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188-038
• STATE OF ALASKA AL._.:A OIL AND GAS CONSERVATION COMN...,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations El Perforate❑ Other D Install ESP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number Name: Hilcorp Alaska,LLC Development[] Exploratory❑ 188-038 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphiC❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20111-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St/A-16RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay/Middle Kenai D Oil,Hemlock Oil,Middle Kenai C Oil,West Foreland,Middle Kenai B Oil 11.Present Well Condition Summary: RECEIVED Total Depth measured 6,844 feet Plugs measured N/A feet true vertical 6,439 feet Junk measured N/A feet MAR 19 2015 Effective Depth measured 6,730 feet Packer measured 351 feet AOGCC true vertical 6,331 feet true vertical 351 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 10,059' 13-3/8" 10,059' 10,042' 3,090 psi 1,540 psi Intermediate 6,814' 9-5/8" 6,814' 6,411' 6,870 psi 4,760 psi Production Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8 6.5#L-80 5,727'(MD) 5,384'(TVD) 351"(MD) 299'(MD) Packers and SSSV(type,measured and true vertical depth) Dual ESP Pkr 351'(TVD) SSSV 299'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 193 250 633 730 115 Subsequent to operation: 230 333 963 760 240 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development l] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil EI Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ 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: 315-057 Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature J1 t ti7212-61— Phone (907)777-8323 Date 3/18/2015 Form 10-404 Revised 10/2012 ,/y// 4,Zf„l ,, // Submit Original Only %L/L� RBDMS, APR - 3 2015 Trading Bay Unit ` SCHEMATIC Monopod Platform Well #A-16RD API #50-733-20111-01 Completed: 02/19/15 RKB to TBG Hngr=40.08' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" _ 61 K-55 Butt 12.515 Surf. 1059' J 1 9-5/8" 47.0 N-80&5-95 8rd LT&C 8.681 Surf 6814' 2 Tubing: _ 2-7/8" 6.5 L-80 8rd EUE Surf 5727' JEWELRY DETAIL NO. Depth ID Item 40.8' Tubing Hanger 3 1 299' 2.313 SSSV 2 351' 2.980 Packer w/Vent valve 3 2,104' 2.441 GLM 4 4 3,408' 2.441 GLM 5 4,302' 2.441 GLM 6 4,695' _ 2.441 GLM 7 5,727' - Discharge 8 5,728' - Pump(x4) 9 5,816' - Intake 5 10 5,837' - Motor(x2) 11 5,905' - Bottom of ESP Perforation Detail Top Btm Top Btm Accum. Date Present Zone (MD) (MD) (ND) (ND) Amt. SPF Last Opr. Condition C-2 4,752' 4,774' 4,477' 4,498' 22' 5 10/31/13 Open f/prod. C 48-7 4,957' 4,968' 4,667' 4,677' 11' 5 10/31/13 Open f/prod. 6 C 50-0 5,118' 5,132' 4,816' 4,829' 14' 5 10/31/13 Open f/prod. C 50-3 5,145' 5,158' 4,841' 4,853' 13' 5 10/31/13 Open f/prod. C 50-6 5,234' 5,241' 4,923' 4,930' 7' 5 10/31/13 Open f/prod. C 51-6 5,308' 5,380' 4,992' 5,059' 72' 5 10/31/13 Open f/prod. D 53-0 5,460' 5,495' 5,134' 5,167' 35' 5 10/31/13 Open f/prod. DZN 2 5,530' 5,543' 5,199' 5,211' 13' 5 10/31/13 Open f/prod. I D 53-8 5,556' 5,602' 5,224' 5,267' 46' 5 10/31/13 Open f/prod. D 54-5 5,626' 5,642' 5,289' 5,304' 16' 5 10/31/13 Open f/prod. D 54-9 5,654' 5,710' 5,316' 5,368' 56' 5 10/31/13 Open f/prod. , = D 55-7 5,729' 5,763' 5,386' 5,418' 34' 5 10/31/13 Open f/prod. D 56-1 5,779' 5,817' 5,433' 5,469' 38' 5 10/31/13 Open f/prod. D 57-2 5,902' 5,975' 5,549' 5,618' 73' 5 10/31/13 Open f/prod. C Zone E 58-1 5,992' 6,010' 5,634' 5,650' 18' 5 10/31/13 Open f/prod. E 58-1 6,020' 6,035' 5,660' 5,674' 15' 5 10/31/13 Open f/prod. E 58-7 6,060' 6,120' 5,698' 5,754' 60' 5 10/31/13 Open f/prod. E(58-1) 6,020' 6,030' 5,660' 5,669' 10' 8 12/3/1988 Open f/prod. E 60-0 6,156' 6,190' 5,788' 5,820' 34' 5 10/31/13 Open f/prod. E(60-0) 6,159' 6,190' 5,791' 5,820' 31' 8 12/3/1988 Open f/prod. E 61-1 6,284' 6,293' 5,909' 5,918' 9' 5 10/31/13 Open f/prod. j = HEM 6,308' 6,560' 5,932' 6,170' 252' 5 10/31/13 Open f/prod. , Hemlock 6,308' 6,631' 5,932' 6,238' 323' 8 10/24/1988 Open f/prod. i 7 = Hemlock 6,308' 6,325' 5,932' 5,948' 17' 12 2/4/1997 Open f/prod. if D Zone 8 = Hemlock 6,350' 6,385' 5,972' 6,005' 35' 12 2/4/1997 Open f/prod. Hemlock 6,440' 6,460' 6,057' 6,076' 20' 12 2/3/1997 Open f/prod. MIT 9 Hemlock 6,480' 6,503' 6,095' 6,116' 23' 12 2/3/1997 Open f/prod. II10 = WFLND 6,650' 6,673' 6,255' 6,277' 27' 5 10/31/13 Open f/prod. 11 = I = E Zone Hemlock West Foreland KB ELEV=101' PBTD=6730' TD=6,844' ANGLE thru INTERVAL=21.1° Updated by: JLL 03/18/15 Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 2/10/2015 2/20/2015 �y i x 7♦ ;yf'+ 7& mm,;,} rj, "k A x x r ;,�&�r: ":a''& y Xw y r+ " „A; �t:�'. � x�r�E°Y� .a 3i �� `S.ii� rt. : 2�s.. kF:.;a,�a..„. ",`,^„,�.^",'�,7^.�^�o� xWsK .�.'. 02/10/15-Tuesday Disconnect control lines and circulating lines from tree.Set BPV. Nipple down tree.Rig down circulating manifold.Dress hanger control lines.Install blanking plug. Install riser.Nipple up BOPE. 02/11/15-Wednesday Continue Nipple up BOPE and associated equipment.Chg/out saver sub t/4-1/2”IF.Chg/out whip line on Sea Trax crane.House clean work areas. Build 5"test jt and r/up test equipment.Perform shell test 250-2500 psi.Chg out test manifold.1/4 turn isolation valve and dart valve leaked,go to FOSV and bring back up dart valve to rig floor while waiting on State man.Continue chg/out of whip line on Sea Trax crane. Daily fluid loss=415 bbls 3%8.6 KCL.Total Fluid Loss to Well=1255 bbls 3%8.6 KCL. Average Daily Loss Rate=N/A BPH.Sized Salt Pill=40 bbls.Total Sized salt=160 bbls. Annulus Pressures:20"X 13-3/8"=20 psi,13-3/8"x 9-5/8"=170 psi. Start BOPE as per AOGCC regulations 250-2500 psi,while State inspector Johnny Hill is in route to location.Continue w/annual Inspections of cranes.AOGCC inspector,Johnny Hill on location.Received safety/orientation briefing and joined test in progress.Reviewed crews, JSA and charts of 8 test performed.Finish testing on 5"performed Koomey test and chg/out test jt t/3-1/2".Finish testing same. Tested all gas alarm w/no failures.Released State man to production for M.I.T test. Remove LH blanking plug (stack did not drain).L/dn test tool.L/dn 3-1/2"test jt.R/dn test equipment. R/up circ lines in well room and test same t/250-1500(ok). Close blind rams.Circulate 30 bbls down tubing to overcome 370 psi below BPV.Pull BPV.Make up landing joint. Circulate well to production at 3 BPM/60 psi ICP-160 psi FCP.Caught oil returns at 150 bbls pumped and clean fluid at 220 bbls pumped.Pumped a total of 330 bbls(STS)before shutting down. Monitor shut in well for one hour to establish loss rate.Bring pump on at 3 BPM/60 psi ICP-160 psi FCP taking returns to production.Caught oil returns at 119 bbls pumped and clean fluid returns at 130 bbls pumped.Shut down and shut in annulus.Loss rate 119 BPH. Lay down 3 1/2"drill pipe landing joint(ID too small for slick line tools).Make up 3 1/2"tubing landing joint with 3 1/2"8rd FOSV.Rig up slick line.Test lubricator at 250 L/1500 H.RIH with 2.75 GR to 4,439'.RIH with GS tool and pull plug in'Y'block at 4,439'WLM.Rig down slick line. Change out landing joints back to 3 1/2"drill pipe.Pump 40 bbl SS pill and chase with 40 bbl KCL at 3 BPM/70 psi with annulus shut. Monitor well while allowing pill to soak. 02/12/15-Thursday Sweep well to production at 3 BPM 50 psi ICP-165 FCP for 60 bbls total.Caught oil returns at 43 bbls pumped and clean KCL at 52 bbls pumped. Shut down.Loss rate 43 BPH.Continue assisting w/annual inspection of cranes. Keep tubing full with charge pump to establish hour loss rate @ 95> 75 bph.Continue and finish building#5 sized salt pill. Pump#5,40 bbl Sized salt pill @ 3 bpm ICP 230 psi FCP @ 100 Psi with 9-5/8"from 0<165 psi to slight vacuum in 1 hr.Chase pill clear lines w/8 bbls brine. Oil states found serious issue w/Boom hoist gear box(Very high metal content in oil) And taking Sea trax crane out of service for normal operations.Chasing parts and repair plan. Continue monitor well and let pill soak.Build pill#6. Continue chasing parts and repair plan for Boom hoist chg out.Rearrange pipe rack for link belt(west crane operations only)for ESP pull and DP P/up.Rig maintenance and house keeping.Crane parts on location chk for correct(ok). Daily fluid loss=753 bbls 3%8.6 KCL.Total Fluid Loss to Well =2008 bbls 3%8.6 KCL. Average Daily Loss Rate=N/A BPH.Sized Salt Pill=120 bbls.Total Sized salt=240 bbls.Annulus Pressures:20"X 13-3/8"= 20 psi,13-3/8"x 9-5/8"=170 psi. Finish work on Koomey unit and function test(ok). Sweep well to production at 3 BPM.Caught returns at 30 bbls pumped.Pumped a total of 50 bbls. Back out lock down screws.Pull hanger loose&up 20'to clear seals.92 K to pull hanger and up hole. Fill well establish loss rate @ 98 BPH.Circulate well through gas buster at 4 BPM/200 psi.High gas of 595 units at bottoms up and stabilizing at 300 units after second STS volume pumped.Loss rate remaining steady at 58 BPH.Shut down.Allow gas buster to drain.Open annular preventer. Pump 40 bbl SS pill#6 and chase with 10 bbls 3%KCL.Keep hole full through kill line allowing pill to'soak'.Establish loss rate at 25 BPH.Mix SS pill#7. Circulate well at 4 BPM/200 psi.Max gas 261 units and stabilized at 52 units.17 BPH fluid loss rate. Pull tubing hanger to rig floor.Lay down tubing hanger and landing joint.Blow down TDS.Change dies in pipe handler and break out 10'pup joint. Hold PJSM with all to be involved in laying down completion string.POOH laying down 3 joints of tubing.Hang sheaves. Hilcorp Alaska, LLC HilcorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16R0 50-733-20111-01 188-038 2/10/2015 2/20/2015 Daily Operations: 02/13/15-Friday Continue POOH laying down 3-1/2"RTS-8 gas lift/ESP"V"block completion string.No anomalies or norm recorded above back ground. Loss rate Avg =24 bph.Continue with cosmetic work of replacement of Boom hoist gear box on Seatrax and continue w/annual inspections of both cranes. Crew chg.PTSM review bare pipe shut in procedure.L/dn last 3 jts 3-1/2"tbg and prep floor for L/dn of"V"Block ESP and Bypass string L/dn.Loss rate Avg =28.8 bph. Separate"V"block from 2-7/8"bypass string and I/dn ESP and bypass string as duals.Recovered 79 cannon clamps,6 motor clamps and 44 bands.37 BPH loss rate. Daily fluid loss=753 bbls 3%8.6 KCL.Total Fluid Loss to Well=2761 bbls 3%8.6 KCL. Average Daily Loss Rate=31.3 BPH.Sized Salt Pill=0 bbls.Total Sized salt=240 bbls.Annulus Pressures:20"X 13-3/8"=20 psi,13-3/8"x 9-5/8"=170 psi. Organize and clean rig floor,pipe deck,stairs,handrails and camp areas.Offload/back load work boat.Install wear ring(9"ID).Build 3%KCL volume.Remove ratcheting mule shoe from seal assembly.Service TOS and equipment.42 BPH loss rate. Pick up BHA#1:Packer mill,triple combo sub,4 boot baskets,bit sub, BS/OJ,string magnet,pump out sub,X0,9 ea 61/2"DC's,XO,Acc Jars=346.39. 48 BPH loss rate. 02/14/15-Saturday RIH w/BHA#1.P/up rabbit and strapping 5"S-135 DP 19.5#f/346't/4,700'w/loss rate Up t/48 BPH. Tag Prk @ 4,712'DPM.Kelly up and circ btm @ 12 bpm @ 1540 psi and establish parameters.Loss rate @ 79 BPH. Mill on prk f/4,710't/4,714'@ 2-40k WOB @ 8 bpm @ 710 psi and 90 rpm w/ 12k off btm TQ w/loss rate ranging f/30-160 BPH. Circulate out tail pipe gas at 5 BPM/330 psi.High gas of 470 units.70 BPH loss rate while circulating gas out. Push packer down hole to 4,795'.Spot 40 bbl sized salt pill.Loss rate 35 BPH. Daily fluid loss=1377 bbls 3%8.6 KCL.Total Fluid Loss to Well=4138 bbls 3%8.6 KCL. Average Daily Loss Rate=57.3 BPH.Sized Salt Pill=40 bbls.Total Sized salt=280 bbls.30 lbs metal off ditch magnets.Annulus Pressures:20"X 13-3/8"=20 psi,13-3/8"x 9-5/8"=170 psi. POOH 10 stands.RIH picking up 30 joints of drill pipe.Loss rate 32 BPH. RIH on elevators with stands out of the derrick from 4,795'to 5,740'without issue.Loss rate 12 BPH. Circulate bottoms up at 5 BPM/330 psi. Max gas 610 units.Loss rate 20 BPH while circulating. RIH picking up 5"drill pipe from 5,740'to 6,299'. Tagged top of fish.Loss rate 13 BPH. Kelly up.Mill/push fish from 6,299'to 6,309'. 02/15/15-Sunday Circulate hole clean at 6,309'.@ 7 bpm w/max gas @ 756 units&back ground+70 units.Recovered>1/2 bbl sand/sludge. Mill on tail pipe fish& packer junk @ 6,309'in attempt to c/out fill and ensure fish bore clean w/10-15 WOB @ 5 BPM @ 430 psi&60 rpm w/loss rate+/-40 BPH. Circ @ 5 bpm @ 6,281'to chk for stable well.Had high gas of 331 unit&back ground of+/-70 units w/Trace sand/sludge in returns.W/loss rate 20-40 bph. Monitor static loss @ 16 bph. POOH slow thru perf areas t/+/-4,700'w/loss rate @+/-21 BPH. Daily fluid loss=389 bbls 3%8.6 KCL.Total Fluid Loss to Well=4527 bbls 3%8.6 KCL. Average Daily Loss Rate=16.2 BPH.Sized Salt Pill=40 bbls.Total Sized salt=320 bbls.30 lbs metal off ditch magnets.90 lbs metal out of boot baskets.Ditch magnets 42 lbs total.Annulus Pressures:20"X 13-3/8"=20 psi,13-3/8"x 9-5/8"=170 psi. Spot and balance 40 bbl sized salt pill on bottom leaving it a little heavy in DP. Continue POOH to BHA.Loss rate @+/-31 BPH. Lay down BHA#1. Recovered 55 lbs off of string magnet.Recovered 90 lbs metal out of boot baskets.12 BPH loss rate. Make BHA#2:Spear,X0,X0,BS/OJ,string magnet,pump out sub,XO,9 ea 6 1/2"DC's,X0,Acc jars=330.90'.Service rig and equipment. RIH with BHA#2 to 6,300'. Circulate bottoms up at 5 BPM/2900 psi.High gas of 600 units.31 BPH loss rate. Establish parameters:P/U 185 K,S/0 152 K,2 BPM/560 psi.Engage fish at 6,310'.Set down to 6,315'with 15 K.Pick up to 235 K and jar 3 licks.Fish came free.Pull up hole to 6,296'. Circulate gas out at 4 BPM/2100 psi.High gas 450 units.23 BPH loss rate while pumping.Obtain static loss rate of 18 BPH. Blow down TDS.POOH with BHA#2.First 7 stands had over pulls up to 30K over at casing collars.Static check at 4,700'was 17 BPH loss rate.**Lay down middle joint of stand#41 due to washout 2'up from pin end. Work BHA#2. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 2/10/2015 2/20/2015 Daily Operations 02/16/15-Monday Work BHA#2.Recovered 20.5#iron off string magnet also had full recovery of prk junk and tail pipe assy. Recovered+/-1.00'of burned prk(no rubber)Both 10.00'seal bore w/xo(2)2-7/8"pup jts w/"X"nipple&WLRG(Matches running tally).WLRG shows signs of spinning on fill.Attempted to brk out"X"nipple no joy(junked all for over torqued). P/up and m/up Bha#3 8-1/2"RR mill tooth bit loaded w/20's,7"junk bsk,9-5/8"csg scraper,(2)7"junk bsk,bit sub w/float,6-1/4"BS,6-1/4"oil jar,string Magnet,POS,XO,(9)6-1/4"Dc's,XO,6-1/4"Acc.Jar=344.09'.Rih 1 std dp loss rate @ 20-24 bph. P/up RIH rabbit and strap(15)more jts 5"S-135 dp 19.5#. RIH w/Bha#3 w/DP out of derrick t/top of perfs @ 4,699'fill pipe. Service rig.All traveling equipment adjust service loop,clean rig floor&strap DP. Daily fluid loss=612 bbls 3%8.6 KCL.Total Fluid Loss to Well =5139 bbls 3%8.6 KCL. Average Daily Loss Rate=25.5 BPH.Sized Salt Pill=41 bbls.Total Sized salt=361 bbls.14 lbs metal off ditch magnets.0 lbs metal out of boot baskets.Ditch magnets 56 lbs total.Annulus Pressures:20"X 13-3/8"=20 psi,13-3/8"x 9-5/8"=170 psi. Tag fill @ 6,347'.Wash and c/out fill f/6,347't/6,592' w/high gas of 642 units. Service rig.Lock tight and tighten bolts on dwk stuffing box.Inspect TDS.Install tie wires on bail clamps. Continue wash and clean out fill f/6,592't/6,726'.8 BPM/520 psi. 39 BPH loss rate while circulating. Continue RIH double scraping perf intervals t/+5900'.Continue straight RIH to 6,300'brk circ,loss rate up to 20-32 bph.Establish parameters up/dn/rot 195/147/170k @ 8 BPM @ 465 psi. Service rig.Retighten wrap on TDS service loop. Circulate/work pipe at 6,592'and unload well bore.8 BPM/500 psi.Max gas of 615 units. Circulate/work pipe at 6,726'(PBTD)to clean out sand.8 BPM/520 psi.Had+/-18 bbls crude oil on bottoms up.Max gas of 1185 units. Loss rate 32 BPH while circulating.Recovered 26 bbls of sand during clean out. POOH laying down 5"drill pipe to 4,700'.Static loss rate 7.8 BPH. Spot 40 sized salt pill and chase with 73 bbls 3%KCL. Continue POOH laying down 5"drill pipe. 7.2 BPH loss rate. 02/17/15-Tuesday Finish L/dn DP w/loss rate @ 7.8 BPH. Lay down inspect and clean BHA#3.Recovered(4)large 3/8"square stock of iron 10-12"long wrapped around bit sub and btm scraper tool jt and 73#iron off string magnets(also found some strip gun scallops)&all three junk baskets full=72#. Monitor well static loss @ 7.2 BPH.Work boat.Load DP and BHA on boat and off load ESP equipment and 2-7/8"tbg and rack same.House clean work areas.Service rig.Perform monthly check of Koomey N2 bottles.Work on changing out shackles to 4 part in derrick. Daily fluid loss=309 bbls 3%8.6 KCL.Total Fluid Loss to Well=5448 bbls 3%8.6 KCL. Average Daily Loss Rate=13 BPH.Sized Salt Pill=0 bbls.Total Sized salt=361 bbls.73 lbs metal off ditch magnets.72 lbs metal out of boot baskets.Ditch magnets 56 lbs total.Annulus Pressures:20"X 13-3/8"=10 psi,13-3/8"x 9-5/8" =6 psi. Prepare to test BOPS on 2 7/8 tbg.Pull wear ring and flush stack.7 BPH loss rate. Make up test joint. Rig up annulus to gravity feed from trip tank. Test BOPE 250 L/2500 H as per sundry.Good test/no failures.Witness waived by AOGCC(Jim Regg)on 2-16 at 1500 hrs.9 BPH loss rate. Lay down test joint.Clear rig floor. Hold PJSM on picking up tubing.Rig up Weatherford. RIH picking up 2 7/8"6.5#EUE tubing to 1,575'.10 BPH loss rate. Service rig and equipment. RIH picking up 2 7/8"6.5#EUE tubing from 1,575'to 5,944'.12 BPH loss rate. Rig up pump in sub and circulating lines. 02/18/15 Wednesday Circulate well at 5,944'.8 BPM/2000 psi.Max gas 700 units at bottoms up.It dropped back sharply to 450 units,then tapered off to 350 units by second bottoms up.Circ until gas leveled off at 320 units and shut pump down. Monitor well with a loss rate of 9.6 BPH. Circ bottoms up again to see if any gas had migrated while monitoring.At 200 stks gas units were back over 350.On bottoms up gas went to 500 units.Gas finally leveled out at about 350 units but would not go below.Decided we needed to get at least below the E zone to circ gas out. PU 9 more jts of 2 7/8 tbg and 2 jts of 3 1/2 DP to get to bottom of E zone at 6,296'. RU circ head and circ at 8 BPM and 2000 psi.Gas units at bottoms up were 683 units.Then they fell down to 250 units.Just before the second bottoms up the gas units hit 450 units and then came down to 325 units.Decision was made to wt up. Wt up from 8.6 to 8.8 and the gas units fell off to 50 units.Loss rate is 20 BPH. POOH and lay do the 2 jts of DP and 9 jts of 2 7/8 tbg.Standing back 63 stands 2 7/8 tbg in the derrick.Stop at 4,700'and monitor well.Static loss 20 BPH. Continue POOH. 23.7 BPH loss rate. Pick up/make up ESP assembly.16 BPH loss rate. Daily fluid loss=334 bbls 3%8.6 KCL.Total Fluid Loss to Well=5782 bbls 3%8.6 KCL. Average Daily Loss Rate=14 BPH. Sized Salt Pill=0 bbls.Total Sized salt=361 bbls.Ditch magnets 56 lbs total.Annulus Pressures:20"X 13-3/8"=10 psi,13-3/8"x 9-5/8"=6 psi. RIH with ESP with 2 7/8"6.5#L-80 8rd EUE tubing out of derrick. 15 BPH loss rate. • I Hilcorp Alaska, LLC HilcorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 2/10/2015 2/20/2015 Daily Operations: 02/19/15-Thursday RIH with ESP installing canon clamps on every collar and in the middle of every jt on completion that will be in the perfs.After the X-nipple,started putting canon clamps on just the collars.RIH to 3,790'.Hole taking 14 BPH. PU last GLM and continue RIH w/2 7/8 tbg out of the derrick.Installing canon clamps on every collar.RIH to 5,532'. PU packer assem.Meg cable to make sure everything is good before we make the splice.Measure and cut cable.Make splice. Make up SSSV and test at 5000 psi.RIH to tubing hanger. Make up landing joint and tubing hanger with bar drop assembly. Dress tubing hanger.Meg test good. Land tubing hanger.77K S/O weight.Run in lock down screws.Drop bar and set packer at 3900 psi for 30 minutes. Daily fluid loss=402 bbls 3%8.6 KCL.Total Fluid Loss to Well=6184 bbls 3%8.6 KCL. Average Daily Loss Rate=17 BPH.Sized Salt Pill=0 bbls.Total Sized salt=361 bbls.Ditch magnets 56 lbs total.Annulus Pressures:20"X 13-3/8"=10 psi,13-3/8"x 9-5/8"=6 psi. Test annulus at 1500 psi on chart for 30 minutes.Good test.R/D lines and test equipment. Lay down landing joint.Set BPV.Lay down tubing out of derrick.R/D Weatherford.R/D ESP sheaves.Clear rig floor. Nipple down flow nipple.Nipple down BOPE. 02/20/15-Friday Nipple down BOPE and trolley off to the side.Pull riser. Clean up and prep tbg spool.Nipple up tree,valves,and flow line.Test void to 5000 psi.Pull BPV and set TWC.Test tree to 5000 psi.Good test.Pull TWC. RU slickline.Test lubricator to 2000 psi.Run#1.RIH w/2"JDC and retrieve bar.Run#2. RIH w/2"GS and retrieve plug.RD slickline. Prep to skid rig.Turn well over to production. ic \��\�/77* THE STATE Alaska Oil and Gas '� o Conservation Commission ,•� � fALAS� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS' Fax 907.276.7542 www.aogcc.alaska.gov % NNS FE 2 f1 15 Trudi Hallett O 3� Operations Engineer �. Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B. C, and D Oil, Hemlock Oil, and West Foreland Oil Pool, Trading Bay ST A-16RD Sundry Number: 315-057 Dear Mr. Hallett: 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, Daniel T. Seamount, Jr. Commissioner DATED this 7 day of February, 2015 Encl. EC EI D STATE OF ALASKA FEE 0 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill El Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations,❑ Perforate❑ Pull Tubing 0 • Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. InstaH ESP E • 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 188-038 • 3.Address: 3800 Centerpoint Dnve,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20111-01 • 7.If perforating: 8.Well Name and Number: • What Regulation or Conservation Order governs well spacing in this pool? N/A / Will planned perforations require a spacing exception? Yes ❑ No CI Trading Bay ST A-16RD '• I/ 9 Property Designation(Lease Number): 10 Field/Pool(s): - • Trading Bay/Middle Kenai D Oil,Hemlock Oil,Middle Kenai C Oil,West Foreland,Middle Kenai B Oil ADL0018731 ' 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): 6,844 • 6,439 6,730 . 6,331 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,059' 13-3/8" 1,059' 1,042' ▪ 3,090 psi 1,540 psi Intermediate 6,814' 9-5/8" 6,814' 6,411' ▪ 6,870 psi 4,760 psi Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade Tubing MD(ft) See Schematic See Schematic 3-1/2"&2-7/8" 9.3#RTS-8&6.5#L-80 4,409'&4,743' _ Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) Model D Perm Packer&SSSV 4,704'(MD)4,432'(ND)and 277'(MD)277'(ND) 12 Attachments. Description Summary of Proposal 0 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development:El Service ❑ 14 Estimated Date for 15 Well Status after proposed work: Commencing Operations: 2/20/2015 Oil CI • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WI NJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi Hallett Title Operations Engineer ItaSignature Phone (907)777-8323 Date 2/4/2015 COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: \ _ 0 _,r Plug Integnty ❑ BOP Test e Mechanical Integrity Test ❑ Location Clearance El ,/ Other: 2.SW GeSc f I— ( AMS I —1 [ J rS- Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required /6••—Veil 0( �/ APPROVED BY L j 1 ' 5 Approved by: v�/ COMMISSIONER THE COMMISSION Date: I / ORIGINAL Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. tta me is in Duplicate RBDMS�� FEB 1 I '015•,, Z .'-.i ' • Well Prognosis Well: A-16RD Hilcorp Alaska,LL Date:02/03/2015 Well Name: Monopod A-16RD API Number: 507332011101 Current Status: Combo gas-lift ESP Leg: N/A completion Estimated Start Date: February 20,2015 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: _Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 188-038 First Call Engineer: Trudi Hallett (907)777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: Current Bottom Hole Pressure: —1,393 psi @ 5,982' (5,623' TVD) SBHP Survey 8/2/2009 SI 119 days Maximum Expected BHP: —1,595 psi @ 6592' (6201' TVD) Max.Anticipated Surface Pressure: —475 psi. Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary The A-16RD well is currentlycompleted as a combogas lift ESPproducer and utilizinggas lift with the ESP P isolated. The last test was on 1/24/2015: 138 bopd, 555 bfpd, 50 mscfd. The recompletion plan involves pulling the existing combo completion,and clean out welly PBTD @ 6,730'.A new ESP completion string will be ran which will consist of GLM's and a small ESP below the packer and SSSV. Duringthe most recent workover on A-16RD,the casingwaspressure tested on Nov. 25,2013 to 1,500 slg P from 4720'to surface and charted for 30 min. c, Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU slickline and shift the sliding sleeve at 4,584'. RD slickline. 3. Circulate Hydrocarbon off of the well with 3% KCL. 1/- 4. /4. ND Wellhead, NU BOP and test to 250psi low/2.500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. Unseat Hanger and pull tubing free of seals. POOH laying down production tubing and ESP completion. 6. Mill and recover production packer at 4.704'. 7. PU Clean out assembly for 9-5/8"47#casing and RIH cleaning out to PBTD(6730'). PU and circulate clean. POOH. 8. PU and run ESP completion production tubing string w/high set packer @+/-350'and hang off same. Pump set depth @+/-5900'.Test to 1500 psig charting for 30 minutes. 9. ND BOP, NU wellhead and test. to"`'k .. (IA 10. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current/Proposed Wellhead(same) Trading Bay Unit SCHEMATIC Monopod Platform Well #A-16RD API # 50-733-20111-01 Completed: December 4, 2013 RKB to TBG Hngr=40.08' CASING AND TUBING DETAIL SIZE WT _ GRADE CONN ID TOP BTM. [i 13-3/8" 61 K-55 Butt 12.515 Surf. 1059' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 Surf 6814' Tubing: 3-1/2" 9.3 RTS-8 Surf 4,409' 2-7/8" 6.5 1-80 8rd EUE 4,409' 4,743' JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 277' 2.992 SSSV 2 2,172' 2.992 GLM 3 3,470' 2.992 GLM 4 4,328' 2.992 GLM 5 4,409' 8.25 Y Block 6 4,422' 4.0 Head Bolt On Discharge 7 4,424' 4.00 Pump(x3)D5800N C-CT Stg 400/400 8 4,495' 4.56 Protector-MaximusLSBPB-S/LT 9 4,504' 4.56 Motor 456,18,4181 Maximus RA-S 10 4,540' 4.5 Bottom of ESP 11 4,584' 2.313 Sliding Sleeve 12 4,633' 2.441 Chemical Injection Mandrel 13 4,704' 4.00 Model D Permanent Packer 14 4,734' 2.313 X Nipple 15 4,744' 2.441 WLEG A9 Perforation Detail x Top Btm Top Btm Accum. Date Present Zone (MD) (MD) (TVD) (ND) Amt. SPF Last Opr. Condition C-2 4,752' 4,774' 4,477' 4,498' 22' 5 10/31/13 Open f/prod. C 48-7 4,95T 4,968' 4,667' 4,677' 11' 5 10/31/13 Open f/prod. _ C 50-0 5,118' 5,132' 4,816' 4,829' 14' 5 10/31/13 Open f/prod. C 50-3 5,145' 5,158' 4,841' 4,853' 13' 5 10/31/13 Open f/prod. C 50-6 5,234' 5,241' 4,923' 4,930' 7' 5 10/31/13 Open f/prod. C 51-6 5,308' 5,380' 4,992' 5,059' 72' 5 10/31/13 Open f/prod. C Zone , D 53-0 5,460' 5,495' 5,134' 5,167' 35' 5 10/31/13 Open f/prod. _ DZN 2 5,530' 5,543' 5,199' 5,211' 13' 5 10/31/13 Open f/prod. = D 53-8 5,556' 5,602' 5,224' 5,267' 46' 5 10/31/13 Open f/prod. D 54-5 5,626' 5,642' 5,289' 5,304' 16' 5 10/31/13 Open f/prod. D 54-9 5,654' 5,710' 5,316' 5,368' 56' 5 10/31/13 Open f/prod. D 55-7 5,729' 5,763' 5,386' 5,418' 34' 5 10/31/13 Open f/prod. - D 56-1 5,779' 5,817' 5,433' 5,469' 38' 5 10/31/13 Open f/prod. D 57-2 5,902' 5,975' 5,549' 5,618' 73' 5 10/31/13 Open f/prod. E 58-1 5,992' 6,010' 5,634' 5,650' 18' 5 10/31/13 Open f/prod. E 58-1 6,020' 6,035' 5,660' 5,674' 15' 5 10/31/13 Open f/prod. D Zone - E 58-7 6,060' 6,120' 5,698' 5,754' 60' 5 10/31/13 Open f/prod. E(58-1) 6,020' 6,030' 5,660' 5,669' 10' 8 12/3/1988 Open f/prod. E 60-0 6,156' 6,190' 5,788' 5,820' 34' 5 10/31/13 Open f/prod. E(60-0) 6,159' 6,190' 5,791' 5,820' 31' 8 12/3/1988Open f/prod. E 61-1 6,284' 6,293' 5,909' 5,918' 9' S 10/31/13 Open f/prod. EEE HEM 6,308' 6,560' 5,932' 6,170' 252' 5 10/31/13 Open f/prod. Hemlock 6,308' 6,631' 5,932' 6,238' 323' 8 10/24/1988 Open f/prod. = Hemlock 6,308' 6,325' 5,932' 5,948' 17' 12 2/4/1997 Open f/prod. ' Hemlock 6,350' 6,385' 5,972' 6,005' _ 35' 12 2/4/1997 Open f/prod. = E Zone Hemlock 6,440' 6,460' 6,057' 6,076' 20' 12 2/3/1997 Open f/prod. Hemlock 6,480' 6,503' 6,095' 6,116' 23' 12 2/3/1997 Open f/prod. ' WFLND 6,650' 6,673' 6,255' 6,277' 27' 5 10/31/13 Open f/prod. ) = Hemlock West Foreland KB ELEV=101' PBTD=6730' TD=6,844' ANGLE thru INTERVAL=21.1° Updated by: JLL 01/06/14 Trading Bay Unit PROPOSED Monopod Platform - lit Well #A-16RD API # 50-733-20111-01 Completed: FUTURE RKB to TBG Hngr=40.08' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 9 /8" - 61 K-55Butt 18.681 - Surf. 1059' fliiiim [ 9-5-5/88" 47.0 N-880&S-95 8rd LT&C 8.681 Surf 6814' 2 Tubing: 2-7/8" 6.5 L-80 JEWELRY DETAIL 3 NO. Depth ID Item 40.8' Tubing Hanger 1 ±300' SSSV I 4 2 ±350' Packer w/Vent valve 3 ±2,100' GLM 4 ±3,400' GLM 5 ±4,300' GLM 6 ±4,700' GLM 7 ±5,900' Bottom of ESP I ) 5 Perforation Detail Top Btm Top Btm Accum. Date Present Zone (MD) (MD) (TVD) (TVD) Amt. _ SPF Last Opr. Condition C-2 4,752' 4,774' 4,477' 4,498' 22' S 10/31/13 Open f/prod. C 48-7 4,957' 4,968' 4,667' 4,677' 11' 5 10/31/13 Open f/prod. 6 C 50-0 5,118' 5,132' 4,816' 4,829' 14' 5 10/31/13 Open f/prod. C 50-3 5,145' 5,158' 4,841' 4,853' 13' 5 10/31/13 Open f/prod. C 50-6 5,234' 5,241' 4,923' 4,930' 7' 5 10/31/13 Open f/prod. C 51-6 5,308' 5,380' 4,992' 5,059' 72' 5 10/31/13 Open f/prod. D 53-0 5,460' 5,495' 5,134' 5,167' 35' 5 10/31/13 Open f/prod. DZN 2 5,530' 5,543' 5,199' 5,211' 13' 5 10/31/13 Open f/prod. D 53-8 i 5,556' 5,602' 5,224' 5,267' 46' 5 10/31/13 Open f/prod. D 54-5 _5,626' 5,642' 5,289' 5,304' 16' _ 5 10/31/13 Open f/prod. D 54-9 5,654' 5,710' 5,316' 5,368' 56' _ 5 10/31/13 Open f/prod. D 55-7 5,729' 5,763' 5,386' 5,418' 34' 5 10/31/13 Open f/prod. D 56-1 5,779' 5,817' 5,433' _ 5,469' 38' 5 10/31/13 Open f/prod. D 57-2 5,902' 5,975' 5,549' 5,618' 73' S 10/31/13 Open f/prod. C Zone E 58-1 5,992' 6,010' 5,634' 5,650' 18' _ 5 10/31/13 Open f/prod. _ E 58-1 6,020' 6,035' 5,660' 5,674' 15' 5 10/31/13 Open f/prod. E 58-7 6,060' 6,120' 5,698' 5,754' 60' 5 10/31/13 Open f/prod. E(58-1) 6,020' 6,030' 5,660' 5,669' 10' 8 12/3/1988 Open f/prod. 1-77_ E 60-0 6,156' 6,190' 5,788' 5,820' 34' S 10/31/13 Open f/prod. = E(60-0) 6,159' 6,190' 5,791' 5,820' 31' 8 12/3/1988 Open f/prod. E 61-1 6,284' 6,293' 5,909' 5,918' 9' 5 10/31/13 Open f/prod. = HEM 6,308' 6,560' 5,932' 6,170' 252' 5 10/31/13 Open f/prod. Hemlock 6,308' 6,631' 5,932' 6,238' 323' 8 10/24/1988 Open f/prod. ------ Hemlock 6,308' 6,325' 5,932' 5,948' 17' 12 2/4/1997 Open f/prod. -_=-- D Zone Hemlock 6,350' 6,385' 5,972' 6,005' 35' 12 2/4/1997 Open f/prod. Hemlock 6,440' 6,460' 6,057' 6,076' 20' 12 2/3/1997 Open f/prod. Hemlock 6,480' 6,503' 6,095' 6,116' 23' 12 2/3/1997 Open f/prod. leiLim] �l == WFLND 6,650' 6,673' 6,255' 6,277' 27' 5 10/31/13 Open f/prod. ! I 7 E Zone Hemlock West Foreland KB ELEV=101' PBTD=6730' TD=6,844' ANGLE thru INTERVAL=21.1° Updated by: .111 02/03/15 Monopod Platform .11 A-16RD Current 08/08/2013 Ililrarp:tlnrkn.l.0 Monopod Platform Tubing hanger,Seaboard- A-16rd ESP-EN,11X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 3 1/2 and Susp w/3"Type H BPV profile,2-34 CCL,Prepped for BIW penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I lw. Valve,Swab, 31/85M FE,HWOO,,DD DD trim la (Y1 •J. Valve,Wing,WKM-M,3 1/8 Valve,Wing,WKM-M,2 1/16 5M FE,w/15"OMNI 5M FE,HWO,DD trim is operator,DD trim Illgk:gall 11 o 11 Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim * Am IIL a Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ I��' i ,1 411/ed focBI we e Y CCL, ported for BIW penetrator Tubing head,S-8,13 5/8 3M r �.��_x115M,w/2-2 1/16 5M — ._uii ����i��= SSO,w/BG bottom w/1-2 1/16 5M WKM-M 1.1 1 111 valves IA ,i- ul • 1 r j � � In Casing head, Shaffer KD, 135/83MX III _ = 111 133/8SOW,w/2-2" 1 * 2"LP OW ball valve LPO, al 11.IIM[ I •I. Monopod Platform 2013 BOP Stack 03/12/2013 Hilrnrp:Unrka.1.I.(. Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe 11l 111!III1111II O 0 fain ffll nn fll 3.74' Shaffer 13 5/8 5M 26.25' Shaffer LXT © 2 7/8-5 Variables 2.50' 135/85M 168— � ... Blind I P•111'111.1 1.111 1.76 ��..Wt1lT� r,F��11�'� 7e...4;1011.11 fll®r 1 1 � 1. 1 . Mud Cross I�LI�LIIIr111.111� �/ .135/85M FEXFE w/31/85MEFO w/2 1/16 5M Choke and Kill valves w/Unibolt end III t l l l l l :1 connections for lines .mel C5l/wg I - 2 83' 13,E j- Dual Cameron Flex rams f �rtfirfhtft .70' Ij t�W4314� 14.20" Drill deck UOCD 1911 Rlsr 14.20' 13 5/8 5M FE x 15585M FE rif31rfllnirt I n1 I11111 I!l 111 Spacer spool 15' 135/8SM FEX113M ie 111 ill 111 111 Wellhead @ 15.00' Image 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 RESCAN Color items: Grayscale items~ Poor Quality Originals' Other: DIGITAL DATA Diskettes, No, [] Other, No/-1-ype TOTAL PAGES' NOTES: ORGANIZED BYi BEVERLY BREN VINCEN1 SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other ISI Project Proofing PROOFED BY BEVERLY BREN VINCENT SHER'~L M,t. RIA I. OWELL DATE [] Staff Proof By Dale' ISI ~:~(-.A. NNEC) EY BEVEIRLY BREN VINCENI SHEPYt~ LOWELl IS~ ~t~(.,. ¢ ScAr-~r4[O 6,','i~) Br~[N VINC[N] SHE[~Nt M,:m~A LOWELt Notes or (]ocnmenls about th~s f~le Oual~ty Checked (dooc~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other 0 Install ESP Performed: Alter Casing❑ Pull Tubing] Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 188-038 4. 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20111-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 0 Trading Bay St/A-16RD • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay/Middle Kenai D Oil,Hemlock Oil,Middle Kenai C Oil,West Foreland,Middle Kenai B Oil 11.Present Well Condition Summary: R EC Total Depth measured f 6,844 feet Plugs measured N/A feet E k a.- true vertical 6,439 feet Junk measured N/A feet AN 08 l Effective Depth measured . 6,730 feet Packer measured 4,704 feet t �`* true vertical 6,331 feet true vertical 4,432 feet t.l Casing Length Size MD ND Burst Collapse Structural Conductor Surface 10,059' 13-3/8" 10,059' 10,042' 3,090 psi 1,540 psi Intermediate 6,814' 6-5/8" 6,814' 6,411' 6,870 psi 4,760 psi Production Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4,409'(MD) 4,743'(MD) Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#RTS-8 4,157'(ND) 2-7/8"6.5#L-80 4,469'(ND) 4,704'(MD) 277'(MD) Packers and SSSV(type,measured and true vertical depth) Model D Perm.Pkr 4,432'(ND) SSSV 277'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): MAY 16 2014 Set packer©5,406'-Scale squeezed D Zone perfs from 5,460'-5,975'. RBDMS 3 Treatment descriptions including volumes used and final pressure: 201 bbl scale squeeze and over flush 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 52 '737 303 710 180 Subsequent to operation: 221 552 3071 1022 188 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development[] p Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil i ElGas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSPD 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: 313-435 Contact Ted Kramer Email tkramerCc�hilcoro.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature 1�•".'--'— _ Phone (907)777-8420 Date 1/8/2014 Form 10-404 Revised 10/2012s.Zz �y ��/ / Submit Original Only Trading Bay Unit • 11 SCHEMATIC Monopod Platform Well #A-16RD API # 50-733-20111-01 Completed: December 4, 2013 RKB to TBG Hngr=40.08' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. li 13-3/8" 61 K-55 Butt 12.515 Surf. 1059' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 Surf 6814' Tubing: 3-1/2" 9.3 RTS-8 Surf 4,409' , i 2-7/8" 6.5 L-80 8rd EUE 4,409' 4,743' JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 277' 2.992 SSSV 2 2,172' 2.992 GLM 3 3,470' 2.992 GLM 4 4,328' 2.992 GLM 5 4,409' 8.25 V Block 6 4,422' 4.0 Head Bolt On Discharge 7 4,424' 4.00 Pump(x3)D5800N C-CT Stg 400/400 8 4,495' 4.56 Protector-Maximus LSBPB-S/LT 9 4,504' 4.56 Motor 456,18,4181 Maximus RA-S 10 4,540' 4.5 Bottom of ESP 11 4,584' 2.313 Sliding Sleeve 12 4,633' 2.441 Chemical Injection Mandrel 13 4,704' 4.00 Model D Permanent Packer 14 4,734' 2.313 X Nipple 15 4,744' 2.441 WLEG inil fl."' - ~ ' Perforation Detail X Top Btm Top Btm Accum. Date Present eiiIi Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Condition C-2 4,752' 4,774' 4,477' 4,498' 22' 5 10/31/13 Open f/prod. C 48-7 4,957' 4,968' 4,667' 4,677' 11' 5 10/31/13 Open f/prod. C 50-0 5,118' 5,132' 4,816' 4,829' 14' 5 10/31/13 Open f/prod. C 50-3 5,145' 5,158' 4,841' 4,853' 13' 5 10/31/13 Open f/prod. C 50-6 5,234' 5,241' 4,923' 4,930' 7' 5 10/31/13 Open f/prod. C 51-6 5,308' 5,380' 4,992' 5,059' 72' 5 10/31/13 Open f/prod. C Zone D 53-0 5,460' 5,495' 5,134' 5,167' 35' 5 10/31/13 Open f/prod. DZN 2 5,530' 5,543' 5,199' 5,211' 13' 5 10/31/13 Open f/prod. D 53-8 5,556' 5,602' 5,224' 5,267' 46' 5 10/31/13 Open f/prod. D 54-5 5,626' 5,642' 5,289' 5,304' 16' 5 10/31/13 Open f/prod. D 54-9 5,654' 5,710' 5,316' 5,368' 56' 5 10/31/13 Open f/prod. D 55-7 5,729' 5,763' 5,386' 5,418' 34' 5 10/31/13 Open f/prod. D 56-1 5,779' 5,817' 5,433' 5,469' 38' 5 10/31/13 Open f/prod. D 57-2 5,902' 5,975' 5,549' 5,618' 73' 5 10/31/13 Open f/prod. E 58-1 5,992' 6,010' 5,634' 5,650' 18' 5 10/31/13 Open f/prod. E 58-1 6,020' 6,035' 5,660' 5,674' 15' 5 10/31/13 Open f/prod. D Zone E 58-7 6,060' 6,120' 5,698' 5,754' 60' 5 10/31/13 Open f/prod. E(58-1) 6,020' 6,030' 5,660' 5,669' 10' 8 12/3/1988 Open f/prod. E 60-0 6,156' 6,190' 5,788' 5,820' 34' 5 10/31/13 Open f/prod. -- E(60-0) 6,159' 6,190' 5,791' 5,820' 31' 8 12/3/1988 Open f/prod. E 61-1 6,284' 6,293' 5,909' 5,918' 9' 5 10/31/13 Open f/prod. HEM 6,308' 6,560' 5,932' 6,170' 252' 5 10/31/13 Open f/prod. Hemlock 6,308' 6,631' 5,932' 6,238' 323' 8 10/24/1988 Open f/prod. = Hemlock 6,308' 6,325' 5,932' 5,948' 17' 12 2/4/1997 Open f/prod. Hemlock 6,350' 6,385' 5,972' 6,005' 35' 12 2/4/1997 Open f/prod. = E Zone Hemlock 6,440' 6,460' 6,057' 6,076' 20' 12 2/3/1997 Open f/prod. Hemlock 6,480' 6,503' 6,095' 6,116' 23' 12 2/3/1997 Open f/prod. = WFLND 6,650' 6,673' 6,255' 6,277' 27' 5 10/31/13 Open f/prod. = Hemlock West Foreland KB ELEV=101' \ PBTD=6730' TD=6,844' ANGLE thru INTERVAL=21.1° Updated by: JLL 01/06/14 Hilcorp Alaska, LLC Hilturp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 b'ditrj(:bpe tttili : 10/29/13-Tuesday Rig up to circulate 8.6 KCL kill fluid down long string on A-16.Tie short string into production header.Circulate down long string on A- 16,taking returns up the short string to production header.Pumped 230 bbls,(108 bbls over calculated STS bbls)with mostly gas and intermittent oil returns.Pump and spot 15 bbls balanced sized salt pill and chase with 31 bbls KCL.Caught oily returns @ 5 bbls into sized salt pill. Lost returns when chasing pill with KCL. Pumped 3-3.5 BPM with 0 pump pressure.90 psi on 9 5/8".[Pump 50 bbls down long string with slight gas and oil returns from short string.Pump 25 bbl size salt pill and chase with 12 bbls of KCL. Shut well in and let it soak.Rig spotted over A-16RD @ 04:00 hrs.Secure rig,install handrails,landings etc..Fluid loss today 3%KCL= 292bbls.Total 3%KCL loss=292 bbls.Sized Salt Pill 40 bbls.Total sized salt pill loss 40 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0. 2-7/8"tbg LS 0 psi, SS 60 psi,9 5/8 ann.100 psi. 10/30/13-Wednesday Rig up lines on tree&check well for pressure"Cr on L/S and 50 psi on S/S. Pump 131 bbls of 8.6 ppg FIW w/3%KCL at 4 bpm w/"0"pressure followed with 25 bbls salt pill,shut down pump L/S on vacuum.Monitor well while building volume.Removed gas lift line f/95/8 csg valve had"0" pressure on 9-5/8 annulus.Rig up Echometer.Rig up circ lines to S/S side and rig up circ line to 9-5/8 x 2-7/8 annulus to monitor pressure open well with 60 psi on S/S,pump at 1 bpm Tbg pressure increased f/CO psi to 80 psi then broke back to 20 psi pump total of 31 bbls increasing pump rate to 2 bpm w/"0"psi,while monitoring L/S(on vacuum)and the 95/8 x 2-7/8 annulus w/("o")psi,shut down pump monitor well.Rig up Slick line to shift open SS sliding sleeve.Set Slick line aside to standby for Sleeve run.Rig up to circulate down long string.Pump B BBLS Sized Salt Pill and chase with 8 BBL KCL @ 3 bpm,25 psi,placing the pill inside the tubing and just above top Perf @ 5460'.Shut in and allow pill to fall from tubing. Note:9 5/8"annulus builds pressure while pumping below packers on SS or LS and goes on a vac when pump is off.Rig up circulating line to 95/8" annulus. Pump and fluid pack 95/8"upper annulus while letting Pill soak.Caught 95-100 psi pump pressure after 200 bbl.Pumped 20 BBLS over calculated annular volume of 221 bbls and appear to be pumping by dual packer @ 5,385'with 100 psi pump pressure with no increase on either tubing strings.Shut down and shut in pump with DO psi on 9 5/8"annulus.Bled back 1/2 bbl brine/gas before 9 5/8"annulus went on a hard vac. Rig up to pump down Long String taking returns up Short String.Caught pressure after 41 Bbls pumped.160 PSI @ 4 BPM.Maintain 175 to 200 psi pump pressure @ 3.5 bpm.Had returns @ wellhead after 240 bbls pumped.Final pump rate at 3 bpm with 1/2 bpm returns.Shut down and shut in Mud Pumps monitor well with vac on both strings and 95/8"annulus.Rig up on short string and pump 40 bbls sized salt pill and chase with 10 bbls KCL placing 20 bbls pill out side pipe and 20 bbls inside pipe.Shut in and allow to fall/soak.Pump down Long String,catch pressure @ 3)bbl pumped,4 bpm,50 psi.Adjust SPM as pump pressure climbed to 330 psi FCP @ 3 BPM.KCL Returns to surface at 133 bbls pumped.9 5/8"annulus built to 150 psi.Shut down and shut in pump.Rig up to pump down short string.Pump D bbls Sized Salt Pill down short string.Chase with KCL and catch returns up Long String at 29 bbls pumped.Shut down and wait on pill while mobilize Slick Line to shift sleeve on short String.Pump down Short String to ensure pill is clear of Sliding sleeve.Catch DO psi pump pressure @ 13 bbls pumped.Catch KCL returns up Long String @ 43 bbls pumped @ 3 bpm 330 psi.Estimate 40-45 BPH losses.Rig up slickline on Short String.PT Lubricator to 500 psi.TIH to open Sliding Sleeve.Could not get past 100'. Scale and paraffin on shifting tool.RIH with 2360 GR.Could not get past 265'.Rig up Production Diesel manifold to lubricator to pump diesel down lubricator to help with paraffin.Note:Spot D bbls Sized salt down SS while rigging up diesel manifold.Fluid loss today 9'KCL= 761bbls.Total 3%KCL loss=1238 bbls.Sized Salt Pill 90 bbls. Total sized salt pill loss 144 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=0.Recovered 0 lbs from Ditch magnets. Ditch magnets total=Olbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs Hilcorp Alaska, LLC Hilcorp Alaska.LLC Well Operations Summary Well Name API Number _Well Permit Number _Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 Daily Operations. 10/31/13-Thursday Make up and dress slick line tools to pull SCSSV on short string side.RIH&latch 27/8 Otis ball valve at 269'-jarred several times came free pooh w/ same.RIH w/2.30 gauge to 5,380'RIH w/J-latch shifting tool&open sliding sleeve at 5259'ft.Pooh 1/d tools.Rig down lubricator f/S/S&R/U on L/S.RIH w/2.30 gauge ring to 5,980 ft w/no problems.POOH,R/U to circ down s/s taking returns from 9-5/8 annulus.Pump down S/S monitor the 9-5/8 annulus pumping at 3 bpm w/"o"psi w/14 bbls pumped,pump pressure increased to 130 psi steady increased to 200 psi w/50 bbls pumped with L/S holding 150 psi while pumping pump down the S/S. Had oil in returns at 110 bbls pump,had brine back on 9-5/8 annulus,pump 35 bbls oil to production w/brine back to surface shut down pump pressure bleed to zero.R/U slick line on S/S&RIH and close sliding sleeve at 5,359'.POOH.R/d slick line.R/u&pump down S/S at 4bpm w/"0"psi,monitor L/S for returns at 37 bbls pumped on 8.6 ppg FIW[pump press at 130 psi,pump 40 bbls salt pill at 140 psi at 2.5 bpm pressure decreased 20 psi continue chasing pill w/25.bbl of 8.6 ppg FIW,had oil back on L/S pump pressure at 190 psi shut down pump pressure bleed to zero.Monitor Well while building Sized Salt Pill.Pump Size Salt Pill down short string, catch returns @ 24 bbls pumped.Chase pill with 13 bbls KCL with 150 psi On Long String and 9 5/8"Annulus. Shut down and monitor well. No flow or vac on SS/LS.Rig down Circulating equipment.Set BPV's in SS/LS.N/D and remove production Tree from well had room.Inspect Tbg Hgr lift threads.Plug control line ports.Stage new Tbg Spool w/11"3M x 13 5/8"5M adapter spool in well head room.Land 13 5/8"Drilling riser,M/U flange.N/U13 5/8"BOP and associated equipment.AOGCC Test Witness Notification Request for BOPE Test on Monopod Platform,KUUPIK Rigs Sent Thursday,October 31,2013 2:05 AM via e-mail. AOGCC does intend to witness.TOTAL IFO DAYS 8i,Fluid loss today 3%KCL=624bbls.Total 3%KCL loss=1862 bbls. Sized Salt Pill 64 bbls.Total sized salt pill loss 208 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=0 Recovered 0 lbs from Ditch magnets. Ditch magnets total=Olbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs. 11/01/13-Friday R/U&Change upper Kelly valve,install rotary hose&Kelly spinner air lines.Install lower Kelly valve&saver sub&torque same.Test upper Kelly Valve to 250 PSI low&2500 PSI high.R/U&Pull BPV in long string&short string.Install two way checks.R/U Test Jts&make up into L/S,attempt to shell test,Low had leak @ hanger pins.Tighten-Attempt to retest leaking worse-close btm 27/8 Rams.Attempt low test not holding-Added packing to hanger gland. Pull Two way checks and clean same.Install test jt.Test BOP's and related surface equipment with 27/8 and 5"pipe 250 low and 2500 PSI high.Held each test 5 mins,test with water.Perform Koomey test,had one fail/pass on triplex pump(not primed),primed same, test ok.BOP test was witness by Chuck Sheeve AOGCC.BOP Test all pass no fails.Mr.Sheeve departed platform @ Q30 hrs.R/D test equipment. Set back Kelly.Install mouse hole. Pull Two Way Check Valves. Mixing Size Salt Pill.Install Bales and 27/8"elevators.Remove and re-seal drip pan and air boot.Rig up landing joint and circulating equipment to Short String.Pump 6i bbls Size Salt Pill and chase with 10 bbls KCL down Short String @ 3 BPM with no returns.Monitor well and allow pill to fall with Opsi on 9 5/8"annulus and slight vac on tubing.R/U Landing Joint and E- Line on Long String.RIH with Tubing punch.Tag fill @ 5739'WLM.Log up hole and tie in to Tubing Tally Dated&DEC-88. Punch holes in bottom of 10'Pup Joint @ 5,524'.POOH.M/U Radial Torch Cutter.RIH with Radial Torch cutter.Tie in to Tbg Tally. Cut tubing @ top of 10'pup Joint @ 5,539'.POOH.E-Line out of hole, load 21 bbls Size Salt Pill w/charge pump down SS through Kill line and chase with 60 bbls KCL before getting returns up LS.Re-arm Radial Torch Cutter.RIH and cut tubing D'above sliding Sleeve @ 5,356'. POOH,Swap Landing joint to Short String.Fill hole down Long String.Took 41 bbls to fill hole.RIH with Radial Torch and cut Short String 6 above the PKR @ 5,379'.POOH to rig down E-Line.TOTAL IFO DAYS 86,Fluid loss today 3%KCL=624 bbls.Total 3%KCL loss=1862 bbls.Sized Salt Pill 64 bbls.Total sized salt pill loss 269 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=0 Recovered 0 lbs from Ditch magnets.Ditch magnets total=0 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs. Hilcorp Alaska, LLC Hi'carp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 lif `i 11,61, ro 3 < "4'7; 11/02/13-Saturday Spotted 19 bbls sized salt pill down short string at 3bpm/500 psi,got returns up long string max gas 260 units.R/up 5'pup jt w/circ equipment pull s/s hanger at 55k pull up 2'weight at 80k,Brk circ at 4.5 bpm at 820 psi down s/s,weight dropped f/80k to 65k circ out gas max gas 660 units, had course black sand and scale back at shaker.Increase pump rate to 6bpm/1100 psi max gas at 360 units circ two btms up,shut down pump monitor well-well taking 11 bph.Pull hanger through rotary table.Lay down hanger.Pooh laying down s/s 27/8 6.4 n-80 butt,tbg w/special clearance collars 3.250".Lay down 170 jts tbg,6-GLM's,SSSV,Sliding Sleeve and 16'cut off joint.9 control line bands. Static loss rate @ 12 BPH. M/U landing joint to Long String hanger.BOLDS.Pull Hanger to floor.Lay down landing joint and Hanger and 2pups.Clean Rig Floor.POOH laying down 19 jts tubing, SSSV with 10 bands on control line.Static loss rate @ 12 BPH.PJSM.Continue to POOH laying down 27/8"Long string tubing. Rig down handling equipment.Clean up rig floor and Top deck.Prep to Pick Up BHA#1,TOTAL IFO DAYS 87,Fluid loss today 3%KCL=390bbls. Total 3%KCL loss=2287 bbls.Sized Salt Pill 43 bbls.Total sized salt pill loss 312 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=8 BPH. Recovered 0 lbs from Ditch magnets.Ditch magnets total=Olbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs. 11/03/13-Sunday Pick up BHA#1-8.5"x 7-1/4"smooth ID Od shoe,2JTS 8-1/8"wash pipe,top sub drive bushing,x/over pin x pin,7'boot basket,7"boot basket, bit sub,bowen 6-1/7"lub bumper sub,bowen 6-1/4 Oil jar,x/o,9 each,6-1/2"drill collars,x/o=367.26'.Static loss at 5 bph.Trip in hole to 2,7357 pump 193 bbls dirty fluid from OBM tank to Trading Bay,fill pipe at 4bpm circ btm up at 7 bpm/400 psi,Max gas 250 units had black sand and scale over shakers,continue in hole f/2,735'to 5,334';tagged fill at 5,334'.Make up Kelly and circ btm up at 7 bpm/260 psi max gas300 units, wash f/5,334'pumping at 7.5 bpm 260 psi,to top of fish at 4354' dpm,work over top of fish and continue wash down to top of packer to 5386', rotate at 20 rpm,0 to 5 WOB.Circ btm up at 10 bpm had sand back shaker max gas 304 units,pump dirty fluid out of active pits to OBM tank,clean pits,Filling pits with clean FIW,Pumping clean 86 FIW down hole swapping out fluid in hole.at 3bpm 75 psi.Service rig while swapping fluid. Shipped 651 bbls 8.6 ppg 3%KCL to Production.Set back Kelly.TOH from 5386'to 367'.Static loss rate @ 45 BPH.Rack Back Drill Collars,Lay down BHA.Clean out Boot Baskets and recover 17 lbs sand/fill.Clear and clean up Rig floor.PU BHA#2as follows:8-1/8"Overshot with 2-7/8" Catch, Lubricated Bumper Sub,Oil Jar,Pump Out Sub,X Over,6ea.61/2"DC's,X Over-Total BHA Length =212.89'.TIH from 212'to 5,327'.PU Kelly.Break circulation @ 5 BPM with 100 psi,PU 158K,DN 130K.Rot 140K @ 10 RPM.Wash down from 4327',engage and latch top of fish @ 5,354'.Pick up190K(32K Over)and pull Dual PKR Free.Mouse hole single with Kelly.Blow down and set back Kelly.Encountering 5-20K Drag,TOH Slowly from 5,300'to 4,600'.Loss Rate 8 BPH.TOTAL IFO DAYS 88,Fluid loss today 3%KCL=190bbls.Total 3%KCL loss=2477 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 312 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=8BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=0 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs. 11/04/13-Monday Continue TOH with PKR fish from 4600'to 212'.Loss Rate 8 BPH. Rig up tongs and lay down 2-7/8 tbg and dual packer and short string tail assembly and 3 blast joints from long string,2ft cut pup below blast jt.2ft cut piece had hole in same.Rig down equipment-static loss at 6bph. Pick up BHA#3 overshot assembly:81/8"Overshot with 2 7/8"Catch-MCP,Lubricated Bumper Sub,Oil Jar,Pump Out Sub,X Over,%a.61/2" DC's,X Over.Total BHA Length =311.86'. Service rig. Trip in hole to 5,512'pick up Kelly. Wash f/5,512'tagging fish at 5,554'3k down on fish/ pump press increased f/115 psi to 900 psi p/up wash down to 5,558',set down 15k on fish.p/up had 20k over pull for 30 ft then fell back to 10k drag.Set Kelly back.Monitor well 6BPH Static Loss TOH slow w/fish from 4554'to 300'.Stand Back Drill collars.Lay down Bumper Sub and Jars and Over shot.Rig up tubing handling equipment.Lay down 10 Blast Joints and a 1'section of 2 7/8"pup joint.Pressure wash and clean rig floor.Pick up BHA #4as follows:8 1/8"Overshot with 31/4" Catch,X Over Bushing,ljt 8 1/8"Wash Pipe,Top Sub Drive Bushing Lubricated Bumper Sub, Oil Jar,X Over,Sea.6 1/2"DC's,X Over.Total BHA Length =330.41'.TIH from 330'to 5,698'.Lay down single and PU 20'Pup to 5,718'. PU Kelly.Break circulation @ 5 BPM with 250 psi,PU 173K, DN 135K.Rot 152K @ 10 RPM.Wash down from 4738', engage and latch top of fish @ 5,731'. Attempt to jar fish free with 250K(75K Over).Hit Jars 10 Times with no movement.Circulate Bottoms up 11/2 times with 612 Max Units of gas.Monitor well with 4BPH Static Losses.Set back Kelly.Lay down 20'Pup.PU single.TOH from 4718'to 990'.TOH Laying down 7 stands 5'DP for working singles on next trip.TOTAL IFO DAYS 8, Fluid loss today 3%KCL=1171bbls.Total 3%KCL loss=2648 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 312 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=4BPH. Recovered 0 lbs from Ditch magnets.Ditch magnets total=Olbs.Recovered 0 lbs from Boot Baskets. Boot Basket total=0 lbs.Total metal recovered=0 lbs. Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 awl gyp"`. ' `' � �,�ad�» ,y.vl�.ks?� �`�� ��„p ,.. b'a`r. §�€*h: .... .�"�u � �-. .� ���kf,;; ��r' .; 'l3!; rxz _ wk wE 11/05/13-Tuesday POOH stand back drill collars and lay down jars and wash pipe with over shot static loss at 3bph.Rig up to pick up 2 jts of 8-1/8"wash pipe and 15 jts 5-3/4"wash pipe. Rig down wash pipe handling tools.BHA=&1/2"X 7-1/4"smooth Idx OD shoe,x.o bushing,2jts 7-5/8"x line wash pipe, x/over bushing,15 jts 5-3/4" TTS wash pipe,top drive sub 5-3/4"TSS,Xo,XO DPIN,bit sub,bowen 61/4"lub bumper sub,bowen 6-1/4"oil jar,xo 9 each 6-1/2"DC's,x/o Acc jar,826.00'. TIH w/wash pipe to 5,719'filling pipe at 3,163'.Make up Kelly.Wash and reaming f/5,719' to 5,760'Tag fill at 5,760', UP WT 175K,RT WT 155K,5/0 WT 135K. Wash and ream F/5,760'to 5,782'-could not wash past 5,782'. Circ hole clean at 5,782'at 10 bpm 500 psi. Trip out of hole from 5,719'to BHA.Stand Back Drill Collars.Lay down bumper Sub/Jars, Lay down 3jts 5-3/4", Stand back 4 stands of wash pipe,Lay down 2jts 8"wash pipe.Pick up BHA #6 as follows:8-1/8"Overshot with 3-1/4"Catch, X Over Bushing, ljt 8-1/8" Wash Pipe, Top Sub Drive Bushing,Lubricated Bumper Sub,Oil Jar,X Over,Bea.6-1/2"DC's,X Over,Accelerator Jar,Total BHA Length =219.85'. TIH from 250'to 5,698'.Lay down single and PU 10'Pup to 5,712'. PU Kelly.Break circulation @ 5 BPM with 130 psi,PU 168K,DN 132K.Rot 148K @ 10 RPM.Wash down from 5,712', engage and latch top of fish @ 5,752'with 300 psi increase in pump pressure.Set down 15K.Attempt to jar fish free with 220K(50K Over)Hit Jars 3times.Appear to have pulled off fish or parted tubing.Set back down in attempt to re-latch with no increase in pump pressure or string wt.Blow Down Set back Kelly.Lay down D'pup joint. Monitor Well with 4BPH Static Loss. TOH from 5712' to 250'. Lay down Accelerator,Stand back Drill Collars,Pull wash pipe/overshot to surface with 2'piece 2-7/8"tubing in over shot. Lay down fish, wash pipe and Overshot.Clear and organize Rig Floor.Prep to PU BHA#7. TOTAL IFO DAYS 89,Fluid loss today 3%KCL=146bbls.Total 3%KCL loss=2794 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 312 bbls.Daily Loss rate average- BPH.Report Time Loss Rate=4BPH.Recovered 0 lbs from Ditch magnets. Ditch magnets total=Olbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=Olbs.Total metal recovered=0 lbs. 11/06/13-Wednesday P/U BHA#7 Drag tooth washpipe assembly.Trip in hole to Z700'.Circulate and condition Kelly up.Fill pipe @ 6 BPM CBU 6 BPM/135 PSI. Continue to trip in hole to 5,707'.P/U 10'pup&1 jt DP.TIH 5,707'-5,749'.Fill pipe, UP Wt.=175K DN Wt.=140 K,RT Wt=158K @ 20 RPM/7.5 KTQ.Pumping @ 5 BPM/160 PSI.Service Rig.Circulate @ 10 BPM/680 PSI.Background Gas=9 units,Highest Gas=114 units.Reaming/ Washing/Tag Up @ 5,782'.Wash/Ream @ Various Parameters 5782'-5,787'w/3 to 5K WOB.Torque 9000k,pumping f/2.5 bpm t/10 bpm 270 psi.Circulate and Condition @ 10 BPM/600 PSI.Monitor Well.POOH lay down BHA#78-1/8"Wash pipe and clean boot baskets(recovered 42 lbs of scale and metal).Clean rig floor.Pick up BHA#8(6"x 4-7/8"shoe w/MM ID,3jts 5-3/4"wash TSS WASH pipe,top drive sub 5-3/4"TTS, X/O,X/O PXP,7 boot basket,7"boot basket,bit sub w/float,Bowen 61/4"lub bumper sub,Bowen 6-1/4"oil jar,X/O,(9)6-1/2"drill collars,X/O, accelerator Jar.=417.65)continue tripping in hole to 2,325',filling pipe and servicing rig.Trip in hole to 5754',Kelly up get parameters,tag fish at 5,759'dpm,space out work over top of fish at 5759'.P/u wt 180k,R/T W/T 150K,S/O WT 135K SPM 70,P/PRESS 270.Wash 5 ft of fill. Wash and reaming f/5,779'to 5,785'.Fish in hole:ljt 2-7/8"-6.4#N-80 tubing,3 blast jts 3-3/4"OD,2 jts 2-7/8"-6.4#N-80 tubing,12 blast jts 3-3/4"OD, pup jt 2-7/8"-6.4#N-80,2 blast jts 3-3/4",1 blast jt 3-3/4"OD,pup jt 2-7/8"-6.4#N-80,Otis"XA"sleeve,pup jt 2-7/8"-6.4#N-80,XO 3-1/2"butt pin X 2-7/8"butt box,Locator sub,Baker seal assy =435.92(4-3/4"OD X 3"ID,XO 2-7/8"butt pin X 3-1/2"butt box,1 jt 2-7/8"-6.4#N-80 tubing, Otis 2-7/8"X-nipple,pup jt 2-7/8"-6.4#N-80,3.50"OD Re-Entry guide(44.06 below packer).Fluid loss today 3%KCL=136bbls.Total 3%KCL loss =2930 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 312 bbls. Daily Loss rate average- BPH.Report Time Loss Rate=6BPH.Recovered O lbs from Ditch magnets.Ditch magnets total=Olbs.Recovered 42 lbs from Boot Baskets.Boot Basket total=.2 lbs.Total metal recovered=0 lbs. Hilcorp Alaska, LLC Hilcorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date _End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 Daily Operations ; 11/07/13-Thursday Reaming/Washing Parameters=UP WT 180,DN WT 135,RT WT 150.7 BPM 250 PSI 40 RPM,8-10 K TQ.Tag @ 5,979'.Wash down to 5,784'300 PSI increase.40K overpull to break free.Wash back down adjust parameters.Minimal progress/Blow dn/Rack Back Kelly.Trip out of hole L/D single.POOH from 5,784' to BHA,LAY DOWN 5-3/4"wash pipe shoe worn 3/4 of inch on one side looking like a mule shoe,Cleaning rig floor.Pick up Bha#9 Pick up(8-1/8"wavey bottom shoe x 6.15/16"ID,3 jts 8-1/8" TS WASH pipe,top sub drive bushing TSwp,X/O PXP,7 boot basket, 7"boot basket,bit sub w/float,Bowen&1/4"lub bumper sub,Bowen 6-1/4"oil jar,X/O,(9)6-1/2"drill collars,X/O,accelerator Jar.=403.43) continue tripping in hole filling pipe and servicing rig.Kelly up,fill pipe,P/u wt 180k,R/T wt 153k,5/O wt 133k,rpm 50 w/8k torque slacking off rotary stalled out picked up had 55k over pull before coming free,continue to wash and ream without making any hole past 5780'.Blow down Kelly,set same back,POOH,lay down 81/8"wash pipe BHA.Make up Johnny Wacker sub and wash out stack,lay down same.Rig up test plug with 1-1/2"cs pipe and filling stack w/water.Fish in hole:ljt 2-7/8"-6.4#N-80 tubing,3 blast jts 3-3/4"OD,2 jts 2-7/8"-6.4#N-80 tubing,12 blast jts 3-3/4"OD,pup jt 2-7/8"-6.4#N-80,2 blast jts 3-3/4",1 blast jt 3-3/4"OD,pup jt 2-7/8"-6.4#N-80,Otis"XA"sleeve,pup jt 2-7/8"-6.4#N- 80,XO 3-1/2"butt pin X 2-7/8"butt box,Locator sub,Baker seal assy =495.92(4-3/4"OD X 3"ID,XO 2-7/8"butt pin X 3-1/2"butt box,1 jt 2-7/8"- 6.4#N-80 tubing„Otis 2-7/8"X-nipple,pup jt 2-7/8"-6.4#N-80,3.50"OD Re-Entry guide(44.06 below packer). Mr.Jim Regg,AOGCC,waived witness of BOP Test at 12:15 pm hrs on 11-7-2013.Fluid loss today 3%KCL=122 bbls.Total 3%KCL loss=3052 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 312 bbls.Daily loss rate average- BPH.Report Time Loss Rate=6BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=0 lbs.Recovered 42 lbs from Boot Baskets.Boot Basket total=62 lbs.Total metal recovered=0 lbs. 11/08/13-Friday Test the Hydril with 1-1/2"cs Hydril pipe to 250 psi low and 2500 psi high.Rig down test plug.R/U&test bop's and related surface equipment to 250 psi low and 2500 psi high.Perform Koomey test.Witness of test waived by Jim Regg,AOGCC.Tig down test equipment&clear floor.Install wear bushing,slip and cut 125'drill line,function crown a matic w/drill line.Service rig.Monitor well, 9bph loss.Load floor with 11/2"handling tools.MU 1-1/2"BHA#s 10a/10b with 1 1/2"tbg-5 blade flat btm mill 1/2"jet in center/mill.RIH with BHA#10a/10b,Obtain parameters-174k puw-130k sow-150k rtw/20 rpm/7.8 trq-3 bpm/650 psi.Work over/into fish at 5,761'-reaming washing slowly 3k/4k wob-from 5,761'to 5,946'-unable to make hole.Observe 400 psi loss in pump press-increase in gas units to I50 units,CBU prep to POOH to inspect BHA.Fluid loss today 210 bbls-Total 3%brine fluid loss to well 3262 bbls-Metal recovered from ditch magnets today 45 lbs-Metal recovered from boot baskets today 0 lbs-Total metal recovered 45 lbs-Sized Salt Pill pumped today Obbls-Total SSP pumped to well 312 bbls. 11/09/13-Saturday Circ/cond gas out of well-650 max units-break off and blow down Kelly.POOH to inspect BHA.Filter Koomey hyd oil.Build vol,LD BHA#D b- std back DC-LD jars-bumper sub-xo's.Monitor well-static loss 93ph.Cont POOH with BHA#10 b-10 jts 1 1/2"CS Hydril tbg-left 5jts 1 1/2"tbg, bit sub,2-1/4"5 blades mill:in hole=168'also shear pin assembly.Service rig,Kelly spinner.Clean rig floor.Static loss 9bph.PU/MU BHA#11-8 1/8"over shot-6 1/4"bumper sub-6 1/4"oil jar-6 1/8"xo-9 ea 6 1/2"dc-6 3/16"x0-6 1/4"accelerator jar.RIH with BHA#11,Obtain parameters- 174k puw-130k sow-150k rtw/20 rpm/7.8 trq-3 bpm/650 psi.Engage fish at 5,762'with 15k dn-no inc in pump psi at 7 bpm-235 psi'-monitor well-10 bph loss,POOH with BHA#11.Recovered and LD Shear Pin Assy.Clean rig floor.MU BHA#12-8 1/8"cut lip guide-8 1/16"wp xo-5 3/4" shear pin guide-2 ea jts 1 1/2"cs Hydril tbg-4 1/8"x0-4 1/2"xo-6 3/16"xo-6 1/4"bumper sub-6 1/4"oil jar-6 1/8"xo-9 ea 6 1/2"dc-6 3/16"xo-6 1/4"accelerator jar-oal 383.44'.RIH with BHA#12 to 5,751'.MU Kelly-gas at surface-CBU to clear gas-138 max gas.Engage fish with 7k dn wt- no over weight or drag when picking up-monitor well-12 bph loss.POOH slow to inspect BHA.Fluid loss today 215 bbls-Total 3%brine fluid loss to well 3477 bbls-Metal recovered from ditch magnets today 0 lbs-Metal recovered from boot baskets today 0 lbs-Total metal recovered 45 lbs- Sized Salt Pill pumped today 0bbls-Total SSP pumped to well 312 bbls. Hilcorp Alaska, LLC Hilcorp Alaska,LLC. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 a .. °fir �.�.., �.A41 "' "�.. ., .%. 11/10/13-Sunday Finish POOH.LD BHA#ll-no recovery.Service rig-inspect draw works-hawk jaw-static loss 2 bph.MU BHA#12.RIH with BHA#12,CBU to clean gas out well-max gas 29,Obtain parameters-puw 175k-sow 135k.Tag Stub at 5,785'-attempt to engage fish.POOH to inspect BHA. Monitor well-fluid loss 10 bph.LD BHA#12-no recovery-spear was bent.Service rig.Fabricate wash tool for fishing tools.MU BHA#8.RIH with BHA#13-81/8"cut lip guide-8 1/16"wp xo-5 3/4"shear pin guide-2 ea jts 1 1/2"cs Hydril tbg-4 1/8"xo-4 1/2"xo-6 3/16"xo-6 1/4"bumper sub-6 1/4"oil jar-6 1/8"xo-9 ea 6 1/2"dc-6 3/16"xo-6 1/4"accelerator jar-oal 386.20".Circ/cond well.Obtain parameters-179k puw-130k sow- 130k rtw/20 rpm/7.9 trq-3 bpm/150 psi.Tag TOH at 5,786'-ream/wash using various parameters trying to get into 11/2"tbg fish-from 5,786' to 5,789'with 3k-5k wt do-no pressure increase to indicate fish was engaged.POOH to inspect BHA.Monitor well static loss 7.5 bph.LD BHA#13- 1 5/16"mule shoe stinger missing-bottom of 11/2"tbg is rounded inward as if trying to enter inside the 11/2"tbg fish.Service rig-inspect draw works-hawk jaw-Kelly-blocks-crown-slips dog collars. Clean floor. Static loss bph. MU BHA#14-8 1/8"cut lip guide-8 1/16"wp xo bushing-5 3/4"wp extension-S 3/4"shear pin guide-2 ea jts 1 1/2"cs Hydril tbg-4 1/8"x 0-4 1/2"xo-6 3/16"xo-6 1/4'bumper sub-6 1/4"oil jar-6 1/8"xo-9 ea 6 1/2"dc-6 3/16"xo-6 1/4"accelerator jar-oal 386.20'.RIH with BHA#14.Fluid loss today 245 bbls-Total 3%brine fluid loss to well 3722 bbls-Metal recovered from ditch magnets today Olbs-Metal recovered from boot baskets today Olbs-Total metal recovered 45 lbs-Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 312 bbls. 11/11/13-Monday Finish trip in hole w/BHA#14 to 5,754'.Kelly up get parameters P/u wt=170,R/T=150K,S/0=135k,Torque=5k at 20 rpm,pumping at 3 bpm=240 psi.Tag top of 1-1/2 fish at 5,785',made several attempts to engage fish w/different weights and pump pressures,was able to get a partial latch on fish,lost 100 psi pump pressure,shut down pump and blow down Kelly and set back same.Trip out of hole to BHA,lay down 11/2 Bha and subs,lost tapered tap.Cleaning rig floor.Finish laying down BHA cut lip guide,x/o bushing,spear guide.Making up BHA#b Overshot,bumper sub =13 ft.Trip in hole to 5,762'.Work over 2-7/8"tbg fish at 5,762',latch same and pull up to 10k over,set slips.Held pre job safety meeting w/ wireline. R/up lubricator and test same to 930 psi(held ok)Run#1-Rih w/2.15 swedge gauge ring CCL-to 5762'ELM,could not work down into fish,Pooh to run smaller gauge.GR had dings on face.MU/RIH with Run#2 redressed 1.75"GR/CCL to 5,762'ELM-unable to enter 27/8"stub- POOH GR had same dings on face.MU/RIH with Run#3-redressed 2.15"GR with centralizer-set down at 5762'ELM-POOH GR had same dings. MU/RIH with Run#4-redressed 1.75"GR add 2nd centralizer-set down at 5,762'ELM-POOH GR had same dings.LD Lubricator-slack of DP tension to neutral wt-RU lubricator.MU/RIH with Run#Swith redressed 1.75"GR-2 centralizers-set down at 5762'ELM-POOH GR had same dings.Fluid loss 9 bph.RD eline equip.PU sgl DP-find neutral wt-rotate overshot off fish.Install TIW-RU to CBU-open well-CBU at Dpm/430 psi-No gas to surface-blow down circ lines-Fluid loss D bph.POOH with BHA#15.LD BHA#15.PU/MU BHA#16-7"cut lip guide w/(21/4"5 blade inner dress off mill x 43/4"5 blade metal muncher mill)-5 3/4"wp ext-5 3/4"-wp ext-5 3/4"tc bush-6 1/8"xo-6 1/4"ox-7"boot bskt-6 1/8"bit sub w/flt-6 1/4"bumper sub-6 1/4"oil jar-6 1/8"xo-9 ea 6 1/2"dc-6 3/16"xo-oal 320.44'.RIH with BHA#16.Fluid loss today 210 bbls-Total 3% brine fluid loss to well 3932 bbls-Metal recovered from ditch magnets today Olbs-Metal recovered from boot baskets today Olbs-Total metal recovered 45 lbs-Sized Salt Pill pumped today Obbls-Total SSP pumped to well 312 bbls. 11/12/13-Tuesday RIH w/BHA#16 to 5,751',Establish parameters,Up 180k,Dn 135k,Rt 152K,8 BPM at 640 Psi,7K Tq at 80 RPMs.Tag top of fish at 5762'and dress 6"of tbg stub before torque started to increase.Blow down and POOH to BHA.Stand back DCs and lay down BHA.Left.9 of 2 1/4"dress off mill in hole.Hole taking 8 BPH.Service Rig.-8 bph static loss.MU BHA#17-8 1/2"x6"opticut shoe-4 jts of 8-1/8"wash pipe-8"bushing-6"xo-4 ea 7" boot bskts-6 1/8"bit sub-w/flt-61/4"bumper sub-6-1/4"oil jar-6 1/8"xo-9 ea 6-1/2"dc-6 1/8"xo-6 1/4"accel jar-oal 437.13'.RIH with BHA#17- fill pipe at 2,805'-5,731'-Kelly up-obtain parameters 175k puw-138k sow-150k rtw-150k-trq 8.5k at 60 rpm-8 bpm/355 psi.9 bph loss.Washing over 2 7/8"tbg stub at 5,762'to 5,862'-taking wt and trq-milling with 1-5k wt and 8k-10k trq-use various parameters to inc milling rate.Used max amount of wash pipe in BHA(100').Circ/cond well-prep to POOH.Fluid loss today 178 bbls-Total 3%brine fluid loss to well 4110 bbls- Metal recovered from ditch magnets today Olbs-Metal recovered from boot baskets today Olbs-Total metal recovered 45 lbs-Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 312 bbls. Hilcorp Alaska, LLC IliIcor!Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD `�'� 50-733-20111-01 188-038 10/29/2013 12/4/2013 11/13/13-Wednesday y Circ hole clean.Got back traces of oil and black sand.Had a high gas of 63 units.POOH to BHA.Lay dn BHA#17,Mill shoe was in good shape still at about 80%.Recovered 101.5 lbs from the boot baskets.Service Rig.Hole taking 12 BPH.PU BHA#18=8-1/2"Opti-Cut Mill Shoe,4jts 8-1/8"TSWP, X-over bushing,11 jts 7-5/8"X-line WP,X-over bushing,3jts 5-3/4"TSS washpipe,Triple connection bushing, 2XOs,4 boot baskets,Bit sub w/ float,Pump out sub,Bumper sub,Oil jars,XO,9DCs,XO,Accelerator jars.=855.46'. RIH with 8-1/2"mill shoe,filling pipe at 2,600'and 5,683'. Work down over top of fish at 4762'to 5,862'.Lay dn one sng and Kelly up.Wash/ream from 4862'to 5,917'using various parameters and staying within max torque of the 5-3/4"wash pipe-unable to make any more footage.Blow dn/rack back Kelly.POOH to BHA#E.LD BHA#18- remove 5-3/4"wash pipe from BHA and LD.Fluid loss today 1257bb1s-Total 3%brine fluid loss to well 4367 bbls-Metal recovered from ditch magnets today 95 lbs-Metal recovered from boot baskets today 132 lbs-Total metal recovered 242 lbs-Sized Salt Pill pumped today Obbls- Total SSP pumped to well 312 bbls. 11/14/13-Thursday Stand back all the 7-5/8"washpipe.Break mill shoe.Shoe worn about to about 33%.PU BHA#19=8-1/2"Opti-Cut Mill Shoe[Re-run f/#17],4jts TSWP,X0,11 jts X-line WP,Top Bushing,4 Boot baskets,Bit sub w/Float,Pump out sub,Bumper Sub,Oil Jars,Xo,9 DCs,XO,Acc Jars=757.58'. RIH filling pipe at 2,646'and 5,682'. Work over top of fish at 4762'with no issues. Continue in hole to 4872'and Kelly up.Establish parameters,Wash down to 5,917'-mill to 5,920'after picking up we were unable to return any deeper than 5919'.POOH-break off/blow down/rack back Kelly. L/D sgl-monitor well 11 bph loss.LD BHA#19-LD accelerator jars-stand back DC-recovered 43 lbs metal from boot baskets-clean floor-break down wash pipe safety vlv.RU BOPE test tools-pull wear ring-flush stack-drain stack-set test plug-fill equip-start testing BOPE as per Kuukpik- HAK-AOGCC procedures. Witness of test waved via email 11/14/13-4:59 pm by AOGCC Jim Regg. Fluid loss today 277bb1s-Total 3%brine fluid loss to well 4644 bbls-Metal recovered from ditch magnets today 122 lbs-Metal recovered from boot baskets today Olbs-Total metal recovered 459 lbs-Sized Salt Pill pumped today Obbls-Total SSP pumped to well 312 bbls. 11/15/13-Friday Testing BOPS.Test all BOP equip to 30 psi low and 2500 psi high.No failures.Witness of test was waived by Jim Regg,AOGCC.Rig dn test equip and line everything back up for normal operation.Service rig.Service and inspect draworks,hawkjaw,crown,Kelly,blocks,and rotary table.Adjus drwks brakes and rollers.Have Totco rep install new hoses,purge,and calibrate wt indicator.Installed new relay valve on high drum clutch.Make Up new 8-1/2"Opti-cut mill shoe on WP and RIH.BHA#33=Mill shoe,4jts 8-1/8"TSWP,XO bushing,11 jts 7-5/8"X-Line WP,Drive sub,4boot baskets,Bit Sub[w/float],Pump out sub,Bumper sub,Oil jars,X0,9DCs,X0,Acc jars=758.18'.RIH filling pipe at 3,119'and 5,683'.RIH over top of fish at 5,762 to 5,873'and Kelly up.Wash down to 5,878'and started taking wt. Attempt to work through tight spot but couldn't work past it. Circ bottoms up not getting anything back on bottoms up.Mill over what we think is collapsed tbg f/5876't/5,893'using varied parameters. Gained 10k on up wt and down wt. Acts like we may have some fish stuck in washpipe.Set Kelly back and POOH to last stand of washpipe.When we broke it off we had a jt of 1-1/2"tbg and 2-7/8"tbg along side each other.Back out ljt of 1-1/2"tbg and lower it out of the hanging stand of WP,Cut 10'2-7/8"tbg stub,latch onto last stand of washpipe and pull above rotary.Last stand full of tbg and junk.Break shoe and start laying down fish.Not sure how much was recovered at report time.Fluid loss today 734 bbls-Total 3%brine fluid loss to well 4938 bbls-Metal recovered from ditch magnets today 80 lbs-Metal recovered from boot baskets today 33 lbs-Total metal recovered 559 lbs-Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 312 bbls. Hilcorp Alaska, LLC Hilcorp Alaska.LLC Well Operations Summary Well Name _API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 11/16/13-Saturday Lay down fish.Recovered 95.20'of 2-7/8"tubing and blast jts and 116.15'of 1-1/2"tubing. Also had 63 lbs of metal recovered in boot baskets.Mill shoe was worn to about 30%.PU BHA#21=8-1/2"mill shoe,4jts 8-1/8"WP,XO,l0jts 7-5/8"XL WP,XO,Top drive sub,XO,4Boot baskets,Pump out sub,Bumper sub,Oil jars,XO,9DCs,XO,Acc jars,=732.68'. RIH filling pipe at 3,100'and 5,847',tag fish at 5,895'and mill over fish to 5,920',8 BPM 400 psi,WOB 2 to 15k,up wt 185k,Down wt 13k,Rotate wt 155k.Vary milling parameters as torque allows.Blow down Kelly.Monitor well w/ hole taking 15 BPH.POOH to top of perfs at 5460',Spot balanced 20 bbl size salt pill at top of perfs.POOH to BHA. Lay do jars and boot baskets, stand back washpipe,last jt of washpipe was packed full of balled up tbg.Broke mill shoe off and laid down the jt of wash pipe so we could work on getting the fish out while it was on the pipe rack.Recovered 53 lbs from boot baskets.PU BHA#22=8-1/2"opti-cut mill shoe,3jts of 8-1/8" WP,XO bushing,10 jts 7-5/8"WP,XO bushing,Drive bushing,XO,3boot baskets,Bit sub w/float,Pump out sub,Bumper sub,Oil Jars,XO,99Cs, XO,Acc jars,=704.93'.RIH filling pipe at 3,073'and 5,851'. Change out bail bumpers on Kelly swivel.Shakers blinded off.Pressure wash shakers and change out screens.Mill on fish[blast jts]at 5920'.Fluid loss today 285 bbls-Total 3%brine fluid loss to well 5223 bbls-Metal recovered from ditch magnets today 91 lbs-Metal recovered from boot baskets today 53 lbs-Total metal recovered 703 lbs-Sized Salt Pill pumped today 20 bbls-Total SSP pumped to well 3332 bbls. 11/17/13-Sunday Mill over fish[blast jts]from 5920'to 5,924'.Mill wouldn't drill off any more even after using various parameters.Blow down and set back Kelly. Monitor well,hole taking 6 BPH.POOH to BHA.Lay down acc jars,had abandon platform drill.Secure well and report to assigned bruckers.POOH w/BHA,lay down boot baskets,bumper sub,and jars.Stand back washpipe and break mill shoe.Mill shoe was D0%worn on the face and 50% worn on the sides.It had a groove cut right in the face of the shoe.Recovered 3i lbs metal from the boot baskets.RIH w/BHA#23=8-1/2"X 7- 1/4"Mill Shoe,3jts 8-1/8"WP,XO,10jts 7-5/8"WP, XO,Drive bushing,3boot baskets,Bit sub w/float,Pump out sub,Bumper sub,Oil jars,XO 9 DCs,XO,Acc jars,=703.42'. P/U Kelly,Establish parameters:10 BPM w/600 PSI,UP Wt 185K,DN WT 132K, Rot WT 152K, 8-13K TQ @ 50-70 RP. Mill over fish[blast jts]from 5924'to 5,958'.Gradually increase WOB to 20K with no ROP or Torque swings.Blow Down and set back Kelly. Monitor Well. 9 BPH Static loss rate.TOOH from 5958'to 3,582',Slip and cut Drill Line.Continue to TOH from 3582' w/BHA.Lay down boot baskets,bumper sub and jars.Stand back wash pipe and break mill shoe.Fluid loss today 16 bbls-Total 3%brine fluid loss to well 5389 bbls- Metal recovered from ditch magnets today 337 lbs-Metal recovered from boot baskets today 3)lbs-Total metal recovered 725 lbs-Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. 11/18/13-Monday Finish cleaning boot baskets and clean up rig floor.Recovered 17#from boot baskets.MU BHA#24=8-1/4"Opti-cut mill shoe w/6-3/4"ID,XO,3 jts WP,XO,10 its WP,XO,Drive bushing,XO,Boot baskets,Bit sub[w/float],Pump out sub,Bumper sub,Oil jars, XO,UCs,XO,Acc jars=705.42'. RIH filling pipe at 3,547'and 5,915',Wash to bottom at 5958'. Fan bottom to get junk off bottom.Mill over blast jts from 5958'to 6,042'.Gained 10k up wt and mill was either worn out or spinning.Run lto 5k WOB,10 to 14k torque,10 BPM 625 psi,Up wt 180,Dn wt 130,Rotate wt 150.High on gas units was 400.Blow Kelly down and set back same.Monitor well at 9BPH losses.POOH to BHA. POOH w/BHA,lay down boot baskets, bumper sub,and jars.Stand back washpipe and break mill shoe. Recovered 8)lbs metal from the boot baskets.P/U BHA#3- 8-1/2"X 7-1/4" Mill Shoe,3 jts 8-1/8"WP,XO,10 jts 7-5/8"WP, XO,Drive bushing,3boot baskets,Bit sub w/float,Pump out sub,Bumper sub,Oil jars,XO 9JCs, XO,Acc jars,=704.73'.RIH w/BHA#25 from 703'to 5,914'.P/U Kelly,wash over TOF @ 5918'.Continue to wash down and tag fill @ 0038'.Fan bottom several times. Wash and Mill over fish from 038'to 6,075'.P/U 180K,SO 135K,Rot 152K, 10 BPM with 700 psi, 50-80 RPM,Oto 20K WOB, 300 units gas @ 6,060'Oil and sand @ Shaker.Fluid loss today 193 bbls-Total 3%brine fluid loss to well 5582 bbls-Metal recovered from ditch magnets today 243 lbs- Total metal recovered 1005 lbs-Sized Salt Pill pumped today 0bbls-Total SSP pumped to well 332 bbls. Hilcorp Alaska, LLC flihorpAlaska.LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 Daily Operation$:' 11/19/13-Tuesday Mill over blast jts from 4075'to 6,078'.Blow down Kelly.Monitor well at 9BPH losses.POOH to BHA. Stand back DCs,lay dn boot baskets,had to lay dn 2 bad jts of washpipe,break mill shoe.Shoe still had carbide on the face and still had its original ID and OD.Approx D%used.Recovered 49.5 lbs out of boot baskets.PU BHA#26=8-1/2"X 6-3/8"Opti-cut mill shoe,3jts 8-1/8"WP,XO,8jts 7-5/8"WP,XO,Drive bushing,XO,3boot baskets,Bit sub w/float,Pump out sub,Oil jars,XO,9DCs,XO,Acc jars=647.56'.RIH filling pipe at 3,293', continue TIH and work over TOF @ 5,918'.P/U Kelly @ 6,047',Wash down and tag @ 6,078'.Fan bottom several times.Wash and Mill over fish from 6078'to 6,166'.P/U 185K,SO 132K,Rot 155K,10 BPM with 675 psi,50-80 RPM,Oto 15K WOB. Encounter stall outs and high torque @ 6166'.Attempt to make hole with no success. P/U off bottom with 20K overpull.Set back down on top of fish and P/U hole with 20K over string weight.Attempt to Rotate 33'off bottom with no success.Blow down and set back Kelly.Monitor well with 6BPH static loss rate.TOOH from 6166'.Fluid loss today 217 bbls-Total 3%brine fluid loss to well 5799 bbls-Metal recovered from ditch magnets today 239 lbs-Metal recovered from boot baskets today 43.5 lbs- Total metal recovered 1237 lbs-Sized Salt Pill pumped today Obbls-Total SSP pumped to well 332 bbls. 11/20/13-Wednesday POOH to BHA.Laid down Acc jars and Stood back one DC and mule winch broke.Set back last 2stds of DCs.POOH with the rest of the BHA.Lay dn boot baskets,bumper sub,and jars.Break mill and lay dn 2jts of WP.Clean boot baskets.Recovered E6.5 lbs of metal.PU magnet and run it up and down through stack on Kelly.PU 11.5 lbs of metal.Service rig and install repaired mule winch at derrick board.PU BHA#D=5-3/4"overshot w/upper extension&8"oversized guide[Dressed with 3-3/4"grapple],XO,Bit sub w/float,pump out sub,Bumper sub,oil jars,Magnostar magnet,XO 9 DCs,XO,Acc jars.=342.87'.RIH and fill hole at 2,995'and 5,900',Circ one full circulation. Wash down on fish at 6918'and swallow 6'to 5,925'.PU with slight overpull.Pumping at 43 spm 90 psi,increased to 325 psi when we got over fish and picked up.Blow down and set back Kelly.TOH from 5,900'to 370'. Lay down Accelerator Jars.Rack back drill collars.Clean string Magnet(Recover b lbs Metal).Remove fish from Grapple.Lay down Bumper Sub and Jars. Lay down 9blast jts(176.54').Clean and Organize floor.PU BHA#28=5-3/4"overshot w/upper extension&8"oversized guide[Dressed with 3-3/4"grapple], XO,XO,Bit sub w/float,pump out sub,Bumper sub,oil jars,Magnostar magnet, XO,9 DCs,XO,Acc jars.=342.87'.TIH from 343'to 6,026'(60 stds).P/U 10'pup and single.P/U Kelly,break circulation, P/U 185K,SO 140K.RIH and tag TOF @ 6,096'.Work over fish to 4104'. Jar 50-100K over in 25K increments.Jared free with 190K new Up Wt. RIH to 4110'with overshot. No Tag.Blow down and set back Kelly.Lay down single and 10'pup joint.TOH from 4096'with possible fish.24 hr BOP Test notification sent to AOGCC on Thu 11/21/2013 5:29 AM via e-mail.Fluid loss today 212 bbls-Total 3%brine fluid loss to well 6011 bbls.Metal recovered from ditch mags today 485 lbs.Total Metal Ditch Mags 1722 lbs.Metal recovered from boot baskets today Olbs.String Mag Metals 78 lbs.Total metal recovered 1800 lbs.Sized Salt Pill pumped today Obbls-Total SSP pumped to well 332 bbls. 11/21/13-Thursday Break fish out of overshot.Recovered 19.48'of blast jt,and 20 lbs off magnets.Hole taking 9 BPH.PU BHA#29=8-1/2"opti-cut mill shoe,2jts 8- 1/8"WP,XO 3 jts 7-5/8"WP XO drive bushing,3 Boot baskets,Bit sub w/float,Pump out sub,magnostar magn-et,XO,921Cs,XO,Acc jars= 490.89'.RIH and fill pipe at 3,330'and 6,143'.Fill pipe and wash to bottom.Work mill shoe next to bottom to clear cuttings.Mill over fish f/4166' t/6,227' (Top Of Packer).PU 195K,SO 130K,RT 155K,10 BPM @ 660 PSI,70 RPM @ 200-500 AMPS.Circulate bottoms up 1-1/2 times. Sand and oil at shaker.360 units gas.Blow down and set back Kelly.Monitor well with 9BPH static Loss.TOH from 6227'to 490'. Lay down Acc.Jar.Rack back drill collars.Clean string magnet (44.5 lbs metal recovered),break down boot baskets,Stand back 1 stand wash pipe,lay down wash pipe and overshot.Fluid loss today 190 bbls-Total 3%brine fluid loss to well 6201 bbls.Metal recovered from ditch mags today 165 lbs.Total Metal Ditch Mags 1887 lbs.Metal recovered from boot baskets today 01b.String Mag Metals 20 lbs. Total metal recovered 1985 lbs.Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date lEnd Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 ea141.1;;C: 11122/13-Friday Work BHA.When we broke the stand of WP off there was a blast jt inside.Made stand back up and RIH.Lay down two jts of WP and we had abou: a 15'blast jt stub sticking up.Lay dn WP and fish.Recovered%.75'of blast jts and 36.60of tbg.Total recovered%.35'.Recovered 44.5 lbs off magnet and 52 lbs out of boot baskets.Rig up to test BOPs.Flush stack.Had a slow bleed off and traced it back to the test plug.Pull test plug, cleaned it up and put duct tape over rubber.Ran back in stack and purged the air out of the system.Resime testing BOPs.Test all BOP equip to 250 psi low and 2500 psi high.Witness of test was waived by Jim Regg. Rig down test equipment.Blow down all surface equipment.Note: Removed 3 blast jts,Sliding sleeve,2 partial pup jts(58.64)from 8"wash pipe on the deck. Estimate 14'+/-tubing fish left on top of packer @ 6,227'.Set wear Bushing,P/u BHA#30:8-1/2"x 6"MM PKR Shoe,lit 8-1/8"WP, Top Sub Drive Bushing,XO p x p,3Boot baskets,Bit sub w/float, Pump out sub, Bumper Sub,Oil Jar,magnostar magnet,XO,9DCS,XO,Acc jars.Total BHA Length=379.59'.TIH from 380'to 6,158'. PU 10'pup and single to 6,199'.PU Kelly,Break circulation and establish parameters:/32K PU,140K SO,165K Rot @ 60 RPM w/10K TQ,0-12K WOB.Mill on Packer and junk from 6,227'to 6,231'.Fluid loss today 110 bbls-Total 3%brine fluid loss to well 6311 bbls.Metal recovered from ditch mags today 75 lbs.Total Metal Ditch Mags 1961 lbs.Metal recovered from boot baskets today 2 lbs.String Mag Metals 45 lbs.Total metal recovered 2156 lbs.Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. 11/23/13-Saturday Mill over packer f/6,231'to 6,233'and chase to 6,241'.Circ out gas and oil,had a high of 580 units of gas.Wash in hole to 6285'where we started taking wt.Circ bottoms up gas and oil out.Blow down Kelly and POH to BHA.Clean magnet and lay down boot baskets.Recovered 5 lbs from boot baskets,and 44 lbs from magnet.Break off shoe and recovered about I)lbs of assorted junk in shoe.PU BHA#31.=overshot dressed with a 6"grapple,XO.1 jt WP,XO,bit sub with float,pump out sub,bumper sub,oil jars,magnet,XO,9Xs,XO,acc jars=365.01'. RIH filling pipe at 3,205'and 6,270'.PU Kelly and single to 6,270'. Circulate bottom up @ 10 BPM with 450 psi with 550-600 Max Gas Units. Establish parameters:4 BPM with 60 PSI,195K PU,140K SO, Tag TOF @ 6285'. Set 10K down,PU with 1-3K over pull,Set 25K down with same over pull,Rot slowly with 10K down with 20-30 PSI increase and no positive indication of engagement.Blow down and set back Kelly.Monitor well with,Trip out of the hole from 6,238'to 365'.Lay down Acc.Jar.Rack back drill collars,clean string magnet (44.5 lbs metal recovered)Inspect grapple with no indications of grapple engagement.Lay down wash pipe and overshot.Call for 47/8"grapple to fish Locator Sub on top of PKR.Helicopter on weather hold. Service Rig.Perform Derrick inspection.Clean and organize rig floor.Lay down string magnet,bumper sub,Oil Jars,Washpipe.Change over to 3/4"handling equipment.RIH laying down 3 stds 5"washpipe from derrick.Clear all un needed fishing tools from rig floor and put in baskets.PU BHA#32=overshot dressed with a 4-7/8"grapple,XO.1 jt WP,XO,bit sub with float,pump out sub,bumper sub,oil jars,magnet,XO,9X5,XO, acc jars=365.01'.TIH with BHA#32 from 365'. Fill pipe @ 3,280'.Fluid loss today 104 bbls-Total 3%brine fluid loss to well 6415 bbls.Metal recovered from ditch mags today 177 lbs.Total Metal Ditch Mags 2138 lbs.Metal recovered from boot baskets today lbs.String Mag Metals 44 lbs.Total metal recovered 2472 lbs.Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. 11/24/13-Sunday Continue RIH.Fill pipe at 6,270'.Circ bottoms up had 580 units and traces of oil.Engage fish at 6290'.Had 120 psi increase in pressure.Pulled 15k over and fish came free.Ended up with a 51(wt increase.Blow down Kelly.Monitor well w/hole taking 4BPH.POH to BHA.Stand back DCs.Clean magnet.Recovered 12 lbs metal. POH to shoe and had seal assem hanging out of shoe w/XO,1jt 2-7/8"tbg,X-nipple,2-7/8"tbg pup,Re-Entry Guide.Recovered 58.20'of fish.PU BHA#33=Spear w/4.805"catch grapple,XO,Bit sub w/float,Pump out sub,Bumper sub,Oil jars,magnet, XO,9 DCs,XO,Acc jars=337.64'.RIH filling pipe at 3,177'and 6,274'.Wash down and spear into fish at 6298'. Had a 100 psi increase,PU 30k over and packer started to drag up hole with 10k to 20k over pull.PU to 6,274'.Circ 1 full circ.Highest gas units were 20,and traces of oil.Blow down, set back Kelly.Monitor well,hole taking 3 BPH.POH from 6274'to 620'.TOH L/D 9)jts 5"DP,Lay down Accelerator Jars,Rack back drill collars, Clean string Magnet(Recover 19 lbs Metal),Break Spear and Lay down PKR fish.PU BHA#31: 8-1/2"Bladed Junk Mill, 3)Boot Baskets,Bit Sub w/float, Pump Out Sub,Bumper Sub,Oil Jar,String Magnet,X Over,96-1/2"DC's,X Over,Accelerator Jar.Total BHA Length= TIH from 350 to 3,192'.Fill Pipe,blow down circ lines.TIH to 6287'. L/d single(jt 189). PU Kelly.Break circulation and establish parameters.Wash and ream from 6,287'to 6,495',10 BPM with 568 PSI,P/U 195K,DN 142K,Rot 165K,RPM 50-80,WOB 0-25K.Total Gas Units while Circulating=623. Fluid loss today 112 bbls-Total 3%brine fluid loss to well 6527 bbls.Metal recovered from ditch mags today 12 lbs. Total Metal Ditch Mags 1250 lbs.Metal recovered from boot baskets today Olbs.String Mag Metals 19 lbs.Total metal recovered 2503 lbs.Sized Salt Pill pumped today 0 bbls- Total SSP pumped to well 332 bbls. Hilcorp Alaska, LLC Hiliorp Alaska,LL( Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 tWq , 0atlQtis: 11/25/13-Monday Mill on fill and junk f/6,495't/6,725'. Top of float collar.Circ hole clean.Tag bottom to check for fill.No fill.POOH to BHA.Lay down Acc jars, Stand back DCs,Lay down magnet,Jars,Bumper sub,Pump out sub,Bit sub,Loot baskets,and a junk Mill.Recovered 80 lbs off magnet and 51 lbs from boot baskets.Rig up E-Line.RIH with GR/CCL.Locate bottom @ 0709'(WLM)(6725'DPM).Log up from 0709'to 1,059'.POOH with E- Line.Rig Down E-Line. PU and TIH with RTTS from Surface to 4720',Set RTTS @ 4720'.PU 120K,DN 90K,Set RTTS with 1-1/2 turns to the right.Rig up to Pressure Test the Casing to 1500 psi.Pressure test 9-5/8"casing to 1500 psi from 4,720'to surface.Test good.Bleed down and Release RTTS. TIH from 4,720'to 6,254'.Set RTTS.Rig up Circulating lines.Line up to circulate well to production.Displace well to clean Brine.Circulate to pits @ 4-5 BPM.Feed production from OBM Tank @ 2BPM.Shipped 700 bbls 3%KCL Brine to Trading Bay.Perform injectivity test prior to Scale Squeeze. PT Lines to 250/2000 psi.Perform injectivity @ 1 BPM,Pumping 25 bbls away with 1880 psi and climbing. Consult with town on results.Fluid loss today 99 bbls-Total 3%brine fluid loss to well 6626 bbls Metal recovered from ditch mags today 518 lbs,Total Metal Ditch Mags 2150 lbs. Metal recovered from boot baskets today 51 lbs. String Mag Metals 80 lbs.Total metal recovered 3152 lbs.Sized Salt Pill pumped today Obbls-Total SSP pumped to well 332 bbls. 11/26/13-Tuesday Release RTTS and monitor well while cleaning the trip tank.POOH with RTTS. Waiting on E-line perf guns to arrive on rig.PU 0'x 2-1/2"6 SPF Perf Gun. PT Lubricator to 2500 psi. RIH with Perf Gun,correlate and tie in to CCL.Park @ 6506'CCL depth placing top shot @ 4515'to 6,535'. Fire gun. POOH with gun.All Shots fired.Rig down E-Line.Static loss rate 3BPH before Perf.Static loss rate 45 BPH After Perf.PU and TIH with RTTS from Surface to 6254'. Set RTTS @ 0254'. PU 163K,DN 111K,Set RTTS with 1-1/2 turns to the right. Rig circulating lines.Perform injectivity test prior to Scale Squeeze. PT Lines to 30/2000 psi.Perform injectivity @ 1 BPM,Pumping 15 bbls away with 1880 psi and climbing.Consult with town on results.Decision made to pull up hole above E-Zone to 4985'. Release RTTS.TOH to 51975'.PU 15'pup jt.to 5,985'. Set RTTS between E and D zone @ 5985'. Perform injectivity starting @ 1BPM and staging up to 2.5 BPM,Pumped 31 bbls away with 1770 psi and climbing.,Release RTTS TOH to 5406',Set RTTS above all perfs @ 5406'. Perform injectivity test with final injection rate @ 3bpm with 800 psi.Start mixing Preflush pill with 2-330 gal totes WAW5206 to 185 bbls FIW.=201 bbls total. Fluid loss today 96 bbls-Total 3%brine fluid loss to well 6722 bbls.Metal recovered from ditch mags today Olbs,Total Metal Ditch Mags 2150 lbs.Metal recovered from boot baskets today Olbs String Mag Metals 0 lbs.Total metal recovered 3152 lbs.Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. 11/27/13-Wednesday Held Pre Job meeting&JSA with RTTS set at 5406'.Pumped and spotted 80 bbls Preflush WAW 5206 in work string.Shut down pump,closed by pass,continue to bull head additional fluid pumping at total of 192 bbls pumping at 2.5 bpm.Final pressure fo 920 psi. Shut down pump and monitor presure while mixing second batch of scale squeeze. Pressure bleed f/TO psi to"0"in 10 min. Continue bull heading 140 bbls of SCW 4004 AT 2.5 bpm at 900 psi. Displace same w/96 bbls 8.6 FIW W/3%KCL followed with additional 175 bbls of 8.6 FIW W/3%KCL for overflush at 2.5 bpm with fiinal pressure of 1209 psi.Shut down pump,monitor pressure for 15 minutes,pressure bleed f/1209 psi to 37 psi. Release RTTS. R/D circ lines and blow down same.Flow check,found the knife valve leaking on flow line,clean and gel same.Fluid loss at 2 bph. POOH w/RTTS and lay out by pass.RIH w/3 std of drill collars. Make up RTTS w/storm valve and set same at E ft below rotary and test same to 1500 psi for 5 min good test.Rig up and pull wear bushing.N/D Down BOP. Bleed off Koomey,install P/U slings,break flanges,pull mouse hole,master bushings, bell nipple, flow box and set BOP stack aside. Pull and L/D riser,drilling spool and old tubing head.Prep wellhead for new Tbg Head.Land and N/U Tbg Head.Test pack off.Land and N/U Riser and Bop and associated equipment.Fluid loss today 83 bbls-Total 3%brine fluid loss to well 7523 bbls. Metal recovered from ditch mags today Olbs.Total Metal Ditch Mags 2150 lbs.Metal recovered from boot baskets today Olbs. String Mag Metals 0 lbs.Total metal recovered 3152 lbs. Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls.Losses from squeeze= 618 bbl Hilcorp Alaska, LLC ll ik.orp Alask=a,LL(: Well Operations Summary Well Name _API Number _Well Permit Number Start Date _End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 11/28/13-Thursday Rig up and and test BOP related surface equipment to 30 low and 2500 psi high,with 2-7/8",3-1/2"&5"pipe all test made with water and held for 5 min on low and hi test.No failures reported.Conducted Koomey test 31 sec to pressure up to 200 psi and 172 sec to pressure up system to 3000 psi.Witness of test waived by Jim Regg,AOGCC.L/d test equipment&install wear bushing. RIH w/lstd of 5"drill pipe and screw in to storm valve.Check drill pipe for pressure, "0',pipe on vaccum.Close hydril and release RTTS tool and pull up into the BOP'S.Fill hole with 23.3 bbls 8.6 FIW w/3%KCL.Static loss at 7.5 bph.Lay out RTTS&POOH w/3stds of 6.5 D.C.s. Rigging up safety jt.for guns.Pick up TCP gun assembly as followed(bull plug and blank,bottom shot,4-5/8"5 spf Millennium guns,4-5/8"safety spacer and subs,Model IIID fire head w/156 No go,1 jt 2- 7/8"EUE tubing,ported fill disk,ljt 2-7/8"tbg,Ra marker sub,x/o 2-7/8"x 4-1/2"IF,drill pipe to surface.Total length of assembly at 2006.51. Change over to 5"DP handling equipment.TIH with perf guns on 5'DP.Tag bottom @ 6,723'. Stand Back 1 stand and PU 1 single and Park @ 6,675'EOP and 4,469'RA Marker.Drill Pipe Measurement.(2.00'Deep). Rig up WireLine.RIH with Wireline and correlate gun depth to RA Marker. Locate RA Marker @ 4665'(2.00'Shallow) Need to be @ 4,667'. POOH and set Wireline aside.P/U 5 pup jt and reposition pipe 2.00'down hole. RIH with Wireline and correlate gun depth to RA Marker.Locate RA Marker @ 4667'. Send log to town for depth approval.Receive ok to drop bar.Rig down E-Line.R/U Bar drop Sub and circulating lines in preparation to drop bar."Fluid loss today 27 bbls-Total 3%brine fluid loss to well 7650 bbls.Metal recovered from ditch mags today Olbs.Total Metal Ditch Mags 2150 lbs.Metal recovered from boot baskets today Olbs.String Mag Metals 0 lbs.Total metal recovered 3152 lbs.Sized Salt Pill pumped today 0 bbls-Total SSP pumped to well 332 bbls. 11/29/13-Friday Drop bar,fire guns,had good indication.Well took 6bbls to fill hole.(Top shot at 4752 ft and btm shot 6,673 ft. Circ out perf gas on choke w/86 ppg FIW w/3%KCL with drill press at 240& csg press at 247 psi.Circ thru ported fill sub at 4701'.Shut down pump,bleed down csg press f/220 psi to 80 psi w/4 bbls back.Close choke,pressure increased to 240 psi in 10 minutes.Weighting up surface pits f/86 ppg to 9.3 ppg. Circ well increaseing fluid wt f/86 ppg to 9.3 ppg. Shut down pump,open well,flowed back 6bbls.Close well-pressure increased to D psi.Circ well increasing fluid wt f/9.3 ppg to 9.5+ppg.Monitor well.Oil breaking out @ surface but Well Static.Open bag and circulate @ 4BPM,125 stage up to 6.5 BPM with 380 psi.Gain 1 to 1 1/2 BPM while circulating.Shut in with no pressure build.Pump and spot Balanced 98 ppg 3%KCL.above perfs.Monitor well.Fluid falling @ 10-15 BPH.TOH 5 stands to 6,675'EOP and 4,167'circulating depth through ported disk.Gained 5bbls on 5 stands.Monitor well on trip tank with flow @ 15 BPM slowing to and staying @ 1 BPM. Shut in with 40 psi in 30 Min.Open Bag,circulate and Weight up active to 9.9 ppg in and out.Monitor well with 1to 11/2 BPM flow back.Closed bag,pump down drill pipe and Bullhead N bbls below ported disk.Open bag,flow back slowed.CBU,losing 20 bbl on circ.with no gas(=70 BBLS 9.9 ppg below ported disk=1431'). Monitor well with 60 BPH losses @ end of circulation and slowing to 42 BPH.TOH from 0173'stopping periodically for static loss rate.Loss rate staying at 4I BPH. TOH to 4,280'standing pipe back on off drillers side to make room for 4'DP on the next well. Static loss @ 42 BPH.TIH with Remainder of 5'DP from Drillers side Derrick to 6178'. Monitor well @ 6,178'Static loss rate @ 3O BPH.Pump and Spot 38 BBL size salt pill.Monitor well. 11/30/13-Saturday Trip out of hole f/6,173'to 5,416'.Monitor well letting salt size pill fall due to U-tubing.Continue to POOH to gun assembly at 2,006'.Lay down TCP gun assembly.Clear rig floor of TCP Tools.Clean up rig floor from gun run.Monitor Well on Trip Tank.Gain Loss fluctuating due to oil breaking out at surface. Flush oil from stack and trip tank.Monitor well on trip tank. Gain Loss still fluctuating due to oil breaking out at surface. Bull Head CI BBLS.Monitor Well with 8 BPH Loss Rate. Drain Stack.Pull Wear Bushing.Rig up to Monitor well on Trip Tank below Test Plug.Rig up 31/2"Test Joint and equipment. Set test Plug.Flood Stack and Choke Manifold.Open Trip Tank to annulus and monitor well with 2BPH Static Loss Rate.Test BOP to 250/2500 psi:Bag to 3-1/2"and @ 2-7/8"Pipe Size.KHCR,CHCR,4ea choke manifold valves.Blind Rams.Monitor well on trip tank with 2 BPH losses.Pull test plug and rig down BOP test equipment.Rig up E-Line to Set Packer @ 4704'.PU Packer Assembly As Follows:9-5/8"36-53.5# MODEL D Permanent Packer,3250"Concentric Packer Adapter,3250"Seal Bore Extension 10'3.250"ID,3.250"Concentric Tandem Adapter, 3.250"Seal Bore Extension 10'3.250"ID,Tubing Adapter 3.250"SB to 2-7/8"eue 8rd box,2-7/8"EUE 8RD Pup Joint,Landing Nipple,2313"X Profile w/2-7/8"8RD BxP (WITH PLUG INSTALLED),27/8"EUE 8RD Pup Joint,WLEG 27/8",Total Length of Packer Assembly=40.29'."Fluid loss today 213 bbls-Total 3%brine fluid loss to well 7973 bbls.Metal recovered from ditch mags today Olbs.Total Metal Ditch Mags 2150 lbs.Metal recovered from boot baskets today Olbs.String Mag Metals Olbs.Total metal recovered 3152 lbs.Sized Salt Pill pumped today 40 bbls.Total SSP pumped to well 372 bbls. Hilcorp Alaska, LLC Hilcorp Alaska.LU. Well Operations Summary Well Name API Number Well Permit Number Start Date _End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 i 4..:a 12/01/13-Sunday Continue to RIH w/9-5/8"36-53.50# Model D Permanet Packer.Log on depth and set packer at 4,704'ELM.Pooh rig down E-line.Packer assembly =2-7/8"WLEG,2-7/8"6.5#,L-80 tbg pup,2-7/8"X-laning nipple(with Xplug with pring installed),2.7/8"6.5#L-80 tbg pup,Tubing adapter w/2- 7/8"EUE Box,3.250"seal bore extension,3.250"Concentric packer Bottom adapter,9-5/8"36-53.50#model packer total length=40.29'. Rig up& test packer to 500 psi for 5 minutes(good test). Finish rigging up sheeves in derrick for chemical inj line and electric cable making up seal assembly w/indexing mule shoe,chemical injection mandrel,pups and sliding sleeve.Continue to PU and MU ESP Pump and By pass Pipe assembly as Follows:Anode,motor base plug,base gauge,motor,protector,intake,AGH,pump DSOON,pump DS800N,pump D5800N,discharge pressure sub assy,head bolt on discharge PMP,XO 35"EUE B X 2-7/8"EUE,XO PMJ B X 35"EUE P,Tubing Pup Joint PMJ B X P, Y-Tool Right (Isolation sleeve installed)Nipple,handling Sub 3-1/2"EUE Box X 3-1/2"PMJ PIN, XO 3-1/2"RTS-8 Box X 3-1/2"EUE Pin.Rig up 3-1/2"Tubing Handling equipment. "Fluid loss today 21 bbls-Total 3%brine fluid loss to well 7,994 bbls. Metal recovered from ditch mags today Olbs.Total Metal Ditch Mags 2150 lbs.Metal recovered from boot baskets today Olbs.String Mag Metals Olbs.Total metal recovered 3152 lbs.Sized Salt Pill pumped today 40 bbls-Total SSP pumped to well 372 bbls. 12/02/13-Monday Trip in hole picking up 3-1/2"9.3#L-80 RTS 8 Tubing w/20 ft 3.250"seals and ESP pump,Y Block Assembly,Chemical injection line and motor lead,installing cannon clamps on every other jt.Test chemical injection line and mag motor lead at 2175',3,164'&3,728'-all good test.Make up SSSV.Pressure test same to M00 PSI for 15 Min.Test Good.Continue to TIH picking up 3-1/2"tubing ESP Completion. Locate top of PKR @ 4,704'.Pass 20'Seal assembly through Seal Bore with 3.7K Dn Wt.Stack out Locator Sub @ 4704'(23.50'in on Jt 140). Dn Wt 57K before Seal Bore.Dn Wt 50K with Locator Sub stacked.Space Out Tubing as follows: L/D Jt 110(23.50)and Jt 139(31.17')=(54.39'L/D)-(41.00'RKB)= (13.67'Needed)-(3.82'Tbg Hgr)=(9.85'Pup)PU 9.75 RTS-8 Pup,XO Pup to 3.1/2"8rd,TBG HGR.PU Landing Joint. Up/Wt E6K,Dn/Wt 57K,Splice Motor Lead and Control lines to Tbg Hgr.Test Motor Lead.Good Test.Test Control lines.Good Test.Drain Stack.Slack off and land out Tbg Hgr. Pass Seal assembly through Seal Bore with 37K Dn Wt.RILDS on Tbg Hgr.Pump Down the Annulus and attempt to pressure test top of PKR and Seals.Had immediate returns up the Tbg with the Charge Pump Pressure @( l Psi). Pump down the tubing with the Charge Pump and had same results out the annulus.Consult with Town.Rig down Completion Running Equipment.Clear and clean Rig Floor.Ran 31/2"9.3#RTS-8 Tubing Completion As follows:2jts Tubing,Pup Jt,GLM 7,Pup Jt,27 jts Tubing,Pup Jt,GLM Z Pup Jt, 41 jts Tubing,Pup Jt,GLM 3 Pup it, 60 jts Tubing, Pup Jt,SSSV,Pup 1t,8jts,XO Pup,Pup 1t,HGR 138 Joints total.Used 50 SS Bands.Used 90 Cannon Clamps."Fluid loss today Obbls-Total 3%brine fluid loss to well 7994 bbls.Metal recovered from ditch mags today 0 lbs.Total Metal Ditch Mags 2150 lbs. Metal recovered from boot baskets today Olbs.String Mag Metals 0 lbs.Total metal recovered 3152 lbs. Sized Salt Pill pumped today 40 bbls-Total SSP pumped to well 372 bbls. 12/03/13-Tuesday Rigging up lubricator onto landing jt.Test same to 1500 psi.RIH w/2.80 gauge ring on 1-1/2"tool string 24.5 ft long to Isolation sleeve at 4,447'slm.POOH w/no problems.Fill circ lines,attempt to test back side to]100 psi got returns on tbg after reaching 700 psi on backside,shut down pump and blow down lines.RIH w/kick over tool and locate gas lift and tap down on each dummy valve,still unable to test back side. Rlh w/3-1/2"GS tool to 4,447'slm and latch and pull Isolation sleeve in Y block.POOH,made two runs w/2.25'magnet tagging up at 4,749 ft slm each time.Recovered small amount of metal shavings. Slick line RIH w/225 LIB to 4,749'slm made impression.POOH.Had impression of prong fishing neck looking up. Made up 2"RB pulling tool. RIH latch prong,unseated same,POOH,no recovery. RIH w/2'SB pulling tool latch prong POOH recovered prong,had 50 psi on tbg. Rlh w/GS tool to pull plug, pooh did not pull plug.RIH w/blank plug unable to set same.POOH.Redress packing on Isolation sleeve. RIH and set same in Y-block at 4447'slm.POOH w/slick line.Install night cap on tbg SICP 775 PSI.Pressure up on the 9-5/8"x 3.5"annulus and top of the 9-5/8"model d Permanent pkr and seals to 1500 psi in 250 psi increments hold for 15 mins on chart(good test)tbg holding at 175 psi. Rlh w/3-1/2"GS tool to 4,447'slm and latch and pull Isolation sleeve in Y block.POOH.RIH w/Z7/8"x-line w/2.313 x- plug to 4,625'set down on x/o sleave, POOH.,OOH found tool had sheared,prep plug and running tool to go in the hole. RIH w/same and 4745' slm and set plug.POOH.RIH w/prong and set in plug.POOH.Rig down slick line. Hilcorp Alaska, LLC Ili!carp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-16RD 50-733-20111-01 188-038 10/29/2013 12/4/2013 'Daily Operations: 12/04/13-Wednesday Lay down landing jt and install BPV. Nipple down BOPS'.Remove turn buckles,bell nipple and flow line.Install bridge crane on annular. Pick up BOP stack and trolley out of way,nipple down riser and lay out same.Nipple up tree and install SSV and wing valve and torque down.Finish nipple up tree and test void hanger.Void to 5000 psi/30 min.Finish pumping fluid to Trading Bay(total of 433 bbls pumped.)Test tree to 250 psi/5 min and 3500 psi/30 min.Pull TWC.Rig up slickline lubricator,PT lubricator to 600 psi.RIH and set catcher sub at 4749'.When swab and master valve were open well had 560 psi on tubing.Pull chem inj dummy valve at 4676'.Set chem inj valve at 4,676'.Pull GLM#3 dummy valve at 4,372'. Pull GLM#2 dummy valve at 3,517'.Pull GLM#1 dummy valve at 2,225'.Set GLM#1 valve at 2,225'. Set GLM#2 valve at 3,517'.Set GLM#3 valve at 4,372'.Pull catcher sub at 4,748'. Pull prong at 4,749'.Pull plug at 4,749'. Verify sliding sleeve is closed at 4,605'.Set isolation sleeve in Y tool at 4,431'.Rig down slickline and get ready to skid rig.Tubing pressure M psi. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 26, 2013 1:20 PM P 7v To: 'Ted Kramer'; Bettis, Patricia K(DOA) Subject: RE: Monopod Well -A-16RD, Sundry#313-435 I ( P r 0'7 C) _�- J b Ted, The perfs in the W. Foreland are covered by CO 93B. No problem with comingling. The changes to sundry#313-435 as proposed are approved. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Ted Kramer [rnailtotkramerohilcorp.com] Sent:Tuesday, November 26, 2013 11:41 AM To: Bettis, Patricia K(DOA); Ferguson, Victoria L(DOA) Cc: Schwartz, Guy L(DOA) Subject: Monopod Well -A-16RD, Sundry # 313-435 Patricia and Victoria, *V1 We are currently on the above well with a workover rig. • Our reservoir engineer/geologist has added an additional set of perforations to this well. The set of added perfs is located within the West Foreland bench and is called out depth wise below. • Add perforation interval 6,650'—6,675' (25') There is no spacing exception needed for this zone per Conservation Order 93B dated September 24,2013. Hilcorp respectfully requests the commission grant approval to continue with the above noted changes under the existing sundry. Please let me know if these changes are acceptable to AOGCC. I have included a schematic with the added perfs highlighted so you can see how they lay in with the existing perforations. As always,please feel free to contact me if you have additional questions. Respectfully, Ted Kramer Sr.Operations Engineer 1 • w �\ I%%i s� THE STATE Alaska Oil Gas w ALAS KA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF mr-"' p, Anchorage, Alaska 99501-3572 ALASY' Main: 907.279.1433 SC Fax: Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer 1 g g 0 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C & D & Hemlock Oil Pools, Trading Bay ST A-16RD Sundry Number: 313-435 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. This approval is subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. Please note other conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /9..):7?„ 41-- Cathy '. Foerster Chair DATED this 5 day of September, 2013. Encl. <. III c?Ak.5 '�'� AUG 0 2W3 STATE OF ALASKA q ALASKA OIL AND GAS CONSERVATION COMMISSION Val APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 to New Pod [ ' Repair WeN❑ Change Approved Program❑ 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate ❑ � 9e MP �9 Suspend❑ Plug Perforations.❑ Perforate El . Pull Tubing El • Time Extension ❑ Operations Shutdown!❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. InstaN ESP t.'& O• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development El • 188-038 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 . 50-733-20111-01 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes El No❑ Trading Bay ST A-16RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay/Middle Kenai D Oil,Hemlock Oil,Middle Kenai C Oil Pools " I 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): , Total Depth ND(ft): • Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 6,844 6,439 6,730 6,331 5,745(fill) Casing Length Size MD ND Burst Collapse Structural Conductor Surface 10,059' 13-3/8" 10,059' 1,042' 3,090 psi 1,540 psi Intermediate 6,814' 9-5/8" 6,814' 6,411' 6,870 psi 4,760 psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5,460'-6,503' 5,134'-6,116' LS 2-7/8"&SS 2-7/8" LS 6.4#N-80&SS 6.4#N-80 LS 6,229'&SS 5,405' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Model A-5,Baker Dual Twin,Baker Model D Pkr&Otis SSSV 5,385'(MD)5,064'(TVD);5,385'(MD)5,064'(ND);6,230'(MD)5,858'(TVD)&269'(MD)269'(TVD);298'(MD)298'(ND) 12.Attachments: Description Summary of Proposal in 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch GI Exploratory ❑ Stratigraphic❑ Development:0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/15/2013 Commencing Operations: Oil 0 Gas El WDSPL El Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramerahilcorp.com Printed Name/ ��Teed Krraraammerr Title Sr.Operations Engineer Signature x`1/6 -7i _ Phone (907)777-8420 Date 8/9/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 —q35 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ f✓1 Other: - Z SDD 5 /50 ic j ,x- Ni p ,eon rte, (4.)eit raze a.ptroue c U 5 .c.;, ,kx...»-p 044\c,Spacing Exception Required? Yes II No ❑ Subsequent Form Required: /Q—Y OL1 RBDMS OCT 1 0 2 A. / APPROVED BY Approved by: / / p COMMISSIONER THE COMMISSION Date: y'"J J/ 3 OR GINAL 2,z O ' , 0.1 Submit Form and CAI Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate `YYY • • Well Prognosis Well: A-16RD Hilcorp Alaska,LL Date:08/8/2013 Well Name: Monopod A-16RD API Number: 507332011101 ' Current Status: Dual String Oil producer Leg: N/A (Gas Lifted) Estimated Start Date: September 15, 2013 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 188-038 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Trudi Hallett (907)777-8323 (0) AFE Number: Current Bottom Hole Pressure: 1,393 psi @ 5,982' (5,623' ND) From 2009 Redoubt Volcano SI. Maximum Expected BHP: 2,190 psi @ 5,380' (5,058' ND) Max.Anticipated Surface Pressure: 319 psi. (Using all oil in tubing from 5,058' to surface and a .37 psi/ft. oil 7 gradient. Assuming the C Zone is fully recharged.) Brief Well Summary The A-16RD well is currently is currently completed as a dual string gas lifted oil well. The short string is shut in but the most recent well test on the long string shows the well makes 49 bopd, 305 bwpd and 763 Mcfd. The re-completion plan involves pulling the existing dual completion, clean out well to PBTD @ 6,730'. The / well will then per re-perforated plus the C Zonewill be added. A new completion string will then be ran which will consist of an SSSV,GLMs,and a small ESP above a permanent packer. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU Slickline and shift the sliding sleeves at 5,359'(SS)and 5,365'(LS). RD slickline. 3. Circulate Hydrocarbon off of well with 3%KCL. 4. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. RU E-line. RIH and cut short tubing string at 5,380'(+/-).Cut the long tubing string at 5,370'(+/-). RD E-line. 6. POOH with 2-7/8"X 2-7/8"dual tubing string and lay down the same.(Note:strings may be,"/ pulled one at a time). 7. PU Packer milling assembly. RIH W/washpipe and mill. Burn over dual packer at,385'. POOH with mill. 8. PU and RIH with Overshot and latch onto Long String. Work long string to pull tubing out of seals of lower Packer at 6,230'. If successful,go to step 11. Otherwise go to step 9. 9. RU E-line. RIH with Tubing Cutter to 6,225'. Pull tension on tubing string,cut tubing. POOH with cutter. RD E-line. 10. POOH with 2-7/8"tubing string,lay down same. 11. PU RIH with washpipe and milling shoe to packer at 6,230'. Burn over packer. POOH with washpipe. 12. PU RIH with packer retrieving tool. Latch onto packer and POOH with same. • • Well Prognosis Well: A-16RD Hilcorp Alaska,LL, Date:08/8/2013 13. PU RIH with bit and scraper,clean out to PBTD. Circulate hole clean. POOH with same. 14. PU RTTS test packer. RIH to 4690'and set. Pressure test casing to 1,500 psi.for 30 minutes. Chart same. POOH with RTTS test Packer. 15. RU E-line. PU RIH with GR/CCL logging tool to 6,720'+/-. POH logging well up to 1,059'. RD E- line. 16. PU RIH with TCP perforating guns spacing out as per Final approved Perforation Request Form. RU E-line. Run tie in log. Place guns on depth . Fire guns. 17. PU on guns and circulate out perf gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 18. Once well is stable,POOH with TCP guns. 19. PU Permanent packer and RI well on work string to 4,704'+/-. Set packer. - 20. PU completion string consisting of SSSV,2 GLMs,Y tool, ESP,sliding sleeve on 2-7/8"8rd EUE L- 80 X 3-1/2" RTS-8 L-80 production tubing. Space out and set seals into packer. Hang off tubing. 21. ND BOPs, NU Wellhead and test. 22. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. •Iti .Trading Bay Unit Well#A-16RD Completed 11/88 CASING AND TUBING DETAIL RKB to TBG Hngr=40.80' SIZE WT GRADE CONN ID TOP BTM. Tree connection: Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 Surf. 1059' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 Surf 6814' Tubing: A -13-.- o - 1 LS 2-7/8" 6.4 N-80 Butt SPL CLR 2.441 Surf 6229' SS 2-7/8" 6.4 N-80 Butt seL CLR 2.441 Surf 5,405' B _ Ine 2 JEWELRY DETAIL C on NO. Deeth ID Item _ 3 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, D WO SHORT STRING M 4 E A 269' 1.50 2-7/8"Otis Ball Valve,SSSV,2.313 _ 5 B 2217' GLV#1 Flo-Petrol GLV STIM-lA 2100'TVD F C 3185' GLV#2 Flo-Petrol GLV STIM-IA 3050'TVD 1=1 6 D 3758' GLV#3 Flo-Petrol GLV STIM-1A 3551'TVD G E 4320' GLV#4 Flo-Petrol GLV STIM-IA 4120'TVD _ 7 F 4791' GLV#5 Flo-Petrol GLV STIM-IA 4525'TVD /X/x / /�/1/` G 5287' GLV#6 Flo-Petrol GLV STIM-1A 4990'TVD H 1 0 "0 8 ' H 5359' 2.313 2-7/8"Otis")CH"Sliding Sleeve (Closed) 9 53g5 I 5385' Baker Pkr.Model A-5 Dual w/40,000#shear rel.w/LHS corn.J 5405' 2.205 2-7/8"Otis"XN"Profile Nipple,2.313" LONG STRING J • • 1 298 1.50 2-7/8"Otis Ball Valve,SSSV,2.313 2 2249' GLV#1 Flo-Petrol GLV STIM-1A 2100'TVD 3 3223' GLV#2 Flo-Petrol GLV STIM-1A 3053'TVD _ 4 3818' GLV#3 Flo-Petrol GLV STIM-1A 3560'TVD 5 4352' GLV#4 Flo-Petrol GLV STIM-1A 4125'TVD I 1 6 6 4860' GLV#5 Flo-Petrol GLV STIM-1A 4574'TVD 10 7 5327' GLV#6 Flo-Petrol GLV STIM-lA 4998'TVD 8 5365' 2.313 2-7//8"Otis"XA"Sliding Sleeve (Closed) = 9 5385 Baker Pkr.Dual Twin Seal,2-7/8"X 2-7/8"X 9-5/8"w/ I I - 45,000#LS shear rel.w/LHS Conn. 11 10 5466' 3 Blast Joints 5525' 11 5536' 10 Blast Joints 0 5776' 12 12 5776' 3 Blast Joint 5834' 13 5898' 12 Blast Joint 6134' 113 = 14 6153' 2 Blast Joint 6203' 15 6214' 2.313 2-7/8"Otis"XA"Sliding Sleeve (Closed) 16 6228' 2.441 Crossover,2-7/8"X 3-1/2" II = 17 6229' 2.5" Locator Seal Assy.11.56'long 14 18 6230' 4.00 Baker Model"D" Retainer Production pkr. 19 6241' 2.441 Crossover,3-1/2"X 2-7/8" 20 6273' 2.205 Otis"XN"Profile Nipple,2.313 15 21 6284' Reentry Guide 0 btm 6285' 16 FILL 17 LS Tagged w/2.00"GR on 11/13/02 @ 6003' (Reed sample sand in 5/01) 18 LS Tagged w/1.90"GR on 1/5/04 @ 5745' ■ ■ 19 20 PERFORATION DATA Date Zone Top Btm Amt. SPF Last Opr. Present Condition D 5.460' 5,495' 35.0' 12/3/1988 Open f/prod. _ D 5,530' 5,543' 13,0' 12/3/1988 Open f/prod. = D 5.556' 5,602' 46.0' 12/3/1988 Open f/prod, = Hemlock D 5,626' 5,642' 16,0' 12/3/1988 Open f/prod. D 5.654' 5,710' 56,0' 12/3/1988 Open f/prod. D 5.779' 5,817' 38.0' 12/3/1988 Open f/prod. D 5.902' 5.975' 73.0' 12/3/1988 Open f/prod. _ E(58-11 5.992' 6.010' 18.0' 12/3/1988 Open f/prod. E(58-1) 6.020' 6,030' 10.0' 12/3/1988 Open f/prod. E(58-7) 6,060' 6,120' 60,0' 12/3/1988 Open f/prod. E(60-0) 6,159' 6.190' 31.0' 12/3/1988 Open f/prod. Hemlock 6,308' 6,631' 323,0' 10/24/1988 Open f/prod. Hemlock 6,308' 6.325' 17' 1 2/4/1997 Open f/prod. KB ELEV=101' Hemlock 6.350' 6,385' 35' 1 2/4/1997 Open f/prod. Hemlock 6.440' 6.460' 20' 1 2/3/1997 Coen f/prod. PBTD=6,730' Hemlock 6.480' 6.503' 22.5' 1 2/3/1997 Open f/prod. ANGLE thru INTERVAL=21.1° A-16RD Schematic 1-5-04 REVISED: 9/27/00 DRAWN BY: SLT , ti • • Trading Bay Unit PROPOSED Monopod Platform Well #A-16RD API # 50-733-20111-01 Completed: Future RKB to TBG Hngr=40.08' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. i INIM11- 1 ' 13-3/8" 61 K-55 Butt 12.515 Surf. 1059' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 Surf 6814' Tubing: 3-1/2" 9.5 RTS-8 Surf ±4,429' 2-7/8" 6.5 L-80 8rd EUE ±4,429' ±4,736' JEWELRY DETAIL Vin.: NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 ±300' SSSV 2 ±2,108' GLV 3 ±4,367' GLV 4 ±4,429' Y Block 5 ±4,584' Bottom of ESP 11 ±4,684' Sliding Sleeve 12 ±4,694' Chemical Injection Mandrel 13 ±4,704' Packer 14 ±4,735' X Nipple 15 ±4,736' WLEG -a Perforation Detail Top Btm Top Btm Accum. Date Present Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Condition C-2 ±4,754' ±4,774' ±4,479' ±4,498' 20' Future IIMI C 48-7 ±4,957' ±4,968' ±4,667' ±4,677' 11' Future boat C 50-0 ±5,118' ±5,132' ±4,816' ±4,829' 14' Future _� �_ C 50-3 ±5,145' ±5,158' ±4,841' ±4,853' 13' Future ER C 50-6 ±5,234' ±5,241' ±4,923' ±4,930' 7' Future MN C 51-6 ±5,308' ±5,380' ±4,992' ±5,059' 72' Future Future Re-Pert Open f/prod. D 53-0 ±5,460' ±5,495' ±5,134' ±5,167' 35' 12/3/1988 Future Re-pert Open f/prod. DZN 2 ±5,530' ±5,543' ±5,199' ±5,211' 13' 12/3/1988 Future Re-pert Open f/prod. D 53-8 ±5,556' ±5,602' ±5,224' ±5,267' 46' 12/3/1988 - C Zone Future Re-pert Open f/prod. D 54-5 ±5,626' ±5,642' ±5,289' ±5,304' 16' 12/3/1988 Future Re-pert Open f/prod. D 54-9 ±5,654' ±5,710' ±5,316' ±5,368' 56' 12/3/1988 D 55-7 ±5,729' ±5,763' ±5,386' ±5,418' 34' Future Future Re-Pert Open f/prod. D 56-1 ±5,779' ±5,817' ±5,433' ±5,469' 38' 12/3/1988 IL-- Re-Pert Open f/prod. • D 57-2 ±5,902' ±5,975' ±5,549' ±5,618' 73' 12/3/1988 Future Re-Perf Open f/prod. D Zone E 58-1 ±5,992' ±6,010' ±5,634' ±5,650' 18' 12/3/1988 E 58-1 ±6,020' ±6,035' ±5,660' ±5,674' 15' Future Future Re-Pert Open f/prod. EE E 58-7 ±6,060' ±6,120' ±5,698' ±5,754' 60' 12/3/1988 E(58-1) 6,020' 6,030' 5,660' 5,669' 10' 8 12/3/1988 Open f/prod. - E 60-0 ±6,156' ±6,190' ±5,788' ±5,820' 34' Future E(60-0) 6,159' 6,190' 5,791' 5,820' 31' 8 12/3/1988 Open f/prod. _ E 61-1 ±6,284' ±6,293' ±5,909' ±5,918' 9' Future HEM ±6,308' ±6,560' ±5,932' ±6,170' 252' Future Hemlock 6,308' 6,631' 5,932' 6,238' 323' 8 10/24/1988 Open f/prod. E Zone Hemlock 6,308' 6,325' 5,932' 5,948' 17' 12 2/4/1997 Open f/prod. Hemlock 6,350' 6,385' 5,972' 6,005' 35' 12 2/4/1997 Open f/prod. Hemlock 6,440' 6,460' 6,057' 6,076' 20' 12 2/3/1997 Open f/prod. Hemlock 6,480' 6,503' 6,095' 6,116' 23' 12 2/3/1997 Open f/prod. Hemlock KB ELEV=101' PBTD=6730' TD=6,844' ANGLE thru INTERVAL=21.1° Updated by: ILL 08/08/13 • • MoP od Platform 2013 BOP Stack 03/12/2013 Ifilrnrii tIarka.I.I.(. Rig Floor Bottom of air boot flange A 5'below rig floor 16" 14.7T 9.s0' Pipe III III III III III Iii Iil,lil III -7 Iii III III III 3.74' Shaffer 13 5/8 5M III III Ill III III 26.25' Shaffer LXT ® — 2 7/8-5 Variables 2.50' 135/8 SM _ Blind fallilla r ro ,, II I /�1 1.76 pp 1 ��I �{� f• PIS ff III Mud Cross Il' ' ' '/ii� ' `404 '�'ll'135/85MFEXFE 'Aug!III 1 I MB w/31/8 5M EF0 w/2 1/16 5M Choke and Kill valves w/Unbolt end connections for lines I I III III III III iiik , sir-I11 2.83' __4I�� l Dual Cameron Flex rams II! !ill tlllil it .70' •1 1 11 1 V Drill deck uou` 1911 Riser 14.20' 135/85M FE X 135/8 SM FE II: i Il i' I 1 i I 1. Spacer spool 1.5' 135/85M FEX113M Ill II! I I i' Wellhead @ 15.00' • • • Monopod Platform A-16RD Current 08/08/2013 Ililrnrp Ala+.kn.l.l.(. Monopod Platform Tubing hanger,dual,CIW- A-16rd DCB,11 3M X 2 7/8 EUE 8rd 133/8X95/8X27/8X lift X 2 7/8 EUE bottom, 2 7/8 w/2 1/2"type H BPV profile, 1/8 non cont control line ports in hangers Tree assy,dual block,CIW-F, 113MX29/165MX 2 1/16 5M,prepped on 4 1/2 center,3"CIW seal pockets,''npt control line exits 0..-i- i-0 1 II # •Iiir. s —_ Valve,Safety,Willis C-20, Valve,Safety,Willis C-20, r://0143111111111111 • 2 1/16 5M FE 2 1/16 5M FE rl >! _. r 4 .l � • 0.04, lin ! ter..1;:; _. A Iii 1i1 1111.71111111._ Tubing head,CIW-DCB, _. 001 g =_ 13 5/8 3M X 113M, 1 1 1 I I I w/2-2 1/16 5M SSO, Valve,CIW-F,2 1/16 SM FE, X-bottom prep - ' 107, ^ HWO'AA II II .a(l( ' . JI►1111 -I-..- 111 - E Casing head, — I Shaffer KD, 135/83MX 111 111 13 3/8 SOW,w/2-2" - LPO, ! w, 2"LP CIW ball valve S )= uulll t i I w._1. Iii- • • Monopod Platform A-16RD Proposed 08/08/2013 Hilrnrp %tnwkn.1.11, Monopod Platform Tubing hanger,Seaboard- A-16rd ESP-EN,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 3 1/2 and Susp w/3"Type H BPV profile,2-M CCL,Prepped for BIW penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 11 I., All M Valve,Swab,WKM-M, ,, 3 1/8 5M FE,HWO,DD trim f 4 Valve,Wing,WKM-M,3 1/8 Valve,Wing,WKM-M,2 1/16 5M FE,w/15"OMNI 5M FE,HWO,DD trim — operator,DD trim 11 0,)1 imir Valve,Master,WKM-M, ' 1 •;1.4 3 1/8 5M FE,HWO,DD trim NS 11 a Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ 1s1 NI 411/16 pocket,w/2-%CCL, o�_�-i ii ported for BIW penetrator Tubing head,S-8,13 5/8 3M � ■emu• W 4 • x 11 5M,w/2-2 1/16 5M 1 i t SSO,w/BG bottom U RI w/1-2 1/16 5M WKM-M valves II I 4 j_ 1ii a gall`i „ l� 1 Imo-i. iii _ lil , . Casing head, II Shaffer KD, _ 135/83MX Ill 111 13 3/8 SOW,w/2-2" ' 2"LP CIW ball valve•„=_. .,_-. at ___ , _._ • • E [11 [F [LAsA _, SEAN PARNELL, GOVERNOR ALASKA OIL AND xS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 April 6, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 RE: No -Flow Verification Trading Bay State A-16RD 1880380 Dear Mr. Myers: On March 28, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay State A -16RD located on the Monopod Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that Hilcorp verified no obstruction exists in the wellbore, the well was shut in, and calibrated flow measurement equipment with suitable range and accuracy was installed. The Trading Bay State A -16RD no flow test consisted of 3 separate 1 -hour flow monitoring periods separated by 30- minute shut ins with flow monitoring through calibrated flow measurement equipment. During the flow monitoring periods, the maximum flow rate was 500 standard cubic feet per hour was measured. There was no measurable liquid production to surface. The subsurface safety valve must be returned to service if Trading Bay State A -16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Monopod Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg {. - DATE: 3/28/12 P. I. Supervisor FROM: Bob Noble SUBJECT: No -Flow Test Petroleum Inspector Hilcorp Alaska LLC Trading Bay State A -16RD - PTD 1880380 - Monopod Platform 3/28/2012 I flew out to the Hilcorp's Monopod platform to witness a No -Flow test on Trading Bay State A -16RD (PTD 1880380). On arrival I met with Hilcorp lead operator Greg Gellar. He told me that the gas lift for the well had been shut in 36 hours before and they had — been bleeding the well off into the flare line for 24 hours. I witnessed the following: Time TIO Pressures Flow Rate Remarks (psi) (scf /hr) 0900 0/0/110 0 Tubing shut in; bleeding to flare line 0930 0/0/110 0 Opened well; no sign of flow; well shut in Hose removed from flare line and placed in 1000 0/0/110 500 - bucket of water; flow meter went to zero within a few seconds; water was bubbling like a slow boil 1100 0/0/110 0 Water bubbling slowly; well shut in Opened well; flow meter went to zero in a 1200 0/0/110 400 few seconds; slow boil in water; left well open Well had been open for 1 hour; barely 1330 0/0/110 0 bubbling in bucket; if push the hose to 4 or more inches deep in water the flow would stop TIO is tubing, inner annulus, and outer annulus I feel the flare line had a very small amount of back pressure (not enough to show on the pressure gauge) on it and that was the reason I did not see any flow on the meter the first time I opened it up. After hose was disconnected from the flare line we would get a quick spike of flow and within 5 seconds the flow rate was at zero scf /hour. - Summary: I witnessed a successful no flow test of Trading Bay State A -16RD. - Attachments: none - StAilitliED APR 2 4 ZU1 No Flow Test Monopod A -16RD 3 -28 -12 noble RE: Monopod well status e e Sub.iect: RE: Monopod well status From: "ßraul1, Eric D" <brauncd(éi)unocal.conr> Datl': Fri, 10 .lun 2005 09:32:23 -0800 To: Thomas Maunder <tom maundcr(ii)ldmin.statc.ak.us> -. The well has been down a couple of years due to gas lift restraints, we are doing well tests to see if it is worth producing now that we have a little more gas. Thanks for forwarding the info. l<6f5-0<;~ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, June 10, 2005 7:00 AM To: Braun, Eric D Subject: Re: Monopod well status Thanks Eric, Has the well been down for some time?? Testing the safety valve and sending in the report is appropriate. Please be sure that you send these reports to Jim Regg at iim regg(â?admin.state.ak.us and Bob Fleckenstein at bob fleckenstein(â?admin.state.ak.us. Jim is the Inspections Supervisor and Bob takes care of getting the inspection information into our database. I have forwarded your report to them. Tom Maunder, PE AOGCC Braun, Eric D wrote: / r>.. -\\0 Q\) Tom we brought well Ä-16short on, 6-8-05. «Ä-16s 6-9-05.xls» Thanks Eric Braun " 1 of 1 1/26/20067:29 AM AI!a Oil and Gas Conservation cornman Safety Valve System Test Report Operator: Unocal Operator Rep: . AOGCC Rep: . Submitted By: Eric Braun FieldlUnitlPad: Monopod Separator psi: LPS Date: 6/9/2005 HPS ;{> . fJa !' ~o"Wo·.'" :>i,~' .. ,', .. (,..'..... ',' > ,., '. :.,; ·.~"C'· .'. ~'" " Well Permit Separ Set LIP Test Test Test Date Passed Retest Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, SI A-OIRD 1901470 A-02 1660490 A-03RD3 1971300 A-04 1670020 A -05RD2 1760250 A-06 1670250 A-07 1670460 A-09RD 1810360 A-I0 1670760 A-ll 1700240 A-13 1680020 A-14 1680270 A-15RD2 2020190 A-16RD S 1880380 60 44 P P P 6/9/2005 OIL A-16RD L 1880380 A -17RD 1810670 A-18 1680760 A-21 1700470 A-22 1700310 A-23DPN 1720200 A-24RD 1810400 A-27RDl 1970630 A-28RD 1890920 A-30 1730140 A-32 1770180 o Components: 3 Failures: o Failure Rate: 0.00% 090 Day Wells: Remarks: RJF 12/21/04 Page 1 of 1 A-16s 6-9-05-1.xls MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder,/3'~ P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thumdav, ADri! 5, 200!: I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates I witnessed the testing of 18 wells and 53 components, with four failures:The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. I indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location I inspected the platform and found it very clean and it appeared to be in excellent cOndition. Summar!/: I witneSsed the semi annual Safety Valve System testing at Unocal's - Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted' A,.ttachm..ent: svs TBF Monopod Platform 4/5/01 JJ NON-CONFIDENTIAL SVS TBF Monopod Platform 4-5-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Submitted By: Jeff Jones Date: 4/5/01 Operator Rep: Gary Smith Field/Unit/Pad: Trading Bay Field Monopod AOGCC Rep: Jeff Jones Separator psi: LPS 65 HPS : ::~:: i,~ :i ;::: :~ !,.i !i .:¢::!),:i.::~i!i:i.::i'~:~O :i?.:~i~:~!i~?~i' ::ili?!~:i:~!?~:;: ,,, ,,, ~ :~ , ' ' ' ' i~ ' .... i"i :: :," i '::'"' :,:':';; 'i f' ",':: i ~- :~''' ~': .... ~ !~:~--::!~:~ ~.~:~-~i:~;;:~ ~:~'~'~:i '~'~:~:i!~: ~:'~::: :':' ': : '~ ?:~i :: Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE A-01RD 19014~0 '65 45 42 P' 'P ' ''P ....... OIL A-~2 ..... 1660490 "65 45 ' 26 3' P '43 .... 4/5/01 OIL A-03RD3 1971300 65 45 42 P P P OIL A-04 1670020 A-06 1670250 65 45 45 P P --'43 OIL A-07 1670460 65 45 42 P P P '0IL A-09RD 1810360 A-10 1670760 " , , , ,I ,, A-11 1700240 65 45 43 P P ~3 0IL A-13 1680020 ' 65 "45 41 P P OIL A-14 1680270 A-15 1680330 65 45 45 P ' ' P P OiL A-16RD 18'~0380 ..... 65. 45 4i/42 e P P '" OIL ~-17RD 1810670 65' 45 43 P' P P .... OIL A-18 1680760 65 ~5 47 P P 'P .... OIL A'21 1700470 65 4~' 46 P P ' OiL ~_2~ 1700310 65 45 44 P P P .... OIL ., A-23 17O0590 A-23DPN' 1720200 .... X-2~RD ' 1810400 65 45 4'1 P P P OIL ..... , . . A-27RD1 1970630 65! 45 43 P P P OIL , A-28RD 1890920 65! 45 45 P P P OIL ~-30 1730140 " A-32 1770180 65 451 44 P P P OIL , .. Wells: 18 Components: 53 Failures: '4 Failure Rate: 7.5% ['-]90Da¥ Remarks: A- 13 & A-21 reported as No-Flow wells. SSSV's removed for re]pair: A-02 out since 2/24/00, A-11 out since 11/7/99. A.-0.2 p~ot .rep,aired and r. etested "OK". A-06 SSSV failed to close. A~ 16 RD is a dual complet!on.. , 4/9/01 Page t of 1 SVS TBF Monopod Platform 4-5-01 JJ Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: MONOPOD PLATFORM WELL A-16RD APl NUMBER 50-733-20111-01 This is to inform you that the coil tubing cleanout, approval No. 94-291 was completed on 11/26/94. See accompanying history for specifics. Sincerely,,, ,, _. G. Russell Schmidt Drilling Manager Attachment GRS/leg R£CEIV£D APR 0 5 1996 Alaska 011 & ~.s Cons, Oon~mission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operatiOn shutdown: Stimulate: Plugging: Perforate: , , Pull tubing: Alter casing: Repair well: Other: X Coiled Tbg Clean Out 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal), Development: x 37' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196246 Anchorage, AK 99519 Service: Trading Bay State 4. Location of well at surface 8. Well number 1610 N & 566' w/f SE Corner Sec. 4, T9N, R13W, SM TBS A-16RD ,,,, At top of productive interval 9. Permit nUmber/approval number 662.61' N & 1573.72' W f/SE Corner Sec. 4, T9N, R13W, SM0R]GINAL 88-38/94-291 At effective depth 10. APl number 843.36' N & 1975.48" W f/SE Corner Sec. 4, T9N, R13W, SM 50- 7'33-20111-01 At total depth 11. Field/Pool 866.89' N & 1992.26' W f/SE Corner Sec. 4, T9N, R13W, SM Tyonek & Hemlock -i 2."Present well condition summary Total depth: measured 6844' feet Plugs (measured) true vertical 6439' feet Effective depth: measured 6730' feet Junk (measured) true vertical 6334' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1095' 13-3/8" 1000 sx & 200 sx 1059' MD 1135' TVD Intermediate w/3% CACI2 Production 6814' 9-5/8" 1400 sx & Spherelite 6844 MD 6411' TVD Liner & 475 sx Class 6 Perforation depth: measured See attachment true vertical Tubing (size, grade, and measured depth) Long string: 2-7/8", 6.4//, N-80 Butt; 6285' MD Short string: 2-7/8", 6.4~, N-80 Butt; 5406' MD Packers and SSSV (type and measured depth) Otis BXE SSSV @ 298' MD, Baker Dual Twin 2-7/8" x 2-7/8" x 9-5/8" @ 5385' Baker FB pkr @ 6230' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injectio~ Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 91 7'33 711 1135 90 Subsequent to operation 109 358 709 1115 110 1 ~;. Attachments: 16. Status of well classification aS: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: x Gas: Suspended: Servi!~: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: ~, C ~, C J V' ~ L~ APR 0 5 1996 Alaska 011 & (3as Cons. Commisaion Anchorage Signed: G. Russell Schmidt ~~./~ ~L~,~'/~'itle: Drilling Manager Date: 3/26/96 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MONOPOD PLATFORM A-16 673O' PBTD DAY 1 U.O. 50% CLEANOUT FILL MI EQPT. TO PLATFORM. RU GAS BUSTER & ASSOCIATE EQPT. RU CTU & HELD PRE-JOB SAFETY MEETING. RIH TO 5000' & UNLOADED WELL. MIX & PUMPED FOAM & MONITORED RETURNS. NO FOAM IN RETURNS & PRESSURE EQUALIZED TO ANNULUS. DETERMINED POOR FOAM QUALITY DUE TO CONFIGURATION OF SURFACE EQPT & ANNULUS PRESSURE DUE TO LEAKING GLV. SHUT DOWN TO DUMMY GLM'S & OBTAIN PROPER SURFACE EQPT. A-16 6730' PBTD DAY 2 CLEANOUT FILL PULL 6 GLV'S & REPLACE W/DUMMYS. MODIFY SURFACE EQPT 673O' PBTD DAY 3 RIH W/COILED TUBING TO 2000'. FOAM UP, GENERATING FAIR FOAM QUALITY. RIH & TAGGED FILL AT 6635'. CLEAN OUT F/6635'- 6732', FILL APPEARS TO BE FORMATION SAND. CIRC. CLEAN & POH W/COILED TUBING. RIH W/2-3/8" SCRATCHER TO 6510' ON WIRELINE, COULD NOT WORK DEEPER. 6730' PBTD DAY 4 RIH W/1-3/4" SCRATCHER TO 6517', COULD NOT WORK DEEPER. RIH W/COILED TUBING TO 6450' & FOAM UP. CLEAN OUT F/6450'- 6719' (COUNTER OFF DUE TO SNOW AND ICE). CIRCULATE 3-1/2 HOLE VOLUMES. RECOVERED FINE FORMATION SAND THEN HOLE CLEANED UP. DEVELOPED HOLE IN COILED TUBING AT 6528'. CUT COIL & STRIP 700' OFF REEL. RECONNECT COIL @ REPORT TIME. RECEIVED APR 0 5 '/99; Anchorage 6730' PBTD DAY 5 RECONNECT COIL & POOH. RIH WI1-3/4" SCRATCHER ON SLICKLINE AND TAG @ 6530'. POOH. RIH & REPLACE DUMMYS W/GLV'S. INSTALL SSSV. TOTAL RECOVERY F/WELL 9-13 BBLS FINE FORMATION SAND. PREPARE COILED TUBING F/MOVE TO A- 13. RI CEIVED APR 0 5 199; Alaekl Oil & gae C~ont, Commiaiion Anohorage Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Monopod Platform, Well A-16RD ~"-~ ~ APl Number 50-733-20111-01 This is to inform you that Unocal withdraws the Sundry Request to pull tubing, with Approval No. 91e.139. It is no longer a viable proposal, please cancel the Request for Sundry Approval. ,R' Very truly yours, Attachment Candace Williams ~-- STATE OF ALASKA ...-~ ~ / .~KA OIL AND GAS CONSERVATION CO. ~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing __ Alter (~asing__ Repair well _ _ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 Perforate Pull tubing __ Other X 5. Type of Well: Development X Exploratory __ Stratigraphic_ _ Service _ _ 4. Location of well at surface Monopod Platform Conductor #29 1610' NSL, 566' WEL, Sec. 4, T9N, R13W, SM At top of productive interval 5460' MD, 5134' TVD, 2312' NSL & 2138' WEL, Sec. 4, T9N, R13W, SM At effective depth 6730' MD, 6331' TVD, 2500' NSL & 2517' WEL, Sec. 4, T9N, R13W, SM At total depth 6844' MD, 6439' TVD, 2518' NSL & 2549' WEL None 6. Datum elevation (DF or KB) RT 101' MSL 7. Unit or Property name Trading Bay State 8. Well number A-16RD feet 9j~,r~l't~umber/approval_~/91 - 139 numb~ ,~ 10. APl number 50-733-2011-01 11. Field/Pool Tyonek & Hemlock 12. Present well condition summary Total depth: measured 6844' feet true vertical 6439' feet Plugs (measured) Effective depth: measured 6730' feet Junk (measured) true vertical 6331' feet Casing Length Size Cemented Measured depth Structural Conductor Surface 1059' 13-3/8" 1200 sx 1059' Intermediate Production 6814' 9-5/8" 1875 sx 6814' Liner Perforation depth: measured Same true vertical Same True vertical depth 1 O35' 6411' REC£1V£D Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80 dual at 5406' SS & 6285' LS Packers and SSSV (type and measured depth) Baker "FB" pkr at 6230' & Baker Dual pkr at 5385' SSSV at 269' & 298' OCT 3 1 1994 Ataska 0il & Gas Cons. Corem Anchor~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Change in plan~tions pe'rformed~ Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Change in plans; no operations performed Tubing Pressure 15, Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations _ _ 16. Status of well classification as: Oil x_ Gas __ Suspended _ _ Service 17. I hereby certify that the forego_ing is true.and cor.r~ct to the best of my knowledge. Signed G. Russell Schmidt~[.~~e Drilling Manager Form 10-404 Rev 06/15/88 Date 10/26/94 SUBMIT IN DUPLICATE ~s%0n STATE OF ALASKA ....... ALA; . OIL AND GAS CONSERVATION COMM .ON APPLICAi'ION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Alter casing__ Repair well Change approved program __ 2. Name of Operator 15. I UNION OIL COMPANY OF.CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension Stimulate Pull tubing _ _ Varianoe __ Perforate__ Other X Type of Well: 6. Datum elevation (DF or KB) Location of well at surface 1610' N & 566' Wf/SE Corner Sec. 4, T9N, R13W, S.M. At top of productive interval 662.61' N & 1573.72' W f/SE Corner Sec. 4, TgN, R13W, S.M. At effective depth 843.36' N & 1975.48' Wf/SE Corner Sec. 4, TgN, R13W, S.M. At total depth 866.89' N & 1992.26' W f/SE Corner Sec. 4, TgN, R13W, S.M. Development Exploratonj Strafigraphio 37' 7. Unit or Property name Trading Bay State 8. Well number TBS A-16RD 9. Permit number 10. APl number 50-733-20111-01 11. Field/Pool Tyonek & Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6,844' feet 6,439' feet 6,730' feet 6.334' feet Plugs (measured) Junk (measured) Casing Structural Conductor Length Size Cemented Measured depth True vertical depth Surface 1095' 13-3/8" Intermediate Production 6814' 9-5/8" Liner Perforation depth: measured See attachment true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments 1000 sx & 200 sx 1059' MD 1135' TVD w/3% CACI2 1400 sx & Spherelite 6844' MD 6411'TVD & 475 sx Class 6 RECEIVED OCT 1 4 1994 Alaska Oil & Gas Cons. Commission Long stdng: 2-7/8", 6.4#, N-80 Butt; 6285' MD Anchorage Short string: 2-7/8", 6.4#, N-80 Butt; 5406' MD Otis BXE SSSV @ 298' MD, Baker Dual Twin 2-7/8" x 2-7/8" x 9-5/8" @ 5385' Baker FB pkr @ 6230' MD Description summary of proposal X_ Detailed operations program,_ BOP sketch X 14. Estimated date for commencing operation October 21,1994 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the fo~/g~ng.~//i~Je~a/~::~_~to{l/V~ the best of my knowledge. Signed G. Russell Schmidt/~..~~itle Drilling Manager FOR COMMISSION USE ONLY Date October 13, 1994 Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by the order of the Commission Original Signed By David W. Johnston Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) Trading Bay Field Monopod A-16 (Long String ) Coiled Tubing Clean -Out Procedure Verify tree/C.T. BOP connections before moving C.T.U. to the Monopod Platform. Hold safety meeting and discuss procedure w/coiled tubing personnel and production personell before starting job. Fill out C.T. pre-job checklist. MIRU C.T.U, Nitrogen Unit, choke line, double choke manifold, kill line, flow tank, and return tank. (Allow 2 days for rig up time.) NU BOP on A-16's long string (located in slot #29). Perfrom shear test w/shear rams. Mix up BBLS of 3% KCI water. Two tanks of Nitrogen should be more than enough for A-16. Only two Nitrogen tanks are available. Pressure test BOP, 1-1/4" C.T., and all surface lines to 3~000 psi for 10 minutes. Complete BOP Inspection MU C.T. BI-IA #1 as follows: 1) 1.75" wash nozzle 2) 1.75" check valve RIIt w/BHA #1 following the attached pump schedule. Begin Pumping Foam before exiting tubing. Extreme care must be taken when the top of the fill is being encountered. Wash fill from 6~490'-6~640'. If possible, wash to 6~730'. Discuss alternative plans w/office if foam clean-out is ineffective. Note: Gas lift is available to lift solids if needed. A) If there are no fill returns, POOH w/wash tool and RIH w/motor and 1.75" mill. POOH w/BI-IA #1 and 1-1/4" CT. RD C.T. Unit. ND BOP. RU slickline and install Otis Ball Valve (See slickline procedure) Turn well over to production. RECEIVED OCT 1 4 1994 Alaska 011 & Gas Cons. Commission Anchora~o MWD A16CTPRO.DOC 10/13/94 TEXAS TQOLS: TUBING STRIPPER/PA K~R' S,000 psi Working Pre~,'re ~:]~:'..' H,S service ~ i.O0'$erfes DS32~ ;~ohora~ ,~. P:' ~ ' P.O. Box TgT2T'Houston, Texas Telex: 790906 TX TOoL~Hou · RECEIVED' ~ OCT '~ ~-~4 .~..JJ"wm- 'r~ ['' ~il.& Gas Cons. Commission . .. ~ phoner (7'~) 4ZOS API'50.-lb3-20111-O1 Monopod'Pbtform ' Conductor 29 TBS A- I ~RD Trading B_ay State Trading Hay Field ~'~ Lqev. 101 irt. ~SL flXl h,,,,,~ FIq Dep(h 40.80 Ft. I~id--Peff De~a[ion 21.1 Degs. PERFORAtiONS ~ - ,5,394' RE1RV. PACKER Baker Dual Twin ,Seol Pkr 54~- 5~95' P~ D, ~', 12/,]/88 55~0- 5543' Pm D, 13', 12/3/88 ~- ~o~' Pm D, ~', ~/~/~ 5~- 5710' Pm ~, ~', 12/~J88 5992- roOlO' Pm D, 18, 12/,~/88 6020- 6035' Pm D, 15', 12/3/88 ~- 6120' PI~ D, ~, 12/3/88 lsg- o go' Pm 62~ - 62,:]4' PgI([R I~k~r B PI~ W/ 61~ - ~' CB, tI~ PLUG ' 0~1 ~ell ~ ~: lor Redrilled & Completed 12/8/88 PBTD: 6308- 66.31' Pm H~ 32.3', 11]/24/88 RECEIVED OCT 1 4 1994 Alaska Oil & Gas Cons. Commission AnchoraL~ '~i JU.-IJJ-/:U I I I-UI MonoOod Plo[form Cohd~:lor 2§ Il:lb A- 1 bKl) Trodinc ~oy State Tredini ~o7 [~eld I 10,59 - 105§' SHOE 22? 20" OD CSC ~ - 1059' 13.575" O0 61.00//ft J-55 SURF' CS(; 42- 4.5~' 9.~5" O0 47.~/ft N-80 P~D CS(; 45JJ - 681,I' 9.625" O0 47.O0t/ft S-95 PI~O[I ~ 6292 - 6461' F1LL 1¥13~90 Togged Bottom W~2.,5" ~r 6~- §7~ Fill 2/92 Togged F'iff W/ 6730 - 684.4' CEMI~ PLUC 6812 - 6814' FL(~HO[ Oil Well Redrilled & Completed 12/8/88 K8 ~: 101' PBTD: 67~' .~KB Elev. 101 Fl. ~$L ]"DB, .J Fig. Dep[h 40.80 Bi(l-Perf' De¥1ation 21.1 Begs. 3~ - ~229' 2.S75" OD ~.~/ft N-~ ~ t~ S~IN(; L ~22g ~2~' z875" o~ ~.40//ft ~i-80 ~c LO~ ST~NC 41- 42' ~C[R 298 - $0' ~SY 2249 - 7256' ~UFT VAL~ 3223 - 3250' C, ASUFT YN_~ t2, f'lo-Petrol CLM $~-1A ~818- ,~25' 4~2- 4860- ~1' 5327- 5,Lq' C-~SUFT YALVE/~, Fio-Petroi C~ ~UFT YA~ t4, flo-Peb'ol CLM S~-IA ~UFT YAL~ t5, rio-Petrol C~ S~-IA ~UFT V~V~ j~, ~-Pe~l CL~ ~-~ RECEIVED OCT 1 4 1994 Alaska Oil & Gas Cons. commi~ion ~chora~o 5~69' ~J~ 0tis Xk Closed 5525' BL~ JOINT 51J2' DAS'T JOINT ~4'~ JOl~ 6217' ~ ~s ~ 6229' CEO~R 3 1/2" x 2 7/~" 6230' L~TOR JOl~ 6241' 4.7? OD 3.~'D ~ 62~4' P~ER ~ker ~ ~ W/~1 ~ 627~' ~DI~ NIPPE ~ X 6285' RE~ JOl~ APl bU-/,~3:-2D111-01 M,onoPod Platform Conductor 29 1059 - 1059' SHO[ lEIS A-16RD Trading ~_ay $[a[e Trading Bay field SHORT S~NG .~RKB Elev. 101 FL ~SL ]'hq ,.~,~d flq Depth 40,80 Fl, ~id'-Perf De~alion 21.1 Degs. L 41 - 5'I05' 2.815"00 6.~/ft N-80 TBG Sl-iORT STRING 4.1 - 42' HANGB Camco I~ol l'l)g Hanger 269 - 271' SSSV Otis Ball Yal~re 2217 - 2224' C~UFT ¥~ tl, rio-Petrol CL¥ STI/-I^ 3185 - 3192' C~ YAL~ t2, rio-Petrol ~ S~-I^ 37~ - 316b' C/~LIFT ¥~ t~, Flo-Peb'ol C~ $~-lA 4,~20 - 4321' G/LSlJfl Y~ 14, flo-Pe~ol G~ S~-IA 4791 - 4798' ~fl ~ t5, ~o-Pebol C~ S~-IA 5281 - 5~'~ Y~l ~6, flo-Pdr~ C~ S~-IA mi' ,LL 2/1¢o Tagged 6488- §7~ F1LL 2/02 Togged Fill 67~ - r~14' ~ PLUG ~12- 6814' FL~ISH~ i~ B_[V: 101' PB1D: 67~0' 'iD:. 68,M' ~ - 5~62' ~ Olis XH ~ - 5~92' PACI~R Baker Du~l Twin Seal PI~ .5405 - 5~7' NO-CO NIPPIL Otis XN RECEWEg Gas Cons. Gommissio~ '~chora~a Oil We~ Re(frilled & Completed 12J8/88 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing m Repair well ~ Change approved program Pull tubing ..T,_ Variance Perforate % ,,.,,~.,, ~.--.-,~-.. l 2UNn~e°f~e~t°~ompany of California 5. Type of Well: ion Development Exploratory __ 3pA. c~r.eSSBox 190247, Anch., AK, 99519 Stratigraphic __ Service __ 4. tocation of well at surface Monopod Platform Conductor #29 Operation shutdown m Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Other 6. ~ ~.l~,~ti~n ~1~) MSL feet 7. Unit or Property name Tradinq Bay State 1610' NSL & 566' WEL of Sec. 4, T9N, R13W, SM At top of productive interval Sec. 4, T9N, Ri3W, SM 5460' MD, 5134' TVD; 2312' NSL & 2138' WEL At effective depth Sec. 4, T9N, R13W, SM 6730' MD, 6331' TVD; 2500' NSL & 2517' WEL At total depth Sec. 4, T9N, R13W, SM 6844' MD, 6439' TVD; 2518' NSL & 2549' WEL feet Plugs(measured) 6,844 feet 6,439 12. Present well condition summary Total depth: measured true vertical Effective depth: measured feet Junk (measured) true vertical 6,730 feet 6,331 Casing Length Size Cemented Structural 8. Well number A-16RD 9. Permit number 68-39 10. APl number 50-- 733-2011-01 11'Field/P°~,onek & Hem] Measured depth .... :'"~[T~ ve~ical depth Conductor Surface Intermediate 1059' 13-3/8" 1200 SX 1059 ' 1135 ' Production 6814 ' 9-5/8" 1875 sx 6814 ' 6411' Liner Perforation depth: measured See attached true vertical 2-7/8", 6.4#, N-80 dual at 5406' SS & 6285' LS Tubing (size. grade, and measured depth) Baker "FB" pkr at 6230' & Baker Dual pkr at 5385' Packersand SSSV (type and measured depth) SSSV (s) at 269' & 298 · 13. Attachmenis Description summary of proposal Detailed operations program __ BOP sketch -x-. 14. Estimated dateMayfOr commencingoperation15, 1991 J 15. Status of well classification as: 16. If proposal was verbally approved I Oil ~ Gas __ Suspended Name of approver Date approved Service 17. I here_by certify that/'h,e foregoing is tr/~eand correct to the best of my knowledge c Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ~¢,;' ~ ORIGINAL sIGNED BY LONNIE C. SMITH Commissioner Approved by order of the Commission Form 10-403 Rev 06/15/88 [Approval No. Date SUBMIT IN TRIPLICATE A-16 REDRILL Workover Procedure April '24. 1991 i . Miru · ~ ~ Kill well with 3% KCL/FIW at 64 PCF. Install bpv, remove tree, install and test BOPE. Pull existing dual completion from 6285'. Mill over and recover Baker "FB" perm. packer at 6230'. Clean out fill (240') inside 'the 9-5/8" casing to 6730' ETD. Fill has been tagged with wireiine at 6490'. Re-run the existing dual completion as before. Place well on production and RDMO. Note: Should H2S be encountered, Unocal will conform to ali. requirements as set forth in 20 ACC 25.065. Anticipated SBHP: 2100 psi. r 13-3/8"61~ J-55 O 1059' 9-5/8" 47# N-80 4533' ~ 9-5/a,, 47# s-95 t ~ 6814' / 1 2 TUBING DETAIL 2-7/8% 6.4~, N-80 TBG BT&SC. LONG STRING: 1) SSSV AT 298' 2) C,I_M'S (6): 2249'; 3222'; 3817' 4352'; 4860'; 5327' 3) XA SLEEVE AT 5365' 4) BAKER DUAL PACKER AT 5385' 5) XA SLEEVE AT 6213' 6) BAKER "FB" PACKER AT 6230' 7) X NIPPLE AT 6273' 8) WL RE-ENTRY GUIDE AT 6285' SHOI~I' S?E]~G: 1) SSSV AT 269' 2) GLbl'S (6): 2223'; 3192'; 3764'; 4327'; 4797'; 5287' 3) XA SLEEVE AT 5358' 4) XN NIPPLE AT 5406' "D" ZONE AT INTEEVALS 546O'-5495' 5530'-5543' 5556'-5602° 5626'-5642' 5654'-5710' 5779'-5817' 5902'-5975' 5992'-6010' 6020'-6035' 6060'-6120' 6159'-6190' H]~E,OCK ZONE 6308'-6631' FLOAT COLLAR AT 6730' ETD WELL TBS A-16RD PRODUCER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (db(:] UNOCAL) DRAWN: CLL SCALE: NONE DATE: 01-09-91 2" KILL LINE WITH (2) 2!' 5M VALVES I (.r; :1,, KILL LINE FROM MUD PMP &: CEMENT UNIT BELL NIPPLE 12" .3000 PS! ANNULAR I PIPE RAMS BLIND RAMS PIPE RAMS I FLOWLINE 13-5/8" 3M FLANGE ADAPTER 'SM x 5M 15-5/8" 5M FLANGE i DOUBLE GATE 5M I 15-5/8" 5M FLANGE ,, ] 4-" CHOKE LINE WITH ONE REMOTE &~ 1 MANUAL 4" 5M VALVE ([) ' ,:1) '1 CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) I j 13-5/8" 5M FLANGE I SINGLE GATE 5M I 15-5/8" 5M FLANGE RISER 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL ! 15-5/8" BOPE 5M STACK ALL DRILLING OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: GSB SCALE: NONE DATE: 10/22/90 TO 10" CROWN VENT BLOW DOWN GAS BUSTER TO CHOKE PANEL MANUAL 1 O" TO SHAKER SWACO CHOKE NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. TO BOPE SWACO CHOKE CHOKE MANIFOLD Unocal PLATFORM RIGS 4-1/1¢ & 3-1/8', 5M MSP STATE OF ALASKA ALASKA ,.,,L AND GAS CONSERVATION CC ..,MISSION /q 'WELL COMPLETION OR RECOMPLETION REPORT AND LCG~ -~ 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE Classification of Service Well 2. Name of Operator Union 0il Company of California dba Unocal 3. Address P. O. Box 190247, AnchoraRe, Alaska 99519-0247 4. Location of well at surface 1610' N, 566' 14 f/SE corn., Sec 4, T9N, R13N, S. H. At Top Producing Interval 5460' Sl), 5135' TVl), 662' N & 1574' W f/Surf. Loc. At Total Depth 6844' MD, 6442' TVD, 867' N & 1992' N f/Surf. Loc. 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 101' RT above MSL I ADL 18731 7. Permit Number 88-38 8. APl Number 50- 733-20111-01 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-I6RD 11. Field and Pool Trading Bay Field Tvonek "D" Zon~ and H~mlnt- 9/13/88 +' 'll0~,16/88 1,9. Directional Survey ! 20. Depth where SSSV set { 21. Thickness of Permafrost 17. TotalDePth(MD TVD) 118' ugSackDepth(MD+.Pv, D)j12./8/88 . J 61',feetMSk 6844'MD/6442' ~ 6730'MD/6335'lVD ] YES:~ NO [] ~H:'' ~' feet MD { NA 22. Type Electric or Other Logs Run Dual Tnd. LS Sonic; Comp. Neut.; Como. Den., GR: Diplog, Cemt. Bond Log: Velocity Survey 23. CASING, LINER AND CEMENTING RECORD CASING SIZE]WT. PER FT. t GRADE SETTING DEPTH MD [ { TOP [ BOTTOM HOLE SIZE 'CEMENTING RECORD AMOUNT PULLED 9-5/8" 47# S-95 4533 6814 12-1/4" 1400sx Spherelite & None 9-5/8" 47// N-80 6414 - 0 - 12-1/4" 475sx class" None 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number} See Attached 25. TUBING RECORD SIZE [ DEPTH SET (MD} I PACKER SET (MD) 2-7/8", 6.4//, N-80 5406' 5392' 2-7/8"~ 6.4//~ N-80 6285' 5392' & 6241' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH~.NTERVAL (MD) J AMOUNT& KIND OF MATERIAL USED 6308' - 6631' Frac. w/62500// ISP Sand @ 4500 PSI 27. Date First Production 12/20/88 Date of Test Flow Tubing Press.. 700 Hours Tested 24 Casing Pressure 1000. 28. PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR ,OIL-BBL [GAS-MCF IWATER-BBL ICHOKESIZE GAS-OILRATIO TESTPER,OD* J CALCULATED __IOIL-BBL GAS-MCF JWATER-BBL JOILGRAVITY-API(corr) }413 LS/ 112 LS/85SS 26 API 24-HOUR RATE 283 SS 800 CORE DATA Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED &laska Oil.& Gas Cons. C0m~lssl0a "~ ~nchorago ' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicateC 29. 30. ',.. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... 31. LIST OF ATTACHMENTS Perforation Detail, History, Directional Survey, _ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~).~/_ ~ ~/~" Environmental Signed .... ~¥~-~ Title Engineer Date 03/08/89, 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 v,..'ater 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 Ope[a.tion' 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". Trading Bay State TBS A-16 Redrill Perforating Record Measured Depth 5460-5495 5530-5543 5556-5602 5626-5642 5654-5Y10 5902-59Y5 5992-6010 6020-6035 6060-6120 6156-6190 6308-6631 True Vertical Depth 5135-5167 5202-5215 5226-5269 5292-5309 5316-5367 5436-5471 5552-5621 5630-5652 5664-5678 5698-5755 5791-5825 5932-6240 Interval ft. 13 46 16 54 38 73 18 15 6O 34 323 O019n UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE TRADING BAY STATE .WELL NO A-16 FIELD. TRADING BAY STATE DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1988 Feet 9/13/88 9/14/88 9/15/88 9/16/88 9/17/88 9-18-88 7434'TD 7,434'TD 7,434'TD 7,434'TD 7,434'TD 7,434'TD MIRU on A-16 RD at 0900 hours 09/13/88. RU coiled tubing unit on short string. Could not test 1-1/4" BOPE. Rigged down same. Tested new BOPE to 3000 psi - OK. RIH in short string with 2.7" flat bottom mill on 1.75" Navi-Drill. Could not work past 43'. Tripped for 2.25" flat bottom mill. Cleaned out short string to ball valve at 307'. Tripped for 2.7" flat bottom mill. Could not work past 43'. Tripped for 2.5" flat bottom mill. Could not work past obstruction at 43' in short string. Rigged down coiled tubing unit. Rigged up wireline on long string. Ran 2.8" gauge cutter to ball valve at 309'. Pulled ball valve - ok. Ran 2.3125" gauge cutter to 4600'. Pulled out of hole. Rigged down wireline. Pumped down short string with 19 barrels FIW to 2000 psi - no bleed off. Rigged up coiled tubing unit on short string. Ran in hole with 2.7" tapered mill to 43' - no progress. Pumped FiW down long string - had communication to 9-5/8" casing. Shut in well and bullheaded water down long string with 25 barrels to 2000 psi - no bleed off. Rigged up wireline on long string. Opened XA's at 4453' and 4382'. Rigged down wireline. Pumped FIW down long string - pressure stabilized at 2000 psi. Rigged up 1-1/4" coiled tubing on short string at 2400 hours. Ran in hole on short string with 1-1/4" coiled tubing and 2.7" bull nose mill on Dyna-Drill. Milled bad spot at 43' without success. Tripped for 2.5" flat bottom mill - no success. Tripped for 2.625" tapered mill on 2.375" Navi-Drill. Milled from 43'-44'. Tripped for 2.5" taper mill - no progress. Tripped for 2.375" flat bottom mill. Worked thru bad spot at 43'. Tripped for 2.5" flat bottom mill. Worked thrU tight spot and ran in hole to ball valve at 307'. Tripped for 2.7" bull nosed mill - no progress. Tripped for 2.625" flat bottom mill. Worked thru bad spot at 43' at 2400 hours. Milled bad spot from 43'-45'. Ran in hole to ball valve. Tripped for 2.7" flat bottom mill. Worked thru tight spot at 307'. Pulled out of hole. Rigged down coiled tubing. Rigged up wireline. Ran 2.85" gauge cutter in short string. Could not work past 46'. Pulled out of hole with wireline. On long string, pumped 15 barrels green dye to find hole in string. Unable to see dye in returns. On short string, rigged up coiled tubing. Milled bad spot 45'-52' with 2.875" flat bottom mill on 2-3/8" Navi-Dri!l. Worked same thru tight spot at 90'. Ran in hole to ball valve at 307'. Pulled out of hole. Ran in hole with open ended coiled tubing. Washed short string from ball valve to surface. Rigged down coiled tubing. Rigged up wireline. Ran in hole with 2.85" gauge cutter to retrieve ball valve. Could not pull ball valve. Rigged up coiled tubing on long string. Ran in hole with 2.25" flat bottomed mill on 1.75" Navi-Drill. Cleaned out fill from 4665'-5027'. Could not work deeper. Rigged down coil tubing. Spotted 20 gallons HCL around short string ball valve. Still could not recover ball valve. Rigged up coil tubing on short string. Ran in hole to 400' and circulated out HCL. Rigged down coil tubing. Rigged up wireline. No recovery of ball valve. Rigged down wireline. Circulated well over to 68 pcf mud. Ran in hole with coiled tubing to 1000' in short string. Displaced with 68 p cf mud. Rigged down coiled tubing. Rigged up wireline. Ran in hole and set "P x N" plug in long string XA sleeve at 4453'. Rigged down wireline. Set BPV's. Removed tree. Nipple up 13-5/8" 5M BOPE. Pulled BPV's. Function tested BOPE. Circulated 68 pcf mud. Slight flow. Weight up to 70 pcf. Rigged up wireline. Ran in hole in long str~ng with 2.75" jet cutter to 294' ~" ,~':~'~ ~,~ ~'!: ';"' ~' UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE TRADING BAY STATE 'A-16 TRADING BAY STATE WELL NO FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1988 9-19-88 9-20-88 9-21-88 9-22-88 9-23-88 9-24-88 9-25-88 Feet 7,434'TD 7,434'TD 7,434'TD 7,434' TD 7,434'TD 7,434 'TD 7,434'TD Pulled out of hole and laid down the long string tubing and hanger. Rigged up wireline and cut the short string at 290'. Pulled out of hole and laid down the short string tubing and hanger. Ran in hole and engaged the short string and attempted a back off below the ball valve. Recovered joint of tubing without the ball valve. Ran in hole with an overshot and engaged the long string. Attempted to run a 2-1/8" tubing cutter but stopped at the top of the fish. Rigged up coil tubing and ran a 2-1/2" tappered mill. Cleaned out through the top of the fish. Rigged up wireline and ran in hole to 4000'. Ran in hole with 2-1/4" jet cutter and cut the long string at 4325'. Pulled out of hole and laid down tubing. Picked up 3-7/8" sizing mill and milled over the short string ball valve. Made up fishing tools. Ran in hole and back off the short string at 3300'. Pulled out of hole laying down the ball valve and 2983' of tubing. Pressure testing the BOPE. Pressure tested the BOPE. Made up fishing assembly and ran in hole. Engaged the short string fish at 3295' and backed off fish. Recovered 66.59' of 3-1/2" tubing. Reran the fishing assembly and engaged the short string fish at 3362'. Backed off the fish and recovered 985.17' of 3-1/2" tubing. (TOF at 4347'). Made up fishing assembly and engaged the long string fish at 4329'. Circulated through the open "XA" sleeve at 4382'. Rigged up slick line and ran a 2-5/16" cutter. Cutter stopped at the top of the fish. Pulled out of hole with slick line. Rigged up coil tubing and ran in hole with a 2-3/8" mill to the top of fish (4326'). Milled from 4326' to 4328'. Pulled out of hole and picked up a 2-1/4" mill and ran in hole. Tagged fill at 4393' and cleaned out to 4423'. Coil tubing and drill pipe annulus packed off and returns began to come up the drill pipe and casing annulus. Coil tubing began to stick. Closed the BOP and forced returns up the drill pipe. Worked the coil tubing up the hole to 4338'. Tubing stuck at 4338'. Waiting on coil tubing chemical cutter. Ran in hole with coil tubing cutter and stopped at 2105'. Set cutter at 2100' and attempted cut. Puled out of hole with cutter and found cutter had malfunctioned. Rigged down wireline and made a blind backoff of 2-7/8" tubing. While making backoff coil tubing dropped down hole. Ran in hole down 5" drill pipe with 2-7/8" tubing and overshot and recovered the coil tubing. Coil tubing was free and pulled out of hole with coil tubing. Rigged down coil tubing unit and pulled out of hole with 5" drill pipe. Recovered 61.33' of 2-7/8" tubing fish. Top of LS @ 4386'. Picked up bit and scraper and ran in hole to 4325'. Picked up cement retainer and ran in hole to 4300'. Established break down at 1-1/2" BPM and 2300 psi. Mixed and pumped 275 sxs Class "G". Squeezed 175 sxs of cement below the retainer and balanced 75 sxs of cement on top of retainer. Final rate was 1 BPM and 2700 psi. Cement in place at 2225 hours 09/24/88. Pulled out of hole. Rigged up wireline and ran CBL-VDL-GR from 4000' to 800'. Ran gyro survey from 4000' to surface. Ran in hole and shot 5 holes from 2002' - 2004'. Rigged down wireline and ran in hole with cement retainer. Set retainer at 1982'. Mixed and pumped 65 sxs of Class "G". Pumped 45 sxs cement below the retainer and balanced 20 sxs on top of retainer. Final squeeze pressure was 1050 psi at 3 BPM. Cement in place at 1655 hours 09/25/88. Pulled out of hole and picked up cement retainer. Ran in hole and set retainer at 1250'. Nippled down BOPE and removed DCB spool. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE TRADING BAY STATE A-16 WELL NO FIELD_ TRADING BAY STATE DATE E~.D. 1988 Feet DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9-26-88 ,434'TD 9-27-88 ,434'TD 09-28-88 ,434'TD 09-29-88 434'TD 09-30-88 7,434'TD 10-01-88 1,200 'TD 10-02-88 !,709'TD 10-03-88 2,414'TD 10-04-88 3283'TD Nippled up the BOPE and made up a 9-5/8" casing cutter. Ran in hole and cut 9-5/8' casing at 1200'. Speared the casing and worked up to 350000# without movement. Rigged up and ran a free point at 380'. At 380' the pipe was 100% free. Ran a free point at 800' and pipe was 100% free. Continue to run free point to locate the deepest point of free pipe. Free point casing at 1000' and cut casing at 1027'. Attempted to pull casing without success. Made up casing cutter and ran in hole. Cut 9-5/8' casing at 775' and attempted to pull without success. Nippled down the BOPE, pulled the casing slips and nippled up the BOPE. Reran the freepoint and made a cut at 350'. Casing cutter malfunctioned. Reran casing cutter and cut at 355'. Pulled 9-5/8" casing free at 355'. Laid down 355' of 9-5/8" casing. Ran in hole with 12-1/4" bit and cleaned out to 355'. Pulled out of hole and made up spear. Ran in hole and attempted to pull casing from 775' without success. Pulled out of hole and ran in hole with casing cutter. Cut casing at 565'. Recovered casing from 565'. Reran spear and pulled casing to 775'. Ran in hole with 12-1/4' bit and cleaned out to 775'. Ran in hole with 8-1/2' bit and attempted to get into the top of the 9-5/8" casing stub without success. Ran in hole with open ended drill pipe to 775' and unable to wash deeper. Pulled out of hole and made up an 8-1/2" fishtail bit. Ran in hole and cleaned out to 1245'. Made up casing cutter and cut at 1120' and 910'. Pulled out of hole and made up spear. Ran in hole and recovered casing stub at 910'. Cleaned out to the casing stub at 910' Ran in hole with casing spear and attempted to pull casing from 1027; Without success. Ran in hole with casing cutter and cut at 975' and 1055'. Ran in hole with casing spear and recovered casing to 975'. Cleaned out to the top of the casing stub at 975'. Ran in hole with casing spear and recovered casing to 1027'. Ran in hole with 12-1/4' bit and cleaned out to 1027'. Pulled out of hole and made up spear. Ran in hole and recovered casing to 1120'. Ran in hole with 12-1/4' bit and cleaned out to 1120'. Pulled out of hole and made up spear. Ran in hole and recovered casing to 1200'. Made up 15' underreamer and ran in hole. Reamed from 1059' to 1200'. Pulled out of hole. Ran in hole open ended to 1240' and laid a balanced plug with 314 sxs of class "G' with 2% CaC12 and .5% CFR-3. Pulled six stands and reverse circulated. Applied 150 PSI to the cement and held for 30 minutes. Pressure bled back to 100 PSI. Cement in place at 0100 hours 10/1/88. Pulled out of hole and made up new bottom hole assembly.= Ran in hole and tagged cement at 9.30'. Cleaned out cement to 1016' then pressure tested the casing to 1500 PSI and held for 30 minutes. Continued cleaning out cement to 1070'. Performed leak off test at shoe. Pressure tested shoe to 560 PSI or EMWof 146 PCF. Pulled out of hole and tested BOPE. Finished testing BOPE. Made up kick off assembly and ran in hole. Drilled to 1209' and performed second leak off test. Pressure tested the shoe to 475 PSI or EMWof 134 PCF. Changed over mud system to XC polymer. Directionally drilled 12-1/4' hole to 1709'. Continued to drill and gyro survey to 2022'. Circulated and conditioned mud then pulled out of hole. Made up new bottom hole assembly and changed out MWD tool. Ran in hole and reamed to 2022'. MWD and gyro surveys were reading the same. Drilled from 2022' to 2414'. Continued to drill and survey 12-1/4" hole to 2540'. Circulated and conditioned mud and pulled out of hole. Changed the bit and ran in hole. Reamed from 2508' to 2540'. Drilled 12-1/4" hole to 3125'. Changed out swivel packing. Drilled 12-1/4" hole to 3283' and circulated. Pulled out of hole and changed bit and BHA. Ran in hole. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE TRADING BAY STATE A-16 WELL NO, FIELD, TRADING BAY STATE DATE E.T.D. 1988 Feet 10-05-88 02'TD 10-06-88 'TD 10-07-88 'TD 10-08-88 4987'TD 10-09-88 5555'TD 10-10-88 5950'TD 10-11-88 6184'TD 10-12-88 6184'TD 10-13-88 6184'TD 10-14-88 6430'TD 10-15-88 6616'TD 10-16-88 6844'TD 10--17-88 6844 'TD 10-18-88 6844'TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Wash and reamed 12-1/4' hole from 2300'-3283'. Drilled 12-1/4' hole to 3771'. Made short trip to 3020' - no problems. Drilled 12-1/4' hole from 3771'-3961'. Tripped for bit and BHA change. Drilled 12-1/4' hole from 3961'-4102'. Continued to drill and survey 12-1/4' hole from 4102'-4177'. Tripped from new bit. Drilled 12-1/4' hole from 4177'-4537' and short tripped. Finished short trip. Drilled 12-1/4' hole from 4537'-4753'. Tripped for mud motor to correct right hand walk. Dyna-drilled 12-1/4" hole from 4753'-4860'. Dyna-drilled 12-1/4" hole from 4860'-4884'. Tripped for reaming BHA. Reamed Dyna-drill run. Drilled 12-1/4" hole from 4884'-4961'. Tripped for conventional BHA- tight from 4022'-4156'. Re~ned from 4753'-4761'. Drilled 12-1/4" hole from 4961'-4987'. Drilled 12-1/4" hole from 4987'-5127'. Maae short trip to 3350' - no problems. Drilled 12-1/4" hole from 5127'-5376'. Made short trip to 3698' - no problems. Drilled 12-1/4" hole from 5376'-5555'. Drilled 12-1/4' hole from 5555' to 5561'. Tripped for a new bit. Tested the BOP equipment. Ran in hole and drilled from 5561' to 5747'. Short tripped to 4907' (tight from 5524' to 5357'). Drilled from 5747' to 5950'. Drilled 12-1/4" hole from 5950' to 5963'. Short tripped to 4098' (tight 5923' to 5614'). Drilled from 5963' to 6184'. Circulated bottoms up and pulled out of hole. Laid down a stabilizer and picked up a new bit. Ran in hole to the casing shoe and cut and slipped the drill line. Continued running in hole to 6140'. Picked up to 6125' and picked up kelly. Drill pipe stuck on up stroke. Mixed and spot 40 bbls of mineral oil around the bottom hole assembly. Rigged up wireline and ran free point. Pipe was 100% free to 6065' (baffle plate as deep as could get). Ran string shot and attempted to back off at 6037' without success. Ran another string shot and attempted another back off at 6037' without success. Ran string shot and backed off at 6001'. Pulled out of hole with drill pipe. Top of fish at 6001' and bit at 6124'. Made up fishing assembly and ran in hole. Screwed into the fish and jarred down. Fish fell free. Circulated and conditioned mud and pulled out of hole. Laid down fishing tools and inspected the bottom hole assembly. Ran in hole. RIH and reamed from 6000' to 6184'. Circulated and conditioned. Drilled from 6184' to 6318'. Short tripped. Drilled from 6318' to 6410'. Short tripped. Drilled from 6318' to 6430'. Drilled from 6430' to 6501'. Short tripped. Drilled from 6501' to 6563'. POOH and changed BHA. RIH and drilled to 6616'. Drilled from 6616' to 6687'. Short tripped. Drilled from 6687' to 6752'. Short tripped. Drilled to total depth to 6844'. Circulated and conditioned mud. Short tripped to 13-3/8" casing shoe at 1059'. Tight from 6844'-6302'. Ran in hole and reamed from 6814'-6844'. Circulated and conditioned. Pulled out of hole, tight from 6844'-6213'. Ran in hole and reamed from 6834'-6844'. Circulated and conditioned. Pulled out of hole and laid down BHA. Rigged up wireline and ran DIL/GR/LSS from 6807'-1052'. Ran in hole with CNL/FDC/GR. Ran CRL/FDC/GR log and 4-arm dipmeter log from 6807'-1052'. Rigged down Western Atlas wireline. Restrung travelling blocks from 8 to 10 lines. Ran in hole with clean out assembly and reamed from 6734'-6544' (had i0' fill). Circulate and conditioned hole. Hade short tri~. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. LEASE TRADING BAY STATE A-16 ,WE th NO., FIELD TRADING BAY STATE DATE 1988 10-19-88 10-20-89 i0-21-88 10-22-88 10-23-88 10-24-88 10-25-88 10-26-88 1!-24-88 E.T.D. Feet i844 ' TD 1844'TD i844 ' TD 844 ' TD ;844'TD 6844'TD 6844' TD 6844' TD 6844 ' TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Completed short trip to 2800'. Hole tight from 6815'-6844'. Circulate and condition mud. Pulled out of hole. Laid down HWDP and BHA. Set test plug and changed to 9-5/8" casing rams in lower double gate. Test BOE - ok. Rigged up and ran 55 joints 9-5/8", S-95, 47# and 109 joints, N-80, 47# casing. Set 9-5/8" shoe at 6814', F.C. at 6730'. Installed cement head and reciprocated and circulate to condition mud. Pumped 50 bbl of dual spacer. Began to mix cement at 2400 hours. Mixed and pumped 1400 sxs of Spherelite lead cement w/.5% Halad 344, 1% CFR-3, .5% HR7 and 3% KCL. (Mix weight 12.1 ppg). Mixed and pumped 475 sxs of class "g" tail cement w/.5% Halad 344, .2% CFR-3 and .1% LWL (Mix weight 15.8 ppg).. Displaced cement with mud and bumped plug w/2000 PSI. Had 30 bbls of cement returns. Nippled down BOPE, lifted stack and set slips. Cut casing and unstabbed DCB spool. Tested wellhead. Nippled up BOPE. Restring blocks from 10 to 8 lines. Tested BOE to 3000 psi - ok. Ran in hole with 8-1/2" bit and casing scraper. Clean out cement and plugs from 6726'-6730'. Circulate and reduced M.W. to 75 PCF. Pulled out of hole. Rigged up Western Atlas and ran multi-shot gyro from 6715' to surface in 100' intervals. Ran CBL/VDL/Signature log from 6730' ~ to surface without pressure. Prep to rerun CBL log under pressure. Reran CBL/VDL/Signature log with 1000 PSI on casing from 6730'-5200' DIL and from 2500'-2000' DIL. Ran in hole with geophone to 6695' DIL and ran velocity survey profile to surface (30 stations). Rigged down Western Atlas. Ran in hole with 8-1/2" bit on 9-5/8" casing scraper to 6730' DPM. Pumped 50 bbls of HEC/FIWspacer with 25 PPB coarse frac. sand to clean casing. Circulate with FIW for 2 full well volumes. Cleaned mud system. Began.to mix 70 PCF KCL/FIW/NACL completion fluid. Completed change over to 3% KCLfluidmixed to 70 PCF. Filtered fluid using Baker D.E filters to 50-65 NTU's. Pulled out of hole - laid down same 5" drill pipe. Tested 9-5/8" casing to 3000 psi - ok. Made up 5" TCP guns to perf Hemlock zone. Ran in hole with 5" TCP guns. Correlated guns with GR to DIL. Set RTTS at 6263'. Top shot at 6308' DIL, bottom shot at 6631' DIL. Rigged up HOWO0 test manifold. Pressured up annulus to 2800 PSI. Guns fired at 1520 hours. Flowed well to producton for 10 minutes. SI well for 2 hours. 'Reversed circulation to production. Released RTTS. Well taking 2 BPM. Set RTTS at 6220'. Laid down test manifold. Began to· circulate 65 PCF fluid. Finished circulating 65 PCF fluid (3% KCL and NaCL). Pulled RTTS free. Hole taking 0.5 BPM. Pulled out of hole laying down tubing conveyed guns. Ran in hole with OEDP and circulated. Hole taking little fluid. Pulled out of hole, picked up Baker model "D" packer and ran in hole to 6218' DIL. Dropped setting ball. Packer would not set. Pulled out of hole with packer. Packer running tool had restricted ID. Made up new setting tool. Ran in hole with Baker 9-5/8" model "D" packer and set at 6218' DIL. Pulled out of hole. Ran in hole with 3-1/2" temporary completion. Stabbed into packer, spaced out and hung off with tail at 6290' DIL. Tested packer and hanger - ok. Installed BPV. ND BOPE. NU and test single 4-1/2" tree. Released rig at 2400 hours. Rigged up fracturing equipment. Attempted to set tree saver without success. Sent lower cup assembly in to be turned down. Set the tree saver and began testing surface equipment to 8000 psi. Had electrical problem with large (902) turbine. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE TRADING BAY STATE A-16 TRADING BAY STATE WELL NO FIELD DATE 1988 11-25-88 11-29-88 11-30-88 12-01-88 12-02-88 12-03-88 12-04-88 12-05-88 12-06-88 E.T.D. Feet 6844'TD ;844'TD 6844'TD 6844'TD 6844' TD 6844'TD 6844'TD 6844'TD 6844' TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Repaired turbine and tested surface equipment. Performed injectivity test, step rate test, flow back test and leak off calibration. Found gel slurry had not cross linked. Mixed new slurry and repeated data fracture. Fractured the Hemlock zone from 6308' - 6631' with 62,500# of ISP sand. Final treating pressure was'4500 psi. Monitored pressure for closure. Began rigging down fracturing equipment. Will finish work on A-14. Nippled up BOPE and tested to 1500 PSI. Pulled seals from packer and well taking fluid at + 90 BBL's/hour. Circulated out oil and gas then stabbed back into pack--er. Built surface volume of F~ and 3% KCL. Mixed a size salt pill. Built surface volume. Mixed a 50 bbls sized salt pill. Spotted pill to the end of the tubing. Well stabilized. Pulled out of hole with workover tubing. Picked up 2-3/8" tubing stinger and ran in hole. Cleaned out frac. sand from 6462'-6730'. Pulled to 6200'. Ran in hole and tagged at 6730'. Mixed a high viscosity sweep. Pumped high viscosity sweep at 6730'. Changed the well over to clean completion fluid. Losing fluid to perfs at 22 BPH rate. Spotted a 50 bbl sized salt pill at 6450' and pulled to 5825'. Squeezed pill with 300 PSI. Pulled out of hole and laid down 2-3/8" stringer. Made up 4-3/4" O.D. S-1 packer plug and ran in hole. Set plug in packer at 6230', sheared and pulled off plug. Spot sand on top of packer to 6212'. Pulled out of hole. Nippled down BOPE and changed out D~3 spool. Nippled up and tested to 3000 PSI. Ran in hole and tagged sand at 6212'. Cleaned out sand to 6217'. Pulled out of hole. Made up 4-5/8" tubing conveyed perforating guns and ran in hole. Ran gamma ray log to place guns on depth. Set packer and shot 8 HPF from 5460'-6190' in 11 intervals. Pressured up on annulus to fire the guns. Did not have positive indication of shot. Dropped a bar and indication of firing head fired. Observed well, opened IPO valve and reversed out. Pulled packer to pull out of hole. Pulled out of hole to 2636' and well not taking the correct amount of fluid. Shut in well with 30 PSI on drill pipe. Circulated well on choke. Shut in well again with 175 PSI on drill pipe. Raised mud weight from 65 to 67 PCF and circulated well dead. Unable to run in hole due to high winds. Ran in hole and circulated well from 5278'. Pulled out of hole with guns and all shots fired. Made up 9-5/8" scraper and ran in hole. Ran in hole with 9-5/8" casing scraper, tagged fill at 6209'. Circulate at 6150'. Tripped for S-1 packer plug overshot. Reversed out debris from 6209'-6230' ETD. Latch plug and equalized, pulled packer plug free. Hole taking .75 BPM. Spotted sized salt pill of 25 bbls. Pulled out of hole. Make up 710' of 2-3/8" stinger and ran in hole on 3-1/2" drill pipe. Continued in the hole with 2-3/8" tubing stinger and 3-1/2" tubing. Tagged at 6730' (ETD). Pulled out of hole laying down tubing. Changed out rams on BOPE. Picking up and running dual 2-7/8" completion. UNION OIL Co. OF CALIFORNIA DRILLING RECORD PAGE NO, LEASE., DATE 1988 12-07-88 12-08-88 0587N TRADING BAY STATE 6844' TD 'TD A-16 TRADING BAY STATE WELL NO .... FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Finished running 2-7/8" dual completion as follows: _Long String Short Strin,~ Re-entry guide 6285' Otis "XN" 5406 Otis "X" Nipple 6273' Dual Pkr 5385 Seal Section 6229' Otis "XA" Sleeve 5258 Perm.- Pkr. 6230' GLM #1 5287 Blast Jts. 6202'-5466' GI24 #2 4797 Dual Pkr. 5385' GLM #3 4327 Otis "XA" Sleeve 5365' GLM #4 3764 GLM #1 5327' GLM #5 3192 GLM #2 4860' GLM #6 2223 GLM #3 4352' GL~ #4 3817' GLM #5 3222 ' GLM #6 2249 ' SSSV 299 ' Pulled out of hole with plug. Nippled up wellhead and pulled BPV's. 12-8-88. Installed BPV's and nippled down BOPE. Released rig at 1200 hours SURVEY REPORT UNOCAL CORPORATION TRADING BAY WELL A-16 RD KENIA, ALASKA MONOPOD OCTOBER 25, 1988 Oil It, Gas cons, .commi~lon Gyrodata Incorporated RO. Box 79389 Houston, Texas 77224 713/46t -3146 October 25, 1988 .- Mr. R..C. Warthen Unocal Corporation 909 W. 9th.Ave. Anchorage, Alaksa 99502 RE: Trading Bay Well A-16 RD Kenai, Alaska Dear Mr. Warthen: Enclosed please find one (1) original and six (6) copies of the completed survey of Well No. A-16 RD. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Gary W. Uttecht Vice President, Technical Services GWU/cv Enclosure .A~s~ O~ & ~s,,iX~t~o~c~eC,°~s' Gyrodata Services, Inc. Houston, TX/Lafayette, LA / New Orleans, LA/Ventura, CA, Aberdeen, U.K./Calgary, Alberta A Gyrodata Directional for Surv'ey UNOCAL TRADING BAY WELL A-16 RD KENAI, ALASKA Date Run: 21-0CT-88 12:15:0 Job Number: AKlO88GIll Surveyor: AL KUDRLE Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 53min 48sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: N 68deg Omin Osec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference UNOCAL TRADING BAY WELL A-16 RD KENAI, ALASKA Job Number: AKlO88Glll A Gyrodata Directional Survey.. Page 1 MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 I00.0 0 9 200.0 0 13 300.0 0 22 400.0 0 45 500.0 1 0 600.0 5 40 700.0 9 39 800.0 14 12 900.0 17 54 1000.0 21 1 1100.0 21 51 1200.0 21 45 1300.0 22 17 1400.0 22 32 1500.0 22 55 1600.0 22 50 1700.0 22 49 1800.0 22 35 1900.0 22 51 2000.0 22 22 2100.0 22 4 2200.0 22 12 2300.0 21 50 2400.0 21 38 2500.0 21 42 2600.0 21 27 2700.0 21 7 2800.0 20 49 2900.0 20 22 N 00E N 67 40 E N63 9E S69 9E S 520W DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' ft ft CLOSURE' DISTANCE. BEARING ft deg min .00 .0 .0 .0 N 0 0 E MD REF TO RKB ELEV 101 FT TO MSL MULTISHOT GYRO SURVEY RUN IN 9 5/8" CASING' .15 100.0 -.1 .1 N 67 40 E · 07 200.0 -.3 ..5 N 66 3 E .28 300.0 -.8 .9 N. 77 5 E .75 400.0 -1.5 1.5 S 67 52 E S 59 53 W .84 500.0 -1.2 N 73 58 W 5.03 599.8 3.7 N 81 33 ~ 4.09 698.9 16.8 N 79 Il W 4.58 796.7 37.0 N 87 5 %; 4.28 892.8 63.7 N 88 28 W N 84 36 W N 74 24 W N 72 39 W N 73 50 W N 7346 N74 8W N74 6W N 75 36 N 73 29 N66 2W N 65 32 W N 65 21 W N65 8W N 64 56 W N 65 26 W N 65 42 W N 64 55 W N 64 58 W N64 2%; 1.'9 S 18 24 E 5.6 S 63 25 W 18.0 N 89 1 W 38.6 . N 84 24 W 66.2 N 83 52 W 3.15 987.1 95.0 1.65 1080.1 129.7 3.78 1173.0 166.0 .84 1265.7 203.3 .52 1358.1 241.3 99.4 N 85 11W 136.0 N 85 32 W 172.9 N 84 15 W 209.8 N 82 20 W 247.6 N 80 57 W · 38 1450.4 279.7 .16 1542.5 318.4 · 02 1634.7 356.9 · 62 1726.9 395.2 .85 1819.2 433.6 285.9 N 79 59 W 324.6 N 79 16 W 363.2 N 78 43 %; 401.8 N 78 20 W 440.3 N 78 0 W 2.90 1911.5 472.0 .36 2004.1 509.8 .15 2096.7 547.4 .37 2189.4 584.9 .22 2282.3 621.9 478.4 N 77 21W 515.5 N 76 30 W 552.5 'N 75 45 %; 589.4 N 75 5 W 625.9 N 74 30 W .20 2375.2 658.7 .28 2468.2 695.5 .43 2561.4 731.7 .29 2654.8 767.5 .56 2748.4 802.6 662.4 N 73 59 W 698,7 N 73 32 W 734.7 N 73 8 W 770.1 N 72 45 W 804.9 N 72 24 %; HORIZONTAL COORDINATES feet .00 N .05 N .18 N .21 N .57 S 1.82 $ 2.51 S .31 N 3.77 N 7.07 N 8.36 N 10.58 N 17.34 N 27.97 N 38.96 N 49.74 N 60.49 N 71.11N 81.20 N 91.49 N 104.78 N 120.29 N 135.95 N 151.65 N 167.29 N 182.78 N 197.99 N 213.15 N 228.30 N 243.45 N .12 E .41 E .92 E 1.40 E .6O 5.02 18.03 38.40 65.82 99.09 135.56 172.03 207.97 244.47 281.57 W 318.92 W 356.22 ''~ 393.4~ ) 430.70 ~ 466.74 501.23 535.50 569.54 603.12 636.63 W 670.11W 703.08 W 735.49 W 767.23 W UNOCAL TRADING BAY WELL A-16 RD KENAI, ALASKA Job Number: AKlO88Glll A Gyrodata Directional Survey.. Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY £t deg .in deg min deg/iO0' 3000.0 20 14 3100.0 19 54 3200.0 19 31 3300.0 19 37 9400.0 20 11 3500.0 21 1 3600.0 21 27 3700.0 21 41 3800.0 22 18 3900.0 22 11 4000.0 21 59 4100.0 21 50 4200.0 21 26 4300.0 21 16 4400.0 21 i1 4500.0 21 7 4600.0 20 57 4700.0 20 34 4800.0 21 6 4900.0 22 44 5000.0 22 59 5100.0 22 26 5200.0 21 56 5300.0 21 35 5400.0 21 12 5500.0 20 41 5600.0 20 13 5700.0 19 59 5800.0 19 58 5900.0 19 31 N6347W N 62 22 W N 62 22 W N62 3W N6! 34W N61 33W N60 5W N 59 45 W N 58 54 W N58 N 57 9 W N 57 21W N 56 56 W N 56 26 W N 56 45 W N56 12W N 54 51 W N 53 57 W N60 2W N65 9W N65 N 63 45 W N63 6W N 63 33 W N63 14W N 63 27 W N 63 33 '4 N 63 25 W N 64 21 W N65 OW VERT VERT DEPTH SECTION £t £t .16 2842.2 837.2 .58 2936.1 871.4 .39 3030.3 904.9 .15 3124.5 938.2 · 59 3218.5 972.1 · 82 3312.1 1007.0 · 68 3405.3 1043.0 .27 3498,3 1079.4 · 69 3591.0 1116.4 .35 3683.6 1153.7 · 38 3776.3 1190.7 · 17 3869.0 1227.3 · 44 3962.0 1263.5 · 24 4055.1 1299.2 · 14 4148.4 1334,7 .21 4241.6 1370.1 .51 4335.0 1405.1 .51 4428.5 1439.6 2.23 4521.9 1474,5 2.51 4614.7 1511.6 .25 4706.8 1550.4 .82 4799.1 1588.9 .55 4891.7 1626.6 .39 4984.6 1663.5 .40 5077.7 1699.9 · 52 5171.1 1735.5 .46 5264.8 1770.3 · 24 5358.7 1804.6 · 32 5452.6 1838.6 · 50 5546.8 1872.4 CLOSURE~ DISTANCE. BEARING £t deg min 839.3 N 72 3 W 873.2 N 71 42 W. 906.5 'N 71 21 W. 939.5 N 71 2 W 973..2 N 70 42 W 1007.9 N 70 23 W 1043.6 N 70 3 W 1079;8 N 69 43 W 1116.7 N 69 22 W 1153.9 N 69 1W 119o.8 N 6~ 39 w 1227.4 N 68 19 W 1263.5 N 67 59 W 1299.3 N 67 40 W 1334,8 N 67 22 W 1370,3 N 67 5 W 1405,4 N 66 48 W 1440,1 N 66 29 W 1475,2 N 66 16 W 1512.4 N 66 10 W 1551.2 N 66 9 W 1589.8 N 66 7 W 1627.5 N 66 3 W 1664.6 N 65 59 W 1701.0. 'N 65 56 W 1736.7 N 65 53 W 1771.6' N 65 50 W 1805.9 N 65 47 W 1840,1 N 65 45 W 1873.8 N 65 44 W HORIZONTAL COORDINATES feet 258.70 N 798.39 274.24 N 828.9~ 289.88 N 858.86 305.50 N 888.49 321,58 N 918.50 338.33 N 949.44 355.98 N 981.05 374.40 N 1012.86 393.51 N 1045.06 413.31N 1077.31 433.46 N 1109.05 453.65 N 1140.44 473.64 N 1171.40 493.64 N 1201.82 513.57 N 1232.05 533.50 N 1262.13 553.82 N 1291.72 574.46 N 1320.54 593.83 N 1350.35 611.00 N 1383.48 627.28 N 1418.75 643.88 N 1453.59 660.77 N 1487.35 677.41N 1520.48 693.75 N 1553.09 709.78 N 1585.03 725.38 N 1616.29 740.72 N 1647.04 755.74 N 1677.70 770.19 N 1708.23 UNOCAL TRADING BAY WELL A-16 RD KENAI, ALASKA Job Number: AKlO88Glll A Gyrodata Directional Survey. Page 3 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY it deg min deg min deg/lO0' 6000.0 19 30 N 64 48 W 6100.0 19 21 N 64 53 W 6200.0 19 1 N 63 34 W 6300.0 18 50 N 63 28 W 6400.0 18 55 N 63 53 W 6500.0 18 54 N 63 36 W 6600.0 18 58 N 62 53 W 6700.0 18 57 N 61 49 ~ 6715.0 18 48 N 59 38 W Final Station Closure: 2140.1 feet VERT VERT DEPTH SECTION it it .07 5641.0 1905.7 .16 5735.3 1938.9 .55 5829.8 1971.7 .18 5924.4 2004.0 .16 6019.0 2036.3 · 10 6113.6 2068.6 · 24 6208.2 2100.9 · 34 6302.8 2133.2 4.85 6317.0 2138.1 North 65 deg 29 min 9 sec West CLOSURE' DISTANCE. BEARING £t deg min 1907.2 N 65 43 W 1940.5 N 65 42 W' 1973.3' N 65 41 W. 2005.7 N 65 39 W 2038.,0 N 65 37 W 2070.4 N 65 35 W 2102.8 N 65 33 W 2135S3 N 65 30 W 2140.1 N 65 29 W HORIZONTAL COORDINATES £eet 784.36 N 1738 47 798.49 N 1768~5 812.78 N 1798.1~ 827.24 N 1827.17 841.58 N 1856.17 855.91N 1885.22 870.52 N 1914.19 885.60 N 1942.97 887.97 N 1947.20 , I I · i . 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I I UNOEAL ' lIRA.Il[NE :BRr NELL A-16 RI] · i . I ]O ' I' Unooal Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UIIOCAL Alaska Distric! DOCUMENT TRANSMITTAL January 17, 1989 HAND DELIVERED TO: John Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: lrading Bay Field - A-16RD ~'--. One (1) cooy of 1,iStings for tapes previously sent (12/21/88) Regarding: Trading Bay Unit, McArthur River Field - D-3ORDtt2 One (1) sepia and one (1) blueline: Acoustic Cement Bond Log/VDL/Signature/Gamma Ray RDK-lOO/Gamma Ray/CCL One (1) magnetic tape with listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT RECEIVED BY: , DATED: .............. ~____..~lasl~.Oil A Gas Con~. Com~sslo.~ Unocal Oil & Gas Divisi¢ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL 3anuary 17, 1989 HAND DELIVERED TO: $ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: .Regarding: Trading Bay Field - A-16RD One (1) cooy of listings for tapes oreviously sent (12/21/88) Regarding: Trading Bay Unit, McArthur River Field - D-3ORD#2 One (1) sepia and one (1) blueline: Acoustic Cement Bond Log/VDL/Signature/Gamma Ray PDK-lOO/Gamma Ray/CCL One (1) magnetic taoe with listing RECEIVED BY: DATED: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT Unocal Oil & Gas Divisi¢ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL December 21, 1988 HAND DELIVERED TO: $ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA 0IL & GAS CONSERVATION COMMISSION .Transmitting as Follows: Regarding: Trading Bay Field - A-16RD (CORRECTED) One (1) blueline and one (1) sepia: ~' Computed 4-Arm Diplog .... Compensated Densilog/Gamma Ray ~7~oA~p~a~_~i~omoensated Neutro. _ ....... ~,n/Gamma Regar.__~din~: Trading Bay Unit, McArthur River Field - Steelhead M-1 One (1) blueline and one (1) sepia: ~ ~. Dual Burst Thermal Decay Loo ~~'.~-~. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: . .~'~ ~"" ~ AnCi'~orage Unocal Oil & Gas Divisi,. Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL December 14, 1988 HAND DELIVERED TO: 3ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows' Regarding: Trading Bay Field - A-16RD One (1) blueline and one (1) sepia: - Dlolog ~Computed 4-Arm Dlplog ~Compensated Densllog/Gamma Ray ~Compensated Densllog/Comoensated Neutron/Gamma Ray ~BHC Acoustllog/Gamma Ray ~Dual Induction Focused Log/Gamma Ray ~Dual Induction Focused Log/Compensated Densllog/BHC Acoustilog/ Compensated Neutron/Gamma Ray '"'~ne (1) copy of Survey Report ~One (1) magnetic tape with listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL' THANK YOU. Aias 0ii & Gas Cons, .Commission STATE OF ALASKA AL~oKA OIL AN D GAS CONSERVATION COM M I~..,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program Pull tubing __ Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate ~ Variance ~ Perforate ~ Other 2. Name of Operator ! 5. Type of Well: Union 0il Company of California (UNOC1L) Development__ Exploratory __ 3. Add ress Stratigraphic ~ P.O. BOX 190247, Anch, Al<., 99519-024-~ Service__ 4. Location of well at surface 1610' N, 566' W from SE cor. Sec 4, TgN, Ri3W, S.M. At top of productive interval 4472' MD, 3.B~I'TVD, ll'N & 1911'W of Surface Location At effective depth 7356' MD, 6437' TVD, 55' N & 3314' W of Surface Location At total depth 7434'MD, 6503 ' TVD, 57' N & 3354' W of Surface Location 6. Datum elevation (DF or KB) 101' RT above MSL 7. Unit or Property name Trading Bay State 8. Well number TBS A-16 9. Permit number .~!i~,,.3¢~,,¢ 'e - o"~ ~.~ 10. APl number 50-- 733-2011 11. Field/Pool Trading Bay Field feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 1,059' 7,434' measured See 7,435' feet 6,503' feet 7,356' feet 6,437' feet Size Plugs (measured) Junk(measured) 30' of 1-11/16" Link DiCone Perforating gun ~ +7,326'. -- Cemented Measured depth True vertical depth 13-3/8" 1200 SXS 1,059' 1,044' 9-5/8" 835 sxs 1st stage 7,434' 6,503' 1000 sxs 2nd stage Attached true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) ~ Butt - ~;943' L.S. 2-7/8" N-80 :~ Butt 424' S S. 3-1/2" N-80 Side String 1-1/2" I3 4,422' - 6,846' ot Ssssv"WO" otis 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation April 1, 1988 16. If proposal was verbally approved Name of approver Mike 09-25/88 Minder Date approved 15. Status of well classification as: Oil ix; Gas_ Suspended __ Service 17. I hereby certify that the foregping is true and correct to the best of my knowledge. Signed ~a~ D. Aoberts Title Environmental Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Approved Copy ORIGINAL SIGNED BY Approved byorderoftheCommissioner LONNIE C. SMITH //--~:'~gT~ L;omm~smoner IApproval No. ~ _ ~g, Date //--",,~,~'--'~;~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE l) 2) 3) 4) 7) 8) 9) MONOPOD PLATFORM TBS A-16 ABANDONMENT PROCEDURE MIRU. Rigged up coil tubing and cleaned out the long string to 4600'. Rigged up coil tubing in the short string. Milled and cleaned out to the SSSV at 307'. Attempted to pull SSV without success. Built the mud weight to 70 PCF and bullheaded down the long string to kill well. Set BPV and removed the tree. Rigged up BOPE. Ran jet cutter and cut the long string at 280'. Made up fishing tools and backed off the short string at 289'. RIH with overshot to top of long string fish, ran jet cutter and cut the tubing at 4325'. Overshot top of the short string and backed off to 4382'. Overshot the long string and attempted to run jet cutter. Cutter would not pass top of fish at 4325'. Rigged up coil tubing to clean out. Coil tubing became stuck at 4325'. RecovereO coil tubing. Backed off long string to 4386'. RIH with cement retainer and set at 4300'. Established breakdown at 1 1/2 8PM and 2300 PSI. Mixed and pumped 250 sacks of class "G" with .25% Halad 344, 0.1% LWL and 0.2% CFR-3. Squeezed 175 sacks of cement below the retainer. Final rate was 1 BPM at 2700 PSI. Pulled out of the retainer and balanced 75 sacks of cement. Rigged up and ran CBL-VDL-GR. Ran gyro survey on existing wellbore. Shot 5 holes from 2000' to 2002'. RIH and set a cement retainer at 1982'. Mixed and pumped 65 sacks of class "G" with 0.25% Halad 344, 0.1% LWL and 0.2% CFR-3. Squeezed 45 sacks of cement below the retainer. Balanced 20 sacks of cement on top of the retainer. Cut the 9 5/8" casing at 1200' and attempted to pull without success. Ran free point and cut the casing at 1027' and attempted to pull the casing without success. Cut the casing at 775' and attempted to pull without success. Nippled down BOPE and removed casing slips. Nippled up BOPE. Cut and recovered 9 5/8" casing from 355' Cut 9 5/8" casing at 565'. Recovered section of 9 5/8" casing fr~m 565" and 775'. Cut 9 5/8" casing at 910' and 1120'. Recovered 9 5/8" casing from 910'. Had to cut casing again at 975' and 1055'. Recovered 9 5/8" casing from 975', 1027', 1120' and 1200'. RIH with 15" unoerreamer and reameO open i~ole from 1059'-1200'. POOH. RIH with OEDP to 1240' and laid a balanced cement plug: 314 sxs "G" cement with 2% CAC12 and 0.5% CFR-3. Braidenhead squeezed cement with 150 PSI. Top of cement at 930'. Drilled out cement to 1016'. TesteO 13 3/8" casing to 1500 PSI - ok. Drilled cement to KOP at 1070'. LOT at 1070' equaled 146 PCF EMW. TBS A-16 PEiL~DRATED INTERVAL Measu7ed Dept~h True Vertical Depth 4472-4496 (Squeezed) 3931-3950 4540-4578 3983-4013 4628-4644 4052-4066 4650-4666 4070-4084 4708-4720 4116-4126 4856-4870 4236-4246 5042-5180 4387-4501 5219-5306 4534-4609 5332-5368 4631-4662 5444-5454 4729-4738 5662-5674 (S~aeezed) 4924-4934 5858-5886 (Squeezed) 5009-5035 5890-5930 (Squeezed) 5129-5165 6944-7250 6079-6345 *NOTE' = - ~ ~ = be Perzor=~; on~ to abandoned. 0485N (3) CHOKE MANIFOLD SEE DRAWING TO MUD PUMPS & CEMENT UNIT ANGLED FILL UP LINE HYDRIL ~ PiPE RAMS wi II t ~ "'=="FROM MUD PuMP. s ,' ', & CEMENT UNIT ~' ~ CONTRA~TO~ FURNISHED OPERA 70~ FUrNIShED WELL NAME: RIG CONTRACTOR: STACK PRESSURE RATING: CHOKE LINE SIZE & MSP; NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY' WHEN DIVERTER IS CLOSED. 2. FLEX HOSE (~/~) IS TO BE USED IF NECESSARY WITH DDS' APPROVAL. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT DEPT. APPROVAL :. -'2v. i B.,A.W2 6/_...17/86 t 13 .5/8". BOPE STACK 5M OR 10M · ALL WORKOVER OPERATIONS UNION OIL COMPANY OF CALIFOR,,'4.1A -" ,"~ 2 h' 0 R ',¢,.,~- E, ~:,w~ B H E APP'D. SCALE NO J'~: ~ c~a. C G N 612 6/8 5 PR E SENT 133/8", 61~.'J-55. Casing at 1,059' PROPOSED Tup of Dip Tube at ,1.353' elis Model R-tit Triple Packer al ,1,41,1' C'i SA C'2 SA C'3 SA C-4 SA C-5 SA C-7 SA /~JD (,I,172'-,1,196') Squeezed tJD (45,10'-4578') ND (4628°-,1666') ND (,1708'-,1720') fg/'-) (4856'-4870') ND ( 042'-5180,5219-~306 ) ., 7-5 SAND (5332'-5368') Cml Rlnr. 1'1-80 Tubing Sirings · Triple Ilydraulic I':'acker I] ZFIIIE PEI1FI'IIIATlOltS 4 7-5 SAND (5,14,1'-545,1',5622'-56,t0') 50'3 S/~ND Squeeze~t 51-6 SANE) Squeezed 57-2 SAND Squeezed Oils Model R'I'I! Packer al 6,912' Cml. Rlnr. flEItlL OCK F~,I. (09,1.1'-7142',7 162'-7250') :1 95/8", ,10~ & ,13.5¢, J-.55 & H-80, Casino al 7,43,1' T.B.S. A-'I 6 l--iedrill Single Permanen! Packer 9 5/8", ,17,¢., r.l-[~o, Casing 0 FREE GAS KNOCKOUt" , CHOKE MANIFOLD UNOCAL PLATFORM RIGS 4-1/16" & 3-1/8", 5M MSP SC~L£ _N_O_.N E.__ UNION OIL COMPANY OF CALIFORNIA Unocal Oil & Gas Divisi¢ Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska District DOCUMENT TRANSMITTAL October 12, 1988 HAND DELIVERED TO: 3ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Field One (1) seoia and one (1) blueline of Compensated Neutron Gamma Ray log - A-igRD well One (1) cooy of Gyrodata survey reoort - A-16 well PLEASE ACKNOWLEDGE TRANSMITTAL. TH RECEIVED BY:~: DATED: RETURNING ONE COPY OF THIS DOCUMENT 90'72?6754,2 ;~ 1 I~CV BY:Xerox Telecopier' 7020 ;10- 3-88 ; 9:59 -- ..... [I .__ ' -.'2~ "-- - -='- ...... IIIJl ...... ~ = ~ .... !; .... ---~- .... ' ' - --' _; .... ,iii.. _ ~O'?ii&' .,, , ..... :..:....pi, ":'" ' ~.:...~,~ "',' ~) ..... 9~.'~i~i ~:~"':~~:, . _ ' . I __~ I . _ _11 I [ mm ......... I ........ ~, ,,,,~. ~..,~ ~,,..,~,~-,' h:~_.. ~~.'~ ,,,,,.,, ~~,6 ........ ................... .... __ .... ~ ~o~ ,.. Lov,~ h~y ~ Io~ ~,.~o_. ~ ~,._ ~. i it ~-' -' .... .[ . .I ....... L- I -~ ' - ,~,&, Vilv~ .... ................ ~0 ...... Xo. Vs[vu. J~, , ,,~ . ....... ,~_.. ,..~.. , ..,~,, ..... i-'.: O ................ . ...... RECEIVED SEP 2 19 8 Ab~J,m Oil & ~s Cons. Commis~ WELL NAME AND NUM~BER: ,'~~o ~, W~.. ~l~m~ll, A~/~ N~,~__ ........... TOP ~SING HEAD FL~SE SIZE ~D SERIES' t3-:/}" 3 ~ ~ SIZE &ND SER~ES OF B 0 P EQUIPMENT' "~"~ ~~. $~ ~ The foll~ing list ts to be c~cked by th~ d~lltn~ 'Foeman, ~d t~d ~]~ tO the Drilling Su~rin~dent as soon a~ possible afar drilling out, GENERAL, ! there a set; of drawings ~v~itable t,o We ~4g showing t~e BOP stack., t(nes, v~lve.~, and manifolds ),equated? ~ ................ Do all items meet or exceed the p~e~$ure ~atin~) of the ~..O.P. assembly? 2, 4, 5, 6, 8, 12, 13, 14, Is the B.O,P, asse.~ty rating equal to or grew:er ' n cas~mg burst pressure or fomlatio~ br~akdQwn pressure, whichever is Is there available a st~p-by s'tep set of illustwatiems showing how to test ~ll BOP ~tems, including ~op ca~ing jo~n~s, in a minimum number of ste~s? Are ~hese steps followed after esch nipple-up and at specified interv',~ls thereafter?....=_j~.~_. .......... . What intervals? ACC~LATOR Is accumulator properly installed? ..... Y~s.... . m__ ~~'~ Fluid c~pacity i~ ~t S~ndby Nit~gen bottle~ ~ ~' Pu~ capactty~~--- ,, - .... Fluid leal ~t~ _ - .... ~~ ~ m ~ , -__ ~ m ~tm FIu~ d type ~-- ' m Pressu~ on acc~ulator ~fo~ o~eration }~ ~/ ~~~ P~ssu~ i~di~teiy afar op~ratlon .... ~~~~~ ~ ~ydM1 ~gulator control valve ~e~mt~ p~Fly? ~J -~ Are all controls properly marked?_ ~~~~~' A~ ~~ c~t~l valves pr~erly tns~lted?.--_~~s ' ~~ ~ they o~rate pmp~!y~ ~ ...... - ...... ~~~~ ~s accu~lato~ hold pressure wiBout leaking or unusual a~t of pu~ operatio Am all wtves ~een acc~ulator and B~ valves kept o~n at all tiros? ,, ,m mr.- -~ SEP 19BB ~m~g~ ~t,& (~as ~ns. c~mmisSton mi RECEIVED SEP 2 2 198~ Alaska Oil & Gas Cons. Commission Anchorage Choke m~ni fold Kill l~ne Kelly cock , 2. 3. 4. 5. i 9. lO, !1, 13. i5, '16, R~ ~ary hoes h. ISC[LLANEOUS CHECK LIST Are choke lines installed A~e h~n~ wheels tnst~lted and braced? ~ ..... 1I~. ~ .= · .' N ~-- Lm I __ Ii mi ~ ~ Can ~ams be locked ir, closed position from outsid~ substructure? Ko .,,i..--ii,.ii ,iiil.mi,-i.I. Are al~ :~tlets equipped wi~ high pre~$ure fittings? /vAs .... Are rtlief lines of large capacity avai!eble, q f needed to hold pressure down on surface c~ing? Y~ Do valves operate properly? Z~~ .......... Are handles imstalled ~nd within e~sy ~ach? A're BOP's properly b~aced? %~ Are bolts in all bc. lt holes? Y~ Do all bolts h.~ve nuts? Are all threads filled? Are choke line.~ and emergency ftowline tied into mud g~s .~eparator? _,~._.~e._~_ ....... Can !las separaim~i from the mud be ~afeiy discharged or f'Lar~d? ~.,.~ · ~. Are ther~ ~ep~rate fill-up and ki~l lines? ~.~- What chokes ~?e in manifold? L, Choke~ or)l:ca:ion (No, & Size} below t~ position of the r~ms in the BOP ~tack, Size -¢... $ ,~ RECEIVED SEP 2 2 1988 Alaska Oil & Gas Cons. Commission Anchorage RECEIVED SEP 2 2 ]988 Alaska Oil & Gas Con~. CommimNorl Anchorage i ,. - 3- iB. 20. goes each crew have regularly scheduled 'BOP Are "on bottom" d)-ill$, '"while tripping'i d~lls, "drill collar" drills, ~'nd 'lout-of-hole.: drills held at intervals, and ar~. the ti~s and results entered on the daily 6rilti~ report? "/~: .......... -..~_.._-.=.-_.-,,-.- A~e pit level indicator, flow sensor and stroke counter working) p~operty? go ~ta~ work ~nd a~ they set clo~e enough to ~ense immediate loss a~ ,.q~in? for hole filling (number of stands) and is ......... · ,.-~ .~. ~,t 22. 23. 27, Are,charts posteO on the rig showing bar~ets to be pumped from pits with v~r')ou~ amount~ of pipe removed fPom hole? .___.__~ ..... Now is hole fi it-up measu~d? ..... "~ .... Are crews in~tructeU as to p~ocedures dur~n§ trip ~f ~wabbing or lost circulation is detected? ~ .... ~ .... ~.. __ ~ :: _.,. ,mm,--.. ~as e~ch crew been instructed on proper e~ergency back-up ~peration of 8~P system using nit.gert bottle~? ~_~ maximum ~urf~ce pressures allowed in well specifimd and posted? ....... ~,as mu~ program been posted on lac~tion? mud stock available? The BOP equipment conforms to ~pecificat~on~ with the following excepti ohs: ~o Indicate time in seconds to psrform 'the following' .) Open choke manifold .~ Sec, Close Hyd~il ___ ~.o Sec. Close ptp~ rams ~ Sec, Close blind rams ~ Sec, m~ Check accumulator p~e~$ure befo~-e and after above o~eratton~ and record: Before_ ;)~ PSI, After 7-No(~ PSi. ! uompaYy '~ritlt~g- E~'H. naer or D~l ling Forema~ RECEIVED SEP 2 2 ]988 Alaska Oil & Gas Cons. Cammission Anclmrage May 20, 1988 Telecopy.' (907) 276-7542 Mr, Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Trading Bay State A-16 RD Union Oil Company of California Permit No. 88-38 Sur. Loc. 1610'-FNL, 566'FWL, Sec. 4, T9N, R13W, SM Btmhole Loc. 890'FNL, 2142'FWL, Sec. 4, T9N, R13W, SM Dear Mr. Roberts Enclosed is the approved application for permit to redrill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits 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. Vevx tru~y~ours%, · ~ ~. V. Chatterton Chai~an of Alaska Oil and Gas ~onserw~ion ~o~ission BY ORDER OF THE CO~ISSIOM dif Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. P-Ir. Bill H. Lamoreaux ;'-T'~ STATE OF ALASKA '--',,, ALAS,..!,, OIL AND GAS CONSERVATION _;OMMISSION PERMIT TO DRILL 2O AAC 25.OO5 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 Union Oil of California 101' RT above MSL feet Trading Bay Field 3. Address 6. Property Designation "D" and Hemlock P. O. Box 190247 Anchorage,. AK 99517-0247 ADL-18731 ,,, 4. Location of well at surface ~ 7. Unit_or property Name 11. Type Bond(see 20~A~_C 25.025) 1610'N 566'W f/ SE Cor Sec 4'±'~N,.R13W SM Trading Bay State StateWide-Nat Fire ' ' " Ins Co Of Hartford At top of productive interval 8. Well nu ,mber Number 5226'TVD, 670'N & 1660'W f/Surface Location TBS A-16~J~ B5534278 ,5 t tot I depth 9. Approximate spud date Amount 53~VD, 890'N & 2142'W f/Surface Location April 1,1988 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number ~)f acres in property 15. PropOsed depth(MD and TVD) Pr°zP~l~ine feet 16' F/ A-8 feet 3840 7000'/6553' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1200' feet Maximum hole angle21. ~_, Maximum surface 1800 psig At total depth (TVD) 2000 psig .,, 18. Casing program Setti,ng Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 12-1/4 9-5/8" 47# $795 Butt 2000 3000 4649 7000 6553 626 12-1/4 9-5/8 47# N-80 'Butt 5000 0 0 5.000 4649 1566 cuft 19. To be completed for Redrill, Re-entry, and Deepen Opera'iions. Present well condition summary Total depth: measured 7435 feet Plugs (measured) Cmt Ret @ 6900' 5000' 4450' true vertical 6503 feet 2000', 1250";Cmt Plug: 1250' - 900' Effective depth: measured 900 feet Junk (measured) 30' of 1-11/16" Link Dicone true vertical 894 feet perforating gun @ +7326' Casing Length Size cemented Measured depth True Vertical depth Structural Conductor Surface 1059' 13-3/8" 1200 sx 1059' 1044' Intermediate 7~';:~ ] ?' Production 7434' 9-5/8" 835 sx @ TD 7434' 6503'~ Liner 1000 sx @ 5/~a~a 6~'¢& 6as Curls, Perforation depth: measured See Attached .~ ....... true vertical. , 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ Diverter Sketch [] Drilling program Drilling fluid program F~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements :~ ...... 21. I hereby certify that the foregoing is true and corre~ct to the best of my knowledge Signed ~ .g~_~ Titl.e. ~n~ironmental Engineer Roy D Roberts ~L_ .Comr~ission Use Only Permit Numbe~ J API number I .,~r~v?&Sa2~ J See cover letter ,r~¢~ '-~8 50--'~..~--26211'l'-0 J 8 for other requirements Conditions of approval Sample8 required' [] Yes ~ No Mud Icg required [] Yes ~ No Hydrogen sulfide measures [] Yes .~ No Directional survey required [] Yes [] No Required w~,~7//~~; lEI 5M; [] 10M; [] 15M Other: by order of Approvedb~ ~.....,.~', ~,.~'.J/__/_,~._~~ Commissioner the commission Date Form 10-401 Rev. i Subq ~licate Unocal Oil & G?-.Oivision Unocal Corpor~ P.O. Box 19024'~ Anchorage, Alaska 99519-0247 Telephone (907) 276°7600 UNOCAL ) Environmental Department Alaska District May 18, 1988 Mr. Mike 'Minder AK 0il & Gas Conservation Comm, 3001 Porcupine Drive Anchorage, Alaska 99501. RE: Directional Program, A-16 RD Trading Bay State Dear Mike, After reviewing the offset wellbore paths, Union is proposing to use a trajectory further south of the original proposal to hit the targets at 5226' TVD and 6101' TVD in A-16 RD. (See attached Directional Plan). By moving south the A-16 RD wellbore will be 47.62' away from A-2 at the kickoff point and continue to diverge. The A-16 RD wellbore will be 59.76' away from A-12 RD at 2380'TVD. The only other well close to the proposed path of A-16 RD is A-12 original hole at 1920' TVD. A-12 will be within 31.23' of the A-16 RD path at that point UNOCAL will shut-in both Al2 and A-12 RD while redrilling A-16 past these wells. UNOCAL is also planning to use directional MWD equipment to provide a continuous read out of the wellbore path. Included with the MWD equipment is a magnetic interference tool to detect if the A-16 RD wellpath is approaching another well. If we can be of further assistance or answer any questions about A-16 redrill, contact Steve McLean at (805) 658-7600. Sincerely Roy .~Roberts Environmental Engineer MONOPOD A-16 RD DIRECTIONAL PLAN surface Location: -- 1610' North and 566' West of the Southeast corner of Section 4, T9N, R13W, SM B & M. Target le 670' North and 1660' West of the surface location. Depth: 5226' TVD or 5571' MD 2.. 800' North and 1980' West of the surface location. Depth: 6101' TVD or 6513' MD ?_i.rectionai Pia~n:.~ Drop, TUrn and Hold 1. Kick off directional work at 1200'. ¥ Drop the hole angle from 26.63Q to 21.75° at 2:deg/100'. Turn the wel!bore from N 80 W ton 65.44 W. The end of build and turn section is at 1398' TVD and 1450' MD. Displacement - 265' 5. Hold 21.75~ and N 65.44 W to TD at 7000' and 6553' TVD. Total Displacement at TD is 2321'. ,) TBS A-16 PERFORATED INTERVAL Measured Depth True Vertical Depth 4472-4496 4540-4578 4628-4644 4650-4666 4708-4720 4856-4870 5042-5180 5219-5306 5332-5368 5444-5454 5662-5674 5858-5886 5890-5930 6944-7250 (Squeezed) (SqUeezed) (Squeezed) (Squeezed) 3931-3950 3983-4013 4052-4066 4070-4084 4116-4126 4236-4246 4387-4501 4534-4609 4631-4662 4729-4738 4924-4934 5009-5035 5129-5165 6079-6345 *NOTE: Perforations to be abandoned. 0488N (3) A-16 Redrill MUD PRO~4 Mud Program Depth: 1~80' - 7000' Density Viscosity PV YP 72-80 PCF 35-40 Sec/Q~ 8-12 dm/cmz 16-25 #/100ft2 Gels 3/20 pH 8.5-9.0 Water Loss +10-15% CEC 15-25 SML ;jh 0488N(5) PRESENT 133/8", 61.~,'J_55, Casing at 1,O59' Top of Dip Tube at 4,353' elis Model RTH Triple Packer at 4,414' C-1 SAND (4472'-4496')Squeezed C-2 SAND (4540'-4570') C-3 SAND (4628'-4666') C-4 SAND (4708'-4720') C-5 SAND (4856'-4070') C-7 SAND' (5042'-5180',5219'-5306') 4 7-5 SA ND (5332'-5300')" PROPOSED Cml. R -2 "'/I8", ~.~ ,¢, 1',1-80 Tubing Sirings · · Triple Hydraulic Packer 47-5 SAND (5444'-5454',5622'-5640') 50-3 S~ND Squeeze~l 5 1'6 SAND Squeezed 57-2 SAND Squeezed elis Model RTH Packer at 6,912' HEMLOCK FM. (6944'-7142',7162'-7250') 9 5/8", 40¢ & 43.5¥~, J--55 & N-80, Casing al 7,43~ T.B.S. A- 1 6 Red___ril_J_l Single Permanenl Packer IIEI?ILO[;,I( FlUff. PEi'tFO[I~TIONS 9 5/8", 47~,, N-80, Casing ® 0 ® e Bo ® 7e Be 10. 11. 12. TBS A-16 REDRILL PROCEDURE RIH with a 12-1/4" bit to 850'. Pressure test casing to 1500 psi. Polish off kick off plug to 1080'. motor. Orient wellbore and begin redrill. perform a LOT. POOH and pick up bent sub and mud After drilling 10' of new formation Redrill 12-1/4" hole from 1080' to 7000' MD. Run open hole logs. Run and cement 9-5/8" casin~ ~ Run CBL-VDL-GR in 9-5/8" casing. Test the 9-5/8" casing to ~ psi. Perforate as needed for zone isolation. Perforate and fracture stimulate the Hemlock zone. Perforate the "D" zone. Run a dual string completion. (2 strings of 2-7/8", 6.4%/ft, N-80, Butt. tubing. One side string of 1.66", 1.7"/ft, J-55, 10 RND, below dual packer). Rig down and move off. Place well on production. Note: Due to the presence of H2S on the platform, H2S monitoring equipment will be utilized in accordance with AOGCC 20 AAC 25. SML;jh 0488N (4) ,, ~ ,) /r~ ANGLED FILL UP LINE, H. YDRIL . ,,' 5 VALVE _ ,. MANIFOLD · ~~3 - '-~- ' ' ." S E E D RAW IN G ~~~~~ ~. KILL LINE ' CONTRAdTOR FURNISHED OPERA fOR FURNISHED' . NOTES- 1. HYDRAULIC VALVES OPEN . WEL~ NAME: AUTOMATICALLY WHEN RIG CONTRACTOR:, DIVERTER IS CLOSED. RIG: STACK PRESSURE RATING: 2. FLEX HOSE ~x) IS TO BE USED · CHOKE LINE SIZE & MSP: IF NECESSARY WITH DDS NOTE: ALL CHANGES MUST HAVE' WRITTEN APPROVAL ,APPROVAL. BY THE DISTRICT DRILLING SUPERINTENDENT DEPT. APPROVAL , , ,, , ,, ,,, ,, ,, , , REV. ~ DATE DRAWN BHE CKD. CGN s.~,~. ~,~,~- 13 5/8, BOPE'STACK B~A.W. 6/17/86 SCALE NONE 5M OR 10M ~,~ ~,~~ ALL DRILLING OPERATIONS " uNIoN 6IL CoMpANy OF CALIFORNIA , , ~ ,,, j ,, , ANCHORAGEs,, ALASKA, , SHEETS, ~ SHEET O0¥M~ ~dOg o.I, i ., ~g)IOHO OOVM8 leUgd oJ. ,J -- "I'lVM' J.N;IA ~O& 3NI1 .LNgA NMOIdO o01. OJ. NgdO)l .I MONOPOD MUD- PIT SCHEMATIC RESERVE PIT (300 BBLS)~ [~HAKER EQUIPMENT TRIP TANK (28 BBLS) TO MUD PITS MIXING (5o RBLS) Mixing pit i$ one level below tho active system 3HAKER DESANDER 100 EIRLS DESILTER SUCTION PIT {100 BBL$) 1) Reeerve Pit :3) 2-.~hal<ers 4) Pit Lovel Indicator (Viaual & Audio) 5) Fluid Flow Sensor 6) Trip Tsnl( 7) Pit Agitatore ~) Desander 9) Desilter 10) MIxino Pit tT~O ,. HORIZONTAL VIEW UNOCAL CORPORATION TRADING BAY A-.j6 REDRILL CLOSURE: 227g ft N 67.5 W DECLINATION: 24,50 deg SCALE ; ! inch - 500 DRAW~ : i-i4-B8 ~. ,.~-- ~ ~=.-.~ tO00 ~00 ~0 '750 ~00 2~00 2250 2000 ~780 ~00 I~50 /. .; ., · %. ~00 Io00 ,. 3000 ~00 4~00 SO00 ~00 VERTICAL SECTION UNOCAL CORPORATIO~ TRADING BAY A-~6 REDRILL SECl~ON AT N 67,48 N 1VD SCALE: ! inch - t000 feet I DEa SCALE.~( Inch - t000 feet lYO ~l~lf 1170 184 8000 7000 7500 BO00 BSO0 ~00 0 ~00 tO00 i§O0 ~000 L~,O0 ~00 Departure ,1000 4~i00 )000 2OO li50 I liO0 t '$0 100 _ 500 I ,, · i I 50O 450 ' ~00 I I 1 ,350 :300 250 200 J SO ... ~ ' i , , oo.!i ~ -:,i I I I ' : i': ,. .~..200. - lO I UNOCAL SLOT NO' 29, 'WELL MONOPOD PLATFORM, ,00 400 NO, COOK;t,: ,) I 300 I ,45O I 400 ! :350 30 ~00 I 25O 200 1000 000 ! O0 1 O0 ......... : i fro. ! '' 150 ~00 -1 O0 _.0 ..So _--1 O0. I 250~., 2OO 150 :100 5O 5O '"' -3800 I . . 4700 "' g,701 4900 5000 I 4500 , ~1800 I t 9OO ~1700 200 50 J.~..~ O0 O.. C 1 e,~ r- ~ n ¢ e R ~ P o r. t ( S P h e r. i c ~ 1 Me t h ,:, ,:t ) A11 depths ~r'e in ~eet Cznd ,ir.e r. eFer. en,'zed t,:, the REF.F..:RENCE WELL RI<B StePLuise ver. tJ cal depth ststic, ns r-un ~:r'om 1 ] 70, t,::, 64¢~0. ,-~'t: it',ret, va 1 s ,:,.I-'- :,7::0. .l:.~'¢et Re~:er. ence._,¢'lot NAme ."- 2'P Re.Fer. ence I4ell Name :- ~-I./-,RD R e ~ u e s t e d b';.' : - C L 0 CI<W 00 g ObJect :.:;1,:,t Names Object Nel 1 N,~mes 17 A- 1 28 A - :2 12 ' A-:=: ~_,9/- A-12RD 111 16 A-gRD 3 A -:.--.: 0 15 A-29 ~'~ 24. A~.6 · , ,~..,. J A-'.~'8 ~, A-27 Dmte :- lO-MAY-L--:8 Revision Nc, :- 1 F'r-ePa. r-ed B',' :--T ,..IONES Ou r- Re ~: : -- DB 1: [ :_--,'C)(]~, 004 ] P005,S'.7~. 41..10 N,:, t i n P r- ,:, ::.:: i m i t'.,' r. a d i u s. Not ~.n Pr.(:,xim.i.t'.,- r. ad:i,.Js,, N C, t' J. n P r. o ::.:: TJ IT~ .~ 'J.:' "," P ~ ,-~ J I j S . N,:, t i n P r' ,:, >.'. i rn i t'-,' r.a d J u s. /-/-7 Eastman L I0 11 13 14 18 19 20 21 22 23 25 27 30 31 32 A-14 A-i'-' A- 17RB A-1~ A-24RD A-ll A-.:,R£ A-1 A-7 A-4 A-32 A-20 A-26 A-10 A-SRD? Not Nc, t Nc, t N o t Not in Pr-oximit'~.' r'a,Ji,Js. i r, P r-o >.-: i m J t '.,' r.a. d i u s. i n ~ r. o ::.:: i m i t",- r-a d i u s. i r, P r. o ::.=: i m J. t",' r.a (.t i u s. i r, P r. o :.-.'. i m i t",' r' a d i u s. Eastman Whipstock Position on well A-16RD t :Pi I..... C I. I1_ ici T I 0 N 0 F L Ii:: A S T lEI I S T R N C E BETWEFI'J NFLLS TVD NS Closest Positi,:,n c,n well A.- 19 1199.80 1170.00 1222.13 1190.00 1244.41 1210.00 1266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N EW MO TVD NS EW 1288.77 1250.00 1310.84 1270.00 1332.88 1290.0C) 1354.88 1310.00 17.02 N 18.42 N 20.08 N 21.89 N 172.45 W 1180.98 1134.04 25.34 N 182.38 W '1203.23 1153.76 23.91N 192.15 W 1225.00 1173.07 2:2..5.1N 201.75 W 1242.58 1188.14 21.17 N 1 .qv &. 87 1 :_--:30.00 1:~ ):87 1350.00 1420. :-:7 1370.00 1442. ~" oo 1390.00 ~.:,.71 N 25.52 N 27.3:4 N 29.16 N 211.18 W .1.264.43 1206.87 19.51N 220.41W 1286. l:3 1225.50 17.85 N 229.51W 1307.6:3 1244.06 16.20 N 238.49 W 1324.15 1257.90 14.95 N 1464.86 14~0.00 1486.86 1430.00 1508.86 1450.0£) 1530.85 1470.00 :--:0.97 N 32.79 N 34.6.1 N '-'/. 43 N · ~'. L). 247.47 W 134.5.55 1275.58 13.27 N 256.44 W 1366.95 1:293.26 11../::,0 N 265.42 W 1388~34 131C).94 9.92 Iq 274.4.0 W 1409.74 13'.28.63 8.25 N 1552.85 1490.00 1574.85 1510.00 1596.84 1530.00 1618.84 1550.00 38.24 N 40.06 N 41.88 N 43.69 N 2:33.37 W 1431.13 1346.3] 6.57 N 292.35 W 1445.28 1357.99 5.4.6 N 301.32 W 1466.36 1374.66 3.55 N 310.30 W 1487.45 1391.33 1,65 N S '.5: 1640.84 1570.00 1662.84 1590.00 I '~.83 1/_-.,0.00 lz,: -.83 1.630.00 45.51N 47.33 N 49.15 N 50.~6 N 319.28 W :I. 508.54 1408.00 0~26 328.25 W 152';?.63 14'24.67 2.17 337.23 W 1550.71 14.41.34 4.0:.:: . . .~ . :38 5.91 346 20 W 1571 00 14....7 . 1728. o~ F, 00 ..... 16.0. 1750. ::J2 1670. OO 52.78 N 54.60 N 355.18 W 1583.29 1466.64 7.25 364.16 W 1603.78 1482.22 ?.49 :373.1:3 W 1624.68 1497.81 11.74. 382.11W 1645.37 1513.37 13.99 "::'-? 1 08 W 16/:,6.06 .~'-"-' . .. . · _. . 1....',:,.9::: .1. 6 23 S . . m ~ . 400 0/_-, W 1686 76:1 .... 44 57 18.48 S 243.92 W 254.09 W 264.04 W 27:3.00 W 284..13 W 275.20 W 306.23 W 314.77 W R e .F : S C.) 7.1 C):3 ,, C) I.J L-.I D i s t a n c e D i r.,e c i: Be t:tueer, Wel 1 s Wel 1 s 80.9:3 hi8(_') 21 ~, 80.98 N:D2 81.2.1 N83 47g 8:.2. :::::2. N 85:3 9 W 3:26.72 W 96.70 S82 30W :338.64 W 1 ()0.84 S:5:0 2:3W 350.56 W 105. (:)7 '.:;78 2,/_",W :362.48 W 109. :.'.-]8 S 76 3 ?W 374,, 4I W :.3'82. :30 W 395.07 14 407.8:3 W 11:3,75 S75 ¢)W .1. 1:3 42 ': .... --' ..... 7 ..... ./::, 1,,,I 1:24.2:1 S71 1:30.04 S'70 '.'22: W 42...¢). 60 W 1 ._,...':' ~. 9. 2. :--; 69 12 W 43:--:. :37 W 14.1. :..-.-.:2 S68 7W 446.1:7:: W 14,7.7./':. ' S/.:,7 7W .S ':" 7'..2 _~ .. ..=i , _,' :' . 41 W 1 .... ::,. ~:; 6/-,.. '-: W 4.66.38 W 160.7:3 '.-_-;~,4 37~ 479.8! W 167.97 S6:3 493.2:3 W 175.26 S63 7W 50/-, 6.5 N 182 ':= = S/. 2 27 W · _/,.0 C)7 W 18'P. 86 ::; z., 1 51 W · -q:3:7.49 W 197. 17 ::-; 61 1 :.--.,' W /--7-7 Eastman/ , Whipstock MD CAI. CULATION OF LEAST DISTANCE BETWEEN WEL[_S Position on well A-16RD Closest Position ,:.,n well A-.2 TVD PIS EW MO TVO NS EW Ref : S070'=}7.0U0 Distance Oir-ect B e t w e e n B e t td e e Wel 1 s Wel 1 s J199.80 1170.00 1222. 13 11'?0.00 1244.41 1210.00 12_/-_.A 62 1 '-"-,C 00 13.19 13.82 14.68 15.75 N I',1 N N 172.45 W 1188.60 1165.82 182.38 W 1212.01 1187.75 1~2.15 W 1235.2,1 120~.48 201.75 W 1257.87 1230.70 69./:',7 N 72.66 N 75. :z:8 N 77.82 N 158.62 W 58. :30 N1:3 45E 166.24 W 61.05 N15 20E 173.89 W 6:3. :=::==,' N 16 44E 181.4.6 W 65,30' N18 6E 1288.77 1250.00 1310.84 1270.00 1332.88 12~0.00 1354.88 1310.00 17.02 18.42 20.08 21 ':"~ , t...~ .. N N N N 80.06 N 82.30 N 84.53 h.! 86.77 N 189.03 W 66.83 N19 21E ,1. 96.5'~ W 68.20 N 2 C) 27 L:.!: 204 1-4. W 6'=? ..::, 1 N:21 }:".'-- '-' N.,.'....-- :27E z. 11.67 W 70. ":"/-., .... , ""'-' 13,~ '~ 07 1330 00 · :,'.., 7 1. 350 00 1420.87 1370.0C~ 1442.86 1390.00 23.71 25.52 27.34 29.16 N N N N 247.47 W .1 368.06 1333..=_;5 '-'=/. '"".=l':' ':~7 .~....,:, 44 14 1'"'-' . .:, ;~L). 01 1 .=, ........ 265.42 W 141,1..96 1374.40 274.40 W 1433.92 1394.83 89.0:3 N '.~) 1. '...]4 N ?:]:. 46 N ':,-.~5.68 N ...'--' 1 '..} . :37 W 71 . 19. hi 2:316 E 227. I 1 W 72.08 hi:,..-...'4 3E ~.=,4.,:,4 W 72.'=./::: N24 4.9E 24.2.58 W 7::-:. '.~:'(') N'.'.:.'5 34E 1464.86 1410.00 1486.86 1430.00 1508.86 1450.00 15:30.85 1470.00 o3 97 32.7? 34.61 36.43 N N N N 283.37 W 2'~/2.35 W :=:01.. 32 W 310.30 W .11455.87 1415.25 1477.83 14,35.68 1499.78 1456.11 1521.74 1476.53 '77.90 N 100.12 Iq 102.33 N 104.55 N · ::'~C) ::: 1 l,,I 74 '- ..... ' ~' ....... :,.:, N ..'.,:, 17 E 258.04 W 75.77 N27 OE 265~78 W 76.73 N27 47E 27:3.51 W 77.70 N28 22E 1552.85 1490.00 1574. ,:,.J'-'= 1510 .00 15'.-]6.84 1530.00 1618.84 1550.00 1640.84 1570.00 1662.84' 1590.00 . c .... 1610.00 1 -/,,~7:, :33 16:30.00 38.24. 40.06 4.~ .88 4:3.69 45.51 47.33 4'P. 15 50. '.96 N N N N N N N N :328.25 W 337.23 W o4.:,. 20 W '"==' 1 ;-]: W :-:.:/-',4. 16 W 373. 13 W 382. l 1 W 1543.6~ 14~6.~6 1565~64 1517.37 1587.60 1537.8.1 160~.55 1558.24 163;.30 1578.53 1653.24 !5~?.01 1675.17 161~.50 16~7.13 163~.~8 106.77 N 108. 'F~':] Iq 111.20 N 113.42 N 1'1.5.58 N I17.75 N 11'P, ?~2 N 122.08 N · .' ,:, 1. ..._ W 78 . ,_/', :::.. N 2 '.'.? 2 E 288. ':.78 W 7':.-/. 67 N2':9 40E 29./:,. 72 W 80.6::': Iq30 1C:E ':'04 z~ ':' 6'.T, "~ · _,, ~-._, W ,:., 1 . . N 30 E . 311. "7~',E: W 82.76 N:31 :3'PE 31.'~.54 W 8:3.85 N32 22E 327.10 W 84. '76 N3:3 :3E 334.66 W S6.08 h1:33 4-3E 1728.83 1650.00 1750.82 1670.00 1772.81 1690.00 1794.77 1710.00 52.78 54.60 56.44 5:~. ':' ~ N N N N 391.08 W 400.06 W 409. O1 W 417.87 W 1719.07 1660.47 1741.02 1680.96 ]762.95 1701.43 1784.6'P 1721.79 124,, 25 N 126.42 hi 1'-'"' .~c/ N .-',:, p _ . 1 :..:.:0.64 N :342.21 W :5:7.21 N:34 22E 34':.?. 77 W 8:3.36 N:35 OE 357.33 W 8'F/. 48 N35 37E 364.66 W 'F'O. 5.1- N:36 22E 1816.71 1730.00 1838.61 1750.00 1860.50 1770.00 1882.36 1790.00 6, 0.32 /.-,2.36 /=,4.47 66.65 426.66 W 435.37 W 444.00 W 452.55 W 18(.')6.56 1742. :32 1828.4.2 1762.82 1850.26 1783.:31 1872.07 1803.78 132.66 N 134.68 N 136.70 N 138.72 N :=:71. '75 W '? 1.5:3 N:37 6 E 379.24 W 72, 4.4 i",1:37 4.':?E :386.5:3 W 'F/:T.:. 2,/=', hi :..=: 8 :':: ]. E · '_--:~, . 'P 4.00 m N :,3'F.<, 1 ,1. E Whipstock Position on well A-16RD CALCt~LATION OF LEAST DISTANCE BETWEEN WELLS MD TVD NS Closest Pos:Ltion on well A-2 EW MD TVD NS EW Re f : S C) 7 0 ':..? '7 ,, ()UO Distance Direct Between Betwe.~ Wel 1 s Wel 1 s ~904.17 1810.(30 68.88 N 1726.00 1830.00 71.18 N 1747.77 185(3.00 73.56 N 1767.55 1870.00 75.?? N 4Al_ . (31W ;.873. .87 1824. ~'-'~'~,:. 46?.40 W 1915.64 1844.65 477.71W 1937.08 1864.82 485.?5 W 1958.77 1885.27 140.74 142.75 144.66 146.53 401.07 W 94.65 Ix13':.-~ 50E 408. :']:3 W 95.22 N40 415.34. W 95.74 N41 16E 422. :'::4 W 96. :71 N42 3E 1~91.30 1890.00 78.50 N 2013.02 1710.00 81.05 N 2034.72 1W30.00 83.68 N 2056.40 1750.00 86.38 N 494.10 W · ._,,_,::.,IR,_ W 510.18 W 518.10 W 1980.49 1905.75 2002.17 1926.18 2023:.83 1946.60 2045.47 1967.00 148.41 150.2::: 152. 15 154.02 N N Ixl N 429.34 W 96.59 N42 4'.--..'E 4:36. '-"-' . ..:, z. W 96.91 i',! 4:3:3.4 IE 4. 4 :'::. :':: 1 W 9'7.1:3 N.4. 4 _)..7~ I:F.. 450 29 W 9'7. '-"-' Ixl 4. 5 4. Ii::: . . . .~::. 2121. 2142. 06 70 32 1970.00 ~-,o c,.'.-. 14 N 1990.00 91.96 N 2010.00 '.--/4.83 N 2030.00 '~7.78 N 525.94 W 533.71W 541.4(3 W 549.01W 2067.0 ? 1 o,. ,_,_,:, 7. :]-: 8 2087.18:2006.36 2108.7:3 202/:,. 86 2130.75 2047.:35 155.89 157.59 159.30 161.01 N N N N 457. ~._,'-.'/- W 97. :2:4 N4.5 4.9E 4.6:3.60 W 97.42 N4.6 5:3E 469. ?'.'.? W 77.67 N47 5,'3E 476.37 W 97.86 1t4-8 58E 2164. 2186. 2207. 2229. 50 07 62 15 ? o F.O 00 1 (:3 o ~'' ' ....... oO N 2070.00 10:3.87 N 2090.00 107.00 N 2110.00 110.20 N 556.55 W 564.01W 571.37 W 578.70 W 2151.77 2067.82 2173.26 2088.2:3 2194.7:3 2.'108.71 2216. 19 212.'.-). t :3 162.72 164.4.3 166.1:3 167.84 N N N N 482.75 W 97.97 N50 OE 489. 12 W 98.03 I'-,151 3E 4'..7-~5.4.8 1,4 '.:.'8.0:3 N52 5E 501.85 W 97.95 N5:3 8iE 2250. 2272. 2293. 2315. 2336. 2358. '~:79. ~400. 67 17 66 05 52 O0 48 96 2130.00 113,47 N 2150.00 116.80 N 2170.00 120.19 N 2190.00 123.42 N 2210·00 126.84 N 2230. O0 130.2:6 N 2250.00 1 .... ._-,.:,. 6::_: N 2'270.00 137.10 N 585.?4 W 593.10 W 600.18 W 607.05 W 6!4.09 W 6'.-71. '14 W /-,'?P 1':' W 6:35.23 W 2237 /-":' 2.149. M4 · _, ._t 2257.02 *F.Z 1 ./:.8. 14 ':" 27 ::: :::".'? ':' :i o o /. '2299,68 2207. 1 ("3 2321.04 2229.60 · -.o41. 14 2248. '.;~4 2:362.47 22/_-,'.--.~. 50 2383.80 2290.07 169.54 171.00 172.59 174. 17 175.78 177.27 178.83 1:30.39 N N N N N N N hi 508.20 W 9'7.82 N54 12' 513.47 W 9',E:. 02 N 5 !5 4-6 E 519.2:.'.'!: W ?:E:. 22 N57 5E .... -'- 4 ';> 7 W ..... :2:8 I',l.~l :: , E .~ ,", -) ~=,- .... :, (.. 7:3 W 9. :::_./-_, ...,'--' N...., Y:35 E'_ =' '-' _ 99. ..... :., 6. A 1 W 07 N,./::, 1 .5 Ii:.: 541.45 W 9'.-7.70 N62 30E 546. E.',"F¢ W 100.40 hl6:3 54E '?42 ''"' 2443. 2486. 44 92 40 87 2290.00 140.52 N 2310.00 143.94 N oooO 00 147 F:6 N 2350.00 150.78 N 642.27 W 649.32 W 656.36 W 66:3.41W 2405.13 2310.64 2426.46 2331.20 2447 79 ?':'~1 77 . . .~..._.1 ._ · :.--_.'46'F~. 1 '2 2:372. :.3:3 181. '.-75 183.51 1 ':'.=; 06 18,./:,. 6:2 N N N N 552.32 W 101.16 N65 16E 557.76 W 101.97 N/_",6 38E · =56:::. 20 W 102.84 hi/:., 7 58 E .... :,,.-,_./- ..... ::: 1.4 10:':-.: .76 hi,_../-,'-? 17E 2508. ]-,':551. 2572. :2:5 83 31 79 2370.00 154.20 N 2390.00 157.62 N 2410.00 ]61.04 N 2430.00 164.46 N 670.45 W 677.50 W 684.54 W 691.57 W 248'.-T,'./_-, .9 2:2:. ~. 18 '"') ~ . . . · .,:..._ 1..'1. (*)o >-.' 4.1. 2 77 2.=,::-:'?. :]:.1. 24:33.37 · -, =' .='i '-, A2 245:3 97 1:38. 12. 189.6:3 I'F,' J. 14 19'2.65 N N N hi 5'7:3.86 W 104.75 N70 37E 579. 12 W 105.93 N71 .58E · _o4:38 W 1('17 17 N7:q 16E CALCULATION OF LEAST DISTANCE BETWEE:'N WISLLS Re ~: : S07097. ()Uti Positior, or, well A-16RD MD TVD NS Closest Posit,or, on u Jell A-:2 EW MD TVD NS Distance Direct - Betu~eer, Betwe.e~ F'i:W Wells Wells 2594.27 2615.75 2637.22 2658.70 2450.00 2470. O0 2 490.00 2.=, 10.00 167.88 N 171.30 N 174.72 N 178.14 N 698.63 W 705.68 W 7~2.72 W 719.77 W · %=, .9:=: ~._74 2474.56 '-'~¢~' 24. '-' "=~-]. ~._, :. c .... ..'. 4 :: ... 16 2617..~,F, -":,.=, 1R 75 2/-,38.86 2536.35 194.15 N 1~5.66 N 197.17 N 198.68 N 594.90 W 1 ("~'P. 79 N75 47 F 600. 15 W 111.18 Iq77 OE 605.41 W 11. 2.6-'.7: N'7 :=: 11 E 610..$7 W 1:1.4.10 hl79 20E:' 2680.18 2701.66 2723.14 2744.62 2530.00 2550. O0 2570.00 2590. O0 181.56 N 184.98 N 188.40 N 191.81N 726.81W 73:3.86 W 740.90 W 747.95 W 2658.80 2555.67 2680.08 2576.30 2701.36 2596.94 27:22.64 2617.57 20(_'~. 04 N 2 () 1.4.7 N 202.90 N 204.. :33 N ./::. 15.41 W i 15.8 () N:--':O :=:5E 620.40 W 117./:.2 N81 ~4. 4. E .:, ..- ....... W 119,4'P N 82 . E 6 :':: A :=,"T; W 1 '-' ~;,'9 .... ....... ~. 1,4-0 N 8:3 .....E. 2610. O0 2630. O0 2650.00 2670.00 195.23 N 198.65 N 202.07 N 205.49 N 754.99 W 762.04 W 769.08 W 776.1:3 W 2743.91 2638.20 2765.19 2658.84 97~:A 47 'o~70 47 '2805.3:3 2697.78 2'c'x~; 76 N 207.19 N 20C-.:. 62 N 209.87 N 635.3:!3 W 1 :-"3. :34 N84 5:']:E /=.40. :37 W 1'-'"'- ':"":' I',1:=', /-, ~:}E' ~:~.,.,I n ....!-,./ - - · 6-4.5. :=:6 W 127. :2:5 N:-=:6 58E 64,9.70 N 1:29.51 N88 OE · ~o~-~ 01 2873.49 2894.97 2916.45 2690. O0 2710. O0 2730.00 2750. O0 208.91N 212.33 N 215,75 N 219.17 N 783.17 W 790.22 W 797.26 W 804.31W 2P,'.~/-, .=,= '~' ,::,. 4./=, ........... ., ¢71"" :.2847.77 273'.':). 1. 4 O,-,z ,-o ~1'.-..~ '"')'7~°='Y ~' ~. ,.T, 0 C,.. . ~ -- .- ... ,":' 1 2890.22 27::30.4'P 211 1'=' N ':'1'=' .~¢') Iq 2.13. :B'2 N · .'lP; 1:3 N 654.29 W 1:32.00 N89 OE 658.88 W 134.53 hl:3'P 56E 6;.':.::::. 47 W 137.09 '.E;8':=; 10E 6 6 8 () A W 1 :=-: 9 .6 :=: '::":":' 181iii: 2937.92 2959.40 2980.88 3002.36 30c,:3. o4 :3045.32 :=:r-' ~:: 80 :_:;~ .... :~ 27 2770.00 2790. O0 2810. O0 2830. O0 2850.00 ':':='70 00 2 8 9 0.00 791 F) 00 222.59 N · -) .-) . ~..6. O1 N 229, 43 N 232.85 N 236.27 N 2:39.69 N 243.11N 246.53 N 8; 1.35 W 818.4{.'} W ,_--:25~ 44 W 8:32.49 W 837.53 W 846.58 W 853.62 W 860.67 W 2910. '"':' '-' '-' ' c' ,:,(.) .) (92 .-t ._, ~ . 2931.4.3 2820.72 2'.-.-;52.62 2841.4 ~ 2973.82 2:=:62. 10 3016.21 '.=-:90:=:..4.':T; 3037.4-1 2924. 18 .:, ....... :,, 6 C) 294-4 88 216.34. N 217./-,0 N 21 c., 87 '-'. N .::~.J. 1:..--.,' N '-"':'1 4.0 N ~..,:~ · -=,oo 6A N 223.93 N 22F,. 19 N /=,72.26 W 142.43 S87 26E 676.67 W 145.2 ,:!:, :.'.:.;86:36 E /=, 81.08 W :L 4. 8. 11 f:; 85 4'P E /- ':'.~ 4. 9 W 151 0 r) '-'"'"'"" . . .:,,::,.J 689.90 W 15:3.90 S84 19E 694.31 W 156 · 8:3 F: :3 :3 :3 7 E: 698.72 W 159.78 S82 5~:,E 70:2:. 1:3 W 162.76 S82 17E=. 3109.75 3131.2:3 3152.71 3174.19 2?30.00 2950.00 2970. O0 2'P ? 0.00 24'.-?. 95 N .4._,._,.._ 7 N 256.7'.--.; N 260.21 N 867.71W 874.76 W 881.80 W 888.85 W :2:079.8 C) %7965.57 3101.36 29:=:6.61 31 '22.56:3007.3 C) :B 14:3.76 :B 027. 'P9 2'7..'6.4-5 N 227· 75 Iq '"':; ('):=', N 2:30.31 N 707.54- W 165.75 S:=-.: 1 :39 E 7].2.06 W 168.7:2 S81 3E 7.1/- .... =~2 W ]. 71 · 7 C) 'S:30 2:3E: 720.97 W 174.70 .S7'F; 54E 3195.67 3217.14 3238.62 '~'~ (-. i-.~6~) lC) 3010.0C) 3030.00 3050.00 3070.00 267.05 Iq 270.47 N ~.7.3. o,.~ 895.89 W '.;~02.94 W 9(39, 98 W 917.03 W :-=: 164.96:3048.6C-: 31 :=-:6.56 30/::.'P. 75 :B207.77 .309 C). 4. 4 :3228.98 3111.12 2:31.58 Iq 2:;32.89 hi 234. 18 N 2:35.47 Iq · -'M. S79 7z._ 4:3 W :L77.71 21E 729.98 W 180.72 S7:3 50E 7:B4.48 W 183.72 S78 19E 7;~-~H_'-: OW. _186.7:3 :~;7'7, 47E LL_ Whipstock UAI.L:LII_AT I ON OF LEAST D I.:,]'-' "ANP_.E.- BETWEEN WF. LLS Position c,n well A-16RD Cl,:,sest ~,:,sition on u~ell A-2 MD TV[; his EW MD TVD NS EW 3281.58 3090.00 3303.06 3110.00 3324.54 3130.00 3346.02 3150.00 277.31 N 280.73 N -..._,4.1 ~ N · --,..7,57 N 924.07 W 931.12 W 938.16 W 945,21W 3250.19 3131,8~ 3274.74 3155.74 3296.00 3176.39 3317.27 3197.05 236.76 N 238.28 N 239.71 N 241.15 N R ~.-', .1:: : S 07 ()'P 7.0 I...I i} D i s t a. n c e D i r.e c i Be rupee n Be Wel 1 s Wel 1 s 743.48 W 189.75 5;77 21E 748.75 W 192.75 S76 54-E, 753.59 W 195.43 S76 28E 758.44 W 198.12 S76 3E Eastman CAI_CULATION OF LEAST E Io=,TANL, E BETWEEN WELLS R e f: : 'F; C) 709 :=:. 0 LIO Position ,',n well A-16RD MD TVD NS Closest Positic, r, on u Jell A-8 EW MD TVO NR EW D i s t a. n c e D i r- e c t BettCeer, BettCe~ Wel 1 s Wel 1 s 1199.80 1222.13 1244.41 1266.62 1170.00 11~0.00 1210.00 1230.00 13.19 N 13.82 N 14.6:$: N !5.75 N 172.45 W 1190.86 1168.59 182.38 W 1213.14 1188.67 192~15 W 1235.34 1208.73 201.75 W 1257.90 1228.87 C~.47 ':' 1.47 S 2.47 S .~.. 'P.~, S 1288.77 1310.84 1332.88 1354.88 1 250. 1270. 1290. 1310. 00 O0 O0 O0 17.02 N 18.42 N 20.08 N 21.89 N 211.18 W 1279.97 1248.6J 220.41W 1301.96 1268.24 229.51 W lO.=,o,:,,:, o,:, ...... ~ .... ~ .... 1~o7.81 238.49 W 1345.65 1:307.15 3.3'P 3.82 4,25 4.68 S S S 1 ~7/'''/87 1:3 ,,; 87 1420.87 1442 ':'/- 1:330. .=i._ .) 1370. 1 .-"=: o (') 0C) 00 00 00 23.71N 25.52 N 27.34 N :79.16 N '-' . .:,,:.6.50 247.47 W 1.:,67 49 1'-''~' · =, ,=, ,='/ '='~/- 44 W 1 .......... :'=::3 1 .'.3 45 ':'.~ ~ ... #.~. · · I..I ._ 2/-,.~.42 W 14:11 17 1.:,6._ 20 274.40 W 14:32.91 1:3:=:4.4:3 5, 1:3 5.57 /:'.. ~ O1 6.45 S S '-'='"' '--.* 1 W "-"'=.¢ = = ,:...., .-. ........... , '.=; 1. ¢) 41 W 2 ./=,:_=: 02 W '::'":' ' -=' ...... ~.. (.)._, S 11 57 W 273.14 W :34.57 !-713 2W 283.28 W :37.12 S14, OW 1464.86 1486.86 1508.86 15:30.85 1410. 1430. 1450. 1470. 00 O0 00 00 3C). 97 N 32.79 N 34.61 N :36.43 N '-":"='..,_,._,. 37 W 14..,4 .74 14¢)2~ 68. _ 292.35 W 1476.57 1422.9:3 "c 32 · :: .) 1 W 1 49:B 29 1. 44:2. 1 ':' . # - . ,...i 310. :30 W 1521.10 1462.20 6.90 7.35 7,8C) '" 20 ,=. .,-]; S , .£,';/. -_., ._ :---:(')::: 84 W 4.2 '-' ':-"' ':' _ ...... :,...., .... 1/-, 0 W :314. 12 W 4.4.98 '.=_:; 1/::, 4. 7W .-., .-, , ,;:, ..' · =, ..::: 4 '-"-' W 47.57 S .1. ,_,':' C)_ W 1552.85 1574.85 1596.84 1618.84 1640.84 1662.84 1 ~.83 1490. 1510. 1530. 1550. 1570. 1590· 161.0. 1630. 00 O0 00 00 O0 O0 00 0C) :3:3.24 N 40.06 N 41.88 N 43, 69 N 45.51 N 47 '="~: N n ..i 49.15 N 319.28 W 1542.97 1481..4.7 328.25 W 1564.84 I500.7:13 ::-::37 .... . . ..... ,,:,./=, P; 9 ';)'..-'~ · .'.-', W 1='-' 71 1..1 ... 34./".. 20 W 1/=,O'P..5:7 1540. :.3'F/ 355.18 W I631.77 1559.69 364.16 W 1653.68 1578.'P8 37:3 1 :':: W 1675 ':":' 5 q,':' 4':.=" a . ,-.~ 1 ._ .. ,=,. :382.11 W 1697.7:3 1617.79 8,. 20 8. '-,C ':' 2C) 7.76 6./:,7 6.0,5 5.42 1728.83 1750.82 1772·81 1794.77 1650. 1670. 16.90. 1710· O0 O0 00 O0 52.78 N 54.60 N 56.44 N ="-' :35 391.08 W 1719.9(') 16:37.28 400. (36 W 1741.81 1656.4:=: 409. C) 1 W 1763.70 1675./_..,C-: 417. :37 W 17:35..56 16'P4. :34 4.69 3. :36 :=:. 03 '2. '21 S 418.87 W 65.09 S25 48W 4:;.29. :38 W 66.7:3 S26 38W 4:3'P. :--:7 W 6:B. 5:2 S27 26W 45C).:35 W 70.:37 S28 12W 1816.71 1838.61 186C).50 1882.36 1730. 1750. 1770. 1790. 00 O0 00 O0 60.32 N 62. o/. N 64.47 N /=,6.65 N 426.6,6 W 1807.38 171:=:.97 4:35.37 W 1:329.29 173:3.15 44.4,00 W 1851.04 1752.17 452.55 W 1872.75 1771.16 1.3'P 0.49 0,43 . .,~1 ._1 .,.i S N N 4/=,('). 82 W 72. :3 :=: S28 58W 471.38 W 74. :37 S :2: '? 4'? W 4. 81. :B 9 14 7 6,. 5'.--" ',B :30:37 W Whipstock l /. CALCIJLATION OF LEA.:.,] DISTANCE BETWEEN WEI_.LS R e -F : S07098.0tI0 Positi,-,r, on well A-t6RD MD TVD N8 Cl,:,sest P,:,siti,:,r, ,:,ri.well A-8 EW MO TVO NS IS.W D i s t a n c e D i r'. e ,-. t' Between Betwee~ Wel 1 s Wel 1 s 1904. 1926. 1947. 1969. O0 79 55 1810. O0 1830. O0 1850.00 1870.00 68.88 N 71.18 N 73.56 N 75.9? N 461.01 W 1894.43 1790.12 469.40 W 1916.£)7 1809.05 477.71 W 1937.68 1827.95 ~'-' = 9 ~ W 19.~l 9 ~._, 1 .'-, 46. :31 ~ ,7~, ...' m ....... · 27 N ':' 18 N 4.09 N 5. C) 1' N '-' :E:W R C)"..' ,_-,4 W 81 1:3 "-"--"-' 5 i:Z.:. 29 W :3:3.60 S:3:2 50W 52:3.7:2: W :36.19 S:3:3 :]:~ W 5:.--;4. 15 W 8:3.8:3 S:34 11W 1991. 2013. 2034. 2056. .30 02 72 40 1890. O0 1910.00 1930.00 1950. O0 78.50 N :91.05 N 83.68 N 86.38 N 494.10 W 1980.79 1865.65 502.1:3 W 2002.29 1884.4.5 510.18 W 2023.75 190:3.2:3 518.10 W 2045.54 1922.2:_--: 5.92 N 6.82 N 7.73 N 8.70 hi '207~. 20'. 2121. '2142. 06 70 32 92 1 '.=;70.00 1990.00 2010.00 2030. O0 89.14 N 91.96 N 94.83 N 97,78 N 525~94 W 2066,,94 1941.00 5:33.71W 2088.31 1959.70 541.40 W 2109.65 1978.36 549.01 W 2130.95 1996.99 9.70 N 10.69 N 11.68 N 12.67 N 5:.'.-'.:6.15 W 10:3.81 S?!:7 9W 596.4.6 W 107.05 S37 4.0W 606.76 W 110.39 S:3:3 10W 617.04 W 1 J. 3. :L::5 S:3:3 38W 2164. 2186. 2207. 2229. 50 07 62 II 5 2050.00 2070.00 2090.00 21 10.00 100.80 N 103.87 N 107.00 N 110.20 N 556.55 W 2152.22 2015.59 564.01W '217:3.:37 20:34.52 571.39 W 2195.08 2053.£)7 578.70 W 2216.26 2071.60 13.6./:, N 14.73 Iq 15.80 N 16.87 N 627..30 W 117.40 :339 4W . . . '--' .-~ 6:37 7-4- bi 121 00 S:.:3'.~ ..: ..... W 647.96 W 1'.-]4.6'7 S40 C)W 658. 18 W 128.46 S40 25W 2250. 2272. 2293. 2315· 2336. 67 17 66 05 52 00 4:=: 96 2130. O0 2150. O0 2170. O0 2190.00 " 10.00 2%o0 C)C) 2 '250.00 2270.00 113.47 N 116.80 N 120.19 N 123.42 N 126. :34 N 130.26 N 133.6:E: N 137. 10 N 585.94 W 2237.40 209C). 09 593.10 W 2258.51 2108. 600.1 :z: W 2:,--'.'7'?. 59 2 .!. 26. '.-T;9 /_-,07.05 W 2299.96 '214.4.76 61.4.09 W 2321.00 2163.09 621.14 W 2342.04 21F.:1..4:3 628, 18 W 2363.0:.:.: 2:1 ..9'F;. 7/-, ::,..:,...,. 2:3 W 2:3:34. 1,_'-':'.,..'--' .- © 1 ,_,':'. 1 C) 17.95 N 19.02 N 20. C) 8 N '21. :L '2 !',i 2'.7.2..: 0 N 23.28 N 2,'-I.. :36 N 25.44 N 668..".::7 W 1:3:2. :34 S 4. 0 4. :..3 N 678.55 W 1:36.31 S41 9H 688.71. W 14-0.:39 'S41 29W 69:3./-, :2 W 14, 4.56 ::.'.'; 4 :t "",:~) ! 70 :.3.88 W 14 :!3,78 S 4-2 10 W . -- ..., .... ,Z' ~. "} 719. 15 W 1 ~"-'. c)O .... t. ~- 72. 9.41 W 157.2:.3 '...=.;42 4:3W 7.'3'F/. 68 W 16 ].. 4-7 ::;4-:3 5H 2422. 2443. 2465. 2486. 44 92 40 87 2290.00 2310. O0 2330.00 2350. O0 140.52 N 143.94 N 147.36 N 15C).78 N 642.27 14 2405.16 2:236.4:3 649.32 W 2426.2o 2254.77 656..36 W 24.46.23 2272.1 ./.-, 66:_--:. 41 W 2467. :,..74 2290. :}8 26.52 N 27.60 N 28.64 N 2'?. 7:3 N 74'?. 94 W 1 ;:: 5.70 S-4. :3 2 >7 N 76C). 20 W 16'P. '!:";..5 ::;4.::: 770.08 W 174.28 '.E;4 :':: 4/",W 7:30.49 W 17:3./_..,5 :i':; 4. 4. :3 W 2508. 2529. 2551. 2572. :'::5 8:3 31 79 2370.00 ';-':3'~0.00 2410.00 2430. O0 154 ~. 20 N Il 57.62 N 161.. 04 N 164.46 N 670.45 W 2488.°F, 2:30:-': 677.50 W 2509.26 23'26. :31 6:F:4.54 W 25:30.27 2:345. C):F.: 691.5'.-} W 2551. ?8 236.'3.25 30. :--:2 N 31.92 N 33.0.1 N :34.11 Iq 790. '? (') W 1 :-2::3 ,. 0:3 S 4- 4 19 W 801.:31 W 1:37.4.'1. S44:34. W F'11.71 W 191 7'? S44. 4'?W 82--2-rt-L~.~' ~ _1 '? 6. 1:3 :F;~ .5 2 W i/ I t::ast n _ LL:L= : Whipstock21) CAI._CLil..ATION OF LEAST DISTANCE BETWEEN W [:7'. L L'.:~ ReF Position on well A-16RD MD TVD NS zl.-¢D Closest Positi,:,r, ,:,n well A-i'-'- EW MD TVD N~$; EW Distmnce Dir. ect' Between Betwee~ Wel '1 s Wel 1 s 1199.80 1170.00 1222.13 1190.00 1244.41 1210.00 1266.62 1230.00 13.19 N 172,45 W 1211.77 1202,08 32.45 N 13,82 N 182.38 W 1234.04 1223.07 3:3.81 hi 14.68 N 192.15 W 1256.07 1244.0:2 35.17 N 15.75 N 201.75 W 1282.12 1268..52 36.99 N 67.77 W 111.16 N79 34E 74.4.6 W 114.6:3 N79 31E 81.13 W 117.?] N79 33E 87.76 W 120.32 h17~ 16E 1288.77 1250.00 1310.84 1270.00 1332.88 12~0.00 1354.88 1310.00 17.02 N ..-~. 42 N · -.. (- ~') ~'-o ~. ). ,. ,:, N ~°.11. 1~' Wo 1304 .16 1'-'~''--~o .. . 2:2 220.4-1 W 1326.15 1309.86 2.29.51 W 1:2:48.11 1330.48 238.49 W 1371.72 1352.55 38.57 N 40.14 Iq 4.~.71N 43.51N 97 1::: W 1'-"-' . ~. 4-7 N79 1SE '104 ='"" 24 4. .... ,,:, W 1 . 1 N79:2: :3E 111.97 W .1. :26.1 ? I',17':::' 4. E 120. 15 W 127.60 N 7':."~ --,.:: 9 E l O~,,. :--:7 1330.00 ,:, ~ 1 .-....- 87 I..:,...,.,. 00 1420.87 1:370.00 1442.86 1390.00 23.71N 247.47 W 1393.67 1373.05 25.52 N 256.44 W 1415.62 1393.1:~4 27.34 N 265.42 W 1437.57 1414.04 29.16 N 274.40 W 1461.65 1436.41 45.21 N 46.91 48.6.1 N 50.63 Iq 127.83 W 128.95 N79 49E 1 ':'?] =' ........... .1 W 1:3 0. '" (' ~'"'" ,:, ..) Ixl7'F~ ._ ,::,E 14.:3. 19 W 1 ::: 1,65 hi8 0 8 E 151,85 W 1:32.7:3 N::30 4E 1464.86 14.10.00 1486.86 1430.00 1508.86 1450.00 1530.85 1470.00 30.97 N 32.79 N 34.61N 36.43 N 283.37 W 1483.62 1456.76 2~2.35 W 1505.60 1477.12 301.32 W 1527.57 1497.47 310.30 W 1553.88 1521.66 52.57 N 54.50 Iq 56.4:3 N 58.93 Iq 159-]. 90 W 133.78 N 80 5 [: 167.95 W 134.78 hlSO 6E 176.00 W 1:35.78 N80 7F 186.03 W 136.44 N7'F~ 44E 1552.85 1490.00 1574.85 1510.00 1596.84 1530,00 1618.84 1550, 00 1640.84 1570.00 1662.84 1590.00 I '~4.:--:3 1610.00 I ,:~6. '-'" '" (' , ,:,._-~ 16.::.) OC) 38.24 N 40.06 hi 41.88 N 43.69 N 45.51 N 47.33 N 49.15 N 50.96 N · 3] 9.28 W 328.25 W 337.23 W 346. '..20 W 355. 18 W 364.16 W · ]:73.13 W '-~:=:'--' I i W 1575.87 1541.7.1 1597.87 1561.76 !619.86 1581.81 1646.64 1606.02 1668.62 1625.66 16:~0.59 1645. :30 1712.57 1664.95 1737.2:3 1686.88 61.20 N 63.46 N 6.5.72 N 6:3.67 hi 7.1.3C) N 7:3.93 N 76.56 N 79.65 Iq 194.78 W 136.75 N79 3:F.:E 20:3.52 W 137.05 N77 2:3E 212.27 W 137..'_::6 N79 12E 223.....,":' 1 W 1:37 .. '"''.::,._, '= N 78 '")1 IF.: 232.8(.") N 136. :39 1',178 ./:,E 242. '2'P W 1:36,4. 5 N 7'7 41 IS: 251.78 W 1 :".:6. 262.62 ~,,J 135.41 N76:30E 1728.83 1650.00 1750.82 1670.00 1772.81 1690.00 17~4.77 1710.00 52.78 N 54.60 N 56.44 N 58.35 N 391.08 W 400.06 W 409,01W 417.87 W ~759.17 1706.23 1781.11 1725.58 1803.04 1744.92 1824.42 1763.78 82.59 N 85.52 N 88.4./:. N 91.3:3 I",1 272.5::: W 1 :..:4. ~=; N7~ F,'-' 2:--_-:2.45 W 1:3:3.71 N75 16E :292.36 W 132.85 N74. :39E 302. (')'-:' W 1 .'2...: 1.9':.,' N 74 7 E 1816.71 1730.00 1838.61 1750.00 1860.50 1770.00 1882.36 1790.00 60 ':':'-' N 62.36 N 64.47 N 66.65 N 426.66. W 435.37 W 444,00 W 452.55 W 1846.30 1783.10 1868.15 1802.39 1889.97 1821.66 1911.76 184C).70 94.33 N 97.33 hi 100.32 N 103.32 hi :2:11.84 W 1:3 c). 9'P N 7:2: :2:0 E :2:21./- .... .~ W 1 :.7: (:). (") (-) N 72 ._ ._ ~'-7 F- .]::31 4-~ W 1 ":":' o..:, , _ ,-. ........ .~ N72 2C)E ast// ' ' CAI..CI...ILATION OF LEAST D I STANCE BETWEEN WELL'.--'; Re~ : SC)7C)'=7,".:..'. 01..I0 Pc, sitic, n ,:,n well A-I6RD MD TVD NS Clc, sest P,::,siti,:,r, ,:,n ,~ell A-12RD EW MD TVD NS EW I_"l i s t a n c 6, D i r e c t' Between Betwee~ We 11 s We 11 s 1904.19 1926.00 1947.79 1967.55 1810.00 1830.00 1850.00 1870.00 68.88 N 71.18 N 73.56 N 75.99 N 461.01 W 1933.89 1860.36 106.52 N 469.40 W 1955.61 1879.45 109.73 N 477.71W 1977.31 1898.52 112.93 N 485.95 W 1998.99 1917.57 116.12 N 351.25 W 126.50 N71 4E 361.ll W 1~5.14 N70 25E 370.95 W 123.70 N69 45E 380.79 W 122.20 N6'? 7E 1991.30 2034.72 2056.40 1890.00 1910.00 1930.00 1 '.PSO. O0 78.50 N 81.05 N 83.68 N 86.38 N 494.10 W 2022.34 1937.94 119.82 N 502.18 W 2043.88 1956.54 123.53 N 510.18 'W 206,5.40 1975. I3 127.24 N 518.10 W 2086.89 1993.69 130.94 N :'=:':;' 1 F,'=.,, W 120.4-'=' N 6, 8 :3 E -- . # ... 401.7 :=: W 118.5:2: N 6,'7 4. E 4- :11.97 W 116.5:'3 N6~: -"~.,F; .--/..._ 422. 14- bl 114.47 N65--· 5E 207°.,~ 06 · -' 3' .J 70 21 '"' i ":-"-' 2142, 92 1970, 00 1 ¢-' .90 ' 00 2 010, 00 .,:::(.)._ 0 O0 89.14 N 91.96 N 94.83 N 97.78 N 525.94 W 2109~:2:2 2013.0:3 134.87 N 533.71 W 2130.70 2(331.2:3 138.:36 N 541.4.0 W 2152.04 204'?.50 142.84. N 549.01 W 2173.37 2067.71 146.82 N 4-32.8 ] W 11. 2.32 N,'.'::,3 51E 44.3.20 W 109.98 N62:36E 4. :5.. :::_, .~._,.,':' W 107.60 N ./:, 1 20 E 4/=,3. ?5 W 105. 18 N/=-,O 2E 2164.50 2186.07 2207.62 2229.15 2050.00 2070.00 2090.00 2110.00 100.80 N 556~55 W 2194.67 2085.90 150.79 N 103.87 N 564.01W 2218.14 2105.74 155.01N 107.00 N 571.39 W 2239.32 212:3.62 158.79 N 11(].20 N 578.70 W 2260.47 2141.49 162.57 N 474.30 W 102.73 N58 42E 486. 10 W 99.81 N56 4:3E 496.7'.P W 96.85 N55 14E 507.46 W 93.86 N5:3 41E 2250.67 2272.17 2293.66 2315.05 23:36.52 2358.00 2~..~.48 2130.00 2150.00 2170.00 2190. O0 2210.00 2230.00 2250.00 2970 Cx} 113.47 N 116.80 N 120.19 N 123.42 N 126.84 N 1o' ?A ._,0. N 133.68 N 137.10 N 585.94 W 2281.6,0 2159. :33 1/=,/=,. 35 N 593.10 W 2306.09 2179.73 170.71 N 600.18 W 232/:,.94 2196.81 174.40 N 607.05 W 2:347.64 2213.77 178.07 N 614.0'.-} W 2368.48 223£). :33 181.76 N 621.14 W 2:--:89.32 224.7.90 185.46 hi 628.18 W 2410. 15 226,4.. 9./-, 189. 15 N 635. '.23 W 2430.9'? 22:.:.,'2.02 1'72.84 N 5 ] 8. 1 :':: W 90.86 N52 :"::E 530.94 W 87.4.9 N4.'F,' 4. E .M '-' .... .cE · _ 4.,::.. 31 W u :3.7 .1 N 46 ~'-' .~ 5'-' 6. C) W :::(3 ' '= '~E.:. ...... O., 1',14 ~'= / 5/=,4.. 96, W 76.5::: N4.1. 4'PE 57/=,. 33 W 7 :=:. 31 N 3'F-' 4 E 587.6,9 gl 7 C). 2. 8 N 3/.-, :=: IZ 599. C) 6, W ./-, 7.5:3 N 33 (:) Er 2422.44- 2443.92 2465.40 2486.87 2290.0C) 2310. O0 "', '--"=' C) C) C) ....., ._, ... 2350.00 140.52: N 6,42.27 W 2452.78 2299.6,6 196.79 N 143.'74 N 6,49.32 W 2473.27 2:315.69 200.73 N 147.36 N 656.36 W 24.93.75 2331.72 204.67 N 1 .~(') 78 N /-,/-,:~ 4-1 W '-' 514.2':' _ ........ · .' ._, 2:347.75 208./-, 1 N 6,11 2 ] W .:,..., ()(') N 2::=: 54. E 6, 2 :=:, :'=.: 4 W 62.71 N'24:35 E 6:35.4. 6 W 61. C):3 bi 2 C) 2 E 647.5'? W 60.0C) N15 1:3E 2508.35 2529.83 2551.3] 2572.79 2370.00 23?0. O0 241 C). 00 2430. O0 154.20 N 157 ~ 62 N 16]. 04 N 164.46 N 670, 45 W ..-._,.:,4'-'='"'. 72 236:3. 7:_--:'=.'.1.2. 55 N 6,77.50 W 2554. '76 ;7:=:7'?./:,5 2 ]. 6.5(.") N 684.54 W 2575.4:=: 2:F:'.--.~5.7/:, 22. C). 5:3 N 6'?1 59 W 2596 00 2411 :'37 224 hi 6,..59, 72 W 59.4, 6 1'4 .1 C) 25 E 671../::,4 W 6C).07 N 5 41E /=,:=::'::. 6, 8 W 6 .1.. 17 N 0 50 E /-,'- .- '.-'. /-. 2 9 · ' astm-a . / Whtpstock 2_/_ ) CALCUI_ATION OF LEAST DISTANCE BETWEEN WELLS R e ~: : S 0709'P. 0 I_.!1.-..i Position on well A-16RD MD TVD his Closest e,:,sition on well A-12RD EW MD TVD NS EW Dista. nce Directi Between Betweer Wells Wells 2594.27 2450.0£) 167.88 N 2615.75 2470.00 171.30 N 2637.22 2490.£)0 174.72 N 2658.70 2510.00 178.~4 N 698.63 W 705.68 W 712.72 W 719.77 W 2616.51 2427.~8 2637.(}:3 2444.09 2657.55 2460.2] 2678.07 2476.32 228.59 N :-232.6:.2 N 23/..'). 65 N 24.0.68 N 707.77 W 65.:-22 N 8:33W 719.81 W 6:::. 05 I',1 l 3 OW 731.85 W 71.:34 N17 lOW 74:3.90 W 75.02 N'.'..!: 1 6W ~'.~. o¢,. 1C-: . ~o ..... 18 c'5F:0.00 I 56 N 2701.66 2550.00 184.98 bi 2723.14 2570.00 1:::8.40 N 2744.62 2590.00 191.81 N 726.81W 73:3.86 W 740.90 W 747.95 W 26~8.58 2492.43 271~.10 2508.54 274.3.20 2:527.78 27~4.02 2544.78 244.70 N 755.94 W 79.05 N24 46W .-, (-, . . . . Iq ..:,:, 1 OW ... 4,.-:.,. 72, N 767 99 W :.3:3:3/:, ""'-' · ':"~i':' ":"::' I',! 781 7:1 W o . ,_, 7 '-]':'~ N :32 ',1 ~ i...Il .~1 I...I . . '-- .' ... 7; ..:, 07 W . 1.48 1',1:7:: 4:34W /_ · .'...7.'-'?] 29 N ':)"", '.7~ "~766 10 2610 00 1¢~.=, '-"--: N 1; ,'",. :,._, N .Z7,:,7.57 26:30 00 q'-' Z. = 2809.£)5 2650.00 202.07 N 2830.53 2670.00 205.49 N 754.9~ W 762.04 W 769.08 W 776.13 W ~-' .. ....... 1 78 2784. ,:,4 '-.,.=iz- . '-'"'")= ./:,/-, .~.._,7o. 79 ~ ,2, ',. ...I ~ . _ '%' ~ 282'6.4'FY 2595.79 · 9.-::350.12 2615.4-8 '-"/", 1 20 N 265. 12 N 269.03 N 27:_--:. 38 N 804.43 W 95.5 ] N:3./:, 5.1. W 815.79 W 'P 9.65 hi:38 5 L--.-: W I-, "], . -- u '- '.- ~ W c, ~. 7. 16 W 1 C)::: 9 0 N 4 () ":; "- 8:2,'P. 46 W 107./:,7 N4:3 ()W · .~o~o 01 2690 0C) '-'c)~.9 ~ ....~. . ~__, 1 N 2873.49 2710.00 212.33 N 2894.97 2730.00 215.75 N 2916.45 2750.00 2l~.17 N 783. 17 W 790.22 W 797.26 W 804.31 W 2871.09 2632.97 .-.,,-,,--~ o 0/','-' = ' . _ ~/:,...,L) 46 · ' ,~m .. ~. . 2S~ 1:3. C)4 266'7.95 2934.01 2685.44 277.25 N 281.11N 284 ~.z. 288.84 N :--:50.38 W 111.53 IH 4.4 3 ] IAI 8./:, 1. '.-79 W 1 ].._,'=. 4.4 i',14!=~_ '=._,/'.:.W 872.20 W 119.4.0 N47 1,SW :::8:3. 11 W 12:.3.4:2 N4.8 3 ]. IAI 2937.92 2770.00 222.59 N 2959.40 2790.00 226.01N 2980.88 2810.00 229.43 N 3002.36 2830.00 232~85 N 3023.84 2850.00 236.27 N :3045.32 2870.00 239.69 hi 3066.80 28~0.00 243.11N 3088.27 2910.00 246.53 N 811.35 W 818.40 W 825.44 W 832.49 W 8:39.53 W 846.58 W 853.62 W 860.67 W <,,:~.=iz~ ,~,--, 2702. ~_......], .. %..~ . -- 2975.96 272(:). 42 2996.93 2737.?1 3017.90 2755.4.0 3040.23 2774. 15 3061.26 2791.81 '-'¢'-"-' 29 '-"-"" · " ,:,0 :? 47 .-', .),i, -&. . . '-~ '--' '-" 7 31 (')3. :--: 1 ........ 1. 3 · 2'P2.71 N 296.57 hi :2:()0.4-3 hi 304, :30 Iq :308,44. N :312..35 Iq :316. '25 N :320.1.5 I'q 894.02 W 127.47 N49 42H 'PO4.93 W 1:31.56 1',150 4.'PW 915.85 W 135.6'P N51 51W · l=-' .-i ~ ~ 'P:.--'6, 7/-, W 1 :::9 '::'~ N.-, ..'-): W ..... u ,_l ... . ?:3:::. 15 W 14:3.83 N 53 4- 8W 'P48.87 W 147.84. N54 37W 759.6(') W 151. :::7 N55 23W 'P70. :"-:2 W 155. 'P3 N56 7W :3109.75 2930.0C) 249.95 N 3131.23 2950.00 253.37 N 3152.71 2970.0o 256.79 N · _.'~' 17 4 . 1 .r~, 2 9 9 0 . O. 0 __'.-,/-. C)_. ,_'.-, 1 N 867.71 W 874.76 W 881.80 W 8'.z::z: ,:,.=, W # ,.., -_ 3124.34. 2844.78 3145.36 2862.44 :3166.39 2880.10 3187.41 '28?7.76 324.06 N :327.96 hi 331.86 N ':":'~ 77 ._~._,._. 981.05 W 159.99 hl56 4.9W 991.77 W 164.08 N57 29W 1002.50 14 16,8. 18 NSE: 7W 1 (]) 1:3.22 W 172. :30 N5:]-: 4.:3W 3195.67 3217.14 · --,'-, o o 62 3260. 10 3010.00 263.63 N 3030.00 267.05 N 3050.00 270.47 N 3070.00 27:B.8~ N 895.89 W 902.94 W ~09.98 W 917.03 W 32 O'P. 08 2'? 15. ? 6 323 (-). 13 2'P :3:3.6, 9 325I. 17 2'.;~51.4.1 :3272.~..-'-"-' ~_.':"TM. 9_. . 14 339.80 N 34.3.77 N 347.74 iq :351.72 I',! 1024.26 W 176.42 N57 l'PI9 1034.89 W 18(3.4-8 N5'? 50W 1 (-_)45.52 W 184.56 N60 i'?W 1 c) ~6~-{4-] ~W .188.64 .... 1~ 4, 7 W MD Position on TVD 328~.~8 30~0.00 3303.0~ 3~0.00 CALCULATIOIq OF LEAST DISTAIqCE BETWEEN WELLS well A-16RD NS Closest Position on wel-1 A-12RD EW MD TVD NS EW 277 °1 N 280.73 N S~24.07 W 32S~3.27 2'~86.87 355.69 N :~31.12 W 3314.32 3004.5'.~ 35S~. 67 N R e f : S 070'.-';'~ '~). 0 U 0 Dist.m. nce Dir-ec~' Between Betwe~ Wel 1 ~ Wel 1 s 10./:.6.78 W 1S~2.73 N61 13~. 1077.41 W 1'P6.83 N61 Eastman Whipstock CALCI. ILATION OF LEAST DISTAIqIZ:F.. BETWEEN WELL..:.--.; Re -F : :BO 71 (')('), 7Ul.'] Position on well A-16RD MD TVD NS EW MO Closest P,:,sitior, on well A-12RD TVD NS EW D i s t a r, c e D i r. e c t Bet.Joe. BettCee W e 11 s We 11 s 11.99.80 1170.00 13.19 N 1222.13 1190.00 13.82 N 1244.41 1210.00 14.68 N 1266.62 1230.00 15.75 N 172.45 W 1208.59 1199.52 182.38 W 1230.82 1221.04 192.1.5 W 1252.63 1242.14 201.75 W 1275.83 1264.52 39.84 N 39.89 hi 39.70 N :,T.-:9.88 N 58.62 W 120.57 N76 49E 64.2:3 W 124-.91 N77 34E 69.73 W 129.01 N78 27E 75.8:3 W 132.78 N79 9E 1288.77 1250.00 17.02 N 1310.84 1270.00 18.42 N 1332.88 1290.00 20.08 N 1354.88 1310.00 21.89 N 40.24 N 4.0.54 .N 40 '--"--' 4!. 12 N '-'":' ~-'-' :-":5 ,, ,= ..... . ._,,.-., W 1 8.6 N 79 41 E 9(3 24 W '--' '=' '-' '= 1 ........ 1'480 21 E . # . ,..~ ,_$ 96. L=:'.:'.; W 140.68 N :-]: ]. '"'~ E 1 ()3.53 W 14.2.91 N81 -"- .... --~,-tE ...... O. 00 '-"-'. 71 N ¥-,/o. 87 1 ":"~ ' z...:, '-?'-' '~'-~ .~2 N /d :: o P, 7 13.~0. O0 1420.87 137(:). C)0 27.3:4 N 1442. '-'/ . . ,=,~ 1:B90 00 29.16 N 247.47 W 256.44 W 265,.42 W 274.40 W 1401.20 1383~36 1423.11 1403.67 1445.02 1423.98 14.66.93 1444.29 4.1.19 N 41. 19 I',I 4). I? N 41.19 lq 115.40 W 143.51 N82 28E 12 3.61 W 144. I ...' N,'",._-, 16 E i31.81. W 144.76 N84. 5E 140.02 W 145.43 1'4:.:.'!:4 53E 1464.86 1410.00 30.97 N 1486.86 1430.00 32.79 N 1508.86 1450.00 34.61N 1530.85 1470.00 :}6.43 N 283.37 W 292.35 W 301.32 W 3t0.30 W 1499.59 1473.57 1521.50 14.~3.22 1553.88 1521.38 1575.68 1540.16 4;..19 N 41.1.9 N 4.;.30 N 41.40 N 1552.85 1490.00 38.24 N 1574.85 1510.0£) 40.06 N 1596.84 1530.00 4;.88 N 1618.84 1550.00 43.69 N 1640.84 1570.00 45.5; N 1662.84 1590.00 47.33 N ~684.83 1610.00 49.15 N 1706.83 1630.00 50.96 N 3]9.28 W 3'28.25 W 2 37 "'"'-' . ."..3 W :--:46.20 W 355.18 W :364.16 W 37:-_-:,. 13 W 382. I I W 1597.48 1558.94 1619.29 1577.72 1649.63 1603.14. 1671.22 1620.98 :t 6, 99 1 :--: 1 .::,4.:,. o 7 1720.53 1660.86 1741.:=:8 1677. 1763.22 1694. 41.49 N 41.59 N 41,63 N 41.63 Iq 4.;. 59 N 41.48 hi 4.1.37 N 41.26 N 2.--: 0';--2.21 W 125. '? () hi 88 25 E '.-.' ! ":' '.':;.: 7 W 1:3:3 45 1',.189 :!, 4- E '5"5"3 ~' ~-. , . _ .-,C,;I ...... c,; W 1 '--'9 9/-, '-"-'"' 52E 24-1 9.~ W 126 l 4 ,=-,.-.,o ,:..~, -. / '-'F, ,:;,'o 887 .,::..~ 7 W 1 '--"-; 14 42 E . ,.., ~ ..' . 270.91 W 117.26 S 8/_-, 25 E:- 283.8 2 W 112.42.- :--.;85 0 E 296.7.5 W 107.63 S82 21E 17o'R ~: 15:'. _ , ~ ..... ~...,0 00 52.78 N 1750.82 1670.00 54.60 N 1772.81 16~0.00 56.44 N 1794.77 1710.00 58.35 N :--:91. C ,.-, W 400.06 W 409.01 W 4!7.87 W 1784.57 1711.8:3 181'2.52 1732.98 1833.52 1748.82 1854.4-6 1764.63 4.~.14 N 41.59 N 41.95 Iq 42.31 Iq :--: O'Fy. 6, 7 W 10:2.89 S 81 52 E 327.92 W 96../:.',4 S79 47E :_--.:41. 69 W 'F/O. fJ;6 S 77 51 El '-' F:; :'i 42 W 84-, ~'i 1 S 75 ...... .':,1::. ._-,....- . .., '7., / .... 1816.71 1730.00 60.32 N 1838.61 1750.00 62.36 N 1860.50 1770.00 64.47 N 1882.36 1790.00 66.65 N 426.66 W 4:35.37 W 444~ 00 W 452.55 W 1875. :':-: 6 17 8 0.40 1'="-?/- 21 1796 1'--' ,_B .- _m mm 192). 77 1:--:14..'F;'.7. 1942.06 1829.29 42,67 N 43.03 Iq 4-:--:. 75 N 44.62 N 36'?. 12 W 7:--:. 5c) S72 57E 382.7 9 W 72.57 S 6 9 4-'.:.-" E 4c)c)~.. (")7 14 /-,6_ .1/-,.., '.-_-;64 .44. E Position on well A-16RD MD TVD NS 1904·1.9 1810.00 1.926.00 1830.00 1.947.7.9 1850.0¢) 1.969.55 1870.00 1.991.30 1890.00 2013· 02 1910.00 · -.,('r~z~ 72 1930 00 2056.40 1 '.-T,'50. O0 . · .->¢)7o 06 1970 ¢)0 2o 199o oo .._o 1 ~.~, '"' :.)"2. 2(') 10 00 2142.92 2030.00 2164.50 2050.00 2186.07 2070.00 2207.62 20?0.00 2229.15 2110.00 2250.67 2130.00 2272. 17 2150.00 22.93.66 2170.00 2315.05 2190.00 CAL..CUI..ATION OF LEAST DISTANCE BETWEEN WELLS 2336.52 2210.00 2358. O0 2230.00 '": ...... ""'~ 48 '-"-'='(' . .,:..- -.' .4.._, .). (')C) ~,~,_ )96 2270.00 Closest Position EW MO TVD 68.88 71.18 73.56 N N N N 461.01W 1962.2.9 1843.63 469.40 W 1982.4-8 1857.93 477.71W 2002.61 1872.1.9 485.~5 W 2022.69 1886.42 78.50 81.05 83.68 86.38 89.14 97.78 N N N N hi Iq N Iq 494.10 W 2044.05 1901.21 502.18 W 2063.60 1914.83 5~0.18 W 2083.10 1927.40 518.10 W 2102.54 1940.44. 525.94 W 2121.93 1953.45 533.71W 2139.64 1965.10 541.40 W 2J58.68 1977.5.9 549.01W 2177.66 1990.04 1¢)0.80 103.87 107.00 110.20 N N N hi 556.55 W 564~01W 571.39 W 578.70 W '--' 1.9 6 ~'-.'~ '.'.'(') ¢)':' 4 6, · ' m -- . .a... # . .,~. , ~1...47 20t4 84 2234.28 2027. 19 2249.85 2037.35 113.47 116.80 120.19 1'23.42 N N N N 585.94 W 5.93.10 W 600.18 W 607.05 W 2268.34 2¢)4.9.42 2286.7'7 2061.4.6 '.2:,7-.:C) 5.15 207:3.45 ')'--~1':' 27 2081 92 .,., ._ m_~ · · . 126.84 130.26 · Z, -Z: Z~ ,Z, 1:37. 10 N N N N 614. O? W 621. 14 W 628.1,._,° W 635.23 W '2336.24 '2¢)9:3.22 2:354.21 '21 (:)4.5:3 2:37:2. 18 .".' 11 F;... ::: 4. 2:::'-.-~(') .... .14 ...'-'127 .14 on well 45.49 N 46.36 Iq 47.23 N 48.09 N 49.2.1 N 50.47 iq 5.1.73 N 52..99 N 54.24 N 54.99 N 55.74 N 56.49 N 57.24. Iq 57.99 Iq 58.73 Fl 58.56 I',i "i'::' ':":, N .~. l_~ · ._,.,. 5:3. ()7 N · _ ? N 57.60 57.11 hi 56./:)2 N 56.1:2: N 55./::,5 N A- 1:2 R D EW R e t: : '7; 0710 c). 7 i..I 0 Dista. nce Dir. ect Betu;eer, Betwee Wel 1 s Wel 1 s '-"-' .... :,..~,4 llE 4..:.c, 60 W 44-2· 82 W 45.8/:, S.4/.:, 45/:,. '..T."F.' W 40.19 ',F.;:]:E: 12E 471. 13 W 35.61 S'T..~7 58E 48/:,. 4.8 W 500.92 W 5]5.33 W 529.69 W 544.02 W 557.33 W 571./:,7 W ,=;,x,~ 9'7 W 32.28 '._:; ] 4 35E 30.9. 1 .:,'-' 2 21E 32.47 '.L"'; 'F:~J}W 36. ,(:,1 S19 ':.-'.' W 42.64 S27 23W .. (_) 44 :-'];:3:2 :":: f" I,,,,I 5.9. 12 :-'-: 374. 6 W 6:3. :32 S41 50W 600.23 W 77.88 :_;45 5H 6 :t 4.45 W :37. '/,} S 47 4.2 W 628.6,.'3 W 97.7:3 S.4-9 5:1 W 640.4-1 W 10:3.41 :._-.:;50 4. W /_-,54.42 W 119.27 S51 '.'.-':W 668.38 W 1:3 0.2:2 S52 :3W /. ':' 2 :::(') W 141 26 ¢"~'"' ................... .~ 47W ,z- =,~ "], 6.92. :32 W 1.5:2:. 6, C) ......... :. } W 706.2:'-:: W 1 ./.:,4. :':: 1 S5,2 54W 7:7¢) ""'- _ ..... ,~.:~ W 17/-, ('_):3 '-'~--'-' 23W · .'%. 7:34.18 W 1 C-:7.75 '._:;5:3 4.'.:.:'W 74:3. 14. W 1 '? 9.48 S54. 12 I,,,~ [-7-7 Eastman Whipstock l A f~EIr~.'l.,Al~tl:* CA~.~CU[.ATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RD Closest Position on ~,ell A-.'~7~RD MD TVD NS EW MD TVD NS EW ]1~.80 1170.00 1222.13 1170.00 13.19 N 13.82 N 172.45 W 182.38 W R e -F : S,r'], 7 4'.:;' :3.7 U 0 Dist.ance Dir. ect Be'tu~eer, Betwee Wel 1 s Wel 1 s 1166.26 1165.28 51..00 N ?.64 E 186.03 N78 16E i 186. l 0 I 185. 10 51.8'.~ Iq '.~. ':.'-~6 E 1 '.'.'-~6. 1:3 N 78 4-8E Eastman/ MD 1197.80 1222.13 1244.41 1266.62 1288.77 1310.84 1332.88 1354.88 376.87 420.87 442.86 1464.86 1486.86 1508.86 1530.85 Position TVD 1 170.00 1 190. O0 1210. O0 1230. O0 1250.00 1270.00 1290.00 1310.00 1330.00 1350.00 1370.00 1390.00 1410.00 1430.00 1450. O0 1470.00 1490.0C) 151 C). 00 1530.00 CAl...CLIl..ATI01'4 OF LEAST DIF;TANCE BETWEEN WELLS on well A-16RD Closest Position on well A-.=,.) NS EW MD TVD N8 EW 13.17 N 13.82 N 14.68 N 15.75 N 172.45 W 1182.87 1137.43 182.38 W 1202.97 1154.13 192.15 W 1224.91 1171.96 201.75 W 1246.75 1187.71 43.38 S 43.71S 4.3.94 S 44.17 S c',:')74':"=' 71_lFI Re-F : ........... ..,. _ 17.02 N .... 42 N ,'~. OE: N '-' 1 P, 9 N 211.18 W 1265.21 1204.29 220.41W 1286.62 12:21.13 22~.51W 1304.50 1235.05 238.49 W 1325.52 1251.02 44.37 S 44.61S 44. '=' ]. ':' 45.06 S Distmnce Dir-ect Between Betwee Wel 1 s Wel 1 s 23.71N 25.52 N 27.34 N 29.16 N 247.47 W 1346.54 1267.00 256.44 W 1364.04 127~.75 265.42 W 1384.82 1275.26 274.40 W 1402.72 1308.52 45.31 S 4.5.4-8 S 45.67 S 4.5.81 S 220.28 W 80.9:.']: S40 1:3W 231.42 W 83.68 S40 27W 24.4.20 W :=:7.1:3 S41 36W 25/_-,. 91 W ':?0.86 S42 38W 30.97 N 32.79 N 34.61N 36.43 N 283.37 W 292.35 W 301.32 W 310.30 W 1423.52 1323.29 1444.12 1338.07 1462.76 1351.25 1483.23 1:B65.65 45; 84 S 4.5.86 S 45.76 '.=-; 4.5 '='- S . ...I ;/ , .,:._, W '?5.46; ._, :.tz. 54W ~,:, 1.46 W 100.44. S.44 5 W ":":' 67 W 105 '=:'::: '.E;44 '~W · ,..' · l! . . - 3C)6. ':),2 W 112. C)8 .:,4._, 23W ':":' 24 N 40. C)6 N 41 ,:,,_ N 1500.19 1377.5 ./.-, 15'20.48 1 :E:':..-~ 1.5:3 1540.76 14C)5,4':? 45.4./:, ':'._, 45. :34 S 4...5 ':":" , ...,.:. '.:; 319.97 W 118,.27 S46 25W 3:31.74 W 124.97 S4-6, 4.1W 34.5~80 W 131.82 S4'7 45W 358. 11 W 138.81 S4:3 9W 372.4-7 W 146.14 S49 14W # -- --- ,~ .--i # 3F.:6 :::'.--' W 1._.:. 50 :=;5C) l:31/J 4-00.00 W 16,1.08 S50 50W 4-14.!54- W t68.77 S51 48W Eastma. CALCUI...ATION OF LEA:.-:;T DISTANCE BETWEEN WEI_L8 Position on well A-16RD MD TVD N'.=; EW MO Cl,:,sest PC, S'i. tion TVD on L~el 1 NS 1199.80 1170.00 · --,:Z. 1:3 I 190.00 1244.41 1210.00 1266.62 1230.00 13. 19 N 13.82 N 14.68 N 15.75 N 172,45 W 182.38 W 192, 15 W 201.75 W 1.172.83 1128.3:0 1195.02 1147.71 1213,00 1163.14 12:34.7I 1181.79 5.17 S 245, 74 W 7.03 S 256.31 W 8.58 S 2/..':.5.41 W 10.47 S 276.74 W 1288.77 1250.00 1310.84 1270.00 1332.88 1290.00 1354.88 1310.00 17.02 N 1:3.42 I',1 · --i (' ' t'"1 ,' .). (.),:., N '21.8':T/ N 2.11.18 W 220.41W 229.51W 238.4? W 1256,~71 1200.3:5 1278.40 1:2l:3. ,:,'=' 1 1297.99 1237.20 1316.86 1251.14 1376.87 1330. ., 13 ~7 135(:). 00 1420 .~:B7'':' 1370.00 1442. '-'/ ,:, =, 1:390.00 23.71N 25.52 N 27.34 N 29.16 N 247.47 W 256,44 W 265.42 W 274.40 W 1338.22 1268.79 1:359.58 1286.45 1380.94 1304,.1.1 1400.68 1320.42 19.47 S 331.64 W '.T.: 1. :35 S 34:3.52 W 23.2:3 S 355.39 W 24.96 S :2:66.37 W 1464.86 14.1.0.00 1486.86 1430.00 1508.86 14-50.00 1530.85 1470.00 30.97 N 32.79 N 34.6.1. N 36.43 N 283.37 W 2?2.35 W 301.32 W 310.30 W 1422,00 1:337.84 1443.32 1355.26 14-64-.64 1372.68 1485.76 1390.10 26.67 S 378.54. W ":'q :'3'~ .,=,_. S :390.72 W 30. 10 '.=; 402.89 W 31.:Bi S 415.06 W 1552.85 1490.00 1574.85 1510.00 1596.84 1530.00 1618.84 1550.00 38,24 N 40.06 N 4~.88 N 4:3.69 N :3.19.28 W 3::2:3. '.='M W 3:2:7.23: W 346.20 W 1505.00 1405.60 t526.24 1422.76 1547.4.9 1439.92 1568.74 1457.08 '="::' :34 '.=: 425 '.-.~9 W ._... i. . ... ::::.=; C)'~ S 4:.=:8. ::3'F, W 36 '"':' c. ,=,..., ._, 45]0 '-'(" ...... z, ) W ':"-' 4.,.4,:7.: 20 W .... =,. 57 '-' 40.._,':' ..'-' '-'._, 475 ./-,_ 0 W 41.17 S 4:31.66 W 4-:7-:. 47 S 4'.=.' 4,6:3 W 45.77 S 507.71 W 164(:). 84 1570. C)0 / '") 84 I :.6,. 15~0.00 1 / ~'"~,_,._,":"':' 1610.00 i" ,~':: 163C). 00 45.51N 47.3:3 N 47.15 N 50.96 N 355.18 W 364.16 W :373.13 W 382.11W 1589.~? 1474.25 1600.33 1482.57 1621.21 1498.73 1642.07 ~514.88 R e f: : S 074'.--** 1.7 I..I0 Distance Direct Between BetJ~ee Wells Wells 90.03 S72 23W ':P2. 'P:3 S70 44W :1 1:2.6,7 S62 51W . ~'=" '.=¢,S 4 ]-:' L,I 117 ...... , 1 ... 12. 2.4..5 S 6, 0 4. 0 W 127.4-0 S5'=:) :_--: ::.:.: I,,l 1 '-"-' 62' ':'"'~':' 48 W 137. :.-]:6 S58 7W ,1. 43. 1 I S57 30W 14.8.37 S56 55W 15:3.74 S 56 '? W 159.34 S55 42W 164.94 '.=;55 17W 170 ~./:, '-'~'- · . -:, .,.) 4 176,. 17 S54:31W 182. 14 SS:Z-: OW 18'F.,. 0:3 S52 42W 195. '?:2 ::;5'.'.:-: 24W Eastman/ .Whipstock CALCULATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RD Closest ~,.'.,sitic, n c.,n well A-6 MD TVD NS EW MD TVD NS EW 1199.80 1170.00 1222.13 1190.00 1244.41 1210.00 1266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.45 W 1160.93 1128.40 182.38 W 1180.16 1145.66 192.15 W 1201.09 1164.34 201.75 W 1222.04 1183.(25 148.41 N 154. :97 IN 162.29 N 169.62 N Re-F : S07489.0].]Ci 1288.77 1250.00 1310.84 1270.00 1332.88 1290.00 1354.88 1310.00 17.02 N 18.42 N 20.08 N 21.89 N ~' .18 '~ '~: ~11 W 1.,:.4...02 1201.78 2'70.41W 1263.98 1220~5C) 229.51W 1284.02 1238.33 238.49 W 1305.03 1257.01 Distance D:Lr. ect: Between Bet~ee~ Wells Wells 1376.87 1'-'~ · ._-...,0.00 23.71N 247.47 W 1326.04 1275.69 142.49 W 144.61 N~.2 3C)E 147.87 W 151.72 Nl:3 44E 153.80 W 159.20 N14 34E 159.74. W 166.27 N15 16E 176.96 N 165.68 W 17:3.14 N1.5 5:3E 84 '-'"-"~ 179 ':':'.=; 1,~.. Iq 171 ,61 bi , ,...,.~ N :16 24[.-Fi 1 ':). 1 . 5.:. 9. N 177 . :2: ./.",. W 1 :::'_,,..,/- . :37 Iq 1,6 _):, E 198.87 l'q 18:3.42 W 192.77 N1'7 17E 206.34 N 189.47 W 199.17 N17 37E Eastman CALCULATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RD MD TVD NS Closest Position on well A-23 ].199.80 1170.00 1222.13 1190.00 1244.41 1210~00 1266.62 1230.00 13.19 N 13.82 N 14.68 N .15.75 N EW MD TVD NS EW 1288.77 1250.00 1310.84 1270.00 17.02 N 18.42 N 172.45-W 1175.89 1150.41 182.38 W 1196.99 1169.52 192.15 W 1217.65 1187.78 ']'(31 7.5 W 1'~'='° 45 1'~]~ "-' 211 18 W 1°~. '2 . ~,~ 1 1224.27 220.41W 1279.69 1242.36 Re~ : S07509.71...I0 Distance Dir. ectJ Betu)een Betweer Wells Wells 125.8~ S 105.58 W 155,48 S25 42. E 131.71 S 112.25 W 162.84 S25 44E 137.89 S ' 119,68 W 170.36 S25 24E 14.4.18 S 127.:30 W 178.02 S24 58E 150.43 S 156.64. S 134.89 W 185.80 S24 30E 14.2.4:3 W 19:3.6:3 S24 '-~)E Eastman Whipstock Position on well A-16RO MD TVD NS .1. 199.80 I 170. O0 13.19 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well A-14 EW MO TVD PIS EW 172.45 W 1139.26 1090.68 Ref : S07503.7~.,10 Distm. nce Dir~ect Between Betwee Wells ~bl ls 158.37 S 2.16~80 W 194. 14 S14 Eastman Position on well A-16RO MD TVD NS J199.80 1170.00 1222.13 1190.00 1244.41 1210.00 1266.62 1230.00 1288.77 1250.00 1310.84 1270.00 1332.88 1290.00 1354.88 1310.00 1376.87 1330.00 1 :-~ )~7 1 ~'='" 00 ._ ......I ~..J'. 142(:). 87 1376). 6)0 1442 o/. 9(3 00 . ,,o,~ 13 . 1464.86 1410.00 1486.86 1430.00 1508.86 1450.00 1530.85 1470.00 13.19 N 13.82 N 14.68 N .1,5.75 N 17.02 N 18.42 N 20.08 N 21.89 N 23.71N ~5.52 N 27.34 N 29.16 N 30.97 N 32.7:~ N 34.6,1 N 36.43 N CALCL.H..ATION OF LEAS'[ DISTANCE BETWEF. N WELLS Closest P,:,sitior, on well A-13 EW MD TVD his EW 67.45 S 71.04 75. 1.1. 79.16 S 172.45 W 1163.91 1122.16 182.38 W 11:33.34 11:38.91 192.15 W 1205.01 12.57.5;. 201.75 W 1226.56 1176.00 1245.30 1191.92 1266.51 1209.88 1287.60 1227.75 1308.61 1245.54 82.85 87.07 91.27 95.46 '.E; 211.18 W 220.41W 229.51W 238.49 W 1._,'--' o,:,~_,..,. 79 1 _~'/~_, ~'-.' .67. 1349.76 1280.31 1370.74 12'.-}8.00 1:391.71 13.1.5.69 99.48 103.70 107.92 112.15 247.47 W 256.44 W 265,42 W 274.40 W 1412.69 1333.38 1433.66 1351.07 1454.64 1368.76 1475.61 1:}86.45 116.37 120.59 124.81 129.03 S S S S 283.37 W 292 '-'= · i . ~.~._1 W 301.32 W :310.3(') W ReF : S07501.0U0 Distance Dir-ecti Between Bet~eer, Wells Wells 231.61 W 110.86 S36 16W 240.79 W 1.14.99 S34. 33W ~...'-'.=; 1 . 2. 4 W 11. 9. . ~._ ,..,':' '.!:: :3:3 18 W 261.4-3 W 124.4-4 S:32 10W . 4...,W 270 59 W 129.91 S:'-':0 '-""-'" . S 29 ~..4 W ~ o 1.0!5 W 1 '-' = · ::,...,, 7:2 2'--/1 4.5 W 141. '-' © ':; ';:, 9 ...... · . c, .,- ...... W · ?.-:01. :31 W 148.2. 1 S2:3 21W 311.76 W 154.4:3 S27 34W 322.21 W 160.88 S26 58W 3312.66 W 16'7.34 'S26 26W 343. 11 W 173. :..,]: 1 S:25 56W :":: 64.01 W 1 :."-.-:/.,... 79.:,,,,-'-"-'.~, '=' 3 W 374.4.5 W 193.29 S24 39W :':::34.90 W 1. 99.81 '.324- l 6 W Eastman Whipstock Position on well A-16RD MD TVD NS 3.199.80 1222.13 1244.41 1266.62 1288.77 1310.84 1332.88 1354.88 1 ._. 7 .:.. 87 ', :[:7 1442.86 CAI...CI. JI.ATION OF LEA'.-'::]- DISTANE:E BETWEEN WELL~'.=, Closest Position ,:,n well A-17RD EW MO TVD NS EW 1170. 1190. 1210. 1230. 00 00 00 00 13.19 N 1:3.82 N 14.68 N 15.75 N 172.45 W 182.38 W 192.15 W 201.75 W 1172.81 1137.57 1194.78 1157.16 3209.79 1170.29 1231.33 1188.77 90.19 S 93.59 S 96. '-':'-'A c. 100.34 S Re.F : .:,t.. 7._16 1250.00 1270. O0 12'~¢0.00 1310.00 17.02 N 18.42 N 20.08 N 21.89 N 21.1.18 W 1252.75 1207.15 220.41W 1274.04 1225.42 229.51W 1285.00 1234.83 238.49 W 1303.08 1249.56 104.45 S 108.54 S 13.0.65 S 115.40 S Distance Dir. ect' Between Betweel Wells Wells 13:30. 1350. 13:70,. 1 o,::, ' .... ,-. (.). 00 O0 00 00 23.7'; N 27.34 N 29.16 1'4 247.47 W 1323.55 1266.25 256.44 W 1344.01 1282.93 265.42 W 1:2:52.54 1289.74 274.40 W 1372.42 1305.4.:} 120.78 S 126.15 S 128.74 S 135.20 S vA"::... ,-.":,; W 11 o 5.'=i :--; 16 25W .,...~.~ . .'.~ ..... 21z.'-' 24 W 116.22 S1._~ 32W · ~' 19 (') 1 W 12(") 80 '='13:2:7W ~.. . . # 2>-..'9.25 W 126.23 S3.3 20W 1410. O, 0 30.97 N s '"'s _ . , . 28.--' ,. 37 W 1 :--: 92.29 1 :-.: 21 11 9R9 44 W 131 87 o13: 6W .~..... . -..~ . ~ :.]":7 249 ..., 6 W 1 .68 S ! '2 ~./.;. W 254 77 W 14.4- 1:3 c'1(': . . ....s 2. 64 . ¢). 'P. W 1....~ ..";' .17 S 1. 0 ..:,'-' 4. tO 274.65 W 160.24 S 10 :-_-:'F..' 14 :...'85.20 W 168.3:.--.: S 10 4.4W 28'.--.~. 62 W 177. 17 '._=; 8 4.'F~W 299.97 W 186.60 :__.; 8 51W 141.66 S 3 :i. (') . ._-,'-' 1. W 196. C). 4 S 8 52 W Eastman/ CALCULATION OF LEA.-:,T D I.:,TAN_.E BETWEEN WELL.'._=; Position on well A-16RD Closest ~.~ositi,:,r, ,.-.,r, wel 1 A-171-~D MD TVD NS EW MO TVD NS EW 1199.80 1170. 1222.1:3 1190. 1244.41 1'21(]). 1266.62 1230. 00 13,.19 N 00 13.82 N 00 14.68 N 00 15.75 N 172.45 W 1165.777 1126.83 100.70 S 1 :::2 ":"-' . .~ ._-, 1146 20 104 '-' =' ':' .. ..... :, W 1187 ':~'-' .... ::, .... ._, 1'72. 15 W 1203.71 1160.01 106.90 S :.201.75 W 1 ,...,..._':"' 9 ?,..,.-_.,_ 9. 1178 .40110, 7:3 ._,':' R e ~ : '._::07517.71..I0 1288.77 1250.00 1310.84 1270.00 1332.88 12~0.00 1354.88 1310.00 Distar, ce Dir. ecti Betu~een Between Wel 1 s Wel 1 s 1376-87 1330.00 '):3'?~, ):7 1:350. O0 i4 ~'0.87 1:370.00 1442.96 1:390.00 23.71 25.52 27.34 29.16 N N N N . ~'~ 1 6 ~o 2/-,0 26 2'--.~ 247 47 W 1.:,'.-' I i 16 ':' # -- . m . . '256.44 W 1:342.4.5 1277./:,6 1:34.08 5; 2/-,.=; 4':' W 1.:,..,4 0:3 1287 '-":' ......... : ..... 1:..:.:7 11. ':' '-' " .", J4 4-:3 143:3~ S 274.40 W 1.:,74..::1 I'-'(' . . . 2.1.7 9'.-.,.' W 1:::0 1° ':":'1 44W 227.67 W 133.72 S20 58W 234.85 W 138.22 S19 21W 245.46 W 1. 43.43 S 1. '~ 4W 2 .... ~/-, .01 W 14 :E:. ,:, 7 '.B 1 ,_,':' 4' 9 W ~,_6.51 W 154 49 S.1.8 276, 94 W 160. ._,":',_,':' S .1 ,_,':' ' · .-.".7'-., 6 5 W 16 6 7/-, S 16 4 9 W .~--'....i... . 292. :3.1. W 174.03 S16 31W :302.97 W 181.31 S16 15W 308.47 W 189.00 ,.E; 14 40W 317.5:} W 197.2'? S14 3W Eastman Position on well A-16RD MD TVD NS CA[~CU[.ATION OF [..EAST DISTANCE BETWEEN WELLS ]199.80 Closest Position ,:,n well A-15 EW MD TVD NS EW 1170.00 13.17 N 172.45 W 1141.42 1117.66 Re.F : '.=-:C)7504.01.10 Dista. nce Dir'ect~ Between Betu;eer Wel 1 s Wel 1 s 178.42 N 75.39 W 198.65 N30 26E /-7-7 Eastman CALCLILATION OF LEAST DI.::,TAN_.E BETWEEN WELL.S Position on well A-16RO Closest Position ,:,n well A-:.24RD MD TVD NS EW MD TVD his EW 11CY?~. 80 I 1,70.00 1222. 13 11SrO.O0 1244.4] 1210.00 1266.62 1230.00 .1.3. ICY N 13.82 N 14.68 N 15.75 N 172.45 W 116.1.30 1.118.7') 86.68 S 1 o o 'R.~ "-"-' 9 9 . 1 ,...,.~. .... S ,...,.. ....... W 1 11 :.:7.4..5 -'Ty 1 24 1Sy2, 15 W 1200. O0 1152.08 '.-}4. :_--:2 S 201.75 W 1220. '.~8 116'.:~. 45 '.~'F~. 2'~ S Re ~: : .S074'..-..~4.71_10 1288.77 1250.00 1310.84 1270.00 1332.88 12~0.00 1354.88 1310.00 17.02 N 18.42 N 20.08 N 21.87 N Distance Dir. ecti Between Between We 11 s We 11 s 137/ .... 1330.00 137 ~i 1350.00 1420. 1370.00 1442.86 13~0.00 23.71N 25~52 N 27.34 N 27.16 N 247.47 W 13~8.64 1249.53 120.26 S 256.44 W 1339.16 1265.71 124.77 S 265.42 W 1359.69 1281.88 129.28 S 274.40 W 1380.22 1278.05 1:33.77 S 222.18 W 122.76' S26 28W '-.":' "-' '.':.' 5 '=' '.-.' .~ '..7:'. :3 W ,~....,.- ..... W 1 :..-_"7 62 # . ._~ .t...._ 240.14 W 1:3:2.6:4 S:,..7:3 40W 251.02 W 1 :.:-::':.-~. 03 S2:]-: 11W 302.72 W .!. 7:::. '~¢4 'S:21 OW 314.52 W 181.84 S21 :-IN 326.32 W 18':-.¢. 75 S21 15W 3:38.13 W 1 ';~7. ,/--,6 S21 22W L' I i Eastman CALCt~.ATION OF LEAST DISTANCE BETWEEN WELLS Pomition on well A-16RD MD TVD hiS Closest Position on well A-24RD EW MD TVD NS EW ]1~9.80 1170.00 1222.13 1170.00 1244.41 1210.£)¢) 1266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.4-5 W 1170.17 1132.~8 67.80 S 216.98 W 182.38 W 1186.62 1147.42 70.69 S 224.28 W 192.15 W 1208.26 1165.95 74.88 S 234.65 W 201.75 W 1229.78 1184.36 79.05 S 24.4.96 W 1288.77 1250.00 1310.84 1270.00 1332.88 1270.00 1354.88 1310.00 17.02 N 18.42 N 20.08 N :..--' 1.89 N 211. 18 W 1251.17 1202.68 83.19 S 22o.41 W 1272.45 1220.89 87.31 ... '=' 729~51 W 1287.78 1233.5:.--: .90.60 S 238.49 W 1308.60 1250.78 'P5.08 S 255.2]. W 265.41W 273.36 W 284.18 W 1376.87 1330.00 ' '~',~ '.~7 1350.00 1~,. 7 1370.00 1442.86 1390.00 23.7] N 25,52 N 27.34 N 29.16 N 247.47 W 1329.41 1267.98 99.56 S 256.4.4 W 1350.22 1285.18 104.04. S 265.42 W 1364.00 1296.57 107.01S 274.40 W 1382.14 1310.83 111.47 S Re t: : S07495.7U0 1464.86 1410.00 1486.86 1430.00 1508.86 1450.00 30.97 N 32.79 N 34.61 N 283.37 W ]402.51 1326,86 116.49 S 292.35 W 14.22.88 1342.88 1:21,50 S 301.32 W 1443.25 1358.90 126.52 .S Distance Dir. ecti Between Betueer Wells Wells 99.56 S28 48W 103.47 S,26 22W 108.48 S25 23W i13.74 S24 30W 19.25 S:Z3 43W 24.96 S2:.-:: 3W s 1.74 1 " "t4 5:8.8 4 S 21 ...'.":.) W 295.00 W 145.95 S21 5W 305.82 W 153.0./:, S20 52W 312.'P8 W 160.33 S19 30W 323.25 W 168./_.:.2' S 19 9W 334.78 W 176.92 S]9 13H :]-:4-6. ::ii: 1 W 185. :23 S 19 17 W '-'~" :.:"; 19 20 W · '-, ...., 7,9 4 W 1 '.:.:' :'::, 5 :.-3 . _ Eastman / Position on well A-16RD MD TVD N8 1222.13 1244.41 1266.62 1288.77 1:310.84 1332.88 1354.88 CALCULATION OF LEA:.:-..:T D I.~=,TAN...E BETWEEN WELLS 1376. o7 13 ~7 14~.,,~. c,7 Closest P,:,sition ,:,n wel 1 A-11 EW MD TVD NS EW 1170.00 1190.00 12].0.00 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.45 W 1199.33 1193.56 1:~2.38 W 1220.72 1214-.23 192.15 W 1242.05 1234.84 201,75 W 1268.86 1260.51 30.87 S :33.82 S 36.76 S 4.0 6C) ':' 1250.00 1270.00 1290.00 1310.00 1330.00 1 :'.=,o 00 137£). 00 17.02 N 18.42 N 20.08 N 21.89 N '-"'=' 71N '25..~,2 N 27. :34 N 211.18 W 1290.21 1280.92 220.41 W 1311.48 1301.27 2' 2' 9, 51 W 1._,,.., ,..'=' ':' '-", 69 1._,~.'=' '~' 1 , ...M....=~ 2:38.49 W 1:354.59 1:342. :37 247 47 W 1.-, ~, om.-, . .:.7._ 68 1 .....~.4.~ 256.44 W 1:392.11 1377.97 265.42 W 1412 .001.:,~'~:, . o ~' ~ 42:. 67 S 46.73 .:.,'-' 49.79._,':' 5:3.28 '...=.: R e F : S C) 7 5 0 0.0 I...I 0 D i s t,-~ n c e D i r-e c t .i. Bet~,een Betu~eer, Wel 1 s Wel 1 s · _:"':'--~... 22 W14- 2 . .~. '~'':',_, S 71 4. :2 E 43.85 W 148.48 S71 ()E 4-8.47 W 154.61 S70 18E 55. 18 W 159.96 S68 58E 60.61 W 1 :,._, . ...., .:, 6 c, :3 E 66.02 W 17(_").46 S67 ~E 7 ~1.4 2 W 17 5.7 0 '.=; 6 6 _)., E . .. ,--' ~. I=*., - 77 21 W 180.8 A .:, .:,.,.., 0 E' i,-:; 8:,2.84 W 1:3/:., 07 S 6:3 ._ ,:-,E 87.0'.9 W 191.6'7 S 6:3 1/.':, E '92 16 W 197 ~:A ,:./.c, ................ ~ 17E Eastman/ CAI_CI...ILATION OF LEAST DISTANCE BETWEEN WELLS Ref : So7497.01~10 Position on well A-16RD MD TVD NS Closest Positi,:,n on well A-7 EW MD TVO NS EM Di ._~ t.in ce Bi r. ec (- Betu;eer, Betwee~ Wel 1 s Wel 1 s 1199. '-'f' . o ) I 170 00 1 '."'.:"-' 13 11 c~ 0 00 East manz Whipstock CALCU[.ATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RD Closest Position EW MD TVD MD TVD NS 1199.80 1170.00 1222.13 1190.00 13.19 N 13.82 N 172, 45 W 182.38 W 1~83.36 1182.50 1211.84 1210.68 on well NS 17.53 S 20.41S A-32 EW Ref : S07505.7U0 Dista. nce Dir. ecti Between Between Wel 1 s Wel 1 s 14.6:.2 E 189.99 S80 4~E 11.79 E 198.24. S80 OE CAI CI lt..AT I FiN OF LEA.:,] D I..-.,] AN_.E BE]'WF:EN WEI_LS Position on well A-16RD Closest Position ,:,n ~ell MD TVD NS EW !'tO TVD bi:--; EW 11 ¢/9 '-'(" · . .,=,.~ 1:170. 1'-" 19 N 1~ 49 ¢' Re~: : S07511.7LIt-.~ Distance Dir. ecti Between Betueer Wel 1 s Wel 1 s [-7 F. astman / L ~ Whipstock l ~~ Position °n well A-t6RD MD TVD NS 1199.80 1222.13 1244.41 1266.62 1288.77 1310.84 1332.88 1:354.88 1376. o7 139' ']7 142c.,.~,'~'~ 1442.86 CALCULATION OF LEAST DISTANCE BETWEEN WELL.'.--; 1464.86 1486.86 1508.86 1530.85 Closest Position on well A-10 EW FID TVD NS EW 1170. 1190. 1214). 1230. 00 O0 00 O0 13.19 N 172.45 W 1173.06 1138.75 13.82 N 182.38 W 1194.86 1158.:27 14.68 N 192.15 W 12].6.49 1177.67 .1.5.75 N 201.75 W 1238.06 1197.04 94.42 S 98.52 S 102.60 8 106.69 S R e t: : S 074. 99.0 UI_-.I 1250.00 1270.00 1290.00 1310.00 17.02 N 18.42 N 20.08 N 21.89 N 211.18 W 1259.5:2 1216.3]. 220.41W 1280.88 1235.49 229.51W 1302.14 1254.58 238.49 W 1325.13 1275.128 110.76 S 114.81S 118.84 S 123.13 S Dista, nce Dir. ecti Between Between Wel 1 s Wel 1 s 1330. 1350. 1370. 1:390. 00 00 00 00 23.71 Iq 25.52 N 27.34 N 29.16 N 247.47 W 256.44 W 265.42 W 274.40 W o / .-,.~ 2.94. 1._,4 z, 1 54. 1367.58 1313.79 1388.80 1333.05 1410.02 1.:352.30 126.98 130.82 134~66 l':'q ~1 · ._, ~_ . .~. 19]..8]. W 1].3.72 C-;tO 12W 200.59 W 118..1.5 '3 9 12W 209.23 W 122.85 '.=_; 8 17W 217.80 W .1.12'7, 81 S 7 .'.::8 W 14].0. 1430. 1450. 1470. O0 O0 O0 O0 30.97 N 32.79 N 34.61N 36.43 N 283.37 W '-"'-?-" 35 W 301.32 W 310.30 W 1431.25 1371.55 1452.47 1390.8:[ 1473.69 1410,,06 1494.92 1429.32 142.35 S 146.19 S 150.04 S 153.88 S 226, :34 W 13:-..:, 0 ] :=; 6 46W 2:34 '"':::'-' W ]. "'"'-' 37 '=' . ..:) C,. '.-~. .-, 6 1 1W ~:4._-,. 27W 144,02 S 5 o.~,.-., .~,,_-, 4'~, ~ W ~ .... ~..~,_,W I 76 S 5 260. :2:4 W 155 ~ 3:.7': S 4 53W .~'-"/:...,,_,'='. 4. 0 W 160 . '".?. ?,_ '.=; 4. 22 W 27/-,.... 4 ~.5 W 166 . .~._ ._, ~":.' '.F_; .5:54 W 2:5:4....51 W 172 .1 ....'=; ._,'=' :':: ~'-' 7 W 292.57 W 177.78 S 3 2W 30c).63 W 18:]-:.41 S 2 39W :30:-=:. 69 W 18'F.;. 06 '.E; 2 17 W 316.74 W 1'74.71 S 1 56W /-7-7 Eastman Whipstock CALC~.~LATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RD Closest Position EW MO TVD MD TVD NS 1199.80 1170.00 1222.13 1190.00 1244.41 1210.00 ~266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.45 W 1.1,66.57 1148~47 182.38 W 1187.19 1167.88 192.15 W 1207.72 1187.20 201.75 W 1228.16 1206.44 1288.77 1250.00 17.02 N 2~1.18 W 1248.51 1225.59 on well A-SRD2 NS EW Reef : S07517':.0U0 Distm. nce Between Wells 122.52 S 87.66 W 161.46 12.8.16 S '.;~1.76 W 169.88 · ..:,.:,. 77 S o.~] 84 W 178 42 139.36 S 99.90 W 187.05 144.72 S 103.94 W .t, 95.76 Dir-ecti Between Wells S32 OF S32 33E S32 5E:E '._--::33 17E S 33 31 E ,- Eastman CALCULATION OF LEAST DISTANCE BETWEEN WELLS Position on well A-16RO Closest Position on well A-5RD2 EW MO TVD NS EW MO TVD NS 1199.80 1170.00 L222.13 1190.00 t244.4~ 1210.00 L266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.45 W 1].66.57 1148.47 122.52 S 182.38 W 1187.19 1167.88 128.16 S 192.15 W 1207.72 1187.20 133.77 S 201.75 W 1228.16 1206.44 139.36 S 87.66 W 91.76 W 95.84 W 99.90 W L288.77 1250.00 211.18 W 1248.51 1~ 59 144.92 S 103.94 W Ref : S07514.0U0 Oi stance Between Wells Oipecti Betu~eer Wells 161.46 16 9. ':":' 17:5:. 42 187.05 S:B2 OE S:B2 :B3E S32 58E S3:B 17E 195.76 '.:,..::.:, ::: 1 E Eastman I-:AI.~CI..ILATIFIN OF I_EAST TII STANCE BETWEEN WELL'.--; Positior, on well A-16RD Cl,:,sest P,:,siti,:,n or, well A-SRD2 MD TVD NS EW MO TVD NS EW 19-~. 80 1170.00 222.13 1170.00 244.4.1 1210.00 266.62 1230.00 13.19 N 13.82 N 14.68 N 15.75 N 172.45 W 182.38 W 1'P2.15 W 201.75 W 1166.57 lJ48.47 I187.19 1167.8:3 1207.72 1187.20 122:3.16 1206.44 122.52 S 128.16 S 133.77 c.._. 139.36 S R e f : ':'._, 07515 . ('il. lO .-,o~ ];7 12.=,¢) 00 · .-,11.18 W 1248.51 1.... ........ D i s t ~a r, c e D i r- e c t i Between Between Wel 1 s Wel 1 s 87.66 W 161.46 S32 C)E 91.76 W 169.8:3.?, S32 33E 'F/5.84 W 178.42 ~--:32 58E 99. ':.-~0 W 187.05 S3:3 17E 144 9'7 c. lC)3 '.--/4 W 1'-= 76 # . .. ...., ,, ::Y.~]I ,, '="--'"::' 31E ._1 ._! ) R 13 W ~9 28 27 26 N. TRADING BAY UNIT TS-9 ,,;;, TS 5 ,4~ /,*,' !'], ~.. .' %~ ~." ,, , . ,; ..... ~..[ -- ?-~,,," /; ~ ''~- / TS I ~'" ," ' I ARCO,' RADING BAY TS-7 ~ ~ ~'~"'~'/ ~' ~" ~'"' /7' ARCO TS ~ ,.-' / · MIDDLE RIVEF ST. ~ /' T ~ ,,' ,/ .~ ~x,co s-e~ I 0 TS ~ T~DING BAY TRADING BAY / N 5 4 A-18 ~ 5 I UNI~ ~-9 ~ ~ ' ~ W. TRAD. BAY . ~ UNION ~ I TRAD. BAY ' [ / 9 '.. ~ ' N ~ :, ......... ~, ~.~, t,,.= . '-.. ~ : ,..~_~ .',, ~,' ,:"/ A-I9 ' · A-16 ":' "1'[ ~;~ '" ' .................... ....... "---::::: ?-~ ~ t;:~ ~ ~-~=~ .... t A~i, ~.:~-- ,~'-'~. ~' v3_ ,--< ~; ~ ,~ '~ UNION "MONOPOE' PLATFORM .. -- - - ~,~..- ,.. ,.:.,, .-':' .~%..-' .+ ..' ~o , A-ff -""~'''"' ' ,/'. ,, ~ I UNION ~ ..... '~A'~. ~A~td-2 .' " ~ E.TR&OING BAY U~ I0~/ ", TRA lNG BAY /'" '/ '"" ~' ~ ~'x:-'~'' ..,' ,,.., A-26 ' ~' '" '", A-20 '": ALASKA OIL AND GAS ANCHORAGE, ALASKA TRADING FIELD . ,~o' o ,~o' ~,~o', ~,~' SCALE: L , JAN. 16, Unocal Oil & ( )ivision Unocal Corporal,,_,, RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL$ Environmental Department Alaska District May 18, 1988 Mr. Mike Minder AK 0il & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Directional Program, A-16 RD Trading Bay State Dear Mike, After reviewing the offset wellbore paths, Union is proposing to use a trajectory further south of the original proposal to hit the targets at 5226' TVD and 6101' TVD in A-16 RD. (See attached Directional Plan). By moving south the A-16 RD wellbore will be 47.62' away from A-2 at the kickoff point and continue to diverge. The A-16 RD wellbore will be 59.76' away from A-12 RD at 2380'TVD. The only other well close to the proposed path of A-16 RD is A-12 original hole at 1920' TVD. A-12 will be within 31.23' of the A-16 RD path at that point UNOCAL will shut-in both A'2 and A-12 RD while redrilling A-16 past these wells. UNOCAL is also planning to use directional MWD equipment to provide a continuous read out of the wellbore path. Included with the MWD equipment is a magnetic interference tool to detect if the A-16 RD wellpath is approaching another well. If we can be of further, assistance or answer any questions about A-16 redrill, contact Steve McLean at (805) 658-7600. Sincerely RoyCe=ts Environmental Engineer MONOPOD A- 16 RD DIRECTIONAL PLAN surface Location: 1610' North and 566' West of the Southeast corner of Section 4, T9N, Ri3W, SM B & M. Target 1. 670' North and 1660' West of the surface location. Depth: 5226' TVD or 5571' MD 800' North and 1980' West of the surface location. Depth: 6101' TVD or 6513' MD Directional Plan: Drop, Turn and Hold , 1. KiCk off directional work at 1200'. 2. Drop the hole angle from 26.63° to 21.75° at 2~deg/100'. 3. Turn the wellbore from N 80 W to N 65.44 W. 4. The end of build and turn section is at 1398' TVD and 1450' MD. Displacement - 265' 5. Hold 21.75~ and N 65.44 W to TD at 7000' and 6553' TVD. Total Displacement at TD is 2321'. STATE OF ALASKA ALAS .... . OIL AND GAS CONSERVATION COk,,t. .... SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend i-q Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program E] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Union Oil Company of California 5. Datum elevation (DF or KB) 101' RT above MSL feet 3. Address :P. O. :Box 190247, Anchorage, AK. 99519-0247 4. Location of well at surface 1610'N, 566'W Yrom SE cor. Sec 4, T9N, R13W, S.M. At top of productive interval 4472'MD, 3931" TVD, ll'N & 1911'W of Surface Location A! effective depth 735'6'MD, 6437'TVD, 55'N & 3314'W of Surface Location At total depth r 7434'MD, 6503'TVD, 57'N & 3354'W of Surface Location 6. Unit qr.Pr.operly name 7..Well. number ~TBS~6',, 8. Permit number 9. APl number 50-- 733-2011 10. Pool ~rading Bay Field 11. Present well condition summary Total depth: measured true vertical 7435 ' feet Plugs (measured) 6503' feet Effective depth: measured 7356' true vertical 6437' Casing Length Size Structural Conductor Surface 1059 13-3/8" Intermediate Production 7434 9-5/8'~ Liner Perforation depth: measured See Attached feet feet true vertical Tubing (size, grade and measured depth) Junk(measured) 30' of 1-11/16" Link DiCo~e perforating gun @ +7326'. Cemented Measured depth True Vertical depth 1200 sxs 1059' 835 sx 1st Stage 1000 sx 2nd Stage 7434' L.S. 2-7/8" N-80 6.4# Butt - 6943' S.S. 3-1/2" N-80 9.2# Butt - 4424' Side String~ 1-1/2" IJ 4422'- 6846' 1044' 6503' Packers andSSSV(typeand measured depth) 1. Otis "WD" @ 69t2' 2. Otis "RTH~' @ 4423' @ 311' & 310' 3. SSSV 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation April 1, 1988 14: If proposal was verbally approved Name of approver Date approved 15. I heret-~certify that the foregoing is true anc~cqrr¢ct to the best of my knowledge Signed~2~7~/~ ..~~~z~~I~/"T:litle Env.ironmental Engineer ~Ro~D. Roberts ~ ~ommission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test F-] Location clearance Approved Copy Returned ORIGINAL S. :NED BY LONNIE C. SMITH Approved by Commissioner Date by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate _TRADING BAY STATE A-16 ABANDONMENT PROCEDURE 1. Kill well. Install and test BOPE. · Pull out of the hole with dual production tubing and side string. Recdver dual hydraulic packer and seal assembly.. 3. Rig up and run a CBL-VDL-GR.log from 4000' to 1000' in the 9-5/8" casing. RIH with cement'retainer and set at 6900'. Pump into perforations (6944'-7250') and establish a breakdown rate and pressure. Pump a minimum of 200 cu. ft. of Class "G" cement with 10% sand. Pull out of cement retainer and leave 50 linear feet of cement on top of retainer. (Cement plug from 6900' to 7250', plus 100 linear feet excess and 50' above the retainer). . Pick up 3 stands and reverse circulate a~ cement from the drill pipe. POOH. . RIH with 9-5/8" cement retainer and set at 5000'. Pump into perforations (5042'-5454') and establish breakdown rate and pressure. Pump a minimum of 260 cu. ft.' of Class "G" cement with 10% sand. Pull out of cement retainer and leave 50 linear feet of cement on top of retainer. (Cement plug from 5000' to 5454', plus 100' below perforations and 50' above the retainer, · Pick up 3 stands and reverse circulate any cement from the drill pipe. POOH. . RIH with a 9-5/8" cement retainer and set at 4450'. Pump into perforations (4472'-4870') and establish a breakdOwn rate and pressure pump a minimum of 250 cu. ft. of Class "G" cement with 10% sand. Pull out of cement retainer and leave 50 linear feet of cement on top of retainer. (Cement plug from 4450' to 4870', plus 100' below perforations and 50' above the cement retainer. ) · Pick up 3 stands and reverse circulate any cement from the drill pipe. POOH. 10. 11. 12. 14. RIH .with wireline and perforate (4 SPF) 1 foot in the 9-5/8" casing at 2000'· RIH with a 9-5/8" cement retainer and set at 1980'. Pump into the perforations and establish a breakdown rate and pressure· Pump 80 cu. ft. of Class "G" cement with 10% sand· Pull out of the cement retainer and leave 50 linear feet of cement on top of the retainer. Pick up 3 stands and reverse circulate any cement from the ~ri,~.~ RIH with cement retainer and set at 1250'. RIH and cut 9-5/8" casing at 1200' POOH laying down 9-5/8" RIH open ended and lay a cement kick-off plug from 1250' to 900'. (Note: 13-3/8" casing shoe is at 1059'·) 0488N (2) TBS A-16 PERFORATED INTERVAL Measured Depth True Vertical Depth 4472-4496 (Squeezed) 3931-3950 4540-4578 3983-4013 4628-4644 4052-4066 4650-4666 4070-4084 4708.4720 4116-4126 4856-4870 4236-4246 5042-5180 4387-4501 5219-5306 4534-4609 5332-5368 4631-4662 5444-5454 4729-4738 5662-5674 (Squeezed) 4924-4934 5858-5886 (Squeezed) 5009-5035 5890-5930 (Squeezed) 5129-5165 6944-7250 6079-6345 *NOTE: Perforations to be abandoned. 0488N (3) PRESENT PROPOSED 133/8', 61~,'J-55, Casing at 1,059' Top of Dip Tube at 4,353' elis Model RTl! Triple Packer at 4,414' ¢.~"1 SAND (4472'-,1496')Squeezed ! ND (4540'-4578') C-3 SAND (4628'-4666') C-4 SAND (47o8'-,172o') C-5 SAND (4856'-487o') ? C-7 SAND' (5042'-5180',52i9'-5306') 4 7-5 SA ND (5332'-5368') 4 7-5 SAND (5444'-5454',5622'-5640') 5d-3 S/iNO Squ~eze~ 5 1-6 SAND Squeezed 5 7-2 SAND Squeezed elis Model RTH Packer al 6,912' . Cml. Rlnr. flEA,LOCK FM. (6944'-7142',7162'-7250') 9 5/8', 40¢ & 43.5¢, J-.55 & N-80, Casing al 7,434' Cml. Rlnr. i /-2 "/18", ~,~.'~, N-80 Tubing Strings · Triple llydraulic Packer !] ZO~,IE 'PEI1FOfl^TIO}tS Single Permanent Packer IIEI~dLllCt( Fl'Cl. ?EFIFO[I~TIONS 9 5/8", 47,~, N-80, Casing T.B.S.. A- 16 Redrili ,, ~ ...... ~ ANGLED FILL UP LINE ,J ' IN HYDRIL '; ~; ~,0 .HYDRAULIC' - MANIFOLD ' )J~J.~l.j, _ .~ ~!:::::::::~ _...._- . SEE DRAWING~~~."_m'.~~(~-~"~')jl~'~(~-'.~'~(~'~'' KILL LiNE ~ ___ u ~,,,~,, .u..,,~--.L,,.--~ ~ ,.,-, } [ '"~ ~ '""' ~"~-'-'~/F~OM MUD PUM .S ~ J . . ~ & CEMENT UNIT - CONTRACTOR FURNISHED OPERA TOR FURNISHED NOTES' 1. HYDRAULIC VALVES OPEN WELL NAME: AUTOMATICALLY WHEN RIG CONTRACTOR: DIVERTER IS CLOSED. RIG: STACK PRESSURE RATING: 2. FLEX HOSE (~/~) IS TO BE uSED CHOKE LINE SIZE & MSP; IF NECESSARY WITH DDS' APPROVAL, NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT DEPTo APPROVAL REV. j DATE B DmCW~ BHE c~o. CGN ~.~~,~,~ 13 5/8". OPE STACK _B,A,.W,; 6/17/86 SCALE NONE 1 5M OR 10M ~,~ ~,~,~ .... ALL WORKOVER OPERATIONS , , UNION OIL COMPANY OF CALIFORNIA . J ANCHORAGE , ALASKA SHEETS S~EET FREE GAS KNOCKOUT k -I CHOKE MANIFOLD UNOCAL PLATFORM RIGS 4-1/16" & 3-1/8", 5M MSP UNION OIL COMPANY OF CALIFORNIA · CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (s) (3) Admin ~~ ~/~.~/~S 9. (9 thru 13) 10. z. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) <6) OTHER ~ ~/~/~g~ (29 thru 31) Company iIA/f.©A3 Lease & Well No. 7~;'~ /~ /~/g ~.i,.~ YES NO ~) _3 REMARKS' 1. Is the permit fee attached .......................................... ~ 2'. Is well to be located in a defined pool ............................. ~ 3.~ Is well located proper distance from property line .................. O~ 4. Is well located proper distance from other wells .................... ~__ 5. Is sufficient undedicated acreage available in this pool ..' .......... c~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. Cg 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. d~ Is. a conservation order needed ...................................... Is administrative approval needed ................................... ~_ Is the lease number appropriate ..................................... '~ Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of dlvcrtcrc_~d BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones~ ..... .... 30. Are seismic analysis data presented on shallow gas zones ... 31. If an offshore loc., are survey results of seabed conditions Geology: Engi~ering: rev: 02/17/88 6.011 32 Additional requirements INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. PROGRAM: LiSC$~,.~'J '~VlCION: 5 i PART Start of execution: Mon 16 JAN ,~9 1:23:~ **** R:~L HEADER **** LIS 8,:311011 7 ATLAS 01 LES CUSTOMER FORMAT TAPE **** TAPE HEADER **** LTS 8g/10/t? 3507 01 CN-DENSITY MAIN PAss.DENSiTY LOG ' : ~chorage CORRECTED AT THE COHPUTER CENTER. FiLE ~? I **** FiLE H~AOER **** MAIN .001 CN : UNOCAL WN : TRADING GAY FN · TRADING BAY COUN : KENAI ST~T : ALASKA UNiT TBF A-16 RD ~ORMAT RECORD (TYPE~ 64) ONE D:PTH PER FRAME T~PE .f3~PTH UNIT : FT 14 UNiT CTS CTS APl ~YTES 4 *~r~;~TA mECORD:, DEPTH CAL SSN (TYPE~ SSD TTEN LSN 96~,~. ~,,~YTES, * LS~ SPD CN GR DE N~' CNC T~PiP CORm P0RD 6 ~3,39,000 11'~ .,,.' ii 405 167! ,233 ~.~9739 15,,""-' 59.75396 2.4~9941 19.00000 0.0000000 0.0000000 9.094471 o739,000 I 5. 43481 1 09. 340 $ .339 3.75 9 73.95462 457,4404 26.730'39 57.97295 6o,4g031 2.146241 61 .97295 O. 0'300000 -0.2517605E-01 30.5303?. 670~ ,00~ 13,&5t2% 1 33.7!3! 450.5566 -!852.826 34. $OOz,') 459. 3376 :'6 23o'q ,._ . ~7 4o2o0 56.23152 4t.42290 O.O00OO00 0.~0~1~04E-01 3~i.30731 6x~9.OOi~ t4.77396 1t'1.~609 46!. 0964 ! "~'~,~ 437 64"~ 4~7~ ~0.22~40 5,:~ . 41 I 99 1 .952120 54,22440 '=O00OO0 42.29576 I 7 530~.~ 1 75 16S~'~ 339. 7350 -2<2.~ .'-..~673. 55,7!609 77.55119 13.40401 45.07976 ~.395236 17.40402 0.0000000 -0.2932549~-0~ 15.44022 6559,000 17,36110 231 .56~6 33P 1 -4,91 1 08. 0500 11,54504 45.31o02 2.37'~1 33 1 5. 5450~ 0. 9.942'_,23 O 2 E-O 2 16.41917 a21.6940 5527 9187 247.6169 ..; , ...; .. ",__ . ... 14,73017 45.60072 2.%7P588 17.73016 0 . qooooo0 0.3586~60E-01 1 6 =8958 6459.000 12.t0095 216.1!75 359,~900 1487,<77 2g5,559t 1 5.54832 42 1~3x2 2 lg.54~32 O. 54C046 7E-01 lO.23151 6409.000 1!.o6147 2t6 4~39. 2622 20;P.3254 -'. "61 2~.-~ 57._: 15.1!204 45.27567 2.331753 19.11284 0.0000000 '-'0133E-01 0.09,., 19,28534 1!.93239 204.430L 6309 ,.uO0 12.27977 ~259 GOO 1~,,~9566 61 59. 000 1 2.34720 159.0157 6109.000 17 31~4 , ~:~ 605~.003 I 2.5 31 (}7 2'3.2.. 11 64 6099.0fi0 12.35377 205.5573 12./-.,.0410 g~8.4464 590~ .009 I 'P ~,64° 1 210.9347 5609.000 12.46319 u, 2.o~14 ~7 50 000 1 2.43a, 56 210.7 ,? 1 2 20O. 0128 "J 3. ~', 951 t 554.7214 835.08~;4 42.02110 363 c~2'~ 110,00~3 ~2.12170 1977.3~o 39.45t~0 3 ,.*_~ 5. 0023 -7~9~'zlJ~ 47.6fiF:~I 344.6790 22~'x 7~ 0cI'70 340.1340 341 2,6C1 136.42191 333. o 71 9 3781 .971 107 I ~35..~313 74.84.821 337.158~ 3205.552 67.34320 :<27 2927, ~310 ~6.7~o10 28.65630. 16.52780 9.870913 27~.9021 2~,. :?6730 2© 11 ,'~2© 25.997t0 44,4364] 257.0044 2~ .76720 1 7.4,S7 96 273.227g ~8,77950 29 9~965 ~a6 231 2 79.13770 24.72974 265.7~46 2a.53320 Ig.64374 28.99120 9 ~3~~ i ~¢. ~ .... 2~,7 21 0901 5293 2S0,6575 29.59081 In c015~, 2/~~ n41 5 ~!;' 7g~10 2 3410'~5 20.527~3 ~1 437,515 2.4o3_P52 13.87'3.91 ~!.12274 2.34.5269 33.1132~ 2,44051.5 48.4~643 4a.3~059 2.302669 ~1.4&?o6 46.3719~ 2.230918 ~4 o3~65 71. 717~& 2. _;-: 936 ~6 28.72974 51. ~ 70 '35 P.~07oo4 2= ~4.3 74 45.50052 2. 43~6,33~_ 13.83522 46.12437 ?. 24.3°79 25.9o013 50.94774 2. 2721 3o 24. ~d, 8334 43.g036~ 2.259709 ,,:2. 501 5~ 47.19036 2. "71 51 4z; O. 9479713E-01 18.7~51z+ 0.0000000 0.476~848E-01 9.499872 n onoono0 ,, m ~J .,..., O. 11 39631 1 3. 58972 0.0000000 O.O356976E-01 12.69607 n r _ 00 ~,.. ~OOO0 -0.1 53541 6F-01 21.05037 ~,.O00OO00 -0.6170273E-01 22 3685';~ 0.0000000 -0.17,ol.8158-01 21.77~61 0. 0000000 -0.93'35995E-01 '"'C 731~4 O.OOOO00O -O.5S68053E-01 13.17071 O. 00000'30 -0.1152706E-01 24.69725 0.0000000 -O.e134129E-01 22. c;0067 0.0000000 -0.71.~570~c-01 O. 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'1321 ~ 2.138654 40. 561 ~4 03.01642 2,037025 57,68924 46.11933 2.22130~ 37.5699~ 52.~E626 ?,236323 34,~.9349 .58,1032c 2,265057 4.'5.73109 53.93 h2,~ ! .fi99og0 62.27719 5 7.1 6 dO6 I. 47O321 04.~,7737 1.354427 0,9000000 -0,¢478214E-01 30.25500 0 nOonono 0.3375053E-02 3t.69142 O,O0000OO -0,7572365E-01 27.77533 9. O000OOO -0.~3q;0531E-01 1 6.3 6003 0,0090000 0.!296425E-01 29.8oS39 O.OOOO000 -0.3186607E-01 30.99960 0.0000000 ~ ~8~2:~9~-01 37.0~544 O.O00OOOO -0.6516647E-01 25.og!57 0.0000000 -0, 7430935 E-©1 25 , !371 2 ? O.O000OO0 -0,4507923E-01 23,2~955 0.09000()0 0.6401157E-01 45.47357 0.0030000 -0.1151009 70.9502o 0.900900!3 -0.1 9~7065 105'~ 000 4:38 41*? 4.~":-.? n*:7^ '~.6,5':~0c ,3 c, O00000 14 ~974~ -2~27.~5r, 27 27100 1 ~44043 -n 1~o.35~'~ 1t3 I~.;~ ~ ~- 100~;'.0©0 119,'!::$¢~r~,~,,~., 87.9'al)7., ,_ ~x4.74390 O.O000OOO 1 2 '~940-,' -?,,? ........ .... ,02 4.02 27 79719 1 o4.S396 -1.--'_"~4017 132 9r~-9~ Ic 99340 ic, 9 76~4 !13 705~ 60 70323 TOTAL DATA RECORDS STARTING TAP? DEPTH ,=ILE Tq&ILER **** : 727 = 6809.00 ENDING TAP~} DEPTH 1000.00 13507 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL TAPE : 734 **** ~EEL LIS 881t0/17 ATLAS 01 TRAILER *'*** TOTAL RECORDS IN T~IS LOGICAL TOTAL RECORDS IN THIS PHYSICAL End of execu'tion: Man 16 JAN ~¢lapseci execu+ion., t4m,.~_. ._. = i] minutes,, SYSTEM R~TURN CODE = 0 REEL : R~EL: 1:26p 735 . ...5 sec oncJ ~. PROGRAM: LISCAN REVISION: 5.1 PART NUMBER: W579O-PE32 Start of execution: Thu 27 OCT 88 9:39a **** REEL HEADER **** LIS 88/10117 ATLAS 01 LIS CUSTOHER FORMAT TAP= **** TAPE HEADER **** LIS 88/10/17 3567 01 COMPOSITE OF MAIN AND REPEAT: DIFL,AC,CN/CDL. FILE # 1 MAIN .001 **** FILE HEADER **** 1024 FORMAT ONE OEP RECORD (TYPE# 64) TH PER FRAME TAPE DEPTH UNIT : FT I 3 CURVES : NAME I CHT 2 CILD 3 GR 4 RILM 5 RILD 6 RFOC CODE SAMPLEN UNIT 68 I LB 68 1 MMHO 68 I API 68 I OHMM 68 1 OHMM 68 I OHMM AR I ~T BYTES 4 4 4 4 RECEIVED DEC i ~, 1988 Aiask~ Oil & Gas Cons. Commission ' ~ ~chorage 9 CAL 68 1 10 TEMP 68 1 11 SP 68 1 12 AC 68 1 13 ACQ 68 1 INCH DEGR MV MSFT MSFT * DATA RECORD DEPTH RILD TEMP 6807.000 4.228197 0.0000000 6757,000 4,008Q65 0.0000000 6707.000 4.773224 0.0000000 6657.000 7.377876 0.0000000 6607,000 14.53991 0.0000000 6557,000 26.40327 0,0000000 6507.000 16.01175 0.0000000 6457.000 24.77917 0.0000000 6407.000 30.S1076 0.0000000 6357.000 -~0.04160,, 0.0000000 6307,000 1 3.33475 0,0000000 6257.000 4.908720 0.0000000 6207.000 (TYPE¢ CHT RFOC SP -11500.00 2.089005 -11.46686 -11500.00 4.261998 -12.56026 -11500.00 6.365759 -10.49299 -11500.00 9.1197:34 -11.79974 -11500.00 13.12161 -35.14961 -11500.00 24.36212 -46.08781 -11500.00 18,26462 -47.92749 -11500.00 20.81477 -48.61922 -11500.60 24.79135 -45,2~o84 -11500.00 26,25742 -41,88235 -11500.00 11.28747 -34.05382 -11500.00 5.624003 -17.46094 -11500.00 O) 101 BYTES CILD SPD AC 236.5074 26.90730 123,8626 249.4409 31 .99681 76.92496 209.5020 31.99681 90.88370 135.5403 32. ,o9670 114.7517 68.77621 30.59660 72.26633 37,87410 35,40721 58.73495 62.45412 32,50761 9t ,49818 40.35648 32,32361 78.62178 32.77533 32.50171 59,96793 33,28719 32.50041 77.45706 74.99202 32.51111 71.83777 203,7191 28.17989 87.07957 205.1386 GR TTEN 33.96136 -1817.618 0.0000000 33. 961 36 25.06918 3.000000 44.26199 144.6967 0.0000000 45.80772 -2487.326 0.0000000 75.77019 316.6541 O.CO00000 42.75134 1667.929 0.0000000 42,53221 -5=0~,, .3337 0.0000000 39.54012 -165g.501 0.0000000 42.66031 2037.077 4.000000 43.62073 1658.971 0.0000000 50.18407 -819.0532 0.0000000 77.90291 -6403.313 0.0000000 82.11728 2112.644 RILM CaL 3.931840 -1.000000 3.658139 -1.000000 4.317367 -1.000000 7.222853 -0.6584001 17.71683 0.0000000 21.83603 0.5662000 14.08900 1.033999 1.030400 22.57016 0.8979000 19.66528 1.966200 14.77785 1.024200 5. 231 968 I .0169~9 4.932838 1.196900 6157.000 I 5.51922 0.0000000 6107.000 20.9370/, O. 0000000 6057,000 1!.05762 0.0000000 6007.000 22.37839 0.0000000 5957,000 20.74016 0.0000000 5907.000 16.12500 0.0000000 5857,000 6.184449 0,0000000 5807.000 10.59531 0.0000000 5757.000 5.760018 0.0000000 5707.000 23.87581 0.0000000 5657.000 11.97910 0.0000000 5607.000 9.Q38942 0.0000000 5557.000 10.72424 0.0000000 5507.000 9,284500 0.0000000 5457,000 6.729303 0.0000000 5407,000 5.784573 0.0000000 -11500.00 16.46414 -26,81595 -11500,00 16.86574 -26.58421 -11500.00 10,77867 -22,94136 -11500.00 16.85719 -t9,42233 -11500,00 38.85901 -24.31766 -11500,00 15.24481 -24.10765 -11500,00 8,016354 -19.02724 -11500.00 10.69549 -21.85648 -11500,00 7.218930 -22.74756 -11500.00 21.32654 -13.55832 -11500.00 10.67771 -20,06398 -11 5 O0. O0 6,933313 -14.24840 -11500.00 9,637186 -23.54346 -11500.00 8,521946 -22.06158 -11500,00 7.587947 -13,66751 -11500.00 5.775552 -12.27868 64 28 84 47. 28. 86. r~O. 28. 91. 44. 28. 90. 48. 28, 53. 62. 29. 82. .43623 .49680 .44241 76222 49680 88841 43539 57100 12718 68597 63811 13777 21564 58279 18040 01549 15350 15854 161.6959 29,22031 86,70168 94,38141 29,20320 95.36592 173,6105 29.39061 98,85066 41.88339 29.27670 78,75464 83,47874 29,37950 101.5161 100.6143 29.59760 10t .2018 93.24669 29,40331 96,57510 107.7064 30,12361 95,80173 148.6038 29.99110 91.53349 172,8736 30,02681 95,00131 48.68871 1354.206 O.O00000O 46.21779 1746.234 0.0000000 59.63799 -1762.871 0,0000000 45.28087 3694.634 0.0000000 J7,81Q99 -2324.955 1.000000 48,41025 -878.1387 O,O0000OO 45.75761 1728.704 0.0000000 41.48Z89 4431.117 0.0000000 45.61758 4834.324 0.0000000 46.72253 3673,352 0.0000000 61.64552 1380.060 0,0000000 76.70551 -1640,634 0.0000000 55.68701 4147.000 0.0000000 61,98352 -2237.816 0,0000000 74.47195 -427.3870 0.0000000 75.87129 1256.402 0,0000000 12.76368 0.9830000 14.28299 2.087600 8.938002 0.9889004 16,66039 2.006300 23.59700 1.341600 12.78011 0.Q391004 6.704927 1.562500 10.16291 1.081400 6.218095 1 .521200 12.71420 I .675600 9.86R099 1.314801 8.268944 0.9696001 10.21612 1.312200 8,206627 0,~9269Q6 6.645897 1.926000 5.953069 1.314809 8.559147 0,0000000 5307,000 !0,09062 0.0000000 5257.000 14.68243 0.0000000 5207.000 8.263338 0.0000000 5157.000 7.382301 0.0000000 5107.000 28.80502 0.0000000 5057,000 6.579902 0.0000000 5007.000 21.53062 0.0000000 4957.000 10.40055 0.0000000 4907.000 6.096002 0.0000000 4857,000 7,373652 0.0000000 4807.000 13.10602 0.0000000 4757.000 6.734588 0.0000000 4707.000 11.39598 0,0000000 4657.000 4.740333 0.0000000 4607.000 4.316647 0.0000000 4557.000 A 11.21711 -33.78368 -11500.00 8.573725 -t8.94180 -11500.00 9. 1015C~7 -16.42387 -11500.00 7.883368 -22.82544 -11500.00 9.732037 -30.22694 -11500.00 17.48073 -11.98083 -11500,00 6.226821 -13.9660t -11500.00 19.54118 -8.804207 -11500.00 7.810619 -20.47983 -11500.00 5.731166 -13.03960 -11500.00 8.290377 -12.92965 -11500.00 12.07039 -24.72069 -11500.00 6.888091 -27.25690 -11500.00 10.11101 -12.30662 -11500.00 5.459394 -31 .95764 -11500.00 5.805512 -27.75597 -11500.00 ~_PPR77g 28,66451 100,9293 99.10191 28.66440 96.97646 68.10861 28.79111 118.4300 121 .0164 28.57349 103.8242 135.4591 28.86461 91.93839 34.71617 29.36140 128.0769 151.9779 29.42661 68.13026 46.44547 29.45830 127.3468 96.14879 29.20311 96.41284 164.0419 29.23300 106.6307 135.6180 28.02699 79.90019 76.30083 27.91780 72.54823 148.4872 27.63289 94.97429 87.75027 28.23299 113.9515 210.9556 28.63280 89.64439 231.6613 28.07069 90.04800 211.4627 28.32991 0,0000000 65.41898 -1024.178 0.0000000 48.34920 -1836.643 0.0000000 59.36263 -2199.960 0.0000000 45.70732 -540.5017 O.O00000O 52.50125 2621 .532 0.0000000 73.97501 1175.552 4.000000 47.66692 1295.658 0.0000000 61.23073 -6184.473 0.0000000 78.31531 109,0815 0.0000000 55.34001 -710.9915 0.0000000 42.84811 1114.034 0.0000000 41.27849 -3448.159 0.0000000 59.40086 -3586.321 0.0000000 42.73778 1910.063 0.0000000 62.85464 -386.4058 0.0000000 59.49475 5231.805 13.~2109 1 .032700 16.73886 2.125300 7.383998 1.590401 7.661842 0.9148999 27.25368 1.023200 6.784785 0.7460001 21.3o575 0,6708000 9.499630 0.3390000 5.944312 0.7290001 6.393983 0.5505000 17.19830 0.8399999E-01 7.161740 0.6708000 9.774355 -0.4728000 5.476517 0.1872000 4.647760 0.7485000 4.679506 0.4338000 4507.000 3.656754 0.0000000 4457.000 7.982718 0.0000000 4407.000 4.302455 0.0000000 4357,000 5,984969 0.0000000 4307,000 6,48751 2 0.0000000 4257.000 4.445653 0.0000000 4207.000 5.570199 0.0000000 4157.000 4. 76041 9 0.0000000 4107.000 5.520333 O.O000000 4057.000 6.579622 0.0000000 4007.000 6.373601 0.0000000 3957.000 6.974588 0.0000000 3907.000 4.83462~ 0.0000000 3857.000 3.34083.5 0.0000000 3807.000 7.123313 0.0000000 3757.000 5.679179 0,0000000 -11500.00 3.297195 -4.392282 -11500.00 5.288172 -3.322257 -1t500.00 4.548927 -7.432548 -11500.00 8.089985 -25.92870 -11500.00 6.303079 -26.21419 -11500.00 5.791317 -24.82071 -11500.00 6.563806 -3,664186 -11500.00 6.664429 -14.39340 -11500.00 5,509434 4.136242 -11500.00 5.360404 -8.018393 -!1500.00 7.588543 -6.387959 -11500.00 6.8441~)9 9.124992 -11500.00 4.526910 9.643555 -11500.00 3.355906 16.89175 -11500.00 6.695002 -12.53128 -11500.00 4,736605 -4.200753 273.4666 28.36559 67.99730 125.2706 28.62691 115.6680 232.4238 28.40929 95.04695 167.0852 28.53191 80.63510 154.1423 29,16750 94.24326 224.9388 29.14410 99.27530 179.5268 29.25810 79.02773 210.0655 29.32390 85.39154 181.1485 29.32390 102.7387 151.9844 29.40331 79.24500 156.8972 29.62860 74.15927 t43.3776 29.27071 82.33560 206.8414 29.82071 98.47810 299.3264 30.15341 106.3542 140.3841 30.12361 104.5557 176.0818 30.29990 106.1005 6 -7 O. 8 -4 O. 4 1 O. 4 -8 O. 4 4 O. 8 -4 O. 4 -5 O. 5 -2 O. 4 -5 2 4 7 O. 5 -2 1 4.81 837 32.7571 .000000 6 3 O. 6 -2 O. 7 -5 1 2.29126 87.2483 0000000 3.25900 25.6470 0000000 3.17767 308.240 0000000 4.34836 44.4087 0000000 5.98485 642.645 0000000 2.87082 98.7661 0000000 2.44156 049,082 0000000 5.75169 426.590 0000000 0.36075 039.184 .000000 2.43829 66.9058 0000000 4.41988 172.841 .000000 73.~2485 540.0942 1.000000 9.29767 113.854 0000000 8.79723 010.810 0000000 9.01451 52.842R .000000 3.520539 0.4712000 12.84830 0.6653000 3.959686 0.3171000 6.725820 0.3560000 '::: 7421 58 0.34,63031 4.660440 0.5978000 5.134957 0.5757999 5.480929 1.009500 4.564448 0.3972000 7.391360 0.6816000 6.258726 1.514101 6.553550 0.841o001 4.699~20 0.5089999 3.518244 1.009700 5.471317 0.5687000 5.055880 O,~ ~943000 0.0000000 3657.000 28.62053 0.0000000 3607.000 17.77777 0.0000000 3557.000 4.425823 0.0000000 3507.000 2.601189 0.0000000 3457.000 4.601343 0.0000000 3407.000 11.20461 0.0000000 3357.000 6.459174 0.0000000 3307.000 2.775531 0.0000000 3257.000 3.219627 0.0000000 3207.000 3.816193 0.0000000 3157.000 3.103209 0.0000000 3107.000 6.209304 0.0000000 3057.000 4.531289 0.0000000 3007.000 3.686032 0.0000000 Z957.000 3.905394 0.0000000 2907.000 7.713596 -3.383229 -11500.00 19.91843 -7.770119 -11500.00 12.50258 -0.7547826 -11500.00 4.400628 -3.528018 -11500.00 3.361375 -15.00006 -11500.00 4.414211 -4.996390 -11500,00 8.797880 -6.477250 -11500.00 4.622830 0,4434032 -11500.00 3.257091 4.856592 -11500.00 3.355367 4.345010 -11500.00 3.912692 -6.402472 -11500.00 3.653052 -4.984994 -11500.00 5.623665 5.905490 -11500.00 3.564607 7.239952 -11500.00 3.382535 8.873308 -11500.00 3.336562 8.641825 -11500.00 4.585961 E-01 .'>U · U¥~ I 114.3769 34.93996 30.19720 107.6633 56.25000 30.12361 131.7502 225.9467 30.17329 107.8000 384.4397 30.00291 105,3772 217.3278 30.72322 109.2365 89.24895 30.99692 110.1614 154.8185 30.79671 123.7717 360.2915 30.79681 131.5105 310.5950 32.06442 110.9061 262.04t3 33.20268 117.1t77 322.2471 27.25829 134.5588 161.0486 27.10059 132.3927 220.6877 27.16769 121.3941 271.2944 27.83490 109.2606 256.0562 27.89389 114.5349 129.6412 27.99719 0.0000000 45.57990 1996.239 1.000000 33.88115 633.2673 0.0000000 76.69290 718.4749 0.0000000 42.49518 -1399.756 1 .000000 66.34109 -4391.152 0.0000000 43.31708 -1756.849 O.O000000 68.53072 1808.691 0.0000000 62.92680 2314.762 0.0000000 65.70578 886.2769 0.0000000 47.74294 -1790.388 0.0000000 48.07332 479.2358 3.000000 62.64575 -7.846069 0.0000000 69.51857 -301 .8789 4.000000 72.22928 3072.778 0.0000000 66.62042 910.7910 0.0000000 62.32980 -2554.307 U.g~IOUUU 18.80208 1.066599 22.98904 0.0000000 4.199517 0.0000000 2.8452_57 0.7520002E-01 4.542648 0.0989997 10.72555 -0.1504000 ~.754254 -0.5590001E-01 2.502105 O. 1000017E-03 3.128676 -0.3292000 3.821926 0.1460000E-01 3.236055 -1.307402 5.492255 -1.897901 5.670326 -5.288000 3.610318 -15.69151 3.740554 -10.98300 6.306185 -8.000002 2857.000 20.75648 0.0000000 2807.000 24.64375 0.0000000 2757.000 5.9~1255 0.0000000 2707.000 6.254268 0.0000000 2657.000 7.678780 0.0000000 2607.000 15.44663 0.0000000 2557.000 3.034948 0.0000000 2507.000 1.991321 0.0000000 2457.000 2.423456 0.0000000 2407.000 2,332334 0.0000000 2357.000 2.796590 0.0000000 2307.000 3.588051 0.0000000 2257.000 2.968095 0.0000000 2207.000 2.380837 0.0000000 2157.000 10.08632 0.0000000 2107.000 4.128249 0.0000000 -11500.00 24.99524 13.32427 -11500.00 20.88980 -17.73071 -11500.00 5. 281 898 -15.86843 -11500.00 4.537965 -15.71145 -11500.00 6.323539 -17.82561 -11500.00 14.93378 -8.919065 -1i500.00 2.650769 -14.51222 -11500.00 2.582897 -24.64230 -11500.00 2.711674 -24.14006 -11500.00 2.851508 -26.2~221 -11500.00 3.344113 -16.37869 -11500.00 3,370236 -12.5849t -11500.00 3.658181 -26.37115 -11500.00 3.667271 -25.84244 -11500.00 8.142000 -13.90036 -11500.00 3.140355 -11.67174 48.17770 28.16760 161.4294 40.57825 28.31129 147.6277 168.8823 27.96739 108.9811 159.8908 27.99719 110.9210 130.2290 28.02699 113.9138 64173904 28.17349 147.0925 329.4949 24.68011 117.9437 502.1792 25.99739 138.1832 412.6338 32.71710 126.8510 428.7551 27.99719 179.6800 357.5784 28.32639 117.7990 278.7029 28.15948 107.3883 336.9165 28.07660 115.2581 420,0203 28.15009 103.8201 99.14415 28.27669 127.7129 242.2334 28.99710 205.5041 20.00034 1191.013 0.0000000 24.23933 -1000.174 1.000000 71 .78769 1750.912 0.0000000 68.18755 1033.131 0.0000000 66.31342 -454.2195 0.0000000 24.26885 411.7437 0.0000000 72.73901 3505.288 0.0000000 42.35390 135.1351 0.0000000 43.96912 223.7652 0.0000000 38.05260 403.6426 3.000000 65.31569 675.5249 0.0000000 71.30173 4740.207 0.0000000 37.87302 -1997.460 0.0000000 40.33875 4260.203 O.O000OO0 48.39615 -529.1069 3.000000 50.02127 1408.333 I .000000 27.82877 -5.010800 18.78256 -3.254001 5.885606 -2.127401 6.254760 -1.450900 7.030064 -1.049800 21.64151 0.0000000 2.815962 -0.2540000 2.141575 -0.1400000E-01 2.571648 0.5262001 2.763760 -0.6486001 2.949438 -0.8032001 3.369424 -0.72¢0071 2.977831 -1.538200 2.708398 -1.410600 9.976007 0.5370001 3.798033 0.18200005-01 1:! . ~/(0.3 0.0000000 2007,000 4,777659 0,0000000 1957,000 3,619087 0,0000000 1907,000 3.290552 0,0000000 1857.000 2.688204 0.0000000 1807.000 2.407'522 0.0000000 1757.000 2.392891 0.0000000 1707,000 3,773738 0,0000000 1657,000 3,915713 0.0000000 1607.000 2.983957 0.0000000 1557,000 4.688766 0.0000000 1507.000 10.33427 0.0000000 1457.000 8.378193 0.0000000 1407.000 5.012797 O.OOOO000 1357.000 9.249121 0,0000000 1307,000 9,797482 0,0000000 1257.000 5.060966 ).O0~U-IY -7.860851 -11500.00 3,898328 -3.000171 -11500.00 4.580527 -18.36537 -11500.00 2.480614 -7.811632 -11500.00 2,437506 -6.544626 -11500,00 2.445236 -7.655418 -11500,00 2,702997 -13,92977 -11500.00 3.594272 -t2,37817 -11500,00 3.321812 -10.41783 -11500.00 3.327217 -t8,4318t -11500.00 4.031861 -18,71411 -11500,00 7,186838 -21,16418 -11500.00 6,016042 -21,72729 -11500.00 3,955695 -21.50279 -11500.00 7.403831 -27.84505 -11500.00 6.414745 -30,95331 -11500,00 3,972850 148.7679 209.3075 29.49741 194,7860 276.3127 29.34100 209,6727 303.9004 29.84061 173,9984 371,9956 29.65311 122.3667 415.3647 29.56100 134.5117 417,9045 29.49741 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TAP=, ~. --- CREAT$O_ 5Y qE;q~ ~ PROGRAH ,,o 2.0 TOTAL RECORDS IN THIS LOGICAL REEL : 6 5 TOTAL RECORDS IN T~ZS F, HYSICAL REEL: ,635 ~nd of execut±on: Mort 15 JAN ,'.8g 1:42o 'laosecl execui:ion 'time = 2 minuteS, 5t.0 seconds. _~YSTEM RETURN ,.,uDE = 0
