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185-078
XHVZE Imag~roject Well History File C°ver{~ge This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J_ ~ ,~_- ~ _~ ~ Well History File Identifier ~ DIGITAL DATA OVERSIZED (Scannable) Ior items: r~ Diskettes, No. [3 Maps: [3 Grayscale items: [] Other. No/Type [3 Other items scannable by large scanner o Poor Qualit" OVERSIZED (Non-Scannable) [3 Other: NOTES: [3 Logs of various kinds [3 Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Scanning Preparation ~- x 30 = I~,~ BY: BEVERLY ~) VINCENT SHERYL MARIA LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: /.-~' Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: 'ES NO BY: BEVERLY BREN VINCE~ MARIA LOWELL DATE/O/,~//OO~,~/ ~ (SCANNING IS COMPLETE AT THIS POINT UNLES~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES) III IIIIIIIIIII II III ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: DATE: Isl Quality Checked (done) lO/25/02Rev3NOTScanned.wpd ' STATE OF ALASKA r IV E® ALA-.A OIL AND GAS CONSERVATION COMM. f1N2 3 2014 REPORT OF SUNDRY WELL OPERATIONS (��` 1.Operations Abandon ElRepair Well ❑ Plug Perforations 1=1Perforate ®GCOther❑ Run Kill String Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 185-078 .. 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20180-01 4 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 • Trading Bay Unit/K-25 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil,Middle Kenai G,West Foreland Oil Pools 11.Present Well Condition Summary: Total Depth measured , 14,325 feet Plugs measured N/A feet true vertical 9,657 feet Junk measured 13,442(fill) feet Effective Depth measured ' 13,442 feet Packer measured 8,545 feet true vertical 9,139 feet true vertical 6,426 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,997' 13-3/8" 1,997' 1,996' 3,090 psi 1,540 psi Intermediate Production 12,373' 9-5/8" 12,373' 8,538' 6,870 psi 4,750 psi Liner 7,828' 7" 14,323' 9,657' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED MAY 2 7 20?4 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 2,030'(MD) 2,030'(ND) Packers and SSSV(type,measured and true vertical depth) Baker SC1 Pkr 8,545'(MD)6,426'(ND) SSSV-N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM MAY 16 2014 Attempted to squeeze hole in casing from 5,782'-6,735' Treatment descriptions including volumes used and final pressure: Pump 45 bbls(230 sacks)of 15.8#/gal Class G Cement followed with 3 bbls of FW spacer.Displace with 37 bbls of FIW. Final squeeze pressure=725 psi. 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 50 50 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil • 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-507 Contact Ted Kramer Email tkramera..hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature Phone (907)777-8420 Date 1/23/2014 Form 10-404 Revised 10/2012 g-2-7--'441 Submit Original Only ,4► fAi</y Trading Bay Unit King Salmon Platform SCHEMATIC Well No. K-25 As Completed: 12/27/13 Hilcorp Alaska,LLC CASING DETAIL RKB to TBG Head=35' SIZE WT GRADE CONN ID TOP BTM. Tree connection: 13-3/8" 61 K-55 BTC 12.515" Surf. 1997' 1, I 47- L-80 BTC " f ' Missing N-80 BTC 7903Sur' 101779038' [ 9-5/8" Tally guessing 5 95 BTC 10178' 12373' 13 3/8" order 29 L-80 BTC 6.1848.681" 6495' 11001' 8111997' S-95 BTC 11001' 12072' 7"liner 06/11/08: L-80 BTC 12065' 13274' USIT logs S-95 BTC 13274' 14323' ran,csg in TUBING DETAIL good shape 4-1/2" 12.6 L-80 Hdril 503 3.958" Surface 2,030' w/metal loss >20%@ 6350-6480, 7"Liner 3900,3800& top has 3500 collapsed 1�i\\\\\\\\\\\\\\\\\\\\\\\ c_104- S Z��' 7"Liner Hanger @ 6,481' JEWELRY DETAIL Split csg 8,400' 44NO. Depth ID Item Est TOC on back side i;' � i 4 6481' NA Baker Model A Simplex liner hanger @10,7777of 5 " @103' 5 8545' 4" Baker Model SC 1 Packer with±450'of screen(4" :,, j,1 centralizers OD=5.10'))+Slotted Liner(3''/:")hanging mum f 7"Liner Hanger !rs" .,�.. below. @ 12,049' S .6- 5 12049' Baker Model A Simplex liner hanger .111111. 9518"@ - 12,373' % - ► ; Top of Packer 6 G-1 8545',below G-2 combination =G-3 PERFORATION DETAIL of 4"Screen+ 3'/i'Slotted -G-4 Zone Top Btm. Condition Liner,bottom _ G-1 12521 12545 06/06-4-5/8"TCP @ 9076' —C'-5 G-2 12585 12610 06/06-4-5/8"TCP -HB-1 G-2 12625 12645 06/06-4-5/8"TCP HB-2 G-3 12645 12697 06/06-4-5/8"TCP G-4 12787 12840 06/06-4-5/8"TCP Clean out G 5 12933 12955 06/06 4-5/8"TCP depth(6/14/08) G-5 12975 13045 06/06-4-5/8"TCP 13,442' -HB-3 02/86-cmt iso.Sq°Perls(293'-29513/86-(305'-340'-frac HB1 13293 13340 w/20,0008);9/91-(300'-320'-2-1/8"jet guns);6/06- (293'-318'-4-5/8"TCP) Sq.P 13378 13380 02/86-cmt iso°Sq.Perfs .-HB-4 HB2 13390 13420 01/88-2-1/8"jet guns;02/90-2-1/8"jet guns 02/86-cmt iso.Sq.Perfs(542'-5441;9/90-(556'-586'-2- HB3 13542 13586 1/8"jet guns);9/91-(550'-580'-2-1/8"jet guns);6/06- (525'-550'-4-5/8"TCP) HB-5 3/86-(715'-745'-frac 60,000#);9/90-(650'-680';695'- H84 13629 13815 715';770'-800'-2-1/8"jet gun);9/91-(650'670';710' 730';780'-800'-2-1/8"jet gun);9/95-(629'-815'-2- 1/8"gun) 9/98 2-1/8"he 4spf PBTD=14,282' TD=14,323' 2/90-(860'900'2-1/8"jetgun);9/91-(860'-900'-2- H B5 13850 13902 1/8"jetgun);9/95-(850'-902'2-1/8"jetgun)9/98 2-1/8" MAX HOLE ANGLE=62° @ 12,100' he 4spf Revised by ILL 01/23/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/4/2013 -Wednesday RU Rig floor, set up tongs. Install two way check, PU test joint, MU BOP, safety valve, pump in sub, MU to hanger. Fill BOP stack to pretest. Add hand rails, windwalls to rig floor. Install tarps back around BOP stack. JeffJones waived BOPE witness. Test BOPE to 250psi low/2,500'psi high., Break out ported sub. Screw into hanger. Circulate well clean with waterflood to Trading Bay. Pump @ 3bpm for 360bbls. Well clean, no gas detected. Break out joint install drip pan. Install adapter spool. MU joint of tubing and safety valve, attempt to pull 13-5/8" hanger. Would not go through adapter spool. Remove adapter spool and pull hanger. Pull 13-5/8" hanger, too tight to break with rig tongs onboard. PU manual tongs and break out hanger. Schlumberger ready to pull ESP assembly and production tubing. 12/5/2013 -Thursday RU Foster tongs and change out tong heads and dies. PU on production string and L/D 15 joints/then 2 joints/pull flatback line through sheave. Hang sheave off in tubing board. POH with 4-1/2" Hyd. 505 production tubing and flatpack, 195 joints, 5 pup joints, 2 crossovers and sliding sleeve. L/D ESP pump assembly. RD Schlumberger equipment. Waiting on boat to offload 3-1/2" PH-6 workstring and backload 4-1/2" Hyd. 503 production string. 12/6/2013 - Friday RU test pump test variable rams on 3-1/2 " tubing. Move all crossover subs,valves and accesory tools to pipe rack and organize. PU test joint, crossovers to 4-1/2" ported sub,test, charted good. RD test equipment, pull test plug, PU wear bushing, install. Screw in hold down screws. MU adapter spool. 13-5/8" 5M x 11" 5M. Tally first bundle of 3-1/2" PH6 tubing. PU 7" x 9-5/8" scraper BHA MU same,TIH picking up singles. TIH tallying each joint. Install pollution pan. Continue TIH with 3-1/2" PH6 workstring. 12/7/2013 -Saturday Continue to tally 3-1/2 PH6 workstring and RIH. 215 joints plus BHA tagged fill at 6,694'. Layed down joint 215, MU safety valve and pump in sub. Pump 20bbls. down tubing to flush tubing. Switched to reversing. Break circulation at 25 bbls. Wash through tag up depth at 6,694', lost circulation, workstring plugged up. Switched pumping down tubing, unplugged tubing. Began reversing again, work pipe up and down. Wash down to 6,704'. Circulate BU x 2 at 6,704'. Minimal sand in returns. Shut down pumps attempt to lower down tagged solid, set 20K down no luck. RU pump attempt to wash down. RD safety valve and pump in sub. Layed down single joint. Pull wiper rubber. MU DSA to annular. Bolts too long to make up. Filled out hot work permit performed JSA. Used band saw to cut bolts. Installed DSA. RU MU Power Swivel, safety valve, xover. Hook up brackets for snub line. MU joint 216 tagged at 6,712'. Attempt to wash down. Workstring plugged up again. Pumped down tubing, pressured up. Attempt to pump down tubing and casing. No luck. Worked 2 hours pressuring up and releasing pressure, working pipe up and down. No luck. POOH wet to 9-5/8" scraper. Break out same. Continue to POOH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/8/2013 -Sunday Finished POH with 3-1/2" PH6 workstrin_g_and 7" csing scraper. Found fine sand in bit and partial bottom tubing joint. Clean off rig floor. NU DSA for Eline unit. Hold JSA on RU Eline and running casing caliper log. RU Eline. RU Eline lubricator and test to 1,500psi. Test good. RIH with 9-5/8" x7" casing caliper log. Tagged at 6,713 WLM. Tubing tag prior was 6,712 DPM. POOH with Eline and caliper tool. Analize caliper log. Determine 9.5/8" casing has holes and possible part or large hole from 6,334' -6,495' top of 7" liner. PU MU 9-5/8"test packer. TIH to 6,316'.Set test packer and test to 500psi on 9-5/8" casing. Test good. Mix 18bbl PolyPlug Clear Gel fluid loss pill. Fill hole with 19bbls. Pump 18bbl pill plus 5bbl. Mix second half of pill 18bbl. Pump and displace 30 bbl. Pill leaving 5bbl in 9-5/8" casing at 1:00 am. Wait for plug to cure. 12/9/2013 - Monday Wait on PolyPlug to set for 500 psi test. Release test packer and lower one stand to 6,241', set 9-5/8" packer and test 9- 5/8" csing to 500psi. Test good. Lower packer one stand to 6,481' tagged top of 7" liner. PU packer to 6,453', set packer and test 9-5/8" casing to 500 psi. Test good. Mix 34 BBI PolyPlug Gel pill. Displace pill @ 11/2bpm leaving 5bbls in casing. Wait on pill to set 4 hours. Pressure would build up to 200psi and bleed off slowly. Release packer and wash @ 1/2 bpm 1 joint to 6,484'. POOH slowly though pill area. POOH with 103 stands break out 9-5/8" test packer. Layout. PU 3-1/2" Muleshoe. MU to 3-1/2" PH6 workstring. TIH to 6,707' inside 7" 29#casing. Begin washing sand tagged at 6,712'. Change out leaking standpipe hose. RU power swive, break circulation, pump 9bbls to fill. Begin washing down reversing to wash sand. getting good returns. 12/10/2013 -Tuesday Continue to wash to 6,712' @ 3pbm. Wash to 6,764', slow returns pumping at 3.5 bpm getting 1.5bbls back @ 200 psi. Lost all returns. Pulled up above 7" liner top at 6,481'. Mixed 20 bbl salt pill. Spot 20 bbl salt pill at 6,671'. Top of sand fill @ 6,764'. Attempt to wash down. No returns. Pulled up above 7" liner top. Rerouted hopper and jet above 40bbl mixing tank. Clean sand trap. Wait on Poly Plug chemicals. Mix 60bbl PolyPlug pill in 30bbl batches. Displace to 6,661' leaving 5bbls in 7" casing. Winds picking up considerably, temperature dropping. Tieing off tarps, as tarp on BOP area split in half. BOPE witness test today. State inspector coming around noon weather/winds permitting. Focused on improving tempurature readings on critical areas. POOH with 3-1/2" PH6 workstring and muleshoe. 12/11/2013-Wednesday RD power swivel. Repaired hydraulic tongs. POOH with 3-1/2" PH6 workstring and muleshoe. Take out stripper head, remove drip pan, remove 13-5/8" x 7-1/16" adaptor spool. PU test joint, install safety valve, IBOP, pump in sub. Pull wear bushing, install test plug. RU test manifold, pneumatic pump, connect to waterflood. Fill stack. Reroute waterflood line under rig carrier and out to waterflood. Begin testing BOP stack. Leak found on flange of riser. Winds 50-60 MPH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 ,Daily Operations: 12/12/2013 -Thursday TEST BOPE PER AOGCC REGULATIONS,ALL BOPE TEST WITNESSED BY CHUCK SHEVE WITH AOGCC. TEST VBR RAMS, CHOKE MANIFOLD, BLIND RAMS,TIW VALVES, IBOP, KILL LINE &CHOKE HCR VALVES TO 250 PSI LOW & 3000 PSI HIGH. TEST HYDRIL TO 250 PSI LOW& 2500 PSI HIGH. R/D TEST EQUIPMENT. PREPARE TO TEST CASING PATCH. CLOSE BLIND RAMS&ATTEMPT TO PRESSURE TEST 9-5/8" & 7" CASING. PUMPING IN AT 2 BPM & 200 PSI. SHUT PUMP DOWN & 200 PSI BLED DOWN IN 2 MINUTES. ORDER OUT CEMENT EQUIPMENT& PERSONNEL. CONTINUE WINTERIZING. PUMP NON- PRODUCED FLUID FROM PITS TO TRADING BAY. BEGIN CLEANING RIG FLUID TANKS. FIW LINE FREEZING INSIDE PIPE RACK AREA. THAW FIW LINES TO MUD PITS. WIND GUST UP TO 50 MPH.TIH WITH MULE SHOE & 3-1/2" PH-6 TUBING. DEPTH @ 0600 HRS = 3,799'. 12/13/2013 - Friday TIH WITH 3-1/2" PH-6 TUBING & MULESHOE, TAG FILL @ 6,750'. SPACE OUT&SET END OF MULE SHOE AT 6,735'TUBING MEASUREMENTS. CLEANING MUD PITS, WINTERIZING RIG & EQUIPMENT WHILE WAITING ON CEMENT EQUIPMENT& PERSONNEL. POOH WITH 10 STDS FROM 6,750'TO 6,117'. SECURE WELL SAME. CLEAN MUD PITS, FILL RIG PIT WITH 150 BBLS OF FIW & RECIRCULATE FLUID INTO TANK TO HEAT FIW FOR CEMENT JOB. 12/14/2013 -Saturday WINTERIZING RIG & EQUIPMENT WHILE WAITING ON CEMENT EQUIPMENT& PERSONNEL. 12/15/2013 -Sunday WINTERIZING RIG & EQUIPMENT. GENERAL HOUSEKEEPING WHILE WAITING ON CEMENT EQUIPMENT. LAY OUT& M/U CHICKSAN IRON FROM RIG FLOOR TO SOUTH EAST LEG. R/U PUMP & EQUIPMENT, ROUTE FIW LINES, FINISH LAYING OUT HIGH PRESSURE DISCHAGE LINES TO RIG FLOOR. TIH WITH 10 STDS OF 3-1/2" PH-6 TUBING TO 6,735'TUBING MEASUREMENT. HOLD PREJOB MEETING WITH PERSONNEL. ATTEMPT TO ESTABLISH INJECTION RATES, UNABLE TO KEEP FIW FEED LINES & OTHER LINES ON PUMP FROM FREEZING. REROUTE HEATER HOSES& WRAP PUMP WITH TARPS TO THAW. HANG WINDWALLS AROUND WEST SIDE OF PLATFORM WHILE THAWING LINES. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/16/2013 - Monday CONTINUE HANGING WINDWALLS ON NORTH SIDE OF KING SALMON &THAWING CEMENT PUMP LINES. ATTEMPT TO BREAK CIRCULATION, BEGIN PUMPING 2 BPM @ 200 PSI. PRESSURE INCREASING TO 2 BPM @ 500 PSI AFTER 20 BBLS PUMPED. LINE UP TO REVERSE CIRCULATE. CIRCULATING HOSES FLASH FREEZING. SWAP HOSES & BREAK CIRCULATION. REVERSE CIRCULATE 90 BBLS. HAD SAND IN RETURNS. LINE UP & PUMP NON-PRODUCED INLET WATER TO TRADING BAY. SHUT PUMP DOWN, SWAP HOSES & LINE UP TO ESTABLISH INJECTION RATES. MANIFOLD FLASH FROZE ON #3 VALVE. LINE UP & DIVERT FLUID TO BACKUP VALVE. ESTABLISH INJECTION RATES OF 2 BPM @ 500 PSI. PUMP 18 BBLS OF FW AHEAD, MIX& PUMP 45 BBLS (230 SACKS)OF 15.8#CLASS G CEMENT. FOLLOW WITH 3 BBLS OF FW SPACER. DISPLACE WITH 37 BBLS OF FIW. BREAK DOWN PUMP LINE OFF FLOOR, POOH FROM 6,735' TO 5,782'. REVERSE CIRCULATE 1.5 TUBING VOLUMES @ 3 BPM. HAD TRACE OF CEMENT ON BOTTOMS UP. ISOLATE ANNULUS& LINE UP PUMP LINE ON TUBING. SQUEEZE 10 BBLS OF CEMENT BEHIND CASING PUMPING 1 BPM @500 PSI. SHUT DOWN PUMP &WAIT 15 MINUTES. PRESSURE BLED TO 300 PSI. SQUEEZE 10 BBLS OF CEMENT BEHIND PIPE PUMPING 1/2 BPM. FINAL SQUEEZE PRESSURE = 725 PSI. SECURE WELL AT RIG FLOOR TRAPPING PRESSURE. CLEAN OUT& R/D EQUIPMENT. HOOK UP RIG PUMP LINES BACK ONTO MANIFOLD &WINTERIZE SAME. BLEED OFF 100 PSI OF REMAINING TRAPPED PRESSURE FROM TUBING, PREPARE TO POOH. POOH WITH 3-1/2" PH-6 TUBING FROM 5,782' TO SURFACE. L/D MULE SHOE SAME. 112/17/2013-Tuesday HANG WIND WALLS, RUN GLYCOL LINES ALONG PUMP & FLUID LINES TO KEEP THAWED, FINISH INSTALLING NEW INSULATED HEATER DUCTS WHILE WAITING ON CEMENT. MEASURE OUT 9-5/8" CLEANOUT ASSEMBLY. P/U 9-5/8" CLEANOUT ASSEMBLY WITH 8.5" BEAR CLAW MILL& 8.5" STRING STABILIZER. REMOVE DRIP PAN & 7-1/16" SPOOL ADAPTOR. STRIP OVER BHA SAME. INSTALL 7-1/16" ADAPTOR FLANGE, DRIP PAN, & CLOSE BACK TARPS AROUND BOP STACK. TIH WITH 3-1/2" PH-6 TUBING,TAG CEMENT @ 6,462'. L/D TAG JOINT& PREPARE TO R/U POWER SWIVEL. R/U POWER SWIVEL, INSTALL HALLS HEAD RUBBER & M/U DRILL JOINT. R/U &TEST 9-5/8" CASING TO 500 PSI. AGAINST TOP OF CEMENT AT 6462'. 12/18/2013 -Wednesday DRILL OUT CEMENT FROM 6,462'TO 6,480'. REVERSE CIRCULATE 3.5 BPM &400 PSI AT 6,480'. CEMENT RETURNS CLEARED. SHUT DOWN RIG PUMP & PREPARE TO POOH. R/D POWER SWIVEL& REMOVE HALLS HEAD RUBBER. POOH WITH 3-1/2" PH-6 TUBING FROM 6,480' TO BHA. RACK BACK(6) 4-3/4" DRILL COLLARS IN DERRICK, N/D DRIP PAN &7- 1/16" ADAPTER FLANGE. POOH, BREAK & L/D JARS, 8-1/2" STABILIZER WITH 8-1/2" BEAR CLAW MILL. RETRIEVE WEAR BUSHING, P/U & M/U BOP TEST ASSEMBLY WITH TEST PLUG. R/U TESTING MANIFOLD, INSTALL NEW CHARTER RECORDER. TEST BOPE PER AOGCC REGULATIONS. WITNESSED WAIVED BY JIM REGG ON 12-17-13 @ 09:35. TEST ALL BOPE TO 250 PSI LOW& 2,500 PSI HIGH. PERFORM KOOMEY DRAW DOWN TEST. INITIAL PSI = 3,000, PSI AFTER OPENED = 1,700, 200 PSI BUILD UP= 29 SEC., FULL PRESSURE BUILD UP = 142 SEC. PERFORM BACKUP NITROGEN BOTTLES MONTHLY TEST ON 12-19-13 = 1900 PSI. BLOW DOWN LINES & R/D TESTING EQUIP. WINTERIZE RIG & EQUIPMENT. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/19/2013 -Thursday L/D 20 JOINTS OF 3-1/2" PH-6 TUBING FROM DERRICK FOR DRILLING OUT CEMENT. P/U & M/U BHA#3 WITH 6" MILL TOOTH BIT, SPIRAL STRING MILL,JARS& (6) 4-3/4" DRILL COLLARS. TIH WITH 101 STANDS OF 3-1/2" PH-6 TUBING TO 6,465'. R/U POWER SWIVEL& INSTALL HALLS HEAD STRIPPER RUBBER & BREAK CIRCULATION WITH 3.5 BPM & 500 PSI. WASH CEMENT FILL F/6,470'TO 6,481'. ATTEMPT TO DRILL OUT CEMENT INTO TOP OF LINER HANGER WITH NO SUCCESS. BIT TORQUING UP ERATICALLY&JUMPING. CIRCULATE BOTTOMS UP. BLOW DOWN PUMP LINES& R/D POWER SWIVEL. POOH WITH 101 STANDS OF 3-1/2" PH-6 TUBING & BHA. REMOVE DRIP PAN & 7-1/16" ADAPTER FLANGE, P/U & M/U 8.5" TAPERED MILL PIGGY BACKED WITH 8.5" SMOOTH STRING STABILIZER. STRIP OVER & INSTALL ADAPTER FLANGE & DRIP PAN. TIH WITH REMAINING BHA ASSEMBLY, (6)4-3/4" DRILL COLLARS,JARS, &X-0 SUB. TIH WITH 3-1/2" PH-6 TUBING. DEPTH @ 0600=4,695' 12/20/2013 - Friday CONTINUE TIH WITH 3-1/2" PH-6 TUBING F/4,695'T/6,450'. TAG SAME. R/U POWER SWIVEL& INSTALL HALLS HEAD STRIPPER RUBBER. BEGIN REVERSE CIRCULATING 3.5 BPM @ 500 PSI, ATTEMPT TO WASH WITH TAPERED MILL AT 6,450' WITH NO SUCCESS. BEGIN ROTATING WITH POWER SWIVEL WITH 80 RPM & 2500- 3000 FT/LBS OF TORQUE. MILL FROM 6,450'TO 6,453'. HAD WHAT LOOKED LIKE COAL COMING OVER SHAKERS, ROTATION WAS ROUGH LIKE ROTATING ON IRON. CIRCULATE BOTTOMS UP & PREPARE TO TEST CASING. PRESSURE UP ON 9-5/8" CASING TO 500 PSI, SEEN 25 PSI DROP OFF IN 10 MINUTES, PRESSURE UP TO 750 PSI AND HAD 100 PSI DROP OFF IN 4 MINUTES. BLEED OFF PRESSURE SAME. CIRCULATE BOTTOMS UP @ 6,453' WHILE PREPARING TO POOH. POOH WITH 3-1/2" PH-6 TUBING TO SURFACE, COUNT PIPE & HAD ONE JOINT MISSING ON SURFACE. FOUND JOINT UNACCOUNTED FOR INSIDE STRING. CORRECTED BOTTOM DEPTH 6,484'. L/D 8-1/2" MILL&8-1/2" STRING MILL. FILL HOLE &CLOSE BLIND RAMS, TEST CASING TO 600 PSI. PRESSURE BLED BACK TO 500 PSI IN 14 MINUTES. DECISSION WAS MADE TO P/U 7" CLEANOUT ASSEMBLY&TIH TO DRILL OUT CEMENT. M/U 6" MILL TOOTH BIT WITH 5.969" SMOOTH OD STRING MILL, (6) 4-3/4" DRILL COLLARS,JARS & X-O SUB. TIH WITH 3-1/2" PH-6 TUBING TO 6,465'. R/U POWER SWIVEL& INSTALL HALLS HEAD STRIPPER RUBBER. REVERSE CIRCULATE @ 3.5 BPM & 300 PSI. TAG @ 6,481'. BEGIN ROTATING 60 RPM, TORQUE OFF BOTTOM = 2,700 FT/LBS,TORQUE ON BOTTOM = 3,500 FT/LBS. PIPE TORQUING ERATIC &JUMPING. WORK PIPE THREE TIMES ATTEMPTING TO SLIDE INTO LINER TOP WITH NO SUCCESS. REVERSE CIRCULATE & OBTAIN NON-PRODUCED FLUID TRANSFER TO TRADING BAY. RECEIVED 1-2 INCH PIECES OF COAL BACK ON BOTTOMS UP. TRANSFERING DIRTY INLET WATER TO TRADING BAY, PREPARING TO DISPLACE WELL WITH CLEAN FIW. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/21/2013 -Saturday PUMP 300 BBLS OF NON-PRODUCED DIRTY INLET WATER TO TRADING BAY TO CLEAR RIG PITS. DISPLACE 1.5" HOLE VOLUME AT 6,481' (600 BBLS) WITH FIW SENDING ALL RETURNS TO TRADING BAY. R/D POWER SWIVEL& REMOVE HALL HEAD STRIPPER RUBBER. POOH WITH 3-1/2" PH-6 TUBING PUMPING TUBING DISPLACEMENT EVERY 10 STDS. HOLE TOOK PROPER FILL. RACK BACK (6) 4-3/4" DRILL COLLARS, L/D STRING MILL& BIT. NO SIGNS OF WEAR ON BIT. HAD MARKINGS ON LOWER SECTION OF STRING MILL BLADES. TIH WITH 3-1/2" PH-6 TUBING & MULESHOE TO 6,481',TAG SAME, P/U TO 6,479' & R/U CIRCULATING HOSES. SPOT PRIORITY E-LINE EQUIP. WHILE TIH, REVERSE CIRCULATE 2 TUBING VOLUMES AT 3.5 BPM & 200 PSI. HAD CLEAN RETURNS, BEGIN R/U PRIORITY E-LINE EQUIP. WHILE CIRCULATING. R/U SIDE ENTRY SUB WITH LUBRICATOR, M/U PRIORITY E-LINE TOOLS & PREPARE TO RIH. RIH WITH 2.125" GAUGE RING TO 6,423', POOH & L/D GAUGE RING SAME. P/U & RIH WITH 2-1/8" EXPRO 3 VIEW HAWKEYE DOWNHOLE CAMERA. 12/22/2013 -Sunday RIH WITH EXPRO 2-1/8" HAWKEYE THREE DOWNHOLE CAMERA WITH SIDE VIEW &TAG @ 6,481' UNABLE TO OBTAIN PICTURE INSIDE OR OUTSIDE OF TUBING. CIRCULATE DOWN TUBING @ .5 BPM TO OBTAIN PICTURE WITH NO SUCCESS. POOH WITH CAMERA& LENS WAS CLEAN WITH NO DEBREES NOTICABLE. REVERSE CIRCULATE (2) TUBING VOLUMES WITH CLEAN FIW. HAD LITTLE COAL RETURNS ON BOTTOMS UP. P/U DOWNVIEW EXPRO HAWKEYE CAMERA& RIH. TAG & 3,671', UNABLE TO WORK PASS. CIRCULATE DOWN TUBING &OUT CASING @ 1 BPM. ATTEMPT TO LOWER CAMERA PAST 3,671' WITH NO SUCCESS. PRIORITY E-LINE UNIT CONTINUING TO THROW BREAKERS ON PLATFORM. MELTING EXTENSION CORDS. POOH SAME. CAMERA WAS BENT ON END AND AFTER FURTHER OBSERVATION HAD BEEN BENT FROM JAMMING BODY UPON R/U. PRIORITY E-LINE UNIT DETERMINED TO HAVE SHORT& ELECTRICAL PROBLEMS INSIDE MAIN BOARD OF UNIT. UNABLE TO USE ELECTRONICS INSIDE UNIT. P/U & RIH WITH 2.125" GAUGE RING TO 6,471' WITH NO OBSTRUCTIONS. POOH & R/D PRIORITY E-LINE. HANG WINDWALLS&WINTERIZE WHILE WAITING ON POLLARD E- LINE. OFFLOAD, SPOT, & R/U POLLARD E-LINE.TROUBLESHOOT EXPRO DOWN VIEW CAMERA. UNABLE TO OBTAIN PICTURE ON SURFACE TEST. CHANGE OUT BOW SPRING CENTRALIZER & OBTAIN SURFACE PICTURE. RIH WITH EXPRO 1- 11/16" DOWN VIEW HAWKEYE 3 CAMERA. TROUBLE SHOOT CAMERA AT 5,300', REPEATEDLY LOSING SIGNAL. OBTAIN SIGNAL& RIH TO 6,471' ELM. PUMP FIW DOWN TUBING @ 2 BPM &OBTAIN PICTURES OF 7" LINER TOP. POOH WITH POLLARD E-LINE. R/D EXPRO CAMERA& POLLARD E-LINE. POOH WITH 2 STANDS&WAIT ON ORDERS. 12/23/2013- Monday DECISION WAS MADE TO TEMPORARILY ABANDON K-25 WELL, R/D POLLARD E-LINE & LUBRICATOR. PREPARE TO POOH LAYING DOWN 3-1/2" PH-6 TUBING. POOH LAYING DOWN 3-1/2" PH-6 TUBING FROM 6,354'TO 5,912'. RIG ENGINE RADIATOR FAN SHROUD BROKE SENDING PIECES OF THE FAN & HOUSING THROUGH THE RADIATOR. SECURE WELL SAME. RIG DOWNTIME: TAKE APART RIG RADIATOR & FAN ASSEMBLY. ATTEMPTING TO LOCATE PARTS WITH MONCLA MANAGEMENT. la Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-25 50-733-20180-01 185-078 12/4/13 12/27/13 Daily Operations: 12/24/2013 -Tuesday WAITING ON RADIATOR ASSEMBLY PARTS FROM MONCLA SHOP IN KENAI. UNLOAD RADIATOR& PARTS FROM BOAT. RIG DOWNTIME: UNABLE TO LOCATE RADIATOR TO FIT MONCLA 404 IN ALASKA REGION. WILL DO COMPLETE REBUILD ON BUSTED RADIATOR. ETA ON REBUILD = 12-30-13 12/25/2013 -Wednesday POOH LAYING DOWN 3-1/2" TUBING FROM 5,912' TO 851'. CONTINUE LAYING DOWN 3-1/2" PH-6 TUBING TO SURFACE. TIH WITH TUBING FROM DERRICK& L/D SAME. TIH WITH (6) 4-3/4" DRILL COLLARS& POOH LAYING DOWN SAME. PREPARING TO P/U BOPE TEST ASSEMBLY&TEST BOPE @ 0600 HRS. TEST WITNESS WAIVED BY JIM REGG ON 12-26-13 @ 12:14 AM. 12/26/2013 -Thursday R/U BOPE TESTING EQUIPMENT. M/U 4-1/2" TEST JOINT WITH TEST PLUG & LAND OUT SAME. TEST ALL BOPE PER AOGCC REGULATIONS.TEST ALL BOPE TO 250 LOW AND 2500 HIGH, CAPTURE ALL TESTS ON CHART FOR 5 MINUTES PER TEST. TEST WITNESS WAIVED BY JIM REGG ON 12-26-13 @ 12:14 AM. R/D TEST EQUIPMENT& PREPARE TO P/U 4-1/2" HYDRIL 503 TUBING. P/U &TIH WITH 64 JOINTS OF 4-1/2" HYDRIL 503 TUBING & (1) 15' X-O PUP JOINT. TOTAL OF 64 JOINTS & (1) 15' PUP = 2030.42'. INSTALL 13-5/8"TUBING HANGER WITH BPV& LANDING JOINT. LAND OUT HANGER & RUN IN LOCK DOWN PINS. R/D TONGS, POWER SWIVEL, WIND WALLS, WINTERIZATION TARPS, CLEAR SUBS& EQUIPMENT FROM RIG FLOOR. RIG DOWN & REMOVE RIG FLOOR. PREPARE DERRICK TO HALF MAST FOR BOP REMOVAL WITH CRANE. 12/27/2013 - Friday CONTINUE R/D RIG FLOOR & PREPARING TO HALF MASS DERRICK TO N/D BOP'S WITH CRANE. REMOVE FLOOR FROM DERRICK. ATTEMPT TO HALF MASS DERRICK WTH NO SUCCESS. LOAD OUT 3-1/2" PH-6 WORKSTRING ONTO M/V RESOLUTION. BEGIN BREAKING DOWN STUDS ON BOP'S& RISER TO REMOVE WITH RIG BLOCKS& R/U LINES. N/D 13-5/8" HYDRIL, BOP'S, MUD CROSS, & RISER, LAY OUT SAME ON PRODUCTION PIPE RACK. INSTALL 5000 PSI PRODUCTION TREE WITH 13-5/8" UNIHEAD ADAPTOR FLANGE. N/U SAME. TEST TREE TO 5000 PSI. R/D RIG PUMP, FLUID HOSES, ACCUMULATOR & BOP LINES WHILE WAITING ON MECHANIC. CONTINUE RIGGING DOWN WINTERIZATION & MISC. EQUIP. oF ,�\\I%%s9 THE STATE Alaska it and Gas "' �fALAs�� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS ,t � Main: 907.279.1433 '� 4 Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer A �, Hilcorp Alaska, LLC 1 C�?'5`' 3800 Centerpoint Drive, Suite 100 t Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Middle Kenai G, West Foreland Oil Pools, K-25 Sundry Number: 313-507 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 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 P. oerster Chair, Commissioner DATED this Z-s day of September, 2013. Encl. 0 A ,tMV F , w: 4-d STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION bI-s 9(2/S) 1 3 APPLICATION FOR SUNDRY APPROVALS ` t.. 1 -- 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program El Suspend❑ Plug Perforations❑ Perforate p Pull Tubing p Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Complete/ESP p 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. -?I► 0 Hilcorp Alaska,LLC Exploratory ❑ Development p , V4iø — /85- CD. 4i\IM 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20180-01 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A ' <, S Will planned perforations require a spacing exception? Yes ❑ No ❑ Tradi�g'ea Unit/ 5 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730- McArthur River Field/Hemlock Oil,Middle Kenai G,West Foreland Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 14,325 • 9,657• 13,442 • 9,139 • N/A 13,442(fill) Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,997' 13-3/8" 1,997' 1,996' 3,090 psi 1,540 psi Intermediate Production 12,373' 9-5/8" 12,373' 8,538' 6,870 psi 4,750 psi Liner 7,828' 7" 14,323' 9,657' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 4-1/2" 12.6#/L-80 6,226 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SC 1 Pakcer and SSSV:N/A N 8,545'(MD)6,426'(ND)and N/A 12.Attachments: Description Summary of Proposal p . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch C - Exploratory ❑ Stratigraphic❑ Development El Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/15/2013 Commencing Operations: Oil p • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature ,,.•1 d';7 G-""1/4--- Phone (907)777-8420 Date 9/20/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3‘.3 —5 cf-c Plug Integrity ❑ BOP Test V p Ies- }'Mechanical Integrity Test CI Location Clearance ❑ Other: -I( Z5-00 /'5[. ,.v 1 RBDMS OCT 10 I4J Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: /6- y 0 l APPROVED BY Approved by: /9 COMMISSIONER THE COMMISSION Date: 5 /3 RSubmit Form and q �\b Form 10-403(Revised 10/2012) Approve plfcati n v li r 2 hs from the date of approval. Attachme in Dupli e f�� II • • Well Work Prognosis Well: K-25 Hilcorp Alaska,LLC Application Date: 09/20/2013 r sue' SN^ Well Name: K-25 API Number: 50-733-2018-01 Current Status: Oil Producer(SI) Leg: Leg#4 (NW corner) Estimated Start Date: October 15,2013 Rig: Moncla Rig 404 Reg.Approval Req'd? 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 185-078 First Call Engineer: Ted Kramer Office: 907-777-8420 Cell:985-867-0665 Second Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: (907)398-9904 AFE Number: Budgeted Cost: Status: Shut In ESP Producer Objective: Pull ESP Completion, remove packer and screen,Clean out to PBTD(14,282). Perforate G-Zones 1 through 5 and 7,and Hemlock Zones 1, and 3 through 7. Re-run ESP with screens mounted below the ESP for coal mitigation. Brief Well Summary: The K-25 well is a Shut In ESP producer.The ESP failed in this well in June 2012 and was not replaced. Prior ESP failures were due to coal being produced in the well fluid which blocked the pump intake,starving the pump. This well was last worked over in July 2011. During this workover a packer with a screen mounted below it was installed in the 7" casing liner at 8545'. The workover plan involved removing this screen set up and cleaning out the well and look�g or a possible casing leak The first option is to locate the leak and repair it. The ESP will then be re-ran with a screen mounted below the ESP on a shrouri to nreven*Ge,i from entering the pump. Current BHP: 3,861 psi @ 13,212 MD(9,010 ND) From 2009 Redoubt pressure buildup. Max.Expct'd BHP: 3,861psi @ 13,212 MD(9,010 ND) Max.Anticipated Surface Pressure: 0 psi Well will not flow based on an expected oil and water gradient of.437 psi/ft. Procedure: 1. Move In and Rig up Moncla 404 Pulling unit. 2. Pump through ESP to circulate hydrocarbon off the well to production 3. ND Wellhead, NU bop and test to 250 psi low/ 2,500 psi high according to the attached BOP Test Procedure— Attachment # 1 (Note: Notify AOGCC 24 hours prior to conducting BOP test to allow them the opportunity to witness). 4. POOH with tubing string and ESP pump laying down the same. '. 5. PU Workstring. RIH with 9-5/8"clean out assembly to 6,495'. POOH with same. - 6. PU 7" 29#C/O assembly and RIH cleaning out 7" casing to top of the SC-1 Packer at 8,545'. POOH with Cleanout assembly. 7. PU,RIH with SC-1 retrieving tool. Latch into packer and POOH with packer,screens and slotted liner.- . PU 7" 29#C/O assembly and RIH cleaning out 7"casing to PBTD(14,282').• �SQC� s� r—l8 9. Change hole to clean fluid, PU TCP guns and RIH with same. . L— 'P �5' GAS i /' 10. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. Fire Guns. • 5.e'} , 11. Pick up guns above perforations. Shut down(+/-)1 hour monitoring fluid level with Echometer. 7 k0 12. Once the well is stable, POOH with TCP guns. 9•Zti O Y G� 13. RU Schlumberger, MU, RIH with ESP Assembly, capillary lines, and ESP electrical cable with Screens on bottom to V(-0't/ 6,445'. 14. Hang off tubing. ND BOP,NU wellhead and test. 15. Turn Well over to production 16. RDMO Moncla 404 Pulling unit. . • • Well Work Prognosis Well: K-25 Hilcorp Alaska,LLC Application Date: 09/20/2013 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(No Change) 4. BOP Drawing • • King Salmon Platform ' . 14 SCHEMATIC Well No. K-25 As Completed: 7/1/11 Hilcorp Alaska,LLC CASING DETAIL RKB to TBG Head=35' SIZE WT GRADE CONN ID TOP BTM. Tree connection: 13-3/8" 61 K-55 BTC 12.515" Surf. 1997' t 47— L-80 BTC 8.681" Surf 7903' to i a, ' Missing N-80 BTC 7903' 10178' 1" 1 J 9-5/8" Tally guessing S-95 BTC 10178' 12373' 2 , order 13 318" 4, 11` 29 L-80 BTC 6.184" 6495' 11001' 011997' S-95 BTC 11001' 12072' 3 7'liner 06/11/08: L-80 BTC 12065' 13274' USIT logs A S-95 BTC 13274' 14323' ran,csg in II B TUBING DETAIL good shape gm w/metal loss 4-1/2" 12.6 L-80 I Hdril 503 I 3.958" Surface 6226' >20%@ C ESP Cable 6350-6480, - -, - D w/(2) 3900,3800& E Chem inj Flat pack w/chem.Inj lines(.75"x.41") Surface 6222' 3500 G`I VI lines 7"Liner Hanger @6,481' JEWELRY DETAIL Split csg 8,400' V2- ' NO. Depth ID Item Est TOC on A 6092' 3.813" XD Sliding shift down to open back side m m of 9-5/8" B 6152' 3.725" "X N"Nipple 3.725"No-Go @10,773' _ C NA ESP motor Assembly 7"Liner Hanger @ 12,049' :;',<1 li D 6274' NA ESP Pump Intake E 6334' NA ESP Pump Assembly&Phoenix XT1 w/Anode 4 6481' NA Baker Model A Simplex liner hanger I I 9 518"@ I Baker Model SC 1 Packer with±450'of screen(4" 12,373' I 5 8545' 4" centralizers OD=5.10'))+Slotted Liner(3'''A")hanging • I LI ■ below.• 5 12049' Baker Model A Simplex liner hanger Top of Packer G-1 - 8545',below : G-2 combination G-3 PERFORATION DETAIL of 4"Screen+ 3'A"Slotted G-4 Zone Top Btm. Condition Liner,bottom G-1 12521 12545 06/06-4-5/8"TCP @ 9076' G-5 G-2 12585 12610 06/06-4-5/8"TCP HB-1 G-2 12625 12645 06/06-4-5/8"TCP HB-2 G-3 12645 12697 06/06-4-5/8"TCP G-4 12787 12840 06/06-4-5/8"TCP G-5 12933 12955 06/06-4-5/8"TCP Clean out depth(6/14/08) G-5 12975 13045 06/06 4-5/8"TCP 13,442' HB-3 02/86-cmt iso.Sq.Perfs(293'-295');3/86-(305'-340'-frac HB1 13293 13340 w/20,000#);9/91-(300'-320'-2-1/8"jet guns);6/06- (293'-318'-4-5/8"TCP) Sq.P 13378 13380 02/86-cmt iso.Sq.Perfs HB-4 HB2 13390 13420 01/88-2-1/8"jet guns;02/90-2-1/8"jet guns 02/86-cmt iso.Sq.Perfs(542'-544');9/90-(556'-586'-2- HB3 13542 13586 1/8"jet guns);9/91-(550'-580'-2-1/8"jet guns);6/06- (525'-550'-4-5/8"TCP) HB-5 3/86-(715'-745'-frac 60,000#);9/90-(650'-680';695'- • ••••• • • ••••• H64 13629 13815 715';770'-800'-2-1/8"jet gun);9/91-(650'-670';710'- •• / 730';780'-800'-2-1/8"jet gun);9/95-(629'-815'-2- 1/8"gun) 9/98 2-1/8"he 4spf PBTD=14,282' TD=14,323' 2/90-(860'900'2-1/8"jetgun);9/91-(860'-900'-2- HB5 13850 13902 1/8"jetgun);9/95-(850'-902'2-1/8"jetgun)9/98 2-1/8" MAX HOLE ANGLE=62° @ 12,100' he 4spf Revised by JLL 09/09/13 H . • Trading Bay Unit . - n King Salmon Platform PROPOSED Well No. K-25 As Completed: Future Hilcorp Alaska,LLC CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=35' 13-3/8" 61 K-55 BTC 12.515" Surf. 1997' Tree connection: 47-Missing L-80 BTC 8.681" Surf 7903' ',"� 9 5/8„ Tally N-80 BTC 7903' 10178' id guessing 4' 5-95 BTC 10178' 12373' order 29 L-80 BTC 6.184" 6495' 11001' ;r4,,, i S-95 BTC 11001' 12072' 7"liner L-80 BTC 12065' 13274' 13 3/8" 4, S-95 BTC 13274' 14323' rep 1997' TUBING DETAIL 06/11/08: 4-1/2" 12.6 L-80 I Hdril 503 I 3.958" Surface ±6224' USIT logs ESP Cable w/ ran,csg in 11 Chem inj line Flat pack w/chem.In]line(.75"x.41") Surface ±6334' good shape w/metal loss >20%@ 6350-6480, -- 3900,3800 JEWELRY DETAIL 3500 NO. Depth ID Item 1 ±6,224' ESP Ea _ 1:11114 7"Liner Hanger 2 ±6,334' Screen i 6,481' Split csg 8,400' .1'1. Est TOG On 11P...t� PERFORATION DETAIL back side s' ,t1:, Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Condition of 9-5/8" j 7'1' G-1 12,521' 12,545' 8,616' 8,631' 06/06-4-5/8"TCP @10,773' ,. '"" .�'"w ,APYm .. G-1 ±12,523' ±12,561' ±8,618' ±8,640' Future i�: q ')' G-2 12,585' 12,610' 8,654' 8,670' 06/06-4-5/8"TCP 7"Liner Hanger t • ' @ 12,049' 2 """ G-2 ±12,599' ±12,624' ±8,663' ±8,678' Future LL 4 G-2 12,625' 12,645' 8,679' 8,691' 06/06-4-5/8"TCP v" G-2 ±12,642' ±12,660' ±8,689' ±8,701' Future a i+ :,, . Ih G-3 12,645' 12,697' 8,691' 8,724' 06/06-4-5/8"TCP '�� G-3 ±12,707' ±12,768' ±8,730' ±8,765' Future 9 518"@a(M G-4 12,787' 12,840' 8,776' 8,806' 06/06-4-5/8"TCP 12,373' :1)...-,*", ,"?{ G-4 ±12,798' ±12,920' ±8,782' ±8,850' Future � „ 6-5 12,933' 12,955' 8,857' 8,869' 06/06-4-5/8"TCP G-5 ±12,944' ±13,064' ±8,863' ±8,929' Future M G-1 G-5 12,975' 13,045' 8,880' 8,918' 06/06-4-5/8"TCP 0-7 ±13,230' ±13,272' ±9,021' ±9,044' Future s G-2 HK-1 ±13,291' ±13,346' ±9,055' ±9,086' Future 1 02/86-cmt iso.Sq.Perfs(293'-295');3/86-(305'-340'-frac w/ M G-3 HB1 13,293' 13,340' 9,056' 9,082' 20,000#);9/91-(300'-320'-2-1/8"jet guns);6/06-(293'-318'-4- G-4 5/8"TCP) Sq.P 13,378' 13,380' 9,104' 9,105' 02/86-cmt iso.Sq.Perfs G-5 HB2 13,390' 13,420' 9,110' 9,127' 01/88-2-1/8"jet guns;02/90-2-1/8"jet guns B G-7 HK-3 ±13,530' ±13,685' ±9,190' ±9,278' Future 02/86-cmt iso.Sq.Perfs(542'-544');9/90-(556'-586'-2-1/8"jet s HB-1 HB3 13,542' 13,586' 9,197' 9,222' guns);9/91-(550'-580'-2-1/8"jet guns);6/06-(525'-550'-4- 5/8"TCP) ME HB-2 3/86-(715'-745'-frac 60,000#);9/90-(650'-680';695'- 715';770'-800'-2-1/8"jet gun);9/91-(650'-670';710'- H84 13,629' 13,815' 9,246' 9,352' 730';780'-800'-2-1/8"jet gun);9/95-(629'-815'-2-1/8"gun) m HB-3 9/98 2-1/8"hc 4spf HK-4 ±13,685' ±13,806' ±9,278' ±9,347' Future 2/90-(860'900'2-1/8"jetgun);9/91-(860'-900'-2- HB 4 H85 13,850' 13,902' 9,373' 9,403' 1/8"jetgun);9/95-(850'-902'2-1/8"jetgun)9/98 2-1/8"hc 4spf HK-5 ±13,852' ±14,021' ±9,374' ±9,475' Future HK-6 ±14,021' ±14,103' ±9,475' ±9,524' Future HB-5 HK-7 ±14,157' ±14,197' ±9,557' ±9,581' Future = HB-6 = HB-7 PBTD=14,282' TD=14,323' MAX HOLE ANGLE=62° @ 12,100' Revised by JLL 09/20/13 II • • King Salmon Platform 2013 BOP Stack(Moncla) 09/19/2013 IIIh9lrp:\1Ieku_LMA. • : '*" 111 Ill 1 III I 1 III Iii 3.74' Shaffer 13 5/8 SM Ill Ill Ill Ill Ill ORM III 1!I III !I I clww-u © �e Variable 2 7/8-5 41111111 13 5/8-5000 iii ..._Blind Rams III III III III III Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses 1 I11 I11 I11 I11 111 ]� ' ' Ill 1 1 1 Ill 1 1 1 III fl IF II I Riser,13 5/8 5M FE X 13 5/8 5M API 413 hub 13.70' it II • King•Salmon Platform K-25 Current 09/19/2013 11 "•,u I. 11;∎,,,.i, 1.1 I King Salmon BHTA, B-11-A0,4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-25 1A-ESP, 13 X 4'/2 BTC lift 24X 133/8X 95/8X 4 1/2 r R ) and susp,w/4"Type H MP INIIIIII MIMI BPV profile, 3/8 cont control line port Valve, Swab,WKM-M, �G c 4 1/16 5M FE, HWO, IA ;. Valve,Wing, OCT-120,4 1/16 5M EE trim � v.z- FE,w/Axelson AM oper, EE trim Valve,Wing,WKM-M, it./ 2 1/16 5M FE, HWO, 1'' } )11 Il AA trim "I'' i .... i Valve, Master, WKM-M, �• ".'�'- 4 1/16 5M FE, HWO, EE '' �� trim mu�•I UI 10.1.r b Void test good _ Valve,Wing,WKM-M,4 1/16 5M 5/12/2010 /1. FE, HWO, EE trim 250/5000psi EL • Adapter, OCT-A5-ESP, 13 5/8 5M_ 4 I1IiiI-■ O API hub X 4 1/16 5M stdd top,w/2- '/2 control line exits, prepped w/OCT 1 -'=1 400-4 pocket V, = 'i1 If 'III , -11 ,• All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M 1111 1111111■ ; 0 2 1/16 5M FE OCT-20, API hub top X 13 3/8 BTC casing 11 �JA': HWO 14 bottom,w/1-2 1/16 5M SSO on iii .. - 4:4 C� lower section, 1-2 1/16 5M SSO MI.. _ -1 on middle section, 3-2 1/16 5M r.► = +:7 Packoff replaced in 2008 SSO on upper section , IP 1 - .1 Q' internal lockpin assy (� I ?� _ter !! _ 15rW�; - i _ �., Valve, OCT-20, 3 1/8 2M Starting head, OCT, 21 '/n 2M r ,� _ �� /. FE, HWO FE X 24" SOW,w/1 3 1/8 2M _ �- '.;..111j I; EFO,full set of lockpins I 24" _ - 113 3/8" J 9 5/8" 4 '/2" • • Moncla Rig 404 BOP Test Procedure riiiro.P Alaska,1.11. Attachment W. Attachment#1 Hilcorp Alaska, LLC- BOP Test Procedure: Moncla Rig 404, King Salmon 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.) • • Moncla Rig 404 BOP Test Procedure $II1 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. • Moncla Rig 404 BOP Test Procedure IIIIeorp u,.kn,i.0 Attachment#1 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 2nd 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. • • Moncla Rig 404 BOP Test Procedure Ilikorp Alaska,I.I.0 Attachment#1 Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion 111,111 I11 I11 111 111 III III 3.74' I'll lil lillil lit IiiI11InI11I!I CPN31 Variable 2 7/a•5 4.67 :666bi _ • 13 S7D 6000 et Blind Rams t1 lLt tiuiiliti II Chose and Kill Valves 21/16 533 w/Un boll connections for �18711r�7 ff1 hoses -_ ---113'4 �F-Y` s t 1 2.00' `11,���f� jl•3 ]IS/8-Saw }I i .+ } �• !IIjI III I!1 Riser,13 5/8 5h1 PE%13 5/8 SM API R13 hub 13.70' � I tk--- • 0 iii Moncla Rig 404 BOP Test Procedure Iliir,.t 1tn<l,n I I: Attachment#1 Diagram B: King Salmon Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ,ball valves Si 2 / I, l 1 Vii ; 1111 IMMO iv li Chokes are 90 degrees off in drawing in order to show detail ! i it s. ril l u . �I t.i. 1 Swaco I it It �r ■ ri I 1 —L--- 1:‘-' .� t N mn .., n1- r. Nimes MIMI - cowl It From Bop Choke Line 2 1/16 5M Uniboll Flange Valve Type #1 National Ball Valve B3260,3%."Ball port,6000psi working pressure #2 National Ball Valve B3260,3'/" 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 82650,2 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 Y:'Ball port,6000psi working pressure #10 National Ball Valve B1560, 1 Vs'Ball port,6000psi working pressure . . = t RIG-.!.:404 /. /I r .-- , FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING. UP TUBING "REVERSE CIRCULATING" STANDPIPE h PANIC UNE • 1- H::0 I I , / - 50P r1 LIN UAL- :: ,-AUTO LIATC •C .7C STACK .11r. MO ICE CHOKE W I i.:• X , o ... - I-1 -I MUD r .11$1171. — Z PUMP IP. 1 PUMP I C\- a MANIFOLD KC P. VALWE 7 x-P LP 0.4 SUCTION II 05713;\1/4 UNE i'M 0 4 FLUID TANKIPIT E el = -CI Oil et "•1 .,... 0 .3=. ..... r, cz L 2. TD1 . ' S 41) 11 Moncla Rig 404 BOP Test Procedure 11111terp Almike,1,1,C Attachment 01 gv 18 X, 0 w I a° :1: ii--1--(,)--1t I :....9 2 _'ILA/ 111 1 -1 Te: 0 V ----,._._ ------7:—-- ■-__......,.._ 0. ....____ 0 P. ( ) CO ( ra..; V* ■ ■ le 5 t-- (I) 0 ■ I 1 X() CD ILI Z + % (7) L 9 o — --- cr ° W A b 0 IT) o 6 __, LL /— LH 1----- V UJ . :3 z 0 S .. :1: 5 o 3 Y 5 ce .5 t- 9 i • _, 0 o x. te. z o 0 z 1) 0 CK i..3 • • SPAITE SEAN PARNELL, 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 August 30, 2011 Mr. Chris Myers Field Superintendent Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 RE: No -Flow Verification Trading Bay Unit K -25 `011 McArthur River Field PTD 1850780 Dear Mr. Myers: On August 15, 2011 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a "no flow test" of Trading Bay Unit K -25 located on the King Salmon Platform in Cook Inlet. The well is operated by Union Oil Company of California (Union). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that Union verified no obstruction exists in the wellbore. Trading Bay Unit K -25 was monitored 3 hours for flow by opening it to atmosphere through flow measurement equipment with suitable range and accuracy. During the flow monitoring period, the gas flow rate was less than 180 standard cubic feet per hour as recorded on the calibrated flow meter. Total liquid production was less than 1 gallon. The subsurface safety valve must be returned to service if Trading Bay Unit K -25 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska p Alaska Oil and Gas Conservation Commission TO: Jim Regg k [�f6 //( DATE: August 15, 2011 P.I. Supervisor (1 FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector Unocal / King Salmon PLT K -25 5 i 1,} t ;' PTD- 1850780 Trading Bay Unit August 15, 2011: I traveled to Unocal's King Salmon Platform in Cook Inlet to witness a No -Flow Test on well K -25. On my arrival on the platform I met with Unocal Lead Operator Dale Njaa and we discussed the operational details of the test. Mr. Njaa indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Unocal representative Chuck Morris performed the test today in a safe and proficient manner. Well K -25 was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and ,/ liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test. Well K -25 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Unocal's Trading Bay Unit well K -25 on the King Salmon Platform. Well No -Flow Test Data Operator: Union Oil Co. Operator Rep: Chuck Morris/Dale Njaa AOGCC Rep: Jeff Jones Field /Unit/Pad TBU / King Salmon PLT Well: K -25 Time Well Flow : Comments Gas Liquid 7:30 <180 scfh none Start Test 8:00 <180 scfh none 8:30 <180 scfh none 9:00 <180 scfh none 9:30 <180 scfh none 10:00 <180 scfh none 10:30 <180 scfh none End Test Produced to open top container through a new Armor -Flow meter model #3461- 03T0 -13 ser. # 112377 Total liquid produced: less than 1 gallon. Attachments: none RJF 09/19/02 Page 1 of 1 2011- 0815_No -Flow TBU_K -25 jj.xls - ' STATE OF ALASKA ° '` ' � ` ° ALASKA. AND GAS CONSERVATION COMMISSION Mi (, 1 .j ' ii [ REPORT OF SUNDRY WELL OPERATIONS It i i; 3 ` ! � Life. ?: Ft�9fflISSiOfi 1. Abandon U Repair Well 11 Plug Perforations 11 Stimulate U Other U; r „��S4,Repair Alter Casing ❑ Pull Tubing 0 Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 185 -078 ' 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Nujnber: 50- 733 - 20180 -01 ...CO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 (King Salmon Platform) Trading Bay Unit K -25 9. Field /Pool(s): McArthur River Field / Middle Kenai G Oil, Hemlock Oil, West Foreland Oil Pools 10. Present Well Condition Summary: Total Depth measured 14,323 feet Plugs measured N/A feet true vertical 9,657 feet Junk measured 13,442 (Fill) feet Effective Depth measured 13,442 feet Packer measured 8,545 feet true vertical 9,139 feet true vertical 6,426 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,997' 13 -3/8" 1,997' 1,996' 3,090psi 1,540psi Intermediate Production 12,373' 9 -5/8" 12,373' 8,538' 6,870psi 4,750psi Liner 7,828' 7" 14,323 9,657' 8,160psi 7,020psi Perforation depth Measured depth See Schematic True Vertical depth See Schematic Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6 #, L -80 6,240' 4,976' 8,545'MD Packers and SSSV (type, measured and true vertical depth) Baker SC 1 Packer 6,426' TVD N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): ; y ft it! (� q{ N/A evi E AUG 1 6 �Ut$ Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 175 73 1,835 65 70 Subsequent to operation: 594 237 5,518 50 75 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Si r Service ❑ StratigraphicEl Daily Report of Well Operations Y 15. Well Status after work: Oil p Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 16. 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: 311 -160 Contact Amjad Chaudhry 263 -7637 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C._8_ Phone 276 -7600 Date 8/1/2011 Form 10 -404 Revised 10/2010 110Z f 0 my svvatek, Submit Original Only Chevron . ■0 0 rading Bay Unit King Salmon Well No. K -25 ft. Actual Completion Landed 7/1/11 CASING AND TUBING DETAIL GRAD Burs TVD CMT RKB to TBG Head = 35' SIZE WT E CONN ID t Top Btm Btm CMT Top Tr r-e connection: 13 -3/8" 61 K -55 BTC 12.515 3090 Surf. 1997, 1260 sx Good " rtns to surf. it 9 -5/8" 47 — L -80 BTC 8.681" 6870 Surf 7903' 2 ° cmt job Est R k - Missing N -80 BTC 6870 7903' 10178' w /500sx TOC Tally S-95 BTC 8150 10178' 12373' Rtns to surf at guessing 10,773 Likely TOC only at csg split. 13 3/8" order (aa 1997' 7'Iiner 29 L -80 BTC 6.184" 8160 6495 ' 11001' 750 sx —RIH w/NO 06/11/08: 9 S - 95 BTC 9690 11001' 12072' sign cmt on top. USIT 10 A I II ran, csg in good shape ` 1 4 B L -80 BTC 8160 12065 13274' o l' t job So 13,100 w /metal loss 5 -95 BTC 9690 13274 14323' j y- q C intervals 13200' >20% @ onl 6350 -6480, - - 3900, 3800 & E Tubing: ' 3500 4 -1/2" 12.75 L -80 Hdril 3.958" Surf 6240' 503 7" Liner Hanger . ESP Cable Flat pack w/ chem. Inj. lines Surf 6236' Dogleg > 4 /100': @ 6,481' w/ (2) Chem (.75" x .41") 2200'md — 5.28/100ft Inj lines 8500'md 4.52 /100ft Split csg JEWELRY DETAIL 8,400' 2 y! NO. Death4 ID Item 9200'md — 4.39/100ft Est TOC on 111 lip A 6108' 3.813" XD Sliding shift down to open 9500'md - 4.16/100ft back side of 9 - 5/8" It B 6168' 3.725" "X N" Nipple 3.725" No -Go w @10,773' 1 C NA ESP motor Assembly Rotating Hours: � n 7" Liner Hanger 4 A S . D 6289' NA ESP Pump Intake 13 -3/8" Csg — 832 @ 12,049' " r.::?I 3 hrs E 6349' NA ESP Pump Assembly & Phoenix XT1 w/ Anode 1 6481' NA Baker Model A Simplex liner hanger — tested to 1500 : ' 44i 7 7 2 8545' Baker Model SC 1 Packer with f450' of screen (4" centralizers (6/85) OD= 5.10')) + Slotted Liner (3 % ") hanging below. 9 5 /8" Csg 196 hrs "+ 3 12049' Baker Model A Simplex liner hanger 9 5/8" @ 12,373' • Original well drilled out of K- 16(inj) kicked out below the 13 - 3/8" csg. Poor cement • Reason to believe (cannot verify) the 9 - 5/8" was run with 2000' from original K - 16 bond from 12,650' - Top of Packer L G_1 pipe, across the split interval. 12,900' 8545', below G • Suspect the cement job on backside of 7" liner went out through the 9 -5/8" csg split. combination _ G_3 Good of f 4 4" • 8/19/02 l pressure gauges au es with AD - 2. 4" Screen + cement bond 3 ' /2' Slotted — G - • Lost 756 discs from EJ charges during the 09/98 perf job. 13,100' — Liner, bottom _ • Left 2 cannon Clamps, 5 bands and 11 pins in hole.06 /09/08 13.200' @ 9076' • 06/11/08: RU Schlumberger and ran USIT log F/6483' (TOL) to surface on 06/11/08. = HB -1 Casing in good Shape with metal loss >20% at 6350'- 6480', 3900', 3800' and 3500'. No bond any • HB -2 Saw TOC @ 2000'. Ran gyro survey from 6487' to surface . where else in Ran gyro survey from 6487' to surface. the open hole 7" liner. _ HB_3 PERFORATION DATA Clean out Zone Top Btm Condition • depth'6 /27/11) 0-1 12521 12545 06/06.4- 6/8"TCP (8616' -8630' TVD) 13,442' 0-2 12585 12610 06/06 - 4- 6 /8'TCP (8864' -8889' TVD) s HB -4 G -2 12625 12645 06/06 - 4.6/8'TCP (8879' -8691' TVD) G -3 12645 12697 08/06 - 4- 6/8"TCP (8691' -8723' TVD) G-4 12787 12840 06/06.4- 6 /8 "TCP (8776 TVD) G-5 12933 12955 06/06 - 4- 6 /8"TCP (8866' -8868' TAD) T HB -5 G-5 12975 13045 06/06 - 4- 6/8'TCP (8879'-8918' TVD) HB1 13293 13340 02 /86 -emt Iso.Sq.Perfs (293'-296');3/86 - (306'- 340' -frae w/ 20,0008); 9/91 - (300'•320'•2.1/8" jet '.'.'. .'.- guns); 6106 -( 293 ' - 318'- 4- 6/8 "TCP)(9066' -9081' TVD) Sq. P 13378 13380 02 /86 -emt Iso.Sq.Perfs (9103' -9104' TVD) HB2 13390 13420 01/88 - 2 -1/8" Jet guns; 02/90- 2 -1/8" Jet guns (9109'-9126' TVD) PBTD = 14,282' TD = 14,323' HB3 13542 13586 02 /86 -cmt Iso.Sq.Perfs (642'-644');9190 - (658' - 586'- 2 -1/8" jet guns);9/91. (660' -680'- 2 -1/8" Jet MAX HOLE ANGLE = 62° @ 12,100' guns);8 /08 -( 626 '•660'- 4- 6/8"TCP)(9198' -9221' TVD) H64 13629 13815 3186 -( 715'- 745' -frac 80, 000 10;9190 -( 850'- 880'; 695'-715'; 770'- 800' -2 -118" jet gun);9191 -( 850'- 670';710'- 730 ;780'- 800' -2- 118" jet gun);9195- (829'- 815' -2 -118 "gun) 9/982-1/8 he 4spf (9245' -9351' TVD) HB5 13850 13902 2/90 -( 860' 900' 2- 1 /8"jetgun);9/91- (660'-900'-2- 1/8"jetgun);9/95- (860'- 902'2 -1/8' Jetgun) 9/98 2 -1/8" K -25 Actual Schematic 2011.doc he 4spf (9372' -9403' TVD) 06/16/11 AC Chevron • • IMO Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K -25 TRADING BAY UNIT K -25 ADL0018730 5073320180 AR4405 100.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 6/18/2011 7/6/2011 Work Over (MRWO) • Primary Wellbore Affected Wellbore UWI Well Permit Number K -25 507332018001 1850780 D uy Operatton8 • '6/17/2011 00:00 - 6/18/2011 00:00 Operations Summary RU Slickline. Pressure test luibricator to 250psi low /2400psi high. RIH w/3.79" GR to 6204'. P0011. RIH and set w /cat standing valve and set in XN nipple @6201'. POOH w /Slickline. Bob Noble of AOGCC waived witness of upcomming BOP test. 6/18/2011 00:00 - 6/19/2011 00:00 Operations Summary RIH w /shifting tool, shifted SS, no clear indication that the SS is open. pump down tubing, pressure tested tubing to 1500 PSI for 10 minutes. RD slickline. RU Eline, Pressure test lubricator 250psi low /2500psi high, RIH with tubing punch and punch tubing 6,155' to 6,200', POOH. Circulate well. RD WL unit and move the same, make preparation to set BPV and ND tree. 6/19/2011 00:00 - 6/20/2011 00:00 Operations Summary ND production tree and NU BOPE, MU 4" test JT and started testing, low test good, high test found leack in uni bolt connection on choke. MU &NU the same, double check remaining choke line connections. 6/20/2011 00:00 - 6/21 /2011 00:00 Operations Summary Pressure Tested BOPE with 4" and 4 1/2" test joints 250 PSI Low/ 3000 PSI High, Annular to 250 PSI Low/ 1500 PSI High, LD test jts, pumped sized salt — pill. 6/21/2011 00:00 - 6/22/2011 00:00 Operations Summary Monitor well, pull tubing hanger, mix & pump second sized salt pill, tubing packed off, Toss rate decreased , began POOH w/ 4 -1/2" ESP tubing completion. 6/22/2011 00:00 - 6/23/2011 00:00 Operations Summary POOH 4 1/2" Completion equipment, LD ESP, Monitor well, RU Slickline, RIH w /5" Guage Ring w /junk basket, Tag @ 9037', POOH junk basket full of coal, RD Slickline monitor well, prepare top run, cleanout BHA. 6/23/2011 00:00 - 6/24/2011 00:00 Operations Summary Continue RIH w /cleanout assembly on 4 1/2" L80, 12.6# , tubing and 4" DP to 6520'. 6/24/2011 00:00 - 6/25/2011 00:00 Operations Summary Continue RIH w /6" CO assembly, RIH to 9660' broke circulation, started washing down. 6/25/2011 00:00 - 6/26/2011 00:00 Operations Summary Circuilate well, continue RIH to 13442',pumped sweep. 6/26/2011 00:00 - 6/27/2011 00:00 Operations Summary Circulate and condition while working pipe, started POOH to BHA, Notified AOGCC of upcomming BOP test. 6/27/2011 00:00 - 6/28/2011 00:00 Operations Summary LD BHA, Pulled Wear Ring, tested BOPE with both 4 1/2" & 4" test joints.250 psi low/ 3000 psi High. BOPE witness waived by AOGCC Jeff Jones . —� Begin running filter assembly (combination of 4" screen+ 3 1/2" Slotted liner on Packer and set in 7" Liner) 6/28/2011 00:00 - 6/29/2011 00:00 • Operations Summary Continue TIH w /screen and slotted liner assembly to 8545', test lines to 5000 psi, set packer © 8545', bottom of 4" screen and 3 -1/2 "Slotted Liner @ 9,076', Started P0011. 6129/2011 00:00 - 6/30/2011 00:00 Operations Summary Continue POOH to 4 1/2" ,L80, 12.6# Tubing to BHA, LD BHA, PU and MU ESP assembly 6/30/2011 00:00 - 7/1/2011 00:00 Operations Summary Continue PU ESP assembly, PU and MU XN nipple and SS, started TIH with 4 -1/2 ", L80, 12.6# tubing, performed meg test every 1000' 7/1/2011 00:00 - 7/2/2011 00:00 Operations Summary RIH w /last 4 stands. MU tubing hanger and dress the same. Land hanger, ESP pump intake @ 6,289', bottom of ESP assembly @ 6,349', begin ND of BOP Equipment. 7/212011 00:00 - 7/3/2011 00:00 Operations Summary Continue ND BOPE. NU Tree and test to 5,000 psi, turn well over to production. • • Aubert, Winton G (DOA) From: Aubert, Winton G (DOA) ' S - 0 7� Sent: Monday, June 27, 2011 12:55 PM To: 'Bonnett, Nigel (Nigel.Bonnett)' Subject: RE: TBU K -25 ; PTD 185 -078 ; Sundry Number : 311 -160 : Additional Work Scope Mr. Bonnett, Your proposed change to Sundry No. 311 -160 (TBU K -25, PTD 185 -078), as described below, is hereby approved. All other sundry approval stipulations apply. Winton Aubert 3 0,4 AOGCC 793 -1231 From: Bonnett, Nigel (Nigel.Bonnett) [mailto:Nigel.Bonnett @chevron.com] Sent: Monday, June 27, 2011 12:08 PM To: Aubert, Winton G (DOA) Cc: Chaudhry, Amjad [Swift Technical Services]; Tyler, Steve L; Nienhaus, Doug R; Fouts, Tom [EMC Engineering]; Martin, J. Hal Subject: TBU K -25 ; PTD 185 -078 ; Sundry Number : 311 -160 : Additional Work Scope Mr. Aubert, On retrieving the failed ESP from K -25, the pump intake was discovered to be heavily plugged with formation debris. Consequently, we propose to run a 7" SC -1 packer assembly with 13 joints of 3 -1/2" slotted pipe / 4" sand screen, set at - 8500 ft MD, to act as a filter for the ESP. Enclosed is an updated proposed wellbore schematic for TBU well K -25. With reference to the AOGCC approved sundry 311 -160, after step 13 the following operational sequence will occur :- • PUMU filter assy (7 joints of 3 -1/2" slotted pipe, 6 joints of 4" Bakerweld screen plus 1 joint of 4" tubing) and Baker SC -1 packer. • Run packer & filter assy on DP to - 8500 ft MD. • Drop setting ball & hydraulically set packer. • Release running tool & POOH. Proceed with Step 14 of approved Sundry. I request your approval for the outlined changes to the TBU well K -25 Sundry No. 311 -160. Regards, Nigel Nigel Bonnett • • Drilling Engineering Manager MCA SBU - Alaska Chevron North America Exploration & Production 3800 Centerpoint Drive Suite 100 Anchorage, Alaska 99503 Telephone (direct) : (907) 263 7853 Mobile : (907) 350 6267 Facsimile : (907) 263 7884 E -mail: nigel.bonnett(u�chevron.com 1 Chevron • • 111110 Trading Bay Unit Ki Salmon Well No. K -25 I N O Proposed Completion ( ■SING :1vn 11. 11NC 1)1.1. All. CR: I) Burs TVD ( \I 1 RKB to TBG Head = 35' slzl: 11T E CONN In t Top Brm Btn1 c11T T Tr connection: 13 -3/8' 61 K -55 BTC 12.515 3090 Surf. 1997' 1260 sx Good rtns to surf 1 9 -5/8" 47 - L-80 BTC 8.681" 6870 Surf 7903' 2" ' out job Est Missing N -80 BTC 6870 7903' 10178' w /500sx TOC 2 Tally S -95 BTC 8150 10178' 12373- Rtns to surf at guessing 10,773 133/8 I . ) order ' 11997 7'liner 29 L -80 BTC 6.184" 8160 6495' 11001' 750 sx -RIH w/JO 3 g: S -95 BTC 9690 11001' 12072' sign cmt on top. USIT lo USIT logs A csg split. only at ran, csg in good shape B L -80 BTC 8160 12065' 13274' l' job no 13,100 ' t w/metal loss C S-95 BTC 9690 13274' 14323' joy 2 � a s9 intervals 13200' >20% @ onl 6350 -6480, D Tubin x 3900, 3800 & E g' L ` x 3500 4 -1/2" 12.75 L -80 Hdril 3 Surf 6226 503 ►tel ►""`` 4 151' Cable Surf 6222' - Dogleg > 4 /100': 9 7" Liner Hanger Flat pac k rr/ chem. Inj . lines �/ 2 cl 'm @s,asr (.75" x.al 1 2200 d — 5.28 /100ft ' lines 8500'md — 4.52/100ft Split csg JEWELRY DETAIL moo' 44 r No. Dcprh 11) 9200 - md — 4.39/100ft Item 9500'md - 4.16 /100ft Est TOC On ' 4 1 ±2400' 3.833" GI A1 4 -1/2" SFO -2 GI.11 R2 rd RK Latch (Dummc) back side, Es t/ 2 ±450(1' 3.833" (:1.11 4 - 1/2" SFO - 2 (:111 R2 w/ RK Latch (Dummy) 1 of 9 - 5/8 ' 1 .,� @10 773 ", - ' 1. 3 ±55(10' 3.833" 61.11 4 -1/2" SF0-2 (1.11 R2 w/ RK Latch (Dummy) Rotating Hours: .: 4 13 -3/8" Cs — 832 hrs 7" Liner Hanger I k ' 4t "°, �;1 1 ±610 ? ' 3.813 CD Sliding shift down to open g Q 12,049' , 07. ►� "" tested to 1500 (6/85) 11 ± 3.725' "X N" Nipple 3.725" No -Co 9 -5/8" Csg — 196 hrs = ;' rf • ( ' N,1 ESP motor ,tsscmb■ 7 Casing — hrs 1igi '. # " ,< ;x� 1) ±6 276' NA ESP Pump Intake > .1a*4- 9 5/8" @ S� e h 1f. N:1 ESP Pump Assembly & Phoenix XTI rr /:Anode T{, 12,373' , -„,,.; 4 6481 NA Baker Model A Simplex liner hanger ,x x. ; S5( U 1 Baker Model S( I Packer with 450 of screen (4') Slotted w ,-.,`.. .,,�*, liner (3 ; I haugmt bclmc. Poor cement 5 12049' Baker Model A Simplex liner hanger bond from G -1 12,650' — Top of Packer _ G 2 • Original well drilled out of K- 16(inj) kicked out below the 13 -3/8" csg. commbbinaati 12,900' co below G-3 o • Reason to believe (cannot verify) the 9 -5/8" was run with 2000' from original K -16 — Good of 4" Screen + pipe, across the split interval. cement bond 3 slotted G -4 13,100'— Liner • Suspect the cement job on backside of 7" liner went out through the 9 -5/8" csg split. 13.200' G -5 • 8/19/02 lost pressure gauges with AD -2. HB - 1 • Lost 756 discs from EJ charges during the 09/98 perf job. No bond any HB -2 • Left 2 cannon Clamps, 5 bands and 11 pins in hole.06 /09/08 where else in ��,� • 06/11/08: RU Schlumberger and ran USIT log F/6483' (TOL) to surface on 06/11/08. the open Casing in good Shape with metal loss >20% at 6350'- 6480', 3900', 3800' and 3500'. hole 7" liner. Saw TOC @ 2000'. Ran gyro survey from 6487' to surface. HB - 3 Ran gyro survey from 6487' to surface. Clean out Pi[RFORA I ON DAT 1 depth'6 /14/08) Zone Top Btm Condition 13,440' G -1 12521 12545 06/06 - 4 -6/8 "TCP HB -4 6-2 12585 12610 06/06 - 4.6/8 "TCP 6-2 12625 12645 86/06.4 -6/8 "TCP G -3 12645 12697 06/06 - 4 -6/8 "TCP G-4 12787 12840 06/06 - 4 -6/8 "TCP HB - 5 6-5 12933 12955 06/06 - 4 -6/8 "TCP 6-5 12975 13045 06/06 - 4 -6/8 "TCP HB1 13293 13340 02 /86 -emt iso.Sq.Porfs (293'- 296');3/86 - (306' - 340' -fr•e w/ 20,000#); 9/91 - (300'- 320'-2 -1/8" jet r- guns);6 /06- (293'- 318' -4 -6/8 "TCP) Sq. P 13378 13380 02 /86 -emt iso.Sq.P.rf HB2 13390 13420 01/88 - 2 -1/8" jet guns; 02/90- 2 -1/8" jot guns PBTD = 14,282' TD = 14,323' HB3 13542 13586 02 /86 -emt iso.Sq.Porfs (642' - 644');9/90 - (666'- 686'- 2 -1/8" jot guns);9 /91- (660'- 680'- 2 -1/8" jet MAX HOLE ANGLE = 62° @ 12,100' euns);6 /06 (626'- 660' 4 -6/8 "TCP) HB4 13629 13815 3/86- (715' - 745' -frac 60,0008);9/90-(650'.680%695 jet gun);9/91- (650'-670';710' - 730';780' - 800' -2- 1/8" jet gun);9/95- (629'- 815' -2 -1/8 "gun) 9/98 2-1/8" he 4spf K -25 Proposed Schematic MOC 02_06- 16- 2011.doc HB5 13850 13902 2/90 -(860' 900' 2- 1 /8 "jotgun);9 /91 -( 860'- 900' -2.1/8 "jotgun );9/96 - (860' - 902'2 -1/8 "jotgun) 9/98 2 -1/8" 06/16/11 AC he 4spf • Regg, James B (DOA) Page1of2 PH) 1C S —G"76 From: Newell, Jack R. [Swift Technical Services] [JNewell @chevron.com] g� ,/ � � (�� Sent: Thursday, June 23, 2011 12:52 PM / To: DOA AOGCC Prudhoe Bay Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett) Subject: AOGCC BOP Closure Notification / H2S Alarm Notification This Message is sent in Behalf of Chevron Drilling Superintendent, Doug Nienhaus Date June 21, 2011 Time of BOPE Use / (H2S Alarm) JUN 4 2 . 0 - 2045 hours Well/Location/PTD Number Trading Bay Unit K 25/King Salmon Platform /185 - 078 Rig Name CUDD #136 Operator Contact Sloan Sunderland, Drill Site Manager Cell 907 230 7262 Doug Nienhaus, Drilling Superintendent Office 263 -7840 Cell 907- 223 -6947 Operations Summary, including events leading up to BOPE use Approximately 20:45 hours June 22, 2011 the rig system H2S (20 PPM) alarm had triggered a BOP closing event on Well K -25 on the King Salmon platform. The blind rams were closed @ 2045 hours to secure the well. There were no comple tion or workover components across BOP stack at that time. Crews mustered and individual H2S meters were taken to area of the bell nipple (place of alarm) to test for H2S. The handheld meters calibrated for H2S indicated '0 p Q (B PPM in the area. The volume beneath the blind rams still closed was tested and ° O P rt^ indicated . The H2S sensor was examined and no damage indicated, checked proper calibration. Crews resumed operations, blind rams were opened, continued monitoring, no indications of H2S. 6/23/2011 • Page 2 of 2 BOPE Used 13- 5 /80$B!I ❑(B Blind Rams Reason for BOPE Use H2s alarm at bell nipple. Actions Taken / To Be Taken (including the date used BOPE was tested) Check for flow, Well still taking 15 BPH. Last BOP test date 6/20/11 Jack R Newell I $B! J ] (B L] $B! I ❑ (B jnewell @Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel 1 907 263 -7832 Fax 1 866 401 0624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7832. 6/23/2011 • • sirofE [F ELAsIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg -/ � Drilling Manager V(6 5 Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU K -25 Sundry Number: 311 -160 Dear Mr. Brandenburg: , 1 „ Enclosed is the approved Application �ry Approval relating to the above referenced well. Please note the',:lea �ons 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, Daniel T. Seamount, Jr. Chair DATED this' day of May, 2011. Encl. . wttyh iiiLe tl loll 0 ctiA6,t, 5, II/. RECEIV STATE OF ALASKA tAAY 0 4j1'i ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Afa2ka oil 8 ;, c ons. G omm i sskpa 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ chan ogram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Esp Repair El • 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development 0 . Exploratory ❑ 185 -078 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20180 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El TRADING BAY UNIT K -25 , 9. Property Designation (Lease Number): 10. Field /Pool(s): McArthur River Field/ Middle Kenai G Oil and Hemlock Oil Pools ADL0018730 (King Salmon Platform) 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): 14,323. 9,657 , 13,440 9,138 N/A 13,440' (fill) Casing Length Size MD / TVD Burst Collapse Structural Conductor Surface 1,997' 13 -3/8" 1,997' 1,996' 3,090psi 1,540psi Production 12,373' 9 -5/8" 12,373' 8,538' 6,870psi 4,750psi Liner 7,828' 7" 14,323' 9,657' 8,160psi 7,020psi Perforation Depth MD (ft): ( / Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,521 - 12,545, 12,585 - 12,610, 8,616 - 8,630, 8,654 - 8,669, 8,679- 4 - 1/2" 12.75# L - 6,234' 12,625 - 12,697, 12,787- 12,840, 8,723, 8,775 - 8,805, 8,856 - 8,868, 12,933 - 12,955, 12,975- 13,045, 8,879 - 8,918, 9,055- 9,081, 9,103- 13,293- 13,340, 13,378- 13,380, 9,104, 9,109 - 9,126, 9,196- 9,221, 13,390- 13,420, 13,542- 13,586, 9245- 9,351, 9,372 -9,403 13,629 - 13,815, 13,850 - 13,902 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): N/A and N/A N/A and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 15- Jun -11 Commencing Operations: Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263 -7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature e''' '.---- i Phone 276 -7600 Date 5/6/2011 t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 511-t 0 O Plug Integrity 0 BOP Test [V] Mechanical Integrity Test El Location , . Location Clearance Other: re Yctw- 1j OPE 4 3 000 yLi� *�5� c44,„„_,4,144„ lopE fO 1800 to - Subsequent Form Required: t O — q 0 c.{ , / APPROVED BY 7 Approved by: / COMMISSIONER THE COMMISSION Date: S 1 Z G DM , -n V �j Form 10 403 Revised 1/2 MA Y 1 2 291 RIG 1 N A L Submit in Duplicate Chevron Trading Bay Unit 1111 110 K -25 5 -6 -2011 Objective: • Pull current ESP completion; re -run new 4 -1/2" ESP completion with Gaslift mandrels. Current BHP: 3780 psi @ 8882' TVD 8.1 ppg EMW Maximum BHP 3780 psi @ 8882' TVD 8.1 ppg EMW (Based on previous actual Phoenix Reading) Current water cut is 93 % MASP: psi (based on actual reservoir conditions and water cut of 93% (0.432psi /ft) with added Sa Factor of 1000' TVD of oil cap) Procedure Summary: 1. MIRU HWO unit. 2. RU Wireline. Pressure test lubricator 250psi Low/ 3000psi High. /' 3. RIH w/ 3.5" GR to drift tubing to top of pump ±6235' D. 4. PU RIH 4 -1/2" CAT standing valve and place in XN profile at 6201' MD. 5. Shift sliding sleeve @ 6186' MD or punch holes in tubing © ±6141' MD. 6. RD Wireline. 7. Circulate wellbore with 3% KCL -FIW (filtered inlet water). 8. Spot sized salt bridging pill as necessary. 9. ND tree. NU and test BOPE. 250psi Low/ 3000psi High, Annular 250psi Low/ 1500psi High. 10. Recover 4 -1/2" completion and ESP assembly. 11. RU Slickline, RIH w/8.5" gauge ring w /junk basket to TOL © 6,481'MD. POOH. 12. RIH w/ 5" gauge ring w /junk basket to ±13,440' MD and POOH. Contingency: (If tag above +/- 13,390') RIH with work string and cleanout fill to ±13,440' MD. 13. RD slickline. 14. RIH 4 -1/2" 12.75# L -80 ESP and GLM completion w/ pump intake set at depth ±6,276' MD. 15. ND BOPE. NU and test tree. 250psi Low/ 5,000psi High 16. Secure and turn well over to production. 17. Rig down HWO unit and release HWO unit. 05/6/2011 AC Chevron %. • 'trading Bay Unit King Salmon Well No. K -25 %. Proposed Completion CASING AND TUBING DETAIL Burs TVD CMT RKB to TBG Head = 35' SIZE WT GRADE CONN ID t Top Btm Btm CMT Top Tree connection: 13 -3/8" 61 K -55 BTC 12.515 3090 Surf. 1997' 1260 sx Good 1I rims to surf. 1 9 -5/8" 47 - L -80 BTC 8.681" 6870 Surf 7903' 2" cmt job Est Missing N -80 BTC 6870 7903' 10178' w /500sx TOC at 2 Tally S -95 BTC 8150 10178' 12373' Rtns to surf 10,773 guessing 133/8" , l II I order 1997' 3 7 'liner 29 L -80 BTC 6.184" 8160 6495' 11001' 750 sx-R11-1 w/NO sign 06/1 1/08: S -95 BTC 9690 11001' 12072' cmt on top. Likely U SIT logs TOC only at csg split. ran, csg in A L -80 BTC 8160 12065' 13274 1" job no 13,100 O good shape _ B S -95 BTC 9690 13274' 14323' joy. 2° sq ' w /metal loss intervals 13200' >20% @ 1- c only 6350 - 6480,• D Tubing: 3900, 3800 & E '4-•: 4 -1/2" 12.75 L-80 Hdril 3.958" Surf 6226' • 3500 503 iiiiiK4 ESP Cable Flat pack w/ them. Inj. lines Sub ""/ Dogleg > 4 /100': 7" Liner Hanger w /(2) Chem (.75" x .41 ") ✓ 2200'md — 5.28/100ft @ 6,481' inj lines Split csg 8500'md — 4.52/100ft 8,400' JEWELRY DETAIL 9200'md — 4.39/100ft Est TOC on NO. Depth ID it 9500'md - 4.16/100ft back Side 4 1 +2353' 3.833" GLM 4 -1/2" SFO -2 GLM R2 w/ RK Latch (Dummy) of 9 -5/8° . @10,773' i 2 ±4000' 3.833" GLM 4 -1/2" SFO -2 GLM R2 w/ RK Latch (Dummy) Rotating Hours: 7" Liner hanger 3 ±5869' 3.833" GLM 4 -1/2" SFO-2 GLM R2 w/ RK Latch (Dummy) 13 - 3/8" Csg - 832 hrs @ 12,049' i -,� to 1500 "` .r A ±6184' 3.813" XD Sliding shift down to open 6/85 ) B ±6202' 3.725" "X N" Nipple 3.725" No 9 - 5/8" Csg - 196 hrs 7" Casing - hrs ,` C ±6228' NA Reda Pump Assy 9 5/8" @ D ±6276' NA Pump Intake 12,373' E ±6345' NA Phoenix XT1 4 6481' NA Baker Model A Simplex liner hanger Poor cement ill 5 12049' Baker Model A Simplex liner hanger 1 0' - — G 1 • Original well drilled out of K 16 in kicked out below the 13 -3/8" cs 12,850' g ( j) csg. 12,900' — G -2 • Reason to believe (cannot verify) the 9-5/8" was run with 2000' from original K-16 Good —G -3 pipe, across the split interval. cement bond =G -4 • Suspect the cement job on backside of 7" liner went out through the 9.5/8" csg split. 13,100' - 13.200' =G -5 • 8/19/02 lost pressure gauges with AD-2. —HB -1 • Lost 756 discs from EJ charges during the 09/98 perf job. No bond any • Left 2 cannon Clamps, 5 bands and 11 pins in hole.06 /09/08 where else in = HB - 06/11/08: RU Schlumberger and ran USIT log F/6483' (TOL) to surface on 06/11/08. the open Casing in good Shape with metal loss >20% at 6350'- 6480', 3900', 3800' and 3500'. hole 7" liner. Saw TOC @ 2000'. Ran gyro survey from 6487' to surface. =_ HB -3 Ran gyro survey from 6487' to surface Clean out PERFORATION DATA depth'6 /14/08) Zone Top Btm Condition 13,440' G -1 12521 12545 06/0 6 -4 -5/8" TCP -=HBO G -2 12585 12610 08/0 8- 4 - 5/8"TCP G -2 12625 12645 06 /0 6 -4 -5/8 "TCP G -3 12645 12697 06 /0 6 -4 -5/8 "TCP G - 12787 12840 06 /0 6 -4 -5/8 "TCP G -5 12933 12955 06 /06 -4 -5/8 "TCP HB -5 G -5 12975 13045 06/0 6 -4 -5/8 "TCP H B1 13293 13340 02186 -cm t iso.SgPe rts (293'- 295');3/86 - (305'- 340' -frac w/ 20, 0006); 9/91- (300' -320'-2.118 "jet g on s);6 /0 6 -(29 3' - 318' -4 -5/ 8 "TCP ) Sq. P 13378 13380 0286- cm tiso.SgPerts H B2 13390 13420 0188 -2 -18 "jet guns; 02 /9 0- 2 -1/8" jet guns PBTD= 14,282' TD = 14,323' H B3 13542 13586 g un s u2N8- cm );6 /0 -(52 5'- ro. 550' -4 -5 r O'- 4-5 a'- /8 " 2 T 644');9 /9u -IS 56'- 566'- 2 -1/6" jet gu );9/91 - (500' - 550' - - /6 " Jet CP) MAX HOLE ANGLE = 62° @ 12,100' H B4 13 62 9 13 81 5 3/86-)715'- 745' -frac 600004);990 -( 650' - 680'; 695' -715; 770'100'- 2 -18 "IA g1/n);9/91- (650' - 670';710'-730';780' -000' -2- 18"japun);9195.( 629 '-815'- 2.18"8un) 9/982 -18"hc 4spf H B5 13850 13902 2 /90- (860'9 00'2 -18 "jet gun);9 /91- (860'- 900'- 2- 1 /8 "jetgun);9 /95- (850'- 902'2 -18 "jetgun) 988 2 -1/8" he 4spf K -25 Schematic 03- 18- 11.doc 03/18/11 AC Chevron • 1 %0 erading Bay Unit K ing Salmon Well No. K -25 1%0 Completion CASING AND TUBING DETAIL TVD CMT RKB to TBG Head =35' SIZE WT GRADE CONN ID Burst Top Btm Btm CMT Top Tree con tion: 13 -3/8" 61 K -55 BTC 12.515 3090 Surf. 1997' 1260 sx Good nns to surf. 9 -5/8" 47 — L -80 BTC 8.681" 6870 Surf 7903' 2 nd cmt job Est al , Missing N -80 BTC 6870 7903 10178' ' w /500sx TOC at Tally Rtns to surf 10,773 guessing 5 -95 BTC 8150 1017 12373' order 8' 13 3/8" 1997 7'liner 29 L -80 BTC 6.184" 8160 6495 11001' 750 sx —RIH w/NO sign cmt on top. Likely 06/11/08: S-95 only at csg split. USIT logs 5 -95 BTC 9690 1100 12072' 1 ' ran, csg in good shape L -80 BTC 8160 1206 13274' 1 ' job no 13,100 w /metal loss 5' joy. 2n sq >20% @ S -95 BTC 9690 1327 14323' intervals 13200' 6350 -6480, 4' only 3900, 3800 & Tubing: 3500 trr t 4 -1/2" 12.75 L -80 Hdril 3.958" Surf 6234' 4. O Dogleg > 4 /100 7" Liner Hanger p ESP Cable Flat pack w / chem. Inj. lines Surf 6340' @ 6,481' �V 5 w/ (2) Chem ( -75" x .41 ") 2200'md — 5.28/100ft Split csg inj lines 8500'md — 4.52/100ft 8,400' 9200'md — 4.39/100ft Est TOC on i JEWELRY DETAIL 9500'md - 4.16 /100ft back side .. NO. Depth ID Item of 9 -5/8" L . 1 6186' 3.813" XD Sliding shift down to open @10,773' 2 6201' 3.725" "X N" Nipple 3.725" No -Go 3 6235' NA Pressure Head Rotating Hours: 7" Liner Hanger 4 6236' NA Discharge Head 13 -3/8" Csg — 832 hrs *12,049' - 5 6256' NA 68 Stage Reda 538 SN8500 Pump —tested t0 1500 (6/85) 6 6276' NA 68 Stage Reda 538 SN8500 Pump 9 -5/8" Csg — 196 hrs 9 5/8" @ 12,373' L e 7 6283' NA Seal Assembly 8 6338' NA Motor — Reda 450 HP 3137 V/86.5 A j . , 7" Casing — hrs 9 6342' NA Phoenix Sensor XT -1/ Anode /Centralizer (bottom @ 6382') 10 6481' NA Baker Model A Simplex liner hanger _ G- 1 11 12049' Baker Model A Simplex liner hanger Poor cement G - • Original well drilled out of K- 16(inj) kicked out below the 13 3 /8" csg. bend from 12,650' - 12,900' — G - • 13 3 /8" has high rotating hrs. G-4 • Inj test in the 13 3 /8 "x 9 s/8" annulus .(10/25/00). G -5 • Reason to believe (cannot verify) the 9 3/4" was run with 2000' from original K-16 Good cement bond pipe, across the split interval. 13,100' - • Suspect the cement job on backside of 7" liner went out through the 9 %" csg split. 13.200' • 8/19/02 lost pressure gauges with AD HB - • Lost 756 discs from EJ charges during the 09/98 perf job. No bond any where else in HB -2 • Left 2 cannon Clamps, 5 bands and 11 pins in hole.06 /09/08 the open • 06/11/08: RU Schlumberger and ran USIT log F/6483' (TOL) to surface on 06/11/08. hole 7" liner. Casing in good Shape with metal loss >20% at 6350'- 6480', 3900', 3800' and 3500'. H B 3 Saw TOC @ 2000'. Ran gyro survey from 6487' to surface Clean out PERFORATION DATA depth'6 /14/08) Zone Top Btm Condition 13,440' G -1 12521 12 54 5 06/96 -4 -5/8 "TCP = HB G - 2 12585 1261 06,06 - 4 5 /8"TCP G -2 12625 12645 06/96 -4 -5/8 "TCP G -3 12645 12697 06 /96 - 4 - 5 /8"TCP G -4 12787 12 84 0 06/96 - 4 - 5/8" HB - G - 5 12933 12955 06 /96 - 4 5 /8" G -5 12975 13045 06/96 -4 -5 /8 "TCP HB1 13293 13 34 0 02)86- cmtiso.SgPerfs (29 3'-295');3/86-(30 5'-340'-frac wl 20,0004); 9/91- (300'- 320' -2 -1)8 "jet gins); 6 /0 61293%318%4 - 318' -4 -5/8 "TCP ) PBTD = 14,282' TD = 14,323' Sq. P 13378 13380 02/8 6- cmtiso.Sq.Perfs MAX HOLE ANGLE = 62° @ 12,100' HB2 13390 13420 01)88 -2 -1/8 "jet guns; 02/9 0- 2 - 1/8" jet guns HB3 13 54 2 13586 tzR1 cmtlso.SgPerts(542'- 544');9/90 -( 556' - 58 -2 - V 9 " jet guns);9191- (990'- 580'- 2- 1/8"jet gins); 6 /9 6 -(52 5' - 550' -4 -5 /8 "TCP ) H B4 13629 13 81 5 3186( 715' - 745' -frac 60,0001{);990(650' - 680';695'.715; 770800'.2. 118 "jet gun);9'9 - ( 650 ' . 670 - 730 - 1/8 "jet gun);995(629'. 815' -2 -118 "gun) 998 2.118"hc 4spf HB5 13850 13902 2/90- (860500'2- 1)8'jetgun);9 /914860' -900'- 2.1 /8 "jetgun);9 /95 -( 850' - 902' 2- 1 )8 "jetgun) 958 2 -1/8" he 4spf Chevron King Salmon Platform * BOP Stackup 03/14/2011 J King Salmon ------- 2011 ESP Workovers —_ ii-, BOP Drawing K -1, K -13, K -30 iii ii, 111111 u • • 4.54' BOP based on Cudd rental Hydril stack drawing 13 5/8" 5000 me III 11111 1 1 111 III I!I • 4.67' -E— CU — II ' _,_ 1 _4 ® i=1.) lie lip 111 hie 1 1 — — All choke and kill line valves 2 1/16 5M w/ _ 1 19e1'Urllrl 1 2.00' .01110114t:-:. I � I :.' i h unibolt end connections �' .111.111J 1 L � :� O` - , 111 111 up 111 I n 2.83' o f CIW -U 0 hie lie lie lie 111 .70' 111 1.1111 1 13.70' Drill deck Riser 13 5/8 5M FE X135/85MAPI 1 Hub 12.98' 0 0 ° it I ' Au v, /r►� � Q 5.70' X11 11 �':�..; ■.. — 1M1.1. 7 i• .11 ~-~, STATE OF ALASKA ~ ` ~ p~ AL~ OIL AND GAS CONSERVATION CON~SO r,~;~~ REPORT OF SUNDRY WEL OPERATIO~S~~~ ~. _ ~, 1. Operations Abandon Repair Well Plug Perforations Stimulpte _ Other - Re-Run ESP & Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ `Yime Extension^ Clean out Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ Exploratory^ 185-078 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20180-01- 7. KB Elevation (tt): 9. Well Name and Number: 42.9' Trading Bay Unit K-25 8. Property Designation: 10. Field/Pool(s): , Cook Inlet ADL0018730 #25 (King Salmon Platform] McArthur River Field /Hemlock & Middle Kenai G Oil 11. Present Well Condition Summary: Total Depth measured 14,282 feet Plugs (measured) N/A true vertical 9,632 feet Junk (measured) 13,347' (fill) Effective Depth measured 13,648 feet true vertical 9,256 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,997' 13-3/8" 1,997' 1,996' 3090 psi 1540 psi Surface Intermediate 12,373' 9-5/8" 12,373' 8,538' 6870 psi 4760 psi Production Liner 7,828' 7" 14,323' 9,657' 8160 psi 7020 psi Perforation depth: Measured depth: Reference attachment , ~ ,~~q~y n ~$~I\J~lli~l.r t~l~l7 .t ~~ 2U~D True Vertical depth: a Reference attachment Tubing: (size, grade, and measured depth) 4-1/2" L-80 12.75# 6,234' Packers and SSSV (type and measured depth) none none 12. Stimulation or cement squeeze summary: N/A 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: 520 0 7300 75 75 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-197 Contact Chantal Walsh 263-7627 Printed Name Timothy. C. Brandenburg Title Drilling Manager `~ ..- ". .- ~`" Phone 263-7600 Date 7/21/2008 ~ ' Signature Form 10-404 Revised 04/20 6 ~ubmit Original Only ~° Chevron • • Trading Bay Unit King Salmon Well No. K-25 Completion CA SING AND TUBING DETAIL Burs TVD Carr RKB t0 TBG Head = 35' SILE WT GRADE CONK ID t To Btm Btm CMT To T Conn ion: 13-3/8" 61 K-55 BTC 12 515" 3090 Surf 1997' 1260sx Good . . : rtns[o A, t SUrf. 9-5/8" 47 - L-80 BTC 8.681" 6870 Surf 7903' 2"d cmt job Est Missing N-80 BTC 6870 7903' 10178' w/SOOsx TOC at Tally 5-95 BTC 8150 10178' 12373' Rms to surf 10,773 guessin 133/8" order ~ 1997" 7'liner 29 L-80 BTC 6.184" 8160 6495' l 1001' 750 sx-RIH w/NO sign S-95 BTC 9690 l 1001' 12072' cmt on top. Likely TOC onl at cs slit. L-80 BTC 8160 12065' 13274' 1"job no 13,100 5-95 BTC 9690 13274' 14323' JoY 2"n sq ' intervals 13200' 7" Liner Hanger s,a81' Split Csg 8,400' Est TOC on back side of 9-5/8" @10, 773' T' Liner Hanger 12,049' 9 5/8" aLD 12,373' Poor cement bond from 12,650' - 12,900' Good cement bond 13,100' - 13.200' No bond any where else in the open hole 7" liner. Clean out depth'6/14/08) 13,347' 4-1/2" 12.75 L-80 BTC 3.958" Surf 6234' ESP Cable Surf 6340' Flat pack w/chem. Inj. lines w/(2lChem (,75"x.41") j~O~if~ > -I /it)t)': in' line 2200'md - 5.28/100ft JEWELRY DETAIL 8500'md-4.52/100ft NO. De th ID Item 9200'md-4.39/100ft 1 6186' 3.813" XD Slidin shift down too en 9500'md - 4.16/100ft 2 6201' 3.125" "X N" Ni le 3.725" No-Go i F7"25' NA PfPCf11rP FlParl 4 6236' NA Dischar a Head 5 6256' NA Pum Lower 538 Series, SN-29B8A24843 Rotating Hours: 6 6276' NA Pum U er 538 Series, SN-29B8A248436 13-3/8" Csg - 832 hrs 7 6283' NA Seal Assembl tested to 1500 (6/85) 8 6338' NA Motor - 450 HP Model #RA-UT SN-1HB82A24996 - 196 hrs 9-5/8" Cs 9 6342' NA Phoenix Sensor XT-1/Anode/Centralizer (bottom @ 6382') g 7" Casing -hrs 10 6481' NA Baker Model A Sim Iex liner han er ~_ 11 ~ 12049' ~ i Baker Model A Simplex liner hanger ~ G-1 G-2 G-3 G-4 G-5 B-1 B-2 B-3 B-4 B-5 PBTD = 14,282 TD = 14,323 MAX HOLE ANGLE = 62° @ 12,100' • Original well drilled out of K-16(inj) kicked out below the 13-3/8" Csg. • 13 3/a" has high rotating hrs. • Inj test in the 13-3/8"x9-5/8" annulus (10/25/00). • Reason to believe (cannot verify) the 9-5/8" was run with 2000' from original K 16 pipe, across the split interval. • Suspect the cement job on backside of 7" liner went out through the 9-5/8" Csg split. • 8/19/02 lost pressure gauges with AQ2. • Lost 756 discs from EJ charges during the 09/98 erf •ob. PERFOR:1"PION DA"1'A Zone Top Btm Condition G-1 12521 12545 06/06 - 4-5/8"TCP G-2 12585 12610 06/06 - 4-5/8"TCP G-2 12625 12645 08/08.4-5/8"TCP G-3 12645 12697 OB/06-4-5/8"TCP G-4 12787 12840 08/OS-4-5/8"TCP G-5 12933 12955 Os/OS - 4.5/8"TCP G-5 12975 13045 os/os - a-5/a'•rcP H61 13293 13340 02/88•cmt iao.Sq.Perts (283'-295');3188-(305'•340'-(roc w/ 20,000#); 9/91-(300'-320'•2-1/8" jet guns ); 6/O6-(293' -318'-4-518"TCP ) Sq. P 13378 13380 02186-cmt iso.Sq.Perfs HB2 13390 13420 01/68 -z-1/8"jet guns; oz/9o- 2-1/8" jet guns HB3 13542 13586 02188-cmt iso.Sq.Perfs (542'-544');9190 •(556'-588'-2-1/8" jet guns-;9/91-(550'-580'-2-1/8" jet guns);6/06-(525'-550'-4-5/8"TCP) H84 13629 13815 ' ' ' ' ' ' ' " ' ' ' ' ;710 -730 ;780 •800 -2• jetgun);9191-(650 •670 •715 ;770 -800 -2.118 ;695 3186{715'-715'-frac60,000i1);9190-(650'•680 118" jet gun);9195-(629'•815'•2.118"gun) HB5 13850 13902 2/90 9/95-(850'-902'2.1/8"jetgun) 900' 2 1/8"jet un) 9/91 860' 860'900'2 1/8" t ; - - g gun); -( - -( . je 07/17/08 CVK r~ Chevron Chevron -Alaska Daily Operations Summary Well Name K-25 Field Name MCARTHUR RIVER, API/UWI 507332018001 Lease/Serial ADL0018730 CHEVNO AR4405 License No./Prope... 1850780 Orig KB Elev (ftKB) 100.0 Water Depth (ft) ---- Jobs - - _ .T_ Job Cat Type AFE No. -J QC Eng Workover ESP UWDAK-R8016 Datly Operations _ _ _ _ _ 6/4/2008 00:00 - 6/5/2008 00:00 Operations Summary Mobe rig. Notified AOGCC Bob Noble of upcoming BOP test. 6/5/2008 00:00 - 6/6/2008 00:00 Operations Summary Mobe rig. 6/6/2008 00:00 - 6/7/2008 00:00 Operations Summary Mobe rig. Test BOPS, 250 low, 3000 high. Test witnessed by AOGCC Bob Noble. 6/7/2008 00:00 - 6/8/2008 00:00 Operations Summary Circulate well. Pull hanger. Mix size salt pill. 6/8/2008 00:00 - 6/9/2008 00:00 Operations Summary Pump size salt pill. 10 bbls saturated salt spacer, 90 bbl size salt pill, 40 bbl satruated salt spacer. Bullhead into formation. POOH with tubing. LD same. 6/9/2008 00:00 - 6/10/2008 00:00 Operations Summary Continue to POOH with tubing, LD GLM (gas lift mandrel), and ESP equipment. Recover all ESP equipment except 2 cannon clamps, 5 flat bands, and 11 pins. First 2500' of cable megged bad, remaining 4000' OK. Motor checked OK, but oil smelled burnt. 6/10/2008 00:00 - 6/11 /2008 00:00 Operations Summary PUMU clean out BHA. 8-1/2" smooth OD mill, 9-5/8" csg scraper w/ bit sub and XO sub. RIH. CBU (circulate bottoms up) @ 11 bpm. Recover 1 SS band and pins. Tagg top of liner at 6492'. Pump high vis sweep. 6/11/2008 00:00 - 6/12/2008 00:00 Operations Summary POOH laying down tubing, and clean out assembly. RU eline. PUMU USIT/Gyro tools. RIH with same to top of liner at 6487'. Log to surface. 6/12/2008 00:00 - 6/13/2008 00:00 Operations Summary Finish running Gyro log on eline. RD eline. PUMU BHA #2. (6" junk mill, junk basket, & drill collars). PU 4" DP to RIH. 6/13/2008 00:00 - 6/14/2008 00:00 Operations Summary RIH w/ BHA #2 to top of 7" liner. Continue into 7" liner. Upcoming BOP test waived by AOGCC Jim Regg and extension given ti116/15/O8. Continue to work into hole to 12,673' RKB. 6/14/2008 00:00 - 6/15/2008 00:00 Operations Summary CBU 3 times. Continue to RIH to 13,347', attempted to circ and rotate, could not get passed. Pump high vis sweeps. No returns to surface. POOH laying down workstring. 6/15/2008 00:00 - 6/16/2008 00:00 Operations Summary POOH. LD DP. PU and set HES storm packer. Change out 9-5/8" x 13-5/8" packoff. Test 250 psi low/5000 psi high. Good. Test BOPs 250 psi low, 3000 psi high. AOGCC Jim Regg waived witness to BOP test. Pull storm packer and fill backside. 6/16/2008 00:00 - 6/17/2008 00:00 Operations Summary CBU. POOH racking back 4" DP. POOH w/ BHA. Junk mill showed signs of junk along side assembly had been occurring when working down hole. PU 4-1/2" Hydril 503 tbg and rack back. 6/17/2008 00:00 - 6/18/2008 00:00 Operations Summary Finish racking back 503 tbg. PUMU ESP completion BHA. Begin RIH with same. 6/18/2008 00:00 - 6/19/2008 00:00 Operations Summary RIH w/ ESP completion. Land same. ND BOP NU tree. Turn well over to production. 6/30/2008 00:00 - 7/1/2008 00:00 Operations Summary No Flow test performed and passed per lead operator David Myers • • f +`' SARAH PALIN, GOVERNOR ALASKA O~ ~ t> •i~ il `j[A S 333 W 7th AVENUE, SUITE 100 -~,T y~ 7 ~~ ~ ~ 7 T CO1sS~l~QAilO1~ CO~~i1~iiSSIOl` ANCNORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 JUIy 28, 2008 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 ~~t~ld~lE~ JUL ~ ~ 2U0~ RE: No-Flow Verification Trading Bay Unit K-25, PTD 185-078 Dear Mr. Myers: On June 30, 2008 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a "no flow test" at Ilnocal's King Salmon platform, Trading I3ay Unit Well K-25. T'he well was opened to atmosphere through (low measurement equipment with suitable range and accuracy and monitored. During the 3 hour monitoring period, unassisted slow of gas and liquid did not exceed the allowable Ilow rates (900 standard cubic feet per hour gas and 6.3 gallons per hour liquid). Less than 1 cup of liquid was produced to surface during the test. The subsurface safety valve may be removed from service in Well K-25 based on this no- flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platform. Sincerely, /~ ~ :''"7 `~t- (1;'~-~4;~ ; ~~~ ~ ~'lC James B. Regg Petroleum Inspection upervisor ce: Bob Fleckenstein CI7£Vi'Ot1 ~ncisCO Castro Chevron North~rica Exploration and Production ~ ~-~ Technical Assistant AOnchorageh AK 99501 ~`'~'"~y~ Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE 7uly 7, 2008 To: AOGCC Mahnken, Christine R ~ ~ JUG ~ ~~~$ 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 yr ! ~5~ ~~~'~ ; ~~ ~ ~ l~ Please acknowledge>receipt by signing and returning one copy of this transmittal ar FAX to 907.263 7828. 1; r Received By.; ~ ~ ,: ~ __:.--~~ Date: r' ~,~ ,i ~ - WELL LOG TYPE SCALE LOG DATE INTERVAL RUN # B-UNE CD NOTES -LAS, LOGGED PDS, DLIS GRANITE POINT ST 18742 37 USIT 5" 14-Jun-08 200-9874 PS-1 1 1 LAS, PDS PACKER SETTING SCU 436-08 RECORD 5" 9-Jun-08 5746-5940 2 1 1 PDS COMPLETION SRU 34-28 RECORD 5" 1-Jul-08 5940-6228 1 1 1 PDS TBU K-25 USIT 5" 11-Jun-08 200-6463 PS-1 1 1 PDS,LAS • IViEM®I~A~1®l1~V1 TO: Jim Regg ~ 1 P.I. Supervisor ~~~n 11 Z"`' ~7c`'~ 4Q FROM: Jeff Jones >~~+4 JUL ~ ~ ZU~U Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: June 30. 2008 SUBJECT: No-Flow Test Unocal /King Salmon PLT K-25 PTD-1850780 - Trading Bay Unit June 30, 2008: I traveled to Unocal's King Salmon Platform in Cook Inlet to witness a No-Flow Test on well K-25. On my arrival on the platform I met with Unocal Lead Operator Jim Ryan and we discussed the operational details of the test. Mr. Ryan indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Unocal representative Mark Farnsworth performed the test today in a safe and proficient manner. Well K-25 has an electric submersible pump (ESP) installed and was lined up from the tree top swab valve through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and as the data below indicates, well K-25 meets the AOGCC requirements for a No-Flow status determination. Summary: I witnessed a successful No-Flow Test on Unocal's Trading Bay Unit well K-25 on the King Salmon Platform Well No-Flow Test Data Operator: Unocal /Chevron Operator Re Jim Ryan /Mark Farnsworth AOGCC Rep: Jeff Jones Field/[Jnit/Pad TBU /King Salmon PLT WeII: K-25 T,n~e we~a Fi~w omme~ts Gas L' uid 1045 am 200 scfh No significant amount Start Test 1115 am 250 scfh No significant amount 1145 am 250 scfh No si ificant amount 1215 pm 250 scfh No significant amount 1245 pm 200 scfh No significant amount 1315 pm 200 scfh No si ificant amount 1345 m 200 scfh No significant amount End Test Produced to open top container through Armor-Flow mete,- model #3461-03T0 calibrated 6/27/08 Total liquid produced: less than I/2 cup. This well has an ESP (electric submersible pump) installed. Attachments: none CC: Chris Meyers, Wayne Johnson (Unocal) RJF 09/19/02 Page 1 of 1 No-Flow TBU King Salmon PLT K-25 6-30-08 JJ.xls • Page 1 of 1 Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Tuesday, June 03, 2008 2:26 PM To: Maunder, Thomas E (DOA) Subject: K-25 Tom JJ, ~o~~ \~b The current campaign on the King Salmon Platform planned to move from the first two wells, K-19 and K-22 both located on leg 1, to the next series of wells on leg 4. Equipment availability has eliminated the possibility of moving to the K-01 RD2 (Sundry #308-111) well without incurring cost associated with rig down time. Please consider expediting our request for the processing of the K-25 sundry. Thank you, Chantal Walsh Contract Engineer Chevron, Alaska ~~~`~~~ JUN ~ ~ 2008 6/3/2008 • ~~ ~ ~ ~~ ,,~~ ~ "~~ ~""~ ~~~ ~ SARAH PAL/N, GOVERNOR ~1[>•-7~ OI~ Alsil ~5 333 W 7th AVENUE, SUITE 100 CO1~T5ERQA'1'I011T COMDIIS5IOI'1T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 ~~~},(i11~E~ ,lUN ~ ~ ~~~~ C~ Anchorage, AK 99519 ~ ~ b 1 0 ~~ Re: McArthur River Field, Hemlock/G Oil Pool, Trading Bay K-25 Sundry Number: 308-197 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Comrrvission's petroleum field inspector at (90?) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 3 day of June, 2008 Encl. .~ ,~ STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COM~SION ~ UN ~ ~ p i 1- APPLICATION FOR SUNDRY APPROVA gg ~ `~ 20 AAC zs.28o ~1as~a ail & Gas ions. Co f t3i~~:~:u! . 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver OtherO Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ RE-Run ESP Change approved program^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ & Clean out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 185-078 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20180-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Tradin Ba Unit, K-25 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL018730~#25, Cook Inlet Basin, Offshore 100' McArthur River Field /Hemlock & G Zone ` 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,325' ~ 9657' 14323' 9631' N/A 13,685' Casing Length Size MD TVD Burst Collapse Structural Conductor 1962' 13-3/8", x55 1997' 1996' 3090 1540 Surface Intermediate 12,338 9-5/8" 12,373' 8538' 6870 4750 Production Liner 7892' 7", 29#, L80 14,325' 9687' 8,160 7,020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Attachment Reference Attachment 4-1/2" 12.6# L80, BTC 6308' Packers and SSSV Type: Packer-less Completion Packers and SSSV MD (ft): Packer-less Completion No flow potential NA No SSSV 13. Attachments: .Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development ^~ Service ^ 15. Estimated Date for Jun-08 16. Well Status after proposed work: Commencing Operations: Oil^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh - 263-7627 Printed Name Timothy C. Branden~u~rg Title Drilling Manager Signature Q Phone 263-7657 Date 3-Jun COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~-, Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: i ~c~ ~o ~ ~ ~~c~ p~.~. c ~y,~~~ ~t3Q ~ pS", ~.~ ~.v ~--. ~ ~ ~~ C~~-es~, ~ ~~''~ ~~ ~~ • ~~~~C7ul~~`~i~L ' v ~~~ s T- ~c~ r `vo T\o.'.1 "[-~~i 1~ c~~> o~ vac\~~~c-~ ~Q Subsequent Form Required: ~® APPROVED BY ~) ~ /~ Approved by COMMISSIONER THE COMMISSION Date: Qf~ Form 10-403 Revised 06/2006 o R o G i ~ A ~. _ ~. ai~t ~ ~ ~~ ~. Z . o~ 200 s .. ~ Chevron , ! Trading Bay Unit K-25 ESP Change Out Revision #0: 06/02/2008 OBJECTIVE: • Change out of the K-25 ESP completion, re-run new Dual ESP completion and return to production operations as an ESP artificially lifted well. PROCEDURE SUMMARY: • PF -Discus Sim-ops and preparation procedures with production personnel on platform. Platform will need to perform certain tasks for safe WO operations -Secure well for well operations. Blind and isolate from platform as required. Pressure check of well pressures -Circulate Kill • PJSM -RIG - MORU HWO equipment and RU over well name "Trading Bay Unit K-25 on the King Salmon Platform. NU BOPE Test same. PUMU landing joint. Circulate well to production displacing with FIW w/ 3% KCL to kill well. Spot salt pill if required. Check for flow. • PJSM -RIG - RU ESP handling equipment (spooler, sheaves, power washer and etc.). Pull hanger to HWO jack work window. Disconnect the cable and control line(s). LD hanger. Inspect hangar replace all seals, prepare for reusing same. • PJSM -RIG - POOH LD 4 '/2" tbg. Clean, inspect, strap, and dope threads as LD. LD Cannon Clamps. Reference Tubing Tally for clamps, fasteners, and splice information. • POH ESP assembly to work window, secure same, RU crane to pull ESP and LD same • PJSM - WL - RU slick line to recover lost items from ESP pull • PJSM -RIG - PU Casing mill -RIH hole t/ 14,000' to clean out 7" liner, tandem w/ 9-5/8" casing scraper • PJSM -RIG - PU 9-5/8" scraper /Clean out assembly -RIH t/ 6481' ,Circulate bottoms up - POH • PJSM -RIG -Repair 9-5/8" x 13-3/8" wellhead packoff assembly • PJSM - EL - RU E-Line RIH GR/ Junk Basket to Top of Liner - POH - RU USIT and Gyro -Log from Top of 7" Liner to surface - RD E-Line • PJSM -RIG - RU to run Dual ESP using platform crane • PJSM -RIG - PUMU ESP Completion consisting of Dual ESP equipment. - Run completion to approximately 6200', and land hanger. • PJSM -RIG - ND BOPE. NU tree. Test same. RDMO Cudd Pressure Control HWO to next well on King Salmon Platform. • PRODUCTION -Release well back to production and turn platform cathodic protection back on. K-25RD_ Recomplete Objective and Procedure Summary.doc REVISED BY: JRN 03/13/08 Chevron 909 West 9Th Avenue Anchorage, Alaska 99501 ADL18730 #25, Cook Inlet Basin Perforation Data: K-25 Zone Top Btm Condition G-1 12521 12545 os/os - a-5/s"rcP G-2 12585 12610 os/os - a-5/s"rcP G-2 12625 12645 O6/O6 - 4-5/8"TCP G-3 12645 12697 06/06 - 4-5/8"TCP G-4 12787 12840 O6/O6 - 4-5/8"TCP G-5 12933 12955 os/os - a-5/s"TCP G-5 12975 13045 06/06 - 4-5/8"TCP H61 13293 13340 02/86-cmt iso.Sq.Perfs (293'-295');3/86-(305'-340'-frac w/ 20,000#); 9/91-(300'J20'-2-1 /8" jet guns);6/06-(293'-318'-0-5/8"TCP) Sq. P 13378 13380 02/86cmt iso.Sq.Perfs HB2 13390 13420 01/88 -2-1/8" jet guns; 02/90- 2-t/5" jet guns HB3 13542 13586 02/86-cmt iso.Sq.Perfs (542'-544');9/90 -(556'-566'-2-1/8" jet guns);9/91-(550'-580'-2-1/8" jet guns);6/06-(525'-550'-4-5/8"TCP) HB4 13629 13815 3186•(715'•745'•frac 60,000#);9190•(650'-680';695'-715';770'-800'-2.118" jet gun);9191 •(650'•670';710'-730';780'•800'-2.118" jet gun);9195(629'-815'-2.118"gun) HB5 13850 13902 2/90-(860'900'2-1 /6"jetgun);9/91-(860'-900'-2-1/8"jetgun);9/95-(850'-902'2-1/8"jetgun) • Chevron C7 Trading Bay Unit King Salmon Well No. K-25 Completion RKB to TBG Head = 35' 13 3/8" ~ 1997" Tubing Punch: 6238' - 6234' 7" Liner Hanger ~ 6,481' Split csg 8,400' Est TOC on back side of 9-5/8" 10, 773' 7" Liner Hanger 12,049' 9 5/8" ~ 12,373' Poor cement bond from 12,650' - 12,900' Good cement bond 13,100' - 13.200' No bond any where else in the open hole 7" liner. Clean out depth'6/24/06 = 13,648' (Cuddy Iii or 13606' Ong I~~ ~ I I'~ RKB ~' GLM s X1888' 3956' ~ 5826' G-1 G-2 G-3 G-4 G-5 B-1 B-z B-3 B-4 B-5 PBTD = 14,282 TD = 14,323 MAX HOLE ANGLE = 62° @ 12,100' ~~ecrvr_ earn •rr~urvr_ nc~rerr SI7.E WT GRAD E CONN ID Burs t To Btm TVD Btm CMT CMT To 13-3/8" 61 K-SS BTC 12.515" 3090 Surf. 1997 1260 sx Good rtes to surf. 9-5/8" 47- L-80 BTC 8.681" 6870 Surf 7903' 2ndcmtjob Est Missin N-80 BTC 6870 7903' 10178' w/SOOsx TOC g Tally guessin order 5-95 BTC 8150 10178' 12373' Rtns to surf at 10,773 ' Tuner 29 L-80 BTC 6.184" 8160 6495' 11001' 750 sx-RIH w/NO S-95 BTC 9690 11001' 12072' sign cmt on top. Likely TOC only at cs slit. L-80 BTC 8160 12065' 13274' I"job no 13,100 5-95 BTC 9690 13274' 14323' JoY 2"e s9 intervals ' 13200' only Tubin 4-I/2" 12.6 N-80 BTC 3.958" Surf 6308' ESP Cable w/ (2) 3/8" Chem in ~ lines 3.7 1/USOLBC 90FB 185 GAL (2.361" x 1.611 ") Surf 6308' 1)t1~,r;iC'~ > ~ ~1 Of)' - - 2200' and - S • 28/ 1 OOft 8500'md - 4.52/1 OOft NO. De th ID Item 9200'md-4.39/100ft a. 1888' 3.958" 4-1/2" SFO-2 GLM w/RK Latch drift ID = 3.833" 9500'md - 4 16/IOOft b. 3956' 3.958" 4-1/2" SFO-2 GLM w/RK Latch drift ID =3.833" . c 5828' 3 958" 4-1/2" SFO-2 GLM w/RK Latch drift ID = 3 833" . . . 1 6256' 3.813" "X N" Ni le 3.752" No-Go 2 6308' NA Pressure Head Rotating Hours: 3 6309' NA Dischar a Head 13-3/8" Csg - 832 hrs 4 6310' NA Pum Model HC7800 HPHVM AR 1-1, SN-OIH-0072806 -•[CStCd t0 ISOO (6/8S) 5 6323' NA Pum Model HC7800 HPHVM AR 1-1, SN-OIH-0072807 " 6 6337' NA Seal Assembly 9-5/8 Csg - 196 hrs 7" Casing - hrs 7 6352' NA Motor - 600 HP HM[ SN-21H-0048909 8 6379' NA Phoenix Sensor XT-I/Anode/Centralizer (bottom , 6382') 9 6481' NA Baker Model A Sim lex liner hanger 10 12072' Baker Model A Sim lex liner han er • Original well drilled out of K-16(inj) kicked out below the 13-3/8" csg. • 13 '/8" has high rotating hrs. • Inj test in the 13-3/8"x9-5/8" annulus (10/25/00). • Reason to believe (cannot verify) the 9-5/8" was run with 2000' from original K-16 pipe, across the split interval. • Suspect the cement job on backside of 7"liner went out through the 9-5/8" csg split. • 8/19/02 lost pressure gauges with AD-2. • Lost 756 discs from EJ charges during the 09/98 perf job. Zone Top PERFORATION DATA Btm Condition G-1 12521 12545 06/06 - as/a"TCP G-2 12585 12610 06/06 - 4-5/8"TCP G-2 12625 12645 o6/os - a-s/a"TCP G-3 12645 12697 06/06.4.5/8"TCP G-4 12787 12840 06/06 - 45/8"TCP G-5 12933 12955 06/06 -4.5/8"TCP G-5 12975 13045 O6/O6 - 4-5/8"TCP H61 13293 13340 02186-cmt iso.Sq.Perts (293'-295');3186-(305'-340'-frac wl 20,000#); 9191-(300'-320'-2-t18" jet guns);6106-(293'-318'-4-518"TCP) Sq. P 13378 13380 02/86-cmt iso.Sq.Perfs HB2 13390 13420 o1/es -2-1/8"jet guns; 02/90- 2-1/8" jet guns HB3 13542 13586 02186-Cmt iSO.5q.Perts (542'-544');9190 -(556'-586'-2-118" Jet gUns);9/91-(550'-580'-2-1IS" jet guns);6/06-(525'-550'-4-5/8"TCP) HB4 13629 13815 3186•(775'•745'•trac 60,000#);9190•(650'•680';695'-715';770'•800'•2.118"jet gun);9191•(650'•670';710'•730';780'•800'•2• 118" jet gun);9/95•(629'•815'•2.118"gun) HB5 13850 13902 2/90-(860'900'2-118"jet un) 9/91-(860'-900'-2-1/8"jet un) 9195-(850'-902'2.118"jet un) ; g ; g g Ol/l5/07 CRW Chevron • Trading Bay Unit King Salmon Well No. K-25 June 2008 Proposed Completion recrnr_ e~nTt utcr n~Ten RKB to TBG Head = 35' 13 3/8" ~ 1997" ~~ 7" Liner Hanger e,aa1' Split csg 8,400' 9 5/8" @ 12,373' Proposed Clean out depth' 06/2008 = 14,025' KB G-1 G-2 G-3 G-4 G-5 B-1 B-2 B-3 B~ B-5 PBTD = 14,282 TD = 14,323 MAX HOLE ANGLE = 62° ~ 12,100' SIZE WT CRADE CONN ID Burs t To Btm TVD Btm CMT CMT To 13-3/8" 61 K-55 BTC 12.515" 3090 Surf. 1997' 1260 sx Good rtes to surf. 9-5/8" 47 - L-80 BTC 8.681" 6870 Surf 7903' 2"" cmt job Est N-80 BTC 6870 7903' 10178' w/SOOsx TOC at 5-95 BTC 8150 10178' 12373' Rtnsto surf 10,773 7'liner 29 L-80 BTC 6.184" 8160 6495' 11001' 750 sx-RIH w/NO si8n 5-95 BTC 9690 11001' 12072' cmtontop. Likely TOC onl at cs slit. L-80 BTC 8160 12065' 13274' ls`jobno 13,100 S-95 BTC 9690 13274' 14323' loY 2"a s9 intervals ' 13200' onl Tubin 4-1/2" 12.6 N-80 BTC 3.958" Surf 6140' ESP Cable " 3.7 Surf 6451' w/ (2) 3/a Chem id lines le > -t ~ 1 OO": Do Pro osed JEWELRY DETAIL g g 2200'md - 5.28/100ft 8500'md - 4.52/100ft NO. De th ID Item 9200'md - 4.39/100ft 1 6140' 3.813" "X N" Ni le 3.752" No-Go 9500'md - 4 16/100ft 6180" U er Y-Tool Assembl . 6197' Bolt on Dischaz a Head U ESP A er ss 6199' U er Pressure Dischaz a Sub 6246' U er VGSA 538/ 540 Intake U er Pum Rotating Hours: 6345' Lower ESP Assembl Bolt on Dischaz a Head 13-3/8" Csg - 832 hrs 6347' Lower Pressure Dischaz ~e Sub _tested t0 1500 (6/8S) 6394' Lower VGSA 538/ 540 Intake Lower Pum 96 h / " 6451 Multi Sensor XTl rs 9-5 8 Csg - 1 7" Casing -hrs 6453' Motor Base Plu 6481' Baker Model A Sim lex liner han er 12072' Baker Model A Sim lex liner han er 1. Well will have an USIT and Gyro run to top of 7" Liner hanger. NOTE: USIT will be used to determine that the hole is in gauge, and if they is any casing damage. NOTE: Gyro will verify dog legs and should be calculated on: Bogle severity /100', dogleg severity / 50', and dogleg severity / 25'. PERFORATION DATA Zone Top Btm Condition G-1 12521 12545 06/06 - 4.5/8"TCP G-2 12585 12610 06/06 - 4.5/8"TCP G-2 12625 12645 06/06 - a-s/e"rcP G-3 12645 12697 06/06 - 4-5/8"TCP G-4 12787 12840 06/06 - a-s/e"TCP G-5 12933 12955 o6/os - a-s/e"TCP G-5 12975 13045 06/06 - 4-5/8"TCP HB1 13293 13340 02/86-cmt iso.Sq.Perts (293'-295');3/86-(305'-340'-frac w/ 20,000#); 9191-(300'-320'-2-1/9" jet guns ); 6/06-(293' •318'-4-5/8"TCP ) Sq. P 13378 13380 02/a6-cmt iso.Sq.Perfs HB2 13390 13420 o1/ae -2-1/a"jet guns; oz/9o- 2-t/s"jet guns H 63 13542 13586 02/86-cmt iso.Sq.Perfs (542'-544');9190 -(556'-586'-2.118" jet guns);9191-(550'-580'-2.118" jet guns ); 6/06 -(525'-550'-4-5/8"TCP ) H64 13629 13815 3186•(715'-745'-frac 60,0000);9190•(650'•680';695'-715';770'-800'-2.118"jetgun);9191•(650'-670';710'-730';780'•800'-2• 118" jet gun);9195•(629'•815'•2.118"gun) H65 13850 13902 2/90-(860'900'2.1/8"jetgun);9l91-(860'-900'-2-1/8"jetgun);9/95-(850'-902'2.1/8"jetgun) + R ~ • f p 4 King Salmon K-25 BOP Stack Btm of Trolly beam BASKET RAIL Bottom of wind 40.7 13 5/8" Shaffer 5M 13 5/8" Shaffer Sm DBL Gate RAIL Blind Rams JACK BASKET RAIL 5/8" 5 M A 2 1/16" SM HCR Valve B 2 1/16" 5M Manual gate valve Top of drill deck C 2 1/16" 5M Manual gate Kill line D 2 1/16" SM Manual gate Kill line 13 5/8" 5M E 2 1/16" 5M Target Tee Riser ,, 13.3 F 2 1/16" 5M Target Tee T Top of FMC Type 3 Well Head Chevron ~';' Francisco Castro Technical Assistant December 4, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com PERMI` ~ A?I NUMBEF; ~' -T- -- - -- ';~E~~ ~ LOG TYPE SCALE LOG DATE INTERVAL ~ RUN ~ B- ~ FILI,4 ~ CD LOGGED # LINE PERFORATING DEPTH CORRELATION 185-078- GAMMA RAY / 27-Jun- 11875 - 0 507332018001 K-25 CCL 5" 06 12460 1 1 1 1 ~:~ `~ ~s D~.G ~ 20t~Z ~ `~~~~ ~~~ ~5~ DOTES - i AS, ~~G )LIS 'DS Please acknowledge receipt by signing and returning one copy of thi ~rAt6°~07 263 7828. Received By: Date: ~~~ ~ ~~ ~~~ ~~ ~9iheGy f'tif SL C.:~c + tsti" ~ ~ rr~~b~S'~,''; RECEIVE a STATE OF ALASKA I 0 ALA~ Oil AND GAS CONSERVATION COM SION JUL 2 6 2006 REPORT OF SUNDRY WELL OPERA TIONSska Oil & G as Co 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool 0 Perforate [] 4. Current Well Class: Development [] Stratigraphic 0 Stimulate oragfIDn E Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing [] · Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: Exploratory 0 Service 0 7. KB Elevation (ft): RKB to TH = 35' 8. Property Designation: King Salmon Platform/Cook Inlet 11. Present Well Condition Summary: Â)i; (>/673{) ..J~ .,·¿?Ò(. 185-078 . 6. API Number: 50-733-20180-01 9. Well Name and Number: K-25 10. Field/Pool(s): ,wi,µ? ØDlro~. ..,.DIt> McArthur River Field/ HemlocklG-Zone ..., ~ Total Depth measured 14,325 feet true vertical 9,657 feet Effective Depth measured 14,221 feet true vertical 9,595 feet Casing Length Size MD Structural Conductor Surface 1,962' 13-3/8" 1 ,997' Intermediate 12,338' 9-5/8" 12,373' Production Liner 7,892' 7" 14,325' Plugs (measured) N/A Junk (measured) Pressure Gauges - 13,685' TVD Burst Collapse 1,996' 8,538' 3,090 psi 6,870 psi 1,540 psi 4,750 psi 9,687' 8,160 psi 7,020 psi Perforation depth: Measured depth: 12,521' - 13,550' (See Attached Schematic) True Vertical depth: 8,736' - 9,201' Tubing: (size, grade, and measured depth) 4-1/2" N-80, 12.6 ppf 6,308' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A RBDMS BFl JUL 3 1 2006 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Gas-Mcf Water-Bbl 420 MCFD 3351 BWPD 339 MCFD 6754 BWPD . 15. Well Class after proposed work: Exploratory 0 Development [] 16. Well Status after proposed work: Oil[]. Gas 0 WAG 0 17. I hereby certifY that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 196 BOPD 212 BOPD Representative Daily Average Production or Injection Data Casing Pressure 1230 psi 75 psi Tubing Pressure 195 psi 75 psi N/A Attached Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 306-149 ' Contact Title Drilling Manager Signature Phone 907-276-7600 Date 7-'"2.1-4- I GIN A L AFE: R6004 1-.... .d" ,', ,,,,,L _ ßU,~inal Only "" ~fJ..-""" .¢-' ~?Q~ 7·Z,1·O(. "Chevron === e e Trading Bay Unit King Salmon Platform Well # K-25 RKB to TBG Hanger = 35.00' SIZE WT 13-3/8" 61 9-5/8" 47 7"Liner 29 CASING AND TUBING DETAIL GRADE CONN TOP J-55 BTC 35' S-95/N80/L80 BTC 35' S-95/L-80 BTC 6481 ' BOTTOM 1,997' 12,373 ' 14,373' Tubing: 4-1/2" 12.6 N-80 BTC 35' 6,308' JEWELRY DETAIL 2 NO. Depth Item 1. 35' FMC Hanger wi 2 ea.3/8" cont. cap. Lines and CIW Type H BPV profile. 2. 1,888' SFO-2 R-2 GLM wi RK Latch 3 3,956' SFO-2 R-2 GLM wi RK Latch 4 5,828' SFO-2 R-2 GLM wi RK Latch 3. 6,256' XN-Nipp1e 5 4. 6,308' HC 7800 ESP Pumps wi 600 HP Motor 5. 6.382' Bullnose centralizer clw anodes. FISH DETAIL NO. Depth Item A. ? Lost pressure gauges with AD-2 - 8/19/02. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 12,521 12,545 G-1 6 Jun-06 . 4-5/8" TCP 12,585 12,610 G-2 6 Jun-06 4-5/8" TCP 12,625 12,645 G-2 6 Jun-06 4-5/8" TCP 12,645 12,697 G-3 6 Jun-06 4-5/8" TCP 12,787 12,840 G-4 6 Jun-06 4-5/8" TCP 12,933 12,955 G-5 6 Jun-06 4-5/8" TCP 12,975 13,045 G-5 6 Jun-06 4-5/8" TCP 13,305 13,340 H-1 4 13,293 13,318 HB-1 6 Jun-06 4-5/8" TCP 13,390 13,420 H-2 4/8 Clean-out depth 13,525 13,550 HB-3 6 Jun-06 4-5/8" TCP 6/24/06 = 13648' A 13,542 13,586 H-3 4/8 <£)3 Lost 621 perf 13,625 13,811 H-4 4 9/29/1998 disks 13,640 13,760 H-4 4/8 13,770 13,800 H-4 4 [ Lost 135 perf 13,846 13,898 H-5 4 9/28/1998 disks 13,860 13,900 H-5 4 PBTD = 14,221' TD = 14,325' MAX HOLE ANGLE = 62° REVISED: 7/13/06 DRAWN BY: LWB Daily Operations 6/5/2006 00:00 - 6/6/2006 00:00 Operations Summary Rig up HWO unit over K-25 6/6/2006 00:00 - 6/7/2006 00:00 Operations Summary RlU HWO unit. RlU e-line. RIH to 11,365'. 6/7/2006 00:00 - 6/8/2006 00:00 Operations Summary Punch holes in tubing from 11,311 '-11 ,317'. RID e-line. Start to circulate well. 6/8/2006 00:00 - 6/9/2006 00:00 Operations Summary Circulate well with 3% KCL brine. Pump a 30 bbl sized salt LCM pill. NID tree. 6/9/200600:00 - 6/10/2006 00:00 Operations Summary N/U BOPE. Test to 3,000/250 psi. Circulate well with 3% KCL brine. 6/10/200600:00 - 6/11/200600:00 Operations Summary Engage tubing hanger and pull off seat. Pull and UD tubing string. 6/11/200600:00 - 6/12/2006 00:00 Operations Summary Continue to pull and UD tubing. 6/12/200600:00 - 6/13/2006 00:00 Operations Summary Finish out of hole. M/U wire grab spear. Recover stainless steel control line just below wellhead. Test blind rams to 3,000/250 psi. M/U packer fishing BHA. 6/13/200600:00 - 6/14/2006 00:00 Operations Summary RIH with fishing BHA on 3-1/2" drill pipe to 8545. 6/14/200600:00 - 6/15/2006 00:00 Operations Summary Work in hole to 9325'. Unable to go deeper. POOH for clean-out assembly. 6/15/200600:00 - 6/16/2006 00:00 Operations Summary Continue out of hole. M/U clean-out BHA. Run in hole. 6/16/200600:00 - 6/17/2006 00:00 Operations Summary Continue in hole washing to 11,189'. 6/17/200600:00 - 6/18/2006 00:00 Operations Summary Continue in hole to packer top at 13,082'. Circulate and POOH. 6/18/200600:00 - 6/19/2006 00:00 Operations Summary POOH. Test BOPE to 250/3000 psi. 6/19/200600:00 - 6/20/2006 00:00 Operations Summary Finish testing BOPE. M/U packer fishing BHA and run in the hole. 6/20/200600:00 - 6/21/2006 00:00 Operations Summary Engage packer and work packer loose. Circulate well. POOH. 6/21/2006 00:00 - 6/22/2006 00:00 Operations Summary Finish out of the hole with no recovery. Reconfigure fishing BHA. RIH and engage packer at 13,130' and jar loose. Circulate bottoms up. 6/22/2006 00:00 - 6/23/2006 00:00 Operations Summary Continue to circulate well. POOH. Full recovery of packer. J 6/23/2006 00:00 - 6/24/2006 00:00 Operations Summary M/U clean-out BHA. Run in the hole to 13,560'. Daily Operations 6/24/2006 00:00 - 6/25/2006 00:00 Operations Summary Clean-out casing to 13,648' with 3% KCL brine and polymer sweeps. Pump a sized salt LCM pill from 13,167' to 11,996'. POOH. 6/25/2006 00:00 - 6/26/2006 00:00 Operations Summary Finish out of the hole. Test BOPE to 250/3000 psi. 6/26/2006 00:00 - 6/27/2006 00:00 Operations Summary RlU to run TCP guns. RIH 6/27/200600:00 - 6/28/2006 00:00 Operations Summary Finish in hole with TCP assembly. RlU e-line and correlate assembly. Drop bar and fire guns. Monitor well. POOH. 6/28/2006 00:00 - 6/29/2006 00:00 Operations Summary Finish out of the hole. All guns fired. 6/29/200600:00 - 6/30/2006 00:00 Operations Summary RlU and run ESP completion. . 6/30/2006 00:00 - 7/1/2006 00:00 Operations Summary Land and test tubing hanger. N/D BOPE. 7/1/2006 00:00 - 7/2/2006 00:00 Operations Summary N/U and test tree to 5000 psi. UD drill pipe and RID and release HWO Unit. Note: No-flow test will be conducted within 14 day of production start-up. e e FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AIWD GAS CONSERVATION COMMISSION July 25, 2006 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent U nocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit K-25, PTD 185-078 ,. (~ f\~\~Et. ''Jr~:{~'~ .,..... '" Dear Mr. Myers: On July 10,2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's King Salmon platform, Trading Bay Unit Well K-25. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no gas or fluid flow while open to atmosphere, and no pressure build-up during a 3-hour shut in monitoring period. The subsurface safety valve may be removed from service in Well K-25 based on this no- flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platform. Sincerely, ..---. ~ ,/"'""".., '-;-)' . I L.. ^. "" '------_lvt¡Lt~ D . €ú Co James B. Regg ( ( Petroleum Inspection Supervisor cc: Bob Fleckenstein . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P. I. Supervisor DATE: July 10, 2006 FROM: Chuck Scheve, Petroleum Inspector King Salmon Platform SUBJECT: No Flow Trading Bay Unit K-25 PTD# 1850780 Monday. July 10. 2006: I traveled to Unocal's King Salmon Platform and witnessed a no- flow test on well K-25. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was shut in and observed for three hours with no pressure build up observed and no flow when reopened. I recommend Well K-25 on the King Salmon Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well K-25 meets the AOGCC requirements for no flow status. sCANNED SEP 0 82DDü Re: 06-05-06 BOP test letter . . Evan, et al: Your proposal is acceptable with one change. As you pointed out, the well is likely to be taking fluid at some nominal rate and the only tubular size you are planning to pull prior to replacing the hanger is 4-1/2". Depending on whether the tubing pulls out of the packer or not, you could be pulling 3-1/2" tubing as well. Based on guidance document 6-03, if you will be pulling 3-112" tubing it will also be necessary to test on 3-112". Good luck with the operations, Tom Maunder, PE AOGCC Harness, Evan wrote, On 6/5/2006 2:21 PM: Tom we have Bullheaded a Sized Salt pill as of last night - We have not yet perforated the well close to the packer to cir the annulus - The well dose go completely dead but we do not have a good handle on whither or not it will stand full at this time - Our past experience is that the wells tent to take +/- 10 to 20bbl/hr even after the LCM pill Evan K. Harness Drilling Superintendent Union Oil Company of California 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron.com i e -----Original Message----- From : Thomas Ma unde r [!1~i:i~~.t:..?:t:?!1~ma unª~ES'!!9:?:0~:£1::§t:"': t:<::i't~:'::l_f?] Sent: Monday, June 05, 2006 2:13 PM To: Harness, Evan Cc: Jim regg@admin.state.ak.us; Brandenburg, Tim C; Buster, Larry W Subject: Re: 06-05-06 BOP test letter Evan, Does the well stand full of fluid? Tom Maunder Harness, Evan wrote, On 6/5/2006 1:03 PM: 1 of 1 6/5/2006 2:55 PM . . Monday, June 05, 2006 To: AOGCC Att: Mr. Jim Regg, Mr. Tom Maunder Re: King Salmon K-25 Permit to Drill # 185-078 Union Oil Company of California currently has a Cudd Hydraulic W orkover unit working our Proj ects on the King We are currently moving from K-13RD #2 to K-25 K-25 is planned for a conversion to an Electric Submersible Pump - Reservoir Pressure of current completion is reported at 5 to 6ppg MWE depending on water flood support We have been working to prep the well for the upcoming Work - The tubing string in this well has known holes in the pipe - In addition it looks like we have communication to the Annulus and/or tubing through the control line for the Sub Surface Safety Valve To date we have been unable to get an isolation test on the hanger void - The lack of a good test here puts the Hanger Neck seals along with the tubing hanger body seals in question Our forward plan is to 1) Bullhead a tubing Volume (Done) 2) Fill the Annulus (Done) 3) Bullhead a sized salt lost circulation pill into place (Done) 4) Rig up the Jack on the Cudd Subbase (Tree on) 5) Perforate the tubing above the existing packer 6) Circulate the well with Filtered Inlet Water (Complicated by Holes in tubing) 7) Confirm well static 8) Set Back Pressure Valve 9) Nipple down tree and plug control line port 10) Nipple up BOP 11) Install Test Joint and attempt to Pressure Test BOP - If we are leaking by the hanger body seals we will have to change the hanger out to get a BOP test - We would pressure test the choke manifold at this time a. Do a low pressure shell test of the BOP stack against injection pressure b. Re-check the well for static c. Ensure we have reviewed shut in procedures with Rig crew d. Ensure we have Active system full of Filtered Inlet Water . . e. Pull Hanger off seat and ck well for static f. Pull Hanger to Rig Floor and layout same g. Lay down 4 Yz" tubing - Pull enough tubing to get below the hole in tubing (estimated to be close to GLM #1 at 2,340 tubing tally measurements) - We would pull additional tubing below that point to get to competent tubing - Well Bore would be kept full of Filtered Inlet Water h. Make up Test Plug or redressed hanger depending on condition of hanger 1. Re-Land tubing on test plug or hanger J. Pressure test Annular preventer and VBR pipe rams on 4 Yz" tubing (Note we have recently tested the VBR's on 3 Yz" while working on K-13RD2), Kill & Choke Line Valves would also be tested at this time - We request not to test the VBR's on 3 Yz and to not test the Blind/Shear rams at this point k. Cont POH and layout existing completion 1. Set Test Plug and do a conventional BOP test - Testing VBR's on 3 Yz & 4 Yz . . FRANK H. MURKOWSKI, GOVERNOR AIfASKA. OIL AND GAS CONSERVATION COMMISSION Timothy C. Brandenburg Union Oil Company of California PO Box 196247 Anchorage, AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 --- -,~-'" \%6--ö1~ Re: McArthur River Field, Hemlock, K-25 Sundry Number: 306-149 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ild.ay of April, 2006 Encl. 20 MC 25.280 I?~~ " ~('('1;1. 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate L.::J /" " \Ì'Ì1ai-6èr~ L, ,) Ci ,) Other L.::J . Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate i¡b !~~.¡::~~sjQI1iQ. , J;SI? ~~~sion Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter SuspendeQ X'4!1I bJ f'~, 'j, ,,', 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 185-078' 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20180-01 . 7. KB Elevation (ft): 9. Well Name and Number: RKB to TH 35' K-25 8. Property Designation: 10. Field/Pools(s): King Salmon Platform/Cook Inlet McArthur River Field/ .¡./4J1A..i~ - $'" ¿DI2C ~þ f l./...Q ,.. 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): 14,~"'3~Ç ,!J,.J. 9,687' q,"~71 11.",,,,",, 14,221' 9,595' n/a press gauges-13,685' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,962' 13-3/8" 1,997' 1,996' 3,090 psi 1 ,540 psi Intermediate 12,338' 9-5/8" 12,373' 8,538' 6,870 psi 4,750 psi Production 7,892' 7" 14,373' 9,687' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13,305 to 13,898' 9,062 to 9,401' 4-1/2"; 3-1/2" N-80; N-80 13,155' Packers and SSSV Type: Baker 7" FHL packer/Cameo TRDP-1A SSSV Packers and SSSV MD (ft): Packer = 13,128' ; SSSV = 281' 12. Attachments: Description Summary of Proposal L.::J 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/12/2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry W. Buster 263-7853 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ - ¿7. <:Lß- /~ Phone 907-276-7600 Date cr - /e- ~ -.-- 0 /,/~ COMMISSION USE ONLY L.... Sundry Number: l ~O ~ ' (<{~ Conditions of approval: Notify Commission so that a representative may witness ~ ~ 0 ~\.O""'"" ~~\. ø Plug Integrity 0 BOP Test M~ca~riÌÑ.6st Location Clearance 0 Other: >()CO\'S', 'OC>\' 'L,;,:>', ~¡;'~\c,,~ ....'+"'-,... \'-\. ~'i <'Cç;. ¡"..Ù""> ~\ ,,~'" ctlú:~", ~"'\-~~ .~~ ~\\,)~ ~\ \)cc:. ~<;\êð ~,,\.(';.\ .~\~ \~\'\''-'::>~~~C:: \{)\, S,b"",ue"' F~ Req,iredo '"'(7j RBDMS 8Ft ,ô.PR 2 8 2006 T /~. , A~OMMISSI0NER APPROVED BY 4..1 ?--ø Approved by: THE COMMISSION Date: '-""'" ~ O~GINA 4ö -;/. 4 -6~ Form 10-403 Revised 07/2005 I Subl1'!i> in Duplicate ~' <f/26;d6 STATE OF ALASKA D~ ~ J/ 1- ALA.ILANDGASCONSERVATIONCOMMI_N ~.:;i¡~::t~'rl'~.I.:.::~\IC;:~.$ 1<. > / APPL~ATION FOR SUNDRY APPRè7rA~~"'~'""~'-'">¡ i,.,4t" VrJI, /-6 /~.. RKB to TBG Hanger 35.00' 3,4 Max safe depth 13685', PBTD = 14,221' TD = MAX HOLE ANGLE = 62° J-55 BTC S-95/N80/L80 BTC 35' 12373 ' T' S-95/L-80 BTC 6481' 14373' BTC 35' 6320' BTC 6320' 13155' 1. 2, 3. 4. 5. 6. 281 ' 6320' 13 099' 13128' 13144' 13156' Cameo TRDP-l A SSSV nipple 4-1/2" x 3-1/2" crossover Otis PBR (pinned 40,000#) Baker T' FHL packer (75,000# sh~ar) Cameo NoGo nipple (ID=2.812") Baker WLEG and 3-1/2" tubing tail 4-112" Cameo MMG wIR20 4-1/2" Cameo MMG w/R20 valve 1 2 2340' 4883' 3-1/2" Cameo KBUG w/BK valve 3-1/2" Cameo KBUG w/BK valve 3-1/2" CameoKBUG w/BK valve 3-112" Cameo KBUG w/BK valve and 3-1/2" Cameo KBUG wlBK 3-1/2" Cameo KBUG w/BK valve A. 1012105: 3" Scratcher to 13200'. 2.72" GR to 11951' B. 8/21/04: 2.70" GR to 13,160'. Did not tag. C. 8/19/02: Lost pressur~gauges with AD-2. Max safe 3 4 5 6 7 8 6447' 8355' 10010' 11406' 12680' 12717' 13305 13390 13542 13640 13625 13340 13420 13586 13 7 60 13811 13770 13800 13860 13900 13846 13898 H-l H-2 H-3 H-4 H-4 4 4/8 4/8 4/8 4 9/29198 Lost 621 perf disks H-4 H-5 H-5 4 4 4 9/28/98 Lost 135 REVISED: 4/21/05 DRAWN BY: JHM 3 Max safe depth 13,685' Well Narne: Operator: Field: API: Permit: Well Type: MAX HOLE ANGLE RKB to TH: TD/TVD: Type BTC 7" 29 $-95/L-80 Tubing Detail Size Wt Grade 4-1/2" 12.6# Jewelry Detail Type 1, Gas Lift Mandrels STC STe Type 1ST Top (FT) Btm (FT) 35 35 6481 Proposed, perforations are in bold. COMMENTS TOP 6·Jun 6·Jul1 Reperforate 8-Apr 4 9/29/1998 Lost.621 perf disks 8-Apr 4 4 9/28/1998 Lost 135 perf di$k$ 4 13,540 13,542 13,625 13,640 13,770 13,846 13,860 Slickline/Fish/FiII Information: A. 10/2/05: 3" $cratcherto 13200', 2.72"GR to 11951', 8, 8/21/04: 2.70" GR to 13,160', Did not tag, C. 8/19/02: Lost pressure gauges with AD-2. Max safe depth of 13685', Test Pressure: 250/3000 psi 31J16"SM x 41J16"SM DSA Top Deck A 41/16" 5M Foster HCR Valve B 41/16" 5M Manual gate valve C 31/16" 5M Manual gate Kill line D 3 1/16" 5M Manual gate Kill line Gralock Hub 55" 34" 27" ¡ 14" . . ' Chevron === . . King Salmon Platform Well K-25 ESP Conversion OBJECTIVE: Pull the existing single string gas lift completion, clean-out the well bore, perforate and run an ESP completion. PROCEDURE SUMMARY: 1. Shut off gas lift gas and bleed pressure off annulus. 2. Set BPV and NID tree on Well K-25. NIU BOPE and CUDD HWOU. Test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi./ 3. Attempt to pull tubing string free out ofPBR. If unable, then follow steps 4 thru 8 below. 4. RIU e-line. RIH and cut 4-1/2" tubing at an intennediate point. POOH. RID E-line. 5. Circulate annulus with Filtered Inlet Water. 6. POH wi existing completion and cut tubing. 7. MIU overshot assembly and RIH with drill pipe to top of tubing stub. 8. Engage tubing stub and pull tubing and seals out of polished bore. 9. Circulate well with 3% KCL in Filtered Inlet Water. 10. POOH with tubing and seal assembly. 11. MIU fishing assembly to recover retrievable packer. RIH engage packer and POOH. 12. MIU casing clean-out assembly and RIH cleaning out the 7" casing as required. 13. Spot LCM pill if required and POOH. 14. MIU TCP gun assembly and RIH. Correlate on depth and perforate 252' of new G-Zone along with existing Hemlock Benches 1 and 3 (see attached proposed schematic for proposed intervals). 15. Monitor well and spot LCM pill as required. POOH. LID TCP gun assembly. 16. RIU and run ESP assembly on 4-1/2" tubing spotting pump just above the 7" liner hanger. 17. Install BPV. RID CUDD HWOU. NID BOPE. NIU & test tree. 18. Conduct No-Flow Test on Well. L. W\\-\-..\,,- \'-\ ~'l~ o-\. ~\~<-\,,~ ~t\\ \~ ~~~C-*\'C~, ~..~œ,>C!.~\-\ ~\'-.)k 'l'-\.~~\-~Q:\-e:..>~" ~\-\O\ -\0 \~\\'\tt.\.\~\ ,,~~c.:-~r-, ),()<. <Y\J\ /J m: rv ( ~/ :>Co-Ci.p AOGCC K-25 ESP Conversion Summary 10fl March 29, 2006 \ STATE OF ALASKA 1 ALA~.~ OIL AND GAS CONSERVATION COM"'..,. ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development [2] Stratigraphic 0 Stimulate U Other @Ea~In~~OO1 Waiver 0 Time Extension 0 Re-enter suspenQ~~íIiD54 5. Permit to Drill NumbE1,r;r::i"¡1f,)'(""!i'f".~ ExploratoryD 85-78 ",J,~,n>il,J.¡~~" Service 0 6. API Number: 50-733-20180-01 9. Well Name and Number: K-25 10. Field/Pool(s): McArthur River Field/Hemlock 7. KB Elevation (ft): 35' RKB to Tubing Hanger 8. Property Designation: King Salmon Platform 11. Present Well Condition Summary: Total Depth measured 14,373' feet true vertical 9,686' feet Effective Depth measured 14,221 feet true vertical 9,594' feet Casing Length Size MD Structu ral Conductor Surface 1997' 13-3/8" 1997' Intermediate 12373' 9-5/8" 12373' Production Liner 7892' 7" 14,373' Plugs (measured) 14,221' Junk (measured) 13,685' TVD Burst Collapse 1997' 3,090 psi 1,540 psi 8536' 6,870 psi 4,760 psi 9687 8,160 psi 7,020 psi Perforation depth: Measured depth: 13,305 to 13,900 True Vertical depth: 9,061 to 9,402' Tubing: (size, grade, and measured depth) 4-1/2" ,12.6#, N-80,BTC @ 6320'; 3-1/2" 9.2#, N-80, BTC from 6320'-13,155' Packers and SSSV (type and measured depth) Cameo TRDP-1A SSSV @ 281'; Baker FHL Packer @ 13,128' SCANNED r £1:1 2 J lODS 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 557 3346 1010 456 3411 1250 15. Well Class after proposed work: Exploratory n Development rJ1 16. Well Status after proposed work: Oil [2] Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 237 276 Tubing Pressure 90 140 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service n x GINJ 0 WINJ 0 WDSPL 0 Sundry Numb3~~ ~ cf¡9VmPt~ Contact Printed Name Neil Magee Title Acting Drilling Manager Signature -,/) f2{Þr(l (f~ Phone 907-276-7600 Date 2/18/2005 RBDMS 8Ft FER 2 2 700S Form 10-404 Revised 04/2004 Submit Original Only ) ) 1/7/05 RU. PJSM. Pull cable spool from unit to lighten unit. Spot unit, install spool. Stab lower lubricator and wireline BOP on well, make tubing patch tool string and upper lubricator on deck. Arm firing head. Drag tool string in lubricator, and strip remaining lubricator over tool string on deck. MU lubricator to well. Test lubricator to 1250 psi. RIH tie into PDS Caliper log dated 12-3-04, put tubing patch on depth 79' to 109'. Set patch 3 1/2 minute setting time, extremely strong surface indication of patch setting. POH, break off lubricator, lay down setting tool, kinked wire on top of tool string. Schlumberger redress head, Expro break down setting tool and put together 2nd patch assembly, stab lubricator on well. RIH tag lower patch and space off of same. Put patch on depth 52' to 73'. Set tubing patch. 90 second setting time, extremely strong surface indication of patch setting. POH. RD/MO K-25 (163374) morning report summary, CONFIDENTIAL: last revised 2/18/2005, Page 1. UNOCAL8 ') Trading Bay Unit King Salmon Platform Well # K-25 Current Completion 3/17/86 L 81 SIZE WT 13-3/8" 61 9-5/8" 47 7" 29 CASING AND TUBING DETAIL GRADE CONN TOP J-55 BTC 35' S-95/N80/L80 BTC 35' S-95/L-80 BTC 6481 ' BOTTOM 1997' 12373' 14373' RKB to TBG Hanger = 35.00' ~ Tubing: * 4-1/2" 12.6 N-80 BTC 3-1/2" 9.2 N-80 BTC *Tubing Patch @ 52-73' and 791-1091' 35' 6320' 6320' 13155' JEWELRY DETAIL NO. Depth Item 1. 281' Camco TRDP-1A SSSV nipple (ID = 3.813") 2. 6320' 4-1/2" x 3-1/2" crossover 3. 13099' Otis PBR (pinned 40,000#) U2 4. 13128' Baker 7" FHL packer (75,000# shear) 5. 13144' Camco No Go nipple (ID=2.812") 6. 13156' Baker WLEG and 3-1/2" tubing tail Gas Lift Information 1 2340' 4-1/2" Camco MMG w!R20 valve and RK latch 2 4883' 4-1/2" Camco MMG w!R20 valve and RK latch LI ~ 3 6447' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 4 8355' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 5 10010' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 6 11406' 3-1/2" Camco KBUG w/BK valve and RK-2latch 7 12680' 3-1/2" Camco KBUG w/BK valve and RK-21atch 8 12717' 3-1/2" Camco KBUG w/BK valve and RK-2 latch . ~ ~ 3,4 - 5 - 6 ::J TOP BTM 13305 13340 13390 13420 13542 13586 13640 13760 13625 13811 PERFORATION DATA ZONE SPF DATE COMMENTS H-1 4 H-2 4/8 H-3 4/8 H-4 4/8 H-4 4 9/29/98 Lost 621 perf disks 8/19/02: Lost Press Gauges wi AD-2 stop in hole. 8/31/02: Max safe - depth 13685'. ::J ::J ~~ ::J ::J ::J 13770 13800 13860 13900 13846 13898 H-4 H-5 H-5 4 4 4 9/28/98 Lost 135 perf disks LI PBTD = 14,221' TD = 14,373' MAX HOLE ANGLE = 62° REVISED: 2/18/05 BY:DED ) . ~'1T 1TŒ (ffi~ ~~~~I ~ ) AltASIiA OIL AND GAS CONSERVATION COlWlISSION / I FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .m,....../>'î01'i'~ ~~#V' f ~f;;T Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Trading Bay K-25 Sundry Number: 304-490 Dear Mr. Brandenburg: 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior C ~ unless rehearing has been requested. .-' DATED this30 day of December, 2004 Encl. SCANNED JAN 0 6 2.DüS Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to tbg hanger = 35' 8. Property Designation: King Salmon Platform 1. Type of Request: 11. Total Depth MD (ft): 14373' Total Depth TVD (ft): 9687' Length Casing Structural Conductor Surface Intermediate 1962 13-3/8" 12338 9-5/8" 7892 7" Production Liner Perforation Depth MD (ft): 13305' - 13898' '\ STATE OF ALASKA '\ AlA,-.IA Oil AND GAS CONSERVATION COMIVI._lION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: k'i7G-~ fJ75 12(30 I 4- Suspend U Repair well D Pull Tubing D Perforate U Waiver U Other LJ Stimulate D Time Extension D run tbg patch Re-enter Suspended Well D 5. Permit to Drill Number: 0/ Exploratory D 85-0078-0 \ %S--e~~ D 6. API Number.: /' 733-20180-01 V Development Stratigraphic 0 D Service 9. Well Name and Number: K-25 10. Field/Pools( s): Trading Bay Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14221' 9595' Plugs (measured): Junk (measured): Press. Gauges na Size MD TVD Burst Collapse 1997' 12373' 14373' 1996' 8538' 3090 6870 1540 4750 7020 9687' 8160 Perforation Depth TVD (ft): 9062' - 9401' Tubing MD (ft): 13155' Packers and SSSV Type: Baker 7" FHL packer/Cameo T 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ""/'1 _.~~ () - b -- -~ Phone 907-276-7600 Date 1;1/#13/6 'f ~ ~ COMMISSION USE ONLY Jan. 03, 2005 Date: Tubing Size: 4-1/2" - 3-1/2" Tubing Grade: N-80 Packers and SSSV MD (ft): Packer = 13128' SSSV = 281' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 0 Service D D D Abandoned WDSPL D D Plugged WINJ Contact Steve Tyler (263-7649) Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 L{ - l(90 Mechanical Integrity Test D Location Clearance D R E C E IVE D . . \ C\ . ~ DEC 2 3 2004 Other. 'ßOÇ) ~\)\\>1V\t ~ '"' ô.L<I;::)~\",-~\O da~~(.,d--S' ~1 t; . i t Alaska Oil & Gas Cons. Commission . Anchorage Requi d: ' 7 \-\ Plug Integrity D BOP Test D Form 10-403 Revised 11/2004 ~ ¡¿M~R APPROVED BY THE COMMISSION I~ rtf Date: ~ Submit in Duplicate ) ) #K-25 TUBING PATCH PROCEDURE SUMMARY . Conduct a Pre-Job Safety Meeting. MIRU wireline unit. RlH wi scraper/brush to clean tubing walls to 165'. POOH . . RlH wi 2.85" GR to 165'. POOH. . RD wireline unit. . MIRUE-line Unit. Test BOPE RlH wi 35' string shot. Detonate string shot @ 78' to 113'. POOH RlH w/25' string shot. Detonate string shot @ 50' to 75' . . . PUMU Owen 30' x 4-1/2" tubing patch and control rod onto Owen setting tool, CCL and weight bar. . RlH set patch to straddle from 80' to 110'. (Probable holes @ 84' and 95'). POOH. PUMU Owen 20' x 4-1/2" tubing patch and control rod onto Owen setting tool, CCL, and weight bar. . . RlH, set patch after all have agreed on depth, to straddle from 52' to 72'. POOH. RD E-line unit. . . RU slickline. Gauge tbg patches. POOH. RD Put well back on production. . '" þ UNOCALe ) RKB to TBG Hanger = 35.00' SIZE WT 13-3/8" 61 9-5/8" 47 T' 29 . L. ~ Tubing: 4-1/2" 12.6 3-1/2" 9.2 J 00' -- Hole(s) in tubing. U2 NO. 1. 2. 3. 4. 5. 6. L1 1 2340' 4-1/2" Camco MMG w/R20 valve and RK latch 2 4883' 4-1/2" Camco MMG w/R20 valve and RK latch ~ 3 6447' 3-1/2" Camco KBUG w/BK valve and RK-2latch 4 8355' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 5 10010' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 6 11406' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 7 12680' 3-1/2" Camco KBUG w/BK valve and RK-2 latch 8 12717' 3-1/2" Camco KBUG w/BK valve and RK-2 latch PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13305 13340 H-l 4 13390 13420 H-2 4/8 13542 13586 H-3 4/8 13640 13760 H-4 4/8 13625 13811 H-4 4 ~ ~34 , - 5 - 6 =:J =:J =:J 8/19/02: Lost Press Gauges wi AD-2 stop in hole. 8/31/02: Max safe ---- . depth 13685'. --. c£:)3, =:J 13770 13800 13860 13900 13846 13898 =:J =:J Tradin~ lay Unit King Salmon Platform Well # K-25 Current Completion 3/17/86 CASING AND TUBING DETAIL GRADE CONN TOP J-55 BTC 35' S-95/N80/L80 BTC 35' S-95/L-80 BTC 6481 ' BOTTOM 1997' 12373' 14373' N-80 N-80 BTC BTC 6320' 13155' 35' 6320' JEWELRY DETAIL Depth 281 ' 6320' 13099 ' 13128' 13144' 13156' Item Camco TRDP-IA SSSV nipple (ID = 3.813") 4-1/2" x 3-1/2" crossover Otis PBR (pinned 40,000#) Baker 7" FHL packer (75,000# shear) Camco NoGo nipple (ID=2.812") Baker WLEG and 3-1/2" tubing tail Gas Lift Information 9/29/98 Lost 621 perf disks H-4 H-5 H-5 4 4 4 9/28/98 Lost 135 perf disks L] PBTD = 14,221' TD == 14,373' C:\Documdkf~èHGhiì~m€ì'618cal Settings\Temporary Internet Files\OLK67\K25schm_9-30-98 perf.DOC 12/14/04 REVISED: DRAWNBY:JHM RE: King 25 ) ') F"'" . I"" Subject: RE: King 25 From: "Tyler, Steve L" <tylersl@unocal.com> Date: Wed, 29 Dec 2004 13:38:03 -0900 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Tom here is a copy of a discussion summary from the Asset Tech Engineer #K-25 TUBING PATCH SUMMARY 12/22/04 BY BRIT AGLER Discussion: 1. Pollard Wireline ran a diagnostic Gas Lift Survey 11/26/04 that indicated a hole in the tubing @ 103' RKB. 2. Ran a PDS Multifinger Caliper Survey 12/3/04 to confirm a hole and the general condition of the tubing to the 4-1/2" x 3-1/2" crossover @ 6320'. Results indicate probable holes in Joint #2 @ 84' and 95'. Nothing shows at 103' but I consider it prudent to cover this area with the patch anyway. There are several other areas with pitting in the 40% -50% range in the 53' to 70' area as well. Therefore it is recommended to run two patches. Additionally there is a slight buildup in the ID of the tubing in various areas. Min. ID observed on the caliper run was 3.74" down to 120' - therefore it is recommended to brush the tubing and run a gauge ring prior to running the patches. Steve Tyler Workover Foreman / Engineering Tech Unocal Alaska (Office: (907) 263-7649 (Cell:, (907) 350-6295 (Home: (907) 696-1837 -----Original Message----- From: Thoma s Ma unde r [~~9.:.?::..~..!:.?..:...:t:.?..!!.:.....~.~.~Ede r@ad..~,~..~..:._§.!:..~.t._~._:..~.~..:._~.§) Sent: Tuesday, December 28, 2004 1:44 PM To: Steve Tyler Subject: King 25 Steve, I have received the sundry for setting a patch in this well. Could you provide a little description/discussion regarding the problem and solution?? Thanks, Tom Maunder, PE AOGCC 1 of 1 " f,(øl~ \ Ltr''' 12/29/2004 1:41 PM MEMORANDUM TO: Mike Bill Commissioner THRU: Tom Maunder Petroleum Engineer FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 20, 2003 SUBJECT: No-Flow Test Unocal / King Salmon PLT Well K-25 PTD: 1850780 McArthur River Field / TBU January 20, 2003: I traveled to Unocal's King Salmon Platform to witness a No-Flow Test on well K-25 in the McArthur River Field. Unocal representative Chuck Morse performed the test today in a safe and proficient manner. Well K-25 was lined up from the wing valve through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) and a 1/2" hose terminating in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test. Well K-25 meets the AOGCC requirements for a No- Flow status determination. Summary: I witnessed a successful No-Flow Test on Unocal's McArthur River Field well K-25 on the King Salmon Platform in Cook Inlet. Attachments: Well completion schematic (1) CC; Dwight Johnson / Dave Condon (Unocal) Operator: Unocal Date 1/20/2003 Operator Rep: Chuck Morse AOGCC Rep: Jeff Jones Fiel~nit/Pad MRF~,,T....BU/Kin§ Salmon · Well K-25 PTD: 1850780 G Liquid 7:30 AM 180 SCFH Gas Condensate droplets 8:00 AM ! 180 SCFH Gas Condensate droplets 8:30 AM 180 SCFH Gas Condensate droplets 9:00 AM <180 SCFH Gas Condensate droplets 9:30 AM <180 SCFH Gas Condensate droplets 10:00 AM <180 SCFH Gas Condensate droplets 10:30 AM <180 SCFH Gas Condensate droplets Produced to open top container through Armor-Flow meter model #3461-03T0. Flow meter calibrated by IISCO: 4/16/02 Total liquid produced: less than 1 quart. RJF 09/19/02 Page 1 of 1 NO-FLOW TBU King Salmon K-25 1-20-03 JJ.xls From: Jeff Jones 9077768850 To: Tom Maunder UNOCAL ) ~IC8 to TBG Hanger = 35.00~ SIZE WT 13-3/8" 61 9-5/8" 47 7" 29 Date: 1/22/03 Time: 4:39:5~,,~ Trading Ba.~ Jt King Salmon Platform Well # K-25 Current Completion 3/17/86 CASING AND TU~ING'bE-TAII, GRADE CONN TOP J-55 BTC 35' S-95/N80/L80 BTC 35' S-95/L-80 BTC 6481' SOTTOM 1997' 12373' 14373' 4-1/2' 12.6 N-80 BTC 35' 6320' 3-1/2" 9.2 N-80 BTC 6320' 13155' Page 2 of 3 3,4 LAST FILL TAG 13,963' dummy gun o~ 9/20/98 PBTD: 14,221' TD = 14~3' MAX HOLE ANGLE = 62° K25schm_9-30-98 perf. DOC 1. 2. 3. 4. 5. 6. 1 2 JEWELRY DETAIL Depth Item 281' 6320' 13099' 13128' 13144' 13156' Camco TRDP-1A SSSV nipple (ID = 3.813") 4-1/2" x 3-1/2' crossover Offs PBR (pinned 40,0ff)~) Baker 7" FHL packer (75,000~ sheaz) Camco NoGo nipple (ID=2.812") Bak~ WLEG and 3-1/2" tubing tail ,Gas Lift Information 2337' 4-1/2" Camco MMG w/R20 valve and RK latch 4883' 4-1/2" Camco MMG w/R20 valve and RK latch 6447' 8355' Iff)10' 11406' 12680' 12717' 3-1/2' Camco KB[X} w/BK valve and RK-2 latch 3-1/2' Camco KBUG w/BK valve and RK-2 latch 3-1/2" Camco KBUO w/BK valve and RK-2 latch 3-1/2" Camco KBUG w/BK valve and RK.2 latch 3.1/2" Camco KBUO w/BK valve and RK-2 latch 3-1/2" Camco KBUG w/BK valve and RK-2 I~t__eh PERFORATION DATA TOP BTM, ZONE SPF 13305 13340 H-I 4 13390 13420 H-2 4/8 13542 13586 H-3 4/8 13640 13760 H-4 4/8 13625 13811 H-4 4 13770 13800 H-4 4 13860 13900 H-5 4 13846 13898 H-5 4 DATE COMMENTS 9/29/98 Lost 621 pelf disks Alaska Oil & Gas Oor~.lSommmston R~. 05/19/99 DRAWN BY: TAB Attach to file: NO-FLOW TBU King Salmon K-25 1-20-03 33.xls ALASKA OIL AND GAS CONSERVATION COPl~IISSION January 31,2003 FRANK H, MURKOWSKI, GOVERNOI~ 333 W, 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Cook Inlet Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99501 RE: No-Flow Well Status TBU Well K-10RD TBU Well K-25 PTD 174-047 PTD 185-078 Dear Mr. Johnson: On December 30, 2002 AOGCC Petroleum Inspector Jeff Jones witnessed Safety Valve System (SVS) tests at UNOCAL's King Salmon Platform, Trading Bay Unit (TBU), McArthur River Field. The overall failure rate experienced was 16% (4 of 25 components). This performance requires that the SVS be re-tested in 90 days. The subsurface safety valves (SSSV) in wells K-10RD and K-25 failed the test and are of particular concern. Unocal personnel indicated the wells were considered "no-flow", however no records verifying authorization to remove the valves from service were provided. In addition, the Commission had no record that an Inspector had witnessed any "no-flow" test on these wells. Please explain why these wells were operating without operable SSSVs. Your response should be received by February 14, 2003. 20 AAC 25.265 (a) (2) requires that an offshore well capable of unassisted flow must be equipped with a fail-safe surface-controlled subsurface safety valve (SSSV). Removing or having an inoperative SSSV without prior authorization of the Commission is a violation of the regulation. Please provide the AOGCC a list of all offshore wells operating without SSSVs and the date of Commission approval by February 14, 2003. Inspector Jones subsequently witnessed "no-flow" tests on wells K-10RD and K-25 on January 20 - 21, 2003. No-flow tests are usually conducted at the Operator's request to seek approval to remove the sub-surface safety valve (SSSV). Over the course of the nearly 3 hour witnessed test periods, the performance of K-10RD (174-047) and K-25 (185-078) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. During the observation periods, the wells produced Iow volumes of gas with less than 1 quart of liquids each. Based on these satisfactory test results, these wells need not be equipped with a commission approved fail-safe automatic surface-controlle(~{~~~fe.~y~v~ Dwight Johnson January 31, 2003 Page 2 of'2 However, these wells must continue to be equipped with fail-safe automatic surface safety valve ("SSV") and associated equipment capable of preventing uncontrolled flow, which must be maintained in proper working condition. If for any reason either of the wells becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board King Salmon. Please contact me at 793-1250 with any questions. Sincerely, ' Tom Maunder, PE Sr. Petroleum Engineer SCANNED FED 0 4 2D03 Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) 08/01/01 RECEIVED AUG 0 i 2001 Alaska 0il & Gas Cons. CommJssi0n Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform Approved and Proposed Annulus Disposal Wells Well K-6RD (Approved) Well K-12RD Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the AOGCC to dispose of drilling waste from proposed drilling on the Monopod platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you. Two wells, K-6RD and K-19, were approved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1RD, K-13RD2, K-18RD and will be used for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workovers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exceeding the 35,000 bbl limit on any one annulus. Therefore, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King. doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings. Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform-and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long term storage of cuttings in drums. The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as they are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The Monopod-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mUd cuttings from the Monopod platform to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001: If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request:. Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular Injection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface R E C ~=' t V ~ L~ 8. Well number 731' FSL & 142' FEL of Sec. 17, T9N, R13W, SM King Salmon K-25 / At top of productive interval 9. Permit number / 3074' FSL & 3239' FEL of Sec19, TgN, R13W, SM FEB 1 5 Z001 85-78 ./ ,. At effective depth 10. APl number//' 2370' FSL & 2983' FEL of Sec 19, TgN, R13W, SM Alaska 0il & Gas Cons. Commission 50- 733-.~180-01 At total depth Anchorage 11. Field/P/e'ol 2255' FSL & 2945' FEL of Sec 19, TgN, R13W, SM Mc/~ur River/Hemlock Pool 12. Present well condition summary Total depth: measured 14,373 feet Plugs (measured) true vertical 9,686 feet q( / Effective depth: measured 14,221 feet Junk (measured) ~'~' ~one ' Casing trueve~inCalth 9,594 Slzefeet Cemented ~'/~"//YMeasureddepth Trueverticaldepth iStructural ' ~,~_~/ Measured dep ' Conductor 396' 24" Circ to Su~y' 396' 396' Surface 1997' 13-3/8' 1260 sx circ/t'o surf 1997' 1997' I;~oe rd um~fidior~te 12373' 9-5/8" 75~x 12373' 8536' liner 7892' 7' ~ /l~50sx _ 6481'-14323' 5109'-9637' Perforation depth: measured 13305'-13340', 13390~1342~ 1~4~', 13629'-13815', 13850'-13902' true vertical 9061 '-9081 '~'~' 9 9195'-9220', 9244'-9350', 9370'-9402' · Tubing (size, grade, and measured depth) 4.~ ~1~, N-80 @ 6320', 3-1/2', 9.2#, N-80 @ 6320'-13156'' Packers and SSSV (type and measured depth) ~, I~. ~iker I~-IL-1 packer @ 13,128' ~.1~~ ~A ~ retrievable SSSV @ 281' 14. Estimated date for commencing operation '~./...// 15. Status of well classification as: · 3/1/00 '"'./ 16. If proposal well verbally approved: / Oil: X Gas: Suspended: / Name of approver .// Date approved Service: 17' I here~ertify tibet t~eg°ing is true an~'~°rrect t° the best °f mY kn°wledge' ' "- ~'1~ "' Sign e(~~/~jJ~J~J~/am so n Title: Drilling Manager Date: ,,~ ~ / FOR COMMISSION USE ONLY Conditions of approval: NolJfy Commissigh so representative may witness IApproval No. Plug integrity~ / BOP 'lest __ - Location clear.~ance. I ,"~ Mechanical Integrity ~/t/ _ Subsequent form required 10- / Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ._ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager February 14, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Sundry Application (Form 10-403) McArthur River Field, King Salmon Platform, Well K-6RD Well K-12RD Well K-25 Well K-26RD Applications for Annulus Injection Commissioner Heusser: Enclosed are Sundry Applications (Form 10-403) for King Salmon Well #K-6RD, K-12RD, K- 25 and K-26RD. Unocal requests permission to dispose of oil-based mud and cuttings from the upcoming drilling program at King Salmon into the 9-5/8" x 13-3/8" annulus at these four wells in addition to the annulus of K-19 which had a Sundry Application Form 10-403 submitted 12/28/00. The 1planned drilling program at King Salmon will be K-1 RD2, K-13RD2, K-5RD, K-20RD and potentially K-18RD. There are five proposed annuli because if one of the annuluses becomes plugged during disposal operations, the process can continue in the remaining four annuli. The attached pages to each Sundry Application provide information required under 20 AAC 25.080 regarding annulus disposal. Also included for all four applications is a summary of all the surface casing cement jobs at King Salmon and a summary of leak-off tests performed beneath the surface casing. There has been no prior annulus disposal at any of the wells at King Salmon platform according to ARCO and Unocal records and production personnel on the platform are not aware of any prior annulus disposal at King Salmon. The expected start date for annulus disposal is March 1, 2001 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager RECEIVED FEB 1 5 2001 Alaska 0il & Gas Cons. Commission Anchorage AOGCC cover letter K-25.doc Tim Billingsley UNOCAL ) RKB to TBG Hanger = 35.00' 3,4 LAST FILL TAG @ 13,963' w/2.50" dummy gun on 9/20/98 PBTD = 147221' TD = 14,373' MAX HOLE ANGLE = 62° K25schACT.DOC SIZE WT Trading Bay Unit King Salmon Platform Well # K-25 Current Completion 3/17/86 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 24" 35' 396' 13-3/8" 61 J-55 BTC 35' 1997' 9-5/8" 47 S-95fN80/L80 BTC 35' 12373' 7" 29 S-95/L-80 BTC 6481' 14323' Tubing: 4-1/2" 12.6 N-80 BTC 35' 6320' 3-1/2" 9.2 N-80 BTC 6320' 13155' JEWELRY DETAIL NO. Depth Item 1. 281' 2. 6320' 3. 13O99' 4. 13128' 5. 13144' 6. 13156' Camco TRDP-1A SSSV nipple (ID = 3.813") 4-1/2" x 3-1/2" crossover Otis PBR (pinned 40,000#) Baker 7" FI-IL packer (75,000g shear) Camco NoGo nipple (ID=2.812") Baker WLEG and 3-1/2" tubing tail Gas Lift Information 1 2337' 4-1/2" Camco MMG w/R20 valve and RK latch 2 4883' 4-1/2" Camco MMG w/R20 valve and RK latch 3 6447' 3-1/2" Camco 4 8355' 3-1/2" Camco 5 10010' 3-1/2" Camco 6 11406' 3-1/2" Camco 7 12680' 3-1/2" Camco 8 12717' 3-1/2" Camco KBUG w/BK valve and RK-2 latch KBUG w/BK valve and RK-2 latch KBUG w/BK valve and RK-2 latch KBUG w/BK valve and RK-2 latch KBUG w/BK valve and RK-2 latch KBUG w/BK valve and RK-2 latch PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13305 13340 H-1 4 13390 13420 H-2 4/8 13542 13586 tt-3 4/8 13629 13815 H-3&4 4 13640 13760 H-4 4/8 9/29/98 Lost 621 disks 13770 13800 H-4 4 13860 13900 H-5 4 13850 13902 H-5 4 9/24/98 Lost 135 perf disks RECEIVED FEB 1 15 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage REVISED: 01/24/01 DRAWN BY: TAB Information Required for Annulus Disposal of Drilling Waste 20 AAC 25.080 K-25 Annulus to be used for disposal: K-25, 9-5/8" x 13-3/8" annulus, 13-3/8" shoe is at 1997' MD/1997' TVD. RECEIVED FEB 1 5 2001 Alaska Oil & Gas Cons, Commissior~ Anchorage 2 Depth to the base of freshwater aquifers and permafrost There is no permafrost at the King Salmon platform. At the 13-3/8" casing shoe depth of 1997' MD/1997' TVD for K-25, the formation waters exceed 6000 ppm chlorides. Also, there is a fresh water exemption for wells at the King Salmon platform. Stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission findinq that the waste will be confined and will not come to the surface or~ except to the extent allowed under (e) I of this section, contaminate freshwater The 13-3/8" shoe is at 1997' MD/1997' TVD in K-25. This corresponds to the Middle Tyonek formation. The waste is expected to be confined within this strata as this is the primary gas trap in the McArthur River Field with no evidence of surface breaching. List of all publicly recorded wells within ~ mile, and all publicly recorded water wells within one mile, of the well that will be receiving drilling waste The attached plat shows the adjacent wells to King Salmon K-25. Types and maximum volume of waste to be disposed of and the estimated density of the waste slurry The waste will consist of 9.0 ppg oil base mud with small concentrations of drill cuttings mixed with high concentrations of fresh wash water (appx. 90/10 ration of water/OBM). The density of the waste will be appx. 8.8 ppg. Seawater will be injected ahead and behind the waste slurry injections. The estimated maximum volume from the five potential redrills to be disposed of is 8,000 bbls OBM/water and 26,000 bbls seawater. Description of any waste souqht to be determined as drillinq waste under (h){3) of this section: 20 AAC 25.080(h)(3) Other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. None at this time. Estimate of the maximum anticipated pressure at the outer casinq shoe durinq disposal operations and calculations showinq how this value was determined. An injectivity test was performed on the 9-5/8" x 13-3/8" annulus of K-25 on 10/26/00 and 800 BWPD was injected at 1050 psi. The maximum injection pressure while disposing of mud and cuttings down the K-25 annulus will be 1500 psi. The proposed 1500 psi limit on injection pressure will not cause a problem with 13-3/8" casing burst or 9-5/8" casing collapse as shown in item #9. Details that show that the shoe of the outer casinq is set below the base of permafrost, if present, and any freshwater aquifer,other than freshwater excepted under ¢e)(1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include (A) cementing records; and (B) a cement aualitv Ioq or formation integrity records; The 13-3/8" shoe on K-25 was set at 1997' MD/1997' TVD which is below any freshwater aquifer. (A) The casing was cemented on 3/24/69 with 860 sx (1789 cuft or 319 bbls) of 12.8 ppg lead cement and 400 sx (82 bbls) of 15.8 ppg tail cement. Full returns were observed throughout the job with "good cement returns to surface". The well was known as "K-16" in 1969 when it was first drilled and completed. When the well was redrilled in 1985, the 9-5/8" casing was cut and pulled and an open hole kick-off was performed. The redrilled well was named "K-25". (B) No bond log was run on the 13-3/8" casing. There also was no leak off test below the 13-3/8" shoe when the well was first drilled in 1969 as K-16. However, in 1985, the 9-5/8" casing was cut and removed and the well was redrilled as K-25 from an open hole kick- off plug. A leak-off test was perfomred on 6/26/85 after kicking off from the open hole cement plug at a depth of 2202' MD/2202' TVD. The LOT was 11.5 ppg EMW. This is based on the 13-3/8" shoe depth of 1997' MD/1997' TVD and 9.1 ppg mud which was pumped away at 250 psi. Details that show that the inner and outer casinq strings have sufficient strenqth in collapse and burst to withstand the anticipated pressure of disposal operations: The 13-3/8" outer casing in K-25 is 61#, J-55 which has a burst rating of 3090 psi for new pipe. Therefore, the anticipated maximum injection pressure of 1500 psi will not be a problem and will only be 49% of new pipe burst rating. The 9-5/8" inner casing in K-25 is as follows: RECEIVED 47#, L-80 from surface to 7903', collapse rating = 4750 psi 47#, N-80 from 7903' to 10,178', collapse rating = 4750 psi 47# S-95 from 10,178' to TD of 12,373', collapse rating = 5080 psi 7" 29# L-80 liner top at 6481 ', collapse rating = 7020 psi FEB I 5 2001 Alaska 0il & Gas Cons. Commission Anchorage The collapse force exerted by the anticipated maximum injection pressure to 1500 psi on the 9-5/8" x 13-3/8" annulus would be: (1500 psi + (8.8 ppg x .052 x TVD)) minus the internal gas lift pressure on the 9-5/8" x tbg inner annulus which is 1020 psi. The worst case would be just above the top of the 7" liner at 6481' MD/5109' TVD in the 9-5/8" 47# L-80 which would be: ((1500 psi + (8.8 ppgx.052x5109'))-1020 psi =2818 psi = 59% of new collapse rating of 4750 psi for 9-5/8 47#, L-80 casing 10 11 This collapse pressure is acceptable and there will be a requirement placed on the annulus disposal crews to verfiy that the K-25 inner annulus does have 1020 psi in gas lift pressure before injecting in the outer 13-3/8" x 9-5/8" annulus. The injectivity test in K-25 on 10/25/00 indicated the formation below 1997' MD/1997' TVD will readily take flUid at 1050 psi. Therefore, the actual disposal pressure will be probably be less than 1500 psi but will not be allowed to exceed 1500 psi. The downhole pressure obtained during a formation inteqrity test conducted below the outer casinq shoe; Originally, K-25 was named K-16. K-16 was drilled in 1969 by ARCO. There was no leak-off test performed when the 12-1/4" hole was drilled below the 13-3/8" casing shoe at 1997' MD/1997' TVD. When the well was redrilled in 1985 by ARCO, the well was renamed K-25. The 9-5/8" casing was cut and pulled all the way back to surface. An open hole cement plug was utilized to kick-off the redrill. On 6/26/85, a leak-off test was performed after drilling off the cement plug at 2202' MD/2202' TVD with 9.1 ppg mud. The pressure built to 250 psi before leaking off which equates to a 11.5 ppg EMW at the 13-3/8" shoe depth of 1997' TVD. There was no indication of any circulation to surface so this would indicate a frac gradient of .60 psi/fi. On 10/26/00, an injectivity test with 8.5 ppg filtered inlet water was performed down the 9- 5/8" x 13-3/8" annulus of K-25. The test injection rate was 800 BPD at 1050 psi. The 13- 3/8" x 24" annulus was monitored during this test. There was no communication up to the 24" conductor set at 396' during the injectivity test. Due to the Iow frac gradient and the record of good 15.8 ppg tail cement around the 13-3/8" shoe, all of the injection was entering the formation below the 13-3/8" shoe and not migrating around and up the outside of the 13-3/8" casing shoe. As per 20 AAC 25.080(e)(2), Unocal requests the AOGCC to grant an exception for the downhole disposal pressure exceeding the downhole pressure obtained during the formation integrity test conducted below the outer casing shoe in 1985. The proposed maximum disposal pressure of 1500 psi at the surface with 8.8 ppg disposal slurry as opposed to the 250 psi with an 9.1 ppg mud during the leak off test in 1985 is justified due to the good 15.8 ppg tail slurry pumped at the 13-3/8" casing shoe with cement circulated to surface, the evidence of no communication up to the 24" conductor shoe at 396' during the injectivity test, and the geological interpretation that the Middle Tyonek formation is sufficiently confined with no evidence of surface breaching in the McArthur River Field. Identification of the hydrocarbon zones, if any~ above the depth to which the inner casing is cemented; The 13-3/8" shoe is at 1997' MD/1997' TVD and the 9-5/8" shoe is at 12,373' MD in K-25. There is a 7" liner top at 6481'. There was a bond log run on the 9-5/8" casing on 8/23/85. The top of cement on the bond log is 11,210' MD. The open annulus in K-25 is therefore from 1997' MD/1997' TVD to 11,210' MD/7927' TVD which is in the Middle Tyonek of the Main Feature of the McArthur River Field. This interval in K-25 is Iow on structure and there are no hydrocarbons present. 12 The duration of the disposal operation, not to exceed 90 days; RECEIVED FEB 1 5 2001 Alaska Oil & Gas Cons, Commission Anch0ra¢le 13 Unocal requests permission to use K-25's 9-5/8" x 13-3/8" annulus for oil based mud and cuttings disposal for more than 90 days. It is anticipated that the workover/drilling program at King Salmon will be 3 workovers and up to 5 major redrills. The first drilling well will be K-1 RD and disposal from this drilling well should commence about 3/1/01 and the entire drilling program could last until December 1, 2001. Disposal operations for the drilling mud from the five drilling wells should be completed by December 31, 2001. There will be applications for annulus disposal at four other wells at King Salmon in case one or more annuli become plugged. The five wells which will be applied for annulus disposal are: K-6RD, K-12RD, K-19, K-25 and K-26RD. Whether drilling waste has previously been disposed of in the annular space of the well and, if so, a summary of the dates of the disposal operations~ the volumes of waste disposed oft and the wells where the drillinq waste was qenerated; No drilling waste has previously been disposed of in the annular space of K-25. There has also been no known annulus disposal at any of the other King Salmon wells. 14 The well where the drilling waste to be disposed of was or will be generated; 15 16 The 2001 proposed drilling program consists of K-1 RD, K-13 RD, K-20RD, K-5RD and possibly K-18RD. There will also be 3 workovers at K-15RD, K-24RD and K-30. Fluids from these three workovers will not be disposed of in the K-25 annulus. If the operator proposes not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent; Compliance with section (d) limitations as outlined below will not be a problem. The commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well. (2) For a period longer than one year through the annular space of a single well (3) Into a hydrocarbon-bearing stratum; or (4) Through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. Any additional data required by the commission to confirm containment of drillin~ waste; The attached spider plot describes K-25's 13-3/8" casing shoe in relation to other King Salmon wells' 13-3/8" shoes. In order to verify that the proposed annulus injection in K- 25 does not communicate to other wellbores, Unocal proposes to monitor the following four 9-5/8" x 13-3/8" annuli: K-6RD, K-15RD, K-4RD, and K-12RD. These four wellbores are close to K-25 and in different directions from K-25 thereby surrounding the proposed injection point with monitoring locations. RECEIVED FEB I 5 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage King Salmon Platform Surface Casing Cement Summary Well Surf Csg Size Shoe MD Shoe TVD Cmt Volume, sx Comments K-1 RD 13-3/8" 2384' 2147' 2608+80 Tag firmcmt at 82', pump 8o sx top job with cmt to surf "' . K-2RD 13-3/8" 2372' 2298' 2608+450 Lost returns during primary job, pump 450 sx top job @ 350' with cmt to surf K-3RD 13-3/8" 2506' 2337' 1560 No top job required No cmt to surf on 3675 sx primary job. Top job found TOC @ 125', pump 125 sx with K-4RD 13-3/8" 2880' 2769' 3675+125 Rood cmt to surf K-5 13-3/8" 2476' 2252' 1625 Cmt returns to surf K-6RD 13-3/8" 2186' 2088' 1760 Cmt returns to surf K-7RD 13-3/8" 3618' 3039' 1600 650 sx 1st stage and 950 sx thru DV tool @ 1480' K-9 13-3/8" 2492' 2360' 1625 No top job required K-10RD 13-3/8" 4998' 3883' 2255 1300 sx 1st stage, 955 sx thru DVT @ 1511', 335 sx cmt returns to surf , K-11 13-3/8" 2470' 2400' 1550 Cmt circ to surface, 500 cuff K-12RD 13-3/8" 25'10' 2429' 1500 Cmt circ to surface, 150 sx. "k_l 3RD 13-3/8" 5011' 4166' 1050+200 650 sx 1st stage, 400 sx thru DVT @ 2509', 200 sx top job @ 180' with 25 sx to..surf K-15RD 13-3/8" 2401' 2284' .1550 Cmt circ to surf, 500 cuff K-17 13-3/8" 2183' 2032' 1371 Cmt circ to surf~ 350 cuff K-18 13-3/8" 2477' 2283' 1800 Cmt circ to surf, 1030 cuff K-19 13-3/8" 2591' 2302' 1750 Cmt circ to surface, 800 cuff K-20 9-5/8" 4999' 2899' 2325 1400 sx 1 st stage, 925 sx thru DVT @ 1396', circ 150 sx cmt to surf on 2nd stag'e K-21 RD 13-3/8" 2714' 2390' 1775 Cmt circ to surface, 798 cuff K-22RD 13-3/8" 5493' 4825' 2200+500 1500 sx 1 st stage, 700 sx thru DVT @ 2881 ', 500 sx (905 cuff) bradenhead top job K-23 13-3/8" 5005' 3940' 2387 Cmt circ to surface K-24RD 13-3/8" 5712' 4229' 2412 Cmt circ to surface, '798 cuff K-25 13-3/8" 1997' 1997' 1260 Originally known as K-16, cmt circ to surface K-26RD 13-3/8" 2938' 2710' 2050 Cmt circ to surface, 80 bbls. K-30RD 13-3/8" 2187' 2012' 1490 Cmt circ to surface Bold indicates updated information from K-19 12/28/00 info and 1/23/01 info. Tim Billingsley KS surf csg cmt and LOTsummary.xls 1/26/01 , King Salmon Platform Surface Casing Leak-off Test Summary Well Surf Cs~l Size Shoe MD Shoe TVD LOT, ppg Comments K-1 RD 13-3/8" 2384' 2147' No leak-off test performed below 13-3/8" shoe, 1 i/2/67 K-2RD 13-3/8" 2372' 2298' No leak-off test performed below 13-3/8" shoe, 11/10/67 K-3RD 13-3/8" 2506' 2337' No leak-0ff test performed below 13-3/8" shoe, 10/68 K-4RD 13-3/8" 2880' 2769' No leak-off test performed below 13-3/8" shoe~ 1/15/68 K-5 13-3/8" 2476' 2252' No leak-off test performed below 13-3/8" shoe, 2/26/68 No leak-off test performed below 13-318" shoe, 2/26/68, on original K-6 well. K-6RD had 9-5/8" cut and pulled and an open hole kick-off; LOT on 4110188 @ K-6RD 13-3/8" 2186' 2088' 15.0 ~95' MD/2190' TVD was.15.0 ppg EMW. K-7RD 13-3/8" 3618' 3039' No leak-off test performed below 13-3/8" shoe, 7/9/68 K-9 13-3/8" 2492' 2360' No leak-off test performed below 13-3/8" shoe, 5/28/68 K-10RD 13-3/8" 4998' 3883' . No leak-off test performed below 13-3/8" shoe, 1/24/69 K-11 13-3/8" 2470' 2400' No leak-off test performed below 13-3/8" shoe, 10/3/68 No leak-off test performed below 13-3/8" shoe, 12/9/68, on original K-12 well. K-12RD had 9-5/8" cut and pulled and open hole kick-off Just below 13-3/8' shoe K-12RD 13-3/8" 2510' 2429' but no LOT on 8/19/78, K-13RD 13-3/8" 5011' 4166' :No leak-off test performed below 13-3/8" shoe, 12/6/68 K-15RD 13-3/8" 2401' 2284' No leak-off test performed below 13-3/8" shoe, 2/18/69 K-17 13-3/8" 2183' 2032' 10.6 i2/5/73, pumped into formation at 150 psi with 9.2 ppg mud @ 2257' MD/2091' TVD K-18 13-3/8" 2477' 2283' 10.3 :6/4/73, pumped into formation at 125 psi with 9.3 ppg mud @ 2492' MD/2295' TVD K-19 13-3/8" 2591' 2302' 11.3 13/1/74, pumped into formation at 325 psi with 8.6 ppg mud @ 2637' .MD/2336' TVD K-20 9-5/8" 4999' 2899' No leak-off test performed below 9-5/8" shoe, 7/17/69 K-21 RD 13-3/8" 2714' 2390' No leak-off test performed below 13-3/8" shoe, 5/23/75 K-22RD 13-3/8" 5493' 4825' 11.3 2/17/75, pumped into formation at 550 psi with 9.1 ppg mud @ 5560' MD/4852' TVD K-23 13-3/8" 5005' 3940' 12.5 2/9/78, pumped into formation at 625 psi with 9.5 ppg mud @ 5070' MD/4000' I'VD K-24RD 13-3/8" 5712' 4229' No leak-off test performed below 13-3/8" shoe, 10/28/79 Originally known as K-16, no LOT on 3/23/69. K-25 had 9-5/8" cut and pulled and an open hole kick-off: LOT on 6/26/85 @ 2202' K-25 13-3/8" 1997' 1997' 11.5 @ shoe MD/2202' TVD with 9.1 ppg mud pumped away @ 250 psi. '12/23/93, pumped into formation @ 735 psi with 8.6 ppg mud @ 2946' MDI2716' K-26 RD 13-3/8" 2938' 2710' 13.8 TVD K-30RD 13-3/8" 2187' 2012' No leak-off test performed below 13-3/8" shoe, 1/29/70 , , Bold indicates updated information from K-19 12/28/00 info and 1/23/01 info. RECEIVED Tim Billingsley FEB i 5 2001 Alaska Oil & Gas Cons. Commission Anchorage KS surf csg cmt and LOTsummary.xlsLOTs ! SCALE IN FEET K-10 +.._.---- K-10RD K-1 K-§RD K-i~ G-29RD 0-27 30 K-3RD O-15 G-13 ~9 / A-27 -25 K-17 .t~ .tO ~o (oH) G-25 ~radmg Bay Unit Boundary 9N 13W K-6RD ., K-2RD K-22RD J 3883'~ ing~Prop Plats~King Prop OBMud Disp Wells-K~!'i~:5.Dwg 0 I1,000 2400: 2,000 i SCALE IN FEET 3,000 2284'(K-15! -~?) rtl I M-30 21 K-6 K-2 · STATE OF ALASKA ALASKA (JIL AND GAS CONSERVATION t.,OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development: X KB 100' above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Trading Bay Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 731' FSL, 142' FEL, Sec. 17, T9N, R13W, SM K-25 At top of productive interval 9. Permit number/approval number 3074' FSL, 3239' FEL, Sec. 19, T9N, R13W, SM 85-78 At effective depth 10. APl number 2370' FSL, 2983' FEL, Sec. 19, T9N, R13W, SM 50- 733-20180-01 At total depth 11. Field/Pool 2255' FSL, 2945' FEL, Sec. 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 14373 feet Plugs (measured) 14221 true vertical 9686 feet Effective depth: measured 14221 feet Junk (measured) 13963 true vertical 9594 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1997' 13-3~8" Yes 1997' 1997' Intermediate 12373' 9-5~8" Yes 12373' 8536' Production Liner 7892' 7" Yes 6481 '-14323' 5109'-9637' Perforation depth: measured 13,305'-13,340', 13,390'-13,420', 13,542'-13,586', 13,629'-13,815', 13,850'-13,902' true vertical 9061'-9081', 9108'-9126', 9195'-9220', 9244'-9350' 9370'-9402' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80,BTC @ 6320'; 3-1/2" 9.2#, N-80, BTC from 6320'-13,155'i;¢.,~"";' ~' ~:~.'~"~ ~ ' ~ ~. ?..~, Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 281'; Baker FHL Packer @ 13,128' 13. Stimulation or cement squeeze summary Intervals treated (measured) 0R1G~NAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 276 4600 1320 140 Subsequent to operation 350 4300 1320 140 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCALe) RKB to TBG Hanger = 35.00' LAST FILL TAG @ 13,963' w/2.50" dummy gun on 9/20/98 3,4 PBTD = 14,221' TD = 14,373' MAX HOLE ANGLE = 62° K25schACT.DOC TOP 13305 13390 13542 1362.9 13640 13770 13860 13850 SIZE WT Trading Bay Unit King Salmon Platform Well # K-25 Current Completion 3/17186 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 61 J-55 BTC 35' 1997' 9-5/8" 47 S-95/N80/L80 BTC 35' 12373' 7" 29 S-95/L-80 BTC 6481' 14373' Tubing: 4-1/2" 12.6 N-80 BTC 35' 6320' 3-1/2" 9.2 N-80 BTC 6320' 13155' JEWELRY DETAIL NO. Depth Item 1. 281' 2. 6320' 3. 13099' 4. 13128' 5. 13144' 6. 13156' Camco TRDP-1A SSSV nipple (ID = 3.813") 4-1/2" x 3-1/2" crossover Otis PBR (pinned 40,000g) Baker 7" FHL packer (75,000g shear) Camco NoGo nipple (ID=-2.812") Baker WLEG and 3-1/2" tubing tail Gas Lift Information 2337' 4-1/2" Camco MMG w/R20 valve and RK latch 4883' 4-1/2" Camco MMG w/R20 valve and RK latch 6447' 3-1/2" 8355' 3-1/2" 10010' 3-1/2" 11406' 3-1/2" 12680' 3-1/2" 12717' 3-1/2" Camco KBUG w/BK valve and RK-2 latch Camco KBUG w/BK valve and RK-2 latch Camco KBUG w/BK valve and RK-2 latch Camco KBUG wfBK valve and RK-2 latch Camco KBUG w/BK valve and RK-2 latch Camco KBUG w/BK valve and RK-2 latch PERFORATION DATA BTM ZONE SPF DATE COMMENTS 13340 H-1 4 13420 H-2 4/8 13586 H-3 4/8 13815 H-3&4 4 13760 H-4 4/8 9/29/98 Lost 621 disks 13800 H-4 4 13900 H-5 4 13902 H-5 4 9/24/98 Lost 135 perf disks REVISED: 11/05/98 DRAWN BY: TAB K-25 Coil Tubing Cleanout and Reperf Daily Summary of Operations 9/18/98 to 9/30/98 9/18/98 RU 1-3/4" coil tubing unit on K-25. Test BOPE to 200 psi and 5000 psi. RIH with mud motor and 3.8" drag bit. Start pumping at 500' and continue RIH with no indications of scale, tag 4-1/2" x 3-1/2" crossover at 6213'. POOH 9/19/98 RIH with 2.72" drag bit. Tag hard scale at 9950', mill through with no problem and continue RIH while circ to 10,650'. Pump sweep to clean hole. Continue RIH to tubing tail at 13,160'. POOH to 6320' and RIH to 13,500' while circ to clean up hole. 9/20/98 RIH from 13,500' to 13,864', check pick-up weight -- 35,500. Unable to clean out deeper due to max pick up weight for coil. Circ hi vis sweep and POOH. RD coil tubing unit. RU slickline and RIH with 2-1/2" dummy gun. Tag fill at 13,963' and POOH. RD slickline. 9/23/98 RU Schlumberger perfunit. Log GR/CCL from 13,932' to 11,900' for perftie-in log. 9/24-29/98 Perforate with 2-1/8" Enerjet guns as shown on attachment: k-25daily summary.doc 1 PERFORATION DATA SHEE'f King Salmon K-25 Perforate Hemlock 2-1/8" Enerjet Guns, 4 HPF, 0 deg phasing Date Zone Interval MD Interval TVD 9/29/98 HB 3&4 13,629'-13,815' 9244'-9350' 9/24/98 HB 5 13,850'-13,902' 9370'-9402' Perforations Open to the Wellbore MD TVD 13,305'- 13,340' 13,390'- 13,420' 13,542'- 13,586' 13,629'-13,815' 13,850'-13902' 9061'-9081' 9108'-9126' 9195'-9220' 9244'-9350' 9370'-9402' k-25perfdata. DOC Tim Billingsley 11/5/98 Alaska Region Unocal North American~--.- Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL COMM RES ENG ~ SR ENG SR ENG ENG ASST ENG ASST SR G E O_~, ~-~ O-E' ASST GEOL ASST STAT TECH STAT TEC-H~ FILE i November 10, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: On July 9, 1991 an Application for Sundry Approval, number 91-201 was approved to perforate well K-25 in the Trading Bay Unit. However, after researching the files, I~ve found that the work was never done. Ralph P. Holman RECEIV£D NOV 1 5 '1995 Aiaska Oil & Gas Cons. Commission Anchorage Unocal North American~.~, Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region November 10, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: On ~_~ry 2~20~0, 1990~he following intervals were perforated in well K-25 at 4 shots per foot, 0°Phasing: BENCH TOP BOTTOM TOTAL HB2 13,390' 13,420' 30' HB3 13,556' 13,586' 30' HB4 13,650' 13,680' 30' I-{B4 13,695' 13,715' 20.__~' TOTAL 110' Sincerely, Ralph P. Holman Engineer Technician RPI-I/rph RECEIVED NOV 1,5 1 -g,,x Alaska Oil & Gas Cons. Commission Anchorage ..... STATE OF ALASKA . ALASKA _ AND GAS CONSERVATION OCr~-''~.SSION ~/~ REPORT OF SUNDRY WELL OPE ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other J~/~'/~? 2. Name of Operator -- 5. Type of W-~l: 6. Datum ei-eevation (DF or KB) Unocal Development X KB 100' above MSL F_xpk)ratory feet ~..~ ..... Strafigraphic P.O. BOX 196247 Anchorage, Alaska 99519-6247 Service Trading Bay Unit K-25~ 9. Permit number/approval number 4. Location of well at surface 731' FSL, 142' FEL, Sec. 17, TDN, R13W, SM At top of productive interval 3074' FSL, 3239' FEL, Sec. 19, TDN, R13W, SM 85-78 At effective depth 10. APl number 2370' FSLI, 2983' FEL, Sec. 19, TDN, R13W, SM 50-733-20180-01 At total depth 11. Field/Pool 2255' FSL, 2945' FEL, Sec. 19, TDN, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 14373 feet true vertical 9686 feet Plugs (measured) 14221 Effective depth: measured 14221 feet true vertical 9594 feet Junk (measured) 13960 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True vertical depth 1997' 13-3/8" Yes 1997' 1997' 12373' 9-5/8" Yes 12373' 8536' 7892' 7" Yes 6481'- 14323' 5109'- 9637' 13305 - 13340,13390 - 13420,13542 - 13586,13640 - 13760,13770 - 13800, 13860 - 13900 9040 - 9060,9088 - 9105,9175 - 9199,9229- 9298,9304 - 9321,9357 - 9381 13. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 BTC @ 9320'; 3-1/2", 9.2#, N-80 BTC from 6320' - 13155' Packers and SSSV (type and measured depth) Camco TRDP 1 -A SSSV @ 281 '; Baker FHL pkr. @ 13128' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED NOV 1 5 1993 Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 336 1832 844 3842 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X_ Gas __ Suspended _ Service 117., her~ce~:rfy~:~ ,~nd correct to the best of my knowledge. Signed /'~-1~'~"'4~Y~ Title ~'~ 0,.[L,t.i.,~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 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 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS'20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversations conceming the subject, it had been explained to me that either ARCO or Marathon had been the sub-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, Joan Miller Statistical Technician Well Permit No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Tradinq Bay Unit Description Perforate 2-91 Perforate 5-91 Workover 4-91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush , G. Bush G-5 67-71 G-6 82-33 3/15-91, 91-086 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this well Perf. 10-19-91 Perf 4-92 G. Bush G. Bush G. Bush G-17 78-3 G-19 69-17 G-21 72-42 G-27 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 K-9 68-38 11-1-91, 91'331 11-10-92, 92-238 4-21-92, 92-094 6-17-93, 93-154 4-21-92, 92-95 1-6-93, 92-203 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate Temp. log 10-15-92 Perf 4-92 Coil tubing cleanout Perforate Convert to inj. Production profile Perforate 2/90 Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 Perforate 2/90 Repair well, p. tubing, stimulate, perforate G. Bush G. Bush G. Bush R. Schmidt G. Bush R Schmidt G. Bush R. Roberts R. Roberts G. Bush G. Bush R. Roberts R. Roberts Well Permit Approval No. No. Date & No. K-17 73-1 7-9-91, 91-198 K-25 -85~7~8~;~r~-~ ~ 2-9-90, 90-079 7-9-91, 91-201 M-25 87-86 11-1-91, 91-326 M-28 90-19 7-30-91, 91-224 8-27-91, 91-252 9-20-91, 91-285 -2- Description Perforate 6/91 Perforate 2/90 Perforate 6/91 Perf. G/WF intervals & rerun jet pump 10-22-91 Perf. & evaluate BWF potential 7-14-91 Install jet pump, pump-in test 8-15-91. Ba~al W/F Refrac 9/91 10-403 Signed By G. Bush R. Roberts G. Bush G. Bush G. Bush G. Bush G. Bush STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~blIS~ .ON APPLICATION FOR SUNDRY Suspend m Operation Shutdown m Re-enter suspended well _ Plugging __ Time extension _ Stimulate Repair well Pull tubing Variance Perforate 1. Type of Request: Abandon Alter casing __ Change approved program 2. Name of Operator UNOCAL Corporation (AR(~O Alaska. Inc. is sub-ooeratorl 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 731' DSL, 142' FEL, Sec. At top of productive interval 3074' FSL, 3239' FEL, At effective depth 2370' FSL, 2983' FEL, At total depth 2255' FSL, 2945' FEL, 5. Type of Well: 6. Datum elevation (DF or KB) Development X Exploratory _ 1~)0' KB above MSL feet Stratigraphic _ 7. Unit or Property name Set, ce __ Trading Bay Unit 8. Well number K-25 9. Permit number 10. APl number __50-773-201 86 11. Field/Pool Hemlock R ¢EIVED 12. 13. Attachments Description summary of proposal _ Detailed operation program .X_._ BOP sketch Proposed perforations attached. 14. Estimated date for commencing operation June, 1991 16. If proposal was verbally approved Name of approver Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 1 962' 1 3- 3/8" yes Intermediate 1 2 3 3 8' 9-5/8" yes Production Liner 7892' 7" yes Perforation depth: measured 13305-13340' ;13390-13420' ; 13770-13800' ;13860-13900' true vertical 9061-9086' ; 9109-9126' ; 9324-9341'; 9377-9401' Tubing (size, grade, and measured depth 14373' feet Plugs (measured) 14221' 9686' feet 14221' feet Junk (measured) 13960' 9594' feet Size Cemented Measured depth 1997' 1997' 12373' 8536' 14373' 9686' 13542-13586' ; 13640-13760' ; 9195-9220' ; 9251-9318' ; 4-1/2", 12.6#, N-80 BTC @ 6320' MD ; 3-1/2", 9.2#, N-80 BTC fm. 6320'-13155' MD Packers and SSSV (type and measured depth) Camco TRDP 1-A SSSV @ 281' MD; Baker FHL pkr @ 13128' MD Date approved 15. Status of well classification as: Oil X Gas Suspended Service J U L - 9 !J99 Alaska 0ii .& Gas Cons. C0mmiss Anchorage True vertical depth 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~::~-~ .5: ,,o~_~-,~-~-.~ ,~, Title ~ ~ FOR COMMISSION US~ONL~' Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- Date IApproval No. / ORIGINAL $1GNEO BY Approved by the order of th&(~ll~Gs~11Tn-'-" Form 10-403 Rev 5/03/89 Approvecl uoPY Fijeturr~ed / /t I !1 - Commissioner Date''~ {(~ IfiJ SUBMIT IN TRIPLICATE 17-T9N-R 13W-SM Sec. 19-T9N-R13W-SM Sec. 19-T9N-R13W-SM Sec. 19-T9N-R13W-SM SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-25 1. RU E-line unit. (June, 1991) 2. Perforate the following intervals under draw-down conditions: Run No, Bench Intervgl (MD-I~ET) Interval (MD-DIL) 1 5 1387 6-13896 13880-13900 2 5 13856-13876 13860-13880 3 4 13776-13796 13780-13800 4 4 13696-13716 13700-13720 5 4 13650-13670 13654-13674 6 3 13560-13580 13564-13584 7 3 13550-13560 13554-13564 8 2 13 386-13406 13390-13410 Note: Lubricator will be pressure tested to 2500 psig prior to each mn. 3. RD E-line unit and lubricator. Lenmh 20' 20' 20' 20' 20' 20' 10' 20' 150' SPF E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead MOH 6/1/91 STATE OF N.ASKA ~,,.,<A OIL AND GAS CONSERVATION ~M,,.~51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ 2. Name of Operator UNOCAL Corporation (ARCO Alaska. Inc. is sub-oDeratofl 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 731' DSL, 142' FEL, Sec. 17-T9N-R13W-$M Sec. 19-T9N-R13W-SM Sec. 19-T9N-R13W-SM Sec. 19-T9N-R13W-SM 6. Datum elevation (DF or KB) 100' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number K-25 9. Permit number 85-78 At top of productive interval 3074' FSL, 3239' FEL, At effective depth 2370' FSL, 2983' FEL, At total depth 2255' FSL, 2945' FEL, 10. APl number 50-733-201 80-01 11. Field/Pool Hemlock feet 12. Present well condition summary Total Depth: measured 14373' feet Plugs (measured) 14221' true vertical 9686' feet -; Effective depth: measured 14221' feet Junk (measured) 13960' true vertical 9594' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1 997' I 3-3/8" yes 1997' 1 997' Intermediate 1 2 3 7 3' 9-5/8" yes 1 2 3 7 3' 8 5 3 6' Production Uner 7892' 7" yes 1 4 3 7 3' 9 6 8 6' Perforation depth: measured 13305'-13340'; 13390'-13420' ; 13542'-13572' ; 13640'-13760' Detailed operation program .Z.. BOP sketch 13. true vertical 9061'-9081' ; 9109'-9126' ; 9195'-9212' ; 9252'-9321' Tubing (size, grade, and measured depth 4-1/2", 12.6#, N-80 BTC @ 9320' MD ; 3-1/2", 9.2#, N-80 BTC fm. 6320'-13155' MD Packers and SSSV (type and measured depth) Camco TRDP 1-A SSSV @ 281' MD; Baker FHL pkr ~ 13128' MD Attachments Description summary of proposal _ Proposed perforations attached. Estimated date for commencing operation 15. Status of well classification as: February, 1990 Oil x Gas _ If proposal was verbally approved 14. 16. Date approved Suspended _ Date 2/8/90 Service IApproval Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~jned~'~.¢,-~~. ~-¢-'~ Title Environmental Engineer ~o~ D. Ro~berts FOR CC~ISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test~ Subsequent form require 10- n,~' '¢~, . B~' U~,~.l~.:tl~ '~ ~ - Commissioner Approved by the order of the Commission Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Approved Copy Returned SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-25 (February, 1990) 1. RU E-line unit. 2. Perforate the following intervals under draw-down conditions: RIjn NO. Bench Interv¢l {MD-CET) Interval (MD-DIL) I 5 I 3877-1 3897 13880-13900 2 5 I 3857-1 3877 13860-13880 3 4 I 3767-1 3797 13770-13800 4 4 I 3692-1 371 2 13695-13715 5 4 I 3647-1 3677 13650-13680 6 3 I 3553-1 3583 13556-13586 7 2 I 3387-1 341 7 13390-13420 Note: Lubricator will be pressure tested to 2500 psig prior to each run. 3. RD E-line unit and lubricator. SPF 2O 4 20 4 3O 4 2O 4 3O 4 3O 4 3O 4 180 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension ~ Manual'-Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 Unocal Oil & Gas Divisiop Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 U OCAL® Alaska District DOCUMENT TRANSMITTAL April 22, 1988 HAND DELIVERED TO: John 8oyle FROM: R: C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay U zt~~_-'t~,~~well One Sepia and one blueline each of: Recomputed CNL log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: Unocal Oil & Gas Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 L NOCA Alaska District DOCUMENT TRANSMITTAL FeOruary 19, 1988 HAND DELIVER TO: 3ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska Dlstrlct ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Regarding: TBU,~~' Data, as follows: One Magnetlc tape wlth verification 11stlng One Oluellne and one sepla - Formation Density/Compensated Neutron log DATED: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. ~ ~- ~ ~ ~ \/E F1 ~ ~J~s~a Oi~ & Gas Cons. Commissim~_ ARCO Alaska, Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 S~klP LE TRThNSMITTAL · Handcarr¥ SHIPPED TO' State of Alaska Oil & Gas C.C. 3001 Porcupine Dr. Anchorage, Alaska 99501 DATE' February 8, 1988 OPEraTOR' ARCO Sz%MP LE TYPE' Chips West Beach St. IA L 3 - 23~ ~~ N~IE ' NUMBER OF BOXES' 14 S~IPLES SENT: . L3-23 Trading Bay Unit K-25' 11434-11439~ 13698.0-13731.0 11514 11533~x,,~ 13732.0-13756.0 13757.0-13775[~. West Beach State iA 13777 0-13791 9670.0-9698.! ~ 13797.0-13822.0 9719.0-9736 13823.0-13826.0 9737.0-9753 9807.0-98249782.0-9806 ~ ftC_ ~ f~-$2. -~ ~3~ ~ ~L"~I. '- . 00 9.0- 005 *On these samples, if you need further information,, contac~ Rick Levinson, at 265-1652 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREP.%NCIES AND ~i~IL A SIGNED COPY OF THIS FOP~%I TO: RECEIVED BY- ARCO ALAS~2R, INC. P.O. BOX 100360 kNCHORAGE, A!ASKA 99510 ATTN: Paleo Lab ~ .- ABV/100 ARCO Alaska, Inc. ~.*~;:*' ' ~.,', Posl Office Box .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Handcarr¥ SHIPPED TO' SAMPLE TRANSblITTAL , State of' Alaska Oil & Gas C.C. 3001 Porcupine Dr. Anchorage, Alaska 99501 DATE: Feb.ruary OPERATOR' ARCO West Beach St. lA NAME-L3-23, Tradinq Bay K-25 S:~PLE TYPE' Chips NUMBER OF BOXES: 14 S~tPLES SENT' L3-23 ~11434-11439 11514-11533 West Beach State iA 9670.0-9698.0 9719.0-9736.0 '9737.0-9753.0 9782.0-9806.0 . 9807.0-9824.0 10009.0-10038.0 '10039.0-10053.-0 Trading Bay Unit K-25' e~13698.0-13731.0 13732.0-13756.0 13757.0-13775 0 13777.0-13791.0 13797.0-13822.0 13823.0~1.-3826.0 · *On these samples, information, 265-1652 if you need further contact Rick Levinson, at UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAlL A SIGNED COPY OF THIS FORM TO: ARCO ALAS~R, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab : ABV/100 . RECEIVED BY: iN ~,,,. · LO'' lo~R .,'s. (;ommlrmlo~ ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL (ARCO Alaska, Inc. is sub-operator) IO0'KB above MSL 3. Address 6. Unit or Property name Post Office Box 190247, Anchorage, AK 99519 Trading Bay Unit 4. Location of well at surface Leg 4, cond. 28, King Salmon PLatform 7. Well number Feet 731' DSL. 142' FEL, Sec. 17-9N-13W-SM At top of productive interval 3074' FSL, 3239' FEL, Sec. 28-9N-13W-SM At effective depth 2370' FSL, 2983' FEL. Sec. 28-9N-13W-SM At total depth 2255' FSL, 2945' FEL, Sec. 28-9N-13W-SM K-75 8. Approval number 7- Ioo~_ 9. APl number 50-- 773-2018~ 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 4373 ' feet 9686 ' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 1997 ' Intermediate 12373 ' Production Liner 7892' 14221 ' feet 9594 ' feet Size Plugs (measured) 14221 ' Junk (measured) 13970 ' Cemented Measured depth True Vertical depth 13-3/8" yes 1997' 1997' 9-5/8" yes 12373' 8536' 7'I Perforation depth: measured Bench 1 Bench 4 true vertical Bench 1 Bench 4 Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80 BTC to 6320' Packers and SSSV (type and measured depth) yes 14373' 9686' 13305'-13340' MD; Bench 2 13390'-13420' MD; 13640'-13760' MD; Bench 3 13542'-13572' MD; 9061'-9081' TVD; Bench 2 9252'-9321' TVD; Bench. 2 9108'-9125' TVD; 9195'-9212' TVD. MD; 3-1/2", 9.2#, N-80 BTC fm. 6320'-13155' MD Baker 'FHL' pkr. @ 13128' MD, Camco TRDP-1A SSSV @ 281' MD 12. Stimulation orcementsqueeze summary Intervals .treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 228 72 140 800 874 319 686 1080 100 200 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing Roy D. Roberts Signed /~2~~. ,v~~ Form 10-404 Rev. 12-1-85 is true and correct to the best of my knowledge Title Envirom~ntal gnninoor Submit in Duplicat~~.~ DAILY REPORT OF WELL OPERATIONS TBU WELL K-25 The following intervals were added to well TBU K-25 on January 3, 1988' New Perforations Zone Interval (MD) Length (MD) Interval (TVD) Bench 3 13542-13572' 30' 9195-9212' Bench 2 13390-13420' 30' 9108-9125' TOTAL FOOTAGE = 60' NOTE: Lubricator was pressure tested to 2500 psi prior to perforating. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Suspend -- Operation Shutdown -- Re-enter suspended well -- Alter casing _- Time extension -- Change approved program :- Plugging -- Stimulate - Pull tubing -- Amend order - Perforate .~ Other -- 2. Name of Operator UNOCAL (ARCO Alaska, Inc. is sub-operator) 3. AdOress P. O. Box 190247, Anchorage, AK 99519 LOcation of well at surface Leg 4, cond. 28, King Salmon Platfo 731' FSL,.142' FEL, Sec. 17-9N-13W-SM At top of productive interval 3074' FSL, 3239' FEL, Sec. 28-gN'13W-S~ At effective depth 2370' FSL, 2983' FEL, Sec. 28-gN-13W-SM At total depth 2255' FSL~ 2945' FEL~ Sec. 28-9},'.-13W-~ Plugs (measured) 5. Datum elevation (DF or KB) 100' KB above MSL feet 11, Present well condition summary Total depth: measured 14373 ' . feet true vertical 9686' feet Effective depth: measured 14221 ' feet true vertical 9594' feet Casing Length Size Structural Conductor Surface 1997 ' 13-3/8" Intermediate 12373' Production __ Liner 7892' ,Perforation depth: measured Bench 1 Bench-4 ;rue vertical BenCh 1 Bench 4 Tubing (size, grade and measured depth) Junk (measured) Cemented yes 9-5/8" yes 7" yes 13305'-13340' }~ 13640'-13760' .MD 9061'-9081' ~TD 9252'-9321' TVD L-l/?", 1~ 6#, ~-80 BTC to 6320' ~; 3-1/2" 9 ?~ N-80 3TC fm. Packers and SSSV(type and measured depth) 3a~e~ ~'L' ~kr. ~ 13128' M'D, Camco ?.RZ)?-IA SSS¥ ~ 281' .ND 6. Unit· or Property name Tradin.~ Bay Unit :m7. Well number K-25 8. Permit number 9. APl number 50-- 733-2018~ 10. Pool Hemlock RECEIVED 13970' Abs[~ 0ii & Gas Cons, C;0mmissi0[~ Measured depth Af~a~0rtical depth 1997' 1997' 12373' 8536' 14373' 9686' 6320'-13155' 12.Attachments Description summary of proposal~ :Detailed operations program * Proposed perforation intervals are attached. BOP sketch '- 13. Estimated oate for commencing operation December, 1987 14. If pro2osal was verbally approved Name of approver Date approved 15. I hereby certify ~nat the foregoing is true and correct to the best of my knowledge Cigned~D ~o7~. _-.. . _.. . . ~_ o~'_ Title Environmental Engineer Date Commission Use Only Conditions of apprc, val Approved by Notify commission so representative may witness Approval No. ~ _.- '--- Plug integrity ~'. BO~ Test : Location clearance! , ,/ .. [;~...~,,,4~,,)~ Returned ORIGINAL SIGNED BY / ~ --.._~D. ~)'~ LONNIE C. SMFrH ~''-- by order of Com~ner;~ ,~ '~ the commission Datec,,~,~,, SUMMARY OF PROPOSED PERFORATIONS TBU WELL K-25 (December, 1987) 'New Perforations Zone Interval (MD) Length (MD) Interval (TVD) Bench 3 13542-13572' 30' 9195-9212' Bench 2 13390-13420' 30' 9108-9125' TOTAL FOOTAGE = 60' NOTE: Lubricator will be pressure tested to 2500 psi prior to perforating. Unocal Oil & Gas Divis Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276°7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL June 6, 1986 HAND DELIVER TO: Bill Van Alen FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: ARCO TBU K-25 McArthur River Field Cook Inlet, AK Sec 28, TgN R13W (SM) AP1 #50-733-20180-01 For the well indicated above, please find 1 blueline and 1 sepia each of the following logs (for Run 1 dated 1 Feb 86): Induc/SN/SP (2" & 5" TVD) Array Sonic (2" & 5" TVD) CNL/FDC-GR (2" & 5" TVD) FDC-GR-DRHO (2" & 5" TVD) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF' 'THIS DOCUMENT TRANSMITTAL. ~THANK YOU. ~ /x~ ~~ RECEIVED BY: ' A k,,_.../ Alaska Oil & Gas Con~. Corr]missior_, Anchorage STATE OF ALASKA ', ALASKA i~,L AND GAS CONSERVATION ~./,~,MISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~'¢/ / , OILX[~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-78 3. Address 8. APl Number P. O.Box 100360, Anchorage, AK 99510-0360 50- 733-20180~-0~ 4. Location of well at surface 9. Unit or Lease Name 731' FSL, 142' FEL, Sec.17, T9N, R13W, SM ,--i,i..____ Trading Bay Unit i~ LOCATIONSt At Top Producing Interval ~ VERIFIED [ 10. Well Number 2204' FNL, 2041' FWL, Se0.28, T9N, R13W, SM ~., Surf~_~i~): K-25 2291' FSL, 2321' FWL, Sec.28, T9N, R13W, SM ' McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) i 6. Lease Designation and Serial No. Hemlock Pool 100' RKB MLLWIADL 18730 - . 12. Date Spudded06/24/85 13. Date T.D. Reached02/02/86 03/114' Date C°mp" Susp' °r Aband' [ 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns7/86 100 feet MS L 1 17. Total Depth (MD+TvD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 14325'MD, 9657'TVD 1 ~282'MD,9631 'TVD YES~[] NO [] 281 feetMDI N/A 22. Type Electric or Other Logs Run CBL/CCL/GR, I RT/FDC/CNL/GR/SP, CBL/CR/CCL, Gyro/CST, Cs g Inspection log, CET, Digital Sonic, CR/CCL/Temp, 23. . - cASING, LINER AND CEMENTING RECORD Base Line Temp log SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 1,~-~/15" ~1.0# J Surf 1997' 18" 1260 sx Class G 9-5/8" ~7.0# L'8. ~/N-80/S-95 Surf 12374 ' 12-1/4" 750 sx C1 ass G 7" !9.0# .-80/S-95 12049' 14,323' 8-1/2'" 800 sx Class G 7" !9.0# /-80/S-95 6481' 12,083' 8-1/2" 750 sx Class G (tieback ~leeve) 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number.) ~ SIZE DEPTH SET (MD) PACKER SET (MD) 13,305' - 13,340' (go62-g085) 4-1/2"/3-1/2" 13,156' 13,126' 13,640' - 13,760' w/4 spf (9262-9315') 2'6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13,715' - 13,745' w/1 spf (g2~-gJ05')_ DEPTH INTERVAL (MD) AMOUNT & KIND OI~ MATERIAL USED 7" liner lap 325 sx Class G .,. 13542'-13544' 125 sx Class G . . 13293'-13295' 175 sx Class G .. See attached Well H story for fracture, 2-~./A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) - Gas Lift Date°'fTes't 54/10/8 Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZEII GAS-OIL RATIO 12 ,TEST PER~OD I~ 654 199 174 --- 304 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 1000 ~24-HOUR RATE I~ 1308 398 348 32 28. '.., CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. C'ore description not available. RECEIVED JUNO 4 1986 Alaska Oil & Gas Cons, i;ommi~sio~ / Anchorage , . Form 10-407 (DAM) WC1/006 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. i~F'O GEOLOGIC MAR . RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hemlock 13,298 ' 9057 ' N/A Base Hemlock 14,202' 9582' 31. LIST OF ATTACHMENTS _?ell History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowiedge ,f~;~; -: INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification. of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: IndiCate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental reCords for this well should show the detailS of any multiple stage cement- lng and the location of the cementing tool. Item 27. Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 : ndOas ComPany Well History- Initial Report - Daily Instn~ctien.d prepare and submit the "leiflat Rel~' on the first Wedne~lay after a well is spudded or workover operations are started. Dally wo~ prior to spudding should be summarized on the form giving inclusive dates only. District -~: - ICounty, pariah or borough AZaska I[ - Field Lease or Unit Trading Bay Unit ADL 18730' Auth. or W.O~ no. ITItl® AFE 495689 I North Slope Borough P & A K-16/Redrill K-25 IState Alaska Well no. K-1~/K-25RD PDC - ARCO #58 6/20/85 Operator ARCO Alaska, Inc. Spudded or W.O. begun JDate IHour Redrill 6/20/85 Date and depth as of 8:00 a.m. 6/19/85 6/20/85 6/21/85 6/22/85 thru 6/24/85 6/25/85 Complete record for each day reported The above is correct Signature Z~.~_~ ~ ' For form preparation and distr~ution, see Procedures Manual, Sectioh 10, Drilling, Pages 86 and 87. rARCO W.I. Prior status 21.66% if s W.O. 1600 hrs. 9-5/8" @ 10~798' 10,655' PBTD, Activate Rig Wt.9.8, PV 19, YP 9, PH 12.5, WL 9.2, Sol 10 Activate Rig. 9-5/8" @ 10,798' 10,655' PBTD, Activate Rig ~.~ ...... ~----"---------'-~- Activate Rig. P&A K-16, will sidetrac~&redrl as K-2_~5.~j 9-5/8" @ 10,798' 10,655' PBTD, Displ ann w/9.5 ppg mud Wt. 9.5, PV 9, YP 3, PH 11, WL 19, Sol 7 Instl BPV. Accept rig @ 1600 hfs, 6/20/85, ND tree, NU & tst BOPE to 3000 psi. Displ ann w/9.5 ppg mud thru choke. 13-3/8" @ 1997' 2320' PBTD, Circ& Cutting Mud Back Wt. 9.4 Fin displ ann w/9.5 mud, circ & bal mud in hole & pits. LD 4½" CA. Chg rams to 5" & tst. RIH, tag pkr @ 10,094' DM, circ & cln hole, POOH. RIH w/cmt retnr, set retainer @ 10,089 DM, pull out of retnr, tst csg 2000#. Tst lines, broke formation thru perfs @ 10,190'-10,655' w/ll00# @ 4-¼ BPM. Set cmt plug w/350 sx CL "G" w/1.2% D-19, 1 gal per 100 sx D-6L, wt 15.9, tailed w/15 bbl wtr, displ w/mud. (Top of cmt plug @ 9953') Tst csg. POOH, LD 5" DP. RU DA, work pipe free, stuck @ 2100' & 2250'. RIH w/Baker bridge plug, set @ 2320'. PU & RIH, cut 9-5/8" csg. POOH w/csg & LD. RU & PU 20 jts 2-7/8" tbg, RIH on 5" DP. ' 13-3/8" @ 1997' 2030', RIH Wt. 9.1, PV 8, YP 2, PH 12, WL NC, Sol 6 RU BJ, pmp 15 bbls wtr, mia~-& pmp 350 sx CL "GV + 1% A-7 + 10 gal 100 sx D-31L + 1 gal per 100 sx D-6L, w.16# yield 1.15. RI w/5 bbl wtr & displ w/mud. CIP @ 0805 hfs, 6-25-85. Circ, POOH, LD DP & tbg. PU BHA, RIH, tag cmt @ 1800'. Tst csg 1500#. Drl cmt f/1800'-2030'. C&C, POOH, PU BHA, RIH. Date 12/12/85 J U N 0 Oil & (~$ ¢ons~ ¢ommi:~ior,~ Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inslructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District IICounty or Parish I State Alaska North Slope Borough . Field Lease or Unit Trading Bay Unit ADL 18730 Alaska Well no. K-25RD Date and depth as of 8:00 a.m. 6/26/85 6/27/85 6/28/85 6/29/85 thru 7/01/85 7/02/85 'Complete record for each day while drilling or workover in progress 13-3/8" @ 1997' 2257'(227'), Building new mud system Wt. 9.0 Dressed off cmt plug w/DD f/2030'-2063'. Kicked off @ 2063', DD to 2202'. Tst well @ 11.3 ppg. POOH, LD 27 its DP & DD. RIH, drl f/2202'-2257'. Circ& build mud sys. 13-3/8" @ 1997' 3259', (1002'), Drlg Wt. 9.2, PV 12, YP 8, PH 8.5, WL 7.8, Sol 5 Displ hole w/new mud. Drl & surv f/2257'-3259'. 2327', 10.8°, Sl4.0E, 2324.65 TVD, 17.23 VS, 16.72S, E4.24 2771', 24.5°, S14.7E, 2746.47 TVD, 152.67 VS, 147.07S, E41.19 3116', 35.2°, S13.6E, 3046.27 TVD, 322.03 VS, 311.87S, E81.57 13-3/8" @ 1997' 3935' (676'), DRLG Wt. 9.3, PV 16, YP 10, PH 8.5, WL 7, Sol 5 Drl & surv f/3259'-3649. POOH f/new bit. Ream f/3570'-3650'. Drl & surv f/3649'-3935'. 3307', 41/1°, S14.3E, 3196.85 TVD, 439.18 VS, 425.85S, E109.53 3591', 49.7°, S15.4E, 3395.84 TVD, 641.27 VS, 621.24S, E161.78 13-3/8" @ 1997' 5753' (1818'), Drlg Wt. 9.6, PV 12, YP 8, PH 8, WL 7.4, Sol 9 Drl & surv f/3935'-5273'. TIH w/bit #3, POOH. Tst BOPE, RIH to 5273'. Dynamatic brake went out. POOH to 13-3/8 shoe @ 1997'. Remove brake, install wtr ins to brakes. TIH, drl f/5273'- 5753'. 3621', 50.1°, Sl6.1E, 3415.17 TVD, 664.21VS, 643.33S, E168.01 4250', 54.8°, S14.7E, 3797.70 TVD, 1164.46 VS, 1124.29S, E306.01 4852', 54.4°, S14.0E, 4144.92 TVD, 1654.37 VS, 1599.57S, E427.42 5325', 53.9°, S14.3E, 4422.39 TVD, 2036.87 VS, 1970.99S,E521.14 13-3/8" @ 1997' 6330' (577'), Drlg Wt. 9.7, PV 12, YP 10, PH 8, WL 7.1, Sol 10 Drl & surv f/5753'-6330'. RIH, drlg. The above is correct Signature For form preparation and distdt~ution see Procedures Manual Section Drilling, Pages 86 and 87 POOH f/ BHA chg. LD Teleco MWD. JUNO a 1986 JDate ~J.~.ska Oil & Gas Cons. (;ur,,,, ........ Title 12/12/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and deptl~ as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Trading Bay Unit ADL 18730 Complete record for each day while drilling or workover in progress 7/03/85 7/04/85 thru 7/05/85 7/06/85 thru 7/08/85 7/09/85 7/10/85 7/11/85 7/12/85 IState Alaska JWell no. K-25RD 13-3/8" @ 1997' 6692' (362'), RN'G Wireline Survey Wt. 9.6, PV 10, YP 11, PH 8, WL 8.8, Sol 10 Drl & surv f/6330'-6692'. Drop surv pmp pill, POOH f/bit & BHA. RIH, rn WL surv. 13-3/8" @ 1997' 7785' (1093'), Drlg Wt. 9.8, PV 10, YP 10, PH 8, WL 7.6, Sol 10 Surv @ 6692', Drl f/6692'-7474'. Drop surv, pmp pill, POOH. Retrv surv, chg BHA & bit. TIH, rem 80'-7474'. Drl f/7474'- 7785'. 13-3/8" @ 199~' 8307' (522'), Drlg Wt. 9.8, PV 12, YP 13, PH 8, WL 7.2, Sol 10 Drl, DD & surv 12¼" hole to 8307'. 7933', 50°, SllE, 6041TVD, 4076.96 VS, 3956.16S, 1007.46E 8204', 49.5°, S8.5E, 6216 TVD, 4282.01VS, 4159.99S, 1042.48E 8330', 49°, S8.5E, 6296 TVD, 4376.29 VS, 4254.46S, 1056.18E 13-3/8" @ 1997' 8550' (146'), Drlg Wt. 9.8, PV 12, YP 12, PH 8, WL 7.1, Sol 10 Drl 12¼" hole to 8550'. 13-3/8" @ 1997' 8727' (177'), RIH Wt. 9.8, PV 14, YP 14, PH 8, WL 6.8, Sol 10 Drl & surv 12¼" hole to 8727'. 8574', 48-1/4°, S15-1/2E, 6459.28, 4558.41, 4433.59S, 1093.44E 8694', 50-1/2°, S16.0E, 6537.41, 4649.46, 4521.24S, 1118.16E 13-3/8" @ 1997' 8946' (219'), Chg BHA Wt. 9.8, PV 13, YP 13, PH 8, WL 7.0, Sol 10 RIH, rm 8657'-8727', drl & surv 12¼" hole to 8946'. 8907', 56°, S14.5E, 6664.81TVD, 4819.95 VS, 4686S, 1163E 13-3/8" @ 1997' 9100' (154'), Drlg Wt. 9.9, PV 13, YP 15, PH 8, WL 6.6, Sol 11 Drl 12¼" hole to 9100'. J U N 0 4 198G The above is correct Signature ~p.~ ~~ For form preparation and di~ribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 iDate 12112/85 JTitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completiom Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and I'ollowing setting of oil string until completion. District Field Alaska ICounty or Parish IStale North Slope Borough Alaska ILease or Unit IWell no. ADL 18730 I K-25RD Trading Bay Unit Date and deptll as of 8:00 a.m. 7/13/85 thru 7/15/85 7/16/85 7/17/85 7/18/85 7/19/85 7/20/85 thru 7/22/85 The above is correct Signature For form preparation and distl'ibution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 13-3/8" @ 1997' 9235' (135'), RIH w/bit Wt. 10.0, PV 18, YP 17, PH 8, WL 7.0, Sol 11 Drl 12¼" hole to 9205', POOH, hit tight spot @ 7600', drl string stuck. RU & rn freept; pipe completely stuck @ 6435'-6450'. RIH w/APRS, BO @ 6405' WLM, POOH. RIH w/FTA #1, tag TOF @ 6387', screw into fsh & jar free, POOH, hit tight spot @ 6187', pipe stuck, wrk pipe free, POOH w/fsh. RIH, make cln out rn to btm, C&C hole cln, POOH f/DD rn. RIH, DD to 9235'. 9110', 55-1/4°, S13-3/4°E, 6779.42 TVD, 4987.24 VS, 4848.31S, 1203.92E 13-3/8" @ 1997' 9300' (59'), DD Wt. 10.0, PV 14, YP 8, PH 8, WL 7.2, Sol 12 Drl & surv 12¼" hole to 9300'. 13-3/8" @ 1997' 9404' (104'), MU BHA #15 Wt. 9.9+, PV 12, YP 12, PH 8, WL 6.6, Sol 11 DD to 9404', POOH f/bit chg. 13-3/8" @ 1997' 9640' (236'), Drlg Wt. 10, PV 14, YP 12, PH 8, WL 7, Sol 10 DD, drl & surv to 9640'. 9406', 53.2°, S17.7E, 6952.45, 5227.25 VS, 5079.41S, 1268.99E 9564', 57.3°, S17.5E, 7042.78, 5356.84 VS, 5203.03S, 1307.91E 13-3/8" @ 1997' 9703' (63'), DD Wt. 10, PV 13, YP 13, PH 8, WL 7.4, Sol 11 Drl & surv 12¼" hole to 9672', DD to 9703'. 9227', 57.7°, S16.8E, 7076.53 TVD, 5410.04 VS, 5253.81, 1323.75 13-3/8" @ 1997' 9715' (12'), Jar fsh Wt. 9.8, PV 13, YP 11, PH 8, WL 6, Sol 10 DD 12¼" hole to 9715'; pipe stuck on btm. Wrk pipe, M&P Black Magic pill. RU DA, rn A~R. Rn freept, found top of DC @ 9470' stuck. RIH w/string shot, spot across HWDP tl jt @ 9434', POOH; BO @ 9056'. RIH w/string shot, fire string shot across tl jt @ 9434', POOH, rec'd partial fsh. RIH w/fsh'g assy to TOF @ 9056', jar on fsh & circ Black Magic pill. rDate ITitle 12/12/85 ARCO Oil and Gas Company Daily Well History--Interim Inetru¢lion,,: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Trading Bay Unit ADL 18730 Complete record for each day while drilling or workover in progress 7/23/85 7/24/85 7/25/85 7/26/85 The above is correct 7/27/85 thru 7/29/85 IState Signature For form preparation and di~ribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Alaska JWell no. K-25RD 13-3/8" @ 1997' 9715' (0'), POOH w/fsh Wt. 9.7, PV 14, YP 12, PH 8, WL 6, Sol 9 Circ & jar on fsh. Rn freept. RIH w/string shot, fired BO shot @ 9565' DPM, POOH w/fsh. 13-3/8" @ 1997' 9715' (0'), POOH Wt. 9.8, PV 18, YP 12, PH 8, WL 6, Sol 11 Fin POOH; rec'd partial fsh. RIH w/fsh'g assy, screw into TOF @ 9565' DPM, fsh plugged, unable to circ. RIH w/string shot to 9500', lost CCL, POOH. RIH w/WL OS; unable to latch onto WL fsh, POOH, RD DA. POOH w/fsh'g assy. 13-3/8" @ 1997' TOC @ 8816', TOF @ 9559', 9715' TD, PU BHA Wt. 9.7+, PV 14, YP 8, PH 8, WL 6.2, Sol 10 RIH w/CED? to 9400', C&C, PU to 9200'. RU f/bal cmt plug. M&P 300 sx Cl "G" w/additives. Displ w/9.7 ppg mud. CIP @ 1920 hrs, 7/24/85. POOH 10 stds, rev circ DP cln, POOH w/OEDP. WOC. 13-3/8" @ 1997' 9039' PBTD (cmt), Wt. 9.7, PV 13, YP 6, PH 9, WL 6.0, Sol 9 RIH to 8825', wsh & rm f/8825'-8925', drl soft/med cmt f/8925'-9020'. Dress off cmt plug to 9039', C&C, POOH, chg BHA, RIH, tag btm @ 9039'. 13-3/8" @ 1997' 9305' PBTD, (266'), RIH Wt. 9.7, PV 13, YP 10, PH 10, WL 7.3, Sol 10 RIH w/steering tl, sidetrack cmt plug @ 9039', drl to 9305'. 8907', 56°, S14.5E, 6664.81TVD, 4819.95 VS, 4685.83S, 1163.03 9039', 55.63°, S14.13E, 6738.98 TVD, 4929.00 VS, 4791.63S, 1190.03 9062', 56.0°, S14.0E, 6751.90 TVD, 4948.00 VS, 4810.09S, 1194.65 IDate 12/12/85 JTitle Alaska Oil & Gas Cons. ~u,,~,, ...... Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska Trading Bay Unit County or Parish Lease or Unit North Slope Borough ADL 18730 IState Alaska Well no. K-25RD Date and depth as of 8:00 a.m. 7/30/85 7/31/85 8/01/85 8/02/85 8/03/85 thru 8/05/85 8/06/85 8/07/85 Complete record for each day while drilling or workover in progress 13-3/8" @ 1997' 9520', (215'), RIH Wt. 9.7, PV 14, YP 7, PH 9.5, WL 7.8, Sol 10 Drl & surv 12¼" hole to 9520'. 9312', 49-3/4°, S22E, 6902.71TVD, 5147.05 VS, 4999.42S, 1256.17E 9484', 54°, S22E, 7008.88 TVD, 5281.86 VS, 5124.84S, 1306.84E 13-3/8" @ 1997' 9845', (325'), Drlg Wt. 9.7+, PV 15, YP 7, PH 9.0, WL 7.6, Sol I0 RIH, ream f/7631' to btm. Drl f/9520'-9833'. Circ, rn sand in, surv @ 9790'; 15 std, short trip. Drl to 9845'. 13-3/8" @ 1997' 9934', (89'), Setting cover on rotary mtr Wt. 9.8+, PV 14, YP 8, PH 9.5, WL 7.6, Sol 10 Drl f/9845'-9934'. Rotary table problems, circ, slug pipe. Replace rotary coupling. 13-3/8" @ 1997' 10,054 (120'), RU to Tst BOPE Wt. 9.8+, PV 13, YP 9, PH 9.5, WL 7.1, Sol 10 Fin rotary repair, drl f/9934'-10,054. 13-3/8" @ 1997' 10,453', (399'), POOH f/Bit Chg Wt. 9.7+, PV 14, YP 12, PH 9.0, WL 6.8, Sol 10 Tst Bope, RIH w/new bit, slips & cut drl In. RIH drl f/10,054'-10,289'. Drop surv, POOH. PU 9½" Navi Dril, TIH w/ND, hit bridge @ 4192' & 6342'. Pipe sticking @ 6342', PU Kelly, work pipe thru tight spot. POOH, tight @ 5874'. LD/ND, TIH w/PDC bit. POOH, chg bit drl f/10,289'-10,453'. 10,210', 56-3/4°, S21-3/4E, 7425.52 TVD, 5874.35 VS, 5676.19, 1529.21 13-3/8" @ 1997' 10,678 (225'), Drlg Wt. 9.8+, PV 13, YP 14, PH 8.5, WL 7.4, Sol 10 Drl f/10,453'-10,678'. Make 10 std, short trip @ 10,468'. WL surv @ I0,555'. 10,510', 56.34°, S21E, 7590.01, 6124.58 VS, S5909.81, E1620.65 13-3/8" @ 1997' 10,806' (128'), Drlg Wt. 9.7+, PV 12, YP 12, PH 8 5,. WL 7.4, Sol Drl f/10,678-10,806'. Short trips @ 10,678'~[ T0,774' jUY,. The above is correct Signature see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate 12/12/85 ITM ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pertorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. Date and depth as of 8:00 a.m. District JCounty orParish ]State Alaska North Slope Borough Alaska Field ~Lease or Unit Trading Bay Unit I ADL 18730 Complete record for each day while drilling or workover in progress 8/08/85 13-3/8" @ 1997' 10,988' (182'), Drlg Wt. 9.7+, PV 14, YP 15, PH 8.5, WL 7.5, Sol 10 Drl f/1-,806'-10,928'. Rn WL surv @ 10,928', 10 std, short trip @ 10,950'. Drl to 10,988'. 8/09/85 13-3/8" @ 1997{ 11,042' (54'), RIH Wt. 9.8, PV 14 YP 16, PH 8.5, WL 7.2, Sol 10 Drl f/10,988'-11,042'. Circ, drop surv, POOH. Ret surv, LD, stab & MLC. Repair 3" ck vlv. Tst BOPE, cut & slip drl in. PU, MU BHA. TIH, hit tight spot @ 9041'. Wsh & rm f/9041'-9086'. Cont RIH. 8/10/85 13-3/8" @ 1997' thru 11,494' (452'), Drl'g 8/12/85 Wt. 9.8, PV 13 YP 15, PH 8.5, WL 7.2, Sol 10 FRIH, ream f/10,990'-11,042'. Navi Drl f/11,042'-11,058'. POOH, chg BHA, RIH, ream f/11,000'-11,058'. Drl f/11,058'- 11,380'. WL surv @ 11,380'. Drl'd f/11,380'-11,494'. 8/13/85 13-3/8" @ 1997' 11,793' (229'), Drl'g Wt. 9.8, PV 13 YP 15, PH 8.5, WL 7.6, Sol 10 Drl f/11,494'-11,498'. 10 std, short trip @ 11,498'. Drl f/11,495'-11,723'. 8/14/85 13-3/8" @ 1997' 11,739' (16'), RIH Wt. 9.8, PV 14, YP 15, PH 8.5, WL 7.2, Sol 10 Drl f/11,723,'-11,726'. Circ, work pipe. WL surv @ 11,726', 15 std, short trip @ 11,726'. RIH, drl f/11,726'- 11,739'. CBU, POOH, chg BHA, RIH. 8/15/85 13-3/8" @ 1997' 11,933' (194'), POOH f/Bit Chg Wt. 9.8, PV 14, YP 11, PH 8.5, WL 7.4, Sol 10 FRIH, ream f/11,640'-11,739'. Drl f/11,739'-11,933'. POOH f/bit chg, tight @ 10,450' & 9600'-9100', work thru. 8/16/85 13-3/8" @ 1997' 12,005' (72'), Drlg Wt. 9.9, PV 13, YP 13, PH 8.5, WL 7.4, Sol 10 RT f/new bit, retrv surv, tst BOPE. Drl f/11,933-12,005 11,895', 60-3/4°, S22E, 8345.49 TVD, 7282.76 VS, S6996.01, E2028.15 The above is correct Well no. K-25 Signature ~O~ form ~re~a~ation a~d see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate 12/12/851~it'~ Drilling .Su.Per_in, te.n.d.e_nt Alaska Oil & Gus . : ,'4~ '~'~.-~. ',L; ARCO Oil and Gas Company Daily Well History--Interim instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin; until completion. District ICounty or Parish I State Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Trading Bay Unit I ADL 18730 I K-25RD Date and depth as of 8:00 a.m. 8119/85 8/20/85 8/21/85 8/22/85 Complete record for each day while drilling or workover in progress 13-3/8" @ 1997' 12,400' (395'), Pre f/Cas'g Wt. 9.9, PV 15, YP 15, PH 8.5, WL 8.0, Sol 10 Drl f/12,005'-12,400', POOH f/new bit. Drop surv, POOH, tight @ 10,300'. TIH w/bit #28, drl f/12,196'-12,400', short trip, prep f/csg. 9-5/8" @ 12,373' 12,400' PBTD (0'), Rn 9-5/8" 6sg Wt. 9.9, PV 15, YP 16, PH 8.5, WL 8.0, Sol 10 C&C hole, POH. RU & rn 9-5/8" csg. 9-5/8" @ 12,374 12,286' (0'), RIH Wt. 9.9, PV 15, YP 20, PH 8.5, WL 8.0, Sol 10 Fin rn 198 its, 47#/ft, L-80, 57 jts 47#/ft, N-80, 55 jts 47#/ft, S-95 w/FS @ 12,374', & FC @ 12,286'. RU & pmp 750 sx CL "G", w/12 gal per 100 sx D-136, & 6 gal per 100 sx R-12L, + 1 gal per 100 sx D-6L @ 15.9 ppg. Displ w/899 bbl mud, CIP @ 2100 hrs, 8-20-85. Set & tst pack off, LD 12¼" BHA, PU 8½" BHA, RIH. 9-5/8"@ 12,374' 12,286' PBTD, RIH w/RTTS Wt. 9.9, PV 13, YP 13, PH 9.5, WL 9.6, Sol 10 Fin PU BHA, break dn surv equip. RIH, tag FC @ 12,286'. C&C mud, att to tst 9-5/8" csg to 2000 psi; bled dn to 700 & 500 psi w/rtns on 9-5/8" & 13-5/8" ann. Tst pack-off; OK. Ck surf equip to 2500 psi; OK. Att to re-press up 9-5/8" csg to 2000 psi, bled dn to 500 psi, w/rtns on ann. Circ, POOH, chg BHA. RIH w/Rtts tool assy. Press tst 9-5/8" csg @ ±400 to 500 psi-, w/rtns on ann. Cunt RIH. The above is correct For form preparation ution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate [Title 12/12/85 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "Interim" sheets until tinat completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oi1 string until completion. District ICounty or Parish IState Alaska NotCh Slope Borough Field ~Lease or Unit Trading Bay Unit I ADL 18730 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 8/23/85 8/24/85 thru 8/26/85 Alaska IWell no. K-25RD 9-5/8"@ 12,374' 12,286' PBTD, POOH. Wt. 9.8, PV 13, YP 14, PH 8.5, WL 9.8, Sol 10 RIH & tag FC @ 12,286'. Set RTTS @ 12,256'. Att to tst 9-5/8" csg to 200 psi. Circ @ 500 psi w/rtns on 9-5/8" & 13-5/8" ann. Tst'd backside @ 12,256' to 2000 psi; OK. Unseat RTTS, circ w/no fluid lost. Re-check surf equip to 3000 psi; OK. Circ, POOH, LD tool assy. RU DA, RIH w/CBL/CCL/GR, rn CBL f/12,286'-11,950' & f/ll,810'-10,000'. POOH, LD tool assy. 9-5/8"@ 12,374' 12,256' CR, Operations suspended Wt. 9.8, PV 15, YP 8, PH 9.0, WL 9.6, Sol 10 Evaluate log results, RD DA. Circ thru 9-5/8" & 13-3/8" ann w/B rams closed. Pmp dn kill ins. C&C mud, CO flowln, tst kelly assy to 3000 psi. RIH w/EZ cmt ret, set retnr @ 12,256'. Unsting f/retnr, tst well to 1500 psi; OK. Re-sting into ret. C&C mud & hole @ 5 BPM. M&P 500 sx CL "G" cmt + 12 GHS D-3U, + 4 GHS R-12L + GHS D-6L, followed by 10 bbls FW @ 5 BPM. Displ cmt w/205 bbls mud; good rtns. CIP @ 0255 hrs, 8-24-85. Unsting f/ret, reverse out DP, POOH. LD 76 jts "E" DP & 30 jts HW DP. Blow dn Kelly & choke manifold. RIH w/5" OEDP to 9870'. Tst 9-5/8" csg to 2000 psi; OK. C&C mud, land DP w/tst plug, secure well. Temp suspended f/rig repair. r-. ..... ~;,. r,~ - ,'~.: The above is correct Signature For form preparation and distri~tion see Procedures Manual Sectio~ 10, Drilling, Pages 86 and 87 IDate ITitle 12/12/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska Field ~Lease or Unit Trading Bay Unit Auth. or W.O. no. JTitle I AFE 495689 North Slope Borough ADL 18730 P & A K-16/Redrill K-25 PDC-ARCO Rig #58 API 50-733-20180-01 Operator I A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun ~ Date Redrill J 6/20/85 IAccounting cost center code State Alaska Well no. K-25RD I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O, 1600 Hrs. I Date and depth as of 8:00 a.m. 8/27/85 thru 8/31/85 Complete record for each day reported Old TD I Released rig Date 9-5/8" @ 12,374' 12,256' CR, Final Report Wt. 9.8 Well operations temp suspended, well secure, rig repairs & maint. Final report. New TO PB Depth 12,400' (8/19/85) 12,256' PBTD Kind of rig 1400 Hrs. 8/31/85 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single I Official reservoir name(s) I Trading Bay Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production · Pump size, SPM X length Choke size T.P. C.P. ~ Water % GOR ~r~~ ,AIl~wab{e ~ ~Effective date ~ . . The above is correct For form preparation and {~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent =_.:R.e~ffi't~ on-~h~fl .m~_:Wednesday after a el! is spudded or workover operations are started. . :-~_:DaJl~ork~priot~-t~Ptii:l_duig-%! !~ .o~d be. su~~l~ fo~ gi~ng inclusive Dates only. ._ ~aS~. -'~:~:/i-~- North Slope Borough [ Alas~ Field- ]Le~ or Unit ]Well no. Trading Bay Unit [ ~L 18730 ' ] K-25~ Au~. or W.O. no. [Title . ~ 495689> - ] Res~e operations, suspended 8/25/85 PDC-~CO:Rig 158~.-- ~I 50-733-20180-01 - -. -' i^Rco w.~. O,erator ARCO-Alaaka, Inc.~ I 12% sp,,ded o,w.o. ,eo,,. IDle [,o,r [Prior ,tatua if a W.O. Resume re-drl ope~: 1/03/86 1200 Bra. Date and depth as of 8:~ a.m. 1/04/86 thru 1/06/86 1/07/86 1/08/86 1/09/86 1/10/86 Complete record for each day repoAed 9-5/8" @ 12,37~(~ 12,561', 12,256' PBTD, (161'), Drlg- Wt. 9.7, PV 13, YP 13, PH 11, WL 9.8, Sol 9 Resume operations suspended on 8/25/85. Accept ri~ @ 1200 hfs, 1/3/86. RU Exlog, tst BOPE, C&C mud, POE, LD DP. RIH, tag CR @ 12,256', DO retnr, FC & 40' into shoe jr. No cmt above or below retnr & FC. Att to ret 9-5/8" csg to 3000 psi, bled off to 2270 psi. DO FS @ 12,373' + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 12,561'. 9-5/8" @ 12,37~' 12,750t, (189~), Drlg Wt. 9.8, PV 17, YP 13, PH 10, WL 7, Sol 10 Drl & surv 8½" hole to 12,750'. 12,413', 56.8°, S18.2E, 8609.39, 7727.76, 7414.57S, 2180.83E 12,594', 50.2°, S19E, 8719.08, 7871.52, 7550.87S, 2226.61E 9-5/8" @ 12,37~' 12,881', (131'), Drlg Wt. 9.8, PV 21, YP 15, PH 9.5, WL 6.6, Sol 9 Drl & surv 8½" hole to 12,881'. 12,686', 53°, S21E, 8776.88, 7942.95, 7617.66S, 2252.41E 12,751', 55.8°, S21.2E, 8814.68, 7995.69, 7666.91S, 2271.62E 9-5/8" @ 12,37~' 12,932', (51'), ~ait on elec power ~t. 9.7+, ?V 20, YP 12, ?E 9, ~r~ 7.2, Sol 9 Drl & surv 8½" hole to 12,932'; elec power problem, pull into shoe & wait on elec power. 12,852', 57.6°, S21.6E, 8870.13, 8079.88, 7745.51S, 2302.42E 9-5/8" @ 12,37~' 12,932', (0'), Wait on elec power Wt. 9.7, PV 19, YP 10, PH 9, WL 6.7, Sol 9 Wait @ shoe on platform elec generator repair. 12,885', 57.5°, S21.0E, 8887.83, 8107.66, 7771.45S, 2312.54E The above is correct see Procedures Manual, Section 10, DHIIIng, Pages 86 and 87. Date 4/17/86 Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instmoliona: This form is used during drilling or workover operations. If testing, coring, or peHorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled oul but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District lCounty or Parish [State Alaska JLeese or Unit North Slope BorouRh Unit I ADL 18730 Complete record for each day while drilling or workover in progress Field Trading Bay Date and depth as of 8:00 a.m. 1/11/86 thru 1/13/86 1/14/86 1/15/86 1/16/86 1/17/86 1/18/86 thru 1/20/86 Alaska IWell no. K-25RD 9-5/8" @ 12,37)' 13,634', (702'), Drlg Wt. 9.7, PV 13, YP 9, PH 9, WL 6.8, Sol 9 C&C while waiting f/rig repair. RIH, Drl & surv 8½" hole to 13,634'. 12,915', 57.0°, S21.8E, 8904.96 TVD, 8132.82 VS, 7794.948, 2321.74E 13,131', 56.9°, 822.0E, 9021.72 TVD, 8313.37 VS, 7963.06S, 2389.17E 13,253', 56.3°, 821.2E, 9089.32 TVD, 8414.62 VS, 8057.4tS, 2426.76E 13,410', 56.1°, S20.7E, 9176.76 TVD, 8544.73 va, 8179.09S, 2473.64E q 9-5/8" @ 12,37~' 13,696', (62'), Wrk'g pipe Wt. 9.7+, PV 17, YP 11, PH 9, WL 7.4, Sol 9 Drl 8½" hole to 13,696', tend hole f/coring, POH. MU rm'g BHA, RIH, drl string tk wt @ 13,526', PU, pipe stuck. Jar & wrk pipe @ 13,526'. 13,635', 55.6°, S22.9E, 9303.05 TVD, 8730.33 VS, 8351.97S, 2542.78 9-5/8" @ 12,37~' 13,698', (2'), Wsh & rm Wt. 9.7+, PV 14, YP 13, PH 9, WL 7.5, Sol 9 Wrk stuck pipe, spot SFT, jar free. Rm 13,300'-13,696', drl to 13,698', POH. PU core bbl, RIH, wsh & rm f/12,960'-13,140'. 9-5/8" @ 12,37~' 13,708', (10'), Coring Wt. 9.7+, PV 16, YP 14, PH 9, WL 7.7, Sol 9 Wsh & rm f/13,030'-13,698'. Cut core #1 f/13,698'-13,708', rec'd 1.5'. RIH w/core #2. 9-5/8" @ 12,37~' 13,730', (22'), Coring Wt. 9.8, PV 16, YP 14, PH --, WL 7.3, Sol 9 Core #2 f/13,708'-13,718', no rec'y as yet. Core #3, 13,718'-13,730', incompl. 9-5/8" @ 12,373' 13,787', (57'), Coring Wt. 9.8, PV 18, YP 15, PH 9, WL 6.8, Sol 9 13,748'-13,760'~ rec'd 11.5'. Core #5, 13,760'-13j'~)I~ d ..... ....... , ........... ~' .... [;;;;;;T::'::~" 16'. Core #7, 13,777'-13,787'. '~" ........... '-"'~ The above is correct For form preparation and distri~')ion see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date ITitle 4/17/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inelru¢lione: This form is used during drilling or workover operations. If testing, coring, or pedorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Finel" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin[; until completion. District ICounty or Parish IState Alaska North Slope Borough Field ~Lease or Unit Trading Bay Unit I ADL 18730 Date and deptl~ as of 8:00 a.m. 1/21/86 1/22/86 1/23/86 1/24/86 1/25/86 thru 1/27/86 1/28/86 1/29/86 Alaska IWell no. K-25RD Complete record for each day while drilling or workover in progress 9-5/8" @ 12,37~' 13,792', (5'), Coring Wt. 9.8, PV 17, YP 14, PH 9, WL 6.8, Sol 9 Fin POOH, rec'd 7' f/core #6. Core #7 f/13,787'-13,792', rec'd 4.5'. RIH w/core #8. 9-5/8" @ 12,37~' 13,815', (23'), Coring Wt. 9.7+, PV 20, YP 14, PH 8.5, WL 7, Sol 9 Core #8 f/13,792'-13,805', rec'd 10'. Core #9, 13,805'-13,815', incompl. 9-5/8" @ 12,379' 13,831', (16'), Chg BHA Wt. 9.8, PV 18, YP 12, PH 8.5, WL 7, Sol 8 POH, rec'd 9' f/core #9. Core #10, 13,815'-13,831', rec'd 12'. LD core bbl, chg BHA. 9-5/8" @ 12,37~~ 14,033', (202'), Cond hole Wt. 9.8, PV 16, YP 11, PH 8.5, WL 6.8, Sol 8 RIH, wsh & rm 12,800'-13,831', drl 8½" hole to 14,033', begin 18 std short trip to cond hole. 9-5/8" @ 12,37~' 14,290', (257'), Cond hole f/logs Wt.' 9.8, PV 19, YP 9, PH 8.5, WL 7, Sol 9 Fin cond'g short trip, drl 8½" hole to 14,290'. Cond hole f/logs, POH. RU Schl, RIH w/run #1, tl stuck @ 12,383'. Wrk WL, RIH & strip over WL w/DP, latch fsh, POH, rec'd compl fsh. RIH & cond f/logs. 9-5/8" @ 12,37~' 14,300', (10'), Stripping over WL Wt. 9.8, PV 16, YP 12, PH 8.5, WL 8, Sol 8 Cond hole f/logs, POH. RU SOS, RIH w/DIL/GR; tl stopped @ 12,525', unable to wrk below, POH. Add wt, RIH, tl stopped @ 12,265'; tl stuck. Wrk tl & prep to cut & strip over WL. RIH, 9-5/8" @ 12,378' 14,300', (0'), Cond'g hole f/logs Wt. 9.8, PV 15, YP 16, PH 8.5, WL 9.5, Sol 8 RIH, strip over WL, latch fsh @ 12,280', circ, pull WL out of hole, POH & LD fsh. Tst BOPE. RIH, re-cond f/logs. The above is correct Signatu~~ For form p~ep~ration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ]Title 4/17/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pertorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty orParish ]State Alaska North Slope Borough Alaska Field ~Lease or Unit Trading Bay Unit I ADL 18730 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 1/30/86 1/31~/86 2/01/86 thru 2/03/86 2/04/86 2/05/86 2/06/86 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IWell no. K-25RD 9-5/8" @ 12,37~' 14,300', (0'), POOH w/logging tls Wt. 9.8, PV 16, YP 15, PH 8.5, WL 7.4, Sol 9 C&C hole f/logs, POOH. PU DPC tls, RIH w/log #1, tls stopped @ 12,535', att to wrk thru, POOH w/WL & DPC tls. 9-5/8" @ 12,373' 14,300', (0'), POOH w/DP Wt. 9.8+, PV 15, YP 13, PH 8.5, WL 7.6, Sol 9 POOH, LD DPC logging tls. TIH w/bit, rm 12,508'-12,632', C&C, POOH. Prep f/slim hole logging rn. 7" @ 14,32~' 14,325' TD, 12,049' TOL, (25'), POOH w/DP Wt. 9.9, PV 24, YP 22, PH 8.5, WL 7.7, Sol 9 TIH to 12,373', RU Schl, att to RIH, POOH w/tl, WL wrapped around DP. TIH w/IRT/FDC/CNL/GR/SP, log f/14,270' WLM - 13,108', tl failure, POOH. RIH, rn log repeat f/13,200'-12,400', POOH, RD loggers. RIH, drl to 14,325', C&C, POOH. RU & rn 57 its, 7", 29#, L-80 BTC lnr w/FS @ 14,323', TOL @ 12,049', LC @ 14,207' & FC @ 12,049'. Cmt lnr 50 sx scavenger cmt & w/750 sx C1 "G" w/6% KC1. Displ using rig pmps, bump plug. CIP @ 0400 hrs, 2/6/86. POOH w/DP. 7" f/12,049'-14,323' 14,325' TD, 12,282' PBTD, TIH to drl lnr Wt. 9.8+, PV 15, YP 12, PH 9.0, WL 8.6, Sol 9 Fin POOH, LD lnr rn'g tl. PU bit & 9-5/8".scrpr, RIH to 11,000', WOC. TIH, tag TOL @ 12,049', no cmt on TOL, CBU, POOH, LD DP. TIH w/6" bit. 7" f/12,049'-14,323' 14,325' TD, 12,282' PBTD, TOL @ 12,049', Hold press on sqz job Wt. 9.9, PV 14, YP 13, PH 9.0, WL 8.8, Sol 9 Fin RIH, no cmt in TOL. Tst lnr lap to 3000 psi; lnr not holding. RIH, set RTTS @ 11,750', est IR @ 3 BPM @ 2800 psi. Sqz lnr w/lO0 sx C1 "G" w/6% KC1. Sqz press 3600 psi, bled to 2800 psi. Rel pkr, pull 5 stds, set pkr, press cmt/lnr & hold @ 1000 psi f/3 hrs. 7" f/12,049'-14,323' 14,228' PB~D, TOL @ 12,049', [IH w/6" bit & csg scrpr Wt. 9.8, PV 34, YP 14, PH 11, ~ --, Sol 9 POH w/RTTS. RIH to 11,220', circ& WOC. RIH, tag cmt, CO to TOL ~ 12,072'. Tst lnr; leaks off, unable to est IR, POH. RIH~J w/6" CO assy. ~[17/86 Drilling Superintendent ARCO 0il and Gas Company / Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, cori-ng, or perforating, show formation name in describing work performed. Numbm; all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion· District ICounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Trading Ba] Unit I ADL 18730 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 2/07/86 2/08/86 thru 2/10186 2/11/86 2/12/86 2/13/86 7" f/12,049'-14,323' 14,283' PBTD, Chg CBL string Wt. 9.8, PV 16, YP 8, PH 11, WL --, Sol 9 RIH, CO 7" lnr to 14,283', CBU, POH f/cased hole logs. RIH w/CBL, unable to get below 11,840', POH f/tl string configuration chg. Alaska RU Schl, 7" f/12,049'-14,323' 13,324' PBTD, RIH Wt. 9.8+, PV 14, YP 6, PH 10, WL 12.6, Sol 9 Att to rn CBL; unable to get tls below 11,910'. RIH w/tandem scrprs, circ out, POH. Rn CBL/GR/CCL f/14,268'-11,992', POH. Rn GST/gyro f/14,268'-surf. RU & perf w/4 SPF f/13,542'-13,544' & 13,378'-13,380' WLM. Sqz perfs w/125 sx C1 "G" w/6% KC1. CIP @ 0130 hrs, 2/9/86. RU Schl & perf w/4 SPF f/13,293'-13,295', POH. MU 7" EZSV, RIH, set @ 13,314' WLM, RD Schl. RIH, tag retnr, sting in, est IR. Sqz perfs w/100 sx C1 "G" w/6% KCL. CIP @ 1930 hrs, 2/9/86. Rev, circ DP, POOH. MU 7" RTTS & RIH. 7" @ 12,049'-14,323' 13,324' PBTD, Hold'g sqz press on TOL Wt. 9.8, PV 15, YP 5, PH 10.5, WL 13.9, Sol 8 Fin RIH w/RTTS, set @ 12,721'. Est IR. M&P 100 sx C1 "G" w/6% KC1, 40 gal FL95L, 9 gal R12L & 2 gal SP6L. Sqz 14 bbls thru perfs. Hold 3250 psi f/2 hrs. Rel pkr, POOH, LD 7" RTTS. PU 9-5/8" RTTS, RIH & set @ 11,700'. Press tst 5" x 9-5/8" ann to 3000 psi. Est IR. M&P 125 sx C1 "G" w/6% KC1, 50 gal FL45L, 8.75 gal R12L, 2.5 gal SP6L. Sqz 18 bbls cmt thru TOL. Hold 3200 psi on TOL. 7" @ 14,323' 13,324' PBTD, RIH w/6" bit Wt. 9.8+, PV 19, YP 11, PH 11, WL 19.6, Sol 9 Hold press on cmt f/2 hrs, bleed press. Rel pkr, POH, LD RTTS. PU 8½" bit/9-5/8" csg scrpr, RIH, drl cmt f/11,933'-12,072' TOL, POOH, LD bit & scrpr. PU 6" bit/7" csg scrpr, RIH. 7" @ 14,323' 13,324' PBTD, TOL @ 12,072' Wt. 9.9, PV 15, YP 5, PH 11, WL 20, Sol 9 RIH w/bit & scrpr, wsh cmt stringers f/12,072'-12,290'. Tst lnr lap to 3000 psi; lost pressure to 1500 psi. POOH, PU RTTS, RIH, tst 9-5/8" @ 6000'; OK, leaked dnhole. RIH, tst lnr lap; OK, POOH, lk'g f/leak in 9-5/8" csg. Locate top of leak @ 8395', csg holds 3000 psi, leaks dnhole. Now attempting to pinpoint length of leak. Well no. K-25RD The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 4/17/86 ARCO Oil and Gas Company,~,'a' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report olficial or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska Trading Bay Unit 2/14/86 2/15/86 thru 2/18/86 2/19/86 2/20/86 2/21186 Date and deptl~ as of 8:00 a.m. County or Parish Lease or Unit North Slope Borough ADL 18730 Complete record for each day while drilling or workover in progress The above is correct For forr~preparation and distribution I see Procedures Manual Section 10, Drilling, Pages 86 and 87 IState Alaska JWell no. K-25RD 7" @ 14,323' 13,324' PBTD, TOL @ 12,072', RIH w/lnr dressing tl Wt. 9.8, PV 16, YP 6, PH 11, WL 21.4, Sol 9 Locate leak bet 8395'-8405'. Circ, POOH, LD RTTS. Rn csg inspection log f/8328'-surf. PU & RIH w/lnr dressing tl. 7" @ 14,323' 6481' TOL, Drlg cmt Wt. 9.8, PV 17, YP 16, PH 11.5, WL 16.8, Sol 9 RIH, CO lnr tie-back slv, circ, POOH. RU & rn 106 its, 7", L-80, 29# BTC csg & 27 its, 7", S-95, 29# BTC csg f/6481'-12,083'. Cmt w/750 sx C1 "G" w/6% KC1, 40 gal/100 sx FL45L, 7 gal/100 sx R12L & 2 gal/100 sx SP61. Displ using rig pmp. CIP @ 1730 hfs, 2/15/86. RIH w/bit & scrpr to 5200', WOC. RIH, tag TOL; no cmt on TOL, C&C, POOH, LD DP. Tst BOPE. Chg rams to 3½". RIH w/3½" DP to CO 7". Tst TOL; OK. DO cmt f/11,480'-12,087'. Tst tie-back @ 12,072' to 3000 psi; OK. TIH, drl cmt f/13,070'-13,307'. 7" @ 14,323' 6481' TOL, 12,049' PBTD, Holding press on sqz cmt Wt. 9.8, PV 14, YP 16, PH 11.5, WL 16.6, Sol 9 ~ Fin drlg cmt to 13,358'. Tst perfs @ 1~293'-1~,295'; would not hold, POOH. PU RTTS, pmp 75 sx C1 "G" w/6% KC1, 40 gal/100 sx FL45L, 7 gal/100 sx R12L & 2 gal/100 sx cmt & balance across perfs. Hold 3500 psi on sqz. 7" @ 14,323' 6481' TOL, 12,049' PBTD, Drlg hard cmt Wt. 9.8, PV 15, YP 28, PH 11.5, WL --, Sol 9 Hold press on cmt plug sqz, rel press, POH w/RTTS & LD same. RIH w/bit/scrpr/JB, WOC. RIH, tag cmt @ 12,995', drl cmt to 13,232'. 7" @ 14,323' 6481' TOL, 12,049' PBTD, Prep to tst perfs Wt. 9.6, PV 11, YP 23, PH 11.5, WL --, Sol 8 CO to retnr @ 13,314' WLM, tst perfs 13,293'-13,295' WLM. cmt & rtnr, POH, chg BHA. RIH, drl retnr & cmt f/13,358'-13,370'. Circ & prep to tst perfs. Drl Alaska Oil & Gas IDate 4/17/86 [Tit,e Drilling Superintendent ARCO Oil and Gas Company g~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish [State Alaska Lease or Unit North Slope Borough Trading Bay Unit I ADL 18730 Complete record for each day while drilling or workover in progress 2/22/86 thru 2/24/86 2/25/86 2/26/86 2/27/86 2/28/86 Alaska Well no. K-25RD 7" @ 14,323' 12,049' PBTD, PU 5" DP 8.9 ppg NaC1 w/3% KC1 Tst BOPE to 3000 psi. Fin off-load & spot frac equip. Close blind rams & tst csg w/brine to 2500 psi; OK. PU pkr, tailpipe & t~g guns, RIH on 3½" & 5" DP. 7" @ 14,323' 6481' TeL, 12,049' PBTD, RD Schl 8.8+ ppg NaC1/NaBr w/3% KC1 Displ well to 8.8+ NaC1 brine w/3% KC1, POH. ND Hydrl. RU SOS, rn CET f/11,900'-14,300'. Rn Digital Sonic f/12,300'-14,300', RD Schl. The above is correct see Procedures Manual Section 10. Drilling, Pages 86 and 87 7" @ 14,323' 12,049' PBTD, MIRU CTU 8.8+ ppg NaC1/NaBr w/3% KC1 Fin RIH w/tbg guns. RU SOS, correlate, POOH, RD SOS. Space out. RU & rev out string, set pkr @ 13,651', tst ann to 2500 psi, rel pkr. RU temporary tree & flow ins to tst separator; tst same. Displ string to diesel. Set pkr @ 13,651'. Drop bar, fire guns (shoot 13,715'-13,745'); well did not flow. SI well. RU Camco & tst lub.. Make gage ring run thru tbg tail, POOH. RIH & set press bombs in 2-7/8" nipple @ 13,698'. POOH, RD WL unit. 4/17/86 JTitle Drilling Superintendent 7" @ 14,323' 6481' TOL, 12,049' PBTD, Rev 8.8 ppg NaC1 into cln well FIW (Well Bore) Wsh & rm 200' to TOL, circ hi-vis sweep, POH. RIH, circ hi-vis sweep @ 14,274'. Displ hole w/FIW. RU & begin rev 8.8+ ppg NaC1 into wellbore. 7" @ 14,323' 6481' TeL, 12,049' PBTD, RIH w/8½" bit & 9-5/8" scrpr Wt. 9.6, PV 10, YP 11, PH 11.5, WL --, Sol 8 Press tst perfs @ 13,378'-13,380' WLM to 3000 psi; lost 300-400 psi/30-60, min. Drl retnr & cmt & CO 7" lnr to PBTD. Tst all perf zones & csg to 2600 psi f/30 min; OK, POH. RIH w/7" BP on DP, set @ 6518', POH. MU tst tls, RIH, set @ 6447'. Rn drawdown tst on lap, POH dry, 33 stds wet -- fluid flowed into string prior to first stabilization period. Tst lap to 1500 psi, drawdown OK. Redress tst tls, RIH, set tls @ 6447', re-rn drawdown tst on lap, POH dry; tst good, LD tls. RIH w/6" bit & 7" scrpr, drl retnr @ 6518', POH. PU 8½" bit & 9-5/8" scrpr, RIH to remove junk f/top of lnr lap. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District IiCounty or Parish i Alaska North Slope Borough FioJd Lease or Unit Trading Bay Unit ADL 18730 Date and deptll 3/01/86 thru 3/03/86 3/04/86 3/05/86 3/06/86' 3/07/86 as of 8:00 a.m. Complete record for each day while drilling or workover in progress Alaska IWell no. K-25RD 7" @ 14,323' 12,049' PBTD, Frac 8.9 ppg NaCl/NaBr w/3% KC1 MIRU CTU, RIH to 5000', lifting well w/lift gas. Blow well dry. SI f/4 hr PBU. Blow 13.5 bbls f/string. SI well f/fluid rise, blow well dry. SI well, bleed all ins, rev circ thru choke, rel pkr, CBU, bal fluids. RU WL unit, retrv press bombs. Shift SS to closed position, POOH, RD WL. RU SOS, log GR/CCL/Temp f/12,800'-13,866'. Set pkr @ 13,560' MD. Perform formation breadown, pmp in, flow back & step rate injection tsts. 7" @ 14,323' 12,049', Analysis data frac 9.8 ppg NaC1 Brine w/KC1 M&P data frac@ 15 BPM w/max press of 8900 psi. Rn post data frac temp logs. Prep f/fracture stimulation. Analysis data frac. 7" @ 14,323' 12,049', Mx'g gel 9.8 ppg NaC1 Brine w/KC1 Preheat frsh wtr in pits, transfer to frac tanks. bbls Dowell SF III w/3% KC1. Prep f/frac. Mx 1250 7"~@ 14,323' 12,049', Rn 3rd temp log 8.9 ppg NaC1 w/3% KC1 Cont heat'g frac fluid. Gel up, roll fluid. Prep to frac Bench 4. Tst Ins to 1000 psi. Pmp frac treatment, 1368 bbls slurry w/60,000# 20/40 sand @ 5600 psi-7800 psi @ ±15 BPM. FIP @ 1850 hrs, 3/5/86. Monitor press. RD Dowell. RU Schl, rn post temp logs (Temp/GR/CCL). Rn #1 f/13,904'-13,375'. Rn #2 f/13,865'-13,320'. · 7" @ 14,323' 12,049', Flow tst'g well 8.9 ppg NaC1 w/3% KC1 Fin post temp logs; 3rd rn f/13,865'-13,320'. RD Schl. RU Camco, shift SSlv, set HP gages in nipple @ 13,618', RD Camco. Displ DP to diesel. RU CTU f/gas lifting. Post flow tst Bench 4 frac. 3/08/86 7" @ 14,323' thru 12,049', POH w/tst string 3/10/86 8.9 ppg NaC1 w/3% KC1 Flow tst Bench 4 frac. Gas lift well w/coiled tbg. Stage lift oil/wtr f/2500'-8500' to surf. Flow tst Bench 4 frac thru perf interval 13,715'-13,745' (1SPF). Gas lift well w/coiled tb~ @ Theaboveiscorrect 9000r MD. Production rate of 300-400 BPD. SI f/PBU. Rev & Signature circ out, PI~t~/tst string. [it,e For form preparation and distribution see Procedures Manual Sectioj~p,J~'~ Ddlling. Pages86and8~~.~,~.~..~./~_.....,_.~__.~/ 4/17/86 ARCO Oil and Gas Company~r'~' ' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Alaska I County or Parish Field lLease or Unit Trading Bay Unit I ADL 18730 Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. North Slope Borough IState Alaska JWell no. K-25RD 3/11/86 3/12/86 3/13/86 3/14/86 3/15/86 thru 3/17/86 The above is correct Signatur~~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 7" @ 14,323' 12,049', RU DA perf equip 8.9 ppg NaC1 w/3% KC1 POH w/tst string. Tst BOPE. RU SOS, set EZ retnr @ 13,357' WLM, RD SOS. RIH w/tst string. Set RTTS w/tail @ 13,169' WLM. Displ DP to diesel. RU DA perf guns, equip & lub. 7" @ 14,323' 12,049', SI f/PBU 8.9 ppg NaC1 w/3% KC1 RIH, perf 13,305'-13,340' WLM w/4 SPF, 90° phasing, RD WL. coiled tbt & tst. Gas lift & displ diesel f/DP 0'-10,000'. lift @ 10,000'. No flow. SI f/1 hr. Gas lift @ 10,000' 2 bbls. Well SI f/PBU. 7" @ 14,323' 12,049', Prep f/injection tst 8.9 ppg NaC1 w/3% KC1 Pre-frac flow tst, Bench 1. SI f/PBU. prep f/IR tst. Rev out DP. RU Dowell & 7" @ 14,323' 12,049' PBTD, 14,221' Top of Junk, Rn'g compl 8.7 ppg FIW w/3% KC1 CO 282' of sand to top of retnr, cln hole w/hi-vis sweeps. Drl retnr & CO 518' of sand to top of junk. Cln hole w/hi-vis sweeps, POH, LD DP. Make gage ring/JB rn. MU WL, RIH w/pkr, stopped @ 12,300'+, unable to wrk below, POH, LD pkr & tailpipe. Make gage ring/JB to 13,300'. MU tbg conveyed pkr & begin rn'g 3½"/4½" compl. Date ITitle 4/17/86 Drilling Superintendent RU Gas , rectd 7" @ 14,323' 12~049', Prep to CO sand 8.8 ppg NaC1 w/3% KC1 Perform injection rate tst. Prep f/frac. Pmp frac treatment; treatment press'd out w/20,000# of 20/40 sand in formation. Pull up, rev out, POH. MU CO BHA & RIH. AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Fie~d ICounty or Parish Lease or Unit Title Trading Bay Unit Auth. or W.O. no. A~E 495689 PDC-ARCO Rig #58 Accounting cost center code State Alaska North Slope Borough ADL 18730 Resume operations suspended 8/25/85 Well no. K-25RD AP1 50-733-20180-01 ~erator ARCO Alaska, Inc. A.R.Co. W.I. 121[ Spudded or W.O. begun Date Resume re-drl oper' ,1/03/86 Date and depth Complete record for each day reported as of 8:00 a.m. 3/18/86 thru 3/20/86 Iotal number of wells (active or inactive) on this i Dst center prior to plugging and I bandonment of this well I our [Prior status if a W.O. I 1200 Hrs. 7" @ 14,323' 12,049' PBTD, 14,221' Top of'Junk, RR Rn 76 its, 4~", 12.6#, N-80 BTC tbg & 351 its, 3½", 9.2#, N-80 BTC tbg & lnd w/SSSV @ 281', FHL pkr @ 13,126', TT @ 13,156'. Tst tbg & set pkr. ND BOPE, NU & tst tree. Turn well over to Production @ 1700 hrs, 3/17/86. Fin demobilizing rig @ 0600 hrs, 3/20/86. Old TD [ New TD I PsDepth Released rig ]Date I Kind of rig Classifications (o11, gas.le~0 Mrs. 3/1 ]:y"~ ~ppletion (single, dual, etc.) / Producing method Oil /Official res~]~l~.~l'~(s) / Potential test data Flowing Trading Bay 14,282' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date ~ corrected The above is correct For form preparation and distribution-------~-- --~ ~,.,k..,,__, · n tl]~ ~_r____no.~ ~ ~ ~ a n~_u~er_n_en_e.._ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. SUB.SURFACE DIRECTIONAL SURVEY ~] UIDANCE F~ONTINUOUS r~OOL Company Well Name Field/Location Job Reference No. 71459 Lo~3oed By: HEATH ARCO ALASKA~ INCORPORATED TBU K-25 (731'FSL~14g'FgL,$~¢,lT.TgN~R~3W,SM) MCARTHUR RIVER.KENAI_ALASMA Date , FEB.8,1986 Computed By: KRUWELL SCHLUMBERGER O I RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC WELL TBU K-2S FIELO TRADING BAY COUNTRY USA RUN ONE DATE LOOOEO 08 - FEB - 86 REFERENCE 0000714S9 342. WELL: TBU K-k~ (731'FSL & 142'FEL,SEC.17,T9N,RI3W,SM) VERTICAL PROJECTION -~,ooo -zooo o o ~ooo ~ooo sooo eooo l OOOO ~ooo _..;...~.x_.;...~L,:'_,~-~., ........ ~---.-.'--;-~.-~--7-.~-:.--;--~-J-4-: i: l...;-~.~,-.l- .-~+-~-: ~.74...i...; 1 ..... ;..~ ~..J...._.~..:..LI...i.,;.., ...... ; .... !/.J...:.. ;...;.;'. l ...... ;.-:,.--1-, ~ L~. ~ .--~::'i:.'~::~"~..C--.~:'~:': ~:"..::~:i ::~:::.~':~ :~': [:;.U<::'.-f. t'!::~:5:~l:.~:~'?j:tt.:t t: b~ '('t :.:::!.::!':.~::~:"f.h:'!:'i: f':i:::~:: ::~'. :.-.:~.' !' '!' !"'..':: i' '}' '~-'-.:': ~. 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L~o K-25 TRADING BAY KENAItALASKA SURVEY DATE: 08-FEB-86 ENGINEER: HEATH METH53$ OF COMPUTATION T30L LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION:. LINEAR VERTICAL SECTION: HORIZo DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 17 DE, 3 6 MIN EAST, ARCO ALASKAt INC. T.B.U. K-25 TR&DIN3 B&Y KENAItALASKA CO~PUTATZ3hi DATE: 8-MAY-B6 PAGE DATE OF SUR~rE¥'. 08-FEB-86 KELLY BUSHING ELEVATION: 100.00 FT ENGINEER: HEATH INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ.;DEPARTURE SECTION SEVERITY NORTH/SOUTH EA$T/dEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL ~EVIATION AZIMUTH DEPTH DEPTd. DEPTH DEG qZN DEG 0.00 0.00 -100.00 0 0 N 0 D E 100.00 100.00 0.00 0 5 S 38 4.5 g 200.00 ZO0.O0 100.00 0 4 S I I E 300.00 300.00 200.00 O' 6 S 16 28 E ~00.00 400.00 300.00 0 5 S 56 57 E "qO.O0 500.00 400.00 0 24 N 62 Z6 E 0.00 599.99 699.99 0 28 N 18 39 E ,dO.30 699.99 599.99. 0 18 N 21 23 W 800.OD 799.99 699.99 0 22 N. 10 5 W 900.00 899.99 799.99 0 36 N 37 4.1 W' 0.00 0.00 0.00 N 0.06 0.16 0.08 S 0.17 0.09 0.21 S 0.32 0.06 0.36 S 0.44 0.23 0.4.7 S 0.45 0.77 0.39 S -0.23 0.16 0.6~ N -0.87 0.32 1.13 N -1-39 0.4~ 1.SI N -2.35 0.26 2.50 N 1000.00 999°98 899.98 1100.00 1099.98 999.98 1200.00 1199.97 1099.97 1300.00 1299.97 1199.97 1400.00 1399.97 1299.97 1500.00 1699.97 1399.97 1600.00 1599.97 1499.97 1700.00 1699.97 1599.97 1800.00 1799.97 1699.97 1900.00 1899.97 1799.97 0 27 N 18 29 W -3.15 0 31 N ~,1 SO W -6.12 0 ZO N 20 3 W -6.76 0 12 N 50 I W -5.23 0 17 N 56 4.6 W -5.72 0 7 S 55 14 W -5.83 0 14. S' 70 52 W -5.72 0 8 S 86 52 W -5-72 0 10 S 60:29 W -5.79 0 10 S 64. 23 W, -5.76 0.38 0.36 0.36 1.33 0.45 0.51 0.58 0.50 2000.00 1999.97 1899.97 0'11 2100.00 2099.92 199~.92 2 52 2200.00 Z199.65 2099.,5 7 32 2300.00 2298.23 2198.23 10 10 2600.00 2396.13 2296.13 13 30 2500.00 2492.73 2392.73 16 18 i< ].00 2588.00 24.88.00 19 6 __ .00 2681.54 2581.5, 22 19 2B00.00 2773.34. 2673.0¢ 25 16 S 13 65 E 2900.00 2862.36 2762.36 28 2 'S 13 26 E S 37 29 E -5.55 2.11 S 48 4.8 E -3.94 4.76 S 17 43 E 5.18 3.~3 S 13 3~' E 20.67 2.42 S 16 5 E 40'97 3.62 S 16 4.5 E 66.81 2.88 S 15 26 E 97.15 3.26 S 13 51 E 132.41 3.10 172.67 2.95 217.52 2.46 S 13 6 E 266.54 3000.00 29&9.44 2849.44 31 5 3100.00 3033.60 2933.~0 34 23 3200.00 3114..53 3016.53 37 Z2 3300.00 3192.21 3092.21 40 ~8 3600.00 3266.00 3166.00 4.4 13 3500.00 3336.32 3236.02 4.6 57 3500.00 3401.97 330,1.97 49 52 3700.00 3465.88 3365.88 50 59 3800.00 3528°62 3428.42 51 27 39'00.00 3590.04 3490.04 52 33 ::).00 E 0.06 W 0.13 W 0.08 W 0.03 W 0.27 E O. 66 E 0.70 E 0.56 E 0.11 E 0.00 ~i 0 0 E 0.10 S 37 22 W O. 25 S .31 7 W 0.37 S 12 56 W 0.¢7 S 3 43 W 0.47 S 36 59 E 0.79 N 56 18 E 1.33 N 32 I E 1.71 N 18 29 E 2.50 N 2 33 E S 13 17 E 320,70 S 13 11 E 379.02 S 13 20 E 441.82 S' 13 59 E 509.16 S 14. 56 E 580.46 S 15 16 E 655.57 S 15 22 E 732.44 S 15 25 E 810.44 S 15 30 E 889,16 3.21 N 4.06 N 5.01 N 5.r, 1 N 5.53 N 5.34 hi 5.28 N 5.31 N 5.19 N 0,,29 W 0.81 W 1,17 W 1.50 W 1.85 W 1.85 W 2.08 W 2.30 W 2.4.~ W 2.70 w 3.ZZ N 5 8 W 4.1~ N 11 19 W 4..77 N 16 12 ~ 5.23 ~ 16 4.1 W 5.72 N 18 52 W 5.83 N lB 31 w 5.7~ N 21 18 ~ 5.76 N 23 30 W 5.8~ ~ 26 38 W 5.86 N 27 30 d 5,06 N 4.18 N 4.05 S 19.06 S 38.70 S 63.&3 S 92.58 S 126.75 S 165.95 S 209.60 S 2.4~ W 5.62 N 25 44 W' 0.21 E 4'.19 N 2 50 E 4..45 E 6.02 S 67 43 E 8.35 E 20.81 S 23 38 E 13.53 E ~'1.00 S 19 16 E 21.06 E 66.82 S 18 20 E 29.44. E 97.15 S'17 38 E 38.30 E 132.61 S 16 48 E 67,82 E 172.70 S 16 4. E 58.4,½ E 217.60 S 15 34 E 3.10 2.11 3.23 3.43 3.23 3.63 0.93 1.08 0.33 0.87 257°¢4 S 69-66 E 266.70 S 15 8 E 310.27 S 82.14. E 320,95 S 14. 49 E 367.17 S 95.50 E 379.39 S 14 34. E 428.66 S 109-84 E 642.32 S 14. 22 E 694.01 S 125.77 E 509.77 S 16 16 E 563.14 S 143.56 E 581.15 S 1~ 17 E 635.65 S 163,32 E 656.29 S 14. 24 E 709.85 S 183.55 E 733.20 S 1~ 29 E 785.08 S 204.27 E 811.22 S 16 35 E 860.99 S 225.25 E 889.97 S 14. 39 E ARCO ALASKAt IYC. T.3.U. K-25 TRAOIN~ BAY K~NAItALASKA COMPUTATI3~ DATE: 8-HAY-8S PAGE 'Z DATE OF SURVEY: 08-FEB-86 KELLY 5USHING ELEVATION: ENGINEER: HEATH INTERPOLATED VALUES FOR EVEN 100 FEET, OF MEASURED DEPTH 100.00, FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATIDN'AZ[MUTH 3EPTH DEPTH DEPTH DEG MIN DEG HIM VERTICAL DOGLEG RECTANGULAR COORDINATES H3RIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/LO0 FEET FEET FEET, DEG MIN 4000.00 3650.84 3550.84 53 4100.00 3710.90 3610.90 53 ~7 4200.00 3769.34 3669.34 54 21 4300.00 3827.09 3727.09 54 58 4~00.00 3884.79 3784.79 55 1 '-30.OO 3942.56 3842.56 54 3 JO.O0 ~000.99 3900.99 54 52 ~00.00 4058.33 3958.33 54 38 4aO0.O0 ~116.26 ~016.26 54 31 ¢900.00 4175.03 ~075.03 54 S 15 27 E 96~.52 S 15 26 E 1048.44 S 15 5 E 1129.54 S l& 11 E 1211.10 S 13 50 E 1292.65 S 13 35 E 1374.13 S 13 39 E 1455.14 S 13 41 E 1536.91 S 13 ~1 E 1618.29 S 13 36 E 1699.04 1.65 937.51 S 246.41 E 969.35 S 1~ 43 E Z.6~ 1014.5¢ S 267.82 E 1049.30 S 14 47 E 1.17 1~92.82 S 289.Z0 E 1130.~ S 14 49 E 1.11 1171.80 S 309.83 E 1212.07 S 1~ 48 E 3.52 1251.07 S 329.51 E 1293.73 S 1~ 45 E 2.33 1330.37 S 3~8.82 E 1375.35 S 1~ 41 E 1.38 1~09.23 S 368.01 E 1~56.49 S 1~ 38 E 0.60 1~88.8~ S 387.32 E 1538.40 S 14 34 E 0.95 1568.34 S 406.62 E 1619.91 S 1¢ 32 E 2.74 1646.67 S ~25.68 E 1700.80 5'l~ 29. E 5000.00 ~233.3~ 4133.34 54 2 5100.00 4291.89 &191.89 54 18 5200.00 ~350.75 ¢25~.75 53 ~4 5300.00 ~409-76 ~309.76 53 48 5~00.00 ~469.31 4369.31 52 ~0 5500.00 4529.21 4429.21 53 37 5600.00 ~588.94 4488.9~' 52 59 5700.00 4649,06 ~549.06 52 ~8 5800.00 ~708.92 ~608.92 53 36 5900.00 ~768.59 ~668.69 52 57 S 13 38 E 1780.13 S 13 48 E 1861.05 S 13 43 E 1941.76 S 13 44 f 2022.35 S 13 35 E ZIOZ.S4 S 13 49 E 2182.47 S 13 2~ E 2262.53 S 13 ~33 E 23G2.29 S 13 39 E ~422.23 S 13 38 E 2502.26 0.75 0.46 1.71 0.6~ Z.13 0.79 O.2B 0.67 1.00 2.76 1725.60 S 444.87 E 1782.03 S 1¢ 27 E 1)04.38 S 464.01 E 1863.08. S 14 25 E 1882,89 S' 483.29 E 1943.92 S 1¢ 23 E 1961.27 S 502.58 E 2024.65 S 1~ 22 E 2039.34 S 521.5~ E 2104.97 S 14 ZO E 2117.13 S 540.50 E 2185.04 5 1~ 19 E 2195.06 S 559.~B E 2265.24 S 1~ 17 E 2272.73 S 578.25 E 2345.14~ S 1¢ 16 E 2350.50 S 597.02 E 2~25.23 S 1~ 15 E 2~28.~9 S 616.01 E 2505.~0 S 1~ 14 E 6000.00 4829.95 4729.95 52 18 S 13 23 E 2581.14 6100.00 ¢890.80 4790.80 52 57 S 13 5 E ~660.32 6200.00 4952.41 ~852.~1 51 2 S 12 ~O E 2738.85 6300.03 5013.89 ~913.89 51 ~1 6~00.00 5077.28 4977.28 SO 34 6~.nO.O0 5140.52 50~0.52 50 58 .oo 6,oo.oo S 12 36 E 2817.47 S 12 25 E 289¢.56 S 12 19 E 2971.78 S 12 15 f 3048.81 S 12 6 E 3125.39 S 11. 52' E 3201.64 S 11 15 5 3279.16 0.09 1.98 1.53 3.78 0.58 2.2~ 0.20 1.79 0,¢7 2505.36 S 634.39 E 2584.&3 S 14 12 E 2582.58 S 652.67 E 2663.77 S l& 10 E 2659.36 S 670.16 E 2742.50 S 1~ 8 E 2736.30 S 687.46 E 2821.33 S 1¢ 6 E 2811.80 S 704.20 E 2898.64 S 14 3 E 2887.~5 S 720.90 E 2976.08 S 1¢ I E 2962.99 S 737.35 E 3053.35 S 13 58 E 3338.~9 S 753.63 f 3130.17 S 13 55 E 3113.01 S 769.43 E 3206.69 S 13 52 E 3189.32 S 785.00 E 3284.51 S 13 49 E 7000.00 5457.~0 5357.40 51 27 7100.00 5518.52 5418.62 51 52 7200.00 5579.~4 5479.44 52 59 7300.00 5639.~4 5539.44 :53 ~0 7~00.00 5698.~0 5598.00 54 15 7500.00 5757.~3 5657.03 52 51 7600.00 5816.83 5716.83 53 28 7100.00 5877.90 5777.90 51 22 7BO0.O0 5940.52 5840.52 51 0 7900.00 6003.57 5903.57 51 24 S 10 53 E 3356.83 S 10'18 ~ 3435.39 S 10 B E 3514.18 S 9 4~ E 3593.56 S 9 35 E 3573.92 S 9 3B E 3753.95 S 9 31 E 3833.40 S 9 3 E 3911.85 S 8 27 E 3988.97 S 8 13 f ~065.68 1.91 2.47 t.7Z 2.15 0.33 3.01 1.10 1.40 3265.97 S 800.01 E 3362.53 S 13 45 E 3343.70 S 81~.52 E 3¢41.48 S 13 41 E 3~21.81 S 828.61 E 3520.70 S 13 36 E 3500.61 S 842.37 E 3600.54 S 13 31 E 3580.54 S 855.88 E 3581.~1' S 13 26 E 3560.10 S 869.¢~ E 3761.95 S'13 21 E 3739.13 S 882.78 E 3841.92 S 13 17 E 3817.28 S 895.54 E 3920.92 S 13 12 E 389~.35 S 907.28 E 3998.64 S 13 6,E 3971.14 S 918.56 E 4075.99 S 13 I E ARCO ALASKA. INC. T.B.U. K-Z5 TRADI~S BAY KENAImALASKA COMPUTATID~ OATS:: 8-MAY-B5 PAGE DATE 3F SURVEY: OB-FEE-86 KELLY BUSHING ELEVATION: ENGINEER: HEATH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 100.00 FT TRUE SdB-SEA COURSE MEASURED VERTICAL VERTI:AL DE¥IATIDN AZIMDTH DEPTH DEPTH DEPTH 3EG MIN DEG MIN VERTICAL DOGLEG RECTANSULAR. CODRDZNATES'H3RIZo DEPARTURE SECTION SEVERZTY NDRTH/SDUTH. EAST/WEST DIST. AZIHUT'H FEET DEG/iO0 FEET FEET FEET: DEG MIN 8000.00 $067.14 5967.14 %9 8 8100.00 6131.75 6031.75 49 50 8200.03 6196.81 6096.81 49 3~ 8300.00 5261.90 5161.90 49 1 8~00.00 63Z7.25 5227.25 48 ~9 /00'00 639~'82 629~'82 %6 %9 ~0'00 6462'58 5362'68 '8 17 BFo0'o0 6527'00 6'27'00 50 29 8800'00 6589'01 6489'01 53 59 8900.00 $6¢4,.~4 65,q.9¢ 56 13 9000.00 6700.37 6600.37 56 %0 9100.00 6756.06 S656.06 55 7 9200.00 6815.11 6715.11 52 1 9300.00 6878.79 5778.79 49 39 9400.00 6942.99 6842.99 50 55 9500.00 7002.~9 6902.49 55 5 9600.00 7059.24 6959.24 55 ~2 9700.00 7115.%0 7015.40 55 36 9800.00 7171.62 7071.62 56 28 9900.00 7227.36 7127.36 56 11 S 7 38 E. ~141.86 $ 7 2.E ~217.08 S 5 19 E ~291o77 S 6 3 E ~366.28 S 7 38 E ~4,0.66 S 13 6 E ~513.83 S 13 ~9 E ~587.14 S 13 %6 E 4663.56 S 13 58 E '~7~1.87. S 1'2 58 E ~24.59 S 11 23 E ~90'7.49 S 11 46 E ~990.09 S 15 38 E 5070.59 S 19.25 E 5147.66 S 20 3 E ~22~.22 S 19 52 E 5304.46 S 19 45 E 5386.69 S 19'36 E 5%69.35 S 19 35 E 5551.97 S 19 3~ E 563%.91 3.7~ %047.58 S 929.16 E ~152.86 S 12 55 E 1.58 4123.26 S 938.97 E ~.228.82 5 1Z 49 E 1.79 4198.69 S 947.79 E 4304.33 S 12 43 E 0.90 4274.16 S 955.89 E %379.75 S 12 36 E 3.85 ~349.38 S 96,.32 E 4%55.00 S 12 30 E 2.49 4421.82 S 977.70 E 4528.62 S 12 28 E ¢.62 4%93.15 S 995.16 E %60Z.04 S 12 29 E 1.32 4567.51 S 1013.35 E 4678.57 S 1;2 30 E 5.92 4643.63 S 1032.23 E 4756.97 S 12 31 E 2.4% ~72%.16 S 1051.82 E 4839'83 S 12 33 E 1.11 4805.5~ S 1069.20 E 4923.05 S 12 32 E 3.76 ¢887.04 S 1085.18 E 5006.08 5' 12 31 E 5.48 2.6~, ~.05 0,.9~ 0.49 1.01 1'.29 6365,45 S 110~.10 E 5086.72 S 12 32 E 5038.84 S 1127.65 E 5163.%8 S 12 36 E 5110.88 S 1153-85 E 5239.51 S 12 43 E 5186.,1 S 1181.21 E 5319.22 S 1Z ~9 E 5263.86 S 1209.12 5: 5%00.94 S 1Z 56 E 5341.78 S 1236.97 'E 5%83.13 $ 13 2 E 5~19.64 S 1264.8% E 5565.28 S 13 8 E. 5%97.86 S 1292.66 E 56¢7.78 S 13 13 E 10000.00 7283.89 7183.89 55 13 10100.00 73~0.79 72,~.79 55 ~3 10200.00 7396.08 7296.08 57 22 10300.00 7449. Z9 73,9.29 57 59 10%00.00 7501.64 7401.64 58 ~8 !O-.rnO.O0 755,.~3 7454.63 57 33 · 39 7608.½6 7508.~6 57 25 1 .~0.00 76&2.,3 7562.43 56 53 10800.00 7718.00 7618.00 55 ~¢ 10900.00 7774.33 7674.03 55 55 S 19 23 E 5717.33 S 19 13 E 5799.49 S 19 5 E 5882.76 S 19 IS E 5967.38 S 18 51 E 5052.52 S lB 41 E 5137.30 S 18 9 E 5221.54 S 17 55 E 6305.72 S 17 48 E 5388.85 S 17 29 E 5471.66 0.86 1.89 2.33 1.42 0.82 0.80 O.TB 1.20 1.56 1.81 5575.65 S 1320.12 E 5729.79 'S 13 19 E 5553.23 S 13%7.36 E 5811.57 S 13 24 E 5731'94 S 1374.71 E 5894.~8 S 13 29 E 5811.92 S 1402.49 E 5978.74 S 13 34 E 5892.¢4 5'14.30'30 E 6063.55 S 13 38 E 5972.73 S 1457.6% E 6148.02 S 13 ~2 E 6052.66 S 148¢.33 E 6232.01 S 13 46 5: 6132.73 S 1510.35 E 6315.97 5 13 50 E 6211.86 S 1535.83 E 6398.91 S 13 53 E 6290.78 S 1560.9% E 6~81.55 S 13 56 E 11000.00 7~30.53 7730.53 55 37 lltO0,O0 7887. t5 7787.15 55 35 11200.00 7942.63 78~2.63 56 ~6 11300.00 7996.84 7896.84 57 55 11400.00 8049.69 7949.69 58 ~0 11500.00 8101.59 8001.59 58 %0 11600.00 8153.~4 8053.54 58 50 11700.00 8205.11 8105.11 59 5 11800.00 8256.Z0 8156.20 59 17 11900.00 8307.55 8207.55 59 8 S 1.7 15 E 6554.17 S 17 3 E 5536.60 S 16 42 E 5719.79 S 16 55 5: ~803.82 S 11 B E 6888.71 S 17 16 E .5974.19 S 17 23 E 7059.62 S 17:18 E 7145.29 S 17 13 E 7231.26 S 17 13 E 7317.08 0.18 I.OB 0.92 1.0~ 1 0.85 0.20 0.2% 0.38 0.88 6369.51 S 1585.63 E 6563.91 S 13 58 E 6448.25 S 1610.03 E 6646.21 S 1% I E 6527.90 S 1634.0% E 6729.30 S 1~ 3 E 6608.34 S 1658.32 E 6~13.24 S 1% 5 E 6689.~6 S 1683.33 E 6898.01 S 1% 7 E 6771.14 S 1708.52 E 6983.37 S 1~ 9 E 6~52.$9 S 1733.99 E 7068.67 S 1% 11 E 693~.66 S 1759.56 E 715%.22 S 16 1% E 7016.56 S 1785.07 E 7240.06 S 1, 16 E 7098.5~ S 1810.%5 E 7325.77 S 1~ 18 5: ARCO ALASKA9 INC. T.B.U, K-25 TRADING BAY KENAItALASKA COMP~TATIBN DATE: 8-HAY-85 TRUE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DATE OF SURVEY: 08-FEB-86 KELLY BUSHING ELEVATION: , ENGINEER~ HEATH INTERPOLATED VAL~ES FOR EVEN 100 FEET DF MEASURED DEPTH SUB-SEA CDURSE VERTICAL DOGLEG RE&TANGU'LAR COORDINATES H3R'IZ. DEPARTURE SECTION SEVERITY.N3RTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH 3EG 12000.00 8357.93 8257.93' 60 35 12100.00 8405.85 8305.85 61 52 12200.00 8452.89 8352.89 61 12300.00. 8500.88 8400.88 61 1 12400.00 8549.40 rr ~0'00 8601.¢1 8501.411 '56 57 · JO.~O 8661.92 8561.92 50 15 12700.00 9724.32 8624.32 52 12800.00 8782.37 8682.37 56 13 12900,00 8836.91 8735.91 56.56 13000°00 B891.$8 8791.68 56 13100.00 8946.38 8846.38 56 35 13200.00, 9001.99 8901.99 55 53 13300.00. 9058.23 8958.23 56 4 13~00.0~ 9114.38 9014.38 55 28 13500.00 9171.26 9071.26 55 16 13500.00. 9228.31 912B.01 55 31 13700.00 9284.¢8 9184.48 55 50 13800.00 9340.89 9240.89 54 13900.00 9400.¢5 9300.45 52 55 14000.00:9460.83 9360.B3 52 54 14100.00 9520.78 9~20.78 53 20 1~200.00 9580.84 9480.84 52 ~3 16300.00. 9661.50 9541.60 52 30 1~325.00' 9656.82 9556.82 52 30 PAGE '¢ · 100.00 PT DEG Ml~ FEET DEG/IO0 FEET FEET FEET DEG MIN S 17 14 E 7403.45 S 1T 19 E 7491.22 S 17 12 E 7579.46 S 17 3 E 7667.19 $ 17 ZO E 775~.64 S 17 ~¢ E 7840.03 S 16 53 E 7919.52 S 18 26 E 7997.63 S 19 12 E 8078.99 S gO B E 9162.72 S 20 7 E 82~6.25 S ZO 37 E 8329.84 S 20 28 E 8412.78 S 20 7 E 8495.34 S ZO 2 E 3577.97 S 20 35 E 8660.10 S 21..21 E 8742.25 S 21 B E 882~.55 S 20 27 E 8906.93 S 19 22 E 8987.16 1.43 0.55 0.20 3.65 7.77 1.81 3.09 2.16 1,26 0.53 1.35 0.91 0.78 0.51 0.50 0.62 0.67 0.39 0.65 0.00 0.00 7181.03 S 1836.05 E 7412.0~ S 14 ZO E 7264.82 S 1862.19 E 7499.69 S 14 22 E 7349.10 S 1888.33 E 7587.82 S 1~ 24 E 7~32.93 S 1914-21 E 7575.~5 S 1~ 26 E 7516.~7 S 1940.02 E 7762.80 S 14 28 E 7597.86 S 1965.88 E 78~8,07 S 1~ 30 E 7673.88 S 1989.09 E 7927.48 S 1~.31 E 7748.28 S 2012.92 E 8005.~8 S 1~ 33 E 7825.32 S 2039.17 E 8086.65 S 1~ 36 E 7304.23 S 2067,43 E 8170.14 $ 1~ 39 E 7982.75. S 2096.32 E 8253.41 S 1~ 42 E 8061.24 S 2125,43 E 8336.73 S 1~ 46 E 8138.99 S 215~.76 E 8419.39 S 1~ 49 E 8216.57 S 2183.38 E 8501.72 S 1~ 52 E 8296.27 S 2211.8~ E 8584.12 S 14 55 E 8371.~6 S 2240.23'E 8566.02 S 1~ 58 E 8¢48.32 S 2269.76 E 8747.91 S 15 2 E 8525.18 S 2299.82 E 8829.94 S 15 5 E 8502.31 S 2329.28 E 8912.09 S 15 9 E 8677.88 S 2356.49 E 8992.1~ S 15 11 E 8753.14 S 2382.76 E 9071,66 S 15 13 E 8828.98 .S 2408.33 E 9151.55 S 15 15 E 8904.97 S 2433.18 E 9231.~1 $ 15 16 E 6980.77 $ 2456.89 E 9310.78 S 15 18 E 8999.72 $ 2462.76 E 9330.60 S 15 18 E S' 19 2 E 3066.82 S 18 23 E 91k6.82 S 17 40 E 9Z26.76 S 17 12 E 9306.18 S 17 1Z.E ~326.02 ARCO ALASKA, INC. T.B.U. K-25 TRADING BAY KENAI~ALASKA COqPUTATI~M'DArE: 8-MAY-8S DATE OF SURVEYI 08-FEB-86 KELLY, BUStlING ELEVATION= ENGINEER= HEATH INTERPOLATED VALUES FOR EVEN 1003 FEET DF MEASURED DEPT TRUE SUB-SEA C32RSE MEASURED VERTICAL V~RTI:AL DEVIAT[DN AZ[RUTH 3:PT~ DEPTd DEPTH DEG qIN DEG PAGE IO0oO0.FI VERTICAL DOGLEG RECTANGULAR COORDINATES H3RIZ~ DEPARTURE SECTION SEVERITY'NORTH/SOUTH EAST/WEST DISTo AZIqUTH. FEET DEG/IO0 FEET FEET FEET' DEG 0.00 0.00 -100.00 0 0 N O. 0 E 0.00 1000.00 999.98 899.98' 0 Z7 N 18 Z9 W -3.15 ZO00,O0 1999.97 1899o97 0 41 S 87 29 E -5o55 3000.00 29~9.4~ 28~9.¢~ 31 5 S 13 5 E 266.5~ 40,00.00 3650.84 3550.84 53 I S 15 27 6 968.52 "~0 O0 4233.3¢ 6133.34 54 2 S 13 38 E 1780.13 0:00 4829.95 4729.95 52 18 S 13 23 E Z581.1¢ 7uuO.O0 5457.~0 5357.40 51 27 S 10 53 E 3356.83 8000.00 6067.~& 5967.1~ ~9 8 S 7 38 E ~1¢1.86 9090.90 6700.37 6600.37 56 40 S 11 23 E 6907.49 S 19 23 E. 5717.33 S 17 15 E 6554.17 S 17 16 E 7403.45 S 20. 7 E 8246.25 S 19 2 E 9066.82 S 17 1Z E 9326.02 0.00 0.38 2.11 3.10 1.65 0.76 0.09 1.91 0.00 N 0o00 E 0.00 N' 0 0 E 3.21 N O.Z9 W 3.2Z N 5 8 N 5.06 N Z.~4 W 5.6Z N:.25 44 N Z57.~ S 69.55 E Z66.70' 5 15 8 E 937.51 S 246.~1 E 969.35 S~1~ ~3 E 1725.60 S 444,37 E 1782.03 S 1~ 27 E 2505.36 $ 63¢.39 E 2584o&3 $ 1¢ 12 E 3Z65.97 S 800.01 E 3362.53 S 13 45 E 3.T41 40~7.58 S 929.16 E 4152,86 $ 12 55 E 1.11 ¢805.54 S 1069.Z0 E ~923o05 S 1Z 32 E 0.84 0.18 1-43 0.53 0.67 0.00 5575o6S S 1320.12 E 5729.79 5 13 19 E. 6369,51 S 1585.63 E 6563.91 S 13 58 E 7181.03 S 1836.05 E 7~12.04 S 14 20. E 798Z.75 $ 2096.32 E 8253.~1 5 14 ~2 E 8753o14 S 2382.76 E 9071,66 S 15 13 E 8999.72 $ 2~62.76 E 9330.60 S 15 18 E, 10000.00 7283. a9 7183.89 55 13 11000.00 7830.53 7730.53 55 37 12000.00 8357.93 8257.93 60 35 13000°00 9891.68 879t'68 56 68 14D00.00. 9660.B3 9360.83 52 54 1~325.00 9656.82 9556.82 52 30 A~CO ALASKAt INC. T,.B.Uo K-25 TRJ~DING BAY KENAI, ALASKA CO~PUTATZ]N DATE: 8-MAY~8$ PAGE DATE ~F SUR~EY: OB-FEB-86 KELLY BUSHING ELEVATION:. 100*00 FT. ENGINEER: HEATH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH SUB-SEA COURSE V~RTICAL DOGLEG RECTANGULAR COORDINATES HORZZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZI~UT'H, FEET DEG/IO0 FEET FEET FEET DEG MIN. TRUE MEASURED VERTICAL VERTI:AL DEVIATIDhi AZIHUTH DEPTH DEPT~ DEPTH 3EG ~IN DES 0.00 0.00 100.00 200.00 300.00 -"~0.00 0.00 ~O0.Ol 700.01 800.01 0.00 -100.00 0 0 N 0 3,E 0.00 0.00 0.00 -100.00 0 0 N 0 0 ~ 0.00 0.00 100.00 0.00 0 5 S 38 ~6 W 0.06 0.1¢ 200.00 100.00 0 4 S I I E 0.17 0.0'9 300.00 200.00 0 6 S 16 28 E 0.32 0.05 ~00.00 300.00 0 5 S S& 57 E 0.~ 0'23 500.00 400.00 0 Z~ N ~Z 2½ E 0.45 0.77 600.00 500.00 0 28 N la 39 E -0.23 0.16 700.00 600.00 0 18 N 21 23 ~ -0.87 0.32 800.00 700,00 0 22 N lO 5 W -1.39 900.01 900.00 lO00.OZ 1000.00 900.00 1100.02 llO0.O0 1000.00 1200.03 1200.00 1100.00 1300.03 1300.00 1200.00 1¢00.03 1¢00.00 1300'00 1500.03 1500.00 1¢00.00 1500.03 1600.00 1500.00 1700.03 1700.00 1600.00 1800.03 1800.00 1700.00 800.00. 0 36 N 37 ~1 W -2.35 0.2¢ 0 27 N 1@ 29 W' -3.15 0.38 0 31 N ~1 50 W -~.12 0.35 0 ZO, N 20 3 W' -4.76 0.15 0 12 N 50 O W -5.23 0,36 0 17 N 56 ~5 W -5.72 1.33 0 7 S 55 11 W -5.83 0.45 0 I~ S 70 51W -5.72 0.~1 0 8 S 8~ ~B W -5.72 0,51 0 10 S 60 2~ W -5.79 0.58 1900.03 1900.00 1800.00 0 10 2000'03 2000.00 1900.00 0 ~1 2100.08 ZlO0.O0 ZO00.O0 2 53 2200.56 2200.00 2103.00 7 33 2301.80 2300.00 2200.00 10 13 4.n3.99 2400.00 2300.00 13 38 ~ ].59 2500.00 2~00.00 16 30 2 ~ .73 2600.00 2500.00 19 28 2720.00 2700.00 2600.00 ZZ 53 2829.9~ 2800.00 ZTOO.OO 26 9 S 64 23 W -5.76 0.5.0 'S 87 31 E -5.55 2.11 S ~8 45 E -3.93 ~.7~ S 17 38 E,. 5.25 3.40 S 13 35 E 20.99 S 16 11 E ¢1.92' S 16 36 E 68.98 Z.79 S 15 10 E lOl.~O 3.00 S 13 41 E 1¢0.11 2.70 S 13 47 E 185.63 2.88 29~2.85 2900.00 1800.00 29 9 3059.7¢ 3000.00 2900.00 33 15 3181.76 3100.00 3000.00 36 ~5 3310.31 3200.00 3100.00 41 9 3~8.01 3300.00 3200.00 45 30 3596.93 3400.00 3300.00 49 50 3754.¢5 3500.00 3400.00 51 18 3916.~2 3600.00 3500.00 52 30 ~081.67 3700.00 3503.00 53 19 4252.86 3800.00 3700.00 54 ~0 S 13.13 E 237.97 S 13 19 E 298.29 S 13 12 E 368.01 S 13 25 E 4¢B.55 S 1~ 22 E 543.01 S 15 17 E 653.22 S 15 22 E 774.86 S 15 31' g 902,20 S 15 30 E I033.71 S 1~ 36 E 1172.58 2.87 '3.55 3.57 3.31 2.15 1.17 0.37 1'08 2.7¢ 0.93 0.00 N 0.00 E 0.00 hi 0.00 E 0.08 S 0.06 W 0.21 S 0.13 W 0.36 S 0.08 W 0.~7 S 0.03 W 0*39 S 0*27 E 0.~.~ N 0.66 E 1.13 N 0.70 E 1.62 N 0.54, E 2.50 N 3.21 N 4.'06 N 4.63. N 5.01. N 5.¢1 N 5.53 N 5.34 N 5.28 N 5.3I N 5.19 N 5.06 N 4,.18 N ~t.12 S 19.37 S 39.62 S 65.50 S 96.68 S 13~.24 S 178.55 S 229.54 S 288.&1 S 0.11 E 0.29 W 0.81 W 1.17 W 1.50 W 1.85 W 1.85 W 2.09 W 2.30 W Z.~ W 2,70 W 0.21 E 4.4,7 E 8.42 E 13.80 E O. O0 N 0 0 E 0.00 N' 0 0 E '0.10 S 37 22 W O. 25 S 31 7 W 0.37 S 12 56 W 0.4,7 S 3 4,3 i~ 0,4,7 S 3,~ 59 E 0.79 ~1 56 18 E 1.33 N 32 I E 1.71 N 18 29 E 2,50 N 2 33 E 3.22 N 5 8 W 4- 14 N 11 19 ~ ~+.77 N 14 12 W 5.23 N 16 ¢1 W 5.72 hi18 52 W 5.83 ~ 18 31 ~' 5.7¢ N 21 18 ~ 5.76 N 23 30 W 5.8~, ~12r, 38 d 5.86 'N 27 30 W 5.62 N 25 4,3 W 4,.19 N 2 53 E 6.08 S 47 23 E 21.12 S 23 29 E ¢1.95 S 19 12 E 21.65 E 68.99 S" 18 17 E 30.56 E 101.4,0 S 17 32 E 4,0.13 E 14,0.11 S 16 38 E 50.9Z E 185.67 S'15 55 E 63.17 E 238.07 S' 15 23 E 7&.95 E 298.50 S l& 56 E 356.44 S 92.98 E 368.37 S 1~ 37 E ~35.03 S 111,40 E ¢49.06 S 1~ 21 E 526.88 S 134.07 E 543.67 S 1~ 16 E 533.38 S 162.70 E S53.94, S 1¢ 24, E 750.76 S 19~.83 E 775.63 S 1~ 32 E 873.56 S 228.75 E 903.01 $ 1¢ 4,0 E 1000.34, S 263.88 E 103a.56 S 1~ 4,6 E 1134.4,4 S 300.25 E 1173.50 S 1~ 4,9 E ARCO ALASKA. T.BIU. K-Z5 TRADINS BAY KENA[.ALASKA COqPUTAT[DN DATE: 8-HAY-86 PAGE DATE OF SURVEY: OB-FEB-86 KELLY BUSHZNG ELEVATION:, lOO.O0,FT ENGINEER: HEATH INTERPOLATED VAL]ES FOR EVEN 100 FEEt DF SUB-SEA DEPTH TRUE SYB-SEA COURSE VERTICAL DOGLEG RECTANGULAR CDDRDINATES'H3RZZ..,DEPARTURE ~EASURED VERTICAL VERTICAL OEVIATZDN'AZINUTq SECTION SEVERIT¥,NDRTH/SOUTfl. EAST/NEST DIST. AZZMUTH DEPTH DEPTH DEPTH BEG NIN DEG H[~ FEET DEG/IO0 FEET. FEET FEET: OEG HZN 4426.49 3900,00 3800.00 54 53 4598.29 &O00.O0. 3900.00 54 50 4771.99 ~100.00 ~OOO.O0 54 39 49~3.05 ~ZO0.O0 ~100.00 54 Z4 5113.89 ~300.00 ~200.00 54 15 'q3.~ 4400.00 ~300.00 53 ~2 0.87 4500.00 4400.00 53 17 5~18.38 4600.00 ~500.00 53 4 5784.92 ~700,00 ~600.00 53 35 5951.20 4800.00 ¢700.00 51 59 6115.3& &900.O0 4800.00 52 54 6277.39 5000.00 &900,O0 52 ZO 6¢35.75 5100.00 5000.00 50 37 6593.78 5200.00 5100.00 50 36 67~9.77 $300.00 5200.00 49 ~7 6908.09 5400.00 5300.00 51 30 7069.67 5500.00 5400.00 52 Z8 7234.07 5600.00 5500.00 53 1 7¢03.~3 5700.00 5600.00 54 15 7571.43 5800.30 5700.00 53 7735.20 5200.00 5800,00 51 13 7894.28 6000.00 590~.00 51 20 8050.,8 6100.00 6000.00 50 2 8234.956200.005103.00,938 8358.356300.006200.0049,5 ,oo. o oo.oo n -58 6500.00 6 00.00 50 75 ~.78 6600.00 6500.00 55 8 8999.33 67OO.0O 5600.00 56 ¢0 9175.25 $800.00 5700.00 52 59 9332'81 6900.00 6800.00 49 56 9495.65 7000.00 6900.00 55 2 9672.~4 7[00.~0 700~-00 55 51 9851.18 7200.00 7100.00 56 0 10028.3~ 7300.00 7200.00 55 16 10207.30 7400.00 7300.00 57 32 10396.8~ T500.O0 7~00.00 58 30 10564.3~ 7600.00 7500.00 57 25 10768.04 7700.00. 7600.00 55 59 109~6.00 7800.00 7700.00 55 34 S 13 44 E 1314.31 S'13 39 E 1453.75 S 13 42 E 1595.40 S 13 41 E 173~.05 S 13 51 E 1872.31 S 13 49, E 2009.01 S 13 41 E 2143.03 S 13 32 E 2277.18 S 13 36 E 2410.09 S 13 2~ E 2542.69 S 13 0 E 2672.56 S 12 38 E 2799.69 S 12 31 E 2922.08 S 12 15 E 304~.02 S 11 51 E 3163.28 S 11 13 E 3285.45 S 10 27 E 3411.61 S 9 57 E 3541.1¢ S 9 36 E 3676.68 S 9 33 E 3810.52 S 8 45 E 3938.97 S 8 1¢ E ~061.28 S 7 23 E ~179.6¢ S 6 17 E ~295.48 S 6 21 E ~409.66 S 13 17 E ~519.34 S 13 43 E ¢630.89 S 13 58 E ~757.07 S 11 2~ E ~906.93 S 14 30 E 5051.01 S 19 55 E, 5172.68 S 19 51 E 5300.90 S 19 37 E 5446.76 S 19 35 E 5594.53 S 19 23 E 57¢0.63 S 19 5 E 5888.92 S 18 51 E 5049'82 S 18 15 E $208.36 S 17 50 E 5362.~4 S 17 25 E 6509,64 0.78 1.32 0.80 1.50 3.4¢ 1.22 1.39 1.20 1.03 1.95 3.02 0.53 0.15 1.29 0.70 2.25 0.97 0.33 2.34 1.72 1.47 1.55 1.85 1.28 2.23 0.75 6.8:) 1.11 5.68 1.36 1.05 0.82 1.65 0.58 2.27 0.73 0.76 1.63 0.9~ 1272.1¢ S 334.69 E 1315.43 S 1~ 44 E 1407.87 S 367.68'E 1¢55.09 S 1~ 38 E 1545.77 S 401.19 E 1596.98 ~"1¢ 32 E 1580.75 S 433.96 E 1735.87 S 14 28 E 1815.33 S 466.71 E 1874.36 S 14 25 E 1948.29 S 499.41 E 2011.28 S 1~ 22 E 2078.76 S 531.10 E 2145.$4 S 1~ 19 E 2209.33 S 562.90 E 2279.92 S 14 17 E 2338.78 S 594.16 E 2~13.07 S 1~ 15 E 2~67o87 S 625.47 E 2545,90 S 1~ 13 E 2594.53 S 655.45 E 2676.04 S 14 10 E 2718.89 S 683.56 E 2803.50 S 1~ 6 E 2838.75 $ 710.19 E 2926.24 S 1~ 2 E 2958.29 S 736.33 E 3048.55 S 13 58 E 3075.31. S 761.52.5 3168.20 S 13 54 E 3195.53 S 786.25 E 3290-83 5 13 49 E 3320.15 S 810.21 E 3417.58 S 13 ~2 E 3448.55 S 833.35 E 3547.82 S 13 35 E 3583.28 S' 856'35 E 3684.19 S 13 26 E 3716.36 S 878.95 E 3818.89 S 13 18 E 3844.34 S '899'81 E 3948.2¢ S 13 10 E 3966.73 S 917-93 E 4071.55 S 13 I E ~085.56 S 934.20'E 4191.00 S'12 52 E ~202.~5 S 948.20' E 4308.10 S 12 42 E 4318.11 S 960.57 E ~23.66 S 12 32 E 4e27.19 S 978.98 E 4534.14 S 12 28 E ~535.71 S 1005.60 E 4645,85 S 12 30 E 4658.~0 S 1035.93 E 4772.20 S 12 32 E 4804.99 S 1069.09 E 4922.k9 S 12 32 E 4946.53 S 1098.98 E 5067.15 S lZ 31 E 5062.,40 S 1136.13'E 5188,31 S 12 38 E 5183.06 S 1179.99 E 5315.68 S 12 49 E 5320.~8 S 1229.38 E 5~60.66 S 13 0 E 5~59.79 S'1279.07~E 5507.61 S 13 11 E 5597.65 S 1327.86 E 5752.99 S 13 20 E 5737°76 S 1376.72 E 5900.61 S 13 29 E 5889.89 S 1429.43 E 6060.86 S 13 38 E ~040.15 S 1480o19 E 6218.87 $ 13 46 E 6186.72 S 1527.7~ E 6372.55 S 13 52 E 6327.00 S 1572.35 E 6519.~5 S 13 57 E ARCO ALASK, Ae T.B.U. K-25 TRADING BAY KENAItALASKA CO,qPUTATI~N DATE:. 8-MAY-86 PAGE '8. DATE OF SURV'EY: 08-FE8-86 '~ KELLY 8USHZNG'ELEVAT£DN:. 100.00 FT: ENGINEER: HEATH TRUE HEASURED VERTICAL VERTI:AL DEVI~T'ION'AZIMU'TH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. DEPTH DEPT~ DEPTH DEG MIN DEG MIN FEET DEG/ZO0 FEET FEET FE=T' INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRZZ., DEPARTURE AZZ~UTH DEG 11122.68 7900.00 7800.00 55 52 11305.95 8000.00 7900.00 58 1 11696.96 8100.00 8000,00 58 11590.06 8200.00 8100.00 59 3 11885.37 8300.00 8200.00 59 5 87 55 8600.00 8300.00 61 69 · ~8:19 8500.00 8600.00 61 0 1Z697.37 8600.00 8500.00 57 12650.32 8700.00 8600.00 12832.07' 8800.00 8700.00 56 S 16 56 E 6655.29 S 15 56 E 5808.86 S 17 15 E 6971.60 S 17 19 E 7136.77 S 11 IZ E 7306.54 S 17 20 E 7480.22 S 17 3 E 7665.61 S 17 45 E 7837.80 S' 17 55 E 7966.28 S 19 30 E 8105.75 13015,19 8900,00 8800,00 56 68 S 20 8 E 8258,95 13196,45 9000.00 8900,00 55 55 S 20 29 E 9409,84 13374,63 9100,00 9000,00 55 36 S 20 4 E 9557,09 13550.56 9200.00 9100,00 55 25 S 21 1. E ~701,61' 13727,70 9300,00 9200'00 55 50' S 21 I E 88~7,~4 13899.25 9400.00 9300,00 52 56 S 19 2Z E 8985,56 14065.18 9500.00 9400.00 53 15 S 18 30: E 9118.89 14231.61 9600.00 9500.00 52 36 S 17;29 E 9251.90 14325.00 9656.82 9556.82 52 30 5 17 12 E 9325.02 2.05 6~66.12 S 1615.49 E 6661.87 S l& 1 E 0.75, 6513.17 S 1659.78 E 6818.27 S' 1~ 5 E. 0.89 6768.$7 S 1707.75 E 6980.78 S l& 9 E 0,23 6926,33 S 1757,02 E 7145,71 S 1~ 14 E 0.6¢. 7086.56 S 1806.75 E 7313.25 S 1~ 18 E 0.85 7254,32 S 1858,92 E 7~88,71 S 1~ 22 E 0,1~ 7431,¢1 S 1913,7~ E 7673,87 $ 16 26 E 7.18 7595,74 S 1~65.20 E 7845,85 S 1~ 30 E 2,8~ 7718,50 S 2003,09 E 7974,19 S 1¢ 32 E 1.90 7850.59 S 20~8.06 E 8113.3~ S 1~ 37 E 0,52 7994,59 S 2100.68 E 8266.07, S'I~ 43 E 0.92 8136,24'S 2153.73 E"8~16.~7 S 1¢ 49 E 0,84 827~,62 S 220~,67 E 8563,29 S 1~ 55 E 0,72,' 8410,35 S 2255,00 E 8707,¢1' S 15 0 E 0.76 8546.59 S 2308.07,E 8852.76 5'15. 6 E 0.43, 8677.31 S 2356.29 E 8~91.5~ S 15 11 E 3.7~ 8802,47. S 2399,51E 9123,66 S 15 14 E 0.99 8928.94 S 2440,77 E 9256.53 S 15 17 E 0.00 8999,72 S 2462,76.E 9330,60 S'15 18 E ARCO ALASKAt IqCo T.B.U. K-Z5 TRAOINS BAY KE~IAIt ~LASKA MARKER TOP HEMLOCK ~ASE HEMLOCK (' TO CO~PUTATZDN DATE= 8-MAY-86 INTERPOLATED VALUES FOR CHOSEN' H3R[ZDNS PAGE '9, ~ DATE DF SURVEY= 08-FEB-a6 ', KELLY BUSHZNG ELEVAT[DN: IO0.O0'FT ENGINEERt HEATH .~EASURED DEP1,H BELDNKB FROM KB SURFA:E LOCATION ORIGIN~ 731 FSL9 1&2 FEL ' SEC 17,' T9N~: R13W SM 1'VD REC~'ItNGU'LAR" CODRDINATE~' SUB-SEA NORTH/SOUTH. E&ST/WEST 13298°00 9057.11 9957.11 lkZO2°O0 9582.05 9¢82.05 1~Z82o00 9630.65 9530.$5 1&325°00 9656.82 9556.8Z 8215.02 S 2182o81 E 8906.49 S Z~33,66 E 89S7.13 S 2¢52.67 E 8-399.72 S 2462°76 E '~ ¢;7 ~:,'- ~,,,,?'~ ~.,~ ,,, T.BoU. K-Z5 T R ADZ: I',IG BAY KENAZgALASKA MARKER TOP ~EMLOCK BASE HEMLOCK PBTD TO COMPUTATIgN. DATE: ***:**:**', Jo*** STRATIGRAP~IC qEASURED DEPTH BELOW KB 13Z98o00 ICZSZ°O0 1~325,00 8-MAY-86 SUMMARY FROMKB 9057.11 9582°05 9630.65 9656.8Z PAGE ~0~, ,. DATE DF SUR~'EY: OB-FEB-86 KELLY BUSHING ELEVATION*. 100o00 FT' ENGINEER: HEATH ORIGIN= 731 FSL~ 1&2 TVD SUB-SEA 9~8Z.0S 9530.$5 9556.82 SURFA:E LOCATION AT::' FEL , SEC 17~ Tg~R13W* SM RECJANGULAR COORDINATES NORTH/SDUT,."I EAST/~EST 8215.0Z S 2182.81: E 8906o,~9 S 2&33o65 E 8957o13 S 2&52o67 E 8999.72 S 2,~62.7S E FINAL WELL. LOCATI3N AT TD:, TRUE SUB-SEA HEASURED VERTICAL VERTI:AL DEPTH DEPTH DEPTH 14325.00 9656.82 9556.92 HORIZONTAL DEPARTURE DISTANCE AZIqgTH FEET DEG MIN 9330.$0 S 15 18 . -- ! - SUB-SURFACE DIRECTIONAL SURVEY I~UIDANCE I~ONTINUOUS J~]OOL Company Well Name Field/Location R.~cCEIVED Alaska. _ 0ii ~..~ ~-o,-:~ Cons. Commission _A_~CO ALAST/,_A. INCOR~OR_A_TED ! W~LL T.B.U. K-25 (731' FSL, 142' F~.L, S17, TgN, R13W) MCARTHUR RIVER, KENAI, ALASKA _. Job Reference No. 71310 Log~3ed By: HEATH Date, 01-HARCH- 1986 Computed By: COLSON SCHLUMBERGER GCT DIRECTI3N&L SURVEY SUSTDMER LISTIN3 FOR INC. T.B.U. K'25 MC~RT~JR RIVER KEN&I,~L~SK~ SUR~E¥ D~TE: 8-FEB-B6 ENGINEER: H r'AT H METMD)S 0=, C3~PUT~TIO~ TOOL, LDC.&TI]N: T~N~ENTIAL- 4VE~AGED IflTERP]LATIDN: LINEAR VERTIC&L SECTI]N: qgRIZ, DIST, PRDJECTED DEVIATION ~ND O~TD ~ T~RGET ~ZIMUTH AZIMUTH OF SOUTH 23 DE~ 0 ~IN E~ST ~RCO ~LASq~, I~C. T.B.U. K-25 MS~RTHJR RIVER KENAI,~LASK~ INTERPOLATED VALUES FOR TRUE SJB-SEA ~E~SURED VERTIC&L VERTICAL 2EPT~ DEPTH DEPTH 0.00 0.00 -103.00 100.03 100.00 0.00 2D0.33 200.00 103.00 300.00 300.00 203.00 oo.oo oo.oo oo.oo (,-"o.oo oo.oo o .oo 0,03 599,99 499.99 lDO.OD 699.99 599.99 800.00 799.99 699.99 900,93 899.99 799.99 1000.03 999.98 899.98 llO0.OO 1099.98 999.98 1200,00 1199.97 1099.97 1300.00 1299.97 1199.97 1400.00 1399.97 1299.97 1500.00 1499,97 1399,97 1630.30 1599,97 1499.97 1700.00 1599.97 1599.9? 1BO0.O0 1?99.9? 1599.97 1900,03 1899,97 1799,97 2ODO.OO 1999.~7 1899.97 2100.09 2099.92 1999.92 2200'00 2199.~5 2099.45 2300.00 2298.23 2198.23 2400.00 Z396,13 2295.13 2="-q. OOx 2492.73 2392.73 2~ .03 2588.00 2488.00 ~0'33 2681,~4 !581.54 2800.00 2773.04 2573.04 2900.00 2862.36 2762.36 3000'00 2949.44 2849.44 3100,00 3033,40' 2933-40 3230,00 3114,53 3014,53 3330,00 3192.Z1 3092.21 3$00o00 3266,00 3155.00 3500,30 3336,02 3235,02 3500,00 3401,97 3301,97 3700,03 3465,88 3365,88 3800.03 3528.~2 3428.4:2 3900,00 3590.04 3490.04 CDJRSE ]EVIqTION AZIMUTH ]EG qlN DE~ MIN 0 0 N 0 O E 0 5 S 38 45 W 0 4 S 1 16 0 6 S 16 28 E 0 5 S 54 57 E 0 ~.4 N 42 25 E 0 28 N 18 39 E 0 IS N 21 23 d 022 N 10 5 W 0 36 q 37 41 ~ 0 17 N 18 29 W 0 31 N 41' 50 W 0 ~.0 N 20 3 W 0 12 N 50 I .I 0 17 N 55 45 d 0 ? S 55 14 W 0 14 S 70 52 W 0 8 S 8~ 5Z W 0 10 S 50 29 ~4 0 ID S 54 23 W 0 ~1 S 87 29 E 2 52 S 48 48 E 7 32 S 17 43 E 10 10 S 13 34 E 13 30 S 15 5 E 16 1~ S 16 45 E 19 6 S 15 24 E 22 19 S 13 51 E 25 16 S 13 45 E '2~ 2 S 13 25 E 31 5 S 13 5 'E 34 23 S 13 17 E 37 12 S 13 11 E 40 ~+8 S 13 20 E 44 13 S 13 59 E 46 57 S '14 55 E 49 52 S 15 15 E 50 59 S 15 22 E 51 ~.7 S 15 25 E 52 ~3 S 15 30 E 28-FEB-85 2~TE 3F SURVEY: 8-FE3-86 KELLY BUSqlN3 ELEV&TI3N: ENGINEER: HE~TH Alaska Oil & Gas Cons. Commission :'VEN 100 F~,,~9& ME~SURE VERTICAL DOGLEG RE'TAN SECTION SEVERITY N],RTH! FEET DES/lO3 FEE 0.00 0.00 O. 0.05 0.14 O. 0.15 3.09 O. 0.30 0.05 O. 0.42 0.23 O. 0.46 0,77 O, -0.15 0,15 O. -3,76 O.3Z 1. -1.28 g,44 1. -2.25 3.24 Z. -3.07 3.39 3. -4.05 3.35 4. -4.71 0.15 4. -5.20 3.35 5. -5.71 1.33 5. -5.81 0.45 5. -5.73 0.41 5. -5.76 0.51 5. -5.84 0.58 5. -5.86 0.50 5. -5.61 2,11 5, -3,77 $,75 5,47 3'43 4. 20,81 2,62 19, 40,91 3,62 38, 55,60 2.8B 63, 96.73 3.24 92. 131.64 3.13 125. 171.44 ~.95 165. 215.78 !.~4 209. 264.19 3.10 Z57. 317.70 2.11 310. 375.30 3.23 367. 437,32 3,43 428. 503.88 3.23 494. 574.46 3.63 563. 5~8.93 0.93 535. 725.14 1.08 709. 802.48 0.33 785. 880.56 0.87 360, D DE~TH SULAR CDORDIi~TES H]RIZ. SOUTq E~ST/WEST DIST. T FEET FEET 30 N 0.00 E 0.00 08 S 0.05 W 0.10 21 S 0.13 W 0.25 36 S 0.08 W 0.37 47 S 0,03 W 0.47 39 S 3.27 E 0.~7 44 N 0,65 E 0.79 13 N 0.70 E 1.33 62 N 0.54 E 1.71 50 N O.11 i 2.50 21 N 0.29 W 3.22 06 N 0.81 W G.14 62 ~ 1,17 W 4.77 O1 N 1.50 W 5.23 ~1 N 1.85 W 5.72 53 N 1.85 W 5.83 34 N 2.08 W 5.74 28 N 2.30 W 5.76 31 N 2.44 W 5.84 19 N 2.70 W 5.86 36 ~ 2.44 W 5.62 18 N 0.21 E 4.19 05 S 4.45 E 6.02 06 S 8.35 E 20.81 70 S 13.53 E 41.00 ~3 S 21,04 E 65.92 58 S 29,44 E 97.15 75 S 38.30 E 132.41 95 S 47.82 E 172.70 50 S 58.44 E 217.60 44 S 69.66 E 266.70 27 S 82.14 E 320.95 17 S 95.50 E 379.39 46 S 109.8~ E 442.32 31 S 125.77 E 509.77 14 S 143.54 E 581.15 55 S 163.32 E 555.29 ~5 S 183.55 E 733.20 08 S 204.27 E 911,22 99 S 225.25 E 889.97 130.00 FT DEm~RTURE aZIMUTH DES MIN N O 0 E S 37 22 W S 31 7 ~1 S 12 56 ~ S 3 43 N S 3~ 59 E q 55 18 E N 32 1 E N 18 29 E ~1 Z .33 E N 5 8 ~ N I1 19 d N 14 12 W N 15 4I W N 18 52 W ~ 18 31 W N 21 18 W N 23 30 W xi2~ 38 W ~ 27 30 W ~ 25 44 W N 2505 54743 E S 23 38 E S 19 16 =- S 18 20 E S 17 38 E S 15 48 E SI5 45 S 15 34 i S 15 8 E S 14 49 E S 1~ 22 E S 14 16 E S 14 17 E S lq. 24 E S 14 29 E S 14 35 E S 14 39 E CD~PUT~TI3N D~rE: 28-FEB-85 P~&E 2 ~30 ALASKA, INC. T.~.U. K-25 M:~RTHJR RIVER KEN~I,~LASKA D~TE DF SURVEY: 8-FE3-35 KELLY BUSHING ELEVATION: ENGINEER: HEATH lOO.OO FT INTerPOLaTED VAL~ES FOR TRUE SJB-SE~ qE~SURED VERTICAL VERTICAL 3EPTM DEPTfl DEPTH ~ODO,OD 3650,34 3550,8~ 6100,00 3710.~0 3510,90 4230,00 3769.3~ 3553.3~ 4300.00 3827.~9 3727.09 ~¢DO.~O 388~.79 378~.79 ?' '0.00 39~2.56 3842.56 ~i00.~0 ~058.33 395~.33 4~00,00 ~116.26 ~015.26 ~gO0.~O 6175.03 ~075.03 5000.0 5130.0 5200.0 5330.3 5400.0 5500.0 5500.0 5700.0 5~00.0 .5~00.0 6000. 6130. 6239. 6330. 6~D0. 67'u0. "'6~3 O · ~233.3~, ~291.39 ¢350.75 ~¢09.76 q~469.31 ~529,21 ~588,~4 6708.92 ~768.59 ~829.95 ~952,~1 5013,39 5077,28 5160,52 52~7,92 5332,24 5396-96 5¢57.~0 5518.52 5579.r, 4 5639.~4, 569B.00 5757.03 5816'83 5877.90 59¢0.52 5003.57 7000. 7130. 7230. 7300. 7¢00. 75~0. 7630. 7700. 7800. 7930. C3JRSE DEVI&TIDN AZIMdTH DEG lin DEG ~133.36 ~191.89 q, 253.75 q, 309.76 ~369.31 ~29.21 6¢88,94 ~,549.06 ~508.9~ ~563.59 53 1 S 15 27 E 53 27 S 15 25 E 54 21 S 15 5 E 54 58 S 1~ 1! E 55 1 S 13 50 E 54 3 S 13 35 E 5¢ 52 S 13 39 E 54 38 S 13 41 E 54 31 S 13 ~1 E 54 13 S 13 35 E 5357.40 5~1B.62 5539.44 5598.00 5657.03 5715.83 5777.90 5840.52 5903.57 51 27 S 10 53 E 51 ~2 S 10 18 E 52 59 S ID B E 53 ~,0 S 9 ~ E 54 15 S 9 35 E 52 51 S 9 3~ E 53 28 S 9 31 E 51 22 S 9 3 E 51 0 S 8 27 E 51 ~ S a 1 3 E EVEN 100 VERTICAL SECTION FEET 959.26 1038.5~ 1118.94 t19~.71 1280.35 1350.91 t¢~1.00 1521,83 1602.27 15.82,0~ 175Z.25 1842,2~ 1922,04 2001,74 ZOBI,O0 2150,02 2239.17 2318.00 2397.01 1~75.13 2554.07 2632.29 2709.81 2787.38 2853.43 2939.59 3015.55 3091.05 3165.18 32~2.51 331:3.93 3396.15 3473.55 3551.¢7 3533.32 3703.86 3785.81 3863.74 393~).27 ~+01 4.37 FEE DOG SEV DE~ T O= LEG ERITY /lOO 1.65 2.6~ 1.17 1.11 0.52 2.33 1.33 0,60 0.95 2.7~ 0.75 0,45 1,?1 0.6~ 2.13 ~.7~ 0.28 9.67 1,00 2.75 0,09 1,98 1.53 3.7~ 0.58 2,2~ 0,20 1.45 1.79 .3.~7 1,91 2.47 1.72 2,15 0,33 1.8~ 3.01 2.08 1.10 1.40 ME~SURE RE2T~N N]RTH! FEE 1314. 1171. 1251. 1330. 1~09. 1~88. 1558. 15~6. 1725. 1804. 1882. 1961. 2039. 2117, 2195. 2272, 2350. 2~28. 2505. Z582. 2559. 2736. 2811. 2387. 2962, 3038. 3113. 3189. 3265. 3343. 3~21. 3500. 3580. 3560. 3739. 3817. 3894. 3971. DEPTH SULAR COORDINATES HDqlZ. SOUTH EAST/WEST DIST. r FEET FEET 51 S 246.41 E 969.35 54 S 267.82 E 10~9.30 82 S 289.20 E 1130.64 ~O S 309.83 E 1212.07 07 S 329.51 E 1293.73 37 S 348.82 E 1375.35 23 S 358.01 E 1~55.~9 84 S 387.32 E 1538.~0 04 S 405,62 E 1519,91 57 S 425,58 E 1700.80 50 S 46~.87 E 1782.03 38 S 464.01 E 1363.08 39 S 483.29 E 1~43.92 27 S 502.58 E 2024.55 34 S 521.54 E 210~.97 13 S 5~0.50 E 2185.0~ 06 S 559.48 E 2265.2~ ?3 S 578,25 E 2345.14 50 S 597.02 E 2~25,23 ~9 S 616.01 E 2505.~0 36 S 634.39 E 258~.63 58 S 652.67 E 2563.77 36 S 670.15 E 2742.50 30 S 687.45 E 2821.33 80 S 704.20 E 2898.64 ~5 S 720.90 E 2976.08 g9 $ 737.35 E 3053.35 09 S 753.63 E 3130.17 O1 S 769.43 E 3206.59 32 S 795.00 E 3~.8~.51 97 S 800.01 E 3362.53 70 S 816.52 E 3~41.¢8 81 S 828.61 E 3520.70 51' S 842.37 E 3500.54 54 S 855.88 E 3681.41 10 S 869.44 E 3761.95 13 S 882.78 E 3841.92 28 S 895.5~ E 3920.92 35 S 907.28 E 3998.54 14 S 918,55 E 4075.99 DEPARTURE AZIMUTH DE~ MIN S 16 43 E S 1~ 47 E S 1~ 49 E S l~ 48 E S 1G 45 E S 1~ 41 E S 1~ 38 E S 1~ 34 E S 1% 32 E S 14 29E S 1~ 27 E S 1~ 25 E S 14 23 E S 1~ 22 E S 1~ 20 E S 16 19 E S 1~ 17 E S 1.4 16 E S 1~ 15 ~. S 14 14 E S 1~ 12 E S 1~ 10 E S lq, 86 S 1~ 6 E S 1,~ 3 E S 1~ 1 E S 13 58 E S 13 55 E S 13 52 E S 13 49 E S 13 45 E S 13 41 E S 13 36 E S 13 31 E S 13 26 E S 13 21 E S 13 17 E S 13 12 SI3 6 E S 13 T,B,U, K-25 MC~RTHJ~ ~IVER KEN~I,&LASKA TRUE ~E&SURED VERTICAL 3EPTH DEPTH 8000.00 8100.03 8ZO0,O0 8300,00 8%00.00 J,OO ~0,00 8800,00 8900.00 9900, 9100. 9230, 9300, 9400. 9530, 9630, :9.700, .9800, :9900, OD O0 39 O0 O0 O0 O0 O0 03 00 iFO, O00.O0 !.0100.33 10300,00 L0%00.03 10 0.03 10300.00 lOgO0,OO 11030 11100 lllDO 11~00 ll400 11590 11500 11700 11590 11900 · '00 ,00 ,00 ,00 .OD .OD ,OD .DO $067.14 5131,75 5195,81 6261,90 $327,25 5394,82 $462.$8 5527.00 6589,~1 5644.94 5700.37 $756.36 5815.11 6878.79 5942,99 ?002.%9 7059,24 7115.~0 7171-52 7227.36 7283,39 7340.79 7396.38 ?~49.29 7501,54 7554.53 7608.¢6 7662.~3 7718.00 777~.~3 7830,53 7887,15 79~2,$3 7996,84 B049,$9 8101,59 8153, 54 8205.11 8256-20 3307,55 CgMPUTATI3N DATE: Z8-FEB-B6 INTK-RPOL~TED V~LUES FOR EVEN 100 SJB-S~A CD2RSE VERTICAL VERTICAL DEVIATION &ZIMUT5 SECTION DEPFH 9EG lin DEG MIN FEET 5967,14 49 8 S 7 39 E 4088,87 5031,75 49 50 S 7 2 E %162,36 5095.81 49 34 S $ 19 E ~235.24 5161,90 49 I S 6 3 E ~307,88 5227.25 48 ~9 S ? 3~ E ~380.42 $29~,82 46 %9 S 13 $ E ~452.32 5362,68 48 17 S 13 49 E %52%,80 5427,00 50 29 S 13 45 E %600,36 $48~,01 53 59 S 13 58 E ~677,81 654%.94 56 13 S 12 58 E %759,59 5500.37 56 %0 S 11 23 E %841,30 5655.06 55 7 S 11 45 E ~92~,56 5715.11 52 1 S 15 3g E 5002.13 6778,79 49 ~9 S 1~ 25 E 5078.8~ 684Z.99 50 55 S ~0 3 E 5155.44 5902.'49 55 5 $ 19 5Z E 5235.65 5959.24 55 ~2 S .19 ¢5 E 5317.85 7015,40 55 36 S 19 35 E 5403,45 ?071.~2 56 28 S 13 36 E 5483.02 7127,36 56 11 S 19 3% E 5565,89 7183,89 55 13 S 19 23 E 5648,22 ?243,79 55 ~3 S 19 13 E ~730,28 ?295.08 57 22 S 19 5 E 5813.41 7349.29 57 59 S 19 15 E 5897,90 ?~01,6~ 58 ZB S 18 51 E 5982,88 745~,63 57 33 S 18 41 E 7508.46 57 !5 S 18 ~ E 6151,48 7552.~3 56 53 S 17 55 i 5235,34. 7613,00 55 %4 S 17 48 E 5318,15 757~,03 55 55 S 17 29 E 5~00.60 ??33,53 55 37 S 17 15 E 5482,72 ?787,15 55 35 S '17 3 E 5564,73 7842.63 56 %6 S 16 42 E $6~7.43 7896.84 57 55 S 15 55 E 5730.97 7949.69 58 20 S 17 8 E 5815.41 8001.59 58 %0 S 17 15 E 5900.44 3353.54 58 50 S 17 23 E $985.45 8105.11 59 5 S 17 18 E 7070.72 8155,20 59 17 S 17 13 E 7156.26 3207,55 59 8 S 17 13~ E FEE SEV OEG DATE 3F SURVEY: 8-F13-86 KELLY BUSHING ELEVATI]N: ENGINEER: HE&TH T O: MEASURED DEPTH LEG RECT&N2UL&R ERITY NDRTH/SOUTH tlOD FEET CD~R E~ST FEE P~GE 3 3.7% 1.58 1.79 9.90 3.85 2.49 1.32 5.92 2.4~ 1.11 3.75 5.48 2.6~ 4.05 3.98 1.01 1.29 1,58 0,8% 1,83 2,33 1.42 3,82 9.80 0.76 1.20 1.55 1.81 103,00 FT DINATES H3RIZ. DEP&RTURE /WEST DIST. AZIIUTH T FEET DE3 MIN ~047.58 S 929,15 E 4152,86 S 12 55 E ~123,26 S 938,97 E 4228,~2 S 1Z 49 E 4198.59 S 947.79 E 4304.33 S 1Z 43 E ~274,15 S 955,89 E 4379,75 S 12 36 E 4349.38 S 964,32 E 4~55.D0 S 12 30 : ~21,82 S 977,70 E 4528,52 S 1Z 28 E. ~693,15 S 995,15 E 4502.04 S 12 29 E ~567.51 S 1013.35 E 4678.57 S I2 30 E ~543.53 S 1032,23 E 4755.97 S 12 31 E ~+?~4.16 S 1051.82 E 4~39.83 S 1~ 33 5 ~805.5~ S 1069.20 E 4923.05 S 12 32 E ~887.04 S 1085.18 E 5006.08 S 12 31 E 4965.45 S llO~,IO E 5)85.72 S 12 32 E 5038,84 S 1127,65 E 5163.~8 S 12 36 E 5110.88 S 1153.85 E 5239,51 S 12 43 E 5186.%1 S 1181.21 E 5319.22 S 12 49 E 5263,85 S 1209,12 E 5~00.94 S 12 56 E 5341,?8 S 1235.9~ E 5~83,13 S 13 Z E 5~19,64 S 1264,86 E 5565,28 S 1) 8 E 519~,35 S 1292,65 E 5547.?8 S 13 13 E 12 E 15729,79 S 13 19 E 36 E 5811,57 S 13 24 : 71 E 5394,48 S 13 29 ~ 49 E 5978 74 S 13 34 : ' = 30 E 5363,55 S 13 38 : $~ E 6148,02 S 13 42 E 33 E 6232.01 S 13 46 E 35 E 6315,97 S 13 50 m 83 E 639~.91 s 13 53 ~ 9~ E 6~81.55 S 13 5~ ~ 0.18 1.08 0.92 1.0~ 1.43 0.85 0.29 0.2~ 0.39 5575,65 5553.23 5731.94 5911,92 5892,~4 5~7;'.73 5352.56 6132.73 5211.86 5290.78 S 1320, S 1347, S 1374, S 1402, S 1430, S 1457, S 1484, S 1510. S 1535. S 1560, 6369,51 S 1585,63 E 6563,91 S 13 58 E $648,25 S 1610,03 E 6545,21 S 14 1 E' 5527,90 S 1634.04 E 6?29,30 S 14 3 E 5508.34 S 1658.32 E 6813,24 S 1~ 5 E 6589.~6 S 1683.33 E 6398.01 S 14 7 E 6771.14 S 1708.52 E 6983.37 S 1~ 9 E 5852.59 S 1733.99 E 7368.57 S 1~ 11 E 6334.~6 S 1759.55 E 7154,22 S 14 14 E 7016,56 S 1785,07 E 7240,06 S 14 16 E 7398',~4 S 1810,45 E 7325,77 S 1~ 18 E ARCO ALASKA, I~C. T.B.U. K-25 MS~RTMUR ,RIVER K.-'NAI,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 12000.00 12100.D0 12290.20 12300.00 12400.9O .1'"~0.00 12900.00 12900, 8 8 8 9 8 357.93 ~05.85 452.89 500.88 549.90 601.91 661.92 72~.32 782.37 836.91 13000.33 889 t3100.00 894 13200.00 900 13300.00 905 13490.00 911 13590.00 917 13530.00 922 ,13730.00 928 13900.00 )34 13900.00 940 OD 946 30 952 O0 )58 O0 964 O0 965 1¢000. 14,100. 14200. 1~,330. 14325. 1.58 6.38 1.99 8.23 4.38 1.26 8.~)1 ¢.98 0.99 0.~+5 0.83 0.78 1.50 6.92 COMPUT~TION DARE: 28-FE8-85 [NTE]POL~TED VAL]ES FDR EVEq 100 FEEr O: CDJRSE VERTICAL DO)LEG DEVIATION AZIMUTH SECTION SEVERITY 3EG ~IN DEG qI~ FEET DE0/IOO SJB-SEA VERTICAL DEPTH 60 35 S 17 19 E 1327.57 1.43 61 52 S 17 19 E T~16.91 .3.69 61 ~4 S 17 12 E 7502.71 0.55 61 1 S 17 3 E ?589.99 0.23 60 17 S 17 20 E 7575.98 3.65 56 37 S 17 4~ E 7762.00 7.77 50 15 S 16 53 E 7841.05 1.81 52 ~7 S 18 25 E 7913.84 3.09 56 13 S 19 12 E ~000.02 2.1~ 56 56 S' ZO 8 E 9083.69 1.26 8257.93 ~305.85 8352.89 8400,88 8501.41 8551.92 852~.32 8582,37 8735.91 56 $8 S 20 7 E B167.25 0.53 56 35 S 20 37 E 3250.88 1,35 55 53 S 20 28 E 9333.91 3.91 56 4 S 20 7 E 9415.51 0.78 55 28 S 20 Z E 8499.15 0.51 55 16 S 20 35 E ~581.30 0.90 55 51 S 21 21 E 3563.59 0.50 55 50 S 21 B E 8766.08 0.62 54 ~1 S 20 27 E 3828,59 3.29 52 55 S 19 22 E 8908.?8 8791.68 ~845.38 9901.99 9958.23 901~.38 9071.26 ~128.01. )18~.48 9240.89 9300.45 52 54 S 19 2 E 3988.32 0.67 53 ZO S I~ 23 E )06B.13 0.3) 52 ~3 S 17 40 E 9147.79 3.65 52 30 S 17 12 E ~226.83 O,OO 52 30 S 17 lZ E )245.56 O.O0 9363.83 9~20.78 9~80.84 9541.60 )555.82 ]~TE DF SURVEY: 8-~E5-85 KELLY BUSHING ELEVAT[DN: ENGINEER: HE~TH ME~SURE ND~TH! FEE 7181. 726¢. 7349. 7532. 7516. 7597. 7573. 7748. 7325. 790¢. 7982. 8361. 8138. 8216. 8294. 8371. 8~48. 3525. 8502. 8577. DEPTH 3ULAR SOUTH 03 10 93 ~7 86 88 28 32 23 COORD EAST/ FEET 75 24 99 57 27 ~6 32 18 31 88 100.00 IIATES HDRIZ. OED&RTURE WEST DIST. AZIMUTH FEET DES MIN 1835.05 E 7412.94 S 1¢ 20 E 1862.19 E 7~99.69 S 1~ 22 E 1888.33 E 7587.82 S 19 24 E 191~.21 E 7575.~5 S 1~ 26 E 1940.02 E 7762.80 S 14 28 E 1965.88 E 7848.07 S 1~ 30 E 1989.09 E 7927.48 S 1~ 31 E 2012.92 E 8005,Y+8 S 1~ 33 : 2039.17 E 8:)85.$5 S 1~, 36 ~- 2067.43 E 8170.14 S 1~ 39 E S 2095.3 S 2125.4 S 215~.7 S 2183.3 S 2211.8 S 2240.2 S 2269.7 S 229.).,8 S 2329.2 S 2355.4 8253.~1 S 1¢ 42 833,5 ,73 S 14 46 : 8919,39 S 1~ 49 : 9501.2'2 S 19 52 E 8584.12 S lq. 55 E 8566.02 S lq. 58 E 8/~7.91 S 15 2 E 8829.~6 S 15 5 E 8912.09 S 15 9 E 8992.1~ S 15 11 E 8 753.14 S 8828 o 98 S 890~.97 S 8980.77 S 8)99.7'2 S 2382.76 E 9371.56 S 15 13 E 2408.33 E 9151.55 S 15 15 E 2433.18 E 9Z31.41 S 15 16 E 2456.89 E 9310.78 S 15 18 E 2462,7~ E 9330,60 S 15 18 £- FT T.B,U, K-25 MC&RTHUR RIVER KE4~I~ALASKA C~MPUt~TI~N DATE: ZB-FEB-85 INTERPOLATED VALJ'ES FDR EVEN lOOD FE:T 3: TRUE SdB-S;A ~EASURED VERTICAL VERTICAL 3EPTH DEPTfl DE~TH O,OO 0,00 -100,00 1000,00 9g9,gB 899,98 2000,03 1999,97 [899.97 3000.00 Z949.44 2849.44 4D~O,OD 3650.84 3559.84 m 'O,DD ~233.3~ 4133.34 0.00 ~B29.95 ~72~.95 7000.00 5457.~0 5357.~0 8000.00 6067,[4 5967.14 9000.00 5700.37 $50~.37 CDJRSE )EVIATID4 ~ZIMUTq 2EG MIN DES 0 0 N 0 0 E 0 ~_7 4 1) 29 W 0 ~1 S 87 29 E 31 5 S 13 5 E 53 1 S 15 27 E 54 2 S 13 38 E 52 lB S 13 23 E 51 27 S 10 53 E 49 8 S 7 38 E 56 ~0 S 11 23 E 7183.89 55 13 S lg 23 E 7730,53 55 37 S 17 15 E 8257,93 60 35 S 17 1~ E 8791,68 56 ~B S 20 7 E 9360,83 52 54 S 19 2 E 9555,8Z 52 30 S 17 12 E ~0D00,03 7283,89 CIO)O,OO 7830.53 12ODO,OD ~357.~3 13000,00 8891,58 l¢OOO,DO g¢60,33 1~325,00 3655.B2 ME~SUR VERTICAL DO~LEG RECT&N SECTION SEVERITY N~RTH! FEET DE$~IO0 FEE 0,00 0,00 O. -3,07 ~.35 3. -5,61 2,11 Z66,19 3,10 257, 959,26 1,65 937, ~752,25 D,75 1725. 255~.07 0.09 2505, 3318,93 L.91 3265, ~088,87 3.7~ 4047, ~841,30 1.11 ~B05, PAGE 5 3~TE 3F SURVEY: 8-FES-B6, KELLY BUSHING ELEVAT£DN: 103.00 FT ENGI4EER: HEATH 5668.22 0.84 5575, 5~82-72 O.iB 6369, ?327,57 1.43 7181. B157,25 0,53 7982. ~988.32 0,57 8?53, )245,55 ~,OD 8999. ED DEPT SULAR CD SOUTH EA T F O0 N ~.1 N ~6 N ~4 S 6 51 S 24 50 S 44 36 S 63 97 S 80 58 S 92 54 S 106 55 S 132 51 S 158 03 S 183 1'5 S 209 14 S 238 72 S 246 ORDINATES HRRIZ, DEPARTURE ST/WEST OlST, AZIMUTH EET FEET ]E~ MIN 0,00 E 0,00 4 0 0 E 0,2~ W 3,22 .q 5 8 W Z,~F+ W 5,52 N 25 44 W 9,66 E 266,70 S 15 8 E 6.41 E 969.35 S 1~+ 43 E ~,87 E 1782,03 S 14 27 E 4.3~ E 2584.43 S 1~ 12 E 0.01 E 3)62.53 S 13 45 E 9,16 E 4152,85 S 1Z 55 E 9,ZO E 4~23,05 S 12 32 E 0,12 E 5729,79 S 1) 19 E 5,63 E 6563,91 S 13 58 E 5,05 E 7~12,0~ S 1~ 20 E 5,32 E 8253,~1 S IF+ 42 E Z.75 E 9071,65 S 15 13 E Z,75 E 9330,50 S 15 18 E A~SO ALASKA~ INC. T.B.U. K-Z5 MCARTHgR RIVER KENAI, ALASKA CDMPUTAT[ 3~1 DATE: 28-FEB-85 INTERPOLATED VALUES FOR EVEN 100 FEET O: TRUE SJB-SEA MEASURED VERTICAL VERTICAL 2EPTH DEPTq DEATH O,O0 0,00 -100,00 t00,00 lO0.O0 0,00 ZOO,OD 200,00 100,00 300,00 300,00 200,00 4DO,DO 400,00 303.00 "~0,00 500,00 403,00 ~ 0,01 500,00 500,00 iO0.D1 700.00 600.00 3~0,01 800,00 700,00 900,01 g00,00 1000,02 1000,00 1100,02 1100,00 1230,03 1200,00 1300.03 1300,00 1400.33 1¢00.00 1530.03 1500.~0 1500.33 1600.00 1730.0~. 1700.00 1BOO,D3 1800,00 1900,03 1900'00 20~0,33 2000,~0 2100.08 ZIO0,O0 2200,55 2200,00 2301,80 Z30O.O0 2~03,~ 2400,00 soo,.oo 2 o.00 ZTO0.OO 2~29,02 2800,00 CDJRSE VERTICAL DOGLEG 3EVICTION AZIMUTH SECTION SEVERITY 2EG ~IN DES MIN FEET DEGII03 0 0 N 0 O W 0.00 3.03 0 5 S 33 ~+6 W 0.05 0.14 0 ~+ S 1 I E 0.15 O.Og 0 6 S 15 28 E 0,30 9,05 0 5 S 5~ 5? E 0.¢2 0.23 0 24 N ~2 2~ E 0.46 ,:).77 0 ZB N lB 39 E -0.15 3.15 0 lB N 21 23 W -0.76 0-32 0 22 N 10 5 W' -1.28 ~.4~ 80~.00 gOD.O0 1003.00 1100.00 120~.00 1303.00 1~00.00 1500,00 1500,00 1700.00 0 36 N 37 ~1 W -2.25 0.2~ 0 ~7 N lB 29 W -3.07 0.38 0 31 N ~1 50 W -4.05 0.35 0 20 N 20 3 W -4,71 0,15 0 12 N 50 3 ~ -5,20 9.35 0 1T N 55 ~5 W -5.71 1.33 0 T S 55 11 W -5.81 0 14 S 70 51 W -5.73 0.41 0 ~ S 84 ~8 W -5.76 3.51 0 lO S 50 2~ W -5.84 0.5~ 1800,00 kgO0,O0 2003,00 2100,00 220~,00 2300.00 2400,00 2500.00 250~.00 270~.00 0 10 S 64 23 W -5.8/, 0.50 0 ~1 S 87 31 E -5.61 2.11 2 ~3 S ~B ~5 E -3.77 ~.75 ? 33 S 17 38 'E 5.5~+ 3.~0 10 '13 S 13 35 E 21,12 2,43 13 38 S ,16 11 E 41.86 3.5~ 16 30 S 15 38 E 68.76 Z.79 19 28 S 15 lO E 100.9~ 3.00 22 53 S '13 26 9 S 13 2800,00 2gOO,O0 3000,00 3103.00 3200,00 t300,00 3¢00.00 3500.00 3603.00 3700.00 Zg g S 13 13 E 235.g7 2.87 33 E5 S 13 1~ E 295.55 3.55 36 ~5 S 13 12 E 364.43 3.57 41 9 S 13 25 5 ~43.g7 3.31 ~5 30 S 14 22 E 537.38 2.15 49 SO S 15 17 E 546.60 ~.17 51 18 S 15 22 E 767,20 0.31 52 30 S 15 31 ~ 893.~9 53 lg S 15 3g E I023.g~ 5~ ~0 S 1~ 35 E 1161.58 D,93 2g42.85 2900'00 305g.?~ 3000.00 31)1.75 3100.00 3310.31 3200.00 34~B.01 3300.00 3596.'g3 3~00.00 3?54.45 3500'00 3g16.4~ 3600.00 4081,$? 3700.00 4252.85 3800.00 '! DATE 3F SURVEY: 8-FE3-86 KELLY BUSqING ELEVATIgN: ENGINEER: HE~TH SUB-SEA DEPTH RECT~N NORTH/ FEE SULAR CD3RDINATES H32IZ, SOUTH EAST/WEST DIST. T FEET 0.80 N 9.00 E O,O0 0,28 S 0,06 W 0.10 0,21 S 0,13 W 0.25 0.36 S 0.08 W 0.37 0.~7 S 0.03 W 0.47 0.39 S O.Z? E O.~? 0,44 N 0,65 E 0,79 1,13 ~ O,?O E 1.33 1-52 N 0,54 E 1,71 2,50 N 0,11 E 2,50 3.21 N 0,29 W 3,22 4,06 N 0,81 W ~,14 4.53 N 1,17 W 4,77 5.01 N 1.50 W 5.23 5.41 N 1.85 W 5.72 5.53 N' 1.~5 W 5.83 5.3/+ N 2.og W 5.7~ 5.28 N Z.30 W ~.75 5.31 N 2,~+4 W 5.8~ 5,19 N 2-7'0 W 5,86 5,3~ N 2,44 W 5,52 4,18 N 0,21 E 4,19 4,12 S 4,47 E 6.08 lO.3? S 8./+2 E 21.12 39.52 S 13,80 E z+1.95 65.50 S 21.65 E 68.99 96.58 S 30.55 E 101.40 13~+.24 S 40.13 E 140.11 178.55 S 50.92 i 185.57 229,54 S 63.17 'E 238,07 288,41. S 76-95 E 298.50 355.44 S 92.98 E 368.37 435.03 S 111.40 E 449.06 526.88 S 134.07 E 543.57 533.38 S 162,70 E 653.94 750.75 S 19¢.83.E 775.63 873.56 S 228,75 E ~03,01 1000.34 S 263.88 E 1034.56 1134.44 S 300.25 E 1173.50 P~$E 6 lOD.O0 FT DEPARTURE ~ZlVlUTH DE~ MIN 4 O 0 E S 37 22 W S 31 7 W S 12 56 W S 3 4,3 ~ S 3~. 59 E N 55 18=. '432 1E ~ lB 29 E 4 Z 33 E q 5 8 W 4 11 l'g W N 18 52 W 418 31 ~' N Z1 18 W N 23 30 ~ ~ 2~+ 38 W S 15 23 E S 14 56 E S 1~ 3'? r- S 1~+ 21 E S 14 16 E S 14 2~+ E S 1~ 32 E : S 1~ ~+0 : S 14 49 E ARCO ~LASKA, I~C. T.5.U, K-25 MC~RTHJR ~IVER CDMmUT~TI2N D~tE: 28-FE5-8S INT=~ODL~TED VALJES FOR EVEN 100 FEET 0= TRUE SJB-SEA ~"E&SURE3 VERTICAL VERTICAL DEPTH DEPTH DE~TH 4¢Z6.49 3900.00 3803.00 ¢598.29 4000.30 3903.00 4771.89 ~100.00 ~000.00 ~9~3.05 ~200.00 5113.89 4300.00 ~200.00 3.44 4400.00' ~300.00 0.89 4500.00 4400.00 5'~8.33 ~500.00 ~50O.OO 5?B~.~Z ~?OO.30 ~600.00 5)51.20 ~800,00 4703.00 6115. 6_~ 77. 6~35. 6593. 6908. 7059. 7234, 7433. 7571 · 7735., 789¢, 8050, 83~8 · 8 8~399, 9175. CDJRSE VERTICAL DOGLEG 3EVI~TIDt ~ZIMUTq SECTION SEVERITT 2EG ilN DEG MIN FEET DES/lO0 54 53 S 13 4~ E 1301.78 0.73 54 50 S 13 39 E 1439.62 1.32 54 39 S 13 42 E 1579.64 O.8O 54 Z~ S 13 ~1 E 1715.70 1.50 54 15 S 13 51 E 1853.37 0,4~ 53, 42 S 13 4) E 1988.5~ 1.22 53 17 S 13 41 E 1121.03 1.39 53 4 S 1~ 32 E 2253.65 2.7~ 53 35 S 13 35 E Z385.01 1.20 51 59 S 13 2~ 5 !515.08 1.03 9332. 9495. 95?2. 9851. 10028. 10207. t'0396. 10584, t0768. 10945. 3~ ~900.00 4800.00 52 54 3) 5000.00 4900.00 52 20 75 5100.00 5000.00 50 ?B 5200.00 5100.00 50 35 ?? 53~0.30 ' 520~.00 49 Og 5400.00 5300.00 51 30 51 5500.00 5~03.00 52 28 0T 5600.00 5500.00 53 1 43 5700.~0 5500.00 54 ~3 5800.00 5703.00 53 44 20 5900.00 5803.00 51 13 28 5000.00 5900.00 51 ZO ~8 5100.00 5OO),O0 50 Z ~5 6200.00 5100.00 ~9 38 35 5300.00 5200.00 49 15 5~ 5¢00.00 5300.00 46 54 58 5500.00 5400.00 50 ~5 78 6600,00 5500.00 55 8 33 5700,00 5600.00 56 ~0 25 5800.00 5700.00 52 59 81 $900.00 5800.00 49 36 55 7000.00 $900.00 55 2 54 ?lO0.O0 ?OOO.O0 55 51 18 7200.00 7100.00 56 0 3~ 7300,00 1200,00 55 16 30 7600,00 7300.00 57 32 84 7500,30 740~.00 58 30 3~ 7600.00 1500.00 5? ~5 34 ??O0.O0 ?500.00 55 59 99 7800.00 7700,00 55 34 S 13 3 'E 2644.38 1.95 S 1Z 38 E ~759.84 3.02 S 12 31 E 2890,58 3.53 S 12 15. E 3010.82 0,15 S 11 51 E 3128.39 1,29 S 11 13 E 3248,?1 0.70 S lO Z? E 3372.79 Z.25 S 9 57 E 3500.03 3.91 S 9 35 E 3633.03 3.33 S 9 33 E 3764.36 2.3~ S 8455 S 8 1~ E S 7 23 E S 5 17 E S 5 21 E S 13 17 E S 13 43 E S 13 53 E S 11 24 E S 14 3~ E S 19 55 E S 19 51 E S 19 37 E S 19 35 E S 19 23 E S 19 5 E S 18 51 E S 18 15 E S 17 53 E S 17 25 E 3890.32 1.72 ~010.05 1.47 4125.79 1.55 4238.87 1.45 4350.16 1.28 ~457.77 2.2~ 4558.07 0.75 ~6~2.85 5.80 ~840.74 1.11 4982.72 5.6~ 5103.89 1.35 5232.09 1.05 5377.88 0.8~ 5525.54 1,65 5671.¢9 5819.56 2.2? 5980.19 0.73 5138.34 2.75 5291.84 '1.63 5438.40 ~.9~ D~TE DF SJR~E~: 8-FES-B6 KELLY BUSHING ELECAT[2N: ENGINEER: HE&TH SUB-SE~ DEPTH RECTANSULAR COORDINATES H]RIZ. NDRTH/SOUTH EAST/WEST DIST. FEET FEET FE:T 1272.14 S 334.69 E 1315.63 1~07.87 S 367.68 E 1~55.09 1545.77 S 401.19 E 1596.98 1580.75 S 433.96 E 1735.87 1815.33 S 465.71 E 1874.36 1948.29 S 49~.~1 E 2011.28 2378.76 S 531.10 E 2145.54 Z~09.33 S 562.90 E 2279.92 2338.75 S 594.16 E 2~13.07 2~67.37 S 625.~? E 2545.90 2594.53 S 655.45 E 2575.04 2718,89 S 683.55 E 2803.50 2838.75 S 710.19 E 2925.24 2~58.29 S 736.33 E 3348.55 3075.31 S 761.5~ E 3168.Z0 3195.53 S 78~.25 E 3290.83 3320.15 S 8lO.Z1 E 3417.58 3~48.55 S 833.35 E 3547.82 3583.28 S 856.35 E 3584.19 3716.36 S 878.95 E 3318.89 3944.34 S 899.81E 3~48.24 3966.13 S 917.93 E 4071.55 ~385.56 S 934,20 E 4191.00 4202.45 S 948.20 E 4308.10 ~318,11 S 960.57 E 4423,66 4427.19 S 978.98 E ~53~.14 4535.71 S 1005.60 E ~5~5.85 4558.~0 S 1035.93 E 4772.20 ¢B0~.99 S 1059.09 E 4~22.49 4~6.53 S 1098.98 E 5367.15 5062.40 S 1135-13 E 5188.32 5183.06 S 1179,99 E 5315.58 5320.48 S 1229.38 E 5460.56 5459.79 S 1279.07 E 5507,51 5597.55 S 1327,85 E 5752.99 5737.76 S 1375.72 E 5900.61 5889.B9 S 1429.43 E 6060.86 $340.15 S 1480.19 E 6Z18.87 6186.72 S 15Z?.T¢ E 6372.55 ~327.00 S 157Z.35 6 $519.45 P~GE 7 103.00 FT DEmARTURE ~ZIMUTH DEG MIN S 14 38 : S 14 3Z ~ S 14 28 E S 14 25 E S '1~ 22 E S 1¢ 19 E S 14 17 E S 14 15 E S 14 13 E S 14 10 E S 14 6 E S lq. 2 E S 13 58 E S 13 54 E S 13 49 E S 13 42 E S 13 35 .= S 13 26 E S 13 18 = S 13 10 E S 13 1E S 1.~ 52 E S 12 42 E S 12 32 E S 12 28 E S 12 30 E S 12 32 E S 12 32 E S 1Z 31 E S 12 38 E ,S 12 49 E S 13 0 E S 13 11 E S 13 zO E S 13 29 E S 13 38 E S 13 46 E S 13 5Z E S 13 57 E COMPUTATI34 A~SO ALASKA, IqC. T.B,U. K-25 MS&RTqJR RIVER KENAI,~LASKA 4E~SURED VE 3EPTH 11122.58 ?go0.o0 11305.95 BO00.O0 11695.95 BIO0.O0 11590.05 B20O.O0 113~5.37 8300.00 17~ 97.55 B40O' 00 8.19 8500.00 12~7.37 B$O0.O0 12550.32 ~700.00 ~2~32.07 ~800.00 ~3)15.1~ ~eO0.O0 ~31~6.~5 ~000.00 ~3~74.5~ 9100.00 13550.56 9200.00 ~3727.70 9300.00 13899.25 9400.0'0 14055.18 9500.00 14231.51 ~500.00 16325.00 9656.82 DARE: Z~-FEB-95 [NTE~PDL{TED VALJES FOR EVE4 100 FEET OF CSURSE VERTICAL DOGLEG 3EVI&TIO4 AZIMUTH SECTION SEV=RITY 2EG ~iN DES MIN FEET DEStlOD TRUE SJB-SEA RTIC~L VERTI'AL DEPT4 DEOTH 55 52 58 1 58 ~0 59 3 59 5 61 {9 61 0 57 51 ~1 56 ~B 56 ~8 55 55 55 36 55 25 55 50 52 56 53 15 52 36 52 30 S 15 5~ E 558).31 Z.05 S 15 55 E 5735.98 3.75 S 17 15 E 5897.87 3.89 S 1T lg E ?062.24 9.23 S 17 lZ E 7223.16 0.6~ S IT ZD E ?403.97 O.B5 S 17 3 E 758B.41 0.18 S 17 45 ~ ??Sg.?B 7.1~ S 1~ 55 E ~887.59 'S lg 30 E )025.75 1.90 S 20 B E 8179.95 0.52 S 20 29 E g330.gT 0.92 S ZO ~ E ~478.27 3.86 S 21 ! E 9522.87 O.TZ S 21 ! E B769.01 3.75 S 19 22 E $gOB.19 0.43 S 18 30 E ~040.28 O.?~ S l? 29 E ~172.82 S l? 12 E 9245.55 0.0~. ?803.00 ?900.00 8000.00 3109.00 $200.00 9303,00 8600.00 8500.00 B60D.O0 B?OD.O0 8800.00 8903.00 9000.00 ~100.00 ~200.00 9300.00 ~OO.O0 ~500.00 9556.82 PAGE 8 DATE DF SJR~EY: 8-FE5-86 KELLY BUSflINS ELEVATI3N: lOO.O0 ENGINEER: HE~TH FT SU3-SEA DEOTH RECTANGULAR CDgRDINATES H3RIZ. DEPARTURE N3RTH/SOUTH E~ST/~EST gIST, AZIMUTH FEET FEET FE:T 3E~ MI~ 5666.12 S 1615.4~ E 6564.87 S 1~ 1 E 5513.17 S 1659.78 E 6818.27 S 1~ 5 E 5768.57 S 1707.75 E 6980.78 S 1~ 9 5 5~26.33 S 1757.02 E 7145.?1 S 1~ 16 E 7085.56 S 1806.75 E 7313.25 S 1~ lB E 725~.32 S 1858.92 E 7~88.71 S 14 22 E 7%31.~1 S 1913.7~ E 7573.87 S 1% 26 E 7595.74 S 1965.20 E 7865.85 S l~ 30 ~ 7718.50 S 2003.09 E 797~.19 S' 1~ 32 E 7850.59 S 2068.05 E 8113.36 S 1~ 37 E 7996.59 S 2100.63 E 82.65,07 S 1.% 4.3 E B136.24 S 2153.73 E 84.15.?+? S 1¢ 4.9 E 827~.52 $ 220%.67 E 856~.29 5 1~ 55 E B?,10.35 S 2255.0O E 8707.41 S 15 0 E !)546.59 S 2308.07 E 8852.75 S 15 6 E 8577.31 S 2356.29 E 8991.56 S 15 11 E 8~02.~7 S 2399.51 E 9123.66 S 15 16 E 8928.94, S 24~0.77 E 9256.53 S 15 17 E 8999.72 S 2462.76 E 9330.60 S 15 lB E T.~,U, K-~$ MC~RTHJR RIVER KEqAI~L~SK~ MA~KER DRILLER'S DEPTq CD~tPU'T~TI]N DARE: 28-FE~-$5 P~GE 9 DATE 3F SURVEY: 8-FE~-86 KELLY BUSHINS ELEVATI3fl: lOO.O0 FT ENGINEER: HE~TH INTERPOLATED V~LJES FOR CMOSEN H3RIZ2NS MEASURED DE~TH BELDW KB mRDM KB SJ'RFACE OC&TION ~T 3RIGIq: 731' FSL, 1~2° FELT SEC 17, TgN~ R13W TVD RECTANGULAR CODRDIN~TES S~B-SE~ NORTH/S2UTq E~S~/WEST 1~325.00 )656.82 9556.~2 89gg.7Z S 2~$2.75 E 4~C0 ~LGS~A, INC. T.~.U. K-Z5 MS&RTHJR RIVER KENAI,~LASK& COMPDT~TIO~ OAT'E: 28-FEB-B5 D&TE 3F SURVEY: 8-FE)-~6 KELLY BUSHINS ELEVATION: ENSI~EER: HE&TH 100.00 MARKER DRILLER°S DE~TH ~EASJRED DEPTH BELDN KB 14325.00 FROM KB 9656.82 3RIGIt: 731' TVD SUB-SEA ~555.~2 FSL, SURFACE LOCATI]N ~T 142' FEL, SEC t?, T9N, RI3W RECTANGULAR COORDIN&TES NORTH/S]UTq EAST/~EST 8939.72 S 2~52.75 E ( FINAL MEASURE] , DEPTH 1~325,00 WELL LDS~TION ~T TO: TRUE SjIB-SEA VERTICAL V=RTICAL 2E~TH DEPTH )655.82 9556.82 tDRI[ONTAL ]EP&RTURE DISTANCE AZIMUTt FEET 3EG MIN FT SCHLUMBEROER O t RECT I ONAL SURVEY COMPANY ARCO ALASKA INC ..... WELL T.B.U. K-2S FIELD MCARTHUR RIVER COUNTRY USA RUN ONE DATE LOOOED REFERENCE 000071~10 WELL TBU K-25 (731'FSL, 142'FEL,~ v, T9N, R13W) -,, ZONT~ PROJECTION 4000 REF 000071310 2O0O -2OOO -4000 -6000 -8000 -lO00r NEST 8gALE = 1/2000 IN/FT -GO00 -4000 -2000 0 2000 4000 6000 8000 10000 ERST WELl, '.eBb K-2O (731~FSL, 142'FEL,~.17, TgN, R13W) V~r-ICAL'PROJECTION -4000 -Z000 0 0 Z000 4000 6000 8000 ..+' h-::--~ ~ H4+-i i i: i i ;~-.-t.i ~ i i i i +--.~-t-H~-t-~~t---?--,--;-2-t--t-~.fi~-~?'t"~'~--l"::"'~"t"?'-~?-?~ :t:~Z~:~ "-f-t-~'~r" '-~~- ++-f-~-l'++-~' +~-+-?~hf'ff'" -~-~?f-?f'"rf"'?' ~'"f-'f-'fl-'-f"t-f'~-'-'-f-ff"'f"?t~f"ff--~-' '"r'?"~'f'l"'f"?'hf- -~~ ~ ~ ~ ~- ~ ~4-~.- -~-~4-~. ~~-..~-.- ~.-~4.-~..~...,-4~--....~...~-4-.~...~.,...,-~- ~---~-~-4-~-.~-~.-- · --~~-..~ ,-~. -~-**~ ...~-~-~..~-.~..~--.~. ~-~..~.~.~.-:..~.~...~...~.~...~-.-~. 44...L~...L4-.L&~ ...&.;~-~.~..L. ~-~;ZL.LLL&4... hL~;4...i-L.LL.L L~-;444-LL.L [.&4.4..L}-.4-;-L~.--,-L.L.L4.4..4.-.L.LL. · .~-L.~-.~--i.g.~-....~-.~2..$~-~...i.j...--$..~ &. -.' ~..-&-&4--~...L~..L.&4-~..-~-.-.4-~L-~.4~-g-~-g-.4.~;---& 'J--&-4-~-..4-~-4 ..L-&-.~-~....-~..~--.~;-.~-~.-~...~-L. .... ~..,...~+..~...~-,..~.....~...,...~...~..~..~...~-~-+- ~.-,-~..~.~ ~ -.,--~-.~.--~---~-.,.--~.-~--- ._..~_,~.~..~.+_~.-,_~..~_ ...~...~..~...,_+..~_~...~... -.~-.~...~...,.1.0+..~-,-~......~_~...~.~......~...~...~...,... .._ L~ ..~.4_$..Li. ~-~- ...L.L ~.-L~.--L ~. ~ 4.- ~-~~?L~ ...... ~..~$.~ ~ .LL. %--L-4.4~LLL.L? .... 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'" '-?-??'-?- .1¢~?-~?-i ' ~ i ] i ?¢! ....~-d-- d t~'"?-~¢?'!'-?"*'"t"?'~'-?-' : : ; s : : i ; : :1 lJlJtJ : ; : ; : [ : : : : : : : : : : : ; : : : : i : !~---¢ --?~--~%"-'t-T'~-?T~¢-~'-~'---ff~%!----~-~--t"~'-~ : ~ ?--~--*"~--~t"~' --~.--~-4--.--~--f?~---,!-..~-..?-~.-- ~ ~ ] ~-~ ~ ~ ~-'~+~ ~-~--~+-f-~ -t~%~- %~~%-~- %~~-~----~-+-~-+-~+--f-+---~H-~--~,-~-.~-.+.- +F-+H+~'--'--++~-+'-f~--H- ~~,+~~ } ~H~-H-,-~+H-~---H--H-+.H-~-+H-'-H+H.+ +H-H+~H-----H~-~--d---~+H-f+-.-4~q--~~+H -~+Hq~-+H~.--H--~4+H-b ~--~'~l'~ : : ; : ' ~._~__]._, [ : : : --~'--~"i"~"~'"~'"~ "" : : : : , : : ; ~ ~'::~'--~--: ] : ; : t [ ~'~"'~"--:: [ ~'--~~--~ ] [ ; : i ] [ ; : "~:'~--i--~--~'"~'-- : : : :' ; : : ; --~--'~ '--i"'~'~'~:':~l*~'' : ; : ] : ; : : --~'~"~'"6'" ~ '--~::'~--~':~-- : ; ; : : ; : : --l~]'--~' '~ '"]:':~--]"~'" ~': ~ ; : : ; [ , : --++-+~?~+H~-F4d : i~--~-.%-~%~ .... { ~ -++ ~ ~ i+-~H i ]H-F+-H-lf+f-+-4--++-t-H-f%--i~--]--~+H-~-t--t-'f--I]I-~-+-t--~-- IST, --I PROJECTION ON VERTICAL PLANE IS?. - 997. ~ALEO IN VERTICAL OEPT~ HORIZ SCALE = 1/20DD IN/FT EXACT RAOIWS OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DI STANCE EAST BOTTOM HOLE LOCATION COURSE LENOTH COURSE AZIMUTH MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE SOUTH DISTANCE EAST 0.0 FT 0.0 FT 0.0 FT 0.0 FT 9331.1 FT 164.7 OEO ]432S.0 FT 96S6.7 FT 9000.2 FT 2462.9 FT REF 000071310 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. RepOrts and Materials to be received by: Date , , , Required Date Received Remarks , , Completion Report y~.~ ~ '-~-Z~ ~~ Well History,_ y~.~__ ~-- ~,--~ A~¢~ Samples ,~re Chips ~~~ 7 Registered Survey plau ~ Y'~r.X.i. ~ ~, Ine 1 ~na t ~n~urvey Directional Survey ~tS ~P/ ~--/d--7~ ~3F' ...dK" Drill Stem Test Reports ....... ~~ :~,ductio~~~~]est~- Rep°rts' ~_. . ~~'& ..~r__ , Digitized,, :: Unocal Oil & Gas Divisio '*~"~ Unocal Corporation . RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District April 15, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORT OF DRILLING OPERATIONS, KING SALMON PLATFORM - WELL K-25 Attached for your files are two copies of the March Monthly Report of Drilling and Workover Operations for the King Salmon Rlatform, well No. K-25. Very truly yours, oyv D. Roberts Environmental Engineer cwl 00280 cc' Trading BaY Unit Participants RECEIVED APR 2 2 1986 Alaska 0il & Gas Cons. Commission Anchorage --~ STATE OF ALASKA ALASKA C:,_ AND GAS CONSERVATION CO ,SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling weliX~-I Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-78 3. Address 8· APl Number P. O. Box 100360, Anchorage, AK 99510 50- 733-20180-01 9. Unit or Lease Name Trading Bay Unit 4. Location of Well at surface 731' FSL, 142' FEL, Sec.17, T9N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB HLLW 6. Lease Designation and Serial No. ADL 18730 10. Well No. K-25 11. Field and Pool McArthur River Fi eld Hemlock Pool For the Month of. March ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1200 hfs, 1/3/86. Drilled out cmt retainer ~ 12,256'. Drld 8-1/2" hole to 13,698'. Cored f/13,698' - 13,831'. Cont'd drlg 8-1/2" hole to 14,300'. Ran logs. Cont'd drlg 8-1/2" hole to 14,325'. Ran, cmtd, & tstd 7" lnr. Lnr not holding. Squeezed 7" lnr w/lO0 sx Class G. Ran logs. Perf'd 13,542' - 13,544' & 13,378' - 13,380' for squeeze. Squeezed 13,542' - 13,544' w/125 sx Class G. Perf'd 13,293' - 13,295' & squeezed w/lO0 sx Class G cmt. Squeezed TOL w/225 sx Class G cmt. (see attached sheet) 13. Casing or liner ru.n and quantities of cement, results of pressure tests 7" 29.0#/ft, L-80/S-95, BTC csg f/12,049' - 14,323' Cmtd w/800 sx Class G , · 7", 29.0#/ft, L-80/S-95, BTC csg f/6481' - 12,083', tieback sleeve. Cmtd w/750 sx Class G. 14. Coring resume and brief description Core #1 f/13,698' - 13,708'; cut 10', recovered 1.5' Core #2 f/13,708' - 13,718'; cut 10', recovered 10' Core #3 f/13,718' - 13,748'; cut 30', recovered 28' Core #4 f/13,748' - 13,760'; cut 12', recovered 11.5 Core #5 f/13,760' - 13,777'; cut 17', recovered 16' (see attached sheet) 15. Logs run and depth where run RECEIVE APR 2 2 1986 AJaska 0ii & Gas Cons, C0 IRT/FDC/CNL/GR/SP f/13,200' - 12,400' CBL/GR/CCL f/14,268' - 11,992' Gyro/GST f/14,268' - surface Csg i nspectio_n log f/8328' - surface CET f/14,300' - 11,900' Digital Sonic f/14,300' - 12,300' GR/CCL/Temp f/13,866'-12,800', 13,904'-13,375', and 13,865'-13,320' Anchorage 6. DST data, perforating data, shows of H2S, miscellaneous data 13,715' - 13,745' w/1 spf 13,305' - 13,340' w/4 spf, 90° phasing ramission APR 1 5 1986 Environmental Group 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE c,~,,~,,,,-,'~'~,-,,~+-,1 ~,-,,-,~,~,~,-,~-, DATE I%U~f Ue I ~.L,/U ~ I L~ ..,~ Lily .L I U I III1~1 I brai..L L.I IL~J .L I I~ I NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· I::nrm I F~-~fl4 nA~A'~ /~. o Submit in duplicate Monthly Report of Drilling and Workover Operations K-25 (cont'd) March, 1986 ITEM 12: Drld cmt to 12,072'. Located leak f/8395' - 8405'. Ran csg inspection log. Ran, cmtd, & tstd 7" tieback lnr. Drld cmt to 13,358'. Tstd perfs ~ 12,293'- 12,295'; bled to 2600 psi in 30 minutes. Squeezed perfs w/75 sx Class G cmt. Tstd perfs - ok. Drld cmt to 13,370'. Tstd perfs @ 13,378' - 13,380' - ok. Drld retainer & cmt. PBTD = 14,282'. Displaced well to NaC1 brine. Ran logs. Perf'd well; well did not flow. RIH w/coiled tbg; shut in well. Blow well dry. Ran logs. Pump data fracture @ 15 BPM; maximum pressure 8900 psi. Ran data fracture temp logs. Fracture well. Ran temp logs. Gas lift well w/coiled tbg f/2500' - 8500' to surface. Flow test through perfs f/13,715' - 13,745'. Contd' gas lifting well. Set EZSV @ 13,357'WLM. Perf'd well. Gas lifted well. Fractured well. Drilled out EZSV. Ran completion assembly. ND BOPE. NU tree & tstd. Well turned over to production @ 1700 hfs, 3/17/86. Finished demobilizing rig @ 0600 hrs, 3/20/86. ITEM 14: Core #6 f/13,777' - 13,787'; cut 10', recovered 7' Core #7 f/13,787' - 13,792'; cut 5', recovered 4.5' Core #8 f/13,792' - 13,805'; cut 13', recovered 10' Core #9 f/13,805' - 13,815'; cut 10', recovered 9' Core #10 f/13,815' - 13,831'; cut 16', recovered 12' RECEIVED APR 2 2 !988 Alaska Oil & Gas Cons. Commission Anchorage Unocal Oil & Gas Divi~. Unocal Corporation P,O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District April 11, 1986 Hr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001Rorcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORT OF OPERATIONS WELL K-25~ DOLLY VARDEN PLATFORM Attached for your files are copies of June, July and August, 1985 monthly report of operations for the subject well. Very truly yours, RO~D .' Roberts Environmental Engineer cwl 00280 cc: Trading Bay Unit Participants RECEIVED APR 1 6 1986 (~1 & Gas Cons. ~ommisslon ~ STATE OF ALASKA ..--,... JAN 2 7 1986 ALASKA ~_ AND GAS CONSERVATION C[ ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel]J(~J Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska~ Inc. 85-78 3. Address 8. APl Number P. 0. Box 100360~ Anchorage, AK 99510-0360 50- 733-20180-01 9. Unit or Lease Name Trading Bay Unit 4. Location of Well atsurface 731' FSL, 142' FEL, $ec.17, TgN, R13E, $N 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB MLLW ADL 18730 10. Well No. K-25 11. Field and Pool NcArthur River Field Hem1 ock Pool For the Month of Augusl: ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2130 hfs, 6/2~,/85. Drld hard cml: f/1800' - 2030'. Kickoff ~ 2063'. Dr3d 12-1/~," hole t:o 9205'. Pipe stuck; jarred and reamed. Conl:~d dr]g 12-1/~' ho3e 1:o 97157. Pipe s1:uck; jarred and pumped pi~l. Cul: driP3 line and fished for pipe. Pump cm'c p3ug w/300 sx C3ass 6. Dr3d out cra1:. $ide'crack ~ 9039~. Dr3d 12-1/M~ ho~e 1;o 12~,00'TD (8/19/85). Ran 9-5/8" csg. Ran logs. Se1: retainer ~ 12,256~. 51Hng into rel:ainer, pumped 500 sx Class G cml:. POH & LD dr~3~pipe. Temporari3y suspended well ~ 2100 hrs~ 8/2z~/85. 13. Casing or liner ru.n and quantities of cement, results of pressur~ tests 9-5/8", ~7.0#/f1:~ L-80/N-80/S-95, BTC csg w/shoe ~ 1237~~. Cm~:d w/750 sx C3ass 'C. 14. Coring resume and brief description None RECEIVED Logs run and depth where run CBL/CCL/GR f/12286~ - 11950' 11810~ - 10000~ APR 1 6 ]986 Alaska 011 & Oas Cons. Oommi~ion 1 6. DST data, perforating data, shows of H2S, miscellaneous data None APR i 0 1986 Ak Environmental ~,~,,,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ......... TEMP3/NR29 ~ .... :. :~ ~..,,, JAN 2 ? 1986 STATE OF ALASKA A'LASKA~ ' AND GAS CONSERVATION C~ ~MlSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska~ inc. 85-78 3. Address 8. APl Number P, 0. Box 100360, Anchorage~ AK 99510-0360 50- 733-20180-01 4. Location of Well .. atsurface 731' FSL, 142' FEL, Sec.17, TgN, R13E, SN 5. Elevation in feet (indicate KB, DF, e~c.) 100' RKB MLLW 6. Lease Designation and Serial No. ADL 18730 For the Month of. June , 19 85 9. Unit or Lease Name Trading Bay Unit 10. Well No. K-25 11. Field and Pool McArl:hur Ri vet Fi eld Hem] ock Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2130 hfs, 06/24/85. Drld hard cmt: f/1800' - 2030'. Kickoff ~ 2063'. 5753' as of 06/30/85. Drld 12-1/4" hole to 13. Casing or liner ru.n and quantities of cement, results of pressure, tests None 14. Coring resume and brief description None 15. Logs run and depth where run RECEIVED APR 1 6 1986 011 & Gas Cons. Commission None 16. DST data, perforatingdata, showsof H2S, miscellaneousdata None A; R ] c_'. 198S ~ Ak Environmental 8roup 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S I G N E D TI T L E ~'%~?-~: '~ %~- ¢~* D AT E NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Unocal Oil & Gas I)ivis[ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District March 20, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORT Attached please find two (2) copies each of the Monthly Report of Orilling and Workover Operations for K-25, Trading Bay Unit for your information and files. Very truly yours, Ro~D. Roberts Environmental Engineer tj/O124n Attachments (2) RECEIVED Alaska OJJ & Gas Cons. Comrnissior, Anchorage STATE OF ALASKA '-' ALASKA _ ,L AND GAS CONSERVATION CO,,4MISSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~(~i~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anch°¢_age, AK 99510 4. Location of Well atsurface 73,1' FSL, 142' FEL, Sec.17, TgN, R13,E, UH 5. Elevation in feet (indicateKB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB MLLW ADL 1873,0 7. Permit No. 85-78 8. APl Number 50-- 73,3,-20180-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. K-25 11. Field and Pool McArthur River Fi eld Heml ock Pool For the Month of. February ,19. 86 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1200 hrs, 1/3,/86. Drilled ..out cmt retainer ~ 12,256'. Drld 8-1/2" hole to 13,,698'. Cored f/13,698' - 13,831'. Cont'd drlg 8-1/2" hole to 14,300'. Ran logs. Cont'd drlg 8-1/2" hole to 14,3,25'. Ran, cmtd, & tstd 7" lnr. Lnr not holding. Squeezed 7" lnr w/lO0 sx Class G. Ran logs. Perf'd 13,,542' - 13,,544' & 13,,3,78' - 13,380' for squeeze. Squeezed 13,,542' - 13,,544' w/125 sx Class G. Perf'd 13,293' - 13,,295' & squeezed w/lO0 sx Class G cmt. Squeezed TOL w/225 sx Class G cmt. (see attached sheet) .- 3. Casing or liner ru.n and quantities of cement, results of pressure tests 7", 29.0#/ft, L-80/S-95, BTC csg f/12,049' - 14,3,23,'.. Cmtd w/800 sx Class G. 7", 29.0#/ft, L-80/S-95, BTC csg f/6481' - 12,083,', tieback sleeve,~'mtd w/750 sx Class G. 14. Coring resume and brief description Core #1 f/13,,698' - 13,,708'; cut 10', recovered 1.5' Core #2 f/13,708' - 13,,718'; cut 10', recovered 10' _ Core #3, f/13,718' - 13,748'; cut 3,0', recovered 28' Core #4 f/13,748' - 13,,760'; cut 12', recovered 11.5' Core #5 f/13,,760' - 13,,777'; cut 17', recovered 16' (see attached sheet) 15. Logs run and depth where run IRT/FDC/CNL/GR/SP f/13,200' - 12,400' CBL/GR/CCL f/14,268' - 11,992' Gyro/GST f/14,268' - surface Csg inspection log f/8328' -- surface CET f/Il,900' - 14,300' Digital Sonic f/12,3,00' - 14,3,00' RF_CE!VED 6. DST data, perforating data, shows of H2S, miscellaneous data No depths reported for perforations. ,-,,... 2 1 198~ Alaska Oil & Gas Cons. Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ SIGNED. TITLE Environmental Engineer DATE 03/20/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 n~/~o*~o Submit in duplicate Monthly Report of Drilling and Workover Operations K-25 February, 1986 (cont'd) ITEM 12: Drld cmt to 12,072'. Located leak f/8395' - 8405'. Ran csg inspection log. Ran, cmtd, & tstd 7" tieback lnr. Drld cmt to 13,358'. Tstd perfs ~ 12,293'- 12,295'; bled to 2600 psi in 30 minutes. Squeezed perfs w/75 sx Class G cmt. Tstd perfs - ok. Drld cmt to 13,370'. Tstd perfs ~ 13,378' - 13,380' - ok. Drld retainer & cmt. PBTD = 14,282'. Displaced well to NaC1 brine. Ran logs. Perf'd well; well did not flow. RIH w/coiled tbg as of 2/28/86. ITEM 14: Core #6 f/13,777' - 13,787'; cut 10', recovered 7' Core #7 f/13,787' - 13,792'; cut 5', recover~ed 4.5' Core #8 f/13,792' - 13,805'; cut 13', recovered 10' Core #9 f/13,805' - 13,815'; cut 10', recovered 9' Core #10 f/13,815' - 13,831'; cut 16', recovered 12' RECEIVED Unocal Oil & Gas Divisie ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCALe DOCUMENT TRANSMITTAL Alaska District March 14, 1986 HAND DELIVER TO: Bill Van Alen FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: ARCO TBU K-25 McArthur River Field Cook Inlet, AK Sec 28, T9N R13W (SM) ARI #50-733-20180-01 For the well indicated above, please find the following data: 1 blueline & 1 sepia each for: Induc/SN (~" ~") 12,406 to 14,266' Dens/Neut " 5") 13,008 to 14,240' ~ff~CT (log) 50 to 14,252' 1 copy of the following tapes and listinqs: -~-LIS library tape %q~IS tape listing " ..... ~*~GCT (listing) w/ % - interpol, depths ~&GCT (LIS tape) w/ tape listing 3,0.50 to 11,190 ' 3,050 to ii,19off~-- ~ ,~?' ~-'$'-°/~~ ! ~ O~ - o toi4,325, / ~; 77 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: .. A~ska Oil & Gas Cons. CommWsio~ Anchorage Unocal Oil & Gas Division Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 995ib .,247 Telephone (907} 276-7600 UNOCAL ) Environmental Group Alaska District February 14, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001Rorcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORTS D-43 & K-25 Attached please find two (2) copies each of the Monthly Report of Drilling and Workover Operations for K-25 & D-43, Trading Bay Unit for your information and files. Very truly yours, oy~ D. Roberts Environmental Engineer tj/O124n Attachments RECEIVED FEB 1 8 1986 Oil & Gas Co~s. Commission Anchorage STATE OF ALASKA ' ALAS AND GAS CONSERVATION ISSION 'MONTHLY REPORTiOF DRILLING AND WORKOVER OPERATIONS · Drilling weHXl~'-I Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 731' FSL, 142' FEL, Sec.17, TgN, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB MLLW 6. Lease Designation and Serial No. ADL 18730 For the Month of. January ,19 86 7. Permit No. 85-78 8. APl Number 50-- 733-20180-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. K-25 11. Field and Pool McArthur River Fi eld Hemlock Pool 12. Depth at end of month/footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1200 hfs, 1'/3/86. Drilled out cmt retainer ~ 12,256'. Drld 8-1/2" hole to 13,698'. f/13,698' - 13,831'. · Cont'd drlg 8-1/2" hole to 14,290'. Attempting to log; tool stopping as of 1/31/86. Cored 13. Casing or liner ru.n and quantities of cement, results of pressur9 tests ~ None 14. Coring resume and brief description Core #1 f/13,698' - 13,708'; cut 10', reCovered 1.5' Core #2 f/13,708' - 13,718'i'cut 10', recovered 10' Core #3 f/13,718' - 13,748'i Cut 30', recovered 28' Core #4 f/13,748' - 13,760'i cut 12', recovered 11.5' Core #5 f/13,760' - 13,777'; cut 17'~ recovered 16' (See attached sheet) 15. Logs run and depth where run None RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data None FEB 1 8 Alaska Oil & Iias C~,'~. v ............. ~on Anch0rag~ 17. I hereby certify that zhe foregoing is true and correct to the b~st of my knowledge. SIGNED ' O~'~S TITLE Envi'ronmenta~l Engineer DATE NOTE--Report on this form is ~quired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas ConServation CommiSsion by the 15th of the sUcceeding month, unless otherwise directed. Monthly Report of Drilling and Workover Operations K-25 January, 1986 (¢ont'd) ITEM 14: Core #6 f/13,777'.- 13,787'; cut 10', recovered ?' Core #7 f/13,787' - 13,792'; cut 5', recovered 4.5' Core #8 f/13,792' - 13,805'; cut 13', recovered 10' Core #9 f/13,805' - 13,815'; cut 10', recovered 9' Core #10 f/13,815' - 13,831 '; cut 16', recovered 12' /= April 30, 1985 La~rrence O. Cutting Environmental Technician Union Oil COmpany of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Re: Trading Bay Unit K-25 Union Oil Company of California Permit No. 85-78 Sur. Loc. 731'FSL, 142'FEL, Sec. 17, T9N, R13W, SM. Btmhole Loc. 2107'F~, 2902'FEL, Sec. 28, TgN, R13W, SM. Dear Mr. Cutting: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except ex~perimenta! logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their-drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. ~. Lawrence O. Cutting Trading Bay TJnit K-25 -2- April 30, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonmemt, please give this office adequate advance notification so that we may have a witness present. Very trutv C. V. Chatterton ~ai~an of Alaska Oil and Gas Conse~ation Co~ission BY ORDER OF nE COb~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery Union Oil and Gas Di~:;!.0n: Western Region Union Oil Company o~ Jalifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union April 22, 1985 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK. 99501 PERMIT TO DRILL K-25 Dear Mr. Chatterton: Attached fo~ your approval is a Rermit to Drill for K-25, Trading Bay Unit. . Rlease return the approved Rermit to Drill to the undersigned. LOC/tj Attachment Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED Oil & Gas Cons, Commission .......... ~ /~nch0rage Union Oil and Gas !. sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager ~pril 2~, 1~85 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska NcArthur River Field Application to Drill and Complete TBUS K-25, ADL-187~O (8-86-71-5575-601~52) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State K-25 in the Hemlock Pool pursuant to Rule 5, Conservation Order No. 80. This proposed completion at a crestal final withdrawal point will result in additional recovery of Hemlock Production. Your approval of this request will be appreciated. sk cc: C. Case R. Warthen Very truly yours, Robert T. Anderson ECEIVED APR o 1985 '~laska Oil &~eas Cons. Commission /~nchorage STATE OF ALASKA '---- ALASKA-~.,L AND GAS CONSERVATION CC .,MISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ;J~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ZON [] MULT,PLE ZONE 2. Name of operator Union 0il Company (ARCO Alaska, inc. is Sub-contractor) -':-. ',.--OD 3. Address 909 W. 9th Avenue, Anchorage, Alaska 99501 4. Location of well at surface 731' FSL, 142' FEL, Sec.17,'r~, R13W, SM At top of proposed producing interval 1950' FNL, 2950' FEL, Sec.28, TgN, R13W, SM At total depth 2107' FNL, 2902' FEL, Sec.28, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF etc.) RKB 100' MLLW 6. Lease designation and serial no. ADL 18730 Alaska Oil &,~ ,_Gas 9. Unit or lease name Trading Bay Unit 10. Well number K-25 11. Field and pool McArthur River Field Hemlock Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8011-34-40 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed Kenai NW 24 miles 1950 feet K-4 well ~ 4736'TVD = 81 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 14257'MD, 9654' TVD fec. t 3840 04/26/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2100 feet. MAXIMUM HOLE ANGLE 55 oI (see 20 AAC 25.035 (c) (2) psig@__(ga,S_)_ Surface _~psig@ 9650 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing sting 24" '~xi stin(. 13-3/8" 12-1/4" 9-5/8" '8-i/2,, 7" Weight drive pi 61.0# 47.0# L- 29.0# L- CASING AND LINER - Grade I Couplingl Length pe I W~d I :~e~, u-ss I. C I 1962' o. MD TOP TVD 35' 135' I 35' 135' 33' ~33' I 12107' ~ 8429' MD BOTTOM TVD 400' II 400' 1997' I 1997' 12407' I 8600' 14257' I 9654' I I (include stage data) N/A cmtd to surface 750 sx Class G 400 sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to plug and abandon the existing K-16 wellbore below 2300'MD, The 9-5/8" casing will be cut ~ 2250'MD and pulled. After spotting a cement plug f/1900' - 2250'MD, the well will be directionally drilled to the proposed bottomhole location in the Hemlock formation. After fracture treating Bench 4, the well will be completed with a 4-1/2" x 3-1/2" completion assy, a packer and a surface controlled SSSV. A 13-3/8", 3000 psi, RSRA BOP stack will be used. 1. There are no closer wells in the open-hole section.w~J~;~ 2¢o' FS-~ ~~c 2. See Attachment I for surface pressure calculations. 3. 7" casing which meets or exceeds the proposed 7" casing may be substituted. 23. I hereby c~o~rect SIGNED Lawrence O. Cuttl ng to the best of my knowledge ~ TITLE ENV IRONNENTAL SPECIALS I-~ATE 04-22-8_5 The space below for Commission use CONDITIONS OF APPROVAL .Samples required []YES ~j~.N O Permit number APPROVED BY Form 10401 Mud Icg required Directional Survey required I APl number F1YES [~NO ~YES FINO J 50-- ~7~ - Approval date ~-'7~ SEE R LETTER FOR OTHER REQUIREMENTS ~ ~ ~ ~ ~30~5. COVE _ /~~/~~~MlSSl ON ER DATE (KJG) P~PD68 ~ ~ Submit in tripmicate G 4F-,/ i3[~ ~- 1,~q..L. NO, K ~-25 PROPOSED ~ ~_..*[._.~t'tp~___-I:q..TFM, TBU_, O0_.OK INLET · . _ vERTICAL PROJE -I(]N-:~-:'-~ SCALE 1 IN. - lO00 FEET' · SURFACE _ KOP' TVD-2100 TMD'2100 DEP--'16 -- ~ i~,,~ BUILD 2 1/2 DEO . ' ~,14.1 PER 100 FT ..... . - - . ~3~ 41 AVERAGE ..... ANGLE ~ - .55 DEG- 16 MIN - ~ ~"da~ka Oi! & G~s Co,ns. COD:rniSSiOD BA~ ~~K TV~~ ~-t4057 TO TVD=9654 TMD-1425r DEP~135 ' h I I I I I I I ! I I 1000 0 1 000 2000 3000 4000 5000 6000 7'000 8000 9000 VERTI OAL SEOTt ON i OOC ARCO' ';ASKA, INC* ~'/11% LEG w. SLOT 28, WELL NO, K-25 PROPOSE KING SALMON PLTFM; TBU. COOK INLET. EASTM/d~ WHIPSTOCK, INC.'.. .. lO00 1000 - 2000 - 3000 - 4000 - 5000 - 6000 - 7000 _ 8000 _ 9000 _ 1000 0 WEST-EAST 1000 2000' 3000 I I PLANE OF PROPOSAL S 17 DEC,.15 MIN E 16 21 4000' - -o -. TARGET DIRECT[OH t S 17 DE(:; 6 MINE 2O 29; 21 28 ~.330 FT TAR(~ET TYD-gl IX> ft'lD=~ 3284 SOUTH EAST 2472 ! FT ~,ooaoe aoo":',l!i:i'"~,,'"'"' '!.. ~oo ~2oo~oo' ~4oo 60n ~-"~ . . ~- ~ , '~ , ARCO 'ALASKA, INC, :;~"H'~' LEO 4. SLOT 28. ~LL, K-25'. REDR~;~_~OPO~ED4~z~ ' : ' ' . KENO SALHOH PET~';' COOK INLET; AL~,' ....... ~ EASTHAN ~H[.PSTO~. INC. ':: '~'~ ' : ' 1 900 NOTE, NELL PA~ES EXTEND BEYOND THAIS VEEriNG~ ~[NDO~. 21 i ~ · . 11 ~ : ~' ' , ' , , . , '.. .' . . '.. 2500 ~4- .~,,~ ~:~ ~ '....., .; ... · ." . ~:' .' '..' .' ..5~.._ ' . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 18, 1984 ,/°c~o -/?oo£s/ Mr. H. Hedlund State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: K-8 RD Permit to Drill :.{, "hr'--,-.. Cons. Dear Mr. Hedlund, You raised a question concerning my calculation of anticipated surface pressure on the K-8 RD Permit to Drill. After reviewing that matter, I came to the conclusion that the previous method of- calculating anticipated surface presures is not justified for the King Salmon platform, within the Trading Bay Unit. Previously, the maximum bottomhole pressure was extrapolated to surface using a gas gradient (at constant volume). The following equation was used' Example #1 PiV1 = P2V2 T1 T2 P1 = P2 ' Where V1 = V2 I : Surface 2 = Bottomhole P : Pressure (psi) V : Volume T : Temperature (°R) T1 T2 P1 = P2 T1 ?qoo~TVO T2 This equation may be justifiable in areas where a gas zone will be penetrated but to date, a gas cap has not been detected in the Hemlock formation (target formation at total depth) and none is anticipated. Realizing this, to assume a full column of gas to surface under emergency conditions is, although a worst case, Example #2 Mr. H. Hedlund October 18, 1984 Page 2 highly improbable. Under this worst case, using the above gas law, the maximum surface pressure anticipated would be' P1 =' P2 T1 T2 : 4000 ps i[~ 80+460 = 3375 psi Since I do not think this is possible (if I did, we would be using 5000 psi BOP equipment), I would like to offer an alternative calculation of maximum surface pressure anticipated from the Hemlock formation. One known fact of the Hemlock crude is that it does contain solution gas which has a bubble point of 1700 psi. This tells me that if a full column of crude is brought to the surface and the well is shut in, that over time, gas will break out of the crude (displacing crude into the formation). This will create a gas column at the top of the well until the gas/oil interface is at 1700 psi (surface pressure plus gas column pressure). Upon initial shut in, the surface pressure would be equal to bottomhole pressure minus a full column of crude. As the gas breaks out of the oil and displaces the crude, the surface pressure will increase until this process stops. The following derivation estimates what the maximum surface pressure would be under these "ideal" conditions: Ps + Phg + Pho: PBH Pha = (.08 psi/ft)Y Pho = (.36 psi/ft)X X + Y : 9900 ft & Gas Cons. Oomrnissior~ Anchorage PG/O = Ps + (.08 psi/ft )Y = 1700 psi (.08 psi/ft)Y : 1700 psi - P s Y = 1700 psi - .08 psi/ft P .0'8 psi/ft Mr. H. Hedlund October 18, 1984 Page 3 = PBH- Phg- Pho = 4000 psi - (.08 psi/ft)Y - (.36 psi/ft)X Where, Substituting for X, Substituting for Y, X = 9900 ft - Y Ps = 4000 psi - (.08 psi/ft)Y - [(.36 psi/ft) (9900 ft-Y)] = 4000 psi - .08 psi/ft x Y- 3564 psi + .36 psi/ft x Y = 436 psi + .28 psi/ft x Y = 436 psi + 28 psi/ft [=1700 psi - Ps-"~ L.08 psi/ft ~8 psi/ = 436 psi + 5950 psi - 3.50 Ps 4.5 P = 6386 psi S P : 1419 psi S Ps = Surface Pressure Phg = Hydrostatic Gas Pressure Pho : Hydrostatic Oil Pressure PBH = Bottomhole Pressure Y : Gas Column (ft) X : Oil Column (ft) PG/O = Pressure at Gas/Oil Interface To further back up this alternative, an exploration well (W.F.U. #3) was drilled near the K-8RD bottomhole location in 1966. A drill stem test was performed on the Hemlock @ 9600'TVD wi th a bottomhole pressure of 4290 psi. The shut-in drillpipe pressure after flowing 912 bbls of oil (no gas or water) was 1000 psi. Another well on the platform, G-30, has one of its dual completions in the "G" sand @ 8750'-+TVD. The original bottomhole pressure was 3800 psi+_. The well made 10% H20/90% oil (no gas) and has been shut-in for over a year. Its surface pressure is 1200 psi despite the lower bottomhole pressure and 10% water cut! As I mentioned before, the worst case for maximum surface pressure to occur is when a gas sand is cut. The permit to drill suggests that the maximum surface pressure will be some function of the maximum bottomhole pressure (usually near TD). This is not true if a gas sand is cut, even if it is well above TD. Mr. H. Hedlund October 18, 1984' Page 4 For instance, on K-8RD, there is a possible gas sand at 6300'TVD. This sand has a low permeability and is normally pressured (2700 psi±) so its potential to cause an emergency situation is limited. But it is a gas sand, so under worst conditions, Example #1 could apply. Under these conditions, the maximum surface pressure would be: P1 = P2 T1 T2 : 120 + 460)~ : 2514 psi In any event, our 3000 psi BOPE should be adequate enough to handle any anticipated occurrence in the King Salmon area. As one last comment, I would like to point out that we use 3000 psi BOPE on all our workovers and our highest brine (mud) weights are 8.8 ppg±. During drilling operations, our mud weights will be 10.5 - 11.5 ppg± to control shales and coal seams. If you have any more questions regarding this matter, please call me at 263-4962. Sincerely, K. d. Grimes Drilling Engineer ,. T. L. Fithian Area Dril ling Engineer DATE KJG/80- tw xc' T. L. Fithian glaska Oil & Gas (;oas. Commissio. K-25 PERMIT TO DRILL ATTACHMENT I The anticipated surface pressure shown in Item 20 assumes gas to surface. Since a gas/oil contact has not been detected in the Hemlock, the chance of having a gas column to surface (from the Hemlock) is remote. The highest possible surface pressure (realistic) from the Hemlock would be to assume a gas gradient down to the bubble point (1700 psi) and an oil gradient to the Hemlock (see Attachment II). This would calculate as follows' P = 4000 psi-(.08 psi/ft)Y-[(.36 psi/ft) (9650 ft-Y)] s : Where Y=1700-Pr;.08 ps?/ft: 526 psi+(.28 ps~/ft)L.~8 ps~]'ftJ ~ = 6476 psi - 3.5 P S P = 1439 psi S Since the worst case for maximum surface pressure is when a gas sand is cut, this should occur in the Grayling Gas Sands. The bottomhole pressure there is 2500 psi @ 4500'TVD. Using the equation' P1 = P2T~22 ( 90+460 = 2455 psi The maximum anticipated (realistic) surface pressure in either case should be adequately handled with-3000 psi BOPE. GRU6 / PDO la' tw 04/19/85 I v ED AJaska Oil & Gas Cons, 6o','nrnission Anchorage 7'6 8 6 TRIP .'<.5 SIGNED R['CEIVED APR 2 2 1985 Alaska 0il & Gas Cons, Commission DATE I SIGNED ~-----~]~ 4S 469 SEND PARTS I AND 3 INTACT.- POLY PAK (50 Sets) 4P 469 PART a WILL BE RETURNED WITH REPLY. ARCO Alaska, Inc/-~' Post Office. x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. Larry Cutting Environmental Technician Union Oil Company of California 909 W. 9th Avenue Anchorage, AK 99501 SUBJECT: K-25 Permit to Drill Dear Larry, Please sign the enclosed permit for K-25 and forward it to the Alaska Oil & Gas Conservation Commission for approval. Since we expect to spud on April~, 1985, we would appreciate it if you could expedite the processing of this application. If you .have any questions, please call Kevin Grimes at 263-4962 or Jo Ann Gruber at 263-4944. Sincerely, T. L. Fithian Area Drilling Engineer TLF/JG/tw GRU6/L08 Enclosure CC: K.. j.~ Grimes J. Gruber Well File ARCO Alaska. Inc. is a Subsidiary o! AtlanlicRJchfieldCompany APR2 Alaska 0il & Gas Cons. STATE OF ALASKA --,, ALASKA ~L AND GAS CONSERVATION CE .MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Union 0il Company (ARCO Alaska, Inc. is sub-contractor) 3. Address 909 W. 9th Avenue, Anchorage, Alaska 99501 9. Unit or lease name Trading Bay Unit~?~;% 4. Location of well at surface 731' FSL, 142' FEE, SeC.17,1'~N, R13W, SM At top of proposed producing interval 1950' FNL, 2950' FEL, Sec.28, TgN, R13W, SM At total depth 2107' FNL, 2902' FEL, Sec.28, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF etc.) RKB 100' MLLW 6. Lease designation and serial no. ADL 18730 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8011-34-40 13. Distance and direction from nearest town ' 14. Distance to nearest property or lease line Kenai NW 24 miles 1950 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 14257'MD, 9654' TVD feet 3840 10. Well number K-25 11. Field and pool McArthur River Fi eld Hemlock Pool Amount $500,000 15. Distance to nearest drilling or completed K-4 well ~ 4736'TVD = 81 feet 18. Appro,./~ate spud date o4/.~¢/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~75 KICK OFF POINT 2100 feet. MAXIMUM HOLE ANGLE 55 oI (see 20 AAC 25.035 (c) (2) 4000 Proposed Casing, Liner and Cementing Program psig@ (g~_~_) Surface psig@ 9650 ft. TD (TVD) i SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT i Hole / Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) iexistin~ 24" drive p~iPe Weld 365, 35' I 35' 400' I 400' N/A !existin~ 13-3/8" 61.0# J-55 BTC 1962' 35' , i 35' 1997' I 1997' cmtd to surfa.e.e i12L1/4''. 9-5/8" 47.0# L- or-N-80 BTC 12374' 33' 133' 12407' I 8600' 750 sx Class G !8-1/2" 7" 29.0# L- or N-80 BTC 2150' 12107' I~ 8429' 14257' ~ I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to plug and abandon the existing K-16 wellbore below 2300'MD. The 9-5/8" casing will be cut ~ 2250'MD and pulled. After spotting a cement plug f/1900' - 2250'MD, the well will be directionally drilled to the proposed bottomhole location in the Hemlock formation. After fracture treating Bench 4, the well will be completed with a 4-1/2" x 3-1/2" completion assy, a packer and a surface controlled SSSV. A 13-3/8", 3000 psi, RSRA BOP stack will be used. 1. There are no closer wells in the open-hole section. 2. See Attachment I for surface pressure calculations. 3. 7" casing whi'ch-'meets- or, exceeds,.the, proposed. 7." -casi,ng may, be- substi'tuted~ 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Mud log required i--I YES []NO Approval date CONDITIONS OF APPROVAL The space below for Commission use DATE Samples required []YES E]NO Directional Survey required I APl number ' I--lYES []NO I 50-- SEE COVER LETTER FOR OTHER REQUIREMENTS I Permit number ,COMMISSIONER DATE by order of the Commission APPROVED BY Form 10-401 (KJG) PD/PD68 Rev. 7-1-80 Submit in triplicate .. Il'J,. ~NIti_~' IJl. Tlrq'l'-. TBU. CO01{ INLET ;TIiI i, Mjli~TIIQ~ ll~. · . ~ TVD-2100 THD"2IO0 DEP---I6 444, t~ ~,,~ BUILD 2 2 DE ' ~~ ~1 ' ' . 41 _. '~.~ ~ . _::. ~ s~ ~K rv~ r~~ ~ TD TVD 96~4 THD=14~ O~ I mm I I I I I 1000 0 1000 ~000 )000 SOO0 7000 8000 9000 I I ,!,000 5000 VERTICAL SECTION APR 2 "'" 1985 Alaska Oil & Gas Cons. Commission ! 100 .. EASTIIAN 14H[PSTOCK, [NC'." ' ~ i4EST-E^ST ! 000 0 !0~0 i ' !000 2000' 3000 4000' ~4e PLANE OF PROPOSAL $ 17' DEG-15 H[N E 1000 _ 2O 16 2000 . 3000'. TARGET D~REC:TION, DEC 6 ~I[N E 4000 . 5*000 _ 6000. 7000 21 28 ! ~~ FT 8000 . 9000 TYD.9! O~ SOUTH _ ,¥ED Alaska Oii& G~s ()ohs. Commission Ar-~ci ] o rag ~ NOTE, I,tELL P. ATI~ EXTEND EI~YOND ~ ' , 2200~ . ' .... ~ N ~ . . 2~00 ' ~ '~'~ " ' ' ' , -' ' . " ' . ' , ' ' Z' 2500 . . ~ ~ ' , ,~ , ' r , " K-25 PERMIT TO DRILL ATTACHMENT I The anticipated surface pressure shown in Item 20 assumes gas to surface. Since a gas/oil contact has not been detected in the Hemlock, the chance of having a gas column to surface (from the Hemlock) is remote. The highest possible surface pressure (realistic) from the Hemlock would be to assume a gas gradient down to the bubble point (1700 PSi) and an oil gradient to the Hemlock (see Attachment II). - This would calculate as follows: Ps : 4000 psi-(.08 psi/ft)Y-[(.36 psi/ft) (9650 ft-Y)] = 526 psi+(.28 psi/ft)~1700_P~ -1 Where Y=1700-Pr;.08 ps~'/ft: 526 psi+(.28 psi/ft)[.08 psi[ft] = 6476 psi - 3.5 P Ps = 1439 psi s Since the worst case for maximum surface pressure is when a gas sand is cut, this should occur in the Grayling Gas Sands. The bottomhole pressure there is 2500 psi @ 4500'TVD. Using the equation: P1 = P2 ~ (90'+460 = 2455 psi The maximum anticipated (realistic) surface pressure in either case should be adequately handled with 3000 psi BOPE. GRU6/PDO la: tw 04/19/85 · o ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 OctOber 18, 1984 ~# = ,./ooop.~i Mr. H. Hedlund State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: K-8 RD Permit to Drill Dear Mr. Hedlund, You raised a question concerning my calculation of anticipated surface pressure on the K-8 RD Permit to Drill. After reviewing that matter, I came to the conclusion that the previous method of- calculating anticipated surface presures is not justified for the King Salmon platform, within the Trading Bay Unit. Previously, the maximum bottomhole pressure was extrapolated to surface using a gas gradient (at constant volume). The following equation was used: Example #1 PiV1 : P2V2 T1 T2 G/OJ~F£~Fw~E P1 : P2 ' Where V1 : V2 T1 T2 P1 : P2 T1 11?9oo~rvO T2 I : Surface 2 : Bottomhole P = Pressure (psi) V = Volume T : Temperature (°R) This equa-ti-on-may,~be ju.stifiabl-e-, in areas-where a gas. zone willl. be penetrated but to date, a gas cap has not been detected in the Hemlock formation (target formation at total depth) and none is anticipated. Realizing this, to assume a full column of gas to surface under emergency conditions is, although a worst case, ARCO Alaska. Inc. ~$ a Subs~d~acy of AtlanticRichfieldComp&ny RECEIVED Alaska Oil & Gas Example #2 Mr. H. Hedlund October 18, 1984 Page 2 highly improbable. Under this worst case, using the above gas law, the maximum surface pressure anticipated would be' P1 :' P2 T1 T2 : ooo 180+460).] : 3375 psi Since I do not' think this is possible (if I did, we would be using 5000 psi BOP equipment), I would like to offer an alternative calculation of maximum surface pressure anticipated from the Hemlock formation. One known fact of the Hemlock crude is that it does contain solution gas which has a bubble point of 1700 psi. This tells me that if a full column of crude is brought to the surface and the well is shut in, that over time, gas will break out of the crude (displacing crude into the formation). This will create a gas column at the top of the well until the gas/oil interface is at 1700 psi (surface pressure plus gas column pressure). Upon initial shut in, the surface pressure would be equal to bottomhole pressure minus a full column of crude. As the gas breaks out of the oil and displaces the crude, the surface pressure will increase until this process stops. The following derivation estimates what the maximum surface pressure would be under these "ideal" conditions: Ps + Phg + Pho : PBH Pha : (.08 psi/ft)Y Pho : (.36 psi/ft)X X + Y : 9900 ft PG/O : Ps + (.08 psi/ft )Y : 1700 psi (.08 psi/ft)Y : 1700 psi - P Y = 1700 psi - .08 psi/ft P ' 08 p'si/ft A~aSka O~ & GaS GOnS. ~]o[nn~issloP- Anc?~or~ge Mr. H. Hedlund October 18, 1984 Page 3 P : PBH- Phg- Ph° : 4000 psi - (.08 psi/ft)Y - (.36 psi/ft)X Where, Substituting for X, Substituting for Y, 4.5 Ps = 6386 psi Ps = 1419 psi X = 9900 ft - Y Ps : 4000 psi - (.08 psi/ft)Y - [(.36 psi/ft) (9900 ft-Y)] : 4000 psi - .08 psi/ft x Y- 3564 psi + .36 psi/ft x Y : 436 psi + .28 psi/ft x Y : 436 psi + 28 psi/ft [=1700 psi - Ps -'~ L.08 psi/ft ~08 psi/ = 436 psi + 5950 psi - 3.50 Ps Ps = Surface Pressure Ph : Hydrostatic Gas Pressure g Pho : Hydrostatic oil Pressure PBH : Bottomhole Pressure Y = Gas Column (ft)- X = Oil Column (ft) PG/O : Pressure at Gas/Oil Interface To further back up this alternative, an exploration well (W.F.U. #3) was drilled near the K-8RD bottomhole location in 1966. A drill stem test was performed on the Hemlock @ 9600'TVD wi th a bottomhole pressure of 4290 psi. The shut-in drillpipe pressure after flowing 912 bbls of oil (no gas or water) was 1000 psi. Another well on the platform, G-30, has one of its dual completions in the "G'" sand @ 8750"~TVD.' The original' bottomhole pressure was 3800 psi+_. The well made 10% H20/90% oil (no gas) and has been shut-in for over a year. Its surface pressure is 1200 psi despite the lower bottomhole pressure and 10% water cut! As I mentioned before, the worst case for maximum surface pressure to occur is when a gas sand is cut. The permit to drill suggests that the maximum surface pressure will be some function of the maximum bottomhole pressure (usually near TD). This is not true if a gas sand is cut, even if it is well above TD. RECEiVeD Mr. Fi. Hedlund October 18, 1984 Page 4 For instance, on K-8RD, there is a possible gas sand at 6300'TVD. This sand has a low permeability and is normally pressured (2700 psi±) so its potential to cause an emergency situation is limited. But it is a gas sand, so under worst conditions, Example #1 could apply. Under these conditions, the maximum surface pressure would be: P1 = P2 T1 T2 = 2700 psi F(80 + 460))]120 + 460 = 2514 psi In any event, our-3000 psi BOPE should be adequate enough to handle any anticipated occurrence in the King Salmon area. As one last comment, I would like to point out that we use 3000 psi BOPE on all our workovers and our highest brine (mud) weights are. 8.8 ppg±. During drilling operations, our mud weights will be 10.5 - 11.5 ppg± to control shales and coal seams. If you have any more questions regarding this matter, please call me at 263-4962. S i ncerely, K. d. Grimes /~ Drilling Engineer /~~. T. L. Fithian Area Dril ling Engineer DATE KJG~O: tw xc: T. L. Fithian Alaska 011 & (-~as .... , . 120'~ "SG 4§~--" ' ' 5F 4B~ 4 5 14A · 5313" . ' ~ .1--.~O 51 5lA "- ' 52 67 5F I o o Oil & Gas Cons." ·4..,~..,~o;.' ~' ' CHRISTMAS TREE ASSEMBLY NO. SWE-54 Unihead (Alaska) w/Extended Neck H~ P,i, lq? NO. ' 9CALl PAI'I*r~N Nd.. FOR ATLANTIC F{ICHFIELD CO. · PIlOl'llq11' oP OIL CENTER TOOL CO., INc. · H'OUgTON, TE:XA~ ' ' _ · , I c,o/o~' r..' .' ' ' · · ' '" ' . : e ADJ. CHOKE ,,1 .H 5000 PSI DIAPHRAGM CHOKE LINE :K :O S Q P R' CHECK VALVE -10- TEST 8EQUENCEON VALVE~ i ii ii i · 1 A-K-P-Q-E-M-T · 2 B-G-F-D-$-R ,3. H-SWACO CHOKE-C- ADJUST CHOKE-O · 4 J-I · 5 L · 6 N CHOKE MANIFOLD KILL LINE W/B..O.P. ON k'lkl~ DI · ~'"LisT FOR NEW WELL PERMITS ITEM APPROVE DATE thru 8) (3) Admin /'.;!~tx... 'q 9. O/thru 12) ]0.. (lO ara 12) ~2. (4) Casg ~..~~. ~-~,t- (13 thru 21) 1. Is mi 4. 5. 6. 7. 8. ]4. ]5. ].6. ]7. )8. i9. :~0. ~: 1. (22 thru~ Company Lease & Well No. YES NO IS Is Is Is Is well to be deviated and is wellbore plat included ............... Is operator the only affected party ................................ Can permit be approved before ten-day wait ......................... the permit fee attached ................... ~ ~ ~eoeeeoeeeeeeeleeeeo®eee ,,, well to be located in a defined pool ............................ .~ well located proper distance from property line .' ' well located proper distance from other wells .... ' . sufficient undedicated acreage available in this pool ........... - Does operator have a bond in force .. . ...... , ................ Is a conservation order needed .... Is administrative approval needed .... Is the leaSe number appropriate .... REI~RKS Is Conductor string provided ..................................... Is enough cement used to circulate on conductor and ~urface .. Will cement tie in surface and intermediate or production strings . Will cement cover all known productive 'horizons ................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tensicm and burst Is this well to be kicked off from an existing wellbore , .......... Is old wellbore abandonment procedure included on 10-403 . ......... Is adequate wellbore separation proposed .......................... Is a diverter system required ........ .~ ............................ Are necessary diagrams of dlzz~z~a-~-:and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~-f~P psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ' eeeeeteleeeee.eeel.eeeeeeee· lee.el··lee·cie·e· Additional Remarks: /~ Aa- t,;,;-~,'./ 8;I Geology: Engineering: HW~ i5..' LCS ~C%'~EW ~'~' WVA JAL'i/~ ? rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 5~ I v.o ~ 1-o~ ~ ~.o ~ ~ ~ ° o"~"~ · , , Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi · No special-effort has been made to chronologically organize this category of information. LVP 010,H02 VERIEICATION bISTING PA~E 1 SERVICE NAME IB.DIT DATE 1B'8/02/17 ' ORIGIN~ REE~.NANE ~7257'3 CONTzNUATION # 10! PREVIOUS REEL : COMNENTS :LIS TAPE, ARCO ALASKA, INC, TBU K-25, APl 50-733-20150-0i ** TAPE HEADER SERVICE NANE :EDIT DATE 88/02/17 ORIGi~ ~FSlA TAPE NA~E CONTZNUATIO~ # PREVIOUS TAPE CON~ENTS ~LIS TAPE, ARC[I ALASKA, INC. TBU K-2§, API §0-733-20180-0! EOF ********** ** FIbE HEADER ** FILE NA~E ~EDIT ,001 SERVICE NAME VERSION # DATE: _AXI UN bE, NGIH t 1024 FILE TYPE PREVIOUS FILE ** I~FORMATION RECORDS ** CONTENTS CN ) ARCO ALASKA, WN ~ T.B.U, K-25 FN ~ .MCARTHUR RIVER RANG~ TOWN~ N SECT~ t7 COUN~ KENAI STAT~ AhASKA ** COMMENTS ** UNIT T'¥PE CATE SIZE CODE 000 000 019 065 000 000 012 065 000 000 014 065 000 000 004 065 000 000 002 065 000 000 O02 0~5 000 000 006 065 000 000 006 065 "LYP 010,H02 VE~IFICATIO~ LISTING SCHLUHBERGE~ A~ASKA COAPU'TING CENTER COMPANY = ARCO ALASKA, INC, FI,E~D =', ~[i VER }ACART COUNTY ~ KENAI STATE = AhASKA dDOB NUMBER ~T ACC= 72.573 ATE COMPUTED= 16-FEB-88 ~UN '3' DATE [,OGGEP, .%,.FEB,,86 D'P{ , KOHRING. CASING TYPE F~UiD DENSITY ~SCOSITY FLUID LOSS , 'ATRIX SANDSTONE - .BIT SIZE =. 8,5" TO 14272"(I~OGGER) COMPUTING CENTER RE:MARKS= NPHI..CN5 H~$ BEEN RECO~PU~:ED 'rD USE BITSiZE AS HOI~E SIZE CORRECTION FACTOR INSTEAD OF USING',T}~E BAD CALIPER AS WAS UTILIZED IN FIEbD. NPHI/DPHI POROSITY. ~IL~S AND PRINTS WERE ALSO RECREATED ,AT THIS TI:~,E. DENSITY REPEAT PASS INCLUDED bVP O10,.H02 YE, RIFICATION LISTING PAGE ON THIS blSTAPE BECAUSE IT IS PREFERRED OVER THE: bOG FILE BELOW 14v029' THIS DATA HAS NOT BEEN DEPTH SHIFTED -.OVERLAYS FIELD PRINTS 'SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPEI INDUCTION / SHORT NORMAL bOG (,IRT) FIRST TO LAST READiNG~ 14266' TO 12406' FOR~tATION DENSITY CO P~,NSATED LOG (.FOR) EAT FIbE FIRST TO LAST READiNG~ 14240' TO ~903' FORMATION DENSITY .COMPENSATED bOG C.FDC) LOG F~bE FIRST TO hAST READ'iNG~ t4229' TO 13006' , , , , , , , , , , $ , , ,, , , , , , , , ~ , , , , , , , PAGE -,** DATk FORMAT RECORD ** ENTRY BbOCK, S TYPE SIZE 2 ! 4 ! 9 4 0 ! .ATUM SPECIFI. CA~ION BhOCKS NEM SER¥ICE SERVICE UNIT API I D ORDER ~ DEPOT FT SN iRT Sp IRT RT GR IRT TENS iRT SGR MDT DT DTSM SDT TENS SDT . 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O0 DRMO -999,2500 NCNb -999,2500 IbD "999'2500 "999,'2500 GR -999.2500 CALI -999,2500 DRHO '999.2500 GR -999.2500 NCNb '999,2500 DPHI '999.22500 NPHI ,-999, 500 FCNb '"999 "999 "999 '999 '999 500 RHOB 2500 TENS 2~00 FCNL '999,2500 SP .g4g.8242 DT .2500 RHOB '999.2500 TENS -999.:2500 DPHI -999.2500 NPHI -999'2500 FCNL -999.2500 SP -9:99,2:500 DT '999.2500 RHOB '999.2500 TENS ",9 , O0 '~9~.~00 -999,2500 FCNL ** FILE TRAILER FILE NAME :EDIT ,001 SERVICE NAME VERSION{ DATE~ ~AXI bE GTH ~ 1024 FILE TYPE NEXT FIbE NAME EOF ********** ** TAPE TRAILER SERVICE NAME =EDIT DATE =88/02/17 ORIGIN ~FSlA TAPE NAME CONTINUATION # ~01 NEXT TAPE NAME COMMENTS :LIS TAPE~ ARCO AbASKA~ INC,. TBU K-25~ PAGE -999.2500 -999;2500 ,,999,2500 -200.5625 74.0000 -999;2500 -999,2500 -999,:2500 -999,2500 -999,2500 -999,2500 56,0000 '999,2500 -999,.~500 -,999, 500 -999,2500 -999,2500 -999.2500 55,0000 -999,2500 -999,:2500 99 ,25,00 -999,2500 LVP 010,H02 VERIFICATION bI$?INO PAGE 9 SERVICE DATE ORIGIN { ~EEL_NAME {72573 CO~'TINUATION # COMMENTS ~LXS T~PE~ ARCO A~AS~A~ INC, TBU ~-25w API 50-733-20180-0! LIS T~PE ~ERI:IC~TIO~ LISTINS LVP 010.HOZ VER[FISATI34 LISTIN$ PA~E ~ REEL HE~DER ¢~ SERVICE NAME : E D I'T,', DATE : ,~.$/03/10 ORIGIN : ~EEL N~ME :~~ CON~IN~TION ~ :01 PREVIOUS R~EL : SD4~ENTS :L~BRA2Y T~PE .-~ TAPE HE~DER SE~VI'C E NAME' :EDI~ )AT~ :85/03/10 ORt,~I ~ .0000 ~4PE ~E 11330 COnTINUaTION ~ :01 ~RE~IOJS T~PE : COMqENTS :L~BRA~Y 'T~PE ,',::~: FILE HE~OER S ERVZ C E~E · VERSION J DA ~E : MAXIMUM LENGTH : 102~ FIL~ TYPE P R E V 10 U S F INFORMATION RECORDS ~ MN:_~ CO~TENTS 'N : ~R WN : FN : MC SECT: 17 COJN: KE ST~T: ~L CTR¥: US CD ALASKA INC..E-2 B.U, ~RTMUR. RIV'ER ~SK& CONTENTS ~RES: E COMMENTS J4 IT TYPE OOO ODD 000 000 000 OOO ODD TYPE 000 '&TE 300 300 300 300 ]DO 000 OO0 300 300 000 SIZE 019 011 003 O0 005 005 015 033 SIZE 001 065 065 065 065 065 065 065 065 065 C3DE 065 LV~ 01goH02 VERIFIC~T.Ig~ LISTIN~ PAC, E 2 COMPANY = ARCO AL~S:KA INC~ WELL = T',B,J, <'25 FIELD = 'MCAR'THUR RIVER, FIELD CDJNTY = STATE = JO5 NUMBER AT ~CC.' 71)33 Rdq ~1, DATE LDSGED: I-.FEB-B6 LOP: L" B.: CUDN:EY CASING = p~.$25q' :~ ~.23'73,0:" TYPE FLJID = LD¥. G M~ rJE'NSITY = '9,8'O.LB~ VISCOSITY : ~5.0 S PH = 8.5 FL~Ig L3SS = 5.~ S3 MATRIX SAN'2STO'NE B:IT: SI!E = 8.5" T3 RM R MF I ~+:3 ~ O, 0" = 3.ZOO = 2,583 : 1.356 70.0 DF 70.0 DF 70.0 DF 1~.2. DF LV~ OIO.HDZ VERIFIC~TIg4 LISTINS P~GE 3 THIS DATA MAS NOT BEE4 DED'T~9 SHIFTED - DVER'LA~S SCMLUMBERSER LOGS INCLUDED WIIM Y.t, IS MAGNETIC TAPE: ,.~'" 1,4D~CTIDN / S~DRT ~?D~.T~ AV'~ILA~L I.~ RM~L LOG'(:~) 1~255' T~ 12~05.0' FDR.M~TIDN DE:YSITY/COMPE.NS:ATED.cNE,~.IRDN LO,G:,'CF~N> DATA FOR'MAT,,2E~DRD ENTRY ~L'OC~S TYPE SIZE REPR CODE ENT'R~. 2 I $$ 0 ~ ~ 73 50 ~ ¢ 55 ,.lin 15 O' 1 66 O DAr~M SmECIFICATIDN BLOCKS MNEM SERVICE SERVICE U4IT ~PI API API ~mI FILE SIZE SPL REaR PROCESS ID DR2ER ~ ~OG TYPE CLASS MOD qO. 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