Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
169-017
(-QL9,--0�_7 v\l��cosr Tis UNITED STATES ENVIRONMENTAL PROTECTION AGENCY APR 2, 5 2014 REGION 10 W 1200 Sixth Avenue, Suite 900 z Seattle, WA 98101-3140 r 9<!>gOZe APR or-FicF or COF:lVLIANCE AND ENFORCUAVN`( Reply to: 0C'1"-127 CE'R'TIFIED MAIL - RE"I'L1RN iiI?('t?11''1' ltt?t1tiES'I'E D Mr. William G. Britt,.lr. D -j5 -v ➢22, Environs-ncntal Manager K,-1 l --' K4 -R) Hilcorp Alaska, LLC t L C,I 3500 Centerpoint Drive, Suite 100 Anchorage, Alaska 9950; Re: Under01-ound Injection Control (tJIC) Program Under Pcrmit Dumber AK -1 1006-A substitution of alternate candidate wells: Class I Well DI5-RD2 with D22, Dolly Varden Platlorm, Trading Bay Unit, Cook Inlet, Alaska Class I Well K1 I with K4 -RD, King Salmon Platform; "Trading Bay Unit, Cook Inlet, Alaska Class I Well G16 with G19, Grayling Platform, Trading l3ay IJnit, Cook Inlet, Alaska Dear Mr. Britt: The U.S. Environmental Protection Agency, Region 10 (EPA) has received your request to substitute three listed candidate wells with three alternate candidate wells on three separate platforms. Per the Class I Underground ]ejection Control permit AK.11006-A Part It, A., 1., the permittee is authorized to substitute alternate candidate wells. The EPA approves the permittee's request to substitute Class 1 Well D 15-RD2 with D22 on the Dolly Varden Platform, Class I Well K 1 1 with K4-R.D on the King Salmon Platform, and Class I Well G16 with G19 on the Grayling Platform. All candidate wells are located in the Trading Bay Unit, Cook Inlet, Alaska. If you have any questions regarding this matter, please contact Thor Cutler of my staff at (206) 55? -.1673, or email: cutler.thor(i .epa.gov. Sincer> , G �dwarr J. walski Director 9ANNS v 1, i l 12 0 14 cc: lidhris Wallace Alaska Oil and Gas Conservation Commission -Anchorage Marc Bentley Alaska Department of Environmental Conservation -Anchorage , STATE OF ALASKA ALlikA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well❑ Plug Perforations ❑ Perforate ❑ Other PJ Shut-in Inj.Well Performed: Alter Casing ❑ Pull Tubing El Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory ❑ 169-017 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service 2 6.API Number: Anchorage,AK 99503 50-73320178-00 7.Property Designation(Lease Number): 8.Well Name and Number / C 4:,: ADL0017594 Trading Bay Unit G-19 ✓ 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NOV l 0 2013 McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: 40GCC Total Depth measured 12,291 feet Plugs measured 11,180&11,043 feet true vertical 11,307 feet Junk measured N/A feet Effective Depth measured 11,180 feet Packer measured 9,840&11,034 feet true vertical 10,336 feet true vertical 9,146&10,210 feet Casing Length Size MD ND Burst Collapse Structural 363' 26" 363' 363' Conductor Surface 520' 17-3/4" 520' 520' Intermediate 4,749' 13-3/8" 4,749' 4,535' 3,090 psi 1,540 psi Production 11,217' 9-5/8" 11,217' 10,368' 5,750 psi 3,090 psi Liner Perforation depth Measured depth See Schematic feet SCANNED {�-, f True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 2,027'(MD) 2,0274'(ND) Model D Packer 9,840'(MD)9,146'(ND) Packers and SSSV(type,measured and true vertical depth) BWH Packer 11,034'(MD)10,210'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ D 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: 313-465 Contact Ted Kramer Email tkramer(athilcoro.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature %:v' G �� _�`— Phone (907)777-8420 Date 11/5/2013 1 t.zv.i3 RBDMS NOV - 6 Form 10-404 Revised 10/2012 101 1 Submit Original Only i7/2.-...- II • • McArthur River Field,TBU SCHEMATIC Well: G-19 As Completed: 10/05/2013 Nileorp Alaska,I I RKB to TBG Head=42.78' CASING DETAIL Tree connection: Size Wt Grade Conn ID Top Btm Cmnt J 26" 1/2"Wall Surf. 363' Driven 17-3/4" .312 wall Weld Surf. 520' 17-3/4" 13-3/8" 61 1-55 Seal Lock 12.515 Surf. 4,749' ©520' 9-5/8" 47 N-80 Buttress 8.681 Surf. 76' & -^ 9-5/8" 40 N-80 Buttress 8.835 76' 4,981' 11-* IP / 9-5/8" 43.5 N-80 Buttress 8.755 4,981' 6,853' 5k( l 9-5/8" 47 N-80 Buttress 8.681 6,853' 8,421' 9-5/8" 47 P-110 Buttress 8.681 8,421' 11,217' Scab Liner G Leak identified 7" 29 L-80 Buttress 6.184 5,152' 6,608' None +1-2,709' Tubing Detail 13-3/8"@ 4-1/2" I 12.6 L-80 I Buttress I I Surf. 2,027'Kill String 4,749' L S. JEWELRY DETAIL *Squeezed @aear el No Depth ID Item 42.78' 4-1/2"8rd Tbg Hgr, 1 9,840' Model E Anchor. 2 9,840' 4.75 Baker Model D Packer set on wireline,ELM 3 9,844' 4.75 Mill out Ext. 9,847' Tubing tail is screwed below packer seal bore ) 4 9,884' 3.813" 4-1/2""X"Nipple 5 btm 9,917' 3.96" WLEG with shear-out solid nose ■ 7 11,034' 4.000" Otis BWH pkr 8 11,043' 2.635" 3-1/2"Otis"XN"nipple with plug 9 11,045' 2.99" 3-1/2"tubing tail WLEG 9,840' Eir 1 II FISH e 413 8.5"bit cleaned out to 11,1018'DPM 6/11/1998 11,1018' SLICKLINE WORK Tagged fill w/pressure bombs 34202 11,035' i----N 2.4"GR prior to BHP survey 35765 11,010' 4 Tag fill 39515 11,006' = B-1 PERFORATION DETAIL - B-2 Zone Interval(MD) Interval(TVD) Amt Date Status =B-3 -B-4 HB-1 10,565' 10,595' 9,800' 9,826' 30' 12/11/1989 Open B-5 HB-2 10,610' 10,715' 9,840' 9,932' 105' 12/11/1989 Open 7 " :„ >< HB-3 10,735' 10,830' 9,950' 10,034' 95' 12/11/1989 Open HB-4 10,860' 10,910' 10,060' 10,103' 50' 12/11/1989 Open HB-5 10,930' 11,030' 10,120' 10,206' 100' 12/11/1989 Open 9 ` B-6 HB-6 11,050' 11,115' 10,224' 10,280' 65' 4/22/1969 Iso. B 7 HB-7 11,140' 11,152' 10,301' 10,312' 12' 4/22/1969 Iso. Bridge Plug @ 11,180' 9-5/8"@ 11,217' G ff. 8-1/2"TD=12,291' MAX ANGLE=28°@ 4,400' KOP @ 2,000' • Hilcorp Alaska, LLC I lifeurp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-19 50-733-20178-00 169-017 9/8/2013 10/5/2013 Daily Operations: s1 4" 09/08/13-Sunday Check pressure on tubing.(9-5/8"and 13-3/8"casing) Finish setting up rig. Set BPV. ND tree.Test waived 9/8/2013 by Jim Regg. P/U Riser,nipple up to wellhead. N/U BOPE. M/U unbolt to mudcrosses. P/U rig floor. R/U hand rails. R/U up test lines and test pump. Function test BOP and accumulator. Fly tongs,elevators,TIW,crossovers,pump T,and IBOP on floor.Change out BPV with 2 way check. M/U test joint,TIW,IBOP and pump in to fill stack.Test BOP.Had problems with first chart recorder. R/U second chart recorder. Annular tested good. 09/09/13-Monday Attempt 3,000 psi test on K3 valve. Found leak. Continue to test other BOPE equipment 250 psi low/3000 psi high.Test good. Witness of test waived by Jim Regg,AOGCC on 09/08/13.Will work on K3 valve.Replace K-3 valve.Test good.Complete with BOPE test. R/D test equipment. Pulled 2 way check. RIH with 4-1/2"buttress joint.Spot Eline unit. R/U wireline,back out hold down pins. P/U string wt.plus 20K. R/U Eline unit TIH with Hole punch.Correlate with Packer and 6'pup jt. Punch hole @ 9,789'. POOH. M/U Radial torch cutter TIH to 9,792.5'made cut. POOH with Eline. P/U off slips 108K. Unable to pull hanger through annular. Bleed down accumulator,disconnect line to annular/bleed off lines. Pull hanger. Lay down hanger and lift joint. Recharge accumulator, reconnect annular,Circulate at 3bpm,displace hole with FIW to Trading Bay.800 bbl.hole volume.Showing 250 psi on 13-3/8"casing.Showing 250 psi on 13-3/8"annulus.Current operation. 09/10/13-Tuesday Continue to circulate well clean. 09/11/13-Wednesday Continue to circulate well clean. 09/12/13/-Thursday Continue TIN picking up 3-1/2" PH-6 work string in singles. PU power swivel/Function test swivel/MU to workstring. Make up jt. 306 and 307 on the power swivel. Latch on to the fish and jar @ 140k and 150k.Get off the fish and lay down jt.307 and pick up 12 ft. pup jt.Latch on the fish and pick up. Lay down pup jt.and rig down power swivel. Pull out 153 std.50 std.and BHA in the hole.Shut down for rig repairs. No fluid loss. 09/13/13-Friday Repair to rig completed. Begin POOH with workstring 3-1/2" PH-6 tubing and BHA#1 overshot assembly. POOH with overshot assembly and 21'cut tubing stub,5.15 pup joint and model E anchor latch with seals. Break out/LD fishing assembly and anchor latch assembly.Spot E-line unit/RU wireline lubricator and sheaves. PU/MU MIT mechanical inspection tool for 9-5/8"40.0-47.-# casing. Log 9.625 casing---rig down wire line unit and lubricator. No fluid loss in the well. 09/14/13-Saturday Change out 2 chains in the draworks. Pick up BHA 2,trip in 162 jt.and rig up power swivel. Fluid restricted pumping down the tubing.600 psi on the 13.375 ann by pass manifold and find the restriction in the kill line side.Open the choke line side and cir. back to the flat tank.Make the cut @ 5,213'pumping 4 bbl./min.with 400 psi on the tubing and 100 psi on the 13.375 casing ann. BHA no.2--multi string cutter 5.5"X.5",2.375"---stabilizer 6.0"X2.5",3.79"---4 DC.4.75"X2.0"---X/O 4.68"X2.37", 1.27". Rig down the power swivel and the stripping head.Trip out--lay down BHA no.2. Pick up 4 DCs for a total of 8-8-1/2"OD tapered mill,8-1/2"OD string mill,xo,4-3/4"OD bumper/oil jars,(8)4-3/4"OD drill collars,xo to 3-1/2" PH-6 workstring.20bbl total fluid loss.Max 1200 psi on 13 3/8"annulus during restriction in hose. Now 50 psi. • Hilcorp Alaska, LLC • Hit,.orp Alaska.LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-19 50-733-20178-00 169-017 9/8/2013 10/5/2013 Daily Operations: 09/15/13-Sunday PU McCoy hydraulic tongs attempt to MU milling assembly.Tongs would not bite. RU 60"wrench assembly and MU milling assembly.8-1/2"OD tapered mill,8-1/2"OD string mill,xo,4-3/4"OD Bumper/Oil jars,(8)4-3/4"OD drill collars,xo,3-1/2"PH-6 workstring. TIH to 3,580'tagged tight spot. Milled and reamed tight spot several times while reversing.Still takes 2K to go through with out rotation. Recovered corrosion scale,small beads and pieces of plastic coating.Continue in hole to 5,162'. Rig down power swivel. Trip out and lay down BHA no.3. Pick up BHA no.4--Hang BJ tongs to make and break 4.5 IF connections in BHA 3 and 4, BHA no.4--3.5"mule shoe 5.00"--x/o 2.11"--x/o 1.10"--x/o 1.17"--magnet 19.47"--brush 14.28"--x/o 1.12"--x/o 1.04"jars 7.85"--oil jar 11.02"--8 DC 249.20--acc jar 11.81"--x/o 1.27". Trip in with the brush and magnet--work every stand twice--cir. bottoms up every 20 std. Fluid Loss 24 hrs. 13 3/8" psi 09/16/13-Monday TIH with 9-1/8"OD Bristle Brush and magnet assembly,working each stand twice,circulating BU every 20 stands. BOPE test waived by Jim Regg at 9:28am.Tagged top of scab liner entry sleeve at 5,159'. PU 22'and displace wellbore with FIW.Record pump output rpm's to strokes.Check pump strokes to Choke panel. Maximum SPM 184 at 2100 RPM is 7.3BPM at 90%efficiency. POOH with BHA#4.Stand back drill collars,break out lay down Bristle Brush and Inline Magnet assembly.Shut in well. Prepare for BOPE test. Pressure test BOP.Test pipe rams,blind rams,choke line valves,kill line valves,all to 3000 psi high and 250 psi low. Test annular to 1500 psi high and 250 psi low.Test good.Witness of test waived by Jim Regg,AOGCC. Pick up Model 3L Packer type RPB BHA#5 and trip in and set plug @ 5,163.68'. (163 jt.tubing,5,151.98'--BHA RPB and 2 x/o subs 11.70)bottom hole at 4,964.6'. Note(upper hole at 3,580'), POOH with RPB setting tool. PU/MU Champ packer with RBP retriever tool on bottom.TIH with BHA#6. Fluid loss 24 hours 30bbl. 13 3/8" 100 psi. 09/17/13-Tuesday TIH to 1,600'Champ packer hanging up or pre-setting. POOH check Champ packer. No problems.TBIH to 4,944'and set packer. Record injectivity rates at 1/2 bpm-500 psi. 1 bpm-1000 psi, 1 1/2 bpm-1100 psi,2 bpm-1200 psi,3 bpm-1400 psi. Release packer and pull up hole 110'to 4,834'. Reset packer open valve. Mix 30 bbl Poly Plug HSFL Ultra Squeeze hole plugger.Pumped 23 bbls then added 5 sacks Ultra Seal Plus to 7 bbls, pumped that away and spotted plug material at 4,964'. Pumped 2100 strokes with final pressure of 1200 psi holding. Pressure bled off 100 psi to 1100 psi. Hold for 1 1/2 hour. Pick up 100 ft.and reverse out. Wait 3 hours.Wash down past the hole @ 4,964'.Pull back up to 4,850'and pressure test with 350 psi @ surface for 15 min. Held OK. Trip down to the bridge plug set @ 5,163'.Washed down last 3 jt.Cir.and clean up the top of the bridge plug prior to latching on. Engage RBP and release pull up above repaired hole at 4,964.6'reset RPB set weight down,confirmed RPB is attached.Pulling up the hole to 3,790'to reset RPB below top hole. Fluid loss 24 hrs.0. 13 3/8"csg. 100 psi. 09/18/13-Wednesday Pull bridge plug and reset at 3,780'. Pickup and reset packer at 3,470'. Get injection rate and start mixing pill and prepare for squeeze. Pump poly plug--monitor pres.on 13-5/8"and 9-5/8"for 1.5 hours. Bleed off pressure and cir.and reverse cir.2 bottoms up.Wait 2 hours.Set packer and try to pressure test the well to 350 psi. No test,still communicating with the-9=5/-81—ann. Try to release packer to go down and retrieve the bridge plug. Packer will not travel down. Pull out of the hole and lay down the packer. Trip in with overshot to retrieve the bridge plug. Tag at 3,760'.Wash down to packer at 3,780'. 09/19/13/-Thursday Washing down with RBP retrieval tool. Latch on to/unset RBP. POOH. Elements on champ packer swollen. RBP ok. Pick up Fishing BHA to retrieve ZXP PBR.5.75"od ITCO spear,8.50"stop sub,x-o,x-o,4.75"bumper jar,4.75"oil jar,8 ea.4.75"drill collars,4.75" accelerator,x-o.RIH. RIH with ZXP PBR retrieval BHA. Pump pit over to Trading Bay-260 bbls.Cir. @ 2.5 bbl/min--tagged liner top @ 5,160'-Slacked off 15k. Picked up with+/-5k overpull.Worked up/down couple of times. No overpull seen after initial pick up. Placed pipe in neutral. Rotated pipe to left 2 times. Pipe jumped indicating something broke loose.Picked up with no overpull. POOH checking each connection.Connection between stand 2 and 3 loose. No fish/grapple in release position. Rig down power swivel.Trip out and lay down tools. Nothing retrieved.Pick up bridge plug and RIH. . •Hilcorp Alaska, LLC . ►s<<„ ,f:��.,�►:..LIA Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-19 50-733-20178-00 169-017 9/8/2013 10/5/2013 Daily Operations: 09/20/13-Friday RIH with retrievable bridge plug.Set RBP at 3,630'. POOH with bridge plug running tool.Pick up Champ packer. RIH,Set Champ packer at 3,467'w/15k down.Close Hydril attempt to pressure annulus. No pressure.Getting returns on tubing.Shut down pump. Pull 1 stand. Set packer with 20k down. Pressure annulus.400 psi on 13-3/8"with no returns on tubing. Bleed off psi. Pull 5 stands. Pull 5 stands. Pressure annulus.400 psi on 13-3/8". No returns on tubing. Pull 5 stands, Pull 5 stands. Pressure annulus. 400 psi on 13-3/8". No returns on tubing. Pull 5 stands, Pull 5 stands. Pressure annulus.300 psi on 9-5/8",0 psi on 13-3/8".Packer set at+/-2,470'. RIH 2 stands. Pressure annulus.300 psi on 9-5/8",0 psi on 13-3/8". RIH singles and identify top of leak.Leak identified at+/-2,709'. RIH and retrieve bridge plug. POOH. Lay down tools. RIH and retrieve bridge plug. POOH. Lay down tools. Pick up tools to spear liner hanger and RIH. 09/21/13-Saturday RIH w/fishing assembly to retrieve ZXP upper extension. Rig up power swivel. Break circulation. Record up and down weights-61k down/67k up.Slack off to 45k and latch grapple into ZXP ext. Pick up to 85k and confirm grapple latched.Work pipe up down while activating jars.Slack off to 50k and pick up to 130k. Placed pipe in neutral and applied left hand torque-+/-3000 ft/lbs. worked pipe up down several times without activating jars.After several attempts with no success began working pipe up and down and activating jars while holding torque in pipe. Eventually lost our torque. Put a total of 6 rds to the left and string came free.Our pick up weight now 70k. POOH,OOH. No fish.Oil jar backed off from bumper jar.RIH to screw back into bumper jar. RIH. Rig up power swivel.Screw back into jaqrs. Rig down power swivel. Prepare to POOH.Check connections while coming out of hole. POOH.At drill collars.Change tongs. Rack collars. 09/22/13-Sunday Rack drill collars. BHA OOH complete. Inspect BHA tools.Grapple damaged.Stop sheared off.Change out BHA. RIH w/milling BHA. Pick up power swivel/rig up. Rig halls head/power swivel and line up manifold to reverse cir.--Start cir. @ 3.5 bbl./min and 88 rpm.Start milling @ 5,160'and milled down to 5,166'.--cir.bottoms up. Rig down power swivel and halls head. POOH. 09/23/13-Monday Lost hydraulics on rig. Rig back up. RIH with milling assy. Rig up power swivel. Begin milling.Circulate at 3.5 bpm.250 psi on tubing.300 psi on 13-3/8"gauge.2-3k weight down on ZXP.600-800 ft/lbs of torque.After several hours very little hole made- possibly 10-12 inches.Continue milling. No fluid losses. Rig down power swivel and prepare for trip out. POOH. Work on rig hydraulics. 09/24/13-Tuesday POOH. Pipe over torqued due to milling job. Inspect BHA. Mill in good shape. Lay down BHA, BOP test.Cannot get test plug to set and test. Pulled plug twice.The last we ran in just above the hanger and circulated/washed. Ran plug back in. Finally seated properly and tested. Perform BOP test.Test all components 250 psi low for 5 min.Test the annular to 2500 psi high.Test the blind and pipe rams,all valves to 3000 psi high.All tested OK. Perform a draw down test on the accumulator.AOGCC on the platform to witness the test.AOGCC agent Bob Noble on site to witness BOP test. Pick up tools and trip in. BHA. ITCO SPEAR,SPEAR STOP SUB, X/O SUB, LUB BUMPER JAR,OILJAR,8 DC'S,ACCELJAR,&A X/0 SUP---TOTAL LENGTH 286.12'. Engage ZXP and begin jarring. 09/25/13-Wednesday Engaged ZXP with spear.Jarring on fish. Rig up power swivel to release grapple. POOH.Pick up Milling BHA. RIH. Pick up power swivel and halls head.Milling from 5,160 to 5,161.(dry drill, 120 rpm, 10,000 on mill,torque 3000-6000)No fluid losses. BHA--MM PACKER MILL,2 BOOT BASKETS, BIT SUB, MI DOWNHOLE MAGNET,X/0 SUB, LUB BUMPER JAR,OIL JAR,8 DC'S,ACCEL JAR,X/O SUB. 09/26/13-Thursday Mill on ZXP. POOH with milling assy. Rig up wire line and go in the hole with shot.Get on depth using collar locator. Fire string shot.Top of ZXP 5,167'--top of hanger 5,175'--top of casing 5,180'--casing cut 5,213'--casing collar 5,226'. Pull out of the hole with wire line. Rig down WL.Pick up milling BHA.RIH. • • Hilcorp Alaska, LLC I liteorp 11a..ka.IAA Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-19 50-733-20178-00 169-017 9/8/2013 10/5/2013 ,b0fly Operations: 09/27/13-Friday RIH w/ZXP milling assy. Pick up/rig up power swivel.Tagged fish. Pick up wt 68k Slack off wt 58k free rot torque 3k. Position mill just above fish.Start rotating.Slack off 3k on fish.Torque jumping between 3200 and 5600 ft/lbs. Rev at 3.5 bpm.250 psi pump pressure.300 psi on 13-3/8.Good cuttings coming back over shaker. No fluid losses.+/-24-30"milled off. Penetration rate slowed down.Continue to mill with 3k down.Same parameters as above. No penetration in 1-1/2 hrs. Power swivel stalling out. Pick up. Getting+35k overpull after+/-7-8 feet of pick up travel.Weight falls off. Repeat this several times. Intermittently tagging 7-8 ft high while slacking off.Cannot get back to bottom.Several attempts and we are tagging 1-1-1/2 ft high. Lay down power swivel. Pull 5 stands. RIH back to bottom.Encounter obstruction 7-8'above fish.Work through.Tag fish within 6"of the mill off point. Work pipe up/down several times. Encountered no drag in either direction. Rig up power swivel.Change hall head rubber. Milling on packer, reverse cir.with 3 bbl.min. 100 rpm's and 4 to 10,000 wt.Torque fluctuating between 3 and 5k. No excessive torque build up. No fluid losses.Saw no overpull or drag when working up/down. Rig down power swivel and halls head and POOH. Pick up spear and grapple. RIH. 09/28/13-Saturday RIH w/spear.57k dn wt 65k pu wt. Encounter obstacle a couple of feet above fish.Sit down 3k.pick up w/5-6k overpull.Slack off. Push through with+/-10k dn. Engage fish on depth.Jar on fish.70k over up to 90k over. No movement. Release grapple. POOH. Rig shut down for transmission repairs. 09/29/13-Sunday Rig down_for repairs.Pull remaining stands and lay down BHA. Lay down BHA. RIH w/tubing,On bottom. EOT 5,177'.TOF 5,168' (Workstring depth). Rig up to clean hole using waterflood taking returns to Trading Bay. Pumping 3 bbl./min.down the tubing. Cir. 1000 bbl. Pull 1 std.--rig up wire line and run camera in the hole for EV downhole video. Fluid clear to+/-4,500'. Fluid too cloudy for video once camera on bottom. POOH with wire line and camera. Run stand in hole. Hang sheave in derrick. Run wireline in hole. 09/30/13-Monday RIH with camera on wireline. On bottom with camera.Start circ at 1 bpm. Fluid still coudy but clearing up.Take pictures and video of ZXP packer.Camera quit working.POOH.Change camera. RIH with new camera.Take pictures and video of casing above ZXP packer. POOH. Wireline out of hole. Rig down wireline. Rig down-no hydraulics.Wait on new transmission. 10/01/13-Tuesday Rig repair.Winterization of rig. 10/02/13-Wednesday Prepare rig for installation of new transmission.Test fit/hang lower windwalls on rig. 10/03/13-Thursday Transmission installed. Motor back up and running but making a'knocking'noise.Troubleshoot.Awaiting correct bladder.The one we received was incorrect. Knocking noise quit.Waiting on bladder. 10/04/13-Friday Installed bladder.Re-install all guards and covers. POOH laying down singles. Lay down drill collars. RIH w/3-1/2"out of derrick. POOH. 10/05/13-Saturday POOH laying down singles. Pull wear bushing. RIH with 4-1/2"suspension_string.Total of 66 joints run.Land hanger. Rig down floor.prepare to nipple down. Nipple down BOP and riser. S • Schwartz, Guy L (DOA) From: Schwartz,Guy I(DOA) PTO /4 C7 -017 Sent: Tuesday, October 01, 2013 10:43 AM To: 'Ted Kramer' Cc: Juanita Lovett; 'Regg,James B (DOA) (jim.regg @alaska.gov)' Subject: RE:G-19 Sundry#313-465 Moncla 404 Rig Transmission Failure Thanks for update. AS we discussed before ... close out sundry 313-465 with a well report 10-404. When you re-enter the well to continue operations anther sundry will be required. G-19 will be considered a shut-in producer... not suspended. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Ted Kramer [rla6totkramery'_hilcorp.com] Sent: Tuesday, October 01, 2013 10:33 AM To: Schwartz, Guy L(DOA) Cc:Juanita Lovett Subject: G-19 Sundry # 313-465 Moncla 404 Rig Transmission Failure Guy, While in the hole making our camera run to look at the packer to determine our plan for coming back to this well,The transmission failed on the Workover rig—Moncla 404. Diagnostics on the transmission indicate that the transmission needs to be replaced. A replacement transmission is expected to arrive in Anchorage today and a rig mechanic to replace it is being flown in this afternoon. The time needed to make this repair is estimated to be 5 days. Currently we are on bottom with our workstring at 5,100'with the rams closed and a TIW valve in the work string. Tubing pressure and the casing pressure are both zero psi. The well is static,taking no fluid. Plan Forward after making the repair: POOH with workstring, RIH with 2,000 ft.(+/-)of kill string, RD BOP, NU wellhead and move the rig to G-7. We will notify the AOGCC when the repair is completed and we are ready to come out of the well. Respectfully, Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 • OF TFp • • e,4) 117;. THE STATE Alaska 1 and as of Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 01"ALAS�� �{E� Anchorage, Alaska 99501-3572 fit!! Main: 907.279.1433 Fax: 907.276.7542 Dan Marlowe Operations Engineer F Q 17 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit G-19 Sundry Number: 313-465 Dear Mr. Marlowe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 3 day of September, 2013. Encl. ., ' • • RECEIVED ,�,Ian STATE OF ALASKA q AUG 2 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A G C 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubklg GI Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 169-017 , 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service p 6.API Number. Anchorage,AK 99503 50-73320178-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A(Injector WeN) Trading Bay Unit G-19 r Will planned perforations require a spacing exception? Yes ❑ No G 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 , McArthur River Field/Hemlock Oil Pool . 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,291 11,307 - 11,180 . 10,336 11,180'8 11,043' N/A Casing Length Size MD TVD Burs Collapse Structural 363' 26" 363' 363' Conductor Surface 520' 17-3/4" 520' 520' Intermediate 4,749' 13-3/8" 4,749' 4,535' 3,090 psi 1,540 psi Production 11,217' 9-5/8" 11,217' 10,368' 5,750 psi 3,090 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,565'-11,152' 9,800'-10,312' 4-1/2" 12.6#L-80 9,917' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker 9-5/8"Model D Packer,Otis 9-5/8"BWH Packer/ SSSV-N/A 9,840'(MD)9,146'(TVD),11,034'(MD)10,210'(ND)/SSSV-N/A 12.Attachments: Description Summary of Proposal p , 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El , Exploratory ❑ Stratigraphic❑ Development❑ Service G ° 14.Estimated Date for 15.Well Status after proposed work: 9/21/2013 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ G - 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 Dan Marlowe Email dmarloweta' hilcorp.com Printed Name '-n Marl.,, Title Operations Engineer Sign.'ure / / • one 907-283-1329 Date 8/26/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity CI BOP Test 2/ Mechanical Integrity Test di Location Clearance ❑ RBDMS OCT 1 0 !U13 Other: 3r 3 WOE r0 5 /JCS!° �G` 7 . C ^u f . �V- 2 y r. /4.4( .. 1-1/ Z (b) ,elie„ 2.-° Spacing Exception Required? Yes CI ! No l Subsequent Form Required: /D —y CSI �d i / APPROVED BY Approved by: �i.�.,�,"'Tf°-- COMMISSIONER THE COMMISSION Date: (1,-, - 3 _ �� / /2.o ORIGINAL � 3 +� \ Submit Form and � � Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of a royal. Attachments in Duplicate `t\ • Well Work Prognosis Well: G-19 Hilcorp Alaska,LLC Application Date: 08/23/13 Well Name: G-19 zP API Number: 50-733-20178-00 Current Status: Ai4-P-Fe4ueer 16c,¢o I,,ti' Leg: Leg#4 (SW corner) Estimated Start Date: September 21, 2013 . Rig: Williams Rig 404 Reg.Approval Req'd? 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 169-017 First Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904 (M) Pressures: Bottom Hole Pressure(BHP); Maximum Potential Surface Pressure(MPSP) Current BHP: —3,777 psi .38 psi/ft,(7.3 ppg)at mid perf of Hemlock Max.Expected BHP: '°3,777 psi @ 10,858'TVD .38 psi/ft.(7.3 ppg)Same zones to be re-perfed MPSP: 2,691 psi Using 0.1psi/ft.of True Vertical Depth Status: SI Feb'12 when outer annuluspressured up. Fluid level was shot on 10/23/12 and found at 2,223'. G-19 is a Hemlock injector with communication between the tubing and 9-5/8"casing,and communication between the 9-5/8"casing and the 13-3/8"casing. In November 2004 tubing integrity was lost and the well was shut-in. In 2008 an application was submitted for Administrative Approval to inject at pressures below the burst rating of the 9-5/8"of approximately 2100 psi. Injection continued until February 2012 when the outer casing annulus began to pressure up.,The well has been shut-in since. This well is the only injector in the eastern and most downdip fault block of the Northwest Feature. This well supports offtake from the Hemlock at producers G-17RD,G-13,and G- 28RD. Objective: Pull tubing,remove scab liner, remove packers,cleanout to existing bridge plug at 11,180',evaluate the condition of the 9-5/8"casing, Mitigate leak in 9-5/8"casing. Run injection completion. Notes Regarding Current Wellbore Condition: Scab liner must be removed to remove the production packer communication between the 9-5/8"casing and the 13-3/8"casing Rig Procedure: 1. Skid Williams Rig 404 over well G-19 2. RU Eline. RIH with Tubing punch and punch or cut tubing_one joint above packer. Plumb filtered inlet water (FIW)lines to circulate any hydrocarbons from well. 3. Notify AOGCC 24 hrs before pending BOPE test. Set BPV, ND tree,NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. o Note: If the BPV will not seat,shoot fluid again to confirm well is static. Test BOPE either on top of 2- way check(per standard test procedure)or with a rolling test as described in Attachment. 4. Pull hanger,and tubing string from cut. LD same. Norm check,and send to shore for reclamation. 5. PU, RIH with Overshot on a workstring and grab tubing stub above packer. Unlatch and POOH, LD seal assembly. 6. Cut, mill,and remove 7"scab liner between 5,152'and 6,608'. 7. PU packer burning assembly. Burn over and remove Baker Model D packer at 9,840'. 8. PU new packer burning assembly. Burn over and remove Otis BWH packer at 11,034'. 9. Make 8-1/2"bit/scraper run to the bridge plug at 11,180'. 10. RU E-line. RIH with Casing inspection log to 10,560'. casing from that point to surface looking for casing leaks and bad spots in casing. �6L o • • Well Work Prognosis Well: G-19 Hi!carp Alaska,LLC Application Date: 08/23/13 11. PU retrievable test packer. RIH to just above the bad areas(+/-5,000')identified by the casing log and set. Test backside to 2,500 psi to confirm casing integrity above bad area. 12. RU Perforating company. PU and RIH with TCP guns according to perforating program. Confirm guns are on depth, Fire guns. Pull up hole to clear perf guns from new perforations. Monitor well shooting fluid level shots to confirm well is static. POOH with perf guns. 13. Losses are likely to occur following the re-perforation event until the well finds its stable point again. f•..."1„a There is no need to circulate the hole,following re-perforation. After detonation, monitor well by shooting a fluid level and/or noting any flow. Once the well is determined to be static, POOH. 14. PU RIH with injection straddle packers on new injection tubing. Treat backside with FIW with corrosion inhibitor,circulate around. Land tubing hanger 15. RU and set plug in X-Nipple to set packers, pressure up backside to confirm packer is set.Conduct WO MIT by testing backside to 2500 psi for 30 minutes with a 2-pen recorder. NU tree,test same. Provide Larry Greenstein with the pressure test results as well as the completed 10-426 form for the MIT. „ ; -1-e-7a G 1 16. Set BPV. ND BOPS and NU tree. Test tree. 17. Turn well over to Production for restart of injection. 18. Within 2 weeks of stable injection,schedule an Initial MIT to test upper packer with AOGCC. Provide the AOGCC 24 hour notice prior to the MIT test. All pressure test results and completed 10-426 ar to be provided to Larry Greenstein immediately following the test. Run a baseline temp survey to L "U` .'')-1 confirm integrity of lower packer. '-�- f�� d Attachments: Rolling BOP test procedure As-built(Old)Wellbore Schematic r€ c Proposed (New)Wellbore Schematic 7 As-Built(Old)Wellhead Diagram Proposed (NEW)Wellhead Diagram BOP Drawing C =F '; °C("7 — 4/ 5- O ) • • McArthur River Field,TBU SCHEMATIC Well: G-19 HileoraAlaska,LLC As Completed: 06/14/1998 CASING DETAIL RKB to TBG Head=42.78' Size Wt Grade Conn ID Top Btm Cmnt Tree connection: 26" 1/2"Wall Surf. 363' Driven J L 17-3/4" 312 wall Weld Surf. 520' 13-3/8" 61 1-55 Seal Lock 12.515 Surf. 4,749' @ 52 0'' 9-5/8" 47 N-80 Buttress 8.681 Surf. 76' @ 520' 9-5/8" 40 N-80 Buttress 8.835 76' 4,981' 9-5/8" 43.5 N-80 Buttress 8.755 4,981' 6,853' 9-5/8" 47 N-80 Buttress 8.681 6,853' 8,421' 9-5/8" 47 P-110 Buttress 8.681 8,421' 11,217' 7" 29 L-80 Buttress 6.184 5,152' 6,608' None Tubing Detail 4-1/2" 12.6 L-80 Butt Mod I 3.958' 0' 9,917' 13-3/8"@ JEWELRY DETAIL 4,749' L No Depth ID Item -151= 42.78' 4-1/2"CIW Tbg Hgr, X4-1/2"Srd top x 4-1/2"butt mod bottom 1 9,840' Model E Anchor. n 2 9,840' 4.75 Baker Model D Packer set on wireline,ELM 5c-1,,,:,-,'‘'V 3 9,844' 4.75 Mill out Ext. 9,847' Tubing tail is screwed below packer seal bore t 4 9,884' 3.813" 4-1/2""X"Nipple (s o cX� 5 btm 9,917' 3.96" WLEG with shear-out solid nose t'°�1 �°._S 7 11,034' 4.000" Otis BWH pkr 8 11,043' 2.635" 3-1/2"Otis"XN"nipple with plug ' A , 9 11,045' 2.99" 3-1/2"tubing tail WLEG 9,840' 1 Q O� __r FISH 3 8.5"bit cleaned out to 11,1018'DPM 6/11/1998 11,1018' SLICKLINE WORK Tagged fill w/pressure bombs 34202.11,035' -- 2.4"GR prior to BHP survey 35765 11,010' 4 Tag fill 39515 11,006' = B-1 PERFORATION DETAIL - B-2 Zone Interval(MD) Interval(TVD) Amt Date Status =B-3 B-4 HB-1 10,565' 10,595' 9,800' 9,826' 30' 12/11/1989 Open B-5 HB-2 10,610' 10,715' 9,840' 9,932' 105' 12/11/1989 Open 7 >< 11c.34 HB-3 10,735' 10,830' 9,950' 10,034' 95' 12/11/1989 Open HB-4 10,860' 10,910' 10,060' 10,103' 50' 12/11/1989 Open 8 HB-5 10,930' 11,030' 10,120' 10,206' 100' 12/11/1989 Open 9 _ B-6 HB-6 11,050' 11,115' 10,224' 10,280' 65' 4/22/1969 Iso. B-7 HB-7 11,140' 11,152' 10,301' 10,312' 12' 4/22/1969 Iso. Bridge Plug @ 11,180' a 9-5/8"@ ,.,, 11,217' G 8-1/2"TD=12,291' MAX ANGLE=28°@ 4,400' KOP @ 2,000' H . III McArthur River Field PROPOSED Well #: G-19 HiIvor!,1,1a-la.i.rc Proposed RKB to TBG Head = 42.78' Casing Detail Tree connection: J I SIZE WT GRADE CONN ID TOP BTM. CMT 26" 1/2"Wall Surf. 363' Driven 17-3/4" .312 wall Weld Surf. 520' 17-3/4" 13-3/8" 61 J-55 Seal Lock 12.515 Surf. 4,749' @ 520' 9-5/8" 47 N-80 Buttress 8.681 Surf. 76' 9-5/8" 40 N-80 Buttress 8.835 76' 4,981' 9-5/8" 43.5 N-80 Buttress 8.755 4,981' 6,853' 9-5/8" 47 N-80 Buttress 8.681 6,853' 8,421' li 9-5/8" 47 P-110 Buttress 8.681 8,421' 11,217' 7" 29 L-80 Buttress 6.184 5,152' 6,608' None Tubing Detail il 4-1/2" l 13.55 I L-80 I BTC I 3.40" I Surf ±10,431' I 1 13-3/8"© y 4,749' Jewelry Detail Install straddle packer system to isolate bad Y No. Depth ID Item rd section of casing 42 78' 4-1/2" Tbg Hgr, 4-1/2"8rd top x 4-1/2"butt mod bottom 5,000' 1 .il 1 ±5000 Upper Straddle Packer 2 ±10,400' Lower Straddle Packer 3 ±10,430' X Nipple 4 ±10,431' Tubing Tail,WLEG Zone Interval(MD) Interval(TVD) Amt. Date Status HBV-1 ±10,565' ±10,598' ±9,800' ±9,829' 33' 12/11/1989 Re-Perf Open 10,400 2 Re-Perf HBV-2 ±10,607' ±10,727' ±9,837' ±9,943' 120' 12/11/1989 Open IFA HBV-3 ±10,734' ±10,830' ±9,949' ±10,034' 96' 12/11/1989 Re-Perf Open = B-1 Re-Perf - B-2 HBV-4 ±10,855' ±10,966' ±10,055' ±10,151' 111' 12/11/1989 Open = B-3 - B-4 HBV-5 ±10,966' ±11,024' ±10,151' ±10,201' 58' 12/11/1989 Re-Perf _B-5 Open Re-Perf HBV-6 ±11,049' ±11,111' ±10,223' ±10,276' 62' 04/22/1969 Isolated ± ±10,301' ±10,312' 12' 04/22/1969 Re-Perf HBV-7 ±11,140' 11,152' Isolated B-6 Bridge Plug - B-7 @ 11,180' 9-5/8"@ 11,217' G rh. 8-1/2" TD = 12,291' MAX ANGLE = 28°@ 4,400' KOP @ 2,000' REVISED:08/23/13 JLL i • Grayling Platform G-19 Current 02/15/2012 ['Meng]:%loam.1.1.(. Grayling 19 Tubing hanger, CIW- 133/8X95/8X41/2 DCB, 11 X4 '/ EUE 8rd lift and 41/2 IBT susp,w/4"type H BPV BHTA, CIW, 4 1/16 5M profile, 7" EN, %4" non continuous control line FE X Internal Acme knockup ...mii■m: I.Valve, swab,CIW-FL, ^� 4 1/16 5M FE, HWO, ?'0 �i 0 T-24 • (SO Tee, stdd, 4 1/16 15M 5M X �I I111I Ali: Choke, adj, CIW-CC30, II : I 41/165MFEXFE .. Valve, lower master, PIM WKM-M, 4 1/16 5M FE, HWO, T-24 dr / OpO ,.,ill,.. Adapter, CIW-FBB, 11 5M Void test good 11:0 "' Cm FE X 4 1/16 5M, prepped for 250/5000psi 7" extended neck, 1/2npt _ 2/15/2012 , Ell �� control line port ail : •• b' Tubing head, CIW-DCB, III ICI 13 5/8 3M X 11 5M,w/ 2-21/165M550,X- g fyc1 ' Valve, VJKM-M2 1/16 5M a�� FE, HWO, AA 1 %VR profile III 1 Ill Void test good te '` 250/5000psi U 2/15/2012 Casing head, Shaffer KD, Ii) Ii1 13 5/8 3M X i 2"LP CIW ball valve 13 3/8 SOW,w/2-2" I ��11 I s 1 INI�• LPO, di or • • Grayling Platform G-19 Proposed 08/21/2013 Hilviwp Alnrkn.lit Tubing hanger,CIW-DCB, Grayling 19 11 X 4''/ EUE 8rd lift and 13 3/8 X 9 5/8 X 4 1/2 4'/2 TC-2 susp,w/4"type H BPV profile, 6 1/4"EN,17-4ph Stainless steel BHTA,Bowen,4 1/16 5M FE X 7"-5sa Bowen top,full stainless steel ,n n, III Valve,swab,WKM-M, 4 1/16 5M FE,HWO, O T-26 n r Valve,Wing,WKM-M,4 1/16 0 -60 5M FE,w/15"Safeco ,., ,i operator,T-26 Tee,stdd,41/16 5M X ' '/ 4 1/16 5M I O Full Stainless Steel Valve,lower master, ® 0, WKM-M,41/165MFE, :.nfo HWO,T-26 Q 0 Adapter,CIW-FBB,11 5M FE X 11111111 I I• 4 1/16 5M,prepped for 6 1/4" extended neck,full stainless steel Tubing head,CIW-DCB, VII 135/83MX115M,w/2- III Valve,CIW-FC,2 1/16 5M FE, 2 1/16 5M SSO,X-bottom i� e HWO,AA prep, [11° , (',Ili 1/2 VR profile �• 11 � Casing head, Shaffer KD, I f 1 ' I I I 135/83MX 13 3/8 SOW,w/2-2" 111 ���'� 1—I �i-1�!, 2"LP ball valve LPO, • • , . 11 Grayling Platform Williams Rig BOP (rental) 1/18/2013 iiac,:rp %1AA:..1.1I. Grayling Platform 2013 Workovers BOP Drawing(Williams) 011 I W I I t,- f I III t.. 3.42' .Shaffer _.... 1'5M i 1111I ° III imply l•— 4.54' - � L: � I0-- ifBooster bonnets on botto 11110110_ Ilk Iil.Ill,Iit Ill Kill Side Choke side 21116 5M w/check valve 11/ ; . iv - m Iar. and Unibolt line 2.00 ;I! { } } ` {� �� 2 1116 5M wl HCR and connection ` !�I•,w uI 11I r` Unibolt line connection 1.00'to 2.00' iv will!III I,I Drill deck Riser 11 5M FE X 16.00' 11 5M FE -I 1 Ilii•I 1•I Spacer spool 3.00' ` 11 5M FE X 11 5M FE iI di'II I& n • • Williams Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment#1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program— Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) I • Williams Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same,and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1(inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. • • Williams Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment 41 ii) Valves, 3,4,9. After test,open valves 3&4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5&6, leave 9 closed. iv) Valves,7,8,9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve)and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. • • Williams Rig 404 BOP Test Procedure ictcorp,uaska,t.t.c Attachment#1 Diagram A-1: Grayling BOP stack and Riser Arrangement—Typical for Single Completion Grayling Platform 2013 Workovers BOP Drawing(Williams) MIL � .. II hill iiii Fi iii 3.42' Shaffer 11"5M u tii�iiiii id wimp .� ■C- 4.54' - ll�l'I!� 6U 110— Booster bo "-ts on bottom 10 t tir it i I Kill Side Choke side 21/16 5M w/check valve ''"'"'"'' f and Unibolt line 2.00 h° { } , 11"5M11, -} 11C 2 1/16 5M w/NCR and II,••.II. Il I. k�i ;IIi :II Unibolt line connection connection 1.00'to 2.00' uuuuuy r Drill deck Riser 11 5M FE X 16.00' 11 5M FE )ti rftt F Spacer spool 3.00' 11 5M FE X 11 5M FE t di iIi rL n • • Williams Rig 404 BOP Test Procedure Hilcnrp;U3Qk3.I,Lf.. Attachment#1 Diagram A-2: Grayling BOP stack and Riser Arrangement—Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 Shaffer SL 13 5/8 5M 1 44' IT{TINT 13 5/8 5M Spacer spool 2 00' tif Tdtlut1Ht T1, f i o 0 III!111 _ 1 Width 4.16' 3.74' ' Shaffer 13 6181M III III II! II III Sheffer LWS 13 5/8 6M L W S O 13 6/S SPA dimensions Length Width across body 2.72' Width across flanged - outlets 4G0. - --� - ■���� r!t/-;4:4111 � Y.— ° III II II I I � � ' ! i 1.74' K-3 f > I11 111 K-2 K-1 C-1 C-2'MCP" - Mud Cross "'` Riser above drill deck This number will vary from well to well -... 1.00'to 3 00' Drill Deck 13 6/8 6M MINN 86001bs 135/85MX 1500' 3 1/8 5M EFO III III I III Spacer Spool 136/86M X 136/8 SM 1.95 18001bs Ill III III II Crossover Spool - 135/8 SPA X11SM 18001b5 2.83' III III Top of Wellhead II • • Williams Rig 404 BOP Test Procedure mien.",Ala ka.Lrc Attachment#1 Diagram B: Grayling Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves II'ill 11114 11 ter.4. I, m ,, „.,, "' I" Chokes are 90 degrees off s \ I in drawing in order to show detail :ii. :�! _ II' :1 :.. : al ..: z _ J I � Swaco 6 : ; , i illi is w w I m'• w ill Ili III I I III' i1 From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 1/4" Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3'/4" Ball port,6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 Y4' Ball port,6000psi working pressure #10 National Ball Valve B1560, 1 1,4" Ball port,6000psi working pressure s . II • • Williams Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 u Ja .. 7' , . , V w a � g Y 2 a W 0 a 0 O Q CD 1- Ill CZ • 0 Q co C r ° Y 0 . i 0 M- CD Z m CI H a_ b <LYz vz U " LLOU-H v o -•q ar►Q Q o D •c- wva A ?• LLQ0i&u) ,= J c �= J C _ 2 J > oz ij -< , LI_ Z iz tY < = J D U ct 0 Y + • • Williams Rig 404 BOP Test Procedure Hilcorp Alaska.I.LC Attachment#1 av zu 2 V w Z_ �+ a ►t Qy Z i 3 U r m C' IIlir X mI- V) F r. � m T Q I 5 J z A z ;o Z v 0 Q Z U �° } �<) CC 0 _ Qc , 5azz l 1O 2OO 0 2 ,l ; - Li �w jo > oa- a� > _Ip00 �� z Q J V V • (6) rAl r * f l iI1T LE If PAUN,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL AIO 5.015 Mr. Steve Lambert Advising Petroleum Engineer Chevron North America Exploration and Production P.O. Box 196247 Anchorage,AK 99519-6247 RE: TBU G-19 (PTD 1690170) Request for Administrative Approval McArthur River Field, Hemlock Oil Pool Dear Mr. Lambert: In accordance with Rule 9 of Area Injection Order (AIO) 5.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants Chevron North America Exploration and Production (Chevron)'s request for administrative approval to continue water injection in the subject well. Trading Bay Unit (TBU) G-19 has a history of mechanical integrity issues. A casing patch was installed in 1998 to isolate questionable production casing integrity between 5200 feet and 6500 feet. The well was shut in November 2004 because of pressure communication to the tubing-casing annulus (inner annulus or IA). A 30-day injection test was approved by the Commission on April 1, 2008 to gather information in support of Chevron's effort to enhance the McArthur River Field water flood. Injection in TBU G-19 commenced June 20 and was suspended on July 7, 2008. A static temperature survey was run to assess the well's mechanical integrity. Information provided by Chevron subsequent to the test indicates that while the well pressures show tubing by inner annulus communication, all injected water is exiting the wellbore at the intended downhole location. Chevron does not intend to perform repairs at this time to eliminate the tubing by inner annulus communication in TBU G-19. Information provided with Chevron's TBU G-09 administrative approval request (approved July 29, 2008) indicates an extensive well workover campaign is planned for the Grayling Platform wells once an appropriate workover rig becomes available. The Commission expects Chevron will make appropriate repairs to TBU 0-19 at that time to restore mechanical integrity. Reported results of Chevron's diagnostic procedures and wellhead pressure trend plots indicate that TBU G-19 exhibits at least two competent barriers to the release of well pressure. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's .-' •AIO 5.015 • • August 28,2008 Page 2 of 2 administrative approval to continue water injection only in TBU G-19 is conditioned upon the following: 1. Chevron shall record wellhead pressures and injection rate daily; 2. Chevron shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. Chevron shall perform a temperature survey every 2 years and provide data and interpreted results to the Commission; 4. Chevron shall limit the surface injection and IA pressures to 2100 psi; 5. Chevron shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and a,ti.t iJ 4 T� 7. The anniversary date for the temperature survey is July 8, 2008. .. ...t l,e�l,�`k DONE at Anchorage,Alaska and dated August 28, 2008. f ' ' • f ik /e)11.1 L . i LA/ Daniel T. Seamount,Jr. Cathy '. Foerster t `' ► rum Chairman Commissioner ommissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the Commission grants for good cause shown,a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration,this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[tjhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. oF THE STATE Alaska Oil and as ° f�AsKA Conservation Commission •117 \T GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 � ALAS' Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer s �. At4HED FEB 2 6 20 3 Sr. Operations Engineer 17 Hilcorp Alaska, LLC 1 1 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU G -19 Sundry Number: 313 -002 Dear Mr. Kramer: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P oers er Chair DATED this I $ day of January, 2013. Encl. • • • "L' 0 RECEIVED k STATE OF ALASKA \ JAN 0 3 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS _[L AOGCC 20 AAC 25.280 F 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well (. 3 Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑. Pub Tubing El • lime Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing g Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drift Number. Hilcorp Alaska, LLC Exploratory ❑ Development ❑ 169 -017 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service p 6. API Number. Anchorage, AK 99503 50- 73320178 -00 - 7. If perforating: 8. Weft Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A (Injector Well) Trading Bay Unit G-19 • Will planned perforations require a spacing exception? Yes ❑ No D 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017594 • McArthur River Field / Hemlock Oil Pool ■ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 12,291 11,307 • 11,180 10,336 11,180' & 11,043' N/A Casing Length Size MD TVD Burst Collapse Structural 363' 26" 363' 363' Conductor Surface 520' 17 -3/4" 520' 520' Intermediate 4,749' 13 -3/8" 4,749' 4,535' 3,090 psi 1,540 psi Production 11,217' 9 -5/8" 11,217' 10,368' 5,750 psi 3,090 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,565' - 11,152' • 9,800' - 10,312' 4 -1/2" 12.6# L -80 9,917' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker 9 -5/8" Model D Packer, Otis 9 -5/8" BWH Packer / SSSV - N/A -• 9,840' (MD) 9,146' (TVD), 11,034' (MD) 10,210' (TVD) / SSSV - N/A 12. Attachments: Description Summary of Proposal E • 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El • Exploratory ❑ Stratigraphic ❑ Development ❑ Service El' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/15/2013 Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 151• 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 tkramer @hilcorp.com Printed Name Ted / � � `Lt Kramer Title Sr. Operations Engineer Signature ........;1 .. . i' 6 1 7� ''_ one 907- 777 -8420 Date 1/4/2013 LLL COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l - Oo2. Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 c p 60C / c's r Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /c^j •- 4 C Y Al APPROVED BY e Approved by: i� `„' ' / COMMISSIONER THE COMMISSION Date: ! `(F /3 i JAN 2 8 r • ` :; ��� 3 4 ,4 0 ' ,� ' Submit Form and ,)*/)\_ o ) Oo, n o.�o is . ,1 ) L Approved application is valid / — for 12 months from the date of appro : I. Attachments in Duplicate • • Well Work Prognosis Well: G -19 Hileorp Alaska, LLC Application Date: 01/04/13 Well Name: G -19 API Number: 50- 733 - 20178 -00 • Current Status: Oil - roducer Alejk,r Leg: Leg #4 (SW corner) Estimated Start Date: April 15, 2013 Rig: Williams Rig 404 Reg. Approval Req'd? 10 -403 Date 10 -403 submitted: 01/04/13 Regulatory Contact: Juanita Lovett Permit to Drill Number: 169 -017 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (Office) (907) 351 -4191 (M) AFE Number: 1221771 Budgeted Cost: Pressures: Bottom Hole Pressure (BHP); Maximum Potential Surface Pressure (MPSP) Current BHP: " 3,777 psi Calculated from 10/23/12 fluid level shot. Max. Expected BHP: ^'3,777 psi @ 10,858' TVD Calculated from 10/23/12 fluid level shot. MPSP: 2,691 psi Using 0.1psi /ft. of True Vertical Depth Status: SI Feb '12 when outer annulus pressured up. Fluid level was shot on 10/23/12 and found at 2,223'. Objective: Pull tubing, remove scab liner, remove packer, evaluate the condition of the 9 -5/8" casing, Repair casing with a casing patch and / or run a new production liner. Run injection completion. Rig Procedure: 1. RU Eline. RIH with Tubing punch and punch or cut tubing one joint above packer. Reverse circulate well to remove any hydrocarbons. 2. Set BPV in profile. ND Well head, NU BOPE and Test 200psi Iow000Josi on blind rams. o Note: If the BPV will not seat, shoot fluid again to confirm well is static. Test BOPE either on top of 2 -way check (per standard test procedure) or with a rolling test as described in Attachment #1. (Note: Notify AOGCC 48 hrs. in advance to witness test) 3. Pull hanger, and tubing string from cut. LD same. Norm check, and send to shore for reclamation. 4. PU, RIH with Overshot on a workstring and grab tubing stub above packer. Unlatch and POOH, LD seal assembly. 5. Cut, mill, and remove 7" scab liner between 5,161' and 6,550'. ✓ 6. PU packer burning assembly. Burn over and remove Baker Model D packer at 9,840'. 7. PU new packer burning assembly. Burn over and remove Otis BWH packer at 11,034'. 8. Make 8 -1/2" bit /scraper run to the bridge plug at 11,180'. POOH with same. 9. RU E -line. RIH with Casing inspection log to 10,560'. Log 9 -5/8" casing from that point to surface looking for casing leaks and bad spots in casing. 10. PU retrievable test packer. RIH to just above the bad areas identified by the casing log and set. Test backside to 2,500 psi. to confirm casing integrity above bad area. 11. Run either a casing patch or a scab liner to repair bad casing. 12. PU and RIH with Retrievable test Packer to 10,560 ( + / -) and pressure test to 2,500 psi to confirm casing integrity. POOH with same. f 13. RU Perforating company. PU and RIH with TCP guns according to perforating program. Confirm guns are on depth, Fire guns. Pull up hole to clear perf guns from new perforations. Monitor well shooting fluid level shots to confirm well is static. POOH with perf guns. 14. PU RIH with injection packer on new injection tubing. Treat backside with FIW with corrosion inhibitor, circulate around. Set packer at ± 10,375' and hang off well. 15. ND BOP, NU tree and test. 16. Perform MIT test. Turn well over to Production. 17. Move rig to the next well. • • .,,,, , McArthur River Field SCHEMATIC Well #: G -19 Hikarp Alaska, L1.0 As Completed 6/14/1998 Casing Detail RKB to TBG Head = 42.78' SIZE WT GRADE CONN ID TOP BTM. CMT Tree connection: Q L 26" 1/2" Wall Surf. Driven 17 -3/4" .312 wall Weld Surf. 520' 13 -3/8" 61 1 -55 Seal Lock 12.515 Surf. 4,749' 17 -3/4" 9-5/8" 47 N -80 Buttress 8.681 Surf. 76' @ 520' 9 -5/8" 40 N -80 Buttress 8.835 76' 4,981' 9 -5/8" 43.5 N -80 Buttress 8.755 4,981' 6,853' 9 -5/8" 47 N -80 Buttress 8.681 6,853' 8,421' 9 -5/8" 47 P -110 Buttress 8.681 8,421' 11,217' 7" 29 L -80 Buttress 6.184 5,152' 6,608' None Tubing Detail 4 -1/2" I 12.6 1 L -80 1 Butt Mod 1 3.958' 1 0' I 9,917' ∎ Jewelry Detail No. Depth ID Item N 4 -1/2" CIW Tbg Hgr, 13 -3/8 "@ � 42.78 4 -1/2" 8rd top x 4 -1/2" butt mod bottom 4,749' 1 9,840' Model E Anchor. 7" scab liner, L , 2 9,840' 4.75 Baker Model D Packer set on wireline, ELM y 5,152' 6,608' 3 9,844' 4.75 Mill out Ext. ZXP Packers ® 9,847' Tubing tail is screwed below packer seal bore 1111 5,161' 4 9,884' 3.813" 4 -1/2" "X" Nipple 5 btm 9,917' 3.96" WLEG with shear -out solid nose 7 11,034' 4.000" Otis BWH pkr 8 11,043' 2.635" 3 -1/2" Otis "XN" nipple with plug USIT Log 9 11,045' _ 2.99" 3-1/2" tubing tail WLEG Hole @ 5,280' Bad Spot @ 6,485' FISH Date Depth RTTS Hole 8.5" bit cleaned out to 11,1018' 6/11/1998 11,1018' R 111 5,245'- 5,331' DPM SLICKLINE WORK D Tagged fill w/ pressure bombs 8/21/1993 11,035' 9,840' 1 PAdC` 2.4" GR prior to BHP survey 12/1/1997 11,010' 2 Tag fill 3/8/2008 11,006' 3 Perforation Detail Zone Interval (MD) Interval (TVD) Amt. Date Status HBV -1 10,565' 10,595' 9,800' 9,826' 30' 12/11/1989 Open L---__i HBV -2 10,610' 10,715' 9,840' 9,932' 105' 12/11/1989 Open 4 HBV -3 10,735' 10,830' 9,950' 10,034' 95' 12/11/1989 Open HBV -4 10,860' 10,910' 10,060' 10,103' 50' 12/11/1989 Open HBV -5 10,930' 11,030' 10,120' 10,206' 100' 12/11/1989 Open = B -1 HBV -6 11,050' 11,115' 10,224' 10,280' 65' 4/22/1969 Iso. B -2 HBV -7 11,140' 11,152' 10,301' 10,312' 12' 4/22/1969 Iso. = B -3 B -4 B -5 7 BtN� .L 8 g = B -6 Km B -7 Bridge Plug © 11,180' ' 9 -5/8 "@ 11,217' ,, ff 8 -1/2" TD = 12,291' MAX ANGLE = 28° @ 4,400' KOP @ 2,000' REVISED: 7 /31/2012 MDD f • • McArthur River Field PROPOSED Well #: G -19 Hi4nrp Ala.ka, 1,6 As Completed 6/14/1998 Casing Detail RKB to TBG Head = 42.78' SIZE WT GRADE CONN ID TOP BTM. CMT Tree connection: 26" 1/2" Wall Surf. Driven 17 -3/4" .312 wall Weld Surf. 520' 13 -3/8" 61 1 -55 Seal Lock 12.515 Surf. 4,749' 17 -3/4" 9 -5/8" 47 N -80 Buttress 8.681 Surf. 76' © 520' 9 -5/8" 40 N -80 Buttress 8.835 76' 4,981' 9 -5/8" 43.5 N -80 Buttress 8.755 4,981' 6,853' 9 -5/8" 47 N -80 Buttress 8.681 6,853' 8,421' 9 -5/8" 47 P -110 Buttress 8.681 8,421' 11,217' 7" 29 L -80 Buttress 6.184 5,152' 6,608' None 1 Tubing Detail 4 -1/2" I 12.6 I L -80 I Butt Mod I 3.958' I 0' I 9,917' I Jewelry Detail 13 - 3/8 "@ No. Depth ID Item 4,749 4 -1/2" CIW Tbg Hgr, L , 42.78' 4 -1/2" 8rd to Install patch on 9 -5/8" top x 4 -1/2" butt mod bottom casing - if unable to 1 ±10,375' Injection Packer patch casing, run new 7" liner from surface to e TD. Perforation Detail Zone Interval (MD) Interval (TVD) Amt. Date Date Status HBV -1 10,565' 10,595' 9,800' 9,826' 30' 12/1989 04/2013 Open 9,840' HBV -2 10,610' 10,715' 9,840' 9,932' 105' 12/1989 04/2013 Open HBV -3 10,735' 10,830' 9,950' 10,034' 95' 12/1989 04/2013 Open HBV -4 10,860' 10,910' 10,060' 10,103' 50' 12/1989 04/2013 Open HBV -5 10,930' 11,030' 10,120' 10,206' 100' 12/1989 04/2013 Open HBV -6 11,050' 11,115' 10,224' 10,280' 65' 4/1969 04/2013 Open HBV -7 11,140' 11,152' 10,301' 10,312' 12' 4/1969 04/2013 Open L` � 1 B -1 - - B -2 = B -3 B -4 B -5 B -6 Bridge Plug - B - 7 @ 11,180' 9 -5/8 "@ 11,217' G 8 -1/2" TD = 12,291' MAX ANGLE = 28° @ 4,400' KOP @ 2,000' REVISED: 01/03/2013 JLL Well Work Prognosis Well: G -19 xaeorp Alaska, LLC Application Date: 01/04/13 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure • • ‘, Well Work Prognosis Well: G -19 Hi!carp Alaska, LLC Application Date: 01/04/13 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C -1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. • • Well Work Prognosis Well: G -19 Hilcorp Alaska, LLC Application Date: 01/04/13 d) Open C -1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C -2. This is the HCR (the hydraulic controlled remote) valve just outside C -1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C -1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K -1, K -2, and K -3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure ". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 " set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi "). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut -off after the pressure to builds back to original pressure ( +/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto ", not "Manual" so the pumps will kick -off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Juanita Lovett. • • Well Work Prognosis Well: G -19 Hilcorp Alaska, LLC Application Date: 01/04/13 Diagram A -1: Grayling BOP stack and Riser Arrangement — Typical for Single Completion Williams Workover Rig Grayling Platform BOP 2012 1 O O Weatherford Rental BOP Width 4.16' 3.74• liii$ItlS61ll l 136/86M LWS 136rL.W dimensions © 3.00' 4112 . Length 7.73' Width across body 2.72' I - - Widthacrossflanged . = - -- - -t. outlets 4.00' = _ M: n ■ 1�1. llil `j° - �j V 'a t lit , K -3 K -2 K -1 C -1 C -2 'MGR' • Mud Cross Riser above drill deck This number will vary from well to well 1.00' to 3.00' Drill Deck 13 6/8 6M Riser 8500165 13 5/8 5M X 15.00' 3 1/8 5M EFO III 6 III V IP ' III Spacer Spool 135/85M X 135/86M 1.95' 1800lbs .- +.. IIII II I•II1 II' IUJ Crossover Spool 135/86M X116M 1800lbs 2.87 J Top of Wellhead • • Well Work Prognosis Well: G -19 Hilcorp Alaska, IJ.c Application Date: 01/04/13 Diagram A -2: Grayling BOP stack and Riser Arrangement — Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 —\ 1.44' I e 1 I 111' 13 5/8 5M Spacer spool 2.00 - Il1.1t1.1U1: r 1 O - I - -. - -. — II Weatherford Rental BOP 1 Width 4.16' l r 3.74' Shaffer 37515 iiM I/1 01010101 / - Shaffer LW3 13 LWS 136/86M - dimensions -- Length ® - -_ Length 7.73' 3.00' Width across body 2.72' Width across flanged . ate • outlets 4.00' E _� ' linglir n 1 11 III! ri `� `�• II1 III ' 11 �� K -3 K -2 K -1 C -1 C -2 `I-/CR" Mud Cross Riser above drill deck This number will vary from well to well 1.00' to 3.00' Orill Deck 13 6/8 6M Riser • 8600lbs 13 5/8 5M X 15.00' 3 1/8 5M EFO III III Spacer Spool 136/86M X 135/85M 1.95' 1800lbs I I. 1 _11 - 1 Crossover spool 135/85M X115M 1800Ibs 2.83' II I1 Top of Wellhead • • Well Work Prognosis Well: G -19 Hilcorp Alaska, LH Application Date: 01/04/13 Diagram B: Grayling Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves _ _ ,dli! Iiiiimini - 1 : - .. la 9 ar "' Chokes are 90 degrees off 4 '" ` in drawing in order to show / 1 detail I i . III _ : la ow IIL :/. - rIA� f� � ila I , - Mil ,t. - - 1 1 - - Swaco I I/r 6'E 8 I 111/ I WE li_ I,' I I _I III III 111 III III El III lE 60,0 From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 1 /4' Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3'/4' Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 1 /<" Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 1 /2" Ball port, 6000psi working pressure • T _ WILLIAMS RIG #404 7 , ii 23 FLUID FLOW DIAGRAM NORMAL OPERATIONS //// CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE / A PANIC LIN E 1 ❑ . f --. • I I T P.IP • ��,, H P. E.' - MANUAL ` AUTOUATC. yC 0 STACK HOKE CHOKE ► E6 CG °0 C C 0 ritplI I IA LID w -- P IJM P 1 X.;‘;. --qi G,-- PUMP i MANIFOLD L I ncH uF.L'JE LP GA3 SUCTION BUSTER\ LINE /1 • FLUID TANK/PIT D G G V fD (D E C I o 5 1 - 1 - , 7 kiD A ID w o C = 0 o N 0 1—k W 3 Al WILL LAMS RIG #404 / ii FLUID FLOW DIAGRAM r NORMAL OPERATIONS CIRCULATING DOWN TUBING, UP CASING ANNULAS THE LONG WAY" ' STANDPIPE P PNIC LINE • —5TR !ER V REAO 4 BOP ■ MANUAL —/ef ` AUTO SATC ` C ST ACK = CHOKE CM°KE il■ oC C o p 1€1 I =1 MUD """��� """ 1i'I "' " -, PIMP 41 - Gt PUMP A MANIFOLD U � "CR VALVE LP r , N'.@ `.i k:T. C∎fj B J TER. _ LUt'%E - f FLUID T.ANKiPIT 0 M F* O F., - z to v n, o re 3 0 O H. F-+ H 1 O A N W • • • Well Work Prognosis Well: G -19 HilcarpAlaeka,LLC Application Date: 01/04/13 Williams Workover Rig • • Grayling Platform BOP 2012 I{I III ill 1{I III 111 Ill Ill Width 4.16' 3.74' Weight 13,1009 I {I 111111111 1 1I Total BOP height above 13 5/8 5M LWS drill deck min 11.48' dimensions 1.48' Length 7.73' 3 00' max Width across body 2.72' Width across flanged outlets 4.00' _ Weight95001bs - -" • 9.00' III WWI III III � i i • I r ILA 1 28501bs w/ valves :l� ` 7 I H � ' 4 i I 1.74' Mud o Qi 1i - i. 111 III I {{ 111 111'. � 14,-04 : • Riser above drill deck III -.__.- -- Ill T number will vary from well to well 1.00 100' Drill Deck 13 5/8 5M Riser 85001bs 15 00' III ill III II Spacer Spool 135/85M X 135/85M 1.95' 1800lbs III III Crossover Spool 135/85MX 11 5M 1800Ibs 2.83' I{I III Top of Wellhead • -Ferguson, • Victoria L (DOA) From: Ted Kramer [tkramer@hilcorp.com] Sent: Wednesday, January 09, 2013 4:06 PM To: Ferguson, Victoria L (DOA) Subject: RE: TBU G -19 (PTD 169 -017 Sundry 313 -002) Victoria, I will have to get the Id for you. We are looking at both the Eventure, and the Weatherford patch systems and have not decided on which one yet. The intent is that we will be able to run the injection packer through the patch ID and set it below it. I will send you the ID as soon as we decide. The vendors will be coming in next week to present their proposals. I hope this helps, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985 - 867 -0665 From Ferguson, Victoria L (DOA) j mailto :victoria.ferguson@)alaska.govj Sent: Wednesday, January 09, 2013 1:05 PM To: Ted Kramer Subject: TBU G -19 (PTD 169 -017 Sundry 313 -002) Ted, What will be the ID of the casing patch or scab liner? Will you be able to run the injection packer below this patch? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson aa..alaska.gov 1 • PT 16c10 l7 Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Friday, February 10, 2012 11:14 AM eft 11 3Ii To: Regg, James B (DOA); Michael Dunn Cc: Schwartz, Guy L (DOA); Keith Elliott; Trudi Hallett Subject: RE: Notification of the shut -in of TBU G -19 injector (PTD# 1690170) Attachments: G -19 Pressure plot 2- 9- 12.xls; G -19 Schm 6- 14- 98.doc ✓ Here you go, Jim. All looked fine until recently. We'll be doing some tree maintenance and some diagnostic work to figure out if there really is downhole communication between the inner and outer casing. ✓ We'll get back with you when we know more about the pressures in this well. ✓ Larry From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Friday, February 10, 2012 8:58 AM To: Michael Dunn Cc: Schwartz, Guy L (DOA); Larry Greenstein; Keith Elliott; Trudi Hallett Subject: RE: Notification of the shut -in of TBU G -19 injector Please send plot of pressures (tubing, inner and outer annuli) for past 90 days and current well schematic for TBU G -19 (PTD 1690170). Also please include the PTD number on your correspondence when it applies to well. Thank you Jim Regg AOGCC +� FS �� 6 Z): 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Michael Dunn [mailto:mdunnOhilcorp.com] Sent: Thursday, February 09, 2012 4 :59 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Larry Greenstein; Keith Elliott; Trudi Hallett Subject: Notification of the shut -in of TBU G -19 injector Jim, This is notice that we have shut -in the TBU G -19 injector on the Grayling platform, following a spike in pressure on the 9- 5/8" X 13 -3/8 annulus above the operating pressure limit of the outer annulus (OA). The well was shut -in at 6:30 pm on 2/8/12. If you have any questions today, you can contact me. Otherwise, Larry Greenstein will be back in the office tomorrow. Regards, Mike Dunn Sr. Reservoir Engineer Hilcorp Alaska, LLC Office: (907) 777 -8382 1 Pressure N N O T O O O O O O 12/11/11 I 12/14/11 Iii 12/17/11 0 9 o w tn 6 W W J co 00 ' 12/20/11 12/23/11 12/26/11 — 12/29/11 b • O r + 01/01/12 b z z 01/04/12 C co F 01/07/12 Al 01/10/12 A C 01/13/12 " 2 y ' co 01/16/12 ef 01/19/12 01/22/12 01/25/12 • i 31/28/12 V4 � �� w 1C 01/31/12 �� 02/03/12 16 V 02/06/12 ........■•••••• 02/09/12 A....o.n.o....Jo, r ° O O O O O O O co °° O °° ° O O O ° O BLS MI I NV - w— ■ MI `' 0 • Trading Bay Unit 11111101111FIEFIrffe Well # G-19 — AM 'MR. AII■ WM - - 41111111. As Run 6/14/98 Prit (670/70 CASING AND TUBING DETAIL RKB to TBG Head = 42.78' MD MD TVD Tree connection: SIZE WT GRADE CONN ID TOP BTM. BTM. CMT J 26" 1/2" Wall Surf. Driven 17 -3/4" .312 wall Weld Surf. 520' 13 -3/8" 61 J -55 Seal Lock 12.515 Surf. 4749' 9 -5/8" 47 N -80 Buttress 8.681 Surf. 76' 9 -5/8" 40 N -80 Buttress 8.835 76' 4981' 9 -5/8" 43.5 N -80 Buttress 8.755 4981' 6853' 9 -5/8" 47 N -80 Buttress 8.681 6853' 8421' 9 -5/8" 47 P -110 Buttress 8.681 8421' 11217' 7" 29 L -80 Buttress 6.184 5152' 6608' None Tubing: 4 -1/2" 12.6 L -80 Butt Mod 3.958' 0' 9917' JEWELRY DETAIL NO. Depth ID Item 42.78' 4 -1/2" CIW Tbg Hgr, 1 4749' L , 7" scab liner, 4 -1/2" 8rd top x 4 -1/2" butt mod bottom 5152' -6608' X g ZXP Packers 9917' 3.958 4 -1/2" Buttress modified tubing 5161' -6550' 1 9840' Model E Anchor. 2 9840' 4.75 Baker Model D Packer set on wireline, ELM 3 9844' 4.75 Mill out Ext. USIT Log 9847' Tubing tail is screwed below packer seal bore Hole @ 5280' 4 9884' 3.813" 4 -1/2" "X" Nipple Bad Spot @ 5 btm 9917' 3.96" WLEG with shear -out solid nose 6485' R X 7 11,034' 4.000" Otis BWH pkr RTTS Hole 8 11,043' 2.635" 3 -1/2" Otis "XN" nipple with plug 5245' -5331' 9 11,045' 2.99" 3 -1/2" tubing tail WLEG 9840' = '„ 1 1 I FISH 8.5" bit cleaned out to 11,1018' DPM 6/11/98 ■ . 3 4 SLICKLINE WORK Tagged fill w/ pressure bombs 8/21/93 @ 11,035' 2.4" GR prior to BHP survey 12/1/97 11,010' Tag fill 3/08/08 11,006' = = B B - - = B -3 — B -4 7 _ B -5 i=c ))<1 PERFORATION DATA Accum Last 8 Zone Top Btm Amt SPF Perf Date Present Condition g HB -1 10,565' 10,595' 30' 12/11/89 Open for injection = B - HB - 10,610' 10,715' 105' 12/11/89 Open for injection B - 7 HB -3 10,735' 10,830' 95' 12/11/89 Open for injection Bridge Plug HB -4 10,860' 10,910' 50' 12/11/89 Open for injection @ 11,180' HB -5 10,930' 11,030' 100' 12/11/89 Open for injection HB -6 11,050' 11,115' 65' 4/22/69 Below XN plug 9 -5/8 "@ HB -7 11,140' 11,152' 12' 4/22/69 Below XN plug 11,216' 8 -1/2" TD = 12,291' MAX ANGLE = 28° @ 4400' KOP @ 2000' G -19 Schm 6 -14 -98 REVISED: 02/13/12 DRAWN BY: TAB Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 17, 2010 3:16 PM To: 'Lambert, Steve A' Cc: Brooks, Phoebe L (DOA); Cole, David A; Greenstein, Larry P Subject: RE: G-19 (PTD1690170) AA Temperature Survey Thanks Steve, No issue with running early Tom Maunder, PE AOGCC I concur with your assessment. From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Monday, May 17, 2010 2:29 PM To: Maunder, Thomas E (DOA) Cc: Brooks, Phoebe L (DOA); Cole, David A; Greenstein, Larry P Subject: G-19 (PTD1690170) AA Temperature Survey . Page 1 of 1 Tom, Grayling well G-19 (PTD 169-017) received administrative approval for continued injection on August 28, 2008. As part of the approval, a bi-annual temperature survey is required. The anniversary date for the survey is July 8, 2008. Due to platform activity the survey was run a little early this year. The attached survey was run on May 12, 2010 and it indicates that all fluid continues to be injected within the zone of interest. The well remains on injection. If you have any questions please contact me. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 3800 Center Point Suite 100 Tel 907 263 7658 salambert@chevron.com 5/17/2010 Chevron Well: G-19 Field: Grayling 05-12-2010 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000 2000 3000 4000 .-. ~ ~. 5000 ~ t 6000 Q 7000 8000 9000 10000 11000 60 70 80 90 100 110 120 130 140 150 Temperature ~Deg~ _ 5-12-10 Pressure - Perfs 13-3/8 - ~ 9-5/8 7 TBG 17 3/4" 5-12-10 Temp _ 7-8-08 Tem _- Report date: 5/1712010 April 1, 2008 Mr. Steve Lambert Sr. Advising Petroleum Engineer Chevron PO Box 196247 Anchorage, Alaska 99519-6247 ~, ~ APR ~ 2 200 RE: 30-day Injection Test Trading Bay Unit G-09 and G-19 Dear Mr. Lambert: Your request to perform 30-day injection tests on Trading Bay Unit ("TBU") wells G-09 and G- 19 is approved. Chevron's letter dated February 22, 2008 indicates these injection tests are designed to gather additional information in support of an effort to enhance the MacArthur River field waterflood. Area Injection Order 5 authorizes the injection of water for enhanced oil recovery purposes in TBU and establishes rules for injection activities. The portion of aquifers beneath Cook Inlet described by a 114 mile area beyond and lying directly below the Trading Bay Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Both wells have injected as part of the MacArthur River field waterflood but have been shut in for an extended time period because of the limited water available for injection and because of mechanical integrity concerns (tubing-casing communication). Increased surveillance and continued monitoring of wellhead pressures must be an integral part of the injection tests to confirm fluids remain confined to the wellbore and the intended injection formation. The Commission finds that the 30-day injection tests are an appropriate additional step in gathering the information needed to design acceptable long term injection. The following conditions apply: 1. Water only injection is limited to 30 consecutive days once injection has commenced; 2. Temperature surveys must be run before commencing and after completing injection; 3. Chevron must monitor and record at least daily the tubing and all annuli pressures, and any pressure bleeds that occur; 4. The tubing-casing annulus (inner annulus) shall not exceed 1000 psi; 5. Any indication of pressure communication to the casing-casing annulus (outer annulus) mast be reported i~~ediaielj' to the Con'u'nissiori; adecision will be rriade at that tiiiie if the injection test can continue. Mr. Steve Lambert ~ • April 1, 2008 Page 2 of 2 Information gathered during the 30-day injection tests must be provided to the Commission as part of administrative approval requests (each well) for long term water injection. Administrative Approval requests must also include sufficient detail from the reservoir simulation to confirm Chevron's findings that renewed injection in TBU G-09 and G-19 improve the efficiency of upstructure injectors and result in incremental oil recovery. A timeline for the restoration of mechanical integrity of wells G-09 and G-19 should also be addressed. If the decision is made to not pursue administrative approval for continued injection, Chevron must provide the information gathered within 60 days of completing the test injections. Sincerely, Daniel T. Seamount, Jr. Chair 2 • { } February 22, 2008 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave #100 Anchorage, AK 99501-3539 Dear Tom: ~~q.o~9 Chevron requests approval to perform 30 day injection tests on wells G-9 and G-19. These tests are proposed as the first step to returning these wells to long term injection. This increased injection is part of an ongoing effort to enhance the McArthur River waterflood. Both wells are believed to have tubing casing communication. - Well G-9 (API # 50-733-20098-00, PTD #168-026) was shut-in on July 13, 1995 due to concerns about the wellbore integrity and prioritization of available water injection capacity. The well was subsequently tested for 13 days in 2003. The last measured rate was 1,030 BWPD with 2,350 psi tubing pressure and 1,000 psi casing pressure measured on March 31, 2003. The well has been continually monitored since that time and is reported quarterly on the LTSI report. Well G-19 (API# 50-733-20178-00, PTD #169-026) was shut-in on November 22, 2004 due to pressure communication between the tubing and casing annulus. Due to limited water availability the decision was made to shut the well in. Since that time the well has been continually monitored and is reported quarterly on the report. Wefls G-9 and G-19 are both down structure injectors. These wells have remained shut-in due to limited injection capacity and the less than optimum location of the wells. Chevron has begun a renewed focus on injection within the McArthur River Fietd and as a result the injection capacity on the Grayling platform is being expanded. A portion of the increased injection capacity is planned to be used for injection into G-9 and G-19. Reservoir simulation has shown that renewing water injection into these down dip wells improves the efficiency of upstructure injectors and results in incremental oil recovery. Following is the proposed procedure for bringing each well back on injection. 1) Run a baseline temperature survey. 2) Obtain permission to inject. 3) Inject until the well until injection rate has stabilized. (Limit the length of the test to 30 days.) Steve Lambert Sr. Advising Petro{eum Engineer MidContinent/A{aska • Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com a~" 6VE~ AFR €t ~ X008 MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com • • [Tom Maunder] (Alaska Oil and Gas Conservation Commission] [February 21, 2008 Page 2 4) Follow-up temperature survey. 5) Request an Administrative Approval to continue injection depending on results of the survey. Monitor well daily and repeat temperature surveys every two years. Sincerely, j 9 ' ~~ r Steve Lambert Union Oil Company of California / A Chevron Company http://www.chevron.com MEMORANDUM TO: Camille O. Taylor Chair THRU: Tom Maunder P.i. Supervisor FROM: JO~n Crisp Metro~e~m ~nspector NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: OCtober 1, '2002 suBJEcT: Mechanical Integrity Tests Unocal Trading Bay Unit MeArthur River .Field Grayling Platform . Packer Depth Pretest Initial 15 Min. 30 Min. WellI 'G-5RD I Typel,j.I 'S I T.V.D. I '~s I~u~i~,! ~ooI ~ooI ~ooi ~oo I,,~,,1'4 P.T.D.I 1981200,fypete'~tI P' ImestPsil 2400 I Casingl 760 ! 24001 2400 I' 2400 I 'P/F I:P~ Notes' OA ressure 70 psi . We,I G-~S I Type~ni.i ' s iT'v'D' I 8833 ITubi"el 3250 I ~=~01 =~01 =~0 I~nte~va~l 4 P.T.D.l":1681090.1Typetestl P I'TestPsil 2450 ICasing.I 1900I 2~,so'I 2425. I 2425 I' pIF, ,,,Notes: OA pressure 310 , , ' ' , , ' ,, , We~l,I, G-19 IType~nj.I S I T.V.D. I 91~45 I Tubin~ll 3200 .] 3200 I 3200 l'3200 l~nterva~! 4 I P T D ] '1690170 T: 'e test] ' P ' Test si "2500 Casin 640' 250o 2500 ! 2500 I P/F I '-P, I .- , lYP I . p !~ ~ I . .gl ..I ., I . ..-., Notes: OA pressure 125 - 210 during pressure test. ~ . , ' W~,,I G-22 I'~Ype,nj.l' S' r'T'.V.D. 1,8~s2 I Tubingl ~o~'1 ~ooi ~o01 ~o0 I intervall 4 P.,T,.D.I. 1750160 ITypetes,t,I P, ,' ITestpsil 2350 I Casing l 6~0 ,']. 2350 I '2350 ! ~3so '1 PIE Notes: OA pressure 180 ps!: - 300 durin, g pressure test. , ..... . . We,I G-23RD I Type~ni.I 'S IT'v'D' I 84S9 ITu~ingl 3~001 3~001 3~001 3~00 I~nte~va~l 4 I P.T.D.I 1790140 I Type test'! P ITestpsil 2300 I Casingl' 560 I 2'300 I 2300 I 2300 I P/F Notes: OA pressure 86 psi. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S -- SALT WATER IN J, N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to Kenai Alaska 09-30-02 to be available to travel to the Grayling Platform @ 0630 hrs. 10-01-02. Testing went well w/Water Flood Operator David L. Meyers conducting tests in a safe& efficient manner. No failures were witnessed. All OA pressures were observed & recorded during tests. With no permafroSt concerns, all tests utilized'filtered Inlet water for test fluids. M.I.T.'s performed: _5 Attachments: Number of Failures: Total Time during tests: '4 hm,. CC: MIT report form 5/12/00 L.G. MIT Grayling Pit. lO-01-02jc.xls 101912002 STATE OF ALASKA ALASKA AND GAS CONSERVATION OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: X Other: , 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil .Company of California (UNOCAL) Development: 103' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: X Trading Bay Unit ...... 4. Location of well at surface Conductor No.14 Leg 4 Grayling Platform 8. Well number 1491' FEL & 1827' FSL of Sec. 29, TDN, R13W, SEWARD Grayling G-19 At top of productive interval 9. Permit number/approvai number 3169' FEL & 578' FNL of Sec. 29, TDN, R13W, SEWARD 69-17/398-127 At effective depth 10. APl number 3188' FEL & 292' FNL of Sec. 29, TDN, R13W, SEWARD 50- 733-20178-00 At total depth 11. Field/Pool 3162' FEL & 240' FSL of Sec.20, TDN, R13W, SEWARD McArthur River/Hemlock 12. Present well condition summary Total depth: measured 12,291' feet Plugs (measured) Bridge plug @ 11,180'. true vertical 11,307' feet Otis "X" plug in XN nipple @ 11,043'. Effective depth: measured 11,180' feet Junk (measured) true vertical 10,335' feet Casing Length Size Cemented Measured depth True vertical depth Structural 363' 26" Driven 363' 363' Conductor Surface 520' 17-3/4" 700 sx 520' 520' Intermediate 4749' 13-3/8" 1800 sx 4749' 4520' Production 11,217' 9-5/8" 1000 sx 11,217' 10,363' Liner Perforation depth: measured 10,565'- 11,152' true vertical 9792'- 10298' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 9,917' Packers and SSSV (type and measured depth) Baker 9-5/8" Model "D" Pkr @ 9,840' RECEIVED Otis 9-5/8" BWH packer @ 11,034' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~$ka 0JJ & Gas Cons. Commission Anchorage .... 14. Representative Daily Average Production or Injection Data Water Injector. OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in since 12/92. Subsequent to operation 6/17/1998 0 0 10,899 500 2100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X" Oil: Gas: Suspended: Service: X ~ W~ i J~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: 0 Signed: - Dale A. Haines Title: Drilling Manager Date: 6/18/1998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE '~~)I Grayling G-19 Workover Daily Summary June 1998 6/5/98 ND tree, NU BOPE. Pressure test BOPE to 250 and 5000 psi. 6/6/98 Pulled tubing seals from packer. Circulate well. Pulled tubing above packer and experienced increased losses to formation. Pumped sized salt pill. POOH laying down 4-1/2" tubing. 6/7/98 Change top rams to 5" and test. RIH with 8-1/2" bit/casing scraper clean out assembly. Tag WD packer at 10,389' Circ BU and POOH. 6/8/98 RIH with 9-5/8" retrievable bddge plug. Set bridge plug at 55' and attempt to pressure test wellhead packoffs. Bddge plug leaking. POOH with bddge plug. Set RTTS storm packer at 55'. Pressure test wellhead, secondary packoff leaking. Change out tubing head and secondary packoff. Pulled RTTS. RIH with retrievable bridge plug/RTTS casing test assembly. 6/9/98 Set RTTS at 10,320'. Pressure test annulus would not hold, 890 psi bled to 440 psi in 10 minutes. Released RTTS and set bddge plug at 10,310'. Set RTTS at 10,295'. Pressure test good between bridge plug and RTTS at 2400 psi. POH with RTTS to locate leak. Injected into leak at 1 bbl/min and 1300 psi. Isolated leak between 5245' and 5331'. POOH with RTTS. 6/10/98 RIH and retdeve bridge plug with drill pipe. RIH with packer mill. Tag packer at 10,387' and mill to 10,389'. 6/11/98 POOH with packer. RIH with bit and scraper clean out assembly. Wash and ream from 10,989' to 11,018'. POOH with clean out assembly. RU. Schlumberger. Troubleshoot software problems. 6/12/98 Run USIT casing inspection log. Top of cement at 8600', bad spot in casing at 6485', hole in casing at 5280'. RIH on. E-line with Model D packer/tailpipe including shear out nose in tubing tail. 6/13/98 Set packer at 9840' ELM. POOH and dg down Schlumberger. RIH with lower scab liner hanger and liner top packer on drill pipe. Drop ball and set top of packer at 6541'. Pressure test through drill pipe to 2400 psi, good. (Lower ZXP packer is holding). Rotate off with running tool and POOH. RIH with 7" liner and upper liner hanger and ZXP packer. Stab seals at 6541' and drop' ball to set upper hanger. 6/14/98 Set upper hanger and top of upper ZXP packer at 5152'. Pressure test annulus to 2400 psi. Unable to hydraulic release HR running tool. Work down left hand torque to release HR running tool. POOH with ddll pipe. Run dailysummar¥.doc 4-1/2" L-80, 12.6# buttress modified completion tubing. Stab seals into packer at 9840'. Right hand release from anchor and PU to space out. Reverse circulate corrosion inhibited packer fluid. 6/15/98 Land tubing, test pull on anchor latch to 25k. Test annulus to 2400 psi. Pressure up tubing to 3000 psi to blow out shear nose on end of tubing tail below packer. ND BOPE, NU and test tree. Move Rig. 6/16/98 Perform MIT to 2285 psi, witness waived by Lou Gdmaldi-AOGCC. dailysummary, doc 7' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Unocal FIELD / UNIT / PAO: McAfl~rRiver/Grayling. .. DATE: 6/f6/~8 '- 9,143- 1,700 '1,700 1,700 I~7~ 3:00 G-19 S ! ~% kcl/fi~ 9,835 9 ~8 4~ N-80 4.~ p~85.8 600 2,285 ' 2,285 .. 2,285 AM X COMMEN~S: ," I II COMMENTS: ~OMMENTS: ' , 'TUBING INJECTION FLUID: P = PRODUCED WATER INd. S = SALT WATER INJ M = MISCIBLE INJ. I= SNJECTION N = NOT INJECTING D]st~lbLUion: orlg- Well Fi)e c- Opemt~ c- Database c - Trip Rpt File e- Inspecior ANNULAR FLUID; P.P.G. Grad. WELl- TEST: DIESEL J 0.00 lniUel. . GLYCOL t 0.00 _ 4 - Year_ SALT WATER 8.5 0.45 Workover_ DRILLING MUD - 0,00 _ OtherL X OTHER 0,00 AOGCC REP SIGNATURE Wfiness waived by Louis Grimatdi 6/14/98 OP~T~R REP SIGNATURE ~ , FI O"..i(Rev. RKB to TBG Head = 42.78' Tree connection: 13-3/8" O 4749' 9840' 7 Bridge Plug @ 11,180' 9-5/8' {) 11,216' I 8-1/2" TD = 12,291' 13-1 B-2 = B-4 B-5 B-6 B-7 MAX ANGLE = 28° @ 4400' KOP @ 2000' G'lgjun14.doc SIZE 17-3/4" 13-3/8" 9-518" 9-518" 9-5fa" 9-518" 9-518" 'l~bing: 4-1/2" 7" scab liner, 5152'-6608' ZXP Packers 5161'-6550' USIT Log Hole @ 5280' iBad Spot @ 6485' RTTS Hole 5245'-5331' As Run 6/14/98 Trading Bay Unit Well # G-19 GRADE CASING AND TUBING DETAIL MD CONN ID TOP MD TVD BTM. B'I2Vl. CMT 1~" Wall .312 wall 61 47 4O 43.5 47 47 29 12.6 Sur~L Weld Surf. J-55 Seal Lock 12.515 Surf. N-gO Buttress 8i681 Surt: N-80 Buttress 8.835 76' N-80 Buttress 8,755 4981' N-80 Buttress 8.681 6853' P-110 Burgess 8.681 8421' L-80 Buttress 6.11M 5152' L-80 Butt Mod 3.958' 0' 520' 4749' 76' 4981' 6853' 8421' 11217' 6608' 9917' Driven None JEWELRY DETAIL NO. Depth ID Item 42.78' btm · 4-1/2" CIW Tbg Hgr, · 4-1/2" 8rd top x 4-1/2" butt mod bottom 9917' 3.958 '4-1/2" Buttress modified tubing 9840' Model E Anchor. 9840' 4.75 Baker Model D Packer set on wireline, ELM 9844' 4.75 Mill out E~. 9847' Tubing tail is screwed below packer seal bore 9884' 3.813" ~1/2" ' ,'X" Nipple 9917' 3.96" WLEG with shear-out solid nose 7 11,034' 4.000" Otis B%~ pkr 8 11,043' 2.635" 3-1/2" Otis "XN" nipple with plug 9 11,045' 2.99" 3-1/2" tubing tail WLEG FISH 8.5" bit cleaned out to 11,1018' DPM 6/11/98 SLICKLINE WORK Tagged fill wi pressure bombs 8/21/93 2.4" GE prior to BHP survey I~1/97 @ 11,035' I1,010' PERFORATION DATA ACcum Last Zone ,Top Btm Amt SPF Pert Date Present Condition HB-1 10,565' 10,595' ,30' 12/11/89 Open for iqjection HB-2 , 10,610' 10,715' ,105' 12/11/89 Open forinjecUOn HB-3 10,735' 10,830', 95' 12/11/89 Open for injection HB-4 10,860' 10,910' 50' 12/11/89 Open for injection HB-5 10,,930' 11,030' 100' 12/11189 Open for injection HB-6 1,! ,050' 11,115' 65' 4/22/69 Below XN plug HB-7 11,140' 11,152' 12' 4/22/69 Below XN plug , , I , , , , , , , REVISED: 06/18/98 ]-'~D AI, IFNT l~V, TALC) r'L STATE OF ALASKA CL ALASKAO AND GAS CONSERVATION MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x variance: Perforate: Other: ......... 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 103' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 1491' FEL & 1827' FSL of Sec. 29, T9N, R13W, SEWARD Grayling G-19 At top of productive interval-Hemlock 9. Permit number 3169' FEL & 578' FNL of Sec. 29, T9N, R13W, SEWARD 69-17 At effective depth 10. APl number 3188' FEL & 292' FNL of Sec. 29, T9N, R13W, SEWARD 50- 733-20178-00 At total depth 11. Field/Pool 3162' FEL & 240' FSL of Sec.20, T9N, R13W, SEWARD McArthur River/Hemlock _ -., ,-- ~ ~ I 12. Present well condition summary }~ ~. L ~ ~ V Total depth: measured 12,291' feet Plugs (measured) true vertical 11,307' feet Effective depth: measured 11,180' feet Junk (measured) true vertical 10,335' feet ~JaSk3 0il & Gas Cons. Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural 363' 26" Driven 363' 363' Conductor Surface 520' 17-3/4" 700 sx 520' 520' Intermediate 4749' 13-3/8" 1800 sx 4749' 4520' Production 11,217' 9-5~8" 1000 sx 11,217' 10,363' Liner Perforation depth: measured 10,565'-11,152' true vertical 9792'-10298' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 10,480' Packers and SSSV (type and measured depth) Otis 9-5/8" WD Perm pkr @ 10,387' Otis 9-5/8" BWH packer @ 11,034' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: x ,,,,, 14. Estimated date for commencing operation 15. Status of well classification as: 5/25/98 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: p~ ~l ~ Dale Haines Title: Drilling Manager Date: 5/1/98 Conditions of approval: Notify Commission so representative may witness JAppr?.~al, oNo~ Plug integrity y Test ~ Location clearanceI O ~' ,./. _ / C;~ Mechanical Integrity Test Subsequent form required 10-1-~O ~ - .j.'~aJ Signed BY ~'~~ Approved by order of the Commissioner Oavid W, Johnston .-'~ commissioner Date '-~'-'- ,J J J ~' ~) Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE RKB to TBG Head --' 42.31' Tree connection: 13-3/8"@ 4749' L 12,882' 7 B-6 B-7 Bridge Plu,g T I 8-1/2" TD -- 12,291' MAX ANGLE = 28o @ 4400' KOP @ 2O0O' B-1 B-2 B-3 B-4 B-5 G- 19schematic.doc Drilled 1969 Trading Bay Unit Well # G-19 Last WO 12/15/89 SIZE WT GRADE CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. CMT 26" 1/2" Wall 17-3/4" .312 wall 13-3/8" 61 J-55 9-5/8" 47 N-80 9-5/8" 40 N-80 9-5/8" 43.5 N-80 9-5/8" 47 N-80 9-5/8" 47 P-110 Tubing: 4-1/2" 12.6 N-80, IPC 4-1/2" 12.6 N-80, IPC Surf. Weld Surf. 520' Seal Lock 12.515 Surf. 4749' Buttress 8.681 Surf. 76' Buttress 8.835 76' 4981' Buttress 8.755 4981' 6853' Buttress 8.681 6853' 8421' Buttress 8.681 8421' 11217' MMS Butt Drift=- 0' 10,407' OD=5.000'' 3.779" MMS butt Drift = 10,419' 10,480' OD=4.950'' 3.779" Driven JEWELRY DETAIL NO. Depth ID Item 42.31' 4-1/2" CIW Tbg Hgr, 4-1/2" 8rd top x 4-1/2" US Imprvd Nat'l butt btm 1 10,373' 3.813" Otis 4-1/2" "XA" Sliding Sleeve 2 10,406' Locator Seal Assy. w/11' of seals. 3 10,387' dpm 5.00 Otis WD Pkr 4 10,392' dpm 5.00 Seal Bore Ext. 10,399' btm Tubing tail is stabbed thru seal bore 5 10,448' 3.813" Otis 4-1/2" "X" Nipple 6 btm 10,480' 3.96" WLEG 7 11,034' 4.000" Otis BWH pkr 8 11,043' 2.635" 3-I/2" Otis "XN" nipple with plug 9 11,045' 2.99" 3-1/2" robing tail WLEG FISH SLICKLINE WORK Tagged fill w/pressure bombs 8/21/93 ~ 11,035' 2.9" GR prior to BHP survey 12/1/97 I 1,010' PERFORATION DATA ~,.ccum Zone Top Btm Amt SPF Perf Date Present Condition H13-1 10,565' 10,595' 30' 12/11/89 Open for injection H13-2 10,610' 10,715' 105' 12/11/89 Open for injection HH-3 10,735' 10,830' 95' 12/11/89 Open for injection I-II3-4 10,860' 10,910' 50' 12/11/89 Open for injection HB-5 10,930' 11,030' lUU' 12/11/89 Open for injection HU-§ 11,050' 11,115' es' 4/22/69 Below XN plug H13-[ 11,140' 11,152' 12' 4/22/69 Below )~N plug REVISED: 4/18/97 DRAWN BY: TAB UNOCAL Grayling Well( 19 Rig Workover Workover Procedure Objective: The objective of the workover on G-19 is to repair tubing and/or casing leaks so this well can pass a MIT and return to injection. The well is currently a shut-in water injector in the Hemlock formation. The proposed workover will remove the single tubing string and upper packer. A lower packer above the Hemlock Bench 6 zone will be left in place during the workover. A test packer will be run to evaluate the integrity of the 9-5/8" casing. If any leaks are found, repair options will be evaluated and performed as needed. A new single packer with 4-1/2" injection tubing will be run high enough to allow for the possibility of future addition of the G-zone. Workover Procedure: 1. Check tubing for pressure. Ensure annulus is full of liquid. 2. Install back pressure valve. ND tree. 3. NU BOPE, pull BPV and install 2-way check. witness. Test BOPE with 24 hr notice given to AOGCC for 4. Pull 2-Way check valve. Engage tubing hanger and POOH laying down tubing. 5. RIH with 9-5/8" test packer and bridge plug. Set bridge plug at 9850' and test integrity of 9-5/8" casing above bridge plug. Repair casing as necessary.' 6. RIH and mill packer at 10,387'. POOH with packer. 7. Run 4-1/2" completion with permanent injection packer at 9850' MD/9152' TVD. 8. Set BPV and ND BOPE. NU tree and test annulus to 2300 psi with AOGCC witness for injection well MIT. 9. Release rig. Start water injection. AOGCCproG 19.DOC 5/1/9 8 RKB to TBG Head = 42.31' Tree connection: SIZE 26" 17-3/4" 13-3/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" Tubing: 4-1/2" Trading Bay Unit ( .... Well # G-19 Proposed Casing Repair Workover, 6/98 GRADE CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. 1/2" Wall .312 wall 61 47 40 43.5 47 47 12.6 Surf. Weld Surf. 520' J-55 Seal Lock 12.515 Surf. 4749' N-80 Buttress 8.681 Surf. 76' N-80 Buttress 8.835 76' 4981' N-80 Buttress 8.755 4981' 6853' N-80 Buttress 8.681 6853' 842 I' P-110 Buttress 8.681 8421' 11217' L-80 Butt Mod 3.958' 0' 9950' CMT Driven 13-3/8"@ 4749' 9850' 9-5/8"@ 11,216' JEWELRY DETAIL NO___:. Depth ID Item 42.31' 4-1/2" C1W Tbg Hgr, 4-1/2" 8rd top x 4-1/2" butt mod bottom 9850' 3.958 4-I/2" Buttress modified tubing 1 9850' Locater Seal Assy. w/15' of seals. 2 9850' 5.00 Baker Model D Packer set on drill pipe 3 9865' 5.00 Seal Bore Ext. Tubing tail is stabbed thru seal bore 4 9900' 3.813" 4-1/2" "X" Nipple 5 btm 9950' 3.96" WLEG B,1 7 11,034' 4.000" Otis BWH pkr 8 11,043' 2.635" 3-1/2" Otis "XN" nipple with plug 9 11,045' 2.99" 3-I/2" tubing tail WLEG FISH Possible G-zone Add perfs SLICKL~E WORK Tagged fill wi pressure bombs 8/21/93 ~ 11,035' 10,035'- 2.4" GR prior to BHP survey 12/1/97 11,010' 10,475' / PERFORATION DATA /4gcum Last Zone Top Btm Amt SPF Perf Date Present Condition Hu-1 10,565' 10,595' 30' 12/11/89 Open for injection I-IB-Z 10,610' 10,715' 105' 12/11/89 Open for injection HB-;~ 10,735' 10,830' 95' 12/11/89 : Open for injection HI::l-4 10,860' 10,910' 50' 12/11/89 Open for injection HI:I-5 10,930' 11,030' 100' 12/11/89 Open for injection HB-U 11,050' 11,115' t~' 4/22/69 Below XN plug Ht~-~ 11,140' 11,152' 12' 4/22/69 Be~ow XN p~ug ,, B-2 B-3 = B-4 7 - B-5 8-1/2" TD = 12,291' MAX ANGLE = 280 @ 4400' KOP @ 2000' G- 19propAOGCC.doc REVISED: 05/01/98 DRAWN BY: TAB TO OEP, RICK VENT TO GAS BUSTER /I~ TO WELL CLEAN' TANk: / AUTOMATIC CHOKE CHOKE ;-V'~" ;-V'~" /l"X ;-'~/'~i" FROM CHOKE LINE VALVES UPSTREAM OF CHOKES ARE 10,000 PSi GATE TYPE VALVES 00WN~EAM OF CHOKES ARE ..5,000 PS[ GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: OAC APP'O: GS8 SCALE: NONE DATE: 11/26/~9 25'-9":1: (~- FLOOR 18'-:?':1: TO SHAKERS 'CTYP 2) I' 5'-8'd: . I DRIP PAN HYDRIL ANNULUR PREVENTER 8OTTOM OF' SI~AI, H, OU$1NG~ ¢'-10~'± SHAFT'ER OOUBL£ GATE: BOP 2'-10' GRAYLING PLATF:~RM COOK INLET. ALASKA GRAYLING PLATFORM SHAFFER BLOW OUT PREVENTER STACK ELEVATION UNOCAL~ [_.,G-D-°3311 MIXIN~ PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM / TRIP TANK 45 BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS 67 BBLS 250 BBLS DEGASSER [ DESILTER SHAKER SHAKER RESERVE PIT 475 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WffH A DRILLING PIT LEVEL INDICATOR WITH AUDIO & VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISLIAL. & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE lO) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN BY: DAC APP'D: GSB SCALE: NONE DATE: 11--30--89 ¢~UG-22-97 FP, I 15:57 UNOOC, L ¢~SSET G¢,S GP, P FhX NO, 9072637874 P, 03/04 P~r0cedure, for,MIT on Shut-in Graylin; Injector G-19 -- 1. Record daily tubing, casing, and outer casing pressures for a consecutive ten day period. Date Tubing Pressure, Casing Pressure Outer Casing Pressure 711/97 120 0 ..... 0 .... 712197' .... 120 .... 0 .... ,0. 7/3/97 120 0 0 7/4197 120 ......... p .... 0,, ,,~ 7/5/97 120 ......... 0 7/6/97 .......120 ,,, 0 ..... 0 ....... 7/7/97 .... 120 .... 0 .......0 ........ 7/8/97 100 0 0 7/9/97 ,, 100 ...... 0 ......... 0 .... 7/10/97 100 .... 0 ...... 0 .. .. -- O STATE OF ALASKA ALASKA . AND GAS CONSERVATION COI~ SSION REPORT F SUNDRY WELL OPI 'n'ATIONS 1. Operations performed: Operation shutdown Stimulate __ Plugging __ Perforate __ Pull tubing __ Alter casing__ Repair well __ Pull tubing OtherX__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1491' FEL, 1827' FSL, Sec. 29, T9N, R13W, SM At top of productive interval 3182' FEL, 4708' FSL, Sec. 29, T9N, R13W, SM At effective depth 3242' FEL, 221' FNL, Sec. 29, T9N, R13W, SM At total depth 3194' FEL, 288' FSL, Sec. 20, T9N, R13W, SM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service X 6. Datum elevation (DF or KB) 103' RKB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-19 feet 9. Permit number/approval number 69-17/92- 238 10. APl number 50-733-20178-00 11. Field/Pool McArthur River Field/Hemlock 12. Present well condition summary Total depth: measured true vertical 12291 11307 feet feet Effective depth: measured 11180 feet true vertical 10409 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Size Cemented Structural 363' 26" Driven Conductor Surface 520' 17-3/4" 700 sx Intermediate 4749' 13-3/8" 1800 sx Production 11216' 9-5/8" 1000 sx Liner Perforation depth: measured Uppermost: 10565' Lowermost: 11152' Measured depth 363' 520' 4749' 11216' True verticaldepth 363' 520' 4520' 10363' true vertical Uppermost: 9792' Lowermost: 10298' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 Packers and SSSV (type and measured depth) Otis BWD permanent packer @ 10400' RECEIVED OCT 1 9 199;~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Anchorage 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 RoY 06/1 Date SUBMIT I"N DUPLICATE Unocal North Am~~ ~n Oil & Gas Division~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region October 7, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: I am enclosing a copy of the letter that I wrote to Dave Johnston that accompanied the temperature log that was run on G-19 on November 23, 1992. Ralph p. Holman RPH/rph RECEIVED OCT 1 9 199~ ,Alaska 0il & Gas Cons. 6omnllssio~'~ Anchorage ),. Unocal North American./-".. Oil & Gas Division .... f, ~ Unocal Corporation [ " P.O. Box 190247 % Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region January 8, 1993 Mr. Dave Johnson AOGCC 3001 Porcupine Drive, Anchorage, Alaska Dear Mr. Johnson: As you will recall, Unocal is requesting an MIT variance for well G-19 on the Grayling platform. I have enclosed the temperature Icg and the interpretation by Atlas Wireline as requested by Blair Wonzell when I spoke with him in November. If I can be of further assistance please contact me at 263-7838. Ralph P. Holman Engineer Technician RPH Attachments File Raymond Walker RECEIVED OCT 1 9 1993 Alaska Oil & Gas Cons, Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1~3 TELECOPY: (907) 276-7~2 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, , In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. , · To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the Form ~ 0-404 is required to be filed within 30 days following completion of work. In previous telephone conversations concerning the subject, it had been_~explained to me that either ARCO or Marathon had been thin,operator on the majority of the work proposed; however, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application-of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated We would also appreciate notification of any canceled Work so that the corresponding Application· on file can 'be marked accordingly ........ Sincerely, · Statistical Technidan o.. D-4 82-41 D-sRD'." 80-65 D-26 74-9 5-31-91,' 91'163 7-2-91, 91-188 11-22-91, 91-353 Perforate 5-91 Workovef 4=91 Perforate 11-91 10-403 Signed By G. Bush ?!'G, Bush G. Bush G. Bush D-27 75-24 D-40 82-83 9-2-91, 91-189 9-20-91, 91-284 '- 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 D-42 83-53 5-'31-91, 91-160 7-2-91, 91-190 D-46 G-5 G-6 · G-19 ~ 11-10-92, 92.-238 G-21 72-42 4-2I~92,'.':.92,094 · :i: .:~i':i~(-'..~. ':-'-:: :' . ·6-17-93, 93-154 · ,../. ~.'~..: ..- :" ..i · ' :-,:...:..::,~.: ·.-: :. .-. G-27 ··'78-70 '::*"'" 4.-21~92, 92-95 !76193, 92-203 · · G-31 .69-72 3-21-91, 91-95 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&~4 10-3-91 . Perf 5-91 Scale Cleanout 6-20-91 ~'. . ~ 4~21~92,_92.-093 Per£ 4-92 - .. K-1 67-65 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 K-2RD 78-38 K-3 80-144 2-9-90, 90-081 -. K-9 68-38 11-14-89, 9-987 Perf.. 5~91~ Shor~ A long inj. profile (If work was co~leted~ the 10-403 're~ired a 10-407, Completion, Reco~letion .' . report"for t~s wel~. G. Bush'- G. Bush G. Bush G. Bush G. Bush · .- G. Bush G. Bush ~. Bush G. Bush Perforate G. Bush . . Temp. log 10-15-92 G. Bush.' Production profile : G. Bush Perforate 2/90 R,' Roberts Perf., cement squeeze Stim, p.. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G, Bush Perforate 2/90 R. Roberts Repair well, p.. tubing, stimulate, perforate R. Roberts . . . ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 20, 1993 Ralph P. Holman Engineer Technician UNOCAL P.O. Box 190247 Anchorage, AK 99519-0247 Re: Approval to continue injection into UNOCAL well TBU G-19 Dear Mr. Holman: As you requested in your January 8, 1993 letter, we have evaluated the November 23, 1992 temperature log run on well TBU~G-19. We agree that there are no significant leaks in the tubing or packer; therefore, in accordance with AS 31.05.030(h), you have our approval to continue injection provided that subsequent MITs be run at least every other year to demonstrate the integrity of the tubing and packer. Chairman ~"-.....~ ~ ' ~;) printed on recycled paper b y 0~. September 25, 1992 (Revised November 10, 1992) Mr. Dave Johnson AOGCC 3001 Porcupine Drive, Anchorage, Alaska 99501 Dear Mr. Johnson: On September 22 I discussed well G-19 with Blair Wonzell. This well is an injector on the Grayling platform and has failed an MIT. I spoke with the drilling engineer and foreman that were present when the MIT was performed and both are of the opinion that the tubing and packer have good integrity and that the leak is through a hole in the 9 5/8" casing. From there, they speculate that the water is leaking into the formation through the 13 3/8" casing Shoe. Unocal is proposing to run a temperature log to confirm this condition in order to request an MIT variance and resume injection into this well. Your cooperation is appreciated. - ,ti Sincerely yours, Ralph P. Holman Engineer Technician RPH Attachments RECEIVED JAN 1 2 t993 Alaska Oil & Gas Cons. (;ommiSsio~ ~nchorage Unocal North Americ~~ Oil & Gas Division ~ Unocal Corporation ' P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region January 8, 1993 Mr. Dave Johnson AOGCC 3001 Porcupine Drive, Anchorage, Alaska Dear Mr. Johnson: As you will recall, Unocal is requesting an MIT variance for'Well G-19 on the Grayling platform. I have enclosed the temPerature log 'and the interpretation by Atlas Wireline as requested by Blair Wonzell when I spoke with him in November. If I can be of further assistance please contact me at 263-7838. Sincerely yours, Ralph P. Holman Engineer Technician RPH Attachments CC; File Raymond Walker Western Atlas International A Litton/Dresser Company ATLAS WIRELINE SERVICES January 6, 1993 Mr. Raymond Walker Unocal North American Oil & Gas Division P. O. Box 190247 Anchorage, AK 99519-0247 G-19 TEMPERATIJRE LOG - PACKER INTEGRITY SURVEY Atlas Wireline Services ran a temperature log in well G-19 on the Grayling Platform on November 23, 1992 to investigate the integrity of the packer. Prior to logging the well was shut-in for over a week. A base line temperature log was then run. Water was then injected into the well at a rate of 13,000 BPD (542 bbl/hr) for several hours. The well was then shut-in and a second temperature pass was made. The following comments pertain to the interpretation of the logging results. BASE LINE PRIOR TO INJECTION The solid curves represent the long-term shut-in data. Obviously, this well has had significant volumes of water injected into the perforated intervals by virtue of the cool temperatures when compared to the overburden temperatures found above the tubing tail and packer. Note that the packer assembly appears to be located at approximately 10400 to 10415 ft.o~ Minor variations of the temperature curve above the packer can be attributed to lithology variations (varying thermal conductivity). Long term injection water appears to have entered the intervals from 10570 to below the fill found at the bottom of the well. Note that the shut-in temperature below 10655 ft is slightly colder than the injection temperature. This may be explained by variations of injected water temperature and by frictional, near wellbore heating that occurred during injection. No injected water appears to be found in any zones above this interval, based on the shut-in data. RECEIVED JAN 1 2 3993 The Atlas Advantage AJaska Oil & Gas Cons. Commission 5600 B Street, Suite 201, Anchorage, Alaska 99518, (907) 563-3233, Fax (907) 561-4028 Anchorage Page 2 G-19 Temperature Log January 6, 1993 POST-INJECTION TEMPERATURE PASS The dashed curves represent the post-injection data. The temperature recorded after injection varies from approximately 85°F in the perforated intervals to nearly 100°F above the packer. The temperature increases rapidly by 10°F from the perforated intervals up to the tubing tail located slightly below 10450 ft. Packer integrity is confirmed by the lack of cool water found above the tail pipe and packer..assembly. If injected water had been placed above the packer assembly, a noticeable temperature anomaly should be present on the post-injection temperature curve. The minor variations that are present are probably lithology dependent. Also, there is a good possibility that a gas pocket is present behind the tail pipe. Notice the temperature decay is slightly slower below the packer. If gas is present below the tail pipe, the lack of thermal conductivity would prevent this area from warming. Oppositely, above the packer, the liquid would conduct heat back to the wellbore faster than would pipe with gas located in the annulus. If additional clarification or information is required, please contact me at your convenience. Respectfullv submitted, Chris Barnette Western Atlas International ATLAS WIRELINE SERVICES NUV-1U-gX 'rue 8:34. I~'~X No, 913'(x63'f884 ?, 02 LINOOAL - ~Nr. jHr. jI~AG.E RECEIVED Anchorage September 25, 1992 (Revised November 10, 1992) Mr. Dave Johnson AOGCC 3001 Porcupine Drive, Anchorage, Alaska 99501 Dear Mr. Johnson: On September 22 i discussed well G-i9 with Blair Wonzell. injector on the Grayling platform and has failed an MIT. This well is an I spoke with the drilling engineer and foreman that were present when the MIT was performed and both are of the opinion that the tubing and packer have good integrity and that the leak is through a hole in the 9 5t8" casing. From there, they speculate that the water is leaking into the formation through the 13 3/8" casing shoe. Unocal is proposing to run a temperature icg to confirm this condition in order to request an MIT variance and resume injection into this well. Your cooperation is a.ppreciated. Ralph P. Holman Engineer Technician RPH Attachments Unocal North American Oi~'~' 'ss Division Unocal Corporation ~[ 909 West 9th Avenue, P.O. Bo~. ,~6247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Edward J. O'Donnell Regional Engineering Manager Alaska Region September 25, 1992 Mr. Dave Johnson AOGCC 3001 Porcupine Drive, Anchorage, Alaska 99501 Dear Mr. Johnson: On September 22 I discussed well G-19 with Blair Wonzell. This well is an injector on the Grayling platform and has failed an MIT. I spoke with the drilling engineer and foreman that were present when the MIT was performed and both are of the opinion that the tubing and packer have good integrity and that the leak is through a hole in the 9 5/8" casing. From there, they speculate that the water is leaking into the formation through the 13 3/8" casing shoe. Unocal is proposing to run a temperature log to confirm this condition and is requesting an MIT variance~based on the results of the log. Your cooperation is appreciated. RPH Attachments Since~rely yours, / Ralph P. Holman Engineer Technician J ECEIVED SEP 3 0 1-99,2 Alaska 0ii .& (~as Cons, Commissi0~ Anchorage: ALASK~ ;_ AND STATE OF ALASKA GAS CONSERVATION CO(~";ISSION 0 ~ 16 IN A L APPLICATION FOR SUNDRY AP'i ROVALS 1. Type of request: Abandon SUspend Alter casing__ Repair well Change approved prog ram __ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247, Anchorage, Alaska 99619-6247 4. Operations shutdown ..~___/~-enter suspended well__ ~ Plugging ~ ~,.'3T~xtl~ Stirnulate__ ~_ Pull tub'~5. T~o of~ Perf° ra;.-~-at u mOte ;~ t~ n (~DFmo~; K(~i~' I Development X 103' RKB above MLLW I F--Xploratoly ~ ~~ feet I Stra~graphk= __ 7. Unit or Property name I Serv~e __ Trading Bay Unit Location of well at surface 1491' FEL, 1827' FSL, Sec. 29, T9N, R13W, SM At top of productive interval 3182' FEL, 4708' FSL, Sec. 29, T9N, R13W, SM @ 9789' TVD At effective depth 3242' FEL, 221' FNL, Sec. 29, T9N, R13W, SM @ 10409' 3VD At total depth 3194' FELl, 288' FSL, Sec. 20, T9n, R13W, SM @ 11307' TVD 8. Well number G-19 9. Permit number 69-17/9-483 10. APl number 50 -733 -213178 -0 11. Field/Pool McArthur River Field 12. Present well condition summary Total depth: measured true vertical 12291' feet Plugs (measured) 11307' feet Effective depth: measured 11180' feet Junk (measured) true vertical 10409' feet Casing Length Size Cemented Measured depth Structural 363' 26" Driven 363' Conductor Surface 520' 17 3/4" 700 sx 520' Intermediate 4749' 13 3/8" 1800 sx 4749' Production 11,216' 9 5/8" 1000 sx 11,216' Liner Perforation depth: measured Uppermost: 10,565' Lowermost: 11,152' true vertical Uppermost: 9792' Lowermost: 10,298' Tubing (size, grade, and measured depth) 4 1/2", 12.6#, N-80 (TK-99 Internal coating) Packers and SSSV (type and measured depth) Otis "BWD" permanent packer @ 10,400' True vertical depth 363' 520' 4520' 10,363' RECEIV£D S EP 0 Alaska 0il & Gas Cons. C0m~'ts~ ~Anchorage 13. Attachments Description summary of propoSal X Detail ed operations program__ BOP sketch 14. Estimated date for commencing operation 10/15/92 16. If PropoSal was verbally approved Name of approver 15. Status of well classification as: Oil __ Gas __ Date approved Service Water injector Suspended 17. I herebY ce..rtify that the foregoing is true and correct to the best of my knowledge. Signed ~aJ.~ ~, ~~ Title ~'~-:k,k.Z,l ~ ,,,,,~.~,,.~,., .~ ~ FOR COMMISSION USE ONLY Conditions of a'Pi3rovaE Notify CommissiOn so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~'Olf Approved by the order of the Co Form 10-403 Rev 06/15/88 Date Commissioner Date SUBMIT IN TRIPLICATE GRAYLING DISTANCE &~DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL _ LEG #3: LAT = 60o50' 22.569" LONG =151 °36' 46.519" 2,502,352.30 212,272.70 1804 1 2 .3 4 5 6 7 8 9 l0 ll 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 179'8 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G-33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG ~4: LAT = 60°50' 22.832" LONG =151°36' 48. 042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: 2 · LAT = 60o50' 23.575" LONG =151°36' 4Z. 505" ' 2,502,374.34 212,196.66 G- 14A 1825 2,502,376.65 212,192.79 G'l 9 1827 2,502,380.90 ,. 212,191.32 G-13 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 212,196.85 G- 5 1838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46' 212,204.05 G-2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 ,502,455.60 212,226.40 1906 (Reserved for Compressors) LEG #2: LAT = 60°50' 23.313" LONG =151°36' 45.982" 2,502,427. lO 212,301.20 1880 37 38 39 40 41 42 43 44 45 46 47 48 2,502,421.45 212,297.82 2,502,424.94 212,294.98 2.502,429.45 212,295.05 2,502,432.85 212,297.99 2,502,433.57 212,302,44 2,502,431.26 212,306.31 2.502,427.00 212,307.78 2,502,422.80 212,306.18 G-12, RD & 2 G-31 G-4 G-1 G-9 G-18 G-14 G-30 2;-502,420.60 ............. 212,302.25 ................... G-8 & RD 2,502,425.63 212,299.39 G-6 2,502,429.40 212,:300.83 G-32 2,502,426.27 212,303.38 G-1 6, 1874 1878 1882 1886 1886 1884 1880 1876 1874 1879 1882 1879 FEL 1409 1413 1415 1415 1412 1408 1404 1402 l'Zl04 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 1386 1 389 1389 1386 1 382 1378 1376 ._]378 ....... 1382 1385 1383 1381 AL,I~a Recj:an April 16, 1990 Alaska Oil & Gas Conservation Commission 300I Porcupine Dr. Anckorage, kK 99504 Attn: Ms. Elaine Johnson Dear ,Ms. JohnSon: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, GSB / lew STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing m Alter casing 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O, Box 190247. Ankh. 4. Location of well at surface 1491' FEL, 1827' FSL, Sec. At top of productive interval 3182' FEL, 4708' FSL, Sec. At effective depth 3242' FEL, 221' FNL, Sec. At total depth 3194' FEL, 288' FSL, Sec. Stimulate __ Plugging __ Repair well ~ 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service x___ 29, T9N, R13W, S.M. 29, T9N, R13W, S.M. At 9789' TVD 29, T9N, R13W, S.M. at 10409' TVD 20, T9N, R13W, S.M. at 11307' TVD Perforate ~ Other ~ 6. Datum elevation (DF or KB) 103' RKB above MLLW 7. Unit or Property name Tradln~ R~v Unit 8. VVe~I number - G-19 9. Permit number/approval number 69-17 / 9-483 10. APl number 50-- 733-20178 11. Field/Pool McArthur River Field feet 12. Present well condition summary Total depth: measured true vertical 12291 · feet Plugs(measured) 11307 ' feet Effective depth: measured 11180 · true vertical 10409 · feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth 363' 520' 4749' 11216' Size Cemented 26" Dr iven 17-3/4" 700 sxs 13-3/8" 1800 sxs 9-5/8" 1000 sxs measured Uppermost: Uppermost: trueverticalUppermost: Uppermost: 10565' 11152' 9792' 10298' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, Packers and SSSV (type and measured depth) O~ { m "RWD" 13. Stimulation or cement squeeze summary Measured depth 363' 520' 4749' 11216' N-80 (TK-99 Internal Coating) -- -- Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 363' 520' 4520' 10363' 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Injecting 10391 BWPD 2800 psi Injecting 10132 BWPD 1575 psi ~bingPressure 3025 psi 2475 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended ServiceWater Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~/'~..~'~f (~itleEnvironmental Form 10-404 Rev 06/15/88 Engineer Date 3/16/90 SUBMIT IN DUPLICATE FROM General ~outekeapi~~~l$ _~ ~d ,,8~ec~.m,s .~..,~s~al~~, A~io_ · P~p ina~, el~s, ~es. 200 ~l.w ~ai~.~ ..... ~~ . ,_ Coa~wola, ~a,ter__ . _.. _ ....... ._ _ ......... _ ~ ........ _ '. ..... ' - --L~ ..... ' ' ' - ~ ~ -~ ~'- ~ I .... -- ~ . . ..;~.- tn~, Xall ~ Tea~ ~esSu~e P~pe Ball Type ~'~Tes~ ~. C, ~. Valve ~. Valves ....... , ....... . ...... . ...... ,. -.-- Xill ~ine Valvae ,. ~, C~ee~ Valve A~m~able Obo~em ' , '" , e~a~md choke / . hpa~r or hplaeomon~ o~ ~atled equipment ~o be ~ad. w~t~tu ~lya a~d X~s~eGto~t CO. tandOm O~ime ~o~ifAed. ......... , ' ,, . . .. _ ~ . .................. ,. _....~ .... ~_. _ ............ ~ ...... ._~_.. :Z_ ~ ...' .......-" , .... ..... '~ ~' [ 'STATE OF ALASKA r 11 P, A~ <A OIL AND GAS cONSERVATION COMIV~ ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter sUspended well -- Alter casing __ Repair well __ Plugg~g __ Time extension __ ..Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate L Other 2. Name_or Operator n~on uil Company of CalifOrnia (UNOCAL) ..Address u. t~ox 190247, Anch, Ak., 99519-0247 5. Type of Well: Development __ ExplOratory __ Stratigraphic Service-cc_- 4. Location of well at sudace ~i~,g ~o~ml~ g #4 Con ucto #1 /~ Cor{zer, ~ec. 59, ~N, R13W, SM. At top of productive inte~al 2938' N & 1610' W of ~urface Location At effective depth At total depth 3773' N & 1595' W of Surface Location 12. Present well condition summary Totaldepth: measured 12,291' feet true vertical 11,307 ' feet Effective depth: measured 11,180' feet true vertical 10,338 · feet Plugs (measured) Junk (measured) 969 I;)at~ elevationaBove (D. EarM~,. KB) feet 8. Well number O-19 9. Permit number 69-17 10. APl number 50-- 733-20178 11. Field/Pool McArthur River/Hemlock Casing Length Size Structural 363 · 26" Conductor Surface 520' 17-3/4' Intermediate 4,749 · 13-3/8" Production 11,254' 9-5/8" Liner Perforation depth: measured true vertical Cemen~d Driven 700sxs 1,800sxs 1,O00sxs See Attached Tubing (size, grade, and measured depth) 4-1/2", 12.6# & 3-1/2", Measureddepth 363' 520' 4,749' 11,216' REEEiVED LIUN o 7 Alaska 0ii & Gas (;oas° (;ommisslon 9.2#, ~41~h~ra~L%, 529, ~ueve~icaldepth 363' 520' 4,529' 10,363' Packers and SSSV (type and measured degtD[s Pkr@ 10450'; SSSV @ 285' 13. Attachments Description summary of proposal X__ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: September 1, 1989 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. signed/~~ .~~.~_ Title Environmental Engineer Date 6/2/89 - ~,-,,, n. ~A'.~,A',,-tia ~ FOR COMMISSION USE ONLY Conditions o~'approva~ Notif~ommissioF".,~6 representative may witness I Approval No. Plug integrity __2 B(~P/'r~t__ Location clearance ...... o-" I /" Mechanical Integrity Test .~ Subsequent form required 10- / \ '- Return, eu ORIGINAL SIGNED BY Approved byorderoftheCommissioner LONNIE C. SMITH Commissioner Date Rev 06/15/88 SUBMIT IN TRIPLICATE GRAYLINE PLATFORM WELL G-19 WORKOVER PROCEDURE . . . . . Se . . e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move rig #55 over TBUS G-19, Leg #4, conductor #14. Kill Well. Install BPV, remove tree, install and test BOPE. Pull and lay down 4-1/2" production/injector string. Mill over and lay down Otis permanent packer set at 10,450' DIL. Clean out to top of cement plug at 11,180' ETD with an 8-1/2" bit and 9-5/8" casing scraper. The well was sanded back to 11,028' to restrict injection. Run a casing inspection log from ! 11,180' ETD to the surface. Pressure test the 9-5/8" casing from ~ 10,500' to surface with a (RTTS) packer. Set a cement retainer on wireline at 11,040' DIL and cement squeeze the Hemlock bench 6 & 7; 11,050' - 11,115'; 11,140' - 11,152'. RIH with 8-1/2" bit and 9-5/8" casing scraper and drill out cement retainer at 11,040' DIL. Continue to clean out to 11,180' ETD. RIH with an RTTS packer and set at 11,035' DIL and reverse pressure test (outside - in) the squeezed intervals; 11,050' - 11,115'; 11,140' - 11,152' with back pressure. Pressure test (inside - out) the same intervals to 2,000 psi. Change over to clean completion fluid. Selective perforate the Hemlock underbalanced with 7" OD tubing conveyed at 4 SPF as per Reservoir. Clean out to ~ 11,180' ETD with a 8-1/2" bit and 9-5/8" casing scraper. Run and set a 9-5/8" permanent packer at ~ 10,400' DIL. Run and stab a 4-1/2" x 3-1/2" tubing completion assembly through the packer set at ! 10,400' DIL. Remove BOPE and install a single tree. Return well to Production as a single 4-1/2" x 3-1/~'~~~ injector. Well control fluid: 3% KCL with filtered inlet wate~UN 0 SBHP: 4025 PSI Alaska Oil & Gas Cons. Commission ', Anchorage G-19 Perforation Record (Hemlock) 10,565' - 10,595' 10,610' - 10,715' 10,735' - 10,830' 10,860' - 10,910' 10,930' - 11,030' 11,050' - 11,115' 11,140' - 11,152' TVD 9,800' - 9,826' 9,839' - 9,930' 9,947' - 10,030' 10,055' - 10,098' 10,115' - 10,201' 10,218' - 10,275' 10,297' - 10,307' III o. o.. IV WELL"'. T.B.O.S:-. G.-1 g'.... INJ: 13 ... - -,- :.' .*..** 2~:: '.;.'--'"-":' ' .- f;-~ CASING & ABANDONMENT. .. DETAIL :~'"';:":":':.::; ...... · ' .: t ': ° =. ° '".'- '~'~:' 0 Rotary ,-,-~'&~'l; it 0.00' '-- ....... ' "; ' -::'":" o . I1) Tubing Hanger at 38,00' '. ii-:ii ..... .:..:;. - - · Iii) 17 3/4°. .312' Wall, Spiral Weld Casing at 520' '-. [.~:...-..'.-' IV) 13 3/8°, 61~o J-55 Seal Lock Casing at 474g' ' . .:.:'.':: . ~ ;:. V) Top Cement Plug at 11,180' "...:~'" Vi) ii 518°, 40~-43.5~ & 47~', N-BO & Pl10 ..:.'i:;;~: i!::i~· :: · Casing at 11,216' " ...;: :-.: :- ... TUBING DETAIL .. . · :!: :~ ~ ~.:. :, Otis Ball Valve at 285.33' "~:!."-.. Otis 'CX' Mandrels st 2)2311.03', 3)3812.62', ;':~::'::~.~. ': ;.'L. i.~..., 4)4995.53', 5)5810.71'o 6)6374.41', 7)6817.21 8)7261.26' 9)7705.70', 10)8141.83', :~::~:~ I 1) 10,404.41' 12) Otis Locater st 10,442.86' 13) Otis Packer at 10.450' W/Seal Assembly ,..... .:'~4 .... ' * ' From 10,443.96' To 10,465.14~ .:~r..,:-~.'"'~:':'::":" 14) 4' x :3 1/2' X-OVER st 10,465.14' - :: 15) Otis 'X° Nipple at 10.466.14~ "~':,:'~::~ 16)' Mule Shoe at 10,529.26~ · ' ~ .r*: · :.*:' i;.:::.::: ;:'. :.: ;....'i PERFORATION RECORD DA TE INTERVAL CONDITION ' ,~:;.i ~':;.I-; '~* .***.: **~:.;,'i 10,570' - 10,595' 15-t WATER INJECTION -'r~,~;':--'.~ 10,615' - 10.715' ~5-2. 10,735~ - 10,830' 15-'5/~- :; 10,860'- 10,910' 5-J~ 10.930' - 11,030' ~'~ :' :"::::-:-'....,... . 11,140' - 11,152' ~--! , 'ii,= :~.:.: ' .i',i: .'~'. 10,565'- 10,595'. HB'P1 INJECTION ;!ii:'!:.!;;.' 10,610' -- I 0,710' HBO2 ~ '1 '.-~i.i:ii":'~ :.. :',~":" :~1't~:;] :~'~ .-~ . .. ,: . .,-o.~ ,.: '~1~, .' . .' ' ..', ._.~"'--' o..~ :T~''0 . -* I.:1;~ ;'.'. 'VED "::;' -;:'~ i -:,l ' T:i:, i ~.::.. · t.l.~ tz-:.' · ;,-' °0 -t; "; '= '"'~:; '.'T~:. .' tm&wu BAW~ ~ ' :i~i:: ']'!:'- :. - :- .*:... · . . .' . .~ '%' ~ ·. · . 4 1/2~ 12.6~.' & 3 1/2~ 9.2~, N-80 TUBING 4~22/69 11103/76 : t i I I t . WELL TBUS G-19 INJ. "WELL SCHEMATIC BELL NIPPLE I FLOWLINE 2" KILL LINE WITH (2) 2" 5M VALVES ::L:' KILL LINE FROM MUD PMP ,&: CEMENT UNIT 12" ,3000 PS! ANNULAR I I BLIND RAMS PIPE RAMS I I PIPE RAMS RISER I 15-5/8" ,3M FLANGE ADAPTER ,3M x 5M 13-5/8" 5M FLANGE DOUBLE GATE 5M 15-5/8" 5M FLANGE 4-" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE ~:[:' I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 1,3-5/8" 5M FLANGE SINGLE GATE 5M 1,3-5/8" 5M FLANGE 10" 5M x 1,3-5//8" 5M ADAPTER CAMERON 5M DCB SPOOL 15-5,/8" DOPE 5M STACK ALL DRILLING OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: GSB SCALE: NONE DATE: ,3/12/89 17-;5,/-1-" @ 520' 4.7-1-9' 11"2-16' TUBING: DETAIL 1t XA SLEEVE 2 PERM. PACKER ~ +/- 1 0400' "×" NIPPLE RE-E NTI~Y i~U IDE HB 1 1 0565'-10595' HB'~.1 0795'-1 08;50' HB .,.1- 1 0860'- 1 091 0' HB .4- 1 09~i0'- 1 1 0;50' HB 6 1 1050'-1 1 11 5' 51QZ'D HB 7 1 1 140'-1 1 157.' SQZ'D TOC 11180' ETD ',~ELL '1"BUS !.~-1 9 IN, JECTOR PROPOSE D COl'~ P LETI ON UNION OIL COI',,,IPANY OF CAUFORI",IIA (db,::l UNOCAL) DDT,.VtN: CLL EiC,~,.LE: NONE DATE: ;3-6-89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance ~ Name of Operator ~ 5. Type of Well: 2. Union 0il Company of California (UNdCAL) Development__ / Exploratory __ t Stratigraphic __ 3'Addr. _0. BOX 190247, Anch, Ak., 99519-0 47 Service.~_~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate __ Other'X'x 6. Datum elevation (DF or KB) 99' RT above MSL 7. Unit or Property name Trading Bay Unit 4. Locat~n of well at, surface uona. ±~,Leg 4, 1827' N & 1491' W f/SE Corn., Sec. 29 T9N, R13W, SM. At top of productive interval 2938' N & 1610' W of Surface Location At effective depth At total depth 3773' N & 1595' W of Surface Location 8. Well number 9. Permit number 69-'17 12. Present well condition summary Total depth: mea§ured true vertical feet feet Plugs (measured) 4,487' feet 10. APInumber 50-- 733-20178 11. Field/Pool McArthur River Field RECEI. VED Effective depth: measured true vertical Casing Length Structural 363' Conductor Sudace 520' Intermediate 4,749' Production Liner 11,254' Perforation depth: measured ll,180'feet lO,338'feet Junk(measured) 4,503' Size Cemented Measured depth 26" driven 363' 17-3/4" 700sxs 520' 13-3/8" 1,800sxs 4,749' 520' 4,529' 9-5/8" 1,O00sxs 11,216' 10,563' See Attached true vertical Tubing (size. grade, and measured depth) 4-1/2", 12.6# & 3-1/2", 9.2#, N-80 ~ 10,529' Packers and SSSV (type and measured depth) Otis Packer ~ 10,450' SSSV ~ 285' 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service T~tj ection Suspended __ 17. I herelT~ certify that the fgregeing i, Ftrue and ~orrec.,t to the best of my knowledge. Signed "'- ~oy D. Robe, C~s Title Environmental Engineer Date ~/ FOR OOMM'IS$1ON USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity __ BOP Test __ Location clearance __ I Mechanical Integrity Test __ Subsequent form required 10 ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Commissioner 04/14/89 , , Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-19 Perforation Record (Hemlock) 1,4D 10,565' - 10,595' 10,610' - 10,715' 10,755' - 10,830' 10,860' - 10,910' 10,930' - 11,030' 11,050' - 11,115' 11,140' - 11,152' TVD 9,800' - 9,826' 9,839' - 9,930' 9,947' - 10,030' 10,055' - 10,098' lO,115' - lO,201' 10,218' - 10,275' 10,297' - 10,307' RECEIVED O019n GRAYLING PLATFORM WELL G-19 Request for Continued Operation Under the UIC program administered by the AOGCC, Unocal is required to notify the Commission of any injectors that do not conform to the UIC program. This is to notify the Commission that Well G-19, an active Hemlock injector injecting approximately 10,800 BWPD, demonstrated a tubing leak during recent testing. Work to repair this injector is scheduled sometime during 1~8~, This work schedule is consistent with that presented on November 6, 1~87 during the Trading Bay Unit injection review with the Commission. O01~n Union Oil Compar~~' California union DOCUMENT TRANSMITTAL February 27, 1985 FIRST CLASS MAIL TO: William Van Alen LOCATION: Anchorage AK ALASKA OIL & GAS CONSERVATION COMMISSION FROM: R.C. Warthen LOCATION: Alaska District Transmitting: Re: Trading Bay One (1) copy of directional survey report - tangential GE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: Alaska Oil & Gas Cons. Commission Almhorage February 19, 1985 Directional Services Pressure Services Chemical Transmission Systems Mr. Robert C. Warihen Union 0il Co. of CA P.O. Box 6247 Anchorage, Alaska 99502 Re: Level Rotor Gyroscopic Survey Job No. AK-LB-50009 Well: G-19 Trading Bay Unit Survey Date: February 2, 1985 Operator: McGuire RE: Resubmittion of survey using tangential calculation procedures. Mr. Warthen: Please find enclosed'the "Original'' and seven (7) copies our Level Rotor Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Si ncerel y, NL SPERRY-SUN, INC. Ken '~Broussard Di strict Manager Enclosures NL Sperry-Sun/NL Industries, I nc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECE[VED 0 4 I§85 ,, i .R'O.O ........... 0 ~ · -3. 0o: ';i J',.me 6. 1974 },k o J~$ R. Cai 1erbar Union Oil Co. any of California 90'9 ~e~ 9th $~ree~ ~mehorage. At~k~ 99501 ~he C~k Inlet area I f~u~ a form P-3 '~ice of Inten~) filed ~n a n~er %fading' Bay Llnit~ G~lg: P-3 da~ed 3~13-172. ~Io_ sub~.eque~t notice.. Bay Sta~e,. A-4: P-3 dated ti-9-70.' I{o $~bse~ent notice. Tradin~ Bay Stat~ A-9: P~3 dated II-13-70o Z~ subsequent Notice of Inten~ will be $~ie~ed for approval covering fo~.l well abamdom~nt a~ sub.~e=~ ~11 b~e, di~o~iti~n (i~e, either redrill s Ince. We wo~ld gppre¢tate a check on your records of thes,~ wells and information Thank you. Union Oil Company[?~ ;,alifornia -% State of Alas~ Dept. of Nat~al Resources 5001 Porcine Drive ~c~rage, ~aska 99501 Dear Mr. VonderAhe: Reference is made to your letter dated June 6, 1974 concerning several P-5 forms filed on a number of wells in the Cook Inlet area, which no subsequent notice of work done had been received. Listed below are the four wells in question along with several other wells which we submitted P-3 forms on and since have cancelled the work. ,Trading Bay Unit State G-19 Trading Bay Unit State G-8 Trading Bay Unit State G-1 Trading Bay Unit State G-1 Trading Bay State A-4 _- P-3 dated 3/13/72.~ P-5 dated 5/2/74. P-5 dated 5/6/74. P-3 dated 5/7/74. P-3 dated 11/9/70. Trading Bay State A-9 P-5 dated 11/15/70. Trading Bay State A-17 P-5 dated 12/15/70. Operations were suspended on Trading Bay State A-17 as a result of callapsed csg. A study is presently underway to evaluate the potential of abandoning the existing wellbore and redrilling to a downstructure location as a single string Hemlock Pool Injection Well. Until such time as the Hemlock Pool is determined to be susceptible to pressure maintenance, no well work is anticipated. The condition of the wellbore remains unchanged from that reported to you on the P-5 dated 12/15/70. In the future we will notify you upon any cancellations after submitting the fores required. ~~~ ~ ~ JUN 2 I974 DIVISION Oi OIL AND District Drlg. Supt. A~{C~RAG£ sk F15rm REV, 9-30-6 9 ,. Sabmit "Intentions" in Triplicat~/~ & "Subsequent Reports" in Duplicate OIL ~'~ GAS ,~L,. WEL~. ~ OT. ER water injector I ,5 ENG Union 0il Company of California $. ADDRESS OF OPERATOR : / o 909 W. 9th Avenue. Anchorase, Alaska 99S0~ ~ ~ r..~.~ 4. LOCAZiON O~ W~,' ~ ' ' '1 '! 13. ELEVA!rlONS (Show whether DF, RT, GR, etc. 99' RT above kkSL STATE OF ALASKA, OIL AND GAS CONSERVATIO.N COMMII~E SUNNY NOTICES AND REPORTS ON W (Do not use this fora for proposals m drill or 'p~o~osals.) use "APPLICATION 'FOR PE~iTL" ~or such 2. NADIR OF OPE~TOR $. APl NU3/IF, RICAL CODE 50-155-20178 6. LEASI~. DES/~NATION A.ND SERIAL NO. ADL 1~.594 ?. IF INDIA.N, A.L~O~ OR TRIBE NAAVI~ 8. UNIT~ FAR~ OR LEASE NAME Tra~ing Bay Unit 9. WELL NO. State G-19 (21-29) 10. FIELD AZqT) FOOL, OR WILDCAT Mckrthur River - Hemlock 11.' SEC.] T., R., M., (BOTTOM HOLE Sec. 29, TgN, R13W, Sq. IZ. P~tlVIIT BrO. 69-17 Check Appropriate Box To Ind~te N;at'ure Of"'N~)tice, Re, ,grt, or Other Dafa NOTICE OF INTENTION TO: SHOOT OR ACIDIZE I X~ ABANDONs REPAIR WELL ~_~ CHANGE PLANS ~Other) SUBSEQUENT REPORT OF : WATER SHUT-OFF ~ REPAIRING WELL SHOOTING OR ACIDIZING ABANDONMENT' (Other) (NOTI~: Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clear'If state all pertinent details, and give pertinent dates, including estimated date of starting any propo,ed work. Reference is made to original Sundry Notice of Intent dated 8/12/71 and approved 8/25/71. Proposed program is listed below: FOR STIMULATION: Trading Bay Unit State G-19 is a tlemlock Zone injector on the western flank of the field. lhe well is currently taking 15,200 B/D at 5475 psi. Over 70% of this water is entering the 2nd and 5rd bendxes with no injection into the 1st bench. The recent attempt to acid stimulate well G-19 dorm the existing tbg string proved unsuccessful, and indicated an ineffectiveness in diverting acid to the various benches. To achieve adequate stimulation, each bench in the Hemlock must be acidized individually. High pressure injection work on the Grayling injectors indicate there is almost no chance of stimulation and profile improvement aside from acidizing. The profile and injection volume was greatly improved by acidizing TBUS D-24, a Hemlock injector on the Dolly Varden Platform. It is proposed to selectively reperforate and acid stimulate individual benches using straddle packers, lhis procedure is designed to distribute the injected water over the entire 7 behches, provide improved profile, and increase the injection capability. I~rm P--3 lq_EV. 9-3O-69 ! Submit "Intentions" in Triplicate & "Subsequerit Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'EP,.~IT-~' 'for such 'p~o~osal~.) 1. WELL WELL 4. LOCATION OF WELL At surface 5. AP1 NUMEt~CAL CODE ! 6. I~E DESIGNATION ~ND SERIJ~L NO. 7. IF INDIA.N, ALLOTTEE OR TRIBE NA_M.E OTHER 2. NAME OF OPERATOR 8. UNIT, FARNi OR LEASE NAME 3. ADDRESS OF OPERATOR 9. WELL NO. 10. FIELD AND POOL, OR WILDC.~T TBUS G-19 W0 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PER1VLIT NO. ,4. Check Appropriate Box To I,ndicate Nature of N~tice, Re ~o., or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ] [ ARANDONs REPAIR WELL CHANGE PLANS lOther) SUBSEQUENT REPORT OF: WATER SIIUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENTs (NOTE: Report results of multiPle completion on Well Completion or Recompletion Report and'Log form.) . 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of st&rtlng proposed work. PROCEDURE: 1. Run ~adioactive tracer survey.· 2. Move over G-19 & kill well w/Inlet wtr & CaC12 if needed.. 3. Remove tree ~ install BOB. 4. Pull ~ I.d. all tbg. Retrieve permanent pkr at 10,4S0' Perf individual benches as per attached. RIH w/bit ~ csg scraper ~ CO to 11,180'+-. (?" scraper) Acidize w/straddle tool (Lynes pkrs) as per attached. Set retrievable pkr at 10,550'+- & inject thru dp. Run radioactive spinner - tracer survey thru dp. Set ?" pkr on wireline as indicated by profile logs. Run 3-1/2" tbg w/hydroset Pkr in 7", stab into lower pkr. Set ~ test pkrS. Disp annulus w/diesel oil as pkr tluid. Place well on injection - He~mlock Zone. BSTIMARtiD STARTING DA~' 6/25/72 SIGNED , i~. E. Ta'~[~l ' ' (This space for State 01[tce, use)~, APPROVED BY ~',1 ~ //~~~~~'''~ CONDITIONS OF'APPrOVAL, IF A~: TITLE Dtst, Dr!g. Supt, See [nstrucfions On Reverse Side DIViSiON ~' Oil DATE 3/13/72 Approved COpy Returned Form I~EV. 9-30-6 9 STATE O'F ALASKA S~brnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APP-LICATION 'FOR ~'ER~IT-A2, 'for such 'p~o~osal~.) AP1 NUA/Y_.R/CAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIA_N, ALLOTTEE OR TRIBE NA2VLE OIL ~-~ OAS WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT~ FAR~ OR L~SE NAME 3. ADDRESS OF OPERATOR 9. W'ELL NO. 10. FIELD A,ND POOL, OR WILDCAT TBUS G-19 continued 4. LOCATION OF WELL At surface 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PER1VIIT I~O. ~4. Check Appropriate Box To I,nd~cate Nature of NOtice, Re ~ort, or Other aJasa ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE J J ABANDONs REPAIR WELL CHANOE PLANE /Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , ABANDONME1VT* __ (Other) (NoTZ: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. ~ 5. Pump 1000 gal 2-1/2% HCL acid w/700# J-145 diverting material. All acid (Z-1/2% ~ 12% - 10%) treated w/A-150 inhibitor. ,.,Stage #2 thru #9: Repeated steps #2, 5, 4, S eight (8) times with final stage (stage 9) omittLng step #5. Displaced with 2-1/2% HCL acid. Utilized .total of 45,000 gal 2-1/2% HCL acid and 45000 gal 12% - 10% mud acid w/6500# J-145 diverting material. Observed pressure increases each stage as diverting material hit formation and pressure decreases as mud acid (12-10) hit formation. Initial Breakdown $ bbl/min at 1800#. Avg Injection rate 4-1/2 bbl/min at 2200#..~ax Injection rate $ bbl/min at 2600#. Final Injection rate 4-1/2 bbl/min at 2000#. Completed job at $:10 pm 11/17/71. Returned well to injection service -- }temlock Zone. 16. I hereby certify,' ~d correct SIGNED __ (This space APPROVED BY CONDITIONS OF APPROVAl.,, TITLE Dist. Drlg. Supt. D~TE 11/24/71 NOV 2 6 1971 TITLE See Instructions On Reverse Side DIVIGtON OF OIL AND '" ~' % ?~, ,.? Submit "Intentions"in Triplioate ~R.EV. 9-30-69 & "Subsequent Reports" in Duplicate ~, C. CEC)L · 5. AP1 NU1VIEBiCAL CODS ]--]" hi'AD STATE OF ALASKA OIL AND GAS CONSERVATION COMMITIEE . 50-155-20178 ~-_]~-_~.'.'[a~ I SUNDRY NOTICES AND REPORTS ON WELLS (Do not Use this £orm /or proposals to drill or to de'pen ADL 17594 t 4 use -A~.L~¢.~TmN '~.oR ~'~virr-" '~or su0h'~obosa~.~ ..... i'~ -$ EM© ~'. ' OIL WELL C GA8 ~ ~ o~.., water ~jector ~['2 GEOL Union Oil Co~~ o~ California Tradin~ Say Unit ~--~v ~. ~ss o~ o~.~o~ ~. ~ ~o, '"~ .... ~'a,~Ff-I ' 909 ~es~ 9~ Avenue~ ~ora~e~ ~aska 99501 S~a~e 6-19 (21-29) { SEC ~t,~,.~ Conductor 14, let 4, 1~27~N ~ 14~1'~ ~ M~r~hur ~iver - 1.Ie~~ "~ SE co.er Sec~io~ 29~ TgN, Ri3~, ~. n, s~c,,~.,~,,~,, <so~o~o~.- ..... ~,,. Sec. 29, TgN, Ri$~, ~. 13. ELEVATIONS (Show whether DF, ~T, G~, etc. 1~. P~T ~O. 99' R.T. above MSL 69-11 Check Appropriate Box To I,ndi,cate Niat'ure of N~ti'ce, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE I I ABANDONS REPAIR WELL CHANGE PLANS ~ Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT I~x ALTERING CASING SHOOTING OR ACIDIZINO I ABANDONMENTs (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates including eetlmated date of starting any proposed work. ' Sundry Notice of Ineent, dated 8/25/71, proposed acid stimulating the Hemlock zone in well G-19 to improve injectivity and profile. This was completed as followS- .. 1. RU wri sinker bars. Check top of fill above tip at 11,115'. RU Howco. Mix 54 sx sand w/injection wtr. Disp to tbg tail. Shut well in. RI w/sinker bars. Check top of sand fill at 11,028'. NOT~. Sand fill covers Bench 7 and Bench 6 of Hemlock Zone. Profile logs indicated Bench 6 taking 57.8% of injection fluid. Returned well to normal injection service. 2. Move Dowell pump?~trucks [ blender to platfom. RU portable storage tanks and mud storage tanks to accept acid. Moved 2-1/2% t{CL acid [ 12% HCL - 10% }.~ acid to platfom. Install all suction and discharge lines. 5. Pressure test all lines to 5200# - ok. Con~aenced acidizing down existing tbg string at 8:17 am 11/17/71. Acidized well in 9 stages as follows: Stage #1' 1. Pump 1000 gal 2-1/2% tiCL acid w/700# J-145 water soluable diverting material. 2. Pump 2000 gal 2-1/2% HCL acid w/140 gal U-66 (U-66 is Freflow EB which is a surfactant and de-emulsifying agent). 5. Pump 5000 gal 12-10 mud acid w/50 gal W-35 anti-sludging & de-emulsifying agent. 4. Pump 2000 gal 2-1/2% HCL acid w/140 gal U-66. Bench 1 2 Total Stage 2 3 4 5 6 7 8 RECOMMENDATION~TO'ACIDIZE 'TBUS G-19 'GRAYLING PLATFORM- McARTHUR RIVER FIELD COOK INLET, ALASKA TABLE II - ' Reperfo~ate Interval Feet 10,570-10,580 10,588-10,594 10,626-10,686 10,666-10,676 None 10,761-10,771 10,794-1'0,804 10,810-10,820 None 11,012-11,022 None Straddle Interval 10 10,560-10,600 6 10 10,555-10,595' 10 10,645-10,685 None 10,685-.1 O, 725 10 10,750-10,790 10 10,790-10,830 lO None 10,855-10,895 10 11,000-11,040 None Il,130-11,170 Feet ~Trea teLd. Treatment Volume- Gallons i2-10 HCL-HF ...... 2"L1/_'2%,jHCL Overflush 16 2400 960 10 '10 9 lO 20 9 lO 12 9 10,570-11,152 76 106 1500 1500 1500 1500 3000 600 600 6OO 6OO 1200 1500 1500 '1800 16,200 600 600 72O 6840 Note: GSW/afw 2/28/72 Stage nine might be eliminated .Pending completion of a study of Bench '7. Form ,,--3 ~ ' lB~abrn~t "Intent[ ~s.~,~n '~r,~,i~,,~ ~ r ~ . STATE OF A~KA ,. ~ ~ _ OIL AND GAS CONSERVATION COMMI~EE'~r'-i' EN~"-~ ~ ~'' 50-133-~01TBXm ~e~ c~ ~ ~. ~ ~ ~.. , ,. ' (~ ~ot use t~is ~o~ ~or proposats ~ drill o~ to use "A~btCA~O~ '~O~ ~ai't'Z" ~o~ s,~'~m~os.t~.) ~ 4 ~,~ 'I~ ~ ~WISlON OF OIL AND ~. . o,~ I '~ ~NG I .... ~. ~AM~ O~ O~O~ ' - j.~ 8. UNIT F~ OR ~SE NAME ~ ~ G~OL Trading Bay Unit Union 0il Co. any of Ca~ifo~ia 3 n:~, b. ADDRESS O~ OPERATOR I ~Ev' I~ State ~-19 (21-2g) 90g Ave., cho se., ggs0z ~. ~oc,z~o~ o~ w~ J sec ~ At surface Co~c~o~ ~, Leg 4, 1822'N ~ 14gl"~'~F~~'~ H~rthur River - Hemlock SB co~et Section 29, TEN, R1]W, ~ .~~ n. SEC.,o~w)T., ~., ~., (~OTTO~ .O~ ~_. .... - Sec. 29, T9N, RI]W, ~. , '13. ELEVATiOnS (Show Whethe~ DF, BT, GB,' etc. '" t~. ~T ~O. 99' R.T. above MSL 69-17 14. Check Approprinte Box To I,nd, i~te Nature of NOtice, Re :ort, or Other NOTICE OF INTENTION TO: FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: PULL OB ALTER CASING I~ WATER SItUT-OFF REPAIRING WELL MULTIPLE COMPI,ETE FRACTURE TREATMENT ALTERING CASING ABANDONs SHOOTING OR ACIDIZING ~. ., ABANDONMENTS ~ (Other) ~Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work, REASON FOR STIi~ULATION: Improve profile and injection volume to maintain the maxiJmzn pressure efficiency for secondary recovery of the Hemlock reserves. High pressure injection work on the Grayling injectors indicate there is almost no chance of stimulation and profile improvement aside from acidizing. 'I"ne profile and injection volume was greatly improved by acidizing TBUS D-24 a Hemlock injector on the Doily Varden Platform. ' It is proposed to acidize the Grayling injectors using basically the same technique, of staging 12~10 mud acid, preceeded by a dilute (2.5%) hydrochloric 50-$0 solvent-in- acid dispersion and followed by a dilute (2.5%) hydrochloric acid. Diverting material will be run between stages to allow controlled treatment of the entire interval. It is estimated that this proposed injection stimulation will result in an adequate amount of injection into the 26% (an average for the five injectors) of the producing intervals presently not taking any water and increase the injectivity into an additional 20% of the intervals which are presently receiving an inadequate amount. This treat- ment is necessary for an efficient secondary recovery of the Hemlock reserves. Form Subn~t "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO. N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Us~ "APP-LICATION 'FOR ~EH.I~IT~' 'for such 'p~o~osal.~.) , . OIL WELL WELL OTHER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface TBS A-19 (continued) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 14. Check Appropriate Box To I~ndicate Nature of N~tice, Re 5. APl NUIVLF_~R/CAL CODE 6. LEA~E DESIGNATION AND SERIAL NO. ?. IF INDIA-N, ALLO'i"I',:~- OR TRIBE NA1VLE 8. UNIT, FAHA~ O'R LEASE NAME 9. WELL NO. 10. FLELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERM. IT NO. ~ort, or Other Dal'~ ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDON~ REPAIR WELL CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ~ ABANDONMENT$ (Other) (NOTE: RePort results of multiPle completion on Well Completion or Recompletion Report and Log form.) , 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and gh'e pertinent dates, including estimated date of starting any proposed work. PROCEDURE: 1. Run wireline tools to determine if fill covers existing perfs. If fill covers perfs, circulate clean using macaroni tubing run thru existing tbg. 2. Acidize well thru existing tbg strings as directed, (45,000 gal 12-10 mud acid ~ 44,500 gal 2.5% HCL). 3. Return well to injection service. 4. Run profile log and evaluate. ESTIMATBD STARTING DATE: 10/1/71 .. (Tht~ ~pace for State office/use) CONDITIONS O~PPROVAL, IF ~ Fdcorrect TITLE Dist. Drlg. Supt. DAT~ 8/12/71 TITLE See Instructions On Reverse Side DATE .- ,~a Copy ~;~eturned . .F-/~. ~-/~Z_ IJNION O.1I, ~ GAS DIV!SION A NC II0 RAG E D I STR I C T TO' STATE OF ALASKA FROM' G H. Laughbaum I},,\TE' June 17, 1969 I~!ELL N),}.IE- 'TBU G-19 Transmit,.'~..d herewi,_h are the folJov:i ~' Ih, m No. Final ~p' Blue Scale S, la 1 ..., ~ .... .........~.x ~ . tI ..../ ......., Compen~aged Formation Density T-!igh Ce3ol~.t~em Dip'~eter (t!DT) Cml or PrSnt. out CBU or Po!ywog Plot proximity 2liarologlCalioer Log C:~mca Ray-Neutron Log gamma Ray Collar !.,og Cement Bond fog Sidewall Neutron Porosity Log Laterlog 3 Mud log Core I)oscription~, Conve~tional Cove Descriptions, Sidewall Core Analysis ForF~a t i on -'rests Directi onal. Surveys Core Chips Sample Cut JUN 1,3 1969 DIVL,qtON OF OIL ANDG~ RECE I PT AC KNOP,'LEDG ED' /~-r-~/~7 DATE- RETURN RECEIPT TO' Union Oil ~ gas Division '"~* .ion " - ,,~ ern.'Reg Ancao. aoe District 2805 [~enali Street Anchorage, Alaska 99503 ^ttn: Rochelle Carlto~ No. P--.4 9-30-.6'7 STATE OF AI-ASKA OIL AND GAS CONSERVATION COMMI~EE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRI. LLING AND WORKOVER OPERATIONS 2. N;~ME OF OP~2{ATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage. Ak. 99503 4. LOCATION OF WELL Conductor 14, Leg 4, 1827'N & 1491'W from SE corner Section 29, T9N, R13W, SM. AP1 NLTMEPdC2dL CODE 50-133-20178 LEJkSE DESiGB~ATION AND SERIAL NC). ADL 17594 7. IF INDIAN, AL~DI l~J~ OR TRIBE NAME 8. U~'IT,F.klRA~ OR LEASE NAME Trading Bay Unit 9. w~LL, NO. State G-19 (21-29) 10. FID AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTrVE) Sec. 29, T9N, R13W, SM. 12, PERMIT NO. 69-17 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET ~2N-D VOLU1VI~ USED. PF2P~FOtLiTIONS, 7~STS ~ RESULTS. FISHING JOt~. JUNK I2q HOI.E A2qD SIDE-~CKEA3 HOLE AND ANY OTHER SIGNIFICANT CH2%/~ IN HOLI~ CONDITIONS. TRADING BAY UNIT STATE G-19 (21-29), APRIL_!969 Drld 12-1/4" hole from 10540' to 11152'. Condition hole for logs. Ran Schlumberger DIL, SoniC, Density, HRD & LL3 logs. RI w/d.a., drld to 11220'. Condition for csg. Ran 270 its 9-5/8" csg. Hung w/shoe @ 11216'. Cmtd w/1000 sx "G" w/l% CFR-2. CIP 3:15 AM 4/8/69. Removed BOP. Landed csg. Installed tbg head. Reinstalled BOE. Press ~s,td OK. RI w/d.a. Drld out cmt & shoe. Drld 8-1/2" hole to 11574'. Cut Core #1 11574'-11604'. PO, 100% recovery 30'. (Medium to coarse grains sand, no oil shows). Drld to 12291'TD. Circ & condition for logs. Ran Schlumberger DIL, Density, Sonic, Logs & shot SWS. Ran CBL-GR correlation log across Hemlock. RI w/oedp to plug West Foreland section. Hung tail @ 11460'. Cmtd w/300 sx "G" w/l% CFR-2. CIP 11:00 AM 4/19/69. WOC. RI w/bit & scraper. Drill stringer of ~mt 11156-11165'. No cmt to 11265'. Drill cmt to 11270'. Circ clean. POH. RI w/oedp to 11270'. Cmt w/400 sx "G" w/l% CFR-2. CIP 8:30 AM 4/20/69. POH. WOC. RI, fnd top @ 10,445'.'Cmt extremely hard. Drld out cmt to 11190'. Circ hole clean. Changed over from mud to salt wtr ~fresh wtr w/salt added). Set Baker cast iron BP on wireline @ 11180' Schlumberger perfd ~four 1/2" hpf w/4" carrier guns from 11152-11140' 11115-110~0' 11030-10930' 10910-10860' 10830-10735' le715-10615', 10595-10570' . Set Otis pkr on Schlumberger line @ 10450' . Ran and landed334 its 4-1/2" tbg & jewelry in Otis pkr @_ 10450'. RD BOP's & riser. Installed Cameron Tree, tstd w/5000# OK. Displaced salt wtr w/30,000 gals diesel. Pulled dummy ball valve, closed sleeve ~@ 10906'. Press tstd pkr & tbg w/2000# O,K! HLB TRM RIG RELF. ASED 8:00 PM 4/23/69. CEIVEDOKO ,_~-~-~ KLV 1 5 1969 HWK _ jc~ Di¥1$1ON OF OIL AND GAS REL ,, , ANCHORA,~E .... . with the Division of Mines Minerals by the 15th of the succeeding month, unless otherwise directed. ~ SUBMIT IN DUPLICAT TE OF ALASKA ',See otherqtl~ structions on OIL AND GAS CONSERVATION COMMITTEE reverse side~ WELL C~MPLETION OR RECOMPLETION REPORT AND LOG* DRY [] Other water in~ection WELL WELL DEEP-[] PLUG ~-~ EN BACK la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW [] WOnK ['"] %VELL OVER DIFF. nESVR. Other NAME OF OPERATOR Union.. 0il Company of. California ADDRESS OF OPERATOR 507 W. Northern Lights ~Blvd., Anchorage, Alaska 99503. , LOCATION OF W'i~.LL- ~-Re~ort locatiO'h clearly:*and ~n accordance with any State requirements) At surface Conductor 14', Le 4, 1827' 'W S~'*'* N & 1491 from SE corner section 29, R13~, At top- pr0~I, interval repo~ted below' 2938'N & 1610'W of surface location. At total d~pth 3773'N &. 1595'W of surface location. 13. D~kTE SPUDDED 3/6/69 ,. j :: 4/17/69 4/23/69 18. TOTAL ,DEPTH, iVLD &,TVD~!,PL.TJG, ~[&CK MD &' TVD~;, IF 1VITUL'I' ~i~LE COM~L., ] 21. ~. PRODUCING ~'T~V~(S). OF ~S ~O~l~'rlO~O~, BO~0M, NAME (~ AND ~)* Beal6ck 10570'"~ : 9805'VD i1152 ~ 10309 ...... DIL, FDC, :BHC,: Sqnic,. GR-CBL _ "l' II iiii 'Tr '1 CAS~G ggCO~ (Report all str~gs scl in will) .312 ,wall 17,3 26. LINER R, ECO P,D ~.8. PEI~'OR&TIONS OPmN TO PRODUO~iO~ (Interval sime and number~ (four 1/2" hpf) 10570-~0595 10930-1~030 10~615-10715 11050-11115 10735-10830 11140-11152 10.860-1,09'10 ' _ . -- API NUi~~ CODE ~.~K~ 50-133-20178 KLV 6.-L~E m~IGHk~dW ~~T-'NO' ~_ ~L 17594 REt ff~ ~ ?. IF I1%rDIAI~T, AJ.J~OTI~.. ~ O .~!~TBF. ~ra~rm __ 8. UNIT,FA/~ OR I~SI~ AP~ Trading ,l~ay, ~it 9. WI/ILL NO. "" State G-i9 :;'{21"29) 10. ,FIIII~D A2qn POOL; OR WILDCAT McArthur R~v~'~o ' Hemlock SC~ (MD) · OBJECTIVE) - Sec. 29, ~TgNi R13W, SM. .. 12. PEH1VIIT ~0... 69-17 99 R.T. above .M. SL ~ ': INTERVALS DRILLED % ._,,~ CABLE TOOLS P23. ',W/ES DIRECYPION~L C~ ~,r-2~lrT 1 l~q- G RECOPu]~ 700 sx .. yes , 27. 1800 sx 1000 sx SIZE [ ' 3-1/2" & 4-1/2" ' TUBING RE~.OP~D 10530 -. 10450' 29. ACID, SHOT, FX~CTLrRE, CF_AVIENT FIRST PgODUC~ON [ BODUCTIO5 ME'ii{OD (Flowing, gas lif. t, pump.m~size and typ% 0f prop) ~WEL5 S:Tk~S (Producing or water injector ~'~ :'~ I ~'~) shut in o~BL. G~CF. WkTE~BBL. [HO~S TES~ ' [~iOXE SIZE [PR~D'N:"FO~ ~ GAS-OIL 5ATIO I I OIL GI~a~VITY-API (CORR.) WITNESSED BY ~2. ~i:ST O~' ATTACHMENTS .... 33. I hereb> certif, thg~..i~e fp/l~g~g and attached information is complete and correct aS"-~letermined from allVavallable records l{/f II ' -il'a££e]t) TITLE DiS't. Dr *(See/Instructions and Spaces for Additional Data on Reverse Side) INST~gCT~ON$ Sacks C, em~,n Attsched supplementaJ records ~or this wel) sf,ou[{J show the det~ds of ~ny muh NED Gray Nem!ock West Foreland 9644 ~ 1056(F 11154 ' 12,210 8970~ 9796' 10309~ 112~5! PAGE NO. ~ of I LEASE TRADING BAY WELL NO. FIELD MCARTHUR RIVER TBUS G-19 LOCATION: CONDUCTOR ~14 t LEG RM ~4 1827' N & 1491' W OF, S.E. CORNER, SECTION 29., TgN, R13..W..t S.M. PERMIT NO. 69-17 SERIAL NO. ..ADL 17594 TD 12291' TVD 11307' DEVIATION (BHL) 3714'N & 1703' W OF SURF. LOC COMPANY ENGINEER CHUDANOV, G..RAHAMt .HARNESS SPUD DATE 11-27-89 COMP. DATE 12-17-89 CONTRACTOR pOOL ARCTIC AK RIG NO. 55 TYPE UNIT. NATIONAL 1320 DRILL PIPE DESCRIPTION 5", 19.5~, E&S ELEVATIONS: WATER DEPTH 125 ' RT TO OCEAN FLOOR .., 228' RT TO MLLW 10.3.' RT TO DRILL DECK 23.3' APPROVED \ N~ ._D . SIZE WEIGHT THREAD 26" 17-3/4" .312 Wall Sprial Weld 13-3/8" 61~ Seal Lock 9-5/8" 40~,43.5~,47~ Buttress CASING & TUBING RECORD GRADE DEPTH 363' REMARKS Driven 520' 700 J-55 4749' 1800 sxs N-80, P-110 11216' 1000 sxs . DATE 04-22-69 INTERVAL E.T.D. 10570'-10595' 10615'-10715' 10735'-10830' 10860'-10910' 10930'-11030' 11050'-11115' PERFORATING RECORD REASON PRESENT CONDITION Injection HB-1 Open Injection HB-2 Open Injection HB-3 Open Injection HB-4 Open Injection HB-5 Open Injection HB-6 Isolate w/Pkr 12/12/89 11140'-11152' 11-03-76 10565'-10595' 10610'-10710' 12,11~89 10565'-10595' 10610'-10715' 10760'-10830' 10860'-10885' 10960'-11030' Injection HB-6 Isolate w/Pkr Injection HB-1 Open Injection HB-2 Open Injection HB-1 Open Injection HB-2 Open Injection HB-3 Open Injection HB-4 Open Injection HB-5 Open 12/12/89 INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C. P . T . P. CHOKE MCF GOR REMARKS Water Injection Well TYPE: Shaffer-Cameron WELL HEAD ASSEMBLY CASING HEAD: Shaffer Type "KD" 12" 3M w/2 ea. LP outlets CASING HANGER: _S. haffer 12" x 9-5/8" Model "KD-KS" TUBING HEAD: Cameron Type "DCB" 12" 3M x 10" 5M w/2 ea. 5M studded outlets TUBING HANGER: Cameron Sinqle Type "DCB-FBB" 4-1/2" w/EUE up & USS ImD MMS down TUBING HEAD TOP: 10" 5M MASTER VALVES: Cameron 4" 5M saltwater trim CHRISTMAS TREE TOP CONN: 4T~/2" EUE LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. I of WELL NO. G-~9W0 FIELD.,, GRAYLING DATE ~.T..~D. 11/27/89 11180' 11/28/89 11180' 11/29/89 11180' DETAILS OF OPERATION, DES.CR...IPTIONS .& .RESULTS . COMMENCED OPERATIONS ON TBUS G,19.AT 0OQQ HO.URS ON 11-27-89. Finished x-ray work on Rig #55 .choke manifold. Ail welds passed. Assembled choke manifold. Rig up equipment and tools on Rig #55. Hung new V-Door and set rat hole. Production shut well in at 0800 hours, 11/26/89. Pressure on tubing and 9-5/8" annulus was 400 psi at 0600 hours, 11/27/89. Bled down tubing through a 1/2" line at 0700 hours. At 1500 hours, pressure on tubing and annulus had.built to 300 psi. Hooked up 2" hose from annulus to well clean tank. Rigged up wireline for 3.75" gauge run. Flowed annulus to well clean tank. Annulus and tubing at 0 psi with steady stream of water to well clean tank. Shut well in and pressure started building up. Ran 3.75" gauge ring and set down in SSSV nipple at 292' WLM. Trip for 3.5 gauge ring. Set down at 2312' WLM (CX GLM). Ran scratcher to clean out GLM. Trip for 3.71" gauge ring. Ran 3.71" gauge ring and set down at 574' WLM. Trip for 4-1/2" GS pulling tool to check for GLV in GLM. Ran in and set down at 2312' WLM. Had good over pull and had to beat down to shear off. Due to restricted tubing above, did not try to pull valve. Mix 1000 bbl of 67 pcf brine kill fluid. Bullhead kill weight fluid down tubing and annulus. Starting pressures were tbg-260 psi and annulus = 175 psi. Final tbg and annulus displacement pressure = 1900 psi. Pressure decreased to 100 psi and held at end of pumping. Mixed up 20 bbl high viscosity marker pill. Pumped marker pill down tubing and had returns on annulus after 164 bbls. Calculated circulation depth = 2283' (GLM #1 @ 2312'). Circulated at 2312' and built mud weight to 72 pcf to kill well. Well taking a little fluid at the end of circulation. Rigged up wireline. Attempt to set "PX" plug in SSSV profile-hung up at 70' WLM. Pulled free and tripped for 3.85" gauge cutter. Continued Working 3.85" gauge cutter to SSSV seat at 286' WLM. Trip for "PX" plug and set same at 286' WLM. Trip for prong and set same. Attempt to pressure test tubing plug-no good. Ran in to pull prong and found plug at 500' WLM. Made two attempts to recover prong-no good. Reverse circulated to clean scale from around plug. Ran in with wir~~' ~ and latch~C ~PX" plug at 297 Pulled prong. Ran in and latched and recovered plug. Rigged down wireline. Set BOPE in cellar and stacked same. Checked well-still on slight vacuum. Nipple down tree. Nippled up riser, BOPE and annular preventer. FunctiOn tested stack. Tested 4-1/2" rams to 3000 psi and annular to 2500 psi. Rig up flowline. UNOCAL DRILLINGRECORD ALASKA REGION PAGE NO. 2 of LEASE, M. CARTHUR RIVER .,. WELL NO. G.%9W0 FIELD GRAYLING DATE .E.T. D- , 11/30/89 11180' 12/01/89 11180' 12/02/89 11180' 12/03/89 11180' 12/04/89 11180' DETAILS OF 0PR~.RATION, D~SCRIPTIONS & .RESULTS Continued to rig up flowtine, trip tank line, and bell nipple. Backed out holddown pins. Filled pits with FIW. Attempted to pu~l tubing loose. Picked up hanger at 26K over weight of blocks indicating the tubing was parted at ~ 2400'.. Pulled and layed down tubing. Found string parted in body of GLM #1. Tubing had internal and external scale and severe corrosion. Tested BOPE to Unocal specifications. Repaired stand pipe valve and replaced 4" gate valve in mud pump manifold and one high pressure shock hose. Repair Koomey line leaks. Ran in with overshot with 5-1/2" basket grapple. Continued in with grapple and engaged fish at 2334' DPM. P~lled 93K overpull and tubing parted. Pulled out and recovered 1901.82' of production equipment. Ran in with overshot with 5.2" basket grapple and engaged fish at 4223' DPM. Tubing parted with 79K overpull. Lost 2-1/2 hours due to complete platform shutdown. Pulled out and recovered 3835.51' of production equipment. Tubing had holes and heavy scale. Cleaned rig floor. Ran in with overshot and 4-1/2" basket grapple to 8030' DPM. Engaged fish and pulled 58K overpull and tubing parted. Pulled out and recovered I joint of 4-1/2" tubing (28.64'). Ran in with grapple and engaged fish at 8087' DPM. Pulled 48K overpull and tubing parted. Recovered 586.48' production equipment. Ran in with overshot with 4-1/2" basket grapple to 8674' DPM and engaged fish at 8674, DPM. Pulled 95K overpull and seals pulled out of permanent packer. Pulled on stand and circulated bottoms up. Pulled out of hole standing back 5" drillpipe. First joint of tubing had hole and remainer stood full of fluid. Ran sinker bar in each joint prior to laying down to check for plugs. With 56 joints of tubing laid down it was noticed that two drums of scale from the tubing were generating an excessive amount of heat. Drums were cooled with water and sealed. Suspended operations until protective gear for rig crews could be delivered to platform. Pulled and laid down remainder of production equipment. Full recovery. Standby and perform rig maintenance, while scale samples were anai~ ~2~ Continued on maintenance stand by until 1330 hours. Made up bit for cleanout run. Ran in and tagged permanent packer at 10439' DPM. Circulated well clean. Trip for packer burnover assembly. R E C E ! V LEASE... MC,ARTHUR RIVER UNOCAL DRILLING RECOR[ ALASKA REGION PAGE NO. 3 of WELL NO., G.,-19W0 ' FIELD GRAYLING DATE E. T · D. 12/05/89 12/06/89 12/07/89 12/08/89 12/09/89 12/10/89 DETAILS O.F. OPERATION, DESCRIPTIONS & RESULTS 11180' ETD Ran in with packer burnover assembly. Cleaned out fill from 10419' to 10439' DPM. Milled on paoker from 10439' to 10441' DPM. Tripped for new mill shoe. Continued burning over packer. 11180' ETD Continued milling Otis "WA" packer. No progress. Tripped for a scalloped mill shoe. Shoe showed little wear. Milled on packer at 10440' DPM with little progress. Circulate. Pushed packer to 10682' DPM. Could not push deeper. Circulate. 11180' ETD Tripped for spear. Engaged packer. Pulled 60K over string weight for 60' then came free. Recovered packer. Ran in with bit. Cleaned out and pushed junk from 10682' to 11170' DPM - no problems but firm from 11048' to 11085' DPM. Circulated out scale. 11180' ETD Continued circulating well clean at 11170' DPM. Trip for bit and casing scraper. Ran in with scraper to 11170' DPM. Circulated well clean. Trip for RTTS packer. Assist in laying lines to Leg $4 for soc jobs. Ran in 'with RTTS packer. 11180' ETD Continued in and set RTTS at 11030' DPM and tested lfor zone isolation between HB-5 and HB-6. Established an injection rate of 0.5 BPM at 3100 psi into HB-6. Injected 5 BBL into formation with no returns to surface. Released packer and pulled up to 10543' DPM. Rigged to pressure test casing and blew a hose on rig high pressure system. Replaced hose and pressure tested casing against top pipe rams to 3000 psi for 30 minutes. Trip for bit and scraper. Ran in to 5000' and cut 99' off drilling line. Continued into 11170' DPM and changed well over to clean FIW. Cleaned active system. Checked well for flow-slight flow. Shut well in and checked for pressure. Did not build enough to read on gauges, but had slight flow at choke. Weight up surface system to 65 pcf with NaCL. 11180' ETD Continued Weighting surface system to 65 pcf. Displaced well and checked for flow. Well taking 2 BBL/hr of 65 pcf fluid. Tested BOPE to Unocal specifications. Pulled test plug and set wear bushing. Blew down all lines. Picked up perforating assembly. Ran in hole with guns filling drill pipe to allow for a 500 psi underbalance. Spaced out Guns on dep'~ ...... ~ drill pipe ~,~asurements. k~.~~ ' -- up-electric line for correlation log run. UNOCAL DRILLING RECOR~~ ALASKA REGION PAGE NO. 4._ of LEASE MCART .H33R RIVER ,. WELL NO. G-19W0 , FIELD G~AYLING DATE 12/11/89 12/12/89 12/13/89 12/14/89 E. T .- D. .. DETAILS OF OPE. RATION. DESCRIPTIONS & RESULTS 11180' ETD Continued running in with wireline for correlation log. Made a 0.5' correction and set packer. Reran correlation log. Rigged up and tested surface lines. Open Omni valve and had a slight blow. Pressured annulus to 3200 psi at 0610 hours and perforated HB-1 (10565'-10595'), HB-2 (10610'-10715'), HB-3 (10760'-10830'), HB-4 (10860'-10885'), and HB-5 (10963'-11030') with 4 SPF, 90° phase, 32 gram charges. Flowed well for i hour with strong blow for 50 minutes. Closed Omni valve at 0710 hours for i hour shut-in period. Cycled Omni valve to reversing position and reversed drillpipe clean. Pulled packer loose and circulated well clean. Pulled out and laid down perforating assembly. Made up and ran in with bit and scraper to 11165' DPM. Circulated down to 11170' DPM. Circulated well clean. Trip for isolation packer. 11180' ETD Continued trip for isolation packer. Rigged up electric line with lubricator. Ran 8.27" gauge ring and junk basket to 11180' DIL and confirm tie into DIL. Casing tight at 10750' DIL. Made up Otis "BWD" packer and tail assembly. Ran in and set top of packer at 11034' DIL with wireline reentry guide at 11045' DIL. Ran in with test seal assembly on 5" drill pipe and stabbed into packer at 11023' DPM. Test packer for isolation by injecting through packer into HB-6 at 4 BPM with 2700 psi. No returns to surface. Pressure annulus and inject into HB-1 at 7.2 BPM with 1000 psi. No returns to surface. Rigged up slickline and set PXN plug and prong in XN nipple at 11043' DIL. Test plug to 2000 psi. Trip for permanent production packer. 11180' ETD Ran in with Otis BWD packer with 5" bore and seal bore extension. Set packer at 10400' DIL (10390' DPM). Tested packer to 3000 psi for 30 minutes. Sheared off packer and pulled out laying down drill pipe. Rigged up to run 4-1/2", 12.65, N-80, MMS buttress tubing with TK-99 internal coating. Rigged up hydrotest. Made up and plug tested tail assembly to 3500 psi. Ran in with tubing, hydrotesting to 3500 psi. NOTE: Tubing rabbitted to only 3.779". 11180' ETD Continued running and hydrotesting 4-1/2" tubin~ ':~nded tubi~ .... ~.th 2.5' of " .............. compression~ (25000 #). Ran total of 348 joints for 10416.40'. Tail at 10476.53'; Locator at 10,403.78'; "XA" sleeve at 10369.96'; "X" nipple at 10445.12'. Pressure tested annulus to 2500 psi. Pulled seals out of packer and changed well over to packer fluid. LEASE MCARTHUR. RIVER UNOCAL DRILLING RECORD~' ALASKA REGION PAGE NO. 5 of WELL NO. G-$9WO FIELD ..GRAYLING DATE E. T. D. 12/15/89 11180' 12/16/89 11180' 12/17/89 11180' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Completed change over to packer fluid. Relanded hanger, ran tiedown pins in, and packed off hanger seals. Installed BPV. Removed BOPE. Installed and tested 4-1/2" 50005 CIW single tree. Turned well over to production department at 1000 hours. Removed one stand pipe from Rig ~54 and installed it on Rig #55. Changed to 6-1/2" liners in mud pumps. Moved rig over G-3 in preparation to shoot HB-1 & HB-2. .Removed 5" vent line to crown of rig #55. Installed new prime mover cooling lines. Released Bariod mud man until further notice. Pulled up rig floor to start making modifications to turn rotary table around. Perform rig maintenance. Released rig from TBUS G~19 at 5400 hours. TUBING DETAIL TBUS G-19WO DECEMBER 1989 JTS 1 345 DESCRIPTION LENGTH REENTRY GUIDE SHOE 0.82 4-1/2",12.6#,N-80,BUTT 29.08 OTIS X LANDING NIPPLE 1.51 4-1/2",12.6#,N-80,BUTT 29.28 OTIS X-OVER 0.60 OTIS SEAL ASSY 11.46 oTIS STR SLOT LOCATOR 1.51 4-1/2",12.6#,N-80,BUTT 27.89 OTIS XA SLIDING SLEEVE 4.42 4-1/2",12.6#,N-80,BUTT 10330.16 10373.47 ~CAMERON THO HANGER 1.00 43.31 LANDED BELOW ZERO 42.31 42.31 BOTTOM TOP 10480.04 10479.22 10479.22 10450.14 10450.14 10448.63 10448.63 10419.35 10419.35 10418.75 10418.75 10407.29 10407.29 104.05.78 10405.78 10377.89 10377.89 10373.47 43.31 42.31 0.00 1) TUBING CONNECTION IS USS IMP BUTT W/ TKC MMS COUPLINGS (5" OD). 2) TUBING IS INTERNALLY COATED W/ TUBOSCOPE TK-99 COATING. 3) TUBING WAS SET IN SLACKOFF PLUS 2.5' TUBING COMPRESSION. 4) HANGER: TOP IS 4-1/2" EUE 8RD. BOTTOM IS 4-1/2" USS IMP BUTT TKC MMS PRODUCTION PACKER DETAIL TBUS G-19WO DECEMBER 1989 DESCRIPTION OTIS "BWH" PERMA-DRILL SEAL BORE EXTENSION PACKER BODY LENGTH 7.43' 4.14' BOTTOM 10401.57'DPM 10394.14'DPM TOP 10394.14'DPM 10390.00'DPM ISOLATION PACKER DETAIL TBUS G-19WO DECEMBER 1989 DESCRIPTION REENTRY GUIDE SHOE OTIS "XN" NIPPLE 3-1/2", 9.2#, N-80 OTIS SWAGE PxP OTIS "BWH" PERMA-DRILL LENGTH 0.69' 1.56' 4.11' 0.58' 4.90' BOTTOM TOP l1045.84'DIL l1045.15'DIL l1045.15'DIL l1043.59'DIL l1043.59'DIL l1039.48'DIL l1039.48'DIL l1038.90'DIL l1038.90'DIL l1034.00'DIL PAGE. ONE WELL # G-19 WO FACILITY GRAYLING TUBING X.,. ST~ING SINGLE SIZE 4 1/2 WT 1~'.6 GRADE N-80 THD MMS BUTT CASING NO. DESCRIPTION LENGTH TOP BOTTOM OTIS 4 1/2 BUTT W/L RE-ENTRY GUIDE. OD 4.95 X ID 4.50 0.82 10479.22 10480.04 1 4 1/2 12.6# INTERNALLY COATED MMS BUTT TBG WITH 4.95 OD COLLAR 29.08 10450.14 10479.22 OTIS 4 1/~ BUTT "X" NIPPLE WITH 4.95 OD COLLAR. BODY OD 4.75 X ID 3.813 1.51 10448.63 10450.14 I 4 1/2 12.6# INTERNALLY COATED MMS BUTT TBG WITH 4.95 OD COLLAR 29.28 10419.35 10448.63 XO 4 1/2 10 RD NU >-> 4 1/2 MMS BUTT. OD 4.95 X ID 3.96 0.60 10418.75 10419.35 OTIS SEAL ASSY. 5.00 OD X 3.96 ID 11.46 10407.29 10418.75 OTIS STRAIGHT SLOT LOCATER SUB WITH 5.00 OD COLLAR. 5.500 OD X 3.96 ID 1.51 10405.78 10407.29 1 4 1/2 12.6# N-80 MMS BUTT WITH INTERNA~ COATING AND ~.00 OD COLLAR 27.89 10377.89 10405.78 ~OTIS 4 1/2 MMS BUTT "XA" SLEEVE WITH 5.00 OD COLLAR. 5.50 OD X 3.813 ID 4.42 10373.47 10377.89 345 4 1/2 12.6# N-80 MMS BUTT WITH INTERNAL COATING AND 5.00 OD COLLARS * 10330.16 CIW SINGLE TBG HANGER. 43.31 10373.47 4 1/2 EUE >-< 4 1/2 BUTT 1.00 42.31 43.31 RT TO TBG HANGER 42.31 0.00 42.31 · . 348 TOTAL JOINTS OF PIPE 10416.41 ACCESSORIES 21.32 TOTAL HANGING LENGTH 10437.?3 NOTE: ALL TBG DRIFTED TO 3.779 DUE TO INTERNAL COATING WIRE LINE TOOLS ARE 3.813 OD NOTE: * THIS LENGTH IS A MEASURED LENGTH AND TBG WAS SET IN SLACK OFF PLUS 2 1/2' OF COMPRESSION. (25000#) 17-~/4" @ 520' @ 4749' ,/ TOC 11180' ETD 9-s/8" e 11216' A CEMENT C 5 4/22/69 &! KE~,T BUSHZNG AT 0.00' B! ~ TUBZNG RANGE3t AT 42.31' 17-$/4', 0.312 SPiRaL Nr~DAT 520* D) ~3o3/8°, 6~e, J-SS S~ M ~ AT 4749' ~5/8', 40~. 43.5d, 474, NOS0, Po~Z0 ~ZHG AT ZZ2ZG' COATED, USS AT Z0448.63' ~0480.04' P~-~ P~X~ AT 10390* ~040S.78' ~ A04~8~75' ZSOLATZON PA~KER S) OT2S MODE~, 'M° PE3~-DR2~LPAClCER AT 21034' OZL 6) 3ol/2° OTZS 'XN' NZPPL~ AT 22043,59' D2L 7) O*L~$ RElY GUZDE 147TH BOTTC~AT ~104S.840 OZ~Z, PERFORATXOX RECORD 10570'-10S9S' OPE~ FOR ~i~E~TZOli X06XS'-X0?X$' OPEN I'OR ZIL.TECTXOI 10735'-X0830' OPEN FOR ~0860'-~0910' OPEN FOR ~0930'01~030' OP~ ~R 1Z050'011115' OPRN ~ 11140'~11152' OPEN ~R 10565'0105950 OP~ ~ 10565'-10595' OP~~ FOR 10610'-10~15' OP~ ~R 10~60'010830' OP~ ~R 10860'-10885' OP~ ~R ~0960'-11030' OP~ ~ WELL TBUS G- 19 INJECTOR COMPLETION (12-14-89) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE' 3,/10/90 (~%S~= 9-5/8" 40-47 ~f K-55 ~m~: 4-1/2. u.s ~ zubosc=pa ~ mx: ~8o W~ 431/1012/02/89 (907) 283-7531 O.D. 11 1. 4. 5. 7. 8. 10. K.a, c.z.w. Tubing (345) Joints of Tubin~ Ot/s "XA" Sliding Side Door (P/N 121 XA 126) c~e (1) joirZ o:~ 'robing otis Str. Slot Seal Assembly a. Str Slot Locator 3.96" (P/N 212 S 50000-A) b. Seal Assembly ~ 5 3.96" (WN 212 ES 90O2) ~YCOr 4-1/2" ~J X 4-1/2" ]vl~S ~ one (1) ,3'o.iz'~ o:~ Tubing ~ple (P/N XX x ~8) ~ (~) Jo~ of ~ ~ ~e ~ w~~ 5.0" 42.31' -0- 1.0' 42.31 10,330.16'* 43.31' 3.813" 5.5" 4.42' 5.0" 27.89' 12.97' 5.78" (1.51') 5.05" (11.46') 3.96' 4.95" .60' 5.0" 29.28' 3.813" 4.95" 1.51' 3.96" 4.95" 29.08' 4.95" .82' · Itea No. 3 Total 1etCh is measured length. Tubing was lar~ed in ccmpressim of 25,000 lb equaling 2-1/2'. 10,373.47' 10,377.89' 10,405.78' 10,418~75' 10,419.35' 10,448.63' 10,450.14' 10,479.22' 10.480.04' ,II --, III A. (P/N 212 ~D 9503) With ~ (P/N 212 B 9262) 5.0" 8.12" 4.14' 10,387.45'+ (P/N 212 B 9264) 5.0" 6.28" 7.426 10,391.62' ~OFP~CKERA~)SEALBC~E~ 10.399.04' Page2 , I. II. III. Ve (P/N ~-~ ~D ~400-A) 4.0" 8.12" 4.90' Swathe - 4-3/4"-81~ x 4-1,/2" BLoC P'/.P (P/N 92 C 777) 2.99" 4.94" .58' Pup Joint 3-1/2" 2.99" 4.25" 4.11' 2.635" 4.25" 1.56' O~s ~~~ Nipple (P/N 11 ](N 27560-A) ot:/s wirel~ Gu/c~ (P/N 212 M 5) 2.99" 5.53" .69' 11,033.69' 11,038.59' 11,039.17' 11,043.28' 11. 045.53 ' D~C-28-'89 10:~M T- 12-10-8 9 "~ ~Itrea~ reside Tree 5a/t~a~ Note: Tubing Hanger 4½" EUE Top x 4~" us ~ ~a~t~i success 2I! X-Prep 13 5/8" 3000 Rx-57 2!1 13 3/8" 5/8" 4 1/2" UNIO,, OIL CO.; OF CALIFOI.. IIA WELL RECORD SHEET C PAGE NO ..... LEASEiTrading'Bay Unit State 5VELL NO. G-19 FIELD b[cArthur River CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE .... ~PT~ REMARKS .7-3/4" ~ .312. wall spiral wel.d 520' Spiral Weld Csg. :3r3/8" 61# seal lock J-55 4749' Cmt w/lj50 sx B-J mix + 350 SX CFR'2: cmt.., circ. , 9'-5/8" various buttress N-80,PrllO '11216' 'Cmt.~/1000'sx CFR-2 4-1/2" 12.60 buttress N-80 10530 I' ~* · PERFORATING RECORD · I D.~TE ] I ' INTERVAL E.T.D. REASON PRESENT CONDITION ~/22/69 10570-10.595' il, 180 ' -- 10615-10715 . 10735-1.0830 10860.10910 10930.11030 . 110 SO-I 111 S 111_40-1.1152 . · , · __ . · ,., , . · INITIAL PRODUCTION 'DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF (~OB REMARKS , . . . , . · . , . , , , · .. , . . . . , . , . . . ,, · · WELL HEAD ASSEMBLY TYPE: · CASING HEAD: Shaffer "KD" w/2" S.E. Outlets CASING HANGER: Shaffer 12" Nominal 9-5/8" Model KD-KS CASING SPOOL: TUBING I~EAD: Cameron Dc-B12 12" '3000# x 10" 5000# w/5000# studded outlet TUBING HANGER: DC-FBB i0" Nominal 4-1/2" buttress bottom x 4-1/2" EUE top TUBING HEAD TOP' Single string solid block log type W/master & sab valve. Bottom f!an~ze to 5000# w/7" OD sealpoc~et~ . .OIL, CO', Oi--' C;.\LI I-':'0 iR IA WELL R'ECORD "~'^qE Gr.a_x~ling Platform WELL NO G-19 ?I~I,D._ Mc/\rtln~r River Ficld · ' N Conductor #14,~ Leg ~[4,-'i'a27~ ~OCA~IO ~ Nord~ ~ 1491'l~est '~rom sE co~er section 29~ T9N, R13W~ . ?ERR. lIT NO, 6[)- 17 SERIAL NO. ADL 17594 U.D, T.¥.D. )EVIATION (B.}I.L.) ' ~.OR'IPAI, Y ENGINEER SPUD DATE 1~/16/71 CONTIIACTOI% ~ ~ r rYP~ UNI r_ DRILL P1PE DESCRIPTION. 13H lilZ.'F A PAGE NO .... · . coMP. Dow¢ll RIG NO. _ _~ ELEVA'£IONS: W;Vi'EI[ DEF'I'it IL T. TO OCI£AN FLOOR Il. T. TO- ,~ iLL~V 1__7_-3/4:,' .31,2 Fa] ! ' kpiral' wield ' 520' Spiral weld- csg .i3-3/8:' 61# seallock " ' J'-SS 2[~49' Cmt w/1450-sx BJ mix + '3'bO §k'Ct:K-2 .~nt. - ' ' -§-5/8"I various ~uttress ' N-80','P-110 '11216' (~nt 'w/i000' sx Ck'i(-2 cml, " .... ~ ~_4~-1/2"; i2'.6.#' '"buttress h-80 i0530" ~b~'W/pkr"it"10,45.0' I ' ' _~. .--__- -- _____ ~ - _. -: -- ~ ~ --~ . .~ · PERFORATI[t.IG RECORD _.4___/22/6~) 10570.-10595 lllS0'BP .. .... . ........ . 10615-'10715 .11028' sand ' -' · · ~ ...... i0860'-"10.910 ' t ' ' ' ' · _ .. .l,u~ou- z~uou · ' (1'1050-11115~ 'probably ine::fect'ive - below', sauid fill AL i1028'. - --- .. .... . .... ,.~-~:,~,-,~.,-,,-,r~.~n:~?~ ,, .,, " " " " '" -- -' o . · · . · · · o . · . o · o · . .- ....... - _ ~ , ,,, · , ,1 , · _, J - INITIAL PRODUCTIO}~ AT~E _ · 'II'~+ER.~,'~L ,~ N_ET_OIL '.CU~' GRA. V. 1 ' C.P. . . · . . . . · · . · · -. o . -- -' -- , -'' · . , .......... ,,, .... , ' L WELL I~~_~/IB LY · - .YPE: :ASING HEAD: sa~e" as orig- hi'Storyl;dated 4/2.3/69.' · . . ,IA'SING 'HANGER:. ' ~ASING SPOOL:. 'UBING HEAD: , · .. 'UBING HANGER: · · .... '. ... ..' .-- .:........: .... ...: . --.. : -- .-..."..::';.; .... · IUBING IIEAD TOP' [ASTER VALVES: HR!STMAS TREE TOP CONN.:.. o. ,. i. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO.~~ LEASE Trading Bay Unit State WELL NO. G-..!9 ..... FIELD.. McArthur River Field DATE 11/10/71 11/16/71 il/i7/7i li/18/?i E. T. D. 11,180' BP 11,028' sand 11,028 ' sand fill 11,028' smid fill DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RU wireline sinker bars. Check top of fill above BP at 11,115'. RU liowco. Mix 34 sx sand w/injection wtr. Displace to tbg tail. Shut well in. RI w/sinker bars. Check top of sand fill at 11~028'. ~VO~: Sand fill covers Bench 7 and Bench 6 of Itemlock Zone. Profile ~indicated Bench 6 taking 57.8% of injection fluid. Did not want to continue injection into zone at this rate and did not want to stimulate. Sand bridge isolated intervals effectively enough to accomplish this. ' Returned well to normal injection service. Aug. injection rate 13,500 B/D at 3450#. Move D¢qell pump trucks and blender to platform. RU portable storage tanks and mud storage tanks to accept acid. Moved 2zl/2% tiCL acid and 12% 1EL - 10% t~ acid to platform. Install all suction and discharge lines. Pressure test all lines to 5200# - ok. Commenced acidiZing dCvn existing tbg string at 8-17 am 11/17/71. Acidized well in 9 stages as follows: .szage !: 1. 1000 gal 2-1/2% ICL acid w/700# J-145 water soluble diverting material. 2. Pm~p 2000 gal 2-1/2% tiCL acid w/140 gal U-66 (U-66 is Freflow EB whid~ is a surfactant mid de-enmlsifying agent). 3. Punp 5000 gal 12-10 mud acid w/SO gal W-35 anti-sludging [ de-6mulsifying agent. 4. Pun~ 2000 gal 2-1/2% t-EL acid w/140 gal U-66. 5. Pun9 1000 gal 2-1/2% HCL a~id w/700# J-145 diverting material. All acid (2-1/2% & 12% - 10%)treatedw/A-130 inhibitor... Stage 2 thru 9: · . Repeated steps 2, 3, 4,. 5 eight (8) times with final stage (stage 9) omitting step 5. Displaced wifli 2-1/2% t.~L acid. Utilized total of 4.5,000 gal 2-1/2% t~L acid and 45,000 gal 12% - 10% nmd acid w/6300# J-145 diverting material. Observed pressure increases each stage as diverting material hit formation, and pressure decreases as mud acid (12-10) hit formation. Initial breakdown 5 bbl/min at 1800#. Avg Injection' rate 4-1/2 bbl/min at 2200#. Max Injection rate 5 bbl/min at 2600#. Final Injection rate 4-1/2 bbl/min at 2000#. Completed job at 5:10 pm 11/17/71. Returned well to injection service - HmnloCk zone (See attached Dowell report for detail). Injection rate 13,585 bbl/day at 3250#. LOC, I , , , I I I PROP~ AN{) I. IQIJII;st~ IKJEC'fF, I) ,.. B; f ¢&L LJIMYi~ , ~bT~'/'.' t.i;~: ((.,¥,.( (o(,%'Ni, ¢,t II f', %t,I/l$l,s! n '1 '"l -: UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D 5 PAGE NO. LEASE Trading Bay Unit State VV-ELL NO. G-19~ FIELD McArthur River DATE 3~5/69 6 10 12 13 14 E.T.D. 363 ' 534 ' 1075 2000' 2275 4750 4750 4750 4750 DETAILS OF OPERATIONS. DESCRIPTIONS & rESULTS Moved rig from G-17 (Conductor #23) to 9-16 (Conductor #14). Spudded G-19 @ 2:00 am (3/6/69). Made'up drilling assembly.& tagged fill in conductor @ 36'3'. Drld 15" hole from 363' to 534'. Opened 15" hole to 22" hole w/Servco Exp. HO. Reamed thru shoe of 26" cond w/exp HO & 18" mill. POH. Ran 13 its 17-3/4" csg (.312 wall) . Landed @ 520', w/Howco stab in float .shoe on bottom of jt #1. Cmtd w/650 sx CFR-2 w/2% CaCl2 and Inlet wtr followed by 50 sx CFR-2 w/4% CaC12. Displaced Cmt w/52 ft3 wtr, Had 100 ft3 cmt returns'to surface. CIP 8:00 pm 3/6/69. Back pressure valve did not hold. Maintained pressure'in dp. WOC & NU BOE, on 17-3/4" csg. 17-3/4" CasinE_qetail Howco "S~ab-In" Float Shoe 13 its 17-3/4" csg (.312 wall spiral weld) Total Casing String Less Csg above table Csg Landed (Rot-a~y Table) 2.30' 520.00' 522.30' -2.30' 520.00' Installed 20" Hydril & completed NU. blade up B.H.A. pressured up 17-3/4" csg w/500 psi for 15 min. OK. RIH w/B.H.A. #1 & 15" bit. Drld Guide Shoe @ 520' & CO cmt to 536'. POH for bit change. RIH w/B.H.A. #2 & bit #2. Drld to 1075'. Drld & surveyed 12-1/4" hole to 2000'. PO & picked up DDrl w/B.H.A. #2. Oriented DDrl. DDrld to 2275' w/bit change @ 2127'. Layed down DDrl. PU B.H.A. Drld & surveyed 12-I/4" hole to 4750'. Opened 12-1/4" hole to 17" from 520' to 2466'. Opened hole to 4413' when HO torqued up & dp backed off @ 1865'. PO & PU overshot. Recovered fish - lost 1 roller off t!O. RIH & finished opening hole to 4750. No indication of roller lost in hole. POt{ & RU to run 13-3/8" csg. Ran 13-3/8" csg, set @ 4749'. Mixed & pumped 1450 sx B-J mix plus 350 sx CFR-2. Cmt circ. CIP 7:00 am. 13-3/8" Casin~ Detail From T__o ~ ~ts De s c r ip_t. ion. 4749.76 4747.73 4747.73 4709.48 4709.48 4707.51 4707.51 36.00 36.00 -0- 2.03 38.25 1.97 4671.51 36 . 1 121 Baker "G" Float Shoe 13-3/8" J-55 61# seal lock csg. Baker "G" Float Collar 13-3/8" 61# J-55 seal lock csg. Landed below Rotary Table WOC. 6 hrs. Cut off 13-3/8" cmt fell back down hole. Pumped 50 sx around outside 13-3/8" & 2 sx Cai Seal @ top'. Welded on Shaffer ,'KD" head. 'UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 'State V~LL NO. G-19 FIELD. McArthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3/16/69 17 18 - 2Z 23 24 - 28 3/29/69 to 4/4/69 4:760 ' 5420 7990 8290 9760 11080 11152 ,11152 11220 11270 Tested-head to 3000# .OK. Layed do~n "E" dp. Tested blind rams to 1500# for 15 min OK. RIH & drld float collar @ j707'.. Tested pipe rams to _ 1500# fOr 15 min OK. Drld shoe @ 4749'. Bit started rng rough. Drld to 4758' POH & picked up 12" servco mill. Milled to 4760 (milled on HO pin & cutter).. RIH w/bit & jnk sub. Drld on jnk. By passed same & continued drlg 12-1/4" hole to 5420'. Drld & surveyed 12-1/4" hole to 7990' Lost 6-1/2 hrs repairing RT. While drlg @ 7990, lost 450# pump press. POH, fnd washout in box of Hevi-Wate drill pipe. Continued drlg to 8290'. Again lost pump press. POH to find wash out. Drld & surveyed 12-1/4" hole to 9565. POH, fnd washout between btm monel & stabilizer. Layed down MC & stab, chngd B.H.A. Rill, drld & surveyed 12-1/4" hole to 9760'. Drld & surveyed 12-1/4" hole to 11030. PO, RI w/ n.b., Began reaming to btm, stuck @ 11003. Loaded jars & jarred loose. Continued reaming to btm. Drld to 11080. PO for new bit. Drld 12-1/4" hole to 11080. Lost pump press. PO, fnd washout in Hevi- Wate drill pipe. RIH w/new bit. Drld to 11152, made 15 stand wiper run. Rotary hose ruptured. Pulled pipe into 13-3/8" csg. Changed rotary hoses. RIH circulated and conditinned hole for electric logs. POH. Schlumberger ran DIL, Sonic, Density, LL3 & tiP~. Completed logging. RD Schlumberger. RItl w/d.a. Drld to 11220. Ran 9-5/8" csg. Completed rng 9-5/8" csg. (SEE CASING DETAIL). Cmtd csg w/lO00 sx Class "G" cmt w/l% CFR-2. Bumped plug w/22~50#, released pressure. Floats held OK. CIP 3:15 am 4/8/69. ND BOP's &-riser. (WOC 5 hrs before setting slips due to excessive hook load). Set slips & landed csg w/200,000#. Cut off 9-5/8" csg. installed & tstd tbg head. Tstd w/3000# 10 min OK. NU riser & BOP's~ Tstd blind rams w/1500# 10 mins OK. RI}[ w/d.a, to top of float. Tstd pipe rams & Iiydril w/1500# OK. Drld float collar & shoe. Drld 8-1/2" hole ~o 11270'. _9_-5_/8" Casin~ .Detail J__t~s_ D e_.pc.r ip t i o n ~ AP_P_ b o t t Om 9-5/8" Baker "G" Float Shoe 1 9-5/8" 47# P-110 buttress tbg 9,5/8" Baker "G" Float Shoe 69 9-5/8" 47# P-110 buttress tbg 37 9-5/8" N-80 buttress tbg 45 9-5/8" 43.5# N-80 buttress tbg 117 9-5/8" 40# N'80 buttress tbg 1 9-5/8" 47# N-80 buttress tbg Landed Below Zerb - 217 jts 2.54 11214.32 41.87 11172.45 1.92 11170.53 2749.20 8421.33 1568.23 ' 6853.10 1871.98 4,981.12 4905.27 75.85 41.85 34.00 34.00 0 11216.86 11216.86 UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D 7 PAGE NO, LEASE Trading Bay .UnJt StAte WELL NO._ G-19 FIELD. McArthur River DATE 4/9/69 10 11 12 13 14 & 15 17 18 19 2O 21 22 2.3 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11368 11505 11594 11700 11805 12092 12291 12291 12291 10480 11180 1118O Drld to 11368'.. Drld to 11505'. Drld to 11574, circ for samples 2 hrs. POH & picked up core bbl. Cored from 11574-11594. Cored to 11604. PO, recovered 30' (100%) core #1. 30' med to coarse grained sand, no shoe or odor. RIH w/bit & reamed core hole 11574-11604 & dr!d to 11700'. Drld to 11757. POll for wash out. Found wash out in body of grant RR. RIH & drld 1'. POH for washout, found in Hevi-Wate. Drld to 12092'. Drld & surveyed 8-1/2" hole to 12291. RU Schlumberger. Ran DIL. Log stopped @ 11300. RIH w/dp, circulated hole clean. POH. Schlumberger ran electric logs. Completed logging. Layed down hevi-Wate drill pipe & drill collars. RIH open ended to 11470'. Cmtd w/300 sx Class "G" w/l% CFR-2. CIP @ 11:00 am. RIH w/bit & scraper. Drld stringer of cmt from 11156 to 11165. No cmt from 11165-11265. Drld firm cement to 11270. Void to 11290. Good cmt to 11300. Cmtd thru opened ended drill pipe @ 11300' w/400 sx Class "G" w/i% CFR-2 ~ , CIP @ 8:30 am. Pulled 10 stands & circulated, no cmt returns. Rill w/bit & scraper. Tagged top cmt @ 10445'~' CO cmt to 11190. Circulated hole clean. Displaced mud w/fresh wtr, w/salt added, (25,000 ppm). Schlumberger.ran junk basket w/junk ring to 11190. Ran Baker cast iron BP on wire line & set same @ 11180'. Schlumberger perforated 4 hpf w/4" carrier Hyper-Jets from 10570-11152'. Ran Otis pkr on wire line and set @ 10450. Ran 4-1/2" tbg & jewelry. Completed rng 4-1/2" tbg & jewelry. (See Tubing Detail). Rigged down BOP's & riser, installed & tstd Cameron Xmas Tree. Tstd w/5000# OK. Displaced salt wtr w/30,000 gals diesel. Pulled B.V. dummy & closed sleeve @ 10,405'. Tstd pkr w/2000# OK. Released Rig @ 8:0.0~~_2_~/6~9_. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO LEASE, Trading Bay Unit State VdELL NO. G-19 FIELD McArthur River DATE E, T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Tubing Detail Jts_ Descri tip_~ Le_~t_h_h 3-1/2" butt mule shoe 2 3-1/2" 9.20# N-80 tbg 3-1/2" X-Nipple 4" x 3-1/2" XO Otis 4" x 3.57" seal'assem. Otis Locator 4-1/2" butt × 4-I/2" EUE XO 1 4-1/2" 12.6# N-80 tbg Otis CX Mandrel 74 4-1/2" 12.6# N-80 tbg Otis CX Mandrel 14 4-1/2" tbg Otis CX Mandrel 14 4-1/2" tbg Otis CX Mandrel 14 4-1/2" tbg Otis CX Mandrel 14 4-1/2" tbg Otis CX Mandrel 18 4-1/2" tbg Otis CX Mandrel 26 4-1/2" tbg Otis CX Mandrel 38 4-1/2" tbg Otis CX Mandrel 48 4-1/2" tbg Otis CX Mandrel 65 4-1/2" tbg -, Otis Ball Valve 8 4-1/2" tbg Tubing t{anger Landed Below Zero 336 jts Total .85 10529.26 62.67 10466.59 .45 10466.14 1.00 10465.14 21.18 10443.96 1.10 10442.86 1.10 10441.76 30.85 10410.91 6.20 10404.7]. 2256.68 8148.03 6.20 8141.83 429.93 7711.90 6.20 7705.70 438.24 7267.46 6.20 7261.26 437.85 6823.41 6.20 6817.21 436.60 6380.61 6.20 6374.41 557.50 5816.91 6.20 5810.71 808.98 5001.73 6.20 4995.53 1176.71 3818.82 6.20 3812.62 1495.39 2317;23 6.20 2311.03 2022.70 288.33 3,00 285.33 246.33 39.00 1.00 38.00 38.00 00' 10530.11 Bottom 10530.11 UNION Oil CO. Of caLifOrNia DRILLING RECORD SHEET D PAGE NO., LEASE Trading Bay Unit State WELL NO. G-19 I%9 FIELD McArthur River DATE 6/27/71 28 29 50 7/1/?l E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS' RU Schlum on 6/27/71, to set wireline thru tbg csg plug to isolate btm set of tlemlock zone thief wtr injection perfs. Ckd hole open to 11180' (top of BP). Ran & attempted to set Schlum plus plug. No good. Pushed to btm. RI plus plug #2. Set @ 11047' w/well .on injection. Closed well in. Well flowed back. Checked top of plug at 10960'. Returned well to injection· Checked top of plug at 11040'. Dumped cmt at 11039'. Rill & tagged top cmt @ 11031'. I~C 12 hrs. WOC 20 hrs.' Cont dumping .cmt. Now top cmt @ 11028'. IXnnped 16 sx cmt. I~C. Checke.d top cmt at 11028', no cmt fill. Returned well to injection 300 BPD at $00 psi Ckd top of plug at 11042' · , 14' deep. RI w/dunp bailer. Ckd top of plug at 11048. Closed well in and moved off well -- tool failure. 'R.[C[[VED JUL t5 1971 DIVISION OF OIL AND GAS ANCHOIIAGI~ · ' U N I.O, ,, OIL CO. OF CALIFOi-,,qlA DRILLING RECORD SHEET A PAGE NO. , Trading- Bay Unit Stat%VELL NO.. ,G-19 LEASE FIELD McArthur River - Hemlock LOCATION .Conductor #14, Leg #4, 1827' North and 1491' West from SE corner, Section 29, T9N, R13W.~ Sbi. PERMIT NO 69-17 T.D. 12,291t DEVIATION (B.H.L.) COMPANY ENGINEER -SERIAL NO ADL 17594 ,, T.V.D. SPUD DATE 3/6/69 'COMP. DATE CONTRACTOR WODEC0 TYPE UNIT Rotary National 1320' DRILL PIPE DESCRIPTION 5" 4/23/69 m O ..... 55 ELEVATIONS: WATER DEFrH It. T. TO OCEAN FLOOR · ' ll.T. TO MLLW -B., T. TO g~I~I., D~CK R.T. TO APPROVED: i25.00' 235.60' 110.60' 19.30'" ~-~ 4'2.60' ' ' (B.E. Tal,ley).-i:...i ~ ' BIT RECORD =~'~ , DEPTH & DEVIATION DATE DEPTH NO. SIZE MAKE TYPE .SIZE OUT FEET HOURS ANN. ~ '3/6/691 363 B.R.1 15" HTC OSC3 '3-14 536 173 5-1/2 -., -, " " 2-1/2 - - Opened hole to 22" 6 363 HO1 22" i Servco HO i - 7 I5120 RRR1 15" HTC osc3 3-24 " i6 1 a - Shoe & cmtd · ' 7 536 2 12-1/4" ~iTC OSC3 3-14 2000 1464 21-1/2 108 3~7 8 2000 RR3 " -Reed YTIAG 3-24 21'~7 ! 127 8 'Dyna RR~0 fm GL16 D.D. _ ''' 9 ' 2127 4' " " STIAG " 2275 148 5. Dyaa '9 2275 5 " HTC OSC3A 3-14 3027 752 6-1/2 113 404.. 10 3027 6 " - HTC OSCIG " 3890 863 12 " " 11' 3890 7 " "Globe ST3G 'Y 4486 5~6 9-1/2 " " 11 4486 4RR " ' Reed I STIAG, " 4750 264. 4 " 12 520 HO2 17" Smith' Gp open 3340 2820' 16.. 78 Opened hole to 17" 13 3340 HO3 " " " 'f 4413 1073 15 " Lost 1 rolle~ cutter _ ~.14 4413 :iO4~R " " " " 47'50 337l 9 " ,. 16 4750 8 12-1/4 ' " DGH 3-15 4758 8 1-1/2 " Drld on jn~ ' 16 4758 ~#1' " Servcc " 4760 2 2-1/2 " II[~ ~./~, .~'" 17 ' I 4760 9 " 'Globe MT3 3-15 5077 317 9-1/2 '113 404 T-6, B-'5~M 17 5077- 10 " .Smith DGH 3-14' 5460 383 7-1/2 " " T-6 B-1 1'18 . 5460 11 " ' I Globe sT3" " 5840 380: 9 '" '" T-4 B-4 K'£V 18 ! 5840 12 " Smith ,DGH " 6234' 394 9-1/2 " " HWK 19 6234 13 " Globe ST3G " 6624 390 12-1/4 '" " REt 20' 6624. 14 " " " " 6940 316' i0 " " -, I20 6940 15' " Smith DGH ' " 7329 389 9 " " _ _ 21' 7329 i6 " Globe ST3G .... " '7542 213 7-1/2 " " T-5 B-3 ~I[M . 21 7542 !7 " " Smith DGH " 7812 _2~ 8-1/2 " " T-4 .B-4 ,i 22 Ii' 7822J18 " Smith DGti " 7990 162 7-1/2 " " T-7 B-5 '"23 7990' 19 " Globw ST3G " 8232 ~42 8-1/2 '~ " T-4 B-2 23 '8232 ! 20 " ~10be ST3G " 8290 ' 58 2-1/2 " " Pulled for washout _ 24 ' 8290 2i' " Globe I'ST3G .." 8)87 97 5-1/2 107 370 T-4 B-3 24 8387 22 ,, Smith K2H ,, 8512 1'~5 5_1/2" ,, ,~ T_2 B-2 _ "I25 8512 23 ,', , Reed YTIAG ,, 879.5 ~83 11-1/2 ,, ,, T_3 B-3' 25 . 8795 24 ,, Reed YTIAG ,, 899.7 202 10-1/2" 26 8'997 25 " Glo~e STIAG -" 9'132 153, 7-1/2 " " TL3 B-2 27 ~9132 26 ,, Reed YTIAG " 9295 163 7 " ,, T_4 'B_2' _ 27 9295 27 "' Smith DGH "' "949'2 197 7-1/2 " " T-5 B-3 · , , '28 I 9492 28 " Reed ! YTIAG '" 9565' 73 4-1/2 " " Ti2 B-1 28' ' 9565 29 " Smith .DGH " 9760 "i95 7-1/2 " " T-6 B-3 29 9760 30 I " -Reed i YTIAG " 9909 149 9 100 316 TLS B-3 'II29 9909. 31 ,,i. HTC - ODG 3-15 10103 19'4 11 " " T-8 B23 ..... -. 30 10'103 32' " Smich DGH 3,14 10293 190 10' 95 344 T-7 B-4 31 10293 33 '". Smith K2PH '" 10'414 121 7 "100 317 T-7 B'4' .... 31 10414' 34 ~' Smith K2PH 3-15 10505 131 11-1/2 " " ". " , g/1/69 10540 '35 " Smith K2H " 10610 70 5-1/2 " " T-6 'B-3 "' 2 .. 10610 36 " HTC . X55R " 10820 210 22hrs 104 328 T-1 B-4 "3 10820 37 '" HTC X55R " 11030 210!2421/2 102 323 T-5 B-6 . _ . 4 " 11030 !.38. " HTC' XDR "' ' 11080 50 7 10'1 316 T-5' B-2 4 11080 39 " Globe ~'E3G "' Ll108' 28 2'-1/2 '" " T-I5 B-3 5 11108' '40 " HTC XDR " Ll152' 44 5-1/2 " ." T-2 B-1 ' '7 '' 11152 41 " Reed YTIAG " 11220. 68 4-1/2 " " " " __ 8 11220 42 '8-1/2 Reed YTIAG 3-11 '11'321 '101 6-1/2 170 374 T-7' B24 1/8" O.G. _ II 9 11321 43 " Smith K2H" " [1359 I 38 4 " '~' T-8 B-8 " · 9 11359 44 "' HTC X55R '-' 11405 46 9 " " T-5 B-5 "' ld 11405 45 " t HTC XDR !' L1505i 100 6 155 342 T-6 B-2 1t" 11505 46 I " hTC XDR '~ [1574 69 5 " " T-4 B-ii 12 11574 iCH~-5/8x4" ]hr'is Dia D.A. ~1604 30 8-1/2 Core #1 "12 · %1604' 147 I 8-1/2 iHiC' !xDR 3'11 ~1700 96 6-1/2 ~" " T-5 B-8 .... UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET A PAGE NO,.. LEASE : WELL NO. G-19 SPUD DATE. COMP, DATE .. FIELD. . . CONTRACTOR . LOCATION TYPE UNIT RIG NO. DRILL 'PIPE DESCRIPTION ELEVATIONS: WATER DEPTH PERMIT NO 'SERIAL NO. Ii. T. TO OCEAN FLOOR R.T. TO MLLW T.D. T.V.D. R.-T. TO DRILL DECK ~-' :DEVIATION (B.H.L.) II. T. TO PtlOD'UC~iON DECK COMPANY ENGINEER.. APPROVED: BlT RECORD MUD VEL. DEPTH & DEVIATION "' I~IT 3ET DEPTH .... VERTICAL [] DATE DEPTH .NO. . SIZE }'IAKE TYP. E SIZE ,. OUT FEET HOURS ANN. JET DIRECTIONAL [] 4/14/69 11757 -49 8-1/2" Reed ST'IAG 3-11 11831 74 5-1/2 170.1 375 T-g B-4 "15' '1 11831 5'0 " Reed' " ..... h '11920 89 6 ,, I ,, T-7 "B-2 ..... "15i 11920 5'i " HTC 0DV '"" 12010 90 7'" "" "' ' T-6 'B-6 "' 16 '" 12010 '52 "' ,,' 'i, " " 12092 82 7 " " T-8 B-7 1/2" O.G 16 12170 5'4 " .,, .... " " 12230 .... 60 ....." '" " " ' ' " '"' ' .... .... 17 12291 55 .. " Reed YH'G ' ;' 12291 ...61 .... 7'.'.'.. . '" '". .... " . ' "" ....... 20 .... 12291.1 56 " .. ,, YTIAG ~ 3.-1..5 ..Cleero Out Cement ...... . _ ............ ..... , . , . . ....... , ........ .... . . . , , ., UNIf I OIL CO. OF CALIFC'"NiA MUD RECORD SHEET B Page NO 3 LEASE Trading Bay Unit State WELL NO. G-19 FIELD McArthur River' TYPE ~ DISTRIBUTOR D~T~ I D~T~ W~GHTt V~ SC' W' L' I ~H S~LT O~L 'SOLIDS ~MA~K S . 3/6/69 468 78 50 Spud bIud . .. 8 78 58 12 8.5 18000 . 6.-1/2 ,. I9 2000 79.5 40 9.8 9 19000 5 =o =soo so' 4o I ~ ' 3 8 ~ 9 80 45 9 5' 9.4 19000 65 5 1/ '~ .-. - 12 4560 80 48 9.6 9.5 19000 5 · 13 4750 79 49 8.2 , 9.5 19000 - ~_1/2 Opened 1221'/4. [tole to 17" hole .... 14 4150 79 49 8.2 9.5 19000 5 ..- 15 ' . 78 45. 8.6 9.5 190)0 ~-i/2 17 5420 78 42 9.6 I ,9.5 19000 3-1/2 -- 18 6123 75 45 9.8. 9,5 19000 4 2-1/2 12 · "19 6219 76 45 10,2 9,2 19000 3~1/2 3 13 20 6624 76.5 46 i9,8 9 6 19000 3-1/2 2-1/2 14 ;. ' I ~ 21 7350 74 4,5 8.5 9.5 18000 5 1-3/4 14 · 22 7730 75 50 8' 9.81 18000 5 1-1/2 14 _ 23 7990 74 60, 6.5 9 6 1.8000 5-]/2 ]-1/2 14-1./2 ' 24 8320 75 48 7.5 9.8 1.9000 5 1-1/2 14 25 8512 75 5 47 7,4 9.8 19000 5 l-1/4~ ]3 26 8979 75 57 7.2 9.8 19000 6 -]./2 14 - 27 9262 75 55 5.5 '9.8 lqOO0 7 l-1./4 14 . 28 9539 75 54 ~ 5.2 9,8 19000 7 1-1/4 14 ., - 29 98].8 75 55 5.4 9.5 ]9000 8 1-]./2 14 30 ' 10000 75 57 5 5 9.8 ].9000 8 1-1/2' 14 . 3] 10323 75 59 5.]. 9i8 1.95OO z-I/2 1-]./4 ]4 4/1/6q 1.0500 76 63 5.0 9.8 19500 7-.1/2 1-]/4 14-1/~2 2 '~ - 75.5 62 5.0 9.8 23500 7 l-1/4 14 3 . .., 76 63 4.6 9.6~ 2A00O 7 1-1/214-1/2 4 10990 , 75;5 62 4,8' 9.8 ?TF~FiF) R-1./2 l-l/2 14 5 11105 76 68 4,8 9,8 25500 8 t-1/414-1/2 . " 6 11152 75.5 64 4.8 9.8 25000 8 1'1/4 .14 .... 7 11160. 75.5 68 4.5 9.8 24000 8 1-. 1/4 14 8 11220 SET )-5/8" CASING , WO~'. 9 11270 75 '55 4.4 9.8 22000 5-i/2 1/2 13 10 11399 75 54 4.5 9 8 20000 5-1/2 1/2 13 11 11594 74 53 4.2 9,8 20000 7 1/2 13 ].2 11700- 75 52 4.0 9.8 20000 7 1/2 13 13 11805 75 55 3,8 9,8 20000 8 1/2 13 14 11945 75 55 3,8 9,8 20000 7-1/2 1/2 13 1~, ,' 12092 75 55 3,8 9.8 19800 7 1./2 13 , , 3.6 74,5 61 3.7 9,8 19000 B-l/2 1/2 -13 .18 12291 74 57 2 8 ].0.3 17000 8 1./2 13 , 19 12291. 74 57 2.8 11.2 1.7000 8 1/2 13 - 20 12291 74 54 2,8 11.2.16500 8 .1/2 13 Pluzged BaCk - 2] 122ql. 74 53 3.q ll.O 1.5000 8 1/2 ].3 "- Drld out cmt 22 12291 Fre.~i W~te'~ w/NaC[ 25 000 ppt'~ Completion FlUid -- _ , . . , -- ., -- · , , -- __ · __ · , , i . , __ , . , I 2oo 300 :"' N 50 71 ! o-3O .. O. :I<) 0 15 0 15 0 0 1 15 3 34 6~.-0 7 40' 10 "30 609 96 799.95. , - 89~. 95::.. 20~9.73 21e9.1~ 2590. · 2684. 2778. 2869. 2500 3600 2700 3800 3900 0.81 .08 1.24 1.56 1.79 !.45 I. 20 '0.76 0.21 t~! .. N 0.34 0,62 1.i6 7.10 14 7.45 N 7.22 N 7.75 N 7.64 W 0.63 S 1.05 N 4.74 N. 22<)8.29-~ 11 . 58 N 2~96.62 2 !. 34 N · ~5 67.56 N 120.15 27 88.24 N 149.55 W 68 . 112.13 N 182.30 . 2959.5~ 139.3~ N 21~. ~6 3049.00 1~7.32 N 25!.5~ W 3139.2~ 1~4 . 70 N 284., 78 W ' 3228.90 -223.,' t 4 N 318. 79 3318.77 250.79 N 35~. 81 W . 3409, 36 278.76 N 394. ~3 3500. t2 ~ 306.74 N 415.92 2 0.! 0 .3.'2!': O. !~ .~ 4.06 O. 47. ~&-'W :24 45 3590.94' '~ . <)7 .N 83 W 47 II--':N 24'49 3~81.70 ~3.50 N , 477.62 W 47', 6: H.:, -_.24 .49 3772.47-, 3~2.07 N ~09.'37 W ."- . -... ;: :_.....:~;~'~j::. · ~ -.': . - :/: -4:/ .:~.;:::'.: -.. ., - ' ~ -'. :' 71.86 2.6.7 98.30 2.77 !'29.06 2.65 · 163.81 2.50 203 19 2 S:° 246.14 2.~''.~ t. 290.01 0.58 ~32.35 1.12 376.01 0.84 419.07 ©._47 460. <)6 ,.. 5O2.52 O. '.~3' 544.02 585.67 0. ! 627.33 0.04 UNION OiL OF CALIFORNIA TRADING' BAY UNIT 0 4400 N 45 48 W 27 '55 ' 421~.~ 82 =~:4~--.° Oe N . '4500 'N 45 0 W 27 40 . ... 4'307' 39 .. 5~0,93 4600 N '~ ''~ "~'- 0 4395, ' 4~.~6 W ~' · - ' '~7oo .~ 4~ tl'w 2~'-.4-~ .. 44~s.; 4800 ":N"; 39 :.4 t I*J 28 . 0 -" 457 I-, 38= -. = 687.03 4900 N 3~- & W- 2g '45'-'~'~ 4660..67'- . ?- 721.~6 - - . - - - ~..-::.< _:'~-.:'": "4. 5200 .:N"40-'.2s w ~"~ 4-~2~,0~:'~:': , ~oo "-~Wi::~7' ie w..~-'4., so.~e~_s~':{ · 5400 'N'3&,-53 W 2~ 45 5108.46 8~4,-17 '_ .-._ .,'-. . _. .-~ ,. ,---' '~ -'- ...... ) 'N 3~ 23 W 26 55 51~7.62-- o2~.16 N 5600 -N- 37-'-"6, W 26 45 .-,5286.~2 ~65.06 N =' ~: ~' :'~ ~- 27 ~,8(0 N .~-~-.~...l:~. 25 ' 5465.43- 10~8.20 N 5~ N 35~53'W 27 25 5554.20 1075.50 N ' . '.-~ :~ ~:.: :. '-:f~ .7 "f:'_' :-._ . ~ ~'~ ~' "' ' ~,' 5643. ~.000 .;~ :~ 18 -l'J ,- -26.,,45 50 1 ~00 N ~4'-'3~' W ~': 4_ .- 57~3.32 i 148.85 N 6200 N ~5 49':'W:'' ="'~:~ · ~o~ N 35 23 W 25- '40 5912,72 121~.08 N 6490 N 34 30 W 2~'~5 60'03. el 1~:4 ~7 N ~-6'00:' N~33 36 W ~- '0 .-. "" ~185, 20 1 &700 N :'30"" 6':W 25.' 49 6275.22 1 , . ~,,--~ i ~-~ 6900 N 33 :23't:~: 2~ '3-~ :. 6455.44 1434.68 -~. . - .. 7100 N 3i 30'~' 26..':'.78:- ~'. ~..: 6636- 39 7200 'N 28-36 W- ~:'--:0:/<:"'~727.02' 15'~.06 N 735, N-..: -:. 7 N '7'. VERT I CAL !ON 713.23 7..~.,. 45 ~37.06 W '"'- 904.6! 670.6.3 W E:51 · 19 :.~;?-~.._ ~.-' :.:._-.~. ~44. ~6 81 !174.44 ~ ~-'18.77 ~,ST;: 25 W" !,306.98 _ ~::..:, . - .... 102~.t~ W t397.1~ !048~ W 144t.11 1075.81. W 14~7.07 N -N N" 'I 320.84 W N !344.,59' W. 1389,56 W. 1409, 7~ "::W ~43~,5,4 bi . i8s4.4.<., 1977. '1920. 1963.49 2004. 2047. 2089.14 . I, 06 !. 07 0.60 @ .... 0.45 !-.~7. !. 29 :.: !. 47 O. 70 O. 77 0. 1.~ 39 ~ I !. ~ O. 5'7 1.2-3 7400 N 28 41 W 24 15'': '-'--..::~ '.' ,;'::'-':,ii:::::,.':: ' '::-_:,::::i:7:::~.~::~. ,.. ::. '-, ._ ' ' ' "" 7500 N 27 i8:W 24 7700 'N 24 30 W -'7184. 04 :::_ '- ' ~ - ''- · '- · i ' ' '-" ' ~ ' . : ~'' - "") ~ ~ ' -,~ 7900 N Z6. 6, W 22 ~ y : . ': "~- -. _ _.".'- .':.-~:::::::::::::::::::::::::::::::::::::::::::::::: :-- -~ : ' ...... :" :..:?/.: :.--':"7:~::~' >.':'-:?:::'..- -: .,: . -:- · ' -- .... :, -~- ,': .,, ;- ,:::-:-,?:~?::rs::.:;: :,: ':-:-- .:. , ._ .., . .- -:.. ~-. .... ,, . .. : .. ,:x.,-, ,. :: :.. :~:.:u: .~::~:.:,'{.:,.: _ -:. --., :.. ','L:?:?'~:~;:: :.>':, .... : ' -: :g:: :::: ,-. '::: ..:¢, :;¢;,: ::':~ ;~-., r: ..: .+,,.: , :..>.:.: ..-..~ .., .'" .: -.. - .../-:::" .-_ ::?.x:.'77 .: ::;<-? .... :-;::;::::::,:.:'-~:-::~;{.~:;:~:::)::?--,'-:':::,:>',S, .--, ':::~%i.:::~<,::-:~:~:/,' ' ?-'.::2',.::~'~'-::',::/:.:.f~ G:.:~:;.<??~:, _: ~:.....~' ::'--.~-,-. 7 .< ,'- UN~'~'N'-OIL 'OF CAL:ZFOF(NIA TRADING' BAY UNIT G.-!9 ' ~ ""'~ DIREC;TION'~ AN'OL'£.''. VERTICAL '~ .....RRY., ~N I NC. ~ ~AG~ :3 ::-. NL c.~,:', -¢'1 '. ' ,.~' ' , ,.- LEVEL ROTOR GY~;3$COPIC SURVEY ' LATITUDE DEPTH_ . ::T: ,. . ~. FEET- 'i:-:.,:': ~Ec~IO~::'.~.' LE~-' -' 7553.93 -:': lebl. 56 N 1567.22 [,l :':::-'2'~:42: O. 4~ .' TH~ DOG[EG SEVERITY IS IN DEGREES PER ONE HUNDRED FE~T. '.T- L-lAS COMPUTED ALONG N 40 $ W:{-'i: "'-'-? '-' : : .: _.-,_-"- ,::-?_ ." --' CALCULATIONS ' THE BO.TOM HOLE. -::::;::.;~ :. ?. ..-- . ... . . . _ .:'? .._, -.:~., .:-.~, .< ,. _ :.. -. -.~ ..... :: . :- - - · .<.,_.:.~:, .:--- :- -._. :. ::.... ' .. .... ...... ., . :..::...,. . ,.... .:.. -:: ..... . .,..:. -?-: - .~. , . ,, ". . . , ~" NL SPE FIB'r' -S~N~ "-..-'~ '-' t NCORPSR.qT'ED VERTICRL FR~jECI]ON ~ - N~ NELLS HRVE ~EEN EXT~PDLRIED CUST. UNtON JOB. N~. RK ST~T _- . :}; ;,~" ~.,...:'qLLS ?.:' >_t~--::.'_ ":?? ~;.-:.;~.: ....... :--:- ' ' + + TRADING BAY UNIT 0-19 DRTE, 2-2-85 FINISH MD, = 8100- V, 5.--RZM, = ~20.00 -- . h'L -- t NCOBPOB.flTEO . HOBlZONTRL FBBJECllON SCRLE IS 350 F:EEI'/]NCH - ~'.' . · COURSE LENGTH : I00 ."-_"-~::;:)-..-'--.:~'-'"- '?": ':" 210C + ' - ' ' + + , NO NE[LS HRYE BEEN EXTRqFOLRIED S ~T , REF IS, 7RRDING BRT UNIT G-19 CU~., UN~ON O~L OF'CRLIFORNIR · DRTE, 2-2-8'5 JOB, NS. qK-LB-50009 FINISH MO, = 8100 5TRRT MO, : 0 .. '' ' RXIS IS TRUE NORTH IJ.l CZ: --J . - DEPRRTURE VRLUES ,i 4- ! REPORT and PLAN KLV FILE of SUB-SURFACE SURVEY UNION OIL COMPANY T.B.U. G-I 9 COOK INLET, ALASKA JOB NO ........ DATE, APRIL 1969__ DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA MAY 8 7 1969 DIVISION OF 01/AND OAS DRILLING CONTROL CORP. ~s~T No. · 8UB, VEY DAT& SHEET COMPANY_ ,' Union Oil Com.p~my DATE April. 1969 ' _ ~os No ........ WELL G_:- 19 FIELD-M~~ ~ver ~ _ COUNTY. STATE ._ ~aska TR~ D~IA~ON D~ ~T~G~R C~~A~ ~ASU~ DR~ VER~CAL ..................... R~~ D~ ANG~ CO~ D~N ' ' ...." D~ ~ NO~ $O~ ~T ~T' ' 5~6 536 00 ASS~ ~~ ~) ~:[$ . 623 0° 30~ 623 00 76 S 53° ~ 46 6~ . 7~0 0© [5~ 780 00 69 N 37° ~ 09 ~ 0~ 998 0° 20' .998 00 ~ 90 N 33° W ~ 68 2 06 ~43 0° [5~ ~43 00 64 S 4~° W ~ 20 2 48 ~329 0° ~ ~329 00 82 S 84° ~ ~ ~ 3 30 ~486 0° 15~ [486 ~0 69 ~ 45° ~ '62 3 79 . [707 0° 00~ ~707 00 ~~ 62 3 79 2000 0° 15~ 2000 00 1 29 S 15° E 63 3 45 2077 2° 00~ 2076 95 2 69 N 60° W 72 5 78 2115 3° 4.5~ 2114 89 2 15 N 65° W 1 63 7 73 2178 5° 00' 2177 ~- ~ 5 49 N 67° W 3 77 12 78 2209 6° 00~ 2208 48 3 24 N 60° W 5 39 15 59 2240 6© 15~ 2239 30 3 37 N 54° W 7 37 18 32 2372 8° 45' 2369~77 20.08 N 50° W 20 28 33 70 2465 11° i5' 2460~ 98 18 14 N 49° W 32 18 47' 39 2623 15° 15' 26t3~42 41 56 N 48° W 59 99 78: 28 2840 19° 45~ 2817 66 73 33 N 48° W 109 06 132 77 3027 26° 00: 2985 73 81 98 N 47° W 16~ 97 192: 73 3128 26° i5' 3076 31 44 67 N 48° W 194 86 225~ 92 3252 26° 00~' 3187 76 54 36 N 47° W 231 94 265 67 3599 ,25° 00' 3502 25 146 64 N 46° W 333~ 80 371 15 3890 24° 30:~ 3767 05 120 67 N 44° W 42~ 60 454~ 98 4252 26° 45~ 4090 31 162 94 N 43° W 539~ 76 566 I1 4409 27° 30' 4229 57 72 49 N 44° W 591 90 616 47 DRILLING CONTROL CORP. S.EET S O..,~ r BURVEY DATA BHEET COMPANY .... Union Oil Cc~pany . DATE April 1969 .... JOB NO ....... WELL ~ - 19 : FIELD '~%.1~. Ri'v~.,~ .... COUNTY ........ STATE _~.a~k~ , I' ANGLE 'VERTICALD_ --O~ NO SOUTH ~:;A3T ..... ' . REMAi~ · DEPTH ' ' ~ DIRECTION " ' · ' t · .- ' t,;F'f~ ',- . . .: ...-.-,,, .... , '."'.". :".._ ~ WI~T _.- · J . 'i , .- '. . ,_..' ........... , - .......... , . ~10 ' ' 475'0 28° t5'' '-'' ' 4529~".95 161 :':' N.39'8'W · '~'7i7:'33: ' .... ' · 718 04 ' 4962 27° 30~ 4717 99 97 88 i-' N'38°'W . .794 46. ' 778 30 5077 26° 00' 4821 35 50 41 ! N 39° W ' 833 64 810 03 5460 26° 00' 5165 59 167 90 N 38° W 965 95 913 40 .5840 26° 30' 5505 66 169 56 N 36° W 1103 13 1013 07 623'4 26° 00' 5859 78 172 72' N 35° W 1244 61 1112 14 6624 25° 00' . 6213 24 164 82 N 32° W 1384 39 1199 47 6940 25° 15' · 6499 05 134 80-! N 29° W 1502 29 1264 82 7329 24° 30' 6853 02 161 31 N 2?° W 1646 02 i338 05 7542 2a° 15' 7047 23 87 48 ; N 26° W 1724 65 1376 40 7822 24° 007 7303 02 113 89 ' N 23° W 1829 49 1420 90 8232 21° 15~ 7685 14 148 50 N 21° W 1968 22 1474 15 8387 23° 15' 7827 55 61 18 N 17° W 2026 73 1492 04 ~-~ 8515 23° 15' 7945 16 50 53 N 17° W 2075 05 1506 81 8795 22° 30~ 8203 85 107 15 N 14° W 2179 02 1532 73 8979 25° 30' 8369 93 79 21.! .N 11° W 2256 77 1547 84 9132 25° 45' 8507 74 66 47 N 09° W 2322 42 1558 24 9295 25° 45' 8654 55 70 B1 N 08° W 2392 54 1568 09 9492 26° 00~ 8831 61 86 36 N 07° W 2378 26 1578 61 9760 24° 45' 9074 98 112 21 N 05° W 2590 04 1588 40 9909 24° 45~ 9210 29 62 ~8 N 04° W 2652 27 1592 75 10,103 24° 15~ ~ 9387 18 79 58' N 04° W 2731 76 1598 31 10,292 26° 45' 9555 96 85 ~7.~ N 03° W 2816 71 1602 76 10,414 27° 00' 9664 66 . 55 ~ .... . N 02° W 2872 07 1604 69 10,540 26° 00' 9777 91 55i~4:' N 02° W 2927 28 1606 62 . . ~. · . :[ "~'[ ,, , ~ , . , ................. ........ . DRILLING CONTROL CORP. ~T NO- 3 SURVEY DATA SHEET COMPANY . . UI~Cn 0K1 ~~y ..... DATE . ~2ril 1969 -- JOB NO. , , ~- - 19 ,, . ,.,, WEt. I._ . '~. FIELD M.C3~I~. P&ver COUNTY .... STATE Alaska ...... , ............ TRUE DEVIATION DPEFT RECT~GUI.AR COORDINATES MEASURED DRIFT VERTICAL COURSE DIRECTION · . ............... REMAIW'~ DEFDt ANGIJ~ DEFTH NORIH SOUTH F.~ST W~T 1.1,030 31° 00' 10,201 02 108 15 Iq 03° W 3174 14 1617 13 1.1,220 30° 00' i0,365 56 95 00 N 02° W 3269 08 I 1620 45 11,321 29° 45' 10,453 25 50 12 lq 02° W 3319 17 1622 20 11,405 29° 00' 10,526 72 ~ 40 72 N 01° W 3359 88 1622 91 11,574 29° 30, 10,673 82 83 22 I N 01° E 3443 08 1621 45 11,700 28° 45' 10,784 28 60 61 NORTH 3503 69 1621 45 11,831 26° 45' 10,901 26 58 96 NO~ 3562 65 1621 45 11,920 27© 00' 10,980 56 40 41 N 02° E 3603 04 1620 04 12,092 28° 304 11,131 71 82 08 N 09° E 3684 12 1607 20 12,300 28° 00' 11,315 35 97 66 i N 09°. E 3780 58 1591 93 CIf)St~RE 4102 18 ' N 22° 50 ' W ' . I · I · · 1=---4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT O:F DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPEI~ATOR Uniop Oil Comnany 9f California 3, ADDRESS OF OPEP,,~TOR ' 507 W. Northern Lights Blvd.; Anchorage, Ali~ki~ 99503 4.LOCATiON OF W~:!-T- -- Conductor 14, Leg 4, 1827' North ~ 1491' West from SE corner Section 29, T9N, R13W, SM. (J 50-133-20178 6. LEASE DESIGiX1ATION AND SERIAL NO. ADL 17594 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. U'NIT,FA_RAI OR LEASE NA3~E Trading Bay Unit 9. wELL NO. State G-19 (21-29) 10. I"IJ~L,I) AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC.. T., R., A,I.. (BOTTOM HOLE Sec. 29, TgN, R13W, SM. 12. PERAIIT NO. 69-17 REPORT TOTAL DEPTH AT END OF MONTH, CHA~N'GF.S IN HOLE SIZE, CASING AND CE1VIF2qTING JOBS INCLUDING DEPTH SET A_N-D VOLUtVFES USED, PERFORATIONS, TESTS A_N-D RESULTS. FISHING JOBS, JI/NK IN HOLE A_ND SIDE-TRACKED HOLE AND A.NY OTH~I% SIGNIFICA3~T CHdkHG~ IN HOL~ CONDITIONS. TRADING BAY UNIT STATE G-19 (21-29), MARCH 1969 Spudded: 2:00 AM 3/6/69 Drilled 15" hole to 536'. Opened hole to 22". Ran 13 its 17-3/4" spiral weld cst, hung w/shoe @ 520'. RI w/dp ~ stabbed into Halliburton float shoe Cmtd w/650 sx CFR=2 followed by 50.sx CFR-2'w/4% CaC19. CIP 8:00 p~ 3/6/69. Good cmt returns to surface. Cut off 17-3/4" Est, installed Hydril. Pressure tstd OK. RI w/15" bit. CO cmt ~ shoe @ 520'. PO, RI with 12-1/4"drlg assembly. Drld to 2000'. DDrld to 2275'. Drld to 4750'. Opened 12-1/4" hole to 17" hole 520'-4473'. HO torqued up i released backing dp off @ 1865'. PO, ran overshot, caught fish, recovered ali fish. Opened hole to 17" to 4750'. Ran 124 its 13-3/8" 61# J-55 cst., hung w/shoe @ 4749'. Cmtd w/1450 sx Class "G" cmt mixed with 1/2 cu.ft, perlite per sack, followed by 350 sx CFR-2. Good returns to surface. CIP 7:00 am 3/15/69. Cut off 13-3/8" cst. Cmt @ surface had dropped down hole. Hung 1" at 30 ft in 13-3/8" x 17" annulus. Pumped 50 sx cmt around outside w/2 sx cal-seal @ surface. Installed 13-3/8" cst head, riser ~ BOE. Tstd OK. Drld out float collar, cmt ~ shoe. Drld 12-1/4" hole to 4758', bit ran on iron. PO, ran 12" junk mill. Milled 4758'-4760'. PO, drld to 10,540'. Now drilling. 17 969 DIVISION OF OIL AND GAS --- ANCHORAGE HLB ~ TRM OKG KLV .... -. REi, ~ ~ FILE 14. I hereby certi£~%~t th~ }~i~qing is true arid eorrec-t ' --- . ~r~ Dist. Drlg. Supt. ~A~ 4/15/69 'JIF I NOTE~Re~ort on ~s form is required ior each calendar month, regardless o* the status o[ o~erations, aha must ~ fi~e~ ia ~pHcate with the Division of Mi~s & Minerals b~ the 15th o{ t~e succeedin9 month, un~ess otbe~ise directed. ...... :" 277 .; ~,'~ ~;.': -. .. :. - :/ ..... ... '~..- - ' ' ' 'Hatch il, 1969 WEST FORELAND AREA State of Alaska ADL 17594, ,WFore-2 Director DiviSion of Lands 344 Sixth Avenue Anchorage, Alaska 99501 Dear Sir' In accordance with the provisions of the captJor, ed oil' and' gas lease, I'rading Bay Unit State G-19, drillJn;4 From the Grayling PI att:onn located on State Lease- AD[, ]757~ was spudded on M3rch 6, 1969. The proposed bottom hole location is approxi, ate]y 200' South and 1,790' East of ~'h~ N~V corner Section 29 ;gN, R13W, S.M., on said captioned Very truly yo;~r-~, Robert T. Anderson District Land ~;ade S ,v .,. :,c:, ~ter FORM 401-ANC (REV 8/67) FORM SA- iB FROM: State of Alaska DATE SUBJECT: FORM SA- I B MEMORAN'DUM~ FROM.' State of Alaska DATE SUBJECT, Pon'ri. P--1 ~E~. 9-30-67 (Other instructi.~ reverse side) STATE O'F ALASKA 0IL AND. GAS CONSERVATION ,COMMITTEE ~-TE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DEEPEN [-] PLUG BACK [--I MULTIPLE ~_~ ZONE liL TYPE OF WORK DRILL [] 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS (YF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL At~ur~ace Conductor #14, Leg #4, 1827'N & 1491'W from SE corner Sec. 29, TDN, R13W, S.M.' At proposed prod. zone TOP HEMLOCK: 660' S & 1980'E from NW corner Sec. 29, TDN~ R1.3W, S.M. 13. DISTANCE IN MILES AND DIRECTION FIOM NEAREST TOWN OR'POST OFFICE* 23 air miles NW of Kenai, Alaska 14. BOND INFOiR/VIATION: AP1 50-133-20178 6. LEASE DESIGNATION A_ND S~qJ~,J., NO. ADL 17594 ~z,,, ...... ~,.,~,./~..,~, ~. iF i~m~, ~UUO~T~m OR r~a~3E N~ 8. LrNIT~FARM OR LEASE NAiVII~ Trading Bay Unit 9. WELL NO. State G-19 (21-29) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC.-, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 29, TDN, R13W, S.M. 12. TYPE Statewides~etxand/orNo.United Pacific Insurance Company B-553' 10._NO. OF ACRES IN LEASE : 15. DISTANCE F~OM PRO'POSED~:5 11 6 LO.CATION TO NEAREST PROPERTY OR LEASE LINE, FT, 1500 ' I (Also to nearest drig, unit, if any) I 18. DISTANCE FROM PROPOSED LOCATION* . ~Pt:I'OPOSED D~PTI-I TO NEAREST WELL D~ILL~NG, COM~LETI~D, OR APPLIEnFOR, F?. 111,900'MD ~ ~1 $ TVD 2620' ~, ~ ~ 00' 72 ~mou~, $100~000.00 ~1~. Wo. AC~S ASSIGNED TO ~%IiS WELL 160 20. ROTARY OR CABLE TOOLS ::-..Rot,,~ry 21. ELEVATIONS (Show whether DF, RT, QR, etc.) 22. APPROX>,DATE WORK WILL START* 99' RT above MSL , March 1, 1969 23. 'PROP'OSF~D CASING' ~ND CEMENTING PROGI~ ' SIZE OF HOLE SIZE OF CkSING=~ ':WEIGHT PER 'FOOT" ' ~'RAD~~ :: ~i~G D~?TM " ~': "~: '~ ' ' 7 ~ ~ ' ' ~ ' r QUANTITY 0F' CEMEN_~ ~ ~m .... n ~',=~ ,__ 22" 17-3/4" .312 wall .Spiral Weld 600' 1200'sacks ~ ~i~%~d~ c;~ 17" .13-3/8~,,~: ~ 61~ J,55 47.00' . .5000 " ~ ~ac,~ 8%" 7" nine~ ' ~ 29g N-80 10~700-11~900 500'~., " .. Cement 17-3/4" casing in 22" hole at 600'~ Install 20" Hydrill. Drill 12¼" directional hole to 4,700'. Open to 17" and .cement 13-3/8" casing at. 4,700'. Install BCE. Drill 12¼" directional hole to 10,900'. Run electric 10gs. Cement 9-5/8" casing.at 10,900'. Drill 8½" directional hole to 11,900' Run electric logs. Cement 7" Liner 10,700 - 11,900'. Drill stem test west "F,oreland~'sandS.' '",Isolate WeSt Fo~elrand Perforated intervals. Complete in Hemlock Zone onlY, TOP WEST FORELAND: 540'S & 1790'E from NW corner Sec. 29, TDN, R13W, S.M. BOTTOM HOLE LOCATION: Approximately 200'S i~& 1790'E of the NW corner. Sec. 29.~T~N~ad R13W, S.M -- IN ABoVE SPACE DESCRIBE PROPOSED PI~OGRAIVI: If proposal to deepen o.r plug back, give data on present produ.ctive' proposed new productive zone. If Pro~posal is to drill or deepen direct~onally, give pertinent data on st~bsurface l~cati~ns and rneasure~l and true vertical depths. Give blo~out preventer prograi-n. 24. I h~ify th~t.~e.~For~going~l%ue a~d Correct ...... si~/~~/ DATE, Fe b ruary 27, 1969 TI~ District Land Manage: (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: LSAMPLES AND CORE CHIPS REQUIRE~ / OTHE~ RESULTS: LDI~CTION~ SURVEY ~EQ~ J A.P.I. ~C~ CODE See In~ructi°ns On Revere Side I L i ARCO WFU $ TD 9768' J~ TD 1;),570 (34-19) G-17'" -- ... (14 -19) .... · r PBHL O -.19 · '--... TVD [I,300 (")(21-29) · -- -~ TMD 11,900 "- . .~.~.'~ j Prop Prop T/WF e TV D TMD I0~700 \ \\ (37 -30) "-... ' '-- --. .30 ".. G-5 \ \ \ \ G-4 (22 -28) G-I (32-28) (34- 29) / / (32-32) D-I P (~-~2) 34-32) /f/ G-7 (34-28) ( 12 -33) ~ D-7 ~ (~4-s3 T9N - RI3 W _ UNION G-8 (54-33) ... DIVIS!ON OF C;[L AND GAS OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION MAP OIL CO, OPERATOR UNION TRADING BAY STATE UNIT G-19 _~. (21 -29) I ~" SCALE I" = ~000' 0 I000 ~OO0
