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178-087
STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM,. .JION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well❑ Plug Perforations ❑ Perforate ❑ Other 0 Install ESP Performed: Alter Casing❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver 0 Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 178-087 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20247-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-25RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,510 feet Plugs measured N/A RECEIVED true vertical 10,021 feet Junk measured 11,290 feet FEB 2 0 2015 Effective Depth measured 11,415 feet Packer measured See Schematic feet true vertical 9,941 feet true vertical See Schematic feet AOGCC Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet %AWED -,- ,, ; True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 7,507'(MD) 6,722'(ND) Packers and SSSV(type,measured and true vertical depth) Packer-See Schematic TRMAXX-5E SSSV 353'(MD)353'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 240 212 • Subsequent to operation: 100 174 13688 248 248 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-558 Contact Dan Marlowe ttIVA pp Email dmarIowe(hiICorp.com V Printed Name Dan Marlowe �1 V" � tk. Title Operations Engineer ttemai. -Wro Signature �/. 1JV"' Phone (907)283-1329 Date 2/20/2015 RBDMS FEB 2 3 201 Form 10-404 Revised 10/2012 / / r Submit Original Only 3/11Grf HSCHEMATIC Dolly Varden Well No. D-25RD H,korp Alaska,LLC Completed: 01/20/2015 CASING DETAIL Tree connection:4-1/16"5,000# SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,518' ais mon. 9-5/8" _ 47 P-110 Butt 8.681 Surf 8,155' c 7" 29 N-80 Butt111 6.184 7,938' 11,506' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax Surf 7,507' 1 .. } d imt 116 Holes in casing Jewelry Detail iM MEN 1 3,280`& 5,645' Depth 14 ITSTTmnon No. (MD) ID OD Item illfill g a 353' 3.812 6.90 TRMAXX-5E SSSV h b 387' 3.958 8.312 Hydroset II Packer w/Vent valve c 404' 3.812 5.20 X-Nipple 2,152' 3.833 5.980 7 X SMOR-1A ►, A„ 3,155' 3.833 6.410 2 X SMO 1 GLMGLM O' 3,761' 3.833 6.410 2 X SMO-1 GLM L..... 4,307' 3.833 5.980 7 X SMOR-1A GLM , " Hole in d 4,918' 3.833 5.980 7 X SMOR-1A GLM casing _ 8 202 5,529' 3.833 5.980 7 X SMOR-1A GLM g 208' 6,142' 3.833 5.980 7 X SMOR-1A GLM ♦ IM- DD 6,816' 3.833 5.980 7 X SMOR-1A GLM E *M/ IMA 7,297' 3.833 5.980 7 X SMOR-1A GLM G e 7,507' - 6.78 Discharge,Bolt-On 3 11/08:Holes F 7,509' - 6.75 Pump(x2)45 Stage,SH16000 4in tbg g 7,546' - 6.75 Intake 'i 8373',8376', 5-9 and 8406'. h 7,564' - 7.25 Motor(x2)BHI 725,550 I 7,619' - 5.62 Anode/Centralizer 10 Upper Scab Liner Assembly A 7,799' 6 8.218 Packer,9-5/8"Baker Mod.F(DP set) hid :kat_ A-1 I I B 7,895' 4.892 5.5 Crossover,7"Buttress Box x 5-1/2"15.5#Hydril Pin A-2 C 8,338' 4.375 5.63 Seal assembly,5" Located in 5'Upper PBR 11 D 8,349' 4 5.5 Anchor,Baker Mod.E-22 12 E 8,350' 4 5.875 Packer,7" x 4",Baker Mod."FA" G-2,3,4 - F 8,354' 4.5 5.53 Millout Extension,4'Long w/4ea.1"Holes 10/5/10: 4 10,625'- G 8,357' 4 5 Lower Seal Bore Extension,14'Long 2.70"GR - H-0 10627' 4 8,372' 2.992 5.57 Crossover,5"LTC Box x 3-1/2"Butress Pin tagged up Sqz.200 at 10825'. \\44, H-1 sx 5 8 400' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch H-2 6 8,802' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch ,� 7 9,234' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch �/ I Ratty 8 9,636' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch cement II x above 9 10,007' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch H-3 10,802' 10 10,053' 3 4 Locator,Seal Assembly III 11 10,093' 2.813 3.88 Otis,'X'Nipple,2.813 IV : -' : � - • 12 10,126' 2.992 3.865 Wireline Entry Guide V x " A-1 10,055' 4 5.875 Packer,7",Baker Mod."FB-1" (DP set-WL Correlated) A-2 10,058' 4 5 Seal Bore Extension VI ' H-4 Fill Cleaned Lower Scab Liner(DP set-WL Correlated) , ontto 1t,o9t' I 10,835' 4 5.87 Baker Packer 0 II 10,860' 2.813 3.88 'X'Nipple(2.813"),3-1/2"Buttress III 2.992 3.5 Scab Liner,3-1/2",9.2#,L-80,Buttress IV 10,920' 4 5.872 Baker Packer,Mod.F-1 44- V 10,948' 2.75 3.87 `XN'Nipple(2.75"),3-1/2"Buttress H-5 VI 10,960' 2.992 3.865 Wireline Entry Guide 0 ?*10 PBTD=11,415' TD=11,506' MAX HOLE ANGLE=39.75° See Next Page for Perforation Information. / Revised By:JLL 02/20/15 SCHEMATIC Dolly Varden . II Well No. D-25RD Hilrnrp Alaska,LLC Completed: 01/20/2015 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979;SQZ 1/17/1979,5021/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978;SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978;SQZ 12/6/1978 6-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 6-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 6-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 6-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 6-6 10,590' 10,593' 9,285' 9,288' 3/5/1973;502 3/7/1973 6-6 10,625' 10,627' 9,313' 9,314' 1/16/1979;SW 1/17/1979 6-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989;11/25/1989;3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 6-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB-1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB-1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB-1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB-1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB-1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB-1 10,727' 10,742' 9,392' 9,404' 3/8/1992 118-1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB-2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB-2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB-2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB-3 10,865' 10,880' 9,501' 9,513' 1/9/1989;11/25/1989;1/9/1998 HB-3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973;11/13/1985 HB-3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB-3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB-3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB-3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB-3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB-3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB-3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB-3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB-3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB-4 11,030' 11,050' 9,632' 9,647' 1/9/1989;11/25/1989 HB-4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB-4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB-4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB-4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB-4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB-4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB-4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB-4 11,053' 11,060' 9,650' 9,655' 3/2/1991 H8-4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979;11/13-17/1985 HB-4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB-4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB-4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB-4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB-4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB-4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 H8-4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB-4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB-4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB-4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB-4 11,110' 11,130' 9,695' 9,711' 1/9/1989 H8-4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB-4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB-4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB-5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB-5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB-5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB-5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB-5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB-5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB-5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By:JLL 02/20/15 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date •End Date D-25RD 507332024701 178-087 1/14/15 1/23/15 Daily Operations: 01/14/15-Wednesday Service rig and perform safety and compliance check. Fill out JSA and work permit, attend morning safety meeting. Check all connections on surface lines and fill up same w/8.5 PPG FIW. Spot equipment on deck, start rigging up slickline. Test surface lines to 2500 PSI test good. Finish rigging up slickline stand by for rig ops. Bull head 8.5 PPG FIW down tbg ICP= 35 PSI @ 1 BPM FCP 1060 PSI @ .5 BPM total BBLs pumped 83 BBLs. Rig up on well head flange up and run lubricator to rig floor. Install companion flange on tree and rig up lubricator. Pick up lubricator and tools make up 3.5" K kick over tool and ML pulling tool/stab on well test lubricator to 250 PSI low 2500 PSI high. Valve stem leaking on swab valve. Bleed off pump grease in valve. Pressure test same.Test good. Test lubricator to 2500 PSI stem leaking on crown valve on tree production, repair same. Retest lubricator to 2500 PSI test good. RIH had trouble locating side pocket mandrel finally latch @ 472' wlm. Attempt to latch valve and pull tool. Slipped off, POOH. RIH w/2.75" K Kick over tool tag @ 472' SLM. Latch GLV POOH w/same. Close in tree, bleed off press on lubricator, break lubricator. No GLV scale on tool. POOH, tool sheared and paraffin on tools. Repin tool. RIH tried to locate pocket on several passes. Latch valve @ 472' wlm. Repin kick over tool & RIH w/same.Tag 472' SLM. Latch GLV and POOH w/same. POOH. Retrieve valve. Secure well. Repin valve. Stand by for rig ops. Bull head down tbg ICP= 115 PSI @ .5 BPM FCP= 0 @ 1 BPM total BBLs pumped = 100 BBLs. Monitor well, ok. RIH w/slickline to 472' SLM set 4 string 3.5" K-Kick over tool. POOH, rig down slickline. Monitor well 5 PSI on tbg. Rig up high pressure line to top of tree. Pump 3.7 BBLs inlet water down tbg, 710 PSI bleed down tbg pressure 15 PSI. Pump 1 BBL pressure 1050 PSI, bleed down tbg pressure 25 PSI. Pump 2 BBLs pressure 400 PSI bleed down tbg pressure 25 PSI. Monitor well while building 8.7 LB inlet water. Pump 20 BBLs monitor well.Tbg on vacuum. Set BPV and prepare well head. Nipple down tree and set in well_b ay._Install riser. Nipple up wing valves. Install 3' riser. Install BOPs, accum lines, tighten BOP bolts on stack. 01/15/15-Thursday CONT TIGHTENING BOP BOLTS ON STACK. INSTALLED POLLUTION PAN ON BOPS. INSTALLED BARRICADE AROUND BOP AREA. INSTALLED FLOOR PLATE AND REMOVED BARRICADE. MADE UP 4.5"TEST JOINT AND LANDED SAME IN HNGR WHILE RIGGING UP TEST MANIFOLD. FILL SURFACE LINES AND ATTEMPT TO PERFORM SHELL TEST. PRESSURED UP TO 2500 PSI. PRESSURE FELL OFF TO 0 PSL ATTEMPT TO PRESSURE BACK UP, NO SUCCESS. ATTEMPT TO OPEN BLEED OFF AND BACK OUT TEST JT, NO SUCCESS DUE TO GAS IN TEST JT AND STACK. PUMPED 20 BBL 8.7#WEIGHTED FIW THRU HNGR TOP TO FLUSH OUT_BPV-AND DISPLACE GAS OUT, PUMPING 3/4 BPM 360 PSI. SHUT DOWN PUMP PRESS=0. PULL TEST JT- INSPECT THREADS, OK.TEFLON THREADS AND MAKE UP TEST JT IN HNGR. ATTEMPT TO PERFORM SHELL TEST, NO SUCCESS. PULL TEST JT WHILE MAKING UP DRY ROD. ATTEMPTED TO PICK UP DRY ROD WI HOIST. ROD BROKE IN BEAVER SLIDE. SENT ROD TO WELDING AREA AND WELDERS REPAIRED SAME. PULL BPV. SET 2-WAY CHECK. FILL STACK W/8.7. CLOSED BLINDS&ATTEMPTED TO PRESSURE UP, NO SUCCESS. PULL 2-WAY CHK. INSTALLED BPV & RIGGED UP CIRC HOSE TO 9-5/8 CSG VALVE. PUMPED DOWN CSG @ .5 BPM 0 PSI GETTING GAS BACK IN STACK (THRU HNGR). SHUT DOWN PUMP. SECURED WELL AND RIGGED DOWN 4.5 "TEST JOINT WHILE REP REPACKS VOID IN HNGR. ATTEMPTED TO ADD PACKING MATERIAL IN VOID ON HANGER. IT WAS FULL. R/D 4 1/2" TEST 1NT. R/U 3 1/2"TEST JNT WI SIDE ENTRY& TIW.ATTACHED CIRC LINE. RECEIVED PERMISSION TO PERFORM ROLLING BOPE TEST FROM MR.JIM REGG WI AOGCC. MR.JOHNNIE HILL WI AOGCC ONBOARD. FIRST TEST FAILED DUE TO SURFACE LEAK. GREASED&WORKED ALL SURFACE VALVES. PERFORMED ROLLING BOPE TEST ON HYDRIL& INSIDE WINGS PUMPING 10 SPM 250 PSI FOR LOW TEST- 68 SPM 2500 PSI FOR HIGH TEST. SWITCHED TO PIPE RAM AND OUTSIDE WINGS AND TESTED GOOD. MAX PRESSURE ON 9 5/8" WAS 1400#S. R/U AND TESTED CHOKE MANIFOLD & 3 1/2" SAFETY VALVES 250 PSI/ LOW 2500 PSI/ HIGH AS PER HILCORP &AOGCC PROCEDURES. - Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 178-087 1/14/15 1/23/15 Daily Operations: 01/16/15- Friday FINISHED TESTING CHOKE MANIFOLD AND TIWs AS PER HILCORP &AOGCC SPECS 250 PSI LOW 2500 PSI HIGH. PULLED 3.5" TEST JOINT AND ASSISTED REP PULLING BPV AND SETTING 2-WAY CHECK. PERFORMED_IGU NG Bb's-TEST-ON BLIND RAMS AND INSIDE MANUAL WING VALVES PUMPING 10 SPM 250 PSI 68 SPM 2500 PSI. ASSISTED REP PULLING 2-WAY CHECK. MADE UP LANDING JOINT INTO HANGER. RIGGED UP CIRC HOSE & BULL HEADED 1 TBG VOL. ASSISTED REP BACKING OUT HANGER PINS. P/U ON STRING UNSEATTING HANGER AT 110K. CONTINUED PICKING UP PIPE 10 FT NEVER SEEING A PKR SHEAR (AT 443'). R/U TO BULLHEAD DOWN BACKSIDE. PUMPED DOWN ANNULUS AT 1/2 BPM WITH PRESSURES VARYING. ATTEMPTED TO INCREASE RATE BUT PKR WOULD SEAL OFF CAUSING US TO HAVE TO WORK PIPE TO RELAX PKR ELEMENT. PUMPED A TOTAL OF 32 BBLS DOWN ANNULUS W/A FCP @ 235 PSI. SHUTDOWN PUMP AND PRESSURE FELL TO ZERO. WELL ON VACUUM. PULLED HANGER TO RIG FLOOR. CUT AND SECURED CABLES AND LINES FROM HANGER TO 1ST FULL JNT OF TB. BACKED OUT HANGER AND SECURED WELL W/SV. LAID DOWN HANGER AND LANDING JOINT. MADE UP TEST PLUG ONTO PRODUCTION STRING AND LANDED SAME IN TB HEAD, P/U 98K S/O 70K. RIGGED UP TO TEST BOPs. TESTED HYDRIL&VAR RAMS WITH 3 1/2" &4 1/2"TEST JNT.TESTED 4 1/2" TIW.TESTED HIGH PRESSURE HOSES FOR CHOKE &CIRC MANIFOLD.TESTED BLIND RAMS, 250 PSI LOW& 2500 PSI HIGH TO HILCORP & AOGCC PROCEDURES. WITNESSED AND APPROVED BY MR.JONNIE HILL W/AOGCC. PULLED 4 1/2" TEST JNT. LAYDOWN SAME.R/U 3 1/2" LANDING JNT AND SCREWED INTO TEST PLUG. PULLED AND LAID DOWN SAME. STARTED POOH WITH 3 1/2" L-80 9.2#SUPERMAX PROD TBG, PKR & ESP ASSM UNTIL THERE WAS ENOUGH CABLE TO STRING UP. HUNG SHEAVES AND CONTINUED PULLING ASSM. 01/17/15 -Saturday SERVICED RIG AND PERFORMED SAFTEY AND COMPLIANCE CHECK. CONT POOH W/3.5" SUPERMAX TBG, POWER CABLE, FLAT PACK AND CHEMICAL INJECTION LINES (CLEANING PIPE AND LINES WITH STEAM CLEANER. PUMPING DISPLACEMENT TIMES 2 EVERY 10 JTS). LAID OUT SSSV AND BAKER 51A6 TWIN SEAL PKR ALONG WITH ASSOCIATED HARDWARE. CONTINUED POOH WITH PRODUCTION STRING. ASSISTED IN CUTTING CABLES AND LINES TO SWITCH SPOOLING REELS. INSTALLED SAFETY VALVE AND PUMPED 2 BPM F/30 MINS DOWN ANNULUS IN EFFORTS TO CLEAN PIPE AND CABLE (ANNULUS ON VACUUM). CONTINUED POOH WITH PRODUCTION STRING. RIGGED UP CIRCULATING HOSE AND PUMPED TB VOLUME @ 1 BPM 70 PSI IN EFFORTS TO FLUSH OIL(TB ON VACUUM). R/D HOSE. CONTINUED POOH W/3 1/2" SUPERMAX PROD TB, FLAT PACK, CHEM LINES AND ESP ASSM. WASHING PIPE WITH PRESSURE WASHER. HAD TO STOP SEVERAL TIMES TO FLUSH OIL FROM ID OF TB. 01/18/15 -Sunday SERVICED RIG AND PERFORMED SAFTEY AND COMPLIANCE CHECK. CONT POOH W/3.5 SUPERMAX PRODUCTION TBG AND ESP. CLEANING AND INSPECTING, LINES, CABLES & PIPE FOR DAMAGE WHILE PULLING OUT HOLE. ASSISTED IN LAYING DOWN ESP. HILCORP REP SUPERVISING DISSASSEMBLY& LAYDOWN. RIGGED DOWN EUIPMENT. CLEARED AND CLEANED RIG FLOOR AND PIPE RACK. N/U SHOOTING NIPPLE WHILE SPOTTING S/L EQUIP. IN PLACE. R/U S/L. M/U RS, SWIVEL, 1 3/4" STEM X 2, KNUCKLE, OIL& SPANG JAR, #25 JUNK BASKET W/8.32" GAUGE RING. TESTED LUB 500 PSI AGAINST BLINDS. RIH WITH JUNK BASKET TO 4,760' (SLM)TAKING WEIGHT. STOPPED & POOH (RECOVERED SMALL PIECES OF METAL& RUBBER FROM FLATPACK CABLE). RIH WITH SAME TO 7,800' (SLM- NO PROBLEMS) POOH (RECOVERED METAL IN JUNK BASKET). M/U 3" CENTRALIZER W/2.2" SWEDGE ON STEM &JARS. RIH TO 8,260' (SLM) SET DOWN. POOH. R/D M/0 S/L. CHANGED OUT DERRICK FINGERS FROM 3 1/2" TO 4 1/2" & OFFLOAD REMAINDER OF 4 1/2" TBG F/WORK BOAT. M/U 4 1/2" COLLAR ON BOTTOM OF FIRST JNT&START RIH W/4 1/2" 12.6# L-80 SUPERMAX PRODUCTION TBG. STRAPING & DRIFTING SAME. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 178-087 1/14/15 1/23/15 Daily Operations: 01/19/15 - Monday SERVICED RIG AND PERFORMED SAFTEY AND COMPLIANCE CHECKS. CONT TIH W/4.5 SUPERMAX PRODUCTION TBG PICKING UP F/ BEAVER SLIDE STRAPING AND DRIFTING SAME. ASSISTED CRANE CREW MOVING BUNDLES OF PIPE FROM WEST PIPE RACK TO EAST PIPE RACK. CONT TIH W/4.5 SUPERMAX PRODUCTION TBG PICKING UP F/ BEAVER SLIDE STRAPING AND DRIFTING SAME.TIH WI 220 TOTAL ITS. P/U 81K, S/O 70K. CIRC WELL VOL @ 3 1/2 BPM 143 PSI TAKING RETURNS TO TRADING BAY @ ONE WELL VOL. STILL GETTING A LOT OF OIL BACK. CONTINUE CIRC A HALF WELL VOL. R/D CIRC HOSE &START POOH W/4 1/2" SUPERMAX PROD TBG RACKING BACK IN DERRICK. 01/20/15-Tuesday SERVICED RIG AND PERFORMED SAFTEY AND COMPLIANCE CHECKS. FINISHED POOH WI 110 STANDS OF 4.5" SUPERMAX PRODUCTION TB RACKIING BACK IN DERRICK. HELD JSA. M/U ESP PUMP ASSY& R/U SHEAVES IN DERRICK. FINISH M/U ESP PUMP ASSY. HOOK UP POWER LEAD INTO UPPER MOTOR ( INTAKE PSI 47, TEMP INTAKE 57.7, PRESSURE DISCHARGE 55.1, MOTOR TEMP 59.5, VIBRATION X .6, LINE VOLTAGE 35.5,VIBRATION Y .05, CURRENT LINK 6.5, MA PHASE TO PHASE 1.9, PHASE TO GROUND 5.37, MOTOR LEAD PLUGED IN AT SURFACE ). R/U PUMP#1, PUMP#2. R/U PORTED PRESSURE SUB & DISCHARGE. TIH W/4 1/2" 12.60#SUPERMAX PROD TBG FROM DERRICK INSTALLING CLAMPS ON TB AS NEEDED TO CONTAIN LINES. STOPPING EVERY 1,000'TO CHECK FLAT PACK WIRE (OK). 01/21/15 -Wednesday SERVICED RIG AND PERFORMED SAFETY COMPLIANCE CHECKS. CONTINUED TIH W/6 3/4" ESP ASSY, CABLE AND FLAT PACK ON 4 1/2" 12.60#SUPERMAX TB INSTALLING CLAMPS EVERY JT FOR THE 1ST 75 STANDS THEN EVERY OTHER CONNECTION.TESTING CABLE AND FLAT PACK EVERY 1,000'. AT 4,929' ELECTRICAL CABLE REEL WAS SWAPED OUT REQUIRING SPLICE TO BE MADE ON MOTOR CABLE. TESTED GOOD. CONTINUED TIH WI ESP ASSY ON SUPERMAX PROD TBG. CHECKING CABLE AND FLAT PACK AS BEFORE. P/U 9-5/8" DUAL STRING HYDRALIC SET PACKER WI VENT. CUT POWER CABLE. RAN CABLE THRU PKR & INSTALL PLUG ON SAME. SWAP POWER CABLE REEL. SPLICE CTRL LINES THRU PKR &CONNECT CTRL LINE TO VENT. TEST ALL LINES/CABLES "OK". P/U SSSV. M/U CTRL LINE &TEST SAME. CONT'TO TIH W/4.5" SPRMX PROD TBG, ESP, CABLE & CTRL LINES. ASSIST REPS INSTALL CANON CLAMPS AS NEEDED &CHECKING (TIH TI 7,576'TBGM). P/U HANGER. M/U & ORIENTATED SAME. ASST. REPS CONNECT&TEST CABLES/LINES AS NEEDED. R/D CTRL LINE & POWER CABLE SHEAVES. P/U LANDING JNT& M/U SAME. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 178-087 1/14/15 1/23/15 Daily Operations: 01/22/15 -Thursday SERVICED RIG AND PERFORMED SAFETY COMPLIANCE CHECKS. M/U LANDING JT AND TIW IN HGR. FILLED HOLE W/8.5# FIW,48 TOTAL BBLS PUMPED. LANDED HGR AND ASSISTED RUNNING IN HGR PINS. PACKED OFF HGR VOID. R/U S/L EQUIPMENT W/ FULL LUBRICATOR. M/U 2" RB TOOL AND PX PRONG, TESTED LUBRICATOR TO 3500 PSI. RIH W/S/L TO 400' (SLM)AND SET/LANDED PRONG. PRESSURED UP TO 3300 PSI ON TBG AND SET HYDROSET II PKR AT 387' AS PER REP. R/U HOSES TO CSG VALVE AND PRESSURED UP TO 1500 PSI ON CSG, LEAKED OFF. CHECKED ALL SURFACE EQUIPMENT FOR LEAKS. PRESSURED TO 1500 PSI ON CSG. LEAKED OFF AGAIN. LINED UP ON TBG & PRESSURED UP TO 3500 PSI, HOLD FOR 30 MINS TO ENSURE PACKER SET AS PER REP. PRESSURED UP ON CSG TO 1500 PSI FOR 30 MINS ON CHART DATED 1-22-2015. POOH W/ 2" RB TOOL AND PX PRONG. M/U 4" GS PULLING TOOL AND RIH W/SAME. POOH W/SL. L/D TBG PLUG &TOOLS. R/D LUBRICATOR & EQUIPMENT. B/0 LANDING JNT F/ HGR & L/D SAME. ASST REP SETTING BPV. BLEW DOWN ALL CIRCULATING LINES W/AIR. BLED OFF ACCUM UNIT. R/D POLLUTION PANS. N/D 11" X 5M RISER SPOOLS, HYDRIL, DBL STACK RAMS, CHOKE & KILL WING VALVES, FLOW CROSS AND RISOR SECTION. ASST REP PREPARING TOP OF HGR&CTRL LINES FOR TREE. N/U PRODUCTION TREE &TEST VOID TO 5000 PSI F/ 15 MINS. R/D MISC HOSES FROM WELL BAY. R/D LINES FROM MUD PUMPS&TRANSFER PUMPS. CLEAR WATER FROM PUMPS. R/D CHOKE MANIFOLD, GAS BUSTER, EXPRO CHOKE &OTHER MISC EQUIPMENT IN PREPARATIONS FOR RIG MOVE. 01/23/15- Friday RIG DOWN MISC RIG EQUIPMENT& COMPONENTS IN PREPARATION FOR RIG MOVE. TURNED OVER TO PRODUCTION TO PROGRAM ESP TO TEST RUN SAME. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, December 30, 2014 9:49 AM To: 'Dan Marlowe' Cc: Ted Kramer, Juanita Lovett; Daniel Taylor; Trudi Hallett Subject: RE: D-25RD Sundry 314-558, PTD 178-087 Dan, Modification of completion to use the packer vent valve is approved (replaces GLM under packer to recombine gas). Similar system is in use by Cealus for their ESP completions on North Slope. ScSSV and packer vent valve share common hydraulic line to activate valve closure simultaneously. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aov). From: Dan Marlowe[,,nailto:dmarlowe(abhilcorp.com] Sent: Monday, December 29, 2014 1:40 PM To: Schwartz, Guy L (DOA) CC: Ted Kramer; Juanita Lovett; Daniel Taylor; Trudi Hallett Subject: D-25RD Sundry 314-558, PTD 178-087 Guy We have revised the completion design on this one to give ourselves a backup production option. Let me know if you have any questions thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(c-).hilcorp.com Hilcorp A Company Built on Energy 1 SCAyNED JAN U 5 2015 E 3- 4- 5-9 10 11 C d e Holes in casing 3,280`& 5,645' I1SIT run on B Hole m casing 8,202'- 0 8,208' •D .17 G 11/08: Holes in tbg 8373', 8376', and 8406'. 12 Ifs OD Item PROPOSED ±417' Dolly Varden 61 K-55 10/5/10: Well No. D-25RD ifilleo m klaska. LU, 10,625'- 2.70" GR Completed: Future H-0 10627' CASING DETAIL Tree connection: 4-1116" 5,0006 SIZE WT GRADE CONN ID TOP BTM a H-1 sx 7,938' E 3- 4- 5-9 10 11 C d e Holes in casing 3,280`& 5,645' I1SIT run on B Hole m casing 8,202'- 0 8,208' •D .17 G 11/08: Holes in tbg 8373', 8376', and 8406'. PBTD =11,415' TD =11,506' MAX HOLE ANGLE = 39.75" 12 Ifs OD Item -2 3 4 , ±417' 13-3/8" 61 K-55 10/5/10: 12.515 Surf 10,625'- 2.70" GR 47 H-0 10627' tagged up Surf 8,155' Sqz. 200 at 10825'. N-80 H-1 sx 7,938' 11,506' H-2 GLM -3-1/2" SFO -2 ±3,742' 3.5" GLM - 3-1/2" SFO -2 ±4,324' Ratty GLM - 3-1/2" SFO -2 cement GLM - 3-1/2" SFO -2 �) 493' above GLM - 3-1/2" SFO -2 111 ±6,140' H-3 10,802' GLM -3-1/2" SFO -2 N ±6,787' V GLM - 3-1/2" SFO -2 ±7,373' 3.5 GLM - 3-1/2" SFO -2 Vi H-4 Fill Cleaned Bottom of ESP Out to 11,091' Upper Scab Liner Assembly A 7,799' H5 8.218 n B PBTD =11,415' TD =11,506' MAX HOLE ANGLE = 39.75" TUBING DETAIL 4-1/, L-80 I Superma, I I Surf 1 ±7,585' Jewelry Detail No. Depth (MD) Ifs OD Item a ±417' 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 4-1/, L-80 I Superma, I I Surf 1 ±7,585' Jewelry Detail No. Depth (MD) Ifs OD Item a ±417' SSSV b ±443' Packer w/ Vent valve C ±460' X -Nipple ±2,130' 3.5" GLM - 3-1/2" SFO -2 ±3,160' 3.5" GLM -3-1/2" SFO -2 ±3,742' 3.5" GLM - 3-1/2" SFO -2 ±4,324' 3.5 GLM - 3-1/2" SFO -2 3.5" GLM - 3-1/2" SFO -2 493' 3.5" GLM - 3-1/2" SFO -2 ±6,140' 3.5 GLM -3-1/2" SFO -2 ±6,787' 3.5" GLM - 3-1/2" SFO -2 ±7,373' 3.5 GLM - 3-1/2" SFO -2 ±7,710' - Bottom of ESP Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PER D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 1 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 1 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 1 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 1 3.88 1 'X' Nipple (2.813"), 3-1/2" Buttress See Next Page for Perforation Information. Revised By: JLL 10/10/14 THE STATE of�A GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska GES and 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-25RD Sundry Number: 314-558 Dear Mr. Marlow: 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. DATED this /� day of October, 2014. Encl. Sincerely, Cathy P Foerster Chair VC 22 2014. RECEIVED STATE OF ALASKA OCT 13 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 4"9 /Of /S/ / 4` APPLICATION FOR SUNDRY APPROVALS �OGC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Q Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Replace ESP ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 178-087 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20247-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit D-25RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018729 I McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools ' 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): 11,510 •10,021 - 11,415 - 9,941 11,290 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic • See Schematic 3-1/2" 9.2# / L-80 7,618 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packers (see schematic) / SSSV Packers (see schematic) / SSSV - 417' (MD) 417' (TVD) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0. Exploratory ❑ Stratigraphic [I Development 2], Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/15/2014 Oil Ell Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(Whilcorp.com Printed Name Dan lowe Title Operations Engineer Signature Phone (907) 283-1329 Date 10/13/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S Plug Integrity ❑ BOP Test 2 Mechanical Integrity Test ❑ Location Clearance ❑ Other: -2—SOO P5L 86/ /c.S C 11 &4s : 6`!v Spacing Exception Required? Yes ❑ No d Subsequent Form Required: Yo`( APPROVED BY COMMISSIONER THE COMMISSION Date: Approved by:a�41 / `0 ( _ JG Submit Form and Form 10-403 (Revised 10/ 012) QjZd 411NAd[or 12 months from the date of approv`dl. Attachments in Duplicate ROE MS OCT 2 0 201 Hilcorp Alaska, LLC WO Work Prognosis Well: D-25rd Date: 10/10/14 Well Name: D-25rd API Number: 50-733-20247-01 Current Status: ESP Producer Leg: Leg #A-1 (NE corner) Estimated Start Date: November 15, 2014 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 178-087 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)-777-8420 (0) (985)-867-0665 (M) AFE Number: Budgeted Cost: Current BHP: 2,830 psi @ 7,738 MD / 6,919' TVD Measured pressured at ESP Max. Expected BHP 2,830 psi @ 7,738' MD/ 6,919 TVD Measured pressured at ESP Max. Anticipated Surface Pressure: -690 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b) (4) Brief Well Summary D-25rd is a G -Zone and Hemlock Producer that was converted to an ESP from a gas -lift completion in 2012. The ESP experienced a down failure September 16, 2013 and was replaced in July of 2014. The well then could not pass a no -flow so a high set packer and SSSV were installed in August 2014. During this latest work - over it appears that we damaged the pressure sensing line on the ESP discharge resulting in a washout requiring us to pull and replace the equipment. Casing last pressure tested on 06/07/12 to 1,500 psig charted for 37 minutes @ 7,233'. . Prnrarh ira- 1. MIRU HAK #1 Work -over rig. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production and kill well. 3. ND Wellhead, NU BOP and test to 250psi low /2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). - 4. Pull failed ESP assembly 5. RIH with new ESP assembly �— A 6. Land ESP with the bottom of the assembly at +/- 7,710'. --� cs 7. ND BOP, NU wellhead and test. (> 8. Turn well over to production. Attnrhmantc- 1. Current Wellbore Schematic 2. Current Wellhead Diagram 3. Proposed Wellbore Schematic 4. Proposed Wellhead Diagram (same as current) 5. BOP Drawing Hilcorp Alaska, LLC Tree connection: 4-1/16" 5,000# 'ra � c d Holes in casing e 3,280`& f g 5,645' TTSTT nm on h i 1 12 B Hole in G-2, 3, 4 ID TOP casing 1Q 625'- 2.70" GR 8,202'- tagged up 0 8,208' H-1 sx D H-2 E Butt I Ratty o F cement 3 G 11/08: Holes 4 IV in tbg V x Crossover 8373', 8376', 5-9 - and 8406'. 10 g 7,623' - r A-1 Pump (x 2) - 45 Stage, SH 12000 h A-2 - 11 Seals 1 12 WT GRADE G-2, 3, 4 ID TOP 10/5/10: 1Q 625'- 2.70" GR H-0 10627' tagged up Sgz.200 at 10825'. H-1 sx 9-5/8" H-2 P-110 Butt I Ratty 8,155' cement II x above III H-3 10,802' IV 11,506' V x Crossover SCHEMATIC Dolly Varden Well No. D-25RD Completed: 08/29/2014 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Supermax 1 2.992 1 Surf 1 7,618' Jewelry Detail No. Depth ID OD Item a 417' 5.46 5.375 Baker TE -5 SSSV b 443' 2.992 8.44 Baker 53A6 Twin Seal Packer C 460' 2.810 4.50 X -Nipple d 470' 2.992 SFO -1 GLM, RO-15/16" orifice, BK -2 Latch e 7,618' 2.992 5.00 Crossover f 7,621' - 5.13 Discharge, Head Bolt -On g 7,623' - 6.75 Pump (x 2) - 45 Stage, SH 12000 h 7,666' - 5.13 Seals 1 7,684' - 5.62 Motor (x 2) - 562 Series, 340 HP j 7,748' - - Anode Centrilizer Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8400, 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 j 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis,'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: 1LL09/29/14 SCHEMATIC Dolly Varden uVell No. D-25RD Idc,r„ Alaska, LLC Completed: 08/29/2014 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 71315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989;3/2/1991 G-7 1 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 1 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985; 3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989;11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 1 11,080' 11,200' 9,671' 9,768' 2/18-19/1973; 3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By: JLL 09/29/14 PROPOSED Dolly Varden Well No. D-25RD Hilcorn Alaska, LLC Completed: Future CASING DETAIL Tree connection: 4-1/16" 5,000# 15L b c Hales in casing 3,280`& 5,645' 1 iS1T run on e 10 A-1 A-2 i 12 B GRADE G-2, 3, 4 ID TOP 10/5/10: 10,625'- Hole in H-0 10627' tagged up casing at 10825'. sx 8,202'- H-2 0 8,208' I D 8,155' E II x above III o F IV 3 G 11/08: Holes 4 in tbg Upper Scab Liner Assembly 8373', 8376', 5-9 6 and 8406'. 10 A-1 A-2 i 12 WT GRADE G-2, 3, 4 ID TOP 10/5/10: 10,625'- 2.70" GR H-0 10627' tagged up H-1 Sqz. 200 at 10825'. sx 9-5/8" H-2 P-110 Butt I Ratty 8,155' cement II x above III H-3 10,802' IV 11,506' V y Bottom of ESP u VI H-4 Fill Cleaned Out to 11,091' 71 .......... H-5 PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 4-1/2" 1 12.6 L-80 I Supermax I I Surf 1 ±7,585' Jewelry Detail No. Depth ID OD Item a ±417' SSSV b ±443' Packer t/ c ±460' X -Nipple d ±470' GLM e ±7,710' - - Bottom of ESP Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) I 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 1 Wireline Entry Guide See Next Page for Perforation Information. Revised By: AL 10/10/14 PROPOSED Dolly Varden Well No. D-25RD Iilcorp Alaska, LLC Completed: Future Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB' -1 10,726' 10,741' 9,392' 91403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 91517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989;11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' _ 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 1 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HBA 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB -0,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By: ILL 10/10/14 Dolly Varden D-25RD 133/8X95/8X41/2 Valve, swab, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 4 1/16 5M FE, HWO, T-24 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom, Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO, CA slips installed in head BHTA, Bowen, 4 1/16 5M FE X 7" stub acme Dolly Varden Platform D-25RD Current 04/10/2014 Tubing hanger, CIW-DCB- ESP, 11 X 4 % IBT lift and susp, w/ 4" type H BPV profile, 5'/4 EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Cross, stdd, 4 1/16 5M X 3 1/8 5M X 2 1/16 5M Valve, WKM-M, 3 1/8 5M FE, w/ MA -16 operator Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 % ESP neck, 2- % npt continuous control line ports Valve, WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim xilverp Almoko. LK Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 9 2014 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Othe s a ac er/SSSV Equip. Performed: Alter Casing ❑ Pull Tubings] Stimulate - Frac ❑ Waiver ❑ Time Extension F1 Change Approved Program ❑ Operat. Shutdown[-] Stimulate - Other ❑ Re-enter Suspended Well[-] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development lw Exploratory ❑ Stratigraphic❑ Service ❑ 178-087 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20247-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 Trading Bay Unit D-25RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,510 feet Plugs measured feet true vertical 10,021 feet Junk measured 11,290 feet Effective Depth measured 11,415 feet Packer measured See Schematic feet true vertical 9,941 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 7,618' (MD) 6,818' (TVD) Packers and SSSV (type, measured and true vertical depth) Packer: See Schematic SSSV: 417' (MD) 417' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A q OCT 16, 4014. Treatment descriptions including volumes used and final pressure: SCANNED N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 181 109 11074 90 200 Subsequent to operation: 82 67 7672 206 144 14. Attachments: 15. Well Class after work: ^ Copies of Logs and Surveys Run Exploratory❑ DevelopmentE] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil [2) Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-466 Contact Dan Marlowe Email dmarlowe(ahilcorp.com Printed Name Dan Marlowe Title Operations Engineer i Signature Phone (907) 283-1329 Date 9/29/2014 lo- 71Y_ RBEMS OCT - 1 20'kForm / 10-404 Revised 10/2012 /j � �F�l�� Submit Original Only SCHEMATIC Dolly Varden Well No. D-25RD Hilcorp Alaska, LLC Completed: 08/29/2014 CASING DETAIL Tree connection: 4-1/16" 5,000# a b Inc a ' Holes in casing e 3,280`& f g 5,645' IISTT nm nn h i 1 10 A-1 A-2 11 12 B Hole in G-2, 3, 4 ID TOP casing 10,625'- 2.70" GR s,2o2'- tagged up � 8,208' H-1 sx D H-2 E Butt I Ratty o F cement 3 G 11/08: Holes 4 IV in tbg V Crossover 8373',8376' 5-9 - and 8406'. 10 A-1 A-2 11 12 WT GRADE G-2, 3, 4 ID TOP 10/5/10: 10,625'- 2.70" GR H-0 10627' tagged up Sgz.200 at 10825'. H-1 sx 9-5/8" H-2 P-110 Butt I Ratty 8,155' cement II x above III H-3 10,802' IV 11,506' V Crossover PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.750 SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Supermax 1 2.992 1 Surf 1 7,618' Jewelry Detail No. Depth ID OD Item a 417' 5.46 5.375 Baker TE -5 SSSV b 443' 2.992 8.44 Baker 51A6 Twin Seal Packer c 460' 2.810 4.50 X -Nipple d 470' 2.992 SFO -1 GLM, RO-15/16" orifice, BK -2 Latch e 7,618' 2.992 5.00 Crossover f 7,621' - 5.13 Discharge, Head Bolt -On g 7,623' 6.75 Pump (x 2) -45 Stage, SH12000 h 7,666' 5.13 Seals i 7,684' 5.62 Motor (x 2) - 562 Series, 340 HP j 7,748' - Anode Centrilizer Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: AL 09/29/14 SCHEMATIC Dolly Varden Well No. D-25RD Hi1�rv,�l,ekeI.I.0 Completed: 08/29/2014 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978;SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978;SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 _ G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' _ 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973;SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979;5QZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989;3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979; 7/24/1981; 1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 11,030' 1 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 1 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 1 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -0,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -0,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -511,200- 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By: JLL 09/29/14 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 1 178-087 1 8/26/14 8/29/14 Daily Operations: 08/26/14 -Tuesday DISPL WELL DOWN CSG, TAKING RETURNS UP TBG TO TRADING BAY @ 3-1/2 BPM 200 PSI W.8.5# F.I.W. TOTAL BBLS PUMPED 522 bbls. Bullhead 100 BBLS 8.5# F.I.W. Down 9 5/8" csg @ 4.0 BPM 250 psi. ( Monitor Well Static). Install B.P.V. & N/D Tree. N/U Riser, BOPE, Wing Valves, Spacer Spool, Hook Up Koomey Hoses & Pressure Up Koomey Unit. Install Pollution Pans, Floor Beams & Floor Plates Getting Rig In Compliance. P/U & M/U Test Jt. & Assy. Rig Up Test Manifold. 08/27/14 - Wednesday SERVICE RIG AND PERFORM SFTY AND COMPLIANCE CHK. TEST 11" 5M BOPE AND SURFACE 250 LOW AND 2500 HIGH A$ PER AOGCC & HILCORP SPECS.WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. PERFORM KOOMEY TEST & RIG DOWN TEST EQUIP. PULL 2 -WAY CHK AND M/U LANDING JT. SPOT EQUIP ON DECK. B/O HNGR PINS. PULL HNGR TO R/F. P/U WT. 85K. UNDRESS HNGR & L/D SAME. POOH W/ 366' OF 3 1/2" SUPER MAX TBG RACKING BACK IN DRK SPOOLING UP CNTRL AND ELEC CABLE. HELD PREJOB SFTY MTG W/ CREW. SERVICE RIG. P/U PACKER ASSY & RIH W/ SAME. TEST ESP CABLE (OK). CUT SAME. SPLICE PACKER FEED FOR ESP. R/U SHEAVES IN DERRICK. TEST CHEMICAL INJECTION LINE & ESP LINES. CONT RIH W/ PACKER ASSY. R/U & MADE UP CONTROL LINE TO SSV. TEST SAME 2000 PSI "OK". CONT RIH W/ PACKER ASSY & 3.5 SUPER MAX PROD TBG. M/U HANGER & LANDING JT. BEGIN MAKING UP HANGER SPLICE. TOTAL FLUID LOSS = 252 BB LS. 08/28/14 - Thursday HPJSM W/ CREW AND PERFORM SFTY AND COMPLIANCE CHECK. M/U LANDING JT INTO HNGR. M/U 1/2" CNTRL INTO HNGR FOR SSSV & OPEN SAME / 5000 PSI. "OK". SPLICE FLAT PACK AND ELEC CABLE & R/D SHEAVES F/ DIRK. INSTALL CONNECTION ON ELEC CABLE. INSTALL ELEC LINE, FLAT PACK & SENCOR TO HNGR. TEST FLAT PACK TO 2500 PSI."OK". LAND HNGR. TEST HOLE MOTOR TEMP = 140.2, TEMP INTAKE = 139.8, PSI INTAKE = 2831, DISCHARGE PRESS =2829, CZ/ MA = 803, CLA/MA = 20-833, CIP/MA = 0, VIBRATE/G = 0, PHASE TO GROUND = 235. RUN IN HGNR PINS. INSTALL PROD TBG HGNR & TEST VOID TO 5000 PSI FOR 15 MIN."OK". R/U LUBRICATOR. M/U 2.80" GAUGE ON SLICK LINE. TEST LUBRICATOR TO 3000 PSI, "OK". RIH W/ 2.80" GAUGE RING ON SLICK LINE TO 460' SLM. POOH W/ SAME. M/U 2.813 X - LINE RUNNING TOOL W/ END PLUG TO 460' SLM. ATTEMPT TO SET PLUG, NO SUCCESS. POOH. POOH W/ PLUG & REDRESS PACKER. RIH W/ plug TO 460' SLM. ATTEMPT TO SET PLUG, NO SUCCESS. POOH. CLEAN & SERVICE RIG WHILE WATING ON WIRE LINE PLUG TO ARRIVE. M/U & RIH W/ PX PLUG ON SLICK LINE & SET PLUG @ 460' WLM. POOH. M/U 2.5 RB RIH TO 460' WLM. ATTEMPT TO PRESSURE UP TO 2500 PSI TO SET BAKER 9 5/8" PACKER WITH NO SUCCESS. POOH W/ 1.75" P - PRONG. RIH W/ 2.5" GS RETRIEVING TOOL TO 460' WLM. POOH W/ 2.8" PX -PLUG. CHANGE OUT PX -PLUG. RIH TO 460' WLM, SET PLUG IN XN nipple. POOH W/ SLICK LINE. M/U & RIH W/ 1.75 P -PRONG TO 460'. PRESSURE UP ON TBG W/ RIG PUMP & 8.5 F.I.W. TO 25Q0 PSI HELD FOR 3 MIN. BLED PRESS DOWN TO 1000 PSI. LINE UP ON 9 5/8" CSG. FILL BACKSIDE & PRESSURE UP TO 1500 PSI FOR 3 MIN. Pressured up on tbg to 3500 psi setting twin seal packer at 448' md. BLED OFF TBG & CSG. LINE UP ON 9 5/8" CSG & TEST SAME TO 1500 PSI ON CHART FOR 30 MIN."GOOD". POOH W/ 2.5 P -PRONG. RIH IN HOLE TO 460'W/ 2.5 RETRIEVING TOOT_ TO 460'& POOH W/ PX -PLUG. R/D SLICK LINE. L/D 4 1/2" LANDING JT. INSTALL BACK PRESSURE VALVE IN TBG HANGER. CLEAR & CLEAN WORK AREA. REMOVE FLOOR PLATES & BEAMS. R/D KOOMLY HOSES, N/D BOPE STACK. R/D POLUTION PAN. 08/29/14 - Friday Continue N/D 11" 5M Hydril, Double Ram & Wing Valve. Pull & L/D Riser. Prep Well Head. Install Adapter Flange On Well Head. Install Tree And N/U Same. Pull BPV And Install 2 -Way Check. Test Void To 5000 psi "OK". Test Tree To 5000 psi On Chart. Remove 2 -Way Check. Turn Well Over To Prod. @ 1400 Hrs. 4 THE STATE La GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska G-Jil 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pool, TBU D-25RD Sundry Number: 314-466 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this 6 day of August, 2014. Encl. Sincerely, P Cathy P Foerster Chair KANNED - STATE OF ALASKA 11S t ALASKA OIL AND GAS CONSERVATION COMMISSION q APPLICATION FOR SUNDRY APPROVALS 9n AAS ?r, ?Rn RECEIVED AUG 14 2014 Anter( 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 2 Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install Packer/SSV Equip. 0' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development (] Stratigraphic ❑ Service ❑ 178-087 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20247-01 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit D-25RD - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018729 I McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools . 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): 11,510 10,021 11,415 9,941 11,290 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft73-1'/2" ing Size: Tubing Grade: Tubing MD (ft): See Schematic , See Schematic 9.2# / L-80 7,583 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packers (see schematic) / SSSV - N/A Packers (see schematic) / SSSV - N/A 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q. Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/18/2014 Oil F1, Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer f�L- �� �fs�-i, �- Signature Phone 907 283-1329 Date 8/14/2014 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: A Z56 V Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1`i �` rKa s llsf°�I �� Submit Form and Form 10-403 (Revised 10/201 Apprgvep li r onths from the date of approval. s upli t Hilcnrp AlaAn. LLC. Well Work Prognosis Well: D-25rd Date: 08/14/14 Well Name: D-25rd API Number: 50-733-20247-01 Current Status: ESP Producer Leg: Leg #A-1 (NE corner) Estimated Start Date: August 18, 2014 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 178-087 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)-777-8420 (0) (985)-867-0665 (M) AFE Number: Budgeted Cost: Current BHP: 2,830 psi @ 7,738 MD, / 6,919' TVD Measured pressured at ESP Max. Expct'd BHP: 2,830 psi @ 7,738' MD/ 6,919 TVD Measured pressured at ESP Max. Anticipated Surface Pressure: -690 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary D-25rd is a G -Zone and Hemlock Producer that was converted to an ESP from a gas -lift completion in 2012. During this workover the casing was pressure tested to 1,500 psig and charted for 30 minutes. The ESP experienced a down failure September 16, 2013 and was replaced in July of 2014. The well was acidized and a scale inhibition squeeze spotted. Currently the well has 120 psi SITP_ and will not pass a no -flow. This workover will install a packer and an SSSV to bring the well into compliance. ✓ Procedure: 1. MIRU HAK #1 Work -over rig. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production and kill well. 3. ND Wellhead, NU BOP and test to 250psi low 12,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Pull completion up -400'. � � I Soy P 5- 5. Install Packer and SSSV equipment 6. Land ESP with the bottom of the assembly at +l- 7,710'. 7. ND BOP, NU wellhead and test., N 8. Turn well over to production. 9. Produce well for >48 hours to clean-up 10. Conduct a no--ftow-test within 2 weeks of achieving stabilized flow. Attnrhments, 1. Current Wellbore Schematic 2. Current Wellhead Diagram 3. Proposed Wellbore Schematic 4. Proposed Wellhead Diagram (same as current) 5. BOP Drawing Hileorn Alaska, J.LC Tree connection: 4-1/16" 5,000# E 3- 4- 5-9 10 _ 11 10/5/10: 2.70" GR tagged up at 10825'. I I I III IV V a b C d e f 12 Holes in casing 3,280`& 5,645' 1JSTT mn on B i Hole in casing 8,202'- C S,zoB' 'D G 11/08: Holes in tbg 8373', 8376', and 8406'. 1 2, 3,4 10,625'- H-0 10627' H-1 Sqz. 200 sx H-2 Ratty cement above H-3 10,802' u VI H-4 Fill Cleaned Out to 11,091' H-5 PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° SCHEMATIC Dolly Varden Well No. D-25RD Completed: 07/16/2014 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Supermax 1 2.992 1 Surf 1 7,583' Jewelry Detail No. Depth ID OD Item a 7,580' 2.992 5.00 Crossover b 7,583' - 5.13 Discharge, Head Bolt -On c 7,585' - 6.75 Pump (x 2) - 45 Stage, SH12000 d 7,628' - 5.13 Seals e 7,646' - 5.62 Motor (x 2) - 562 Series, 340 HP f 7,710' - - Anode Centrilizer Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By:1LL 08/11/14 SCHEMATIC Dolly Varden Well No. D-25RD ` Hilcorp Alaska, LLC Completed: 07/16/2014 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985; 3/2/1991 HB -1 10,726' 10,741' 9,392' 91403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/97-1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 1 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973; 3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 1 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 1 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 11,285' 9,768' 1 9,836' 11/13/1985 Revised By:1LL 08/11/14 Hileorp Alaska, IAX Tree connection: 4-1/16" 5,000# E 3- 4- 5-9 10 - W 10/5/10: 2.70" GR tagged up at 10825'. IV V c f#• d l Holes incasing f f 3,280`& 9 5,645' IISIT nm on h i 1 G 11/08: Holes in tbg 8373', 8376', and 8406'. A-1 A-2 AVIH-4 Fill Cleaned Out to 11,091' H-5 PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° PROPOSED Dolly Varden Well No. D-25RD Completed: 07/16/2014 CASING DETAIL SIZE WT GRADE 3, 410,625'- ID TOP BTM 13-3/8" 61 H-0 10627' Butt. LT&C Sqz. 200 A-2, H-1 sx 9-5/8" H-2 P-110 If 8.681 Ratty 8,155' cement 29 above Butt H-3 10,802' AVIH-4 Fill Cleaned Out to 11,091' H-5 PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° PROPOSED Dolly Varden Well No. D-25RD Completed: 07/16/2014 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Supermax 1 2.992 1 Surf 1 ±7,583' Jewelry Detail No. Depth ID OD Item a ±313' SSSV b ±338' Packer c ±350' X -Nipple d ±366' Gas Lift Mandrel e ±7,710' Bottom of ESP Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Buttress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: 1LL08/11/14 PROPOSED Dolly Varden Well No. D-25RD Hilcorp Alaska, LLC Completed: 07/16/2014 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985; 3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 1 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 1 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 1 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973; 3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -0,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 1 11,285' 9,768' 1 9,836' 11/13/1985 Revised By: JLL 08/11/14 Hilrurp Absoka. IJ Dolly Varden D-25RD 13 3/8 X 9 5/8 X 4 1/2 Valve, swab, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 4 1/16 5M FE, HWO, T-24 Tubing head, CIW-DCB 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom, Casing head, CIW- 135/83MX133/8c thread bottom, w/ 2- 5M EFO, CA slips ins in head BHTA, Bowen, 4 1/16 5M FE X 7" stub acme "Inn. Dolly Varden Platform D-25RD Current 04/10/2014 Tubing hanger, CIW-DCB- ESP, 11 X 4 % IBT lift and susp, w/ 4" type H BPV profile, 5'/4 EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator 0 Cross, stdd, 4 1/16 5M X o M 3 1/8 5M X 2 1/16 5M Valve, WKM-M, 3 1/8 5M FE, w/ MA -16 operator oadstool, 11 5M A FE, prepped for - % npt continuous ine ports NKM-M, 2 1/16 5M FE, HWO, DD Qty 2 fe, CIW-F, 2 1/16 5M =E, HWO, AA trim Hd—rp Alu.ka. I.I.I. Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 Attachment #1 Hilcorp HAK #1 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden 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. 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 Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. 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.) Hileorp Alaska. LLC Hilcorp HAK #1 BOP Test Procedure 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-2 (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-2. 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. Hilcorp Alaska, LLC Hilcorp HAK #1 BOP Test Procedure 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-3. 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 C-1, C-2, and C-4 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. Hilcorp HAK #1 BOP Test Procedure Hileorp AlaAa. Ll.f Attachment #1 Diagram A: Dolly Varden BOP stack and Riser Arrangement — Typical for Single Completion J, lot Dolly Varden Platform 2014 BOP Stack (HAK #1) • v 01/10/2014 Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Hilrnrp Alaska. 1.1.1', Diagram B: Dolly Varden Choke Manifold Hilcorp HAK #1 BOP Test Procedure Attachment #1 From Bop Choke Line 2 1/16 5M Unibolt Flange Ifilanrp Alaska, LLC ern Ilam+ Hilcorp HAK #1 BOP Test Procedure Attachment #1 Hilcorp Alaska, LLC Hilcorp HAK #1 BOP Test Procedure Attachment #1 u f3 4. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other E] Install ESP Performed: Alter Casing ❑ Pull TubingQ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown[:] Stimulate - Other I] Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 178-087 6. API Number 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 50-733-20247-01 13 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 Trading Bay Unit D-25RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,510 feet Plugs measured feet true vertical 10,021 feet Junk measured 11,290 feet Effective Depth measured 11,415 feet Packer measured See Schematic feet true vertical 9,941 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 7,583' (MD) 6,787' (TVD) Packers and SSSV (type, measured and true vertical depth) Packer: See Schematic SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treated perforations from 10,185 — 10,866 Treatment descriptions including volumes used and final pressure: Pumped 55 gallons Baker Petrolite WAW -5206, 330 gallons Xylene, 107 bbls 15% HCL Acid, followed by 150 bbls FIW. Final treating pressure 200 psig. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 120 90 Subsequent to operation: 181 109 11074 90 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentE] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-237 Contact Dan Marlowe Email dmarlowe(a)hilcorp.com Printed Name Dan Marlowe Title Operations Engineer SignaturePhone (907) 283-1329 Date 8/12/2014 Form 10-404 Revised 10/2012 �. � � Submit Ori mal Oni /� / R$OMS XUG 13 44 SCHEMATIC Dolly Varden Well No. D-25RD Hiic„P„ Alaska. LLC Completed: 07/16/2014 CASING DETAIL Tree connection: 4-1/16" 5,000# PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Supermax 1 2.992 1 Surf 1 7,583' Jewelry Detail No. Depth ID OD Item a 7,580' 2.992 5.00 Crossover b 7,583' - 5.13 Discharge, Head Bolt -On c 7,585' - 6.75 Pump (x2)-45 Stage, SH12000 d 7,628' - 5.13 Seals e 7,646' - 5.62 Motor (x 2) - 562 Series, 340 HP f 7,710' - - Anode Centrilizer Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer 11 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: JLL 08/11/14 SCHEMATIC Dolly Varden Well No. D-25RD Hilcorp Alaska, LLC Completed: 07/16/2014 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989;3/2/1991 G-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979; 7/24/1981; 1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992; 7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HBA 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HBA 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 91707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB -0,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB 4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 91741' 9,757' 1/27/1979 31 11,200' 11,272' 9,768' 9,826' 1/27/1979; 7/24/1981 HB -5 1 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By: JLL 08/11/14 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 1 507332024701 1 178-087 1 6/24/14 7/16/14 Daily Operations: 06/24/14 - Tuesday Rigging up. 06/25/14 - Wednesday Rigging up. 06/26/14 - Thursday Rigging up. 06/27/14 - Friday SPOT ACCUMULATOR IN PLACE AND R/U SAME. INSTALL KOOMEY LINES TO BOPS AND FUNCTION TEST SAME "OK". RIG UP AND TEST BOP'S ANNULAR, MANIFOLDS, VALVE AND LINE TO 250 PSI LOW, 2500 PSI ON CHART FOR 5 MIN EACH. TEST WITNESS WAIVED BY JIM REGG ON 6/27/14 @ 14:20 HRS 06/28/14 - Saturday CONT TESTING 11" X 5M BOPS AND SURFACE EQUIPMENT AS PER AOGCC & HILCORP SPECS 250 LOW / 2500 HIGH ON CHART DATED 6-28-2014. TEST FROM MAIN AND FUNCTION REMOTE. R/D TEST EQUIPMENT AND PULL 2 -WAY CHECK. P/U 3-1/2" LANDING JNT & M/U TO HANGER. BACK OUT LOCKING PINS & CHECK WELL FOR FLOW (STATIC). SET GAS BUSTER IN PLACE & R/U SAME. P/U TO FILL HOLE. P/U HANGER +/- 4' WHEN GAS ALARMS WENT OFF. SHUT-IN WELL & WENT TO MUSTER AREA. SICP=O, SITP=O, REVERSE CIRC @ 4 BPM W/250 PSI. PUMPED 24 BBLS & GOT RETURNS. PUMPED 46 BBLS & STARTED GETTING OIL BACK. P/U & PUMPED DWN TBG @ 2 BPM W/750 PSI. PUMPED 8 BBLS & GOT OIL BACK, MONITOR WELL WHILE R/U HOSES TO DISPLACE WELL TO TRADING BAY THRU PRODUCTION HEADER. SICP=O, SITP=O, DISPLACE WELL W/ 700 BBLS. OF 8.5 PPG FIW SENDING ALL RETURNS TO TRADING BAY THRU PRODUCTION HEADER @ 2-2-1/2 BPM W/ 1800 - 2000 PSI. (RETURNS CONTAINED OIL & GAS) 06/29/14 - Sunday MONITOR WELL. GAS BREAKING OUT ON CSG AT SURFACE. CIRCULATE BTMS UP DOWN TBG AND UP CSG THRU GAS BUSTER @ 2-1/2 BPM 1300 PSI. TOTAL PUMPED= 500 BBLS. MONITOR WELL, WELL TAKING 50 BBLS AN HOUR. R/D CIRCULATING HOSES AND PULL HGR TO RIG FLOOR. TERMINATE CONTROL LINES AND ELECTRICAL CABLE FROM HGR. BREAK DOWN LANDING. BREAK OUT HANGER AND LAYDOWN SAME. R/U EQUIPMENT, STRING CONTROL LINE AND ELECTRICAL CABLE THRU SHEAVES AND HANG SHEAVES IN DERRICK. R/U CTRL LINE AND ELECTRICAL CABLE TO SPOOLERS. POOH SLOW W/3-1/2" PRODUCTION TBG, CONTROL LINE AND ELECTRICAL CABLE. STAND BACK PRODUCTION TBG IN DERRICK AND STRAP SAME. CONT' TO POOH W/ 3-1/2" HYDRIL 533 PRODUCTION TBG, CTRL LINE, ELECTRICAL CABLE & ESP TO 6,196' TBGM. PRESSURE WASH, STRAP & STAND BACK SAME. CUT ELECTRICAL CABLE & CHANGE OUT POWER CABLE SPOOL. CONT' TO POOH W/ 3-1/2" HYDRIL 533 PRODUCTION TBG, CTRL LINE, ELECTRICAL CABLE & ESP. PRESSURE WASH, STRAP & STAND BACK SAME. Hilcorp Alaska, LLC Well Operations Summary Well NameAPI Number Well Permit Number Start Date End Date D-25RD 507332024701 1 178-087 1 6/24/14 7/16/14 Daily Operations: 06/30/14 - Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" 533 PROD TBG AND ESP ASSY. STAND BACK IN DERRICK & STRAP SAME. BREAK DOWN ESP PUMP AND LAYDOWN SAME. FULL RECOVERY, 244 JTS, 2 PUP JT, 2 X -OVERS, PUMP AND HGR ASSY= 7,706' DPM. REMOVE SHEAVES FROM DERRICK & CLEAR HANDLING TOOLS FROM RIG FLOOR FOR ESP ASSY. WASH/CLEAN RIG & PLATFORM. FABRICATE & INSTALL FLANGES ON 230 BBL TANK & R/U HOSES TO MIXING PUMP & MIXING HOPPER. R/U KELLY HOSE IN DERRICK & FOSTER TONG HANG LINE. R/D MCCOY TONGS & R/U FOSTER TONGS. DRESS OUT FOSTER'S FOR 3-1/2" DP. P/U 3-1/2" P.H.E. TEST RUN EQUIPMENT AND OFF-LOAD 3-1/2" PH -6 FROM BOAT. R/U KELLY HOSE IN DERRICK & FOSTER. R/D McCOY TONGS & R/U FOSTER TONGS. DRESS OUT FOSTER'S FOR 3- 1/2" DP. P/U 3-1/2" P.H.E. TEST RUN EQUIPMENT. P/U 3-1/2" MULE SHOE & TIH W/SAME WHILE P/U SINGLES FROM V - DOOR. STRAPPING & DRIFTING SAME. (15 JTS) & 9.625" SCRAPPER TOTAL BHA = 479.68'. CONT' TO TIH WHILE P/U SINGLES F/ V -DOOR. STRAPPING & DRIFTING SAME. 35 JTS RAN @ 06:00 hrs 07/01/14 -Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT P/U 3-1/2" PH6 OUT OF V -DOOR AND TIH. STRAP AND RABBIT SAME TO 7,614' DPM. R/U KELLY HOSE AND BREAK CIRCULATION, WASH DOWN THE LONG WAY FROM 7,614' TO 8,143' D DPM @ 3 BPM 330 PSI, REVERSING OUT A BTMS UP EVERY KELLY DOWN, @ 3 BPM 100 PSI. GETTING SOME SCALE AND SLUDGE BACK IN RETURNS. 340 BBLS LOST TO FORMATION IN 24 HRS. TOTAL LOST TO FORMATION = 500 BBLS. 07/02/14 - Wednesday CONT WASHING DOWN THE LONG WAY F/8,143'-8,245' DPM @3 BPM 330 PSI, REVERSING OUT BTMS UP EVERY 30'@ 5BPM 400 PSI. POOH W/3-1/2" PH6 WORKSTRING, SCRAPER ASSY AND MULE SHOE. LAYDOWN MULE SHOE, WASH AND CLEAN RIG FLOOR AND PREP RIG FLOOR TO TIH. M/UBHA #2--- 4-11/16" OVERSHOT W/3-1/2" GRAPPLE, JARS, 15 JTS 3- 1/2" PH -6 TBG & 6.50" OD DRILLING JARS. TOTAL BHA= 567.98'. TIH W/3-1/2" PH6 AND OVERSHOT BHA, SPACE OUT AND TAG TOF @ 8,235' DPM. ROTATE/WORK OVERSHOT OVER FISH AND LATCH SAME. VERIFIED BY SETTING 14K DOWN & PULLING 16K OVER. (ORG P/U = 94K, S/O = 74K), R/U CIRCULATING EQUIP, AND GATHERED ESSENTIAL PERSONNEL FOR JSA ON ACID JOB. PRESSURE TESTED LINES TO 2000 PSI. PUMPED SOLVENT PREFLUSH @ 2 BPM @ 400 PSI - 330 GALLONS XYLENE, 330 GALLONS BAKER PETROLITE WAW -5206 MUTUAL SOLVENT. PUMPED 107 BBLS OF 12.5% HCL ACID _@ 2 BPM STARTING PRESSURE 300 GRADUALLY FALLING OFF TO 200 PSI. DISPLACED W/ 72 BBLS OF 8.5 PPG FIW @ 1 BPM W/ 80 PSI. SHUT IN TO SOAK FOR 6 HOURS. FLUSH AND RIG DOWN TANKS, PUMP, HOSES. Fluid loss = 60 bbls + 195 BBL SQUEEZE = 255 BBLS in 24 hrs. Total fluid loss = 755 bbls. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 178-087 1 6/24/14 7/16/14 Daily Operations: 07/03/14 - Thursday CONT WAITNG ON ACID TO SOAK AS PER HILCORP ENGINEER. PERFORM GENERAL RIG MAINTENANCE AND HOUSEKEEPING WHILE WAITING. BULL HEAD 157 BBLS 8.5# FIW DOWN TBG @ 3BPM 450 PSI AND SQUEEZE ACID INTO FORMATION. R/U SLICKLINE UNIT AND LUBRICATOR. M/U 2.50" GAUGE RING ON S -LINE, TEST LUBRICATOR TO 1500 PSI. RIH W/S-LINE, ENCOUNTER TIGHT SPOTS @ 8,238', 8,368', 8,406' SLM,TAGGED @ 8,409' SLM. UNABLE TO WORK DEEPER. POOH W/S-LINE AND R/D SAME. P/U TO 165K (75 K OVER) AND ATTEMPT TO PULL SEALS FREE, INDICATION GRAPPLE SLIPPED OFF. ATTEMPT TO LATCH BACK ON TO FISH NO SUCCESS, BREAKDOWN SPACE OUT ASSY AND LAYDOWN SAME. POOH W/3-1/2" PH6 AND O/S BHA. B/0 & L/D 0/S BHA & INPECT SAME. FOUND BROKEN GRAPPLE (30% OF GRAPPLE LEFT IN HOLE) & ALSO FOUND ACID EROSION ON GRAPPLE WICKERS. P/U 3-1/2" TEST JNT & WEAR BUSHING R/R TOOL. PULL WEAR BUSHING & SET TEST PLUG. R/U BOP TESTING EQUIP. TEST 11" X 5M BOPS & SURFACE EQUIP W/ 3-1/2" TO 250 PSI LOW 2500 PSI ON CHART FOR 5 MINS. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. HYDRIL LEAKED ON HIGH TEST, INCREASED PRESSURE AND TESTED OK. VALVE #24 LEAKED AT GREASE FITTING ON HIGH TEST. REPLACED FITTING GREASED AND TESTED OK. R/D TEST EQUIP & L/D 3-1/2" TEST ASSY. R/U ESP EQUIP, POWER CABLE & CTRL LINE REELS. PREP TO P/U E.S.P. 07/04/14 - Friday FINISH RIGGING UP ESP EQUIPMENT, RUN ELECTRICAL CABLE AND CTRL LINE IN SHEAVES AND HANG SHEAVES IN DERRICK. P/U & M/U ESP PUMP ASSY, FILL SAME W/OIL AND CHECK CONTINUITY ON ELECTRICAL CABLE "OK". TIH W/ESP PUMP ASSY & 3-1/2" 533 PROD TBG OUT OF DERRICK, DRIFTING SAME. CHANGE OUT POWER CABLE REEL @ 4,120' TBGM. SPLICED & TESTED POWER CABLE. (OK), CONT' TO TIH W/ ESP ASSY & 3-1/2" HYDRIL 533 PRODUCTION TBG OUT OF DERRICK, DRIFTING SAME. INSTALLING CANON CLAMPS BETWEEN EVERY STD & TESTING CONTINUITY EVERY 20 STDS. AT 4,700' TBG SLIPS HUNG ON CLAMP WHILE SLACKING DAMAGING POWER CABLE. PULL 2 STDS AND CUT AND SPLICE CABLE, FLUID LOSS = 75 BBLS. TOTAL FLUID LOSS = 1030 BBLS. 07/05/14 - Saturday CONT SPLICING ELECTRICAL CABLE ON ESP PUMP AND CHECK CONTINUITY "OK". CONT TIH W/3-1/2" 533 HYD PROD TBG AND ESP ASSY. TONGS OVER TORQING PIPE, DUE TO TORQUE GAUGE OUT OF CALIBRATION. CONSULT OVER TORQUING OF PIPE W/ HILCORP ENGINEER. DECISION MADE TO CHANGE OUT PROD STRING. POOH W/3-1/2" PROD TBG AND ESP PUMP, CTRL LINE AND ELECTRICAL CABLE, STANDING BACK IN DERRICK. ASSIST ESP REPS DIS -ASSEMBLE PUMP AND LAYDOWN SAME. R/D CABLE & FLAT PACK SHEVES L/O SAME. SERVICE RIG & PERFORM SAFETY CHECKS. TIH W/ 3-1/2" HYDRIL 533 TBG OUT OF DERRICK. SET UP PIPE RACKS & TEMP WALL. PREP TO L/D PIPE. POOH W/ 3-1/2" HYDRIL 533 TBG. L/D SINGLES IN V -DOOR. CLEAN INSIDE/OUTSIDE & SHRINK WRAP SAME. CHECK FOR N.O.R.M. PRIOR TO BACK - LOADING ON BOAT. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-25RD 507332024701 1 178-087 1 6/24/14 7/16/14 Daily Operations: 07/06/14 - Sunday SERVICE RIG AND CONT POOH W/3-1/2" 533 PRODUCTION TBG LAYING DOWN SAME. WASH/CLEAN INSIDE & OUT OF EACH JT. CLEAR RIG FLOOR OF HANDLING TOOLS FOR 3-1/2" 533 PROD TBG. WASH/CLEAN RIG FLOOR AND PREP SAME TO TIH W/3-1/2" SUPERMAX TBG. STAGE & R/U EQUIPMENT, REELS, & SPOOLERS. SPLICE TOGETHER FLAT PACK CABLE & POWER CABLE. RAN CTRL LINES & POWER CABLE THRU SHEAVES & HUNG SAME. P/U E.S.P. ASSY AS PER REPS. INSTALL CTRL LINES ON MOTOR. FOUND BAD O-RING ON PUMP SECTION, REPLACED SAME. STRIPPED OUT BOLT ON PUMP SECTION, TAPPED SAME. REMOVED AIR FROM MOTOR SECTION & FILLED W/ OIL. PLUGGED IN POWER CABLE & WRAP SAME. CONTINUE P/U ESP SECTIONS INSTALLING CANON CLAMPS AS NEEDED. FLUID LOSS = 145 BBLS. TOTAL FLUID LOSS = 1225 BBLS. 07/07/14 - Monday CONT MAKE UP ESP PUMP ASSY, TEST CTRL LINES AND CHECK CONTINUITY ON ELECTRICAL CABLE "OK". TIH W/3-1/2" SUPERMAX PROD TBG. & ESP PUMP ASSY INSTALLING CABLE CLAMPS AS PER REP. STRAP & RABBIT SAME. REP CHECKING CONTINUITY ON ELECTRICAL CABLE EVERY 1000'. CONT TIH W/3-1/2" SUPERMAX PROD TBG & ESP ASSY INSTALLING CANON CLAMPS, CHECK CONTINUITY ON CABLE EVERY 1000'. SWAP OUT ELECTRICAL CABLE REEL & SPLICE TOGETHER POWER CABLE. SPLICED CABLE, CONT TIH W/3-1/2" SUPERMAX PROD TBG & ESP ASSY INSTALLING CANON CLAMPS. CHECK CONTINUITY ON CABLE EVERY 1000'. FLUID LOSS = 25 BBLS. TOTAL FLUID LOSS = 1250 BBLS DEPTH =7600'. 07/08/14 -Tuesday CONT TIH W/3-1/2" SUPERMAX TBG AND ESP ASSY. M/U LANDING JT AND HGR. SPLICE ELETRICAL CABLE TO PENETRATOR AND INSTALL SAME IN HGR. MAKE UP (2) 1/4" CTRL LINES TO HGR. TEST CTRL LINE TO 5000 PSI FOR 15 MINS & CONTINUITY ON ELECTRICAL CABLE "OK". LAND HGR & ASSIST REP RUN IN HGR PINS. CHECK CONTINUITY ON ELECTRICAL CABLE "OK". BACK OUT LANDING JT AND LAYDOWN SAME. INSTALL BPV. PREP R/F TO N/D 11" X 5M BOPS AND RISER SECTIONS. NIPPLE DOWN BOPS AND RISER SECTIONS. TESTED VOID ON HANGER TO 5000 PSI ( OK). N/U PRODUCTION TREE & FLOW -LINE. TEST TREE TO 5000 PSI . R/D KOOMEY UNIT, CHOKE MANIFOLD, CAT -WALK, V -DOOR, MISC STAIRS/WALK-WAYS, & OTHER MISC EQUIP TO PREP TO SKID RIG. TURN WELL OVER TO PRODUCTION. 07/16/14 - Wednesday Rig up tanks and pumping equipment. Attempt to inject into well with FIW, well locked up. Max pressure 1700 psi. Flow well to remove obstruction, scale fines observed at flowline sample point. Pump scale inhibitor squeeze per program. 2.5 bpm injection rate, max pressure 300 psi. Preflush / 5 drums WAW -5206 mixed 7.5% with 79 bbls FIW = 85.6 bbls. Scale Inhibitor / 36 drums SCW-4004 mixed 12.5% with 330 bbls FIW = 377 bbls. Overflush - 583 bbls of FIW. Shut in well for 12 hour soak. Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Monday, August 11, 2014 4:04 PM To: Schwartz, Guy L (DOA) Cc: Ted Kramer, Daniel Taylor; Juanita Lovett Subject: RE: D-25rdX Casing was tested 06/07/12 @ 21:00 hrs, 7,233' MD, 1500 psig for 37 minutes From: Dan Marlowe Sent: August 11, 2014 3:42 PM To: 'Schwartz, Guy L (DOA)' Cc: Ted Kramer; Daniel Taylor; Juanita Lovett Subject: RE: D-25rd2 Guy Here is the well test data Current shut-in pressure is 120 psig A few more weeks can't hurt us but not sure how much they will help either. Here is some more data that we can discuss WELL TEST D-25rd Date Hrs. Sep. Total % Net f otal Tota: GOR 24 tested # Fluid CUT Oil CVD, Inj. 992 07/18/2014 From: Schwartz, Guy L (DOA) [ma iIto: guy. schwa rtz@alaska.M) Sent: August 11, 2014 2:37 PM To: Dan Marlowe Cc: Ted Kramer; Daniel Taylor; Juanita Lovett Subject: RE: D-25rd2 1 New ESP 07/09/14 Summit 07/12/2014 24 4 9516 98.2 171 170 0 170 992 07/18/2014 24 3 10680 99.5 53 129 0 129 2416 07/19/2014 24 3 10630 99.5 53 19Z 0 194 3650 07/20/2014 24 3 10810 99.5 54 250 0 250 4625 07/22/2014 24 3 11660 99.3 82 165 0 165 2022 07/23/2014 24 3 11580 99.0 116 200 0 200 1727 07/24/2014 24 3 11570 99.0 116 173 0 172, 1495 • 07/25/2014 24 3 11494 98.8 138 160 0 160 1160 08/01/2014 24 3 11257 98.3 191 250 0 250 1306 08/02/2014 24 4 11406 97.8 251 233 0 233 929 08103/2014 24 4 10836 97.9 228 396 0 396 1740 08/06/2014 24 4 9931 97.7 228 419 0 419 1834 From: Schwartz, Guy L (DOA) [ma iIto: guy. schwa rtz@alaska.M) Sent: August 11, 2014 2:37 PM To: Dan Marlowe Cc: Ted Kramer; Daniel Taylor; Juanita Lovett Subject: RE: D-25rd2 1 r1% Dan, Can you give me an idea of how much higher than anticipated the pressure is? What kind of production ? Water cut, GOR etc. Do you think you would be able to draw down reservoir in a couple more weeks or is it stable since mid July? What is shut in pressure? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.aov). From: Dan Marlowe rmailto:dmarlowe(ahilcorp.com] Sent: Monday, August 11, 2014 12:48 PM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Daniel Taylor; Juanita Lovett Subject: D-25rd2 Guy We completed the D-25rd2 well Sundry 314-237, PTD 178-087 on July 16th. Since that time we have been working to stabilize the well so that we could proceed with a no -flow test. We shut the well in August 07th @ 17:00 in an unsuccessful attempt to bleed it down and we have left it shut-in until I could talk to you about a plan forward. It appears that the acid remediation was successful and we have restored productivity higher than anticipated. Given the higher than expected pressures, I would like to workover the well as soon as possible and install a high set packer and SSSV as we have in a couple of other ESP applications recently. I am currently designing and sourcing the required materials and will schedule the work as soon as I possible. In the meantime our options are: a) Kill the well with —detrimental to future production b) Leave the well shut-in with pressure on the well — doesn't solve anything c) Put the well back on production and repair as soon as feasible I will call you to discuss Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(a)-hilcorp.com Hilcorp A Company Built on Energy I-v 1//i�,. � 11 E STATE E, , . ;',:_i C '\.3�� K,,,,, l':'5'-':. t 333 West Severt�� A��er,;e :_:.::::1) (; horage, Alaska 99501-35-/2 °"==r"' f ,O�'i�R\r(�„� SI;A\r FAiZ�:P, Anc I.I, "/ t,/,--, ,- 9r7.2 79 1433 �- x. t�A{ 0 12014 Dan Marlowe Operations Engineer f 0 q 7 Hilcorp Alaska, LLC ` '/ U 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-25RD Sundry Number: 314-237 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (W6P4-e„,(4,- Cathy P.7oerster Chair DATED this�day of April, 2014. Encl. 3 .. ., w . APR 1. 4 LLi .•: STATE OF ALASKA h7 4,12.2.1 1'4- ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well❑ _la, Change Approved Program 0 Suspend❑ Plug Perforations 0 At-Perforate re Pull Tubing[[W" N't?`IY Time Extension El Operations Shutdown 0 Re-enter Susp.Well 0 A c timulate L7 Alter Casing 0 Other. Run ESP ❑ 2.Operator Name: 4.Current Weft Class: 5 Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development 0 1 `178-087 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic CI Service I=1 N6.API Number: Anchorage,AK 99503 50-733-20247-01 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes 0 No 9 Trading Bay Unit D-25RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 • McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools • 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): 11,510 • 10,021 • 11,415 • 9,941• 11,290 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi ' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic I See Schematic 3-1/2" 9.2#/L-80 7,629 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ' Packers(see schematic)/SSSV-N/A Packers(see schematic)/SSSV-N/A i 12.Attachments: Description Summary of Proposal 9 • 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 9 . Exploratory ❑ Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for 15.Well Status after proposed work: 5/15/2014 Commencing Operations: Oil 0 ' Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature hone (907)283-1329 Date 4/14/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / �k {- 1V1 1 Plug Integrity CI BOP Test Q' Mechanical Integrity Test ❑ Location Clearance 0 Other: 2 S-610 jaSi, j 6 TCS F REOMSCK,MAY 0 7 2014 Spacing Exception Required? Yes ❑ No [K( Subsequent Form Required: /o—y 0Y P APPROVED BY Approved by: ' .ems-_ COMMISSIONER THE COMMISSION Date: 4Z Z , 'A Submit Form and Form 10-403(Revised 10/2012) ApprpvecRP f GliNid�pr[months from the date of approval. Attachments in Duplicate 14 Well Work Prognosis Well: D-25rd Hilcorp Alaska,11,1XDate: 04/10/14 Well Name: D-25rd API Number: 50-733-20247-01 Current Status: ESP Producer Leg: Leg#A-1 (NE corner) Estimated Start Date: May 15, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 178-087 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) AFE Number: Budgeted Cost: Current BHP: 2,899 psi @ 7,738 MD, /6,919' TVD Measured pressured at ESP Max. Expct'd BHP: 2,899 psi @ 7,738' MD/6,919 TVD Measured pressured at ESP Max.Anticipated Surface Pressure: 0 psi (Using 0.435psi/ft.to surface) Brief Well Summary D-25rd is a G-Zone and Hemlock Producer that was converted to an ESP from a gas-lift completion in 2012. During this workover the casing was pressure tested to 1,500 psig and charted for 30 minutes. The ESP experienced a down failure September 16, 2013. We plan to pull the current ESP completion and replace with a new ESP. We also plan acidize the rat-hole to remediate known scale and perform a scale inhibition squeeze. Procedure: 1. MIRU HAK#1 Work-over rig. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e- line and RIH to+/-7,600' and punch tubing. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. PU work-string and cleanout to 7,895' 6. PU overshot and RIH to 7,895' 7. Pump Acid Job a) Establish Injection into the Well with FIW. Once injection is established maintain a low steady rate until starting Squeeze. b) Premix and pump the Pre-flush—1 drum WAW-5206 mixed 330 gallons xylene c) Pump 107 bbls 15% HCL Acid d) Pump work-string volume of FIW to displace Acid. e) Soak for 6 hours then displace into formation with 150 bbls FIW f) Rig down pumping equipment. 8. RU wireline bailer and bail down to expose hemlock bench 2. 9. RU e-line and reperforate hemlock bench 2. 10. POOH with work-string. 11. PU, RIH with ESP completion. 12. Land ESP with the bottom of the assembly at+/-7,985'. 13. ND BOP, NU wellhead and test. 14. Turn well over to production. 15. Produce well for>48 hours to clean-up 16. Pump Scale Inhibitor Squeeze . , 14 Well Work Prognosis Well: D-25rd Hilcorp Alaska,LLCDate: 04/10/14 a) Establish Injection into the Well with FIW. Once injection is established maintain a low steady rate until starting Squeeze. b) Premix and pump the Preflush—5 drums WAW-5206 mixed 7.5%with 79 bbls FIW=85.6 bbls c) Premix and pump the Scale Inhibitor— 12 drums SCW-8225 mixed 12.5% with 110 bbls FIW = 126 bbls d) Pump FIW Overflush for 7 ft radial penetration (517 bbls plus 97 bbl tubing displacement = 614 bbls). e) Shut in well for 12 hours for scale inhibitor to adhere and precipitate in formation. f) Rig down pumping equipment. g) Return well to production slowly to minimize swabbing the scale inhibitor back in from the well. 17. Conduct a no-flow test within 2 weeks of achieving stabilized flow. Attachments: 1. Current Wellbore Schematic 2. Current Wellhead Diagram 3. Proposed Wellbore Schematic 4. Proposed Wellhead Diagram (same as current) 5. BOP Drawing 11 SCHEMATIC Dolly Varden • Well No. D-25RD I Hi'cora Alaska,LLC Completed 06/2012 CASING DETAIL Tree connection:4-1/16"5,000# SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,518' 75, 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' to ' "� 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL x 3-1/2" 9.2 L-80 Hyd.533 2.992 Surf 7,629' fiaro Holes in casing b - d 1� 35,645' Jewelry Detail e 11S1Tn°°° No. Depth ID OD Item k 0 Na a 7,629' 2.9 5.5 Crossover 10 ` b 7,631' 2.9 5.5 Discharge Pressure Head °i; c 7,641' 2.9 5.5 Crossover g A� d 7,643' 6.75 Discharge Pump X 3-675 Pump MNL,Model:HPMTAR Type: `, e 7,644' 6.751 [ ti28HC7800,Overall Length:40' Hole in f 7,699' 7.25 Motor-HMI/800,725 Motor MNL,4160 V/114A casing g 7,738' 8 Anode:2 Chemical Line Checks,2,500# 8,202'- 8,208' Upper Scab Liner Assembly E '}‹,\1:1><,�-B D A 7,799' 6 8.218 Packer,9-5/8"Baker Mod.F(DP set) o� F B 7,895' 4.892 5.5 Crossover,7"Buttress Box x 5-1/2"15.5#Hydril Pin 3 G 11/08:Holes C 8,338' 4.375 5.63 Seal assembly,5" Located in 5'Upper PBR 4 ' '4- in tbg D 8,349' 4 5.5 Anchor,Baker Mod.E-22 AN - 8323',8326', E 8,350' 4 5.875 Packer,7" x 4",Baker Mod."FA" 5-9 € • and 8406'. ,mt , F 8,354' 4.5 5.53 Millout Extension,4'Long w/4ea.1"Holes aIMII G 8,357' 4 5 Lower Seal Bore Extension, 14'Long 10 _4 4 8,372' 2.992 5.57 Crossover,5"LTC Box x 3-1/2"Butress Pin _ A-1 5 8 400' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch I , -I A-2 6 8,802' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 11 7 9,234' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 8 9,636' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 12 - -G-2,3,4 9 10,007' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 10/5/10 -•-411 10,625'- 10 10,053' 3 4 Locator,Seal Assembly 2.20"GR I H-0 10627' 11 10,093' 2.813 3.88 Otis,'X'Nipple,2.813 tagged up pSE sgz.200 12 10,126' 2.992 3.865 Wireline Entry Guide at 10825'.-� rrIt~t H-1 sX A-1 10,055' 4 5.875 Packer,7",Baker Mod."FB-1" (DP set-WL Correlated) ii, L H-2 A-2 10,058' 4 5 Seal Bore Extension Il Ratty Lower Scab Liner(DP set-WL Correlated) 4 cement above I 10,835' 4 5.87 Baker Packer II " ^" H-3 10,802' IIIII 10,860' 2.813 3.88 X'Nipple(2.813"),3-1/2"Buttress • III 2.992 3.5 Scab Liner,3-1/2",9.2#,L-80,Buttress IV a _Fr- IV 10,920' 4 5.872 Baker Packer,Mod.F-1 V X n 0* V 10,948' 2.75 3.87 'XN'Nipple(2.75"),3-1/2"Buttress Lt VI 10,960' 2.992 3.865 Wireline Entry Guide VI li H-4 Fill Cleaned - �c. ..7- Out to 11,091' i, See Next Page for Perforation Information. 4A'= H-5 0 2 PBTD=11,415' TD=11,506' MAX HOLE ANGLE=39.75° Revised By:.ILL 06/12/13 SCHEMATIC Dolly Varden • Well No. D-25RD H;i,,,,,,,Ata'k<,>Lc Completed 06/2012 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979;SQZ 1/17/1979;SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978;SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978;SQZ 12/6/1978 6-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 6-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973;SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979;SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 6-7 10,645' 10,660' 9,328' 9,340' 1/9/1989;11/25/1989;3/2/1991 6-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB-1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB-1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB-1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB-1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB-1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB-1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB-1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 H8-2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB-2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 - HB-2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB-3 10,865' 10,880' 9,501' 9,513' 1/9/1989;11/25/1989;1/9/1998 HB-3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973;11/13/1985 HB-3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB-3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB-3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB-3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB-3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB-3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB-3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB-3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB-3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB-4 11,030' 11,050' 9,632' 9,647' 1/9/1989;11/25/1989 HB-4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB-4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB-4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB-4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB-4 11,031' 11,125' 9,632' 9,707' 7/24/1981 H8-4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB-4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB-4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB-4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979;11/13-17/1985 HB-4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB-4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB-4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB-4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB-4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB-4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB-4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB-4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB-4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB-4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 H8-4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB-4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB-4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB-4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 1 HB-5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB-5 11,150' 11,167' 9,727' 9,741' 1/27/1979 H8-5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB-5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB-5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB-5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB-5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By:JLL 06/12/13 . - n PROPOSED Dolly Varden Well No. D-25RD Hilcorp Alaska,LLC Completed: Future CASING DETAIL Tree connection:4-1/16"5,000# SIZE WT GRADE CONN ID TOP BTM 13 3/8" 61 K 55 Butt.LT&C 12.515 Surf 2,518' 9 5/8" 47 P 110 Butt 8.681 Surf 8,155' z.,- 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 9.2 L-80 Hyd.53, 2.992 Surf ±7,629' -1 A a Holes in casing ' b 3,280`& d 5,645' Jewelry Detail e f tiStTumnn No. Depth ID OD Item a ±7,629' 2.9 5.5 Crossover f b ±7,631' 2.9 5.5 Discharge Pressure Head c ±7,641' 2.9 5.5 Crossover g A , a d ±7,643' 6.75 Discharge e ±7,644' 6.75 Pump X 3-675 Pump MNL,Model:HPMTAR Type B 28HC7800,Overall Length:40' xl =.` Hole in f ±7,699' 7.25 Motor-HMI/800,725 Motor MNL,4160 V/114A casing g ±7,738' 8 Anode:2 Chemical Line Checks,2,500# - O - s 208 ' Upper Scab Liner Assembly D A 7,799' 6 8.218 Packer,9-5/8"Baker Mod.F(DP set) E o o e-/1♦ F B 7,895' 4.892 5.5 Crossover,7"Buttress Box x 5-1/2"15.5#Hydril Pin g ' G 11/08:Holes C 8,338' 4.375 5.63 Seal assembly,5" Located in 5'Upper PBR 4- '♦ in tbg D 8,349' 4 5.5 Anchor,Baker Mod.E-22 8373',8376', E 8,350' 4 5.875 Packer,7" x 4",Baker Mod."FA" 5-9 Ma and 8406'. F 8,354' 4.5 5.53 Millout Extension,4'Long w/4ea.1"Holes G 8,357' 4 5 Lower Seal Bore Extension,14'Long 10 , 4 8,372' 2.992 5.57 Crossover,5"LTC Box x 3-1/2"Butress Pin _ A-1 5 8 400' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 1 A-2 6 8,802' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 11 - 7 9,234' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 12 _ 8 9,636' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch �G-2, 3,4 9 10,007' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 10/5/10 ="41 10 625'_ 10 10,053' 3 4 Locator,Seal Assembly 2.70"GR = H-0 10627' 11 10,093' 2.813 3.88 Otis,'X'Nipple,2.813 tagged up = H-1 Sgz.200 12 10,126' 2.992 3.865 Wireline Entry Guide at 10825'. _, sx A-1 10,055' 4 5.875 Packer,7",Baker Mod."FB-1" (DP set-WL Correlated) H-2 A-2 10,058' 4 5 Seal Bore Extension J� j4 Ratty cement Lower Scab Liner(DP set-WL Correlated) II x above I 10,835' 4 5.87 Baker Packer B H-3 10,802' III -► II 10,860' 2.813 3.88 'X'Nipple(2.813"),3-1/2"Buttress IV J III 2.992 3.5 Scab Liner,3-1/2",9.2#,L-80,Buttress V x \ , IV 10,920' 4 5.872 Baker Packer,Mod.F-1 1' --�"--I i V 10,948' 2.75 3.87 'XN'Nipple(2.75"),3-1/2"Buttress I. VI 10,960' 2.992 3.865 Wireline Entry Guide VI H-4 Fill Cleaned :::..::.:::::::: Out to 11,091' >i See Next Page for Perforation Information. H5 4 PBTD=11,415' TD=11,506' MAX HOLE ANGLE=39.75° Revised By:1LL 04/10/14 til PROPOSED Dolly Varden Well No. D-25RD • HilcorpAlaska,LLC Completed: Future Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979;SQZ 1/17/1979;SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978;SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978;SQZ 12/6/1978 6-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 6-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 6-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973;SQZ 3/7/1973 6-6 10,625' 10,627' 9,313' 9,314' 1/16/1979;SQZ 1/17/1979 6-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 6-7 10,645' 10,660' 9,328' 9,340' 1/9/1989;11/25/1989;3/2/1991 6-7 10,648' 10,660' 9,331' 9,340' 7/28/1979 6-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB-1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB-1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB-1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB-1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB-1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB-1 10,727' 10,742' 9,392' 9,404' 3/8/1992 r HB-1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB-2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB-2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB-2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB-3 10,865' 10,880' 9,501' 9,513' 1/9/1989;11/25/1989;1/9/1998 HB-3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973;11/13/1985 HB-3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB-3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB-3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB-3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB-3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB-3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB-3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB-3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB-3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB-4 11,030' 11,050' 9,632' 9,647' 1/9/1989;11/25/1989 HB-4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB-4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB-4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB-4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB-4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB-4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB-4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB-4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB-4 11,062' 11,093' 9,657' 9,682' 1/30-31/1979;11/13-17/1985 HB-4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB-4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB-4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB-4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973;3/132-22/1973 HB-4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB-4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB-4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB-4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB-4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB-4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB-4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB-4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB-4,5 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 HB-4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB-5 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 HB-5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB-5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB-5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB-5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB-5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB-5 11,200' 11,285' 9,768' 9,836' 11/13/1985 Revised By:JLL 04/10/14 ' . Eli Dolly Varden Platform D-25RD Current 04/10/2014 Hilrt.rp Ala■ka,IAA BHTA, Bowen,4 1/16 5M FE Doll Varden X 7"stub acme Dolly Tubing hanger,CIW-DCB- D-25RD PI ESP, 11 X 41/2 IBT lift and 133/8X95/8X41/2 susp,w/4"type H BPV profile, 5'A EN,2-3/8 1.1 i; III continuous control line ISports, prepped for BIW �1 III penetrator Valve,swab,WKM-M, a o 4 1/16 5M FE, HWO, ) 1,r Cross,stdd,4 1/16 5M X _�^� 3 1/8 5M X 2 1/16 5M T-24 G .P, It. ,.. Valve,wing,WKM-M, ��►' E. �' 2 1/16 5M FE, HWO, M'r : l! QO Valve,WKM-M,3 1/8 5M FE, T-24 - w/MA-16 operator illIII Iti Valve, lower master,WKM-M, ��� 4 1/16 5M FE, HWO,T-24 1.1 III 1.1111 Adapter,CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for - 5'/4 ESP neck,2-' npt continuous I control line ports Tubing head,CIW-DCB, 4 ii tit: 13 5/8 3M X 11 5M,w/ 2 2 1/16 5M SSO, III 1111 Valve,WKM-M,2 1/16 5M FE, X bottom, :a , ■ ,moi\ ; : c HW00, DD .1. „ �l � , ii , ty 2 ..� ! 110'x.; tat1 lu II _:- Casing .._ head,CIW-WF, v:,,,,..„,,,_,,,..4 13 5/8 3M X 13 3/8 casingm Valve,CIW-F,2 1/16 5M thread bottom,w/2 2 1/16 ill Ill FE, HWO,AA trim 5M EFO,CA slips installed E =_ __ 1— L' E in head II" "III i d�, Illi. -L: 4 L O R , Dolly Varden Platform 2014 BOP Stack(HAK#1) 01/10/2014 iiilimrp Alaska,HA. Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack ii•Iji III III III Iii lII lit 3.42' 111 lit III Iii it 111 III If{ill ill 4.54' CIU e. di 'os.. IISI111111ilIll w .111 111111 ii1 11i 2.00' e •Cho 111 lil I11 I11 lit M Kill Side Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line 21/16 5M w/HCR and Unibolt line connection 1111�11�1111111 connection Drill deck Riser 11 5M FE X 16.00' 11 SM FE I11 III!hal tit 1*I IP'!'lil 111 3.00' Spacer spool 11 5M FE X 11 5M FE 111 lil Ill sit iii STATE OF ALASKA ALAO OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS i 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver, ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other QA%_ Re-enter Suspended Well[] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 2 Exploratory ❑ Stratigraphic❑ Service ❑ 178-087 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, AK 99503 50-733-20247-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 Trading Bay Unit D-25RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,510 feet Plugs measured feet true vertical 10,021 feet Junk measured 11,290 feet Effective Depth measured 11,415 feet Packer measured See Schematic feet true vertical 9,941 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SWIAED AUG 122013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 7,629' (MD) 6,827' (TVD) Packers and SSSV (type, measured and true vertical depth) Packer: See Schematic SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treated tubulars to 10,126', perforations from 10,185'- 10,866' Treatment descriptions including volumes used and final pressure: Stage 1 - Pumped 83 bbls FIW spearhead, 3,593 gallons (275 gallons WAW -5206 mutual solvent mixed with 79 bbls FIW), 107 bbls 15% Hydrochloric Acid, followed by 70 bbls FIW. Stage 2 - Pumped 5,280 gallons (660 gallons SCW-8225 scale inhibitor mixed with 110 bbls FIW), followed by 614 bbls FIW. Ending pressure 750 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 27 60 2510 100 138 Subsequent to operation: 75 10 1455 100 86 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 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG[] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1313-332 Contact Dan Marlowe Email dmarloweCaD-hilcorp.com Printed Name Dan Marlowe OE Title Operations Engineer Signature Phone (907) 283-1329 8/5/2013 4 2013 Hilcorp Alaska, LLC Tree connection: 4-1/16" 5,000# E 3- 4- 5-9 10 - 11 10/5/10: 2.70" GR tagged up at 10825'. IV V a ;d e 12 G-2, 3, 4 H-0 H-1 X X VI H-4 Fill Cleaned Out to 11,091' Holes in casing 3,280`& 5,645' 1JSTT nm on B '' Hole in casing s,2oz'- C s,zos' D G 11/08: Holes in tbg 8373',8376', and 8406'. E PBTD = 11,415' TD= 11,506' MAX HOLE ANGLE = 39.75° SCHEMATIC Dolly Varden Well No. D-25RD Completed 06/2012 CASING DETAIL SIZE 10,625'- GRADE CONN 10627' TOP BTM Sgz.200 61 K-55 Butt. LT&C 12.515 Surf sx 9-5/8" H-2 P-110 Butt Ratty Surf 8,155' cement 29 N-80 above 6.184 H-3 10,802' 6.75 PBTD = 11,415' TD= 11,506' MAX HOLE ANGLE = 39.75° SCHEMATIC Dolly Varden Well No. D-25RD Completed 06/2012 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 3-1/2" 1 9.2 L-80 I Hyd.533 1 2.992 1 Surf 1 7,629' Jewelry Detail No. Depth ID OD Item a 7,629' 2.9 5.5 Crossover b 7,631' 2.9 5.5 Discharge Pressure Head c 7,641' 2.9 5.5 Crossover d 7,643' 6.75 Discharge e 7,644' 6.75 Pump X 3 - 675 Pump MNL, Model: HPMTAR Type: 28HC7800, Overall Length: 40' f 7,699' 7.25 Motor - HMI/800, 725 Motor MNL, 4160 V/ 114A g 7,738' 8 Anode: 2 Chemical Line Checks, 2,500# Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis,'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress III 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress IV 10,920' 4 5.872 Baker Packer, Mod. F-1 V 10,948'3,87 'XN' Nipple (2.75"), 3-1/2" Buttress V-1-10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: AL 06/12/13 0 SCHEMATIC 0 Dolly Varden Well No. D-25RD Hilcorp Alaska, LLC Completed 06/2012 Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978;SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978;SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G-6 10,625' 10,627' 9,313' 9,314' 1/16/1979;SQZ 1/17/1979 G-7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G-7 10,648' 10,660' 9,331 9,340' 7/28/1979 G-7 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985;3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 1 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989; 11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979; 7/24/1981; 1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 1 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992;7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HB -4 1 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 1 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973; 3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 1 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 1 11,110' 11,140' 9,695' 9,719' 3/13-22/1973 11,126' 11,285' 9,708' 9,836' 11/24/1989 11,140' 11,150' 9,695' 9,727' 3/132-22/1973 11,150' 11,167' 9,727' 9,741' 1/27/1979 11,150' 11,187' 9,727' 9,757' 7/24/1981 E 11,150' 11,182' 9,727' 9,753' 11/13/1985 11,167' 11,187' 9,741' 9,757' 1/27/1979 11,200' 11,272' 9,768' 9,826' 1/27/1979; 7/24/1981 11,200' 1 11,285' 9,768' 9,836' 11/13/1985 Revised By: 1LL06/12/13 Hilcorp Alaska, LLC Hilcorp Alaska. LLC Well Operations Summary Well Name JAPI Number IWO Permit Number IStart Date End Date D-25RD 50-733-20247-01 178-087 7/4/2013 7/5/2013 Daily Operation i 07/04/13 - Thursday Pressure test equipment. Filling casing with FIW. Injectivity test. Mixed acid. Started pumping @ 1.2 BPM at 200 PSI. Finished pumping acid and spotted with 70 BBLS FIW just below the ESP. Acid spotted and well shut in for acid soak. Returned to production for 2 hours to displace acid. 07/05/13 - Friday Shut in ESP. Filling casing with FIW. Pumped two totes of SCW-8225 mixed with 110 bbls FIW chemical pumping complete @ 04:15. Pumped 614 bbls FIW overflush, cleaned up and turned well over to production. THE STATE GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 CONED 2m Ted Kramer S� � b Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-25RD Sundry Number: 313-332 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this Zb day of June, 2013. Encl. 14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAr 91; 9Rn 2C. 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Wel ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time/ Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ .4c i A Stimulate (] Alter Casing ❑ Other. rwn 2. Operator Name: 4. Current Wel Class: 5. Penn it to Dril Number. Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 178-087 , 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, AK 99503 50-733-20247-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit D-25RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018729 McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 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): .11,510 .10,021 -11,415 _ 9,941 11,290 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13-3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9-5/8" 8,155' 7,266' 9,440 psi 5,300 psi Liner 3,568' T' 11,506' 10,016' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 19.2# / L-80 7,629 Packers and SSSV Type: Packers and SSSV` MD (ft) and TVD (ft): Packers (see schematic) / SSSV - N/A Packers (see schematic) / SSSV - N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/28/2013 Oil R)' Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 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 I Phone (907) 777-8420 Date 6/21/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3)3-53a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS JUL - 120 Other: Spacing Exception Required? Yes ❑ No Z/ Subsequent Form Required: APPROVED BY THE COMMISSION Date: Approved by: COMMISSIONER / G•ZS"/3 RII�Gd I WAILonth, Sut . Form andForm 10-403 (Revised 10/2012) Appro a! fro the date of approval. Attach nt�s ii Du licate '�J1 4y • (ell Work Prognosis II: D-25RD Application Date: 6/21/2013 Well Name: D-25RD API Number: 50-733-20247-01 Current Status: Oil Producer Leg: Leg # A-1 (NE corner) Estimated Start Date: June 28,2013 Rig: N/A Reg. Approval Req'd: 10-403 Date 10-403 submitted: 6/21/13 Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 178-087 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) AFE Number: Budgeted Cost: Status: D-25RD is a Shut-in ESP producer that was shut in on the 11th of this month due to seeing scale formation in the production stream. This well is a scale former and completely scaled off last year. Objective: The objective is to pump an acid and Scale inhibition treatment in order to dissolve scale that has formed down hole followed by a scale inhibitor treatment that will protect the well from scale formation for one year. Pressures: Current BHP: 2,899 psi @ 7,738 MD, / 6,919' TVD Measured pressure at ESP Max. Expct'd BHP: 2,899 psi @ 7,738' MD/ 6,919 TVD Measured pressureat ESP Max. Anticipated Surface Pressure: of the pump. Procedure: 2,200 psi Limited to pressure output 1. Obtain a representative production test during the week prior to the squeeze treatment. 2. Contact TBPF 48 hours in advance. Complete Non -Produced Fluids Transfer and fax to TBPF prior to shipping any fluid. 3. Ensure that pump is recorded in Temporary Equipment Database — Use Engine # "185", Unit ID# - "Squeeze Pump Connex", S/N — "497578" 4. Verify that MSDS sheets are onsite for all chemicals and that safe handling procedures are followed. 5. Conduct safety meeting with platform foreman, operators, and pumping personnel to ensure safe operating procedures are followed. • Review mixing and pumping procedures prior to rigging up and complete JSA & Work Permit. • All hot work to be shut down on drill deck during pumping operations. • Implement Safe Practices Standard 7.16 "Well Servicing Operations" including the safety checklist. 6. Rig up pump, filters, and tanks. Verify tank location's can support tank with fluid. • Install a check valve in the treating line as close to well head as possible. • Monitor tubing pressure, casing pressures, pump rate. • Ensure that all equipment is grounded and bonded prior to any pumping or chemical transfers. Pressure test lines first at low and then high pressure. Use a low pressure of 500 psig and a high pressure of 2000 psig. • Test from pump to swab valve. • Pressure test from pump to master valve and production wing valve. • II Work Prognosis 11: D-25RD Application Date: 6/21/2013 • Bleed off pump pressure to verify that check valve holds. 8. Establish Injection into the Well with FIW. Once injection is established maintain a low steady rate until starting Squeeze. 9. Premix the Preflush — 5 drums WAW -5206 mixed 7.5% with 79 bbls FIW = 85.6 bbls 10. Pump preflush. 11. Pump 107 bbls 15 % HCL Acid 12. Pump 70 bbls FIW to displace Acid to below ESP Equipment 13. Shut in well for 6 hours for acid to soak. 14. Turn on ESP and run for 2 hours 15. Premix the Scale Inhibitor —12 drums SCW-8225 mixed 12.5% with 110 bbls A =126 bbls 16. Pump Scale Inhibitor Pill. 17. Pump FIW Overflush for 7 ft radial penetration (517 bbls plus 97 bbl tubing displacement 114 b 18. Shut in well for 12 hours for scale inhibitor to adhere and precipitate information. 19. Rig down pumping equipment. 20. Return well to production slowly to minimize swabbing the scale inhibitor back in from the well. Hileorp Alaska, 1.11: Tree connection: 4-1/16" 5,000# E 3- 4- 5-9 10 _ 11 ] 0/5/10: 2.70" GR tagged up at 10825'. IV V 12 • SCHEMATIC Holes in casing 3,280`& 5,645' 1 JSTT nm on B Hole in casing 8,202'- C; S,zos' •D G 11/08: Holes in tbg 8373',8376', and 8406'. 2, 3,4 10,625'- H-0 10627' Sqz. 200 H-1 sx H-2 Ratty cement above H-3 10,802' A H -4 Fill Cleaned Out to 11,091' H-5 PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° • Dolly Varden Well No. D-25RD Completed 06/2012 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,518' 9-5/8" 47 P-110 Butt 8.681 Surf 8,155' 7" 29 N-80 Butt 6.184 7,938' 11,506' TUBING DETAIL 31/2" 9.2 L-80 Hyd.533 2.992 Surf 7,629' Jewelry Detail No. Depth ID OD Item a 7,629' 2.9 5.5 Crossover b 7,631' 2.9 5.5 Discharge Pressure Head c 7,641' 2.9 5.5 Crossover d 7,643' 6.75 Discharge e 7,644' 6.75 Pump X 3-675 Pump MNL, Model: HPMTARType: 28HC7800, Overall Length: 40' f 7,699' 7.25 Motor - HMI/800, 725 Motor MNL, 4160 V/ 114A g 7,738' 8 Anode: 2 Chemical Line Checks, 2,500# Upper Scab Liner Assembly A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4 5.5 Anchor, Baker Mod. E-22 E 8,350' 4 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3-1/2" Butress Pin 5 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 6 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 7 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 8 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 9 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO -2, R-2, RK Latch 10 10,053' 3 4 Locator, Seal Assembly 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055 4 5.875 Packer, 7", Baker Mod."FB-1" (DP set- WL Correlated) A-2 10,058' 4 5 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) 1 10,835' 4 5.87 Baker Packer II 10,860' 2.813 3.88 'X' Nipple (2.813"), 3-1/2" Buttress 2.992 3.5 Scab Liner, 3-1/2", 9.2#, L-80, Buttress 10,920' 4 5.872 Baker Packer, Mod. F-1 EV�Zil 10,948' 2.75 3.87 'XN' Nipple (2.75"), 3-1/2" Buttress 10,960' 2.992 3.865 Wireline Entry Guide See Next Page for Perforation Information. Revised By: JLL 06/12/13 SCHEMATIC 0 Dolly Varden 4 'SWell No. D-25RD Hilcorp Alaska, LLC Completed 06/2012 Perforation Detail Zone Top (MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 71139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G-2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G-3 1 10,267' 10,285' 9,034' 9,048' 4/10/2000 G-4 1 10,322' 10,345' 9,078' 9,096' 4/10/2000 G-6 1 10,580' 10,593' 9,278' 9,288' 3/3/1973 G-6 1 10,590' 10,593' 9,285' 9,288' 3/5/1973;SQ7 3/7/1973 G-6 1 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G-7 1 0,638' 10,658' 9,323' 9,338' 1/9/1998 G-7 1 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G-7 1 10,648' 10,660' 9,331' 9,340' 7/28/1979 G-7 1 10,670' 10,690' 9,348' 9,363' 3/132-22/1973 HB -1 1 10;715' 10,778' 9,383' 9,433' 3/132-22/1973 HB -1 1 10,720' 10,730' 9,387' 9,395' 3/132-22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744 9,392' 9,406' 11/13/1985; 3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132-22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132-22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132-22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132-22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989;11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132-22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979;7/24/1981;1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13-22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132-22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992;7/28/1992 HB -3,4 1 11,010' 11,040' 9,616' 9,640' 3/132-22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HBA 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 HBA 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB- 1 11,062' 11,093' 9,657' 9,682' 1/30-31/1979; 11/13-17/1985 HB -4 1 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 1 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18-19/1973; 3/132-22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -0,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB-4ft11,140' 11,124' 9,695' 9,707' 11/24/1989 HB -4,511,140' 9,695' 9,719' 3/13-22/1973 HB -4,511,285' 9,708' 9,836' 11/24/1989 HB -511,150' 9,695' 9,727' 3/132-22/1973HB-511,167' 9,727' 9,741' 1/27/1979 HB -511,187' 9,727' 9,757' 7/24/1981HB-5 11,150 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979;7/24/1981 HB -5 11,200' 1 11,285' 9,768' 1 9,836' 11/13/1985 Revised By: ILL 06/12/13 , , STATE OF ALASKA OSKA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other CI Convert to ESP Performed: Alter Casing ❑ Pull TubingL Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well10 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development C Exploratory ❑ 178.087 " 6. API 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 50 -3 20247x01 ® �+ ( ^r 1 Anchorage, AK 99503 7. Property Designation (Lease Number): 8. Well Name and Number: Trading Bay Unit / ADL0018729 Dolly Varden / D-25RD JUL 18 2012 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): r Hemlock and Middle Kenai G Oil Pools AO(� GC 11. Present Well Condition Summary: Total Depth measured 11,510 feet Plugs measured feet true vertical 10,021 feet Junk measured 11,290 feet Effective Depth measured 11,415 feet true vertical 9,941 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13 -3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9 -5/8" 8,155' 7,268' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4 -1/2" 12.6# L -80 7,793' (MD) 6,966' (TVD) Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# N -80 10,126' (MD) 8,920' (TVD) Baker Mod F -1; Baker Mod.F; Baker Mod. FB -1, Baker Model FA; Baker Model F and Howco, x0O Packers and SSSV (type, measured and true vertical depth) 10,920 (MD) 9,545(TVD); 10,835 (MD) 9,478(TVD); 10,055' (MD) 8,862(TVD) 8,350 (MD) 7,432(TVD); 7,799 (MD) 6,971(TVD) and 285 (MD 2nsrtvn1 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 4 a i ) +9 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 162 746 3,790 920 150 Subsequent to operation: 266 141 6,227 110 140 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Developmenitf1 s Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil p „ 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: Contact Ted E. Kramer Printed Name Ted E. Kramer ) �. Title Operations Engineer 4 �� C. _. Signature -4f ' Phone 907 - 777 -8420 Date 7/18/2012 o ? A AS JUL 19 2Q Form 10-404 Revised 11/2011 Submit Original Only . 'n • • Dolly Varden Well No. D -25RD Haeorp Alaska, LLC Proposed Completion CASING DETAIL Tree connection: 4 - 1/16" 5,000# SIZE WT GRADE CONN ID TOP BTM 1 a 13 -3/8" 61 K -55 Butt. LT &C 12.515 Surf 2,518' 9 -5/8" 47 P -110 Butt 8.681 Surf 8,155' z.r tip 7" 29 N -80 Butt 6.184 7,938' 11,506' • CASING DETAIL 3 -1/2" 1 9.2 1 L -80 I Hyd. 533 1 2.992 I Surf I 7,629' Holes in casing Jewelry Detail "' 3,280`& 5,645' No. Depth ID OD Item 1 'NIT mn nn 50' CIW -DCB -ESP, 11 x 4 -1/2" IBT lift and Susp. Tbg Hngr 1 ' la 51' Crossover 4 -1/2" to 3 -1/2" a+ 1 b a 1b 7,641' Crossover to ESP *.* 2 2 7,643' ESP (Bottom @ 7,738) " 3 8,361' 3 4 Locator, Seal Assembly, 7.23' Long Y,, A Upper Scab Liner Assembly c. ,. A 7,799' 6 8.218 Packer, 9-5/8" Baker Mod. F (DP set) B ' B 7,895' 4.892 5.5 Crossover, 7" Buttress Box x 5 -1/2" 15.5# Hydril Pin ;F,, , Hole in 1 casing C 8,338' 4.375 5.63 Seal assembly, 5" Located in 5' Upper PBR _ 8,208' 8202'- D 8,349' 4 5.5 Anchor, Baker Mod. E -22 E 8,350' 4 5.875 Packer, 7" x 4 ", Baker Mod. "FA" E ►�� ► F 8,354' 4.5 5.53 Millout Extension, 4' Long w/ 4ea. 1" Holes .1, 0 , G 8,357' 4 5 Lower Seal Bore Extension, 14' Long 3 G 11/08: Holes 4 8,372' 2.992 5.57 Crossover, 5" LTC Box x 3 -1/2" Butress Pin 4 ' in tbg 5 8 400' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO -2, R -2, RK Latch MB 8373',8376', 5 -9 gm and 8406'. 6 8,802' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO -2, R -2, RK Latch 7 9,234' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO -2, R -2, RK Latch 10 .... 8 9,636' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO -2, R -2, RK Latch F illi A 20 A -1 9 10,007' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO -2, R -2, RK Latch =h A-2 10 10,053' 3 4 Locator, Seal Assembly 11 11 10,093' 2.813 3.88 Otis, 'X' Nipple, 2.813 12 10,126' 2.992 3.865 Wireline Entry Guide 12 = G -2, 3, 4 A -1 10,055' 4 5.875 Packer, 7 ", Baker Mod. "FB -1" (DP set- WL Correlated) A -2 10,058' 4 5 Seal Bore Extension 10 /5 /10: � _ 10,625 - Lower Scab Liner (DP set -WL Correlated) 2.70" GR H -0 10627' tagged up E. Sgz.200 I 10,835' 4 5.87 Baker Packer at 10825'. = H -1 SX II 10,860' 2.813 3.88 'X' Nipple (2.813 "), 3 -1/2" Buttress H -2 III 2.992 3.5 Scab Liner, 3 -1/2 ", 9.2 #, L -80, Buttress I .. N . . Ratty IV 10,920' 4 5.872 Baker Packer, Mod. F -1 cement V 10,948' 2.75 3.87 'XN' Nipple (2.75 "), 3 -1/2" Buttress II II Ma above VI 10,960' 2.992 3.865 Wireline Entry Guide III H -3 10,802' v _// See Next Pages for Perforation Information. Ali 1 H -4 Fill Cleaned Out to 11,091' ii H -5 ' Q -.' PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° REVISED by TDF: 7 -16 -2012 . , t • • Dolly Varden Well No. D -25RD Hilcora Alaska, LLC Proposed Completion Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date GGS 8,000' 8,002' 7,138' 7,139' 1/17/1979; SQZ 1/17/1979; SQZ 1/20/1979 GGS 8,170' 8,172' 7,281' 7,283' 12/7/1978; SQZ 12/8/1978 GGS 8,210' 8,212' 7,315' 7,316' 12/5/1978; SQZ 12/6/1978 G -2 10,185' 10,190' 8,968' 8,972' 4/10/2000 G -3 10,267' 10,285' 9,034' 9,048' 4/10/2000 G -4 10,322' 10,345' 9,078' 9,096' 4/10/2000 G -6 10,580' 10,593' 9,278' 9,288' 3/3/1973 G -6 10,590' 10,593' 9,285' 9,288' 3/5/1973; SQZ 3/7/1973 G -6 10,625' 10,627' 9,313' 9,314' 1/16/1979; SQZ 1/17/1979 G -7 10,638' 10,658' 9,323' 9,338' 1/9/1998 G -7 10,645' 10,660' 9,328' 9,340' 1/9/1989; 11/25/1989; 3/2/1991 G -7 10,648' 10,660' 9,331' 9,340' 7/28/1979 G -7 10,670' 10,690' 9,348' 9,363' 3/132- 22/1973 HB -1 10,715' 10,778' 9,383' 9,433' 3/132- 22/1973 HB -1 10,720' 10,730' 9,387' 9,395' 3/132- 22/1973 HB -1 10,724' 10,742' 9,390' 9,404' 1/9/1998 HB -1 10,726' 10,744' 9,392' 9,406' 11/13/1985; 3/2/1991 HB -1 10,726' 10,741' 9,392' 9,403' 7/28/1992 HB -1 10,727' 10,742' 9,392' 9,404' 3/8/1992 HB -1,2 10,730' 10,770' 9,395' 9,426' 3/132- 22/1973 HB -2 10,758' 10,773' 9,417' 9,429' 1/9/1998 HB -2 10,808' 10,823' 9,456' 9,468' 3/132- 22/1973 HB -2 10,850' 10,866' 9,489' 9,502' 3/132- 22/1973 HB -3 10,865' 10,880' 9,501' 9,513' 1/9/1989; 11/25/1989; 1/9/1998 HB -3 10,884' 10,894' 9,516' 9,524' 3/132- 22/1973; 11/13/1985 HB -3 10,884' 10,895' 9,516' 9,525' 1/9/1998 HB -3 10,885' 10,895' 9,517' 9,525' 1/9/1989; 11/24/1989 HB -3 10,914' 10,934' 9,540' 9,556' 3/132- 22/1973 HB -3 10,962' 11,016' 9,578' 9,620' 7/28/1979; 7/24/1981; 1/9/1998 HB -3 10,970' 10,990' 9,584' 9,600' 3/13- 22/1973 HB -3 10,970' 11,016' 9,584' 9,620' 11/13/1985 HB -3 10,980' 11,010' 9,592' 9,616' 3/132- 22/1973 HB -3 11,000' 11,015' 9,608' 9,620' 4/22/1992; 7/28/1992 HB -3,4 11,010' 11,040' 9,616' 9,640' 3/132- 22/1973 HB -4 11,030' 11,050' 9,632' 9,647' 1/9/1989; 11/25/1989 HB -4 11,030' 11,070' 9,632' 9,663' 11/24/1989 HB -4 11,030' 11,053' 9,632' 9,650' 3/2/1991 HB -4 11,030' 11,060' 9,632' 9,655' 3/8/1992; 7/28/1992 HB -4 11,031' 11,062' 9,632' 9,657' 7/28/1979 HB -4 11,031' 11,125' 9,632' 9,707' 7/24/1981 HB -4 11,031' 11,123' 9,632' 9,706' 11/13/1985 REVISED by TDF: 7 -16 -2012 . ‘ ii • • Dolly Varden Well No. D -25RD Hilcorp Alaska, LLC Proposed Completion I Perforation Detail Cont. Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date HB -4 11,050' 11,070' 9,647' 9,663' 11/23/1989 HB -4 11,053' 11,060' 9,650' 9,655' 3/2/1991 HB -4 11,062' 11,093' 9,657' 9,682' 1/30- 31/1979; 11/13- 17/1985 HB -4 11,067' 11,285' 9,661' 9,836' 11/15/1993 HB -4 11,070' 11,097' 9,663' 9,685' 3/2/1991 HB -4 11,077' 11,100' 9,669' 9,687' 11/13/1985 HB -4,5 11,080' 11,200' 9,671' 9,768' 2/18- 19/1973; 3/132- 22/1973 HB -4,5 11,088' 11,285' 9,678' 9,836' 6/14/1996 HB -4,5 11,090' 11,285' 9,679' 9,836' 4/22/1992 HB -4 11,094' 11,125' 9,682' 9,707' 1/27/1979 HB -4 11,100' 11,123' 9,669' 9,706' 11/13/1985 HB -4,5 11,105' 11,285' 9,691' 9,836' 2/20/1992 HB -4,5 11,108' 11,285' 9,694' 9,836' 2/28/1991 HB -4 11,110' 11,130' 9,695' 9,711' 1/9/1989 HB -4 11,110' 11,124' 9,695' 9,707' 11/24/1989 HB -4,5 11,110' 11,140' 9,695' 9,719' 3/13- 22/1973 HB -4,5 11,126' 11,285' 9,708' 9,836' 11/24/1989 HB -5 11,140' 11,150' 9,695' 9,727' 3/132- 22/1973 HB -5 11,150' 11,167' 9,727' 9,741' 1/27/1979 HB -5 11,150' 11,187' 9,727' 9,757' 7/24/1981 HB -5 11,150' 11,182' 9,727' 9,753' 11/13/1985 HB -5 11,167' 11,187' 9,741' 9,757' 1/27/1979 HB -5 11,200' 11,272' 9,768' 9,826' 1/27/1979; 7/24/1981 HB -5 11,200' 11,285' 9,768' 9,836' 11/13/1985 REVISED by TDF: 7 -16 -2012 • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -25RD 507332024701 178 -087 6/3/12 6/13/12 wily Operations: 06/02/2012 - Saturday MIRU wireline to set tbg plug for csg integrity test as per revised program to secure Sundry Permit to proceed with well conversion. RIH w/ 2.80" GR. Tag at 7,828', work to 7,849' and POOH. RIH w/ 2.76" GR work thru tight spots at 8,387', 8,865', 9,198', 9,861',9,960' and tag at 10,801'. Confer with Operations Engineer to RD Slick line. Proceed with RU of CUDD. 06/03/2012 - Sunday 12:45 6/2/12 -Left 1st 48 hr notification msg of upcoming BOPE test scheduled for 6/4/12 to AOGCC - Jim Regg. 06/04/2012 - Monday Left 2 nd notice on AOGCC Jim Regg phone of upcoming BOPE test est 12:00 pm 6/4/12. RU E -line unit. PT lub 250 psi low /2,500 psi high. RIH with 1- 9/16" - 6' gun loaded with 20 shots at 1/2 "- 5/8 ". RIH tie in with Tbg tally dated 3/30/00. Log onto depth at 8,330' (CCL 4' to top of gun) with shots from 8,334' - 8,340' and fired guns. No surface indication gun fired. Acted like a dead short. POOH. Break down tool, water in firing head, rebuild gun. PT lub 250 psi low /2, 500 psi high. RIH with 1- 9/16" - 4' gun loaded with 13 shots at 1/2 " -5/8 ". Log onto depth at 8,296'(CCL 4' to top of gun) shots from 8,300' - 8,304'. Had surface indication gun fired. POOH. Break out lub, verified all shots fired. R/D a -line. NOTE: Left 2nd 24 hr notice at 0845 on AOGCC Jim Regg phone of upcoming BOPE test est 1200 hrs 6/4/12. Notified Prudhoe Bay AOGCC Insp Chuck C at 2100 and e- mailed AOGCC Jim Regg of probable delay of BOPE test on 6/4/12. 06/05/2012 - Tuesday Prep t/ build salt pill. Build 50 bbl sized salt pill. Spot 48 bbl size salt pill @ top of perfs close ann squeeze 25 bbls into perfs @ 3 bpm, 750 psi fcp. R/d circ lines & set BPV. N/D tree, N/U DSA, riser spools & BOP equip. NOTE: @ 9:00 AOGCC Jim Regg waived witness of upcoming BOPE test. 06/06/12 - Wednesday Continue NU BOPE. PU 3 -1/2 test its. Install test jt in hgr w /milling clamp installed to prevent test jt from releasing from damaged hgr thrds. Install IBOP. Begin BOPE test. Test bop's w/4 -1/2 TJ, 250 low, 3,000 high, annular, top VBR's, lower VBR's & choke line valves. Pull 4 -1/2 TJ, pull BPV & set TWC. Fill stack & test blinds 250 low, 3,000 high. All BOPE components passed / no failures. M/U C -DIM Tubing spear assy. latch up & pull hanger free @ 120k. Tested BOPE as per AOGCC- CUDD - Hilcorp SOP- test all components to 250 / 3,000 BOPE passed. Witness of test waived by Jim Regg AOGCC 06/07/2012 - Thursday Continue LD hgr and land jt. Release fishing grapple f /hgr. LD fishing BHA and mill clamp. POOH. LD 4 -1/2 tbg with control line for SSSV. LD SSSV recovered 19 of 21 SS bands for CL. Change over to two legs. Continue LD 4 -1/2 tbg to 7,256'. Pull remaining 4 -1/2 tubing. Change out handling equipment. 06/08/2012 - Friday PU / MU Halliburton 9 -5/8 RTTS - PU 4 HT -38 DP. RIH with RTTS and PU 3 -1/2 tbg. Cont RIH with RTTS - set at 7,233' with circulating valve open - on line with pump load well down tbg up ann with 4 bbls FIW. Close circ vlv. Test 9 -S /8 csgto r� 1,500 psi with FIW hold for 37 mins. Release pressure. Release RTTS. POOH. SDFN. (fi 06/09/2012 - Saturday POOH with RTTS to 4" HT38. Change dies in stationary slips to 4 ". R/D Hawkjaws and R/U Tubing tongs. Continue POOH to RTTS. Break and lay down RTTS. P/U M/U Overshot BHA. RIH with 4" HT -38 work string. R/D Hawkjaws and R/U tubing tongs. TIH to 1,536'. Change out slip dies to 3 -1/2 ". TIH to 2,446'. Continue TIH to top of fish @ 7,233' and engage same. Pull up to 100K for tubing cut. R/U E -line. RIH with 2.0" GR to 8,490'. POOH. C/O tools for radial torch. RIH and correlate on depth @ 8,340'. Cut tubing. No movement on string. POOH with e-line. OOH w/e -line. Cutter did fire. M/U 2.0" LIB/GR. 06/10/2012 - Sunday RIH with 2.0" LIB /GR to 8,490' to insure no obstructions from tubing cut. Consult with supervisor to determine best area to cut tubing. Mobilize free -point to platform. M/U 1" free -point tool w /ccl and 1- 11/16" weight bar. Run free -point tool and locate free point @ 8,230'. POOH and M/U 2" radial torch cutter. RIH and correlate on depth @ 8,235'. Pull string up to 110K and fire radial torch cutter. Good indication of cut. Pull e-line up hole 300'. Work string up to 130K at which time string weight dropped to 96K. Cut accomplished. POOH and R/D e-line. New top of fish = 8,235'. POOH with fish. R/D tubing tongs and R/U Hawkjaws. Finish POOH and lay down fish (full recovery from tubing cut). AOGCC was notified of upcoming BOP test and granted waiver in it's entirety. 06/11/2012 - Monday P/U ESP equipment to work basket and window. Service equipment. Scope in gin pole. Pick up sections of ESP and prepare same for running in the hole. 06/12/2012 - Tuesday RIH 4 stands to 263'. RIH with ESP to 6,136'. Meg test @ 1,000' intervals. Change out cable spools. Splice ESP cable. Continue RIH with ESP to 7,700'. M/U cross - overs, c/o slips, install tubing hanger and landing joints. Make final splice at tubing hanger in window. 06/13/12 - Wednesday Make final splice and prep tubing hanger in work window. Land tubing hanger. Run in lock down pins. Test hanger to 5,000 lbs. Change out casing valve. Lay down remaining stands of 3 -1/2" 533 tubing. Scope in gin pole. N/D flow nipple and BOPE. Meg test ESP connections and prepare tubing spool for tree. Nipple up tree. Install wing valves and test void and tree 250 psi Low / 5,000 psi High. Assist with installing flow lines on D -25RD. Return to production. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D -25RD 507332024701 178 -087 6/3/12 Deity Operations: 06/13/12 - Wednesday Make final splice and prep tubing hanger in work window. Land tubing hanger. Run in lock down pins. Test hanger to 5,000 lbs. Change out casing valve. Lay down remaining stands of 3 -1/2" 533 tubing. Scope in gin pole. N/D flow nipple and BOPE. Meg test ESP connections and prepare tubing spool for tree. Nipple up tree. Install wing valves and test void and tree 250 psi Low / 5,000 psi High. Assist with installing flow lines on D -25RD. Return to production. 06/14/2012 - Thursday No operations to report. • 06/15/2012 - Friday No operations to report. 06/16/2012 - Saturday No operations to report. 06/17/2012 - Sunday No operations to report. 06/18/2012 - Monday No operations to report. 06/19/2012 - Tuesday No operations to report. 21.1 JUL 2 3 01Z • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D -25RD 507332024701 178 -087 6/3/12 Daily Operations: 06/06/12 - Wednesday Continue NU BOPE. PU 3 -1/2 test jts. Install test jt in hgr w /milling clamp installed to prevent test jt from releasing from damaged hgr thrds. Install IBOP. Begin BOPE test. Test bop's w/4 -1/2 TJ, 250 low, 3,000 high, annular, top VBR's, lower VBR's & choke line valves. Pull 4 -1/2 TJ, pull BPV & set TWC. Fill stack & test blinds 250 low, 3,000 high. All BOPE components passed / no failures. M/U C -DIM Tubing spear assy. latch up & pull hanger free @ 120k. Tested BOPE as per AOGCC- CUDD - Hilcorp SOP- test all components to 250 / 3,000 BOPE passed. Witness of test waived by Jim Regg AOGCC 06/07/2012 - Thursday Continue LD hgr and land jt. Release fishing grapple f /hgr. LD fishing BHA and mill clamp. POOH. LD 4 -1/2 tbg with control line for SSSV. LD SSSV recovered 19 of 21 SS bands for CL. Change over to two legs. Continue LD 4 -1/2 tbg to 7,256'. Pull remaining 4 -1/2 tubing. Change out handling equipment. 06/08/2012 - Friday PU / MU Halliburton 9 -5/8 RTTS - PU 4 HT -38 DP. RIH with RTTS and PU 3 -1/2 tbg. Cont RIH with RTTS - set at 7,233' with circulating valve open - on line with pump load well down tbg up ann with 4 bbls FIW. Close circ vlv. Test 9 -5/8 csg to 1,500 psi with FIW hold for 37 mins. Release pressure. Release RTTS. POOH. SDFN. 06/09/2012 - Saturday POOH with RTTS to 4" HT38. Change dies in stationary slips to 4 ". R/D Hawkjaws and R/U Tubing tongs. Continue POOH to RTTS. Break and lay down RTTS. P/U M/U Overshot BHA. RIH with 4" HT -38 work string. R/D Hawkjaws and R/U tubing tongs. TIH to 1,536'. Change out slip dies to 3 -1/2 ". TIH to 2,446'. Continue TIH to top of fish @ 7,233' and engage same. Pull up to 100K for tubing cut. R/U E -line. RIH with 2.0" GR to 8,490'.POOH. C/O tools for radial torch. RIH and correlate on depth @ 8,340'. Cut tubing. No movement on string. POOH with e-line. OOH w/e -line. Cutter did fire. M/U 2.0" LIB /GR. L. M J U L I € 2012 06/10/2012- Sunday RIH with 2.0" LIB /GR to 8,490' to insure no obstructions from tubing cut. Consult with supervisor to determine best area to cut tubing. Mobilize free -point to platform. M/U 1" free -point tool w /ccl and 1- 11/16" weight bar. Run free -point tool and locate free point @ 8,230'. POOH and M/U 2" radial torch cutter. RIH and correlate on depth @ 8,235'. Pull string up to 110K and fire radial torch cutter. Good indication of cut. Pull a -line up hole 300'. Work string up to 130K at which time string weight dropped to 96K. Cut accomplished. POOH and R/D a -line. New top of fish = 8,235'. POOH with fish. R/D tubing tongs and R/U Hawkjaws. Finish POOH and lay down fish (full recovery from tubing cut). AOGCC was notified of upcoming BOP test and granted waiver in it's entirety. 06/11/2012 - Monday P/U ESP equipment to work basket and window. Service equipment. Scope in gin pole. Pick up sections of ESP and prepare same for running in the hole. 06/12/2012 - Tuesday RIH 4 stands to 263'. RIH with ESP to 6,136'. Meg test @ 1,000' intervals. Change out cable spools. Splice ESP cable. Continue RIH with ESP to 7,700'. M/U cross - overs, c/o slips, install tubing hanger and landing joints. Make final splice at tubing hanger in window. • • similizE orf iii,\IslA 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 Ted E. Kramer Senior Operations Engineer i ri., o1I7 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 - Re: Hemlock Field, Middle Kenai G Pool, Dolly Varden D -25RD Sundry Number: 312 -190 Dear Mr. Kramer: 5iLiktritiED JUL 012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sinc - re ; a t 0. u om ssioner DATED this day of June, 2012. Encl. 1 0 w C • RECEIVED l0 1 � MAY 2 12012 STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION 011.. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing p Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Convert to ESP Q - 2. Operator Name: 4. Current Well Class: 5. Pemiit to pal Number. Hilcorp Alaska, LLC Development CI Exploratory ❑ 178 -087 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50 -733- 20247 -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 cianges: Spacing Exception Required? Yes ❑ No o DoNy Varden / D-25RD • 9. Property Designation (Lease Number): 10. Field / Pool(s): Trading Bay Unit / ADL 0018729 . Hemlock/Mid Kenai G -Zone 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): 11,510 • 10,021 - 11,415 9,941 11,290' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,518' 13 -3/8" 2,518' 2,449' 3,090 psi 1,540 psi Intermediate Production 8,155' 9 -5/8" 8,155' 7,268' 9,440 psi 5,300 psi Liner 3,568' 7" 11,506' 10,016' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached See Attached 4 -1/2" & 3 -1/2" 12.6# L-80, Buttress & 9.2# N-80, Buttress 7,793 & 10,126 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Mod. F -1; Baker Mod.F; Baker Mod. FB -1; Baker Model FA; Baker Model F and Howco, XXO 10,920 (MD) 9,545(TVD); 10,835 (MD) 9,478(TVD), 10,055' (MD) 8,862(1 VD) 8,350 (MD) 7,432(1VD), 7,799 (MD) 6,971(TVD) and 285 (MD) 285(TVD) 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: Commencing Operations: 5/28/2012 Oil f/ . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: C Z., • 1 2...- WINJ ❑ GINJ ❑ WAG ❑ Abandoned CI Commission Representative: 6 S, 4_�.. " GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is tru and correct to the best of my knowledge. Contact Ted E. Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature ��< �' - Phone 907 - 777 -8420 Date 5/21/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,� 1.--1 0 Plug Integrity ❑ BOP Test X Mechanical Integrity Test ❑ Location Clearance ❑ Other: — 8 o p f- /' 3 000 I751., r N o h I 4.-1 (C fot el 5 Subsequent Form Required: - J `5/ -el S/ ✓7 p I �t ✓ j 1✓' /--e i s 1" rte rJ l "� APPROVED BY `�' Approved by: . ,F.,( / COMMISSI ONER THE COMMISSION Date: � '`' � � II 1, ZYg ReDAAS JUN • • 112 2U 12 g Y Z -; Fo rm 10403 Revised 1/2010 ` { Submit in Duplicate 7 A • • Dolly Varden D -25RD Actual Perforations 5/21/2012 Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments G -2 10,173' 10,190' 8,958' 8,971' 17' G -3 10,267' 10,285' 9,034' 9,048' 18' G -4 10,322' 10,345' 9,078' 9,095' 23' HB -0 10,645' 10,660' 9,324' 3,940' 15' HB -1 10,726' 10,744' 9,391' 9,406' 18' HB -3 10,865' 10,880' 9,501' 9,513' 15' Isolated by Scab Liner HB -3 10,884' 10,895' 9,516' 9,525' 11' Isolated by Scab Liner HB -4 10,962' 11,016' 9,578' 9,620' 54' HB -4 11,030' 11,130' 9,632' 9,711' 100' HB -5 11,150' 11,187' 9,727' 9,757' 37' HB -5 11,200' 11,285' 9,767' 9,836' 85' 393' • McArthur River Unit D -25RD Hilcorp Alaska, LLC 5/20/12 Well Summary Page Obiective: 1 To convert the above well from gas lift to an ESP completion utilizing the CUDD Hydraulic Work Over Unit. Current Well Status: Producing on gas lift. General Information: .Miffr MGO —( 371 J(. 1 ) 7 67' I2 i G Max Down Hole Pressure: 3,800 psi @ 9336' TVD (Based on 2009 shut in bottom hole pressure survey taken during the redoubt volcano shutdown) 1 MASP = 0 psi (based on a pressure gradient of 0.440 psi per foot of true vertical depth) Well is equipped with an SSV and will be after the workover. BOP Configuration: see attached drawing. Tree Sketches: See attached drawings for both current and proposed. Engineer Contact Information: Ted Kramer — phone 907 — 777 — 8420 E -Mail: tkramer @hilcorp.com Pano 1 nf 7 • • McArthur River Unit D -25RD Hilcorp Alaska, LLC 5/20/12 PROCEDURE: 1. MIRU CUDD Hydraulic Workover Unit. 3O 2. ND wellhead and NU BOP stack is. Pressure test BOP to 250 pounds low /256trpounds high. ✓ Note: notify AOGCC 48 hours in advance of test for witness. ✓' 3. RIH with tubing punch and punch tubing ( + / -) 40 feet above the FA Packer. 4. Reverse circulate one tubing volume of FIW. 5. Monitor fluid loss and adjust loss to acceptable level by pumping graded rock salt (or other acceptable fluid loss material) pill and FIW (well will not flow). 6. RIH with tubing cutter on E- line to ( + / -) 8,345 feet and cut tubing. 7. POOH with 4 1/2 inch X 3 1/2 inch tubing string and lay down same. (Note: conduct ESP cable cutting drill on 3 1/2 inch t bing as it is being pulled from the well) --°�' 1L3'F G45 ao 4� - a p fb / SvVrsG Cad +-,J \ 8. MU / PU ESP. 9. RIH with ESP and cable on 3 1/2 inch 9.3 # L 80 HYD 533 IJ PCID tubing and sef the bottom of the unit at 7749 feet ( + / -). r 10. Landed ESP and nipple down BOP. 11. NU ESP tree. 12. Turn well over to production. Dona 7 .,f 1 II 0 Dolly Vn Well No. 25RD Hilcorp Alaska, LLC Actual Completion 5/00 Tree connection: 4 -1/16" 5,000# CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. - 13 -3/8" 61.0 K -55 Butt. LT &C 12.515 Surf 2,518' 1 9 -5/8" 47 P -110 Butt 8.681 Surf 8,155' 4' }'� 7" 29 N -80 Butt 6.184 7,938' 11,506' t' 2 '# Tubing: II 4 -1/2" 12.6 L -80 Butt 3.958 Surf 7,793 3 3 -1/2" 9.20 N -80 Butt 2.992 7,789' 10,126' ' �' >' Holes in casing 3,280'& JEWELRY DETAIL 4 5,645' NO. Depth ID OD Item T JSTT nm on j. 5 40.87' 4 -1/2" Cameron Type DCB 8rd X 8rd Tbg Hngr }"�' 6 1 285' 3.813 6.125 SSSV, Howco, XXO, (3.813" I.D.) }`1 7 � 2 2,349' 3.883 7.063 GLM, 4 -1/2 ", Camco MMG, 1 -1/2" R -2 Valve RK Latch i 8 . 3 3,726' 3.883 7.063 GLM, 4 -1/2" Camco MMG, 1 -1/2" R -2 Valve RK Latch ►, N A irt' 4 4,791' 3.883 7.063 GLM, 4 -1/2" Camco MMG, 1 -1/2" R -2 Valve RK Latch ,a 4, 9 * 5 5,727' 3.883 7.063 GLM, 4 -1/2" Camco MMG, 1 -1/2" R -2 Valve RK Latch B ' ` 6 6,537' 3.883 7.063 GLM, 4 -1/2" Camco MMG, 1 -1/2" R -2 Valve RK Latch i 7 7,248' 3.883 7.063 GLM, 4 -1/2" Camco MMG, 1 -1/2" R -2 Valve RK Latch +, 1:,: Hole in 0 casing 8 7,796' 3.000 7.500 Fluted Locator, 7.5" O.D. 8,202'- C 8,208' 9 7,836' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch MO lo)-•... 10 8,361' 3.000 4.000 Locator, Seal Assembly, 7.23' Long E ��� ' ��t � F CVO o O" Upper Scab Liner Assembly 10 _ : G A 7,799' 6.000 8.218 Packer, 9 -5/8" Baker Mod. F (DP set) 11/08: Holes 11 in tbg B 7,895' 4.892 5.500 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin =' 8373',8376', C 8,338' 4.375 5.630 Seal assembly, 5" Located in 5' Upper PBR 12 -16 and 8406'. D 8,349' 4.000 5.500 Anchor, Baker Mod. E -22 lil E 8,350' 4.000 5.875 Packer, 7" x 4 ", Baker Mod. "FA" 17 F 8,354' ran ❑1 5.530 Millout Extension, 4' Long w/ 4ea. 1" Holes =,_, _„ • -1 G 8,357' 4.000 5.000 Lower Seal Bore Extension, 14' Long I_' _II! A -2 11 8,372' 2.992 5.570 Crossover, 5" LTC Box x 3-1/2" Butress Pin 18 12 8 400' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 13 8,802' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 19 0 G -2, 3,4 14 9,234' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 15 9,636' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 10/5/10: 14 10,625'- 16 10,007' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 2.70" GR = H -0 10627' 17 10,053' 3.000 4.000 Locator, Seal Assembly tagged up = Sqz. 200 at 10825'. ° H sx 18 10,093' 2.813 3.880 Otis, `X' Nipple, 2.813 H -2 19 10,126' 2.992 3.865 Wireline Entry Guide I „ ' / 1 Ratty c cement A -1 10,055' 4.000 5.875 Packer, 7 ", Baker Mod. "FB -1" (DP set - WL Correlated) II a above H -3 10,802' A -2 10,058' 4.000 5.000 Seal Bore Extension 111 i IV //- - / Lower Scab Liner (DP set -WL Correlated) V Mill s'a I 10,835' 4.000 5.870 Baker Packer Alit II 10,860' 2.813 3.880 `X' Nipple (2.813 "), 3 -1/2" Buttress H 4 Fi Cleaned III 2.992 3.500 Scab Liner, 3 -1/2 ", 9.2 #, L -80, Buttress Out to 11,091' IV 10,920' 4.000 5.872 Baker Packer, Mod. F -1 o. 4 . 0.. V 10,948' 2.750 3.870 'XN' Nipple (2.75 "), 3 -1/2" Buttress I VI 10,960' 2.992 3.865 Wireline Entry Guide al H -5 Perforation Data See Perforation Data Sheet PBTD = 11,415' TD = 11,506' MAX HOL ANGLE = 39.75° C: \Users \tfouts\Desktop\Proposed Schematics\D -25RD Schematic 05- 21- 2012.doc REVISED: 5 -21 -2012 DRAWN BY: TDF II • Dolly V n Well No. 25RD Hilcorp Alaska, LLC Proposed Completion CASING AND TUBING DETAIL Tree connection: 4- 1/16" 5,000# SIZE WT GRADE CONN ID TOP BTM. 13 -3/8" 61.0 K -55 Butt. LT &C 12.515 Surf 2,518' ' 9 -5/8" 47 P -110 Butt 8.681 Surf 8,155' pia 1 ', Z 5 IC ,,, 7" 29 N -80 Butt 6.184 7,938' 11,506' s 1 i 2 ` r Tubing: 4 -1/2" 12.6 L -80 Butt 3.958 Surf 7,793' 3 -1/2" 9.20 N -80 Butt 2.992 7,789' 10,126' s' Holes in casing 4 ; 3,280'8c JEWELRY DETAIL 5,645' NO. Depth ID OD Item k INSTT mn on 1 +/- 7,649' 2.992 3 -1/2" Hydril 533 IS IPC Tubing 2 +/- 7,749' Baker ESP Top @ +/ -7,649 smor = > e, e, i . i' , r Hole in 1 casing _ 8,202'- 0 8,208' D E ��� I►M� F Upper Scab Liner Assembly m ' i G A 7,799' 6.000 8.218 Packer, 9 -5/8" Baker Mod. F (DP set) ' 11/08: Holes 11 in tbg B 7,895' 4.892 5.500 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin E: 8373',8376', C 8,338' 4.375 5.630 Seal assembly, 5" Located in 5' Upper PBR 12 -16 = and 8406'. D 8,349' 4.000 5.500 Anchor, Baker Mod. E -22 _ ; E 8,350' 4.000 5.875 Packer, 7" x 4 ", Baker Mod. "FA" 17 F 8,354' 4.500 5.530 Millout Extension, 4' Long w/ 4ea. 1" Holes _�, A -1 G 8,357' 4.000 5.000 Lower Seal Bore Extension, 14' Long A -2 11 8,372' 2.992 5.570 Crossover, 5" LTC Box x 3-1/2" Butress Pin 18 I h s*a 12 8 400' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch I■ 13 8,802' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch G 2, 3, 4 14 9,234' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 15 9,636' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 10/5/10: 10,625'- 16 10,007' 2.867 5.968 GLM, 3 -1/2" McMurry Macco, SFO-2, R -2, RK Latch 2.70" GR = H -0 10627' 17 10,053' 3.000 4.000 Locator, Seal Assembly tagged up Sqz. 200 = at 10825'. H sx 18 10,093' 2.813 3.880 Otis, `X' Nipple, 2.813 E. ri H -2 19 10,126' 2.992 3.865 Wireline Entry Guide I / / . 1 Ratty cement A -1 10,055' 4.000 5.875 Packer, 7 ", Baker Mod. "FB -1" (DP set- WL Correlated) © H -3 II A -2 10,058' 4.000 5.000 Seal Bore Extension 10 a bove ,802 ' III IV ~ Low er Scab Liner (DP set -WL Correlated) IJ I 10,835' 4.000 5.870 Baker Packer ■ II 10,860' 2.813 3.880 `X' Nipple (2.813 "), 3 -1/2" Buttress H -4 Fill Cleaned III 2.992 3.500 Scab Liner, 3 -1/2 ", 9.2 #, L -80, Buttress Out to 11,091' IV 10,920' 4.000 5.872 Baker Packer, Mod. F -1 ■ ∎' V 10,948' 2.750 3.870 AN' Nipple (2.75 "), 3 -1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide oii H -5 Perforation Data See Perforation Data Sheet PBTD = 11,415' TD = 11,506' MAX HOLE ANGLE = 39.75° C: \Users \tfouts\Desktop\Proposed Schematics\D -25RD Proposed Schematic 05- 21- 2012.doc REVISED: 5 -21 -2012 DRAWN BY: TDF • Dolly Varden Platform 2012 BOP Stack 05/15/2012 Ililrllrp tlni11e.1.1.(: Dolly Varden 2012 ESP Workovers BOP Drawing (Cudd) D -12 and D -25 4.54' • Hydril • GK 13 518 -5000 tit 111 1111/11/1 I11 111 111 111 111 4.67' — • IM • —° 2 7/8 -5 variables mar •ster bon. -tson •. — Blind Shear lit 111111 ti1 111 111'mu 111 2.00 I :111 I I y �ll •OI 111 al Ilt 111 191 r 111 111 111 111 tat 2.83' • —° 2 7/8 -5 variables • 119 111 111111 191 1. 7' 111 11111I 111 111 Drill deck Riser 13 5/8 5M FE 14.20' X 13 5/8 5M FE 111 111 191 111 111 III 111 111 111 111 Spacer spool 2.16' 135/85MFEX 135/85M Ili Ill 1/1111111 FE 111 11111I 111 III Spacer spool 2.00' 13 5/8 5M FE X 13 5/8 5M 111 111 111 t 11 111 FE UOCD 111 111111111 111 Crossover spool 1.41' 1227 111 ;1111111111 135/85MFEX 11 5M FE Top of wellhead @ 18.60' below deck • Dolly D -25RD Varden Platform 05/21/2012 Ilikorp %NA . 1 1 Dolly Varden Tubing hanger, CIW -DCB- BHTA, CIW, w/ internal FBB, 11 X 4 1 /2 EUE Iift X 4 133/8X95/8X41/2 knockup cap, 4 1/16 5M FE 1 /2 BTC susp, w/ 4" type H BPV, 1/8 non continuous control line, 7" extended neck prep iv 11 Ili Installed 08/1999 0 Valve, CIW -F, 4 1/16 5M i. ,, 0 ,, 0 FE, HWO, EE trim , y Tree, Block, CIW -F, 11 5M r, � © 11 1 X 4 1/16 5M run X 3 1/8 ,. _ F. i al 5M wing, double master, `. wing valve, EE trim mom prepped for 7" FBB type hanger neck, w/ 1 /2 control line exit CA *,;1 Void test good crt rrt 250 /5000psi - ' _,_ 10/19/2009� 1 _.: ■ r°:6 Tubing head, CIW -DCB, me I!1 Valve, CIW -F, 2 1/16 5M 135/83MX 11 5M,w /2 FE HWO, AA trim 2 1/16 5M SSO, X bottom, Im1i .?. ' N 1 N style lockpins i . , ` ®' 111 111 11.1 • F � - ,s Valve, CIW -F, 2 1/16 5M Casin head, CIW -WF, FE HWO AA trim g 1I1 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 ( , 4 10 `1 i t i�l %� 1 — ..A. �1 ° ° v - I L II • • Dolly Varden Platform D -25RD Proposed 05/21/2012 Iliir orp %IAA *. 1.1.1: BHTA CIW, 4 1/16 5M FE X Dolly Varden Cameron internal blanking nut Tubing hanger, CIW -DCB- ESP, 11 X4''AIBT lift and 133/8X95/8X41/2 MAP susp,w /4" type H BPV Ill profile, 5'/4 EN, 2- 3/8 II! 1' continuous control line ports, prepped for BIW ,187 penetrator Valve, swab, WKM -M, //e' 0 p o Cross, stdd, 4 1/16 5M X 41 /165MFE,HWO, LIAM / 31185MX 21/165M T -24 e Valve, wing, WKM -M, - /d.; ' 1 - 2 1/16 5M FE, HWO, tv 01 Valve, WKM -M, 3 1/8 5M FE, T -24 ® o - I . _ w/ MA 16 operator Valve, lower master, WKM -M, '* 4 1/16 5M FE, HWO, T -24 1.1 Adapter, CIW - Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5' /4 ESP neck, 2 -' /2 npt continuous _ i+. control line ports Tubing head, CIW -DCB, '— —' 13 5/8 3M X 11 5M, w/ 2- ''!I 1 ril- 2 1/16 5M SSO, X bottom, its 1 1 Valve, WKM -M, 2 1/16 5M FE, installed in 08/1999 HWO, DD N style lockpins r © 0 - I 1■ , c ,, o . ° i . , Qty 2 II ' a1 MI il■ I I Casing head, CIW -WF, ii? 13 5/8 3M X 13 3/8 casing Valve, CIW F, 2 1/16 5M thread bottom, w/ 2- 2 1/16 1 11 tip FE, HWO, AA trim 5M EFO, CA slips installed s 0) , in head I 11 '/I�1i�l ■� - i.: MINK IV lir • • TONY KNOWLES, GOVERNOR • ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3192 PHONE: (907) 279 -1433 FAX; (907) 276 -7542 June 20, 2000 Chris Meyers /Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 9961 1 Re: No -Flow Verification MRF Wells D -25R and D -42 Gentleman: On June 16, 2000 our inspector Lou Grimaldi witnessed "no -flow test on UNOCAL's McArthur River Field TBU wells D -25R and D -42. Prior to his arrival, both wells had been routed to the "Well Clean" tank, which is about 2 psig back pressure. Both wells had bled down when Lou arrived. He observed both wells for several hours and recorded gas rates far below the "no -flow" limit of 900 scf /hr. He noted rates of 190 to 600 scf /hr on D -25R and 180 to 275 scf /hr on D -42. Neither well had any fluid production. He recommended that "no -flow" status be given to both wells. McArthur River. Field TBU wells D -25R (178 -087) and 0-42 (183 -053) meet the criteria of "no- flow" performance test and as such, are considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A) they are not required to have a fail -safe automatic SSSV, however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Sincerely, iltr Blair E. Wondzell Sr. Petroleum Engineer • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, DATE: June 16, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor ges(oO FROM: Lou Grimald&'- SUBJECT: No Flow Verification Petroleum In pector Unocal, Dolly Varden McArthur River Field D -42 PTD #183 -053 D -25RD PTD #178 -087 NON - CONFIDENTIAL Friday, June 16, 2000; 1 traveled to Unocal's Dolly Varden platform to verify the No- Flow status of wells D -42 and D -25 in the McArthur river field. I had been in contact with Greg Geller and Dave Kerkvleit (production operators) over the past two days checking on the wells status. I arrived to find both wells routed to the "Well Clean" tank which is the lowest back - pressure separator (approx. 2 psi) available on the platform. These wells had been bled down and both had negligible pressure on there production casing. At first we checked the gas flow using a small gas meter, which was rigged up using a' /2 high pressure hose. I felt we would lose flow due to the length of the hose and asked it be removed from the inlet of the meter. Greg Geller (Lead Operator) complied and mounted the meter directly to the cap of the wellhead. 1 feel this gave a much more accurate flow rate reading. D-42 • 0900 check gas flow <180 scf /hr, install 100 psi gauge and shut -in well @2 psi. • 0925 -SI @5 psi. • 1010 -SI @11 psi. • 1045 -SI @15 psi, bled to 10 psi (fast), shut -in flow line. • 1100 -SI @13 psi, bleed to 2 psi. Check flow 275 scf /hr. Put well back to production. D -25 • 0910 -Check gas flow 190 scf /hr, install 100 psi gauge and Si well © 3 psi. • 1005 -SI ©7psi, check gas 300 scf, SI. • 1040 -SI @9 psi. • 1055 -SI @9 psi, bleed to 5 psi (fast). Check flow 600 scf /hr. Put well back to production Both wells had no fluid production and slight gas flow but were below our 900 SCF maximum. I recommend these wells be granted No -Flow status. Summary: I verified the No -Flow conditions on Unocals wells D -42 and D -25RD in the McArthur River Field, Both wells passed. Cc; Bill Smith (Unocal Dolly Varden foreman) 1 No Flow TBU UNOCAL D -25 D -42 6 -16 -00 LGI • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, May 23, 2012 4:06 PM To: Ferguson, Victoria L (DOA); Tom Fouts - (C) Cc: Juanita Lovett; Larry Greenstein; Schwartz, Guy L (DOA); Regg, James B (DOA); Tom Fouts - (C) Subject: RE: D -25RD 10 -403 Submittal Attachments: No flow test 6- 20- 2000.pdf Victoria, In answer to your first bullet point please find attached the approval from the no flow test conducted in 2000. (I just saw that you found it) The pressure test history on the annulus is that D -25RD has been a gas lifted producer since 2000. Gas lift pressure on the annulus is currently 900 psi. A gas balance is conducted daily on our gas system which has indicated that while these bad spots were identified in the casing by a USIT log ran in 2000, they are not leaking. Furthermore, converting this well to ESP will decrease the annulus pressure from 900 psi to 120 psi. Because of these mitigating factors, we do not see the need for or plan on running casing patches at this time. We can test the BOP's to 3,000 psi. However, the likelihood of having a full column of gas in a 95% water cut oil well is slim to none. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) J mailto :victoria.ferguson @alaska.govl Sent: Wednesday, May 23, 2012 3:01 PM To: Tom Fouts - (C) Cc: Ted Kramer; Juanita Lovett; Larry Greenstein; Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: D -25RD 10 -403 Submittal Tom, There are several issues with this Sundry: • A packerless completion is not allowed unless the well has had a no flow test. According to 20 AAC 25.200 "All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing- casing annulus from fluids being produced" • Can you run casing patches for the holes in the casing at 3280' and 5645' MD? What is the pressure test history on the annulus? 1 • • • The MASP assuming a column of gas is 2866 psi so the BOPs will need to be pressure tested to 3000 psi. 20 AAC 25.280 (4) Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(cilalaska.gov From: Tom Fouts - (C) jmailto:tfouts©hilcorp.com] Sent: Monday, May 21, 2012 3:56 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Ted Kramer; Juanita Lovett; Larry Greenstein Subject: D -25RD 10 -403 Submittal Guy/ Victoria, We delivered the 10 -403 for D -25RD to your office this afternoon. If it would be possible to expedite the review of this procedure, it would be greatly appreciated. We would like to begin the work -over on this well in a week. Thanks, Tom Fouts 1 Construction Manager Hilcorp Alaska, LLC tfoutsPhilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351 -5749 2 • Page 1 of 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, June 04, 2012 11:39 AM To: Schwartz, Guy L (DOA); Ted Kramer Cc: Chris Myers; Regg, James B (DOA); Ferguson, Victoria L (DOA); Norman, John K (DOA) Subject: RE: Revised Procedure #2 for D -25RD Ted, As we discussed this morning ... Test casing to 1500 psi for 30 min with 9 5/8" test packer. Setting depth should be as close as practical to the top of the scab liner. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Saturday, June 02, 2012 11:10 AM To: Ted Kramer Cc: Chris Myers; Regg, James B (DOA); Ferguson, Victoria L (DOA); Norman, John K (DOA) Subject: Re: Revised Procedure #2 for D -25RD Ted, Agree .... A casing test can still be accomplished after tubing is pulled using a retrievable packer. You have approval to pull tubing as we discussed. An alternative casing test( workstring set packer) will be discussed on Monday. Guy Sent from my iPhone On Jun 2, 2012, at 10:30 AM, "Ted Kramer" <tkramer @hilcorp.com> wrote: Guy, Thanks for calling me back. This e -mail is to document our phone discussion of today June 2, 2012 at approximately 9:35 AM. Since we are unable to get a plug down the tubing to bundle test the tubing and 9 -5/8" casing we will proceed with rigging up the CUDD Hydraulic workover unit and prepare to pull the well. This will most likely take 48 hours and will give you time to review the Sundry 312 -190 and discuss with Victoria what has transpired last week on Monday morning. I will call you at 10 AM Monday and we can discuss a plan forward at that time. Tentatively, as we discussed, we will proceed as if we plan to pull the tubing and run a temporary retrievable packer to pressure test the 9 -5/8" Casing. We will discuss further on 6/4/2012 • Page 2 of 4 Monday what the testing pressure needs to be and for how long. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985- 867 -0665 From: Ted Kramer Sent: Saturday, June 02, 2012 9:17 AM To: Ferguson, Victoria L (DOA) Cc: Chris Myers; 'John.Norman @alaska.gov'; Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov); jim.regq©alaska.gov Subject: FW: Revised Procedure #2 for D - 25RD Victoria, Victoria, We have attempted to set a plug to perform a pressure test as required for Sundry 312 -190, Dolly Varden /D -25RD below. The result of this operation was that we were unable to get the plug down to the depth needed to set it due to hard scale deposits in the tubing. If you recall, from our discussions last week, that this was a high risk path to take because scale deposits on the Dolly Varden Platform make it difficult if not impossible to set plugs in the tubing. Additionally, if we can get the plug to the seat nipple, it is highly unlikely that we will be able to get the plug out due to scale falling on top and sticking the plug which results in losing the well's production. Since we now have a rig on the well, 1 have called the AOGCC North Slope number in hopes of getting ahold of someone to report this finding and agree on a path forward. Hilcorp still maintains that there is not a leak in the 9 -5/8" casing and that the data submitted to the commission adequately supports this view. Since there is now a rig on the well, it is imperative that a swift and decisive decision be made to resolve this issue so that we can proceed with converting this well to ESP artificial lift, thereby lowering all pressures involved. Thank you for your assistance in this matter, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 6/4/2012 • Page 3 of 4 0 907 - 777 -8420 C 985 - 867 -0665 From: Chris Myers Sent: Friday, June 01, 2012 4:48 PM To: Tom Fouts - (C) Cc: John Lee; Joe McInnis - (C); Ted Kramer; Rick Brumley - (C) Subject: FW: Revised Procedure #2 for D -25RD Here is our path forward. Chris Myers Operations Manager TBU /TBF /CIPL Hileorp Alaska LLC Work 907 - 777 -8333 CeII 907 - 398 -9955 Fax 907 - 777 -8510 From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Friday, June 01, 2012 4:31 PM To: Chris Myers Cc: Norman, John K (DOA); Schwartz, Guy L (DOA) Subject: RE: Revised Procedure #2 for D -25RD Chris, You have verbal approval to proceed with Sundry 312 -190, Dolly Varden /D -25RD with the following contingency: The 9 -5/8" casing is to be pressure tested as outlined in your procedure and must hold pressure for 30 minutes. If the casing pressure test fails you do not have approval to proceed with Sundry 312 -190. In your procedure the BOP test should be to 3000 psi. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson aS alaska.gov From: Chris Myers (mailto:cmyers©hilcorp.coml Sent: Friday, June 01, 2012 4:04 PM To: Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C) Subject: Revised Procedure #2 for D -25RD 6/4/2012 Page 4 of 4 Victoria, I am writing in regards to our conversation earlier this afternoon. It is my understanding that we are to install a plug in the tubing X nipple, circulate the well with filtered inlet water and perform a charted pressure test of the 9 - 5/8" casing to a minimum of 200psi for a 30 minute duration on D -25RD. Upon the positive results of this test we would then be allowed to continue with the procedure. It is our intent to begin these activities later this afternoon to set the plug and perform the casing pressure test. Please review the revised procedure attached to this email and inform myself and Tom Fouts if this is acceptable. Thank you, Tom Fouts 1 Construction Manager Ililcorp Alaska, 1..I.(. tfouts @hilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351-5749 6/4/2012 • ATTACHMENT #1 TBUS D -25 Cementing Record 13 3/8" Casing 1600 Sacks - Class "G ", 1 /2ft Pearlite, 4% Gel, 1% D -31 400 Sacks - Class "G ", 2% Calcium Chloride 9 5/8" Casing (1st Stage) 800 Sacks - Class "G ", 4% Gel, 1 /2ft / Sk Pearlite, .5% R -5, 8% 550 Sacks - Class "G ", .8% D -31, 1% D -19, .5% R -5 D. V. Stage Tool @ 7150' (2nd Stage) 800 Sacks - Class "G ", 4% Gel, 1 /2ft / Sk Pearlite, .5% R -5, .82 550 Sacks - Class "G ", .8% D -31, 1% D -19, .5% R -5 Squeeze Cementing 9 5/8" Casigv Shoe (11,337') 300 Sacks - Class "G ", 1% D -19, .5% R -5 Perforations 11,080'- 11,200' 150 Sacks - Class "G ", 1% D -19, .5% R -5 150 Sacks - Class "G ", 1% D -19, .5% R -5 100 Sacks - Class "G ", 1% D -19, .5% R -5 Perforations 10,590'- 10,593' 150 Sacks - Class "G ", 1% D -19, .5% R -5 200 Sacks - Class "G ", 1% D -19 100 Sacks -- Class "G ", 1% D -19 200 Sacks - Class "G ", 1% D -19 FORM 484 REV. 7 -88 • •," • Page 5 DATE MARATHON OIL COMPANY FIELD McArthur Riv HISTORY OF OIL OR GAS WELL BLOCK WELL NO. D - 25 LEASE Trading Bay Unit SEC. TWP. R. PARISH STATE COUNTY ELEV. • ' TOP OF OIL STRING ELEV. HISTORY PREPARED BY MEASUREMENTS TAKEN FROM ,TOP OF ROTARY TABLE ELEV. TITLE GRD. OR MAT ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 2/4 PBTD 11,252' - Completed running 9 -5/8" casing. Ran 279 jts 9 -5/8 ", 47 #, P -1l Buttress casing to 11,337'. Broke circulation & circulated for 1? hrs. Rigged up B -J Services & cemented casing in two stages: FIRST STAGE: Mixed & pumped 800 sacks Class "G" cement w /4% gel, /cu ft Perlite, 0. 5% R -5, 0. 8% D -31, followed by 550 sacks Class "G" Neat cement w /0. 8% D -31, 1% D -19, & 0. 5% R -5. Pumped 10 BBLS mud sweep ahead of cement & 10 BBLS water behind slurry. Slurry weight 12.5# /gal--gel cement & 15# /gal Neat cement. Displaced slurry w/824 BBI mud w /rig pump. Bumped plug w /2, 000 psig. Released pressure & plug held. CIP @ 10 :00 PM 2/3/73. Dropped D -V bomb & opened D -V collar w /1, 200 psig. Circulated 11 hrs. Circulated approx. 60 BBLS cement from 1st stage. SECOND STAGE: Mixed & pumped 800 sacks Class "G" cement w /4% gel, # /cu ft Perlite, 0. 5% R -5, 0. 8% D -31, followed by 550 sacks Class "G" Ne; cement w /0. 8% D -31, 1% D -19, & 0. 5% R -5. Pumped 10 BBLS mud sweep ahead of slurry & 10 BBLS water behind slurry. Slurry weight 12. 5# /gal gel cement & 15# /gal Neat cement. Displaced slurry w/523 BBLS mud w /ril pump. Bumped plug w /3, 000 psig. Released pressure & plug held. CIP @ 2 :30 AM 2/4/73. Had cement returns to surface w /15 BBLS excess cement. Set casing in slips & began installing 9 -5/8" tubing spool. Rigged down B -J Services. 9 -5/8" Casing Detail Eff. From To KB to top of casing 40. 80 174 jts 9- 5/8", 47 #, P110, Buttress 7,108.37' 40.80' 7,149.17 1 Baker DV Collar 1.75' 7, 149. 17' 7,150.92 102 jts 9 -5/8 ", 47 #, P110, Buttress 4,101.94' 7,150.92' 11, 252.86 1 Baker Float Collar 1.98' 11,252.86' 11,254.84 2 jts 9 -5/8 ", 47 #, P110, Buttress 79.72' 11,254.84' 11, 334.56 1 Baker Float Shoe 2.55' 11,334.56' 11, 337.11 Total Overall 11,296.31 2/5 PBTD 11,252' - Cut off casing & installed tubing head, tested to 3,000 psi, OK. TT! 1 _ 1 _ •1 I1T i 1 .• _. 1 . 1 1, • _. 1 /NTV r. _ • /Olet 1_ ±1. 0 1__ ±11 _ 1 _a_ 4••••::ri,9.1.700,:r.....77,171".4011.11.7_,,_ 3=76 i, 9:711:w, - - 1.- % 4.1. 44 kkol b ,... ,,„., ,,,-......•,.., w ,„„ - —,- 1--- -q-- IfttiltP aitr.ilt7aStlar liOr iti, '' 1 ow III= _ t 1 f•-:- -:1-Mitititie***41.■41Ntt a ,,' „,.., ;:‘,-,' ,„\-:,,,,, ,. --.'",., :v '''' --=',"-”; --. - - -0,13.,nr-r. -0' : ,_ ,,, ' l''‘,*., 00 i ',X/ '''''„",..t"-,4,.' )'-',;;;;',/- 4. ,, ,WW 0 ' . 01NMail.' - ±, - - . '47 -, ' ,. 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Si,* ,41i41: 4,14,1448.,'W.,,4•- =AI 0 ,,,,. -A_' .'- -.:,--' . --... , , „ , ' , < . , 1 ‘ 41ten***04,,,,,alt:- M : ,-t- -- -fa A,' .:, - . ,. -4- , ',,><,/ .-X, ,-, 43 4* ' #4•• .424‘4,M="-gr;"==0111-00010-.1e70-.)--,44 ,,,,, -'( ,,,, 4 , 4.470ww# 44,-47,4,744...Analpt. sma-N - ow i-i•'-_, ---::?„-;--,„ ' ,,_/: , //,- ,.,_,. 4,+ 441,„_ __41,1, a ti.,,qo p &V,411411,,,INVApallast .,..___. mrarsalt 0001010,0 „--, -*-:, ,- ,* ,,, , ..,,,,>(/:, d e - V, , 414*,40; At* 4W0,11ftro..., -4 -4_ , ,.,-:.,--:,-- ,,, , ; ri \:-- -- , .x , / \ 4r., Iiimp ice • ' i '"11ir..i' ` Zt� 6""" : + 9 �d Page 1 of 2 • Schwartz, Guy L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Sunday, June 03, 2012 9:08 AM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA); Chris Myers; Larry Greenstein Subject: D -25RD 9 -5/8" Casing Integrety Question on Conversion to ESP Sundry 312 -190 - Summary Attachments: D -25RD Schematic 05- 21- 2012.doc; Copy of Copy of D -25RD 2009 pressure data supportting 2012 403 submission.xls; Gas Balancing Spreadsheet (2).xlsx; 2- 16- 11.pdf; 4- 20- 11.pdf Guy, I know you will want to confer with Victoria but I wanted to send you a summary to help bring you up to speed on this well. I realize that by sending you this with you just coming back from vacation could be misconstrued as me "shopping" regulators in an attempt to secure a more favorable outcome. I assure you that this is not the case. My intent, and Hilcorp's is simple - to arrive at the best plan forward for operating this well. Hilcorp's decision to convert the D -25RD from gas lift to ESP is due to two reasons: 1. We want to decrease the pressure in the 9 -5/8" casing from the 1,300 psi currently applied due to gas lift, to the 150 to 200 psi that will be on the back side with an ESP. 2. The well is capable of producing more fluid than can be recovered by using Gas Lift as the means of artificial lift. The first attachment (D 25 RD schematic) is the well schematic. The well completion is somewhat busy but the job involves pulling out of the seals (item 10), removing the tubing from there up, and running an ESP back to a depth between items 7 and 8. The second attachment (Copy of 25 RD 2009 pressure data) is pressure data from 2009 when the field was shut down due to the Mount Redoubt Volcano Eruption. Victoria felt that this data (although good data) was too old to be valid. I do not disagree with your assessment sounds the data is now three years old. However, 1 do believe that the data has significance because it demonstrates that the 9 5/8 casing was not leaking at that time. The third attachment (gas balancing spreadsheet) contains data and some plots derived from more recent well test information. This data demonstrates that the formation gas in the GOR have been increasing in the D 25 RD over time. Since this data is calculated from the difference between gas injected from gas lift and the gas produced, it demonstrates that gas is not being lost from the 9 5/8 casing. If there were such a loss, with the small gas volumes, there very likely would be a test reflecting negative formation gas produced. That is not the case. The last two attachments are charts from more recent well shut -ins of the D — 25 RD. These charts have both a red line and the blue line. The blue line is the pressure recorded from the 9 5/8 inch casing during the time that the well was shut in and all surface valves closed. The red line is a differential line of how much gas is being injected. The fact that it is a flat consistent line indicates that no gas is being added to the 9 5/8 inch casing. I believe that these charts demonstrate that the 9 5/8 inch casing was intact as of the most current date on the chart which was 4 -20 2011. This also is a better indicator of a leak than a TTS isolation Packer will be because this test is done with gas, and isolation test using a packer will be done with water. 6/4/2012 Page 2 of 2 • When one collectively looks at all of this data, I believe the conclusion can be reached that the 9 -5/8 inch casing is intact and not leaking. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985 - 867 -0665 6/4/2012 • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer ©hilcorp.com] Sent: Wednesday, May 30, 2012 10:09 AM To: Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Schwartz, Guy L (DOA); Regg, James B (DOA); Larry Greenstein Subject: RE: D -25RD 10 -403 Submittal Attachments: Gas Balancing Spreadsheet (2).xlsx Victoria, Attached is the Gas Balancing Spreadsheet Compiled from well test data for the D -25RD Well. The spreadsheet consists of two charts and a data sheet. Since the D -25RD is a gas lifted well, the injected gas lift gas is metered at the well head as it enters the 9 -5/8" casing and the return gas is measured at the test separator. The difference between the gas out and the injected gas is reported as the formation gas. If the 9 -5/8" casing were leaking gas, one would expect to see a downward trend in the formation gas as the leak worsens over time (leaks never decrease with time, especially with gas). The trend observed with D -25RD is the opposite. Although the data does jump around some, The overall trend for the formation gas (See chart labeled Formation Gas) has actually been increasing over the last two years. The same slightly increasing trend is observed in the GOR Plot (See Chart labeled GOR). Hilcorp believes that taken in its entirety, the long term shut in pressure data from the Redoubt eruption coupled with seeing an increase in the formation gas and GOR plots demonstrate that the bad spots indicated by the USIT log are not leaking gas. We will be finishing the ESP conversion of D -12RD today and the D -25RD well is the next well in the workover schedule. Therefore, any help we can give you in increasing your comfort level please let me know. We would be happy to come over to discuss this well if that would help. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 CeII Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson ©alaska.gov] Sent: Friday, May 25, 2012 3:20 PM To: Ted Kramer Cc: Tom Fouts - (C); Schwartz, Guy L (DOA); Regg, James B (DOA); Larry Greenstein Subject: RE: D -25RD 10 -403 Submittal • • Ted, Please provide us with recent gas balance results including interpretation. We are concerned with how old your data is — USIT (12 years) and shut in pressure data (3 years). We will consider this information before making a decision. Thanx, Victoria From: Ted Kramer [mailto:tkramer @hilcorp.com] Sent: Friday, May 25, 2012 11:49 AM To: Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Schwartz, Guy L (DOA); Regg, James B (DOA); Larry Greenstein Subject: RE: D -25RD 10 -403 Submittal Victoria, Performing a casing pressure test on this well presents unnecessary risk to the well operation and I believe I can show you something that will be even better. Here is why Hilcorp does not want to run this pressure test. The only way to perform this test with open perforations and active gas lift valves would be to run a plug in the tubing and set it in the X nipple located at 10,093 feet and then simultaneously pressure up on the tubing and casing together (commonly referred to as a jug test). The risk comes in because it is uncertain if the plug will hold and if it does, there is additional risk that we will not be able to retrieve the plug once the test is over due to scale deposits becoming dislodged from the sides of the tubing and falling on top of the plug ( this has already happened on another Dolly well this year). In looking at our records, we found a pressure plot of the time frame that the well was shut in during the Mt. Redoubt Volcano eruption (see attached). During the time period from 5/28/09 to 6/25/09 the D -25RD well was shut in. The tubing and 9 -5/8" casing pressure equalized (through the gas lift valves) at 1590 psi. during this time period. The 13- 5/8" casing string did not change (other than normal thermal effects) and only increased from 98 to 106 psi. Hilcorp believes that this proves that the two bad spots identified by the USIT log ran in March of 2000 are not communicating to the 13 -5/8" casing and serves the purpose of the pressure test mentioned below. Hilcorp asks that the commission accepts this evidence in lieu of an additional pressure test for granting this packerless completion. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 2 'WOj lef!wgnS £0t7-0I 4bsZ-a :pa(gnS (voa) 8 saweC '66a1:1 :(yoa)1 An0 'zlJeMgDS 'ulaasuaaJO AJJel e}!uenc :Jawe.01 pal :aD (j) - spoj wol :ol Wd TO :£ ZIOZ '£Z AeW 'AepsaupaM :was [Ao6'e)Isele©U uosn6Ja}'epop!A:olllew] (yoa)1 elJOp!A'uosn6aa3 :woaj S990 - S86 auoyd Ilan OZ178 LLL - L06 auoyd a3!} }0 311 'e)ISelb daoDl!H Jaau!Su3 suo! }eJado •JS JaweiN pal `Allnp. •auou wlls s! IIaM I!o ln3 Ja1e" %S6 e u! 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According to 20 AAC 25.200 "All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing- casing annulus from fluids being produced" • Can you run casing patches for the holes in the casing at 3280' and 5645' MD? What is the pressure test history on the annulus? • The MASP assuming a column of gas is 2866 psi so the BOPs will need to be pressure tested to 3000 psi. 20 AAC 25.280 (4) Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria. ferQuson(c�alaska.gov From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Monday, May 21, 2012 3:56 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Ted Kramer; Juanita Lovett; Larry Greenstein Subject: D -25RD 10 -403 Submittal Guy/ Victoria, We delivered the 10 -403 for D -25RD to your office this afternoon. If it would be possible to expedite the review of this procedure, it would be greatly appreciated. We would like to begin the work -over on this well in a week. Thanks, Tom Fouts !Construction Manager Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351 -5749 4 D -25RD Formation Gas Over Time 1200 1000 800 _ _ 7 V � r c 600 A,,,A — 1 lir , ..._ o 400 ■ — , i i! y i\ !! • 200 0 I 1 t 1 I I 1 1 1 i 1 1 I 1 1 1 I 1 1 f NQ' NC) N9 y 0 y 0 , N> ' . titi yti yti titi N,'' ' " ' ' ' ti ' ' ' 'Q' 'Q' 'Q' 'Q' 4< J� �J\ PJ% c e� O` „.\(5: cr a � <,esP ma c P9 c � 4" ��\ PJ � c4e9 O`er 0 - 4 oe c% , < la c Pi c Date • l 0 er 0 lO e c to h i s i Sir , �r F r �� -O F lailly l r o„ �lr rlo %l a) flit rr ,c O � �l l l0 6> CU rl, PO { O �' llo S � 9 O CO rl rS /s ° fj 1 ' . l' 06,4 RS O� o l /l�' V1 r 0 � � 1 to 0 /1 Q r °� r '°r ip or � % o 63 al bob WINN oz '< <- 0 o pair 0 0 0 0 0 o S ol 0 0 0 ° C 0 0 o ° iO 0 11e 8 110 se9 oo et Pressure & Rate vs Time - Well D -2511110 1800 - Tubing and Casing Equalize at 1,590 psi. , 9 5/8" 1600 - 133/8" -..- __.- .. ---- ■■■■Tubing - _ _ rimil 1400 I I I 1 0.4)16""v Volcano Shut down 1200 lr : 1•to 6/15/09 -0 I iiii - i t 1 1/4.4,4 , lil 1000 v N N a` 800 —. 600 — — - l i 13 5/8 remains constant with only thermal effects. 400 — 200 r apill 46004111 SVIVIIPIL L . St ae L 0 1 rn co rn m rn rn rn rn o rn m rn m 0 0 0 0 0 0 0 0 0 0 0 0 0 c� o o rn w 0 N el O a O O O a o M N N N N N cn v N in r a a) o N 0 0 0 0 0 0 o n n o Date 133/8" ng TIO Report 01 /01 /10 95 140 12/31/09 95 160 Data Sheet 12/30/09 95 180 12/29/09 94 160 12/28/09 100 180 D - R D 12/27/09 100 160 12/26/09 102 170 12/25/09 100 170 12/24/09 102 160 12/23/09 102 170 12/22/09 102 180 Permit # 1780870 12/21/09 100 200 12/20/09 100 + 200 12/19/09 104 190 API # 50 733 - 20247 - 01 12/18/09 104 190 12/17/09 106 190 12/16/09 105 170 01/01/2009 to 01/01/2010 12/15/09 106 200 12/14/09 110 180 12/13/09 105 160 12/12/09 105 340 12/11/09 110 160 12/10/09 108 160 12/09/09 110 160 12/08/09 110 180 12/07/09 110 180 12/06/09 110 160 12/05/09 110 190 12/04/09 100 160 12/03/09 110 160 12/02/09 112 160 12/01/09 112 170 11/30/09 116 - 300 11/29/09 116 180 11/28/09 106 . 210 5/2502709 • ports 7e.1tk4 00 11 Dolan Copy of D -25RD 2009 pressure data supportting 2012 403 submission D -25RD • • Ferguson, Victoria L (DOA) From: Regg, James B (DOA) Sent: Friday, May 25, 2012 12:37 PM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: D -25RD 10 -403 Submittal TBU D -25RD (PTD 1780870) Some thoughts for consideration...They are asking us to approve this on 3 yr old pressure test (equivalent) and 10 + yr old USIT log. Because 13 -3/8" shoe is so much shallower than the compromised 9 -5/8" casing, there is no guarantee that they will ever see pressure communication through 13 -3/8" except for the gas balance. Perhaps that should be a condition of approval if we decide to approve — require gas balance submitted to AOGCC (monthly ?) and first indication of problem the well is SI. Even that is a stretch for accurate monitoring of integrity for decisions about allowing the well to operate. They should provide gas balance results as supporting documentation with this request since they are against running patches. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Ted Kramer [mailto:tkramer @hilcorp.com] Sent: Friday, May 25, 2012 11:49 AM To: Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Schwartz, Guy L (DOA); Regg, James B (DOA); Larry Greenstein Subject: RE: D -25RD 10 -403 Submittal Victoria, Performing a casing pressure test on this well presents unnecessary risk to the well operation and I believe I can show you something that will be even better. Here is why Hilcorp does not want to run this pressure test. The only way to perform this test with open perforations and active gas lift valves would be to run a plug in the tubing and set it in the X nipple located at 10,093 feet and then simultaneously pressure up on the tubing and casing together (commonly referred to as a jug test). The risk comes in because it is uncertain if the plug will hold and if it does, there is additional risk that we will not be able to retrieve the plug once the test is over due to scale deposits becoming dislodged from the sides of the tubing and falling on top of the plug ( this has already happened on another Dolly well this year). In looking at our records, we found a pressure plot of the time frame that the well was shut in during the Mt. Redoubt Volcano eruption (see attached). During the time period from 5/28/09 to 6/25/09 the D -25RD well was shut in. The tubing and 9 -5/8" casing pressure equalized (through the gas lift valves) at 1590 psi. during this time period. The 13- 5/8" casing string did not change (other than normal thermal effects) and only increased from 98 to 106 psi. Hilcorp believes that this proves that the two bad spots identified by the USIT log ran in March of 2000 are not communicating to the 13 -5/8" casing and serves the purpose of the pressure test mentioned below. Hilcorp asks that the commission accepts this evidence in lieu of an additional pressure test for granting this packerless completion. 1 • • Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson©alaska.gov] Sent: Thursday, May 24, 2012 1:37 PM To: Ted Kramer Cc: Tom Fouts - (C); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: D -25RD 10 -403 Submittal Ted, Please perform a 1000 psig pressure test for 30 minutes on the casing. If the well passes then a packerless completion can be approved. Thanx, Victoria From: Ted Kramer [mailto:tkramer@ hilcorp.com] Sent: Wednesday, May 23, 2012 4:06 PM To: Ferguson, Victoria L (DOA); Tom Fouts - (C) Cc: Juanita Lovett; Larry Greenstein; Schwartz, Guy L (DOA); Regg, James B (DOA); Tom Fouts - (C) Subject: RE: D -25RD 10 -403 Submittal Victoria, In answer to your first bullet point please find attached the approval from the no flow test conducted in 2000. (I just saw that you found it) The pressure test history on the annulus is that D -25RD has been a gas lifted producer since 2000. Gas lift pressure on the annulus is currently 900 psi. A gas balance is conducted daily on our gas system which has indicated that while these bad spots were identified in the casing by a USIT log ran in 2000, they are not leaking. Furthermore, converting this well to ESP will decrease the annulus pressure from 900 psi to 120 psi. Because of these mitigating factors, we do not see the need for or plan on running casing patches at this time. We can test the BOP's to 3,000 psi. However, the likelihood of having a full column of gas in a 95% water cut oil well is slim to none. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC 2 • Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Wednesday, May 23, 2012 3:01 PM To: Tom Fouts - (C) Cc: Ted Kramer; Juanita Lovett; Larry Greenstein; Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: D -25RD 10 -403 Submittal Tom, There are several issues with this Sundry: • A packerless completion is not allowed unless the well has had a no flow test. According to 20 AAC 25.200 "All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing - casing annulus from fluids being produced" • Can you run casing patches for the holes in the casing at 3280' and 5645' MD? What is the pressure test history on the annulus? • The MASP assuming a column of gas is 2866 psi so the BOPs will need to be pressure tested to 3000 psi. 20 AAC 25.280 (4) Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a alaska.gov From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Monday, May 21, 2012 3:56 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Ted Kramer; Juanita Lovett; Larry Greenstein Subject: D -25RD 10 -403 Submittal Guy/ Victoria, We delivered the 10 -403 for D -25RD to your office this afternoon. If it would be possible to expedite the review of this procedure, it would be greatly appreciated. We would like to begin the work -over on this well in a week. Thanks, 3 . ,- STATE OF ALASKA ALASKA O,_ AND GAS CONSERVATION C ...!MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface Leg A-l, Cond. 8, Dolly Varden Pl~tf,~'"., ,~, .~,,,~.~ ~ ~,,:~-,.¢~'~ ~,~' ~ ~; ~ ~;~-, 8. Well number 751' FSL, 1,210' FWL, Sec. 6-8N-13W-SM i:!'~*~..,;i'*"*~,/~ ~ ....... ~.,,'~ D-25RD At top of productive interval 9. Permit number/approval number 360' FNL, 735' FWL, Sec. 8-8N-13W-SM ¢ .., ..) 92-053/399-265 At effective depth /~,..;,.]"._3 L) ~::' "' '; ~"- 10. APl number At total depth ,;~J~(~ -:'.3~i ¢ L;~.~ 5~}~'i~5:,, ~.',Oi'..q~;fiig~!OB 11. Field/Pool 498' FNL, 1,206' FWL, Sec. 8-8N-13W-SM ~4P0~0~'~(} Hemlock/Tyonek G-Zone 12. Present well condition summary Total depth: measured 11,510' feet Plugs (measured) true vertical 10,021' feet Effective depth: measured 11,415' feet Junk (measured) Perf gun @ approx. 11,290' true vertical 9,941' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,514' 13-3/8" 2,514' 2,446' Intermediate Production 8,155' 9-5/8" 8,155' 7,268' Liner 3,568' 7" 750 Sx 11,506' 10,015' Scab Liner 551' 5-1/2" x 7" 7,799'-8,350' 6,962'-7,422' 85' 3-1/2" 10,835'-10,920' 9,465'-9,532' Perforation depth: measured true vertical See Attached ORIGINAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Buttress @ 7,793'; 3-1/2",9.2#, L-80, Buttress @ 7,793'-10,126' Packers and SSSV (type and measured depth) Baker, Mod. F @ 10,920'; Baker Mod. F @ 10,835'; Baker Mod. F @ 10,055'; Baker Mod. FA @ 8,350'; Baker Mod. Mod. F @ 7,799' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/16/00 140 145 2,276 601 120 Subsequent to operation 5/6/00 307 156 1,635 1,171 130 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: Signe~~/C~illiamson Title: Drill,ng Manager Date: '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Dolly Varden D-25RD Actual Perforations 5/3/00 Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments G-2 10,173' 10,190' 8,958' 8,971' 17' G-3 10,267' 10,285' 9,034' 9,048' 18' G-4 10,322' 10,345' 9,078' 9,095' 23' HB-0 10,645' 10,660' 9,324' 3,940' 15' HB-1 10,726' 10,744' 9,391' 9,405' 18' HB-3 10,865' 10,880' 9,501' 9,513' 15' Isolated by Scab Liner HB-3 10,884' 10,895' 9,516' 9,525' 11' Isolated by Scab Liner HB-4 10,962' 11,016' 9,577' 9,620' 54' HB-4 11,030' 11,130' 9,632' 9,711' 100' H B-5 11,150' 11,187' 9,727' 9,757' 37' HB-5 11,200' 11,285' 9,767' 9,836' 85' 393' UNOCALe Dolly Varx[en Well No, 25RD Actual Completion 3/30/00 Tree connection: 4-1/16" 5,000# E 10 11 12-16 17 18 I SIZE 13-3/8" 9-5/8" 7" A A-1 __ ^-2 19 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 61.0 K-55 Butt. LT&C 12.515 Surf 2,518' 47 P-t 10 Butt 8.681 Surf 8,155' 29 N-80 Butt 6.184 7,938' 11,506' Tubing: 4-1/2" 12.6 L-80 Butt 3.958 Surf 7,793' 3-1/2" 9.20 N-80 Butt 2.992 7,789' 10,126' JEWELRY DETAIL NO. Depth ID OD Item 40.87' 4-1/2" Cameron Type DCB 8rd X 8rd Tbg Hngr 1 285' 3.813 6.125 SSSV, Howco, XXO, (3.813" I.D.) 2 2,349' 3.883 7.063 GLM, 4-1/2", Camco MMG, 1-1/2" R-2 Valve RK Latch 3 3,726' 3.883 7.063 GLM, 4-1/2" Camco MMG, 1 ~1/2" R-2 Valve RK Latch 4 4,791' 3.883 7.063 GLM, 4-1/2" Camco MMG, 1 ~1/2" R-2 Valve RK Latch 5 5,727' 3.883 7.063 GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch 6 6,537' 3.883 7.063 GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch 7 7,248' 3.883 7.063 GLM, 4-1/2" Camco MMG, 1-1/2" R~2 Valve RK Latch 8 7,796' 3.000 7.500 Fluted Locator, 7.5" O.D. 9 7,836' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch 10 8,361' 3.000 4.000 Locator, Seal Assembly, 7.23' Long Hole in Upper Scab Liner Assembly casing A 7,799' 6.000 8.218 Packer, 9-5/8" Baker Mod. F (DP set) 8,2o2'- 8,208' B 7,895' 4.892 5.500 Crossover, 7" Buttress Box x 5-1/2" 15.5# Hydril Pin C 8,338' 4.375 5.630 Seal assembly, 5" Located in 5' Upper PBR D 8,349' 4.000 5.500 Anchor, Baker Mod. E-22 E 8,350' 4.000 5.875 Packer, 7" x 4", Baker Mod. "FA" F 8,354' 4.500 5.530 Millout Extension, 4' Long w/4ea. 1" Holes G 8,357' 4.000 5.000 Lower Seal Bore Extension, 14' Long 11 8,372' 2.992 5.570 Crossover, 5" LTC Box x 3-1/2" Butress Pin 12 8 400' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch 13 8,802' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch 14 9,234' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch 10,625'- 10627' 15 9,636' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch Sqz. 200 16 10,007' 2.867 5.968 GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch sx 17 10,053' 3.000 4.000 Locator, Seal Assembly 18 10,093' 2.813 3.880 Otis, 'X' Nipple, 2.813 19 10,126' 2.992 3.865 Wireline Entry Guide A-1 10,055' 4.000 5.875 Packer, 7", Baker Mod."FB~I" (DP set- WL Correlated) A-2 10,058' 4.000 5.000 Seal Bore Extension Lower Scab Liner (DP set -WL Correlated) I 10,835' 4.000 5.870 Baker Packer II 10,860' 2.813 3.880 'X' Nipple (2.813"), 3-1/2" Buttress Fill Cleaned III 2.992 3.500 Scab Liner, 3-1/2", 9.2#, L-80, Buttress Out to 11,091' IV 10,920' 4.000 5.872 Baker Packer, Mod. F-1 V 10,948' 2.750 3.870 'XN' Nipple (2.75"), 3-1/2" Buttress VI 10,960' 2.992 3.865 Wireline Entry Guide ~. ~ '~, ~, ,~-,~, ~, ~; Perforation Data :, ....... .-,.--, See Perforation Data Sheet ?~ ;,.; ¥: ': :.',, 9 v" H-0 H-1 H-2 H-3 H-4 H-5 REVISED: 8/1/00 TCB DRAWN BY: TCB Workover Summary Dolly Varden, Well No. D- 25rd 3-1-00 to 6-25-00 3~6~00 DAY 1 RU APRS E-LINE. RIH AND CUT TUBING AT 10,512'. POOH. RD APRS. DISPLACE WELL WITH 700 BBLS 3% KCI. 3~7~00 DAY 2 INSTALL BPV AND REMOVE TREE. RU BOPE. 3/8/00 DAY 3 CONT. NU BOPE - RISER, MUD CROSS, 13-5/8" 5M DBL. GATE, 13-5/8", 5M ANNULAR. TEST BOPE TO 5,000 PSI WITH STATE WITTNESS. BACK OUT LOCK DOWN SCREWS. PULL HANGER OFF SEAT W/125K. PULL TO 195K - PARTED AT TUBING CUT. 3~9~00 DAY 4 POOH WITH 4-1/2" X 3-1/2" GAS LIFT COMPLETION. 3/10/00 DAY 5 POOH WITH 4-1/2" X 3-1/2" GAS LIFT COMPLETION. RECOVERED ALL OF 4-1/2" COMPLETION. FOUND TUBING HAD PARTED AT 4-1/2" X 3-1/2" CROSSOVER LEAVING ALL OF 3-1/2" COMPLETION IN HOLE. ESTIMATED TOP OF FISH AT 7,851'. MU FISHING BHA NO. 1 - 5-3/4" OVERSHOT W/3-1/2" BASKET GRAPPLE/RIH PU DRILL PIPE. TAG FISH AT 7,855'. ATTEMPT TO LATCH FISH. UNABLE TO ENGAGE FISH. POOH. 3111/00 DAY6 POOH W/BHA NO. 1. RECOVERED CROSSOVER PUP, AND 26' OF TUBING JOINT. TUBING BADLY CORRODED. NEW TOP OF FISH AT 7,882'. MU BHA NO. 2 - 8-1/8" OVERSHOT W/EXTENSIONS AND 4-1/4" BASKET GRAPPLE. RIH. TAG TOF AT 7,886'. ATTEMPT TO ENGAGE FISH. APPEAR TO GAIN 2K OF WEIGHT. POOH. 3/12/00 DAY7 POOH. RECOVERED 2 JTS. NEW TOF AT 7,942'. TUBING RECOVERED CORRODED. MU BHA NO. 3 - 5-3/4" OVERSHOT W/3-1/2" BASKET GRAPPLE. RIH. TAG FISH AT 7,942. ATTEMPT TO ENGAGE FISH. POOH. NO RECOVERY. MU BHA NO. 5 - 1 JT 5-3/4" WASH PIPE, EXTENSIONS, OVERSHOT DRESSED W/4-1/4" GRAPPLE. RIH. TAG FISH AT 7,942'. ATTEMPT TO GET OVER FISH. 3/13/00 DAY 8 UNABLE TO GET OVER FISH. POOH. MU BHA NO. 6 - 5-3/4" BURN SHOE ON WASH PIPE. RIH. BURN OVER FISH FROM 7,942' TO 7,957'. NO PROGRESS. POOh. SHOE W-O.. iRErO~.~ MU NEW SHOE RIH W/BHA NO. 7. TAG TOF AT 7,952'. BURN OVER FISH FROM 7,952' TO 7,958' 3114/00 DAY9 BREAK THROUGH FROM 7,958' AND CONT. TO 7,984'. POOH. NO RECOVERY. MU BHA NO 8 - OVERSHOT W/4-1/4" BASKET GRAPPLE AND 5-3/4" WASH PIPE. RIH AND ENGAGE FISH AT 7,950'. ATTEMPT TO PULL FREE W/25K OVER. NO SUCCESS. WORK 11 ROUNDS LEFT HAND TORQUE TO PERFORM BLIND BACK OFF. POOH. RECOVERED 742' OF 3-1/2' FISH. NEW TOF AT 8,692'. MU BHA NO. 9 - 5-3/4" OVERSHOT WITH 4-1/4" BASKET GRAPPLE. RIH. ENGAGE FISH AT 8,693' 3115100 DAY 10 RU APRS E-LINE. RIH W/2-3/8" GAUGE RING. SET DOWN AT 8,688' (TOF ELM). ATTEMPT TO WORK THROUGH. NO-GO. POOH. MU 2" LIB. RIH. SET DOEN 8,688'. POOH. IMPRESSION OF METAL TAB - POTENTIAL LIP ON TOP OF FISH. RD E-LINE. RU SLICK LINE. RIH W/1-3/4" SWEDGE. SET DOWN 8,688' WORK TOOL. FALL THROUGH TO 8,870' RIH TO 10,530'. POOH. MU 2.2 SWEDGE. RIH. SET DOWN AT 8,840'. WORK PAST CONT. RIH TO 10,530'. POOH. RD SLICK LINE. RU APRS E-LINE. RIH W/2-3/8" GAUGE RING. SET DOWN 8,840' AND 9,170'. CONT IN HOLE TO 10,530' POOH. TIGHT AT 8,688'. POOH. MU STRING SHOT. RIH AND PLACE STRING SHOT ACROSS CHEMICAL CUT AT 10,512'. PULL 40K OVER AND FIRE STING SHOT. PIPE NOT FREE. POOH. 3/16/00 DAY 11 RIH W/2-3/8" CHEMICAL CUTTER. SET DOWN 8,700' ELM. (11' INTO FISH). UNABLE TO WORK DEEPER. POOH. ARM 1-3/8" SPLIT SHOT TO SPLIT COUPLING. RIH. LAY ACROSS COLLAR AT 10,521' AND FIRE. WORK FISH TO 45K. NOT FREE. POOH. WORK FISH TO 80K OVER. FISH MOVING UP HOLE. POOH WITH FISH. 100% (1,898') RECOVERY OF 3-1/2" GAS LIFT COMPLETION. MU BHA NO. 10 PACKER MILL AND RETRIEVING TOOL. RIH. 3/17~00 DAY 12 CONT. RIH W/PACKER MILLING ASSSEMBLY. ENGAGE PACKER AND METAL MUNCH FROM 10,533'-10,537'. PACKER MOVING DOWNHOLE. PULL 40-45K OVER-PACKER FREE. POOH. LD BHA NO. 10. RECOVERED 1.32' OF MILLED PACKER AND 7.71' SEAL BORE EXTENSION.. JUNK BASKETS FULL OF 80% SCALE 20% IRON. MU BHA NO. 11 8-1/2" BIT, 9-5/8" CASING SCRAPPER. RIH TO TOL. REVERSE CIRCULATE A 6-1/4 BPM @500 PSI. 3/18/00 DAY 13 CONT. REVERSE CIRCULATE ANNULUS VOL. 20 BBLS LOST TO WELL. VERY FINE SCALE IN RETURNS. PUMP DRY JOB. POOH. LD BHA. MU BHA NO. 12.6" MILL 2 BOOT BASKETS, 6" STRING MILL. RIH ON DRILL PIPE (DID NOT SEE TOL). SET DOWN AT 10,638' (H-0 TOP PERF). KELLY UP AND SINGLE IN. TIGHT AT 10,638'-10,650'; 10,880'-10,895'; 10,955'-10,963' & 10,987'; 11,088'-11,091'. UNABLE TO GO DEEPER. CIRC. 40 BBL HIGH VIS SWEEP W/ VERY FINE SCALE IN RETURNS. PULL UP TO 11,045' AND REVERSE CIRCULATE. 3/19/00 DAY 14 ATTEMPT TO RIH AND TAG BOTTOM. UNABLE TO MOVE UP OR DOWN. PUMP 40 BBL HIGH VIS SWEEP. FINE SCALE IN RETURNS. RU E-LINE TO FREE POINT. RIH. 7,945' 100% STUCK. 7,913' 90% STUCK. 7,881' 100% FREE. WORK 7 ROUND RH TORQUE IN TO PIPE AND SLUMP. NO-GO. RIH W/STRING SHOT TO TOOL Jt AT 7,849'. LH TORQUE AND FIRE SHOT. BACK OFF AT 7,849'. POOH RD APRS. POOH. MU BHA 13. TAG FISH AT 7,848'. KELLY UP. SCREW INTO FISH. UNABLE TO CIRC. 3~20~00 DAY 15 ATTEMPT TO BUMP DOW. RE-ESTABLISH CIRC. ATTEMPT TO JAR FREE W/100K AND 150K OVER PULLS. NO MOVEMENT. RU APER E-LINE. RIH TO FREE POINT. 100% STUCK A'F 7,913'. POOH. RIH WITH STRING SHOT AND BACK OFF PIPE AT 7,848'. POOH. MU BHA NO. 14 - SCREW IN SUB AND JARRING ASSEMBLY. ENGAUGE FISH AT 7,848'. 3/21/00 DAY 16 JAR DOWN W/75K WHILE WORKING TORQUE INTO PIPE. NO MOVEMENT. FIRE JARS AT 200K OVER AND STRIGHT PULL TO TO 250K OVER. NO MOVEMENT. RU APRS E-LINE. RIH AND FREE POINT. PIPE 100% STUCK AT 7,943'. POOH. RIH WITH STRING SHOT AND BACK OFF AT 7,881'. POOH. MU AND RIH W/BHA NO. 15 - 8-1/8" CRIPPLED SHOE, 62' OF 8-1/8" WASH PIPE. RIH. WORK THROUGH TIGHT SPOT FROM 3,290'-3,392'. 3/22/00 DAY 17 CONT. RIH. WASH OVER FISH 7,889'-7,939' (TOP OF 7" LINER). PUMP HIGH VIS SWEEP. PC)OH. MU AND RIH WITH BHA NO. 16 - SCREW IN SUB AND JARRING ASSEMBLY. ENGUAGE FISH AT 7,881'. JAR DOWN WITH 65K. JAR UP AT 150K OVER. STRAIGHT PULL TC) 225K OVER. NO MOVEMENT. PUMP 40 BBL HIGH VIS SWEEP. JAR UP AT 200K OVER. FISH PULLED FREE. 3123100 DAY 18 POOH WITH FISH. 100% RECOVERY. LAY DOWN BHA. MU AND RIH W/BHA NO. 17 - MILL, S~FRING MILL, BOOT BASKET, JARS, 12 EA. DRILL COLLARS. RIH WITHOUT PROBLEMS AND TAG AT 11,081 '. POOH TO 10,565' (ABOVE PERFOARATIONS) AND CIRC TWO TIMES BOTTOMS UP. NO SIZABLE RECOVERY. POOH W/BHA. RU SCHLUMBERGER E-LINE. 3/;24/00 DAY 19 CC)NT. POOH LOGGING W/SWS USIT TOOL. RD SWS. TEST BOPE TO 5,000 PSI. GOOD TE-'ST. RIH W/BAKER 9-5/8" TEST PACKER TO 7,850'. SET AND TEST 9-5/8" TO 1,500 PSI FOR 20 MIN. NO BLEED OFF. GOOD TEST. POOH. RIH TO 10,920' W/7" BAKER "F-l". TIE IN WITH GR. SET PACKER AT 10,920'. CIRCULATE IN BREAKER. POOH. 3/25/00 DAY 20 RIH WITH 7" BAKER "F-l" PACKER AND SCAB ASSSEMBLY. SET DOWN ON PACKER AT 101,920'. TURN PIPE 3 TURNS AND STAB TAILPIPE THROUGH PACKER. CONT RIH AND STAB SEALS. SET UPPER SCAB PACKER AT 10,835'. SI ANNULAR AND PRESSURE TEST BACKSIDE TO 1,000 PSI. NO BLEED OFF, NO COMUNICATION UP DP. UNABLE TO BLOW BALL SEAT W/3,600 PSI.. RELEASE FROM PACKER. PRESSURE UP WITH TEST PUMP TO 4,000 PSI. NO SHEAR. 3-:26-00 DAY 21 PP, ESSURE TO 4,200 PSI, NO SHEAR. POOH WET. FOUND BALL FLUID CUT. RIH WITH 7" BAKER, MOD. FB-1 PACKER TO 10,055'. RU SWS. RIH AND CORRELATE W/GR. POOH RD E-LINE. DROP BALL. SET PACKER. SI ANNULAR. PT ANNULUS TO 1,000 PSI FOR 5 MIN. NO COMMUNICATION UP DRILL PIPe, NO BLEED Off. RELEASE FROM PACKER. CIRCULATE WELL TO 3% KCl TAKING BROKEN POLYMER RETURNS TO PRODUCTION. 3-27-00 DAY 22 CONT. DISPLACING WELL TO 3%KCI. SPOT CORROSION INHIBITOR. POOH. MU LOWER COMPLETION ASSEMBLY - 2 JTS. TAIL PIPE, SNAP LATCH, 49 JTS TBG, 5 EA GAS LIFT MANDRELS, 7" BAKER "FAB" PERMANENT PACKER. RIH ON DRILL PIPE. STAB TAIL PIPE THROUGH PACKER AT 10,055'. RIH. ENGAGE SNAP LATCH INTO PACKER AT 10,055'. SNAP OUT OF PACKER AND SPACE OUT WITH SNAP LATCH ONE FOOT ABOVE PACKER. DROP BALL AND SET 7 .... FAB" AT 8,350'. PRESURE ANNULUS TO 1,000 PSI. NO RETURNS UP DRILL PIPE. RELEASE FROM PACKER. PRESSURE UP AND SHEAR BALL SEAT. POOH. 3-28-00 DAY 23 PU ANCHOR SEAL ASSEMBLY, UPPER PBR W/5" X 5' SEALS PINNED IN, 5-1/2" X 7" LINER AND 9-5/8" BAKER MOD. "F-I" PERMANENT PACKER. RIH. LATCH ANCHOR SEAL ASSEMBLY INTO PACKER AT 8,350'. SHEAR OUT SEAL ASSEMBLY FROM UPPER PBR. PU ONE FOOT FOR SPACE OUT. DROP BALL. PRESSURE BACK SIDE TO 1,000 PSI TO CHECK INTEGRITY OF SEALS. NO COMMUNICATION UP DRILL PIPE. SET PACKER AT 7,799'. RELEASE FROM PACKER. SHEAR BALL SEAT. POOH. PICK UP UPPER COMPLETION - SEAL ASSEMBLEY, 3-1/2" TUBING, LOCATOR AND 4-1/2" GAS LIFT COMPLETION. RIH. 3-29-00 DAY 24 CONT. RIH W/COMPLETION. STAB SEAL ASSEMBLY INTO SEAL BORE EXTENSION IN PACKER AT 8,350'. CHECK SPACE OUT. SEALS NOT BURRIED DEEP ENOUGH IN SEAL BORE EXTENSION. POOH. ADD 2' PUP IN 3-1/2" TUBING TO LOWER SEALS IN SEAL BORE EXTENSION. 3-30-00 DAY 25 RIH W/COMPLETION. MU SSSV LANDING NIPPLE. OBTAIN SPACE OUT. MU HANGER. LAND COMPLETION. RU SLICKLINE. MU 2-1/2" X 20' DUMMY GUNS. RIH TO 11,090' WLM W/NO PROBLEMS. POOH. RD SLICKLINE. NIPPLE DOWN BOPE. INSTALL TREE AND TEST TO 5,000 PSI. RELEASE WELL FOR UNLOADING. 251 BOPD 1,790 BWPD, 150 MCFD 4-14-00 DAY 26 RU SCHLUMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. RIH AND PERFORATE G-3 10,267'-10,285' WITH 2-1/2" POWER JET, 5 SPF, 60 DEG. PHASING. RD E- LINE. 242 BODP, 1,588 BWPD, 185 MCFD 4-28-00 DAY 27 RU SCHLUMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. RIH AND PERFORATE G-4 10,322'-10,335' WITH 2-1/2" POWER JET, 6 SPF, 60 DEG. PHASING. RD E- LINE. ?~.:~ !?~', ~;:"~-~. ~'~ ~i~',' ~, :...,~, · 4-30-00 DAY 28 RU SCHLUMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. RIH AND PERFORATE LOWER G-4 10,335'-10,345' WITH 2-1/2" POWER JET, 6 SPF, 60 DEG. PHASING. RD E-LINE. 280 BOPD, 1,635 BWPD, 156 MCFD 5-3-00 DAY 29 RU SCHLUMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. RIH AND PERFORATE G-2 10,185'-10,190' WITH 2-1/2" POWER JET, 6 SPF, 60 DEG. PHASING. RD E- LINE. 307 BOPD, 1,588 BWPD, 136 MCFD 6-24-00 DAY 30 RU SLICKLINE. RUN PRODUCTION SURVEY. 6-25-00 DAY 30 RU SLICKLINE. RUN PRODUCTION SURVEY. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner · Blair Wondzell, P. I. Supervisor FROM- John Crisp? ~ ~. SUBJECT: Petroleum Insi~ector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000' I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON,CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Ry./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set' L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 p P OIL D-04RD 1820410 110 80 80 p P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 p P P OIL~ D-08RD 1740030 110 80 75 P P P OIL! D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS! D-20 1690950 110 80 90 P P OIL ~~ 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL, D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 p P OILi D-42 1830530 110 80 70 p p OIL~ D-43RD 1853110 110 80 70 p P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [~] 90 Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Pit. 6-22-00jc 1 ALASKA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 20, 2000 Chris Meyers/Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification MRF Wells D-25R and D-42 Gentleman: ' ~ On June 16, 2000 our inspector Lou Grimaldi witnessed "no-flow test on UNOCAL's McArthur River Field TBU wells D-25R and D-42. Prior to his arrival, both wells had been routed to the "Well Clean" tank, which is about 2 psig back pressure. Both wells had bled down when Lou arrived. He observed both wells for several hours and recorded gas rates far below the "no-flow" limit of 900 scl/hr. He noted rates of 190 to 600 scf/hr on D-25R and 180 to 275 scf/hr on D-42. Neither well had any fluid production. He recommended that "no-flow" status be given to both wells. McArthur River Field TBU wells D-25R (178-087) and D-42 (183-053) meet the criteria of"no- flow" performance test and as such, are considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A) they are not required to have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Sincerely, Blair E. Wondzell d~' Sr. Petroleum Engineer ~- fTO# t7cg- eyr MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman DATE: March 8, 2000 THRU: Blair Wondzell, Æ~ P. I. Supervisor :3 (f'{( oÒ SUBJECT: BOPE Test Dolly Varden 76 Unocal 0-25 Q \) McArthur River Field TBU ero-;~ \~'i;-O%\ NON-CONFIDENTIAL k-~~.I' ~ Wednesday, March 8. 2000: I witnessed the initial BOPE Test on UNOCAL's f O~ Dolly Varden platform (Rig #76) which was preparing to workover well #0-25 in ~-¥ the McArthur River field. FROM: Lou Grimaldi;P~ Petroleum In~p~ctor The test went well with all BOP equipment functioning properly and holding their respective pressure tests. There was some flange leaks that were attributed to nippling up. One on the choke manifold required the changing of a "O"-ring. The rig was in some need of cleaning and straightening up, Doug Nienhaus (Drilling foreman) had this scheduled for this evening after the conclusion of the test. SUMMARY: I witnessed the initial BOPE Test on UNOCAL's Dolly Varden platform rig 76. No failures, 4 hours test time NON-CONFIDENTIAL CC: Dan Williamson, Unocal Attachment: BOP Unocal 76 0-25 3-8-00 LG.XLS BOP Unocal 76 D-25 3-8-00 LG ( ~- 1\ /, <6 --0<67 Contractor: Nabors Rig Rep.: Donnie Fowler Operator: UNOCAL Rep.: Hauck/Nienhaus Well Name: D-25RD Location: Section: Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/5000 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: blair_wondzell@admin.state.ak.us and john_spaulding@admin.state.ak.us Rig No.: 76 DATE: 3/8/00 Rig Phone: 776-6847 Rig Fax: Op. Phone: 776-6847 Op.f~: \1%-ö<6'l ~?n1 -'-/~"OÇ PTD # "",' Meridian: Umiat Township: Ö,'<Ï Range: 13W Workover: X Explor.: Weekly: Other: Annular: 250/3000 Valves: 250/5000 TEST DATA 6 MISC. INSPECTIONS: FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly Housekeeping: P Dr!. Rig P Lower Kelly PTD On Location P Hazard Se P Ball Type 2 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size P/F CHOKE MANIFOLD: Annular Preventer 1 13 5/8 P Quantity P/F Pipe Rams 1 3x6 P No. Valves 13 F Lower Pipe Rams tv1anual Chokes 1 P Blind Rams 1 P Hydraulic Chokes 1 P Choke Ln. Valves 1 3" P HCR Valves 1 3" P ACCUMULATOR SYSTEM: Kill Line Valves 2 3" P Time/Pressure P/F Check Valve System Pressure 3000 P Pressure After Closure 1650 P MUD SYSTEM: Visual Alarm 200 psi Attained :49 P Trip Tank P P Full Pressure Attained 2:49 P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4@2000 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time: ~ Hours. Components tested 27 Repair or replacement of equipment will be made within N/A days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: blair_wondzell@admin.state.ak.us Remarks: Flange leak on Choke manifold, repared "OK". Otherwise GOOD TEST. Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO Waived By YES 24 HOUR NOTICE GIVEN X NO Witness Lou Grimaldi Unocal Corporation P.O. Box 196247 Anchorage, AK 99519 (907) 276-7600 UNOCAL ) Wednesday, December 22, 1999 AOGCC Attn' Mr. Jack Hartz 3001 Porcupine Drive Anchorage, AK 99501 Application for Sundry Approvals (10-403) Dear Mr. Hartz: Please find enclosed three Application For Sundry Approvals (Form 10-403) for the Dolly Varden Platform No. 25rd. The scope of the well work is to include the removal of the current completion, isolation of Hemlock Bench 3, and running a new completion that will allow for the addition of Tyonek G Zone intervals. Additionally a variance is requested for the following: Employ the use of secured 7,500 psi flexible lines fitted with WECO 1502 unions for service as a downstream choke line. This system is considered adequate for D-25rd, which has an estimated Hemlock reservoir pressure of 4,000 psi at 9,258'. This system was employed for the previous Dolly Varden workover (D-12rd) in September of this year. If you should have any questions regarding this request, please feel free to contact me at 263-7677. Dan Williamson Drilling Manager RECEIVED DEC ;5 0 1999 Alaska 0il & Gas Cons. Commission Anchorage .... STATE OF ALASKA .... ALASKA AND GAS CONSERVATION C ,MMISSION 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: X Variance: X Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 106' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 Anchorage Alaska 99519 Service: Trading Bay Unit 4. Location of well at surface Leg A-l, Cond. 8, Dolly Varden Platform 8. Well number 751' FSL, 1,210' FWL, Sec. 6.-8~-13W-SM D-25RD At top of productive interval 9. Perm,.number 360' FNL, 735' FWL, Sec. 8-8N-13W-SM 78-87/92-053 At effective depth 10. APl number 50-733-20247-01 At total depth 11. Field/Pool 498' FNL, 1,206' FWL, Sec. 8-8N-13W-SM Hemlock [') r"" 12. Present well condition summary ,~~, L ~,, [~ i V r"' Total depth: measured 11,510' feet Plugs (measured) None true vertical 10,021' v/ feet Effective depth: measured 11,415' feet Junk (measured) Perf gun @ approx. 11,29/~' true vertical 9,941' feet--laska 0il & Gas Cons. C0mr, Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,514' 13-3/8" 2,514' 2,446' Intermediate Production 8,t 55' 9-5/8" 8,155' 7,268' Liner 3,568' 7" 750 Sx 11,506' 10,015' Perforation depth: measured See Attached true verticalORIGINAL Tubing (size, grade, and measured depth) 4-1/2" N-80 @ 7,853', 3-1/2" N-80 @ 10,595' Packers and SSSV (type and measured depth) WD Packer @ 10,530' and 11,130", Otis LX Ball Valve w/DK Wireline Valve 13. Attachements Description summary of proposal: X DetaJlecl operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/1/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17.I hereb.~,~rtify that the foregoing is true and correct to the best of my knowledge. Sign ed.'~~?,J~~~J Dan Williamson Title: Drilling Manager Date:/2 %~ 3 ""~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. _ Plug integrity BOP Test ~ Location clearanceI .¢ ¢¢- Mechanical Integrity Test Subsequent form required 10- ~ ORIGINAL SIGNED'BY Robert N. Christenson Approved by order of the Commissioner Commissioner Date ~ission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Dolly Varden Platform Well No. D-25RD UNOCAL ) Cut Tubing RU E-Line. RU Lubricator, Pressure Test. RIH cut tubing above Packer. POOH. RD APRS. Kill Well Mix Kill Fluid. Displace Well to 3% KC1 Water. Pull Completion 1 Install BPV. 2 ND Tree. 3 NU Riser, DBL Gate, Hydril and valves. 4 Install Two Way Check, Test Joint. 5 Test BOPE to 5,000 psi. 6 Pull Test Joint, Two Way Check. 7 RU to Pull Completion. 8 MU LD Joint., Back Out Lock Down Screws. 9 POOH/LD 4-1/2" Tubing (7,853'). 10 RU to Pull 3-1/2" Tubing (2,677'). Mill 11 12 13 14 15 16 17 18 19 20 21 22 23 24 and Retrieve Packer Clear Rig Floor. RU to PU 3-1/2" Drill Pipe. PU BHA No 1. Packer Milling Assembly. RIH PU 3-1/2" Drill Pipe. MU Kelly. Mill 7" "WD" Permanent Packer at 10,530'. POOH. LD Milling Shoe/MU Milling Shoe No. 2 RIH to top of packer at 10,530'. Mill/Chase Packer. CBU. POOH. LD Milling Assembly. PU Overshot/Packer Fishing Assembly. RIH to Top of fish at 10,900'. Page I 12/23/99 Unocal Alaska Business Unit Dolly Varden Platform Well No. D-25RD UNOCAL ) 25 Catch Fish. 26 POOH. 27 LD Fish and Fishing BHA. Clean Out Fill 28 MU 6" Mill and Scraper Assembly. 29 RIH to 10,997'. 30 Clean out fill from 10,997'-11,130'. 31 Circulate sweep. 32 POOH. Run Scab Liner Assembly to isolate Bench 3 Perforations (10,865'-10,895') 33 RUE-Line. 34 RIH and Set Permanent Packer. 35 POOH with E-Line. 36 RD E-Line. 37 MU Scab Liner Assembly. 38 RIH. 39 Stab into Lower Packer, set Top Packer. 40 POOH LD Drill Pipe. Set Production Packer 41 RU E-Line. 42 RIH and Set Permanent Packer. 43 POOH with E-Line. 44 RD E-Line. Run Completion 45 Pull wear bushing, Prep to PU Completion. 46 PU Completion. 47 RIH with 3-1/2" Completion 2,200'. 48 RU to run 4-1/2" Completion. 49 RIH with 4-1/2" Completion 7,853'. 50 MU SSSV/Control Line. 51 RIH banding Control Line. 52 Space Out. 53 MU Tubing Hanger - Land. 54 Pressure test annulus. Page 2 12/23/99 Unocal Alaska Business Unit Dolly Varden Platform Well No. D-25RD UNOCAL ) 55 LD Landing Joint, Set BPV. 56 Nipple down BOPE. Perforate 57 Reperforate Hemlock Benches 0, 1, 3, 4. 58 Perforate G-Zone Benches 2, 3, 4. Page 3 12/23/99 UNOCALe RKB to TBG Head = 36.58' Tree connection: 4-116" 5,000# 15 8,000'-8,002' 1 Sqz. 200 sx Failed PT 2 sqx. 200 sx test to 2,500 psi 10,625'- 10627' Sqz. 200 sx i B-0 i B-1 B-2 -- B-3 PBTD = 11,415' TD = 11,506' SIZE 13-3/8" 9-5/8" 7" Tubing: 4-1/2" 3-1/2" NO. 8 9 10 11 12 13 14 15 16 17 18 19 20 ZONE WT Trading ~y Unit Well # b...3RD Completed 1/24/79 61.0 47 29 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 12.6 9.20 K-55 Butt. LT&C 12.515 Surf 2,518' P-110 Butt 8.681 Surf 8,155' N-80 Butt 6.184 7,938' 11,506' Depth ID N-80 AS[, 3.958 Surf N-80 Butt 2.992 7,853' JEWELRY DETAIL Item 41' 3.958 296 2.122 7,853' 10,595' 2,367' 3.890 3,731' 3.890 4,980' 3.890 6,064' 3.890 7,008' 3.890 7,835' 3.890 4-1/2" Cameron Type DCB 8rd X Butt Tbg Hngr 4-1/2" Otis DK Nipple (3.812" X profile). WLR SCSSV Gas Lift Mandrels are 4-1/2" & 3-1/2" Camco MMG w/1-1/2" Macco CM2-RC valve w/RK Latches 4-1/2" Mandrels Mandrel #1 w/12/64" port. Mandrel #2 w/12/64" port. Mandrel #3 w/12/64" port. Mandrel #4 w/12/64" port. Mandrel #5 w/16/64" port. Mandrel #6 w/16/64" port. 3-1/2" Mandrels 8,509' 2.875 9,026' 2.875 9,340' 2.875 9,648' 2.875 9,924' 2.875 10,236' 2.875 10,432' 2.875 Mandrel #7 w/16/64" port. Mandrel #8 w/20/64" port. Mandrel #9 w/20/64" port. Mandrel #10 w/20/64" port. Mandrel #11 w/20/64" port. Mandrel #12 w/24/64" port. Mandrel #13 w/24/64" orifice. 10,530' 3.00 10,566' 2.75 10,595' 2.992 1 I~.LA_30' 3.25 !_!,138' 2.75 "~11,148' 2.992 Fill Tagged on FISH: Otis "WD" Perm. Pkr. w/8' SBE, 20' Seal assy Otis "X" profile Nipple Mule Shoe Otis "WD" Pkr. Otis "X" profile nipple Bell Guide 4/5/99 10,997' WLM Perf. Gun 1/30/79 BarrelGrapple off GLV PT 8/17/96 Latch off Barrel Grapple on GLV #3 4,980' PERFORATION DATA TOP BTM AMT ASPF 11,290' WLM 11,067' WLM B-0 10,645 10,660 15' 16 B-1 10,726 10,744 18' 16 B-3 10,865 10,880 15' 8 10,884 10,895 11' 12 B-4 10,962 11,016 54' 20 11,030 11,130 100' 28 B-5 11,150 11,187 37' 12 11,200 11,285 85' 12 DATE REVISED: 12/13/99 TCB 1/89 7/92 11/85 11/85 7/92 3/92 11/85 11/85 DRAWN BY: SLT UNOCAL Tree connection: 4-1/6" 5,000# 8 9 10 11 15 16 17 18 19 ~ G-2 G-3 (3-4 B-0 B-2 B-4 PBTD = 11,415' TD = 11,506' 8,000'-8,002' 1 Sqz. 200 sx Failed PT 2 sqx. 200 sx test to 2,500 psi 10,625'- 10627' Sqz. 200 sx Fill Cleaned Outto 11,130' SIZE 13-3/8" 9-5/8" 7" Tubing: 4-1/2" 3-1/2" NO. 2 3 4 5 6 7 8 9 I0 11 12 13 14 15 16 17 18 19 ZONE G-2 G-3 G-4 B-0 B-1 B-3 B-4 B-5 WT Dolly V¢-~a~en Well No. _.-25RD Proposed CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 61.0 47 29 12.6 9.20 Depth ID K-55 Butt. LT&C 12.515 Surf 2,518' P-110 Butt 8.681 Surf 8,155' N-80 Butt 6.184 7,938' 11,506' L-80 Butt 3.958 Surf N-80 Butt 2.992 7,850' JEWELRY DETAIL Item 7,850' 10,110' 41' 300' 4-1/2" Cameron Type DCB 8rd X Butt Tbg Hngr SSSV GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 3-1/2" GLM, 3-1/2" GLM, 3-1/2" GLM, 3-1/2" GLM, 3-1/2" GLM, 3-1/2" GLM, 3-1/2" 10,100' TOP Locator, Seal Assembly Packer, 7", Perm. Seal Bore Extension Otis, 'X' Nipple, 2.813 Wireline Entry Guide Scab Liner Assembly Baker Packer 5", 15#, L-80, Scab Liner Baker Packer PERFORATION DATA BTM AMT ASPF DATE 10,173 10,267 10,306 10,645 10,726 10,865 10,884 10,962 11,030 11,150 11,200 10,193 20' 6 Proposed 10,285 18' 6 Proposed 10,345 39' 6 Proposed 10,660 15' 16 1/89 10,744 18' 16 7/92 10,880 15' 8 Scab 10,895 11' 12 Scab 11,016 54' 20 7/92 11,130 100' 28 3/92 11,187 37' 12 11/85 11,285 85' 12 11/85 REVISED: 12/13/99 TCB DRAWN BY: SLT Dolly Varden D-25RD Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments HB-0 10,645' 10,660' 9,328' 3,940' 15' HB-1 10,726' 10,744' 9,391' 9,405' 18' HB-3 10,865' 10,880' 9,501' 9,513' 15' HB-3 10,884' 10,895' 9,516' 9,525' 11' HB-4 10,962' 11,016' 9,577' 9,620' 54' HB-4 11,030' 11,130' 9,632' 9,711' 100' HB-5 11,150' 11,187' 9,727' 9,757' 37' HB~5 11,200' 11,285' 9,767' 9,836' 85' 335' Dolly Varden D-25RD Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments G-2 10,173' 10,193' 8,957' 8,974' 20' Proposed G-3 10,267' 10,285' 9,034' 9,048' 18' Proposed G-4 10,306' 10,345' 9,064' 9,095' 39' Proposed HB-0 10,645' 10,660' 9,328' 3,940' 15' Reperf HB-1 10,726' 10,744' 9,391' 9,405' 18' Reperf HB-3 10,865' 10,880' 9,501' 9,513' 15' Proposed Isolation HB-3 10,884' 10,895' 9,516' 9,525' 11' Proposed Isolation HB-4 10,962' 11,016' 9,577' 9,620' 54' Reperf HB-4 11,030' 11,130' 9,632' 9,711' 100' Reperf HB-5 11,150' 11,187' 9,727' 9,757' 37' HB-5 11,200' 11,285' 9,767' 9,836' 85' 412' 20' 18'-7" 18' RIG FLOOR BOTTOM ROTARY TABLE BTM RT BEAM PITCHER NIPPLE BOTTOM TROLLEY BEAM 116,, RISER I HYDRIL 13-5/8" GK 5M ANNULUR PREVENTEF · CHOKE 13-5/8" SM DOUBLE GATE BOP ( TOP PIPE RAM ~ BLIND CELLAR FLOOR DRILL DECK 17' FLOOR 13-~" x 11" 'i 5M CROSSOVER SPOOL DOLLY VARDEN PLATFORM COOK INLET, ALASKA CONTRACTOR i CONIC. JOB NO. SDL 272:. DOLLY VARDEN PLATFORM ..... BLOW OUT PREVENTER ..... D-25RD c).^~wo NO. UNOCAL D-DV-01 5 ..~ ~/3o/~ ~ 1 OF 1 To Production Header: 1502 Weco Threaded Connection x 2" 7,500 psi flexible line UNOCAL Portable 5M psi Choke Manifold To Crown Vent Line: 1502 Weco Threaded Connection x 2" 7,500 psi flexible line Choke All valves are National 5M psi manual ball valves Choke To Drain: Manual Choke From BOP Choke line: 2" 7,500 psi flexible line with Baker-locked 4-1/16" 5M psi flange bolted to inlet Unocal North American Oil & Gas Division .... Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL December 1, 1992 TO: Larry Grant LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT D-7, D- Z 1, D- 12RD, D-25RD 1 blueline and 1 sepia Perforating Record PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANS~IITTAL. THANK YOU RECEIVED BY: ~.~ ~ i~ u' ' ~" DATED: ~ ~,,; ,:..; ' ~:: Alaska 0ii & Gas Cons. Anchorage MEMORAN TO: THRU: David Johrjs~, Chairma[~P' Blair Wondzell, ,x'~. P. I. Supervisor State Alas.ka ' Alaska Oil and Gas COnservation Commission~ DATE: April 9, 1994 FILE NO: 9VEJDHBD.DOC FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No Flow Verification -' Wells #D-20,12,27,28,&25 Marathon Dolly Varden platform Middle Ground Shoal Field Friday, April 8, 1994: I traveled to Marathon's Dolly Varden platform in the Middle Ground Shoal field of Cook Inlet to verify t'he No Flow status of five wells. When I arrived the wells had already had their gas lift shut in and the tubing flowed down to the group separator, These were then flowed to the well clean system which has approximately .5 psi back pressure on it. The wells tubing was then routed to open top containers with water in them. All wells bled only gas and died off quickly with the exception of well #D-25 which kept flowing gas and would build up to 160 psi rather quickly, this may have been residual gas in the annulus coming through a leaky gas lift ~alve. The platform needed this well back for production and we did not attempt any further tests on other wells. Recommendations: Wells # D-20, D-12, D-27, and, D-28 exhibited a inability to flow from the formation without the assistance of artificial lift and met the criteria for No Flow status. Well # D-25 would not die off and should be maintained as a flowing well. Summary: I verified the no flow status of 4 wells on Marathon's Dolly Varden platform. cc: Don Lacour (Production Superintendent) 0 R I G I ALASKA OIL AND GAS GONSERVATION COIVIMI$$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging m Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator I 5. Type of Well: ,,J _ D, evelopment X UNOCAL (Marathon Oil Comnanv - Sub U,lperaT. or}Exploratory__-- 3. Address ' ' " ! Stratigraphic w P. 0. Box 190247 Anchoraqef AK 9951~ Service__ 4. Location of well at surface Leg A-1 Cond. #8 Dolly Varden Platform 751' FSL, 1,210' FWL Sec. 6- 8N- 13W- SM At top of productive in[erval ' 360' FNL, 735' FWL, Sec. 8 - 8N - 13W - SM At effective depth 12. Perforate At total depth 440' FNL, Present well condition summary Total depth: measured true vertical 1,252' FWLf Sec. 8- 8N- 13W- SM 11,510' feet 10,021' feet Other 6. Datum elevation (DF or KB) L06' KB above MSI 7. Unit or Property name Trading Bay Unit 8. Well number D-25RD 9. Permit number/approval number 78-87 / 92-053 10. APl number 5o1-33-20247-0! 11. Field/Pool Heml cc k feet Plugs (measured) None Effec!ivedepth: measured 11 415' feet Junk(measured) true vertical i feet 9,941' Perf Gun @ approx. 11,290' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,514' 13-3/8" 2,514' 2,446' Intermediate Production 81155' 9- 5/8" 8, 155' 7,268' Liner 3,568' 7" 750 s x 11,506' 10,015' Perforation depth:measured true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' Packers and SSSV (type and measured depth) SSSV - Otis XL ball valve nipple w/DK wireline valve r)f_i~ WF) 4.(10" hore nkr w/8' SBE fa 10.530' and fa 11.130~ ~...,-.~ 13. Stimulation or cement squeeze ~ummar~/ K ~ L b I V ~ L~ 14. Intervalstreated (measured) ...... !'d ~,/ ~ 7 !O00~,~ Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0mmiss~0~ Representative Daily Average Production or Injection I~h°ra~[~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 267 ,¢~ 293 1226 1140 160 Subsequent to operation 304/: 223 1332 1140 120 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (3_,._,., % . ~ ~~ Title v, ,~,\ Form 10-404 Re"'VV~06115/~ Date \t./t~ }o'1 L~ SUBMIT IN DUPLICATE DAILY WELL OPERATIONS D-25RD 3/7/92 Safety meeting. RU BOPE and lubricator. Pressure tested BOPE and lub to 2500 psi. Established CBO. MU & armed 30', 2-1/8' strip, 4 SPF, 20.5 gram DP charges. RIH. CCL malfunctioned. POOH. 3/8/92 RIHwith 30' 2-1/8" strip, 4 SPF. Opened well to flow. Perforated HB #4 11,030' - 11,060' DIL underbalanced. POOH. All shots fired. MU & armed 15' 2-1/8" strip, I SPF gun. RIH. Set down @ 10,760' DIL. Unable to lower guns. POOH. RIH w/ weight bar and CCL. Tag 0 11,061' DIL. POOH. RIH w/ 16' perf gun. Unable to work guns past 10,760' DIL. Aborted HB-3 reperf. Perforated HB #1, 10,727 to 10,742' DIL w/ 2-1/8", 4 SPF strips underbalanced. All shots fired. RD. Returned well to production. H: \wp\WE LLOPS\D25RD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate m Plugging __ Perforate ~ Pull tubing __ Alter casing ~ Repair well __ Other 2. Name of Operator UNOCAL (Marathon 3. Address P. 0. Box 190247 ! 5. Type of Well: Oil Company - Sub (~perato~vel.°Pm.entIx ! ~xp~ora[ory ~ ! Stratigraphic Anchorage, AK 995:]9 Service---' Leg A-1 Cond. #8 Dolly Varden Platform FWL, Sec. 6- 8N- 13W- SM FWL, Sec. 8 - 8N - 13W - SM 4. Location of well at surface 751' FSL, 1,210' At top of productive interval 360' FNL, 735' At effective depth Att°~az~)elptl~NL, 1,252' FWL, Sec. 8- 8N- 13W- SM 12. Present well condition sUmmary Total depth' measured true vertical 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-25RD 9. Permit number/approval number 78-87/92-207 10. APl number 50-133-20247-01 11,510' feet 10,021' feet 13. Plugs (measured) feet 11. Field/Pool Hemlock None Effective depth: measured 11,415' feet Junk(measured) Perf Gun @ approx. 11,290' true vertical 9,941 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,514' 13-3/8" 2,514' 2,446' Intermediate Production 8,155' 9-5/8" 8,155' 7,268' Liner 3,568' 7" 750 sx 11,506' 10,015' Perforation depth:measured true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' S S p andmea ured h) SSSV - Otis XL ball valve nipple w/DK wireline valve %gckl%Sa~ ~.~ elJore p~r w~&p~ SBE @ 10,530' and @ 11,130' RECeiVED stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure I": 2 0 1392 Alaska OiJ & Gas Cons. Cornrnissiort Representative Daily Average Production or I njection~,~10ra§~ Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 14. Tubing Pressure 160 / 223 1890 1180 150 454 ¥ 172 2396 1100 150 16. Status of well classification as: Oil X__ Gas __ Suspended __ Prior to well operation Subsequent to operation Service Date SUBMIT IN DUPLICATE 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _.~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~c~.,,.~% ~'~. ~)~ Title "~;,~\~,,.~,.~ Bench 0 1 2 3 4 5 Attachment #1 TBU Well D-25RD Perforation Intervals MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' docs\dvp\d25rd, doc DAILY WELL OPERATIONS D-25RD 7/27/92 P. T. lubricator to 2500 psi - OK. Est. communications black-out & arm guns. RIH w/ 2-1/8", 4 SPF, zero phased, strip gun. Offset 30 degrees. Perforated 11,030' - 11,060' DIL. 7/28/92 Made up 30' select fire 2-1/8" enerjet perf gun w/ 2 - 15' intervals. Establish communications blackout. RIH. Flowed well for 30 min. Perforated HB #3 11,000' - 11,015' DIL. Picked up and perfed HB #1 10,726' - 10,741' DIL. POOH. All guns fired. Rigged down. Return well to production. H: \wp\WEL LOPS\D25RD ..... STATE OF ALASKA .... 0 g I G ~ A L ALASKA OIL AND GAS CONSERVATION COMMISSION ~) FIF_POFIT OF SUNDRY WELL OPEi: TIONS 1. Operations pedormed: Operation shutdown __ Stimulate__ Plugging __ Perforate Pull tubing Alter casing __ Repair well __ 2. Name of Operator I 5. Type of Well: ~ ..... ,1__~ Development ~ UNOCAL (Marathon Oil Co - Sub vprerctuur] Exploratory__ 3. Address ! Stratigraphic ~ P.O. Box 190247 Anchorage, AK 9951~9 Service__ 4. Location of well at surface Leg A-Z, 6ond. #Z Dolly Varden Platform 751' FSL, 1,210' FWL, Sec. 6-8N-13W-SM At top of productive interval 360 FNL, 735' FWL, Sec. 8 At effective depth Other X CT Cleanout & Pe 'f 6, Datum elevation (DF or KB) 7. Unit or Property name Trading Bay Unit 8. Well number 8N-13W-SM At total depth 440 FNL, 1,252' FWL Sec. 8-8N-13W-SM D-25RD 9. Permit number/approval number 78-87 10. APl number 5o- 133-20247-01 11. Field/Pool Hem 1 cc k feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,514' Intermediate Production 8,155 ' 3,568' Liner Perforation depth: measured true vertical 11,510' 10,021' 11,415' 9,941' Size feet feet feet feet 13-3/8" 9-5/8" 7" See Plugs (measured) Junk (measured) Cemented 750 sx Attachment #1 Tubina (size, grade and measured depth) . 4 1./2", 12'.6#, N-80 ASL Tubing to 7,853' x 3-1/2" SSV = 0tis LX ball Packers and SSSV (type and measured depth) 13. ~tlmulatlon or cemem squeeze summary None Perf Gun 6 approx. 11,290' Measured depth True vertical depth 2,514' 2,446' 8,155' 7,268' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/18/92 309 / 339 1259 1140 130 Subsequent to operation 4/23/9 2 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~ 303 / 364 2972 1250 16. Status of well classification as: Oil ~W Gas_ Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev ((~5/8~ .._) Date '-1 I%t SUBMIT IN DUPLICATE Bench 0 1 2 3 4 5 Attachment #1 TBU Well D-25RD Perforation Intervals MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD .... 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' docs~dvp~d25rd, doc RECEIVED AU G 1 7 1992 Alaska 0il & Gas Cons. Commission Anchorage DAILY HELL OPERATIONS D-25RD 4/4/92 R/U Otis. Pressure tested to 2500 psi. TEST GOOD. RIH and latched DK 6 269' Bled CL pressure. POOH w/ valve. C/O GB w/ 2.7" GRL. RIH and tagged hard fili 0 9240' WLM. RD off well. RT well to production. Otis cleaning up and prep equip to move. Otis to beach. 4/5/92 Crews on board. Platform safety orientation. Safety and operational meeting with foreman, operators, crews. Started spotting equipment for RU. SI well to RU on D-25RD. CT RU on well w/ blank tubing. Pressure tested coil, surface lines, BOPE, BOPS, lub to 2500. GOOD. Tested same to 5000 spi. GOOD. Tested pipe rams, shear rams. GOOD. MU tool string and test ops. Tested check valves. GOOD. Started blending polymer pill ~ 2.5 lbs/BBL for tbg. Started RIH w/ 2.7 bit, motor, circ sub, HYD disc, check valves, x-over. Started stacking gas 0 5000 CTM. Slight gas bubbling @ x-over in tree. Tbg press @ 1400 psi. SI lift gas and opened well to flow to relieve pressure. Gas leak stopped 0 450 psi. POOH w/CT. OOH w/ CT. Pulled x-over and taped w/ teflon. Pressure tested to 5000 psi. TEST GOOD. Secured surface equipment for night. C/O stripping element and test. GOOD. SDFN. Started stacking gas to tubing under closed valves for high pressure gas test in a.m. Warming up equipment. 4~6/92 RIH w/ drilling assembly @ 85 FPM. 3800'. PTBG ~ 1400 psi. Cracked choke. Opened well to flow @ 0945 w/ tbg hanging 0 7800'. Drilled 0 30 FPM w/ PU weights normal. PU torque @ 10,200. Circulated 10 BBL pill (2.5 lbs/BBL xanvis w/ breaker). Continued drilling @ 20 FPM w/ slick water (qrt/1,000 gal FR26L). Cleared tubing tail w/ 2.7" diamond bit. Pumped 2nd 10 BBL pill and circ bottoms up w/ slick water 0 2 BPM. Rolled pumps 0 1/2 BPM while POOH to 8000'. SO pumps & SI lift gas. OOH w/ ct. All tools recovered. OD of used bit 2.7". C/O bit w/ under reamer and added circulating sub. Function test underreamer. GOOD. Pressure test to 5000 psi. TEST GOOD. RIH w/ underreamer @ 60 FPM. Set down on bridge 0 8300' Rolled pumps to 3/4 BPM and tried to roll tools. PU coil to 4-1/2 tbg. RT weil to flow. Bridge let go. RIH w/ well flowing. Cleared tbg tail. Rolled pumps to 1.75 BPM and started underreaming. Pumped 10 bbl pill 0 10,860'. Worked through tight spots @ 10,860', 10,865', 10,884', 10,960'. Unable to work deeper than 11,088' Pumped 4th pill @ 11,~88' Worked underreamer up and located tbg tail @ ~0,561. Corrected TD 11,124 . ~tarted 30 bbl C/U pill. Dropped 1/2" ball to open circ sub. 4~7~92 Circulation of polymer completed. Slowed pumps to 1BPM. POOH. SD pumps. OOH w/ ct. closed TP mstr. Circ 3~o KCL to production. C/O 3~o w/ FIW to displace reel. Full recovery of tools. Little damage to cutting arms. Started RD & cleaning area. Well secured & rt to production. RD surface equipment & policed area. RD complete & decks cleaned. Crews to beach. H: \wp\WELLOPS\D25RD -2- 4/21/92 SWS on platform. Platform safety meeting for new crews. Well Operational meeting with operator and SWS. Spill reporting, waste segregation and handling, and safety issues discussed. SI well to RU. Pressure test to 2400 psi. Test good. Established CBO. MU and armed 15', 2-1/8", 4 SPF, O-Phase, offset 30 degree strip gun. Disarmed gun. Unable to read out tension. Secured well with night cap. RT to production w/ swab closed. SDFN. New tension device out on a.m. chopper. 4/22/92 Equipment on DVP. Check out and test. Good. Est CBO. Re-armed gun. RIH w/ 15' EJ strip, 4 SPF, 2-1/8", O-phase offset 30 degree. Opened well to flow for underbalance, tag TD ~ 11,090' DIL. Tied into DIL. Perforated HB @ 3 from 11,000' to 11.015' (15') DIL w/ guns noted. Flowed 20 minutes for clean up. SI well to POOH. Re-established CBO @ 1000' ELM. OOH with guns. All shots fired. Recovered 5/60 charge bases. RD and clean up pipe rack. Secured well with tree cap. Well RT to production. Crews to beach. H: \wp\NEL LOPS\D25RD MARATHON OIL COMPANY TRADING BAY T WELL D-25Rb 13-3/8' 61~ K-55 Butt Csg e 2518' 4-1/2' x 3-1/2' X-Over ~ 7B53' TOL 7' 1~ 7938' ~ 9-5/8' 47~ N-80 Csg e 8155' 7' 29ff N-80 Linen to 11,506' Tagged Fill 11,184' 4/98 Complete01 01/24/79 10,530' 10,566' 10,595' B-O B-1 11,130' 11,138' 11,148' Att measurements are RKB to ±up oF equipment. 41' Cameron Type DCB 8RD x Butt Tbg HnQr (3.958' ID) 296' Otis XL Bat[ Valve Nipple wiretine ret. valve Completion String: 0'-7853' 4.52 18.6t4 N-80 ASL Tbg. (3.958' ID), 7853'-1.0,595' 3.5', 9.2ft N-80 Butt Tbg. (2.992' ID). Gas LiFt Mandrels are 4,5' & 3.5' Camco MMG w/ Macro 1.5' CM2-RC valves w/RK Latches. 4.5' mandrels = (3.890' ID), 3.5' mandrels = (;3.875' ID). 4.5' Mandrels VaLve~ 2367' ~1 12/64 Port 3731' ~2 12/64 Port 4980' ~3 1;3/64 Port 6064' ~4 1;3/64 Port 7008' ~5 16/64 Port 7835' ~6 16/64 Port 3.5' Mandrels 8509' ~7 90;36' ~8 934O' 9648' ~lO 9924' ~11 10,;336' ~12 10,438' t~13 Otis 4.00' ~/D Pkr (3.00' ID) w/8' SBE. (3.00' ID) stung into pkr. Otis X nipple Mule shoe 16/64 Port ;30/64 Port 20/64 Port 20/64 Port 20/64 Port 24/64 Port ;34/64 OriFice ;30' seal assy Per Foration~; B-O 10,645'-10,660' 4 SPF O' Phasln9 1/89 B-1 10,7;36'-10,744' 4 SPF ' 11/85 B-2 10,865'-10,880' 4 SPF ' 1/89 10,884'-10,895' 4 5PF ' 1/89 B-3 10,968'-11,016' 4 SPF ' 11/85 B-4 11,030'-t1,130' 4 §PF ' 1/89 B-5 1L150'-11,187' 4 SPF ' 11/85 11,200'-11,285' 4 SPF ' 11/85 Avg. Dev. = 37.75' Otis ~JD Pkr (3.250' ID). Otis X nipple. Bell Guide. B-5 Lost PerF Gun ]/30/79 PBTD ~ 11,415' 'rD ~ 11,506' Revision Date: 7/27/92 Revised By: JDM/evo Reason, CT Ceonout Previous Revision, 1E/17/91 STATE OF ALASKA AL~CKA OILAND GAS CONSERVATION COMM~t~Nt ~ i J~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ ' Alter cas~nQ __ Repair well __ Change a~oroved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time ex'tens,on __ ,,St~mulale __ Puli tubing __ Vanance __ Pedorate ~ Other __ - y UNOCAL (Marathon 0ii Company - Sub ~peratoPiFe?o~em" | ~xploratorv __ · 31 Address | StratigraphiC __ P. O. Box 190247 Anchorage, AK 995~9 Service__ 4. Locat)on of wetl at surface L:g A-1 Ou,d. #~ Dul ~y Vardun Pi~LFo,",~ 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 360' FNL, 735' F14L, Sec. 8 - 8N - 1314 - SM At effectwe depth total depth 440' FNL, 1,252' F14L, Sec. 8 - 8N - 1314 - SM 106' KB above NSL feet 7. Umt or Property name Trading Bay Unit 8, Well number D-25RD 9. Permit number 78-87 10. APl number 5cr-~33-20247-01 11. Field/Pool H eml ock 12. Present well condition summary Total del)tin: measured true vertical 11,510' feet 10,021" feet Plugs (measured) None Effective depth: measured 11,415 ' true vertical 9,941' feet Junk (measured) feet Perf Gun (a approx. 11,290' Casing Length Size Structural Conductor Surface 2,514' 13-3/8" Intermediate Production 8,155' 9-5/8" Liner 3,568' 7" Perfora[ion depth: measured true vertical %;b~ng (s~ze, grade, and measured depth) Cemented 750 sx Measured depth True vertical depth See Attachment #1 2,514' 2,446' 8,155' 7,268' Al~$k~ Oil & G~s Cons. Commissio~ Anchorage 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' Pa,c.k~rsandSSSVftvDeandmeasureddeDth) SSSV - Otis XL ball, valve nipple w/DK wireline valve 0~:]s WD 4.00'1 bore pkr w/8' SBE @ 10,530' and @ 11 130 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operation 7/24/92 16. If proposal was verbally approved Name of approver ['like Minder 7/23/92 Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Gc,_~-. -, ~ , (~,._.,~ Title ~-'"~_o.,,, ~ -~ ~ ~.-A..~,r ~ -~ ' ' FOR COMMISSION USEO~ILY %' ' Conditions oflaCprovaT: Notify Commission so representative may witness Date Plug integrity __ Mechanical Integrity Test __ Approved by order of the Commission Location clearance __ BOP Test __ bpproval No. ~",2 - ,.~) O '7 Approved ,Jc,_ py Returned Subsequent form required 10- .~O~ Original Signed By David W. Johnston Commissioner Date SUBMIT IN Tt~IPLICATE Form 10-403 Rev 06/15/88 Attachment #1 TBU Well D-25RD Perforation Intervals Bench M_~D 10,645' - .10,~6q0' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' 11,016' 11,030' - 11,130' 11,150' 11,187' 11,200' 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' \docs\dvp\d25rd.doc RECEIVED AU(3 1 ? 1992 Alaska 011 & Gas Cons. CommiSSion Anchorage NELL D-25RD e . . . ~,n a 24-hour test w;th a minimum of four ~) WC s. ~u,,uuct safety meeting. Ensure adequate lighting for night operations. Skid Rig over well D-25RD (Leg A-l). RU wireline unit. Hook up communication system in unit. Pressure test lubricator and BOPE to 2500 psi. SI lift gas and let well die. SI choke and manumatic. RIH w/ 4-1/2" pulling tool dressed to pull WLR DK SCSSV. Latch valve and POOH. RIH w/ 2.70" GR and tag fill. POOH w/GR. RD wireline unit. RU E-line unit. Hookup communication system. Pressure test lubricator and BOPE to 2500 psi. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish communications blackout. Re- establish communication black out when guns are at 1000' when POOH. SI well to RIH. RIH with 2-1/8" strip guns, 4 SPF, 0 degrees phasing, offset 30 degrees and perforate the following interval underbalanced (well flowing). Open choke and stabilize flow prior to perforating. RUN BENCH INTERVAL (DIL) FOOTAGE I HB #4 11,100' - 11,130'* 30' 2 HB #4 11,030' - 11,060' 30' 3** HB #3 11,000' - 11,015' 15' HB #1 10,726' - 10,741' 15' 4 HB #0 10,645' - 10,660' 15' * or as close to bottom as possible. Flow well for clean-up approximately 15-20 minutes after perforating interval. Prior to POOH, shut in well. ** Use select fire system to shoot HB#1 and #3 in a single run. H: \wp\WLPRO\D25RD -2- 12. 13. 14. 15. 16. 17. RD E-line. Flow well to group separator at a reduced rate slowly opening the choke completely over about 4 to 6 hours. Continue to flow well in group separator for clean-up. Obtain a 24-hour well test. RU wireline unit. Hook up communication system in unit. Pressure test BOPE and lubricator to 2500 psi. SI wel 1 with manumatic and choke. RIH with 4-1/2" setting tool dressed to set Otis DK SCSSV @ 296'. Set DK SCSSV and POOH. Test SCSSV by bleeding tbg pressure and monitor for PBU. RD Otis. Equalize across SCSSV and open WLR SCSSV. Return well to producti on. Obtain a 24-hour test. H: \wp\WLPRO\D25RD REEEIVED Alaska Oil & Gas Cons. Anchorage MARATHON OIL CFZ~PANY TRADING BAY IT WELL }-85Ru 13-3/8' 61~ K-55 Butt Csg e ~'518' 4-1/2' x X-Over ~ 7853' / TOL 7' ~ 793B' 9-5/8' 47~ N-80 Csg ~ 8i55' 7' 89~ N-80 Liner to 11,506' Togged FiLL 11,184' 4/98 Completed 01/24/79 J ~U measurements are RKO to ±OD OF equipment. 41' Cameron Type ~,retine ret. valve Comptetion String: 0'-7853' 4.5', 18.6~ N-80 ASL TOg. (3.958' ID). 7853'-10,595' 3.5', 9.8~ N-80 Butt Tbg. (~.99~' ~D). Gas LiFt Mandreis are 4.5' & 3.5' Camco MMG w/ Macco 1.5' CM2-RC valves w/RK [arches. 45' mandrels = (3.890' ~ 3.5' mandrets= (;~.875' ID). ~.~' MonolreL~ Votves 2367' ~:1 12/64 Port 3731' ,~8 12/64 Port 4980' ~3 ]~/64 Port ~064' ~4 ]8/64 Port 7008' ~5 ]6/64 Popz 7835' ~6 16/64 Popt 3.5' MandreLs 8509' ¢7 !6/64 Port 9086' ~8 20/64 Port 9340' ~9 20/64 Port 9648' ~10 20/64 Port 9924' ~11 20/64 Port i0,236' ~12 24/64 Port 10,438' ~13 84/64 OriFice 10,530' Otis 4.00' ~D Pkr (3.00° ID) w/8' SBE. PO' seat ass¥ (3,00' LO) stung into orr. ]0,566' ~tis X nipple 10,595' Mule shoe 11,130' 11,1:38' 11,148' B-O 10,645'-10,660' B-1 10,7;~6'-10,744' B-8 10,865'-10,880' 10,884'-10,895' B-3 10,968'-11,016' B-4 11,030'-11,130' B-5 11,150'-11,187' 11,200'-11,285' P~rFQration~ 4 SPF O' Phasing 1/89 4 SPF ' 11/85 4 SPF ' 1/89 4 SPF ' 1/89 4 SPF ' 11/85 4 SPF ' 1/89 4 SPF · 11/85 4 SPF · 11/85 Avg. Dev, = 37.75' Otis V/D Pkr (3.250' ID). Otis X nipple. BeLL Guide. B-5 Lost Per? Gun 1/30/79 PBTD I~ 11,415' 1-D 8 11,506' Revision Date: 7/27/92 Revised By: dOM/eva Reason: CT Ceanout Previous Revision: 1~/17/91 DOLLY VARDEN P~ATFORM Wireline Lubricator w/Associated BOPE ,,. GREASE HEAD (Hydraulically Activated) , LUBRICATOR MANUALLY OPERATED BOP REEEIV£D AU G 1 ? 1992 Alaska Oil & Gas Cons. GommlsSlon Anchorage 4' ~1X.-1.6~. '5 0 0 0 psi CHISTMAS TREE POSITIVE CHOKE ----- 2' 5000 pal ..- 2' 3ooo 13 3/8' CASING .... 0 R I G I N /L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandor~ __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension ~ Stimulate __ Pulltubing__ Variance__ Pedorate~ other.~__OT C] eanout 2. Name of Operator ~ 5. Type of ,Well: UNOCAL (Marathon Oil Company - Sub ~)peratd:le])e~opment~ J Exploratory __ 3. Address _ _L_ Stratigraphic_ P. O. Box 190247 Anchorage, AK ggSit9 Service__ 4. Location of well at surface "-.9 ""-.'- ~.'.""-'- ~'.-.' L/V, ,y va, uc,, , ,,-,,..,~,, ,,, 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top ofproductive interval 360' FNL, 735' FWL, Sec. 8 - 8N - 13W - SM At effective depth 6. Datum elevation (DF or KB) 106' KB above MSL .~ Uni,t pr Pro,qerty raalng m~ay nua~nl~t 8. Well number D-25RD 9. Permit number 78-87 10. APl number 5o-133-20247-01 1;~, Fidd/Pool Hem I OCK Att°t~lzCi~'l~thFNL, 1,252' FWL, Sec. 8- 8N- 13W- SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,510' feet 10,021' feet 11,415' feet 9,941' feet Plugs (measured) Junk (measured) None Perf Gun La approx. 11,290' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 2,514' 13-3/8" 2,514' 2,446' 8,155' 9-5/8" 3,568' 7" measured 750 sx 8,155' 7,268' APR 1 0 199 true vertical See Attachment #1 Alaska Oil & Gas Cons. Cornrrtis¢On Tubing (size, grade, and measured depth) Anchorage 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' SSSV - 0tis XL bail valve nipple w/DK wire'line valve Pa~.~r~a~]SS~d~e n~d~r'n~ e a~sp. Le d. _d. ~l~t h ) , , ~uv~ p~r w/o SBE La 10,530 and La 11,130 13. Attachments 1, 2, Description summary of proposal 3,&4 Detailed operations program __ BOP sketch .,X- 14. Estimated date for commencing operation April 4, 1992 16. If proposal was verbally approved Russ Douglass ~ Name of approver April 3, 1992 Date approved 15. Status of well classification as: Oil ..X_ Gas __ Suspended __ Service 17. I hereby c/e~ify that the foregoing is true and correct to the best of my knowledge. Conditions of a~rova~otify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-. ¢ ¢ Date JApproval No. ~.~_ O ~(~ Approved by order of the Commission Commissioner feet Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench 0 1 2 3 4 5 Attachment #1 TBU Well D-25RD Perforation Intervals MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' docs\dvp~d25rd, doc Gas Gons. Attachment #2 TBU Well D-25 PROCEDURE · Skid rig #76 over D-25RD. Obtain 24-hour well test w/ 4-WC's. Swap power to rig #76 and ensure draw works are operational. 2. Hold operational meeting with OTIS and operators. SI well. e RU wireline unit. Install new packoff in wireline lubricator and insure adequate lighting for night operations. Hook up communication system in unit. MU 4-1/2" GS pulling tool. Pressure test BOPE to 2500 PSI. Secure unit with chains. e RIH and latch DK ball valve @ 296' WLM. Bleed CL pressure and POOH w/ DK ball valve. RIH with 2.7" GR and tag scale in tubing. POOH. RD OTIS completely. RT well to production while spotting CT equipment. Clear East Pipe Rack of all non-required equipment. Spot CT unit & accessories, pumping unit and blenders. e Hold operational meeting with CT and pumping personnel, production foreman, and operator. Route D-25RD to well clean tank. SI lift gas and let well die. · RU coiled tubing unit. RU communication system in CT unit. Ensure adequate two-way radios for all parties. Pressure test BOPE, lub, and check valve w/ WF to 2500 PSI. Open CT to ensure check valve is holding. Pressure test lines to pump and CT reel to 5000 PSI w/ pumps against tree valves. e RIH w/ 1.5" coiled tubing w/ fishing neck, check valve, 2-3/8" motor, and 2.7" diamond bit to 7800'. **** Notify Trading Bay Production Facility of polymer w/ breaker being pumped though pipeline. ge RT well to production and let stabilize. Blend polymer +/- 40 BBLs. Roll pumps up to I BPM w/ FIW while RIH to 2.7" scale tagged with GR. Pump a 10 BBL polymer pill. Drill out scale pumping a 10 BBL pill every 300' or as conditions dictate. Work 2.7" bit to tubing tail @ 10,600'. Pump 10 BBL pill after clearing tubing tail followed by 160 BBLS FIW to clean up tubing. Use lift gas for assistance. 10. Decrease pump rate to 1/4 BPM FIW and POOH slowly with drilling assembly. SI lift gas and pumps ~ 8000'. 11. Break out 2.7" bit and downhole motor. Gauge bit and determine wear. Repeat drill out if bit is less than 2.67" OD. 12. MU hydraulic disconnect, downhole motor, 2-3/8" ported sub, circulating sub and 2-3/8" underreamer w/ 5-3/4" blades. 13. Mix 3~o KCL with FIW and blend polymer pills w/ potable water w/ 3% KCl and potasium persulfate breaker. 14. RIH w/ coiled tubing and underreamer to 10,625'. Return well to production. Start pumping 3~o KCL at 2 BPM.Obtain PU weights and use as base line. 15. Underream from 10,625' to 10,750'. Pump polymer pill w/ friction reducer maintaining 2 BPM. Chase pills with 22 BBL slug KCL. Continue underreaming downhole not exceeding 1500 pounds on underreamer alternating 10 BBL polymer and 22 BBL KCL. Alter size of spacers of KCL according to ROP and depth. 16. Continue underreaming to 11,125' CTM. Drop 1/2" ball to open sleeve in circulating sub. 17. Pump a 20 BBL polymer pill and circulate bottoms up (184 BBLs) ca 2-2.5 BPM. Continue moving tbg up and down over lower 400' of interval while circulating. 18. Slowly POOH pumping KCL ca 2 BPM. Shutdown pump when downhole assembly is at 10,625'. SI lift gas. POOH w/ underreaming assembly. NOTES: 1. PUMP RATES SHOULD BE 2 BPM 2. VOLUME EST OF POLYMER: 180 * 1.5 S.F =270 BBL 3. POLYMER WILL BE XANVIS (NON-IONIC, 3.0#/ BBL) 4. FRICTION REDUCER: XANVIS ca 1/4#/ BBL AS REQUIRED e NOTIFY TBPF OF NON PRODUCED FLUIDS (XANVIS POLYMER AND FIW W/3~ KCL) 6. pH OF XANVIS REQUIRED: 8.5. · MAX TENSION ON 1.5" COILED TUBING 30K (1004 YIELD) 25K ( 80% YIELD) CAPACITIES: 1.5" CT = 1.597 BBLS/iO00' 1.5" CT X 3.5" TBG = 0.00651 BBLS/FT 1.5" CT X 4.5" TBG : 0.01303 BBLS/FT 1.5" CT X 7.0" CSG : 0.03496 BBLS/FT 19. RD Coiled tubing unit and pumping equipment. RECEIVED APR 1 0 1~2. Alaska Oil & Gas Cons. CommissiOr~ Anchorage 22. 23~ RT well to production. Obtain 2 ~ 24-hour tests obtaining 4 WC's per test. Test well every other day for 12 hours obtaining an additional three tests. Reperforate selective zones and pump scale treatment. Reset WLR DKX ball valve. \docs\dvp\d25rd.doc RECE V,£D APR 10 ~992 Alsslm Oil & Gae Cone. Anchorage STLC :LHEAD PLATFI RM Coiled TUbing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 I~si WP HYDRAULIC RAMS' ..'4'1~16", 5000 psi CHISTMAS TREE POSITIVE CHOKE "' 2' 5000 2' 3000 13 3/8' CASING M~RATHF1N Ii]IL 'MP~NY TR~DIN~ ~¥ dNIT WELL 13-3/8' K-55 Butt Csg e 8518' 4-t/E' x 3-1/E' X-Over e 7853' TOL 7' ~ 7938' 9-5/8' 47t~ N-80 Csg ~ 8155' 7' 29ff N-80 Liner to 11,506' Tagged Fill 1Ll15' 3/89 AIL measurements ore RKB to top oF equipment. 41' S~meron Type DC3 8RD x Butt Tbg Hngr (3.958' 296' Otis XL B~Lt Valve N;ppLe (3.81P' ID) ~/ DK wireline ret. vo~ve (2.000') Comp{etlon String: 0'-7853' 4.5% 12.6~ N-80 AgL Tb9. (3.958' 7853'-~0,595' 3.5% 9.~ N-80 But~ Tbg. (~.992' Gas LiFt Nandrets are 4.5' & 3.5' Camco MMG w/ Macao 1.5' CMP-RC valves w/RK Latches, 4.5' mandrels = (3.890' 3,5' monc~reLs = (~,875' ID). 4.5' Mondr~{~ VoLves 2367' ~1 12/64 Port 3731' ~2 ~2/64 Port a980' ~3 1~/64 Port ~064' =4 i~/64 Port 7008' ~5 i6/64 Port 7835' ~6 }6/64 Port 3.5' Nondrets 8509' ,"7 16/64 Port 9086' ~8 _P0/64 Port 9340' ~9 ~0/64 Port 9648' ¢10 20/64 Port 9924' :ll _20/64 Port 1'3,236' =12 _P4/64 Port 10,438' ¢13 E4/64 ~riFice 10,530' Otis 4.00' '~/D Pkr (3.00' ID) ~/8' Z3E. 20' se~ cssy (3.00' .rD) stung into pkr. 10,566' Otis X nipple 10,595' ~u{e shoe 11,130' 11,138' 11,148' °er Fo, ra~cion5 ~-0 :3,645'-!0,660' 4 3PF C' Phasin9 1/89 B-1 10,726'-!0,744' 4 SPF ' 11/85 ~-~ :0,865'-!0,880' 4 SPF 1/89 ~0,884'-t0,895' 4 SPF 1/89 B-3 :0,968'-!1,016' 4 SPF ' 11/85 B-4 :1,030'-!1,]30' 4 SPF ' 1/89 B-5 11,150'-11,187' 4 SPF ' 11/85 11,200'-11,285' 4 SPF ' 11/85 ~vg. Dev. = 37.75' Otis WD Pkr (3.250' ID). Fltis X nipp!,e. BetL Guide. B-5 Lost PerF Gun 1/30/79 PBTD ~ 11,415' TD ~ 11,506' Revision Date: 1~/17/9l Revised By; jDM/evo Reason: Update Previous Revision: 8/91 STATE OF ALASKA .~*~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator. UNOCAL (Marathon Oil Company Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Puli tubing ~ Variance __ Pedorate ._X. Other __ ! 5. Type of Well: 6. Datum elevation (DF or KB) - Sub Dperat(f~e~°~ment~-- 106' KB above MSL r Exploratory __ feet 3'Addr~)ts 0 BOX 190247 Anchorage,, AK 995~9 4. Location of well at surface LC~I ~-- t,U~U. #O UU~ ~y 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 360' FNL, 735' FWL, Sec. 8 - 8N - 13W - SM At effective depth Stratigraphic Service Att°t~l~l~thFNL, 1,252' FWL, Sec. 8- 8N- 13W- SM 7. Uni! or Property name Trading Bay Unit 8. Welt number D-25RD 9. Permit number 78-87 10. APl number 50--].33-20247-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,510' feet 10,021' feet Effective depth: measured 11,415 ' feet true vertical 9,941 ' feet Casing Length Size Structural Conductor Surface 2,514' 13-3/8" Intermediate Production 8,155' 9-5/8" Liner 3,568' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing Pa(~.~r.~ a~DS~y(~/Be ¢,nd meas, ured d¢~t¢) Dore pKr W/~-- SBE 0 10,530' Plugs (measured) Junk (measured) Cemented None Perf Gun Measured depth [a approx· 110290' True vertical depth 2,514' 2,446' 8,155' 750 SX 11,506' See Attachment #1 ....... 7,853' x 3-1/2" 9.2¢ ~-80 Butt tbg to 10,595' SSS~ - Otis Xk ball valve nipple ~/~[ ~ireline valve and 0 11,130' 13. Attachments 1, 2, 3&4 14. Estimated date for commencing operation 2/29/92 16. If proposal was verbally approved Mike Mender 2/28/92 Name of approver Date approved Description summary of proposal -X. Detailed operations program __ BOP sketch 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~( (3...,.~ %, ~~ Title (~e~, '~'~.~, ~ FOR COMMISSION USE ON"r.Y Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- '/-¢O Approved by order of the Commission Date ORIGINAL SIGNED BY LONNIE C. SMITH Approval No. C'O~'~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench 0 1 2 3 4 5 Attachment #1 TBU Well D-25RD Perforation Interval s MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' docs\dvp\d25rd, doc Attachment # 2 DVP Well D-25RD Perforation Procedure 1) 2) 3) 4) 5) CONDUCT SAFETY AND OPERATIONAL PROCEDURE MEETING. RU WIRELINE UNIT. INSTALL NEW PACKOFF IN WIRELINE LUBRICATOR AND INSURE ADEQUATE LIGHTING FOR NIGHT OPERATIONS. HOOK UP COMMUNICATION SYSTEM IN UNIT. SECURE UNIT WITH CHAINS. MU TOOL STRING AND 1.8" BROACH. PT LUBRICATOR TO 2500 PSI. CHOKE WELL BACK AND MONITOR FOR HEADING. RIH. CHIP SCALE AS NEEDED THROUGH TUBING TAIL. POOH. CONTINUE WIRELINE RUNS WITH PROGRESSIVELY LARGER BROACHES UNTIL A 2.50" OD BROACH WILL CLEAR THE TUBING TAIL. RD SLICKLINE. RU E-LINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. 6) NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATIONS BLACKOUT. RE-ESTABLISH COMMUNICATION BLACKOUT WHILE POOH ABOVE 1000' ELM. RIH WITH 2-1/8" STRIP GUNS, 4 SPF, 00 PHASING, OFFSET 30-DEGREES AND PERFORATE THE FOLLOWING INTERVAL UNDERBALANCED (WELL FLOWING). OPEN CHOKE AND STABILIZE FLOW PRIOR TO PERFORATING. RUN BENCH INTERVAL DIL FOOTAGE I HB #1 10,726' - 10,744' 18' 2 HB #3 11,000' - 11,015' 15' 3 HB #4 11,030' - 11,060' 30' **FLOW WELL FOR CLEAN-UP APPROXIMATELY 15-20 MINUTES AFTER PERFORATING INTERVAL. PRIOR TO POOH, SHUT IN WELL. D-25RD Perforation i-, ~cedure Page 2 8) RD E-LINE. FLOW WELL TO GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL IN GROUP SEPARATOR FOR 12-24 HOURS OBTAINING WC's EVERY FOUR HOURS. MONITOR SEPARATOR SCREEN FOR PERFORATING DEBRIS. 9) SI WELL WITH CHOKE AND MANUMATIC. 10) RU WIRELINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST BOPE AND LUBRICATOR TO 2500 PSI. 11) RIH WITH 4-1/2" SETTING TOOL DRESSED TO SET OTIS DK SCSSV 0296'. SET DK SCSSV AND POOH. TEST SCSSV BY BLEEDING TBG PRESS AND MONITOR FOR PBU. RD OTIS. EQUALIZE ACROSS SCSSV & OPEN WLR SCSSV. RETURN WELL TO PRODUCTION. ~dvp\d25rd.doc Attachment MARATHDN DIL ~'MPANY TRADING_-BAY _NIT WELL D-85RD _ Comp(e 13-3/8' 61~ K-55 Butt Csg 8 2518' 4-1/2' x 3-t/2' X-Over 8 7853' TOL 7' ~ 7938' ~ 9-5/8' 47~ N-80 Csg ~ 8155' 7" 29~ N-80 Liner to 11,506' Togged Fill 11,115' 3/89 01/24/79 AL[ MeasureMents ore ~KB to top oF equipment. 41' CaMeron Type DCB 8RD x Butt Tbg Hngr (3.958' ID) 29G' Otis XL Bat1 VaLve N;ppte (3.812' ID) ,/ DK ,itel;ne ret. valve (2.000') COMD{~tiOn String: 0'-7853' 4.5% 18.6~ N-80 ASL Tbg. (3.958' ID). 7853'-10,595' 3.5% 9.2# N-80 Butt Tbg. (8.998' ID). 10,530' 10,566' 10,595' B-O Gas LiFt MandreLs are 4.5' & 3.5' C~mco MMG w/ Macco 1.5' CM2-RC valves w/RK Latches. 4.5' mandrels = (3.890' ID), 3,5' manC~re[s = (2,875' ID). 4.~' Manc~reLs VaLves 2367' ~1 18/64 Port 3731' #2 12/64 Port 4980' ~3 12/64 Port 6064' ~4 12/64 Port 7008' ~5 16/64 Port 7835' ~6 ]6/64 Port 3.5' Nandrets 8509' ~7 16/64 Port 9026' ~8 20/64 Port 9340' ~9 20/64 Port 9648' ~10 20/64 Port 9924' ~11 20/64 Port :0,236' ~12 24/64 Port 10,432' ~13 24/64 OriFice 2tis 4.00' %/D Pkr (3.00' ID) w/8' 5BE. 20' seat assy (3.00' ID) stung into pkr. Otis X nipple Mute shoe 3-! B-3 B-4 3-0 B-1 3-2 B-3 B-4 B-5 P~r FQr~ tion~; :0,645'-10,660' 4 SPF C' Phas;n9 i/89 10,726'-10,744' 4 SPF · !1/85 1o, 865'-1o,88o' 4 SPF · 1/89 ] 0,884'-10,895' 4 §PF ' 1/89 ;0,962'-11,016' 4 SPF ' 11/85 i],030'-11,130' 4 SPF ' 1/89 11,150'-11,187' 4 SPF ' 11/85 11,800'-11,885' 4 SPF ' 11/85 11,130' 11,138' 11,148' Avq, Dev. = 37.75' I]t;s WD Pkr (3.250' ID). F]~is X nipple. Bet[ Guide. B-5 Lost Per? (]un 1/30/79 PBTD ~ 11,415' TD @ 11,506' Revision D6te: 12/17/91 Revised By: JDM/evo Reason: Update Previous Revis;on~ 2/91 Attachment #4 .. · .. DOLLY VARDEN 'PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP .4' ~1~'.-1.6~. 5000 CHISTMAS TREE - GREASE HEAD (Hydraulically Activated) LUBRICATOR POSITIVE CHOKE ~ 2' 5000 pal ]_- 2' 3ooo psi 13 3/8' CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Change approved program __ 2. Name of Operator i 5. Type of Well: / Development __ UNOCAL '~-(Marathen Oil Cnmnany- g,,h pperatoE)ploratory__ 3. Address ' ' ! Stratigraphic_ P. O. Box 190247 Anchoraoe. AK 995119 Service__ 4. LocaUon of well at surface Leg A-1 Cond. #8 Dolly Varden Platform Abando~ ~ Suspend ~ Operation shutdown ~ Re-enter suspended well ~ Alter casing __ Repair well __ Plugging __ Time exqens~on __ Stimulate __ Pull tubmg __ Vanance__ Pedorate ..~ '' Other __ 6. Datum elevation (DF or KB) !06' KB above MSL 7. Unit or Properly name Trading Bay Unit 8, Well numOer feet 751' FSL, 1,210' FWL Sec. 6- 8N- 13W- SM At top of productive interval ' 360' FNL, 735' FWL, Sec. 8- 8N- 13W- SM At effective depth At total depth 440' FNL, 1,252' FWL, Sec. 8 - 8N 12. Present well condition summary Total depth: measured true vertical 11,510' 10,021' Effective depth: measured 11,415 ' true vertical 9,941 ' Casing Length Structural Conductor Surface 2,514' Intermediate Production 8,155 ' Liner 3,568' Perforation depth: measured true vertical - 13W - SM feet feet ~. ~'Srml~number 7~_R7 16.'~PTAumber 50--1 11. Field/Pool Hem] oc k Plugs (measured) None feet feet Junk(measured) Size Perf Gun ~ approx. 11,290' Cemented RECEIVED Measured depth See 2,514' :,::[~ 2 8 1'°q! 9_ 5/¢)as,ka 0il & Gas ConS. Gom~ssi0~ ~-.~.-.. '"' "- 8,155' 7" ' ' ~O~~x' 11,506' ~ / Attachment ~1 4 ; Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt Packers and SSSV (type and measured depth) SSSV - Otis XL ball valve nipple Otis WD 4.00" bore pkr w/8' SBE 0 lO.~30' and fa 13. Attachments Cf I, 2 ~ Description summary of proposal x Detailed operations program 3,&4 True vertical depth 2,446' ~,,: 7,268' 10,015' tbg to 10,595' w/DK wireline valve BOP sketch 14. Estimated date for commencing operation HaY'ch 2, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X__ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~o_~_.u %, i~,...~.~ Title go..~. '~,r'¥~, Conditions~o~pp~at: FOR COMMiS~N USE ~LY Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Original Signed David W, john~'i Approved by order of the Commission Approved Copy Returned i Approval No.? CommiSSioner Date I -c:i I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 TBU Well D-25RD Perforation Intervals Bench MD 10,645' - 10,660' 4- ~?/.~, ~: 10,726' - 10,744' ~ 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' \docs\dvp\d25rd.doc 1) 3) 4) 5) 6) 7) Attachment # 2 Well D-25RD Procedure OBTAIN A 24-HOUR WELL TEST WITH A MINIMUM OF FOUR (4) WC'S. SI LIFT GAS AND LET WELL DIE. SI CHOKE AND MANUMATIC. RU WIRELINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. RIH WITHW~F~ 4-1/2" PULLING TOOL DRESSED TO PULL WLR OTIS DK SCSSV. LATCH DK SCSSV AND POOH. RIH W/ 2.72" GR & TAG FILL. POOH W/ GR. RD WIRELINE UNIT. RU E-LINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATIONS BLACKOUT. RE-ESTABLISH COMMUNICATION BLACKOUT WHILE POOH ABOVE 1000' ELM. RIH WITH 2-1/8" STRIP GUNS, 4SPF, O-PHASING, OFFSET 30-DEGREE AND PERFORATE THE FOLLOWING INTERVAL UNDERBALANCED (WELL FLOWING). OPEN CHOKE AND STABILIZE FLOW PRIOR TO PERFORATING. RUN BENCH INTERVAL DI L FOOTAGE 1 HB #4 11,076'-11,106' 30' 2 HB #4 11,030'-11,060' 30' 3 HB #1 10,726'-10,744' 18' 4 HB #0 10,645'-10,660' 15' **FLOW WELL FOR CLEAN-UP APPROXIMATELY 15-20 MINUTES AFTER PERFORATING INTERVAL. PRIOR TO POOH, SHUT IN WELL. 8) RD E-LINE. FLOW WELL TO GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL IN GROUP SEPARATOR FOR 12-24 HOURS OBTAINING WC'S EVERY FOUR HOURS. MONITOR SEPARATOR SCREEN FOR PERFORATING DEBRIS. 9) SI WELL WITH CHOKE AND MANUMATIC. 10) RU WIRELINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST BOPE AND LUBRICATOR TO 2500 PSI. 11) RIH WITH 4-1/2" SETTING TOOL DRESSED TO SET OTIS DK SCSSV ~ 296'. SET DK SCSSV AND POOH. TEST SCSSV BY BLEEDING TBG PRESS AND MONITOR FOR PBU. RD OTIS. EQUALIZE.ACROSS SCSSV & OPEN WLR SCSSV. RETURN WELL TO PRODUCTION. 12) OBTAIN 24-HOUR TEST IN SEP #2 OBTAINING WC'S EVERY 6 HOURS. NOTE: Max anticipated SBHP : 4403 psi (6/2/90) \docs\oe55\18.doc Attachment #3 uOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) -' ~ - LUBRICATOR , CHISTMAS TREE POSITIVE CHOKE 2' 3000 psi 3/8' CASING 13 Attachment #4 ..... ~ MARATHBN DIL CDMPANY TRADING BAY UNIT ~ELL D-25RD Completed 01/24/79 AiL measurements are RKB to top o? equipment. 41' Cameron Type ])CB 8RI) x Butt Tbg Hngr <3.958' II)) 296' ntis XL Ball Vmtve Nipple (3.812' II)) w/ DK wlrellne ret. valve [;omB[etlon ~rln9~ 0'-7853' 4.5; 12.6# N-80 ASL Tbg. (3.958' ID). 7853'-10,595' :~5', 9.2# N-80 Butt Tbg. (2.992' ID). 13-3/8' 61# K-55 Butt Csg 8 2518' 4-1/2' x 3-1/2' X-Over @ 7853' Oas LIFt Mandrels are 4.0' & 3.5' Camco MM6 w/Mocco 1.5' CM2-RC vctves w/RK t~tches. · 3.0' m:ndre[s : (2.875' ID). 4.~' V~v..eF 2367' #1 3731' fl2 4980' fl3 6064' #4 7008' #5 7835' #6 3.5' Valv~,~ 8509' #7 9026' #8 4.0' mandrets = (3.890' I])), 12/64 Port 12/64 Port 12/64 Port 12/64 Port 16/64 Port 16/64 Port 16/64 Port 20/64 Port TOL 7' I~ '7938' 9-5/8' 47# N-80 Cs9 ~ 8155' 7' 29# N-BO Liner to 11,506' T(zgged Fill 11,115' 3/89 10,530' 10,566' 10,595' B-O B-I B-3 B-4 9340' #9 9648' #10 9924' #11 10,236' #12 10,432' #13 Otis 4,00' ~/D Pkr (3.00' ID) w/8' SBE, (3.00' ID) stung Into pkr. O%ls X nipple Mute shoe 20/64 Port 20/64 Port 80/64 Port 24/64 Port 24/64 Port 20' seal ~ssy Pgr?oro~;on~ B-O ~0,645'-10, G60' 4 SPF 0® Phasing 1/B9 ]~-1 10,726'-10,744' 4 SPF ' 11/85 B-2 10,865'-10,880' 4 SPF ' 1/89 10,884'-10,895' 4 SPF ' 1/89 ]~-3 10,962'-11,016' 4 $PF ' 11/85 B-4 11,030'-I1,130' 4 SPF ' 1/89 B-5 11,150'-11,187' 4 SPF ' 11/85 IL200'-11,285' 4 SPF ' 11/85 Avg. Dev. = 37.75' 1LI30' Otis WD Pkr (3.250' II)). 1L138' Otis X nipple. IL148' Belt Gu;de. Lost PerF Gun 1/30/79 Revision O~te, 2/91 Revised By, EVD PITT9 @ 11,415' Re~so~ Tagged .,~,+,~~Prevm~ Rev~smn, ~89 ~ TD ~ 1L~6' ,,~-~---.. ~.~-~ . ,..~ .... ~....~ .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Pull tubing w Alter casing m Repair well ~ 2. Name of Operator ! 5. Type of Well: J De~ velopment UNOCAL {'Marathon 0il ComDanv - Sub Uperator[x¢oratory-- 3. Address - ' - / Stratigraphic Z Po 0. Box 190247 Anchorage, AK 995]~9 Service. Stimulate __ Plugging __ Perforate ~ Other 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 4. Location of weil at surface Leg A-1 Condo 751' FSL, 1,210' FWL, Sec. 6 At top of productive interval 360' FNL, 735' FWL, Sec. 8 At effective depth At total depth 440' FNL, 1,252' FWL, Sec. 8 #8 Dolly Varden Platform - 8N - 13W - SM - 8N - 13W - SM -8N- 13W- SM 8. Well number 9. Permit number/approval number 90-504 10. APl number 5o-133-20247-01 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: 11,510' feet 10,021' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) None measured 11,415' feet Junk(measured) Perf Gun @ approx. 11,290' true vertical 9,9 41 ' feet Length Size Cemented Measured depth True vertical depth 2,514' 13-3/8" 2,514' 2,446' 8,155' 9-5/8" 8,155' 7,268' 3,568' 7" 750 sx 11,506' 10,015' measured true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' Packers and SSSV (type and measured depth) SSSV - Otis XL ball valve nipple w/DK wireline valve Otis WD 4.00" bore okr w/8' SBE e 10,530' and e 11,130' 13. Stimulation or cement squeeze summary , 14. Intervals treated (measured) AUG Treatment description including volumes used and final pressure ,~; ~. I ,--,as,m Oil & Gas Cmos. Comm[ssio~ Representative Dail~ Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations __ Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 R 5/88~ J Service ~,~-, Date SUBMIT IN DUPLICATE Bench Attachment #1 TBU Well D-25RD Perforation Intervals MD¸ 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD ,L 9,328' - g,340' g,391' - g,405' 9,501' - g,513' 9,516' - g,525' g,577' - g,620' g,632' - g,711' g,727' - g,757' g,767' - g,836' docs\dvp\d25rd, doc Attachment #2 TBU Well D-25RD Daily Summary of Well Operations 6/16/90 RU wireline and PT lubricator to 2500 psi. RIH w/ 3.7" gauge ring to 4.5" x 3.5" X-over at 7850' WLM. POOH. RIH w/ 2.75" gauge ring to 10,500' WLM and cut scale in tubing tail. POOH. 6/17/90 RIH w/ DKX safetY valve and set at 296' WLM. Test valve, OK. RD. \docs\dvp\d25RD.doc 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 $ e_.._~ Name of Operator ~ 5. Type of Well: 2. · ~ velopment X UNOCAL (Marathon O~l Company, - Sub ~perato ~xploratory-- 3. Address ! Stratigraphic Z P. 0. Box 190247 Anchorage, AK 995],9 Service__ 4. Location of well at surface Leg A-I 6ond. #5 uoi 'ly varden Hi aT. form 8. Well number 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM D-25RD At top of productive interval 9. Permit number 360' FNL, 735' FWL, Sec. 8- 8N- 13W- SM 78-87 At effective depth At total depth 440' FNL, 1,252, FWL, Sec. 8 - 8N - 13W - SM SCSSV 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Properly name Trading Bay Unit 10. APl number 5o--133-20247-01 11. Field/Pool Hem 1 oc k 12. Present well condition summary Total depth: mea§ured true vertical 11,510' feet Plugs (measured) None 10,021' feet Effective depth: measured 11,415' feet Junk(measured) Perf Gun @ approx. 11,290' true vertical 9,941 ' feet Casing Length Size Structural Conductor Sudace 2,514' 13-3/8" Intermediate Production 8,155' 9-5/8" Liner 7,938' 7" Perforation depth:measured Cemented Measured depth True vertical depth 2,514' 2,446' 750 sx 8,155' 7,268' ,EO EIVED J U N ~_ '[ 1990 truevertical See Attachment #1 Alaska 0il & Gas Cons. 6om~tss'toft Tubing (size, grade, and measured depth) AQchorage 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' $22V - Otis XL ball valve nipple w/OK wireline valve Packers and SSSV (tvoe i~nd meaqured d¢~D[h) 0t~s WD 4.00" Dore per W/~' SBE ~ 10,530' and 0 11,130' 13. Attachments 2 & 3 Description summary of proposal ~ Detailed operations program __ BOP sketch _~X 14. Estimated date for commencing operation 6/25/90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X__ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ("~~ ~,~ ~,~,..~,,~ Title ('~,, ~'6\~.~ ~ ~ FOR COMMISSION USE ONLY Conditions of a'l~oval~Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~ JApproval No.¢~::~,._,.~.¢ z/ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LO~:.t"!!E C. SMITH .. Approved Copy Re~rne¢ U ,~FF, iS$iGi~6i' Date SUBMIT IN TRIPLICATE Attachment #1 TBU Well D-25RD Perforation Intervals Bench MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' docs\dvp\d25rd, doc RECEIVED j UN 'g '~ 1990 Alaska Oil & Gas Cons. 'Anchorage · · · Attachment #2 TBU Well D-25 SCSSV Setting Procedure Flow well & establish steady production. SI lift gas & close masters. RU BOP & riser. Pressure test riser to 2500 psi. Open masters & re-establish production. RIH with scratchers and clean scale & deposits to depth of the SCSSV. Flow well to remove debris. POOH. SI lift gas. RIH with SCSSV & set. POOH. RD BOP & riser. Re-establish production. Note: Maximum anticipated SBHP is 4400 psi. \docs\dvp\d25rd. doc RECEIVED JUN 2 ?' 1990 A!aska Oii& Gas Cons. Anchorage Attachment #3 ,JOLLY VARDEN PL ,TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) -- BRICATOR · 4'::1/~1,6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE ~I 2T1990 '"" Gas Cons. Commission ~ ~ Anchorage '~~~I~--- 2' 5000 pal I J 13 3/8 CASING Unocal North Americ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, G . u Regional Drilling Manager GSB/lew DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, 18N, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL .. . LEG #A-1: LAT = 60°48' 28.272" LONG =151°37' 57.620" 2,490,836.22 208,461.20 757.5 6 7 8 9 lO ll 12 2,490,836.95 2,490,840.99 2,490,842.79 2,490,841.51 .2,490,837.76 2,490,833.28. 2,490,830.18 2,490,829.90 2,490,832.58 2,490,835.56 2,490,838.66~ 2,490,834.00 FWL ,. LEG #A- 2' 1 2 3 4 5 6 7 8 9 l0 ll 12 2,490,835.42 2,490,836.16 2,490,840.19 2,490,842.00 2,490,840.72 2,490,836.97 2,490,832.49 2,490,829.39 2,490,829.11 2,490,831.78 '2,490,834.77 2,490,837.86 2,490,833.21 1212.0 208,454.55 D-27 758.1 1205.5 208,456.66 D-28 .762.1 1207.4 208,460.79 D-29 764.0 1211.5 208,465.11' D-32 762.9 1215.8 208,467.60 D-40 759.2 1218.4 208,467.10 D-41 754.7 1218.0 208,463.83 D-26 751.5 1'214.8 208,459.34 D-25 & RD 751'.1 1210.3 208,455.72 753.7 1206.7 208,458.66 D-24 & 34A 756.8 1209.5 208,462.17 D-31 & RD 760.0 1213.0 208,462.61 D-24A 755.3 1213.5 LEG #B-1 · LAT : 60°48' 27.485" LONG =151037' 57.564" 2,490,756.22 208,381.20 754.7 1132.1 1 2 3 4' 5 6 7 8 9 10 11 12 2,490,755.48 2,490,751.45 2,490,749.65 2,490,750.92 2,490,754.67 2,490,759.15 2,490,762.25 2,490,762.53 2,490,759.86 2,490,756.87 2,490,753.78 2,490,758.43 208,374.66 D-1 755.3 , 208,376.67 D-17 759.4 208,380.80 D-11 761.3 208,385.11 D-7 & RD 760.1 208,387.60 D-9 756.4 208,387.10 D-19 751.9 208,383.84 D-23 748.8 208,379.34 D-21 748.4 208,375.72 ' D-5 & RD 750.9 208,378.66 D-15 & RD.& 2 754.0 208,382.17 D-3 & RD 757.2 208,382.61 D-13 752.5 LEG #B-2: 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 208,462.00 677.5 1214.8 208,468.53 D-8 & RD 677.0 208,466.53 D-6 672.9 208,462.40 D-14 & RD 671.0 208,458.08 D-20 672.1 208,455.59 D-16 675.8 208,456.10 D-22 680.3 208,459.36 D-2 & A & RD 683.5 208,463.85 D-4 683.9 208,467.48 D-10 681.3 208,464.53 D-12 & RD 678.3 208,461.02 D-18 675.1 208,460.58 D-30 & RD 679.7 674.8 2,490,755.43 208,382.00 (Reserved for Compressors) 1221.4 1219.5 1215.4 1211.1 1208.5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~] REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ Stimulate __ Plugging __ Perforate ~ Alter casing __ Repair well __ Other __ 2'NamUeN~))~rat°iMarathon Oil Company - Sub 3. Add~.ss 0. BOX 190247 4. Location of well at surface 751' FSL, 1,210' At top of productive interval 360' FNL, 735' At effective depth At total depth 440' FNL, 1,252' Anchorage, AK 995 Leg A-1Cond. #8 Dol FWL, Sec. 6 - 8N - 5. Type of_Welh ) e r a t o D~)velopment Exploratory Stratigraphic Service · y Varden Platform .3W - SM FWL, Sec. 8 - 8N - 13W - SM FWL, Sec. 8 - 8N - 13W - SM 6. Datumelevation(DForKB) 106' KB above MSL feet T~. UQit or Prc. p_erty, oamp aol ng t~ay un'~ c 8. Well number D-25RD 9. Permit number/approval number 9-986 10. APl qup;~be~ 50_.oo-~0247-01 11. Field/Pool Hemlock 12. Present well condition sUmmary Total depth: measured true vertical 11,510' feet 10,021' feet Effec!ive depth: measured 11,415 ' feet true vertical 9,941 ' feet Casing Length Size Structural Conductor Surface 2,514' 13-3/8" Intermediate Production 8,155' 9- 5/8" Liner 7,938' 7" Perforation depth' measured Plugs (measured) Junk (measured) None Perf Gun @ approx. 11,290' Cemented Measured depth ~ue vertical depth 2,514' 2,446' 8,155' 7,268' 750 sx 11,506' 10,015' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing Packers and SSSV (type and measured depth) Otis WD 4.00" bore pkr wi8' SBE 13. Stimulation or cement squeeze summary to 7,853' x 3-1/2" 14. 9.2# SSSV - Otis XL ball valve @ 10,530' and @ 11,130' Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data N-80 Butt tbg to 10,595' nipple w/DK wireline valve Prior to well operation 11/24/89 Subsequent to operation 12/08/89 15. Attachments 2 Copies of Logs and Surveys run __ Daily Report of Well Operations ~ OiI-Bbl Gas-Md Water-Bbl CasingPressure ~bingPressure 654 359 897 1080 120 417 265 2813 1190 160 16. StatusCwellclassification as: Oi1_,% Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~z ~-~¢C,,¢ ~'~ ' ~ ~. (~TitleEnvi ~"/~:-~'2~ ronmen ta 1 Ana 1 ys t Signed Form 10-404 Rev 06/15/88 / Date 1 / 1 2/90 SUBMITIN DUPLICATE Attachment #1 TBU Well D-25RD Perforation Intervals Bench 0 1 3 4 5 MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' em/64/DVP2 Attachment #2 TBU Well D-25RD Daily Summary of Well Operations 11/25/89 PERFORATION RU E-line. MU 20~ 2-1/8" JRC strip guns, 4 SPF, 0° phasing, 20.7 gm charges. PT to 2500 psi. OK. RIH w/ well choked back. Open tubing choke, correlate to VDL (11/15/75). Perforate 11,030~ - 11,050~ DIL (20~ B-4). Flow well 15 min. Choke well back. POOH. All shots fired. MU two 15~ guns as above. SI well. RIH out tubing tail. Bring well on line. Correlate and perforate 10,865~ - 10,880~ DIL (15~ B-3). Correlate and perforate 10,645~ - 10,660~ DIL (15 B-O). Flow well 10 min. POH. 12/3/89 CLAY STABILIZER RU E-line. Back out tubing and PT to 3000 psi. OK. Pump 100 gal 15% HC1 followed by 105 bbls FIW w/ 2% NH4Cl. Flow back acid. 12/4/89 PT to 3000 psi. Pump 8000 gal 2% NH~C1 w/ 0.1% Lowsurf 300 and 0.6% Cla-Sta XP. Overflush w/ 11,000 gal. 2% NH~Cl w/~0.1% Lowsurf 300. Displace to end of tubing w/ 125 bbls 2% NH4C1. Final injection rate, 2-1/2 BPM @ 1300 psi. RD. Slowly unload well. ~docs~DVP~d25rd. doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ~ 5. Type of Well: UNOCAL (Marathon Oil Company - Sub' I -~perato~V~,°~e~',x-~- 3. Address m ~-~'-""-'"-" y! Stratigraphic Z P. 0. Box 190247 Anchorage, AK 995.~9 Service__ 4. Location of well at surface Leg A-I Cond. #~ Dolly varden I-,iat. form Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ StimulateY,~__ Pull tubing __ Variance __ Pedorate ~ Other __ 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 360' FNL, 735' FWL, Sec. 8 -8N - 13W - SM At effective depth At total depth 440' FNL, 1,252' FWL, Sec. 8- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Welt number D-25RD 9. Permit number 78-87 10. APl number 5o-t33-20247-0! 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,510' feet 10,021' feet Plugs (measured) None Effective depth: measured 11,415 ' true vertical 9,941 ' Casing Length Size Structural Conductor Surface 2,514' 13 - 3/8" Intermediate Production 8,155' 9-5/8" Liner 7,938' 7" Perforation depth: measured true vertical feet Junk (measured) feet Cemented 750 sx Perf Gun @ approx. 11,290' Measured depth True vertical depth 2,514' 2,446' See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# Packers and SSSV ltype and measured depth) SSSV - Otis XL ball valve Otis WD 4.00" bore pkr w/8' SBE 8 10,530' and @ 11,130' 8,155' 7,268' , t ,",\ ;, ",, , ,.,~, N]-80 Butt tbg to 10,595' nipple w/DK wireline valve 13. Attachments 2 & 3 Description summary of proposal ._~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation November 15, 1939 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Environmental Signed/~z¢_~/~. /~~-C~.,//~ Title Engineer ' ./'/ Re? D. Roberts FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 1"~-- z'/o Approved by order of the Commission , ,Al SIGNED BY OR!G~N. ~ L'"'*m~E 6, SMITH .t,J!¥ P t ... Date 11/8/89 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 TBU Well D-25RD Perforation Interval s Bench 0 1 3 4 5 MD 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' em/64/DVP2 Attachment #2 DOLLY VARDEN PLATFORM WELL D-25RD REPERF/CLAY-STAY PROCEDURE · e R/U slickline. Test lubricator. Retrieve WLR-DK SSSV from 296'. RIH with 2.25" gauge ring and tag fill. RD slickline. RU electric line. Test lubricator. Pinch back flow and RIH with 2-1/8, 4 SPF strip gun. Once below the tubing tail, increase flow to maximize underbalance. Perforate the following intervals' BENCH INTERVAL DIL FOOTAGE 0 10,645' - 10,660' 15' 3 10,865' - 10,880' 15' 10,885' - 10,895' 10' 4 11,030' - 11,070' 40' 11,110' - 11,130' 20' 100' 5. Bring well on slowly and flow until pumping equipment {s rigged up. 6. RU pumping equipment and test lines to 4000 psig. 7. Bullhead 1000 gallons of 15% HC1 and displace to end of tubing with FIW. 8. Unload acid. Notify TBPF 24 hours prior to shipping acid. 9. Pump the following clay stabilizer treatment' a· 8000 gal FIW w/2% ammonium chloride, 0.1% Losurf 300 and 1.2% Cla-Sta XP. b. 11,000 gal FIW w/ 2% ammonium chloride and 0.1% losurf 300. c. Displace to the end of tubing with FIW containing 2% clayfix. 10. RD pumping equipment. 11. Put well in test. Return well to production slowly over 48 hours. Note' Maximum anticipated SBHP is 3500 psi. ~docs\oe43\93. doc Attachment #3 OLLY VARDEN PL.. I'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4-:~1J~-1,~6'-'-. 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi _...- 2' 3000 psi 13 3/8' CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF'SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ~ 5. Type of Well: UNOCAL (Marathon Oil Company - Su~ Opera~8~.Pm.ent x-- ' / ~x¢loratory __ 3. Address ! Stratigraphic __ P. O. Bo× 190247 Anchorage, AK 9~519 Service__~ 4. Location of well at surface Leg A-I Cond. #~ Dolly Varden ~'±at'rorm Perforate ~ Other 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-25RD 9. Permit number/approval number 8-898 _ 10. APl number 50-- 133-20247-01 751' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 360' FNL, 735' FWL, Sec. 8 - 8N - 13W - SM At effective depth At total depth 440' FNL, 1,252' FWL, Sec. 8- 8N - 13W - SM 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,510 ' feet 10,021 ' feet Effective depth: measured 11,415 ' feet true vertical 9,941 ' feet Casing Length Size Structural Conductor Surface 2,514' 13-3/8" Intermediate Production 8,155 ' 9-5/8" Liner 7,938 ' 7" Perforation depth: measured Plugs (measured) Junk (measured) Cemented 750 sx None Perf Gun @ approx. 11,290' Measured depth True vertical depth 2,514' 2,446' 8,].55' 7,268' 11,506' 10,015' true vertical See Attachment #1 ~bing(size. grade, andmeasumddepth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# PackersandSSSV(typeandmeasureddepth) SSSV - Otis XL ball valve Otis WD 4.00" bore pkr w/8' SBE @ 10,530' and @ 11,130' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N-80 Butt tbg to 10,595' nipple w/DK wireline valve ,EL. EI V EL7 aJaska 0il & Gas Cons. C0mmissi0r 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data r~,,,,,,,,, ~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 12/31/88 495 160 843 1100 70 1/21/89 1043 273 903 1080 110 15, Attachment~: ¥f2 Copies of Logs and Surveys run __ Daily Report of Well Operations ___x 16. Status of well classification as: Oil ~ Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Environmental Engineer Form 10-404 Rev 06/15/88 Date 2/1/89 SUBMIT IN DUPLICATE Attachment #1 TBU Well D-25RD Perforation Intervals Bench 0 1 3 4 5 10,645' - 10,660' 10,726' - 10,744' 10,865' - 10,880' 10,884' - 10,895' 10,962' - 11,016' 11,030' - 11,130' 11,150' - 11,187' 11,200' - 11,285' TVD 9,328' - 9,340' 9,391' - 9,405' 9,501' - 9,513' 9,516' - 9,525' 9,577' - 9,620' 9,632' - 9,711' 9,727' - 9,757' 9,767' - 9,836' em/64/DVP2 ~%iaska Oil & Gas Cons. Commission, A.cimrage Attachment #2 TBU Well D-25RD Daily Summary of Well Operations 1/8/89 RU E-line and PT lubricator to 2500 psi, OK. Made six perforating runs using 2-1/8" Enerjet guns, 4 SPF, 0° phasing, offset 30°. RIH, correlated and perforated B-4 11,110' - 11,130', 11,050' - 11,070', and 11,030' - 11,050'; B-3 10,885' - 10,895', and 10,865' - 10,880~; and B-0 10,645' - 10,660'. POOH, RD. Flow well for 12 hours, put in test. em/64/DVP2 STATE OF ALASKA ~-' ALA~sKA OIL AND GAS CONSERVATION COMM Ib,.,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ 2. Name of Operator t 5. Type of Well: UNOCAL (Marathon Oil Company - Subl OperatD~l~)9. Pment-x [ Exploratory __ 3. Address / Stratigraphic_ P. O. Box 190247 Anchorage, AK 99p19 Service__ 4. Location of well at surface Leg A-1 Cond. ~';S Do%iy Vanden, Fi~LfuLL- 751' FSL, 1,210' FWL, Sec. 6 - 8N - 13W- SM At top of productive interval 360' FNL, 735' FWL, Sec. 8 - 8N - 13W- SM At effective depth Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pulltubing __ Variance __ Perforate x Other __ At total depth_ 440' FNL, 1,252' FWL, Sec. 8- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-25RD 9. Permit number 78-87 10. APl number 50-- 133-20247-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural Conductor Surface 2,514 ' 13-3/8" Intermediate Production 8,155 ' 9-5/8" Liner 7,938 ' 7" Perforation depth: measured 11,510 ' feet Plugs (measured) 10,0 21 ' feet 11,415 ' feet Junk(measured) 9,941 ' feet None Perf Gun @ approx. 11,290' C.~?~tfd,\ ..~ ~.., ~ i !V, ¢' ~k~,)asured depth 2,514' 0il & G~s 00ns. Commis~io§, 15 5' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tubing to 7,853' x 3-1/2" 9.2# N-80 Butt tbg to 10,595' SSSV - Otis XL ball valve nipple w/DK wireline valve Packers and SSSV (ty~e,~nd measured depth_), Otis ~) 4.00 bore pkr w/8 SBE @ 10,530' and @ 11,130' 13. Attachments 2 & 3 Description summary of proposal _~x Detailed operations program __ BOP sketch x__ 14. Estimated date for commencing operation 15. Status of well classification as: December 1988 16. If proposal was verbally approved Oil __x Gas __ 17. II~rm:b;~e%iPf~°t~%rt the foregoing ?true and correct~oai~;~eP~oV~dmy knoS:lrevidCg%. Mechanical Int~rity Test .~ --~ubsoquent form required 1-~7'- ~ Z~¢ Approved Copy SIGNED BY Returneg¢¢~ ORIGINAL ~t,. Approved by order of the CommissionerLONNIE C. SMITH / _;'P/,_- "(~fmmqssioner Suspended __ Date 12/01/88 IAppr°val N°'8 ~ FOrm 10-403 Rev 06/15/88 feet True vertical depth 2,446' 7,268' 10,015' Date SUBMIT IN TRIPLICATE _/ Attachment #1 TBU Well D-25RD Perforation Intervals Bench 0 1 3 4 5 10,648' - 10,660' 10,726' - 10,744' 10,884' - 10,894' 10,962' - 11,016' 11,031' - 11,125' 11,150' - 11,285' 11,200' - 11,285' TVD 9,330' - 9,340' 9,391' - 9,403' 9,516' - 9,524' 9,557' - 9,617' 9,632' - 9,707' 9,728' - 9,759' 9,759' - 9,836' em/64/DVP2 Attachment #2 Well D-25RD Procedure 1. RU slickline. PT to 2500 psi. 2. Pull WLR-DK SSSV at 296'. RD slickline. 3. RU Electric line. PT to 2500 psi. 4. Perforate the following intervals underbalanced w/ 2-1/8" strip gun, 4 SPF, 0° phasing, offset 30°: Bun Bench Interval DIL Footage 1 B-4 11,110' - 11,130' 20 2 B-4 11,050' - 11,070' 20 3 B-4 11,030' - 11,050' 20 4 B-3 10,885' - 10,895' 10 B-3 10,865' - 10,880' 15 5 B-0 10,645' - 10,660' 15 Test for 12 hours, then continue perforating. 6 B-2 10,760' - 10,775' 15 5. RD E-Line. e Note: RU slickline and re-run WLR-DK SSSV at 296'. RD slickline. Maximum anticipated SBHP is 3500 psi. em/64/DVP2 Attachment ~*~ D~LLY VARDEN PLA'-=ORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) - LUBRICATOR '4 ~t/~,"6~-sooo psi CHISTMAS TREE POSITIVE CHOKE 2' 5000 pal ]D---- 2' 3000 psi 13 3/8' CASING Unocal Oil & Gas Divisio Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL 4/ / Environmental Group Alaska District October 1, 1985 Hr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Hr. Chatterton: TRADING BAY UNIT D-25RD Attached for your approval are three copies of Marathon's intention to perforate Benches 1 and 3 and reperforate Benches 4 and 5 in TBU D-25RD. Please note this intention received verbal approval from Harold Hedlund September 13, 1985. Please'retUr'~copyi'6f the approved Sundry Notice to the undersigned. Very truly yours, ~'~Candace Loc Environmental Group cwl Attachments RECEIVED Alaska 0ii & (~as Cons. C?,mmqJssio;~ ..... STATE OF ALASKA ALASKA C _ AND GAS CONSERVATION CO ~IISSION SUNDRY NOTICES AND REPORTS ON WELLS t. DRILLING WELL [] COMPLETED WELL/ OTHER [] 2. Name of Operator '¢_/, *'~"~ 7. Permit No. Union Oil Company of California* ~ ~'~ t 78-87 3. Address -~;'~<2 ~') % '~ I 8. APl Number P. O. BOX 6247 Anchorage, AK 99502 ~ c.~ ',//~,150_733_20247_0 4. Location of Well ~ ~ "-~'~9. Unit or Lease Name Surface: ~¢od.~ ~-~ ~ Tradina Bav Leg A-l, C°nd. #8, Dolly Varden PlatformO~e_~.~ ~ 10. WelINumber" 751' FSL, 1012' FWL, Sec. 6-8N-13W-SM ~° '~., D-25RD ~,~. 1 1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. -¢ McArthur River 106' KB above MSL ADL-18729 Field 12. Check Appropriate Box To Indicat'e Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (S.~nit in Triplicate) Perforate Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) ~ Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pe. rtinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-25RD PERFORATION It is Marathon's intention to perforate Benches 1 and ~ and reperforate Benches 4 and 5 with 2-1/8" guns, 4 SPF, 0 phasing under drawdown at the following intervals. New intervals: Bench 1 10,726' - 10,744' DIL Bench. 3 10,864' 10,884' - 10,880' DIL - 10,894' DIL Reperforate intervals: Bench 4 10,962' - 11,016' DIL Bench. 5 11,150' 11,031' - 11,125' DIL 11,200' - 11,182' DIL - 11,285' DIL The August 1985 well test averages were 713 BFPD, 85% WC, 107 BOPD, 606 BWPD. ~.. Verbal approval for the~:'above operations was received from Harold Hedlund of AOGCC on Septembez~".!;3, 1985, by W. J. Laverdure. *Marathon Oil Company - SuB operator 14. I hereby c~go~correct to Signed L"awrence 0~" Cuttinq The space below for Commission use 'the best of my knowledge. Title Env ~ ronmenta t Spec Date 10/01/85 Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas D~sion: Western Region Union Oil Company or California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL November 4, 1983 Hand Carried TO: William Van Alen FROM: LOCATION: 3001 Porcupine Drive LOCATION: Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: One (1) tape and verification listing each of the following wells: TBU D-25RD - Run Tau a-25RU - Run Tau D-34A Deepen TBU D-15RD ¢2 ~'~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: February 4, 1983 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 7247 Anchorage, Alaska 99502 Dear Mr. Anderson~ The Alaska Oil and Gas ~Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commi~slon. The Oil and Gas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data.has been submitted to the Commission and, if not, that you comply with .the regulation with r~gard to the following wells: Trading Bay Unit No. D-34A Trading Bay Unit No. D-15 RD Trading Bay Unit No. D-3 RD Trading Bay Unit No. D-25 RD Trading Bay Unit ~o. K-21 RD Trading Bay Unit No. K-24 Tungak Creek Mo. 1 Trading Bay St. ~o. A-17 RD Cannery Loop Unit Uo. 1 Cannery Loop Unit ~o. 2 Cannery Loop Unit ~o. 3 Kenai Tyonek Unit No. 43-6X Thank you for your cooperation in this matter. Yours very truly, Harry ~;. Kugl~r Commt~ loner BY ORDER OF THE CO~',MISSIO~ be STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLXI~ OTHER [] 2. Name of Operator 7. Permit No. Union 0il Company of California* 78-87 3. Address 8. APl Number P, 0, Box 6247, Anchorage AK 99502 50-733-20247-01 4. Location of Well Leg A-l, Cond #8, Dolly Varden Platform 751'FSL, 1210'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2' above MSL 12. I 6 . Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-25RD 11. Field and Pool McArthur River Field XX Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~1~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). July 24 - 26, 1981: Perforated following Hemlock intervals under drawdown: Bench 4: 10,962'-11,016' 4 HPF 2-1/8" gun 0° Phasing 11,031'-11,125' " " " Bench 5: 11,150'-11,187' " " " 11,200'-11,240' " " " 11,240'-11,272' " 2-1/2" gun 180° Phasing Production test: Before perfs - 1613 BFPD 27% WC 1177 BOPD After perfs - 2096 BFPD 29% WC 1489 BOPD Verbal approval 1981. to perforate received from Russ Douglass to John Barnes on July 15, RE[EIVED *Marathon Oil Company - Sub-Operator AUG 5 1981 ~,.~.k~ 0il & G~.s O0ns, Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title BIS'I' FIRI G SUPT The s e below for Commission uso D~t~ 8/4/81 Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ;=orm 10-403 REV. ~1-10~73 Subrnl t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-133-20247-01 SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME O,L >F~ GAS I--I --- WELL[' - I WELL i I OTHER 8. UNIT, FARM OR LEASE NAME 2. N,~[VIF_.OF O~I~I~AT~OR un~on u~/ uompany of Cai ifornia* Trading Bay Unit 9. WELL NO. 3. ADF:P,R~.S OF OPERATOR Box 6247, Anchorage AK 99502 D-25RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field 4. LOCATION OF WELL At surface Lo9 A-l, Cond #8, Dolly Varden Platform, 751~FSL, 1210tFWL, Sec. 6, T8N, R13W, SM 13. E~i~geA~IPKNBS (~.oc~whether DF, RT, GR, etc.) CheCk Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N, R13W, SM 12. PERMIT NO. 78-87 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF fRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 07'28'79 thru 07-29'79 Perforated fol lowing intervals under drawdown: Bench 0 lO,648'-10,660~DIL 4 HPF Bench 4 10,962'-11,016~DIL 4 HPF 11,031'-11,062~DIL 4 HPF 2-1/8" SOS Enerjet gun 2-1/8" SOS Enerjet gun 2-1/8" SOS Enerjet gun Production Tests: Before Perforation: After Perforation: 1800 BFPD, 23% WC 3102 BFPD, 14% WC *Marathon 011 Company - Sub-Operator 16. I hereby ~'~that the fo~olng is true and correct S I G~' .~/~~T IT (~a~ce for Stat~ ~fice use) ge Dist. Drlg. Supt. DATE: 9/19/79 APPROVED P¥ CONDITION& O~ ~,PPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side - GEOPHY[ICAL/GEOLOGICAL DA7 . . TRANSMITTAL LIST FROM: MARATHON OIL COMPANY Mr. H. W. Kugler DEPT. ISENDER COMImANY Expl. I Dick Atchison Union Oil Co. - FORWARD ADDR E. SS ~OORES$. P. O. Box 2380 P. O. Box:'~: 6 2 4 7 VIA Anchorage, Alaska 99510 ii . QUANTITY 1 each -- L [;/~ a ch . TO: DESCRIPTION MARCH 15, 1979 -~-'~iq~:-- I 3 ENG --1-,'.;'ix"!~ I -1 [---1---':" ,,:;~xS!LJ/j hi .... :'='"- Ancho.r. age, AK 99502 ~ ':'~.""-:'L 14_1 WELL.- DollY Varden,' Trading Bay Unit "D-25" Redrill 1 print - Scientific Drilling Directional Survey Report '-TANG ., 1 Print - Scientific Drilling Directional Survey' Report - RADIUS 1 .sepia & 1 blueline print - "D-25" Redrill ~a'raband (Computer Processed Log) 'Borehole Compensated Sonic Loq 11 5 i! 11 !1 II II 2 II ~ [ ,~ ~ ~. ,~"'-' Dual Induction - SFL 2" · ., AJasl<a (~i ~ 6 :~ , "';', uummisslori " " " ArlOhora~j# 5" Compensated N~.u~ron-ForT~ation Density (Open Hole) 5" " " " " (Cased Hole). 5" Compensated Formation Density Log ( Gamma-Gamma ) 5" WELL - MarathOn "Tradinq Bay uni. t" .,~D'-4q -,: Dolly V.a. rden, Scientific Drillinq Controls Directional Survey Report GYRO .& Radius NOTE: ~P-ERRY SUN ~D-40 GYRO IS WRONG. SENDING NEW ' ~ SUBMIT IN £ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE [CATE' <o., thor lll- .~t ruct runs on rever,~e side: WELL COMPLETION OR RECOMPL.ETION REPORT AND LOG* i i ii i i la. TYPE OI" WELL; oil, ~ u~ ,,',:u. ,,.r.,, ~ D,, El Other Redrill b. TYPE OF COMPLE~ON: Union Oil Company of California* P. 0. gox 62~7. Anchorage AK 99~02 ~ ~o~, Leg R-l, Conductor 8 0~1 ly Var~n Platform. 1210"F~L, 751'FSL, Sec. 925'~, 550'F~L, ~c. 8-8N--~-Sn At :~l 1265'~L, 625'FNL, Sec. 8-~1~-SM 7" 79~8' t 1 1 _';06' ! 7~;O. Bench 4: ~1,062'-11,125' 1% It?F Bench 5: 11,150'-11,187' It HPF Bench 5: il,200'-11,272' q HPF 50- 133 202~ - - } Trading Bay acArthur River O~E~IVE) Sec. 8, TSN, R13W. 12. P~MIT ~O. _ 78-87 12-02-.78 01-11-79 01-30--7~ KB 106.2'MSL · 62 'MSL :ZL DRILLED ~¥' I~")~F'~i~' l}25-3i~]rL "~ ~i:"i~%-~l~Lt' ~~ ~~ ~~~ . [ ~~OLS 'INTERVALS P~'~X~ ~%'~., O~ ~ C~~. ~~ ~ ~ ~ .,.; ~ ' ~'' ~ ]~. WAS DiRE~ON~ Top of ~mlo~: 9314'~D 10,642'MD :' ~} i Btm of ~mlock: ~2'~0 1],305'MD /' ;.- -~ I. Yes ~i~:'-,, ·, , ., . I"d~l. , .~ . . ....... e, t [ ,,. ~-S/8" ,'7 tP'''Ot 8155[ t 12' i (Kickoff Point) , , , ,, ~ , ~ 8000'-8002' {5q~a 375 ~x .3~ Halad 22-A (2.,PF) l l~ CFR-2. C l G cmt __ ............. ~Ha lad 22-A .... ~ ~SZ PfiOC. UC~ON i ~ODD-~IO~ IlEI {{OD ,F~,n.g. ~ KIi. pUIglp~g--S~ altd ~'~ Oi pumP, I V, ELL $'FA'[U~ t Producing or } O1-30c79 Gas Lift' I Producing .... ! , I ! I ',2Z , 150 !050 ] - ~! 3128 I 1011 Lift Gas and Sales 3~'. l.l:~T OF AZ'TACH.MK.~T~ Well History, Casing and Tubing Details :,2. I h~r~-bv cer,ttfv that the ' / . , furegoiag and attached./i"f"rmatl"n is complete and correct a~ determmt.~ from ~tll available recurd~ f/ S,ON'~:,,_'~4?-~ ,)~. ~ ~-~~/ / . TITLE ~ist.?Drlng Superintendent DATE ~ruar~4,197 i i iiii i ii ' i i i ii i IL II IIII I I I *(See InstructiOns and Spaces Jar Additional Data on Reverse Side) Sub-Operator WATER,---DBL. I OIL GRAVITY-APl (COILR,) ] , , 21~ ' ,] 3S° ~T WITN£SSI~D BY O. R. McClellan *Marathon Oil Company Form 10-403 REV. 1-10~73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Union 0i] Company of Ca]ifornia* 3. ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL Atsurface Leg A-1 , Conductor 8, Do] ]y Varden Platform 1210'FWL, 751'FSL, Sec. 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB 106.21 MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20247-01 6. LEASE DESIGNATION AND SE~-- ^DL-18729 8. UNIT, FARM OR LEASE NA~ Tradinq,Bay Unit McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N, R13W, SM 12. PERMIT NO. 78-87 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Change reported MULTIPLE COMPLETE ABANDON* CHANGE PLANS locations SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of ~arting any proposed work. Upon evaluation of our final Gyrosppic Surveys we are noting the following changes. Top Producing interval: 735'FWL, 360'FNL, Sec. 8-8N-13W-SM At Total Depth: 1252'FWL, 440'FNL, Sec. 8-8N-13W-SM Producing intervals: Top of Hemlock: 9325TVD 10,642'MD Bottom of Hemlock: 9852TVD ll,305'MD Total Depth 11,510 MD IO,O18'TVD 16. I hereby certif~i/~hat the foregoing is true and c..orj:3~t ~ .~ (Thi ~, r State office u~) CONDITIONS OF AP.ROVAL,,~F ANY. *Harathon 0il - Drilling Engineer DATE 3/14/79 Company Sup-operator DATE ....~/]' [~/~ See Instructions On Reverse Side F~rra No. P--4 l~lgV. $-1-70 STATE O, ALASKA OIL AND OAS CONSERVATION CON'dWlTTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS WELL wELL OTHER NAME OF OPE1R.ATOR Un i on 0 i I Company of Ca I i torn i a* Post Office Box 6247, Anchorage AK 99502 4. LOCATION OF WELL Surface: 12IO'FWL, 751'FSL, Sec. TD: Sec. 8, T8N, R13W, SM SUBMI~ ]~t D1LTPLICA~I~ API NU~IERICAJ~ CODS 50 133-20247-01 LEASE DESIGI~ATION A.~'D ADL- 18729 8. L~IT F.~ OR LEASE NAME Trading Bay Unit g W~ ~O D.2[RD 10, FI~ ~ND P~L O~ WI~DC&W . j .' .:, ~ Sec. 8, T8N, R13W, SM 13, REPORT TOTAL D~ AT ~D OF MON~, ~TS SET ~ VOLI~ USED, p~O~TIONS, AND ~NY O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. JANUARY REPORT OF DRILLING OPERATIONS 01-01 10,728'TD 01-02 10,772'TD 01-03 lO,790'TD Tested DOPE & related equipment--OK. RU Schl & ran GR/SP/DIL log for correlation. RD Schl. RIH w/ bit //17. Drld from 10,650" to 10,728'. Drld from 10,728' - 10,763'. C&C mud for coring. POH. RIH w/ Christensen coring eqpmt. Cut 4" core in Bench 2, Hemlock Zn, from 10,763' - 10,772' Top of Hemlock by correlation log @ 10,620' (Bench 0). POH after coring from 10,763' ~ 10,772' (9')? Rec 5' of solid core & 4' of unconsolidated core. RIH. Cut & slipped drlg line, Cored from 10,772' - 10.,790' (18') in 13½ hrs.. 01-04 lO,816'TD Cored from 10,778' - 10,794'. POH w/ core //2. (Rec 11' out of 22' cut.) RIH w/ core bbl. Cored from 10.794' : 10 816'- (22'). Started POH. 01-05 lO,8951TD 01-06 10,982'TD LD core & core bbl. (Rec 22'. out of 22' cut.) RIH w/ bit //19. Drld from 10,816' - 10,895~.~ POH. R!H w/ bit //20. Drld from 10,895' - 10,972'. POH. RI.H w/ core bbl. Cored from 10,9721 - 10,982' (_Bench 4, Hemlock). 01-07 11,052'TD POH w/ core //4. Rec ~0'- of sd~ gravel, & core fragments. LD core bbl. RIH w/ bit //21. Drld from 10,982' ~ 11,050'. POH. RIH w/ core bbl. Cored from 11,050'- - 11,052' ,..:- , --~\~ ~ "~ r- ;" Dis r S ' t~AT~ ~ V,f-, ~ZTZ.~ is r S ' F~~ 1979 --, port on ,hi, form il r.quir, d for .each cai.rider ~nth, r.gardles, of ,ho .,atu. of op.rations, and must ~ ,lied 'In dupllcat, with th. ................. oil and gus conservation commiflee by the 15~ of the suGc~ding month, unle~ otherwise directed, *Marathon Oil Company - Sub-Operator January Report of Drilling Operations Well D-25RD Page 2 01-08 11,074' TD 01-09 ll,301'TD 01~10 11,445'TD 01-11 ll,510'TD 01-12 ll,510'TD 01-13 ll,510'TD ll,415'PBTD 01-14 I1,510'TD I1,415'PBTD 01-15 ll,510'TD ll,415'PBTD 01-16 I1,510'TD 11,415' PBTD 01-17 ll,510'TD 11,415' PBTD 01-18 11,5 IO'TD 11,415' PBTD Cored from 11,052' - 11,069'. POH w/ core bbl & core //5. Rec 13' of core out of 19' cut. RIH w/ core bbl to cut core //6. Cored from 11,069' - 112074'. Started out of hole. POH w/ core #6. Rec 6~ of unconsolidated core, RIH w/ bit #23. Drld from 11,074' - 11,301'. Drld from 11,301' ~. 11~374'. CBU. Dropped surv. POH, Press tstd BOPE. PU bit #24, chgd 1 stab, & RIH. Reamed 90' to btm. Drld 11,374' - 11,445'. Drld from 11,445' ~ 11,510~'. Made short trip to 8155'. POH. RU Schl & ran DIL/SP log. Now running BHC/Sonic log. Schl reran BHC/Sonic log & ran FDC/CNL log. RD Schl. RIH to 11,510' & circ. Made short trip to 9155'. RIH to 11~510'. C&C mud & hole to run 7~' lnr. POH. POH. RU csg crew. RIH w/ 7", 29#, N-80, Butt lnr w/ BOT lnr eqpmt on 5:~ DP. Set lnr w/ FS @ 11,506', LC @ 11,415', hgr @ 7947 & tie-back slv@ 7938'. Halliburton cmtd 7~' lnr w/ 750 sx Cl G w/ 1% CFR-2, .3% Halad 22-A~ & 3% KC1 preceded by 20 bbls of mud flush. Bumped plug to 2500 psi. CIP @ 2400 hrs~ 01-12-79. MU BHA. Chgd out hydromatic seals & cut & slipped drlg line while WOC. Measured in hole. Tagged top of lnr @ 7938'. No cmt @ top of lnr. Press tstd csg to 2500 psi-~-OK. POH. LD HWDP & 6¼" DC. PU 6'~ bit & started in hole PU 3½" DP. Fin RIH w/ 6" bit on 3½" & 5" DP. Tagged cmt @ 11,275'. Drld cmt (140') to 11,415' (landing clr). Press tstd csg & lnr to 2500 psi-~OK. PU Johnston DST tools & RIH for dry test on lnr lap. Set pkr ~ 7801'. Ran dry test w/ 1500' WC. Surf data indicates no lnr lap leak. Rev out WC. POH w/ DST tools. RU DA & ran CBL. Closed blind rams. Tstd csg & lnr to 2500 psis-OK. RU gyro & ran gyro surv from surf to PBTD on DA WL. RD DA. Started in hole w/ 6" bit & csg scraper. Tripped w/ 6" bit & scraper to 11,415' RU DA & perfd for isolation sqz ~ 11,625' - 11,627' w/ 4"' csg jet loaded 2 HPF. DA set Halliburton EZ-Drill cmt rtnr @ 10,600~ RIH w/ rtnr stinger. Tstd lines to 5000 psi. Prep to sqz. PI: perfS'@ 10;625" - 10,627' w/ 3300 psi @ 1½ BPM. Mixed 200 sx C1 G w/ 1% CFR-2 & .3% Halad 22-A. Sqzd 180 sx into perfs w/ FP of 4000 psi. Rev 20 sx. POH. RU DA & perfd @ 8000~ - 8002" w/ 4" jet, 2 HPF, for sqz @ top of lnr. DA set Halliburton EZ.-..Drill cmt rtnr ~ 78~0'-. RIH w/ rtnr stinger on 5'~ DP. PI perfs ~ 8000' - 8002' w/ 2800 psi @ 2½ to 4 BPM. Mixed 200 sx Cl G cmt w/ additives as above & pumped all 200 sx thru perfs @ 1700 to 2900#. Cleared perfs w/ 20 bbls wtr & 10 bbls mud, Rev out. WOC. January Report of Drilling Operations ~Vel 1 D-25RD Page 3 01-19 ll,5101TD 11,415'PBTD 01-20 ll,510'TD ll,415'PBTD 01-21 ll,510'TD ll,415'PBTD 01-22 ll,510'TD ll,415'PBTD 01-23 ll,510'TD ll,415'PBTD 01-24 ll,510'TD ll,415'PBTD 01-25 ll,510'TD 01--26 I1,510'TD II,415'PBTD 01-27 ll,510'TD ll,415'PBTD 01-28 ll,5101TD ll,415'PBTD WOC. RU Halliburton for stage 2 @ top of lnr. Stabbed into cmt rtnr @ 7890'. Press to 4500 psi. Could not pump into perfs @ 8000' - 8002'. POH w/ rtnr stinger. RIH w/ 8½:1 bit & drld rtnr @ 7890'. Pushed remains of rtnr to top of lnr & fin drlg rtnr. POH. Tstd BOPE. Fin testing BOPE. RIH W/ 6I' bit. Fin drlg rtnr & pushed same to top of lnr & fin drlg._ Drld cmt stringers from 7986' - 8014'. Tstd csg & lnr lap sqz to 2500 psi. Press bled to 500 psi in 5 min. Pushed junk & cmt to 8167'. POH. RIH w/ Halliburton EZ-Drill cmt rtnr on 5" DP. Mixed 200 sx C1 G cmt w/ .3% Halad 22-A & 1% CFR-2. Stabbed into rtnr ~ 7880~ & sqzd 175 sx below rtnr into perfs @ 80001 - 8002" in lnr lap. FP 3500 psi. Rev 25 sx cmt. POH. WOC. RIH w/ 8½': bit. Now prep to drill rtnr @ 7880'. Drld cmt rtnr @ 7880' & cmt to top of lnr @ 7938'. POH. PU 6~: bit & RIH to 7938'. Drld cmt to 8024' & cmt stringers to 8100'. Tstd lnr lap (perfs @ 8000' - 8002')i w/ 2500 psi for 15 min. Held OK. RIH to 10,600' & drld cmt rtnr. Drld cmt to 10,630'. Tstd sqz perfs @ 10,625' - 103627' w/ 2500 psi for 15 min. Held OK. POH. RU DA & ran gauge ring & JB to 8000' to check top of lnr for obstruction. Lnr top OK. POH. RIH w/ 6" bit & scraper to 11,415'. Displ mud in csg w/ FIW. POH LD DP. DA set Otis ~./D perm pkrs @ 11,130~ & 10,530'(CBL). RIH w/ 3½" x 4½" prod tbg. (Had 4500'. in hole @ 0700 hrs,) Fin RIH w/ 4½'~ prod tbg Gator-Hawking to 5000 psi. Landed seals in Otis WD pkr @ 10,530' & tstd same. Set BPV & ND BOP. Instl Xmas tree ~ 0700 hrs. Tstd Xmas tree to 5000 psi. Connected flow line & GL line to tree. RU Otis & pulled BV @ 296'; Unloaded 300 bbls wtr by GL. DA perfd Bench 5 of Hemlock @ 11,252'. ,. II~272'DIL w/ 2.6'',~ Slim.-Kone jet (14 HPF). Presently gas lifting well @ 0700 hrs. Well stab @ rate of 935 BFPD ~ 30% WC (654 BOPD) from perfs ~ 11,252' -.- 11,272'. DA perfd Bench 5 of Hemlock @ 11,221' - 11 252' DIL w/ 2.6~' Slim~Kone jet (4 HPF). GL well @ rate of 1450 BFPD @ 20% ~.~C (1160 BOPD). DA perfd Bench 5 of Hemlock @ 11.200' - I1,221'DIL w/ 2.6" Slim-Kone jet (4 HPF). GL well @ rate of 1950 BFPD @ 20% ~VC (1584 BOPD). DA perfd Bench 5 of Hemlock @ 11~,167' - I1,187'DIL w/ 2.6'~ Slim-Kone jet (4 HPF). GL well @ rate of 2400 BFPD @ 15% VJC (2040 BOPD). DA perfd Bench 5 of Hemlock @ 11,150~' to II,167'DIL w/ 2,6'''~ Slim-Kone jet (4 HPF). GL well ~ rate of 2880 BFPD ~ 12% WC (2534 BOPD), RU Camco to run press BU surv, Camco found short in elec line. January Report of Drilling Operations Well D-25RD Page 4 01-29 ll,510'TD ll,415'PBTD 01-30 11,510'TD 11,415' PBTD 01-31 11,510'TD 11,415'PBTD 02-01 ll,510"TD ll,415'PBTD Repaired odometer on Camco unit. Camco RIH w/ HP press gauge to 10,500'. Stab well ~ 2856 BFPD w/ 12% WC (2513 BOPD). Ran BU surv. SIBHP of Bench 5 = 3691 psi. RD Camco. RU DA & perfd 11,094' - ll,125~DIL in Bench 4 of Hemlock w/ 2.6" Slim~Kone jet (4 HPF). Prod well @ rate of 3504 BFPD @ 11% WC (3118 BOPD). DA perfd 11~062~ - II,093'DIL in Bench 4, Hemlock, w/ 2,6TM Slim.-~Kone jet (.4 HPF) Perf gun hung in Otis X nipple @ 10 566'. /4orked line & pulle~ out of DA's rope socket. Placed well back on prod @ 0700 hrs. Well had stab @ 3200 BFPD ~ 8.5% WC (2928 BOPD). It appears that the btm 10' section of the 30' gun hung & stuck in the X nipple below the upper pkr. Gun would not move up or dwn. Plans are to make an attempt to pull the gun rrm the tbg using an Otis unit w/ braided line. The upper Otis WD pkr is @ 10,530'. The X nipple is @ 10,566'. Prod well by GL t~ rate of 3360 BFPD @ 9% WC for 4 hrs.. RU Otis WL unit. RIH w/ OS to latch fish (perf gun).. Ran WI tools to 10,590'. Did not engage fi'sh, Top of fi,sh should have been @ 10,541'. Perf gun evidently, fell out of the X nipple ~ 10,566' & has probably landed in the Otis X nipple below the Otis WD pkr @ 11,130' Released rig @ ~2400 hrs, ~317~30~-79. Well prod @ rate of 3400 BFPD @ 8% WC (3128 BOPD) from Benches 4 & 5 of Hemlock Zn. FINAL REPORT ' SUBMIT IN DU~..,I :ATE* STATE OF ALASKA ~s,.,.oth~r t.- st ructions on OIL AND GAS CONSERVATION COMMITTEE WELk cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: .xEw [] v¥onK ~ WELI, OVER o., ~ oAS i~"~ ~ Other Redrill WELL WELL ~ DRY EX BACK P. ESVR, Other NAME OF OPERATOR 'Union 0il Company of California* 3, ADDRESS OF OPERATOR P. 0. Box 6247. Anchoraa¢ AI~ 9950?. 4. t. Oc*T~ON or WELL '(Report location clearl~ and in accordance with any State r~quireme,~ts)* at~ff~ Leg A-l, Conductor 8 Dolly Varden Pta~form 1210'FWL, 751'FSL. Sec. 6-8N-13W-SM At top prod. interval reported below 925'FWL, 550'FNL Sec. 8-8N,,13W-SM ..... ~ "-'. At total dep~ ~ ' ' 1265'FWL, 625'FNL, Sec. 8-8N,13W-SM - 5. AP1 NUM.E~CAL .CODE 50-133 20247-01 6. LEASE DESiGNATiON AND SERIA~L, NO. ADL-18729 ~ 7. IF INDIAN, ALLOTTEE OR 'I'I{IBE 8. UNIT,FARNI OR LE~kS~i NAME Trading Bay Unit 9. WE'LL NO. D- 25RD 10. FIELD A~qD POOL, O1~. WII~DC/kT McArthur River Fiel 11. SEC., T., R., IVI., (IOOTTOM HOL~ O/2~/Ec-rlvz/ Sec. 8, TSN, R13W ~12. PETt.!VI IT 78-87 12-02', 78 01-11-79 01-30,:~79 KB 106.2'MSL ~ 62'MSL lC. TOTAL DEPTH, ';VLID & TVD[19. PLUG, BACK MD & 'i'VD~20. IM' MULTIPLE CO1VI~L., 21. INTER~,'At.$ I)RiI.I.ED IsY ll,510'MD / ll,4.15'MD | ~o,v~. .eT^,.' TOO,..~ I'--.^.~.E TOO,,.~ ___.z0~nv~,T, VD , / 9,ggl'TVD ,/ All ~2. PRODO~-II~IG ~NT~-.R~AL(S), OF TI-/Z$ CO,NiPI2gTIO~--TO,P, BO'IWOM, NAME (MI) AND 'I'~,q))~ ~3. WA,q D!I~ZCT]ONAL ! SUHVE¥ MADE Top of Hemlock: 9314ITVD 10,642'MD { Btm of Hemlock: 9842'TVD ll,305'MD ' Yes 24. TYPE ELECTRIC AND OTHE~ LOGS RUN DIL/SP, BHC-Sonic., FD_C/,CNL, CBL, GR-.Caliper, Gi,yro 25. C/~SLN G SIZE 13-3/8" 9-5/8" , CASING REC:ORD (Report all strings set in well) , 4.7 0 8155' 12¼ (Kickoff Point) , ,,,, 7I' 79_ ' 11 ;506' 750 4vx3~ 10,596' 10,,530' & .... I I I ' 11,1~0' ~. PEI~FORATi. ONS OP~ TO PRODUC~ON' (interval, size and number) 29. ACID, St:eT, Fi~AC'~ GRE, C~dENT SQU L~;:.~ 'r:~ , DEPI~i INT~VAL (MD) I AMwUN~ ~D I~LND OF 51A/~ZU[iAL USED Bench 4: 11 062' 11 125' 4 HPF ' ' 8ooo'-8o02, ~za 375 s~ .3a a~ad'~-A Bench 5' 11,150'II1,187' 4 HPF (2 HPF) }1% CFR-2,, Cl G cmt ..... Bench 5' 11,200'-11,272' 4 HPF 10,625'-10,627',[Sqz '180 ~X cmt 1% CFR 2 30. P~ODUCTION DATE FIRST PI'reDucTIoN [ P~ODUCT1ON M~IHO'D (Flowi~g, gaa titi, p~mping~size and type of pump, IV, ELI., STATUS ~Producing or 01-30-79 } Gas Lift I ...... ~-;'"' Produci nq FLOXV, TUBING CAS~qG PRESSURE IcALc~T~ OI~BBL. GAS--r,[CF. W/k~R~DBL. [OIL GRAVITY-~I (CORR.) 150 1050 3128 ~ 1011 I 2 0 .... 31. DISPOSITION OF GAS (~O~d, u~ed ~or ~ue[, vented, etc.) ST WITNESJ ' Lift Gas and Sales J, R. McClellan ~2. LIST OF t1'TACHM~NTS Well History, Casing and Tubing Details 33. I hereby ~tify that the foregoing and attached information is complete and correct a~ deter~ine'~ from all-available records // ~ ~ .~ ' / .... : *(S ions ond Sp~e,s ~or Addilionol Dote on R,v~rs, Side) *Marathon ~1 Company Sub-0pe~ator INSTRUCTIONS General. This form is designed for submitting a complete arid correct well completion report end log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown! for depth measure- ments given in cther spaces on this forr'~ ancJ n any atta-h;:~e?,ts Items 20, and 22:: If this well is completed for separate prc, duction fro,"" r"'~ore than one iatervat zone (multiple completioa), so state ~n item 20. and im Ite'~ 22 show the p:c.dLJc~r~g interval, or imtervaJs, top(s), bottom(s) and name (s) (if any) for only the interv~ll reported in ~ter'm 30. S,,.JJ:-)mit a separate report (page) on this form, adequately identified, for each additiomal interval to be seperately produce.d, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shouIJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). 34. SUMMAItY OF FORMATION TF.~'I'S IN('LUDIN(; INTERVAl. TF~STED. PHE.~kSURE DAT~. ~ ~OVERI~ OF OIL GAS. 35. G~GIC WAT~ AND MUD _ , , , . , . ., ~N.~ D.~i~E~q~ED St'IO:WS. OF. O.IL, GAS- O'R WA~I:. DATE February 2, Z979 MARATHON OIL COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River WELL No..D-25RD LEASE STATE Alaska BLOCK Tradin~ Bau SEC. 8 PARISH COUNTY Kenai Peninsula Borough TWP. 8N R 13w 106.2 ' ELEV. KB ToP OF OIL STRING ~ ELEV.. HISTORY PREPARED BY MEASUREMENTS ~Top OF ROTARY TABLE ELEV. TITLE TAKEN FROM ~ ..... ~GRO. OR MAT ELEV. L. G. Hauwood Secre ta ry It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1978 11-30 1 2-01 12-02 12-03 12-04 12-05 12-06 12-o7 12-08 12-09 WELL HISTORY - TBU D-25RD (Marathon AFE 4620) ll,350'TD Accepted rig #76 at 1200 hrs, 11-29-78. Skidded rig over Well D~25. lI,243'PBTD RU kill lines & lub. Otis opened circ slv@ 10,448'. Started circ mud to kill well. ll,350'TD Circ 9.6#/gal mud & killed well. Instld BPV in tbg. ND Xmas tree. ll,243'PBTD NU BOPE. 11,350'TD Fin NU BOPE. Tstd BOPE. POH w~ 4.-1/2" SL tbg & Otis RH pkr. Chgd ll,243'PBTD rams in BOP & suction .vlvs in mud pumps. Instld wear bushing. PU 8-1/2" bit & started in hole PU 5" DP. ? ll,350'TD Fin RIH w~ 8-1/2" bit. Tagged fill @ 11,142~. CO fill over Bench 6.,. lI,243'PBTD Hemlock Zn to PBTD ~ 11,243'. Circ out gas & oil cut mud on choke. C&C' mud. Started POH. ll,350'TD POH. RIH w~ OEDP to 11,215'. RU Halliburton & laid 90-sk Cl G cmt lO,568'PBTD plug w~ .1% HR-6L from 11,215' ~ 10,925' & 125~sk Cl G cmt 'plug w~ .1% HR-6L from 10,918' ? 10,568' (all benches of Hemlock isolated). POH. PU csg scraper & started in hole. ll,350'TD RIH to 5549'. Bit plugged w~ cmt scale while filling DP. POH, lO,568'PBTD Attempted to CO cmt scale. RIH w~ csg scraper. LD 36 jts DP (cmt scale inside). RIH to 9309' w~ csg scraper, Now circ@ 9309'. -_ li,350'TD Circ & pumped slug. POH w~ csg scraper. Set Halliburton BP @ 9000'. lO,568'PBTD Perfd 2 HPF from 8210' ~ 8212'. Set Halliburton EZ~Drili cmt rtnr ~ 8190'. RIH w~ Halliburton cmt rtnr seal assy for sqz. ll,350'TD RIH & tagged rtnr ~ 8190'. Tstd lines to 5000 psi. Pumped into fm 9,000'PBTD w~ 2800 psi. Mixed 150 sx Cl G cmt. Sqzd perfs (8210~ ~ 8212') to max press 4400 psi. Final sqz press 3600 psi. Rev out 11 bbls good cmt. Pumped dwn wiper plug. POH. Perfd 8170' ~ 8172r w/. 4" gun loaded w~ 2 SPF. Now RIH w~ HOWCO cmt rtnr:. !!~350'TD Fin in hole w~ cmt rtnr. Set rtnr ~ 8140'. Tstd line to 5000 psi. 9,000'PBTD Estab break dwn rate of 2 BPM ~ 3650 psi. Sqzd perfs 8170' .- 8172~ .. w~ 100 sx Cl G cmt. Sqzd 85 sx & rev out 15 sx. Max & final press 3100 psi. Rev out & POH. Tstd BOP's. RIH w~ drlg assy. Now drlg on top cmt rtnr. ll,350'TD Fin drlg cmt rtnr @ 8140'. Drld cmt & junk to 8190~. Drld rtnr ~ 9,000'PBTD 8190'. CO to 8600'. C&C mud & POH. RIH w~ milling tools. Milled 9-5/8" csg from 8155' ? 8157'. Well History - TBU Well D-25RD Page 2 12-10 ll,350'TD Milled 9-5/8" csg from 8157' - 8158'. C&C mud to incr visc. Milled 9,000'PBTD 9-5/8" csg from 8158' - 8177'. Circ & cleaned hole. POH ~ dressed mill. RIH. Filled pipe & found mill plugged. POH. Broke dwn mill looking for obstruction. 12-11 ll,350'TD Found cuttings to be plugging tattle-tail of section mill. RIH w~ 9,000'PBTD section mill #2. Milled from 8177' - 8179' in 3 hrs. POH. Blades of mill smooth. RIH w~ section mill #4. Milled from 8179' - 8181' in 8 hrs. Started out of hole. 12-12 ll,350'TD POH w~ mill #3. Had drag all the way out of hole. Rec 6' section of 9,000'PBTD 9-5/8" csg w~ 50-75% of radius of curvature in tact for entire length. Pulled wear bushing. Rec 2' section of 9-5/8" csg. RIH w~ mill #4. Reamed from 8155' - 8181'. Milled 9-5/8" csg from 8181' - 8186'. Started out of hole. 12-13 ll,350'TD Fin POH w~ mill #4. RIH w~ mill #5. Milled from 8186' - 8197' in 9,000'PBTD 1i hrs. POH. RIH w~ mill #6. 12-14 ll,350'TD Fin RIH w~ mill #6. C&C mud for 2 hrs. Milled 9-5/8'~ csg from 8197' - 9,000'PBTD 8210'. Strapped out of hole & LD Servco milling tools. RIH w~ OEDP to set cmt plug to start directional drlg ops. Section in 9-5/8'~ csg from 8155' - 8210' (55'). 12-15 ll,350'TD C&C mud to lower visc. RU Halliburton. Mixed 70 sx Cl G cmt w~ 1% 8,100'PBTD CFR-2 and laid plug from 8100' - 8250'. POH. Tstd BOPE & related eqpmt. Cleaned sd trap. WO mud pumps. RIH w~ 8.-1/2" bit. 12-16 RIH to '8019'. WOC. Tagged cmt plug @ 8137'. Drld soft cmt to 8147'. 8,165'PBTD WOC for 5 additional hrs. Drld firm cmt to 8165'. POH. RIH w~ 8.-1/2" ? diamond bit & Dyna-drill to 8163'. RU WL & steering tool & RIH. Steering tool failed to operate. POH w~ steering tool. 12-17 Ran 2nd steering tool. Could not get steering tool to seat in bent 8,165'PBTD sub. POH w~ WL eqpmt. POH w~ wet string. Found obstruction in btm steel DC. RIH w~ DD to 8163'. RU DA & steering tool. Could not break circ w~ 2500 psi. RIH w~ WL. WL tools would not pass 7815'. POH w~ wet string. Btm Monel DC & DD plugged w~ cmt scale. 12-18 8,235 ' TD LD 1st DD. RIH w~ 2nd DD to 8165'. RU WL & steering tool. RIH & oriented tools. DD for KO from 8165' - 8235'. POH w~ steering tool. RU to run SS surv. 12-19 ~'~-~ 8,336'TD .. 12-20 8,534 ' TD 12-21 8,710 ' TD Ran SS surv. POH w~ DD. RIH w~ angle bldg assy, Circ btms up. Ran SS survs. Hole angle reading 33-1/2° but direction reading erratic due to metal interference. POH. RIHw/ "locked in" BHA. Drld 8235' - 8336'. Worked by junk. POH. RIH w~ short tooth bit. Ran on junk & drld 94'. Circ & took surv ~ 8390'. POH to chg BHA & bit. RIH & drld 8430' - 8534'. .. Drld from 8430' - 8710'. POH. Repaired kelly spinner & slipped drlg line. PU DD & RIH. 12-22 8,773'TD .. RU steering tool & RIH. Drld w~ DD from 8710' - 8773'. POH w~ steering tool. Started out of hole w~ DD. 12.-23 8,985'TD POH w~ DD. RIH w~ bit #9. Drld from 8777' ~ 8934'. POH. Tstd BOPE & related eqpmt. RIH w~ bit #10. Drld from 8934' - 8985'. 12-24 9,420'TD Drld from 8985' - 9339'. POH. RIH w~ bit #11. Reamed from 9061' - 9339'. Drld from 9339' - 9420 . Well History - TBU Well D-25RD Page 3 12-25 9,620'TD 12-26 9,800'TD 12-27 9,964'TD 12-28 lO,097'TD 12-29 10,222'TD 12-30 10,442'TD 12-31 lO,650'TD 1979 01-01 10 , 729 ' TD 01-02 10_,772'TD 01-03 lO,790'TD 01-04 IO,~16'TD 01-05 ~.~10,895'TD 01-06 10,982'TD '. 01-07 ll,052'TD 01'-08 ll,074'TD O1-09 11 , 301; TD Ol-lO 11,445'TD Drld from 9420' - 9516'. POH. Chgd rotary chain. Cut & slipped drlg line. RIH w~ bit #12. Drld from 9516' - 9620'. Drld from 9620' - 9750'. POH. RIH w~ bit #13. Drld from 9750' - 9800' Drld from 9800' - 9964'. POH. RIH w~ bit #14. Pipe began filling on its own. (Float instld above bit.) Stuck pipe momentarily 100' off btm due to under-gauge hole. Pulled free. Circ w~ 1500 psi pump press. Started out of hole to check for washout. Found hole in jt of Grade E DP immediately above HWDP while POH. RIH to 9587' w~ bit #14. Reamed 12 jts to btm. Made 5 std short trip. Drld from 9964' - 1.0,035'. Made connection & drld 1' when pipe became stuck. Could circ but could not rotate pipe. Lowered mud wt while jarring. Pipe came free w~ 35Q,000# pull. Lowered mud wt to 9.4#. Drld from 10,035' - 10,097'. Surv. Drld from 10,097' - 10,128'. POH. RIH w~ bit #15. Reamed 90' to btm. Drld from 10,128' - 10,222'. Surv. POH. RIH w~ bit #16. Drld from 10,222' - 10,442' Drld from 10,442' - 10,650'. POH to 9-5/8'~ csg shoe. Slipped drlg line. POH. Tstd BOPE & related eqpmt. RU Schl & ran GR/SP/DIL log for correlation. RD Schl. RIH w~ bit #17. Drld from 10,650' ~. 10:728'. Drld from 10,728' - 10,763~'. C&C mud for coring. POH. RIH w~ Christensen coring eqpmt. Cut 4': core in Bench 2 of Hemlock from 10,763' - 10,772". Top of Hemlock by correlation log ~ 10,620' (Bench 0). POH after coring from 10,763' .- 10~772' (9'). Rec 5' of solid core & 4' of unconsolidated core. RIH. Cut & slipped drlg line. Cored from 10,772' - 10....790' (18') in 13.~1/2 hrs. Cored from 10,778~ - 10,794'. POH w~ core #2. (Rec ll' of 22' cut.) RIH w~ core bbl. Cored from 10~794' - 10~816~' (22'). Started out of hole. LD core & core bbl. {Rec 22' of 22' cut.) RIH w~ bit #19. Drld from 10,816' - 10,895'. POH. RIH w/ bit #20. Drld from 10,895' - 10,972~. POH. RIH w~ core bbl. Cored Bench 4 of Hemlock from 10~972' - 10,982~? POH w~ core #4. Rec 10' of sd, gravel, & core fragments. LD core bbl. RIH w~ bit #21. Drld from 10,982' - 11,050". POH. RIH w~ core bbl. Cored from 11~050~ - 11,052'. Cored from 11,052' - 11,069'. POH w~ core bbl & core #5. Rec 13' of core out of 19' cut. RIH w~ core bbl to cut core #6. Cored from 11,069' - 11,074'. Started out of hole. POH w~ core #6. Rec 6~ of unconsolidated core. RIH w~ bit #23. Drld from 11,074' - 11,301'. Drld from 11,301' - 11,374'. CBU. Dropped surv. POH. Press tstd BOPE. PU bit #24. Chgd 1 stab. RIH & reamed 90' to btm. Drld 11,374' - 11,445'. Well History - TBU ~¢ell D-25RD Page 4 Ol-ll O1-12 O1-13 01-14 01-15 O1-16 O1-17 01-18 01-!9 01-20 O1-21 O1-22 O1-23 O1 --24 ll,510'TD Drld from I1,445' - 11,510'. Made short trip to 8155' Schl & ran DIL/SP log. Now running BHC/Sonic log. POH . RU i1,510' TD Schl reran BHC/Sonic log & ran FDC/CNL log. RD Schl. RIH to 11,510' & circ. Made short trip to 9155'. RIH to 11.510'. C&C mud & hole to run 7" lnr. i1,510'TD POH. RU csg crew. RIH w~ 7"~ 29#, N-80, Butt lnr w~ BOT lnr eqpmt ll,415'PBTD on 5" DP. Set lnr w~ FS @ 11,506", LC ~ 11,415' . hgr ~ 7947' & tie-back sly @ 7938'. Halliburton cmtd 7" lnr w~ 750 sx Cl G w~ 1% CFR-2, .3% Halad 22~A,. & 3% KCi preceded by 20 bbls of mud flush. Bumped plug to 2500 psi. CIP @ 2400 hrs, 01-12-79. ll,510'TD MU BHA. Chgd out hydromatic seals & cut & slipped drlg line while ll,415'PBTD ~70C. Measured in hole. Tagged top of lnr ~ 7938'. No cmt ~ top of lnr. Press tstd csg to 2500 psi--OK. POH. LD HWDP & 6-1/4" DC. PU 6" bit & started in hole PU 3.~..1/2" DP. ll,510'TD Fin RIH w~ 6" bit on 3-1/2" & 5" DP. Tagged cmt ~ 11,275'. Drld ll,415'PBTD cmt (140'~) to 11,415' (landing clr). Press tstd csg & lnr to 2500#-- OK. PU Johnston DST tools & RIH for dry test on lnr lap. Set pkr ~ 7801'. Ran dry test w~ 1500'WC. Surf data indicates no lnr lap leak. Rev out WC. ll,510'TD POH w~ DST tools. RU DA & ran CBL. Closed blind rams. Tstd csg ll.415'PBTD & lnr to 2500 psi.-.-OK. RU gyro & ran gyro surv from surf to PBTD on DA WL. RD DA. Started in hole w~ 6" bit & csg scraper. ll,510'TD Tripped w~ 6" bit & csg scraper to 11,415'. RD DA & perfd for ll,415'PBTD isolation sqz ~ 11,625' - 27' w~ 4" csg jet loaded 2 HPF. DA set Halliburton EZ-Drill cmt rtnr @ 10,600'. RIH w~ rtnr stinger. Tstd ? lines to 5000 psi. Prep to sqz. ll,510'TD PI perfs @ 10,625'-27~ w~ 3300 psi @ 1.-.1/2 BPM. Mixed 200 sx Cl G w~ ll,415'PBTD 1% CFR-2 & .3% Halad 22-A. Sqzd 180 sx into perfs w~ FP of 4000 psi: Rev 20 sx. POH. RU DA.& perfd ~ 8000~-02' w~ 4" jet, 2 HPF, for sqz ~ top of lnr. DA set Halliburton EZ-Drill cmt rtnr @ 7890'. RIH w~ rtnr stinger on 5" DP. PI perfs @ 8000 ~.-02'~ w/ 2800 psi ~ 2~-1/2 to 4 BPM. Mixed 200 sx Cl G cmt w~ additives as above & pumped all 200 sx thru perfs ~ 1700 to 2900 psi. Cleared perfs w~ 20 bbls wtr & 10 bbls mud. Rev out. WOC ll,510'TD WOC. RU Halliburton for stage 2 ~ top of lnr. Stabbed into cmt rtnr ~ ..ll,415'PBTD ~ 7890'. Press to 4500 psi. Could not pump into perfs @ 8000'-02 ~. POH w~ rtnr stinger. RIH w~ 8,1/2'~ bit & drld rtnr @ 7890'. Pushed remains of rtnr to top of lnr & fin drlg rtnr. POH. Tstd BOPE. ll,510'TD Fin tstg BOPE. 'RIH w~ 6"' bit. Fin drlg rtnr & pushed same to top ll,415'PBTD of lnr & fin drlg, Drld cmt stringers from 7986" - 8014'. Tstd csg & lnr lap sqz to 2500 psi, Press bled to 500 psi in 5 min, Pushed junk & cmt to 8167~. POH. RIH w~ Halliburton EZ-Drill cmt rtnr on 5" DP. .. · ll,510'TD Mixed 200 sx Cl G cmt w~ .3% Halad 22~A & 1% CFR~,2. Stabbed into ll,415.'PBTD rtnr @ 7880' & sqzd 175 sx below rtnr into perfs ~ 8000'.-.02' in !nr lap. FP 3500 psi. Rev 25 sx cmt. POH. WOC, RIH w~ 8-1/2:~ bit. Now prep to drill rtnr @ 7880~'. ., ll,510'TD Drld cmt rtnr @ 7880' & cmt to top of lnr @ 7938". POH. PU 6" bit ll,415'PBTD & RIH to 7938'. Drld cmt to 8024' & cmt stringers to 8100'~ Tstd lnr lap (perfs @ 8000 "-02') w~ 2500 psi for 15 min, Held OK. RIH to 10,600' & drld cmt rtnr. Drld cmt to 10~630'. Tstd sqz perfs ~ 10,625' ~ 27~ w~ 2500 psi for 15 min. Held OK. ll,5IO'TD POH. RU DA & ran gauge ring & JB to 8000" to check top of lnr for ll,415'PBTD obstruction. Lnr top OK. POH. RIH w~ 6" bit & scraper to 11,415'. Displ mud in csg w~ FI?.r. POH LD DP. ll,SlO'TD DA set Otis WD perm pkrs ~ 11,130' & lO,530'CBL. RIH w~ 3rl/2" x ll,415'PBTD 4-.1/2" prod tbg. (Had 4500' in hole ~ 0700 hrs.) .. Well History - TBU Well D-25RD Page 5 01-25 01-26 01-27 01-28 O1-29 01-30 O1-31 02-01 Ii,510'TD Fin RIH ~¢/ 4-1/2" prod tbg Gator-Hawking to 5000 psi. Landed seals ll,415'PBTD in Otis WD pkr ~ 10,530' & tstd same. Set BPV & ND BOP. Instl Xmas tree ~ 0700 hrs. ll,510'TD Tstd Xmas tree to 5000 psi. Connected flow line & GL line to tree. ll,415'PBTD RU Otis & pulled BV ~ 296'. Unloaded 300 bbls wtr by GL. DA perfd Bench 5 of Hemlock 11,252' - ll,272'DIL w~ 2.6" Slimw..Kone jet (4 HPF). Presently gas lifting well ~ 0700 hrs. ll,5tO'TD Well stab ~ rate'of 935 BFPD ~ 30% WC (654 BOPD) from perfs ~ 11,252' - ll,415'PBTD 11,272'. DA perfd Bench 5 of Hemlock 11,221' - ll.252'DIL w~ 2.6" Slim-Kone jet (4 HPF). GL well @ rate of 1450 BFPD ~ 20% WC (1160 BOPD). DA perfd Bench 5 of Hemlock ~ 11,200' - 11,221~IL w~ 2.6'" Slim-Kone jet (4 HPF). ll,510'TD GL well @ rate of 1950 BFPD @ 20% WC (1584 BOPD). DA perfd Bench 5 ll,415'PBTD of Hemlock @ 11,167' - ll,187'DIL w~ 2.6" Slim-Kone jet (4 HPF). GL well @ rate of 2400 BFPD ~ 15% WC (2040 BOPD). DA perfd Bench 5 of Hemlock 11,150' - li,167'DIL w~ 2.6" Slim-Kone jet (4 HPF). GL well @ rate of 2880 BFPD @ 12% WC (2534 BOPD). RU Camco to run press BU surv. Camco found short in elec line. iI,510'TD Repaired odometer on Camco unit. Camco RIH w~ HP press gauge to ll.415'PBTD 10,500'. Stab well ~ 2856 BFPD w~ 12% WC (2513 BOPD). Ran BU surv. SIBHP of Bench 5 = 3691 psi. RD Camco. RU DA & perfd 11,094' - ll,125'DIL in Bench 4 of Hemlock w~ 2.6" Slim-Kone jet (4 HPF). ll,510'TD Prod well @ rate of 3504 BFPD @ 11% WC (3118 BOPD). DA perfd I1,062" - ll,415'PBTD ll,093'DIL in Bench 4 Hemlock w~ 2..6" Slim-Kone jet (4 HPF). Perf gun hung in Otis X nipple ~ 10,566'. Worked line & pulled out of DA's ? rope socket. Placed well back on prod @ 0700 hrs. Well had stab ~ 3200 BFPD ~ 8.5% WC (2928 BOPD). It appears that the btm 10' section of the 30' gun hung & stuck in the X nipple below the upper pkr. Gun would not move up or dwn. Plans are to make an attempt to pull the gun from the tbg using an Otis unit w~ braided line. The upper Otis WD pkr is ~ 10,530'. The X nipple is ~ 10,566'. ll,510'TD Prod well by GL @ rate of 3360 BFPD @ 9% WC for 4 hrs. RU Otis WL ll,415'PBTD unit. RIH w~ OS to latch fish (perf gun). Ran WL tools to 10,590'. Did not engage fish. Top of fish should have been ~ 10,541~. Perf gun evidently fell out of the X nipple @ 10~566' & has probably landed in the Otis X nipple below the Otis WD pkr ~ 11,130'. Released rig ~ 2400 hfs, 01-30-79. ii,5IO'TD Well prod @ rate of 3400 BFPD ~ 8% WC (3128 BOPD) from Benches 4 & ll,415'PBTD 5 of Hemlock Zn. FINAL REPORT ~.~e ] 1 ~o. E~-2..% PJD No. I en th ! J/.O0 Set From IJETA 1 L ANCIIC)I{ACE D1VISION To ~l. O0 42. ~q- 2z78./8, Size Wt. Date !-,,g4- 79 A~L.. A,,SL /Z .G X.-z °----~t /2. &| A-SL_ ASL'~ L ~UTT× A~L. Z-s,z .1 I N - 8oi ' bcJI N ,'~_<L: N_~C BuTT N- 80 F.z-.Vl -~ /3 __Rge. Cond. Remarts A-%L. · . ASL N-Bo A~L X /~.~ A._qL G-.L. /'. dill A~L x I ' ~OTT td-80lo-esso, Il .¢/z .~___~c ASL i N-~O ~o --__ t,) - 80 I! ~.S/''-e, ,~-z ; /.3/0 I Well No. ~-2_~D 'No. I 77' 2.10 &4 7'. 77 Set 6o7'7'.0~ 70o~5 . / 4 7~5/ 7. 04- 2./0 8~17. 2..% · 8.70 202.5. :94 ..9034.4:,4- 2./0 -.9o34./-o-!',. .9o~.74 2...91. ~;o 'J'I;B'I fiG/CAS] I;(; I)ETAI L ANCIIORAGE DIVIS].ON Da te / --2-4 - 79 By ~>F-¢ Size Wt. 4% 4% 4 J/z,. 12.& ' /2,& A~L~ / ~ .~ ~ ~U'T-T · C~.£. ~.~- /.2. , . ,, , /Z..~,. ~,¢'T'~" /2.G -- ...9. z. Thd. Gr.. R_ge. Cond. V. ~/o. ,]~ o~ v~ k)--80 z. 2_ z 2, 2.. Remarks /CAS'~ NC I)ETAI L ANCIIOI~GE DIVISION Well No. Da te ~- 7__4 - 7.9 No. Le_L_~ th From J. /0 Set To Size Wt. Thd. Grt.' ~ge. By /7.9.09 2. 10 .~./0 .3,.8 . ~q .... /a~s~_7. /cs Cond. Remarks 2., '1 -- -- I)E'F^I L ANCIIORACE DIVISION lOell No. ~-~t'~ Date' By Set No. Length From To SSze. Wt. Thd. Gr. Rge. Cond. Remarks TUBI, NG/CASI. NG DETAIL . . WELL NO.: DATE' BY: Item Descri;tion Set Jts Size Wt Thread Grade Range Condition Length From To , ~ ~ . . Remarks: COMPLETION REF'ORT JANUARY 22 ~, .197':? MARATHON OIL,. CO~:, DOLLY VARDEN D.:,25 REDRILL GYROSCOP~C_S~,RV~__Y__ K B ELEV~ 106r~2 FEEl' 1~GENI'[AL METHOD OF COMPUTATIONS JOB NO~ 11~..50-~093~GYM3 COMPUTED FOR SCIEnTiFIC DRILLING CONTROLS BY F~ M~ L~NDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS~ DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISI'ANCE ANGLE D M $ DOG LEG -' SEVERITY DEG/iOOFT 0 0 0 100 0 0 100,00 200 0 0 200,00 30O 0 0 300o00 400 0 0 400~00 500 0 0 500~00 600 0 0 600~00 700 0 0 700,00 800 0 0 800~00 900 0 0 900,00 0,00 -106.20 N O~OOE -6~!9 N O,OOE 93~80 N O,OOE 193o80 N O~OOE 293~80 N O~OOE 393~80 N O~OOE 493~80 N O,OOE 593°80 N O~OOE 693~80 N O,OOE 793,80 N O,OOE 1000 0 0 1000~00 893,80 N O~OOE 1100 0 0 1100,00 993~80 N O,OOE 1200 0 30 1199,99 1093~79 N26,00W 1300 5 0 1299,61 1193,41 S52,00E 1400 8 15 1398o58 1292o38 SSO.OOE 1500 9 45 1497o13 1390~93 S75~00E 1600 12 0 1594~95 1488~75 S73.00E 1700 13 45 1692~08 1585~88 S74o00E 1800 16 0 1788.21 1682~01 STi~OOE 1900 18 30 1883o04 1776~84 S74~00E 2000 20 15 1976~86 1870~66 S73~00E 2!00 23 0 2068~9! 1962~?1 S72~00E 2200 24 0 2160~26 2054~06 S72~00E 0 S 0~00 W 0 S 0.00 W 0~00 S 0~00 W 0"00 S 0~00 VI 0~00 S 0~00 w 0~00 $ O~OOW 0~00 S 0~00 W 0.00 S 0~00 W 0,00 S 0,00 W 0,00 S 0,00 W 0,00 S 0~00 W 0,00 S 0~00 W 0,78 N O,38 W 4,58 S 6~48 E ~,0~ S 20~6! E 11,45 S 36~97 E- 17,53 S 56~85 E 24,08 S 79~70 E 33~06 S 105~76 E 41~80 S 136~26 E 51~92 S 169~56 E 64.~00 S 206~52 E 76~56 S 245~21 E 0.00 S 0 0 0 W '"0.000 0o00 S 0 0 0 W 0~00 S 0 0 0 W 0.00 S 0 0 0 W 0~00 S 0 0 0 W 0~00 S 0 0 0 W 0~00 S 0 0 0 W 0~00 S 0 0 0 W 0~00 $ 0 0 0 W 0~00 $ 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 O W 0,87 N 25 59 ~9 W 7,94 S 54 45 41E 21~79 S 71 3 49 E 38,70 S 72 47 5 E 59o49 S 72 51 35 E 83~26 S 73 11 7 E ]10~81 S 72 38 30 E 142~53 S 72 56 39 E 3.77~t4 S 72 57 18 E 216~2]. S 72 46 ~7 E 256,$8 S 72 39 ~1 E 0~000 0o000 0~000 0~000 OoO00 0~000 0.000 0~000 0~000 OoO00 0~000 0~500 5,454 4o492 1.690 2~28! 1,764 2~377 2~653 1.78! 2~774 1,000 SECT1 0 O. 3; 83~ 110~ 142~ 177 ,, 216~ 256~- RECORD OF SURVEY ALL. CALCULATIONS PERFORMED BY I B M ELEC1'RONIC COMPUIF:-ER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFI' .SEA DIREC DEG~ 2300 25 0 2250~89 2144669 S?7~OOE 2400 27 0 2339~99 2233,?9 S?8oOOE 2500 30 0 2426~60 2320~40 $79~00E 2600 31 0 2512~31 2406~11 S?8~OOE 2?00 31 0 2598~03 2491~83 2800 31 0 2683~75 257~55 S?8~OOE 2900 3~ 0 2769~46 2663~26 S79~00E 3000 30 30 2855~63 2749~43 $?8~OOE 3100 30 45 2941~57 2835~37 S79~00E 3200 30 30 3027~73 2921~53 S78~00E 3300 30 30 3113~89 3007~69 SSO~OOE 3400 30 30 3200~06 3093~86 S?9oOOE 3500 30 45 3286~00 3179~80 SSO~OOE 3600 3! 0 3371~71 3265~51 S80~OOE 3700 31 0 3457~43 3351~23 SSO~OOE 3800 31 0 3543~15 3436~95 S80~00~ 3900 30 45 3629.09 3522.89 4000 31 0 3714~80 3608~60 S79o00E z~lO0 30 45 3800~75 3694~55 S76~00E 4200 31 0 3886~4.6 3780~26 S78~00E 4300 31 15 3971~95 3865~75 S76~00E 4400 31 0 4057~67 3951~47 S77~00E 4500 30 30 4143~83 4037,63 S76~00E 4600 31. 0 4229~55 4123~35 S77~00E 4700 3! 15 4315~04 4208'~84 S76~00E 4500 3! 0 /:-400 ~ 76 6294¢56 $76~00~ 6900 3! 45 &485~79 /:.379~59 S?5~OOE 5000 ~! ~0 457!~06 446~-~86 S76~00E 5!.00 31 15 4656~55 6550~5 S?5~OOE TOTAL COORDINATES 86~07 S 286~39 E 95,51 S 330,79 E 105~05 S 379~87 E 115~76 $ 430~25 E 126~47 S 480~63 E 137~i8 S 531~01 E 147~00 $ 581~57 E 157e55 S 631~21 E 167,3! S 681~4.0 E 177~86 $ 73!~05 E 186~68 S 78i~03 ~ i96~36 S 830~85 E 205~24 S 88!~20 E 2!4~!8 S 931~92 E 223~!3 S 982~64 E 232~07 S 1033~37 E 240~95 S 1083.72 E 250.78 S 1134~28 E 263~15 S 1183.89 E 273¢85 S ]234~26 E 286~40 S 1284~60 E 297~99 S 1334~79 E 310.27 S 1384~03 E 321~$5 S 1434~22 E 334~40 S 1484~:55 E 346~86 $ 1534~53 E 360~48 S 1585,35 E 373~12 S 1636~05 ~ 386e55 S ]686~]6 E CLOSURES DISTANCE ANGLE D M S 299,~04 S 73 1.6 17 E 344.31 S 73 53 39 E 394.13 S 74 32 28 E 445~55 S 74 56 26 E 496~99 S ?5 15 27 E 548~44 S 75 30 54, E 599~86 S 75 48 50 E 650~58 $ 75 59 4 E 701~64 S 76 ~2 15 E 752~37 S 76 19 3t E 803~03 $ 76 33 26 E 853~7~ S 76 A2 9 E 904~V9 S 76 53 ~9 E 956~22 S 77 3 22 E ~007~66 S 77 12 24 E 1059.1t S 77 20 33 E Z110~8 S 77 27 53 E 1161,67 S 77 31 58 E ]212.78 S 77 28 5 E 1264,28 S 77 2~ 23 E 1316~14 S 77 25 52 E 1367,64 S 77 24 53 E 1418~38 S 77 21 5~ E 1469~89 S 77 21 5 E 1521~75 S 77 18 ~9 E 1573~24 S 77 15 46 E 1625~g2 S 77 11 22 E 1678~06 S 77 9 9 E 1729~.90 S 77 5 16 E DOG LEG SEVERITY DEG/IOOFT 2~301 2~047 3~038 1~121 0,000 0~000 0~515 0~715 0,567 0~567 1~0!5 0~50~ 0~567 0~250 0~000 0~000 0~250 0~57t 1,560 1~056 1~064. 0~574 0~715 0~715 0 ~ 574 0~250 0~913 0~58! 0~578 599~ 75 2 852, 90 1004 ] 05 12]] ]2/-2 1366 1416 1520~. ].62z; ~. 1676 RECORD OF SURVEY ALL CALCULATI,ONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE ~'~ ' DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES C LO SUR E'S DISTANCE ANGLE D M S 5200 31 0 4742,,26 4636,~ 06 S76~00E 5,300 30 45 4828~21 4722~01 S?7~OOE 5400 31 0 /+913092 4807~72 S76~00E 5500 31 15 4999~41 4893~21 $76~00E 5600 31 0 5085~13 k978~93 $77~00E 5700 31 15 5170~62 5064~42 S76~00E 5800 3! 0 '5256~34 5150~14 S76~00E 5900 31 30 5341~60 5235~40 S76~00E 6000 32 0 5426~41 5320~2l S75~00E 6100 31 0 6200 3! 15 5597~61 5491~..41 569~00E 399~01S 1736~14 E 410~51S 1785~95 E 422,97 S 1835~93 E 435~52 S 1886~26 E 447,11 S 1936~45 E 1781~40 S 77 3 23 E 1832,53 S 77 3 17 E 1884~02 $ 77 1 34 g 1935~89 $ 76 59 55 E 198.7~40 S'76 59 55 E 6300 31 30 D682~88 5576~68 STO~OOE 553~39 S' 2284,,26 E ~ 2350~33 S 76 22 53 E 6400 31 15 ~768~37 5662~17 $68~00E '572~83 S 2332~36 E' 2401~67 S 76 12 4 E 6500. 31 4 6600 32 0 5938~21 5832e01 S68~00E 6700 32 0 6023001 5916~81 S66~00E 6800 31 lfi 6!08~51 6002~3! S66~00E 6900 31 45 6193~54 6087~34 867~00E 7000 31 0 6279,26 6173~06 S65~00E 7!00 31 15 6364~75 6258~55 S65~00E 7200 3! 0 6450~47 6344~27 S64~00E 7300 31 0 6536~18 6429~98 S60~OOE 7400 30 4[) 6622~!2 65!5~92 S61~OOE 7500 30 0 6708~73 6602~55 S63~00E 7600 30 SO 6794~89 6688~69 562~00~ 7700 32 0 6879~69 6773~z:9 S6!~OOF 7800 3~ 0 6962 ~6C! 6556o40 S59~00[- 7900 34 30 7045~0], 6938~8! S55,00E SO00 32 !5 7!29~58 7023~38 563~00E 612~39 S 2430,28 E 633~94 S 2478~69 E 655~04 S 2526,08 E 675~60 S 2574~52 E 697~7 S 2621~20 E '119~30 S 2668~21 E 741~87 S 2714-~5! E 767~63 S 2759~11 E '192~41 S 2803,83 E 815,11 S 2848~'38 E 838~94 S 2893~!9 E 86/:.~,63 S 2939:54 E 893~,43 S 2987,,z:7 E 925,,92 S 3033~87 E 950,,!5 S 3081~4! E DOG LEG c~C'RITY S~v ~i DEG/IOOFT , 0,574 0,571 0,571 0~250 0 ~574 0 ~ 574 0,250 0~500 0~26 3o289 0~250 n 57 ].~071 0~500 0~250 1,060 0,750 0~723 1~283 0~250 0~574 2~060 0~571 1~259 0~710 1~587 2~27"! 2~.306 L:~939 P ~ · ; 1780 1882~ [ 1934 ~, 2037 2089 ~. 214! ~:; 219~':.~ 22. 45 2297~ 24. 53 2505 25 58 2609 27] 2, 2763 28 2865 2913~ 2962~ ' 3011 31t7~? 3!70~ .... ~.','..~ 2, !! ~.: c 6' (". !') 0 '~ %,% ';~ r,. C? :'~ (3 3 4. ,.~_ 102C~:..'.' 35 ].% I ~'' '~ C' :3' ':~ ? 3 C ] ~.'.,z, .f) :3 '-'. ':} i {': (; C,' 0 i": '; (~ '"5 I ~.~,').3' .r.'! 3 "~. 0 ¥"'? L,I [ V i::.; i~ t f C P. L 7 '1 i 6 ~ 2 T7 o (., ~. 65 796! ~ {?, l 3 C~ :'q z.... r'_.. ,t [ 5: ,. ~' 7 630i · 8'I 2 z~, 22 B 97 L. ) '1 92:)q · i1 c:: rt t 7 s 'i 1. 9 } ~ ~ :' ' ..... ":' :: 7 d, 90 ~ 4. 5 -S 57 ,- O C; Z 1 (: 79 ~, "<~ '7 5 3,," t:"' ,q,., 7772,~'.x. c,:~,. O"E 10S5 4.1': ':: ' ........ , ,. ,. 3550 7 Lt "., ~q ~ '1 ,.~:; ::, q ........... ,: C'.~' C ! 095 ~- 2 ,'"~ ,'c ~.; {i' ~ 1 ,: {; 5 ~:' 3774 ~, 2 ,t " 7 ) 7 55 [' 2 ~. ':~... C'., (.~ [:.'4 (,5 ~ z. q ~" n,'~ 391 ~'~ .~ v ~,~534.i6 ST:~.:)U~Z i1:;4.93 ,.,~' z, OR3.r,i E z~1{;7..29 c 73 27 h6 [' I.) '~5 $701,41 Sl'fi.~',(;L 1220,50 S 4115C,;-i'0 ~ q3'6.'7(, S 73 3~ i3 t! i.71~ $7~_:.3,33 S77.00[' 1.231..t,:1 ,.,': 4186,,00 - -~ _., , L- q'~".pl ~t)? S~C~r:OLi 1'~F?~2''. ~. L;.SGS~z'4 ~ ~:3<. ' ~- ...... ..........,_ .., ~ 4 6 .r'. i · 4 74 ~:'. 75 ?.. 5 ¥: ..q 7 'l ~ ,3 'L'"..1 29 ') · 75' .,c ,:., 55 .':' , ,." ;.' F 6 't ' -,-' ~ ..~ 5 S 7 z'~ ~'" ~, I L -~'. ~ i 5 .i ~ 33,? '-- / q-/c C<'~ I .... ' " 33 :-.. :, ,~ 34-9'3 ~ . 5:3 :"'d' 9 ,, ' 3 ?i'.,., ~:-.:- 3 '7 '7 2 ,:. b,t52 b ~. '-..' 38. 79 ,:.. 35'32 ,, L. x' 3.~ ~ ,, 425b~: 4505," RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M 5LECTRON);C COMPUTER TRUE EASo DRIFT VERTICAL EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEGo TOTAL COORDINATES !000 38 0 9596~Z~6 9~90¢26 582o00E 1331,79 S ~733~72 E 1100 36 45 9676~59 9570~39 $85~00E 1337.00 S 4793032 E .1200 36 0 9757~z:-9" 965!~29 SS~OOE 13z~3o15 S z~851.~78 E .1300 36 0 9838~39 9732019 583~00E 1350~31 S z~910~12 E L!Z>15 ~5 45 9931~72 9825~52 S82,00E ' 1359~65 S 4976~65 E L1510 35 30 10009~06 9902~86 SS~OOE 1368~29 S 5031~1z~ ~ 50T'TOM HOLE CLOSURE 5213~88 FEET Al' S 74 ~7 7 E CLOSURES DISTANCE ANGLE D M S ~917,q9 S 7q. 17 11' E ~976~29 S 7~ 2~'52 E 503~:.~26.S 7~ 31 33 E 5092~41S 7~. $7 24 E 5159~05 S 7~ z~3 9 E 5213088 S 7~ 47 7 E 'DOG LEG SEVERITY DEGIiO©FT 1~8~7 2~209 0~956 ,.0~588 0~55~ 0~667 SECT Li o; · ! N T E R P 0 L A T E D 'il' f'~, U E V E R T I C A L D E P t' I-,t S ,~;, CO0 R D 1 N A T E S A N D C L 0o ~-' U r,i E o ¢ 'F 0 R G l, V El'4' D E P '¥' H S TRI,JE MEASURED VERTICAL TOTAL COORDiNA'i'ES C L, 0 $ U R E DEPTH DEPTH DISTANCE ANGLE D M' 5 SUB SEA F 8245 7335 ~ 18 G 9787 8'529 O-~l 10120 8905~66 BASE 10148 8928 ~24 G'"~'2 10170 8945 ~ 98 BASE 10200 8970 ~17 O~-'~3 10260 9017~77 BASE 10290 9041~57 O''''/'~.-, 1 OB04 9052 ~ 62 BASE ~0350 9088~36 O ~, .; · 1045.4 9168 ~ 74 BASE 10520 9219~48 H,,:, 0 1064-2 9~14 ~.09 BASE 10560 9328~27 BASE 10750 9399 H"'2 10760 9407 ¢,23 BASE 10850 9478 ~26 H--3 10867 9491 ~66 BASE 10940 9549 ~ 18 H-.'4 109 ~:~4 9560 ~ 21 BASE lllZ;O 9708~95 }'l 5 11149 9716~23 BASE 11305 9842 ~45 ~'~'L 11310 9846 ~ 51 WF 1 l~Tg~- 9896 TD 11510 10009~06 1003~56 $ 3203~36 E . , 1193~34 S 4016~71 E 1236~06 S 1239~79 S 1242~72 S 1246~71 S 1253~67 S 1257~!6 .S 1258~76 S 1263~79 S 1274~05 S 4197~61 E 4213~75 E 4226~42 E 4243~71 E 4279~, 56 E 4297~49 E 4305~94 E 4334~,45 ~ 4399 ~ 63 E 1279~71 $ 4441e45 E 129i~76 5 4517~42 E 1317~35 S 1319~34 S 1326~65 S 1327~85 S 1339~46 S 1340~0! 1350~72 S ],351~12 S 1356~33 $ 1368~29 S 45Z:2~53 E 4652~80 E z:-69'/o14 E 4705=67 E 4816e70 E 4821~96 E 4913~0! E 4~15~90 E 49~2~93 E 503t~14 E T R U E MEASLI[~[(D VER'i'[ (fAt, SUB MD'.,,TVD VER'[' ! CAL DE'P TH DETP YH SEA DIFf:ERENCE CORP, EC T I C)N COORD ~NATES 206 206~ lOOe 0 0 BO6 B06~, 200. 0 0 406 406~ 300,~ 0 0 506 506~ 400~, 0 0 606 606~ 500~ 0 0 706 706, 600~ 0 0 806 806~ 7000 0 0 906 906~ 800~ 0 0 ~006 ~006~ 900~ 0 0 1~06 1106~ 1000o 0 0 ~206 1206~ 1100~ 0 0 1307 1306 ~ ~ 200~, 0 0 1408 ]406~ 1300~ 2 2 1509 1506~ ~t:.O0 ~ 3 1 t6!2 1606~ 1500c, 5 2 1715 1706~ 1600e 8 3 18!9 1806t, 1700c 13 1925 1906~- 1800~, 18 5 2032 2006~ 1900~ 26 8 2141 2106~ 200Or, 35 9 2251 2206~ 2t00~: 44 9 2362 2306t 2200~ D6 12 2476 2406c. 2300c. 70 14 2593 2506~ 2400~ 87 17 27~0 26060 2500~ 103 2826 2706~ 2600~ 120 17 2943 2806~ 2700c 136 16 3059 2906c 2800~ 153 17 3175 3006c 2900~ ]69 16 ?; 29 ~. 3]O(,e 3000c ) 85 16 3 z:,O'i' '4206 q~ 00~: .. c 203 16 352z: 330C,~ 3200c 2]7 16 3640 3A. 06~ 3300~ 234 ],7 ...... :: 00 25 ~ ]. 7 0~00 0~:00 OcO0 0~00 0000 0000 0~00 0~.00 0~00 0 ~04 0~4~ 4~74 12,01 18~29 25 ~ 40 34-~ 71 44c, 30 69~!3 81~38 91~93 ]02e60 27 ~ 49 39 ~ 75 o.,c. 30 175~,23 185~,89 2~7~.78 228~ 23, 3 8 c 5 :; AND OTHEFa DATA FOR EVERY I~iVE'N 100 FEE'.T OF SUB SEA TRUE MEASURE[) VERTICAL SUB MD'~:'TVD VERT!CAL DEPTH DEP't'H SEA , DIFFERENCE CORRECT ~C)N '['OTAL COORDINATES 3990 4106 4223 4340 4456 4573 4690 '4806 4924 5041 5158 D274 5391 5508 5625 5?42 5858 5976 6093 6210 6327 6444 6562 6680 679'/ 6915 7032 7148 7~69 738i 749? 7 ~t' 32 't 972 3706~ 3600~ 284 17 3806. 3700~ 300 16 3906~ 3800~ 317 17 ~-006~ 3900~ 334 17 41066 40000 350 16 42060 4100o 367 1Y 4306o 4200~ 383 16 4406~ 4300~ 400 1,7 4506~ 4400~ 418 18 4606~ 4500~ '435 17 4706~ 4600~ 4.52 ~ 17 4806~ 4700c, Z:68 16 4906~ 48006 485 17 5006~ 49006 502 ].7 5!06~ 5000~ 5].8 ].6 5206~ 5100~ 535 17 5306~ 5200~ 552 17 5406~ 5300~ 570 18 55060 5400~ 587 17 5606~ 55000 604 17 5706~ 5600~ 621 17 5806~ 5700~ 638 17 5906~ 5800~ 656 18 6006~ 5900c 674 6106~ 6000~ 691 17 6206~ 6100~ 709 18 6306~ 6200~ 725 16 6406~ 6300c 742 6506~ 6z:.O0~ 759 ].7 6C, 06~ 6500~ ?75 16 6706~ 66C)0~, 791 16 68060 6'/00~ 807 1.6 6906~ 6800~, 826 1.9 7006~ (,900~ 847 21 7105c 7(100~ 866 19 2g~9 ~ 79 S 263~83 S 276,75 S 291e03 S 304~ 90 S 318~70 S 333~1! S 363t, 51 S 378~64 S B93~77 S 407~57 S 421e85 S 436~44 S 450~20 S 464~ 83 S 479~ 5i 495o21 S 515~65 S 537~32 S 558~69 $ 581~59 S 604~ 90 S 629 ~ 67 S 65z;. ~ z: 7 S' 678: 82 S 704~ 28 S 730~21 S 758~62 S '/87082 S 8 !z;-~ 4.9 $ 842~37 873 ~. SA- S 9)..0o 62 94.. 3 ~. 45 1129~20 E 1187~09 E 1245~88 E 1304~65 E 1362 ~ 52 E 1420~54 E 1479t:34 E 1537~78 E 1597~48 E 1656:~65 E 1.7!5~1'1"E 1773~19 1831 ~z;-2 g 1890~23 19z,:.8 ~ 85 E 2007~52 2066~40 E 2126~44 E 2183~40 E 2240~ ]0 E 2297 ~ 37 E 2354~06 E 2411~73 E 2469~ 09 E 2524~80 2581 ~4'] E 2636,~ 0]~ E 2690 ~ 60 27z',3 ~ 5 ! E 2795 ~: 54 E 28z+7 ~.: 0 ~ E 2899'~ 37 E 295/' -,. o 86 E 30!2,. 02 E AND Oi,-'~ER DATA "~' '~"'t""' .... ~'~ 7RUE tqEASURED VEP, T 1CAL SUB Iq D~':,'~I~ VD VERTICAL DEPTH DEPIH SEA DIFFERENCE CORRECTION 8091 7206~. 7100~ 885 19 8210 7306~. 72000 904, 19 8330 7406~ 7300~ 924 20 8449 '7506~ 7400~ 94.3 19 8569 7606~ 7500~ 963 20 8690 7706~ 7600~ 984 21 8812 7806~ 7700~ 100~'., 2 8933 7906e 7800c~ 1027 22 9053 8006~ 7900~ 1047 20 9171 8106~ 8000~ 1065 18 9289 8206~ 81000 1083 94.06 8306~ 8200~, 1.!00 17 9523 8406~ 8300~ 1117 17 9641 8506~ 8400~ 1134 17 975~ 8606~ 8500~ 1153 19 9879 8706~ 8600~ 1)~72 19 9998 8806~, 8700~ 1192 20 'O 10121 8906~ 88~0~, 1214 22 10245 9006~ 8900~ !239 25 10373 9106~ 9000~ 1267 28 10503 9206: 9100~ 1297 30 10632 9306~ 9200~ 1326 29 '10759 9406~ 9300~ ~,352 26 10885 9506:, 9400~, 1379 27 11012 9606~ 9~:.~,00 ~ 1406 27 11137 9706c 9600~ 1430 24 11260 9806:, 9700~, ].454 24 11384 9906~. 9800~, ].4-77 23 I'OI'AL CC)ORDINATES 971054 $ 3125~28 997006 S ~!85~50 E 10!9~16 S 3247~06 E 1040~47 S 3308 1059~47 $ 3372,~31 E 1075~36 S' 3438~50 E 1080~25 S 3506~97 1088~6? S 3574080 E 1100~,68 S 3640~04 E 1113~,43 S 3702~2! E · 1130~28 S 3761~66 E 11z;.5~17 S 3820~76 E 1158~58 S 3879~78 E 13,'15:07 S 3940~05 E 1189~94-$ 4001~99 1206~,00 S 4064~9! E ],220~3] S 4.129~29 E 1236~15 S 4198~00 1251~98 S 4270 ~, 84. 1266~,29 5 4348~67 E 1278~36 S 4430~z:,9 E 1290~ 37 S 4511~42 1306~,65 S 4-587 ~ 4-9 ]32!~51 S 4663~95 E i332~z:2 1339~25 l~Z:-7~,z~6 S 4. E;S&~90 E 1357~,!0 S 4958~z',,5 E D E P TH 1000 2000 3000 4000 5000 6000 70O0 8000 9000 .10000 11000 VER'F ~ CAL e-iF:-' D E P T H $ f./A i'OTAL COORD t 0~00 S OcO0 ¥~ 5!~,92 S 169e36 E 157e55 5 63!o21 E 250~78 S 1134. o28 E 373~12 S 1636~05 E Zi-98~47 S 2138~64, E 697~37 S 262l~20 E 950015 S 3081~4. Z E 1095,~20 S 361!~85 E 1220~,50 S 4130~20 E 1331~79 S 4733~.'12 E \ 4000 ~, \ 4400 4800 '~ 6200 k \ 5~00 i ~OOOX 6400 i~ARATHON OiL CO. DOLLY VARD~N D-~ GYSOSOOPIC SURVEY ~.~.'~'~' DEPTHS SHOWN ~ ARE. TVD. ~ TVD = ;O00g' ARE TVD i ]'VD = ..... 0 0 0 ~ O0 C) 0 2 O0 0 0 300 0 0 4 r..; 0 0 0 5 ,C (.) 0 0 6 O0 0 0 7O0 0 0 $, 00 v,"" 0 900 0 0 :t. 000 0 0 ], ). 00 0 0 i200 0 39 1 3 00 5 0 u:,., S." 15 ]. 5 C'O 9 45 !609 i2 0 !700 },3 45 ] 300 ? :,. O 17(,':?, :i !: FO 2"{'""!J ;:'" '~ ' 2:i!C,:) ~ ,'. 2':;'2'0 ' !, 2:;i'~':' ,. '/ At.t G ~;; 9'>, 8 N ,.. .... ~. 0 0 ]. 93 ,, 2" " 0 593 ,, Ggs ~, o(., 793 ~ C'. ~., 0 ~ OOE 893 ~ 1.073~79 3292~77 1 .$ 9 ). ~. '/" S ? 5 ,' 00 r.: q' ~1:-; 9(:. , ~;,: t,::. . '.' '1 / ( ' r ,' 5 2 E 37 E 9 E 5 S E 7 E 2:~ [' ] '~ [.: D :: P I' H ~ E A 2500 2 7 0 ...... 0 0 ?;,,.:,,: r. (~. 3 Y 0 C' 3900 -. 6 ~ 0 O L, ~ ", "' .,,~ Z; 5 9 0 /. o :-, '0 Z %, O :S 5 2 ':~ DR Z F T D ': R E C C t 0 5 t,.~ [::: E ,5, D :,':,..::: i'/', N C' [: A N O ,', E 1:., U,.:. VFJi:~ i' I ~.. >-', L 5ttr:; D E P T :i 5 FJ A D J. ["i E C 't0 T A L C () 0 F: P, 'f, :,,, T - - ~.~ ,,> ...... 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L> F; L, .- 3, 7 :' 3 186" ~'~., ~ 1, 977 20 36 2095 21 r: ,. 22!1~,11 226° 23S2o35 2440 2496 2552 ~' r'~ . ::~ .,, 2 r. x 2 7 'j $,- 2 ? 2 2:'-~ 8200 7306~ & 3 ,? 9 '~ ~-, ~ 86'7¢ 880]. '/SOS 9 2 8 0 8 c, D L,, 963! 8Do6 974. o 8606 9868 8706 ~., 9988 8806~ 0109 8906~ 02~2 9006~ 0358 9t06~ 04,87 9206 06! 't 9306 074.5 9606 0872 9505~ 0998 t ~2z:, 9706 t.:;4© 9805 ,,, ? ! O 0 £;'; !ii 7200 89" '1''r,.' yl .... '/-:::-00 ? d, () '-' "";' 7 '/00 q' q" [;000 '205 ~'' 820 C, ] 090 830",, ] } 07 8 S 0 0 ! ) 2 5 8500 ] 163 8600 ~ ! fi 2 8 'l 0 0 8800 1,202 8900 ~226 9000 1252 9100 9200 1,3!! 9300 ]. 9500 1 97 C) 0 1. c': c? n 0 ALL DZPY;-;5 SHOWi~., .i A~qE TVD iSARA'~"XON OiS CO. SCAL~ l"a~O00~ iRADIO$ OF' CURVATURE ~a~THOD GYROSCOPIC SURVEY DOLLY VARDEN D-~5 REDR~LL 4/-400 \ \, 6000 % \ 6400 % ',, \ 7ZOO ~ tALL DEPTHS SHOWN i ARE TVD TVC .= !0019' ~o~ so. ~-~ STATE OF ALASKA swart n~ ~t~L~Ca'm OIL AND GAS CONSERVATION COAAAAll-[EE 50-133-20247-01 AND WORKOVER OPERATIONS APL 18729 ........ 2. iXTAI~E OF' OPKP~TdR ...... 8. L.~ZT,~.~RlVl OR L~.^SE Un. ion 0ii Company of California-;, Trading Bay Unit -~. AD~'RESS O~ OPgP~ATOR ............... 9 P 0 Box 6247, Anchorage AK 99502 D-25RD 4. LOCATION OF W~T~ .... ' ' 10. FIEI,E) AND POOL. OR XVILDCA~ Surface: 1210'FWL, 751'FSL, Sec. 6-8N-13W-SM McArthur River TD: Sec. 8-8N- 13W-SM ~i sec., T., R., z~.. (~o~ro~ .o~ :.x.l. Sec. 8, TSN, R13W, ~. - i,,, 1,1 ;',.'"'i ~2. ~ No. - , '- ,, , 78-87 13. REPORT TOTAL DEPTH AT END. -QF:,MONTH, CHA~NGES IN HOLE SIZE, CASING AND CE~iENTING JOBS INCLUDING DEPTH SET AI~D VOLLTME~, .USE]~ :~P,~O1;G~TIoNS, ~TS ~ ~SULTS. FISHING JO~. J~K ~ HO~ ~D SIDE-~CKED HOLE ~ND ~Y o~R SIGNIFIC~T ~~ ~ HO~ CO~ITIONS. NOVEMBER REPORT OF DRILLING 0PERATkONS 11-30-78 ll,350~TD ll,243'PBTD Accepted rig #76 at 1200 hrs~ 11.,-.29-78. Skidded rig over Well D-25. RU kill lines & lub. Opened circ slv@ 10,448' Started circ mud to kill well. 'M~ ' ' hon 0~1 Company - Sub-Operator ~n~/s trot t~, ~o.r,~j~,~ t~u~ ~ ~o~-,~-~ .... DIST. DRILLING SUPT.~a~.~ 1/17/79 --Report on thi~ farm is required for each calendar mOnth~ regardless of [he status of and in operations, mu~t filed duplicate tile oil and gao cOnilrvot(on committee by t~e I§m ot t~e ~ucc~ding mont~, unle~ ot~mrwi~m ~irecte~. Form 1~o. P---4 R]~. $- 1-70 STATE O'. ALASKA s~rr m mmL,ZCA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS ~pI NUiViERiCAL CODE 50~ 133-20247-01 6 L,F, ASE DESIGI~IATION AND SERIAL NO. ADL 18729 1, ? IF INDIA~', ALOTTEE OR TRIBE NAME OIL Wl;L~ WW'L~ OTHER ---- 2. NA/~E OF OPIgl%ATOR Union Oil Company of California* P. O. BOx 6247, Anchorage AK 99502)~:.~!. .' '~ 4. LOCATION OF WELL Surface: 1210'FWL, 751'FSL, Sec. TD: Sec. 8-8N-13W-SM .... 8. L.~IT F.~%M OR LEASE NAME Tradin9 Bay Unit g WELL NO D-.-25RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field II. SEC., T., R., M, (BOTTOM HOI,-E OB.mCTrVF.) Sec. 8, T8N, R13W, SM IZ Pgl~MIT NO. ,., 78--87, I~E~ORT TOTAL D~TH AT END OF MON~4, CHA2'qGES iN HOLE SIZE, CASING AND C~VlENTING JOBS INCLUDING DEPTH SET A/~q) VOLI/1VIES USED, PERFORATIONS. T'~STS AND RESULTS. FISHING JOB~. JLrNK LN HOLE AND SIDE-TRACKED HOLE AND A_NY OTI4ER SIGNIFICANT CHA~G~ IN HOL~ CONDITIONS. 12-01 11 , 350' TD 11,243' PBTD Circ 9.6#/gal mud & killed well. Instld BPV in tbg. ND Xmas tree. NU BOPE. 12-02 11,350'TD 11,243' PBTD Fin NU BOPE. Tstd BOPE. POH w/ 4½" SL tbg & Otis RH pkr. Chgd rams in BOP & suction vlvs in mud pumps, lnstld wear bushing. PU 8½" bit & started in hole PU 5" DP. 12-03 11,350'TD 11,243' PBTD Fin RIH w/ 8½II bit. Tagged fill @ 11,142' CO fill over Bench 6, Hemlock Zn to PBTD @ 11,243". Circ out gas & oil cut mud on choke. C&C mud. Started POH. 12-04 ll,350'TD 10,568' PBTD POH. RIH w/ OEDP to 11,215'. RU Halliburton & laid 90..~sk cmt plug (Cl G) w/ .1% HR-6L from 11,215' ~ 10,925' & 125, sk Cl G cmt plug w/ .1% HR-6L from 10,918' - 10,568' (all benches of Hemlock isolated). POH. PU csg scraper & started in hole. 12-05 ll,350'TD lO,568'PBTD RIH to 5549'. Bit plugged w/ cmt scale while filling DP. POH. Attempted to CO cmt scale. RIH w/ csg scraper. LD 36 jts DP (cmt scale inside). RIH to 9309' w/ csg scraper. Now circ @ 9309' 12-06 11,350'TD 10,568' PBTD Circ & pumped slug. POH w/ csg scraper. Set Halliburton BP @ 9000'. Perfd2 HPF from 8210' - 8212'. Set Halliburton EZ-Drill cmt rtnr @ 8190'. RIH w/ Halliburton cmt rtnr seal assy for sqz. 12-07 ll,350'TD RIH & tagged rtnr @ 8190I. Tstd lines to 5000 psi. PI fm w/ 2800 psi. 9,000'PBTD Mixed 150 sx C1 G cmt. Sqzd perfs (8210'-8212') to max press 4400 psi. Final sqz press 3600 psi. Rev out 11 bbls good cmt. Pumped dwn wiper /7 plug. POH. Perfd 8170'..:8172~ w/ 2 HPF. Now RIH W/ HOWCO cmt rtnr. sm~~~ fO. ( ~/~/~T~ DIST~DKILLING SUPT.DA~. 1/17/79 /N~E--~eport on this form ts required for each calender ~nth~ regardless of lhe Itotus of operations, and must ~ flied in duplicate with th · * Marathon Oil Company - Sub-Operator December Report of Drilling Operations TBU Well D-25RD Page 2 12-08 ll,350'TD 9,000'PBTD 12-O9 11,350'TD 9,000'PBTD 12-10 ll,350'TD 9,000'PBTD 12-11 ll,350'TD 9,000'PBTD 12-12 ll,350'TD 9,000'PBTD 12-13 ll,350'TD 9~O00'PBTD 12-14 ll,350'TD 9,000'PBTD 12-15 lI~350'TD 8,100'PBTD 12-16 u°, 165' P~3TD 12-17 8~ 165'PBTD 12-18 8,235'TD Fin in hole w/ cmt rtnr. Set rtnr @ 8140'. Tstd line to 5000 psi. Estab break dwn rate of 2 BPM @ 3650 psi. Sqzd perfs 8170'-8172' w/ 100 sx C1 G cmt. Sqzd 85 sx & rev out 15 sx. Max & final press 3100 psi. Rev out & POH. Tstd BOP's. RIH w/ drlg assy. Now drlg on top cmt rtnr. Fin drlg cmt rtnr @ 8140'. Drld cmt & junk to 8190'. Drld rtnr @ '8190'. CO to 8600'. C&C mud & POH. RIH w/ milling tools. Milled 995/8'' csg from 8155' ~ 8157'. Milled 9-5/8'~ csg from 8157' - 8158'. C&C mud to incr visc. Milled 9-5/8" csg from 9158' - 8177'. Cleaned hole. POH & dressed mill. RIH. Filled pipe & found mill plugged, POH. Broke dwn mill looking for obstruction. Found cuttings to be plugging tattle-tail of section mill. RIH w/ section mill //2. Milled from 8177' - 8179' in 3 hrs. POH. Blades of mill smooth. RIH w/ section mill //4. Milled from 8179' - 8181' in 8 hrs. Started out of hole, POH w/ mill //3. Had drag all the way out of hole. Rec 6' section of 9-5/8" csg w/ 50-75% of curvature in tact for entire length. Pulled wear bushing. Rec 2' section of 9-5/8'~ csg. RIH w/ mill //4. Reamed from 8155'-8181'. Milled 9-.5/8" csg 8181'-8186'. Started out of hole. Fin POH w/ mill //4. RIH w/ mill #5. Mi lied from 8186' ,' 8197' in 11 hrs. POH. RIH w/ mill //6. Fin RIH w/ mi 11 //6. C&C mud 2 hrs. Milled 9-5/8" csg from 8197' - 8210'. Strapped out of hole & LD Servco milling tools. RIH w/ OEDP to set cmt plug to start directional drlg ops. Section in 9~5/8" csg from 8155' - 8210' (55'). C&C mud to lower visc. RU Halliburton. Mixed 70 sx C1 G cmt w/ 1% CFR-2 & laid plug from 8100'-8250'. POH. Tstd BOPE & related eqpmt. Cleaned sd trap. WO mud pumps, RIH w/ 8½~ bit. RIH to 8019'. V;OC. Tagged cmt plug @ 8137'. Drld soft cmt to 8147'. ~/OC 5 additional hrs. Drld frm cmt to 8165'. POH. RIH w/ 8½I: diamond bit & DD to 8163'. RU WL & steering tool. Steering tool failed to operate. POH w/ steering tool. Ran 2nd steering tool. Could not get steering tool to seat in bent sub. POH w/ WL eqpmt. POH w/ wet string. Found obstruction in btm steel DC. RIH w/ DD to 8163'. RU DA & steering tool. Could not break circ w/ 2500 psi. RIH w/ WL. WL tools would not pass 7815'. POH w/ wet string. Btm Monel DC & DD plugged w/ cmt scale. LD 1st DD. RIH w/ 2nd DD to 8165' RU WL & steering tool. RIH & oriented tools. DD for KO from 81~5'~ - 8235'. POH w/ steering tool. RU to run SS surv, December Report of Drilling Operations TBU ~el 1 D-25RD Page 3 12-19 8,336'TD 12-20 8,534'TD 12-21 8,710'TD 12-22 8,773'TD 12-23 8,985'TD 12-24 9~420'TD 12-25 9,620'TD 12-26 9,800'TD 12-27 9,964'TD 12-28 lO,097'TD 12-29 10,222'TD 12-30 10,442'TD 12-31 lO,650'TD Ran SS surv. POH w/ DD. RIH w/ angle bldg assy. CBU. Ran SS survs. Hole angle reading 33½° but direction reading erratic due to metal interference. POH. RIH w/ 'llocked in" BHA. Drld 8235' - 8336'. Worked by junk. POH. RIH w/ short tooth bit. Ran on junk & drld 94' Circ & surv @ 8390'. POH to chg BHA & bit. RIH & drld 8430' - 853~'. Drld 8430' - 8710'. POH. Repaired kelly spinner & slipped drlg line. PU DD & R!H. RU steering tool & RIH. Drld w/ DD 8710' - 8773'. POH w/ steering tool. Started out of hole w/ DD. POH w/ DD. RIH w/ bit #9. Drld 8777' - 8934' POH. Tstd BOPE & related eqpmt. RIH w/ bit #10. Drld 8934" - ~985'. Drld 8985' - 9339'. POH. RIH w/ bit #11. Reamed from 90611 - 9339'. Drld 9339' ~ 9420'. Drld 9420' - 9516'-. POH. Chgd rotary chain. Cut & slipped drlg li~ne. RIH w/ bit #12~ Drld 9516'~ - 9620~''. Drld 9620' ~ 9750'. POH. RIH w/ bit #13. Drld 9750' - 9800I· Drld 9800' - 9964t. POH. R!H w/ bit #14. Pipe began filling on its own. (Float ilnstld above bit.) Stuck pipe momentarily 100' off btm due to under-gauge hole. Pulled free. Circ w/ 1500 psi pump press. Started out of hole to check for washout. Found hole in jt of Gr E DP immediately above HWDP while POH. RIH to 9587' w/ bit //14. Reamed 12 jts to btm. Made 5 std short trip. Drld from 9964' - 10,035'.. Made connection & drld 1' when pipe became stuck. Could circ but could not rotate pipe. Lowered mud wt while jarring. Pipe came free w/ 350,000// pull. Lowered mud wt to 9.4//. Drld from 10,035' - 10,097'. Surv, Drld 10,097' - 10,128'. POH. RIH w/ bit #15. Reamed 90' to btm. Drld 10,128' - 10,222'~. Surv, POH. RIH w/ bi't //16. Drld 10,222' - 10~442'. Drld 10~442' - 10~650'. P0H to 9~5/8'' csg shoe. Slipped drlg line. POH. Conservation November 15, 1978 Trading Bay Unit D-25PD Union Oil Company Permit No. 7g-87 ~4r. Robert T. Anderson Union Oil-Company P. ©. Box 6247 Anchorage, Alaska 99502 Dear c~r. Enclosed is the approved application for permit to drill the above referenced well at a location in Section 8, Township 8~{, Pange Dr, q, S.~f. Well samples, core chips, and a mud tog are not required. A directional survey is required. }~any rivers in Alaska and their drainage syste~ms have been classified as important for the spawning or migration of anadror~ous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promul- gated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Y-~abitat Coordinator's office, Department of Fish and Game° Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the reguhtions promulgated thereunder (Title 18, Alaska Adn~inistrative Code, Chapter 70) and by the Federal l~iater Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Con- servation. Pursuant to AS 38.40, L~cal Hire Under gtate Leases, the Alaska Depart ~ent of Labor is being notified of the issuance of this permit to qrill. To aid us in scheduling field work, we would appreciate your notif~Sng this office within 48 hours after the well is spudded. We would also ~&'. Robert T. Anderson -2- ??ovember 15, 1978 TBUS D-ZSRD like to be notified so that a representative of the Division may be present to ~Atness testing of blowout preventer equipment before surface casing shore is drilled. In the event of suspension or abandonment, please five this office adequate advance notification ~o that we may have a Mtness present. Very truly yours, / / ~:~arry V¢'. Kugler Executive Secretary Alaska Oil & Cas Conservation Committee Enclosure cc: Department. of m~l~'-~ ..... & Came, Habitat Section w/o encl. Department of En~qronmental Conservation w/o encl. Department of Labor, Supervisor, Labor I,aw Compliance Division w/o encl. Union Oil and Gas l-~dsion: Western Region Union Oil Company oT California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex: 90-25188 union Robert T. Anderson District Land Manager November 8, 1978 State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska TBUS D-25 Rd. ADL-18729 McArthur River Field Gentlemen: Enclosed for your approval are three (3) copies of the Permit to Drill Trading Bay Unit State D-25 Redrill. Also enclosed is our check no. 18873 in the amount of $100.00 to cover the filing fees of this permit. Very truly yours, Robert T. Anderson sk Enclosure STATE OF ALASKA OIL AND GAS CONSERVATION .COMMITTEE' PERMIT TO DRILL OR DEEPEN DEEPEN [-] SURMIT IN TlR ~A'I'~ (Other snst~urtio,,~ o~ revers~ ~lde) '" ': a; API 50-133-20247-01 l&. TYPI~ Or' WOI~K REDRILL ~7. TTP£ Or W~LL ~LL NAME OF ltnion 0il Company of California* Post Office Box 6267, Anchorage AK 99502 4 LOCATION' O V,'EL' A:,~r,a~e ~eg h-l, Cond 8, 1210'FWL, 751'FSL, Sec 6-8N-13W-SM Hemlock Top: 925'FWL, 550'FNL, Sec 8-8N-13W-SM At p:'oI>osed prod. zone ID: 1300'FWL 625'FNL 'Sec 8-8N-13W+SM 13. DISTANCE iN .MILES A~D DIRECTION FRO.%! NEAREST TOWN OR POST OFFICE' 21 Miles Northwest of Kenai, Alaska 18. 'NO. OF ACRES IN LEASE 3085 14. BOND ".NFOH.:'.!ATiON. TYPZ Statewidesure::-~n~o~,~-ognited Pacific Insurance Co. #B~55fiO.2 t sAl.-'o to nearest drl'-:, unit. if an.*') list I PROPOSED DEPTH ll,517'MD 10,O10'TVD 15. DISTANCE FROM PROPOSED' LOCAT~O." TO .','E-~R~ST """"~UUU' ~o~E~.TY o~ ~_ZASE ~,~z. rt. 18. DiSD,,kNCE F~OS, i PROPOSED LOCAi'~IO.N' TO NZARESi' %VELL DRrLLING. COI~,fPLETED. OR APPLIED FOR. FT. 1300~ from D-4 21. ELEVAT:ONS ,Show whether DF, RT. CH. etc., 10~.2~ above MS[. . 2'L PROPOSED CASINO AND CEMENTING PROG[iA.f',I 6.' L~'-kSE DI/~IGNAT10'."I A.N-D 52~:;./AL NO. :: ,, A,.D g,,, :18729 I. IF I:;DiAN. A_LJ,.X3~ OR TFU. IBE NA.'dl5 ---- B UNIT FARM OR LE.'k.~E NA3tE · Trading Bay Unit D-25RD 10. F'IELD AND POOL. Ot~ WILDCAT McArthur River Field Itl. SEC., T. R.. 51. ,F~O'f'roM HOLE oBJECTIVE, Sec, ..8,.T8N, .RI. 3W, SM 12. ,~ou~, s ~q0, O00... I?. NO. ACRES ASSIGNED TO THiS %%'ELL 80 20. ROTARY OR CABLE TOOLS Rotary 11 ~20=78 SIZE OF HOLE sIZE Or CASINO ) V;SIOHT PER rOOT G~ADI~. SLelT!NO DEPTM ' ............ ............., ' ...... quon~i~¥ of cement 8½" .,7".10.r 29g N-80 7955' ,- 11,517' 55,0 sx · .... .... Plug the existing wellbore by placing-cement plugs across Benches 4 & 5 from 1'3,965'-11 200' (90 sx), Bench 3 and remainder of Bench 4 from 10,808'-10,934' (50 sx) and Benches 1 & 2 from 10,6~01-10,778' (40 sx). Sidetrack wellbore by milling· section in 9~5/8" casing from 8155' to 8235'. Lay kick-off plug from 8125' - 8300'. Drill out cement plug to 8290'. Run Dyna-drill assembly and kick off and dri113362' of 8-~" hole to a new location with the Hemlock top approximately 925'FWL, 550'FNL, Sec. 8, T8N, R13W, SM. Run and cement 7" liner. Complete the well as a Hemlock producer on gas lift. IN ABOV~E SPAC'C IDE.GC'HIBE I:rHOPO$'ED' p.~C~R.~.~,i: If p~l IS tO dee~n 'give ~ on present p~u~ive zone and pro~ ne~' pro~u~lve zone. If pro~lt 1~ ~ Grill. Or O~n d~ec%ionally, give perttnen, ~aL% On subsuMa~ ~t~ ~d meas~ and ve~;c~ dcpG'Is. Give -bi~'~u[ preventer p~gram. s,cx~~~. ~~ _.~ :_~~ / D.~ ;: Novemb~ 8 1978 ..... :-.-: k~~~~ar~. 5~ - .,/ ....... ~,, : ' - SAMPL%LS AND CORE CHIPS H~UI~ t MUD LOG~ ~ - , , ~> ,~ ~ , r D:RE~ioN.~ SUHVEY R~L~ A.P.I. ~c~ CODE Dist. Land. ~=,~=.~ __ q g ' 2 7 ~o~ ~^r~ November 15, i978 _ :,.. ~... - ~.. Exec. See~t a~ v.~ 11/15/78 ~ ' *~ I.~on, ~ R,,,~ Side OII/I$10N OF ~11 ANI) CAS / .lAY ,,,¢. llAMa;ON§, gOVERNOR 3001 PORCUPINE ORIV£ -. ANCNORAG£ ALASKA OII- AND GAS CONSERVATION October 31, 1978 A D M I N I S T RA T I VE A P P R O V A L N O. 80.25 Application of Union Oil Company of California, operator of the Trading Bay Unit, to redrill' and complete the Trading Bay Unit D-25 well as the D-25RD well as part of the pressure neintenance project approved by Conservation Order No. 80. M~. Wayne Rodges Landman Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Rodges: The referenced application which was received on October 30, 1978, stated that the drilling and completion of the Trading Bay Unit D-25RD well will result in additional ultimate recovery of Hemlock production. The Oil and Gas ConserVation Committee hereby authorizes the drilling and completion of the referenced well pursuant ~x~ Rule 5 of Conservation Order No. 80. Very truly yours, Harry. W. Kugler Executive Secretary Alaska Oil & Gas Conservation Con~ittee - MARATHON Oil._ GO.- _ DOLLY VARD£N PLATFORM -- -- Mu~' Pan / Flowli~= Drillin~ Hippl~ 'x 13 5/o"~ 5,ooo~ lkn~mcr Oo..) ct~,~ co ~,-,~--~o~- ,, ~ . (Bll'nd RamS) ' ,, ~ S ~5,000-N iii Drill-- Fl°°r . ~ ~GIW 5win~-B01t Olamp -- Diagram~ 2 -- 15~/8"x 5,00'0~ fO 61 ~ Riser g BOP gt~ck Fo~ /0 ~ ~ o,j - Drillin ' From Uhder 15z/6'~ . '. ' ~ ' nl IN_ ' Surf=ce O~sln9 ToTD.-- - [ i . . Room _ N 9_ Ft. Spool Flon~ed Outlets Valves Collar ~ 55~ Gonductor '- N~ARATHON OIL CO. -- DOLLY VARDIEN PLATFORM -- F //--~Flowline Drillin9 Hippie Drill De. ak Floor .... -- Diagram ~ i -- Sfc~rti~ Riser LLsect Before Room _') 20"Riser (20", 2,o00~ Nydril ) %. Clamp-on Hub Ia CT) K. A. TH oMA. D-9 D-14 ®? D-SRD D-14R ./ D-16 ,¢ D-25 D-2 MARA'FHON OIL COMPANY TRADING BAY UNIT E ~ ?' Gi~OUP IvIcARTHUR RIVER FIELD STRUCTURE CONTOUR MAP F ] O~ ~OQ~ -- F"/L~. 7-0 1/, I2Z / / / ~- //,o~ / / !!~ / /, ~_~ ' ? t , I~ /! lO, ?/4'-/o,9 Z4 · /~ 9~- - //, 04.0 ! / - 11, 2ao Robert T. Anderson District Land Manager Union Oil and Gas F sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 Telex: 90-25188 union October 26, 1978 State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle Hamilton TRADING BAY UNIT State of Alaska McArthur River Field Application to Redrill and Complete TBU D-25 (11-8) Gentlemen: Union Oil Company of California, as Operator of the Trading Bay Unit hereby requests approval to redrill and complete the above captioned well in the Hemlock formation on the south flank of the Main Feature, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be redrilled from the 'Dolly Varden Platform by Marathon Oil Company, Sub-operator. The redrill will result in additional ultimate recovery of Hemlock production. Very truly Y0~ V}ay~ Rodges ~ Landman Wa/sk .,' 'i GRAYLI 7 G-2 'rD IO TO D-15 Dt15 RD ,o1~ DOLLY ~O O 1 ~ ~ 4~ / ~_~ ~m~ ..... [~1h750 ~'~ ' ~' ~'~ I TD II Z78 X ~u ~4,~,~ B-28 ~ ~-~ ~TD 13 600 X '~ ~1~ ~ ~ ) 118~0 D-Il D-I ,' ~ ~ ' ~ ~,~ G-12 RDI/c '~- -lTO ,),8oo to D-27 TD 10,628969 TD ~-STD f0,250 D-13'; TO I ~,908 9,360 VD D-25 RD B.H.L 11,517 TMD I0,010 I'VD 11,237 -12 TD t2,381 · 13-8 R13 rD 12,24,7 0 20(X) FEET 18 D-14. RE TD W D-16 TD 11,341 .- TD 16,57 T 9N T8N TO 16,650 - IPROPOSED WELL LOCATION MARATHON SUB-OPERATOR TRADI NG BAY U N IT D-25 RD (11-8) ~('T Alaska District CinCH LIST HDR 1~1~'~ %?.~?~tJ PE~,'iITS C{r.E~anv Yes No Romarks 1 Is ~e ~t fee attached - ' ....................... 2. Is well to ~ located in a defied 3. Ils a regi - i ste=ee surve\? pi_at attach~ ................ 4. Is well located propar, di. mta~n~~ . frem pro~rty. _ line 5 Is we]_l ~p~ pre?er distance frem other wel]_s 6 Is sufficient und~i_cak~l acreage avai]ab!e in ~is 7 Is well to be deviated ...................... 8 Is o~lrater tine enlv affected ~rty ..... . , _ . 9. C~ ~n~it ~ approved ~fore ten-day wait ............. 10. ~oes o~rahor have a ~ond in force ................. ] t,2m Approve !]_. Is a conservation order needed .................. ]2 Is administrative aN:arow~ needed ' · · , · . · -.. 14. IS enough, oeI~en~ used to circulate on conductor and surface 1_5 Wi_Ii c~ent Cie J.n surface and Jnte~Rediate or Dr~4uction. strincs ]6. Will cenent cever all kno~q~ pr~uctive horizens .......... t7. ~,~].]_1 sv~Eace casin~ protect EresN wa~er xones ................ 18. ~.',~. ..... 1]. all casing give ade~aate safety in col ]a~as~',..._, tension & Icc. 2 .? , .. lq. D~as BOPE have sufficient pressure rating - Tesh to _r- ,"i , _ . _.a~ O O~ psig . ~. Has Db~H approved Ph~n of ~eratien Additional Re{leirs~2nts: ('3) Adndn. Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX~ No 'special'effort has been made to chronologically organize this category of information. .o VAX/VMS HOY VAX/VMS HOY VAX/VMS HOY FOR~15 22-SEP-1983 1~:4~ LVAO: 22-SEP-1983 10:40~ DISK1:[LOGGER]FOR~15.DAT;8 FOR~15 22-SEP-1983 1~:4~ LVA~: 22-SEP-1983,1~:40 DISK1:[LOGGER]FORO15.DAT;8 FORB15 22-SEP-1983 1~:4~ LVA~: 22-SEP-1983 1~:4~ DISKI:ELOGGER]FOR~IS.DAT;8 H H 000 Y Y H H 0 0 Y Y H H 0 0 YY HHHHH 0 0 Y H H 0 0 Y H H 0 0 Y H H 000 Y VAX/VMS HOY VAX/VMS HOY VAX/VMS ROY FFFFFFFFFF 000000 RRRRRRRR FFFFFFFFFF 000000 RRRRRRRR FF O0 FF O0 FF O0 FF O0 FFFFFFFF O0 FFFFFFFF O0 FF O0 FF O0 FF O0 FF O0 FF 000000 FF 000000 O0 RR RR B~ ~ O0 RR RR BP 0~ O0 RR RR ~ B~B O0 RR RR ~ ~ O0 RRRRRRRR ~ ~ ~ O0 RRRRRRRR ~ ~ ~ O0 RR RR ~ ~ O0 RR RR ~ ~ O0 RR RR ~ ~0 O0 RR RR ~ ~ RR RR ~~ RR RR ~~ VAX/VMS VAX/VMS VAX/VMS DDDDDDDD AAAAAA TTTTTTTTTT ;;;; DDDDDDDD AAAAAA TTTTTTTTTT ;;;; DD DD AA AA TT ;;;; DD DD AA AA TT ;;;; DD DD AA AA TT DD DD AA AA TT DD DD AA AA TT ;;;; DD DD AA AA TT ;;;; DD DD AAAAAAAAAA TT ;;;; DD DD AAAAAAAAAA TT ;;;; DD DD AA AA TT ;; DD DD AA AA TT ;; DDDDDDDD AA AA TT ;; DDDDDDDD AA AA TT ;; 11 5555555555 11 5555555555 1111 55 1111 55 11 555555 11 555555 11 55 11 55 11 55 11 55 11 55 55 11 55 55 111111 555555 111111 555555 888888 888888 88 88 88 88 88 88 88 88 888888 888888 88 88 88 88 88 88 88 88 888888 888888 H H 000 Y Y H H 0 0 Y Y H H 0 0 Y Y HHHHH 0 0 Y H H 0 0 Y H H 0 0 Y H H 000 Y FOR015 22-SEP-1983 1~:4~ LVAO: 22-SEP-1983 10:40 DISKl:[LOGGER]FORO15.DAT;8 FOR~15 22-SEP-1983 1~:4~ LVA~: 22-SEP-1983 10:4~ DISK1:[LOGGER]FOR~15.DAT;8 FOR~15 22-SEP-1983 1~:4~ LVA~: 22-SEP-1983 1~:4~ DISK1:[LOGGER]FOR~15.DAT;8 VAX/VMS VAX/VMS VAX/VMS REEL HEADER (REEL COUNT 1) LENGTH: 132 BYTES REEL NAME: P,C.D.C, ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: ~1 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 79/ 1/13 TAPE HEADER {TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 54555 DATE: 79/ 1/13 ORIGIN: SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: ~1 PREVIOUS TAPE NAME: COMMENTS: ********************************************************************** E 0 F * * * * * * * * * . . . . . FILE HEADER {FILE COUNT 1) LENGTH: G2 BYTES FILE NAME: EDIT .~01 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: 1~24 OPTIONAL PREVIOUS FILE NAME: WELL SITE INFORMATION LENGTH: 143 BYTES C N : W N F N : C 0 U N : STAT MARATHON OIL COMPANY TBU D-25 REDRILL MCARTHUR RIVER KENAI ALASKA D E N S : 8~. DATUM FORMAT SPECIFICATION LENGTH: 658 BYTES ENTRY BLOCKS: TYPE DESCRIPTION TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS: COUNT MNEM UNITS API API API API FILE LOG TYPE CLASS MOD, NO. 1 DEPT FT 2 SP MV 3 CILD MMHO 4 CILM MMHO 5 CLLB MMHO 6 GR GAPI 7 CALI IN 8 DRHO G/C3 9 NPHI PU 18 RHOB G/C3 11 NRAT C/C 12 NCNL CPS 13 FCNL CPS 14 GR GAPI 15 CALI IN 16 DT US/F SIZE 1 SIZE 8 8 8 8 8 4 7 1 8 8 8 4 7 11 46 8 8 4 7 11 44 8 8 4 7 21 8 8 8 4 42 31 32 8 8 4 42 28 1 8 8 4 42 44 8 8 8 4 42 68 3 8 8 4 42 35 1 8 8 4 42 42 1 8 ~ 4 42 34 92 8 8 4 42 34 93 8 8 4 68 31 32 8 8 4 68 28 3 g 8 4 68 52 32 8 8 4 DATA LISTING OF EVERY lgOTH FRAME 118.832 187.250 172.187 234.234 30.288 96.525 115.878 286.349 26.862 323.837 23.335 457.314 23.335 362.934 16.749 586.228 14.997 476.198 38.288 324.753 18.830 349.635 35.645 11534.880 -999.808 -999.800 -999.808 -999.880 -999.800 11484.800 28.758 130.617 -0.824 2.012 3.112 11434.808 24.258 194.089 8.217 2.434 2.272 11384.800 6.750 64.269 0.418 2.218 .4.288 11334.00~ 39.258 116.950 g.190 2.443 2.358 11284.800 48.5~8 31.623 0.144 2.586 1.798 11234.88~ 50.5~8 24.889 8.118 2.493 1.598 11184.8~0 58.258 24.434 8.158 2.471 1.802 11134.800 56.588 17.061 8.103 2.532 1.486 11084.08~ 56.5~0 15.704 0.185 2.588 1.504 11034.88~ 62.588 27.040 8.160 2.422 1.920 18984.800 65.808 28.512 8.155 2.537 1.794 18934.888 62.758 81.658 -999.008 -999.080 129.428 325.182 281.372 534.534 63.896 291.728 118.032 474.983 39.446 616.473 27.797 716.430 30.479 658.944 24.889 749.892 18.365 716.859 32.818 625.911 24.889 627.627 73.798 -999.888 8.180 188.988 8.488 79.800 83.788 112.688 184.888 57.488 65.580 49.288 58.180 57.280 49.380 48.180 45.688 49.680 51.380 52.888 58.688 47.880 55.280 51.488 REPR CODE ENTRY 66 8 REPR SAMPLE CODE PROCESS LEVEL -999.888 -999.808 8.188 f.808 11.250 8.161 8.258 76.388 8.950 8.891 8.588 79.558 18.888 8.845 7.658 95.158 15.85~ 8.123 9.688 81.688 9.288 8.104 8.758 62.458 8.90~ 8.033 8.388 65.680 8.988 8.045 8.258 78.68~ 8.988 8.842 8.480 64.680 9.850 8.083 8.308 64.288 8.788 8.878 8.480 66.488 8.988 8.084 8.250 67.550 9.250 8.870 1 68 8 1 68 8 1 68 0 1 68 8 1 68 8 1 68 .8' 1 68 .8' 1 68 0 1 68 0 1 68 8 1 68 ,8' 1 68 0 1 68 8 1 68 0 1 68 g' 1 68 8 g.182 18884.888 8.2,83 1,8'834.888 g. 188 18784 g.151 18734 ~. 1~6 1~684 8.154 1~634 g.539 1 g584, g,282 1~534 ,g~g ~,316 18484 ,ggg g,181 18434 .ggg g,299 1~384 ,ggg g,153 18334 ,ggg g,216 1~284 .ggg ~,13~ 18234 ,ggg g,265 18184. g,235 1~134 g,24~ g,488 1 gg 34, g.324 9984 g,383 9934 ,ggg g,247 9884 .ggg g.352 9834 ,ggg g,258 9784 g,249 9734 g 365 9684 g 587 9634 88~ g 213 9584 g 141 9534 g 519 9484 .g 228 9434 g 382 9384 ~.298 2.437 53.258 2.488 67.888 2.485 89.588 2.448 61.258 2.524 12,888 2,545 12,258 1,979 6.258 2,568 5.75~ 2.592 46.258 2,:536 12.758 2,628 15,258 2,554 48,758 2.362 38.588 2.548 28,258 2,541 57.588 2,452 53.588 2,494 8.258 2.338 2.588 2.588 23.250 2,482 82.258 2.457 34.588 2.498 48.258 2.581 42.258 2.582 38.258 2.486 38.758 2.138 53.588 2.486 68.258 2.488 38.758 2.182 2.455 41.758 2.586 47.258 2.585 2.128 42.855 2.224 83.946 2.832 44.855 1.784 28.137 1.668 81.658 2,186 59,784 3,912 2.918 187,647 3,184 71,121 1,898 115.878 3,896 87,896 2,258 65,464 2,264 23,335 1,696 83,176 2.888 69.183 2.398 187.647 2,642 164,437 3,568 181.859 3.858 229.887 3.648 188.382 2.498 88.918 3.368 182.882 2.714 178.688 2.628 78.785 3.568 67.928 4.392 48.753 2.198 29.187 1.742 73.798 4.248 78.469 2.428 86.298 2.956 184.713 2.878 562.848 45.789 525.525 86.298 586.443 39.884 645.216 38,726 676.962 78,785 581.872 68,813 385,877 184.713 416.138 113.763 368,511 63.896 548.969 129.420 384.384 92.845 516.516 58,614 535.392 32.211 672.672 93.756 488.488 74,473 494.288 81.658 483.689 188.382 262.548 185,682 377.891 239.883 287.438 135.519 528.377 88.918 296,439 188.925 394.688 162.938 394.251 82.414 335.478 69.183 253.968 58.119 533.676 29.187 665.888 89.536 242.385 82.414 516.516 87.896 342.342 98.175 353.496 277.563 34.674 252.681 65.464 291.291 26.383 355.212 28.137 429.429 131.826 262.977 38.726 62,634 87.896 135.564 185.682 128.978 45.298 268.983 118.832 124.839 38,288 285,714 48,753 236,888 17,865 488.488 64.269 148.863 61.944 285.928 69.823 162.162 177.811 71,643 88,168 114.543 265.461 86.658 81,658 285,862 78.469 96.896 99.883 148.885 173.788 148.434 64.863 98.241 46.132 56.628 52.481 248.248 26.862 372.881 67,928 56.199 71.121 281.638 71.779 115.838 118.662 122.265 54.188 58.888 57.788 44.888 48.888 41.888 42.888 42.288 47.988 51.888 53.38g 69.888 57.388 78.688 77.988 99.888 99.488 61.188 66.888 69.688 73.888 41.488 39.888 51.588 56.488 56.788 56.488 95.488 68.488 75.688 71.688 75.988 84.488 87.988 83.388 94.788 68,588 67.288 63.788 65.788 18.988 88.388 96.588 86.588 51.588 58.888 95.588 98.388 86.388 91.288 54.588 59.688 54.388 54.588 93.888 89.188 78.688 79.888 92.888 80.188 83.388 82.888 8.788 9.488 8.488 8.958 8.258 8,688 7.888 9.958 8.958 14.158 8.488 12,258 9.658 15.358 9.358 13.888 9.558 9.75~ 8,482 13,488 8.95~ 11.858 9.858 8.888 8.350 9.158 8.888 11.958 8,958 8.788 8.458 18.788 7.988 lg.788 18.358 13.258 8,258 !2.258 8.98g 9.188 8.488 11.888 9.688 18.888 9.458 18.288 9.288 14.558 9.458 13.258 9.658 8.688 8.158 8.688 8.158 12.988 9.858 18.488 9.358 9.988 8.958 11.258 9.888 76.888 g,886 74,788 ~,864 76.158 8,274 71,458 g.143 78,788 8.122 62,788 8.845 123.88~ 8.872 75.688 8.899 74.358 g.189 71.98~ 8.165 71,588 8.881 58.888 8.~62 88.688 g.876 67.958 8,117 73,558 8.884 77.458 g.126 76,188 8,169 91,388 8.142 81,658 8,161 98,588 8.878 88.658 8.119 97.088 8.184 73.358 8.184 78.758 8.897 81.958 8.161 1~5.15~ 8.888 83.258 8.866 73.188 8.186 112.288 0.085 82.658 ~.867 75.858 8.188 75.988 9334. ggg 0,316 9284 t).181 9234 M,165 9184 ,MgM M,274 9134. M.27~ 9884. M.281 9~34 ,N~ ~.651 8984 g,296 8934 g.33~ 8884 g,171 8834. g. 8784 g.235 8.624 8684 g 193 8634 ~ 271 8584 ~ 293 8534 g 434 g 243 ~ 234 8384 g 196 8334 g 373 8284 .ggg g 183 0 442 81~4 g 447 8134 -O gSg ~084 fl~34 7984 38.759, 2.546 68.259, 2.394 86. 259' 2.432 66.259, 2.494 42.759, 2,492 46.99,9, 2.49,9 46.59,9, 1 .538 42.59,9, 2,482 38. 259, 2. 479, 84,259, 2.468 87. 259, 2.466 88.8'9,9, 2.362 46,59,8' 1.558 86.259, 2,436 85.59,Z 2.349 58.9,9,9, 2.58'4 42.59,9, 2.346 78.259, 2. 339, 64.59,9, 2.391 70. 759 2.425 39.258 2.317 88.259, 2.428' 38. 258 2.826 25.50g 2,218 48. 808 48. 888 48.888 g. 888 48. 888 8. 888 48. 888 8. 888 88.716 3.179, 84.723 2.878 136.773 1.888 134.276 2.686 123.595 2.89,2 86.298 2.929, 5.256 167.494 3.9,9,6 158.489 3.148 121.339 1.926 189,.39,2 2.828 194.9,89 2.338 42.462 5.129, 122.462 29,5.116 2.582 123.595 2.719, 134.276 3.748 114.815 2.484 95.499 2.59,2 152.757 2.152 151.356 3.468 148.593 2.876 95.499 3.798 177.811 3.998 98.175 98.175 98.175 98.175 98.175 95,499 388.894 88.918 6~4.832 19,2.89,2 658.364 118.662 378.887 114.815 376.233 99,.365 361.647 37.325 283.775 167.494 364.221 164.437 318.747 95.499 599.313 145.881 576.147 154.178 59,1.59,1 57.9,16 192.192 99.883 523.388 164.437 461.175 136.773 49,7.121 128.233 273.273 19,9.648 491.634 19,8.925 478.184 122.462 565.851 135.519 314.886 121.339 595.452 189.648 259.974 199.526 251.394 8.8Z6 8.888 9,.886 8.886 9,.886 8.888 8.886 8.888 95.499 118.833 48.753 383.732 53.951 333.762 112.729, 159.159 128.233 137.288 63.9,96 118.833 11.695 39.468 131.826 129,.129, 19,1.244 53.456 897 263.486 118.662 29,6 349 12 589 36 894 72 444 259, 536 125 893 181 896 128.233 125.268 152.757 75.584 92.845 203.346 94.624 213.642 96.383 264.264 159.956 97.383 75.162 296.439 267.917 64.358 251.189 65.288 8.9,28 Z.828 g.888 9,.9,28 9,.808 8.828 8.888 8.828 8.888 19,4.98g lg9.4g8 48.89,9, 53.888 47.g8g 46.289, 72.688 84.89,9, 19,3.79,9, 76.19,9, 52.49,9, 53.388 86.789 89.19,9, 19,4.79,8 55.599 58.29,8 46.699 58.19,8 53.99,9, 44.19,9, 52.889, 42.59,9, 49.39,9, 58.19,9, 61.29,9, 79.39,9, 78.89,9, 86.89,8 53.9,9,8 55.888 55.588 47.688 41.49,9, 49.39,8 79.49,8 89.988 45.19,0 45.588 81.89,~ 90.689, 52.29,8 58.59,8 51.888 51.89,8 48.4~8 41.9,89, 9.788 8.988 8.758 8.688 8,258 9.450 8.499 19,.659, 8.358 13.988 9.788 12.759, lg.450 12.159, 9.459, 19,.158 8.658 8.759, 8.358 8.759, 8.359, 8.659 8.459, 16.859 12.459, 8.899 8.289, 7.788 9.39,8 9.958 12.858 8.3gZ 8.7g8 8.9,58 8.888 8.459, 8.988 8.859, 18.888 9.488 B.758 15.100 12.89,8 12.358 12.288 8.800 8.69,8 8.9,89, 8.688 8.688 8.688 9,.9,9i 76.458 8.9,56 78.99,8 0.844 77.788 g.115 78.19,9, 9,.126 77.79,8 8.154 97.858 9,.9,49 139.89,9, 9,.131 76.9,9,9, 9,.19,5 89,.758 9,.9,74 78.19,9, 83.959 9,.9,88 89.19,9, 141.159, Z.Z75 84.789, g.89g 92.19,8 8.119 83.758 9,.112 94.258 9,.9,59, 9,.897 85.39,8 8.178 88.889, 8.9,52 83.69,8 9,.147 94.258 8.134 88.688 57.158 -g.258 69,.680 64.908 -9,.258 57.858 -8.258 57.588 BEGINNING DEPTH: 11534.8~ ENDING DEPTH: 793~.~ DEPTH INCREMENT: -N.5~ THE NUMBER OF FRAMES ENCOUNTERED WAS 7209 FILE TRAILER (FILE COUNT 1) LENGTH: 62 BYTES FILE NAME: EDIT .~1 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: OPTIONAL NEXT FI'LE NAME: 1~24 TAPE TRAILER (TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 54555 DATE: 79/ 1/13 ORIGIN: SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: ~1 NEXT TAPE NAME: COMMENTS: ********************************************************************** REEL TRAILER (REEL COUNT LENGTH: 132 BYTES REEL NAME: P.C.D.C. ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: NEXT REEL NAME: COMMENTS: 1) LIS FORMAT CUSTOMER TAPE DATE: 79/ 1/'13 E 0 F * * * * * * * * * * * * * * E 0 F * * * * * * * * * * * * * * ***END OF JOB VAX/VMS HOY VAX/VMS HOY VAX/VMS HOY FORN15 22-SEP-1983 1~:32 LVAZ: 22-SEP-1983 i~:32 DISKI:[LOGGER3FOR~15.DAT;8 FOR~15 22-SEP-1983 18:32 LVA~, 22.-SEP-1983 1~:32 DISKl:£LOGGER]FOR~15.DAT;8 FOR~15 22-SEP-1983 1~:32 LVA~: 22-SEP-1983 1~,32 DISKl:£LOGGER3FOR~lS.DAT;8 VAX/VMS ':: VAX/VMS:: VAX/VMS H H 000 Y Y H H 0 0 Y Y H H 0 0 YY HHHHH 0 0 Y H H 0 0 Y H H 0 0 Y H H 000 Y FFFFFFFFFF 000000 RRRRRRRR FFFFFFFFFF 000000 RRRRRRRR FF O0 FF O0 FF O0 FF O0 FFFFFFFF O0 FFFFFFFF O0 FF O0 FF O0 FF O0 FF O0 FF 000000 FF 000000 O0 RR RR ~ O0 RR RR ~ O0 RR RR BB OO RR RR ~ O0 RRRRRRRR ~ ~ OO RRRRRRRR ~ ~ OO RR RR B~B~ OO RR RR B~B~ OO RR RR BB O0 RR RR B~ RR RR RR RR 11 11 llll 1111 11 11 11 11 11 11 11 11 111111 111111 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 DDDDDDDD AAAAAA TTTTT~ DDDDDDDD AAAAAA TTTTT' DD DD AA AA T' DD DD AA AA T' DD DD AA AA T' DD DD AA AA T' DD DD AA AA T' DD DD AA AA T' DD DD AAAAAAAAAA T' DD DD AAAAAAAAAA T~ DD DD AA AA T' DD DD AA AA T' DDDDDDDD AA AA T' DDDDDDDD AA AA T' 'TTTT 'TTTT ;;;; 888888 ;;;; 888888 ;;;; 88 88 ;;;; 88 88 88 88 88 88 ;;;; 888888 ;;;; 888888 ;;;; 88 88 ;;;; 88 88 ;; 88 88 ;; 88 88 ;; 888888 ;; 888888 H H 000 Y Y H H 0 0 Y Y H H 0 0 YY HHHHH 0 0 Y H H 0 0 Y H H 0 0 Y H H 000 Y VAX/VMS HOY VAX/VMS HOY VAX/VMS HOY FOR815 22-SEP-1983 18:32 LVA~: 22-SEP-1983 1~:32 DISKi:[LOGGEF]FORZl5.DAT;3 FOR~15 22-SEP-1983 1~:32 LVAO: 22-SEP-1983 10:32 DISK1:[LOGGER]FORO15.DAT;8 FOR~15 22-SEP-1983 1~:32 LVAf: 22-SEP-1983 1~:32 DISK1:[LOGGER]FOR~15.DAT;8 VAX/VMS VAX/VMS VAX/VMS REEL HEADER (REEL COUNT 1) LENGTH: 132 BYTES REEL NAME: P.C.D.C. ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: ~1 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 79/ 1/13 TAPE HEADER (TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 54715 DATE: 79/ 1/]3 ORIGIN: SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: ~1 PREVIOUS TAPE NAME: COMMENTS: ********************************************************************** FILE HEADER (FILE COUNT 1) LENGTH: 62 BYTES FILE NAME: EDIT .~1 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: OPTIONAL PREVIOUS FILE NAME: 1024 COMMENT RECORD: FILE COMMENTS EDITED WITHOUT LOG, USED STANDARD SCALES ACCORDING TO TAPE C ALIB. REPORT WELL SITE INFORMATION LENGTH: 128 BYTES C N : W N : F N : MARATHON TBU D-25 R.D. MCARTHUR RIVER C 0 U N : KENAI STAT DENS ALASKA 8~'8. DATUM FORMAT SPECIFICATION LENGTH.' 378 BYTES ENTRY BLOCKS TYPE D'ESCR IPTION 8 TERMINATOR (NO MORE ENTR. IES) DATUM SPECIFICATION BLOCKS: API API API API COUNT MNEM UNITS LOG TYPE CLASS MOD FILE NO. SIZE 1 DEPT FT 0 ~ ~ B 0 4 2 GR GAPI 42 31 32 ~ 0 4 3 CALI IN 42 28 1 8 8 4 4 DRHO G/C3 42 44 8 8 ~ 4 5 NPHI PU 42 68 3 8 8 4 G RHOB G/C3 42 35 I 8 8 4 7 NRAT C/C 42 42 1 8 0 4 8 NCNL CPS 42 34 92 8 8 4 9 FCNL CPS 42 34 93 8 ~ 4 DATA LISTING OF EVERY 188TH FRAME SIZE 1 8163.888 53.3~8 9.85~ -8.288 8,519 45.474 8113.888 47.1~8 9.~88 -8.288 8.423 52.767 8063.808 49.588 8.958 -8.288 8.377 66.866 8813.888 48.8~8 8.988 -8.288 8.489 42.471 7963.888 29.588 8.908 -8.288 8.339 98.948 7913.888 41.688 8.988 -8.288 8.326 77.228 7863.888 25.588 8.988 -8.273 8.187 286.778 7813.888 29.588 8.988 -8.288 8.402 56.199 7763,888 31.888 8.988 -8.288 8.469 44.616 7713.88Z 38,688 8,980 -8.288 8.540 35,687 7663.888 27,888 8.988 -~.288 8.261 95,238 7613.888 48.488 8.9~8 -8.288 8.538 35.687 2.178 2,249 2 176 2 885 2 488 2 417 2 416 2 177 2.168 1.956 2.384 2.848 REPR CODE ENTRY 66 8 REPR SAMPLE CODE 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 4.166 3.824 3.588 4.244 3.868 3,274 1.894 3.760 4.388 4.628 3.888 4.578 PROCESS LEVEL 194,337 197.769 231,231 177,177 286.572 258.965 384.384 281.281 189.618 171.171 276.276 172.458 7563.fff 36.f36 7513.f~ 43.758 7463.~0~ lf8.537 7413.~ 86.229 7363.f~f 78.356 7313.f8~ 54.~54 7263.~ 39.897 7213.f~f 42.471 7163.~Z 86.658 7113.0f~ 76.791 7f63.ff~ 45.9f3 7~13.~8~ 46.332 6963.0~f 42.471 6913.88f 67.353 6863.8~ 42.f42 6B13.88~ 77.649 37.323 6713.88f 97.383 6663.888 52.338 6613.888 48.326 6563.888 42.842 6513.888 37.752 6463.888 57.486 6413.888 81.881 6363.888 39.f39 6313 888 B4 884 6263 088 67 782 48 986 6163 888 45 845 6113 080 53 196 6063 088 41 184 6~13 888 44.78~ 34.78~ 29.988 33.4~ 36.688 39.2~ 31.4~ 29.4~ 54.48~ 55.3~ 53.8~Z 42.48~ 49.3~ 35.4~ 52.~ 32.4~f 49.8~8 41.38~ 53.58~ 51.388 51.9f~ 28.3~8 47.4f8 32.3~0 35.88~ 45.788 47.388 44.898 46.2~ 33.188 -~.288 -8.288 -Z.288 -8.288 -Z.288 -~.288 -Z.288 -~.29~ -~.288 -f.298 -8.298 -8.298 -f.289 -~.290 -8.29~ -~.298 -8.298 -8.298 -8.279 -Z.298 -8.298 -8.298 -Z.298 ~.584 ~.498 ~.247 8.3Z4 Z.336 Z.413 8.514 Z.482 Z.248 8.338 8.474 ~.479 Z.496 0.374 ~.315 8.552 ~.257 ~.422 ~.514 8.495 8.565 ~.398 ~.365 ~.562 ~.315 8.345 0.462 ~.492 Z.425 Z.488 8.382 2.129 2.856 2.494 2.425 2.584 2.344 2.f59 2.~69 2.312 2.424 2.126 2.142 2.~53 2.384 2.~45 2.331 1.922 2.494 2.878 2.816 2.286 2.178 2.328 2.445 2.1f6 2.445 2.234 2.365 2.433 2.411 1.978 2.465 4.818 4.388 2.912 3.112 3.25~ 4.~16 4.418 4.134 2.888 3.346 4.146 4.138 4.26~ 3.534 4.26~ 3.218 4.442 2.886 4.834 4.328 4.378 4.664 3.728 3.476 4.568 3.226 3.426 4.884 4.368 3.898 4.298 3.282 17f.742 184.841 388.888 274.989 243.672 286.349 172.~29 176.748 255.255 253.118 192.192 192.621 178.464 232.518 179.751 249.678 167.739 29f.884 195.624 169.455 186.186 179.322 212.784 288.995 178.893 262.119 225.654 2~2.488 2~8.343 214.929 175.832 284.856 87.516 5963.888 39.468 5913.888 85.888 5863.888 32.684 5813.888 56.199 5763.888 34.749 5713.888 54.912 5663.888 27.885 5613.888 61.776 5563.888 39.897 5513.888 51.488 5463.888 43.329 5413.888 42.471 5363.888 39.839 5313.888 57.857 5263.888 38.838 5213.888 54.912 5163.888 47.619 5113.888 42.471 5863.888 53.625 5813.888 57.486 4963.888 38.888 4913.888 45.983 4863.888 41.184 4813.888 44.616 4763.888 65.288 4713.888 44.187 4663.888 38.459 4613.888 39.468 4563.888 39.468 4513.888 36.465 4463.888 39.897 46.988 41.688 32.888 47.488 58.288 43.788 14.288 48.888 45.888 37.488 34.288 41.788 38.888 23.488 33.788 28.8g8 28.488 28.688 35.188 28.388 56.688 36.288 48.188 31.888 36.588 25.388 38.488 48.788 42.888 36.488 8.9~8 8. 988 8. 908 8. 988 8. 988 8. 908 8. 908 8. 988 8. 988 8. 988 8. 988 8. 908 8. 988 8. 988 8. 858 8.858 8.858 8. 858 8. 858 8. 958 8. 988 8. 988 8. 988 8. 988 8. 988 8. 908 8. 988 8. 988 8. 988 8. 988 8. 988 -8.298 -8.286 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.248 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 -8.298 8.527 8.319 8.663 8.426 8.578 8.431 8.786 8.388 8.531 8.432 8.486 8.558 8.518 8.418 8.677 8.412 8.438 8.444 8.489 8.389 8.674 8.485 8.551 8.477 8.484 8.477 8.656 8.535 8.581 8.573 8.533 1.997 2.485 1.996 2.358 1.938 2.345 1.885 2.581 2.286 2.321 2.358 2.284 1.952 2.328 1.762 2.266 2.388 2.114 2.236 1.831 1.934 2.256 2.268 2.288 2.458 2.118 1.862 2.187 2.882 2.816 2.115 4.468 3.842, 5.178 3.936 4.888 4.814 5.552 3.788 4.616 4.828 4.288 4.486 4.314 3.988 5.292 3.794 3.974 4.858 3.B52 3.784 5.896 4.256 4.496 4.298 3.764 4.346 5.114 4.384 4.294 4.752 4.336 174.683 277.563 163.878 228.228 175.898 223.589 162.162 238.524 178.464 196.911 187.844 188.689 174.683 217.874 161.384 212.784 187.844 176.748 285.928 218.218 164.736 192.621 193.479 198.476 249.678 181.838 168.817 181.896 169.884 165.594 1B1.838 49.764 4363..8.8.8 35.6.87 4313..8.8.8 44.616 32.175 4213.88.8 18.8.386 4163..8.8.8 37.752 4113.888 35.6M7 4863..8.8.8 63..863 82.797 3963.MOM 53.625 42..842 3863.~g 65.208 3813.80.8 37.323 4M.326 S3.625 28.743 63.921 26.598 34.749 36.~36 3413.888 46.761 3363 888 38 181 3313 888 44 616 3263 888 48 848 3213 808 54 912 3163 57 486 3113 888 52 767 3063 41 184 3~13 42 471 2963 3G 2913 808 ~1 184 2863 39.180 52.7.88 43.2.88 31.4~0 38.6.8.8 48.588 42.7~ 33.3.88 27.8.8.8 39.2.8~ 37.488 33.8.88 45.8~ 35.28.8 42.38~ 23.7.8.8 32.388 14.3.8.8 32.5.8.8 36.18~ 48.688 37.48.8 39.8.8.8 33.58.8 33.78.8 42.18.8 41.58.8 37.488 37,9.80 38.60.8 24.60.8 8. 988 8. 988 8.9.8.8 8.9Y38 8. 988 8. 988 8.9gg 8.9gg 8.98.8 8. 858 8.85.8 8.858 8. 858 8.858 8.85.8 8.85g 8.858 8.858 8.85.8 8. 858 8.85.8 8.9gg 8.858 8. 858 8.85~ 8.85~ 8.85~ 8.85.8 8.85.8 8.85g 8.858 8.85g -8.29.8 -8.298 -8.29.8 -g.298 -.8.298 -.8.298 -8.298 -.8.298 -.8.298 -8.29.8 -8.29.8 -f.29f -g.291 -.8.29.8 -0.298 -.8.29.8 -~.290 -8.298 -8.298 -~.298 -f.291 -0.290 -f.292 -8.298 g.449 8.683 8.492 0.58.8 .8.282 8.537 8.57.8 8.4.88 .8.28.8 8.425 8.525 8.382 8.535 .8.53.8 .8.438 .8.718 g.378 8.735 8.6.85 8.546 g.488 g.542 8.467 8.475 .8.393 0.448 .8.442 8.492 8.485 ~.583 8.587 8.735 2.24.8 1.896 2.313 1.844 2.612 1.936 2.188 2.448 2.442 2.357 2.885 2.475 1.969 2.162 2.248 1.812 2.388 1.68.8 2.129 1.984 2.165 2.182 2.267 2.176 2.215 2.38.8 2.27.8 2.076 1.98.8 2.f66 2.164 1.829 3.836 4.998 4.258 5.83.8 2.956 4.722 4.652 3.762 3..888 3.882 4.532 3.782 4.512 4.554 3.984 5.622 3.538 5.648 4.848 4.466 4.218 4.568 3.994 4.152 3.648 3.968 3.996 4.868 4.338 4.662 4.424 5.644 288.923 167.31.8 191.334 157.443 289.575 178.742 17f.742 22B.657 247.962 213.642 177.6.86 238.524 173.745 182.325 2.82..859 154..811 226.f83 149.721 169.455 167.318 292.859 172.887 19.8.476 192.621 218.218 219.648 213.213 172.~29 184.470 169.884 167.310 155.727 26.598 2813.8gg 32.175 2763.g08 5g.622 2713.~ 48.326 2663.~0~ 35.687 2613.00~ 47.19g 2563.g~ 34.32Z 2513.~Z~ 36.836 3f.10~ 36.2f9 36.5~Z 37.3f~ 39.88g 31.98~ 27.2~ 8.858 8.85~ 8.85~ 8.85~ 8.858 8.85~ 8.88~ -M.29M -M.29~ -~.29~ -M.29M -~.29M -M.29M -M.29~ ~.577 g.435 8.513 ~.6~5 8.488 ~.611 ~.549 1.876 2.142 2.253 1.891 2.342 1.964 2.613 4.894 4.07~ 4.214 5.2~4 4.228 5.148 4.496 16~.446 281.630 184.~41 169.455 198.198 17~.742 166.881 BEGINNING DEPTH ENDING DEPTH: DEPTH INCREMENT: 8163.g~ 2493.gg -g.5g THE NUMBER OF FRAMES ENCOUNTERED WAS 11241 FILE TRAILER <FILE COUNT 1) LENGTH: 62 BYTES FILE NAME: EDIT .~1 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: OPTIONAL NEXT FILE NAME: lg24 TAPE TRAILER (TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 54715 DATE: 79/ 1/13 ORIGIN: SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: ~1 NEXT TAPE NAME: COMMENTS: ********************************************************************** REEL TRAILER <REEL COUNT 1) LENGTH: 132 BYTES REEL NAME: P.G.D.C. ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 01 NEXT REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 79/ 1/13 **WEND OF JOB
