - "~ "' / Exploratory __ 3. Address ~lJ.,v Stratigraphic P. 0. Box 190247 Anchorage, 'AK 9951 Service.-~-~ 4. Location of Well at surface Leg A-Z bond. NIZ Uo I Varden FI atform 8. 752' FSL, 1,134' FWL, Sec. 6 - 8N - 13W - SM D- 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit Well number 45 9. Permit number/approval number 9-985 10. APl number 50- 733-20150-01 11. Field/Pool ~cArtnur River/Hemlock Pool At top of productive interval 1,100' FSL, 2,354' FWL, At effective depth Sec. 6- 8N- 13W - SM At total depth 1,178' FSL, 2,631' FWL, Sec. 6- 8N- 13W- SM 12. Present well condition sUmmary Total depth: measured true vertical 10,415' feet 10,108' feet Effective depth: measured 10,340 ' feet true vertical 10,039 ' feet Casing Length Size Structural Conductor Surface Intermediate 2,492' 13-3/8" Production Liner 10,399' 9- 5/8" Perforation depth: measured true vertical See Plugs (measured) Junk (measured) Cemented 2,405 sx 2,920 sx Attachment #1 None Measured depth 2,492' 10,399' True vertical depth 2,489' 10,093' Tubing (size, grade, and measured depth) 3-1/2", 9.3fl, N-80 DSS-HTC tbg. to 9,124' MD Packers and SSSV (type and measured depth) 9-5/8" Otis BWD Pkr w/ SBE (4.0" ID) @ 9,109' MD RrEcEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 'JAN 1 6,1 9,7 0ii & Gas Cons.. Anch0rag~ 14. Prior to well operation Subsequent to operation 11/17/89 12/20/89 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 998 2405 Tubing Pressure 4000 3850 15. Attachments Z Copies of Logs and Surveys run __ Daily Report of Well Operations _.~ 16. Status of Well classification as: Oil __ Gas ~ Suspended Service ~/ater Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15188' ,// Date 1/12/90 SUBMIT IN DUPLICATE Attachment #1 TBU Well D-45 Current Perforated Intervals M_D TVD B-1 B-3 B-4 B-5 9,716' - 9,730' 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' 9,473' - 9,486' 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' RECEIVED Attachment #2 Daily Summary of Well Operations TBU Well D-45 11/18/89 RU on D-45 to perforate. RU guns and run in lub. PT to 4000 psi. SI injectors. Open swab IP =1800 psi. RIH. Tie in to collars (P = 1250 psi). Flowed well down to 250 psi and perforate B-l, 9716' - 9730' DIL. POH, all guns fired. RU FBS. Hook up to pump in sub. PT equipment to 5000 psi. RIH to 9685' MD. Open waterflood to well (checked to 3000 psi). 11/19/89 Fall off test/ temperature log pass. MU logging passes (P. T. Spinner). Run between 9685' and 10,200' DIL and stationary stops between each level for the following' P = 3850 psi; Q ~ 400 BWIPD; waterflood syst. "= 4000 psi;" 900 " ; " " ": 4500 psi;" 1400 " ; BJ ": 5000 psi;" 1440 " ; BJ SI well. Make temperature pass. \docs\dvp\d45. doc :, ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 16 1. Type of Request: Abandon ~ Suspend __ Operation shutdown Re-enter suspended well __ Alter Casing __ Repair well ~ Plugging __ --Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance __ Perforate ~ Other 2. Name of Operator ~ 5. Type of Weil: UNOCAL (Marathon Oil Company - Sub Oi~erator~e. ve~.°Pm,ent- :1 ~-xp~oratory ~ 3. Address / Stratigraphic_ P. 0. Box 190247 Anchorage, AK__9_95.1~ _.. _S.ervi.ce.X__~_ 4. Location of well at surface Leg A-2 Cond. #J.z UOl ly varoen ~'la~;]-urm 752' FSL, 1,134' FWL, Sec. 6 -8N - 13W- SM At top of productive interval 1,100' FSL, 2,354' FWL, Sec. 6 - 8N - 13W - SM At effective depth At total depth 1,178' FSL, 2.,631' FWL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL 7, Unit or Property name Trading Bay Unit 8. Well number D-45 9. Permit number 88-140 10. APl number 50- 733-20150-01 11. Field/Pool HcArt, hur' River/Hemlock Pool feet 12. Present well condition summary Total depth: meaS'ured true vertical 10,415' feet 10,108' feet Plugs (measured) None Effective depth: . measured 10,340' feet true vertical 10,0 3 9 ' feet Casing Length Size Structural Conductor Surface Intermediate 2,492' 13-3/8" Production Liner 10,399' 9-5/8" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 DSS-HTC tbg. P k r~d S.V (ty n easur th Junk (measured) Cemented See 2,405 sx 2,920 sx Attachment #1 to 9,124' MD ID) 0 9,109' MD Measured depth True vertical depth 2,492' 2,489' 10,399' 10,093' RECE VE 13. Attachments 2 & 3 Description summary of proposal ._.g Detailed operations program __ BOP sketch ._X. 14. Estimated date for commencing operation November ].5, ].989 Date approved 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil __ Gas __ Suspended __ Service t~ater Injection 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.-,~ .¢,,.- d-~ Signed,~¢;'~~. /¢j:2,0.~~ Title E nvi ronmental Engineer ~¢/ /f Rov D. 'Roberts FOR COMMISSION USEONLY ConditiOn's o{approval: Notify Commission so representative may witness ~ ~ Plug integrity __ BOP Test ~ Location clearance ~ Date 11 / 8/89 Mechanical Integrity Test __ Subsequent form required 10- .,~o,~ Approved by order of the Commission ORIGINAL SIGNED BY LoNNtE C. SMITH I Approval N o. ~._._~"'~'''''' · '-~" ' ' Date 11--1~ --~9 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE B-3 B-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' . 10,070' 10,092' - 10,146' 10,156' - 10,176' 9,486' . 9,514' 9,638' . 9,651' 9,678' . 9,706' 9,712' . 9,791' 9,811' - 9,860' 9,869' - 9,888' Attachment #2 DOLLY VARDEN PLATFORM WELL D-45 ADDITIONAL BENCH 1 PERFORATING PROCEDURE · · Note' Shut in injection, but, do not bleed off tubing pressure. RU E-line and test lubricator. RIH with a 2-1/8" strip gun. Tie in depth to perforate 9,716~-9,730' DIL. Once on depth, bleed off tubing pressure to create an underbalance and perforate. POOH, RD E-line. Maximum anticipated SBHP is 4000 psi. \docs\dvp\d45. doc Attachment #3 L 3LLY V'ARDEN PL, 4'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP -4'~tJ~-1,6~. 5000 pal CHISTMAS TREE - GREASE HEAD (Hydraulically Activated) BRICATOR , RECEiVEi) POSITIVE CHOKE ~- 2' 5000 psi ...-- 2' 3000 psi 13 3/8' CASING /'"- STATE OF ALASKA ;'~ ALASKA OIL AND GAS CONSERVATION COMMISSION 0 R I G I N AIm- ~? ~:';~ REPORT OF-SUNDRY WELL OPERATIONS //-¢ 1, Operations performed: Operation shutdown __ Stimulate __ Pull tubing __ Alter casing ~ Repair well Plugging __ Perforate __ Other..~... Step-rate Test 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading) Bay Unit 8. Well number 2. Name of Operator 15. Type of Well: J_ _ _.,. _ _{:)evelopment __ mC r ctL u I') Exploratory 3. Address ! Stratigraphic P. O. Box 190247 Anchorage, AK 9951~ Service X...~. 4. Location of well at surface Leg A-2 Cond, #12 Dolly Varden Platform feet 752' FSL. 1,134' FWL Sec. 6 - 8N - 13W - SM At top of productive interval ' 1,100' FSL, 2,354' FWL, Sec. 6 -8N - 13W- SM At effective depth At total depth 178' FSL 631' FWL 12. Present well condition summary Total depth: measured true vertical 6 - 8N - 13W 10,415' feet 10,108' feet Effective depth: measured 10 340 ' feet true vertical ' feet 10,039' Casing Length Size Structural Conductor Surface Intermediate 2,492' 13-3/8" Production Liner 10,399' 9-5/8" Perforation depth: measured See - SM n_&~; 9. Permit number/approval number 9-664 10. APl number 5o- 733-20150-01 11. Field/Pool McArthur River/Hemlock Pool Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 2,405 sx 2,920 sx Attachment #1 2,492' 10,399' 2,489' 10,093' true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 DSS-HTC tbg. to 9,124' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MD MD RECEIVED Alaska Oil.& ~;as Con& ' ~ AnChorage C°aal,~lOtt 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/10/89 1173 3950 Subsequent to operation 7/25/89 1129 15. Attachments 2' & 3 ~ 16. Status of well classification as: Copies of Logs and Surveys run m I Daily Report of Well Operations ~X Oil ~ Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jsigned/~C~q~. ~¢-~_-//~' Title Environmental Engineer Form 10-4(~4P(ev06/15188 Koy D. Roberts 38OO ServiceWater Injection Date 8/25/89 SUBMIT IN DUPLICATE 8-3 B-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals MD 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' TVD 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' RECEIVED AUG ]~ o ~989 Alaska Oil & Gas Cons, Commission Anchorage ? STATE OF ALASKA .~.- ~ ALASK~,~. ,,L AND GAS CONSERVATION C :.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Water Injection ... 2. Name of Operatpr . 7. Permit Number UNOCAL (Harathon 0il Co, - Sub-Operator 88-!40 · 3. Address : 8. APl Number P. 0. Box 190247 Anchorage, AK 99519 50- 733-20150-01 4. Location of well at surface Leg A-2 Cond. 12 Doiiy Varden Pi atform 9. Unit or Lease Name 752' FSL, 1,134' FWL, Sec 6, 8N - 13W - SM Trading Bay Unit At Top Producing Interval 10. Well Number 1100' FSL, 2,354' FWL, Sec 6, 8N - 13W - SM D-45 At Total Depth 11. Field and Pool 1,178' FSL, 2,631' FWL, Sec 6, 8N- 13W- SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB above MSL ADL 18729 Hemlock Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 4/5/89 5/21/89 6/5/89 128 feet MSL 17. Total Depth (M D+TVD) 10415-10108' 18. Plug Back Depth (MD+TVD) 10340-10039' YES[~ 19. Directional Survey NO[] I20' Depth where sSSV set N/A feet MD I21 ' Thickness Of PermafrOst N/A 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE' WT. PER FT. GRADE ~OP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8 bU# N-80 Surface 2492' 17.5" 2405 sx "G" cmt N/A 9-5/8 53.5# P-110 & Surface -- C-75 9-5/8 47# N-80 .... 9-5/8 43.5# N-80 -- 10399' 12.25" 2920 sx "G" cmt 310,000 lbs 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ., interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9124' 9109' . · See Attachment I for intervals '~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. All perfo/;ations are . DEPTH.INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 5 SPF, 60v phasing .'] ; 27. I nj ect fe~DUCT~ON TEST Date First Production I Method o.f Operation (Flowing, gas lift, etc.) 6/25/89'I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/26/89 24 TEST PERIOD I~ N/A N/A N/A N/A Flow Tubing Casing Pressure . . CALCULATED OIL-BBL GAS-MCF. WATER-BBL OIL GRAVITY-APl (corr) Press. 3580 , 24-HOUR RATE ~ N/A N/A N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . ; Alaska Oil & Gas Oons. f.;ommJssior~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Hemlock Top B-1 GEOLOGIC MARKERS MEAS DEPTH 973O TRUE VERT. DEPTH 9486 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Attach. #1, Perforated Intervals- Attachment ¢/2, Current Wellbore Diag Attachment #3, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ~~'J~' ~~~ Title Environmental Date 8/8/89 ~ ~/ Roz D: Roberts Engin~_e~ . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item :27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 B-1 B-3 B-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals MD 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' TVD 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' Attachment #2 Daily Summary of Well Operations TBU Well D-45 7/16/89 RU pumping equipment and pressure recorder. Test lines to 5000 psig, OK. Stabilize well and start a high pressure step-rate test beginning at 4075 psig, 1440 BWPD rate and stopping at 5060 psig, 4200 BWPD rate. Shut in injection and monitor fall off test. RD pumping equipment and line well up to platform injection system. 7/17/89 Begin low pressure step-rate test w/ production injection pump beginning at 2500 psig, 0 BWPD rate and stopping at 3825 psig, 1500 BWPD rate. RD pressure recorder and put well back on injection. See attached graph for test results. \docs\dvp\d45 Attachment #2 MARATHDN DIL COMPANY TRADING BAY UNIT WELL ]]-45 Completed 6/5/89 ALt mecsucemznts ere RKB ~o top o~ equlpmznt, 41' Ccmeron FBB Stemless Tho Hn©r ~,5~ 8RD Top x DS$-HTC Bottom, 318' Flo~ Cp~§ (3.885' OD) BxP IPC ~/TK69. 324' O~is 'X' N~pple (2.813' II}). 325' Flow CplQ (3.885' OD) BxP IRC w/TK69. ComoLe-l;Ion S-~rlng~ 0'-9124' 3.5', 9.3# N-80 Tbg, [PC w/TK69. (Tbg i~ Condition #1) 9-5/8' 43,515 N-80 to 3,425'j 4715 N-BO & P-IlO to 8,423'; 53,5~ C-75 & P-110 to 10,399', 9109' 9]09' 9124' 9137' 9]69' 9170' 3-3 B-3 B-1 B-3 B-3 B-4 B-4 B-5 B-5 Otls S~r~lght SLot Locotor w/seal ex~ and secL mcn01rels w/16,7' seels, OtIs BWI) P~cker (4.0' ID) ~/SBE mI~Lou~ ex~ (4.0' ID), Mu[eshoe (8,99' ID), 4.5' 8R~x3.5' BTC PxP Crossover. ~:~ 'XN' N~pp~e (2.813' ID) ~/2.75' NoGo. O%~s ~/L Entry Ou~de (~,99' ID), PERFORATIONS 9730'-9762' 5 SPF 60' Phasing 6/3/89 9900'-9914 9944'-9976 9982'-10,070 ]0,092'-10,146 .... 10,156'-10,176 B-5 3-5 PBTD 8 10,340' TI} 8 10,415' Revision I}~te~ 06/05/89 Revise~ By: VHR/ne~ Re~on: New WeLL Prev~ou~ Rev;s;on: 6 D-z 5 INJECTION STEP RATE TEST 5 2 0 0 2 4 6 PRESSURE I I I 1 8 10 12 14 ELAPSED TIME (HOURS) RATE (BWPD) 16 18 20 SURVEY REPORT_ ~THON OIL COMPANY TRADING BAY UN1T, WELL NUMBER D45 MCARTHUR RIVER FI:ELD, KENAI BOROUGH, ALASKA JUNE 5, 5989 /~ .¢-o_ 7..~ . 2o / .¢'o - o / ORIGINAL A Gyrodata ~RATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-45 2ARTHUR RIVgR FIELD, KENAI BOROUGH, ALASKA ~b Number: AKO589G237 Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min ,0 0 0 100.0 200.0 300.0 400.0 500.0 600.0 7O0.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900,0 2000.0 2100.0 2200.0 23OO.0 2400.0 0 27 0 4 N66 llW 0 9 S 7 9W 0 21 N 31 53 E 0 29 0 34 3 25 5 41 5 41 5 23 4 32 3 32 3 1 2 20 2 4 I 48 1 44 1 9 I 0 0 57 0 48 0 37 0 27 0 35 DOG-LEG VERT VERT C L O S U R E SEVERITY DEPTH SECTION DISTANCE BEARING deg/lO0' ft ft ft deg min N 0 0 E .00 .0 .0 .0 N 0 0 E GYRO DATA SURVEY RAN IN 9 5/8 INCH CASING TO T.D. ' ALL MEASURED DEPTHS REFERENCED TO DOLLY VARDON R.K.B. ELEV. N 42 14 W .45 100.0 -.2 .4 N 42 14 W .39 .17 .48 200.0 -.4 .8 N 48 36 W ,300.0 -.6 .9 N 58 9 W 400.0 -.4 .6 N 51 52 W N 46 51 E .17 500.0 .2 N 58 32 E ~ .13 600.0 1.1 N 30 7 E 2.94 699.9 4.1 N 37 27 E 2.32 799.6 10.1 N 70 36 E 3.24 899.1 19.2 N 78 37 E .83 998.6 28.9 N 78 37 E .86 1098.3 37.5 N 81 23 E 1.01 1198.0 44.5 N 80 25 E .52 1297.9 50.2 N 80 22 E .68 1397.7 54.8 N 81 31 E .27 1497.7 58.6 N 80 5 E .27 1597.6 62.0 N 81 3 E .08 1697.6 65.1 N 83 24 E .60 1797.5 67.5 N 83 10 E .14 1897.5 69,4 N 85 13 E .07 1997.5 71.1 N 82 11 E .16 2097.5 72.6 N 76 11 E .20 2197.5 73.8 S 80 25 E .26 2297.5 74.7 N 82 50 E .20 239?.5 75.6 HORIZONTAL C O O R D I N A T E ?'~feet .00 N .00 E .55 N .62 W .47 N .76 W ,37 N .47 W .9 N 1 3 W .92 N .02 W 1.6 N 25 34 E 1.46 N .70 E 5.0 N 38 20 E '3.92 N 3.10 E 12.9 N 35 32 E 10.51 N 7,51 E 22.4 N 43 29 g 16.25 N 15.41 E 31.0 N 52 43 E 39.0 N 58 17 E 45.6 N 61 33 E 51.0 N 63 40 E 55.5 N 65 3 g 59.2 N 66 5 E 62.5 N 66 52 E 65.5 N 67 30 E 67.9 N 68 3 E 69.8 N 68 27 E 71.4 N 68 49 E 72.9 N 69 7 E 74.1 N 69 17 E 74.9 N 69 31 E 75.8 N 69 46 E 18.80 N 24.70 E 20.51 N 33.18 E 21.73 N 60.10 E 22.63 N 45.74 E 24.02 N 54- ~' 24.56 N 57.48 E 25.06 N 60.52 E 25.40 N 63.01 E 25.62 N 64.87 E 25.80 N 66.57 E 25.96 N 68.08 E 26.19 N 69.28 E 26.23 N 70.21 E 26.21 N 71.11 f A Gyrodata Directional for Survey MARATHON OIL COMPANY TRADING BAY UNIT WELL NUMBER D-45 McARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA Date Run: 29-MAY-89 04:10:00 Job Number: AKO589G237 Surveyor: DANNY ADAMS Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 48min 30sec N Bearings are Relative'to TRUE NORTH Proposed Well Direction: N 74deg 13min 12sec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated fr~m Local Horizontal Reference A Gyrodata IRATHON OIL COMPANY ADING BAY UNIT WELL NUMBER D-45 ARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ,b Number: AK0589G237 Directional Survey Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft dee min dee min deE/lO0' 2500.0 0 29 N 82 33 E 2600.0 0 41 N 39 4 E 2700.0 0 40 N 41 32 E 2800.0 0 41 N 40 40 E 2900.0 0 44 N 43 24 E 3000.0 0 41 N 38 16 E 3100.0 0 39 N 65 15 E 3200.0 0 36 N 73 2 E 3300.0 0 32 N 33 35 E - 3400.0 0 44 N 60 2 E 3500.0 0 40 N 65 53 E 3600.0 0 53 N 59 27 E 3700.0 I 7 N 50 46 E 3800.0 1 12 N 56 52 E 3900.0 1 24 N 62 24 E 4000.0 1 22 N 67 16 E 4100.0 1 6 N 56 37 E 4200.0 1 15 N 78 22 E 4300.0 0 59 N 70 2 E 4400.0 1 11 N 75 24 E 4500.0 1 15 N 78 54 E 4600.0 1 2 S 89 13 E 4700.0 I 3 N 72 38 E 4800.0 1 3 N 75 24 E 4900.0 1 12 S 85 26 E VERT VERT DEPTH SECTION ft ft .10 2497.5 76.5 .47 2597.5 77.5 .04 2697.5 : 78.4 .03 2797.4 79.4 .06 2897.4 80.5 .08 .31 .10 .39 .34 .10 .24 .28 .14 .24 2997.4 81.5 3097.4 82.6 3197.4 83.7 3297.4 84.6 3397.4 85.5 3497.4 86.7 3597.4 88.0 3697.4 89.7 3797.4 91.6 3897.3 93.8 .12 3997.3 96.1 .34 4097.3 98.2 .47 4197.3 100.3 .32 4297.2 102.2 .23 4397.2 104.1 .10 4497.2 106.2 .32 4597.2 108.2 .33 4697.2 110.0 .05 4797.1 111.8 .40 4897.1 113.7 C L O S U R E DISTANCE BEARING ft dee min 76.7 N 69 56 E 77.7 N 69 49 E 78.7 N 69 23 E 79.8 N 68 59 E 80.9 N 68 35 E 82.0 N 68 11 E 83.1 N 67 58 E 84.2 N 67 58 g 85.1 N 67 49 E 86.1 N 67 33 E 87.3 N 67 29 E 88.7 N 67 25 E 90.4 N 67 11 E 92.3 N 66 53 E 94.6 N 66 43 E 97.0 N 66 40 E 99.1 N 66 34 E 101.2 N 66 35 E 103.1 N 66 44 E 105.0 N 66 50 E 107.1 N 67 2 E 108.9 N 67 21E 110.7 N 67 35 E 112.5 N 67 42 E 114.4 N 67 59 E HORIZONTAL COORDI NATES= feet 26.33 N 72.04 E 26.81 N 72.92 E 27.71 N 73.68 E 28.60 N 74.45 E 29.52 N 75.28 E 30.46 N 76.10 E 31.18 N 77.00 E 31.56 N 78.01 E 32.14 N 78.79 E 32.89 N 79.58 E 33.44 N 80.66 34.06 N 81.86 35.05 N 83.30 36.25 N 84.93 37.39 N 86.88 38.42 N 89 06 ~3 39.43 N 90i95 40.21 N, 92 84 40.73 N 94.70 E 41.29 N 96.50 E 41.77 N 98.57 41.94 N 100.55 42.21 N 102.34 42.71 N 104.10 42.88 N 106.04 A Gyrodata ~RATHON OIL COMPANY {ADING BAY UNIT WELL NUMBER D-45 :ARTHUR RIVER FIELD, KENAI BOROUGH ALASKA lb Number: AK0589G237 ' Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min dee min deE/100' 5000.0 1 14 S 88 50 E 5100.0 1 9 N 85 54 E 5200.0 1 17 S 82 46 E 5300.0 1 20 S 82 52 E 5400.0 1 34 S 84 42 E 5500.0 1 27 S 76 48 E 5600.0 1 52 S 63 30 E 5700.0 1 49 S 64 5 E 5800.0 1 42 S168 20 E ~ 5900.0 1 38 S 69 43 E 6000.0 1 36 S 71 30 E 6100.0 1 41 S 84 25 E 6200.0 1 45 S 89 5 E 6300.0 1 47 N 85 57 E 6400.0 1 52 N 83 41 E 6500.0 1 55 N 83 54 E 6550.0 2 7 N 73 51 E 6600.0 3 16 N 84 3 E 6650.0 4 55 N 78 2 E 6700.0 6 57 N 71 46 E 6750.0 8 49 N 66 15 E 6800.0 10 39 N 64 28 E 6850.0 11 52 N 65 8 E 6900.0 12 23 N 64 44 E 6950.0 12 53 N 65 10 E VERT VERT DEPTH SECTION ft~ ft .08 4997.1 115.7 .13 5097.1 117.7 .27 5197.1 ' 119.7 .06 5297.0 121.8 .24 5397.0 124.2 .24 5497.0 126.6 .56 5596.9 128.9 .04 5696.9 131.3 .18 5796.8 133.6 .08 5896.8 136.0 .06 5996.7 138.3 .38 6096.7 140.8 .16 6196.7 143.6 .16 6296.6 146.6 .12 6396.6 149.7 .04 6496.5 153.0 .80 6546.5 154.8 2.49 6596.4 157.1 3.39 6646.3 160.6 4.28 6696.0 165.8 4.01 6745.5 172.6 3.73 6794.8 181.0 2.45 6843.9 190.6 1.03 6892.7 201.0 1.01 6941.5 211.7 CLOSURE DISTANCE BEARING ft dee min 116.3 N 68 25 E 118.3 N 68 46 E 120.2 N 69 9 E 122.2 N 69 40 E 124.5 N 70 11E 126.8 N 70 45 E 129.0 N 71 34 E 131.3 N 72 33 E 133.7 N 73 25 E 136.0 N 74 10 E 138.3 N 74 50 E 140.8 N 75 22 E 143.7 N 75 44 E 146,7 N 76 0 E 149.8 N 76 11E 153.1 N 76 21 E 154.9 N 76 22 E 157.2 N 76 25 E 160.8 N 76 31 E 165.9 N 76 28 g 172.7 N 76 10 E 181.0 N 75 40 E 190.6 N 75 7 E 201.0 N 74 35 E 211.7 N 74 5 E HORIZONTAL C O O R D I N A T E ~ feet 42.77 N 108.15 E 42.83 N 110.23 E 42.77 N 112.34 E 42.49 N 114'60 E 42.21 N 117.11 E 41.79 N 119.70 E 40.81 N 122.40 E 39.39 N 125.28 E 38.15 N 128.10 E 37.11 N 130.81 E 36.18 N 133.46 E 35.59 N 136.25 E 35.42 N 139.24 E 35.50 N 142.32 E 35.79 N 145.50 E 36.15 N 148.78 36.49 N 150.5£ 36.93 N 152.80]~ 37.49 N 156.32 38.83 N 161.31 41.29 N 167.70 E 44.81 N 175.38 E 48.97 N 184.22 E 53.42 N 193.73 E 58.05 N 203.63 E A Gyrodata ~RATHON OIL COMPANY ~DING BAY UNIT WELL NUMBER D-45 :ARTHUR R~VER FIELD, KENAI BOROUGH, ALASKA }b Number. AK0589G237 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 7000.0 13 34 N 66 12 E 7050.0 14 23 N 67 26 E 7100.0 15 21 N 69 14 E 7150.0 16 48 N 70 31E 7200.0 17 50 N 71 16 E 7250.0 18 39 N 72 26 E 7300.0 19 10 N 74 21 E 7350.0 19 45 N 75 57 E 7400.0 20 34 N 77 50 E ~ 7450.0 21 41 N 79 24 E 7500.0 22 45 N 78 42 E 7550.0 23 29 N 75 23 E 7600.0 23 59 N 69 41 E 7650.0 25 3 N 66 13 E 7700.0 26 27 N 63 13 E 7800.0 27 28 N 59 12 E 7900.0 26 28 N 59 55 E 8000.0 25 42 N 60 43 E 8100.0 24 17 N 61 3 E 8200.0 23 38 N 61 53 E 8300.0 23 15 N 61 36 E 8400.0 23 6 N 61 34 E 8500.0 22 45 N 61 37 E 8600.0 22 6 N 62 17 E 8700.0 21 18 N 62 51 E VERT VERT DEPTH SECTION ft ft 1.45 6990.2 223.0 1.74 7038.7 235.0 2,16 7087.I , 247.8 2.99 7135.1 261.6 2.11 7182.8 276.5 1.79 7230.3 292.1 1.60 7277.6 308.3 1.58 7324.8 324.9 2.10 7371.7 342.2 2.~9 7418.3 360.1' 2.19 7464.6 379.0 3.00 7510.6 398.6 4.69 7556.4 418.7 3.59 7601.9 439.3 3.82 7646.9 460.7 2.08 7736.0 504.9 1.06 7825.2 548.7 .83 7915.0 591.4 1.42 8005.6 632.5 .74 8097.0 672.1 .41 8188.7 711.0 .14 8280.7 749.4 .37 8372.8 787.4 .69 8465.2 824.7 .83 8558.1 860.9 C L O S U R E DISTANCE BEARING ft deg min 223.1 N 73 40 E 235.1 N 73 19 E 247.8 N 73 3 E 261.7 N 72 53 E 276.5 N 72 47 E 292.2 N 72 44 E 308.4 N 72 46 E 325.0 N 72 53 E 342.2 N 73 5 E 360,2 N 73 22 g 379.0 N 73 39 E 398.6 N 73 49 E 418.7 N 73 45 E 439.3 N 73 29 E 460.8 N 73 4 E 505.2 N 72 1 E 549.6 N 70 59 E 592.9 N 70 12 E 634.6 N 69 35 E 674.8 N 69 6 E 714.3 N 68 41E 753.4 N 68 19 E 792.1 N 67 59 E 830.0 N 67 43 E 866.8 N 67 30 E HORIZONTAL COORD I NATES~- feet 62.76 N 214,05 67.51 N 225.15 72.25 N 237.07 77.O1 N 250.07 81.88 N 264.14 86.76 N 279.02 91.39 N 294.54 95.66 N 310.64 99.57 N 327.42 103.13 N 345.09 106.72 N 363.64 E 111.12 N 382.77 E 117.16 N 401.96 E 124.94 N 421.18 E 134.22 N 440.82 g 156.05 N 480.55 179.02 N 519.62 200.79 N 557.83 221.35 N 594.75 240.75 N 630.44 259.58 N 665.48 E 278.31 N 700.09 E 296.84 N 734.35 E 314.78 N 768.00 E 331.81 N 800.81 g A Gyrodata ~RATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-45 ~ARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ~b Number: AKO589G237 Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft dee min dee min 8800.0 21 47 N 63 18 E 8900.0 23 17 N 64 53 E 9000.0 25 4 N 66 2 E 9050.0 25 25 N 66 47 E 9100.0 25 54 N 67 0 E 9200.0 26 45 N 67 53 E 9300.0 26 59 N 68 9 9400.,0 27 11 N 67 42 E 9500.0 27 36 N 68 14 E 9600.0 27 31 N 68 11 E 9700.0 27 32 N 68 27 E 9800.0 26 9 N 68 47 E 9900.0 26 11 N 68 3 E 10000.0 25 37 N 68 1 E 10100.0 24 55 N 68 7 E 10200.0 23 31 N 67 51 E 10300.0 21 54 N 67 55 E Final Station Closure: 1554.3 feet DOG-LEG VERT VERT SEVERITY DEPTH SECTION deE/lO0' ft ft .51 8651.1 896.9 1.63 8743.5 934.6 1.85 8834.7 ' 975.1 .93 8880.0 996.2 .98 8925.0 1017.7 .94 9014.7 1061.7 .26 9103.9 1106.7 .29 9192.9 1151.9 .48 9281.7 1197.6 .08 9370.3 1243.6 .13 9459.0 1289.6 1.40 9548.2 1334.6 .33 9638.0 1378.4 .57 9727.9 1421.9 .70 9818.4 1464.3 1.39 9909.6 1505.1 1.63 10001.8 1543.4 North 67 dee 25 min 35 sec East CLOSURE DISTANCE BEARING ft dee min 903.4 N 67 19 E 941,7 N 67 11E 9'82.6 N 67 7 E 1004.0 N 67 6 E 1025.6 N 67 6 E 1070.0 N 67 6 E 1115.2 N 67 9 E 1160.7 N 67 10 1206.7 N 67 12 E 1252.9 N 67 14 E 1299.1 N 67 17 E 1344.3 N 67 19 E 1388.4 N 67 22 E 1432.1 N 67 23 E 1474.7 N 67 24 E 1515.7 N 67 25 E 1554.3 N 67 26 E HORIZONTAL C 0 0 R D I N A T E $~.) feet 348.44 N 833.54 E 365.19 N 868.01 E 382.20 N 905.27 E 390,73 N 924.82 E 399.23 N 944.73 E 416.25 N 985.68 E 433.17 N 1027.59 E 450.28 N 1069.78 E 467.54 N 1112.42 E 484.71 N 1155.38 E 501.79 N 1198,32 E 518.26 N 1240.37 E 534.48 N 1281.38 E 550.81 N 1321.88 E 566.75 N 1361.47 E 582.13 N 1399.5P~ 596.67 N 1435.2{ · ftOUSTON INSTRUM[NT ~'Mu,~, '--":: ma:. :~n~.-t, ~:ou,:~~ ~; m'?---'-'-',~ ". 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Attachment #3 : .ROFILHED SURVEY REPORT MARATHON OIL COMPANY TRADING BAY UNIT, WELL NUMBER D-45 MCARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA JUNE 1, 1989 ORIGINAL A Gyrodata ARATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-45 cARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ob Number: AKO589G237 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' .0 0 0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 0 27 0 4 0 9 0 21 0 29 0 34 3 25 5 41 5 41 5 23 4 32 3 32 3 1 2 2O 2 4 1 48 1 44 1 9 1 0 0 57 0 48 0 37 0 27 0 35 VERT VERT DEPTH SECTION ft ft CLOSURE DISTANCE BEARING ft deg min N 0 0 E .00 .0 .0 .0 N 0 0 E GYRO DATA SURVEY RAN IN 9 5/8 INCH CASING TO T.D. ALL MEASURED DEPTHS REFERENCED TO DOLLY VARDON R.K.B. ELEV. N 42 14 W .45 100.0 -.2 .4 N 42 14 W N 66 11 W .39 20020 -.4 .8 N 48 36 W S 7 9 W .17 300.0 -.6 .9 N 58 9 W N 31 53 E .48 400.0 -.4 .6 N 51 52 W N 46 51 E .17 500.0 .2 N 58 32 E .13 600.0 1.1 N 30 7 E 2.94 699.9 4.1 N 37 27 E 2.32 799.6 10.1 N 70 36 E 3.24 899.1 19.2 N 78 37 E .83 998.6 28.9 N 78 37 E .86 1098.3 37.5 N 81 23 E 1.01 1198.0 44.5 N 80 25 E .52 1297.9 50.2 N 80 22 E .68 1397.7 54.8 N 81 31 E .27 1497.7 58.6 N 80 5 E .27 1597.6 62.0 N 81 3 E .08 1697.6 65.1 N 83 24 E .60 1797.5 67.5 N 83 10 E .14 1897.5 69.4 N 85 13 E .07 1997.5 71.1 N 82 11 E .16 2097.5 72.6 N 76 11 E .20 2197.5 73.8 S 80 25 E .26 2297.5 74.7 N 82 50 E .20 2397.5 75.6 HORIZONTAL C O O R D I N A T E $-~ feet .00 N .00 E .29 N .26 W .55 N .62 W .47 N .76 W .37 N .47 W .9 N 1 3 W .92 N .02 W 1.6 N 25 34 E 1.46 N .70 E 5.0 N 38 20 E 3.92 N 3.10 E 12.9 N 35 32 E 10.51 N 7.51 E 22.4 N 43 29 E 16.25 N 15.41 E 31.0 N 52 43 E 39.0 N 58 17 E 45.6 N 61 33 E 51.0 N 63 40 E 55.5 N 65 3 E 59.2 N 66 5 E 62.5 N 66 52 E 65.5 N 67 30 E 67.9 N 68 3 E 69.8 N 68 27 E 71.4 N 68 49 E 72.9 N 69 7 E 74.1 N 69 17 E 74.9 N 69 31 E 75.8 N 69 46 E 18.80 N 24.70 E 20.51 N 33.18 E 21.73 N 40.10 E 22.63 N 45.74 E 23.41 N 503~ ~ 24.02 N 54114~ 24.56 N 57.48 E .25.06 N 60.52 E 25.40 N 63.01 E 25.62 N 64.87 E 25.80 N 66.57 E 25.96 N 68.08 E 26.19 N 69.28 E 26.23 N 70.21 E 26.21 N 71.11 E Gyrodata Directional for Survey MARATHON OIL COMPANY TRADING BAY UNIT WELL NUMBER D-45 McARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA Date Run: 29-MAY-89 04:10:00 Job Number: AKO589G237 Surveyor: DANNY ADAMS Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 48min 30sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: N 74deg 13min 12sec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata ARATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-45 cARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ob Number: AKO589G237 Directional Su~rvey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 2500.0 0 29 N 82 33 E 2600.0 0 41 N 39 4 E 2700.0 0 40 N 41 32 E 2800.0 0 41 N 40 40 E 2900.0 0 44 N 43 24 E 3000.0 0 41 N 38 16 E 3100.0 0 39 N 65 15 E 3200.0 0 36 N 73 2 E 3300.0 0 32 N 33 35 E 3400.0 0 44 N 60 2 E 3500.0 0 40 N 65 53 E 3600.0 0 53 N 59 27 E 3700.0 1 7 N 50 46 E 3800.0 1 12 N 56 52 E 3900.0 1 24 N 62 24 E 4000.0 1 22 N 67 16 E 4100.0 1 6 N 56 37 E 4200.0 1 15 N 78 22 E 4300.0 0 59 N 70 2 E 4400.0 1 11 N 75 24 E 4500.0 1 15 N 78 54 E 4600.0 1 2 S 89 13 E 4700.0 1 3 N 72 38 E 4800.0 1 3 N 75 24 E 4900.0 1 12 S 85 26 E VERT VERT DEPTH SECTION ft ft .10 2497.5 76.5 .47 2597.5 77.5 .04 2697.5 78.4 .03 2797.4 79.4 .06 2897.4 80.5 .08 2997.4 81.5 .31 3097.4 82.6 .10 3197.4 83.7 .39 3297.4 84.6 .34 3397.4 85.5 .10 3497.4 86.7 .24 3597.4 88.0 .28 3697.4 89.7 .14 3797.4 91.6 .24 3897.3 93.8 .12 3997.3 96.1 .34 4097.3 98.2 .47 4197.3 100.3 .32 4297.2 102.2 .23 4397.2 104.1 .10 4497.2 106.2 .32 4597.2 108.2 .33 4697.2 110.0 .05 4797.1 111.8 .40 4897.1 113.7 CLOSURE DISTANCE BEARING ft deg min 76.7 N 69 56 E 77.7 N 69 49 E 78.7 N 69 23 E 79.8 N 68 59 E 80.9 N 68 35 E 82.0 N 68 11 E 83.1 N 67 58 E 84.2 N 67 58 E 85.1 N 67 49 E 86.1 N 67 33 E 87.3 N 67 29 E 88.7 N 67 25 E 90.4 N 67 11 E 92.3 N 66 53 E 94.6 N 66 43 E 97.0 N 66 40 E 99.1 N 66 34 E 101.2 N 66 35 E 103.1 N 66 44 E 105.0 N 66 50 E 107.1 N 67 2 E 108.9 N 67 21E 110.7 N 67 35 E 112.5 N 67 42 E 114.4 N 67 59 E HORIZONTAL C O O R D I N A T E feet 26.33 N 72.04 E 26.81 N 72.92 E 27.71 N 73.68 E 28.60 N 74.45 E 29.52 N 75.28 E 30.46 N 76.10 E 31.18 N 77.00 E 31.56 N 78.01 E 32.14 N 78.79 E 32.89 N 79.58 E 33.44 N 80.66 E 34.06 N 81.86 E 35.05 N 83.30 E 36.25 N 84.93 E 37.39 N 86.88 E 38.42 N 89.06 ~\ 39.43 N 90.9~ 40.21 N 92.84' 40.73 N 94.70 E 41.29 N 96.50 E 41.77 N 98.57 E 41.94 N 100.55 E 42.21 N 102.34 E 42.71 N 104.10 E 42.88 N 106.04 E A Gyrodata ~%RATHON OIL COMPANY .{ADING BAY UNIT WELL NUMBER D-45 ~ARTHUR RIVER FIELD, KENAI BOROUGH ALASKA ~b Number: AK0589G237 ' Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 5000.0 1 14 $ 88 50 E 5100.0 1 9 N 85 54 E 5200.0 1 17 S 82 46 E 5300.0 1 20 S 82 52 E 5400.0 1 34 S 84 42 E 5500.0 1 27 S 76 48 E 5600.0 1 52 $ 63 30 E 5700.0 1 49 S 64 5 E 5800.0 1 42 S 68 20 E 5900.0 1 38 S 69 43 E 6000.0 1 36 S 71 30 E 6100.0 1 41 $ 84 25 E 6200.0 1 45 S 89 5 E 6300.0 1 47 N 85 57 E 6400.0 1 52 N 83 41 E 6500.0 1 55 N 83 54 E 6550.0 2 7 N 73 51 E 6600.0 3 16 N 84 3 E 6650.0 4 55 N 78 2 E 6700.0 6 57 N 71 46 E 6750.0 8 49 N 66 15 E 6800.0 10 39 N 64 28 E 6850.0 11 52 N 65 8 E 6900.0 12 23 N 64 44 E 6950.0 12 53 N 65 10 E VERT VERT DEPTH SECTION ft ft .08 4997.1 115.7 .13 5097.1 117.7 .27 5197.1 119.7 .06 5297.0 121.8 .24 5397.0 124.2 .24 5497.0 126.6 .56 5596.9 128.9 .04 5696.9 131.3 .18 5796.8 133.6 .08 5896.8 136.0 .06 5996.7 138.3 .38 6096.7 140.8 .16 6196.7 143.6 .16 6296.6 146.6 .12 6396.6 149.7 .04 6496.5 153.0 .80 6546.5 154.8 2.49 6596.4 157.1 3.39 6646.3 160.6 4.28 6696.0 165.8 4.01 6745.5 172.6 3.73 6794.8 181.0 2.45 6843.9 190.6 1.03 6892.7 201.0 1.01 6941.5 211.7 CLOSURE DISTANCE BEARING ft deg min 116.3 N 68 25 E 118.3 N 68 46 E 120.2 N 69 9 E 122.2 N 69 40 E 124.5 N 70 11E 126.8 N 70 45 E 129.0 N 71 34 E 131.3 N 72 33 E 133.7 N 73 25 E 136.0 N 74 10 E 138.3 N 74 50 E 140.8 N 75 22 E 143.7 N 75 44 E 146.7 N 76 0 E 149.8 N 76 11E 153.1 N 76 21 E 154.9 N 76 22 E 157.2 N 76 25 E 160.8 N 76 31 E 165.9 N 76 28 E 172.7 N 76 10 E 181.0 N 75 40 E 190.6 N 75 7 E 201.0 N 74 35 E 211.7 N 74 5 E HORIZONTAL C 0 0 R D I N A T E S'~-) feet 42.77 N 108.15 E 42.83 N 110.23 E 42.77 N 112.34 E 42.49 N 114.60 E 42.21 N 117.11 E 41.79 N 119.70 E 40.81 N 122.40 E 39.39 N 125.28 E 38.15 N 128.10 E 37.11 N 130.81 E 36.18 N 133.46 E 35.59 N 136.25 E 35.42 N 139.24 E 35.50 N 142.32 E 35.79 N 145.50 E 36.15 N 148.78 ~ 36.49 N 150.5G 36.93 N 152.80 ' 37.49 N 156.32 E 38.83 N 161.31 E 41.29 N 167.70 E 44.81 N 175.38 E 48.97 N 184.22 E 53.42 N 193.73 E 58.05 N 203.63 E A G y r o d a t a ~RATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-45 ~ARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ~b Number: AKO589G237 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 7000.0 13 34 N 66 12 E 1.45 7050.0 14 23 N 67 26 E 1.74 7100.0 15 21 N 69 14 E 2.16 7150.0 16 48 N 70 31 E 2.99 7200.0 17 50 N 71 16 E 2.11 7250.0 18 39 N 72 26 E 1.79 7300.0 19 10 N 74 21 E 1.60 7350.0 19 45 N 75 57 E 1.58 7400.0 20 34 N 77 50 E 2.10 7450.0 21 41 N 79 24 E 2.49 7500.0 22 45 N 78 42 E 2.19 7550.0 23 29 N 75 23 E 3.00 7600.0 23 59 N 69 41 E 4.69 7650.0 25 3 N 66 13 E 3.59 7700.0 26 27 N 63 13 E 3.82 7800.0 27 28 N 59 12 E 2.08 7900.0 26 28 N 59 55 E 1.06 8000.0 25 42 N 60 43 E .83 8100.0 24 17 N 61 3 E 1.42 8200.0 23 38 N 61 53 E .74 8300.0 23 15 N 61 36 E .41 8400.0 23 6 N 61 34 E .14 8500.0 22 45 N 61 37 E .37 8600.0 22 6 N 62 17 E .69 8700.0 21 18 N 62 51 E .83 VERT VERT DEPTH SECTION ft ft 6990.2 223.0 7038.7 235.0 7087.1 247.8 7135.1 261.6 7182.8 276.5 7230.3 292.1 7277.6 308.3 7324.8 324.9 7371.7 342.2 7418.3 360.1 7464.6 379.0 7510.6 398.6 7556.4 418.7 7601.9 439.3 7646.9 460.7 7736.0 504.9 7825.2 548.7 7915.0 591.4 8005.6 632.5 8097.0 672.1 8188.7 711.0 8280.7 749.4 8372.8 787.4 8465.2 824.7 8558.1 860.9 CLOSURE DISTANCE BEARING ft deg min 223.1 N 73 40 E 235.1 N 73 19 E 247.8 N 73 3 E 261.7 N 72 53 E 276.5 N 72 47 E 292.2 N 72 44 E 308.4 N 72 46 E 325.0 N 72 53 E 342.2 N 73 5 E 360.2 N 73 22 E 379.0 N 73 39 E 398.6 N 73 49 E 418.7 N 73 45 E 439.3 N 73 29 E 460.8 N 73 4 E 505.2 N 72 1 E 549.6 N 70 59 E 592.9 N 70 12 E 634.6 N 69 35 E 674.8 N 69 6 E 714.3 N 68 41E 753.4 N 68 19 E 792.1 N 67 59 E 830.0 N 67 43 E 866.8 N 67 30 E HORIZONTAL C 0 0 R D I N A T E F~) feet 62.76 N 214.05 E 67.51 N 225.15 E 72.25 N 237.07 E 77.01 N 250.07 E 81.88 N 264.14 E 86.76 N 279.02 E 91.39 N 294.54 E 95.66 N 310.64 E 99.57 N 327.42 E 103.13 N 345.09 E 106.72 N 363.64 E 111.12 N 382.77 E 117.16 N 401.96 E 124.94 N 421.18 E 134.22 N 440.82 E 156.05 N 480 55 179.02 N 519i63 200.79 N ' 557 83 221.35 N 594.75 240.75 N 630.44 259.58 N 665.48 E 278.31 N 700.09 E 296.84 N 734.35 E 314.78 N 768.00 E 331.81 N 800.81 E A Gyrodata ~RATHON OIL COMPANY .~ADING BAY UNIT WELL NUMBER D-45 2ARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA ~b Number: AKO589G237 Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 8800.0 21 47 N 63 18 E 8900.0 23 17 N 64 53 E 9000.0 25 4 N 66 2 E 9050.0 25 25 N 66 47 E 9100.0 25 54 N 67 0 E 9200.0 26 45 N 67 53 E 9300.0 26 59 N 68 9 E 9400.0 27 11 N 67 42 E 9500.0 27 36 N 68 14 E 9600.0 27 31 N 68 11 E 9700.0 27 32 N 68 27 E 9800.0 26 9 N 68 47 E 9900.0 26 11 N 68 3 E 10000.0 25 37 N 68 1 E 10100.0 24 55 N 68 7 E 10200.0 23 31 N 67 51 E 10300.0 21 54 N 67 55 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' ft ft .51 8651.1 896.9 1.63 8743.5 934.6 1.85 8834.7 975.1 .93 8880.0 996.2 .98 8925.0 1017.7 .94 9014.7 1061.7 .26 9103.9 1106.7 .29 9192.9 1151.9 .48 9281.7 1197.6 .08 9370.3 1243.6 .13 9459.0 1289.6 1.40 9548.2 1334.6 .33 9638.0 1378.4 .57 9727.9 1421.9 .70 9818.4 1464.3 1.39 9909.6 1505.1 1.63 10001.8 1543.4 CLOSURE DISTANCE BEARING ft deg min 903.4 N 67 19 E 941.7 N 67 11 E 982.6 N 67 7 E 1004.0 N 67 6 E 1025.6 N 67 6 E 1070.0 N 67 6 E 1115.2 N 67 9 E 1160.7 N 67 10 E 1206.7 N 67 12 E 1252.9 N 67 14 E 1299.1 N 67 17 E 1344.3 N 67 19 E 1388.4 N 67 22 E 1432.1 N 67 23 E 1474.7 N 67 24 E 1515.7 N 67 25 E 1554.3 N 67 26 E HORIZONTAL C O 0 R D I N A T E feet 348.44 N 833.54 E 365.19 N 868.01 E 382.20 N 905.27 E 390.73 N 924.82 E 399.23 N 944.73 E 416.25 N 985.68 E 433.17 N 1027.59 E 450.28 N 1069.78 E 467.54 N 1112.42 E 484.71 N 1155.38 E 501.79 N 1198.32 518.26 N 1240.37 E 534.48 N 1281.38 E 550.81 N 1321.88 E 566.75 N 1361.47 E 582.13 N 1399.50 596.67 N 1435.2£. Final Station Closure: 1554.3 feet North 67 deg 25 min 35 sec East AUSTIN. TEXAS CHART NO. IOI515-L pIIINI[D IN U.S.A Oil & ~a.~ cons, Commission A~chorage HVU~IUN INSIHUM~NI AUSTIN. TEXAS CHART HO. IOI$15-L PWlNT[OIN U*S.A. i ]HUR [.:R.[.~' -"R '. E; :.-:~'-~:;~::-;.-::- ': :--.:-::t:::-:;: :.'--:..':~V ,-:'::::'.;. ::.:::::-.:::...::;:::._..:.;_;i.;::;:::~ ::::::::::::::::::::: : L:~: ,~..:;:'::~ ====================== .:..:i:;:; .:'.::;::: -~-;- .-. ..... $: .................. :--.: - · :.-: .................................... ...... ~ .................................. ' ......................................................................................... -?'~--~ ......................... ;- ;"-':-'-: ......... I .................. --~d:~:_Li-:-; :~. ::: ::: ::::~:'::: ~_:::;_::: ~ !.'.2':::: tc':::'::~ ,_~_] ............ ~ .................. 1-~ ................. ~ ......... ::~t~-:~.: ::: :'.-;: :::~'-- '~.::::F:-- :-.: ::-i-~:i-': ...... _~ ,,~. ............................................................ ..... ~..~_..i .......................... ;.._ .... d~~ : ~ ; ~j~ ............... ]-~!F ------~: '~-,- ..... -- .... i-~,q-:----~--~ ..... --~-~'4'~, ..... - ................ fl ..................... ?~-'~-----~ ........... I .............. ~ ......... ! ....................................................... ~.~-:'-..::':::..-: ! :::: ti-'. :..:.;:--;.i ::'z~;::.. !~;::~.:: --??t~.' ':~ .......... ; .... I '1 ........ ! ................ ; ............... ..... ;-->.~:~ ....... : ....................t. |:/ :....:_~.._.: ...... : ....... '~-" I~ ....... ........... I' '~'~ ...................... : ..................................... ._~_: ....~ ............... ,.. i ............................ .......... ~' .................. / ................... ~ ............................................. ? ...... ~ .................... : ............................................ ........ ~L__~ .... ........ ....... : ..................................... .-.-~.~ ...... ..... 1 ............ ,~ ~ ............. '::-'-::i:~ :. :': :".".:' .:,:.::: ::-i-.:-' ::'-~-:' -:.:::-:. .~.,'---,-~-~--,-:--~ .... ?:~--: ....... . . · i :iii ~:_ : .i~ ,~ i!: ':. : ~ :~ :;II i i~ i:ii I I;i ;!~;i~;i ' i.I.i ' ii~'~ ": 'i ,',II :' ~' '"' "" '"' '" '~'" ' '"' "" : ...... , i, GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY MARATHON OIL COMPANY COMPANY # D-45 LEG A-2 COND. # 12 WELL NAME COOK INLET DOLLY VARDEN PLATFORM LOCATION AL489-D17 GYRO, MWD, & SINGLE SHOT 5/23/89 JOB NUMBER TYPE SURVEY DATE DIRECTIONAL ~~~ DON MASON SUPERVISOR NAME TITLE SIGNATURE DEPTH INTERVAL 100 FT 10043 FT FROM TO 4/14/~9 5/19/S9 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. ~REA'r LAND DIRECTIONAL. DRILLING~ ]NC 3! tent .............. : MARATHON OIL. COMPANY 4el ] ...... ' .......... : D-45 ~e~t!cc] Sectton ct.: N 74.2~ E ~laflnettc Dec)tnatton: 24 deg 48 mtn E ')ara file name ...... : C:DNSD.DAT RECORD OF SURVEY :. Computation= RADIUS OF CURVATURE Suz~vey date= 4/14/89 Method ..... : GYRO-MWD-SS RKB Height. = 10{5.0 ft MEAS DR] FT TRUVERT SUBSEA SECT ION DEPTH DG MN DEPTH DEPTH D]ST DIRECTION REL. AT]VE COORDINATES ANGI.E FROM WEL1.-HEAD 100 0 J5 100.00 -6.00 200 0 15 200.00 9e. O0 300 0 15 300.00 19~.00 3~0 0 33 3~0.00 254.00 414 0 18 413.~ 307.~ -0.21 S 58.00 W -0.63 N 79.00 W -0.97 N 56.00 W -1.28 N 71.{50 W -1.45 S /51.PO E 0.12 S 0.19 W O. 19 S 0.60 W 0.03 S 1.00 W 0.1{5 N 1.38 W O.OP S 1.4P W CLOSURE DISTANCE DG NN S 0.22 S 58 0 0 W 0.63 S 72 15 26 W 1.00 S 88 26 12 W 1.3P N 83 30 27 W 1.49 S 8/5 32 24 W /~80 0 36 479.PIP 373. ~02 0 30 ~01.~B 495. 655 I :i2 65h.PB 548. 7].7 3 30 71~.~2 610.~H -1.00 N 85.20 E -0.25 N 74.20 E 0.43 N B4.10 E 1.19 N 42.50 E 3.0~5 N 21.hO E 0.1P S O.P8 W O.O& S O.~q W 0.07 N 0.43 E 0.42 N 1..11 E 2.56 N 2.45 E 1.00 S 78 54 20 W 0.2S S 7/5 28 25 W 0.43 N 80 40 38 E 1.19 N /59 32 34 E 3.55 N 43 45 37 E 779 tt 30 778.77 {572.77 841 /5 0 840.51 734 903 6 0 902.17 796.17 965 5 42 963.85 857.85 1003 5 ~4 1001./57 895./57 5.85 N 27.40 E 10.2/5 N 113.70 E 1/5.30 N /53.60 E 22.69 N 77.fPO E 26.25 N 79.00 E 6.50 N 4.24 E 11.10 N 7.53 E 14.92 N 12.72 E 17.00 N 18.67 E 17.73 N 22.27 E 7.76 N 33 /5 S2 E 13.41 N 34 8 28 E 19.60 N 40 26 SO E 25.25 N 47 41 I E 28.47 N 51 28 12 E 1217 3 18 1215.0~ 1109.04 :1342 2 36 1339.87 1233.87 14~7 1 54 1494.75 1388.75 1{532 I 42 1~2~. ~9 1523. ~9 17h7 1 12 1744.65 1638.65 42.33 N 84.90 E 48.71 N 7/5.80 E 54.76 N 83.20 E 58.98 N 78.20 E ~51.8/5 N 85.30 E 20.01N 38.33 E 21.03 N 44./58 E 22.08 N 50.67 E 22.77 N 54.85 E 23.1P N 57.73 E 43.24 N /52 ~.6 29 E 49.38 N /54 47 SO E 55.27 N /56 27 3 E 59.39 N /57 27 27 E 62.:31 N 68 ? ? E 1872 2122 2372 0 I~II 18{~P. 63 1763./53 0 48 1P94.61 1888.61 0 3/5 2119./50 2013.60 0 a4 a~40.{50 2134.{50 0 30 27'1~.19.59 22{53.5~ 64.10 N 86.70 E 65.91 N 86.70 E 67.43 N 71./50 E 68.48 N /55.90 E 6~.48 N 63.10 E 23.35 N /50.02 E 23.45 N 61.87 E 23.74 N /53.3{5 E 24.12 N /54.35 E 2q. l,~, 1'4 65. ~t'i E /54.40 N /58 44 40 E /5/5.1/5 N {59 14 22 E /57./5/5 N /59 27 41 E /58.72 N /59 27 2 E 69.73 N /59 22 43 E mmmmmmmm 00~ L~B deg/ 0 0.250 0.001 0.000 0.500 0.463 O. NBS O. 323 O.BO0 1.321 3.712 2. ~36 0.351 O. 981 O. E. SO O. O. 43E 0.24( 0.08( O. O. 16=, 0. 071 ,j RECORD OF SURVEY 4EAS DRIFT TRUVERT SUBSEA SECT]ON )EPTH DG MN DEPTH DEPTH DIST DIRECT]ON RELATIVE COORDINATES ANGLE FROM NELL-HEAD 2438 2597 2785 3002 3220 0 30 2z~35.59 2329.59 0 30 2594.59 2488.59 0 30 2782.58 2676.58 0 30 2999.57 2893.57 0 30 3217.56 3111.56 70.04 N 56.60 E 71.34 N 51.50 E 72.86 N 52.20 E 74.61 N 51.90 E 76.36 N 51.20 E 24.85 N 65.76 E 25.66 N 66.88 E 26.{57 N 68.17 E 27.8~, N 69.66 E 29.02 N 71.15 E CLOSURE DISTANCE 13(3 ~ S 70.30 N 69 18 4 E 71.63 N 69 0 33 E 73.20 N 68 37 49 E 75.02 N 68 13 3 E 76.85 N 67 48 39 E [X~ LEG deg/lO0 0.001 0.000 0~ 0.000 3436 3654 3872 4088 4308 0 30 3433.55 3327..S5 1 0 3651.54 3545.5~ '.1 6 3869.50 3763.50 :1 12 4305.41 ~199.41 78.16 N 62.10 E 80.83 N 46.20 E 84.55 N 60.30 E 88.80 N 65.20 E 93.38 N 72.30 E 30.06 N 72.73 E 3:1.72 N 75.03 E 34.1:i. N 78.22 E 36.09 N 82.08 E 37.?d N 86.37 E 78.69 N {57 32 ~t~ E 81.46 N 67 ~1 SS E 85.3~ N 66 ~6 33 E 89.66 N 66 lS S1 E 94.26 N 66 23 8 E 0.000 O. 229 O. 0~6 0. 066 O.O0:t ~553 4798 501~ !3230 5~m~8 {3697 5914 6130 6379 6531 4550.36 4444.36 ~,795.32 4689.32 5011.28 4905.28 5227.25 5121.25 5445.19 5339.19 2 0 5694.07 5588.07 1 36 5910.97 5804.97 1 2~ 6126.89 6020.89 1 ~8 6375.79 6269.79 I 54 6527.71 6421.71 98.29 N 80.00 E 102.74 N 83.50 E 106.4~1 N 87.40 E 110.20 S 83.10 E 114.70 S 79.60 E 120.98 S 63.80 E 125.29 S 46.60 E 127.74 S 36.h0 E 131.91 S 70.10 E 136.29 S 88.80 E 38.94 N 91.14 E 39.58 N 95.58 E 39.88 N 99.34 E 39.73 N 103.29 E 38.99 N ~08.18 E 36.61 N 115.38 E 32.73 N 120.95 E 28.50-N 124.69 E 21~.40 N 130.18 E 23.51 N 13~.99 E 99.11 N 66 52 2 E :103.45 N 67 30 21 E 107.04 N 68 7 38 E 110.67 N 68 57 38 E 11~.99 N 70 10 52 E 121.04 N 72 23 ~7 E 125.30 N 74 S1 27 E 127.91 N 77 7 28 E 132.45 N 79 23 0 E 137.02 N 80 7 16 E 0.041 O.O~l O.OOl' 0.0~6 O. 183 0 .~0~ 0.161 0. 067 6612 3 zt8 6608.61 6502.61 667~ 5 30 6670.40 6564.40 6767 9 12 6762.62 6656.62 6829 10 42 68~3.69 6717.69 6966 12 42 6957.8~ 6851.84 :1~0.25 N 76.50 E 145.28 N 73.50 E 157.13 N 66.60 E 167.73 N 64.90 E 195.24 N 67.70 E 23.94 N 138.98 E 25.24 N 143.83 E 29.29 N 155.01 E 33.69 N 164.78 E ~4.86 N 190.21E 1~1.03 N 80 13 38 E 1~6.03 N 80 2 51 E 157.75 N 79 17 53 E 168.19 N 78 26 35 E 195.43 N 76 ~13 ~7 E 2. 2.7~2 3. 7058 1~ 12 7047.31 6941.31 715:1 16 12 7137.05 703:1.05 '/2h~ :18 6 7225.91 7119.91 7337 19 12 7314.03 7208.03 7~,30 20 36 7401.~,7 7295.47 216.55 N 70.50 E 240.9:1 N 72.60 E 268.33 N 75.10 E 298.03 N 78.60 E 329.50 N 82.10 E 52. **9 N 210.20 E 60.21 N 233.33 E 67.84 N 259.66 E 74.60 N 288.62 E 79.91 N 3:19.82 E 216.65 N 75 58 ~2 E 2~0.97 N 75 31 51 E 268.38 N 75 21 33 E 298.11 N 7S 30 28 E 329.65 N 75 58 20 E 1.64~ 2. 2. OSf 1.ES: 1. RECORD OF SURVEY MEAS mN= DRIFT TRUVERT SUBSEA SECT]ON DIRECTION RELAT)VE COORDINATES DIST ANGLE DEPTH DG MN DEPTH DEPTH 7461 21 24 7430.41 7324.41 7537 23 18 7500.70 7394.70 7631 24 3~ 758~.~1 7~80.~1 7~3 25 48 7~42.71 753~.71 7721 ~5 3~ 7~57.83 7[~1.83 FROM WELL-HEAD 81.37 N 330.83 E 85.59 N 359.42 E 95.03 N 396.35 E 104.45 N 421.00 E 109.42 N 432.32 E 7799 27 48 7737.20 7631.20 '[8~2 27 12 7793.08 7{587.08 7952 2~ {5 7873.52 77{57.52 8045 25 18 7957.32 7851.32 BlOB 24 ~2 B014.53 7908.83 480.81 N 61.70 E 509.28 N {53.10 E 5~8.92 N ~3.50 E 588.59 N ~4.20 E ~14.~5 N 63.80 E 125.32 N 138.80 N 15~. 94 N 174.71 N 1.8~. 27 N 464.22 E 490. O0 E 526.07 E 562.27 E 585.97 E []171 23 42 B072.11 7P{5~.11 8234 23 3{5 8129.82 8023.82 8327 23' 12 8215.17 8109.17 B~19 23 0 8299.7~ 8193.79 8513 22 30 838{5.48 B2BO.hB 639.74 N 64.90.E 6{54, {57 N 6~.50 E 701.07 N {54.50 E 73{5.65 N 64.50 E ?72.~{5 N {54.30 E 197.34 N 208.14 N 2.24.05 N 239.58 N 255.29 N 609.03 E 631.88 E 665.21E 697.79 E 730.57 E 8603 21 54 8469.81 8363.81 8687 20 42 8548.07 8~42.07 8820 21 24 8{572.30 8566.30 Bglh 23 0 8759.33 8653.33 BOG.97 N 64.50 E 836.09 N 65.60 E 860.~7 N {5S.90 E 883.08 N ~6.{50 E 9~8.35 N {58.40 E 269.98 N 282.86 N 293.]9 N 302.18 N 315.77 N 761.2~ E 788.90 E 811.84 E 832.27 E B6S. 08 E 9008 24 42 8845.30 8739.30 956.18 N 69.10 E 9098 25 6 8926.94 8820.94 993.97 N 70.90 E 9187 a6 $2 9007.16 8901.16 103~.44 N ?~.~0 E 9239 27 12 9053.62 8947.62 1055.77 N 71.20 E 9305 27 12 9112.32 9006.32 1085.90 N 71.20 E 329.54 N 900.50 E 342.S0 N 936.11E 3S5.01N 972.55 E 362.54 N 994.6{5 E 372.2~ N ~0~3.~2 E 9397 27 18 9194.11 9088.11 1127.95 N 70.50 E 9487 27 12 9274.12 9168.12 1169.08 N 70.90 E 9549 27 ]8 9329.24 9~23.24 1~97.42 N 70.90 E 9~40 27 42 9409.9{5 9303.9{5 ]239.37 N 71.20 E 9672 27 42 9438.29 9332.29 1254.23 N 70.90 E 399.70 N \1101.91E ~08.99 N 1128.73 E ~22.64 N 1168.48 E 427.47 N 118~.54 E CLOSURE DISTANCE DG NN 340.69 N ?6 10 89 E 369.47 N 76 36 21 E 407.58 N 7{5 30 60 E 4~3.77 N 76 3 60 E 445.95 N 75 47 .SO E 480.84 N 74 53 33 E 509.28 N 74 11 4 E Sh8.gB N 73 23 20 E SBB.7~ N 72 ~4 19 E 614.87 N 72 ~1 SS E 640.20 N 72 2 46 E 665.27 N 71 46 ~ E 701.93 N ?l 23 11 E 737.78 N 71 3 1 E 773.89 N 70 ~t~ 19 E 807.70 N 70 28 20 E 838.08 N 70 16 30 E 863.1{5 N 70 B 3{5 E 885.43 N 70 2 ~13 E 920.91 N 69 56 SO E 958.91 N 69 53 59 E 996.80 N 69 S,~ 13 E 103S.32 N 69 B6 46 E lOSB.6B N 69 S8 26 E 1088.8~ N 70 0 28 E 1230.9{5 N 70 2 21 E 1172.1~ N 70 3 45 E 1200.55 N 70 4 56 E 12~2.S~ N 70 6 S~ E 1257.43 N 70 7 34 E DOG LEG deg/lO0 2.5~8 2.548 3.1P6 1. 837 1. 060 1.22~ 0. 871 1.7~S; 0.84; O. lBS O. 43( 0.21~ O. S3: O. 66'~ 0 0.97~ 1.72' 1.811 0.S7; 1.23 1.92 0.00 O. 19 O. 1~ O. 1~ 0.2C MEAS DRIFT TRUVERT SUBSEA SECTION DEPTI4 DG MN DEPTH DEPTH D]ST ANGLE P860 2~ 18 ~605.73 949~.73 1339.S6 N 70.50 E 9952 25 ~2 P~88.42 9582.42 1379.80 N 70.50 E 100~3 25 12 ~?70.BB 96~.5B 1418.82 N 70.20 E ~1.~7 N 1222.9~ E 455.58 N 12~3.27 E 469.04 N 1301.29 E ~B2.1~ N 1338.12 E DIRECTION RELATIVE COORDINATES CLOSURE DOG LEG FROM WELL-HEAD DISTANCE DG HN S , deg/lO0 · 1300.~3 N 70 9 S E 134~.91 N 70 10 8 E 1383 2~ N 70 10 ~3 E 1422.35 N 70 10 ~0 E 0.6qB 0.8q6 O. 0 DATA ]NTERPOI. ATED FOR EVEN 100 FEET OF SUBSEA DEPTIt ~' S/23/89 4EAS. TRU VERT SUB SEA MD-TVD VERTiCAl. )El:"rl{ DEPTH DEPTH DIFF. CORRECT .'!0~5 10~ 0 0 0 20{5 206 100 0 0 306 30{5 200 0 0 J~06 40{5 300 0 0 506 506 400 0 0 606 {506 500 0 0 706 70{5 {500 0 0 006 006 700 0 0 907 906 800 1007 100{5 900 1 0 1108 1106 1000 1208 120{5 1100 1300 130{5 1200 1~08 1406 1300 1508 150{5 1400 .1{508 1{506 1500 2 0 J708 1706 1600 2 0 .1808 180{5 1700 2 0 1908 1906 1800 2 0 2008 2006 1~00 2 0 2108 2106 2000 2 0 2208 220{5 2100 2 0 2308 230{5 2200 2 0 2J~08 2~06 2300 2 0 2508 2506 2~00 2 0 2600 2{506 2500 2 0 2708 270{5 2{500 2 0 2808 2806 2700 2 0 2908 290{5 2800 2 0 3008 3006 2900 2 0 REL. AT]VE COORDINATES FROM ~ELL.-HEAD O. 12 S 0.21 W 0.I8 S 0.63 W 0.01 S 1.04 W 0.05 S 1.~7 W O. 14 S 0.67 W 0.10 N 0.~8 E 2.18 N 2.22 E 8.53 N 5.69 E 15.05 N 13.09 E 17.78 N 22.60 E 18.84 N 30.12 E 19.91 N 37.65 E 20.75 N ~2.96 E 21.48 N ~7.2~ E 22.-1~ N 51.02 E 22.{55 N 5zt.12 E 23.0S N S6.76 E 23.~.6 N SB.8S E 23.38 N {50.55 E 23.~8 N 62.00 E 23.71 N 63.20 E 2~.01 N 6~.06 E 24.34 N {54.81 E 2~.72 N 65.53 E 25.21 N 66.26 E 25.72 N 66.96 E 26.2{5 N 67.6S E 26.80 N 68.33 E 27.3~ N 69.02 E 27.87 N 69.71E DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH UlEAS. TRU VERT SUB SEA ')I:.P T H DEPTH DEPT14 311,08 3]0{5 3000 3208 320{5 3100 3308 3306 3200 3408 340{5 3300 3508 350~ 3400 3608 3606 3500 3708 3706 3600 3808 3806 3700 3909 3906 3800 hO09 4006 3900 h109 4106 4000 ~209 ~206 11100 h309 4306 11200 A~09 111106 11300 ~509 4S06 111100 h609 4606 11500 4709 4706 11600 ~809 11506 11700 h909 4906 4800 !3009 5006 4900 5109 5106 5000 5209 5206 5100 5309 5306 5200 5h09 !5406 5300 !5509 5506 51100 5509 5806 5700 5909 5906 5800 dO09 ~00¢~ 5~00 MD-TVD VERTICAL DIFF. CORRECT 2 0 2 0 2 0 2 0 ~ 0 2 0 2 0 2 0 3 1 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 RE1. AT]VE COORDINATES FROM WELL-HEAD 28.1t2 N 70.39 E 28.96 N 71.08 E 29.1t5 N 71.80 E 29.92 N 72.S3 E 30.61 N 73.49 E 31.37 N 711.55 E 32.32 N 75.83 E 33.111N 77.29 E 34.1111 N 78.88 E 35.36 N 80.66 E 36.25 N 52.~18 E 37.01 N 84.43 E 37,76 N 86.38 E 38.24 N 88.33 E 38.72 N 90.28 E 39.08 N 92.15 E 39.35 N 93.96 E 39.59 N 95.77 E 39.73 N 97.51 E 39.87 N 99.25 E 39.81 N 101,07 E 39.75 N 102.90 E 39.116 N 105.06 E 39.12.N 107.30 E 38.hl N 109.~ E 37.~5 N 112.83 E 36.39 N 115.68 E 311.61N 118.2S E 3~.82 N 120.82 E 30.87 N 122.60 E DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTlt MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTli DEPTH ~ DIFF. CORRECT RELATIVE COORDINATES FROM WELL-ltEAD 6109 6106 6000 3 0 28.91N 6209 6206 6100 3 0 27.20 N 6309 6306 6200 3 0 2S.SS N 6409 {5~06 6300 3 0 2~.22 N 6509 6506 6~00 3 0 23.6~ N 6~509 6c-~O~i 6500 3 0 23.92 N ¢5710 6706 6600 4 I 26.80 N (581]. 6806 6700 S 1 32. ~12 N 6913 6906 6800 ? 2 ~O.SS N 701~ 700~ 6~00 10 3 ~8.97 N 7119 7106 7000 13 3 S7.54 N 7223 7206 7100 17 ~ 66.13 N 7329 7306 7200 23 6 73.98 N 7435 7406 7300 29 6 80.13 N 7543 7506 7400 37 8 86.17 N 7{552 7606 7500 ~t6 9 98.29 N 776~ 7706 7600 S8 12 118.17 N 7876 780{5 7700 70 12 1,41.71 N 7988 7906 7800 82 12 163.83 N 809~ 8006 7900 93 11 18~'1 . SS N 8208 8106 8000 102 9 203.69 N 8317 8206 8100 111 9 222.3~ N 8h2~ 8306 8200 120 9 240.71N 8534 8406 8300 128 8 258.73 N 8642 8506 8400 136 8 275.9~ N 8749 8~06 8500 143 7 2P1.87 N 8856 8706 8600 150 7 307.h~ N 8~!5 880~ 8700 159 9 323.2~ N 9075 8906 8800 169 10 339.18 N ~186 900~ 8900 180 11 354.83 N 124.33 E 126. ~t E 128.6z~ E 131. lh E 13~t'. 30 E 138.86 E 1,~8.1S E 161.9S E 180.38 E 200.97 E 225.32 E 2S3.76 E 28S.98 E 321.54 E 361.70 E qOq.87 E 4~9.88 E h95.79 E 5qO. 10 E S82. ll~ E 622.45 E 661.63 E 700.14 E 737.76 E 774.03 E 808.92 E 841t.97 E 88~. 31 E 926.96 E 972.02 E .~JiG DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4EAS. )EPTH PS23 ~8~0 ~P71 TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT ~10~ 9000 192 12 920~ 9100 20~ 12 P30~ 9200 217 13 P~lO~ ~300 230 13 ~SO~ 9~00 242 12 P60d 9500 25~ 12 P706 9~00 2~5 RELATIVE COORDINATES FROM WELL-HEAD 371.22 N 388.11 N 40S. 07 N 421. ~7 N 438.95 N 1020.15 E 10~8.80 E 1117.~2 E 11~.5~ E 1215.71E ~55.~2 N 471.8~ N 12~3.~0 E 1309.17 E , DATA INTERPOLATED FOR EVEN 1000, FEET,OF MEASURED DEPTH MEAS. TRU VERT sUB SEA DEPTH DEPTH DEPTH 1000 ~ O~3 17.~B N 2000 l~B 18P2 23.~ N 3000 2~B 2B~2 27.83 N ~lO00 3997 3891 3S.28 N RELAT I VE COORD] NATES FROM WELL-HEAD 6000 B997 5891 31.05 N 7000 6991 6885 ~7.6B N BO00 7917 7Bll 166.11 N 9000 8838 8732 328.37 N 10000 9?32 962~ ~75.98 N 80.51E 99.10 E 122.11~t E 197.60 E Blt,It. 7B E B97.~19 E 1320.71 E 0 600 -~--- .. _ 2400 3000 3600 42O0 4800 ¥ 54OO D 6OOO 6600. 7200 7BO0 B400 9OOO 9600 ~0200 ~OBO0 -600 'vERTIcAL SEC:i'ZON ' SECTION AT N 74.22 E TVD SCALE: ! inch - lEO0 feet DE~ SCALE: 2 Inch - ~200 feet DRA~N ' 5/E3/89 ~ X~ttftCltta ~ ~ ~ ~ ~ t~ tOO ! ........ a ~ tOO~ ~t t , ._ ,.,1 .................. .... t I ~ .... ~ ......... .... ~ ............ _ ......... ~ ' ., 'I . . .............. ,~ ....... ~ · 0 600 1200 tBO0 2400 3000 3600 4200 4900 5400 6000 6600 Departure t~ t~ HORIZONTAL VIEW MARATHON OIL COMPANY 0-45 · CLOSURE: t422 ft N 70.E E DECLINATION: 24.B0 deg E SCALE: t inch - 300 feet DRAWN: 5/23/89 t750 t600 t450 i300 tt50 tOOO 7O0 55O 400 ~0 tO0 5O 200 250 tOO 50 EO0 350 500 650 BOO gso ttO0 t250 t400 t550 ~ STATE OF ALASKA ~ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF'SUNDRY WELL OPERATIO 1. Operations performed: Operation shutdown m Stimulate m Plugging __ Pull tubing ~ Alter casing ~ Repair well __ 2. Na~Rg, f, Qpcrator,, ! 5. Type of Well: UmU~.~L tmarathon 0il Company - Sub Qperatopt)ve~opment-- ' ! Exploratory 3. Address · ! Stratigraphic P. 0o Box 190247 Anchorage~ AK 995]~9 ServiceX' 4. Location of well at surface Leg A-2 COnd, #]2 Do]ly Varden Platform 752' FSL, 1,134' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 1,100' FSL, 2,354' FWL, Sec. 6- 8N- 13W- SM At effective depth At total depth 1,178' FSL, 2,631' FWL, Sec. 6- 8N- 13W- SM 12. 10,415' feet Plugs (measured) 10,108' feet Perforate ~ Other .Y,._ New ~Jel 1 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name feet Trading Bay Unit 8. Well number -9. I~rmit number/approval number 8~-140 10. APl number 5o733-20150-01 11. Field/Pool McArthur River Hemlock Pool Present well condition sUmmary Total depth: measured true vertical Effec.tive depth: measured 10,340 ' true vertical 10,039' feet Junk (measured) feet Casing Length Size Structural Conductor Surface Intermediate 2,492' 13-3/8" Production Liner 10,399' 9- 5/8" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.-1/2", 9.3#, N-80 DSS-HTC tbg. Packers and SSSV (type and measured depth) 9-5/8" Otis BWD Pkr w/ SBE (4.0" 13. Stimulation or cement squeeze summary Cemented See 2,405 sx 2,920 sx Attachment #1 None Measured depth 2,492' 10,399' to 9,124' MD ID) @ 9,109' MD True vertical depth 2,489' 10,093' Intervals treated (measured) Treatment descriPtion including volumes used and final pressure RECEIVED 14. AUG 0 21989 Alaska 0il & Gas Cons. C0mmJssi0n Anchorage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 1512 N/A 6/26/89 15. Attachment~: 2 Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas ~ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -Title Environmental Engineer Service Signed d~'/~._.O- ~/~-~'~' Form 10-404 R~v 06/15/88 Tubing Pressure 3580 ps i W~ter Injection Date 7/31/89 SUBMIT IN DUPLICATE B-1 B-3 8-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals MD 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' TVD _ 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' RECEIVED AUG o 21989 Alaska 0il & Gas Cons. Commission Anchorage Attachment #2 Well D-45 Daily Summary of Well Operations 04/05/89 04/06/89 04/07/89 04/08/89 04/09/89 04/10/89 04/11/89 04/12/89 04/13/89 04/14/89 BHA. RIH w/26" bit. Clean out cmt 127'-208'. POOH. BHA. RIH w/mill. Mill csg 208'-211'. Mill chattering. POOH. BHA. RIH. Mill 211'-251'. Mill csg 251'-283'. POOH. Check mill. RIH w/26" bit. Clean out cmt 204'-283'. Circ. POOH. MU mill. RIH. Mill csg 283'-317'. Mill 13-3/8" csg 317'-342' Circ. POOH. RIH w/26" bit. CO cmt 283'-341' Circ. POOH. ~HA. RIH w/12-1/4" bit. Clean out 13-3/8" csg 342'-~17'. Circ. POOH. MU washpipe. RIH. Wash over 13-3/8" .csg 342'-355'. Attempt to wash past 355' w/o success. Circ. POOH. Change shoes. RIH. Attempt to wash w/o success. POOH. MU mill. RIH. Mill csg 342'-379'. Circ. POOH. BHA. RIH w/26" bit. CO cmt 341'-358'. POOH. BHA. RIH w/18" mill. CO conductor. Mill cmt 360'-377'. Circ. POOH. BHA. RIH w/washpipe. Attempt to wash over csg. POOH. Change shoes. RIH. Washover 13-3/8" csg 379'-381'. Wash over 13-3/8" csg 381'-394'. POOH. Change rotary shoes. RIH. Wash over csg 394'-397' w/high torque. POOH. RIH w/mill. Mill csg 379'-445'. Mill csg 445'-455'. POOH. Change sleeve on mill. RIH. Mill csg 455'-570'. Mill 13-3/8" csg 570'-595'. Circ. POOH. RIH w/spear. Spear loose piece. POOH. Recovered 7.36' piece of csg. LD spear. RIH w/mill. Mill csg 595'-660'. Mill csg 660'-665'. Circ. POOH. RIH. CO 13-3/8" csg 713'-717'. Circ. POOH. RIH w/mill. Mill 665'-700'. Circ. POOH. LD mill BHA. MU 17-1/2" HO and 12-1/4" bit. RIH. Open hole to 17-1/2" from 377' -698'. POOH. BHA. RIH w/OEDP. Circ. Mix and spot 545 sx "G" w/additives for balanced plug 717'-320'. Pull 4 stds. Circ. POOH. Check diverter valves. WOC. Clean up floor. MU 12-1/4" CO BHA. RIH. Tag cmt @ 336'. Drill cmt 336'-441'. CBU. 70% formation in returns. Dr;~ll and survey 441' -627'. CBU. POOH. MU mud motor and 1-1/2v bent sub. RIH. Orient motor. Drill and survey 627'-865'. 04/15/89 Directional drilled 865'-1033'. CBU. POOH. LD motor. BHA. RIH. Wel 1 D-45 Daily Summary of Well Operations Page 2 04/16/89 04/17/89 04/18/89 04/19/89 04/20/89 04/21/89 04/22/89 04/23/89 04/24/89 04/25/89 04/26/89 04/27/89 04/28/89 04/29/89 04/30/89 Ream motor run 627'-1033'. Drill and survey 1033'-1700'. Drill 1700'-2481'. CBU. POOH. BHA. MU 17-1/2" HO. RIH. Open hole 366'-738'. Open hole 738'-797' Hit bridge. POOH. MU 12-1/4" BHA. RIH. WR 780'-1068'. CBU. ~OOH. BHA. RIH w/17-1/2" HO. Open hole 797'-1316'. Hit bridge CBU. POOH. LD bullnose. PU 12-1/4" bit. RIH. Open hole 1316' -1436'. Open hole to 17-1/2" from 1436'-2471'. Circ. POOH. Cleaning BHA. Clean BHA. RIH. Drill to 2503'. Circ. POOH. RU and run 13-3/8" csg to 2492',; Mix and pump 10 bbl H~O, 20 bbl of 11.0 ppg scavenger slurry, 2017 sx "G w/additives mixed at 12.5 ppg, followed by 388 sx "G" mixed at 15.8 ppg. Had good returns. Displaced cmt w/369.5 bbl mud. Circulated 1033 sx to surface. Clean riser. WOC. WOC. ND cmt head. PU riser and diverter. Cutoff 13-3/8" csg. LD cutoff. ND diverter system. Cut off 30" starting head. Weld on 13-3/8" braden head. NU BOPE. NU BOP stack. Test BOPE 250/2500 psi. (Annular 250/1500 psi). LD HO-BHA. RIH w/12-1/4" BHA. Tag cmt @ 2391'. Test csg to 2000 psi. Drill cmt and float collar to 2481'. Test csg to 2000 psi. Displace hole w/co-polymer mud. Clean mud pits. Clean mud pits. Hook up centrifuge. Drill cmt, FS and rat hole to 2503'. Drill new hole to 2513' C,BU. Perform LOT to 14.25 ppg w/no leak off. Drill and survey 2513'-~550 . Drill 3550'-4148'. CBU. POOH. BHA. RIH w/bit #4. TIH w/bit #4. Drill and survey 4148'-4675'. ST to csg shoe. RIH. Drill and survey 4675'-4975'. Drill 4975'-5260'. CBU. ST to shoe. RIH. Drill 5260'-5634'. CBU. ST to shoe. RIHDr. ill 5634' -5665'. Drill and survey 5665'-5944'. CBU. ST 15 stds. Hole in good shape. Drill 5944'-6075'. Drill 6075'-6200'. POOH. Test BOPE to 250/3000 psi. Hydril 250/1500 psi. Test witnessed by AOGCC rep Harold Hawkins. BHA. RIH. Ream 5736'-6200'. Drill 6200'-6319'. Drill 6319'-6575'. CBU. POOH. BHA. BHA. Check MWD. RIH.' Drill 6575'-6577'. MWD quit. Circ. POOH. Check Wel 1 D-45 Daily Summary of Well Operations Page 3 05/01/89 05/02/89 05/03/89 05/04/89 05/05/89 05/06/89 05/07/89 o5/o8/89 05/09/89 05/10/89 05/11/89 05/12/89 05/13/89 05/14/89 05/15/89 05/16/89 05/17/89 05/18/89 05/19/89 electrical problems in #1 gen on EMD #1. POOH. Change MWD. RIH. Check MWD. RIH. Fin RIH. Wash 55' to bottom. 2' fill. Orient motor. Drill 6577'-6850'. Drill w/ motor 6850'-6860'. POOH. BHA. RIH. Ream motor run 6542'-6860~. Drill 6860'-7175'. Drill 7175'-7346'. Circ. ST 15 stds. Hole good. Drill 7346~-7501'. Circ. POOH. BHA. RIH. RIH. Wash 30' to bottom. Drill w/ motor 7501'-7688~. Drill w/ motor 7688'-7766'. CBU. POOH. Test BOPE 250/3000 psi. Annular 250/1500 psi. BHA. RIH. Ream motor run 7450'-7562'. Ream motor run 7562'-7766'. Drill 7766'-8092'. Drill 8092'-8095'. Circ. POOH. Lost 2 cones. BHA. RIH w/ globe baskets and boot basket. Mill over junk 8093' -8095'. POOH. BHA. Cleaned out boot basket. No recovery. RIH w/bit and boot basket. Could not drill past junk. POOH. RIH w/ magnet. Recovered 2 cones. RIH w/BHA. Drld from 8026'-8454'. Drlg. Drld from 8454'-8686'. Drill 8686' -8734'. CBU. Drop survey. POH. Test BOPE. MU BHA. RIH. Drill 8734'-8798'. Drld from 8798'-9042'. Drill from 9042'-9234'. Tripping for new bit. BHA. Test MWD. RIH. Ream 9220'-9234'. Drill 9234'-9403'. Drill 9403'-9437'. Make 10 std ST. Drill 9437'-9590~. Drill 9590'-9629'. Circ. ST 10 stds. No problems. Drill 9629~-9713~. CBU. POOH. POOH. BHA. Ream 9650'-9713'. Drill 9713'-9971'. Drill 9971'-10,086' Circ ST 10 stds. Drill 10,086~-10,099~. Circ. POOH. BHA. Test B~PE. RIH. Wash bridge 4630'-4660~. RIH to 9630'. d.p. stuck. Work stuck pipe. Freepoint d.p. Pipe free to totco ring at 9608'. Circ and wait on fishing tools. Attempt to back off d.p. at first collar above totco ring. No success. MU new string shot. Back off d.c. @ 9514'. RD E-line. POOH. MU fishing BHA. Wel 1 D-45 Daily Summary of Well Operations Page 4 05/20/89 05/21/89 05/22/89 05/23/89 05/24/89 05/25/89 05/26/89 05/27/89 05/28/89 05/29/89 05/30/89 05/31/89 06/01/89 MU fishing BHA. RIH. Screw into fish. Jar fish loose. Circ. POOH. BHA. Recovered fish. RIH. Wash and ream 9546'-10,099'. Drill 10,099'-10,115'. Drill 10,115'-10,415'. Circ. Made 11 std ST. Hole good. Circ in prep to log. Circ. POOH to log. RU E-line. Run the following logs: Run #1 - Phasor induction/LSS 10,400'-2491'. Run #2 - FDC/CNL/GR/CAL 10,400'-2491'. RIH w/ Log #3 FMS/GR/AMS. Finish running FMS/GR/AMS 10,415-9100'. RD E-line. RIH to 13-3/8" shoe. Restrung blocks to 10 lines. RIH. Circ and condition mud. POOH. RU to run 9-5/8" csg. RU to run 9-5/8" csg. Run 251 jts of 9-5/8" csg to 10,399'. Circ and condition mud. Prehydrating gel in mix water for lead slurry. Circ and cond mud prior to cementing. Mixed 2340 sks of lead cmt and 580 sks of tail cmt. Bumped plug. Cmt in place @ 17:00 hrs. Full returns during entire job. Float held ok. WOC. Raised BOP stack. Set 9-5/8" csg slips w/full wt. of 9-5/8" csg. 13-3/8" csg and wellhead subsided approx 2". PU csg wt. Waited on 3" plate. Welded 3" plate between 13-3/8" and 33" csg. Slacked off 9-5/8" csg wt. and set slips, ok. Made rough cut on 9-5/8" csg. Dressed 9-5/8" csg. Installed tbg spool. Tested same to 2800 psi. NU and tested BOP. RIH w/ 8-1/2" bit and BHA. Tagged cmt at 10,280'. Drld cmt and float collar and cleaned out to 10,340'. Circ and cond mud @ 10,340'. POOH. RU Schlumberger. Ran CBL/CET log without pressure and with pressure. Running gyro survey from 10,300 ft. up. Ran gyro survey. Ran seismic survey. Perforated 9886'-9888' w/ 4 spf. RIH w/squeeze pkr. Set same at 9755'. Mixed 100 sks of cmt. Squeezed 88 sks behind pipe. Final squeeze pressure 4450 psi. Cmt in place @ 11:20 hrs. POOH. Made bit and scraper trip to 9850'. POOH. RU and perforated 9781'-9783' w/4 SPF. RD wireline. GIH w/squeeze pkr. Set pkr at 9643'. Mixed 100 sks of cmt. Squeezed 75 sks of cmt into per'fs @ 9781'-9783'. Final squeeze pressure 4500 psi. Cmt in place @ 16:30. Released pkr. Reversed out. POOH. RIH w/8-1/2" bit. Drld soft cmt to 9750'. WOC. Tested csg to 3000 psi. Drld out cmt to 9850' (perfs 9781'-9783'). Tested cs§ to 3000 psi. Drld out cmt and cleaned out to 10,340'. Tested csg to 3000 psi. POOH. RIH w/9-5/8" csg scraper. Reverse circulating with FIW. Well D-45 ? ~ Daily Summary of Well Operations Page 5 06/02/89 Reversing out with FIW. Made wiper trip to 7000'. Reverse circulating. POOH. GIH w/TCP guns. 06/03/89 RIH w/TCP guns. Ran GR/CCL correlation log. POOH w/wireline tools. Set pkr. Pressured annulus. Fired TCP guns. POOH. All shots fired. RIH w/Otis production pkr assembly. 06/04/89 Set Otis production pkr 0 9103'. POOH w/pkr, setting tool. RU to run 3-1/2" tbg. Ran 100 its at report time. 06/05/89 RIH w/3-1/2", 9.3#, N-80, DSS-HTC. Internally coated tbg. Externally tested each jt to 4000 psi. Landed tbg seals and tbg hanger. ND BOP. NU X-mas tree. Tested 3-1/2" x 9-5/8" annulus to 2450 psi. RELEASED RIG from D-45 0 24:00 hrs on 6/5/89. 06/06/89 General rig maintenance prior to moving to Well D-19 (D-46) well slot. 06/07/89 General rig maintenance prior to moving to Well D-19 (D-46) well slot. 06/08/89 General rig maintenance prior to moving to Well D-19 (D-46) well slot. 06/09/89 General rig maintenance prior to skidding to Well D-19 (D-46) slot. 06/10/89 General rig maintenance prior to skidding to Well D-19 (D-46) well slot. 06/11/89 General rig maintenance prior to skidding to Well D-19 (D-46) well slot. East crane on the platform up and running. Installing gas lift valves in mandrels-Well D-11. 06/12/89 General rig maintenance prior to skidding to slot D-19 (D-46). D-11 Well - Attempting to pull gas lift valves. D-7 Well - Reperforated from 12,035' to 12,068'. 06/13/89 General rig maintenance prior to skidding to slot D-19 (D-46) for P&A. In the meantime installed gas lift valves in Well D-11. Skidded rig from D-11 to D-19 (24:00 hrs 6/13/89). \docs\dvp\d45 1. Type of Request: STATE OF ALASKA ' 0 R I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation shutdown m Re-enter suspended well ~ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company - Sub O~eratorD}e~Ve~?pm. ent-- / t-xp~ora~ory __ 3. Address | Stratigraphic __ P. 0. Box 190247 Anchorage, Al< 99511;) Service_,~_ 4. Location of well at surface Leg A-2 Cond. #12 Dolly Varden Platform 752' FSL, 1,134' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 1,100' FSL, 2,354' FWL, Sec. 6- 8N- 13W- SM At effective depth At total depth 1,178' FSL, 2,631' FWL, Sec. 12. Present well condition summary Total depth: measured' 10,415 ' true vertical 10,108 ' 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-45 9. Permit number 88-140 10. APl number 50- 733-20150-01 11. Field~rthur River Hemlock Pool 6 - 8N - 13W - SM Effective depth: measured 10,340 ' feet Junk (measured) true vertical 10,039 ' feet See feet Plugs (measured) None feet Cemented Measured depth True vertical depth 2,405 sx 2,492' 2,489' 2,920 sx 10,399' 10,093' Attachment #1 Casing Length Size Structural Conductor Sudace Intermediate 2,492' 13-3/8" Production Liner 10,399' 9-5/8" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 DSS-HTC tbg. to 9,124' MD Packers and SSSV (type and measured depth) 9-5/8" Otis BWD Pkr w/ SBE (4.0" ID) @ 9,109' MD 13. Attachmentsx: 2 Description summary of proposal ~ 14. Estimated date for commencing operation July 17, 1989 7/14_..,/~9 , uaie approvea RECEIVED AUG 0 21989 Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program ~ BOP sketch __ 15. Status of well classification as: 16. If proposal was verbally approved Mi ke Mi nder Name of approver Oil i Gas I Suspended i Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Env t ronmenta t E:~g t neet FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Commissioner Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH feet Form 10-403 Rev 06/15/88 Date 7/31/89 Appr°val N°' Approved Copy Returned Date SUBMIT IN TRIPLICATE B-1 B-3 B-4 B-5 Attachment #1 TBU Well D-45 Current Perforated Intervals M_~D 9,730' - 9,762' 9,900' - 9,914' 9,944' - 9,976' 9,982' - 10,070' 10,092' - 10,146' 10,156' - 10,176' TV__~D 9,486' - 9,514' 9,638' - 9,651' 9,678' - 9,706' 9,712' - 9,791' 9,811' - 9,860' 9,869' - 9,888' RECEIVED AUG o 2 ~989 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 Dolly Varden Platform Well D-45 Injection Step Rate Test Procedure A. Low pressure portion.** 1. Hook up Mr. six pressure recorder. 2. Choke injection pressure back to approximately 1000 psig. Let well stabilize for two (2) hours. Record time, tubing presure, and bbls injected every 15 minutes. 3. Increase injection pressure to approximately 2000 psig. Let well stabilize for two (2) hours. Record time, tubing pressure, and bbls injected every 15 minutes. 4. Repeat step No. 3 for injection pressures of approximately 3000, 3500, and 4000 ps i g. 5. Shut in injection. Note how long a positive injection pressure is maintained. B. High pressure portion 1. R/U BJ and Mr. Six pressure recorder to Well D-45 and test lines to 5000 psig. 2. Slowly initiate injection. Perform a step rate test, allowing injection to stabilize for one (1) hour at the following pressures: 4000 psig 4500 psig 5000 ps i g 3. After pressure and rate has stabilized at the final rate, shut the well in and record tubing pressures until a negative pressure occurs. 4. R/D BJ. ** If time constraints do not allow the low pressure portion to be completed prior to the high pressure, the order may be reversed and the low pressure data obtained after BJ has obtained the high pressure data. MISC COMMENTS - Do not vary the rate during the stabilization periods. Mr. Six should be set to take readings every 5 minutes or less during the injection step rate and as quickly as possible during the fall off. \docs\dvp\d45 Unocal Oil & Unocal Corpora P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska District DOCUMENT TRANSMITTAL Ouly 12, 1989 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Unit, McArthur River Field - D-45 i blueline and i sepia of logs as follows: Phasor Induction-SFL/SR/GR Long Spaced Sonic/GR Lithodensity/Compensated Neutron/GR Formation Microscanner i magnetic tape with listing 2 directional surveys RECEIVED BY: DATED: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. ~-. ,,,., ~.,, ~ .. . C-O, .... ,~,~ MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~I~ISSION Con, hi ssi oner ~LENO: D.~.029 THRU: TELEPHONE NO: Michael T. Minder SU BJ ECT: Sr. Petroleum Engineer BOP Test Marathon TBU D-45 Permit.No. 88-140 McAurthor Rv Pools FROM: Harold R. Hawkins Petroleum InsPector Friday, ~ril 28, 1989, While I was working on safety valve test a ~ 'tes't ~ame ~P'~-~ ~! 'dropped safety valve test and witnessed the BOP test on D-45. the tests that I witnessed before I left the plat- form at 5:35 pm had no failures. In s~ary, I witnessed the BOP tests on Marathon well D-45. The tests were satisfactorily performed. Chopper was waiting for me and I left the platform, without testing the inside BOP. Attachment 02-001A (Rev. 8/85) 0&G 5184 Reserve Pit Mud Systems Inspector b*/~ ~~ Operator ~~ ~.~ Well O --~ Location: Sec ~ T~ R Location. General ~ Well Si~n General Housekeeping ~/~Rig ViSual Audio Trip Tank Pit Gauge Flow Monitor '~.~ ' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date 4/,~ Y//~'~2 Well Test Pressure BOPE Stack Annular Preventer Pipe Rams ,{ Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ,$doo Representative '~/ Permit .(/ l~~s~ng Set ~ ~y~/ ft. 77 Representative s szm Full Charge Pressure ~ressure After Closure t~'~ psi~ ' Pump incr. clos. pres. 200 psiS..-- min~' sec. Full Charge Pressure A~:ained: ~ ,~in~sec. ~ontrols: gaster DK~ ' ' , . Remote ff~V.. Blinds switch cover Kelly and Floor ~afety Valves Upper Kelly Lower KellX Ball Type Inside BOP Choke Manifold No. Valves /~ flanges ~ ~ No. Test Results: Failures. .~WT~c Repair or Replacement of failed equipment to be made within Commission office notified. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Adjustable Chokes O l(/~t Hydrauically, operated choke a/fA/ _.$6:f~0,, /~t Test Time 2 hrs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor March 3, 1989 Teleeopy: (907)276-7542 Mr. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Re.. Trading Bay Unit D-45 Union Oil Company of California Permit No. 88-140 Rev. Sur. Loc. 752'FSL, l134'FWL, Sec. 6, TSN, R13W, SM Btmhole Loc. l178'FSL, 2631'FWL, Sec. 6, TSN, R13W, SM Dear Mr. Roberts: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated December 2, 1988, accompanying the original approved permit are in effect for this revision. V~ t rtuly~ur s, /~--., I : 7-~" .,/ ./?.. / ~V.' chatterton" Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE CO~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreattx /- STATE OF ALASKA ,' ~ ALASKA OIL AND GAS CONSERVATION C_ ,~IMISSlON PERMIT TO DRILL 20 AAC 25.005 Revision 2-1-89 i la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[2]I Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal (Marathon Oil Company, Sub-Operator) 106'KB above MSL feet McArthur River 3. Address 6. Property Designation G Zone P. O. Box 190247~Anchorage, AK 99519-0247 ADL 18729 4. Location of well at surface Leg A-2 Cond #12 Doll~ 7. Unit or property Name 11. Type Bond ~ee 20 AAC 25.025> Varden 752' FSL, 1134' FWL, Sec 6, T8N, R13W, Trading Bay Unit Statewide SM At top of productive interval 8. Well nu .tuber -N~,bei'- -n-~~~t--e~ =~cific Insurance .~. 1100' FSL, 2354' FWL, Sec 6, T8N, R13W, SM D-45 fa~=o ~T~.~.~ ~o. At total depth 9...~,l~_~mate spud date Amount 1178' FSL, 2631' FWL, Sec 6, T8N, Ri3W, SM ~ 15, 1989 $~ 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD a,d ~VDI property line 10,100 TVD 5350 feet +300 feet 5116 10,399 MD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 360 feet Maximum hole angle 25 0 Maximum surface 3,328 psig At total depth frVD) 4010 psig 18. Casing progra ,m Setting Depth size ., Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 17-1/2 13-3/8 61 J55 BTC 2500 Surfac~ 2500 2499 2978 sx 12-1/4 9-5/8 43.5&47 N80 BTC 9360 Surfac,~. 9400* 8972* 1475 sx 8-1/2 7 29 N80 BTC 1436 9200 3782 10399 10100 250 sx *Note: (.-5/8" c~ sing will b, set at TD if hole c(~nditi ~ns permit 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10,964 feet Plugs (measured) 10,785 (cat) true vertical 10,458 feet Effective depth: measured 10,785 feet Junk (measured) true vertical 10,285 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 33" 350 ' 350 ' Conductor RECEIVED Surface 13-3/8" 2536 ' 2461 ' Intermediate F E.2~ ]. ~'~ Production 9-5/8" 10,964 ' 10,458 ' Liner ~¢![taska Oil & Gas Cons. Commissio[[ Perforation depth: measured 10,244'-10,785~¢'~'i' ~chorage. ' true vertical 9,765-10,285' 20. Attachments Filing fee [] Property plat [] BOP Sketch r-~ Diverter Sketch [] Drilling program [] Drilling fluid program J~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best o.f my knowledge Signed ~~D.'~o~erts Title Environmental Engineer Date2/13/89 (~Jg~ Use Only Commission Permit Number APl number I Approval date I See cover letter ~i;~-/~.("~ 50-- ,7,;7,~ -.2.O/~'¢"43 '"~::~ ! ' 0 3 / 0 3 / 8 9 for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required L-q Yes --~No Hydrogen sulfide measures [] Yes .,~ No Directional survey required /~Yes [] No Required workin.q,~r, essure for~ []2M; [~ 3M; ,~ 5M; [] 10M; [] 15M Other: /'/~/,~/ / .~~,/ / ~/~ (,,__..! ~ ~_ ~~ byorOerof Approved by J- .. ~ Commissioner the commission Date Subm' triplicate 13 11 ,e, lel' 3O ADL 175G4 I 13 ADL 17~02 - , · KING SALMON 20 DOLLY VARDEN 18 .+. · e-it · I-el ADL 18730 ADL 18772 + 27 2~ ' --.' + 34 ~ 35 I I ADL 17579 't I' ........... 16 +I + ! I 10 15 + ~- MARATHON OIL COMPANY TRADING BAY UNIT McARTHUR RIVER FIELD ~ 1#! JyTIIIOII MARATHON OIL COMPANY DOLLY V ARDEN PLATFORM DIVERTER STACK Flowline ~,,1~ O~~ 29 1/2'x500 psi Annular Preventer Operated Valve Operated Valve 30' Spool Pieces to Casing Head Flare Boom 10' Line ~. +100' Crane Rig ~-Targeted Tee Pipe Rack Quarters M: R~THON OIL COMPANY DOLL,'Y; V/~RDEN PLATFORM BOP STACK Flowllne i3 5/8'x 5000 psi Annular Preventer Drill Deck FIoM ~- Pipa' Rams BIi~d. Rams Spool Pieces to Casinohead ..,__.___..--~ Clamg Conneclor 3 5/8' 5000 pti Double Rams Choke Line 3" 5000 psi ! . ~ 3' Howco Lo Torque 5000 pal Valve All Flanges ere 3' 5000 pal Remole AdJualable Choke · 3/4' Manual Choke Pre II, Ute Senior Rig Floor ,M.,ARATHO[4 OIL COMPANY I~LLY V ARDEN PLATFORM CHOKE MANIFOLD p Cock Valve Open) 3' ~'% 1 1/2" Manual __ ' Choke -- Plug m 2" Blind' Flange i6" to Shaker · 0 "'""'--- Choke Line 3" 5000 psi MARATHON OIL COMPANY WELL PROGRAM Well: Dolly Varden Platform Well D-45 Field: McArthur River AFE: 8227-8 Coordinates: Surface: 752' FSL, 1134' FWL, Sec 6, TSN, R13W, SM Top of Objective: 1100' FSL, 2354' FWL, Sec 6, T8N, R13W, SM KB Elevation: 106.2' MSW Total Depth: 10,100' TVD, 10,399' MD Hold Angle: 24.95° Course: N74°E Coring: DST: Logging: GEOLOGIC PROGRAM None Planned None Planned DIL/GR/SP/LSS, FD¢/CNL/GR DRILLING PROGRAM ~~l~(~ffiO.~'~ Pull completion assembly. Abandon existing perforations. Cut and retrieve 9-5/8" casing to below 13-3/8" shoe at 2536'. Cut and retrieve 13-3/8" casing to 600'. Side track and drill 17-1/2" hole to 2500'. Run and cement 13-3/8" casing. Drill out and test casing shoe. Drill 12-1/4" hole to 9400'. Run and cement 9-5/8" casing. Drill out and test casing shoe to 12.0 ppg EMW. Drill 8-1/2" hole to 10,399'. Run and cement 7" liner. DIRECTIONAL PROGRAM Kickoff at 360' and turn from N71.6W to N55E by 460'. Build l°/100 to 4° from 460' to 760' at N55E. Turn from N55E to N74E at 768'. Hold 4° at N74E from 768' to 1100'. Drop l°/100 from 1100' to 1500' for 0° inclination. Drill vertical hole from 1500' to 5000'. Build to 4° at 2°/100 from 5000' to 5200' holding N74E. Hold 4° from 5200' to 6752'. Build to 24.95° at 2.5°/100 from 6752' to 7589'. Hold 24.95° from 7589' to TD at 10,399 at N74E. CASING PROGRAM Size Set At Wt. Grade THD Hole Size Cement Surface: 13-3/8" 2500' 61# J-55 BTC Production: 9-5/8" 8000' 43.5# N-80 BTC 9400' 47.0# N-80 BTC Liner: 7"* 10,636' 29# N-80 BTC 17-1/2" 2978 sx 12-1/4" 1300 sx lead 12-1/4" 175 sx tail to be adjusted based on caliper volumes 8-1/2" 250 sx (25% excess over caliper volume) with 200' lap into 9-5/8" *If hole conditions permit, 12-1/4" hole will be drilled and 9-5/8" casing will be set at TD. Marathon Oil Company Well Program Page 2 MUD PROGRAM FROM TO WT. VIS. 2,500' 9,400 9,400' 10,399' 8.8-9.0 9.0-9.5 35-45 35-45 W,t. 8-10 6-8 PH 9.0-9.5 9.0-9.5 TYPE MUD Water Base Co- polymer system ~050 900 75O 60O 450 300 i50 t50 3OO 45O 600 900 Hfl TV[] DEPRT 360 360 -i 460 460 -! 766 768 t! ~tO0 t099 34 i500 i499 46 5000 4999 46 5200 5i98 55 6752 6747 i64 7589 7553 372 97i6 948i 1269 i0399 iOiO0 i557 HORIZONTAL VIEW MARATHON OIL COMPANY D45 FROM D-13 360 MD KOP CLOSURE 1557 ft N 74.t E DECLINATION: 24.t3 deg E SCALE: I[nch = 300 feet DRAWN: i-30-89 300 \ 450 600 750 go0 iO§O t200 t350 t500 t6§O 6OO ~200 t600 2400 3000 3600 4200 4800 5400 6000 660O 720O 7BO0 8400 go00 9600 ~0200 ~0800 -6OO ,, DUZLD i 0 deg/iOO fi: 1o IVERA6E AN6LE 4. dec ' DROP,t ,0 deg/_~O! VERTICAL SECTION MARATHON OIL COMPANY D45 FROM D-!3 360 HD KOP SECTION AT N 74.13 E TVD SCALE: i inch = i200 feet DEP SCALE: I inch = 1200 feet DRAWN : 1-30-89 MarkeP Identification ~ TVD DEPRT A) SIDETRACK/TURN 360 360 B} BU/LD i.O/iO0 460 460 -! ~ EI~OFBUZLD 768 76B DJ DROP i.O/tO0 ~tO0 i099 34 E} END OF DROP ~500 i499 49 F] BUZLD 2.0/~00 5000 4999 48 ~ END OF BUZLD 5200 5~9B 55 H~ BUZL.D 2.§/~00 6752 6747 ~64 ~ END OF BUZI..D 75B9 7553 372 J} TOP OF HEtLOCK/T6'r 9'/i6 94Bi ~269 rd 'ID t0399 ~OtO0 T iH ~ BUZL] 2.~ deg~'tO0 _ _ ~AVERA6E AN61..E 24.95 dec J __ ,, 0 6oo taoo t,oo 24o0 3000 36oo 4~00 4800 ,400 6000 6600 Departure WELL D-45 PLANNED WELL COURSE INTERFERENCE CHECK After leaving the D-13 wellbore at 360 feet, the D-45 plan has crossings with 18 existing wells. Three of these crossings are summarized below, the others exceed 1000 feet in separation. WELL TVD BKB D-45 TVD D-45 is: D-19 1077 851 226 ft above D-42 776 892 116 ft below D-43 1541 1100 441 ft above Ail wells leaving the Dolly Varden Platform are within 120 feet of D-45 between the surface and 6700 ft. TVD BKB. Close attention will be paid to the area from the surface to a depth of about 500 TVD BKB as many wells are within 10 feet of D-45. These 10' close approaches are summarized below: WELL DISTANCE AT TVD BKB D-15 1 ft. 460 D-0! 5 ft. 460 D-ii 7 ft. 500 D-03R2 4 ft. 400-500 D-07R 9 ft. 500 D-09R 6 ft. 500 D-19 5 ft. 610 D-23 3 ft. 500 D-42 2 ft. 300 D-44 4 ft. 360 D-21 5 ft. 360 D-05R 7 ft. 360 D-05 9 ft. 360 RECEIVED ~ia~ka ~;l & Gas Cons. Commissiot~ .t 1t "e ~"a'~ ~ ,4' · ,~ ~ ....... :>~ ~,~ ~ ,. , , ~~. ~ '... ~ 10 I I I i" + · MARATHON Ol~ COMI)AN¥ · &o, eoe&e ·)e ,ee)e 1 TR&DINO'B'AT i . UNIT. I" IaC'AFITHUR RIVE. Fi£LD}~ i ' · ....., .~ ,.~:';.~.,,,.~.-~.::.,..~,,,.. .... · ~: ~. .. · .:~ ..... i1~11,u · 1.-~ ,. I~1 ~- ! ! .,:. PRESSURE DETERMINATION HEMLOCK RESERVOIR The maximum pressure to be encountered while drilling Well D-45 is expected to occur in the Hemlock reservoir. A pressure of 4010 psi at 9350'SS is predicted based upon a static reservoir pressure of 3660 psi at 9350'SS measured in Well D-17RD in March, 1988. The maximum surface calculated for the Hemlock reservoir is 3,328 psi. This pressure was calculated using the following formula: Ratio = 1 - (.018 x TVD) 1,000 Ratio = 1 - (.018 x 9450') 1,000 =0.830 Maximum Surface Pressure = Ratio x Formation Pressure = 0.830 x 4010 = 3,328 psi LIST OF SOLIDS CONTROL EQUIPMENT 2 each - Brandt Dual Tandem Shale Shakers 1 each - Pioneer Desander 1 each - Pioneer Disilter 1 each - Degasser A Totco mud system has been designed into the driller's console. Each of the active pits are equipped with probes which actuate both visual and audio alarms at the driller's console. Unocal Oil & Gas Die , Unocal Corporation PO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Department Alaska District February 28, 1989 Mr. C, V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Hike Hinder RE: Trading Bay Unit Well No. D-45 As requested by Hr. Hike Hinder, attached is an addendum for the Permit to Drill Dolly Varden platform well D-45. The addendum covers clarification of areas concerning the drilling of injection-type wells, cement tops in the abandonment of well D-13 and a variance request for the diverter system. If you have any questions concerning this addendum, please contact me at 276-7600, Very truly yours, Candace W,~ock~ood Environmental Specialist CWL:cgs:02/28/89 Attachment CC' Cliff Neve Mike Starzer 0013/19 RECEIVED MAR d 1 tg q · aska ~)il & Gas ~na ,Commission :' ~chorage ADDENDUM TO PERMIT TO DRILL REVISION 2/1/89 WELL: Dolly Varden Platform Well D-45 FIELD: McArthur River Field TYPE: Hemlock Water Injection DRILLING PROGRAM Pull completion assembly. Abandon existing perforations. Squeeze casing leak between 3,215'-3,246'. Cut and retrieve 9-5/8" casing to ~800'. Lay 250' continuous cement plug with 100' below casing stub and 150' above casing stub to 650'. Cut and retrieve 13-3/8" casing to ±600' Lay 200' continuous cement plug from ±650' to 450'. Kickoff and drill 17~1/2,, hole to 2,500'. Run and cement new 13-3/8" casing. Drill out and run leak-off test. Drill 12-1/4" hole to ±9,400'. Run and cement 9-5/8" casing. Drill out and test casing shoe to 12.0 ppg EMW. Drill 8-1/2" hole to 10,399' 7" liner. · Run and cement OTHER CONSIDERATIONS Since Well D-45 will be a water injection well, the casings will be cemented and pressure tested in accordance ~ith 20 AAC 25.412 and 20 AAC 25.030. The Commission will be given sufficient notice prior to pressure tests so that a representative of the Commission may witness the tests. The 9-5/8" and 7" casing strings will have a cement bond log run following the primary cementing. Ail conductors in Leg A-2 have had wells drilled through them and it is believed sufficient cement has been pumped to stabilize the lost circulation zone at the conductor shoe. · Well D-45 will not penetrate any formations known to contain hydrogen sulfide. Therefore, H2S detection monitoring, contingency and control, and training are not required. RECEIVED DOLLY VARDEN PLATFORM DIVERTER SYSTEM SPECIFICATIONS Riser: 30" O.D. rated to 500 psi. BOP: 30" Hydril MSP Annular, rated to 500 psi. D~verter Spool : 30" O.D. w/2-10" outlets rated to 500 psi. Diverter Valves : 2 each 10" full opening ball valves w/hydraulic actuators 600 ANSI rating Diverter Line: 250mm nominal schedule 40 ID -- 9.80" O.D. 10.53" It is requested that the Alaska Oil and Gas Conservation Commission approve a variance from 20 AAC 25.035(b)(1) Structural Casing BOPE Requirements. The planned Dolly Varden Platform diverter system will have two 10-inch vent line outlets in the spool immediately below the 30-inch annular preventer. The annular, preventer and diverter valves may be functioned from the main BOP panel, remote BOP panel or Koomey unit. The primary diverter valve's hand control will be mechanically linked to the hand control of the annular preventer on the Koomey unit. In this way, the diverter valve will react in a fail-safe manner such that the valve will open upon closure of the annular preventer or close when the annular preventer opens thus preventing a complete shut-in of the wellbore. December 2, i988 Telecopy; (907)276-7542 Mr. Roy D. R°berrs Environmental Engineer Union Oil Company of California P. O. ~x 190247 Anchorage, AlaSka 99502' Trading Bay ~.~ D-45 Uni°n 0il Co~any of California Pe~t No. 88-140 Sur. Loc. 752'FSL, 1134'~, Sec. 6, T8N, R13W, SM Btmho!e Loc. 1370'FSL, 3436'~, Sec. 6, T8N, R13W, SM Dear Mr. Roberts Enclosed ls the approved aPplication for a permit to redrill well D-13 which you now choose to identify 'as well D-45. The permit to redrill does not indemnify you from the probable need to obtain additional pemits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to Commencing installation of the blowout prevention equipment so that a representative of the Commission may be present tO witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very._ truly ~..ours, Ch~£~n o~ Alaska Oil and Gas Conservation Commission BY O~ER OF ~E COMMISSION dlf Enclosure ~ CC ,. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamorea~ ' ~ STATE Of ALASKA ALASI~,'~ Oil AND GAS CONSERVATION ,.~OMMISSlON PERMIT TO DRILL 20 AAC 25.005 I la. TyPe of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service ~ Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal (Marathon Oil Company, Sub-Operator) 106'KB above MSL feet McArthur River P~odxre~0247 Anchorage, AK 99519-0247 6'~P~7~signati°n Hemlock 4. Location of weil at surface Leg A-2 Cond #12 Dolly 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) '" Varden 752' FSL, 1134' FWL, Sec 6 T8N Trading Bay Unit Statewide R13~! SM ' ' top of productive interval 81 Well nurpber Number 1249' FSL, 3239' FWL, Sec 6, T8N, R13W, SM D-45 2-313-189-11 At total depth 9. Approximate spud date Amount 1370' FSL, 3436' FWL, Sec 6, T8N, R13W, SM December 15, 1988 $500,000 ~ .... 12. Distance t° nearest 13. Distance to nearest well 14. Number of acres in prOperty 15.1~,o~)~d ,~)th(MD and TVD) property line 5900 feet +300 feet 5116 10,641' MD feet .. 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2546 feet Maximum hole angle 18.°2 Maximum surface 3,328 pslg At total depth O'VD) 4010 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade i Coupling Length MD TVD MD TVD (include stage data) 17-1/2 13-3/8 61 J55 BTC 2500 Surfac~ 2536 2401 In place i2-1/4 ~-5/~ 43.5&4/ NS(J ]JT[J l~360 5ur~ac,. W400~ 8972~': 1475 sx 8-i/2 7 29 N~O BTC 1430 9200 ~' '-':;10,641~01.bU Z.bO sx ?Note: (.-5/8" ¢~'sing will b(,. set at TD if hole c~,nditi~)ns pe:.-mit 19. To be completed for Redrill, Re-entry, and D~eepen Operations. Present well condition summary Total depth: measured 10,964 feet Plugs (measured) 10,785 (cat) true vertical 10,458 feet Effective depth: measured 10,785 feet Junk (measured) true vertical 10,285 feet . Casing Length Size Cemented Measured depth True Vertical depth Structural 33" RECEIVED 350' 350' Conductor Surface 13-3/8" 2536 ' 2461 ' Intermediate ~,JOV 1 u ,', 5/8" Production ~- /~ ~i~$;<~ .0ii & Gas Cons. C0.~,~j$~:, 964 ' 10,458 ' Liner ~ '; ~nch0rage Perforation depth: measured 10,244'-10,78~' true vertical 9,765- 10,285' 20. Attachments Filing fee i~ Property plat ~ BOP Sketch~ Diverter Sketch [] Drilling program i~ Drilling fluid program .~. Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ~.~~~/~./,,'~j Title Environmental Engineer Date Roy D~. Roberts ~ ,~_... Commission Use Only / / Permit Number I APl number I AQp, roval date I See cover letter ~"/5/~3 I 50-- ?~3"-~-O/,~ -O/ I 12/02/88 . I for other requirements Conditions of approval Samples required [] Yes ~'No Mud log iequi,red ~ Yes ,;,~0 "' Hydrogen sulfide measures [] Yes ~No Directional survey required ,,~Yes [] No Required working p~,esrsure~r ~ J~2M; ,~ 3M; ~ 5M; [] 10M; [] 15M Other: //,~//~/~.///~ ~ by order of Approved by (~"/-Z ( ~'~~Z~ Comm'ssionerl the commission Date Form 10-401 Rev. 12-1-85 / ' e,,~,,-,,;, ;,. ~ ;,-,,;,.-,,,, 36' I ! I ! ! la. eM' ,,+;-. - · .... '--KING SALMON + 3O 31 '" ' 20 ADL18772 + REC EIVED+ 13 ADL 17~0A ADL 17594 DOLLY m ~ VAR:DEN I¸8 ADL 18730 · ~.m......~ ., +--,, ADL 18729 I '"' 17 I I I ! ! ! ! I ADL 17579 + + 15 --,' _:. uARATHON OIL COMPANY 6k,6Jt &l it, el vi ecl TRADING lAY UNIT McARTHUR RIVER FIELD e · tt;.Aitj~ Plkl _ MARATHON OIL DOLLY VARDEN COMPANY PLATFORM BOP STACK - - Flowline U 13 5/8'x 5000 Annular Prevenler o ..,_.__~ Clamp Conneclor . Pipe Rams [-~ ~13 5/8' 5000 psi Double Rams ~td© Choke Line 3' 5000 psi Drill Deck Floor Spool Pieces to Casinghead · o · (~ 3' Howco Lo Torque 5000 pal Valve All Flangee ere 3' 5000 pal Remote Adluflable Choke 3/4' Manual Choke Prelaure Slnaor Rig Floor ~,.ARATHON OIL COMPANY I~LLY VARDEN PLATFORM CHOKE MANIFOLD 3,l I 1/2' Manual Choke 3" Vent Line 31 Valve Open} Plug 2" Blind Flange 6' to Shaker ~"'""--'-- Choke Line 3" 5000 psi MARATHON OIL COMPANY W~.T. PROGRAM Well Dolly Varden Platform Well D-45 Field: McArthur River AFE: 8227-8 Coordinates: Surface: Top of Objective: KB Elevation: Total Depth: Hold Angle: Course: 752' FSL, 1134' FWL, Sec 6, T8N, R13W, SM 1249' FSL, 3239' FWL, Sec 6, T8N, R13W, SM 106.2' MSW 10,150' TVD, 10,641' MD 18.33° N58 °E G~OIDGIC PROGRAM Coring: DST: Logging: None Planned None Planned DIL/GR/SP/LSS, FDC/CNL/GR DRILLING PROGRAM Pull cc~letion assembly. Abandon existing perforations. Cut and retrieve 9-5/8" casing to below 13-3/8" shoe at 2536'. Sidetrack and drill 12-1/4" hole to 9400'. Run and cement 9-5/8" casing. Drill out and test casing shoe to 12.0 ppg EMW. Drill 8-1/2" hole to 10,636'. Run and c,e~,t 7" liner. Kickoff at 2546'. Drop at 0.7°/100ft and turn at 8.9°/100 ft to 18.23° at S70°E at 3100'. Continue turning to N58°E at 3600'. Hold angle to TD. Size Set At Wt. Grade THD Hole Size , · Surface: 13-3/8" 2536' 61# J-55 BTC In Place Cement Production: 9-5/8" 8000' 43.5# N-80 BTC 9400' 47.0# N-80 BTC 12-1/4" 1300 sx lead 12-1/4" 175 sx tail to be adjusted based on caliper volumes Liner: 7"* 10,636' 29# N-80 BTC 8-1/2" 250 sx (25% excess over caliper volume) with 200' lap into 9-5/8" *If hole conditions permit, 12-1/4" hole will be drilled and 9-5/8" casing will be set at TD. MUD PROGRAM From To Wt. Vis. W.L. PH T~0eMud 2536' 9,400' 8.8'-9'."0 '35-45 8-10 9.0-9.5 Water Base Co- 9400 10,641' 9.0-9.5 35-45 6-8 9.0-9.5 polymer system Marker Identification ~J FOP - DROP/TURN DJ END OF DROP CJ END DE TURN E/ TOP OF BEMLOCK ~ BOTTOM OF HEMLOCK NOBIZONTAL VIEN MARATHON OIL OOMPAM¥ ~45 FROM Bi~ 2546 M~ FOP OLOSURE: 2378 f% M 74.9 E OECLINATZON: 24.t3 dec E SCALE: i i~ch = 500 feet ORA~N: 10/20/88 i7~0 1500 i~50 tO00 i7~0 VERTICAL SECTION T V 0 BOO I000 2400 4200 4000 5400 B000 6600 8400 -600 ANGLE 0-45 D45 FRON Dt3 2548 MO KOP SECTION AT N 58,30 E iTVO SCALE: ! incl~ = i200 feet I OEP SCALE: t irtch = t200 feet WELL D-45 PLANNED WELL COURSE INTERFERENCE CHECK An interference program was run to determine if any Steelhead, Grayling or Dolly Varden wells come within a proximity radius of 300 feet to the Dolly Varden's Well D-45 planned course. There are no wells that fall into this category after leaving the D-13 wellbore at 2536'. . f : ! · 13 ..~ x.x 20 ........... 19 I. · · I I ' _, I · M&R&TH~OiNI Oil. COMPANY &L6 iii iiIIlIKI , I '-'. Mc'ARTHUR. RIVER FIE~D~4' I · .'. ','. ;: ,'t~'?/.~'N'.~.~'~.. I :'' .~ .... r i'" ~ ;"" ~' "~ I .'," ' '~ '"'"' ~":~ ~:' -~,. PRESSURE DETERMINATION HEMLOCK RESERVOIR The maximum pressure to be encountered while drilling Well D-45 is expected to occur in the Hemlock reservoir. A pressure of 4010 psi at 9350'SS is predicted based upon a static reservoir pressure of 3660 psi at 9350'SS measured in Well D-17RD in March, 1988. The maximum surface calculated for the Hemlock reservoir is 3,328 psi. This pressure was calculated using the following formula: Ratio = 1 - (.018 x TVD) 1,000 Ratio = 1 - (.018 x 9450') =0.830 1,000 Maximum Surface Pressure = Ratio x Formation Pressure = 0.830 x 4010 = 3,328 psi LIST OF SOLIDS CONTROL EQUIPMENT 2 each - Brandt Dual Tandem Shale Shakers 1 each - Pioneer Desander 1 each - Pioneer Disilter 1 each - Degasser A Totco mud system has been designed into the driller's console. Each of the active pits are equipped with probes which actuate both visual and audio alarms at the driller's console. CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE (1) Fee ~/~C ~ 1. Is the permit fee attached ..... .., ................................. (2 thru 8) e 3. 4. 5. 6. 7. 8.~ Lease & YES ,, , e 10. 11. 12. 13. Is well to be located in a defined pool ............................. ~ Is well located proper distance from property line .................. ~. Is well located proper distance from other wells .................... 2~_ __ Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ ~._ __ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~-- Is administrative approval needed ................................... _~_ Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ (8) (3) Admin (~thru~ /.zr', _ (10 and 13) - (14 thru 22) Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams.and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~o psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (s) (23 thru 28) 7-.COt zT-V, _ NO REMARKS _ .. , (6) (29 th (6) Add: ~.~ Geology: Engineering: rev: 01/30/89 6.011 For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks , (2 chru 8) (29 t:hr= 31) 08/11/88 2. Is well :o be located in a defined pool ............................ 3. Is well located proper distance from property line .................. 4. Is well loca=ed proper distance from other wells .................... 5. Is sufficient undedicated acreage available in Chis pool ............ 6. Is well =o be deviated and is wetlbore plat included .' , ..... . .. ....... , ........... :::::::"'":'::::" 8. C~ pe~= be approved before fiftaen-~ay.wai~ .... ' ........... 9. Does operaCor have a bond ~ force .................................. I0. Is a corena=ion order needed ...................................... 11 Is ad~is~ra~ive app~ov~ needed 14. Is conduc~ors~r~ provided ........................................ 15. Will surface casing protect a~ zones reasonably ~ec=ed se~e as an underground source of drying water ..................... 16. Is enough cement used =o circ~a=e on conductor ~d surface ......... 17. W~i cement :la ~ surface ~d ~=e~ediate or produc=ion stags ... 18. Wi~ cement cover ~1 ~~ produc=ive hot, ohs ..................... 19. Will ~1 cas~g give adequate s~e~ ~ collapse, tension 20. Is =his well =o be ~c~d off from ~ exis=~g wellbore ............. 2I. Is old we~bore ab~do~en=, procedure included on I~403 ............ . 22 Is adequate we~bore separation proposed ' 23. Is a diver:ar sys~ required ....................................... 24. Is the dr~l~g fled progr~ sche~ic ~d list of eq~ent adequate~ 25. ~e necessa~ diagram~ ~d descriptions of~~ BOPE a~tachad. 26. Does BOPE have s~ficient pressure rat~g -Tes~ co ~7. Does :ha choka~old c w ~-53 .................. 28. ~ ~a presence of H2S Bas probable ................................. Pot ~iora:o~' ~d Scra:iBrap~c we~s: ~9. ~e ~:a presented on po:en:f~ ~e~ress~e zones~ ................ 30. ~e sai~c ~Ts~s da:a preseu:ad ou s~a~ow ~as zo:as ............ 3I. ~ ~ offshore loc., ara ~a7 ~esui:s of seabed co:d~:ious 32. Addtt:tonal requirements ~.. , "i;;:' . [ POOL CLASS STATUS AREA I ,,,, Addi:ional Remarks: NO. SH0~j u . / / , . .o 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. ALASKA COMPUTING CENTER ........ SCHLUMBERGER COMPANY NAME : MARATHON OIL COMPANY ~ELL NAME : T.8.U. D-45 FIELD NAME : MCARTHUR RIVER BOROUGH : KENAI STATE :: ALASKA AP! NUMBER : 50-733-20150-0! RE~ERENCE NO : 7338! .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 *~*~ REEL HEADER SERVICE NAME : EDIT DATE : 89/06/29 ORIGIN : FLIC REEL NAME : 73381 CONTINUATION ~ : PREVIOUS REEL : COMMENT ' MARATHON, MCARTHUR RIVER, TBU D-45, RPI eEO-T33-20150-O! *~ TAPE HEADER ~ SERVICE N~ME : EDIT DATE : 89/06/29 ORIGIN : FLIC TAPE NAME : 73381 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : MARATHON, MC~RTHUR RIVER, TBU D-45~ API #50-733-20150-0! · *~ FILE HEADER 4,~ FILE NAME : EDIT .00! SERVICE : FLIC VERSION : 001A02 DATE : 89/06/29 MAX EEC SIZE : 1096 FILE TYPE : LO LAST FILE : PAGE: COMPANY NAME:' MARATHON OIL COMPANY WELL: To~.U. D-45 FIELD: MCARTHUR RIVER BOROUGH: KENAI STATE: ALASKA API NUMBER: 50-733-20150-01 LOCATION: LEG A-2, CONDUCTOR 12 SECTION: 6 TOWNSHIP: 8N RANGE: 13W ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: PERMANENT DATUM: MSL ELEVATION: 0 LOG MEASURED ~ROM KB 106.2 ABOVE PERMANENT DATUM ELEVATIONS KB: 106.2 DF: N/A GL: N/A DATE LOGGED: 22-MAY-89 RUN NUMBER: 1 TD DRILLER: 10415 TD LOGGER: 10399 CASING: 13 3/8" LB @ DRILLER DEPTH OF 2491' AN LOGGER DEPTH OF 2489' BIT SIZE: 12 1/4" TYPE FLUID IN HOLE: GENERIC ~2 DENSITY: 10 VISCOSITY: 100 PH: 9 FLUID LOSS: 5.4 MUD RESISTIVITY: FILTRATE RESISTIVITY: 1.72 @ 49 1.19 @ 63 TIME CIRCULATION ENDED:' 08:00 2Z-MAY TIME LOGGER ON BOTTOM: 14:20 22-MAY COTE/LSS) TIME LOGGER ON BOTTOM: 21:52 2Z-MAY (LDT/CNL) MAXIMUM TEMP RECORDED: 162 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: KENAI MILLER BRICKEY TOOL NUMBERS: DIS-HC 139 SLS-ZA 637 SGC-SA 667 AMM-AA 8'74 DIC-E A 86 SLC-UA 156 TCC-A 115 FIELD REMARKS: CALIPER READ > 22" IN PLACES. PHASOR INDUCTION RUN IN COMBINATION WITH LONG SPACED SONIC. 3 1/2" STANDOFFS USED ON DITE. CYCLE SKIPS IN RUGOSE HOLE. DTL USED FOR INTEGRATED TRANSIT TIME. BOWSPRING RUN ON CNL WITH SAND MATRIX. DATE JOB STAR'TED: ZS-JUN-S9 JOB REFERENCE NO: 73381 LDP/ANA: J. KOHRING FILE - EDIT.O01 MARATHON OIL COMPANY IS TAPE VERIFICATION LISTING :CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16=2T PAGE: MCARTHUR RIVER T .B .Uo 0-45 50-733-20150-01 MAIN PASS LOG DATA LOT/CML DEPTH-ADJUSTED TO THE DIL/LSS PASS USING GAMMA RAYS FOR CORRELATION DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED- TOOL EXTENSION TOOL TYPE USED NAME DIT-E °DTE LSS .LSS LOT .LOT CNT-A/D/H .CNL PHASOR DUAL INDUCTION SFL 10393' - 2489' LONG SPACED SONIC 10357' - 2489' LITHO DENSITY [0395m - 2489m COMPENSATED NEUTRON 10376' - 2489' TABLE TYPE : CONS TUNI VALU DEFI CN MARATHON OIL COMPANY FN MCARTHUR RIVER WN T.B.U. D-45 APIN 50-733-20150-01 FL LEG A-2, CONOUCTOR 12 SECT 6 TOWN 8N RANG 13W ,C OUN K ENAI STAT ALASKA NATI USA ENGI TROY MILLER WIT:N BRICKEY SON 548635 POAT MSL EPD FT O. LMF KB APO FT I06.2 EKB FT ! 06.2 EOF FT -999.Z5 EGL FT -999.Z5 TOD FT 10415. BLI F1 10393. TLI FT 2489. TCS 08:00 22-MAY TLAB 1~:20 22-MAY COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEERmS NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM BOTTOM LOG INTERVAL TOP LOG INTERVAL TIME CIRCULATION STOPPED TIME LOGGER AT BOTTOM IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: TABLE TYPE : CURV DEPT SFLU ILM ILO SP IDPH IMPH IFRE CIOP CIMP IIRO IIXO IIRM GR TENS MTEM MAES HTEN DT DTL TT1 T TT3 TT4 SP GR TENS MTEM MRES HTEN DPHT RHOB O R H 0 PEF QLS QSS LS LU LL LITH SS1 SS2 LSHV SSHV S1RH LSRH LURH CALI GR TENS MTEM DEFI DEPTH CHANNEL NAME SFL UNAVERAGED IL-MEDIUM RESISTIVITY IL-~EEP RESISTIVITY SPONTANEOUS POTENTIAL INDUCTION OEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASER RESISTIVITY INDUCTION CALIBRATED FREQUENCY INDUCTION DEEP PHASOR CONDUCTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INTERMEDIATE INDUCTION REAL DEEP CONDUCTIVITY INTERMEDIATE INDUCTION QUADRATURE DEEP CONDUCTIVITY INTERMEDIATE INDUCTION REAL MEDIUM CONDUCTIVITY GAMMA RAY TENSION MUD TEMPERATURE MUD RESISTIVITY HE AD TENSION DELTA-T DELTA T LONG SPACING TRANSIT TIME 1 TRANSIT TIME 2 TRANSIT TIME 3 TRANSIT TIME 4 SPONTANEOUS POTENTIAL GAMMA RAY TENSION MUD TEMPERATURE MUD RESISTIVITY HEAD TENSION DENSITY POROSITY BULK DENSITY DELTA RHO PHOTO-ELECTRIC FACTOR QUALITY CONTROL OF LONG SPACING FOR LOT QUALITY CONTROL ON SHORT SPACING FOR CDT LONG SPACING COMPUTED COUNT RATE (LL+LU/2.) LONG UPPER 1-2 WINDOW COUNT RATE (LUI+LU?) LONG LOWER WINDOW COUNT RATE LITHOLOG WINDOW COUNT RATE SHOR'T SPACTNG I WINDOW COUNT RATE SHORT SPACING 2. WINOON COUNT RATE LONG SPACING HIGH VOLTAGE OUTPUT SHORT SPACING HIGH VOLTAGE LOOP OUTPUT SHORT SPACING 1 DENSITY LONG SPACING RHOB (UNCORRECTED) LONG UPPER RHOB CALI PER GAMMA RAY TENSION MUD TEMPERATURE · IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: MAES HTEN NPHI TNPH TNRA NPOR RCNT RCFT CNTC CFTC GR CALI TENS MRES MTEM HTEN DEFI MUD RESISTIVITY HEAD TENSION NEUTRON POROSITY TMERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTEO NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY CALIPER TENSION MUD RESISTIVITY MUD TEMPERATURE HEAD TENSION DATA FORMA'T SPECIFICATION RECORD · ~ SET TYPE - 64EB ~-~ TYPE REPR CODE VALUE ! 66 2 66 3 73 4 66 5 66 6 73 0 0 268 1 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 0 SET TYPE - CHAN '-~* NAME SERV UNI'T SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER a LOG TYPE CLASS MOD NUMB SAMP ELEM CODE DEPT FT 548635 O0 000 O0 0 1 1 ! 4 68 SFLU DTE OHMM 548635 07 220 O1 0 1 1 1 4 68 ILM gTE OHMM 548635 07 120 4,4 0 I I I 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: NAME SERV UNIT SERVICE API API AMI API FILE NUMB NUMB SIZE REPR ID ILO DTE OHMM 548635 07 SP DTE MV 54.8635 07 IDPH DTE OHMM 543635 O? IMPH DTE OHMM 54.8635 07 IFRE DTE HZ 54.8635 07 CIOP DTE MMHO 548635 07 CIMP OTE MMHO 548635 07 IIRO DTE MMHO 548635 07 IIXD DTE MMHO 548635 07 IIRM DTE MMHO 54..8635 07 GR DTE GAPI 54.8635 07 TENS DTE LB 548635 07 MTEM OTE DEGF 548635 07 MRES OTE OHMM 5.48635 07 HTEN OTE LB 5448635 07 DT LSS US/F 548635 07 DTL LSS US/F 548635 07 TT1 LSS US 548635 07 TT2 LSS US 548635 07 TT3 LSS US 54.$635 07 TT4. LSS US 548635 07 SP LSS MV 548635 07 GR LSS GAPI 548635 0'7 TENS LSS LB 54.8635 07 MTEM LSS DEGF 548635 07 MRES LSS DHMM 548635 07 HTEN LSS LB 548635 07 DPHI LOT PU 548635 42 RHO:B LOT G/C3 5486135 42 ORHO LOT G/C3 548635 42 PEF LOT 548635 42 QLS LOT 5448635 42 QSS LOT 548635 42 LS LOT CPS 548635 42 LU LOT CPS 548635 42 LL LOT CPS 548635 42 LITM LDT CPS 548635 42 SS! LOT CPS 548635 42 SS2 LOT CPS 548635 42 LSHV LOT V 548635 42 SSHV LOT V 54.8635 42 SIRH LOT G/C3 54.8635 42 LSRH LDT G/C3 548635 42 LURH LOT G/C3 548635 42 CALI LOT IN 548635 4.2 GR LOT GAPI 5448635 42 TENS LOT LB 548635 42 MTEM LOT DEGF 54.8635 42 MRES EDT QHMM 548635 42 HTEN LOT LB 548635 42 NPHI CNL PU 5448635 42 ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM 120 46 0 I 1 010 O1 0 I 1 ! 120 46 0 I I 1 120 444 0 ! ! 000 O0 0 1 I 1 110 46 0 I I 1 110 44. 0 I I 1 000 O0 0 1 1 1 000 O0 0 1 1 1 000 O0 0 1 1 1 310 01 0 I I 1 635 21 0 I 1 000 O0 0 1 1 1 000 O0 0 1 000 O0 0 1 1 1 520 80 0 1 1 1 520 81 0 1 1 1 522 83 0 1 1 1 522 83 0 1 1 1 522 83 0 1 1 1 522 83 0 I I 1 OlD O1 0 I 1 1 310 O1 0 1 1 1 635 21 0 I 1 1 000 O0 0 i I 1 000 O0 0 000 O0 0 1 1 1 890 01 0 I I 1 350 OZ 0 1 1 1 356 O1 0 1 I 1 358 O1 0 1 1 1 354 01 0 I I 1 354 01 0 I I 1 354. O1 0 1 1 1 354 O1 0 1 1 1 354 O1 0 1 1 1 3544 O1 0 1 1 1 354. 02 0 1 1 1 354. 02 0 1 1 1 354 O0 0 I 1 1 354 O0 0 1 1 350 02 0 1 1 1 350 02 0 1 I 1 350 02 0 1 1 I 280 O1 0 1 I 1 310 O1 0 I 1 1 635 21 0 1 1 1 000 O0 0 1 1 1 000 O0 0 1 1 '1 000 O0 0 I I 1 890 O0 0 1 1 1 PROCESS CODE (HEX) 4. 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 44 68 0000000000 4 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4, 68 0000000000 4 68 0000000000 4. 68 000000000-0 4 68 · 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 0000000000 4 68 0000000000 4. 68 0000000000 4. 68 000000:0000 4 68 0000000000 4. 68 0000000000 4 68 0000000000 4. 68 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: NAME SERV UNIT SERVICE API API API ID ORDER # LOG TYPE CLASS TNPH CNL PU 548635 42 890 O0 TNRA CNL 548635 42 420 O! NPOR CNL PU 548635 42 890 O0 RCNT CNL CPS 548635 42 420 01 RCFT CNL CPS 548635 42 420 01 CNTC CNL CPS 548635 42 420 O1 CFTC CNL CPS 548635 42 420 01 GR CNL GAPI 548635 42 310 01 CALI CNL IN 548635 42 280 01 TENS CNL LB 548635 42 635 21 MRES CNL OHMM 548635 42 000 O0 MTEM CNL DEGF 548635 42 000 O0 HTEN CNL LB 548635 42 000 O0 API FILE NUMB NUMB MOD NUMB SAMP EL EM 0 I I 1 0 I I 1 0 ! I 1 0 I I 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 I I 1 0 1 1 1 0 I 1 1 0 I I 1 SIZE 4 4 4 4 4 4 4 4 REPR ,PROCESS CODE CHEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O0000000OO 68 0000000000 68 0000000000 68 0000000000 DEPT. 10480.500 SFLU.DTE -999..250 SP.OTE -999.250 IDPH.ETE -999.250 CIDP.DTE -999.Z50 CIMP.OTE -999.250 IIRM. DTE -999. 250 GR.DTE -999.Z50 MRES.DTE -999.250 HTEN.DTE -999.250 TTI.LSS 843. 500 TT2.LSS 720.000 SP.LSS -80.375 GR.LSS 36.125 MRES.LSS 0.535 HTEN.LSS -1252.000 DRHO.LDT -999.2 50 PEF.LOT - 999. 250 LS.LDT -999. 250 .LU.LDT -999.250 SS1.LOT -999. 250 S S2.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 GR.LDT -999.Z50 TENS.LOT -999.250 HTEN.LDT -999.250 NPHI.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 CFTC. CNL -999. 250 .GR.CNL -999. 250 MRES.CNL -999.250 MTEM.CNL -999.250 ILM.DTE IMPH.DTE IIRD.§TE TENS.DTE OT. L SS TT3.LSS TENS.LSS OPHI.LDT QLS.LOT LL.LOT LSHVoLOT LURH. LOT MTEM.LOT TNPH. CNL RCFT.CNL CALI.CNL HTEN.CNL DEPT. 10400.000 SFLU.DTE 6.340 ILM.OTE SP.DTE -80.813 IDPH.DTE 6.941 IMPH.DTE CIDP.DTE 144.000 CIMP.DTE 143.125 IIRD.DTE IIRM.DTE 137.125 GR.DTE 36.125 TENS.DTE MRES.DTE 0.535 HTEN..DTE -1389.000 DT.LSS TTI.LSS 84'3.500 TT2.LSS 720.000 TT3.LSS SP.LSS -80.813 GR.LSS 36.125 TENS'LSS MRES.LSS 0.535 HTEN.LSS -1389.000 DPHI.LOT DRHO.LDT 0.002 PEF.LDT 4.285 QLS.'LDT LS.LOT 912.000 LU.LDT 853.000 LL.LOT SS1.LDT 229.125 SS2.LOT 396.000 LSHV.LDT S1RH. LDT 1.736 LSRH.LOT 1.746 LURH.LDT GR.LDT 72.500 TENS.LOT 6344.000 MTEM. LOT HTEN.LDT 1103.000 NPHI.CNL 41.360 TNPH.CNL NPOR.CNL 41.894 RCNT.CNL 2365.480 RCFT.CNL -999.250 ILO.DTE -999.250 IFRE.DTE -999.250 IIXD.DTE -999.250 MTEM.DTE 66.750 DTL.LSS 985.000 TT4.LSS 3274.000 MTEM.LSS -999.250 RHOB.LDT -999'250 QSS.LDT -999.250 LITH.LDT -999.250 SSHV.LDT -999.250 CALI.LDT -999.250 MAES.LOT -999.Z50 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL -999.250 6.875 ILO.DTE 6.980 IFRE.DTE 129.250 IIXD'DTE 6144.000 MTEM.DTE 66.750 OTL..LSS 985'000 TT4.LSS 6144.000 MTEM.LSS 54.29'7 RHOB'LDT -0.084 QSS.LDT 485'500 LITH.LDT 1474.000 SSHV.LDT 1.732 CALI.LDT 167.375 MRES.LDT 42.518 TNRA.CNL 579.325 CNTC.CNL -999.250 -999.250 -999.250 -999.250 65.750 863.500 157.250 -999.25:0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6.789 20.000 10.258 157.250 65.750 863.500 157.250 1.754 -0.048 215.500 1571.000 13.766 0.409 3.659 2130.970 ,IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASKA COMPUTING CENTER CFTC.CNL 577. 577 GR.CNL MRES.CNL 0.409 MTEM.CNL DEPT. 10300.000 SFLU.DTE SP.DTE -78.188 IDPH.DTE CIDP.DTE 162.000 CIMP.DTE IIRM.DTE 166.375 GR.DTE HRES.DTE 0.528 HTEN.DTE TTI.ISS 966.500 TT2.LSS SP.LSS -78.188 GR.LSS MRES.LSS O. 528 HTEN.LSS DRHO.LDT 0.138 PEF.LDT LS.LDT 391.250 LU.LDT SS1.LDT 2¢9. 250 SS2.LDT SIRH.LDT 1. 975 LSRH.LDT GR.LDT 63.875 TENS.LOT HTEN.LDT 911.500 NPHI.CNL NPOR.CNL 17.677 RCNT.CNL CFTC.CNL 1249. 208 GR.CNL MRES.CNL 0.383 MTEM.CNL DEPT. 10200.000 SFLU.DTE SP.DTE -130.625 IDPH.DTE CIOP.DTE 35.469 CIMP.DTE IIRM.DTE 31.922 GR.DTE MRES.OTE 0.526 HTEN.DTE TT1.LSS 828. 000 TT2.LSS SP.LSS -130.625 GR.LSS MRES.LSS O. 526 HTEN.LSS DRHO.LOT 0.035 PEF.LDT LS.LOT 264.250 LU.LOT SS1.LOT 210. 250 SS2.LOT SIRH.LDT 2.3 87 LSRH.LDT GR.LDT 46.906 TENS.LOT HTEN.LDT 965.500 NPHI.CNL NPOR.CNL 11.635 RCNT.CNL CFTC.CNL 2659. 228 GR.CNL MRES.CNL 0.384 MTEM.CNL DEPT. 10100.000 SFLU.DTE SP.DTE -134.125 IDPH.DTE CIDP.DTE 26.406 CIMP.DTE IIRM.DTE 24.984 GR.DTE MRES.DTE 0.531 ' HTEN.DTE TT1.LSS 838. 000 TT2.LSS SP.LSS -134.125 GR.LSS MRES.LSS 0.5131 HTEN.LSS DRHO.LDT 0.1 37 PEF.LDT LS.LDT 261.750 LU.LOT SS1.LOT 234. 875 SS2.LDT SIRH.LDT 2.217 LSRH.LDT GR.LDT 42.281 TENS.LOT HTEN.LD'T 1018.500 N:PHI.CNL NPOR.CNL 10.268 RCNT.CNL CFTC.CNL 3164. 155 GR.CNL 29-JUN-1989 16:27 72.500 CALI.CNL 167.375 HTEN.CNL 5.285 ILM.DTE 6.168 IMPH.DTE 178.000 IIRD.DTE 53.875 TENS.DTE -1389.000 DT.LSS 802.000 TT3.LSS 53.875 TENS.LSS -1389.000 DPHI.LDT 3.205 QLS.LDT 363.250 LL.LDT 342.500 LSHV.LDT 2.246 LURH.LDT 5972.000 MTEM.LDT 18.923 TNPH.CflL 3439.739 RCFT.CNL 63.875 CALI.CNL 167.250 HTEN.CNL 36.469 ILM.DTE 28.158 IMPH.DTE 31.234 IIRD. DTE 35.781 TENS.DTE -1388.000 DT.LSS 716.000 TT3.LSS 35.78! TENS.'LSS -1388.000 DPHI.LDT 2.480 QLS.LOT 251.625 LL.LDT 288.250 LSHV.LDT 2.480 LURH.LDT 5912.000 MTEM.LOT 11.620 TNPH-CNL 4994.293 RCFT.CNL 46.906 CALI.CNE 167.125 HTEN.CNL 59.000 ILM.DTE 3'7. 844 IMPH.DTE 25.031 IIRD.OTE 38.813 TENS.DTE -1389.000 DT.LSS 704.000 TT3.LSS 38.813 TENS.ESS -1 389. 000 OPHI.LDT 2.510 QLS.LOT 248.750 LL,.LDT 312. 500 LSHV.LDT 2.486 LURH.LDT 5968.000 MTEM.LDT 8.892 TNPH.CNL 4892.173 RCFT.CNL 42. 281 CALI.CNL 13.766 1103.000 5.656 5.613 140.375 5964.000 72.000 1133.000 5'964.000 15.367 -0.004 209.750 1477.000 2.248 167.250 20.255 1378.323 14.977 911.500 29.781 32.000 39.656 5888.000 66. 000 1035.000 5888.000 7.403 0.013 138.500 1478.000 2.486 167.125 12.360 2779.460 12.539 965.500 38.063 39.906 31.969 5824.000 63.500 975.500 5824.000 0.777 0.022 137'500 1479.000 2.494 167.375 9.498 3240.632 1,2.836 TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB .LDT QSS.LDT LITH.LDT S SHV. LOT CALI .LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB .LOT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS .CNL ILD.DTE IFRE.OTE IIXD.OTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT OSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LOT TNRA.CNL CNTC .CNL TENS.CNL PAGE: 6344.000 6.145 20.000 14.203 157.125 68.750 980.000 157.125 2.396 0.037 97.438 1572.000 14.977 0.383 2.293 2869.671 5972.000 24.531 20'000 6.867 157.125 64.875 855.500 157.125 2.528 0.015 66.625 1574.000 12.539 0.384 1.742 4416.840 5912.000 32.250 20.000 4.848 157.625 61.750 842.000 157.625 2.637 0.025 67.125 1574-000 12.836 0.387 1.568 4629.814 5968.000 IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASKA COMPUTING CENTER MRES.CNL 0.387 MTEM.CNL DEPT. 10000.000 SFLU.DTE SP.DTE -137.250 IOPH.DTE CIDP.DTE 26.938 CIMPoDTE IIRM.DTE 20.234 GR.DTE MRES.OTE 0.526 HTEN.DTE TT!.LSS 845. 000 TT2.LSS SP.LSS -137.250 GR.LSS MRES.LSS 0.526 HTEN..LSS DRHO.LOT 0.098 PEF.LDT LS.LDT 331.750 LU.LOT SS1.LDT 233. 500 S S2.LOT SIRH.LDT 2.137 LSRH.LDT GR.LDT 38.?50 TENS.LOT HTEN.LDT 968.000 NPHI.CNL NPOR.CNL 15.889 RCNT.CNL CFTC.CNL 1795.558 GR.CNL MRES.CNL 0.384 MTEM.CNL 29-JUN-1989 16:17 167.375 HTEN.CNL 32.875 ILM.OTE 37.094 IMPH.DTE 15.898 IIRD.DTE 39.969 TENS.DTE -1391.000 DT.LSS 721.000 TT3.LSS 39.969 TENS.LSS -1391.000 OPHI.LDT 2.789 QLS.LDT 314.000 LL.LDT 317.500 LSHV.LOT 2.340 LURH.LOT 5884.000 MTEM.LOT 15.555 TNPH.CNL 3802.012 RCFT.CNL 38.750 CALI.CNL 166.750 HTEN.CNL DEPT. 9900.000 SFLU.OTE 10.219 ILM.DTE SP.DTE -107.500 IDPH.DTE 11.258 IMPH.DTE CIDP.DTE 88.7510 CIMP.DTE 98.750 IIRD.DTE IIRM.OTE 92.938 GR.OTE 62.500 TENS.DTE MRES.DTE 0.514 HTEN.DTE -1390'000 OT.LSS TT1.LSS 979,.500 TT2.LSS 827.500 TT3oLSS SP.LSS -107.500 GR.LSS 62. 500 TENS.LSS MRES.LSS 0.514 HTEN.LSS -1390.000 DPHI.LOT DRHO.LDT 0.065 PEF.LD'T 2.828 QLS.LOT LS.LOT 299.500 LU.LDT 284. 000 LL.LDT SS1.LDT 221.625 SS2.LDT 302.000 LSHV.LDT SIRH.LDT 2.258 LSRH.LDT 2.402 LURH.LDT GR.LDT 72.625 TENS.LOT 5784.000 MTEM.LDT HTEN.LDT 964.000 NPHI.CNL 23.033 TNPH.CNL NPOR.CNL 24.121 RCNT.CNL 3132..360 RCFT.CNL CFTC.CNL 1199.843 GR.CNL 72.625 CALI.CNL MRES.CNL 0.370 MTEM.CNL 166.125 HTEN.CNL DEPT. 9800.000 SFLU.D'TE 13.180 ILM'DTE SP.DTE -118.063 IDPH.DTE 15.914 IMPH.DTE CIDP.DTE 62.813 CIMP.DTE 86.813 IIRD. DTE IIRM.DTE 81.875 GR.DTE 52.469 TENS.DTE MRES.DTE 0.522 HTEN.DTE -1390.000 OT.LSS TT1.LSS 1036.000 TT2.LSS 898.500 TT3.LSS SP.LSS -1,18.063 GR.LSS 52.469 TENS.LSS MRES.LSS 0.522 HTEN.LSS -1390.000 DPHI.LDT DRHD. LOT 0.066 PEF.LDT 2. 820 · QLS.LDT LS.LDT 340.164 LU.LOT 321.414 LL.LDT SS1.LDT 225.875 SS2.LDT 31'7.250 LSHV.LDT SIRH.LDT 2.182 LSRH.LDT 2.330 LURH.LDT 'GR.LDT 62-156 TENS.LOT 5593.313 MTEM.LOT HTEN.LDT 898. 844 NPHI.CNL 20.464 TNPH.CNL NPOR.CNL 22.296 RCNT.CNL 2918'000 RCFT.CNL CFTC-CNL 1071.117 GR.CNL 62.156 CALI.CNL MRES.CNL 0.371 MTEM.CNL 165.375' HTEN.CNL 1018.500 PAGE: 9 10.180 ILD.DTE 11.125 10.117 IFRE.DTE 20.000 80.000 IIXD.DTE 6.125 5840.000 MTEM.DTE 156.750 75.000 DTL.LSS 75.750 1131.000 TT4.LSS 978.500 5840.000 MTEM.LSS 156-750 10.302 RHO~.LDT 2.480 -0.001 QSS.LDT 0.028 157.625 LITH.LDT 73.313 1480.'000 SSHV.LDT 1574.000 2.404 CALI.LDT 13.953 166.125 MRES.LDT 0.370 23.098 TNRA.CNL 2,540 1208.889 CNTC'CNL 2950.223 13.953 TENS.CNL 5784.000 964.0 O0 11.570 ILD.DTE 15.602 11.516 IFRE.DTE 20.000 56.594 IIXD.DTE 3.260 5688.000 MTEM.OTE 156.750 77.875 DTL.LSS 74.500 1147.000 TT4.LSS 1021.000 5688.000 MTEM'LSS 156.750 14.704 RHOB.LDT 2.407 -0.015 QSS'LDT 0.016 179.416 LITH.LDT 90.459 1478.666 SSHV.LDT I574.000 2.324 CALI.LDT 22-844 165.375 MRES'LDT 0.371 21.415 TNRA.CNL 2.6.02 1081.688 CNTC.CNL 2737.781 22.844 TENS.CNL 5593.313 898.844 47.000 ILD.DTE 34.188 62.875 IFRE.DTE ZO.O00 27.578 IIXD.DTE 3.111 5768.000 MTEM.OTE 157.000 69.625 DTL.LSS 67.375 996'000 TT4.LSS 849.000 5768.000 MTEM.LSS 157.000 12.062 RHOB.LDT 2.451 -0.013 QSS.LDT 0.035 17,6.750 LITH.LDT 77.000 1479.000 SSHV.LDT 1574.000 2.338 CALI.LDT 13.602 166.750 MRES.LDT 0.384 15.779 TNRA.CNL 2.032 1887.242 CNTC.CNL 3484.614 13.602 TENS.CNL 5884.000 96B.000 IS TAPE VERIFICATION LISTING CHLUI~BERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 10 DEPT. 9700.000 SFLU.DTE 38. SP.DTE -102.375 IDPH.DTE 16. CIDP.DTE 59.313 CIMP.DTE 53. IIRM.DTE 64.1 88 GR MRES.DTE 0.529 HTEN.DTE -1390. TT1.LSS 846. 000 TT2.LSS 699. SP.LSS -102.375 GR.LSS 31. MRES.LSS 0.529 HTEN.LSS -1390. DRHO.LDT 0.156 PEF.LDT 4. LS.LDT 280. 250 LU.LDT 269. SS1.LDT 243.000 SS2.LDT 320. SIRH.LDT 2.135 LSRH.LDT OR.LOT 33.906 TENS.LOT 55B0. HTEN.LDT 930. 500 NPHI.CNL 12. NPOR.CNL 12. 419 RCNT.CNL 4203. CFTC.CNL 1975·4 27 GR.CNL 33. MRES.CNL 0.386 MTEM.CNL 164. DEPT. 9600.000 SFLU.DTE SP.DTE -103.000 IDPH.DTE CIDP.DTE 107.250 CIMP.DTE IIRM.DTE 120.875 GR.OTE MRES.DTE 0.530 HTEN.DTE TT1.LSS 1038.000 TT2.LSS SP.LSS -103.000 GR.LSS MRES.LSS 0.530 HTEN.LSS DRHO.LDT 0.104 PEF.LDT LS.LDT 546.336 LU.LDT SS1.LDT 249.472 SS2.LOT S1RH.LDT 1.844 LSRH.LDT GR.LDT 68.426 TENSoLDT HTEN.LOT 929.500 NPHI°CNL NPOR.CNL 24.603 RCNT.CNL CFTC.CNL 962.250 GR.CNL MRES.CNL 0.384 MTEM.CNL 500 ILM.DTE 844 IMPH.DTE 000 IIRO.DTE 234 TENS.DTE 000 DT.LSS 500 TT3.LSS 234 TENS.LSS 000 DPHI.LOT 566 QLS.LDT 750 LL.LDT 250 LSHV.LDT 438 LURH.LOT 000 MTEM.LDT 307 TNPH.CNL 570 RCFT.CNL 906 CALI.CNL 125 HTEN.CNL 12.$59 9.313 125.375 62.563 -1391.000 797.000 62.563 -1391.000 3.821 506.969 395.611 2.05'7 5562.656 22.873 2660.250 68.426 162.875 DEPT. 9500.000 SFLU.DTE 8.961 SP.OTE -90.313 IDPHoDTE 10.109 CIDP.DTE 9B-813 CIMP.DTE 104.313 IIRM.DTE 99.68B GR.DTE 61.063 MRES.DTE 0.526 HTEN.D'TE -1390.000 TTI.LSS 971.500 TT2.LSS 819.500 SP.LSS -90.313 GR.LSS 61.063 NRES.LSS 0.526 HTEN.LSS -1390.000 DRHO-LDT 0.035 PEF.LDT 2.897 LS.LDT 293.000 LU.LDT 277.750 SS1.LOT 213.682 SS2.LDT 294.473 SIRH.LDT 2.323 LSRH.LOT 2.417 GR.LOT 66.223 TENS.LDT 5511.555 HTEN.LDT 944.944 NPHI.CN:L 25.389 NPOR.CNL 26-700 RCNToCNL 2785.$88 CFTC.CNL 989.750 GR.:CNL 66.223 MRES.CNL 0.372 MTEM.CNL 162.000 ILM.DTE IMPH.DTE IIRD.DTE TENS.DTE OT.LSS TT3.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL ILM.DTE IHPH.DTE IIRD.DTE TENS.DTE DT.LSS TT3.LSS TENS.LSS OPHI.LOT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LDT TNPH.CNL ~CFT.CNL CALIoCNL HTEN.CNL 1¢.773 1B.859 58.313 5808.000 60.125 986.000 5808.000 2.558 -O.O1Z 145.250 1478.000 2.438 164.125 12.966 1921.154 19.688 930.500 7.816 7.973 97.000 5572.000 76.000 1200.000 5572.000 29.032 -0.037 292.945 1476.000 2.049 162.875 23.096 1005.750 21.327 929.500 9.484 9.586 89.563 5604.000 77.750 1136.000 5604.000 11.263 0.001 154.109 1~78.000 2.419 162.000 25.522 974.375 15,.120 944.944 ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEMoLSS RHOB.LDT QSS.LDT LITH.LDT SSHV'LDT CALI.LDT MRES.LDT TNRA.CNL CNTC. CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE OTL-LSS TT4.LSS MTEM.LSS RHQB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LOT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.LSS TT~.LSS MTEM-LSS RHOB.LD'T QSS.LDT LITH.LDT SSHV.LDT CALI .LOT MRES.LDT TNRA.CNL CNTC.CNL 'TENS.CNL 15.805 20.000 6.531 156.375 62.250 854.500 156.375 2.608 0.037 56.594 1573.000 19.688 0.386 1.976 3748.340 5580-000 8 20 7 155 77 1044 155 2 --0 123 15'73 21 0 2 5562 9 20 7 155 78 975 155 2 0 73 1573 15 0 2 2630 5511 .891 .000 .543 .625 .625 .000 .625 .171 .036 .461 .000 .327 .384 .723 .000 .656 .922 .000 .121 .250 .250 .500 .250 .464 .021 .590 .000 .120 .372 .728 .688 .555 IS TAPE VERIFZCATION LISTZNG ,CHLUMBERGER ALASKA COMPUTING CENTER 2g-JUN-1989 16:27 PAGE: 11 DEPT. 9400.000 SFLU.DTE 4.887 ILM. DTE 4.996 ILO.DTE 5.305 SP.OTE -86.000 IDPH.OTE 5.398 IMPH.DTE 5.113 IFRE.DTE 20.000 CIOP.DTE 185.125 CIMP.ETE 195.500 IIRD. DTE 164.250 IIXO.DTE 16.625 IIRM.DTE 188.125 GR.DTE 64.313 TENS.DTE 5728.000 MTEM.DTE 154.125 MRES.OTE 0.495 HTEN.DTE -1391.000 OT.LSS 79.875 OTL.LSS 79.625 TT1.LSS 945.000 TT2.LSS 798.000 TT3.LSS 1102.000 TT4.LSS 951.500 SP.LSS -86.000 GR.LSS 64.313 TENS.LSS 5728.000 MTEM.LSS 154.125 MRES.LSS 0.495 HTEN.LSS -1391.000 DPHI.LDT 13.268 RHOB.LDT 2.431 DRHO.LDT 0.086 PEF.LOT 3.111 QLS.LDT -0.009 QSS.LDT 0.033 LS.LOT 336.000 LU.LDT 316.750 LL.LDT 177.625 LITH.LDT 77.438 SS1-LDT 230.750 SS2.LDT 315.750 LSHV.LDT 1478.000 SSHV.LDT 1572.000 SIRH.LDT 2.150 LSRH.LDT 2.332 LURH.LDT 2.334 CALI.LDT 15.086 GR.LDT 71.563 TENS.LOT 5460.000 MTEM.LDT 161.250 MRES.LDT 0.3¢9 HTEN.LDT 985.000 NPHI.CNL 31.190 TNPH.CNL 31.444 TNRA.CNL 3.114 NPOR.CNL 34.594 RCNT.CNL 2583.342 RCFT.CNL 890.358 CNTC.CNL 2549.791 CFTC.CNL 837.520 GR.CNL 71.563 CALI.CNL 15.086 TENS.CNL 5460.000 MRES.CNL 0.349 MTEM.CNL 161.250 HTEN.CNL 985.000 DEPT. 9300.000 SFLU.DTE 14.711 ILM.DTE 10.031 ILO.OTE 10.367 SP.DTE -81.688 IDPH.DTE 10.586 IMPH.DTE 9.844 IFRE.DTE ZO.O00 CIDP.DTE 94.375 CIMP.DTE 101.500 IIRD.DTE 83.938 IIXD.DTE 5.730 IIRM.DTE 94.313 GR.DTE 85.938 TENS.DTE 5404.000 MTEM.DTE 153.750 MRES.DTE 0.540 HTEN.DTE -1391.000 DT.LSS 78.125 DTL.LSS 80.000 TT1.LSS 1106.000 TTZ.LSS 888.000 TT3.LSS 1290.000 TT4.LSS 1116.000 SPoLSS -81.688 GR.LSS 85.938 TENS.LSS 5404.000 MTEM.LSS 153.750 MRES.LSS 0.540 HTEN.LSS -1391.000 DPHI.LDT 26.393 RHOS,.LDT 2.215 DRHO.LDT 0.079 PEF.LOT 2.230 QLS.LDT -0.026 QSS.LDT 0.027 LSoLDT 486.000 LU.LDT 450.250 LL.LDT 260.750 LITH.LDT 123.688 SS1.LOT 239.625 SS2.LDT 344.500 LSHV.LDT 1475.000 SSHV.LOT 15'72.000 SIRH.LDT 1.955 LSRH.LDT 2.125 LURH.LDT 2.119 CALI'LDT 20.531 GR.LDT 97.063 TENS.LOT 5444.000 MTEM.LDT 160.375 MRES.LDT 0.339 HTEN.LDT 969.000 NPHIoCNL 39.772 TNPH.CNL 37.177 TNRA,.CNL 3.750 NPOR.CNL 38.945 RCNT.CNL 2375.281 RCFT.CNL 626.311 CNTC.CNL 2255.987 CFTC.CNL 636.494 GR.CNL 97°063 CALI.CNL 20.5'31 TENS.CNL 5444.000 MRES.CNL 0.339 MTEM.CNL 160.375 HTEN.CNL 969.000 DEPT. 9200.000 SFLU.DTE 12.234 ILM. DTE 12.344 ILD.DTE 10.930 SP.DTE -94.438 IDPH.DTE 11.477 IMPH.DTE 13.047 IFRE.DTE ZO.OOO CIDP.DTE 87.125 CIMP.DTE 76.625 IIRD.DTE 80.563 IIXO.DTE 7.633 IIRM. DTE 76.750 GR.DTE 74.125 TENS.DTE 5332.000 MTEM.DTE 153.750 MRES.DTE 0.540 HTEN.DTE -1391.000 DT.LSS 75.375 OTL.LSS 74.625 TT1.LSS 941.000 TT2.LSS 797'000 TT3.LSS 1114.000 TT4.LSS 945.000 SP.LSS -94.438 GR.LSS 74.125 TENS.LSS 5332.000 MTEM.LSS 153.750 MRES.LSS 0.540 HTEN:.LSS -1391.000 OPHI.LOT 10.315 RHOB.LDT 2.480 DRHD.LDT 0.168 PEF.LDT 3.398 QLS.LDT -0.007 QSS.LDT 0.035 LS.LDT 356.750 LU.LOT 334.750 LL.LDT 189.500 LITH.LDT 86.563 SS1.LDT 254.125 SS2.LDT 34,4.750 LSHV.LDT 1475.000 SSHV.LDT 1571.000 SiRH. LDT 1.979 LSRH.LOT 2.299 LURH.LOT 2.299 CALI.LDT 17.469 GR.LDT 78.563 TENS.LOT 5352.000 MTEM.LDT 160.375 MRES.LDT 0.401 HTEN. LDT 941.000 NPHI.CNL 24.515 TNPH.CNL 23.,435 TNRA.CNL 2.731 NPOR.CNL 24.105 RCNT.CNL 3287.017 RCFT.CNL 1181'887 CNTC.CNL 3062.211 CFTC.CNL 1183.961 GR.CNL 78.563 CALI.CNL 17.469 TENS.CNL 5352.000 MRES.CNL 0.401 -MTEM.CN!L 160.375 HTEN.CNL 941.000 IS TAPE VERIFICATION LISTING CHLUMBERGER aLASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 12 DEPT. 9100.000 SFLU.DTE 13.586 ILM.DTE 11.461 ILD.DTE SP.DTE -114.125 IDPH.DTE 12.297 IMPH.DTE 11.844 IFRE.OTE CIDP.DTE 81.250 CIMP.DTE 84.375 IIRD. DTE 76.063 IIXD.DTE IIRM.OTE 82.625 GR.DTE 62.469 TENS.DTE 5368.000 MTEM. DTE MRES.DTE 0.543 HTEN.DTE -1392.000 OT.LSS 73.000 DTL.LSS TT1.LSS 890.500 TT2.LSS 760.000 TT3.LSS 1062.000 TT4.LSS SP.LSS -114.125 GR.LSS 62.469 TENS.LSS 5368.000 MTEM.LSS MRES.LSS 0.543 HTEN.LSS -1392.000 DPHI.LDT 12.762 RHOS.LDT DRHO.LDT 0.082 PEF.LDT 3. 188 QLS.LDT -0.037 CiSS. LOT LS.LDT 329.000 LU.LDT 316.750 LL.LDT 170.500 LITH.LDT SS1.LDT 229.000 SS2.LDT 317.750 LSHV.LDT 1474.000 SSHV.LDT SIRH.LDT 2. 170 LSRH.LDT 2.346 LURH.LOT 2.334 CALI.LDT GR.LDT 68.500 TENS.LOT 5384.000 MTEM.LOT 158.875 MRES.LDT HTEN.LOT 995.500 NPHI.CNL 24.513 TNPH.CNL 25.218 TNRA.CNL NPOR.CNL 26.731 RCNT.CNL 2819.905 RCFT.CNL 1013.660 CNTC.CNL CFTC.CNL 1015.842 GR.CNL 68.500 CALI.CNL 15.398 TENS.CNL MRES.CNL 0.405 MTEM.CNL 158.875 HTEN.CNL 995.500 DEPT. 9000.000 SFLU.DTE 25.094 ILM.DTE 11.992 ILD.DTE SP.OTE -80.688 ICPH.DTE 14. 508 IMPH.DTE 12.406 IFRE.DTE CIDP.DTE 68.875 CIMP. DTE 80.563 IIRD.OTE 63.031 IIXD.DTE IIRM. OTE 79.000 GR.DTE 86.313 TENS.DTE 5220.000 MTEM-DTE MRES.DTE 0.546 HTEN.D'TE -1392.000 DT.LSS 82.000 OTL.LSS TT1.LSS 1168.000 TT2.LSS 986.000 TT3.LSS 1338.000 TT4.LSS SP.LSS -80.658 GR.LSS 86.313 TENS.LSS 5220.000 MTEM.LSS MRES.LSS 0.546 HTEN.LSS -139Z.000 DPHI-LDT 8.756 RHDB.LDT DRHO.LDT 0.080 PEF.LDT 3.670 QLS'LOT -0.017 OSS.LDT LS.LDT 293.750 LU.LDT 282.000 LL.LDT 152.875 LITH.LDT SS1.LOT 224.750 SS2.LOT 309.250 LSHV.LDT 1475.000 SSHV.LDT S1RH.LDT 2.242 LSRH.LOT 2.414 LURH.LOT 2.408 CALI.LDT GR.LDT 96.750 TENS.LOT 5344.000 MTEM.LDT 15.8.625 MRES.LDT HTEN.LOT 1028.000 NPHI.CNL 26.077 TNPH.CNL 27.863 TNRA.CNL NPOR.CNL 26.469 RCNT.CNL 3352.270 RCFT.CNL 1056.636 CNTC.CNL CFTC.CNL 1027.159 GR.CNL 96.750 CALI.CNL 16.813 TENS.CN:L MRES.CNL 0.407 MTEM.CNL 158.625 HTEN.CNL IOZB.O00 DEPT. 8900.000 SFLU.DTE 9.883 ILM'DTE 7.508 ILD.OTE SP.DTE -143.625 IDPH.OTE 6.652 IMPH.DTE 7.543 IFRE.DTE CI:DP.DTE 150.250 CIMP.DTE 132.500 IIRD.DTE 131.000 IIXO.DTE IIRM.DTE 125.813 GR.OTE 45.406 TENS.DTE 5264.000 MTEM.DTE MRES.DTE 0.537 HTEN.DTE -1393.000 DT.LSS 76.375 DTL.LSS TT1.LSS 96.8.000 TT2.LSS ,BO5.000 TT3.LSS 1116'000 TT4.LSS SP.LSS -143.625 GR.LSS 45'406 TENS.LSS 5264.000 MTEM.LSS MRES.LSS 0.537 HTEN.LSS -1393.000 DPHI.LDT 13.308 RHOB.LDT DRHO.LDT 0.054 PEF.LDT 2.94I QLS.LDT -0.005 QSS.LDT LS.LDT 320.750 LU.LDT 302.473 LL.LDT 169.516 LITH.LDT SSi.LDT 221.070 SS2.LDT 306.750 LSHV.LDT 1475.000 SSHV. LOT SIRH.LDT 2.237 LSRH.LDT 2.365 LURH.LDT 2.362 CALI.LDT GR.LOT 44.934 TENS.LOT 5153.781 MTEM. LDT 158.250 MRES.LDT HTEN.LDT 907.000 NPHI.CNL 18.320 TNPH.CNL 20.151 TNRA.CNL NPOR.CNL 19.672 RCNT.CNL 4036.000 RCFT.CNL 1672.250 CNTC.CNL CFTC.CNL 1649.625 GR.CNL 44.934 CALI.CNL 12.222 TENS.CNL MRES.CNL 0.398 MTEM.CNL 158.250 HTENoCNL 907.000 11.742 20.000 6.086 153.250 71.750 895.500 153.250 2.439 0.021 75.688 1570.000 15.398 0.405 2.677 2689.173 5384.000 13.969 20.000 4.949 152.875 81.250 1219.000 152.875 2.506 0.018 68.438 1570.000 16.813 2.818 2941.563 5344.000 6.555 20.000 12.523 152.500 76.500 970.500 152.500 2.430 0.022 86.027 1569.889 12.222 0.398: 2.181 3622.625 5153.781 ~IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 8800.000 SFLU.DTE SP.DTE -86.000 IDPH.DTE CIDP.DTE 71.938 CIMP.DTE IIRM.DTE 80.625 GR.DTE MRES.DTE 0.543 HTEN.OTE TT1.LSS 914.000 TTZ.LSS SP.LSS -86.000 GR.LSS MRES.LSS 0.543 HTEN.LSS DRHO.LDT 0.101 PEF.LDT LS.LDT 304.500 LU.LDT SS1.LDT 231.375 SS2.LDT SIRH.LDT 2.182 LSRH.LDT GR.LDT 87.000 TENS.LDT HTEN.LDT 964.500 NPHI.CNL NPOR.CNL 26.644 RCNT.CNL CFTCoCNL 996.913 GR.CNL MRES.CNL 0.410 MTEM.CNL DEPT. 8700.000 SFLU.DTE SP.OTE -138.250 IDPH.§TE CIDP.DTE 53.688 CIMP.DTE IIRM.DTE 57.781 GR.DTE MRES..OTE O. 543 HTEN.OTE TT1.LSS 967. 500 TT2.LSS SP.LSS -138. 250 GR.LSS MRES.LSS 0.543 HTEN.LSS DRHO.LDT 0.066 PEF.LDT LS.LDT 1.322.750 LU.LDT SS1.LOT 224. 125 SSZ.LDT SIRH.LDT 2.213 LSRH.LDT GR.LDT 47.219 TENS.LOT HTEN.LDT 934.500 NPHI.CNL NPORoCNL 16.635 RCNT.CNL CFTC.CNL 1'948.757 GR.CNL MRES.CNL 0.408 MTEM.CNL DEPT. 8600.000 SFLU.DTE SP.OTE -126.375 IDPH.D'TE CIDP.DTE 94-500 CIMP.OTE IIRM.DTE 99.750 GR.DTE MRES.DTE 0.549 HTEN.DTE TT1.LSS 1007. 500 TTZ.LSS SP.LSS -126.375 GR.LSS MRES.LSS 0.549 HTEN.LSS DRHO.LDT 0.11.35 PEF.LOT LS.LOT 313. 000 LU.LDT SS1.LDT 24'1 "000 SSZ.LDT SIRH.LDT 2.109 LSRH.LOT GRoLDT 72.000 TENS.LOT HTEN.LDT 920.500 NPHI.CNL NPOR.CNL 27°140 RCNT.CNL CFTC.CNL 911.665 GR.CNL MRES.CNL 0.409 MTEMoCNL 29'-JUN-1989 16:27 12.352 ILM.DTE 13.883 IMPH.DTE 83.563 IIRD.OTE 76.813 TENS.DTE -1393.000 DT.LSS 752.500 TT3.LSS 76.813 TENS.LSS -1393.000 DPHI.LDT 3.424 QLS.LDT 295.000 LL.LOT 317.750 LSHV.LDT 2.391 LURH.LDT 5140.000 MTEM.LDT 26.363 TNPH.CNL 3075.041 RCFT.CNL 87.000 CALI.CNL 157.625 HTEN.CNL 14.031 ILM.DTE 18.609 IMPH.DTE 62.188 IIRD. DTE 46.875 TENS.OTE -1,394.000 OT.LSS 810.500 TT3.LSS 46.875 TENS.LSS -1394.000 DPHI.LDT 2-768 QLS.LDT 304.750 LL.LDT 311.500 LSHV.LOT 2.361 LURH.LDT 5052.000 MTEM.LDT 15.239 TNPH.CNL 4420.208 RCFT.CNL 47.219 CALI.CNL 157.250 HTEN.CNL 9.906 ILM'DTE 10'570 IMPH. DTE 100.000 IIRD.DTE 73.688 TENS.DTE -1394.000 OT.LSS 855.500 TT3.LSS 73.688 TENS.LSS -1394.000 OPHI.LDT 3.262 QLS.LOT 297.500 LL.LDT 328.000 LSHV.LOT 2.3T7 LURH.LDT 4964.000 MTEM. LDT 26.041 TNPH.CNL 2879.625 RCFT.CNL 72. 000 CALI.CNL 156.750 HTEN.CNL 11.742 11.961 68.000 5132.000 77.750 1073.000 5132.000 8.839 -0.035 157.000 1474.000 2.379 157.625 26.536 1033.593 18.656 964.500 16.422 16.063 50.438 5072.000 74.250 1130.000 5072.000 12.792 -0.007 170.250 2.357 157.250 17.381 2055.333 934.500 9.484 9.992 85.125 4948.000 80.125 1162.000 4948.000 7.541 -0.009 164.125 1473.000 2.375 156.750 28.409 927.730 13.172 920°500 ILD.DTE IFRE.DTE IIXD.OTE MTEM. DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LOT QSS.LOT 'LITH.LDT SSHV.LDT CALI .LOT MAES .LOT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOS.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LOT TNRA.CNL CNTC .CNL TENS.CNL ILO.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTLoLSS TT4.LSS MTEM.LSS R HO B. LO T OSS .LDT :LITH.LDT SSHV.LDT CALI.LDT MRES.LOT TNRA.CNL CNTC.CNL TENS.CNL PAGE: 13 13.289 20.000 5.934 152.250 77.250 918.000 152.250 2.504 0.021 67.625 1570.000 18.656 0.410 2.886 2815.233 5140.000 18.000 20.000 3.395 151.875 74'375 970.000 151.875 2.439 0.020 86.500 1569.000 12.484 0.408 1.982 3924.688 5052.000 10.305 20.000 6.223 151.375 79.375 1003.500 151.375 2.526 0.025' 78.875 1568.000 13.172 0.409 2.720 2536.974 4964-000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 8500.000 SFLU.OTE SP.DTE -88.625 IOPH.DTE C[DP.DTE 93.563 CINP.DTE IIRM.DTE 95.438 GR.DTE MRES.DTE 0.548 HTEN.DTE TT1.LSS 1002. 000 TT2.LSS SP.LSS -88.625 GR.LSS MRES.LSS 0.548 HTEN.LSS DRHO.LOT 0.066 PEF.LOT LS.LOT 336.500 LU.LDT SS1.LOT 225.500 SSZ.LOT SIRH.LOT 2.188 LSRH.LDT GR.LDT 82.750 TENS.LOT HTEN.LDT 924.000 NPH[.CNL NPOR.CNL 27.215 RCNT.CNL CFTC.CNL 894.8 86 GR.CNL MRES.CNL 0.421 MTEM.CNL DEPT. 8400.000 SFLU.DTE SP.DTE -113.125 IDPH.DTE CIOP.DTE 114.750 CIMP.DTE IIRM. OTE 123. 063 GR.DTE MRES.OTE 0.564 MTEN.DTE TT1.LSS 969. 000 TT2.LSS SP.LSS -113.125 GR.LSS MRES.LSS O. 564 HTEN.LSS DRHO.LDT O. 0 99 PEF.LDT LS.LDT 338.000 LUoLOT SS1.LDT 234.375 SS2.LOT $1RH.LOT 2.125 LSRH.LDT GR.LDT 92.125 TENS.LDT HTEN.LOT 958.500 NPHI.CNL NPOR.CNL 27.356 RCNT.CNL CFTC.CNL 904. 874 GR.CNL MRES.CNL 0.428 MTEM.CNL DEP'T. 8300.000 SFLU.DTE SP.DTE -142.750 IDPH.OTE CIOP.DTE 151.250 CIMP.DTE I IRM.DTE 122.125 GR.DTE MRES.OTE 0.550 HTEN.DTE TT1.LSS 993. 000 TTZ.LSS SP.LSS -142.750 GR.LSS MRES.LSS 0.550 HTEN.LSS DRHO.LOT O. 059 PEF.LDT LS.LDT 330.445 LU.LDT SS1.LOT 223. 152 SS2.LDT SIRH.LDT 2.212 LSRH.LDT GR.LDT 40.184 TENS.LOT HTEN.LO'T 909.672 NPHI.CNL NPOR.CNL 18.149 RCNT.CNL CFTC.CNL 1854.313 GR.CNL MRES.CNL 0.415 MTEM.CNL 29-JUN-1989 16:27 11.000 ILM. DTE 10.680 IMPH.DTE 98. 563 IIRD.DTE 81.063 TENS.DTE -1394.000 DT.LSS ~19.500 TT3.LSS 81.063 TENS.LSS -1394.000 DPHI.LOT 2.912 QLS.LDT 317. 500 LL.LDT 316. 500 LSHV.LDT 2.334 LURH.LOT 4920.000 MTEM.LDT 27.332 TNPH.CNL 2659.466 RCFT.CNL 82.750 CALI.CNL 156.250 HTEN.CNL 7.395 ILM.DTE 8.711 IMPH.DTE 129.250 IIRD.DTE 88.313 TENS.DTE -1393.000 DT.LSS gl4.000 TT3.LSS 88.313 TENS.LSS -1393.000 DPHI.LDT 3.367 QLS.LOT 324.250 LL.LDT 321.750 LSHV.LOT 2. 330 LURH.LDT 4.864.000 MTEM.LDT 27.950 TNPH.CNL 2748.062 RCFT.CNL 92.125 CALI.CNL 155. 375 HTEN.CNL 8. 875 ILM.DTE 6.609 IMPH.DTE 126.750 IIRD. DTE 48.688 'TENSoDTE -1395.000 OT.LSS 832.000 TT3.LSS 48.688 TENS.LSS -1395.000 DPHI.LDT 2.308 QLS.LDT 307' 500 LL.LDT 313.750 LSHV.LDT 2.349 LURH.LDT 4805.781 MTEM.LOT 17.947 TNPH. CNL 4402.375 !RCFT.CNL 40.184 CALI.CNL 155.000 HTEN.CNL 9.914 10.141 87.563 5024.000 77.250 1197.000 5024.000 14.421 -0.011 177.750 1472.000 2.332 156.250 26.880 896.539 14.797 924.000 7.676 7.730 102.313 4888.000 74.875 1127.000 4888.000 12.646 -0.035 175.875 1472.000 2.318 15 5.375 27.153 904.335 15.773 958.500 7.730 7.883 134.500 4880.000 80'750 1154.000 4880.000 13.953 0.012 176.791 1472.000 2.352 155.000 18.883 1879.750 1 2.297 909.672 ILD.OTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB .LOT CiSS.LDT L ]:TH. LOT SSHV.LDT CALl .LOT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.OTE MTEM.DTE DTL.LSS TT4 .LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT C~L['LDT ~R E S. LOT TNRA.CNL CNTC .CNL TENS.CNL ILO.DTE IFRE.OTE IIXO.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOS.LDT ,O S S. L O T LI?H. LOT SSHV. LOT CALI .LDT MRES.LDT TNRA.CNL CNTC .CNL TENS.CNL PAGE: 14 10.328 20.000 4.094 151.125 75.875 1001.500 151.125 2.412 0.016 84.625 1568.000 14.797 0.421 2.849 2450.384 4920.000 8.578 20.000 6.859 150.625 74.000 974.500 150.625 2.4.41 0.029 '79.063 1567.000, 15.773 0'428 2.916 2522'449 4864.000 6.523 20.000 12.977 150.000 84.625 999.500 150.000 2.420 0.014 95.201 1567'000 12.297 0.415 2.158 39:15.000 4805.781 ,IS TAPE VERIFICATION LISTING 29-JUN-1989 16:27 ,CHLUMBERGER ALASKA COMPUTING CENTER PAGE: 15 DEPT. 8200.000 SFLU.DTE 50.500 ILM.DTE 13.180 ILO.DTE SP.DTE -106.250 IDPH.DTE 20.875 IMPH.OTE 11.844 IFRE.DTE CIDP.DTE 47.875 CIMP.DTE 84.375 IIRD.DTE 46.78! IIXD.DTE IIRM.DTE 71.875 GR.DTE 50.906 TENS.DTE 4808.000 MTEM.DTE MRES.DTE 0.567 HTEN.DTE -1392.000 DT.LSS 117.250 DTL.LSS TTI.LSS 1204.000 TT2.LSS 961.000 TT3.LSS 1395.000 TT4.LSS SP.LSS -106.250 GR.LSS 50.906 TENS.LSS 4808.000 MTEM.LSS MRES.LSS 0.567 HTEN.LSS -1392.000 DPHI.LOT 56.637 RHOS.LDT DRHO.LDT 0.050 PEF.LDT 1.610 QLS.LDT -0.060 QSS.LDT LS.LDT [075.000 LU.LDT 979.000 LL.LDT 585.500 LITH.LDT SS1.LDT 247.750 SS2.LDT 385.500 LSHV.LDT 1471.000 SSHV.LDT SIRH.LDT 1'540 LSRH.LDT [.660 LURH.LDT 1.650 CALI.LDT GR.LDT 52.969 TENS.LOT 4692.000 MTEM.LDT 154.500 MRES.LDT HTEN.LDT 923.000 NPHI.CNL 63.896 TNPH.CNL 85.433 TNRA.CNL NPOR.CNL 92.442 RCNT.CNL 1641.161 RCFT.CNL 323.583 CNTC.CNL CFTC.CNL 323.077 GR.CNL 52.969 CALI.CNL 17.125 TENS.CNL MRES.CNL 0.429 MTEM.CNL 154. 500 HTEN.CNL 923.000 DEPT. 8100.000 SFLU.DTE 8.219 ILM. OTE 6.746 ILD.DTE SP.DTE -107.188 IDPH.DTE 6.125 IMPH.OTE 6.766 IFRE.DTE CIDP.DTE 163.250 CIMP.DTE 147.750 IIRD. DTE 143.375 IIXO.OTE IIRM.DTE 139.750 GR.DTE 54.063 TENS.OTE 4788.000 MTEM.DTE MRES.DTE 0.567 HTEN.DTE -1395.000 DT.LSS 82'500 DTL.LSS TT1.LSS 1077.000 TT2.LSS 845.000 TT3.LSS 1183.000 TT4.LSS SP.LSS -107.188 GR.LSS 54.063 TENS.LSS 4788.000 MTEM.LSS MRES.LSS 0.567 HTEN.LSS -1395.000 DPHI.LDT 11.855 RHOB.LDT DRHO.LDT 0.079 PEF.LDT 2.81'1 QLS.LOT -0.017 QSS'LDT LS.LO'T 321.000 LU.LDT 305.500 LL.LDT 168..250 LITH.LDT SS1.LOT 227.375 SSI.LOT 315. 250 LSHV.LDT 1471.000 SSHV.LDT SIRH.LDT 2.191 LSRH.LDT 2.363 LURH.LDT 2.357 CRLI.LOT GR.LDT 52.219 TENS.LOT 4668.000 MTEM.LDT 153.625 MRES.LDT HTEN.LDT 931.000 NPHI.CNL 23,.713 TNPH.CNL 24.049 TNRA. CNL NPOR.CNL 24.080 RCNT.CNL 3741.135 R:CFT.CNL 1374.215 CNTC.CNL CFTC.CNL 1386.670 GR.CNL 52-219 CALI.CNL 12.367 TENS.CNL MRES.CNL 0.435 MTEM.CNL 153.625 HTEN.CNL 931.000 DEPT. 8000.000 SFLU.DTE 10.258 ILM.OTE 8.227 ILO.DTE SP.DTE -135.125 IDPH.DTE 7.027 IMPH.DTE 8.305 IFRE.DTE CIDP.DTE 142.125 CIMP.DTE I20.313 IIRD.DTE 122.938 IIXD.DTE IIRM. DTE 114.813 GR.DTE 39.438 TENS.DTE 4952.000 MTEM.OTE MRES.DTE 0.576 HTEN.DTE -1393.000 DT.LSS 78'875 DTL.LSS TT1.LSS 984.000 TT2.LSS 836'000 TT3.LSS 1133'000 TT4-LSS SP.LSS -135.125 GR.LS.S 39.438 TENS.LSS 4952-000 MTEN. LSS MRES.iLSS 0.576 HTEN.LSS -1393.000 DPHI.LDT 13.441 RHOB.LDT DRHO.LDT 0.063 PEF.LDT 2. 551 QLS.LDT 0.003 QSS.LDT LS.LDT 327.000 LU.LDT 306.500 LL.LDT 173.750 LITH.LDT SSI.LOT 223.875 SS2.LDT 309.Z50 LSHV'LDT 1470'000 SSHV.LDT SIRH.LOT 2.211 LSRH.LDT 2. 354 LURH.LOT 2. 355 CALI. LOT GR.LOT 137.688 TENS.LOT 4608,.000 MTEM. LOT 153.000 MRES.LOT HTEN.LDT 936. 000 NPHI.CNL 16.476 TNPH.CNL 17.997 TNRA. C~NL NPOR.CNL 16.400 RCNT.CNL 4654. 557 RCFT.CNL 2007.176 CNTC.CNL CFTC.CNL 1950.685 GR.CNL 37.688 CALI.CNL 12.406 TENS.CNL MRES.CNL 0.443 MTEM.CNL 153.000 HTEN.CNL 936.000 19.656 20.000 0.119 150.000 119.750 1207.000 150.000 1.715 0.033 391.25'0 1566.000 17.125 0.429 4.979 1624.858 4692.000 6.063 20.000 13.375 149.375 81.875 1016:.500 149.375 2.454 O.OZO 82.063 1567.000 12.367 0.435 2.544 3417.711 4668.000 6.969 20.000 12.242 149'000: 78-875 9'95.50'0 149.000 2.428 0.025 88.063 1565'000 12-406 0.443 2.062 4006'350 4608.000 ,IS TAPE VERIFICATION LISTING ~CHLUMBERGER aLASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 16 DEPT. 7900.000 SFLU.DTE SP. DTE -121.188 IDPH.DTE CIDP.OTE 104.188 CIMP.DTE IIRM.DTE 117. 313 GR.OTE MRES.DTE 0.572 HTEN.DTE TTI.LSS 961.000 TT2.LSS SP.LSS -121.188 GR.LSS MRES.LSS O. 572 HTEN.LSS DRHO.LDT 0.135 PEF.LDT LS.LDT 298.250 LU.LDT SS1.LDT 239.250 SS2.LOT SiRHoLDT 2.139 LSRH.LOT GR.LDT 95.625 TENS.LOT HTEN.LDT 920.500 NPHI.CNL NPOR.CNL 22.665 RCNT.CNL CFTC.CNL 1088' 416 GR.CNL MRES.CNL 0.440 MTEM.CNL DEPT. 7800.000 SFLU.BTE SP.DTE -110.625 IDPH. D'TE CIDP.DTE 115.188 CIMP.DTE IIRM. DTE 123- 875 GR. DTE MRES.DTE 0.575 HTEN.DTE TT1.LSS I017. 500 TT2.LSS SP.LSS -110.625 GR.LSS MRES.LSS OD 5'75 HTEN.LSS ORHO.LDT O- 105 PEF.LDT :LS.LOT 324.641 LU.LDT SS1.LDT 234. 375 SS2.LDT SIRH.LDT 2. 140 LSRH.LDT GR.LDT 80.723 TENS.EDT HTEN.LDT 918.000 NPHI.CNL NPOR.CNL 31.735 R:CNT.CNL CFTC.CNL 696. 250 GR.CNL MRES.CNL 0.444 MTEM.CNL DEPT. '7700.000 SFLU.OTE SP.OTE -120.938 IOPH.DTE CIOP.DTE 79.438 CIMP.DTE IIRM. OTE 71.188 GR.DTE MRES.DTE 0.575 HTEN.DTE TT1.LSS 990.500 TT2.LSS SP.LSS -120-938 GR.LSS MRES.LSS 0.575 HTEN.LSS ORHO.LOT 0.040 PEF.LDT LS.LDT 292.500 LU.LOT SS1.LDT 214.750 SS2.LDT SIRH.LDT 2.316 LSRH.LDT GR.LDT 42.656 TENS.LDT HTEN.LDT 980.500 NPHI.CNL NPOR.CNL 17.603 RCNT.CNL CFTC.CNL 1598.'760 GR.CNL MRES.CNL 0.441 MTEM.CNL 8.063 ILM.DTE 9.594 IMPH.DTE 126.063 IIRD.DTE 86.500 TENS.DTE -1396.000 DT.LSS 795.500 TT3.LSS 86.500 TENS.LSS -1396.000 DPHI.LDT 3.133 QLS.LDT 288.500 LL.LDT 319.750 LSHV.LDT 2.404 LURH.LOT 4588.000 MTEM.LDT 22.945 TNPH.CNL 3404.538 RCFT.CNL 95.625 CALI.CNL 152.125 HTEN.CNL 6.563 ILM.DTE 8.680 IMPH.DTE 136.000 TIRD. DTE 74.625 TENS.OTE -1396.000 DT.LSS 851.500 TT3.LSS 74.625 TENS.LSS -1396.000 DPHI.LDT 3.465 QLS.LDT 306.211 LL.LDT 330.141 LSHV.LOT 2.355 LURH.LDT 4468.000 MTEM.LOT ' 30.685 TNPH.CNL 2342.000 RCFT.CNL 80.723 CALI.CNL 151.446 HTEN.CNL 1'5.016 ILM.DTE 12.578 IMPH.DTE 71.688 IIRD.OTE 41.875 TENS.DTE -'1 '397. 000 DT. L SS ~43.500 TT3.LSS 41.875 TENS.ESS -1397.000 DPHI.LDT 2. 594 QLS.LDT 278,,, 500 LL.LOT 295.000 LSHV.LDT 2'418 LURH.LOT 4472.000 MTEM.LDT 17.449 TNPH.CNL 3687.091 RCFT.CNL 42.656 CALI.CNL 150.750 HTEN.CNL 8.055 7.930 93.313 4728.000 79.625 1130.000 4728.000 5.915 -0.029 154.000 1470.000 2.395 152.125 24.066 1146.583 22.547 920.500 7.621 7.348 103.000 4604.000 82.250 llBZ.O00 4604.000 10.81'7 -0.004 171.535 1470.000 2.355 151.446 31.259 709.750 17.661 918.000 13.313 13.938 75.875 4500.000 77.875 1144.000 4500.000 10. 874 -0.005 153.250 1469.000 2.416 150.750 17.866 164'3.859 13.539 980. 500 ILO.DTE IFRE.DTE IIXD. DTE MTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB .LDT QSS.LDT LITH.LDT SSHV.LDT CALI .LOT MRES.LOT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHD8 .LOT QS S. LDT LITH.LDT SSHV.LDT CALI .LDT MRES.LDT TNRA.CNL CNTC;.CNL TENS.CNL ILD.OTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHO~B. LOT QSS.LDT EITH.LDT SSHV.LDT CALI.LDT MRES.LDT rTNRA.CNL CNTC.CNL TENS.CNL 9.414 20.000 5.492 148.000 79.500 966.500 148.000 2.552 0.034 71.813 1565.000 22.547 0.440 2.760 2975.466 4588.000 8.555 20.000 9.945 148.000 83.000 1022.500 148.000 2.472 0.006 77.836 1564.571 17.661 0.4,44 3. 148 2163.563 4468. 000 12.203 20.000 3.775 147.125 77.875 990. 500 147'125 2.471 O.OZZ 75.813 1564.000 13.539 0.441 2.157 3333.354 · 4472.0 O0 ,IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 17 DEPT. 7600.000 SFLU.DTE SP.DTE -123.875 IDPH.DTE CIDP.DTE 137.625 CIMP.DTE I IRM. DTE 109. 313 GR.DTE MRES. OTE 0.567 HTEN.DTE TT1.LSS 963. 500 TT2.LSS SP.LSS -123.875 GR.LSS MRES.LSS 0.567 HTEN.LSS ORHO.LOT 0.077 PEF.LDT LS.LOT 3Z2.125 LU.LOT SS1.LDT 226. 898 SS2.LDT SIRH.LDT 2.195 LSRH.LDT GR.LDT 39.844 TENS.LOT HTEN.LDT 921. 063 NPHI.CNL NPOR.CNL 17.789 ~CNT.CNL CFTC.CNL 1988.188 GR.CNL MRES.CNL 0.446 MTEM.CNL DEPT. 7500.000 SFLU.OTE SP.DTE -79.188 IDPH.OTE CIDP.OTE 49.531 CIMP.DTE IIRM.OTE 48.969 GR.OTE MRES.DTE 0.567 HTEN.DTE 'TT1.LSS 1308. 000 TT2.LSS SP.LSS -79. 188 GR.LSS MRES.LSS O. 567 HTEN.LSS DRHO.LOT 0.004 PEF.LDT LS.LDT 1557.000 LU.LDT SS1.LD'T 233.375 SS2.LOT SIRH.LOT 1.427 LSRH.LOT GR.LDT 43.563 TENS.LOT HTEN.LDT 976.500 NPHI.CNL NPOR.CNL 81.766 RCNT.CNL CFTC.CNL 348. 566 GR.CNL MRES.CNL 0.429 MTEM.CNL DEPT. 7400.000 SFLU.DTE SP.DTE -T0.313 IDPH.DTE CIDP.OTE 155.000 CIMP.DTE IIRM. DTE 169.12:5 GR. DTE MRES.OTE 0.570 HTEN.DTE TT1.LSS 1047- 000 TTZ.LSS SP.LSS -70.313 GR.LSS MRES.LSS 0.570 HTEN.LSS DRHO.LDT 0.052 PEF.LDT LS.LDT 282.000 LU.LOT SS1.LDT 216.62:?.5 SS2.LDT $1RH.LDT 2.313 LSRH.LOT GR.LDT 84.063 TENS.LOT HTEN.LDT 949.500 NPHI.CNL NPDR.CNL 36.355 RCNT.CNL CFTC'CNL 707. 729 GR.CNL MRES.CNL 0.433 MTEM.CNL 11.266 ILM.DTE 7.258 IMPH.DTE 111.875 IIRD.OTE 35.781 TENS.DTE -1396.000 DT.LSS 805.000 TT3.LSS 35.781 TENS.LSS -1396.000 DPHI.LDT 2.675 QLS.LOT 301.313 LL.LDT 308.969 LSHV.LDT 2.362: LURH.LDT 4287.293 MTEM.LDT 14.743 TNPH.CNL 4222.750 RCFToCNL 39..844 CALI.CNL 150.169 HTEN.CNL 9696.000 ILM.DTE 20. 188 IMPH.OTE 43.688 IIRD.DTE 40.188 TENS.DTE -.1393.000 DT.LSS 1093.000 TT3.LSS 40.188 TENS.LSS -1393.000 DPHI.LDT 1.945 QLS.LDT 1367. 000 LL.LDT 402.2:50 LSHV.LDT 1.441 LURH.LOT 4400.000 MTEM.LDT 60. 828 TNPH.CNL 1899.770 RCFT.CNL 43. 563 CALI.CNL · 149. 625 HTEN.CNL 5.348 ILM.DTE 6.445 IMPH.DTE 177.625 IIRD.OTE 73.875 TENS.DTE -1394.000 OT.LSS 904. 000 TT3.ESS 73.875 TENS.LSS -1394.000 OPHI.LDT 3.572 QLS.LDT 2:73.2:50 LL.LDT :294. 500 LSHV.LOT 2.436 LURH.LOT 4r272'000 MTEM'LDT 37'767 TNPH'CNL 2503.588 RCFT.CNL 84. 063 CALI.CNL 149.125 HTEN.CNL 8.648 B.g30 121.625 4448.000 80.500 1122.000 4448.000 11.951 0.009 171.594 1469.823 2.365 150.169 17.105 1983.875 12.258 921.063 19.391 22.875 55.875 4420.000 123.500 1502. 000 4420.000 72.829 -0.038 874.000 1467.000 1.457 14 9.6,25 81. 586 '37 5.,449 21. 672 976.500 5.566 5. 629 139.375 4324. 000 89.500 1226.000 4324.000 9.028 -0.026 145.375 1468.000 2.430 149.125 35.262 699.320 15.906 949.500 ILO.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4 .LSS MTEM.LSS RHOB.LDT DSS .LOT LITH.LDT SSHV.LDT CALI.LDT MRES .LOT TNRA.CNL CNTC.CNL TENS.CNL ILO.OTE IFRE.DTE IIXD.OTE MTEM.DTE DTL.LSS TT4 .LSS MTEM.LSS RHD8 .LOT QSS.LDT LITH.LDT SSHV.LDT CALI .LOT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILO. D'TE IFRE.DTE IIXO.DTE MTEM'DTE DT'L.LSS TT4.LSS MTEM.LSS RHOB.LOT QSS.LDT LITH.LDT SSHV.LDT CALI. LOT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL 7.172 20.000 7.402 146.625 80.50O 961.000 146.625 2.453 0.034 89.883 1563.823 12.258 0.446 1.943 3949.813 4287.293 17.547 ZO.O00 0.000 146.125 120.750 1314.000 146.125 1.448 -0-011 575.500 1563.000 21.672 0.429 4.930 1737.780 4400.000 6.227 20.000 9.898 145.875 90.250 1058. 000 ' 1,45. 875 2.501 0.027 61.625 1562.000 15.906 0.433 3.519 2344.482 4272.000 IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 18 DEPT. 7300.000 SP.DTE -76.625 CI~,P.OTE 161.125 IIRM.DTE 166.500 MRES.DTE 0.575 TT1.LSS 1070.000 SP.LSS -76.625 MRES.LSS 0.575 DRHO.LDT 0.098 LS.LDT 393.250 SS1.LDT 238.625 SIRH.LOT 2.041 GR.LDT 91.250 HTEN.LDT 986.500 NPOR.CNL 35.028 CFTC.CNL 693.413 MRES.CNL 0.443 DEPT. 7200.000 SP.DTE -81.313 CIDP.DTE 90.813 IIRM.DTE 88.813 MRES.DTE 0.583 TT1.LSS 1204.000 SP.LSS -81.313 MRES.LSS 0.583 DRHO.LOT O. 020 'LS.LDT 667.8 59 SSI'LOT 231.893 S1RH.LOT 1.877 GR.LDT 75.012 HTEN.LDT 917.0 72 NPOR.CNL 49.207 CFTC.CNL 492. 813 MRES.CNL 0.444 DEPT. 7100.000 SP.DTE .-93,750 CIDP.DTE 116,750 IIRM.DTE 91.625 MRESoDTE 0.582 TT1.LSS 1044'000 SP.LSS -93.750 MRES.LSS 0.582 DRHO.LDT 0.094 LS.LDT 296'500 SS1.LDT 228.250 SIRH.LDT 2.215 GR.LDT 41-2B1 HTEN.LD'T 911.500 NPOR.CNL 14.926 CFTC.CNL 2269.572 MRES.CNL 0.448 SFLU.DTE 6.109 ILM. DTE IDPH.DTE 6.203 IMPH.DTE CIMP.DTE 175.000 IIRD.DTE GR-.DTE 80.313 TENS.DTE HTEN.DTE -1397.000 DT.LSS TT2.LSS 874.500 TT3.LSS GR.LSS 80.313 TENS.LSS HTEN.LSS -1397.000 DPHI.LDT PEF.LOT 3.234 QLS.LDT LU.LDT 373.250 LL.LDT SS2.LOT 336.250 LSHV.LOT LSRH.LDT 2.244 LURH.LDT TENS.LOT 4240.000 MTEM.LOT NPHI.CNL 34.788 TNPH.CNL RCNT.CNL 2~25.020 RCFT.CNL GR.CNL 91. 250 CALI.CNL MTEM.CNL 148.Z50 HTEN.CNL SFLU.DTE 18'344 ILM.OTE IDPH.DTE 11.000 IMPH.DTE CIMP.DTE 86.000 IIRD.OTE GR.DTE 68.000 TENS.OTE HTEN.DTE -1392.000 DT.LSS TT2.LSS 1010.000 TT3.LSS GR.LSS 68.000 TENS.LSS HTEN.LSS -1392.000 OPHI.LOT PEF.LDT 2.145 QLS.LOT LU.LDT ~$03.643 LL.LDT SS2.LOT 349.820 LSHV.LDT LSRH.LDT 1.947 LURH.LOT TENS.LOT 4129.719 MTEM.LOT NPHI.CNL 48.187 TNPH.CNL RCNT.CNL 1961.500 RCFT.CNL GR.CNL 75.012 CALI.CNL MTEM.CNL 147.625 HTEN.CNL SFLU.DTE 14.922 ILM.DTE IDPH.DTE 8'563 IMPH.DTE CIMP.DTE 94.500 IIRD. DTE GR.DTE 38.125 TENS.DTE HTEN.DTE -1398.000 DT.LSS TT2.LSS 867.500 TT3oLSS GR.~LSS 38.125 TENS.LSS HTEN.LSS -1398.000 DPHI.LDT PEF.LOT 2.900 QLS.LDT LU.LDT 279.000 LL.LOT SS2.LOT 313.250 LSflV.LOT LSRHoLDT 2.412 LURH.LDT TENS.LOT 4090.000 MTEM.LDT NPHI.CNL 14'145 TNPH.CNL RCNT.CNL 4545.015 RCFT.CNL GR.CNL 41.281 CALI.CNL MTEM.CNL I4T.O00 HTEN.CNL 5.65Z 5.711 142.500 4288.000 85.500 1264.000 4288.000 17.915 -0.037 206.625 1468.000 2.230 148.250 34.344 746.046 15.586 986.500 10.656 11.625 85.000 4184.000 112.125 1398.000 4184.000 40.887 -0.024 365.785 1466.000 1.941 147.625 45.660 478,625 13.686 917..072 10,.328 10.570 109.000 4148.000 74.500 1225.000 4148.000 8.026 0.013 157.125 1467.000 2.416 147.000 14.851 2451.426 12.391 911.500 ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.OTE IIXD.OTE MTEM.OTE OTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LOT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILO.DTE IFRE.DTE IIXD.DTE MTEM. DTE OTL.LSS TT4.LSS MTEM.LSS RHOB.LD'T QSS.LDT LITH.LDT SSHV'LOT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL 6.105 20.000 9.352 145.250 84.000 1066.000 145.250 2.354 0.023 101.938 1562.000 15.586 0.443 3.348 2249.998 4240.000 10.734 20.000 4.535 144.B75 111.750 1200.000 144.875 1.975 0.022 228.922 1561.286 13.686 0.444 4.030 1906.750 4129-719 8.406 20.000 11.391 144.375 74.250 1049.000 144.375 2.51.8 0.019 79.125 1561.000 12.391 0.448 1.907 4160.464 4090.000 ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 7000.000 SFLU.OTE SP.DTE -87.188 IDPH.DTE CIDP.DTE 189.875 CIMP.DTE I IRM.OTE 197.125 GR.DTE MRES.DTE 0.581 HTEN.DTE TT1.LSS 1063. 000 . TT2.LSS SP.LSS -87.188 GR.LSS MRES.LSS 0.581 HTEN.LSS DRHD.LDT 0.056 PEF.LDT LS.LDT 316.500 LU.LDT SS1.LOT 221. 125 SS2.LOT SIRH.LOT 2.240 LSRH.LOT GR.LOT 78.563 TENS.LOT HTEN.LOT 914. 500 NPHI.CNL NPOR.CNL 27.394 RCNT.CNL CFTC.CNL 908.060 GR.CNL MRES.CNL 0.450 MTEM.CNL · DEPT. 6900.000 SFLU.DTE SP.DTE -88.250 IOPH.DTE CIDP.DTE 21.359 CIMP.DTE IIRM.DTE 54.438 GR.DTE MRES.DTE 0.581 HTEN.DTE TT1.LSS 1334. 000 TT2.LSS SP.LSS -88.250 GR.LSS MRES.LSS 0.581 HTEN.LSS DRHO.LOT O. 014 PEF.LOT LS.LDT 1852. OOO LU. LOT SS1.LOT 239.000 SS2.LDT SIRH. LDT 1.282 LSRH.LDT GR.LD'T 28.500 TENS.LOT HTEN.LOT 910.500 NPHI.CNL NPOR.CNL 95.634 RCNT.CNL CFTC.CNL 267.637 GR.CNL MRES.CNL 0.450 MTEM.CNL 29-JUN-1989 16:27 4.324 ILM.DTE 5.262 IMPH.DTE 208.125 IIRO.DTE 68.688 TENS.DTE -1398.000 OT.LSS 895.500 TT3.LSS 68.688 TENS.LSS -1398.000 DPHI.LDT 2.980 QLS.LDT 298.500 LL.LOT 307.500 LSHV'LDT 2.371 LURH.LDT 4050.000 MTEM.LOT 27.590 TNPH.CNL 2841.738 RCFT.CNL 78.563 CALI.CNL 146.375 HTEN.CNL 366.750 ILM.DTE 46.781 IMPH.DTE 62.781 IIRD.DTE 28.859 TENS.DTE -1396.000 DT.LSS 1127.000 TT3.LSS 28.859 TENS.LSS -1396.000 DPHI.LDT 2.066 QLS.LDT 1660.000 LL.LDT 415.5'00 LSH¥.LDT 1.340 LURH.LDT 3970.0:00 MTEM.LDT 67.124 TNPH.CNL 1537.301 RCFT.CNL 28o500 CALI.CNL 14,5.875 HTEN. CNL DEPT. 6800.000 SFLU.DTE 45.531 ILM.DTE SP.DTE -66.438 IDPH.DTE 17.125 IMPH.DTE CIDP.OTE 58.344 CIMP.DTE 122.125 IIRD.OTE IIRM. DTE 131.500 GR.DTE 38.125 TENS.DTE MRES.DTE 0.586 HTEN.DTE -1396.000 OT.LSS TT1.LSS 1556.000 TT2.LSS 13:79.000 TT3.LSS SP.LSS -66.438 GR.LSS 38.125 TENS.LSS MRES.LSS 0.586 HTEN.LSS -1396.000 DPHI.LDT DRHO.LDT -0.002 P~F.LOT 3.049 QLS.LDT LS.LDT 1516.000 LU.LDT 1351.000 LL.LDT SS1.LDT 230.125 SSZ.LDT 394.250 LSHV.LDT SIRH.LDT 1.458 LSRH.LOT 1.450 LURH.LOT GR.LDT 32.531 TENS.LOT 3954.000 MTEM.LDT HTEN.LDT 923.000 NPHI.CNL 58.062 TNPH'CNL NPOR.CNL 89.986 RCNT.CNL 1696.371 RCFT.CNL CFTC.CNL 267.148 GR.CNL 32.531 CALI.CNL MRES.CNL 0.458 MTEM.CNL 145.250 HTEN.:CNL 4.766 6.801 166.875 4100.000 87.250 1233.000 4100.000 12.B56 -O.OOZ 167.125 1466.000 2.371 146.375 27.992 909.512 16.719 914.500 17.622 15.922 30.047 4076.000 132.625 1522.000 4074.000 78.618 -0.067 1022.500 1466.000 1.346 145.875 96.525 25,3.489 19.219 91 O. 500 7.172 8.180 56.313 3964.000 152.000 1816.000 3964.000 72.645 -0.056 841.000 1.464 165.250 89.929 286.299 22.953 923.000 ILD.DTE IFRE.DTE IIXO.DTE MTEM.OTE DTL.LSS TT6.LSS MTEM.LSS RHOB.LDT QSS.LOT LITH.LDT SSHV.LDT CALI.LOT MRES.LOT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILO. DTE IFRE.DTE IIXD.OTE MTEM.OTE DTL.LSS TT6.LSS MTEM.LSS RH~B .LOT QSS.LOT LITH.LOT SSHV.LDT CALI.LOT MRES.LDT TNRA.CNL · CNTC. CNL TENS .CNL PAGE: 19 5.164 20.000 11.070 143.750 87.500 '1064.000 143.750 2.438 0.019 77.563 1560.000 16.719 0.450 2.864 2550.697 6050.000 36.719 20.000 0.878 143.250 133.000 1326.000 143.250 1.356 -0.006 674.000 1560.000 19'219 0.4.50 5.210 1389.546 3970.000 15.813 20.000 0.000 143.125 128.500 1555.000 143.125 1.451 -0.008 444.750 1559.000 22.953 0.458 4.813 1364.769 3954.000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 15:27 PAGE: 2O DEPT. 6700.000 SFLU.DTE 6. SP.DTE -89.063 IDPH.DTE 5. CIDP.DTE 183.500 CIMP.DTE 164. IIRM.DTE 159. 125 GR.DTE MRES.DTE 0.583 HTEN.DTE -1392. TT1.LSS 1094. 000 TT2.LSS 909. SP.LSS -89.063 GR.LSS MRES.LSS O. 583 HTEN.LSS -1392. DRHO.LDT 0.030 PEF.LDT LS.LDT 337. 500 LU.LDT 310. SS1.LDT 216.750 SS2.LDT 302. SIRH.LDT 2.248 LSRH.LDT 2. GR.LOT 43.625 TENS.LOT 3890. HTEN.LDT 929. 000 NPHI.CNL 24. NPOR.CNL 24. 607 RCNT.CNL 3358. CFTC.CNL 1178. 608 GR.CNL 43. MRES.CNL 0.450 MTEM.CNL 144. 176 ILM. DTE 445 IMPH.DTE 375 IIRD.DTE 688 TENS.DTE 000 DT.LSS 000 TT3.LSS 688 TENS.LSS 000 DPHI.LDT 809 QLS.LDT 500 LL.LDT 750 LSHV.LDT 334 LURH.LDT 000 MTEM.LOT 288 TNPH.CNL 657 RCFT.CNL 625 CALI.CNL 125 HTEN.CNL DEPT. 6600.000 SFLU.DTE 6.855 SP.OTE -62.156 IBPH.DTE 8.375 CIDP.DTE 119.313 CIMP.DTE 147.625 IIRM.DTE 138.250 GR.DTE 72.250 MRES.DTE 0.583 HTEN.DTE -1397.000 TT1.LSS 1184.000 TTZ.LSS 1021.000 SP.LSS -62.156 GR.LSS 72.250 MRES.LSS 0.583 HTEN.LSS -1397.000 DRHO.LD'T 0.183 PEF.LDT 3.787 LS.LDT 417.250 LU.LDT 391.500 SS1.LDT 262.500 SS2.LDT 364.250 SIRH.LOT 1.867 LSRH.LOT 2.Z07 GR.LDT 64.063 'TENS.LOT 3780.000 HTEN.LDT 895.000 NPHI.CNL 52.421 NPOR.CNL 46.666 RCNT.CNL 1669.793 CFTC.CNL 348.947 GR.CNL 64.063 MRES.CNL 0.449 MTEM.CNL 144.500 DEPT. 6500.000 SFLU.~TE 5.824 SP.DTE -95.000 IDPH.DTE 4.469 CIDPoDTE 223.625 CIMP.DTE 196.375 · IIRM.DTE 186.750 GR.DTH 43.313 MRES.DTE 0.590 HTEN.DTE -1397'000 'TT1.LSS 1130.000 TTZ.LSS 960.000 SP.LSS -95.000 GR.LSS 43.313 MRES.LSS 0.590 HTEN.LSS '-1397.000 DRHO.LDT 0.017 PEF.LOT 2.553 LS.LOT 369.000 LU.LDT 337.000 SS1.LDT 216.250 :SS2.LDT 308.500 SIRH.LD'T 2.221 LSRH.LDT 2.283 GRoLDT 40.813 TENS.LOT 3800'000 HTEN.LDT 911.500 NPHI.CNL 28.834 NPOR.CNL 29.171 RCNT.CNL 2877.165 CFTC.CNL 918.359 GR.CNL 40.$13 MRES.CNL 0.455 MTEM.CNL 143.375 ILM.DTE IMPH.DTE IIRD. DTE TENS.OTE DT.LSS TT3.LSS TENS.LSS DPHI.LDT QLS.LOT L:L.LDT LSHV.LOT LURH.LOT MTEM.LOT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL ILM.DTE IMPH.DTE IIRD.DTE TENS.DTE DT.LSS TT3.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSH'V.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL 5.914 6.078 160.000 3940.000 88.875 1244.000 3940.000 16.650 0.024 182.250 1465.000 2.346 144.125 25.040 1193.855 13.367 929.000 6.824 6.773 109.500 3860.000 101.000 1364.000 3860.000 15.065 -0.024 221.500 1464.000 2.201 144.500 48.698 20.813 895.000 5.031 5.090 194.000 3824.000 95.750 1314.000 3824.000 20.507 0.022 200.625 1463.000 2.295 143.375 29.361 904.335 13.172 911.500 ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LOT CiSS.LDT LITH.LDT SSHV.LDT CALI.LDT MR ES. LDT TNRR.CNL CNTC.CNL TENS.CNI. ILO. DTE IFRE.DTE IIXD'DTE MTEM.DTE DTL.LSS TT4.LSS MTEN.LSS RHOB.LDT QSS.LDT LITH.LD'T SSHVoLDT CAL'I.LDT MRES.LDT TNRA.CNL CNTC .CNL TENS.CNL 5.324 20.000 15.656 142.500 87.750 1094.000 142.500 2.375 0.024 89.313 1559.000 13.367 0.450 2.608 3026'048 3890.000 8.133 20. 000 4.953 142.125 101.750 1190.000 142.125 2.401 0.030 90.688 1559.000 20.813 0.4¢9 4.448 1465.896 3780.000 4.348 2;0. 000 17.969 141.500 95.250 1150.000 141.500 2.312 0.017 104-813 1558.000 13.172 0.455 2.907 2612.554 3800.000 .IS TAPE VERIFICATION LISTIN'S iCHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 21 DEPT. 6400.000 SFLU.DTE 5.766 ILM. DTE SP.OTE -49.719 IDPH.DTE 6.973 IMPH.DTE CIDP.OTE 143.250 CIMP.DTE 163.750 IIRD.DTE IIRM.OTE 156. 500 GR.DTE 72.875 TENS.DTE MRES.DTE 0.589 HTEN.DTE -1398.000 DT.LSS TT1.LSS 1124.000 TT2.LSS 938.000 TT3.LSS SP.LSS -49.719 GR.LSS 72.875 TENS.LSS MRES.LSS 0.589 HTEN.LSS -1398.000 OPHI.LOT ORHO.LDT 0.032 PEF.LOT 3.141 QLS.LDT LS.LDT 2B6. 250 LU.LDT 272. 500 LL.LDT SS1.LDT 212.250 SS2.LDT 291.000 LSHV.LDT SIRH.LDT 2.342 LSRH.LDT 2.430 LURH.LOT GR.LDT 79.875 TENS.LOT 3724.000 MTEM.LDT HTEN.LDT 895.000 NPHI.CNL 35.573 TNPH.CNL NPOR.CNL 37.093 RCNT.CNL 2313.324 RCFT.CNL CFTC.CNL 633.324 GR.CNL 79.875 CALI.CNL MRES.CNL 0.454 MTEM.CNL 142.750 HTEN.CNL DEPT. 6300.000 SFLU.DTE 6.941 ILM.OTE SP.DTE -71.563 IDPH.DTE 8.258 IMPH.DTE CIDP.OTE 121.000 CIMP.DTE 136.500 IIRD.DTE IIRM. DTE 129.375 GR.DTE 78.313 TENS.DTE MRES.DTE 0.589 HTEN.DTE -1399.000 OT.LSS TT1.LSS 1134.000 TT2.LSS 945.000 TT3.LSS SP.LSS -71.563 GR.LSS 78.313 TENS.LSS MRES.LSS 0.589 HTEN.LSS -1399.000 OPHI.LDT DRHO. LDT 0.027 PEF.LDT 3.201 QLS.LOT LS.LOT 274.000 LU.LDT 262.750 LL.LDT SSI.LOT 209.750 SS2.LDT 291.750 LSHV.LOT SIRH.LDT 2.375 LSRH.LOT 2.455 LURH.LDT GR.LDT 83.063 TENS.LOT 3710.000 MTEM.LDT HTEN.LDT 908.500 NPHIoCNL 36.684 TNPH.CNL NPOR.CNL 39.217 RCNT.CNL 2393.085 RCFT.CNL CFTC.CNL 642.949 GR.CNL 83.063 CALI.CNL MRES.CNL 0.456 MTEM.CNL 141.875 HTEN.CNL DEPT. 6200.000 SFLU.DTE 3.570 ILM.DTE SP.OTE -41.906 'IDPH.DTE 4.340 IMPH.DTE CIDP.DTE 230.250 CIMP.DTE 259.000 IIRD.DTE IIRM.OTE 248.000 GR.DTE 70.563 TENS.DTE MRES.DTE 0.592 HTEN.OTE -1396.000 DT.LSS TT1.LSS 1140.000 TT2.LSS 945.000 TT3.LSS SP.LSS -41.906 GR.LSS 70.563 TENS.LSS MRES.LSS 0.592 HTEN.LSS -1396.000 DPHI.LOT DRHO.LDT 0.055 PEF.LOT 3.258 QLS.LOT LS.LDT 308°250 LUoLDT 294.750 ~LL.LOT SS1.LDT 220.1,25 SS2.LOT 301.250 LSHV.LDT SIRH.LD'T 2.258 LSRH.LDT 2.387 LURH.LDT GR.LDT 78.875 TENS.LOT 3660.000 MTEM.LDT HTEN.LDT 911.000 NPHI.CNL 36.313 TNPH.CNL NPOR.CNL 38.725 RCNT.CNL 2146.174 RCFT.CNL CFTC.~CNL 612. 510 GR.CNL 78.875 , CALI.CNL MRES.CNL 0.459 MTEM.CNL 140.750 H'TEN.CNL 6.020 6.102 128.375 3794.000 94.625 1311.000 3794.000 10.697 -O.OOZ 149.875 1463.000 2.432 142.750 37.125 632.166 12.977 895.000 7.289 7.324 107.500 3730.000 93.125 1338.000 3730.000 9.426 -0.006 142.750 1462.000 2.457 141.875 38.T01 654.29,0 13.172 908.500 3.773 3.857 197.750 3710.000 90.750 1329.000 3710.000 11.882 -0.019 160.875 1462.000 2.381 140.750 36.668 650.187 14.344 911.000 ILD.DTE IFRE .DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHDB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LOT MRES.LOT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS T'T4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LD'T TNRA.CNL CNTC.CNL TE:NS.CNL 6.793 20.0OO 4.242 141.250 93.500 1128.000 141.250 2.473 0.024 67.563 1557.000 12.977 0.454 3.323 2109.809 3724.000 8.133 20.000 1.561 140.750 90'750 1142.000 140.750 2.494 0.010 63.031 1558.000 13.172 0.456 3.388 2209.245 3710.000 4.250 20.000 14.195 139.750 90.250 1142.000 139.750 2.454 0.028 78.188 1557.000 I4'344 0.459 3.399 2052.352 3660.000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 6100.000 SFLU.DTE SP.DTE -54.813 IDPH.DTE CIDP.DTE 80.750 CIMP.DTE IIRM.DTE 94.438 GR.DTE MRES.DTE 0.590 HTEN.DTE TT1.LSS 1094.000 TTZ.LSS SP.LSS -64.813 GR.LSS MRES.LSS 0.590 HTEN.LSS DRHD.LOT 0.074 PEF.LDT LS.LDT 332.961 LU.LOT SS1.LDT 227.320 SS2.LDT SIRH. LDT 2.178 LSRH.LDT GR.LDT 40.076 TENS.LOT HTEN.LDT 879.719 NPHI.CNL NPOR.CNL 21.515 RCNT.CNL CFTC.CNL 1133.188 GR.CNL MRES.CNL 0.453 MTEM.CNL DEPT. 6000.000 SFLU.DTE SP.DTE -61.219 IDPH.DTE CIDP.DTE 51.656 CIMP.DTE IIRM.DTE 131.125 GR.DTE MRES.OTE 0.513 HTEN.DTE TT1.LSS 1518.000 TT2.LSS SP'LSS -61.219 GR.LSS MRES.LSS 0.513 HTEN.LSS DRHOoLDT 0.004 PEF.LOT LS.LDT 1967.000 LU.LDT SS1.LDT 232.125 SS2.LDT SIRH.LDT 1.278 LSRH.LDT GR.LDT 29.219 TENS.LOT HTEN.LDT 871.000 NPHZ.CNL NPOR.CNL 79.692 RCNT.CNL CFTC.CNL 264.863 GR.CNL MRES.CNL 0.383 MTEM.CNL 29-JUN-1989 16:27 12.063 ILM.DTE 12.375 IMPH.DTE 98.500 'IIRD.DTE 39.906 TENS.DTE -1399.000 DT.LSS 913.000 TT3.LSS 39.906 TENS.LSS -1399.000 DPHI.LDT 3.096 QLS.LDT 314.676 LL.LDT 313.678 LSHV.LOT 2.339 LURH.LDT 3602.855 MTEM.LDT 21.066 TNPH.CNL 3044.500 RCFT.CNL 40.076 CALI.CNL 139.750 HTEN.CNL 34.688 ILM.DTE 19.344 IMPH.DTE 153.875 IIRD.DTE 30.938 TENS.DTE -1 397. 000 DT.LSS 1282.000 TT3.LSS 30.938 TENS.LSS -1397.000 DPHI.LOT 2.178 QLS.LDT 177'3.000 LL.LOT 420. 250 LSHV.LOT 1.295 LURH.LDT 3544.000 MTE.M.LDT 66. 561 TNPH.CNL 1458.685 RCFT.CNL 29.219 CALI.CNL 139.000 HTEN.CNL DEPT. 5900.000 SFLU.OTE 4.914 ILM.DTE SP.OTE -31.469 ICPH.DTE 4.789 IMPH.DTE CIDP..DTE 208.750 CIMP.DTE 238.625 IIRD.DTE IIRM.DTE 225.500 GR.DTE 56.938 TENS.DTE MRES.DTE 0.599 HTEN.DTE -1397.000 DT.LSS TT1.LSS 1195.000 TT2.LSS 1029.000 TT3.LSS SP.LSS .-31.469 GR.LSS 56.938 TENS.LSS MRES.LSS 0.599 HTEN.LSS -1397.000 OPHI.LDT DRHO.LDT 0.022 PEF.LDT 2.293 QLS.LDT LS.LOT 531. 000 LU.:LOT 484.750 LL.LDT SS1.LD'T 227.000 SS2.LDT 338.250 LSHV.LDT SIRH.LDT 2.008 LSRH.LDT 2.080 LURH.LDT GR.LDT ,63.688 TENS.LOT 3560.000 MTEM.LOT HTEN.LOT 908.000 NPHIoCNL 37.273 TNPH.CNL NPOR.CNL 35.373 RCNT.CNL 2353.191 RCFT.CNL CFTC.CNL 595'222 GR.CNL 63.688 CALI.CNL MRES.CNL 0.485 MTEM.CNL 138.625 HTEN.CNL 10.016 10.148 77.688 3654.000 85.125 1270.000 3654.000 13.638 -0.012 175.586 1462.000 2.338 139.750 21.555 1159.500 17.078 879.719 7.195 6.492 79.813 3610.000 128.250 1763.000 3610.000 81.757 -0.077 1080.000 1461.000 1.309 139.000 80.537 272.315 22.953 871.000 4.156 4.188 177.750 3584.000 97.875 1396'000 35r84' 000 32.597 -0.017 288.750 146'1.000 2.076 138.625 37.246 610.110 16.563 908.000 ILD,DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4oLSS MTEM.LSS RHOB.LDT QSS.LOT LITH.LDT SSHV.LDT CALI .LOT MRES.LDT TNRA.CNL CNTC.CNL TENS .CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM. DTE DTL.LSS TT&.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH'LDT S SHV. LOT C AL I. LOT MR E S. LD'T TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RH:OB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL PAGE: 22 11.750 20.000 0.000 139.250 85.250 1098.000 139.250 2.425 0.027 78.910 1556.000 17.078 0.453 2.491 2772.125 3602.855 16.156 20.000 12.133 138.500 129.250 1527.000 138.500 1.301 -0.030 524.000 1555.000 22.953 0.383 5.277 1317.145 3544.000 4.699 20.000 9.250 138.375 99.000 1210.000 138.3'75 2.112 0.013 159.250 1554.000 16.563 0.485 3.510 2056.088 3560.000 ,IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 23 DEPT. 5800.000 SFLU.OTE 9.875 ILM.OTE 9.023 ILO.DTE 12.117 SP.DTE -61.813 IDPH.DTE 12.484 IMPH.DTE 9.070 IFRE.DTE 20.000 CIDP.DTE 80.063 CIMP.DTE 110. 188 IIRD.OTE 73.813 IIXD.DTE 0.000 IIRM.DTE 104.813 GR.DTE 38.969 TENS.DTE 3540.000 MTEM.DTE 137.875 MRES.OTE 0.604 HTEN.OTE -1398.000 OT.LSS 93.125 DTL.LSS 92.750 TT1.LSS 1174.000 TT2.LSS 993.000 TT3.LSS 1351.000 TT4.LSS 1180.000 SP.LSS -61.813 GR.LSS 38.969 TENS.LSS 3540.000 MTEM.LSS 137.875 MRES.LSS 0.604 HTEN.LSS -1398.000 DPHI.LDT 16.769 RHQB.LDT 2.373 DRHO.LDT 0.062 PEF.LDT 2.656 QLS.LDT -0.012 QSS.LDT 0.023 LS.LDT 358.000 LU.LDT 336.250 LL.LDT 190.000 LITH.LDT 95.500 SS1.LDT 226.500 SS2.LDT 317. 250 LSHV.LOT 1461.000 SSHV.LDT 1554..000 SIRH.LDT 2.158 LSRH.LDT 2.299 LURH.LDT 2.295 CALI.LDT 18.547 GR.LDT 46.188 TENS.LDT 3490.000 MTEM.LDT 138.250 MRES.LDT 0.483 HTEN.LDT 895.500 NPHI.CNL 23.889 TNPH.CNL 25.222 TNRA.CNL 2.718 NPOR.CNL 27.676 ~CNT.CNL 2520.,927 RCFT.CNL 909.512 CNTC.CNL 2468.711 CFTC.CNL 902.991 GR.CNL 46.188 CALI.CNL 18.547 TENS.CNL 3490.000 MRES.CNL 0.483 MTEM.CNL 138.250 HTEN.CNL 895.500 DEPT. 5700.000 SFLU.DTE 9.72'7 ILM.DTE 10.352 ILD.DTE 11.805 SP.DTE -51.906 IDPH.DTE 12.242 IMPH.DTE 10.531 IFRE.DTE ZO.O00 CIDP.OTE 81.625 CIMP.DTE 94.938 IIRO.DTE 74.813 IIXD.DTE 0.000 IIRM.DTE 91.438 GR.DTE 49.188 TENS.DTE 3484.000 MTEM.DTE 137.375 MRES.DTE 0.603 HTEN.DTE -1398.000 DT.LSS 96.000 DTL.LSS -112.375 TT1.LSS 1199.000 TT2.LSS 1017..500 T'T3.LSS 1390.000 TT4.LSS 1201.000 SP.LSS -51.906 GR.LSS 49.188 TENS.LSS 3484.000 MTEM.LSS 137.375 MRES.LSS 0.603 HTEN.LSS -1398.000 OPHI.LDT 13.836. RHOB.LDT 2.422 DRHOoLDT 0.035 PEF.LOT 2.701 QLS.LOT -0.003 OSS.LDT 0.015 LS.LDT 315.250 LU.LDT 297.o 500 LL.LDT 166.625 LITH.LOT 84.688 SS1.LOT 216.000 SS2.LDT 302.750 LSHV.LDT 1460.000 SSHV.LDT 1554.000 S1RH.LDT 2.279 LSRH.LDT 2.375 LURH.LDT 2.373 CALI.LOT 14.539 GR.LDT 48.125 TENS.LOT 3464.000 MTEM.LDT 137'875 MRES.LDT 0.484 HTEN.LDT 898.000 NPHI.CNL 21.664 TNPH.CNL 22.344 TNRA-CNL 2.464 NPOR.CNL 23.147 RCNT.CNL 3704.543 RCFT.CNL 1395.497 CNTC.CNL 3467.464 CFTC.CNL 1428.988 GR.CNL 48.125 CALI,CNL 14.539 TENS.CNL 3464.000 MRES.CNL 0.484 MTEM.CNL 137.875 HTEN.CNL 898.000 DEPT. 5600.000 SFLU.DTE 4.359 ILM.DTE 4.715 ILO.gTE 5.520 SP.DTE -34.063 IEPH.DTE 5.684 IMPH. DTE 4.840 IFRE.DTE 20.000 CIDP.DTE 175.750 CIMP'DTE 206.500 IIRD.DTE 158.875 IIXD.DTE 9.508 IIRM.DTE 199.250 GR.DTE 53.438 TENS.DTE 3490.000 MTEM.DTE 137.500 MRES.DTE 0.608 HTEN.DTE -1398.000 DT.LSS 101.250 DTL.LSS 100.500 TT1.LSS 1219.000 TT2.LSS 102'1.000 TT3.LSS 1430.000 TT4.LSS 1224.000 SP.LSS -34.063 GR.LSS 53.438 TENS'LSS 3490.000 MTEM.LSS 137.500 MRES.LSS 0.608 HTEN.LSS -1398.000 DPHI.LDT 17.567 RHDB.LDT 2.360 ORHO.LDT 0.057 PEF.LDT 2.631 QLS.LDT -0'015 QSS.LDT 0.023 LS.LDT 362.250 LU.LDT 1340.250 LL.LDT 192.000 LITH.LOT 92.563 SS1.LDT 225.625 SSZ.LDT 316.750 LSHV.LDT 1459.000 SSHV.LDT 1553-000 SIRHoLDT 2.160 LSRH.LDT 2.291 LURH.LOT 2.287 CALI.LDT 15.102 GRoLDT 54.844 TENS.LDT 3414.000 MTEM. LDT 137.625 MRES.LDT 0.487 HTEN.LDT 903.500 NPHI.CNL 39.145 TNPH.CNL 40.371 TNRA.CNL 3.573 NPOR.CNL 40.556 RCNT.CNL 2177.976 RCFT.CNL 560.375 CNTC.CNL 1995.748 CFTC.CNL 554'074 GR.CNL 54.844 CALI.CNL 15.102 TENS.CNL 3414.000 MRES.CNL 0.487 MTEM.CNL 137.625 HTEN.CNL 903.500 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16=27 PAGE'. 24 DEPT. 5500.000 SFLU.DTE SP.DTE -41.906 IDPH.DTE CIOP.DTE 159.000 CIMP.OTE IIRM.DTE 164. 500 GR.DTE MRES.DTE 0.616 HTEN.DTE TT1.LSS 1098. 000 TTZ.LSS SP.LSS -41.906 GR.LSS MRES.LSS 0.616 HTEN.LSS DRHO.LDT 0.009 PEF.LDT LS.LDT 326.250 LU.LDT SSI.LOT 208.875 SS2.LDT SIRH.LOT 2.320 LSRH.LOT GR.LDT 43.188 TENS.LOT HTEN.LDT 928.000 NPHI.CNL NPOR.CNL 22.351 RCNT.CNL CFTC.CNL 1263. 509 GR.CNL MRES.CNL 0.494 MTEM.CNL DEPT. 5400.000 SFLU.OTE SP.DTE -60.656 IDPH.OTE CIOP.DTE 428.500 CIMP.OTE IIRM. DTE 330. 000 GR.OTE HRES.DTE 0.619 HTEN.DTE TT1.LSS 1242. 000 TT2.LSS SP.LSS -60.656 GR.LSS MRES.LSS 0.619 HTEN.LSS DRHO.LOT 0.0 07 PEF.LOT LS.LDT 391.004 LU.LDT SS1.LDT 213. 250 SS2.LOT S1RH.LDT 2.221 LSRH.LDT GR.LDT 48.582 TENS.LOT HTEN.LDT 912.344 NPHI.CNL NPOR.CNL 33. 524 RCNT.CNL CFTC.CNL 850.695 GR.CNL MRES.CNL 0.500 MTEM.CNL 4.410 ILM.DTE 6.285 IMPH.OTE 182.125 IIRD.DTE 40.188 TENS.DTE -1398.000 DT.LSS 909.000 TT3.LSS 40.188 TENS.LSS -1398.000 OPHI.LDT 3.094 QLS.LDT 309.750 LL.LDT 295.750 LSHV.LDT 2.355 LURH.LDT 3404.000 MTEN.LDT 21.151 TNPH.CNL 3434.604 RCFT.CNL 43.188 CALI.CNL 137.000 HTEN.CNL 3.807 ILM.DTE 2.332 IMPH.DTE 355.500 IIRD.DTE 51.125 TENS.DTE -1399.000 DT.:LSS 1034.:000 TT3.LSS 51.125 TENS.LSS -1399.000 DPHI.LDT 2.742 OLS.LDT 361.086 LL.LDT 307.750 LSHV.LDT 2.249 LURH.LDT 3334.672 MTEM.LDT 32.377 TNPH.CNL 2805.547 RCFT.CNL 48.582 CALI.CNL 136.583 HTEN.CNL DEPT. 5300.000 SFLU.DTE 20.109 ILfl. DTE SP.DTE -47.719 IDPH.OTE 6.414 IMPH.DTE CIDP.DTE 155.875 CIMP.DTE 117.875 IIRD.DTE IIRM.DTE 132.750 GR.DTE 51.500 TENS.DTE MRES.DTE 0.617 HTEN.DTE -1396.000 DT.LSS TT1.LSS 1074. 000 TTZoLSS 875.500 TT3.LSS SP.LSS -47.719 GR.LSS 51.500 TENS.LSS MRES.LSS 0.617 HTENoLSS -1396.000 DPHI.LDT DRHO.LDT 0.052 PEF.LDT 3.520 QLS.LDT LS.LDT 2'79.500 LU.LDT 263.750 LL.LDT SS1.LDT 216.250 SS2.LDT .292.250 LSHV.LDT $1RH.LDT 2.318 LSRH.LOT 2.443 LURH.LDT GR.LDT 68.625 'TENS.LD'T 3310.000 MTEM.LDT HTEN.LDT 904.500 NPHI.CNL 35.184 TNPH.CNL NPOR.CNL 42.939 RCNT.CNL 2366.890 RCFT.CNL CFTC.CNL 859'289 GR.CNL 68.625 CALI.CNL MRES.CNL 0.500 MTEM.CNL 135.625 HTEN.CNL 5.723 5.488 147.125 3404.000 79.125 1286.000 3404.000 16.660 -0.018 171.375 1459.000 2.348 137.000 22.950 1240.656 13.563 928.000 2.81'8 2.811 351.250 3364.000 110.000 1479.000 3364.000 23.152 -0.002 210.336 1458.000 2.252 136.583 32.995 859.493 12.391 912. 344 7.105 8.477 147.500 3314.000 72.125 1274.000 3314.000 8.691 0.018 147.750 1458.000 2. 453 135.625 33-631 754.395 12.641 904'500 ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH. LDT SSHV.LDT C.ALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LOT QSS.LDT LITH.LDT SSHV.LDT C AL I. LDT MRES.LOT TN.RA.CNL CN?C..CNL TENS.CNL ILD.OTE IFRE.DTE IIXD.DTE MTEM. OTE OTL'LSS TT4.LSS MTEM.LSS RHDB.LDT QSS.LDT LITH.LDT SSHV.LDT C A L I. L O 'T MR ES. LD'T TNRA.CNL CNTC.CNL TENS.CNL 6.031 20.000 10.281 137.000 78.750 1103.000 137.000 2.375 0.013 88.813 1553.000 13.563 0.494 2.405 30T6.079 3404.000 2.334 20.000 65.000 136.375 105.000 1245.000 136.3T5 2.268 0.014 107.688 1552.333 12.391 0.500 3.122 2594.313 3334.672 6.238 20.000 22.391 135.625 71.750 1077.000 135.625 2.507 0.030 63.063 1552.000 12.641 0.500 3.293 2663.315 3310.000 IS TAPE VERIFICATION LISTING 29-JUN-1959 I6:27 CHLUMBERGER ALASKA COMPUTING CENTER PAGE: 25 DEPT. 5200.000 SFLU.DTE 5.262 ILM. DTE SP.DTE -26.344 IDPH.DTE 6.848 IMPH.DTE CIDP.OTE 146.000 CIMPoDTE 169.625 IIRD.DTE IIRM.DTE 162.875 GR.DTE 72.063 TENS.OTE MRES.DTE 0.626 HTEN.DTE -1398.000 DT.LSS TT1.LSS 1258.000 TT2.LSS 1080.000 TT3.LSS SP.LSS -26.344 GR.LSS 72.063 TENS.LSS MRES.LSS 0.626 HTEN.LSS -1398.000 OPHI.LOT DRHO.LDT 0.139 PEF.LDT 3.119 QLS.LOT LS.LDT 413.000 LU.LDT 389.000 LL.LOT SS1.LDT 251.375 SS2.LDT 344.500 LSHV.LDT SIRH.LDT 1.941 LSRH.LDT 2.215 LURH.LDT GR.LDT 73.688 TENS.LOT 3270.000 MTEM.LDT HTEN.LDT 910.000 NPHI.CNL 40.873 TNPH.CNL NPOR.CNL 42.461 RCNT.CNL 2136.923 RCFT.CNL CFTC.CNL 575.402 GR.CNL 73.688 CALI.CNL MRES.CNL 0.500 MTEM.CNL 135.125 HTEN.CNL DEPT. 5100.000 SFLU.DTE 3.293 ILM.DTE SP.DTE -10.500 IDPH.DTE 4. 250 IMPH.DTE CIDP.OTE 235.125 CIMP.DTE 262.250 IIRD.DTE IIRM.OTE 246.875 GR.DTE 53.969 TENS.DTE MRES.DTE 0.620 HTEN.DTE -1399.000 DT.LSS TT1.LSS 1272.000 TT2.LSS 1070.000 TT3.LSS SP.LSS -10.500 GR.LSS 53.969 TENS.LSS MRES.LSS 0.620 HTEN.LSS -1399.000 DPHI.LDT DRHO.LDT 0.068 PEF.LOT 2.939 QLS.LDT LS.LOT 370.750 LU.LDT 350. 250 LL.LDT SS1.LDT 229.000 SS2.LOT 320.000 LSHV.LOT S1RH.LDT 2.127 LSRH.LOT 2.277 LURH.LDT GR.LDT 49.094 'TENS.LOT 3.210.000 MTEM.LOT HTEN.LDT 898.000 NPHI.CNL 35.I35 TNPH.CNL NPOR.CNL 35.123 RCNT.CNL 2426.656 RCFT.CNL CFTC.CNL 675.727 GR.CNL 49.094 CALI.CNL MRES.CNL 0.502 MTEM.CNL 134.375 HTEN.CNL DEPT. 5000.000 SFLU.DTE 2.896 ILM.DTE SP.DTE -20.094 IDPH.DTE 4.117 IMPH.DTE CIDPoDTE 242. 625 CIMP.DTE 269.000 IIRD.DTE IIRM.DTE 248.875 GR.DTE 46.563 TENS.DTE MRES.DTE 0.628 HTEN.DTE -1399.000 OT.LSS TT1.LSS 1184.000 TT2.LSS 955.500 TT3.LSS SP.LSS -20.094 GR.LSS 46.563 TENS.LSS MRES.LSS 0.628 HTEN.:LSS -1399.000 DPHI.LDT DRHO.LDT 0.026 PEF.LDT 2.602 QLS.LOT LS.LDT 358. 250 LU.LDT 335.750 LL.LDT SS1.LDT 217.625 SS2.LDT 309.500 LSHV.LDT $1RH. LDT 2.221 LSRH.LDT 2.299 LURH.LDT GR.LDT 45. 594 TENS.LOT 3194.000 MTEM.LDT HTEN.LOT 929.500 NPHI.CNL 31.884 TNPH.CNL NPOR.CNL 33.742 RCNT.CNL 2655.195 RCFT. CNL CFTC. CNL 758-402 GR.CNL 45. 594 CALI.CNL MRES.CNL 0.505 MTEM.CNL 133.750 HTEN.CNL 5.781 5.891 132.000 3320.000 101.000 1471.000 3320.000 17.205 -0.031 218.500 1457.000 2.205 135.125 40.469 614.220 12.922 910.000 3.791 3.813 203.750 3264.000 102.000 1475.000 3264.000 17.737 -0.025 195.625 1458.000 2.270 134.375 35.578 645.956 13.188 89 8. 000 ILD.DTE 6.645 IFRE.DTE 20.000 IIXD.DTE 5-215 MTEM.DTE 135.375 DTL.LSS 100.000 TT4.LSS 1264.000 MTEM.LSS 135.375 RHDB.LDT 2.366 QSS.LDT 0.043 LITH.LDT 101.188 SSHV.LDT 1551.000 CALI.LDT 12.922 MRES.LDT 0.500 TNRA.CNL 3.611 CNTC.CNL 2034.448 TENS.CNL 3270.000 ILD.DTE 4.144 IFRE.OTE 20.000 IIXD.DTE 16.828 MTEM.DTE 135.000 OTL.LSS 100.250 TT4.LSS 1277.000 MTEM.LSS 135.000 RHOB.LDT 2.357 QSS.LDT 0.028 LITH.LDT 94.438 SSHV.LDT 1551.000 CALI.LDT 13.188 MRES.LDT 0.502 TNRA.CNL 3.304 CNTC.CNL 2190.978 TENS.CNL 3210.000 3.760 ILD. DTE 3.996 3.715 IFRE.DTE 20.000 210.500 IIXD.DTE 19.625 3220.000 MTEM.DTE 134-250 102.750 OTL.LSS 107.500 1388.000 TT4.LSS 1184.000 3220.000 MTEM. LSS 134.250 19.030 RHOB.LDT 2.336 -0.011 QSS.LDT 0.016 190.500 LITH.LDT 95.250 1458.000 SSHV.LDT 1550.000 2.297 CALI'LDT 13"852 133.750 MRES.LDT 0.505 34.057 TNRA.CNL 3.128 801.197 CNTC.CNL 2404.789 13.852 TENS.CNL .3194.000 929.500 IS TAPE VERIFICATION LISTING CHLUMSERGER ALASKA COMPUTING CENTER DEPT. 4900.000 SFLU.DTE SP.OTE -28.578 IDPH.DTE CIDP.DTE 276.750 CIMP.DTE IIRM.DTE 261.750 GR.~TE MRES.DTE 0.626 HTEN.DTE TT1.LSS 1130.000 TT2.LSS SP.LSS -28.578 GR.LSS MRES.LSS 0.626 HTEN.LSS DRHO.LDT 0.108 PEF.LOT LS.LDT 379.000 LU.LOT SS1.LDT 240.250 SS2.LOT SIRH.LOT 2.0~3 LSRH.LDT GR.LDT 50.219 TENS.LOT HTEN.LDT 927.500 NPHI.CNL NPOR.CNL 36.330 RCNT.CNL CFTC.CNL 663.949 GR.CNL MRES.CNL 0.508 MTEM.CNL DEPT. 4800.000 SFLU.OTE SP.DTE -10.773 IDPH.DTE CIDP.DTE 184.000 CIMP.DTE IIRMoDTE 213.625 GR.OTE MRES.DTE 0.628 HTEN.DTE TT1.LSS 1198.000 TT2.LSS SP.LSS -10.773 GR.LSS MRES.LSS 0.628 HTEN.LSS DRHO.LOT 0.027 PEF.LDT LS.LDT 339.250 LU.LOT SS1.LOT 216. 375 S52.LOT SIRH.LDT 2.250 LSRH.LOT GR.LDT 47.813 TENS.LOT HTEN.LOT 903.500 NPHI.CNL NPOR.CNL 28.077 RCNT.CNL CFTC.CNL 875.868 GR.CNL MRES.CNL 0.507 MTEM.CNL DEPT. 4700.000 SFLU.DTE SP.OTE -22.969 IDPH.DTE CIDP.DTE 261.500 CIMP.DTE IIRM.DTE 229.750 GR.DTE MRES.DTE 0.638 HTEN.DTE TT1.LSS 1203.000 TT2.LSS SP.LSS -22.969 GR.LSS MRES.LSS 0.638 HTEN.LSS DRHO.LDT 0.043 PEF.LOT LS.LDT 334.250 LU.LDT SS1.LOT 220.000 SS2.~LDT SIRH.LDT 2.229 LSRH..LOT GR.LDT 54.500 TENS.LOT HTENoLOT 924*500 NPHI.CNL NPOR.CNL 35.782 RCNT.CNL CFTC.CNL 754.685 GR.:CNL MRES.CNL 0.521 MTEM.CNL 29-JUN-1989 16:27 3.322 ILM.DTE 3.611 IMPH.DTE 281.500 IIRD.DTE 45.969 TENS.DTE -1395.000 OT.LSS 927.500 TT3.LSS 45.969 TENS.LSS -1395.000 DPHI.LDT 3.146 QLS.LDT 356.000 LL.LDT 324. 500 LSMV.LOT 2.264 LURH.LDT 3164.000 MTEM.LDT 36.060 TNPH.CNL 2460. 835 RCFT.CNL 50.219 CALI.CNL 133.250 HTEN.CNL 3.760 ILM.OTE 5.430 IMPH.DTE 222.375 IIRD.DTE 51.344 TENS.DTE -1399.000 DT.LSS 997.000 TT3.LSS 51.344 TENS.LSS -1399.000 DPHI.LDT 2.745 QLS.LOT 316.250 LL.LOT 301.000 LSHV.LDT 2.332 LURH.LDT 3090.000 MTEM.LDT 31.510 TNPH.CNL 3144.526 RCFT.CNL 47.813 CALI.CNL 133.250 HTEN.:CNL 4.516 ILM.OTE 3-822 IMPH.OTE 242.750 IIRD'OTE 54.094 TENS.DTE -1399.000 OT.LSS 1008.000 TT3.LSS 54.094 TENS.LSS -1399.000 DPHI.LDT 2.977 QLS.LDT 319'000 LL.:LOT 305.000 LSHV'LDT 2.336 LURH.LDT 3080.000 MTEM.LDT 35.541 TNPH-CNL 2674.904 RCFT.CNL 54.500 CALI.CNL 132.000 HTEN.CNL 3.572 3.549 242.375 3180.000 102.625 1342.000 3180.000 16.156 -0.018 201.125 1457.000 2.260 133.250 37.078 693.106 12.875 927.500 4.391 &.491 169.375 3150.000 100.250 1400.000 3150.000 16.925 0.004 181.125 1456.000 Z.334 133.250 31.765 859.493 12.391 903.500 4.078 4.117 225.125 3110.000 100.375 1377.000 3110.000 15.676 -0-027 174.875 1456.000 2.328 132.000 35.846 811.584 12.391 924.500 ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOS.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILO.DTE IFRE.DTE I IXD. DT E MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LOT LITH.LDT SSHV.LDT CALI.LDT MRESoLDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE DTL. LS S TT4.LSS MTEM.LSS e t-lOS. LOT QSS.LOT L ITH.LDT SSHV .LOT C ALI. LOT MRES .LOT TNRA.CNL CNTC.CNL TENS-CNL PAGE: 3.486 20.000 26.797 133.750 103.000 1139.000 133.750 2.383 0.051 91.250 1550.000 12.875 0.508 3.347 2207.495 3164.000 . 20. 18. 134. 1 O0. 1204. 134. 2. O. 92. 1550. 12. O. 3. 2602, 3090. 20. 25. 133. 100. 1209. 133. 2. 0:. 78. 1549' 12' O. 3' 2437. 3080' 26 285 000 297 000 500 000 000 371 O28 438 000 391 507 064 3;a! 000 717 000 984 000 000 000 000 391 027 750 000 391 521 3O5 704 000 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 27 DEPT. 4600.000 SFLU.OTE SPoDTE -16.500 IOPH.DTE CIDPoOTE 295.000 CIMP.DTE !IRM.OTE 278. 250 GR.gTE MRES.DTE 0.638 HTEN.DTE TT1.LSS 1222.000 TT2.LSS SP.LSS -16.500 GR.LSS MRES.LSS 0.638 HTEN.LSS DRHO.LDT 0.005 PEF.LDT LS.LDT 359.667 LU.LDT SS1.LDT 209.584 SS2.LOT SIRH.LDT 2. 278 LSRH.LOT GRoLOT 38.739 TENS.LOT HTEN.LDT 928.498 NPHI.CNL NPOR.CNL 32.635 RCNT.CNL CFTC.CNL 915.734 GR.CNL MRES.CNL O. 521 MTEM.CNL DEPT. 4500. 000 SFLU. O'TE SPoOTE -7.973 [DPHoOTE CIDP.DTE 55.438 CIMP.DTE IIRM.OTE 61.250 GR.OTE MRESoDTE 0.637 HTEN.OTE TT1.LSS 14 56. 000 TT2.LSS SP.LSS -7.973 GR.LSS NRES.LSS 0.637 HTEN.LSS DRHO.LDT 0.039 PEF.LDT LS.LDT 1053.000 LU.LOT SS1.LDT 244.6,25 SS2.LDT S1RH.LDT !.572 LSRH.LOT GR.LDT 31.484 TENS.LOT HTEN.LDT 903. 500 NPHI.CNL NPOR.CNL 74.400 RCNT.CNL CFTC.CNL 312. 700 GR.CNL MRES.CNL 0.519 MTEM.CNL DEPT. 4400.000 SFLU.DTE SP.OTE -18.781 IDPH.DTE CIDP.DTE 103.500 CIMP.DTE IIRM. OTE 118.938 GR.DTE MRES.DTE 0.644 HTEN.~TE TT1.LSS 1214.000 TT2.LSS SP.LSS -18.781 GR.LSS MRES.LSS 0.644 HTEN.LSS DRHO.LDT -0.002 PEF.LOT LS.LOT 1068.000 LU.LDT SS1.LDT 228.000 SS2.LOT SIRH.LDT 1.678 LSRH.LDT GR.LDT 48.813 TENS.LDT HTEN.LOT 942.000 NPHI.CNL NPOR'CNL 41.961 RCNT.CNL CFTC.CNL 513.407 GR.CNL MRES.CNL 0.526 MTEM.CNL 3.412 ILM.DTE 3.387 IMPH.DTE 297.000 IIRD.DTE 35.969 TENS.DTE -1400.000 OT.LSS 1014.500 TT3.LSS 35.969 TENS.LSS -1400.000 DPMI.LOT 2.689 QLS.LDT 336.750 LL.LDT 303.500 LSHV.LDT 2.298 LURH.LDT 3025.996 MTEM.LDT 31.102 TNPH.CNL 2964.375 RCFT.CNL 38. 739 CALI.CNL 131.333 HTEN.CNL 30.719 ILM.DTE 18.031 IMPH.DTE 57.469 IIRD.OTE 35.969 TENS.DTE -1,~00.000 DT.LSS 1222.000 TT3.LS$ 35.969 TENS.LSS -1400.000 DPHI.LDT 2.191 QLS.LDT 913.000 LL.LOT 376.250 LSHV.LOT 1o67~ LURH.LDT 2970.000 MTEM.LDT 62.224 TNPH.CNL 1662.T87 RCFToCNL 31.&84 CALI.CNL 131.375 HTEN.CNL 6.012 ILM.DTE 9.656 IMPH.OTE I26.500 IIRO.OTE 49.094 TENS.DTE -1400.000 OT.LSS 1063.000 TT3.LSS 49.094 TENS.LSS -1400.000 DPHI.LDT 2.477 QLS.LDT 945.500 LL.LDT 381.750 LSHV.LDT 1.668 L.URH.LDT 2960.000 MTEM.LDT 44.453 TNPH.CNL 2187.950 RCFT.CNL 4B.813 CALI.CNL 129,875 HTEN.CNL 3.355 3.365 252.750 3040.000 98.250 1389.000 3040.000 20.395 -0.011 191.250 1454.000 2.295 131.333 32.040 891.313 12.586 928.498 15.48& 17'391 62.781 3010.000 131.250 1707.000 3010.000 56.465 -0.001 596.500 1454.000 1.691 131.375 74.504 301.757 17.469 903.500 7.941 7.898 94.250 2984.000 115.875 1388.000 2984'000 59.335' -0.029 595.000 1454.000 1.671 129.875 43.925 543.808 12.625 942.000 ILD.OTE IFRE.DTE IIXD.OTE MTEM.OTE OTL.LSS TT4.LSS MTEM. LSS RHOB.LOT QSSoLDT LITH.LDT SSH¥.LOT CALI.LDT MRES .LOT TNRA.CNL CNTC.CNL TENS .CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRR.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL*LSS TT4.LSS MTEM.LSS RHOO.LDT QSS .LOT LITH.LDT, SSHV.LDT CALI. LOT MRESoLDT TNRA .CNL CNTC.CNL TENS.CNL 3.260 20.000 28.219 132.375 100.250 1223.000 .132.375 2.313 0.005 97.666 1548.000 12.586 0.521 3.042 2743.203 3025-996 15.977 20.000 6.309 132.875 129.750 1462.000 132.875 1.718 0.041 400.250 1548.000 17.469 0.519 4.896 1515.468 2970.000 9.242 20.000 4.469 131.375 113.000 1227.000 131.375 1.671 -0.017 442.250 1547.000 12'625 0.526 3.798 1917.478 2960,000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 28 DEPT. 4300.000 SFLU.OTE 67.125 ILM.DTE SP.DTE -27.719 IOPH.DTE 32.375 IMPH.DTE CIDP.DTE 30.859 CIMP.DTE 19.797 IIRD.DTE IIRM.DTE 22.766 GR.OTE 40.$25 TENS.gTE MRES.OTE 0.651 HTEN.OTE -1395.000 gT.LSS TT1.LSS 849.000 TT2.LSS 684.500 TT3.LSS SP.LSS -27.719 GR.LSS 40.625 TENS.LSS MRES.LSS 0.651 HTEN.LSS -1395.000 DPHI.LDT DRHO.LOT 0.200 PEF.LDT 3.988 QLS.LOT LS.LDT 306.500 LU.LDT 299. 000 LL.LDT SS1.LDT 255.500 SS2.LDT 333. 500 LSHV.LOT SIRH.LOT 2.023 LSRH.LDT 2.383 LURH.LDT GRoLDT 39.406 TENS.LOT 2930.000 MTEM.LDT HTEN.LDT 937.000 NPHI.CNL 12.537 TNPH.CNL NPOR.CNL 12.896 RCNT.CNL 4464.646 RCFT.CNL CFTC.CNL 2297.450 GR.CNL 39.406 CALI.CNL MRES.CNL 0.528 MTEM.CNL 129.375 HTEN.CNL DEPT. 4200.000 SFLU.DTE 7.023 ILM.DTE SP.DTE -22.906 IDPH.DTE 7.574 IMPH.DTE CIDP.DTE 132.000 CIMP.DTE 153.625 IIRD.OTE IIRM.DTE 145.625 GR.DTE 62.219 TENS.gTE MRES.DTE 0.649 HTEN.DTE -1399.000 DT.LSS TT1.LSS 1362.000 TT2.LSS 1137.000 TT3.LSS SP.LSS -22.906 GR.LSS 62.219 TENS.LSS MRES.LSS 0.649 HTEN.LSS -1399o000 DPHI.LDT DRHD.LDT 0.063 PEF.LDT 3.061 QLS.LDT LS.LDT 380.965 LU.LDT 353. 500 LL.LDT SS1.LDT 228.715 SS2.LDT 320.536 LSHV.LDT SlRH.LDT 2.119 LSRH.LOT 2.261 LURH.LDT GR.LDT 55.719 TENS,LOT 2840.000 MTEM.LDT HTEN.LDT 917.141 NPHI.CNL 42.793 TNPH.CNL NPDR.CNL 42.661 RCNT.CNL 2153.554 RCFT.CNL CFTC.CNL 549.750 GR.CNL 55.719 CALI.CNL MRES.CNL 0.543 MTEM.CNL 128.857 HTEN.CNL DEPT. 4100.000 SFLU.D'TE 3.357 ILM.DTE SP.DTE -7.605 IDPH.DTE 2.436 IMPH.DTE CIDP.DTE 410.500 CIMP.DTE 492.250 IIRD.DTE IIRM. DTE 439.750 GR.DTE 48.406 TENS.gTE MRES.DTE 0.652 HTEN.DTE -1398.000 OT.LSS TT1.LSS 1466.000 TT2.LSS 1196.000 TT3.LSS SP.LSS -7.605 GR.LSS 48.406 TENS.L:SS MRES.LSS 0.652 HTEN.LSS -1398.000 DPHI.LOT DRHO.LDT 0.032 PEF.LOT 2.658 QLS.LDT LS.LDT 493.000 LU.LDT 449'750 LL.LDT SSI.LDT 227.750 SS2.LDT 336.000 LSHV.LDT SIRH.LDT 2.029 LSRH.LDT 2.119 LURH.LDT GR.LDT 49.500 TENSoLDT 2784.000 MTEM.LDT HTEN.LDT 902.000 NPHI.CNL 45.728 TNPH.CNL NPOR.CNL 44.814 RCNT.CNL 2181..776 RCFT.CNL CFTC.CNL 509.837 GR.CNL 49'500 CALI.CNL MRES.CNL 0.559 MTEM.CNL 128.375 HTENoCNL 41.781 50.469 39.656 2934.000 59.250 1034.000 2934.000 3.214 -0.042 157.000 1454.000 2.371 129.375 13.413 2319.930 12.523 937.000 6.473 6.508 118.063 2880.000 110.000 1558.000 2880'000 19.025 -0.003 Z04.304 1453.857 2.26~ 128.857 41.910 569.107 13.163 917.141 2.098 2.029 329.750 2844.000 110.250 1678.000 2844.000 29.575 -0.009 268°000 1453o000 2.119 128.375 45.674 541.577 12.625 902.000 ILD.DTE IFRE.DTE IIXD.DTE MTEM.OTE OTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LOT MRES. LDT TNRA.CNL CNTC.CNL TENS.CNL ILO.gTE IFRE.OTE IIXD.DTE MTEM. DTE OTL.LS$ TT4.L$S MTEM.LSS RHOB. LD'T QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL 26.875 20.000 5.266 130.875 54.750 856.000 130.875 2.597 0.047 61.625 1547.000 12.523 0.528 1.803 3987.803 2930.000 7.426 20.000 6.996 130.500 109.750 1372.000 130.500 Z .336 0.029 94.0'98 1547.000 13. 163 0.543 3.722 1996.656 2840.000 2.311 20.000 27.500 130.125 109.500 1470.000 130.125 2.162 0.014 138.500 1546.000 12.625 0.559 3.868 1957.506 2784.000 · IS TAPE VERIFICATION LISTING ;CHLUMBERGER ~LASKA COMPUTING CENTER 2 9-JUN-1989 16:27 PAGE: 29 DEPT. 4000.000 SFLU.DTE 5.559 ILM.DTE SP.DTE -34.500 IDPH.OTE 5.859 IMPH.DTE CIDP.D?E 170.500 CIMP.OTE 164.500 IIRD.DTE IIRM.DTE 158.750 GR.OTE 50.656 TENS.DTE MRES.DTE 0.661 HTEN.DTE -1401.000 OT.LSS TT1.LSS 1300.000 TT2.LSS 1085.000 TT3.LSS SP.LSS -34.500 GR.LSS 50.656 TENS.LSS MRES.LSS 0.661 HTEN.LSS -1401.000 OPHI.LDT DRHO.LDT 0.003 PEF.LDT 2.939 OLS.LDT LS.LOT 378. 000 LU.LDT 354. 500 LL. LOT SSI.LOT 210.375 SS2.LDT 305.750 LSHV.LDT SIRH. LDT 2.254 LSRH.LDT 2.268 LURH.LDT GR.LDT 54.406 TENS.LOT 2760.000 MTEM.LDT HTEN.LDT 917.000 NPH[.CNL 29.281 TNPH.CNL NPOR.CNL 30.423 RCNT.CNL 2872.530 RCFT.CNL CFTC.CNL 913.873 GR.CNL 54.406 CALI.CNL MRES.CNL 0.563 MTEM.CNL 127.125 HTEN.CNL DEPT. 3900.000 SFLU.DTE 5.820 ILM.OTE SP.OTE -8.773 IDPH.DTE 5.938 IMPH.DTE CIDP.DTE 168.250 ' CIMP.DTE 183.750 IIRD.OTE IIRM.DTE 178.125 GR.DTE 51.000 TENS.OTE MRES.DTE 0.670 HTEN.DTE -1398o000 OT.LSS 'TT1.LSS 1298.000 TT2.LSS 1088.000 TT3.LSS SP.LSS -8.773 GR.LSS 51.000 TENS.LSS MRES.LSS 0.670 HTEN.LSS --lr398.000 DPHI*LOT DRHO.LDT 0.022 PEF*LDT 3.000 QLS.LDT LS'LDT 364'250 Lu'LDT 344. 250 LL.LOT SS1.LDT 217.250 SS2.LDT 308. 500 LSHV.LOT SIRH.LDT Z.217 LSRH.LDT Z.289 LURH.LOT GR.LOT 58.781 TENS.LDT 2710.000 MTEM.LOT HTEN.LDT 897.000 NPHI.CNL 33.410 TNPH.CNL NP:OR.CNL 38.149 RCNT.CNL 2.763.633 RCFT.CNL CFTC.CNL 654-033 GR.CNL 58.781 CALZ.CNL MRES.CNL 0.559 MTEM.CNL 126.250 HTEN.CNL DEPT. 3800.000 SFLUoDTE 4.156 ILM.OTE SP.DTE -7.758 IDPH.BTE 4.488 IMPH.DTE CIDP.DTE 222.750 CIMP.DTE 224.750 IIRD.OTE IIRM. OTE 213. 500 GR.DTE 55.344 TENS.DTE MRES.DTE 0.663 HTEN.DTE -1402o000 OT.LSS TT1.LSS 1288.000 TT2.LSS 1084.000 TT3.LSS SP.LSS -7.758 GR.LSS 55.344 TENS.LSS MRES,.LSS 0.663 HTEN.LSS -1402.000 DPHI.LDT DRHO.LDT 0.034 PEF.LDT 3.022 QLS.LDT LS.LOT 367.023 LU.LDT :340. 637 LL.LDT SS1.LDT 220.417 SSZ.LDT 315.583 LSHV.LDT SIRH.LD'T 2.192 LSRH.LDT 2.284 LURH.LDT GR.LDT .52.038 TENS .:LOT 2686. 219 MTEM'LDT HTEN.LDT 912.445 NPHI.CNL 39.205 TNPH.CNL NPOR.CNL 39.270 RCNT.CNL 2284.750 RCFT.CNL CFTC.CNL 614.650 GR.CNL 52.038 CALI.CNL MRES.CNL 0.550 MTEM.CNL 126-514 HTEN.CNL 5.934 6.074 151.375 2794.000 106.000 1511.000 2794.000 22.292 -0.020 200-750 1453.000 2.262 127.1Z5 30.346 946.577 12.195 917.000 5.277 5.438 145.750 2764.000 104.750 1538.000 2764.000 19.916 -0.025 192.125 1452.000 2.281 126.Z50 36-513 665.011 1Z.586 897.000 4. 391 4.445 189.875 2724. 000 110.500 150 7. 000 2T24.000 19.408 0.000 196.777 1452.000 2.288 126.5'14 38.892 614.585 12'420 912.445 ILD.DTE IFRE.DTE IIXD.DTE MTEM. DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC .CNL TENS.CNL ILO.DTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LOT SSHV.LDT CALI .LOT MRES.LDT TNRA.CNL CNTC.CNL 'TENS .CNL ILD.DTE IFRE.DTE IIXD.DTE M T E M. DT E OTL.LSS TT4. LSS MTEM.LSS RHOB .LOT QSS .LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL 5.742 20.000 14.828 129.250 111.500 1304.000 129.250 2.282 0.006 99.188 1545.000 12.195 0.563 2.911 2627.018 2750.000 5.793 2.0.000 11.461 128.500 102.750 1306. 000 128.500 2. 321 0.019 92. 375 1546.000 12.586 0.559 3.194 2144.625 2710. O00 4.449 20.000 17.656 128.5O0 109.250 1295.000 128.500 2.330 O.OiZ 94.514 1544.222 12.420 0.550 3.506 2102.625 2686.219 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 3700. 000 SFLU.OTE SP.OTE -34.406 ICPH.OTE CIDP.DTE 167.125 CIMP.DTE IIRM. OTE ! 76. 000 GR. OTE MRES.OTE 0.662 HTEN.DTE TT1.LSS 1391. 000 TT2.LSS SP.LSS -34.406 GR.LSS MRES.LSS 0.662 HTEN.LSS DRHO.LDT 0.012 PEF.LDT LS.LDT 356.750 LU.LDT SS1.LDT 213.375 SS2.LDT SIRH.LDT 2.254 LSRH.LDT GR.LDT 57.625 TENS.LOT HTEN.LDT 907. 500 NPHI.CNL NPOR.CNL 32.412 RCNT.CNL CFTC. CNL 766.494 GR.CNL MRES.CNL 0.556 MTEM.CNL DEPT. 3600.000 SFLU.OTE SP.DTE -19.266 IOPH.DTE CIDP.DTE 155.250 CIMP.DTE IIRM. DTE 156.7 50 GR.DTE MRES.OTE 0.672 HTEN.DTE TT1.LSS 1350. 000 TT2.LSS SP.LSS -19.266 GR.LSS MRES.LSS 0.672 HTEN.LSS DRHO.LDT 0.032 P EF.LDT LS.LDT 399'250 LU.LDT SS1.LDT 222.2 50 SS2.LDT SIRH.LDT 2. 146 LSRH.LDT GR.LDT 53.969 TENS.LDT HTEN. LDT 919.000 NPHI.CNL NPOR.CNL 41.628 RCNT.CNL CFTC.CNL 549.0 50 GR.CNL MRES.CNL 0.554 MTEM.CNL DEPT. 3500.000 SFLU.DTE SP.DTE -27.750 IDPH.DTE CIDP.OTE 143. 250 CIMP.DTE IIRM. DTE !48.750 GR.DTE MRES.DTE 0.677 HTEN.OTE TT1.LSS 1349.000 TT2.LSS SP.LSS -27.750 GR.LSS MRE$.LSS 0.677 HTEN.LSS DRHO.LDT 0.075 PEF.LDT LS.LDT 422.000 LU.LDT SS1.LDT 234. 625 SS2.LDT SIRH.LDT 2.041 LSRH.LDT GR.LDT 38.156 TENS.LDT HTEN.LDT 909-500 NPHI.CNL NPOR.CNL 39. 566 RCNT.CNL CFTC.CNL 519. 421 GR.CNL MRES.CNL 0.552 MTEM.CNL 29-JUN-1989 16:27 8.016 ILM.DTE 5.980 IMPH.DTE 166.375 IIRD.OTE 60.438 TENS.DTE -1403.000 DT.LSS 1138.000 TT3.LSS 60.438 TENS.LSS -1403.000 DPHI.LDT 2.725 GLS.LDT 334.750 LL.LDT 305.250 LSHV.LDT 2.303 LURH.LDT 2620.000 MTEM.LDT 31.825 TNPH.CNL 2642.802 RCFT.CNL 57.625 CALI.CNL 126.063 HTEN.CNL 4.848 ILM.DTE 6.438 IMPH.DTE 169.375 IIRD.DTE 55.406 TENS.DTE -1403.000 DT.LSS 1122.000 TT3oLSS 55.406 TENS.LSS -1~03.000 DPHI.LDT 3.191 QLS.LDT 370. 500 LL.LDT 319. 000 LSHV.LDT 2.Z36 LURHoLDT 2600.000 MTEM.LDT 42.855 TNPH.CNL 2135.425 RCFT.CNL 53.969 CALI.CNL 125.750 HTEN.CNL 5.227 ILM.DTE 6.977 IMPH.DTE 157.750 IIRD.DTE 35.719 TENS.DTE -1399.000 DT.LSS 1130'000 TT3.LSS 35. 719 TENS.L$S -1399.000 DPHI.LDT 3.209 QLS.LDT 1390. 750 LL.LOT 329.250 LSHV.LDT 2.205 LURHoLDT 253~+.000 MTEM.LDT 38.549 TNPH.CNL 1980. 055 RCFT.CNL 38.156 CALI.CNL 125.500 HTEN.CNL 5.344 6.008 150.125 2684.000 115.875 1654.000 268¢.000 19.667 -0.013 189.375 1451.000 2.299 126.063 33.363 736.448 12.391 907.500 6.008 5.898 140.000 2650.000 112.250 1612.000 2650.000 22.535 -0.011 213.875 1450.000 2.236 125.750 41.282 546.057 12.656 919.000 6.332 6.336 127.625 2574.000 116.750 1574.000 2574.000 21.801 -0.012 Z26.625 1450.000 2.203 I25.500 39.341 551.578 13.766 909.500 ILD.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE. DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LOT SSHV.LDT CALI.LOT M~ES.L~T TNRA.CNL C~TC.CNL TE~S.C~L ILD.DTE IFRE-DTE IIXD.DTE MT EM. DTE DTL.LSS TT4.LSS MTEM.LSS RHQB.LDT QSS.LDT L ITH. LOT SS)iV .LDT CALI.LDT MRES.LDT TNRA.CNL CNTC .CNL TENS.CNL PAGE: 30 5.785 20.000 15.461 128.125 115.000 1394.000 128.125 2.326 0.012 95.938 1544.000 12.391 0.556 3.085 2355.582 2620.000 6.289 20.000 8.633 127.750 108.750 1359.000 127.750 2.278 0.018 100.375 1543.000 12.656 0.554 3.712 1963.338 2600.000 6. 863 ZO. 000 8.719 126.625 116.500 1358.000 126.625 2.290 0.034 108.125 1544.0 O0 13.766 0.552 3.506 18:16-118 2534. 000 IS TAPE VERIFICATION LISTING CHLUNBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16=27 PAGE: 31 DEPT. 3400.000 SFLU.DTE SP.DTE -12.523 IgPH.OTE C!DP.DTE 156.750 CIMP.DTE IIRM. DTE 176.375 GR.DTE MRES.DTE 0.673 HTEN.DTE TTI.LSS 1353. 000 TT2.LSS SP.LSS -12.523 GR.LSS MRES.LSS 0,,,673 HTEN.LSS DRHO.LOT 0.067 PEF.LDT LS.LDT 376.500 LU.LDT SSI.LOT 229. 250 S S2.LDT SZRH.LDT 2.119 LSRH.LDT GR.LDT 58. 500 TENS.LOT HTEN.LDT 899.500 NPNT.CNL NPOR.CNL 42.473 RCNT.CNL CFTC.CNL 509.390 GR.CNL MRES.CNL 0.556 MTEM.CNL DEPT. 3300.000 SFLU.DTE SP.DTE -1.665 IDPH.OTE CIDP.DTE 98.563 CIMP.DTE IIRM.OTE 129.750 GR.DTE MRES.DTE 0.681 HTEN.DTE TT1.LSS 1482.000 TT2.LSS SP.LSS -1.665 GR.LSS MRES.LSS 0.681 HTEN.LSS DRHO.LOT O. 071 PEF.LOT LS.LDT 1134.000 LU.LDT SS1.LOT 254.125 SS2.LDT SIRH.LDT 1.479 LSRHoLDT GR.LOT 56.125 TENS.LOT HTEN.LDT 921'500 NPH[.CNL NPOR.CNL 42.937 RCNT.CNL CFTC.CNL 438,. 262 GR.CNL MRES.CNL 0.563 MTEM.CNL DEPT. 3200.000 SFLU.DTE SP.OT~ -11.406 IDPH.DTE CIOP.DTE 205.750 CIMP.OTE IIRM.OTE 210.. 125 GR.DTE MRES.DTE 0.685 HTEN.DTE TT1.LSS 1409.000 TT2.LSS SP.LSS -11'406 GR-LSS NRES.LSS O. 685 HTEN.LSS DRHO.LDT 0.013 PEF.LOT LS.LOT ' 370.320 LU.LOT SSI .LOT 215. 268 SS2.LOT S1RH.LDT 2.222 LSRH.LOT GR.LDT 61.116 TENS.LOT HTEN.LDT 924.355, NPHI.CNL NPOR.CNL 42.309 RCNT'CNL CFTC.CN.L 557.152 GR. CNL MRES.CNL 0.572 MTEM.CNL ¢.395 TLM. DTE 6.379 IMPH.DTE 185.125 IIRD.DTE 50.406 TENS.DTE -1403.000 DT.LSS 1130.000 TT3.LSS 50.406 TENS.LSS -1403.000 DPHI.LOT 3.223 QLS.LDT 350.250 LL.LOT 324.500 LSHV.LDT 2. 268 LURH.LDT 2490.000 MTEM.LDT 41.459 TNPH.CNL 2008.631 RCFT.CNL 58.500 CALI.CNL 125.250 HTEN.CNL 5.992 ILM. DTE 10.141 IMPH.DTE 123.313 IIRO.DTE 45.313 TENS.DTE -1399.000 DT.LSS 1224.000 TT3-LSS 45.313 TENS.LSS -1399.000 DPHI.LOT 2.461 QLS.LDT 1005. 500 LL.LOT 411. 750 LSHV.LOT 1.536 LURH.LOT 2480. 000 MTEM. LOT 4'6. 878 TNPH.CNL 1873.985 RCFT.CNL 56.125 CALI.CNL 124. 125 HTEN. CNL 223. 60' -1399. 1177. 60. -1399. 3. 345. 310. 2. 2~36. 2191. 61. I22. 043 ILM.DTE 855 IMPH.DTE 125 IIRD.DTE 844 TENS.OTE 000 DT.LSS 000 TT3.LSS 844 TENS.LSS 000 DPHI'LDT 526 QLS.LDT 072 LL.LDT 393 LSHV.LDT 276 LURH.LOT 859 MTEM.LDT 542 TNPH.CNL 773 RCFT. CNL 116 CALI.CNL 438 HTEN.CNL 5.332 5.398 139.875 2514.000 112.500 1558.000 2514.000 18.396 -0.005 201.500 1449.000 2.270 125.250 41.978 526.134 13.172 899.500 7.273 8.102 94.875 2474.000 124.000 1754.000 2474.000 56.842 -0.031 631.000 1449.000 1.635 12~.125 44.412 436.246 13.289 921.500 4.465 4.480 179.500 2470.000 118.500 1594.000 2470.000 21.181 -0.007 197.910 1449.000 2.279 122.438 41.994 559.016 12.502 924.355' ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB.LOT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT ~RES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILO.OTE IFRE.OTE IIXO.OTE NTEM.DTE OTL.LSS TT4.LSS MTEM.LSS RHOB..LDT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRES..LDT TNRA.CNL CNTC.CNL TENS.CNL 6.262 20.000 11.406 126.625 112.250 1358.000 126.625 2.346 0.020 93.625 1543.000 13.172 0.556 3.649 1852.330 2490.000 9.617 20.000 6.758 126.375 122.500 1484.000 126.375 1.712 0.004 525.500 1543.000 13.289 0.563 3.948 1659.619 2480.000 4.738 20.000 16.141 126.188 120.000 1416.000 126.188 2.301 0.010 85.93B 1542'000 12.502 0.572 3.691 2013.516 2436.859 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 16:27 PAGE: 32 DEPT. 3100.000 SFLU.DTE SP.DTE -31. 563 IDPH.DTE CIDP.OTE 382.000 CIMP.OTE IIRM. DTE 328.250 GR.DTE MRES.DTE 0.694 HTEN.DTE TT1.LSS 1427. 000 TT2.LSS SO.LSS -31.563 GR.LSS MRES.LSS 0.694 HTEN.LSS DRHO.LDT 0.004 PEF.LDT LS.LDT 424.750 LU.LDT SS1.LDT 214. 000 SSI.LOT S1RH.LDT 2.184 LSRH.LDT GR.LDT 44.063 TENS.LDT HTEN.LOT 9'38. 500 NPH!.CNL NPOR.CNL 35.499 RCNT.CNL CFTC.CNL 731. 888 GR.CNL MRES.CNL 0.572 MTEM.CNL DEPT. 3000.000 SFLU.DTE SP.DTE -23.500 IDPH.OTE CIDP.DTE 229.375 CIMP.DTE IIRM. OTE 211.750 GR.DTE MRES.OTE 0.694 HTEN.DTE TT1.LSS 1404.000 TT2.LSS SP.LSS -23.500 GR.LSS MRES.LSS 0.694 HTEN.LSS DRHO.LDT 0.004 PEF.LOT LS.LDT 399.750 LUoLDT SSI.LOT 212.375 SS2.LOT S.1RH.LDT 2.217 LSRH.LOT GR.LDT 56.406 TENS.LOT HTEN.LDT 896'500 NPHI.CNL NPOR'CNL 38.014 RCNT.CNL CFTC.CNL 666.063 GR.CNL MRES.CNL 0.593 MTEM.CNL 3.115 ILM.DTE 2.832 ILD.DTE 2.553 2.615 IMPH.DTE 2.824 IFRE.DTE 20.000 354.000 IIRD.DTE 318.500 IIXD.DTE 45.156 38.375 TENS.DTE 2420.000 MTEM. DTE 125.563 -1403.000 OT.LSS 126'250 DTL.LSS 123.250 1199.000 TT3.LSS 1669.000 TT4.LSS 1435.000 38.375 TENS.LSS 2420.000 MTEM.LSS 125.563 -1403.000 DPHI.LOT 26.277 RHOB.LDT 2.216 3.098 QLS.LOT 0.012 QSS.LDT 0.005 385.750 LL.LOT 231.875 LITM.LDT 112.813 315.500 LSHV.LDT 1449.000 SSHV.LOT 1541.000 2.201 LURH.LDT 2.211 CALI.LDT 12.484 2414.000 MTEM.LDT 122.188 MRES.LDT 0.572 32.370 TNPH. CNL 34.640 TNRA.CNL 3.t24 2480.947 RCFT.CNL 718.030 CNTC.CNL 2311.159 44.063 CALI.CNL 12.484 TENS.CNL 2414.000 122.188 HTEN.CNL 938.500 4.094 ILM. DTE 4.430 ILO.DTE 4.258 4.355 IMPH.OTE 4.477 IFRE.DTE 20.000 223.250 IIRD.DTE 200.875 IIXD.OTE 21.922 58.500 TENS.DTE 2390.000, MTEM.DTE 125.250 -1402.000 OT.LSS 119.250 OTL.LSS 118.250 1172.000 TT3.LSS 1661.000 TT4.LSS 1408.000 58.500 TENS.LSS 2390.000 MTEM.LSS 125.250 -1402.000 DPHI.LDT 24.328 RHQB.LDT 2.249 3.135 QLS.LDT -0.012 QSS.LDT 0.006 371.250 LL.LDT 214.125 L[?H.LOT 97.563 310.500 LSHV.LDT 1448.000 SSHV.LDT 1541.000 2.234 LURH.LOT 2.234 CALI.LDT 12.297 2314.000 MTEM.LDT 122.438 MRES.LDT 0.593 37.243 TNPH.CNL 37.475 TNRA.CNL 3.396 2399.666 RCFT.CNL 659.892 CNTC.CNL 2217.054 56.406 CALI.CNL 12.297 TENS.CNL 2314.000 122.438 HTEN.CNL 896.500 DEPT. 2900.000 SFLU.DTE 4..325 ILM. DTE 4.961 - ILD.DTE 5.602 SP.DTE -18.203 IOPH.DTE 5.785 IMPH.DTE 5.012 IFRE.OTE 20.000 CIDP.DTE 172.750 CIMP.DTE 199.375 IIRD.DTE 154.375 IIXO.DTE 11.727 IIRM.OTE 189.375 GR.§TE 51.781 TENS.DTE 2330.000 MTEMoDTE 125.000 MRES.DTE 0.691 HTEN.OTE -1399'000 DT.LSS 122.250 OTLoLSS 122.250 TT1.LSS 1431.000 TT2.LSS 1191.000 TT3.LSS 1680.000 TT¢.LSS 1438.000 SP.LSS -18.203 GR.LSS 51'781 TENS.LSS 2330.000 MTEM.LSS 125.000 MRES.LSS 0.691 HTEN.LSS -1399'000 DPHI.LOT .23.701 RHQB-LDT 2.259 DRHO.LDT 0.059 PEF.LOT 3.201 QLS,LOT -0.009 QSS.LDT 0.023 LS.LDT 432.672 LU.:LDT 399.031 LL.LOT 233.176 LITH.LDT 106.830 SS1.LDT 231.285 SS2.LDT 331.393 LSHV.LOT 1448.000 SSHV.LDT 1541.000 S1RH.LDT 2.054 LSRH.LOT 2.189 LURH.LDT 2.191 CALI.LDT 12.704 GR.LDT 53.406 TENS.LDT 2274.859 MTEM.LOT 122.188 MRES.LDT 0.593 HTEN. LD'T 913.000 NPHI.CNL 45.506 TNPH.CNL 43.623 TNRA.CNL 3.858 NPOR.CNL 44.601 RCNT.CNL 2104.375 RCFT.CNL 52~.031 CNTC.CNL 1958.379 CFTC.CNL 526-545 GR.CNL 53.406 CALI.CNL 12'704 TE~S.CNL 2274.859 MRES.CNL 0.593 MTEM.CNL 122.188 HTEN.CNL 913.000 ,IS TAPE VERIFICATION LISTING 29-JUN-1989 16:27 PAGE: ;CHLUMBERGER ALASKA COMPUTING CENTER 33 DEPT. 2800.000 SFLU.DTE 4.777 ILM.DTE 5.410 ILD.DTE 5.918 SP.DTE -19.906 IDPH.DTE 5.965 IMPH.DTE 5.434 IFRE.DTE 20.000 CIOP.DTE 167.625 CIMP.DTE 183.875 IIRD.DTE 147.375 IIXO.DTE 9.672 IIRM.DTE 173.875 GR.DTE 53.813 TENS.DTE 2294.000 MTEM.DTE 124.688 MRES.OTE 0.695 HTEN.DTE -1404.000 OT.LSS 123.750 DTL.LSS 123.250 TT1.LSS 1413.000 TT2.LSS 1198.000 TT3.LSS 1648.000 TT4.LSS 1418.000 SP.LSS -19.906 GR.LSS 53.813 TENS.LSS 2294.000 MTEM.LSS 124.688 MRES.LSS 0.695 HTEN.LSS -1404.000 DPHI.LDT 25.332 RHOS.LOT 2.232 DRHO.LDT 0.010 PEF.LDT 2.992 QLS.LDT 0.001 QSS.LDT 0.021 LS.LDT 416.750 LU.LOT 382.000 LL.LDT 225.875 LITH.LDT 107.250 SSI.LOT 216.675 SS2.LDT 312.000 LSHV.LDT 1448.000 SSHV.LDT 1540.000 SIRH.LDT 2.172 LSRH.LDT 2.211 LURH.LDT 2-217 CALI.LDT 12.297 GR.LDT 55.156 TENS.LOT 2254.000 MTEM.LDT 121.688 MRES.LDT 0.595 HTEN.LDT 925.500 NPHI.CNL 37.083 TNPH.CNL 37.550 TNRA.CNL 3.387 NPOR.CNL 37.060 RCNT.CNL 2443.744 RCFT.CNL 701.413 CNTC.CNL 2205.531 CFTCoCNL 661.673 GR.CNL 55.156 CALI.CNL 12.297 TENS.CNL 2254.000 MRES.CNL 0.595 MTEM.CNL 121.688 HTEN.CNL 925.500 DEPT. 2700.000 SFLU.DTE 16.734 ILM.DTE 11.820 ILO.DTE 13.211 SP.DTE -37.094 IDPH.DTE 13.758 IMPH. DTE 13.141 IFRE.DTE 20.000 CIDP.DTE 72.625 CIMP.OTE 76.063 IIRD.DTE 71.063 IIXD.DTE 4.957 IIRM.OTE $0.125 GR.OTE 33.813 TENS.OTE 2270.000 MTEM.DTE 124.375 MRES.DTE 0.696 HTEN.DTE -1400.000 DT.LSS 140.000 DTL.LSS 139.000 TT1.LSS 1590.000 TT2.LSS 1315.000 TT3.LSS 1862.000 TT4.LSS 1597.000 SP.LSS -37.094 GR.LSS 33.813 TENS.LSS 2270.000 MTEM.LSS 124.375 MRES. LSS 0.696 HTEN.LSS -1400.000 DPHI.LDT 59.800 RHOB.LDT 1.663 DRHD.LDT 0.013 PEF.LDT 1. 706 QLS.LOT ,-0.029 QSS.LDT 0.018 LS.LDT 1108.000 LU.LDT 980.500 LL.LDT 618.500 LITH.LDT 449.500 SS1.LDT 237.500 SS2.LOT 379.750 LSHV.LDT 1444.000 SSHV.LDT 1540.000 SIRH.LDT 1.593 LSRH.LDT 1.646 LURH.LDT 1.649 CALI.LDT 12.297 GR.LDT 33.781 TENS.LOT 2190.000 MTEM.LDT 121.063 MRES.LDT 0.596 HTEN.LDT 896.500 NPHI.CNL 68.418 TNPH. CNL 86.255 TNRA.CNL 5.099 NPOR.CNL 84.786 RCNT.CNL 1669.728 RCFT.CNL 304.164 CNTC.CNL 1497.324 CFTC.CNL 298.127 GR.CNL 33.781 CALI.CNL 12.297 TENS.CNL 2190.000 MRES.CNL 0.596 MTEM.CNL 121.063 HTEN.CNL 896.500 DEPT. 2600.000 SFLU.DTE 5.680 ILM.DTE 7.375 ILD.DTE 8.297 SP.DTE -22'906 IDPH.OTE 8.656 IMPH.DTE 7..125 IFRE.OTE 20.000 CIDP.DTE 115.438 CIMP.DTE 140.250 IIRD.DTE 107.813 IIXD.DTE 7.730 IIRM.DTE 128.000 GR.DTE 48.125 TENS.DTE 2210.000 MTEM.OTE 124.000 MRES.DTE 0.691 HTEN.DTE -1400.000 DT.LSS 121.000 DTL.LSS 117.750 TT1.LSS 15137. 000 TT2.LSS 1268.000 TT3.LSS 1824.000 TT4.LSS 1542.000 SP.LSS -22.906 GR.LSS 48.125 TENS'LSS 2210.000 MTEM.LSS 124.000 MRES.LSS 0.691 HTEN.LSS -]1400.000 DPHI.LOT 28.442 RHOB.LDT 2.181 ORHO.LOT 0.031 PEF.LDT 3.282 QLS.LDT 0.018 QSS.LDT 0.008 LSoLDT 479.750 LU.LDT 430.000 LL.LDT 264.750 LITH.LDT 149.594 SSI.LOT 226°390 SS2.LDT 335.336 LSHV.:LDT 1447.000 SSHV.LOT 1540.000 SIRH.LOT 2.054 LSRH.LOT 2.140 LURH.LDT 2.I49 CALI,LDT 12.307 GR.LDT 48.215 TENS..LO'T 2159.332 MTEM.LOT 119.882 MRES.LDT 0.594 HTEN.LDT 909.777 NPHI.CNL 4,¢. 921 TNPH.CNL 42.779 TNRAoCNL 3.816 NPOR.CNL 39.380 RCNT.CNL 2Y+71. 250 RCFT.CNL 608.781 CNTC.CNL 2097.125 CFTC.CNL 573.891 GR.CNL 48.215 CALI.CNL 12.307 TENS'CNL 2159.332 MRES.CNL 0.594 MTEM.CNL 119.882 HTEN.CNL 909.777 ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER aLASKA COMPUTING CENTER DEPT. 2500.000 SFLU.OTE SP.DTE -21.734 IDPH.DTE CIDP.DTE 135.625 CIMP.DTE IIRM.DTE 128. 125 GR.DTE MRES.DTE 0.688 HTEN.OTE TT1.LSS 1344.0 O0 TT2.LSS SP.LSS -21.734 GR.LSS MRES.LSS 0.688 HTEN.LSS DRHO.LDT 0.027 PEF.LDT LS.LDT 379.250 LU.LDT SS1.LDT 219.625 SS2.LOT S1RH.LDT 2.184 LSRH.LDT GR.LOT 58.688 TENS.LOT HTEN.LDT 916.500 NPHI.CNL NPOR.CNL 42.141 RCNT.CNL CFTC.CNL 605. 040 GR.CNL MRES.CNL 0.593 MTEM.CNL DEPT. 2400.000 SFLU.OTE SP.DTE -174.375 IDPH.DTE CIDP.DTE 56.406 CIMP.DTE IIRM.DTE 30.9'38 GR.OTE MRES.DTE 0.689 HTEN.DTE TTI.LSS 801. 000 TTZ.LSS SP.LSS -174.375 GR.LSS MRES.LSS 0.689 HTEN.LSS ORHO.LDT -999.2 50 PEF..LOT LS.LDT -999.250 LU.LDT SS1.LDT -999.250 SS2.LDT S1RH.LDT -999.250 LSRH.LOT GR.LDT -999.250 TENS.LOT HTEN.LDT -999.250 NPHI.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL MRES.CNL -999.250 MTEM.CNL DEPT. 2396.000 SFLU.DTE SP.DTE -174.375 IDPH.DTE CIDP.DTE 57.125 CIMP.DTE IIRM.DTE 30.938 GR.DTE MRES.DTE 0.689 HTEN.DTE TTI.LSS 801. 000 TTZ.LSS SP.LSS -174. 375 GR.LSS MRES.LSS 0.689 HTEN.LSS DRHO.LOT -999.250 PEF.LDT LS.LDT -999. 250 LU.LDT SS1.LOT -999.2 50 $.SZ.LOT SIRH.LDT -999.250 LSRH.LOT GR.LDT -999.250 TENS.LOT HTEN.LDT -999. 250 NPHI.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL MRES.CNL -999.250 MTEM.CNL 29-JUN-1989 16:27 8.969 ILM.DTE 7.367 IMPH.DTE 141.625 IIRD.DTE 47.250 TENS.OTC -1402.000 DT.LSS 1084.000 TT3.LSS 47.250 TENS.LSS -1402.000 OPHI.LDT 3.594 QLS.LDT 351.000 LL.LOT 307.750 LSHV.LDT 2.264 LURH.LDT 2124.000 MTEM.LOT 39.431 TNPH.CNL 2213.479 RCFT.CNL 58.688 CALI.CNL 119.625 HTEN.CNL 9696.000 ILM.DTE 17.719 IMPH.DTE 31.625 IIRD.DTE 29.328 TENS.DTE -1401.000 DToLSS 693.000 TT3.LSS 29.328 TENS.LSS -1401.000 OPHI.LDT -999.250 QLS.LDT -999.250 LL.LDT -999.250 LSHV.LOT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999,250 C~LI.CNL -999.250 HTEN.CNL 9696.000 ILM.DTE 17.484 IMPH.DTE 31.594 IIRD.DTE 29.328 TENS.DTE -1401. OOO DT.LSS 693.000 TT3.LSS 29.32:8 TENS.LSS -1401.000 OPHIoLOT · -999. 250 QLS.LOT -999. 250 LL.LDT -999.250 LSHV.LOT -999.250 LURH.LOT -999. 250 MTEM-LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 CALI.CNL -999.250 HTEN.CNL 7.367 7.059 126.500 2184.000 114.500 1590.000 2184.000 21.171 0.000 203.875 1447.000 Z.270 119.625 40.000 632.131 12.586 916.500 30.734 31.609 52.219 2180.000 5~.625 914.500 2180.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.,250 -999. 250 -999.250 30.734 31.625 5Z,.219 2180.000 54.625 914. 500 2180.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 ILO.OTE IFRE.DTE IIXD.DTE MTEM.OTE DTL.LSS TT4. LSS. MTEM.LSS RHOB .LOT QSS.LOT LITH.LDT SSHV.LDT CALI.LDT MRES.LOT TNRA.CNL CNTC.CNL TENS.CNL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.LSS TT4.LSS MTEM.LSS RHOB .LOT QSS.LDT LITH.LDT SSHV.LDT C AL I. LOT MRES.LDT TNRA.CNL CNTC.CNL TENS.CNL ILD.OTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.LSS TT4 .LSS MTEM.LSS RHOB .LDT QSS.LDT LITH.LDT SSH¥.LDT CALI.LDT MRES.LOT TNRA .CNL CNTC.CNL TENS.CNL PAGE: 34 7.117 20.000 12.000 123.500 114.000 1354.000 123.500 2.301 0.032 89.500 1539.000 12.586 0.593 3.523 2114.654 2124.000 17.266 20.000 26.219 124.125 56.125 803.500 124.1Z5 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999-250 -999.250 -999.250 17.250 20°000 26.219 124.250 56.125 803.500 124.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 29-JUN-1989 ~6:27 PAGE: 35 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT o001 SERVICE : FLIC VERSION : O01A02 DATE : 89/06/29 MAX AEC SIZE : 1096 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAPE : EDIT DATE : ~9/06/Z9 ORIGIN : FIIC TAPE NAME : 7338! CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : MARATHON, MCARTHUR RIVER, TBU 0-45, API a50-733-20150-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 89/06/29 ORIGIN : FLIC REEL NAME : 73381 CONTINUATION ~ : PREVIOUS REEL : COMMENT : MARATHON, MCARTHUR RIVER, ~TBU 0-~5, API ~50-733-20!50-0!