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175-024
Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Tuesday,January 27, 2015 10:16 AM To: Dan Marlowe(dmarlowe@hilcorp.com) Subject: D-27 (PTD 175-024) Sundry 314-591 Dan, I am looking for an email explaining why you were giving up and running a kill string. I vaguely remember talking about it. do you have the email trail? 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.gov). SCANNED JAN 2 8 201? 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,January 27, 2015 12:34 PM To: Dan Marlowe' Subject: RE: D-27 (PTD 175-024) Sundry 314-591 Dan, When you decide to deviate or stop short of a sundry work scope it is required that you notify the Commission. I will want to know how the well is being left(ie Kill string/ plugs etc) before you do the change of scope. All it takes is an email to notify me. When I read through the dailies I can't always pick up on details that. 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 [mailto:dmarlowe@hilcorp.com] Sent:Tuesday, January 27, 2015 10:25 AM To: Schwartz, Guy L(DOA) Subject: RE: D-27 (PTD 175-024) Sundry 314-591 It is in the weekly reports we sent in sir We fished the tubing down to 8,459' and could not make it down to the top of it again due to the casing being in too rough of shape. The deepest we could get with workstring was 8,397' This well will need major casing repair or a side-track From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@)alaska.gov] Sent: January 27, 2015 10:16 AM To: Dan Marlowe Subject: D-27 (PTD 175-024) Sundry 314-591 Dan, I am looking for an email explaining why you were giving up and running a kill string. I vaguely remember talking about it. do you have the email trail? 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 1 STATE OF ALASKA RECEIVED h_£KA OIL AND GAS CONSERVATION COMrniSSION ` REPORT OF SUNDRY WELL OPERATIONS JAN 0 5 ?015 1.Operations Abandon LJ Repair Well U Plug Perforations LJ Perforatel_ Other A� CC Performed: Alter Casing ❑ Pull Tubing E Stimulate-Frac ❑ Waiver ❑ Time Extension❑ w..� Change Approved Program Q Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ X;G( 5t) 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory Q 175-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99503 50-733-20274-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,101 feet Plugs measured 10,960 feet true vertical 9,805 feet Junk measured 9,683 feet Effective Depth measured 10,949 feet Packer measured 9,899 feet true vertical 9,673 feet true vertical 8,728 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 400' Surface 3,127' 13-3/8" 3,127' 3,011' 3,090psi 1,540psi Intermediate Production 11,100' 9-5/8" 11,100' 9,809' 5,750psi 3,090psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3#/N-80/8rd EUE 2,000'(MD) 1,995'(TVD) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/AB Mod BTC 9,937'(MD) 8,763(TVD) 9,899'(MD) Packers and SSSV(type,measured and true vertical depth) Baker 3H Packer N/A 8,728'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑s Service ❑ Stratigraphic El Daily Report of Well Operations X 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ /1- 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: 314-591 13/41-YY C Contact Dan Marlowe Email dmarIowelU7.hiICort).com Printed Name Dan Marlowe Title Operations Engineer ISignature A 4:L&,.., , Phone 907-283-1329 Date 1/5/2015 r RBC MS JAN 8 215 Form 10-404 Revised 10/2012 l // 0.74 Submit Original Only /moi Dolly Varden 11 SCHEMATIC Well: D-27 Completed: 12/02/2014 Hileorp Alaska.LLC RKB to TBG Hanger=40.23' CASING AND TUBING DETAIL Tree connection=4-1/2" 8rd SIZE WT GRADE CONN ID TOP BOTTOM 33" Conductor Surf 400' I 13-3/8" 61 K-55 BTC 12.515" Surf 3,127' L \ 9-5/8" 40 N-80 BTC 8.835" Surf 2,953' 9-5/8" 47 N-80 BTC 8.681" 2,953' 8,860' 9-5/8" 47 P-110 BTC 8.681" 8,860' 11,100' Tubing: 3-1/2" 9.3 N-80 8rd EUE 2.992 Surf 2,000' 4-1/2" 12.6 L-80 AB Mod BTC 3.958" 8,459' 9937' L , Jewelry Detail Depth Depth NO. (MD) (TVD) ID OD Item 1 2,000' 2.992 3.500 3-1/2"9.3#,N-80,8rd,EUE Kill String 2 3.968 7.000 Gas-Lift Mandrels 4-1/2"Daniels GLM2A @ 8,772',9,237',9,865' 3 9,899' 4.750 . 8.250 Baker model 3H packer 9-5/8"x 6"x 4.75" 4 9,923' 3.813 4.875 Baker X-Nipple 5 9,937' 4.012 5.200 WLREG/Shear Sub DV Stage Collar, 6 10,960' Cement Retainer 6,485' Packer consists of locator seal assembly w115'floating seals,PBR,K-anchor,Baker 3H perm packer. MO extension Perforation Data Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Date Status Estimated Top of G-1 10,020' 10,040' 8,837' 8,855' 11/9/1997 Open Tubing 8,459' G-2 10,080' 10,098' 8,891' 8,907' 11/9/1997 Open G-2 10,080' 10,090' 8,891' 8,900' 8/25/2003 Open G-3 10,146' 10,172' 8,951' 8,974' 11/9/1997 Open G-4 10,200' 10,244' 8,999' 9,039' 11/9/1997 Open 2 G-4 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open HB-1 10,520' 10,580' 9,288' 9,342' 5/20/1997 Open HB-1,2 10,520' 10,545' 9,288' 9,311' 2/24/1989 Open HB-2 10,521' 10,578' 9,289' 9,341' 8/25/1979 Open HB-2 10,520' 10,580' 9,288' 9,342' 11/19/1982 Open ->Q < 3 HB-3 10,620' 10,644' 9,378' 9,400' 11/19/1982 Open HB-3 10,610' 10,640' 9,369' 9,396' 2/24/1989 Open I= 4 HB-3 10,610' 10,645' 9,369' 9,401' 6/7/1992 Open HB-4 10,688' 10,784' 9,439' 9,525' 7/6/1975 Open HB-4 10,688' 10,784' 9,439' 9,525' 7/26/1979 Open 5 HB-4 10,685' 10,785' 9,436' 9,526' 11/19/1982 Open HB-4 10,690' 10,710' 9,441' 9,459' 2/24/1989 Open I G Zone HB-4 10,765' 10,795' 9,508' 9,535' 2/24/1989 Open HB-4 10,710' 10,765' 9,459' 9,508' 6/22/1991 Open FISH at 10,881' HB-4 10,670' 10,690' 9,423' 9,441' 9/22/1991 Open Lost 12/29/98 HB-4 10,670' 10,790' 9,423' 9,530' 8/25/2003 Open WL Tools,X-Lock,and Hemlock HB-5 10,828' 10,928' 9,564' 9,654' 7/6/1975 Open Fishing Tools. MOP HB-5 10,828' 10,928' 9,564' 9,654' 7/26/1979 Open HB-5 10,815' 10,845' 9,553' 9,580' 2/24/1989 Open Top of Sand @ 10949' HB-5 10,895' 10,905' 9,624' 9,633' 3/3/1991 Open 6 HB-5 10,875' 10,895' 9,606' 9,624' 3/3/1991 Open HB-5 10,865' 10,875' 9,598' 9,606' 3/3/1991 Open I HK-6 HB-5 10,845' 10,865' 9,580' 9,598' 3/3/1991 Open HB-5 10,835' 10,845' 9,571' 9,580' 3/3/1991 Open Z. HB-5 10,815' 10,835' 9,553' 9,571' 3/3/1991 Open HB-5 10,815' 10,850' 9,553' 9,584' 8/25/2003 Open PBTD= 10,960' TD= 11,101' HB-6 10,966' 10,992' 9,688' 9,712' 7/6/1975 Isolated MAX HOLE ANGLE=36° REVISED: 2014-12-31 REVISED BY:JLL Hilcorp Alaska, LLC Hilrurp.Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 08/29/14-Friday JSA. Finish Skidding Rig to D-27 Well&Secure Same. Putting Rig In Compliance,OIL Coil Tbg Equip.&Spot Same.Clear Rig Floor. R/D Rig Floor Equip.&Work Platform.R/D BOP Stand F/BOP Deck. Perform General Rig Maintenance&Clean Rig&Platform. 08/30/14-Saturday Cont.getting rig In compliance. L/0 Riser On Deck And M/U Same While Unbolt Tree Top Connection On Well D-27. Nipple Up Companion Flange And 4 1/16" 10M Riser On Tree. Install Hole On Top Deck.Tie Onto Bops W/Block And M/U On Riser.Tie Onto Coil Work Platform And Set Same In place.Connect Lines To Bops And Injector Head Offload And Spot Misc.Coil Equip.On Deck While Hooking Up.Connect Lines To Bops&Injector Head.Offload Head&Spot Misc Coil Equip On Deck While Hooking Up Surface lines.Function Test Bop's,Start Testing Bop's 250 Psi Low &2500 psi High. Perform General Rig Maintenance&Cleaning Rig. 08/31/14-Sunday Test Surface Lines.Test Bop's 250 psi Low&2500 psi High On Chart.Witness of test waived by Jim Regg,AOGCC. Install Coil Injector Head. Held Pre Job SFTY MTG On P/U Injector Head Making Up BHA And Stabbing Injector. Fill Surface Lines And Internal Surface Test Coil TBG Equip 250 psi Low And 2500 psi High. Hold 500 psi Open Well Drop 400 psi.RIH W/Coil And Wash Nozzle Tag @ 5,303 In GLM Pumping 4.3 BPM 8.5 FIW Taking Returns Over Rig Shakers. POOH W/Coil to 4,200',Wash Down @ 1.2 BPM W/2900 PSI f/4,200'&tag In GLM @ 5,303'.Circ bottom up Before POOH. POOH W/Coil TBG.JSA-R/D Inj. Head And Secure Same. Perform General Rig Maintenance And Clean. 09/01/14-Monday Cut 1100'coil tbg,change pack off injector head.Added 6-ft section of riser under injector.Made up 2.215"coil connector pull tested to 20K pressure up to 3000 psi"OK". M/U 2.215 check valve,2.215"disconnect sub,2.215"dual circ sub,2.215"mud motor W/X/O and junk mill.,Stab injector test break to 2500 psi"OK".Open well W/zero psi on tbg. RIH washing 1.2 BPM 3300 psi had no problem @ 5,300'CMT.Cont RIH slow pump to idle @ 6,750'CMT made soft tag @ 6,880'CTM work pipe up 100' checking up wt.=10K cont washing W/NO WT.on mill getting back full returns W/small amount sand.Tag @ 7,030'CTM had 3K over pull.Cont RIH tag @ 7,622' CMT had 6K over pull. Motor did not stall,pulled free had another 6K over pull, motor stalled. Pipe free. POOH W/coil while pumping,started getting coal back over shaker. Plug choke manifold.Cont. POOH bumped up secured well.Had 560 psi on 9 5/8"csg&600 psi on tbg.Wellhead pressure had 600 psi.Attempt to unplug choke manifold& surface lines,choke lines also plugged up. Broke down choke lines&unplug same.Circ through choke&surface lines to ensure lines&choke where clear. R/D injector head. L/D 2.215"BHA&secured injector head. R/D riser from tree&P/U BOP'S&riser hanging in derrick. Riser plug up W/coal unplug same. Prepare rig to skid. Hilcorp Alaska, LLC kli ka.U.( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/04/14-Tuesday N/D PROD TREE. PULL SAME AND REMOVE FROM WELL BAY. PREP WELL HEAD. ATTEMPT TO SCREW 4-1/2"8 RD PUP JT IN HGR, NO SUCCESS.THREADS CORRODED.CLEAN UP THREADS AND M/U 8 RD PUP JT, OK. INSTALL 11"X 5M RISER& N/U SAME. NO SUCCESS, FLOW CROSS TOO HIGH FOR WING VALVES DUE TO X-BRACES ON SUBSTRUCTURE. PULL RISER, RE-ARRANGE RISER SPOOLS AND INSTALL RISER. INSTALL CHOKE AND KILL VALVES ON FLOW CROSS&N/U SAME. INSTALL DBL BOP AND HYDRIL. TIGHTEN BREAKS ON RISER AND BOPS. N/U RISER FROM HYDRIL TO RIG FLOOR AND DRESS STACK. FUNCTION TEST RAMS, HYDRIL AND HCR ON CHOKE,OK. INSTALL RIG FLOOR PLATES AND POLLUTION PANS UNDER RIG FLOOR AROUND RISER. P/U 3-1/2"TEST JNT&ASSY. M/U TEST JNT INTO HGR. FILL ALL SURFACE EQUIP W/8.5#FIW.CENTER BOP STACK&SECURE SAME. R/U TEST EQUIPMENT. TEST 11"X 5M BOPS&SURFACE EQUIP AS PER AOGCC&HILCORP SPECS 250 LOW/2500 HIGH ON CHART.WITNESS OF TEST WAIVED BY JIM REGG,AOGCC.TESTED BOTH 3-1/2"&4-1/2" FROM REMOTE. FUNCTIONED MAIN. ASSIST CAMERON PULL 2-WAY CHK VALVE. R/D FOSTER TONGS&R/U MCCOY TONGS. PREP TO P/U SPEAR ASSY. P/U SPEAR ASSY AND SPEAR TBG AT HANGER AND ATTEMPT TO PULL PRODUTION STRING WITH A MAXIMUM OVER PULL OF 60K OVER PIPE WEIGHT( PIPE WT= 185k). 11/05/14-Wednesday FINISHED TESTING BOP'S. L/D SPEAR ASSY AND M/U 4-1/2" LANDING JT. R/U E-LINE. M/U 2.875" GAUGE RING AND TEST LUBRICATOR TO 1500 PSI. RIH W/E-LINE TO 7,336' ELM. (ENCOUNTERED TIGHT SPOT @ 7,120' ELM). POOH W/E-LINE. P/U TO 115K(20K OVER)AND SET IN SLIPS. M/U 3.625"JET CUTTER ON E-LINE AND RIH W/SAME.CORRELATE CUTTER ON DEPTH AND FIRE CUTTER @ 7,305'. POOH W/E-LINE. HUNG UP IN GLM @ 5,319'ELM.WORK FREE AND POOH. HUNG UP IN GLM @ 2,541' ELM.WORK FREE AND POOH W/E-LINE. P/U TO 92K. PIPE FREE. R/D E-LINE AND R/U CIRCULATING HOSES. DISPLACE WELL W/8.5#F.I.W. @3PM 140 PSI.ALL RETURNS GOING TO PRODUCTION WELL CLEAN TANK. CONT TO DISPLACE WELL W/600 BBLS OF 8.5#FIW @ 3 BPM 165 PSI.TAKING ALL RETURNS TO WELL CLEAN TANK&SENDING TO TRADING BAY FACILITY. R/D CIRC EQUIP&PULL HGR TO RIG FLOOR.TERMINATE CTRL LINE. L/D LANDING JNT&HGR. POOH&L/D 4-1/2" PROD TBG,SCSSSV,& GLM'S.CLEAN SAME.(115 JTS&2 GLM'S OUT=4600'). NORM READING=240. 11/06/14-Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK,CONT POOH W/4-1/2" IBT PROD TBG. LAYDOWN AND STRAP SAME.TOTAL RECOVERED=175 JTS,(1)CUT PIECE AND(5)GLM'S.TOTAL FT=7,270' DPM. C/O HANDLING EQUIPMENT FROM 4-1/2"TO 3-1/2". R/D MCCOY TONGS AND R/U FOSTER TONGS.WASH AND CLEAN RIG FLOOR. P/U LANDING JT. M/U WEAR BUSHING SETTING TOOL AND INSTALL WEARBUSHING. P/U LANDING JT WITH SPEAR ASSY AND BREAK DOWN SAME. M/U 8.125"OVERSHOT DRESSED W/4-1/2"GRAPPLE,OIL/BUMPER JARS,ACCELARATOR JARS AND(4)4-3/4" DC'S.TOTAL LENGTH=163.94'. RIH W/3- 1/2" PH6&0/S ASSY.TAG @ 7,276' DPM. P/U=91K,S/0=71K. N/U STRIPPING HEAD. P/U POWER SWIVEL&R/U SAME. INSTALL STRIPPING RUBBER. BROKE CIRC IN REVERSE @ 3 BPM 400 PSI&EST. PERIMETERS ROT=77K, P/U=71K,S/0=79K. WASH F/7,276'- T/7,302' DPM. PIPE PLUGGING&STALLING OUT. BLEW OUT PIPE&MANIFOLDS. MADE SEVERAL ATTEMPTS TO WASH/ROTATE DOWN W/NO SUCCESS. MANIFOLDS CONT TO PLUG. BROKE DOWN&CLEANED OUT SAME. RECOVERING COAL,SAND,QUARTZ, ROCKS&OTHER MISC METAL DEBRIS.SET 5K DOWN WHILE ROTATING&STALLED AT 7300 FT/LBS.TOOK 29K OVER T/PULL FREE. ALSO SLUGS OF DRILLING MUD BACK IN RETURNS. REV/OUT 90 BBLS @ 3 BPM 300-900 PSI UNTIL RETURNS CLEAN. MAX GAS BACCK=3000 UNITS. BLEW OUT ALL SURFACE EQUIP W/AIR. R/D POWER SWIVEL. PULL STRIPPING RUBBER AND N/D STRIPPING HEAD. PREPARE TO POOH. POOH W/3-1/2" PH6&0/S ASSY. Hilcorp Alaska, LLC ttihorp Uaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/07/14-Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 AND 0/S BHA. BREAK DOWN 0/S BHA. FOUND INDICATIONS THAT OVERSHOT HAD BEEN ON FISH.4-1/2"GRAPPLE WORN. WASH/CLEAN RIG FLOOR&PREP SAME TO TIH. M/U 8.50"JUNK MILL,OIL/BUMPER JARS&(4)4-3/4" DC'S,TOTAL LENGTH= 152.66'. TIH W/3-1/2" PH6 AND MILL ASSY BHA.TAG @ 4,054' DPM.(P/U 40K OVER) PIPE FREE. RACK BACK STD AND P/U SINGLE AND WORK THRU TIGHT SPOT,TAKING 10-20K OVER TO PULL OUT. L/D SINGLE& R/U POWER SWIVEL. MAKE CONNECTION. EST DRILLING PARAMETERS, PUMPING 8 BPM 950 PSI, RPM=60,TORQUE=2-3K AND REAMING THRU 4,056' DPM.CIRC BTMS UP LONG WAY @ 8 BPM 1000 PSI. R/D POWER SWIVEL& L/D SAME. CONT TO TIH W/3-1/2" PH6&MILL ASSY. R/U POWER SWIVEL&REAM THRU TIGHT SPOTS @ 5,126'-5,129',5,147'- 5,150',5,168'-5,172',5,743'-5,747',5,868'-5,871',5,875'-5,880'. REV/OUT BTMS UP AFTER EACH TIGHT SPOT @ 4 BPM 305 PSI. WORK THRU EACH SPOT SEVERAL TIMES UNTIL ABLE TO WORK UP/DOWN W/O ROTATING OR PUMPING. DEPTH @ 0600=7,273' DPM. 11/08/14-Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. N/U STRIPER HEAD. R/U POWER SWIVEL. MAKE CONNECTION&INSTALL STRIPPER RUBBER. TIH,TAG @ 7,300' DPM. BREAK CIRCULATION AND EST DRILLING PARAMETERS. PUMPING 8 BPM 1300 PSI, RPM=60,TORQUE=3-5K.WOB=5K. ROTATE AND WASH DOWN F/7,300' DPM-7,305' DPM. PUMP 3 BBL SWEEP AND DISPLACE W/8.5#F.I.W. @ 8 BPM 1250 PSI UNTIL RETURNS CLEAN. RECOVERED APPROX 10 BBLS SAND.TOTAL PUMPED=720 BBLS. R/D POWER SWIVEL AND N/D STRIPPER HEAD. POOH W/3-1/2" PH6 AND MILL ASSY BHA&L/D SAME. SWAP OUT PHE F/3-1/2"-T/8- 1/2". P/U 8.5" RTY SHOE, (3)JNTS OF 8-1/8"WASH PIPE, BUMPER&OIL JARS AND(4)JNTS 4-3/4" DC'S,TOTAL LENGTH=247.36'. TIH W/3-1/2" PH6&W/P ASSY.TAG @ 4,056' DPM.ATTEMPT TO WORK THRU W/NO SUCCESS.SET UP TO 10K DOWN&TOOK UP TO 15K TO PULL FREE.(ORG P/U=54K,S/0=49K). P/U POWER SWIVEL&R/U SAME. MADE CONNECTION&BROKE CIRC LONG WAY @ 5 BPM 800 PSI. ATTEMPT TO ROTATE&PUMP THRU TIGHT SPOT W/NO SUCCESS.W/1K ON BIT ROTATING @ 70 RPM, PIPE STALLED OUT. MADE SEVERAL ATTEMPTS TO WORK THRU SPOT W/NO SUCCESS. (162 BBLS PUMPED @ 6 BPM 900 PSI) BLACK SAND BACK OVER SHAKER AT BOTTOMS UP. CIRC 237 BBLS LONG WAY @ 7 BPM 960 PSI UNTIL RETURNS CLEAN. L/D(1) JNT OF PH6. BLEW DOWN ALL SURFACE LINES W/AIR. R/D POWER SWIVEL&L/D SAME. POOH W/3-1/2" PH6&W/P ASSY. 11/09/14-Sunday CONT POOH W/3-1/2" PH6 AND WASH PIPE ASSY BHA. LAY DOWN 8-1/2 BURNING SHOE AND M/U 8-1/8" BURNING SHOE,(3) JTS 8-1/8"WASH PIPE,OIL/BUMPER JARS AND(4)4-3/4" DC'S. TIH SLOW W/3-1/2" PH6 AND WASH PIPE ASSY BHA,TAG @ 4,056' DPM. MAKE SEVERAL ATTEMPTS TO WORK THRU TIGHT SPOT, NO SUCCESS. POOH W/3-1/2" PH6 AND WASH PIPE ASSY BHA. BREAK DOWN BHA AND RACK BACK(1)STD OF WASH PIPE IN DERRICK. R/U E-LINE UNIT AND EQUIPMENT. M/U 2.75" MULTI- FINGER CSG CALIPER ASSY.TEST LUBR.TO 1500 PSI. RIH W-E-LINE. CONT TO RIH W/E-LINE TO 7,277'WLM. LOG UP TO SURFACE. R/D LUBRICATOR& EQUIPMENT. PERFORM GENERAL HOUSEKEEPING&MAINTENANCE WHILE WAITING ON TOWN TO REVIEW LOGS. P/U 8-3/8"JUNK MILL,8-1/2"STRING MILL,JARS&DC'S TOTAL LENGTH=160.32'. TIH W/3-1/2" PH6&TANDEM MILL ASSY TO 4,021' DPM. P/U=55K,S/0=51K. N/U STRIPPING HEAD. P/U POWER SWIVEL&R/U SAME. INSTALL STRIPPING RUBBER. BROKE CIRCL/W @ 7 BPM 1100 PSI. EST PERIMETERS ROT=51K, P/U=52K,S/0=52K,TORQUE=3K @ 60 RPM. TAG @ 4,056'DPM W/JUNK MILL. MILL THRU TIGHT SPOT W/JUNK MILL&STRING MILL.WORKED BOTH MILLS THRU TIGHT SPOT.STOPPED ROTATING AND ATTEMPTED TO WORK MILLS THRU AND HAD 5-7 WT DOWN&UP TO GET STRING MILL THRU TIGHT SPOT. CONTINUED ROTATING AND WORKING MILLS THRU TIGHT SPOT FROM 4,056'TO 4,058' DPM. Hilcorp Alaska, LLC !layout) kla.ku.t.l.l: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/10/14-Monday CONT MILLING THRU TIGHT SPOT IN CSG F/4,056'-4,058' DPM. PUMPING 7 BPM 1052 PSI, RPM=70,TORQUE=5-7K.WORK THRU TIGHT SPOT W/O ROTATING,5K TO WORK THRU,5-7 K TO PULL OUT. R/D AND L/D POWER SWIVEL. CONT TIH W/3-1/2" PH6 AND TANDEM MILL ASSY.TAG @ 5,148' DPM. L/D SINGLE. P/U AND R/U POWER SWIVEL. MAKE CONNECTION AND EST DRILLING PARAMETERS, PUMPING 7 BPM 1200 PSI, ROTARY=60 TORQUE 3-4K. ROTATE AND WASH DOWN.TAG @ 5,148' DPM.WORK THRU TIGHT SPOT F/5,148'-5,152',TORQUE=5-7K. PUMP 3 BBLS SWEEP AND DISPL.W/8.5#FIW TREATED WITH CFS-520 @ 7 BPM 1250 PSI UNTIL RETURNS CLEAN. RECOVERD SAND W/SWEEP. LINE UP TO REV/OUT. REVERSE OUT(1)TBG VOLUME @3 BPM 240 PSI UNTIL RETURNS CLEAN. CONT TIH P/U SINGLES OUT OF V-DOOR.TAG @ 5,175'.WORK THRU TIGHT SPOT F/5,175'- 5,178' DPM. REV CIRCULATE BTMS UP @ 3 BPM 340 PSI UNTIL RETURNS CLEAN. CONTINUE WASHING DOWN PICKING UP SINGLES FROM V DOOR TO 5,290'. L/D POWER SWIVEL. RIH TO 5,871'AND TAGGED WITH 5K DOWN. P/U POWER SWIVEL& REAM/MILL OUT TIGHT SPOTS @ 5,871'-5,883',6,487'-6,489' DPM. REV/OUT BTMS UP AFTER EACH SPOT @ 3-1/2 BPM 300 PSI. ROTATE @ 70 RPM W/5-7K FT/LBS TORQUE. P/U=82K,S/0=67K, ROT=71K, P/U=74K,S/0=74K. L/D POWER SWIVEL&CONT TO TIH W/3-1/2" PH6&TANDEM MILL ASSY F/6,489'-T/7,281' DPM. P/U=90K,S/0=71K. P/U POWER SWIVEL&R/U SAME. MAKE CONNECTION&EST PERIMETERS. BROKE CIRC IN REV @ 3BPM 304 PSI. P/U=90K,S/0=71K, ROT=80K, P/U=81K,S/0=81K, TORQUE=4500 @ 70 RPM. WASH F/7,281'T/7,305' DPM (TOF). REV/OUT 66 BBLS @ 3-1/2 BPM 345 PSI UNTIL CLEAN. L/U LONG WAY&PUMP 5 BBL SWEEP AROUND PUMPING @ 7 BPM 1425 PSI.TOTAL METAL BACK SINCE START OF MILLING OPS=45 LBS. R/D POWER SWIVEL. POOH. 11/11/14-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. POOH W/3-1/2" PH6 AND TANDEM MILL ASSY. BREAK DOWN MILL ASSY BHA AND INSPECT MILL.SLIGHT WEAR(APPROX. 1/16"). WASH AND CLEAN RIG FLOOR. PREP SAME TO TIH. M/U BHA#5-8-1/2" TAPERED MILL,8-1/2"STRING MILL,6-1/2" PONY COLLAR,8.740"STRING MILL,OIL/BUMPER JARS&(4)4-3/4" DCS,TOTAL LENGTH=179.56'. TIH W/3-1/2" PH6 AND TRIPLE MILL ASSY BHA,TAG @ 4,052' DPM. N/U STRIPPER HEAD&R/U POWER SWIVEL. MAKE CONNECTION. P/U=56K,S/O=51K. BROKE CIRC LONG WAY @ 7 BPM PUMP PRESSURE=1040 PSI,CSG=250 PSI. EST PERIMETERS. ROT=51K, P/U=52K,S/0=52K,TORQUE=2500 @ 70 RPM. REAM/MILL F/4,050'-T/4,070' DPM.TORQUE RUNNING 3-7K& WOB= 1K.CIRC BTMS UP @ 7 BPM PUMP PRESSURE=1045 PSI,CSG=250 PSI. R/D POWER SWIVEL&LID SAME. CONT TO TIH W/3-1/2" PH6&TRIPLE MILL ASSY.TAG @ 5,778' DPM W/10K DOWN&10K OVER. P/U=72K,S/0=62K. P/U POWER SWIVEL& R/U SAME. EST PERIMETERS. ROT, P/U&S/0=68K,TORQUE=3K @ 70 RPM. REAM/MILL F/5,778'-1/5,780' DPM. CIRC LONG WAY @ 7 BPM 1290 PSI.TORQUE UP TO 4-7K. R/D POWER SWIVEL&L/D SAME. CONT TO TIH T/7,305'DPM. R/U CIRC EQUIP. PUMPED 5 BBL SWEEP AROUND LONG WAY @ 7 BPM 1595 PSI.TOTAL PUMPED=630 BBLS. RECOVERED SAND& (3) LBS OF METAL. R/D CIRC EQUIP&N/D STRIPPING HEAD. BLEW DOWN ALL SURFACE LINES. POOH W/3-1/2" PH6&TRIPLE MILL ASSY.WORKED PIPE UP/DOWN THRU TIGHT SPOTS @ 6,488',5,870',5,170'AND AT 5,170'TAKING 3-4K DOWN TO WORK THRU TIGHT SPOT W/O ROTATING. P/U POWER SWIVEL. Hilcorp Alaska, LLC ►,,,.,. k►:,.k:,.i. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/12/14-Wednesday R/D AND LAY DOWN POWER SWIVEL. CONT POOH W/3-1/2" PH6 AND MILLING ASSY BHA. B/D MILLING ASSY BHA AND INSPECT MILLS. (SLIGHT WEAR). M/U RETRIEVING TOOL. RIH AND PULL WEAR BUSING. RIG UP TEST EQUIPMENT. TEST 11'X 5M BOPS AND SURFACE EQUIPMENT AS PER AOGCC&HILCORP SPECS.250/LOW AND 2500/HIGH ON CHART DATED 11-12-2014.SEE CHART AND DETAIL SHEET FOR INDIVIDUAL TEST.TEST FROM MAIN AND FUNCTION REMOTE. PERFORM ACCUMULATOR TEST"OK".WITNESS WAIVED BY JIM REGG 08:14, 11/12/2014. B/D 4-1/2"TEST ASSY. R/D BOP TESTING EQUIP. PULL TEST PLUG&SET WEAR BUSHING.C/O PHE TO 8-1/8". P/U 8-1/8" RTY SMOOTH SHOE,(3) JNTS 8-1/8"WASHPIPE,JARS&(4)4-3/4" DC'S.TOTAL LENGTH OF BHA#6=247.36'. TIH W/3-1/2" PH6&W/P ASSY.TAG @ 4,054'W/8K DOWN.TOOK 8K OVERPULL.ORG P/U=53K 5/0=50K.ATTEMPT TO ROTATE USING TONGS W/NO SUCCESS. P/U POWER SWIVEL&R/U SAME. ATTEMPT TO ROTATE THRU TIGHT SPOT W/NO SUCCESS.SET 15K DOWN&TORQUED OUT AT 7500 FT/LBS.TOOK 15K OVER TO PULL OUT. BROKE CIRC IN REVERSE. PUMPED 2 BBL CLEANOUT SWEEP&REV/OUT 303 BBLS @ 3 BPM 250 WHILE ATTEMPTING TO WORK PIPE THRU TIGHT SPOT.SET UP TO 20K DOWN. PIPE TORQUED OUT AT 7500 FT/LBS. TOOK 20K OVER TO PULL OUT.TOTAL FLUID LOST WHILE CIRCULATING=16 BBLS. R/D POWER SWIVEL& L/D SAME. POOH W/3- 1/2" PH6&W/P ASSY. 11/13/14-Thursday CONT BREAKING DOWN WASH PIPE ASSY AND LAYING DOWN SAME. C/0 PHE FROM 8-1/2"TO 3-1/2".WASH AND CLEAN RIG FLOOR. M/U 8.13"OVERSHOT DRESSED W/4-1/2"GRAPPLE,OIL/BUMPER JARS,ACCELARATOR JARS AND(4)4-3/4" DC'S.TOTAL LENGTH=162.39'. TIH W/3-1/2" PH6 AND OVERSHOT BHA, CHECKING EACH BREAK FOR TORQUE 7,284' DPM. M/U KELLY&CONT TIH,TAG @ 7,305' DPM.WORK OVER TOP OF FISH AND SET DOWN 12K, P/U TO 115K(30K OVER). HIT JARS, POOH. INDICATION GRAPPLE SLIPPED OFF.WORK OVER FISH AND SET DOWN 30K, P/U TO 115(30K OVER)AND HIT JARS. POOH. NO POSITIVE INDICATION OF FISH. R/D AND LAYDOWN KELLY JT. POOH W/3-1/2" PH6 AND POSSIBLE FISH. B/D OVERSHOT ASSY&L/D SAME. SWAP TO 4-1/2" PHE. POOH&L/D 4-1/2"TBG. RECOVERED(1)GLM, (1) FULL JNT,(2)CUT JNTS(TOTAL LENGTH=92.92'). SHUCK FISH&C/0 GRAPPLE IN OVERSHOT. P/U 8.13"OVERSHOT DRESSED W/4-1/2"GRAPPLE,OIL/BUMPER JARS,ACCELERATOR JARS& (4)4-3/4" DC'S. RIH W/SAME. LENGTH=166.39'. TIH W/3-1/2" PH6&OVERSHOT ASSY. 11/14/14-Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/3-1/2" PH6 AND OVER SHOT BHA ASSY TO 7,377' DPM. M/U KELLY JT AND CONT TIH,TAG TOP OF FISH @ 7,396' DPM.SET DOWN 12K, P/U TO 86K, NO INDICATION OF FISH.SET DOWN 30K, P/U TO 86K, NO INDICATION OF FISH. R/D KELLY JT AND L/D SAME. POOH W/3-1/2" PH6 AND BREAK DOWN OVERSHOT BHA ASSY(NO FISH). M/U 8.50"JUNK MILL,OIL/BUMPER JARS AND(4)4-3/4" DC'S.TOTAL BHA=152.86'. TIH W/3-1/2" PH6 AND MILL ASSY BHA TO TIH TO 7,367' DPM. P/U =84K,S/0=74K. N/U STRIPPING HEAD. P/U POWER SWIVEL&R/U SAME. INSTALL STRIPPING RUBBER& MAKE CONNECTION. BROKE CIRC DOWN TBG @ 7 BPM 1300 PSI. EST PARAMETERS ROT=78K, P/U=80K,5/0=80K, TORQUE=3K @ 65 RPM. WASH F/7,367'-T/7,394' DPM.TAG TOF. MILLED TO 7,396'DPM W/4K WOB. UNABLE TO MILL DEEPER. SET UP TO 20K MAX WOB. HAD NO ADDITIONAL TORQUE OR OVERPULL. MADE SEVERAL ATTEMPTS TRYING TO MILL W/NO SUCCESS. PUMPED 2 BBL N-VIS SWEEP AROUND THE LONG WAY @ 7 BPM 1370 PSI. UNTIL RETURNS CLEAN. RECOVERED WHITE SAND,SLUDGE&(2)LBS OF FINE METAL. PUMPED 3 BBL N-VIS PILL DOWN TBG&SPOTTED ON BTM. NO GAIN/-4 BBLS LOST DURING CIRCULATION. R/D POWER SWIVEL&L/D SAME. N/D STRIPPING HEAD. POOH W/3-1/2" PH6&MILL ASSY. CONT TO POOH W/3-1/2" PH6&MILL ASSY. B/O& L/0 SAME IN CENTER OF MILL, INDICATIONS WIRELINE TOOLS IN TBG. P/U 8.13" OVERSHOT DRESSED W/4-1/2"GRAPPLE,JARS, (4)4-3/4" DC'S&RIH W/SAME.TOTAL LENGTH=165.39'. TIN W/3-1/2" PH6& OVERSHOT ASSY. Hilcorp Alaska, LLC IIiliorp tla.ka.LH Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/15/14-Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/3-1/2" PH6 AND OVERSHOT ASSY TO 7,380' DPM. L/D SINGLE. P/U AND R/U POWER SWIVEL. BROKE CIRCULATION @ 1BPM 45 PSI. CONT TIH&TAG TOF @ 7,396' DPM.WORK DOWN TO 7,408' DPM &SET 20K DOWN. P/U TO 98K(7K OVER),SET DOWN 25K, P/U TO 98K, INDICATION FISH PARTED. R/D POWER SWIVEL AND LAY DOWN SAME. POOH SLOW W/3-1/2" PH6 AND POSSIBLE FISH. B/O&L/0 OVERSHOT AND SHUCK 22'OF 4-1/2"TBG. (TBG FULL OF HOLES AND TWISTED). CLEAN RIG FLOOR.SLIP/CUT 102'OF DRILL LINE. RE-CALIBRATE OMRON SYSTEM&C.O.M.SET ALL E-STOPS TEST SAME. M/U BHA#11-8.50"JUNK MILL, BUMPER&OIL JARS,(4)4.750" DRILL COLLARS,TOTAL LENGTH=152.49'. RIH WITH 3-1/2"WORK STRING AND BHA#11 TO 7,399'. P/U&M/U POWER SWIVEL. BROKE CIRCULATION AND TAGGED UP AT 7,415' 1-2K DOWN AND STARTED MILL WITH 5-6K DOWN PUMPING 6-1/2 TO 7 BPM,WITH 1450 PSI. PUMPING GEL SWEEPS AS NEEDED DEPTH AT 06:00=7,430'. 11/16/14-Sunday CONT DISPL SWEEP W/8.5#F.I.W. @ 7 BPM 1590 PSI, UNTIL RETURNS CLEAN. MAKE CONNECTION AND CONT ROTATE AND MILL DOWN F/7,430'-7,434' DPM. PUMPING @ 7 BPM 1013 PSI, RPM=60,WOB=3-5K,TORQUE=5-7K. PUMP 5 BBL SWEEP AND DISPLACE W/8.5#F.I.W. @ 7 BPM 1400 PSI, UNTIL RETURNS CLEAN. RECOVERED 5 LBS OF METAL AND SAND. R/D POWER SWIVEL. LAY DOWN(2)JTS AND R/D STRIPPER HEAD. ATTEMPT POOH W/3-1/2" PH6 AND MILLING ASSY BHA,"NO SUCCESS". PULL 110K(10K OVER).ATTEMPT TO SLACK OFF,SET DOWN 5K @ 7,390' DPM. MAKE SEVERAL ATTEMPTS TO WORK PIPE FREE. R/U KELLY JT&PUMP 10 BBL SWEEP, DISPLACE(1) HOLE VOLUME W/8.5#F.I.W. @ 9 BPM 1857 PSI. UNABLE TO POOH WITHOUT PUMPING. POOH AND LAY DOWN 4 JTS WHILE PUMPING @ 3BPM 250 PSI. MIX AND PUMP 15 BBL HI-VIS SWEEP(180 VIS). DISPLACE WITH 8.5#F.I.W. @ 9 BPM 1700 PSI UNTIL RETURNS CLEAN. RECOVERD SAND AND 3 LBS METAL. LOST 6 BBLS OF FLUID. POOH W/3-1/2" PH6& MILL ASSY SLOW WATCHING FOR ANY DRAG.SAW 5K OVER @ 5,149'AND 4,055' DPM. B/D MILL ASSY& L/D SAME. NO SIGNS OR INDICATION OF WHAT WAS DRAGGING. DID HAVE MARKS SHOWING MILLING ON 4-1/2 TBG. P/U 8.13" OVERSHOT DRESSED W/4-1/2"GRAPPLE&3'UPPER EXT, BUMPER/OIL JARS,(4)4-3/4" DC'S,ACCELERATOR JARS&RIH W/ SAME.TOTAL LENGTH=165.39. TIH W/3-1/2" PH6&OVERSHOT ASSY. 11/17/14-Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. M/U KELLY JT AND CIRCULATING HOSE.CONT WASHING DOWN,TAG TOF @7,431' DPM.SET 20K DOWN AND ATTEMPT TP LATCH FISH. MAKE SEVERAL ATTEMPTS,"NO SUCCESS". L/D KELLY AND R/U POWER SWIVEL. ROTATE AND WASH DOWN F/7,431'-7,432' DPM @1BPM 180 PSI. PRESSURE INCREASED TO 220 PSI. INDICATION OF GOING OVER FISH. P/U TO 93K, NO INDICATION OF FISH. MAKE SEVERAL ATTEMPTS. L/D SINGLE AND R/D POWER SWIVEL. POOH W/3-1/2" PH6 AND OVERSHOT BHA. B/D OVER SHOT BHA AND INSPECT OVER SHOT. INDICATION OF METAL SHAVINGS ON TOP OF FISH. M/U 8.13" BURNING SHOE,(7') 8-1/8" WASH PIPE,OIL/BUMPER JARS,ACC JARS& (4)4-3/4" DC'S TOTAL LENGTH= 160.99'.TOTAL LENGTH OF SHOE AND EXT.= 14.51'. TIH W/3-1/2" PH6 AND BURNING SHOE BHA ASSY. SERVICE RIG& PERFORMED SAFETY COMPLIANCE CHECKS. CONT TO TIH W/3-1/2" PH6&W/P ASSY.TAGGED @ 4,060'DPM.WORKED THRU TIGHT SPOT W/15K DOWN.CONT TIH TO 7,407' DPM. N/U STRIPPING HEAD. P/U POWER SWIVEL&R/U SAME. INSTALL STRIPPING RUBBER&MAKE CONN. BROKE CIRC IN REVERSE @ 4 BPM 600 PSI.WASH/ROTATE F/7,407-T/7,443' DPM. @ 15 RPM WITH 1-2K WOB.TORQUE=2-4K. REV/OUT 608 BBLS @ 4 BPM 420-590 PSI UNTIL RETURNS CLEANED. RECOVERED SAND, COAL, &55 LBS OF METAL. NO GAINS/NO LOSES DURING CIRCULATION. FLUSHED THRU ALL CIRC LINES/EQUIP W/CLEAN FIW& BLEW DOWN SAME W/AIR. R/D POWER SWIVEL&L/D SAME. N/D STRIPPING HEAD. POOH W/3-1/2" PH6&W/P ASSY. HAD 20K OVER PULL WHEN COMING THRU TIGHT SPOT AT 4,060'. Hilcorp Alaska, LLC Ilih.urp LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/18/14-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 AND BURNING SHOE BHA. B/D BURNING SHOE BHA. WASH AND CLEAN RIG FLOOR. M/U 8-1/8"OVERSHOT DRESSED W/4-1/2"GRAPPLE,OIL/BUMPER JARS,ACC JARS&(4)4-3/4" DC'S,TOTAL LENGTH=165.39'. TIH W/3-1/2" PH6 AND OVERSHOT BHA TO 7,411" DPM. REMOVE AIR SLIPS AND RUBBER, INSTALL TIW IN KELLY JT AND P/U SAME.CONT TIH AND TAG TOF @ 7,432' DPM.SET DOWN 2OK AND ENGAGE FISH. P/U TO 135K(45K OVER)AND HIT JARS.WORK UP TO 190K(100K OVER)NO SUCCESS. BREAK CIRCULATION DOWN TBG @ 2 BPM 120 PSI, PUMP(5 BBL SWEEP), DISPLACE(1) HOLE VOL W/8.5#F.I.W.@ 5 BPM 780 PSI TO DETERMINE DEPTH OF CICRCULATION. CONT ATTEMPT TP JAR FISH FREE HITTING JARS AT(45K OVER)AND P/U TO(100K OVER). WAIT ON SLICK-LINE. PERFORM GENERALHOUSEKEEPING&MAINTENANCE AROUND RIG. R/U SLICKLINE EQUIP&LUBRICATOR. P/U 1-1/2"SLICK TOOL STRING. R/U LUBRICATOR&TEST TO 1000 PSI "OK". RIH W/SLICK-LINE TO 7,442'WLM. UNABLE TO GET DEEPER. POOH W/S-LINE. L/D EQUIP. R/U CIRCULATING EQUIP. PERFORM DERRICK INSPECTION. CONT TO JAR ON FISH. PULL 45K OVER,JARRED UP&PULLED 100K OVER.AFTER 30+ATTEMPTS PIPE STARTED WORKING FREE. L/U&PUMPED DOWN TBG @ 3 BPM 180 PSI.ONCE RETURNS WERE ESTABLISHED PULLED 35K OVER&JARRED UP. PIPE PULLED FREE W/95K HOOKLOAD(5K OVER). R/D CIRC EQUIP&L/D (1)JNT. POOH W/3-1/2" PH6,OVERSHOT&POSSIBLE FISH. 11/19/14-Wednesday FINISH POOH WITH 3.5" PH6 WORKSTRING&BHA. L/D OVERSHOT AND 4-1/2"TBG.TOTAL FISH RECOVERED-19 JOINTS AND 1 CUT PIECE=398.66'. MONITOR WELL FOR LOSSES. LOSSES=17 BPH. PUMP 6 BBLS N-VIS PILL&LET FALL. PULL WEAR BUSHING. INSTALL TEST PLUG&RIG UP TEST EQUIP.TEST BOP'S AND RELATED EQUIPMENT TO 250 PSI LOW/2500 PSI HIGH ON CHART. WITNESS WAIVED BY JIM REGG,AOGCC ON 11/18/2014 @ 16:50 HRS. RIG DOWN TEST EQUIPMENT. PULL TEST PLUG AND SET WEAR BUSHING. BROKE OUT X-OVERS FROM JARS AND COLLARS WITH WRONG ID'S FOR NEXT RUN. GENERAL RIG MAINTANCE WHILE WAITING SHORT CATCH OVER SHOT&GRAPPLES TO ARRIVE FROM OSK.AT 18:00 HRS,TOO ROUGH TO LOAD BOAT& HELICOPTER COULD NOT FLY DUE FREEZING RAIN. 11/20/14-Thursday Service rig while waiting on fishing tools. Made up overshot.TIH tagging fish @ 7,805'. Space out pups,98K pickup and 72K slack off. Rig up stripper head and power swivel.Worked over fish, latch fish,verified latch with 113K,21K over pickup weight. Rig down power swivel and stripper head. Rig up slick line and test lub to 2500 PSI(ok). RIH with 2.6"gauge tag @ 7,815'WLM, POOH. RIH w/2" bailer tag @ 7,815'WLM bail to 7,818'WLM, POOH. RIH w/same tag @ 7,819'WLM and bail to 7,820'WLM, POOH(recovering formation sand,coal and rocks). RIH w/2.62" bailer tag @ 7,816'WLM, bail to 7,820'WLM, POOH(recovered coal and rocks). RIH w/2.2" bailer tag @ 7,820'WLM, bail to 7,824'WLM, POOH(recovered coal and rocks). NEXT BOP TEST IS ON 11-26-2014. 11/21/14-Friday RIH w/2" bailer tag @ 7,823'WLM, bail to 7,825'WLM. POOH. RIH w/2.62" bailer tag @ 7,823'WLM, bail to 7,879'WLM. Pumped 5BBLs inlet water, had a lot of pipe dope. POOH w/2.62'bailer slow due to dragging up hole. Rig down 2.62" bailer to clean same out(tool was packed off with rocks and sand, pumped 5 BBLs). RIH w/2.62"bailer tag @ 7,876'WLM, bail to 7,888' WLM, pumped 5BBLs. POOH w/2.62" bailer slow. Rig down slickline and rig up e line. Rig up lubricator and sheave in crown. Make up 1 9/16"tbg punch,7 shot(ok) make up same,test lubricator @ 2500 PSI(ok). RIH w/1 9/16"tbg punch (7 shots)shoot same @ 7,867'-7,868'WLM (tag @ 7,872) POOH w/same. Prep 2.5" RCT. RIH w/same cut tbg @7,865'WLM w/15K overpull (115K) POOH(weight indicator did not show any loss of weight after cut). Work pipe between 65K and 120K(not cut). Make up new 2.5" RCT and RIH w/same,cut @ 7,864'WLM w/15K overpull(115K)weight dropped to 83K after firing RCT. POOH w/ wireline. Rig down e-line. Hilcorp Alaska, LLC Hiieorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations:; 11/22/14-Saturday Finish rig down e-line.POOH w/3.5" PH6 workstring slow,easy on and off slips(PU 90K). Lay down fish and shuck overshot (recovered GLM#1,JNT and CUT piece total 56.66'). Make up overshot BHA w/4.5"basket grapple, bumper and oil jars,drill collars and acc jars.Start RIH w/3.5" PH-6 workstring. Finish TIH w/3.5" PH6 workstring tag @ 7,865'. P/U 94K and S/0 75K latch fish,jarring on fish(fish has moved up hole 3'and stopped moving cont jarring on same). 11/23/14-Sunday Cont jarring on fish. PU to 130K let jars go off then pull up to 190K. RU slickline.Test lubricator to 2500 PSI. RIH w/2" bailer tag @ 7,906'WLM,bail to 7,908'WLM. POOH(no recovery). RIH w/2"bailer tag @ 7,905'WLM bail to 7,908'WLM POOH(no recovery). Rig down slickline. Jarring down on fish @ 60K,jarring up @ 135K,pulling up to 190K,after jarring on fish 20 cycles,fish came free. POOH with fish working pipe from 120K to 60K for 50'.Had 103K overpull above normal PU of 94K. POOH slow with 3.5" PH6 workstring and fish,easy on and off slips. Break down and rack back 4 3/4"collars and lay down jars. Lay down fish in v door, strap same. Clean and clear rig floor of pipe handling equipment. Recovered total of 15 JTS&1 GLM=622.85 ft. ETOF A/ 8,458.85. 14 bph loss. 11/24/14-Monday Service rig. Pickup 8 jts of 7 3/8"washpipe with BHA-8.25 Ocean wave shoe,8 jts 7-3/8 wash pipe,top bushing,x/o bumper jar, oil jar,(4)4-3/4 d.c. x/over=401.30. TIH w/3.5" PH6 workstring,slow going in with no issues.Tag @ 7,914'. Lay down 30 jts of 3.5" PH6 workstring to wash.TIH to 7,897'. RIH w/15 stands from derrick, Rig up stripper head and power swivel. Washing down f/7,897'dpm to 7,914'dpm.Washing on tight spot at 8,365'dpm. Pump lost prime.Swap over to small pump, pumping at 5 bpm while working on PZ-9 pump. Continue washing through tight spot at 8,365'dpm,2k wob,circ at 7.5 bpm w/1400 psi at 60 rpm, 3k to 6k torq.Washed thru tight spot at 7,914'w/2k wob.Depth at rpt time 8,365'dpm. 469 bbl loss for 12 hrs. Mr.Jim Regg with AOGCC,waived witness on 11/24/2014 at 11:00 AM on BOP test due on 11-26-14. 11/25/14-Tuesday Wash and rotate from 8,365'to 8,371',torque 6500 to 7000,7 BPM, 1460 PSI. Pumped 5 BBLs,NW50 pill(unable to make hole). Finish circ pill around @ 7 BPM, 1450 PSI. Rig down power swivel and stripper head. POOH w/3.5" PH6 workstring and 7 3/8" wash pipe BHA. POOH with BHA racking collars and washpipe in derrick. Make up new BHA-8.5"Tapered Mill,4.5 IF x 4.5 Reg xover,8.5"string mill,4.5 IF x 3.5 IF xover, bumper jars,oil jars,4 ea 4 3/4"drill collars. TIH w/3.5" PH6 workstring and mill assy, tag @ 7,898'DPM w/5K down. Rig up power swivel and stripper head. Wash and ream down from 7,898'to 7,900',torque 4K- 7K,60 RPM, 1500 PSI,7.5 BPM,tagged @ 7,914'.Wash and ream to 7,915'. Mr.Jim Regg with AOGCC,waived witness on 11/24/2014 at 11:00 AM on BOP test due on 11-26-14. 14 BBLs an hr loss. Hilcorp Alaska, LLC Hilcorp Alaska,LILA: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/26/14-Wednesday Cont milling through tight spots @ 7,898'to 7,900',7,909'to 7,915',with 8.5"string mill and 8.5"tapered mill.Torque 6500 to 7000,40 RPM, 1500 PSI,7.5 BPM (pickup 99K slack off 77K). Pump 20 BBLs NW50,drill express and spot on bottom. Rig down power swivel and stripper head. POOH w/3.5" PH6 workstring and mill assy BHA. Pull wear bushing. Install test plug and rig up test equipment. Fill BOPE with 8.5 FIW. Test BOP stack,choke,stand pipe and circ manifold,floor safety valves for 3.5"and 4.5" drill pipe to Hilcorp and AOGCC spec,250 PSI low and 2500 PSI high.Test from main station and function remote.No test failures. Witness waived by Mr.Jim Regg with AOGCC. Lay down test assy. Rig up wear bushing and set same.Run in 4 lock down pins. Make up 8.5"tapered mill assy and RIH. RIH w/3.5"PH6 workstring and new BHA, 8.5"Tapered mill,4.5 IF x 3.5 IF xover,bumper jars,oil jars,4 ea 4 3/4"drill collars. 11/27/14-Thursday Finish TIH with 3.5" PH6 workstring and 8.5"tapered mill,4.5 IF x 3.5 IF xover,bumper jars,oil jars,4 ea 4 3/4"drill collars.acc jars. Rig up stripper head and pick up power swivel. Wash and rotate through tight spots,7,914'to 7,916',8,027'to 8,032'.Work through several times.Cont wash and rotate from 8,032'to 8,365',98 SPM,60 RPM,7.5 BPM,torque 7000, 1480 PSI,WOB 2k, P/U 100K,S/0 78K. Cont washing and rotating through tight spot 8,365'to 8,367',60 RPM,7.5 BPM,torque 4-7K,98 SPM, 1550 PSI, 1-2k WOB. Rig down power swivel and stripper head. Lay down one joint. POOH with 3.5" PH6 workstring and tapered mill assy. Rack back collars and lay out 8.5"tapered mill assy.Secure block.Slip and cut 90'of 1 1/8"drill line. 11/28/14-Friday Finish slip and cut 90'of drill line. Reset crown-o-matic(ok).TIH w/3.5" PH6 workstring w/7.38"ocean wave shoe,8 is of 7 3/8" wash pipe,top bushing,4.5" FH x 3.5" IF xover, bumper jars,oil jars,4jt of drill collars,acc jars. Rig up stripper head and make up power swivel. Start to wash and rotate down hole. Start washing and rotating @ 8,341'DPM,no indication of tight spot. Cont a a-5 I washing and rotating @ 80 RPM,5-7K torque,7.5 BPM 1550 PSI,from 8,341'DPM to 8,382'tag tight spot @ 8,382'reamed down A Chs to 8,389'DPM. Tighten wash pipe on power swivel and grease same. Cont washing and rotating @ 80 RPM,5-7K torque,7.5 BPM 1550 PSI,from 8.389'DPM. Circ 10 BBLs pill on bottom @ 7.5 BPM 1550 PSI. Rig down power swivel and stripper head.Prepare to POOH. 11/29/14-Saturday POOH w/3.5" PH6 workstring and washpipe BHA.(7 3/8 shoe, 8jts of 7 3/8"wash pipe,top bushing,4.5" FH x 3.5" IF xover, bumper jars,oil jars,4jt of drill collars,acc jars)Burning shoe 100%worn out-carbide gone. Make up 8.5"rock bit BHA,4.5" IF x 4.5" REG BIT SUB,3.5" IF x 4.5" IF xover,bumper jars,oil jars,4jts of drill collars,acc jars and RIH w/3.5" PH6 workstring. TIH w/ 3.5" PH6 workstring tag @ 8,377'DPM. Rig up power swivel and stripper head. Break circ in rev,wash and ream @ 3.5 BPM 110 PSI,60 RPM 5-7K torque,no success.Circ well clean. Rig down power swivel and stripper head. POOH w/3.5"PH6 workstring and 8.5"rock bit BHA,4.5" IF x 4.5" REG BIT SUB,3.5" IF x 4.5" IF xover, bumper jars,oil jars,4jts of drill collars,acc jars. Rack back collars and lay out 8.5"rock bit BHA,4.5" IF x 4.5" REG BIT SUB,3.5" IF x 4.5" IF xover, bumper jars,oil jars,4jts of drill collars,acc jars. Clean and clear rig floor of misc equipment. Hilcorp Alaska, LLC HiIcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date D-27 50-733-20274-00 175-024 8/29/2014 12/2/2014 Daily Operations: 11/30/14-Sunday Clean and service rig. Make up mule shoe and TIH w/3.5" PH6 workstring tag @ 8,397'.Space out w/pups.Spotting end of tbg at 8,395 ft dpm. Rig up and displace with FIW @ 3.5 BPM,650 PSI until clean enough to RIH w/camera. Lay out 1 jt.spotting EOT at 8,363'dpm. Rig up a-line and test lubricator to 2500 PSI. RIH w/down hole camera on a-line and log from 8,363'to 8,391'.Only getting side shots,not able to see with down view shots. POOH w/ camera to clean,down hole lens. RIH w/ camera on a-line and log from 8,377'to 8,395'WLM.Only getting side view shots, unable to see with down view. POOH w/down hole camera. Rig down a-line. POOH w/3.5" PH6 workstring. 12/01/14-Monday Laid down 8 jts of 7 3/8"washpipe. Perform general maintenance while waiting on kill string. Clean around rig while waiting on kill string to arrive on location. Off load kill string and prod tree from boat. TIH w/3.5"8RD tbg(1,942')DPM,pickup 22K,slack off 22K,62 jts, 1-4'pup jt. Make up hanger and landing joint. Land hanger and run in lock down pins. Bleed down Koomey and Sf r nipple down BOPs. 12/02/14-Tuesday Finish nipple down. Kill HCR and riser. Prepare well head and install dry hole tree.Test void 5000 PSI 15 min(ok).Test dry hole tree 5000 PSI 15 min(ok). Clean well bay and install grating around D-27. Rig down high pressure lines,hydraulic hoses,unwire air compressor building. Move heaters,choke manifold house and choke manifold,come-a-long air compressor building out from under wing basket. Remove same. Rig down v-door,rig down walkway to driller shack,remove covers from beams,install skid jacks and prepare to skid from D-27. OF, T�� THE STATE 01A iA-6KA GOVERNOR SEAN PARNELL Dan Mar owe Operatioi is Engineer Hilcorp laska, LLC SCANNED NOV 1 4 2014 3800 Cei iterpoint Drive, Suite 1400 Anchorage. AK 99503 \'- 15- 02It Alaska 0-0. "-nd. Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: 4cArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-27 Slundry Number: 314-591 Dear Mr] Marlowe: Enclose 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 tho 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATEDI this -LZday of November, 2014. Encl. STATE OF ALASKA �5h ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED NOV 04 2014 A.0GCG 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program Suspend ❑ Plug Perforations ❑ Perforate F] Pull Tubing 0 Time Extension Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install ESP Ll 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 175-024 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20274-00 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 ❑ No 0 Trading Bay Unit / D-27 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): 11,101 9, 805 10, 960 9,683 10,960 10,881 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 400' Surface 3,127' 13-3/8" 3,127' 3,011' 3,090 psi 1,540 psi Intermediate Production 11,100' 9-5/8" 11,100 9,809' 5,750 psi 3,090 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schemiatic 4-1/2" 12.6# / L-80 9,937 Packers and SSSV Ty : Packers and SSSV MD (ft) and TVD (ft): Baker Model 3H Packe & Halliburton SSSV Packer 9,899' (MD) 8,728 (TVD) & SSSV 376' (MD) 376' (TVD) 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Pr gram ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development U Service ❑ 14. Estimated Date for 1 15. Well Status after proposed work: Commencing Operations: 11/4/2014 Oil El Gas ❑ WDSPL ❑ Suspended ❑ WINJ ElGINJ ❑ WAG E-1AbandonedE]Commission 16. Verbal Approval: Date: f i -� / i Represen ative: /' S 11` f i GSTOR ❑ SPLUG ❑ 17. 1 hereby certify tha the foregoing is true gind correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(Whilcorp.com Printed Name an we Title Operations Engineer Signature 41 Phone 907 283-1329 Date 11/4/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: a ��©� S�Cy- q l�S� S �, Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: e o__L4 0�- s APPROVED BY Approved by: 4 COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 (Revised 10/20 ) GR+G,-ItNA lq for 12 months from the date of approval. Attachments in Duplicate L RBE MS NOV 13 20 Well Work Prognosis Well: D-27 Hilrarp Alaska, LLC Date: 11/04/2014 Well Name: D-27 API Number: 50-733-20274-00 Current Status: SI Producer (Gas -Lift) Leg: Leg #A-1 (NE corner) Estimated Start Date: November 04, 2014 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 175-024 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 AFE Number: Current BHP: — 3,700 psi @ 9,450' TVD/9,690' MD 0.40 psi/ft, (7.7 ppg) mid perf of GZ & HK, 3/6/02 Max. Expected BHP: — 3,700 psi @ 9,450' TVD 0.40 psi/ft, (7.7 ppg) Recomplete same zones Max. Possible SP: 945 psi t Oriper — Brief Well Summa 6 /`s D-27 is a shut-in G and Hemlock zone producer with a gas -lift completion. This workover will remove the current completion, clean out the fill and complete it as an ESP. Work started on this well November 04, 2014 with the intent to convert it to an injector under sundry 314- 446. When approved work will transition to this Sundry per verbal agreement with Guy Schwartz. Procedure: 1. Skid rig and RU HAK Rig 1 over D-27. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and si HIGH. ZS�c `-T' f- " `( 3. RU E -line. Cut tubing in middle of first full joint above seals or as deep as possible (suspect to find obstruction at —6,900'. POOH and RD E -line. 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 5. POOH, LD tubing. 6. RIH latch onto tubing stub, release and POOH with seals and tail -pipe. 7. Mill and retrieve production packer. 8. Clean out fill to a PBD of +/-10,950'. Circulate with FIW to clean wellbore. POOH. 9. RU E -Line and run caliper log to +/- 9,950' 10. If tubing spool needs replaced, PU and RIH with RTTS / Storm packer, set same at 200' and hang off string. Pressure test to 1500 psi. Release from storm packer, POOH. Replace tubing spool. Retest all BOP breaks to 1,500 psi and chart. 11. PU and run 7-5/8" liner to above casing damage. 12. RU Cementing Company and cement 7-5/8" casing in place according to cementing procedure. WOC. 13. RU 7-5/8" cleanout assembly and clean out casing to —10,950. Circulate hole clean. POOH 14. Pressure the 7-5/8" casing on a chart recorder to 2,500 psi for 30 minutes. 15. RUE -line. RIH with Gamma Ray and CCL to 10,500'. Log out of hole running Gamma Ray and CCL. RD E -line. 16. PU TCP guns and RIH and re -perforate the G and Hemlock zones per the Perf Recommendation. 0 Hilcorp Alaska. LLC 17. After detonation, circulate perf gas, confirm well is static, POOH. 18. PU and run ESP completion. 19. Set BPV. NU tree, test same. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack Well Work Prognosis Well: D-27 Date: 11/04/2014 Hilcorp Alaska, LLC Fol FISH at Lost 12 WL To( Fishing Top of S RKB to TBG Hanger = 40.23' PBTD = 10,960' TD = 11,101' MAX HOLE ANGLE = 360 SCHEMATIC Dolly Varden Well: D-27 Completed: 04/12/1997 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 33" 40.23 Conductor 8,837' Tubing hanger with Cameron BPV profile Surf 400' 13-3/8" 61 K-55 BTC 12.515" Surf 3,127' 9-5/8" 40 N-80 BTC 8.835" Surf 2,953' 9-5/8" 47 N-80 BTC 8.681" 2,953' 8,860' 9-5/8" 47 P-110 BTC 8.681" 8,860' 11,100' Tubing: 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open 4-1/2" 12.6 L-80 AB Mod BTC 3.958" 1 Surf 9937' Perforation Data Zone Top MD Btm MD Jowelry Detail I_ DepthM Depth ID OD Rem 40.23 3.875 8,837' Tubing hanger with Cameron BPV profile 376' 3.813 7.500 Halliburton Series 10 SSSV 10,098' 3.968 7.000 Gas -Lift Mandrels 4-112" Daniels GLM2A @ 2,541', 4,126', 5,319', Open G-2 10,080' 6,073', 6,787', 7,336', 7,842', 8,305', 8,772', 9,237', 9,865' 9,899' 4.750 8.250 Baker model 3H packer 9-5/8"x 6"x 4.75" 9,923' 3.813 4.875 BakerX-Ni le 9,937' 4.012 5.200 WLREG / Shear Sub 10,960' 10,244' 1 8,999' 1 Cement Retainer acker consists of locator seal assembly wk16floafing seals, PBR, K -anchor, Baker 3H perm packer. MO extension Perforation Data Zone Top MD Btm MD Top TVD Btm TVD Date Status G-1 10,020' 10,040' 8,837' 8,855' 11/9/1997 Open G-2 10,080' 10,098' 8,891' 8,907' 11/9/1997 Open G-2 10,080' 10,090' 8,891' 8,900' 8/25/2003 Open G-3 10,146' 10,172' 8,951' 8,974' 11/9/1997 Open G-4 1 10,200' 10,244' 1 8,999' 9,039' 11/9/1997 Open G-4 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open H13-1 10,520' 10,580' 9,288' 9,342' 5/20/1997 Open H13-1,2 10,520' 10,545' 9,288' 9,311' 2/24/1989 Open HB -2 10,521' 10,578' 9,289' 9,341' 8/25/1979 Open HB -2 10,520' 10,580' 9,288' 9,342' 11/19/1982 Open 1-113-3 10,620' 10,644' 9,378' 9,400' 11/19/1982 Open 1-113-3 10,610' 10,640' 9,369' 9,396' 2/24/1989 Open HB -3 10,610' 10,645' 9,369' 9,401' 6/7/1992 Open HB -4 10,688' 10,784' 9,439' 9,525' 7/6/1975 Open HB -4 10,688' 10,784' 9,439' 9,525' 7/26/1979 Open HB -4 10,685' 10,785' 9,436' 9,526' 11/19/1982 Open HB -4 10,690' 10,710' 9,441' 9,459' 2/24/1989 Open HB -4 10,765' 10,795' 9,508' 9,535' 2/24/1989 Open HB -4 10,710' 10,765' 9,459' 9,508' 6/22/1991 Open HB -4 10,670' 10,690' 9,423' 9,441' 9/22/1991 Open HB -4 10,670' 10,790' 9,423' 9,530' 8/25/2003 Open HB -5 10,828' 10,928' 9,564' 9,654' 7/6/1975 Open 1-113-5 10,828' 10,928' 9,564' 9,654' 7/26/1979 Open HB -5 10,815' 10,845' 9,553' 9,580' 2/24/1989 Open HB -5 10,895' 10,905' 9,624' 9,633' 3/3/1991 Open HB -5 10,875' 10,895' 9,606' 9,624' 3/3/1991 Open HB -5 10,865' 10,875' 9,598' 9,606' 3/3/1991 Open HB -5 10,845' 10,865' 9,580' 9,598' 3/3/1991 Open HB -5 10,835' 10,845' 9,571' 9,580' 3/3/1991 Open HB -5 10,815' 10,835' 9,553' 9,571' 3/3/1991 Open HB -5 10,815' 10,850' 9,553' 9,584' 8/25/2003 1 Open HB -6 10,966' 10,992' 9,688' 9,712' 7/6/1975 1 Isolated REVISED: 2014-07-21 REVISED BY: JLL McArthur River Field Well: D-27 PROPOSED Completed: Future Hilcorp Alaska, LLC RKB to TBG Hanger = 39.70' DN Stage ( 6,485' HK$ PBTD=10,960' M=11,101' MAX HOLE ANGLE = 36° CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 33" 3 10,960' Conductor 8,837' 8,855' Surf 400' 13-3/8" 61 K-55 BTC 12.515" Surf 3127' 9-5/8" 40 N-80 BTC 8.835" Surf 2,953' 9-5/8" 47 N-80 BTC 8.681" 2,953' 8,860' 9-5/8" 47 P-110 BTC 8.681" 8,860' 11,100' G-3 29.7 L-80 VAMSLIJ-II 6.875" ±9,800' ±10,960' Tubing: 10,146' 10,172' 8,951' 8,974' 11/9/1997 Open G-4 9.2 L-80 SuperMax 1 2.992 Surf ±9,650' Perforation Data Zone Jewelry Detail NO. Depth ID (MD) OD Item 1 38.9' Tubing hanger 2 ±9,750' Bottom of ESP 3 10,960' Cement Retainer Perforation Data Zone To MD Btm MD Too IND Btm ND Date Status G-1 10,020' 10,040' 8,837' 8,855' 11/9/1997 Open G-1 ±10,032' ±10,046' ±8,847' ±8,860' Future G-2 ±10,085' ±10,095' ±8,895' ±8,904' Future G-2 10,080' 10,098' 8,891' 8,907' 11/9/1997 Open G-2 10,080' 10,090' 8,891' 8,900' 8/25/2003 Open G-3 1 ±10,145' ±10,165' ±8,950' ±8,968' Future G-3 10,146' 10,172' 8,951' 8,974' 11/9/1997 Open G-4 ±10,194' ±10,234' ±8,994' ±9,030' Future G-4 10,200' 10,244' 8,999' 9,039' 11/9/1997 Open G-4 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open HK -1 10,520' 10,580' 9,288' 9,342' 5/20/1997 Open HK - 1,2 10,520' 10,545' 9,288' 9,311' 2/24/1989 Open HK -2 10,521' 10,578' 9,289' 9,341' 8/25/1979 Open HK -2 10,520' 10,580' 9,288' 9,342' 11/19/1982 Open HK -2 ±10,530' ±10,580' ±9,297' ±9,342' Future HK -3 ±10,613' ±10,646' ±9,372' ±9,401' Future HK -3 10,620' 10,644' 9,378' 9,400' 11/19/1982 Open HK -3 10,610' 10,640' 9,369' 9,396' 2/24/1989 Open HK -3 10,610' 10,645' 9,369' 9,401' 6/7/1992 Open HK -3 ±10,669' ±10,705' ±9,422' ±9,454' Future HK -4 10,688' 10,784' 9,439' 9,525' 7/6/1975 Open HKA 10,688' 10,784' 9,439' 9,525' 7/26/1979 Open HKA 10,685' 10,785' 9,436' 9,526' 11/19/1982 Open HK -4 10,690' 10,710' 9,441' 1 9,459' 2/24/1989 Open HK -4 10,765' 10,795' 9,508' 9,535' 2/24/1989 Open HK -4 10,710' 10,765' 9,459' 9,508' 6/22/1991 Open HK -4 10,670' 10,690' 9,423' 9,441' 9/22/1991 Open HK -4 10,670' 10,790' 9,423' 9,530' 8/25/2003 Open HK -5 ±10,817' ±10,849' ±9,555' ±9,583' Future HK -5 10,828' 10,928' 9,564' 9,654' 7/6/1975 Open HK -5 10,828' 10,928' 9,564' 9,654' 7/26/1979 Open HK -5 10,815' 10,845' 9,553' 1 9,580' 2/24/1989 Open HK -5 ±10,863' ±10,886' ±9,596' ±9,616' Future HK -5 10,895' 10,905' 9,624' 9,633' 3/3/1991 Open HK -5 10,875' 10,895' 9,606' 9,624' 3/3/1991 Open HK -5 10,865' 10,875' 9,598' 9,606' 3/3/1991 Open HK -5 10,845' 10,865' 9,580' 9,598' 3/3/1991 Open HK -5 10,835' 10,845' 9,571' 9,580' 3/3/1991 Open HK -5 10,815' 10,835' 9,553' 9,571' 3/3/1991 Open HK -5 10,815' 10,850' 9,553' 9,584' 8/25/2003 Open HK -6 10,966' 10,992' 9,688' 9,712' 7/6/1975 Isolated Updated By: JLL 11/04/14 11dromp tla*ka. LIA Dolly Varden D-27 13 3/8 X 9 5/8 X 41/2 Tree, Block, CIW-F, 115M X 41/16 5M run X 3 1/8 5M wing, double master and swab valve, EE trim prepped for 7" FBB type hanger neck, w/ % control line exit Tubing head, CIW-DCB, 13 5/8 3M X 115M, w/ 2- 2 1/16 5M 550, X bottom Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Dolly Varden Platform D-27 Current 06/24/2014 Tubing hanger, CIW-DCB- FBB, 11 X 4 A EUE 8rd lift X 4 X IBT susp, w/ 4" type H BPV, 1/8 non continuous control line, 7" extended neck prep BHTA, CIW, w/ internal knockup cap, 41/16 5M FE 2 1/16 5M FE, AA trim 2 1/16 5M FE, AA trim IlilrnrP .�la+kn. 1.1.(. Dolly Varden D-27 133/8X95/8X31/2 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 3 1/8 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- 21/16 5M EFO BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union Dolly Varden Platform D-27 Proposed 11/04/2014 Tubing hanger, CIW-DCB-ESP, 11 X 3 % EUE lift and susp, w/ 3" type H BPV profile, 5'/4 EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, WKM-M, 3 1/8 5M FE, w/ MA -16 operator Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5 Y4 ESP neck, 2-'Y2 npt continuous control line ports Valve, WKM-M, 2 1/16 SM FE, HWO, DD Qty 2 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Hilcorp Alaska. 1.1.1: 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.) Hilcorp 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 ROPE 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 HAK #1 BOP Test Procedure Hilcorp Alaska, LLC 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 Hilcorp AlaAa. l.l.c Attachment #1 Diagram A: Dolly Varden BOP stack and Riser Arrangement — Typical for Single Completion f 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 Hilcorp Alaska. LIA Diagram B: Dolly Varden Choke Manifold Hilcorp HAK #1 BOP Test Procedure Attachment #1 From Bop Choke Line 2 1/16 5M Unibolt Flange FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULA- - - - - - FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DObVN TUBING, UP CASING ANNULAS 'THE LONG -A-AY" L'i ST o vtr Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 04, 2014 1:34 PM To: 'Dan Marlowe' Cc: Juanita Lovett; Ted Kramer Subject: RE: D-27 PTD 175-024 Sundry request Dan, As we discussed, you have verbal approval to move onto D -27 to perform the scope of work under„new attached sundry (run 7 5/8” scab liner, and ESP). This is a change from the previously approved sundry 314- ji(4 in which the well was going to be converted into an injector from a Gas Lifted producer. Sundry 314-446 will be retracted once this updated sundry to run ESP and keep well a development is approved. (Both sundries, t operations are the same up to the point of TCP perforating. ) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALRY 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 [mailto:dmarlowe@hilcorp.com] Sent: Tuesday, November 04, 2014 12:11 PM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett; Ted Kramer Subject: D-27 PTD 175-024 Sundry request Guy As discussed this morning we would like to transition work from Sundry 314-446 to the attached sundry application which will be delivered via courier in the next hour or two. We had intended to convert this well to an injector but now need to run an esp completion as we were not successful with our D-40 work. We have already began work under Sundry 314-446 as of this morning and will be BOP testing this evening I request verbal approval to proceed thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 THE STATE r GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 \'I5 -02j Al ski C il a. 1c Gari 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.2767542 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pool, TBU D-27 Sundry Number: 314-446 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. t - DATED this day of August, 2014 Encl. Sincerely, Cathy P. Foerster Chair SCANNED q STATE OF ALASKA g11Sl��i ALASKA OIL AND GAS CONSERVATION COMMISSION Q� APPLICATION FOR SUNDRY APPROVALS ,)(-I nor I)r I)nn DECEIVED JUL 2 9 2014 1. Type of Request: Abandor ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing [D Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install Liner & F21 Convert to Infector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development F±) Stratigraphic ❑ Service ❑ 175-024, 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20274-00 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 ❑ No 0 Trading Bay Unit / D-27 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): -11,101 -9,805 11,052 9,760 10,960 . 10,881 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 400' Surface 3,127' 13-3/8" 3,127' 3,011' 3,090 psi 1,540 psi Intermediate Production 11,100' 9-5/8" 3,127' 9,805' 5,750 psi 3,090 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-80 9,937 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker "SB -3A" Packer & SSSV (N/A) Packer 9,899' (MD) 8,728 (TVD) & SSSV (N/A) 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ❑ Service Or 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/15/2014 Oil ❑ 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 hilcor .com Printed Name Dan Marlowe Title Operations Engineer i�/%,_-ItL—Phone Si natu 907 283-1329 Date 7/28/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test R Mechanical Integrity Test [J Location Clearance ❑ Other: L_ y K 90'P tis f a.«� v�r9 w i �•. i� l a � 5 � G(l f � ►� -�- �j',er�; a .. � � Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: 16 - y f, 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 (Revised 10 o12) Appro a c t i vNIfAlmonths from th of proval.Attarh Submit Form and FibmpupAOG 18 2 Hileorp Alaska, LLC Well Work Prognosis Well: D-27 Date: 07/28/2014 Well Name: D-27 API Number: 50-733-20274-00 Current Status: SI Producer (Gas -Lift) Leg: Leg #A-1 (NE corner) Estimated Start Date: August 15, 2014 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 175-024 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 AFE Number: Good cement above 10,240' 50-733-20215-01 176-074 Current BHP: Max. Expected BHP: Max. Possible SP: Brief Well Summa — 3,700 psi @ 9,450' TVD/9,690' MD 0.40 psi/ft, (7.7 ppg) mid perf of GZ & HK, 3/6/02 — 3,700 psi @ 9,450' TVD 0.40 psi/ft, (7.7 ppg) Recomplete same zones 945 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) D-27 is a shut-in G and Hemlock zone producer with a gas -lift completion. This workover will remove the current completion, clean out the fill and complete it as an injector with plastic lined tubing. AOR (status of wells within % mile radius of injection zone): API WellNo Permit WellNumber Current Status Containment Good cement from 10,055- 50-733-20274-00 175-24 D-27 prod 10,065' * CBL 6/26/75 Good cement from 10,663- 50-733-20068-00 167-080 D-01 prod 10,712' CBL 2/24/68 Good cement above 10,240' 50-733-20215-01 176-074 D-31RD prod CBL 2/2/76 640 sx cement + 30 bbls of scavenger cement in 9 5/8" 50-733-20195-02 191-011 D-47 prod 4/4/91 Good cement in 7" 10,710- 50-733-20132-60 199-071 D-48 prod 10,190', bad cement in 9 5/8" Procedure: 1. 2. 3. 4. 5. 6. � C,vhcv. 7"h c Skid rig and RU HAK Rig 1 over D-27. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. RU E -line. Cut tubing in middle of first full joint above seals or as deep as possible (suspect to find obstruction at —6,900'. POOH and RD E -line. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. POOH, LD tubing. RIH latch onto tubing stub, release and POOH with seals and tail -pipe. 416�rod,'clva., l��o/ of'ollnr --d y 3o '501p e"'44 4 040p'" iwed/ r,,.�f S4,1r- /"? -'h X.,r� 20os ` C041��� re cow tae Hileorp Alaska, LLC Well Work Prognosis Well: D-27 Date: 07/28/2014 7. Mill and retrieve production packer. 8. Clean out fill to a PBD of +/-10,950'. Circulate with FIW to clean wellbore. POOH. 9. PU retrievable test packer and RIH to +/-9,900'. Set packer, test casing to 2,500 psi and chart for 30 minutes. Oil" 10. POOH 200' and PU storm packer. RIH and set same at 200' and hang off string. Pressure test to 2,500 psi and chart. Release from storm packer, POOH. Replace tubing head_Test all flange breaks to 2,500 + psi and chart. i" 11. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. 12. PU TCP guns and RIH and re -perforate the G and Hemlock zones per the Perf Recommendation. 13. After detonation, circulate perf gas, confirm well is static, POOH. /j 14. PU injection packer and 4-1/2" plastic lined tubing. RIH with packer at ±9,900' within at 200' of top perforation. S� 15. Spot 1-2% by volume Packer fluid on backside. 16. Land the tubing hanger and set packer. 17. Conduct WO MIT, pressure test annulus to 2,500 psi and chart for 30 minutes. 18. Set BPV. NU tree, test same. 19. Place well on injection. Well is expected to take +/-5,000 bwpd at full header pressure and new perforations. 20. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack D-15 I HILCORP ALASKA, LLC MCARTHUR RIVER FIELD FEET WELL SYMBOLS - Abandoned Water Injector D&A D-27 Measured Distances Gas Well • Injection Well • oil Well X Plugged BAbandoned Oil W I Surface Location From: shut-Inoawell -Take from platform coordinates r Shut-in Water Injector REMARKS Black Dot - top G Zone To Middle Kenai G From p Well Symbol - base Hemlock - - --- ------ - West Section Line 2729' May 7. 2014 - South Section Line 4624' D-41 - Bottom Hole Location From - West Section Line 3082' - South Section Line 4897' � I i -- - --1-----'-- - 7RD i D-17 D-04 D D-25RD Dolly Varden 0 SCHEMATIC well: D-27 Completed: 04/12/1997 Hileorp Alaska, LLC 11t FISH at Lost 12i WL Toc Fishing Top of S RKB to TBG Hanger = 39.70' Tree connection = 4-1/2" 8rd PBTD = 10,960' TD = 11,101' MAX HOLE ANGLE = 36° CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 33" 10,020' Conductor 8,837' 6,073', 6,787', 7,336', 7,842', 8,305', 8,772', 9,237', 9,865' Surf 400' 13-3/8" 61 K-55 BTC 12.515" Surf 3127' 9-5/8" 40 N-80 BTC 8.835" Surf 2,953' 9-5/8" 47 N-80 BTC 8.681" 2,953' 8,860' 9-5/8" 47 P-110 BTC 8.681" 8,860' 11,100' Tubing: 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open 4-1/2" 12.6 L-80 ABMBTC 3.958" Surf 9937' Perforation Data Zone Jeweiry Detail 1. Death Death ID - MD VD - OD Item - 38.9' Tubing hanger with Cameron BPV profile 338' 3.813" Camco TRDP-4A w/ 3.813" profile w/ DB -6 Lock 10,020' Gas -Lift Madnrels 4-1/2" Danials GLM2A @ 2,541', 4,126', 5,319', 8,837' 6,073', 6,787', 7,336', 7,842', 8,305', 8,772', 9,237', 9,865' 9,899' Baker "SB -3A" w/ 11.5' seal assb & 6' MOE 9,923' 3.813" Otis 'X"-Nippleprofile ID = 3.813" 9,937' WLREG 10,960' Cement Retainer )cker consists of locator seal assembly w\1 5'floating seals, PBR, K -anchor, Baker 3H perm packer. MO extension Perforation Data Zone Tom MD Btm MD Top TVD Btm TVD Date Status G-1 10,020' 10,040' 8,837' 8,855' 11/9/1997 Open G-2 10,080' 10,098' 8,891' 8,907' 11/9/1997 Open G-2 10,080' 10,090' 8,891' 8,900' 8/25/2003 Open G-3 10,146' 10,172' 8,951' 8,974' 11/9/1997 Open G-4 1 10,200' 10,244' 1 8,999' 9,039' 11/9/1997 Open G-4 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open HB -1 10,520' 10,580' 9,288' 9,342' 5/20/1997 Open HB -1,2 10,520' 10,545' 9,288' 9,311' 2/24/1989 Open HB -2 10,521' 10,578' 9,289' 9,341' 8/25/1979 Open HB -2 10,520' 10,580' 9,288' 9,342' 11/19/1982 Open HB -3 10,620' 10,644' 9,378' 9,400' 11/19/1982 Open HB -3 10,610' 10,640' 9,369' 9,396' 2/24/1989 Open HB -3 10,610' 10,645' 9,369' 9,401' 6/7/1992 Open HB -4 10,688' 10,784' 9,439' 9,525' 7/6/1975 Open HB -4 10,688' 10,784' 9,439' 9,525' 7/26/1979 Open HB -4 10,685' 10,785' 9,436' 9,526' 11/19/1982 Open HB -4 10,690' 10,710' 9,441' 9,459' 2/24/1989 Open HB -4 10,765' 10,795' 9,508' 9,535' 2/24/1989 Open HB -4 10,710' 10,765' 9,459' 9,508' 6/22/1991 Open HB -4 10,670' 10,690' 9,423' 9,441' 9/22/1991 Open HB -4 10,670' 10,790' 9,423' 9,530' 8/25/2003 Open HB -5 10,828' 10,928' 9,564' 9,654' 7/6/1975 Open HB -5 10,828' 10,928' 9,564' 9,654' 7/26/1979 Open HB -5 10,815' 10,845' 9,553' 9,580' 2/24/1989 Open HB -5 10,895' 10,905' 9,624' 9,633' 3/3/1991 Open HB -5 10,875' 10,895' 9,606' 9,624' 3/3/1991 Open HB -5 10,865' 10,875' 9,598' 9,606' 3/3/1991 Open HB -5 10,845' 10,865' 9,580' 9,598' 3/3/1991 Open HB -5 10,835' 10,845' 9,571' 9,580' 3/3/1991 Open HB -5 10,815' 10,835' 9,553' 9,571' 3/3/1991 Open HB -5 10,815' 10,850' 9,553' 9,584' 8/25/2003 Open HB -6 10,966' 10,992' 9,688' 9,712' 7/6/1975 Isolated REVISED: 2014-07-21 REVISED BY: JLL Q Flileorp Alaska, LLC RFB to TBG Hanger = 39.70' PBTD =10,960' TD =11,101' MAX HOLE ANGLE = 36° 0'6~ PROPOSED ✓ McArthur River Field Well: D-27 Completed: Future CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 33" Tubing hanger Conductor ±9,900' Packer Surf 400' 13-3/8" 61 K-55 BTC 12.515" Surf 3127' 9-5/8" 40 N-80 BTC 8.835" Surf 2,953' 9-5/8" 47 N-80 BTC 8.681" 2,953' 8,860' 9-5/8" 47 P-110 BTC 8.681" 8,860' 11,100' 7-5/8" 29.7 L-80 VAMSLIJ-II 6.875" ±9,800' ±10,960' Tubing: 10,146' 10,172' 1 8,951' 8,974' 11/9/1997 1 Open 4-1/2" 11.6 L-80 TPL4040 Poly Lined 3.40 Surf ±9,922' Perforation Data Zone To MD Jewelry Detail NO. DMS) ID OD Item 1 38.9' Tubing hanger 2 ±9,900' Packer 3 ±9,915' "X" -Nipple 4 ±9,922' WLEG 5 10,960' Cement Retainer Perforation Data Zone To MD Btm MD To TVD BtmTVD Date Status G-1 10,020' 10,040' 8,837' 8,855' 11/9/1997 Open G-1 ±10,030' ±10,050' ±8,846' ±8,864' Future G-2 ±10,072' ±10,095' ±8,884' ±8,904' Future G-2 10,080' 10,098' 8,891' 8,907' 11/9/1997 Open G-2 10,080' 10,090' 8,891' 8,900' 8/25/2003 Open G-3 ±10,146' ±10,167' ±8,951' ±8,970' Future G-3 10,146' 10,172' 1 8,951' 8,974' 11/9/1997 1 Open GA ±10,192' ±10,241' ±8,992' ±9,037' Future G-4 10,200' 10,244' 8,999' 9,039' 11/9/1997 Open G-4 10,190' 10,220' 8,990' 9,018' 8/25/2003 Open G-5 ±10,334' ±10,359' ±9,121' ±9,143' Future G-5 ±10,375' ±10,400' ±9,158' ±9,180' Future HK -1 1 10,520' 10,580' 9,288' 9,342' 5/20/1997 Open HK - 1,2 10,520' 10,545' 9,288' 9,311' 2/24/1989 Open HK -2 10,521' 10,578' 9,289' 9,341' 8/25/1979 Open HK -2 10,520' 10,580' 9,288' 9,342' 11/19/1982 Open HK -2 ±10,523' ±10,580' ±9,291' ±9,342' Future HK -2 ±10,593' ±10,598' ±9,354' ±9,358' Future HK -3 ±10,613' ±10,648' ±9,372' ±9,403' Future HK -3 10,620' 10,644' 9,378' 9,400' 11/19/1982 Open HK -3 10,610' 10,640' 9,369' 9,396' 2/24/1989 Open HK -3 10,610' 10,645' 9,369' 9,401' 6/7/1992 Open HK -3 ±10,670' ±10,713' ±9,423' ±9,462' Future HK -4 10,688' 10,784' 9,439' 9,525' 7/6/1975 Open HK -4 10,688' 10,784' 9,439' 9,525' 7/26/1979 Open HK -4 10,685' 10,785' 9,436' 9,526' 11/19/1982 Open HK -4 10,690' 10,710' 1 9,441' 9,459' 2/24/1989 1 Open HK -4 ±10,758' ±10,790' ±9,502' ±9,530' Future HK -4 10,765' 10,795' 9,508' 9,535' 2/24/1989 Open HK -4 10,710' 10,765' 9,459' 9,508' 6/22/1991 Open HK -4 10,670' 10,690' 9,423' 1 9,441' 9/22/1991 Open HK -4 10,670' 10,790' 9,423' 9,530' 8/25/2003 Open HK -5 ±10,817' ±10,887' ±9,555' ±9,617' Future HK -5 10,828' 10,928' 9,564' 9,654' 7/6/1975 Open HK -5 10,828' 10,928' 9,564' 9,654' 7/26/1979 Open HK -5 10,815' 10,845' 9,553' 9,580' 2/24/1989 Open HK -5 10,895' 10,905' 9,624' 9,633' 3/3/1991 Open HK -5 ±10,898' ±10,929' ±9,627' ±9,655' Future HK -5 10,875' 10,895' 9,606' 9,624' 3/3/1991 Open HK -5 10,865' 10,875' 9,598' 9,606' 3/3/1991 Open HK -5 10,845' 10,865' 9,580' 9,598' 3/3/1991 Open HK -5 10,835' 10,845' 9,571' 9,580' 3/3/1991 Open HK -5 10,815' 10,835' 9,553' 9,571' 3/3/19 Open HK -5 10,815' 10,850' 9,553' 9,584' 8/25/200391 Open HK -6 10,966' 10,992' 9,688' 9,712' 7/6/1975 Isolated Updated By: JUL 07/21/14 . H Hilrm? : laRka. D.l.0 Dolly Varden D-27 13 3/8 X 9 5/8 X 41/2 Tree, Block, CIW-F, 11 5M X 4 1/16 5M run X 3 1/8 5M wing, double master and swab valve, EE trim prepped for 7" FBB type hanger neck, w/ %: control line exit Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M 550, X bottom Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Dolly Varden Platform D-27 Current 06/24/2014 Tubing hanger, CIW-DCB- FBB, 11 X 4 % EUE 8rd lift X 4 M IBT susp, w/ 4" type H BPV, 1/8 non continuous control line, 7" extended neck prep BHTA, CIW, w/ internal knockup cap, 41/16 5M FE 2 1/16 5M FE, AA trim 2 1/16 5M FE, AA trim Hilrn� :►larkp. 6Lt: Dolly Varden D-27 13 3/8 X 9 5/8 X 4 1/2 Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, FF trim Valve, Master, WKM-M, 41/16 5M FE, HWO, FF trim Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO BHTA, Bowen, 41/16 5M X 7"-5 SA Bowen Union Full Stainless Steel Dolly Varden Platform D-27 Proposed 06/24/2014 Tubing hanger, SME -CL, 11 X 4'/: EUE lift and 4 %: TC -2 susp, w/ 4" Type H BPV profile, 2- 3/8 CCL, 6 X extended neck, 17-4PH stainless steel Valve, Wing, WKM-M, 3 1/8 5M FE, w/ 15" Safeco operator, FF trim Full Stainless Steel Adapter, Seaboard, 11 5M FE X 4 1/16 5M, w/ 6 X pocket, 2-'/: CCL exits, Full Stainless Steel Valve, CIW, 2 1/16 5M, HWO, AA liilev�r� :1Lc�ka, T�1_t: Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 Hilcorp Alaska, LLC 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 (ECT) 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.) In 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 HAK #1 BOP Test Procedure H.lco.p Alaska. HT 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 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Hilcorp HAK #1 BOP Test Procedure HaeArp Alaska. ta.c Attachment #1 Diagram A: Dolly Varden BOP stack and Riser Arrangement — Typical for Single Completion Dolly Varden Platform 2014 BOP Stack (HAK #1) �.1 01/10/2014 Dolly Varden Platform 2014 Workovers 80P Drawing (HAK #1) Quail Tool Rental Stack Hilcorp Alaska. LH, Diagram B: Dolly Varden Choke Manifold Hilcorp HAK #1 BOP Test Procedure Attachment #1 From Bop Choke Line 2 1/16 5M Unibolt Flange Hileorp Alaska, LLC HiboqoHAK#1 BOP Test Procedure Attachment #1 HibmrpHAK#1 BOP Test Procedure Attachment #1 CL 00 0 Roby, David S (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, August 04, 2014 2:54 PM To: Roby, David S (DOA); Dan Marlowe Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Wallace, Chris D (DOA); Trudi Hallett; James Young Subject: RE: Sundry applications to convert wells TBU D-27 (PTD 17S-024) and TBU K -LORD (PTD 174-047) to injectors Thanks Dave. We are looking into this and what is required. After we work through it here, I may be calling you for some clarification. Rest assured, we want to get it correct. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 From: Roby, David S (DOA) [mailto:dave.robyaalaska.gov] Sent: Monday, August 04, 2014 2:24 PM To: Ted Kramer; Dan Marlowe Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Wallace, Chris D (DOA) Subject: Sundry applications to convert wells TBU D-27 (PTD 175-024) and TBU K-10RD (PTD 174-047) to injectors Ted and Dan, Unless I am misreading your applications to convert the subject wells from long term shut in producers to injectors it appears that the wells will be setup for commingled injection into the Middle Kenai G and Hemlock Oil Pools. 20 AAC 25.215(c) prohibits commingled injection in a wellbore unless it has been authorized by order of the AOGCC. Therefore, in order to Complete the wells as planned and conduct commingled injection you will need to apply for an order from the AOGCC, and such application is subject to public notice and hearing/comment. You can complete the proposed work, once the AOGCC approves your sundry applications that is, but would not be allowed to put the wells into commingled injection service until an order authorizing such is issued. If you have any questions on this matter please let me know. Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, August 05, 2014 12:58 PM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett; Ted Kramer Subject: RE: D-27 RWO ( PTD 175-024) Guy Please replace steps 9-11 with the following • RU a -line and run caliper log to 9,950' ,1✓' PU and RIH with RTTS / Storm packer, set same at 200' and hang off string. Pressure test to 1500 psi. Release from storm packer, POOH. Install new casing spool. Retest all BOP breaks to 2,500 psi and chart. 'l'ti PU and run 7-5/8" liner to above casing damage. • RU Cementing Company and cement 7-5/8" casing in place according to cementing procedure. WOC. • RU 7-5/8" cleanout assembly and clean out casing to 10,950. Circulate hole clean. POOH • Pressure the 7-5/8" casing on a chart recorder to 2,500 psi for 30 minutes. • RU E -line. RIH with Gamma Ray and CCL to 10,500'. Log out of hole running Gamma Ray and CCL. RD E -line. From: Schwartz, Guy L (DOA) [ naiIto: guy.schwa rtz@alaska.gov] Sent: August 05, 2014 8:57 AM To: Dan Marlowe Subject: D-27 RWO ( PTD 175-024) Dan, In reviewing the procedure for D-27 there is no mention of running the 7 5/8" scab liner(after step #11). Do you have modified procedure you can send over with those details... including cement data. You can either just send me the info to insert in the sundry or redo the procedure. 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 1 or (Guy.schwartz@alaska.aov). STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of request Abandon r-t Suspend [] Alter Casing [] RepairWell [] Change Approved Program [] PulITubing [] Operation Shutdown [] Plug Perforations [] Perforate New Pool [] Re-perforate X Variance r~ Stimulate [] Time Extension Q Re-enter Suspended Well [] Annular Disposal [] Other [] 2. Operator Name: Union Oil Company of California/Unocal 3. Address: PO Box 19-0247, Anchorage, AK 99519 7. KB Elevation (ft): 106' KB above MSL 8. Property Designation: 11. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Dolly Varden Platform 11,101' Feet true vertical 9,805' Feet measured 11,052' Feet rue vertical 9,760' Feet I 4. Current Well Class QQI5.1 Permit to Dril175_24Number: Development X Exploratory 6. APl Number: Statigraphic [] Service 50-733-20274 9. Well Name and Number D-27 10. Field/Pool(s): Trading Bay Unit Length Size MD 3,127' 13-3/8" Production 11,100' 9-5/8" Liner 3,127 Plugs (measured) Junk (measured) Cement Retainer @ 10,960' TVD Burst Collapse 3,011 962 1540 11,100 9,805 916 3090 Perforation depth: measured 10,080 - 10,850' true vertical 8,890-9,584 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", L-80 @ 4,150' Baker "SB-3A" w/11.5' seal assby & 6' MOE RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) n/a Treatment description including volumes used and final pressure OCT 2; 8"' '° Gas Cons. [;;omrnissiot'~ Anchorafl~ 13 Representative Daily Average Production or Iniection Data Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations: X OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 401 1,634 93 870 210 230 389 92 938 260 15. Well Class after proposed work: [] Exploratory X Development [] Service 16. Well Status after proposed work: WAG [] GINJ [] Oil [] Gas X WINJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Printed Name: Steve Tyler Sundry Number: Title: Workover Foreman/Engineering Technician Phone: (907) 263-7649 Date:-~/.1,SH~3- Form 10-404 Revised 2/2003 ORIGINAL , 'o:o0 12: 12:30 19:301 Arrived platform. Orientation and rig up meeting. :Spot equipment, rig up, and prep to start perforating tomorrow AM when new day crew arrives. 8/25/2003 From' To :::.'0:00 J 6:36 6:36 I 7:30 7:30 9:00 13:30 9:00 SDFN ! i Discussed tiein logs with Anchorage. First RIH will be with gun/gamma and perf gun as originally intended. PJSM with new crews. Rig up tools and pressure tested to 500/2500. 13:30 ~ WIH with GR/CCL and 30 foot gun (2 7/8, 6 shot per foot). Slow going breaking in new line. Tied in with Jewelry, upholeGR, and lower DIL. 16:00 i Fired gun #1. Perforated 10,820 - 10,850 (30 feet of HB5). Logged up, flagged line, and POOH. 18:48 iWlH with GR/CCL and 20 foot gun loaded for 18 feet. Tagged fill at 10,847 (Lost 4 feet from prior run). Tied in and flowed well. 19:48 i Fired gun #2. Perforated 10,815 - 10,833 (18 feet of HB5). Logged up, reflagged line, and POOH. I i 19:48 22:00 i WIH with GR/CCL and 30 foot gun. Tied in and flowed well. ::22:00 23:54 i Fired gun #3. Perforated 10,760 - 10,790 (30 feet of HB4). Logged up, reflagged line, and POOH. Rewired head. 8~26~2003 From" ..... 0:06 ...... "- FOo ................... 7:15 10:09 ............. 11:09 12:39 .......... 13:39 To :6:00 7:15 8:27 10!09 11:09 12:39 13:39 15:03 5:03 :16:03 '"~6:03 ': 18:03 "-18:'6'§'"' 19:45 .................... 9:45 23:45 . ................ SDFN SDFN i 1 i I PJSM. Rig up for next perf run. WIH with 30 foot gun ~ and GR/CCL. Tied in and flowed well. No problems. Fired gun #4. Perforated 10,730 - 10,760 (30). Logged up, flagged line, and POOH. WIH with 30 foot gun #5 and GR/CCL. Tied in and flowed well. No problems. Fired gun #5. Perforated 10,700 - 10,730 (30). Logged up, flagged line, and POOH. WIH with 30 foot gun #6 and GR/CCL. Tied in and flowed well. Fired gun #6. Perforated 10,670 - 10,700 (30). Logged up, flagged line, and POOH. WIH with 30 foot gun #7 and GR/CCL. Tied in and flowed well Fired gun #7. Perforated G4 zone, 10,190 - 10,220 (30). Logged up, flowed well, and POOH. WIH with 10 foot gun #8 and GR/CCL. Tied in and flowed well Fired gun #8. Perforated G2 zone, 10,080 - 10,090 (10). Logged up, flowed well, and POOH. Recap Perforating: Guns were 2 7/8 PJHC, 6 shot/foot, 60 degree phasing. (Tagged fill at 10,851 and 10,847) HB5 · 10,820 - 10,850 (30) and 10,815-10,833 (18) HB4' 10,670 - 10,790 (120) G4 · 10,190 - 10,220 (30) G2 · 10,080- 10,090 (10) page 1 UNOCAL ) Trading Bay Unit Dolly Varden Platform Well # D-27 Current Completion 4/12/97 FISH at 10,881' Lost 12/29/98 WL Tools, X-Lock, and Fishing Tools. RKB to TBG Hanger = 39.70' Tree connection = 4-1/2" 8rd CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Conductor Surf 400' 13-3/8" 61 K-55 BTC Surf 3127' 9-5/8" 40/47 N80/Pll0 BTC Surf 11,100' Tubing: 4-1/2" 12.6 L-80 ABMBTC Surf 9937' JEWELRY DETAIL NO. Depth Item 1. 38.90 2. 338' 3. 4. 9,899' 5. 9,923' 6. 9,937' Tubing hanger with Cameron BPV profile Camco TRDP-4A w/3.81Y' profile w/DB-6 Lock Gas-Lift Madnrels 4-1/2" Danials GLM2A ~ 2,541', 4,126', 5,319', 6,073', 6,787', 7,336', 7,842', 8,305', 8,772', 9,237', 9,865' Baker "SB-3A" w/11.5' seal assby & 6' MOE Otis "X"-Nipple profile (ID = 3.813") WLREG Packer consists of locator seal assembly w\l 5' floating seals, PBR, K- anchor, Baker 3H perm packer. MO extension G-Zone Hemlock Top of Sand ~ 10949' TOP PERFORATION DATA BTM ZONE SPF DATE COMMENTS 10,020 10,060 G-1 10,070 10,100 G-2 10,140 10,172 G-3 10,190 10,247 G-4 10,520 10,580 B-l,2 10,610 10,644 B-3 10,685 10,795 B-4 10,815 10,928 B-5 10,966 10,992 B-6 Isolated with CIBP PBTD = 10,961' TD = 11,101' MAX HOLE ANGLE = 36° O:\OOE\OOE Fields\TBU\Dolly\Wells\D-27\D-27 Schm 03-08-02 iREVISED: DRAWN :BY: PAR MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~7 · 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 Rv./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Data Pilots SV SSV Well Type Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code OAS 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 OILi D-17RD 1810230! 110 80 80 P P 43 OILi D-18 1690040 800 700 7001 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 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 OIL 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. 6-22-00jcl STATE OF ALASKA ALASKA O£L- 74ND GAS CONSERVATION C -)MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 106' KB above 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-1 Cond. #1, Dolly Varden Platform 8. Well number 758' FSL, 1,206' FWL, Sec. 6, T8N, R13W, SM D-27 At top of productive interval 9. Permit number/approval number 522' FNL, 2,022' FEL, Sec. 6, TSN, R13W, SM 75-24 At effective depth 10. APl number 50- 733-20274-00 At total depth 11. Field/Pool 351' FNL, 1,825' FEL, Sec. 6, T8N, R13W, SM McArthur Field Hem/Mid Kenai "G" 12. Present well condition summary Total depth: measured 11,101' feet Plugs (measured) true vertical 9,805' feet Effective depth: measured 11,052' feet Junk (measured) true vertical 9,760' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3,127 13-3/8" 2,900 sx 3,127' 3,011' Intermediate Production 11,100' 9-5/8" 3,000 sx 11,100' 9,805' Liner Perforation depth: measured See attachments true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, tbg ORIGINAL Packers and SSSV (type and measured depth) Baker "3H" Retrievable Packer @ 9,900' 13. Stimulation or cement squeeze summary '~-~$,~47 ~ L/ - Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/4/1997 193 29 955 1051 130 Subsequent to operation 11/16/97 753 65 3371 1110 150 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ,~ ~' ,- 0/I ~'-'" Title: Drilling Manager Date: 12-16-~' Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ DOLLY VARDEN PLATFORM 50-733-20274-00 D-27 Summary: 1-28 to 2-2-97 2-21 to 2-23-97 3-7-97 3-8-97 3-9 3-10 3-11 3-12 3-13 3-14 3-15 3-16 3-17 3-18 3-19 3-20 3-21 3-22 3-23 3-24 3-25 3-26 3-27 3-28 3-29 Skid Rig from B-1 to A-1 well room. Perforate tubing above tubing fish. Circulate 3 % KCI to kill well. Mob out and RU Marlin Pacific's HWO. Continue RU MPA equipment RU MPA. Set BPV. ND Tree. NU Stack RU MPA. Start BOP test. Failed Pulled BPV & Set 2Way Check. Tested BOP's. OK Hydraulic Problems Hydraulic Problems Hydraulic Problems Hydraulic Problems Hydraulic Problems Hydraulic Problems Hydraulic Problems Jack Repaired. Test annular 300/3000 psi. Function rams and valves. OK. Pull BPV and MU landing joint. Completion stuck. Work string while attempting Free Point. Released from seals. Start POOH LD completion. LD 7 Joints and SD for Mechanical Problems. 12 hours pulling completion, 12 hours down time. Continue pulling completion with unit problems. Completion OOH. Changed rams to 3-1/2". Test OK. RU to run 3-1/2 DP & C/O assembly. PU and RIH with C/O assembly. Continue RIH with Pkr Milling / C/o Assembly. Break circ at 5880'. Cont RIH. Took weight at 6430'. Worked through. Unit mechanical problems. Continue RIH. Took weight at 6490'. Attempt to ream with motor. Hydraulic Problems with unit. PU work string and MU hanger. Land and set 2 way check. Pressure test all BOP's. Continue Pressure test of BOP's. OK. Pull check valve and set BPV. RD and release MPA Pulling Unit. Back load MPA equipment / Start MOB of Drilling Rig # 76 DOLLY VARDEN PLATFORM 50-733-20274-00 D-27 Summary: (Continued) 3-30 3-31 to 4-3-97 4-4 4-5 4-6 4-7 4-8 4-9 4-10 4-11 4-12 Continue Rig MOB Continue Rig MOB RU of Rig Complete. Pressure test BOP's. Pull BPV and MU Landing Joint. Attempt to work through tight spot at 6454. No Go. POOH. MU BHA #2. RIH Cleared tight spots and RIH with Pipe. Tag packer at 10,357' and milled up. POOH for spear. RIH with spear and latched packer. POOH with spear and packer. LD packer and tail pipe assembly. MU C/O assembly. RIH. Cleaning out fill Cleaned out fill to 10961'. Circ Vis Sweep. POOH. PU RTTS and stinger. RIH and set RTTS at 10,000'. Pressure test annulus to 1200 psi. Test good. Displace well to clean 3 % KCI. POOH to change TBG spool. POOH LD RTTS assembly. RIH with 2066' of 3-1/2" DP. PU bridge plug and storm valve. Set plug at 180'. ND BOP's. Changed DCB Spool. NU BOP's. Changed rams to 4-1/2". Test all breaks on BOP's. Recover storm valve and bridge plug. Start PU and running 4-1/2" Completion. PU & Run 4-1/2" Completion. Set packer at 9,900'. PU and shear from floating seals. Circ corrosion Inhibitor to annulus. Land completion. Set BPV. Start ND BOP's. ND BOP's. NU Tree. Test to 5,000 psi. Release well to production. Prep to skid rig to D-2a. PERFORATION DATA SHEET DOLLY VARDEN D-2 7 Perforate Hemlock W/3-3/8 Hollow Carrier Guns, 6HPF, 60 Phase. D~¢ Zone Interval MD Interval TVD 5/22/97 HB-1 10,520' - 10,580' 9,283' - 9,337' Perforate Tyonek W/3-3/8 Hollow Carrier Guns, 6HPF, 60 Phase. Date Zone Interval MD Interval TVD 11/09/97 G-1 Zone 10,020' - 10,040' 8,831' - 8,849' 11/09/97 G-2 Zone 10,080' - 10,098' 8,885' - 8,902' 11/09/97 G-3 Zone 10,146' - 10,172' 8,945' - 8,969' 11/09/97 G-4 Zone 10,200' - 10,244' 8,994' - 9,034' , Conductor i ]rodirq Boy Unit Flew 106 Dewat~on 26.4 Deg. 109660 - 10992.0' SQUEEZE PERFS HB-6, 4HPF, 26', 0 Phrase 41.0 - 9938~0' 4.50" OD 1X60#/f( L--80 N3G 4/11/97 9938.0 - 99s&r 4.5" O0 I2 60#/f( L-~..O TBC 4/11/97 I0020.0 - 10040.0' PERES G-t, II/9/97, 6HPF, 20', 5-,¥8" Carrier Guns, 60 Phase 10080.0 - 10098.0' PERFS 0-2, il/9,/97, 6HPF, 18', 5-,¥8" Carrier Guns, 60 Phase 10146.0 - 10172.0' PERFS 0-.}, tt/9//97, 6HPF, 26', 5-5,/8" Carrier Guns, 60 Phase 10200.0 - I0244~0' PERES G-4, 11,/9/97, 6HPF, 4¢', 5-5,/8" Carrier Guns, 60 Phase 10520.0 - I0580.0' PERFS HB-I&2, 4-HPF, 60', 0 Phase 10520.0 - I0580.0' PERP5 HB-I&2, 5,/22/97, 6HPF, 60', 5-5,/8" H, Carrier Guns, 60 Phase 10610.0 - 10644.0' PERFS HB-5, 4HPF, Si4', 0 Phase 10685.0 - I0795.0' PERFS HB-4, 6HPF, 1!0', 60 Phase 10815.0 - t0928.0' PERFS HB-§, 6HPF, 115', 60 Phase 88600- i I097.9~ 9 5,/8" OD 47.00#/f( P-! 10 PROO CSG '~ i06' PBTO: 11052' 11101' Oil Wail Compleied 4//11/97 Last Perf'd ' i/09/97 MEMORANDUM TO: THRU: David John, Chairma'~ Blair Wondzell, .~~ P. I. Supervisor ~/'[~' State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 4, 1997 FILE NO: aselddde.doc FROM: John Spaulding,~,~, SUBJECT: Petroleum Insp.~' BOPE Test Dolly Varden Unocal/Mc Arthur Rv. Field PTD 75-24 Trading Bay Unit Friday April 4, 1997: I traveled to the Dolly Varden Platform to witness the BOPE Test on rig 76. The AOGCC BOPE Test Report is attached for reference. The platform had a snubbing unit on location to remove tubing and mill out a packer and re-run tubing. Several mechanical problems developed with the snubbing unit necessatating it's removal from the platform. At this time the decision was made to re-activate rig 76, this rig had not run in quite some time. Rental BOP's, accumulator, and choke manifold were acquired, as well as a service company providing the mud pumps. Several failures were observed as indicated by the long test time, (parts had to be flown out). Upon finishing testing I was satisfied that the rig could finish the half done job from the snubbing unit. Summary: I witnessed the successful BOPE Test on Unocal rig 76. 4 failures, 10 hour test time Attachments: aselddde.xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial Workover: X Pool Rig No. 76 PTD # 75-24 UNOCAL Rep.: D-27 Rig Rep.: Set @ 11,101' Location: Sec. Weekly X Other DATE: 4/4/97 Rig Ph.# 776-6847 Shane R. Houck Fred Oehlert 6 T. 8N R. 13W Meridian Seward .. TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign yes Drl. Rig ok Hazard Sec. yes Quan. 1 Test Press. P/F 300/3,000 P 500/5,000 P 500/5, 000 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P I 500/5,000 P 1 500/5,000 P I 500/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 8 500/5,000 29 500/5,000 Functioned Functioned P/F P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2200 avg. 3,000 P 1,550 P minutes 39 sec. minutes 29 sec. X Remote: X Psig. TEST RESULTS Number of Failures: 4 ,Test Time: (10.0,)Hours. Number of valves tested 15 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev, 12/94) ASELDDDE.XLS 1IflR-27-97 THU 04:57 P~ STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSIO1T APPLICATION FOR SUNDRY APPROVALS Alter casing,,__..' Repair wet_._[.- Ptugg;ng_~.: Time extensi~ Srimutate....~= Change alOProyed' pr .ogram: Put [ tubing: Variance: Perforate: Other.' 2. Name of Operator 5. i:ype~Y ,eCL.' 6. Dat~li'elev~tfon'"iOF or KB; UNOCAL ............ Devel(~pment: X I06~ KB above MSL_~. feet ~". Address Exptoratorx_.' 7~ Un(t o-~ P~-~operty name. ..... PO BOX 190247 ANCHORAGE. AK 99519 Stoat;graphic; Tading Bay Unit Servi ce: --4~"-Locatf'~'~ of Wet[' at s;r~face Leg A-I 'C°nd. #I, Dotty Varden-ptatform "~ 8. l~ett"-~umber 758~ FSL~ 1~206~ Ft~L~ Sec. 6 - 8N ~ I~W - SM D-g7 At top Of productive interval 9. Permit number 52~' FNL, ~,02~~ FEL, Sec. 6 - 8fl - I~ - SM 75-24 At effective depth 10. A~'i 50-7'5~- 20274 · At total depth 11. F~e[d/Poo[ lg. Present ~ett coMitim s~ary Total depth: measured 11~101~ feet PLugs (measure) C~ent Retainer a 10~960~ true vertical 9,805~ feet Effective d~th: measured 11,052, feet Junk (measure) true vertical 9,7~' feetOR]GINAL Cas { ~ Length S J ze ~emented Measured d~th True Pert ~ ca [ d~th Structural Conductor Surface 3,127' 13-3/8" 2,~00 sx ~, 127' 3, 011, ~nterm~i ate Production 11 ~ 100' 9-5/8" S.O00 sx 11,100~ 9,805~ RECEIVED Perforation depth: measur~ See Attachment rue ing (si ze, grade, a~ measur~ depth) ~ O~ & ~s ~ns. ~m~i~ 3-1/Z" $-135 [~tt String a +/- 8300' ~O~g Packers and SSSV (type a~ measur~ depth) Baker sS-3A P~ g I0,36~' : SCssv - C~cO 4-1/2" TRFV ~ , , ,,,,, .. --, ,,, 13. Attaehements Description s~ary of pr~o~ Data{ t~ o~ret~S pr~ram:~aoP S'ket~h= 16/gst~mat~ da':a for ~encf~' o~r~t~'~ .... 15. status ~ ~ett ctas'~if~cation as: ..... ~/27/19~7 .... . 16' If proposal ~el[ verbally a~rov~: of X Gas: ~ ~~ lC ~/~f97 ~ -- ~ame ~3~rover ...... Date epprov~ ~rv~ce~ .._ ,,, _ ....... ~7, ] hePe~ certify that the foregoing i~ t~ue and co~rect to the bc~t o~ ~ Signed; ~ ' Dale ~ai~es T;tLeOritting Manage~ ...... Date: 2/3/1~7 ........................ ~o."~ss~ ~s~ o.j _.,'- . Mechanica~ Integrity Test Su~equent form requir~ Orig;na: 5i~:~5., Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 7 - MflR-27-97 THU 04:5? PM 0-27 Temporary ShUt Doa~Procedure 3/2?/97 - 3:51P~ P~ge ~ I Temporary Shut Down Procedure Dolly Varden Platform We11 P, 03 The 3-1/2" work string will re__-~_in ~ownhole during =he course of the shut in period while the drilling rig is act~vabed. 1) 4) 6) ?) 8) 9) 3.0) Pull wear bushing. Set BOY test plug. Tes= 90~ stack. Pull test plu9. Measure up crossover from 3-1/2t, IF P~n to 4- 1/2~t Buttress Pin. Measure up 11~ DCB Tubing hanger. RIH an la~ cubing hanger. Engage hold down pins. Close bag on la~d£ng Join~. Pressure test bo~y seals to 2,500 psi. Release pressure an~ open bag. Back out landing ]olnt. Set back pressure valve. Close blinds and lock bli~s. Close an4 lock annular valves. Rig down and release MPA unit. BackloadMPA equi~en~ tO beach~ RECEIVED ~., ~flR-27-97 THU 04:56 P~i Unoca[ Corporal: fort P.O. Box lP62¢7 Anchorage, AI, aska 99519 907- 26~. 7676 P, O1 UNOCALe) DaLe Haines Dritting Manager Thursday, March 27, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Do!.ly Varden Platf.o~ W~11.._.2~7 We have encountered difficulties on the workover program and feel the Activation of the Drilling rig is required to complete the workovers. In doing so, we will be securing the well and releasing the Hydraulic Pulling unit. Attached is the securing procedure and the 10~403 requesting a shut dow~ of operations. If you have any questions, please contact the undersigned at 263-7660 or Dan Wil!iamson at 263-7677. Sincerely, e Haines Drilling Manager ORIGINAL GRS/leg STATE OF ALASKA ALASKA~iL AND GAS CONSERVATION CO~-~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reques Abandon: Suspend~ Operation shutdown: Re-enter suspended we[[: Alter casing: Repair we[[: Plugging: Time extensi Stimulate: Change approved program: Pull tubing X Variance: Perforate: Other: 2. Name of Operator 5. Type of we[[: 6. Datum elevation (DF or KB) UNOCAL Development: X 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name PO BOX 190247 ANCHORAGE, AK 99519 Stratigraphic: Tading Bay Unit Service: 4. Location of we[[ at surface Leg A-1Cond. #1, Do[fy Varden Platform 8. Net[ number 758' FSL, 1,206' FWL, Sec. 6 - 8N - 13W - SM D-27 At top of productive interval 9. Permit number 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM 75-24 At effective depth 10. AP! number 50-733-20274 At totat depth 11. Field/Pool 351' FNL, 1,825' FEL, Sec. 6 - 8N - 13~ - SM Hemtock 12. Present wett condition summary Totat depth: measured 11,101' feet Ptugs (measured) Cement Retainer ~ 10,960' true vertical 9,805' feet Effective depth: measured 11,052' feet Junk (measured) true verticat 9,760' feet Casing Length Size Cemented Measured depth True vertical depth Structurat Conductor Surface 3,127' 13-3/8" 2,900 sx 3,127' 3,011' intermediate Production 11,100' 9-5/8" 3,000 sx 11,100' 9,805' Liner Perforation depth: measured See Attachment RECEIVED true vertical Tubing (size, grade, and measured depth) 0 I~ I /~ i~' [~ L ~E~ ~--1~9~ Packers and SSSV (type and measured depth) Alaska Oil & Gas Cons. Commission Baker SB-3A PKR @ 10,365' : SCSSV - CAMCO 4-1/2" TRFV @ 338' Anchorage 13. Attachements Description summary of propo x Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 2/14/1997 16. If proposal we[[ verbally approved: Oi X Gas: Suspended: Name of approver Date approved Service: 17. I hereby c~r_~fy that the foregoing is true and correct to the best of my knowledge. S igned.'~~~~r~a[e Haines T it[eDri[[ing Manager Date: 2/3/1997 FOR COMMISSION USE ONLY Conditions of approval: Notify C~ission so representative my witness IAppro[al No. Plug integrity__ BOP Test / Location clearance__ I Mechanical integrity Test Subsequent form required 10- ~ ,~6 00~I original Signea ~y Oavid W. Johnston _Approved by order of the Commissioner Con~issioner Date~--'~-- ~'/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE T,.~__mg Bay Unit Doily Varden Platform Well # D-27 Current Completion 1/4/91 Last Tags: 3.75" GR ~ 8887' 8/9~ 2.50" GR ~ 9805' 6/91 RKB to TBG Hanger = 39.70' Tree connection -- 4-1/2' 8rd · 6 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM L 33" Conductor Surf 400' 13-3/8" 61 K-55 BTC Surf 3127' 9-5/8" a0/47 NS0/PII0 BTC Surf 11100' Tubing: 4-I/2" 12.6 L-80 ABMBTC Surf 10365' NO. JEWELRY DETAIL Depth Item I. 38.90 2. 338' 3. 4. 10365' 5. 10402' 6. 10420' 7. 10433' Tubing hanger with Cameron BPV profile Camco TRDP-4A w/3.813" profile w/DB-6 Lock Gas-Lift Madm'ets 4-1/2" Danials GLM2A ~. 2,342', 4,298', 5,584', 6,578'. 7,285', 7,831', 8,377', 8,901', 9,424', 9,979', 10,294' Baker "SB-3A" w/11.5' seal assby & 6' MOE Otis "X"-Nipple profile (ID = 3.813") Otis "XN" Nipple profile (3.725" ID) Baker Shearout Sub w/WLREG Fish D~atil: TOF ~. +/-9805' Three Prong Spear +/-20' Slickline wire One Wire Finder Fing~ CT Disconnect. Cite Sub. Wire Grab TOP PERFORATION DATA BTM ZONE SPF DATE COMMENTS 10,520 10.580 B-I.2 Existing 10,610 10,644 B-3 Existing 10,685 10,795 B-4 Existing 10,815 10,928 B-5 Existing 10,966 10,992 B-6 Existing Top of Sand (~ 10949' RF_C FEB 2& 199,7 PWFD = 10,949' TI) = I 1,101' MAX HOLE ANGLE = 36° O ADRILLING~SCHEMATIOaBuktolIy\d27c.docD27C.DOC 9118/96 REVISED: DRAWN BY: PAR D-27 Workovep Procedure ..... 2/7/97 - 1:36 PH Page ~ 1 PROPOSED WORKOVER AND RECOMPLETION Do11¥ Varden Platform Well D-27 It is proposed to workover DVP well D-27 and restore Hemlock oil production. The well is currently competed in the Hemlock formation. The workover will require pulling of the tubing, milling of the permanent packer, and completion of the Hemlock with the option of G- Zone production. The well will be completed with a 4-1/2" gas lift completion. The workover will be complicated with a tubing fish and NORM scaled pipe. Workover fluid will be FIW w/ 3% KC1 unless otherwise stated. PREP WELL FOR WORKOVER: le me e e Se 6e e Be e 10. SI gas lift and allow well to die. Lock out and tag out gas lift header in well room. Bleed tubing pressure to well clean tank. Bleed casing pressure back to 500 psi. RU .125" slickline unit, BOP's, and lubricator. Pressure test to 2,500 psi. Measure up 2.8" Gauge ring. RIH and tag tubing fish @ 9,800'. Measure up 3.8" GR and RIH to 100' to ensure BPV profile is clear of scale. POH and RD slickline. RU E-Line unit, BOP's, and lubricator. Pressure test to 2500 psi. Establish Safeguards for handling perforating guns. MU 10' of 1- 11/16" HC, tubing punch guns. RIH and perforate the tubing above the WL fish as noted in step #2. POOH with perforating guns. RD E-Line. Bleed remaining pressure from 9-5/8" casing to production, then to flare. SI swab valve. Remove tree cap assembly and flange up a 4-1/16" 5K by 1502 adapter. RU BJ 5K hardline and pumping equipment to wellhead. RU 2" return line from casing annular valve to well clean tank in wellroom. Pressure test pumping equipment and hardlines to wellhead swab valve to 5,000 psi. Pressure test annular bleed off line to 1,500 psi. Line out returns from casing to production well clean tank. Start circulating FIW with 3% KCl down tubing taking returns from 9-5/8" casing. Circulate to WCT until returns are at surface. D-27 Workover Procedure 2/7/97 - 1:36 PM Page ~ 2 11. Ensure well is dead. 12. RU BPV lubricator. Pressure test to 2,500 psi. Set a 4-1/2" nominal Cameron Type "H" BPV in profile. RD Lubricator. 13. RU Marlin Pacific Alaska Hydraulic workover unit. 14. RU BJ's 5K choke manifold per attached line layout. Choke manifold to have the option of pumping 1st bottoms up to platform well clean tank (WCT). Pressure test to 5,000 psi. 15. ND production tree and flowlines. Blind flange flowlines per UNOCAL lock out tag procedure. NU BOP's. 16. Pull BPV and set two way check valve. Pressure test BOP low / high to 250 psi/ 5000 psi. Pull two way check valve. 17. Measure up 4-1/2 "EUE 8 rnd landing joint and engage hanger. Back out hanger hold down screws. PU hanger and unstab seal assembly. Maximum pull on 4-1/2" completion is 208k. 18. Circulate 2 bottoms up to productions WCT. Monitor returns in WCT to calculate fluid loss to formation if any. Expect some residual oil and gas from both tubing and casing. Tubing fish may prevent circulation around seal assembly. 19. POOH laying down 4-1/2" 12.6# buttress AB modified tubing. The pipe is expected to have BaSO4 scale. Check tubing for NORM with a LUDLUMMonitor. Norm pipe to be properly marked and handled in accordance with UNOCAL's NORM pipe handling procedures. 20. Make up the following BHA: Smooth OD 8-1/2" Metal Muncher Packer Mill with a 4-1/4" od by 18" stinger, 5-1/2" regular by 4-1/2" regular crossover, BHI 4-3/4" MAC-lXL PDM 3 @ 6-3/4" skirt boot collar baskets 4-3/4" bumper jars 4-3/4" oil jars 12 @ 4-3/4" drill collars 3-1/2" Drill pipe as required 21. 22. TIH with assembly to top of packer at 10,365'. Mill packer with motor @ 6 bpm. Adjust weight on bit to maintain +/- 300 psi operating delta P. Mill on packer until packer moves down hole. Push packer to bottom or until it takes 15k down weight. POOH with milling assembly. 23. PU the following spearing assembly: ITCO spear dressed to catch in a 4-3/4" ID polish bore 4-3/4" "J" joint release 4-3/4" bumper jars 4-3/4" oil jars D-27 gorkover Procedure 2/7/97 - 1:36 PN Page ~ 3 12 @ 4-3/4'' drill collars 3-1/2" Drill pipe as required 24. RIH with spear and engage packer. POOH with packer assembly. 25. 26. Make up the following BHA: Smooth OD 8-1/2" Metal Muncher Packer Mill 5-1/2" regular by 4-1/2" regular crossover, BHI 4-3/4" MAC-lXL PDM 9-4/7" 47# spring type casing scraper 3 @ 6-3/4" skirt boot collar baskets 4-3/4" bumper jars 4-3/4" oil jars 12 @ 4-3/4" drill collars 3-1/2" Drill pipe as required RIH with assembly cleaning fill out to 10,960'. Use 3 #/bbl Xanvis sweeps as required to lift debris from hole. NOT~ Ail solids are to be checked for NORM and retained in boxes on the surface. All wastes generated are to be manifested and sent in for disposal per UNOCAL's guidelines. 27. POOH with work string to 10,900'. Circulate well clean. POOH with work string. 28. PU the one trip completion as noted below. Pipe dope connections with National's Best of Life 2000. Packer set Depth is 9,900'. Baker Ball Seat Shear Sub / WLEG (Dressed for 1.75" ball) 10' 4-1/2" 12.6# Buttress AB modified L-80 pup joint 3.81" ID X profile nipple 15' 4-1/2" 12.6# Buttress AB modified L-80 pup joint Crossover: 7" LTC Box x 4-1/2" Buttress AB Mod. Baker Millout Extension 7" LTC pin by pin Baker Hugh Model "3H" hydraulic set Permanent Packer Sized for 9- 5/8" 47~ casing. Baker Anchor Tubing seal Assembly with 4-1/2" Buttress AB modified box. Baker Packer Bore Receptacle size 80-47 with 4-1/2" AB Mod Butt. box by pin, Scoop guide and Internal retrieving Threads, with seal unit pin in place for 30K shear release. 5' 4-1/2" 12.6# Buttress AB modified L-80 pup joint 4-1/2" Buttress AB Modified tubing w/ 4-1/2" GLM's with live valves placed @ 9810', 9122', 8425', 7703, 6973', 6142', 5275', 4143', and 2430'. 10' 4-1/2" 12.6# Buttress AB modified L-80 pup joint OTIS Series 10 TRSCSSV, 4-1/2", Flapper style 10' 4-1/2" 12.6# Buttress AB modified L-80 pup joint 10 joints 4-1/2" Buttress AB Modified tubing 5' 4-1/2" 12.6# Buttress AB modified L-80 pup joint Cooper Oil Tool 11" tubing hanger dressed for DCB spool D-27 Workovep Procedure 2/7/97 - 1=36 PH Page ~ 4 29. 30. 31. 32. 33. 34. 35. 36. 37. RIH with assembly torqueing connections to make up marks on buttress connections. Ensure AB mod seal rings are intact and good integrity. Replace seal rings as required. Control line to be banded 2 X's on pup joint on SCSSV and 1 per joint to surface. Maintain 5,000 psi on control line while RIH with SCSSV. Rabbit all 4-1/2" tubing joints. Make up landing joint in top of hanger and tie in control line to the top of the hanger. Pressure control line to 5,000 psi to open valve. PositiOnballhangerandl'allowabOve bowl.fall DroPbottom.l.75" steel or bronze packer setting to to Pressure up down tubing~ and hydraulically set packer, j~%%~ Pressure up to 3,600 psi and shear out ball set. PU completion to release seals. Circulate NALCO 9700 at 1% by volume corrosion inhibitor into annulus. RIH and land completion. Engage hold down screws. Bleed off control line pressure and allow SCSSV to close. Set back pressure valve. Cut the control line. ND BOP's and riser. NU Tree. Pull BPV and set 2 way check. Pressure test tree to 5,000 psi. Pull 2-way check. Release MPA and skid rig #76 over D-2A. NU flowlines, gas lift header lines and pressure test. 38. Turn well over to production to unload. UNOCAL RKB 2o TBG Hanger = 39.70' Trading Bay Unit Dolly Varden Platform Well # D-27 Proposed Completlon 2/3/97 SIZE WT CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 33t' Conductor 13-3/8" 61 9-5/8" 40/47 Tubing: 4-1/2" 12.6 Surf 400' K-55 BTC Surf 3127' N80/P110 BTC Surf 11100' L-80 BTC Surf 9870' NO. JEWELRY DETAIL Depth Item le 2. 3. 4. 5. 6. 38.90 Tubing hanger with Cameron BPV profile 338' Otis 4-1/2tTR Flapper StyLe SSSV 4'1/2" GLH's ~ 2,430', 4,143', 5,275', 6,142', 6,973', 7,703', 8,425', 9,122', 9,810', 9870' Perm Packer 9900' Otis "X" 9930' WLREG TOP BTM PERFORATION DATA ZONE SPF DATE COMMENTS 10,068" 10,100" G 10,135' 10,173" G 10,190' 10,210" G 10,520 10,580 10,610 10,644 10,685 10,795 10,815 10,928 10,966 10,992 B-1,2 B-3 B-4 B-5 B-6 Future Future Future Existing Existing Existing Existing Existing Top of Sand @ 10949' PBTD = 10,949' TD = ~,~ ~NGLE = 36o O:\DRILLING\SCHEMATIC\tbu\dotty\D27P.OOC REVISED: 2/3/97 SSL DRAWN BY: PAR DOLLY VARDEN ...... D-27 & D-2A BOP SCHEMATIC I Riser spool, 13-5/8"- 5,000# Flow nipple, 13-5/8" ~ 5,000# w/ 10" - 150# outlet w/2" fill-up line, 28" OAL Annular BOP 13-5/8" - 5,000#, 3'-9" OAL Location of pipe rams Choke Line Double Ram BOP, 13-5/8"- 5,000#, 4'-2" OAL %~~ ILocation of blindsI Kill Line Riser spool I ~ 22 5/8" 72" 21. 375" gAUGE VALVE AT 90 BEOREES Bench B-1,2 B-3 B-4 B-5 B~ Attachment #1 Well D-27 Perforations MD 10,520'- 10,580' 10,610'- 10,644' 10,670'- 10,795' 10,815'- 10,928' 10,966'- 10,992' TVD 9,283' - 9,364' - 9,423' - 9,547' - 9,683' - 9,337' 9,394' 9,529' 9,648' 9,706' [SUN DRY.XLW]Attachment Perfs DOLLY VARDEN ELEVATIONS J\ J\ /\ J\ J\ 22.25' RT 22. x,/ 13.05' 17.45' 45.45' RT 23. 19.45' ~e_.T~ of Tree ,· T~p of DC B ~j ye Tc~p of C~g Head 106' RT 60. /\ 112 218' RT RIG FLOOR DRILL DECK PRODUCTION DECK MEAN SEA LEVEL MUD LINE 10/29/96 MEMORAN TO: THRU: David Joho~, Chairma~" P. I. Supervisor · I State Alaska ' Alaska Oil and Gas Conservation Commission-- 1 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 ihe 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) Unocal Corporation P.O. Box 196247 -~. Anchorage, Alaska 99519 907-263-7676 UNOCALe DaLe Haines DriLLing Manager Friday, February 7, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Dolly Varden Platform Well 27 Unocal is submitting a Sundry 10-403 form for well work on Dolly Varden Platform well D-27. Well D-27 is currently a Hemlock Oil Producer with tubing restrictions. The workover scope is to replace the 4-1/2" tubing and reset a permanent packer above the G-zone interval for commingling at a later date. If you have any questions, please contact the undersigned at 263-7660 or Dan Williamson at 263-7677. S i nc~er ~1 y, Drilling Manager GRS / 1 eg Unocal Corpor~,tion Oil & Gas Operations ,~ 909 West 9th Avenue, P.O. Box '196247 Anchorage, Alaska 995'19-6247 Telephone (907) 276-7600 UNOCAL February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Dolly Varden Platform, Well APl Number 50-733~~.~ This is to infor, cg4a2~hat Unocal withdraws the Sundry Request to perorate, with Approval No( 93~.~~ It is no longer a viable proposal, please cancel the Request for Sundry Approval. ' '% D-- 2,? 7~-~-~.'-/ Very truly yours, ! Candace Williams STATE OF ALASKA ALA,S~, AND GAS CONSERVATION COMM,'~,~SION ~ OIL REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdown__ Stimulate__ Plugging__ Perforate ~ Pull Tubing Alter Casing Repair Well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) (Marathon Oil Company-Sub-Operator) DevelopmentEx¢oratory__X 106' KB above MSL 7feet UNOCAL 3. Address Stratigraphic -- 7. Unit or Property name P. O. Box 190247 Anchorage, AK 99519 Service ~ Trading Bay Unit 4. Location of well at surface Leg A-1 Cond. #1 Dolly Varden Platform 8. Well number 758' FSL, 1,206' FWL, Sec. 6-SN-13W-SM D-27 At top of productive interval 9. Permit number/approval number 522' FNL, 2,022' FEL, Sec. 6-8N-13W-SM 75-24/91-284 At effective depth 10. APl number 50- 733-20274 At total depth 11. Field/Pool 351' FNL, 1,825' FEL, Sec. 6-8N-13W-SM Hemlock 12. Present well condition summary Total Depth: measured 1 1,1 01 ' feet Plugs (measured) Cement retainer @ 10,960' true vertical 9,805' feet Effective depth: measured 11,052' feet Junk (measured) None true vertical 9,760' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3,127' 13-3/8" 2,900 sx 3,127' 3,011' Intermediate Production 11,100' 9-5/8" 3,000 sx 11,100' 9,805' Liner Perforation depth: measured See Attachment #1 true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt Tbg @ 10,433' ~.i~,~-~'~ ~' .... ~!- ~:~ Packers and SSSV (type and measured depth) Baker SB-3A Pkr @ 10,365'; SCSSV - Camco 4-1/2" TRFV @ 338' ~" ::~'::': :~' ~ & E:as 6c?~s~ 13. Stimulation or cement squeeze summa~ Inte~als treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 9/20/91 610 365 1200 1220 100 Subsequent to operation 9/24/91 572~ ~'' 338 2112 1080 120 15. A~achments 16. Status of well classification as: Copies of Log and Su~eys run Daily Repo~ of Well Operations X Oil X Gas Suspended Se~ice 17. I hereby ~e~ify that the foregoing is true and correct to the best of my knowledge Signed~'x.. ~ ~ Title~"(~~ ~~"~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLIC~-~b'~ Bench B-1,2 B-3 B-4 B-5 B-6 Attachment #1 Well D-27 Perforations MD 10,520' - 10,580' 10,610' - 10,644' 10,670' - 10,795' 10,815' - 10,928' 10,966' - 10,992' TVD 9,283' - 9,364' - 9,423' - 9,547' - 9,683' - 9,337' 9,394' 9,529' 9,648' 9,706' : FC VED [SUN DRY.XLW]Attachment Perfs DAILY WELL OPERATIONS D-27 9/22/91 R/U lubricator. Held safety meeting. Tested lubricator to 2500 psi. Good. Established communication blackout. RIH w/ 3-3/8" 6SPF 60 degree phased perf guns. F1 owed well to obtain underbalance. Perforated the following intervals: RUN #1 10,760' - 10,790' DIL #2 10,730' - 10,760' DIL #3 10,700' - 10,730' DIL #4 10,670' - 10,700' DIL RD. Return well to production. F i red F i red F i red F i red , ECE!VED H: \wp\WE LLOPS\D27 .... STATE OF ALASKA .._¢/ ALASKA OIL AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operabon shutdown__ Stimulate t Plugging Pull tubing __ Alter casing ~ Repair well ~ Pedorate .X, Other 2. Name of Operator I 5. Type of Well: / Development _X UNOCAL (Marathon Oil Co - Sub Operat~or] '3. Address !/ ' StratigraohicEXpl°rat°ry--__ P. O. Box 190247 Anchorage, AK 995119 S.erv~ce.__ 4. Location of well at surface Leg A-1 Cond. #1 Dolly Varden F/atTorm 758' FSL, 1,206' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB~ 106' KB above MSL -~2feet 7. Unit or Property name '~ Trading Bay Unit ~ 8. Well number nut ~roval number 10. APl number 5o-7-33-20274 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,101 ' feet Plugs (measured) Cement 9,805' feet retainer (a10,960' Effective depth: measured 11,052 ' feet Junk (measured) none true vertical 9,760 ' feet Casing Length Size Cemented Measured depth Structural Conductor Surface 3,127' 13-3/8" 2,900 sx 3,127' Intermediate Production 11,100' 9-5/8" 3,000 sx 11,100' Liner Perforat,on depth: measured Bench 1,2 10,520' - 10,580' MD Bench 3 10,610' - 10,644' MD true vertical Bench 4 10,670' - 10,795' ND Bench 5 10,815' - 10,928' MD Tubing (size, grade, and measured depth) Bench 6 10,966' - 10,992' MD 4-1/2". s12¢6#'ss L-80 Butt. Tubing ['a 10 433' PacKdrs anti ' (type and measured depth) Baker SB-3A Pkr [a 10,365'. SCSSV - Camco 4-1/2" TRFV ¢ 338' 9,283' 9,364' 9,423' 9,547' 9,683' True vertical depth 3,011' 9,805' - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation ,, 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 469 278 871 1170 1035/' 283 i816 1190 16. Status of well classification as: Oil ~ Gas__ Suspended Service 130 160 17. I hereby, A:ertify that the foregoing is ~ue and correct to the best of my knowledge. Signed ,~ · ~-~~ Title'~t~'( C('' (/~'(~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Daily Summary of Operations TBU Well D-27 Reperf HB-4 6/22/91 Skid rig #76 over Well D-27 PT to 250~ psi. Establish CBO. RIH w/ 30' of 3-3/8" carrier guns loaded ~ SPF and 60 phased, 22 gm charges. Flow well when out of tubing, perf 10,735' - 10,765' of HB-4 underbalanced. Flow 20 more minutes and POOH. CBO @ 1000'. Bleed lube & LD gun. RIH w/ 25' same type gun. Flow well and perf 10,710' - 10,735' (DIL) of HB-4. Flow to clean up & POOH. RD. \docs\dvp\d27. doc STATE OF ALASKA ~ -- ALAS'r,,~, OIL AND GAS CONSERVATION COM~,~SSION OA APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well O.,~ Alter casinT Repair w~i' Plugging -- Time extension Stimula-'~' Change appr~d program -- Pull Tubing -- Variance "~rforate X Oth-~' -- %. Type of Well: -- 6. Datum elevatiOn (DF'"~'r KB) Development X__ 106' KB above MSL fee~ I 1. Type of Request: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) Exploratory 3. Address P.O. Box 196247 Anchorage, AK 99519 Stratigraphic Service 4. Location of well at surface Leg A-1 Cond. #1 Dolly Varden Platform 758' FSL, 1,206' FWL, Sec. 6-8N-13W-SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6-8N-13W-SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6-8N-13W-SM 7. Unit or Property name Trading Bay Unit 8. Well number D-27 9. Permit number/approval number 75-24 10. APl number 50- 733-20274 1. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 1,101' feet Plugs (measured) 9,805' feet 11,052' feet Junk (measured) 9,760' feet Length Size Cemented Cement retainer @ 10,960' None Measured depth 3,127' 13-3/8" 2,900 sx 3,127' 11,100' 9-5/8" 3,000 sx 11,100' See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt Tbg @ 10,433' Packers and SSSV (type and measured depth) Baker SB-3A Pkr (~ 10,365'; SCSSV - Camco 4-1/2" TRFV @ 338' True vertical depth 3,011' 9,805' RECEIVED $ E P - 1995 Alaska 0il & Gas Cons. CommiSsioB ~nchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation Sept. 9, 1993 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil X Gas Service Suspended Signed/d,,.. ~~~ Title "'~(~, ~,~{, ~(,.~. ~lk~i~;k~C{~ Date ~, ~. ~ ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No.~ Plug integrity__ BOP Test__ Location clearance~ ~ r~ '~ Mechanical Integrity Test__ Subsequent form required 10- ~ ~pproved Copy Returned Approved by order of the Commision Form 10-403 Rev 06/15/88 Origina! Signed By Commissioner Date ~-~'/~',~ ........... SUBMIT I~ TI~IPLICATE Bench B-1,2 B-3 B-4 B-5 B-6 Attachment #1 Well D-27 Perforations MD 10,520' - 10,610' - 10,670' - 10,815' - 10,966' - 10,580' 10,644' 10,795' 10,928' 10,992' TVD 9,283' - 9,364' - 9,423' - 9,547' - 9,683' - 9,337' 9,394' 9,529' 9,648' 9,706' R'E( E[VED SEP - ;,~ ~ias~a .Oil & Gas Cons. Cor~missiof', Anchorage [SUNDRY9.XLW]Perf Database PROCEDURE WELL D-27 · e · · Obtain a 24-hour well test with a minimum of four (4) WC's. RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 psi. Apply 4000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE: Prior to arming guns and until guns are 1,000' in the hole, complete the perforating checklist. Re-complete the perforating checklist when guns are e 1,000' when POOH. RIH w/ 3-3/8" carrier guns, 6 SPF, 60-degree phasing and perforate the following intervals underbalance. Run Bench Interval DIL Footaqe 5 10,860' - 10,890' 30 5 10,830' - 10,860' 30 5 10,820"- 10,830' 10 4 10,770' - 10,790" 20 4 10,690.' - 10,710' 20 RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's after cleanup. Test well again within 5 days. H: \wp\WLPRO\D27 E P - j !99 & Gas Cons, Commissio~ Anchorage MARATHE]N BIL CBMPANY TRADING ]}AY UNIT WELL ]3-27 33" Conductor ~ 400' New Compte~ion 1-4-91 3127' 13-3/8",Z 61~, K-55 Butt, 9-5/8" 40 & 47~ N-80 & 47~ P-110 B-i,~ B-3 B-4 B-5 :- B-6 : Ail meosuPements ope RKB to top oF equipment, 40' Come.on 4,5" 8RD x Butt Tb9 Hngr (3,958" ID), 338' CAHCD 4,5" TRDP-4A SCSSV 3,813" I,D, Comptetlon StPing~ 0'-10,433' 4,5", ]8,6~, L-80 Butt Th9 w/ AB modified coupUn9s Gos LiFt mand~ets c~r'e 4.5" D~nlet's GLMSA w/l.5" side pockets. Equiped w/ RK torch. Depth Vatve ~ 8342' ~1 4298' ~2 5584' ~3 6578' ~4 7285' ~5 7831' ~6 8377' ~7 890i' ~8 94~4' ~9 9979' ~10 10,894' dll 10,365' 10,408' 10,480' 10,433' Baker SB-3A Pkn w/ 11.5' sect cssemb[y 6' MiLtout Ext X/D sub Dtis 'X' nippte 3,813~ I,D, Dtis 'XN' (NoGo) n~ppte 3,7~5~ i,D, Shecrout Bait Sect sub/WL Re-entPy guide PERFDRATIDNS B-t,2 10,520'-580' 4 SPF 0~ Phasin9 B-3 10,610'-644' B-4 10,685'-795' 8-5 10,815'-928' Avg Dev = 86,4° $ E P - t995 aJaska Oil & Gas Cons. Commissio~ Anchorage 10,960' Cement Retainer-, 35 Sc~cks Cement sqzd betow r'e±c~iner', Revision ]}ote~ 1-88-91 Revised By: JDH PBTD e 11,05~' Reason: New Comp~e%ion TD e 11,101' Ppevious Revision: n/~ DOLLY VARDEN P-~.ATFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4' ~1/,1.6 -'.. '5 O0 0 CHISTMAS TREE POSITIVE CHOKE 2' 3000 psi - 13 3/8' CASING ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversatiQns concerning the subject, it had been___explained to me that either ARCO or Marathon had been theY'§II'operator on the majority of the work proposed; hoWever, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application-of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on file can'be marked accordingly. ' ' -. _ Sincerely, · · Statistical Technician Well No. Perm/t No. D-4 D-SRD D-26 D-27 82-41 80-65 74-9 75-24 D-40 D-42 D-46 82-83 83-53 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Tradinq Bay Unit Description' Perforate 2-91 Perforate 5-91 Workover 4=91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush'. G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 G-6 67-71 82-33 3/15-91, 91-086 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this wel~ Perf. 10-19-91 Perf 4-92 ~ G. Bush G. Bush G. Bush G-17 G-19 G-21 G-27 G-31 K-1 K-2RD K-3 K-9 78-3 69-17 72-42 78-70 69-72 67-65 78-38 80-144 68-38 11-1-91, 91'331 11-10-92, 92-238 4-21-92, 92-094 6-17-93, 93-154 . 4-21-92, 92-95 1-6-93, 92-203 ., · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate G. Bush Temp. log 10-15-92 G. Bush Perf 4-92 Coil tubing cleanout Perforate Convert to inj. G. Bush" ,~.. R:.'schmidt , . , _.G~Bush_ · R Schntidt Production profile G. Bush Perforate 2/90 R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts STATE OF ALASKA A'~SKA OIL AND GAS CONSERVATION COM E.'~SION REPORT' OF SUNDRY WELL,OPERATIONS I. Operations performed: Operation Shutdown m Stimulate__ Plugging "_. Pedorate ~ Pull tubing __ Alter casing ~ Repmr well __ 2. Name of Operator ! 5. Type of Well: X UNOCAL (Marathon Oil Co - Sub Opera~or) DExeV~p~:~- 3. Address J Straligraphic Z.. P. O. Box 190247 Anchorage, AK 99519 Service__ 4 Locat~on of well at sudace Leg A-I con(1. #1 Dolly Var(/eh Flat. form Other __ 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number 758' FSL, 1,206' FWL, Sec. 6 - 8N - 13W - SM At top of proOuct~ve interval 522' FNL, 2,022' FEL, Sec. 6 - 8N 13W - SM At effectwe depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- - SM D-27 9. Permit number/approval number 75-24/92-178 10. APl number 50-733-20274 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,101' fe~t 9,805' feet Plugs (measured) Cement retainer 010,960' Effective aec)tn: measured 11,052 ' true vertical 9,760' Casing Length Size Structural Conductor Sudace 3,127' 13-3/8" Intermediate Production 11,100' 9-5/8" Liner Perforation depth: measured true vertica~ Tubing (s~ze. grade, and measured depth) feet feet Junk (measured) n on e Cemented Measured depth True vertical depth 2,900 sx 3,127' 3,011' 3,000 sx 11,100' 9,805' Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,610' - 10,644' MD 9,364' Bench 4 10,685' - 10,795' MD 9,431' Bench 5 10,815' - 10,928' MD 9,547' Bench 6 10,966' - 10,992' MD 9,683' p4-.1/2", 12.6#, L-.80 Butt. Tubing acKers and SSSV (type ano measured depth) Baker SB-3A Pkr 0 10,365'. SCSSV 13. Stimulation or cement squeeze summary 10,433' Camco 4-1/2" TRFV R E3~''E / V ~ D 14. - 9,337' TVD - 9,394' TVD- - 9,529' TVD - 9,648' TVD - 9,706' TVD Intervals treated (measure(I) Treatment description including volumes used and final pressure Representative Dally Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 561 ¢" 260 1411 1150 120 Subsequent to operation 637 /" 232 2263 1120 15. Attachments 116. 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. Signed ev~~l(:>,~ Form 10-404 R Service 120 Date Il '- [. g.--~,,z. SUBMITIN DUPLICATE DAILY NELL OPERATIONS D-27 6/7/92 RU on Well D-27. Lock open SCSSV w/ auxiliary pump at 4000 psi. PSI test lubricator to 2500 psi. Test Good. Establish CBO. Arm 15' of 3-3/8" carrier, 6SPF, 60 degree phase. (Select Fire). RIH flow well to obtain underbalance. Fire 10' gun to perforate HB-3 10,635' - 10,645' Fire 5' 10,630' - 10,635'. POOH. All shots fired. Arm'20' of 3-31~'~ to perforate HB-3 carrier, 6SPF, 60 degree phase. RIH. Fire guns to reperforate HB-3 10,610' - 10,630'. POOH. All shots fired. RD off D-27. Turn well over to production. H: \wp\WELLOPS\D27 STATE OFALASKA 0 R 16 Ac[,/ AL -dKA OIL AND GAS CONSERVATION COMMIt'ON ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: ~,Uandor, __ Suspend __ Alter casing __ Repair well __ Cnange approved program __ 2. ,Ne, ,me of Operator T 5. Type of Well: / Oevetopment UNOCAL (Harathon 0il 6:0 - Sub Opera[or) Exploratory __ 3. Address ' ! Stratigraph~c __ P. O. Box 190247 Anchorage, AK 995~9 Service__ 4 Locahon of well at surface Leg A-1 Cond. #1 Dolly Varden Platform 758' FSL, 1,206' At top of productive interval 522' FNL, 2,022' At effective depth Ooeration shutdown __ Re-enter suspended well __ Plugging __ Time extension __ ,,Stimulate __ Pull tubing __ Variance __ Perforate ~ Other __ FWL, Sec. 6 - 8N - 13W - SM FEL, Sec. 6- 8N- 13W- SM At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 11-27 9. Permit number 75-24 10. APl number 5o-733-20274 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,101' feet 9,805' feet Plugs (measured) zt ectlve depth: measured true vertical Casing Length SIructural Conductor Surface 3,127' Intermediate Production ! 1,100 ' Liner Perforation depth: measured 11,052' feet 9,760' feet true vertical 'TUD~ng (s~ze, grade, and measured depth) Size 13-3/8" 9-5/8" Junk (measured) Cemented 2,900 sx 3,000 sx C em¢. .Fi.n V 60, J U L - 6 none Alaska 0il & Gas Cons. 6ommissiOf~ Ancltorage., Measured depth ~rue venice depth 3,127' 3,011' 11,100' 9,805' Bench 1,2 10,520' - 10,580' MD 9,283' -9,337' TVD Bench 3 10,610' - 10,644' MD 9,364' -9,394' TVD Bench 4 10,685' - 10,795' MD 9,431' -9,529' TVD Bench 5 10,815' - 10,928' MD 9,547' -9,648' TVD Bench 6 10,966' - 10,992' MD 9,683' -9,706' TVD 4-1 2" Packer/and,SS~3~.6#. L.-80 Butt .Tubing @ 10 433' (type an(] measurecl ~l~ptn) ' Baker SB-3A Pkr @ 10,365'. SCSSV - Camco 4-1/2" TRFV @ 338' i3. Attachments Description summary of proposal __ Detailed operations program X BOP sketch 14. Estimated date for commencing operation 6/7/92 16. If proposal was verbally approved Name of approver Mike Mender 6/5/92 Date approved 15. Status of well classification as: Oil ~ Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~-~, .~;~ ,.~.<~,,. Title ~_._%, ~~ ~¢ Condition r~ p~l:s~a P~a Notify Commission so FOR COMM~ION USE ONLY representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~o~ Original Signed By Approved by order of the Commission David W. Johnston Date G-~_3-~'L. l Approval No. Approved Copy Returned Commissioner Date '7- lO Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TBU WELL D-27 PROCEDURE TO REPERF HB-3 1. Obtain a 24-hour well test with a minimum of four (4) WC's 2. Skid rig #76 over D-27 (leg A-i). . RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 psi. , Apply 4000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT USING THE PERFORATING CHECK LIST. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE Ca 1000' WHEN POOH. e RIH with 3-3/8" carrier guns, 6'SPF, 60 -Degree phasing and perforate the following intervals underbalance. RUN BENCH INTERVAL (DIL) FOOTAGE 1 HB #3 10,625' - 10,645' 20' 2 HB #3 10,610' - 10,625' 15' 35' , RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's after cleanup. Test well again within 5 days. RECEIVED J U L - 6 1992 Alaska Oil & Bas Cons. bummissio,, Anchorage H: \wp\w I pro. D27 ~° Condud:to~ 400' 3127' 13-3/8',~ 61~I, K-55 Butt. -5/8' 40 & 47~ N-80 & 47M P=tlO ~'dARATH~N L~_. C~NPANY TRADING SAY UNIT WELL D-87 Hew Conote-tlon 1-4-91 - i Att mecsurements ore RK3 ~o ~op o£ equipment, 40' C~meron 4.5' SRO x Butt Tbg Hngr (3,958' ID), 338' CAMCO 4,5' TRDP-~A SCSSV 3,813' I.D. 0'-10,433' 4,5% 18.6~, L-BO ~u~t Tb9 ~/ AB nodlPled couptlngs Gos LIP~ m~ndret5 &ne 4,5' Domet's GLHSA w/J,5' side pockets. Equ;ped w/ RK (~tc~. Depth Votve ~ 2342' Et 4~98' ~8 5584' ~3 6578' :~4 7~85' ~5 7831' ~6 8377' ~7 8901' .~8 9424' ~9 9979' ~tO t0,294' 10,365' !0,402' 10,4~0' 10,433' B6ker SB-3A Pkr w/ Ii.5' seal 6' HIttout Ext X/FI ~ls 'X' nlOD(e 3.813' I.D, Otis 'XN' (NoGo) nlppte 3,725' I.D. She¢rout B~(L Se~ sui~/WL Re-entry.guic = B-I,2 B-3 B-4 B-5 B-6 PERFORATIONS B-L2 10,520'-580' 4 SPF O' Phasing B-3 10,610'-644' ' B-4 10,670'-795' · · B-5 i0,815'-9;=8' · B-6 10,966'-998' ' ' Avg Dev : 85.4' 10,960' Cement Retainer, 35 Socks Cement sqzd betow retnlner. Revision Date, 1-82_-91 PBTD @ tt,058' Revised By, JDM TD 8 tt. lOI' Re~$on, New 6OMptet;on Previous Revl~lonm n/o DOLLY VARDEN F~ATFORM ., Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP · 4' ~1J~-1.6~. '5000 CHISTMAS TREE GREASE HEAD (Hydraulically Actlvat®d) R'ECEIVED LUBRICATOR J U L - 6 1992 Alaska Oil & Gas Cons. ~;ornmission Anchorage POSITIVE CHOKE ---- 2' 5000 psi -..... 2' 3000 psi 13 3/8' CASING -.-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 8 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: A, bando~ __ Suspend __ Alter casing w Repair well Change approved program __ Operation shutdown __ Re-enter suspended well __ Reperf HB 4/Pump Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other ~ C 1 ay S ta b. 2. Name of Operator. ! 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Opera(her) D~vel,opm. ent A / r-xp~ora[ory ~ 3. Address .... L., Stratigraphic P. O. Box 190247 Anchorage, Ah ~bl[t~ Service-- 4. Locat ,.,. ,.,, ,,,,~ ,:,, o,.,, ,,,..,.. 758' FSL, 1,206' FWL, Sec. 6 - 8N - 13W - SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth Att°t~tsd~mFNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL .~ Un~,t pr Pro£erty name raa~ng uay Unit 8. Well number D-27 9. Permit number 75-24 10. APl number 5o--7:33-20274 11. Fidd/Pool Hem1 ock feet 12. Present well condition summary Total depth' measured true vertical 11,101' feet Plugs (measured) 9,805' feet Cement Effeoive depth: measured true vertical 11,052 ' feet Junk (measured) 9,760' feet none Casing Structural Length Size Cemented Measured depth Conductor Surface Intermediate Production Liner 3,127' 13-3/8" 2,900 sx 3,127' 11,100' 9-5/8" 3,000 sx 11,100' Perforation depth: measured Bench 1,2 10,520' Bench 3 10,610' true vertical Bench 4 10,685' Bench 5 10,815' Tubing (s~ze, grade, and measured depth) Bench 6 10,966 ' 4-1/2", 12.6#, L-80 Butt. Tubing ¢ 10,433' - 10,580' MD - 10,644' MD - 10,795' MD - 10,928' MD - 10,992' MD P K rs an S V ty an m sue ,epth) ~er ds~;-~ ¢~r ~ ~,,~5'¢. SCSSV - Camco 4-1/2" TRFV ~ 338' retainer ~10,960' True vertical depth 3,011' 9,805' 9,283' 9,364' 9,431' 9,547' 9,683' - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD 13 Attachments 1, 2, Description summary of proposal .X.- &3 14. Estimated date for commencing operation Sept. 10, 1991 16. If p_roposal was verbally approved Name of approve"r Date approved Detailed operations program 15. Status of well classificati~a,~ C E ~ \/ ED Oil x Gas __ Suspended~ Service Anch0r~ge Commissioner Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~, ~ u,..z::~ Title ~,. "~ ' FOR COMMISSION USE ONLY Conditions of apph'bval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNI5 C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 REPERFORATE HB-4 PROCEDURE 1) 3) 4) 5) Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #76 over D-27 (leg A-l). RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. Apply 4000 PSI control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wel 1 room entry door. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT USING THE PERFORATING CHECK LIST. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE ~ 1000' WHEN POOH. RIH with 3-3/8" carrier guns, 6 SPF, 60 -Degree phasing and perforate the following intervals underbalance (well flowing). RUN BENCH INTERVAL (DIL) FOOTAGE HB #4 10,760' - 10,790' 30' HB #4 10,730' - 10,760' 30' HB #4 10,700' - 10,730' 30' HB #4 10,670' - 10,700' 30' 6) 7) 8) 9) RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's. Test well every other day and obtain 4 WC's per test. If production is increased significantly after two well tests, proceed with Cla-Sta job. The Cla-Sta treatment is designed for 2 barrels/foot assuming 504 of the fluid will enter Bench 4. The treatment will be displaced 6' into the formation. RU pumping unit, filtering equipment and chicksan lines on Well D-27 to bullhead Cla-Sta treatment. Shut in well. Bleed off casing pressure to 500 psig. Pressure test lines to 5000 psig. TBU Well D-27 Reperforate HB #4 Procedure Page 2 10) Proceed with pumping schedule as follows: Notes: If the casing pressure increases after pumping is started, shut down and fill the tbg/csg annulus with FIW. A. Pump 2000 gallons of diesel w/ 5% Musol-A and 1% Hyflo IV at 3-4 BPM. Maximum of 3000 psi surface pressure. B. Pump 440 bbls clay fix w/ 1.2% Cla-Sta XP at 3-4 BPM. ¢. Pump 440 bbls 2% clay fix at 3-4 BPM. D. Displace tubing w/ 24 clay fix. Notes: 1) 24 clay fix is fresh water or drill water mixed with NH4C1 (24) 2) All fluid is to be filtered 11) RD chicksan and pump. 12) Return the well to production immediately but unload well slowly on production choke (30-40 BFPH), opening choke completely over 2 days. 13) Obtain well tests every other day for I week with 4 water cuts per test~ then test the well once per week. \oe59\6.doc Alaska Oii& ~J G0ns~ Anchorage 33' Conductor 8 400' 3127' 13-3/8' 61tt K-55 Butt. 9-5/8' 40 & 47~ N-80 & 47N P=110 J. 'c,-cac,l~ell t -~-~ ~ MARATHON OIL ]MPANY TRADING BA~'UNIT New Completion 1-4-91 WELL D-87 ALi meosurements ore RK~B 4o top of equipment. 40' C~Meron 4,5' 8RD x Butt Tbg Hngr (3,958' ID>, 338' CAMCO 4.5' TRDP-4A SCSS¥ 3.813' I,D, Comp[e~lon String: 0'-I0,433' 4.5', 12.61~, L-BO t~utt Tbg w/ AB modified coupbngs Gcs LIPt m~ndrels ~re 4.5' Donle['s GLM2A w/l.5' slde pockets. Equiped w/ RK Latch. Depth Vclve t~ 2342' ~1 4298' ~8 5584' ~3 6578' ~4 7285' ~5 7831' W6 8377' ~7 8901' ~8 9424' ~9 9979' #10 10,294' ~11 10,365' 10,408' 10,480' 10,433' B:ker SB-3A Pkr w/ 11.5' sect :ssembty 6' Mil[out Ext X/O sub Otis 'X' nipple 3,813' I.l). Otis 'XN' (NoGo) nipple 3.725' I,I). She~rout BaLl Se~ sub/WL Re-entry.guide B-l, 2 B-3 B-4 .PERFORATIONS B-I,2 10,520'-580' 4 SPF O' Phasing B-3 10,610'-644' ' B-4 10,6'70'-795' · B-5 10,815'-928' ' B-6 10,966'-992' ' ' Avg Dev = 26.4' B-5 B-6 10,960' Cement Retainer, 35 Sack~ Cement sqzd beIo~ retainer. Revision D~te~ 1-82-91 PBTD 8 11,052' Revised By, JDM TD ~ tt, lOl' Recson. New CompIe~on Previous Rev~s;om n/~ Attachmen-t~ #3~ .. DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP ------ GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4'~1J;i.6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE RECEIVED 8~cP 19 ~':~ -' Alaska OJi & Gas Cons, Commissio~'~ ---- 2' 5000 psi _-- 2' 3000 pal 13 3/8' CASING STATE OF ALASKA ALA?JKA OIL AND GAS CONSERVATION COM M IS"51'ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abando~ __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type°f Well: UNOCAL (Marathon 0i ] Co - Sub 0nera~lorl Development_.~ r I ~ Exploratory __ 3. Address ! Stratigraphic_ P. O. Box 190247 Anchorage, AK 995~9 Service__ 4. Location of well at sudace Leg A-i Cond. #1 Doily Yarden Fiat. form 758' FSL, 1,206' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Vari,.a~oe'__ Perforate _~ Other __ At total depth 351' FNL, 1,825' FEL, .Sec. 6- 8N- 13W- .SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-27 9. Permit number 75-24 10. APl number 5o-733-20274 11. Reid/Pool Hemlock feet 12, Present well condition summary Total depth' measured true vertical 11,101 ' feet 9,805' feet Plugs (measured) Cement retainer 610,960' Effective depth: measured 11,052' true vertical 9,760 ' feet feet Junk (measured) none Casing Length Size Structural Conductor Surface 3,127' 13-3/8" Intermediate Production 11,100' 9-5/8" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Bench 1,2 Bench 3 Bench 4 Bench 5 Bench 6 4-1/~2", 12.6#, L-80 Butt. Tubing Packer° and SSSV (type and measured depth) Baker SB-3A 'Pkr @ 10,365'. SCSSV Cemented Measured depth True vertical depth 2,900 sx 3,127' 3,011' 3,000 sx 11,100' 9,805' 10,520' - 10,580' MD 10,610' - 10,644' MD 10,685' - 10,795' MD 10,815' - 10,928' MD 10,966' - 10,992' MD 10,433' Camco 4-1/2" TRFV e 338' 9,283' 9,364' 9,431' 9,547' 9,683' - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD 13. Attachments # 1, Description summary of proposal ..,y,_ #2, & #3 14. Estimated date for commencing operation 16. If proposal was verbally approved onni¢ Smith amd OT approver 6/21/91 Date approved Detailed operations program __ 15. Status of well classification as: BOP sketch Oil Gas__ Suspended J-U L - 1 199t Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il .& Gas Cons. 6ommissior Anchorage Title ~,/~--,./,Z,.:-r ~:~z.'-¢¢'~.¢_.¢~ FOR COMMI~SI~I USE ONLY Conditions of approval: Notify Commission so representative may witness Date IApproval Nc.c)/ _ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ,Y'¢~. Approved Copy Original Signed By David Approved by order of the Comm~u~.....~ ~/'~'~'-.-.~L ~) ~--~ Commissioner Form 10-403 Rev 06/15/88 .... r. / SUBMIT I~ TMIPLICATE 1) 2) 3) 4) 5) Attachment #1 .. .... TBU Well D-27 Procedure Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #76 over D-27 (leg A-l). RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. Apply 4000 PSI control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wel 1 room entry door. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT USING THE PERFORATING CHECK LIST. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE @ 1000' WHEN POOH. RIH with 3-3/8" carrier guns, 6 SPF, 60 -Degree phasing and perforate the following intervals underbalance. RUN 1 2 BENCH INTERVAL (DIL) FOOTAGE HB #4 10,735' - 10,765' 30' HB #4 10,710' - 10,735' 25' 6) RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's. Test well for 12-hours every other day with WC's taken every 8-Hours for 5-days. docs\ce56\16, doc REEEJVED JUL - 1 t991 Aias~a.{)ii .& Gas Cons. Commission ~Anchorage Attachment :'~OLLY VARDEN ~PL~TFORM W|reline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4' :1/~-1.'6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE RECEi-VE.D JUL - 1 t991 Alaska OJJ & Gas Cons, Commission Anchorage -.-- 2' 5000 ]~ 2' 3000 psi 13 3/8' CASING Attachment #3 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-27 New Comp(e~lon 1-4-91 33' Conductor ~ 400' 3127' 13-3/8" 61#, K-55 Bu'l:~. 9-5,~8' 40 & 47# N-80 & 47# P=IIO AIl measurements are RK]~ 4o top oF equipment;. 40' Cameron 4.5' 8RD x But~ Tbg Hngr (3.958' ID). 338' CAMCO 4.5' TRDP-4A SCSSV 3.813' I.D. Comple-tlon S train _o2 0'-10,433' 4.5', 12.6tt, L-80 t~utt ]'bg w/ AB mod~"~e ct coup[rags Gas LIP~ mandrels are 4.5' Daniel's GLM2A w/1.5' side pockets. Equiped w/ RK latch. Depth Valve 2342' #1 4298' 5584' a3 6578' #4 7285' #5' 7831' 8377' #7 8901' #8 9424' #9 9979' #10 l~294' #11 10,365' 10,402' lO, 4P-O' 10,433' Baker SB-3A PRr w/ 11.5' sec~t assembly 6' MItlout Ext X/O sub Otis 'X' nipple 3.813' I.D. Otis 'XN' (NoOo) nlppte 3.725' I.D. Shearout ]]att Sea% sub/%lL Re-em%my.guide · B-3 B-4 B-S B-I,~ B-3 B-4 B-5 B-6 FERFORATIDN~ 10,520'-580' 4 SPF O' Phasing 10,610'-644' ' 10,670'-795' ' · 10,815'-988' ' ° 10,966'-992' ,' ' Der = E~6.4' Alaska OJ/& 6as Cons. Commission Anchorage 10,960' Cement Retainer. 35 Socks Cement sqzd below retainer. Revls~on Date, PBTD I~ II,05~3' Revised B)', JDM TD i~ ll, lOl' Reason, New Conple~on Previous Revision, ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Pull tubing Alter casing __ Repair well ~ Name of Operator I 5. Type of Well: 2. . Development X UNOCAL (Marathon 011 Co - Sub ODera~or) ixploratory~ 3. Address ' ~ Stratigraphic ~ P. 0. Box 190247 Anchorage, Al( 995~9 service., 4. Location of well at sudace Leg A-1 6ond. #1 Doily Varden Platform 758' FSL, 1,206' F14L, Sec. 6- 8N- 1314- SH At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 1314 - $H At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM Plugging __ Perforate __ Other X__. 6. Datum elevation (DF or KB) 7. Unit or Property name Trading Bay Unit 8. Well number 13_97 feet -9. ~rmit number/approval number 75-24 10. APl number 50-'/33_20274 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 11,052 ' feet true vertical 9,760 ' feet Casing Length Structural Conductor 11,101' feet Plugs (measured) 9,80 5' feet Junk (measured) Cement retainer @10,960' none Size Cemented Measured depth Surface 3,127' 13-3/8" 2,900 sx 3,127' Intermediate Production 11,100' 9-5/8" 3,000 sx 11,100' Liner Perforation depth: measured Bench 1,2 10,520' - 10,580' MD Bench 3 10,610' - 10,644' MD Bench 4 10,685' - 10,795' MD Bench 5 10,815' - 10,928' MD Bench 6 10~ - 10,992' MD true vertical Tubing (size. grade, and measured depth) 4-1 2" # PackeZandS~t~,,pf~'° '-',-',,,y L-r80 Butt, Tubing ¢ 10 433' and measured depth-) ' Baker SB-3A Pkr @ 10,365'. SCSSV - Camco 4-1/2" TRFV @ 338' 13, Stimulation or cement squeeze summary True vertical depth 3,011' 9,805' 9,283' - 9,337' TVD 9,364' - 9,394' TVD 9,431' - 9,529' TVD 9,547' - 9,648' TVD 9,683' - 9,706' TVD Intervalstreated(measured) 10,960' Cement retainer, 35 sx cement sqzd below retainer to shut off Bench 6, 10,966' - 10,992' TrOt ,r~d~--,s~ri~to~i$1~ding volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ·/a:.',g~ 0J - s Con* O0mmiss)'['~ .... i5~ 9 r io&w~t~,e~a~ 6 n ~2/7/90 151 50 1112 "~ ~llcrl°' a~5:~a 1/11/91 210 70 468 Subsequent to operation 1180 1040 Tubing Pressure 150 140 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service [Signed ~ (:~i¢-.~, ~'~ · ~~ o_4o Date SUBMIT IN DUPLICATE Attachment #1 Daily Summary of Operations TBU Well D-27 12/28/90 Skidded Rig 76 to Well D-27. Rigged up rig. RIH with BHP survey. RIH with SCSSV lock out tool. Locked open SCSSV. Retrieved lock out tool. RIH with tubing punch. Punched holes in tubing at 10,350' DIL. POOH. Circulated 8.6 ppg brine. Monitored well, losing 97 bbls/hr. Spotted HEC pill. 12/29/90 Monitored well. RIH with "XR" plug to 10,377'. Tool failed to set. Rerun "XR" plug and set at 10,377'o Monitored well. Set BPVo ND tree. NU BOPE. Test BOPE. 12/30/90 Compete, testing BOPE. Backed out hold down pins and pulled packer free and pulled hanger to rig floor. Circulated. Spotted high vis pill. POOH and lay down 4-1/2" tubing. 12/31/90 POOH. Lay down 4-1/2" tubing. RIH with storm packer to 503'. ND BOPE. Inspected tubing spool. NU BOPE. Tested BOPE. Retrieved storm packer. RIH with burn shoe and wash pipe. 01/01/91 Washed fill 10,924' - 11,020'. CBU. Reversed circ higll visc sweep. Unable to PU without pumping. Pumped out LD singles to 9,931'. Spot high visc pill. POOH. 01/02/91 POOH with wash pipe. RIH w/ bit & scrapers tagged at 11,020~. POOH. RIH w/ retainer. Correlated w/ GR CCL. Set retainer at 10,960' IES. Mixed & pumped 35 sxs cmt. 01/03/91 Squeeze Bench 6 w/ 35 sxs Cmto Reversed out excess cmt. Circ & filtered hole volume. POOH. RIH and set storm packer at 2007" POOH. Tested storm packer to 1000 psi - leaked. Retrieved storm packer & replaced valve. RIH & set packer ~ 1968'. Tested packer to 1000 psi. POOH. TBU Well D-27 Daily Summary of Operations Page 2 01/04/91 ND BOP's. Change out tubing spool. NU BOP's. Retrieved storm packer. RU & started running production tubing. 01/05/91 Ran production tubing, mandrels, safety valve & hanger. Set packer at 10,366'. Sheared out seal assembly. Pumped inhibitor. Landed hanger. Tested seals to 5000 psi. 01/06/91 Set BPV. N/D BOP's. NU tree & tested. RU flowlines & released rig. docs\oe55\d27, doc Attachment #2 ~ Conductor 400' 3127' 13-3/8' 611~, K-55 Butt. 9-5/8' 40 & 47# N-80 & 47ff P-110 MARATHON []IL COMPANY TRADING BAY UNIT WELL D-27 New Completion 1-4-91 All me~'surement$ ere RKB 4o top oF equlpmen~. 40' Cameron 4.5' 8RD x Butt Tbg PFngr (3.958' ID). 338' CAMCO 4.5' TRDP-4A SCSSV 3.813' I.D. Completion String'. 0'-10,433' 4.5', 12.6t~, L-80 Butt Th§ w/ AB ModiFied couplings -. Gas LIf't mandrets are 4.5' s~de pockets. Equ~ped w/ RK latch. DepCh 2342' 4298' 5584' 6578' ...... 7285' 7831' 8377' 8901' 9424' 9979' 10,294' Votve ff #2 ~3 ~4 #5 #6 ~7 ~8 ~9 #10 #-11 -- B-l, 2: B-3 B-4 B-5 B-6 10,365' 10,402' 10,420' 10~33' Baker SB-3A Pkr w/ 11.5' seal o, smembly 6' MILtou't Extt ' X/O ~ub ' ~"" ' '::'- - Otis 'X' nlppte 3.813' I.D. Btls 'XN' (NoGo) nlppte 3.725' I.I]. She(zrout B~LI Se~t; ~ulo/VL Re-en~?,y g. ulde B-3 B-{ B-5 B-6 PERFORATIONS 10,520'-580' 4 SPF O' Phasing .10,610'-644' ' 10,685'-795' ' 10,815'-928' 10,966'-998' ' Avg Dev = 26.4' 10,960' Cement Re~clner, 35 S:cks Cement sqzd Ioetow ~e~lner. Revision B~te, 1-~8-91 PBTD e 11,052' Revised By, JOM Reason, New Conpte~on ~ ~ iLIOI' Ppevlous Revision, n/~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abando~ __ Suspend Alter casing Change approved program 2. Name of Operator ) 5. Type of Well: / UNOCAL (Marathon Oil Co - Sub Opera or) Exploratory__ 3. Address Stratigraphic __ P. O. Box 190247 Anchorage~ AK 995)J9 Service__ 4 Location of well at surface Leg A-1 Cond. #1 Dolly Varden Platform 758' FSL, 1,206' FWL Sec. 6 - 8N - 13W - SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth Operation shutdown __ Re-enter suspended well __ Plugging B Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate .__X Other At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above Mgl 7. Unit or Property name Trading Bay Unit 8. Well number feet D-27 9. Permit number 7R-g& 10. APl number s°733-20274 11. Field/Pool Hemlock 12. Present well condition summary -fetal depth: measured true vertical 11,101' feet 9,805' feet Plugs (measured) Cement retainer ~10,960' Effective depth: measured 11,052' true vertical 9,760 ' feet Junk (measured) feet Casing Length Size Cemented Structural Conductor Surface 3,127' 13-3/8" 2,900 sx Intermediate Production 11,100' 9-5/8" 3,000 sx Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) none Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,610' - 10,644' MD 9,364' Bench 4 10,685' - 10,795' MD 9,431' Bench 5 10,815' - 10,928' MD 9,547' Bench 6 10,996' - 10,992' MD 9,683' PacE~fr§4-1/2" .an~ s~/~ty~de anT:tSm0easurte;~ 8epTt~)b i n gL- Bu ~ 10,433 ' Baker SB-3A Pkr ~ 10.365'. S655V - Camco 4-1/2" TRFV 0 3]~,' 13. Attachments ]., 2 Description summary of proposal _~ Detailed operations program &3 - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD BOP sketch 14. Estimated date for commencing operation March 2, 1991 16 If proposal was verbally approved Blair Wondzel 1 3/2/91 Name of approver Date approvec Service 17. I hereby certify that the foregoing is true and correct to the best of m,~ knowledge. Signed (~~ %, .~,...,,.~ Title ~~ f'~ rov ¢"~ otify Commission FOR OOMMl$SIOlki USE ONLY Conditions of so representative may witness 15. Status of well classification as: Oil ~ Gas ~ Suspended Date JApproval No. Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE Attachment #1 TBU Well D-27 Procedure 1) 2) 3) 4) 5) NOTE: 6) Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #76 over D-27. RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. Apply 4000 PSI control line pressure to the SCSSV with a hand pump and monitor for any leak off prior to RIH. Hand pump to be located near lower wel 1 room entry door. RIH with 3-3/8" carrier guns, 6 SPF, 60 -Degree phasing and perforate the following intervals underbalance. RUN BENCH INTERVAL (DIL) FOOTAGE I HB #5 10,880' - 10,g10' 30' 2 HB #5 10,850' - 10,880' 30' 3 HB #5 10,830' - 10,850' 20' 4 HB #5 10,815' - 10,830' 15' 5 HB #4 10,765' - 10,795' 30' 6 HB #4 10,690' - 10,710' 20' 7 HB #4 10,670' - 10,690' 20' OBTAIN AT LEAST 3 WELL TESTS FOLLOWING CLEANUP 8 HB #3 10,625' - 10,645' 20' 9 HB #3 10,610' - 10,625' 15' HB #3 MAY NOT BE PERFORATED IF AN INCREMENTAL 200 BOPD IS ACHIEVED FROM HB # 4 & 5 REPERF OR IF TOTAL FLUID PRODUCTION EXCEEDS 2000 BFPD. RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's. Test well for 12-hours every other day with WC's taken every 8-Hours for 5-days. NOTE: Maximum anticipated SBHP is 3630 psi. \docs\dvp\d27.doc Attachment~.,,#2 ~ · _ ~OLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP · . GREASE HEAD (Hydraulically Activated) ,- LUBRICATOR · 4'~1/~-1,6~,'5000 psi CHISTMAS TREE POSITIVE CHOKE 2' 5000 psi -- 2' 3000 psi 13 3/8' CASING 33' Conductor 8 400' 3187' 13-3/8' 61ti, K-55 BuCt. 9-5)8' 40 & 47# N-80 & 47# P-IlO New CoMpletion 1-4-91 Attachment #3 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-87 All measurements ore RKB to top oF equipment, 40' Cameron 4.5' 8RD x But~ Tho Hngr (3.958' ID). 338' CAMCO 4.5' TRDP-4A SCSS¥ 3.813' I.D. .C. pmpletlon String, 0'-10,433' 4.5', 12.6#, L-BO 3utt Tbg w/ AB modl~lecl couplings Oos LIt~t mandreJs are 4.5' DanleJ's GLMSA w/l,5' side pockets. Equlped w/ RK lc~tch. Depth Vo, tve ,fl 2342' 4298' 5584' ~3 6578' #4 7885' ~5 7831' 8377' ~7 8901' #8 9484' ~9 9979' #lO 10,894' 10,365' 10,402' 10,420' 10,433' Baker SB-3A Pkr w/ 11.5' seat assembly G' MIUout Ext X/fl sub Otis 'X' nipple 3.813' I.]), Otis 'XN' (NoGo) nipple 3.785' I.D. She~rout Bolt Se~t sub/WI, Re-entrY.guide , B-l, 2 B-3 B-4 B-L8 B-3 B-4 B-5 B-6 PERFORATIONS lO,5RO'-580' 4 SPF 0° Phasing 10,610'-644' ' 10,685'-795' ' " 10,815'-988' ' 10,966'-992' ' Avg Der = 26.4' B-5 B-G 10,960' Cement Retainer, 35 S~cks Cemen~ sqzd below retolner. Revision g~te~ 1-22-91 Revised By, JDM PBTD 8 11,052' Re~son. New Compl, etlon TD 8 11,101' Previous Revlslom n/~ STATE OFALASKA ;.~ :~..~ ;,? OIL AND GAS CONSERVATION COM M IS"S'TON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandor, __ . Suspend __ Repair well __ Alter casing __ Change approved program __ Pull tubing __ Variance __ Name of Operator ] 5. Type of Well: . ... .I ,~ Development X UNOCAL (Marathon Oi 1 Co - Sup uDera~.or) Exploratory ~ Address ' I Stratigraphic __ P. 0. Box 190247 Anchoraqe, AK 995~9 Service__ Operation shutdown ~ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Perforate ~ Other X.~_I'!oY'kover 6. Datum elevation (DF or KB) 106' KB above MSL Z Unit or Property name Tradin§ Bay Unit Location of well at surface Leg A-1 Cond. //1 Dolly Varden 758' FSL, 1,206' FWL Sec. 6- 8N- 13W- SM At top of productive interval ' 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM Platform 8. Well number D_97 9. Permit number 75-24 10. APl number 5o733-20274 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,101' feet 9,805' feet PI ugs (measured) Sand Plug 010,945' Effective depth: Casing Structural Conductor Surface Intermediate measured 11,052' feet true vertical 9,760 ' feet Length Size 3,127' 13-3/8" Production ~,,,¢1 , 100 ' 9-5/8" L_iner'.., ~,-" t ~ ~ ' ~F~[t~,~l~,~. measured -oo\ Bench 1,2 \ ~,.,~.,~ ~ t) ~'Ji-r)Je ve~t~.CC~: Bench 3 ~ ' Bench 4 ~0~' GAS ~g~S' ~J~i~measured Bench 5 t',~m~~~~ depth) Bench 6 " N-80 ASL ~u ing 10 456' P~¢kV~an8 S~ ¢¢~e and measured *e~,) 0 , Baker FH Pkr 8 10,415'. SCSSV - Ot 13. Attachments ~1, 2 Description summary of proposal 3, P, ~. Junk(measured) 24' expended perf strip gun 8 10,945' Cemented Measured depth True vertical depth 2,900 sx 3,127' 3,011' 3,000 s x 11,100' 9,805' 10,520' - 10,580' MD 9,283' 10,610' - 10,644' MD 9,364' 10,685' - 10,795' MD 9,431' 10,815' - 10,928' MD 9,547' 10,9~6' - 10,992' MD 9,683' - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD is 4-1/2" DCX Tbg. Retrievable Ball Valve ._,.% Detailed operations program ~ BOP sketch ~ 14. Estimated date for commencing operation ,!anuar.v ! 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Y_._, Gas ~ Suspended Service 17 I hereby certif~ t%hat the foregoing is true and correct to the best of my knowledge. Signed {~\10,~.~ '~. ~-~ ~..~.,,, Title ~ ~ ~ r \ ~. ~o¢"' FOR COMMISSI(~ USE OI~ILY Conditions of ap al: N Commission so representative may witness ~' Plug integrity __ BOP Test __ Location clearance __ z/]~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Date [Approval No~/ Date ¢.~'-~/- ~"/ SUBMIT IN TRIPLICATE Attachment # 1 Well D-27 Procedure · 2. 3. 4. 5. 6. 7. 8. 9. Kill well with KCl prior to rig move. Confirm well is dead. Install pump through plug & BPV. ND tree, NU & test BOPE. Recover BPV and plug. Pull 4-1/2" completion. Clean out to 10,965' and recover wireline fish. Set bridge plug at 10,960' to plugback Hemlock Bench 6. RIH with 4-1/2" tubing, S¢SSV, side pocket mandrels, and packer. Set packer and test. 10. Install pump through plug and BPV. 11. ND BOPE. NU and test tree. 12. Remove BPV and plug. 13. Unload well and turn over to production. NOTE: Maximum anticipated BHP is 4200 psi. \docs\dvp\d27.doc oECEIVED .Oil .& Gas Cons. Attachment #2 MARATHON OIL COMPANI DOLLY.VARDEN PLATFORM BOP STACK U Flowline ~'~!_~~.~..~ 13 5/8'x 5000 pal Annular Preventer [o :] . o ...~ Clamp Conneclor ~ . Pipe~ -Rams ..J-~"/ 13 5/8' 5000 pal Double Rams Kill Lin. 3' 5000. p,i~L~ ' Bli,,~-"Ram' Chok. Lin. 3' 5000 pal Spool Pie~es to Calinghead Drill Deck Floo~ ~ (~) 3' Howco Lo Torque 5000 pal Valve All Flanges ere 3' 5000 psi Remote AdJus~ieble Choke · PrlllUrt Senior Manual Rig Floor RECEIVED CHOKE MANIFOLD · ~ ~ -- [ I 'Stop Cock Valve 3' ~ ~ ~ (~BeLeft Open) 1 1/2" Manual o o 2" Blind Flange 6' Io Shaker '""-'-- Choke Line 3" 5000 pal I . Attachment #3 ~OLLY VARDEN PL~,rFORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) - - ,,. LUBRICATOR MANUALLY OPERATED BOP · 4'::1/~1,~6~,'5000 psi CHISTMAS TREE POSITIVE CHOKE 2' 5000 psi ._-- 2' 3000 psi 13 3/8' CASING Attachment #4 ~ 33' Conductop e 400' 3127' 13-3/8' 611% K-55 Butt, 9-5/8' 40 '& 47ft N-80 & 47# P-110 MARATHON []IL COMPANY TRADING :BAY UNIT WELL D-B7 Proposed Completion AU measurements are RKO to top o£ equlpmen~, 40' C(imeron 4.5' 8RD x Butt Tbg Hngr <3.958' ID). ±300' CAHCO 4.5' TRDP-4A SCSSV Completion String: 0'-10,422' 4.5', 12.6I~, L-80 Butt AB Mod Tb9, Gas LiP% mandrets ore 4.5' Domet's GLH2A w/1.5' side pockets. Depth Votve t4 Type Latch Port Size ±2163' ~1 ALTEC RK 24/64 +3286' 4'4261' ~3 :[5096' ~4 +5796' ~5 4-6431 +7029' ~7 4-7578' 4-8094' ~9 4'8570' ~10 +9034' ~11 ±9436' ~12 4'9838' ~13 ±10,200' ~14 ALTEC RE 24/64 /VoT~ : Alp. i Z?~,~rc-/'..s o~ 4'10,375' B~ker SB-3APkr w/ti.6' SeaLs. Mittout Ext X/D sub Otls 'X' nlppte BtlS 'XN' (NoGo) hippie ±10,432' She6rou% Ball Se6t sub/~/L Re-entry 9ulde B-1,2 B-3 B-4 B-l,2 B-3 B-4 B-5 B-6 PERFORATIONS 10,520'-580' .4 SPF O' Phasing 2/89 10,610'-644 .... 10.685'-795 .... 10,815'-928 .... 10,966'-992 .... Avg Dev = 26.4' B-5 ±I0,96~' B6ker Modet 'N' Bridge Ptug. B-G Revision Date, 11/29/90 ReVised By, SL/nef PBT]] I~ 1L052' Re~son, Ppoposed Co.pier;on ~ TD t~ 11,101' Previous Revision, N/A DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, CONDUCTOR LEG #A-1: LAT = 60°48' 28.272" LONG =151°37' 57.620" TSN, R13W "Y" COORD. "X" COORD. WELL # FSL FWL 2,490,836.22 208,461.20 757.5 1212-0 1 2 3 4 5 6 7 8 9 lO ll 12 LEG #A- 2' 1 2 3 4 5 6 7 8 9 lO ll 12 LEG #B-l · LAT = 60°48' 27. 485" LONG :151°37' 57.564" 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11. D-32 762.9 .2,490,837.76 208,467.60 D-40 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 D-17 759.4 2,490,842.00 208,380.80 D-Il 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 2,490,756.22 208,462. O0 " 677.5 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 12t0.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1 2 3 4 5 6 7 8 9 10 11 12 LEG '~ =B-2o 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 &RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 (Reserved for Compressors) 674.8 1221.4 121'9.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 · 1'213.9 1213.4 1134.9 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 ush Regional Drilling Manager GSB/lew ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging Perforate X Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: I!~!OCAL (Marathon Oil Co - Sub Oper~ator) De._vel,opm. ent._.~X .................. ---I r-xp~ora~ory __ 3. Address ! Stratigraphic __ P. 0. Box 190247 Anchorage, AK 99~519 Service ' 4. Location of well at surface Leg A-i Cond. #i Ddiiy 'v'arden Platform Other 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-27 9. Permit number/approval number 9-159 1~7-%-~ ~/ 10. APl number 50- 733-20274 758' FSL, 1,206' At top of productive interval 522' FNL, 2,022' At effective depth At total depth 351' FNL, 1,825' FWL, Sec. 6 - 8N - 13W - SM FEL, Sec. 6 - 8N - 13W - SM FEL, Sec. 6 - 8N - 13W - SM 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,101 ' feet Plugs (measured) 9,805' feet Sand Plug @10,945' Effec!ive depth: measured true vertical 11,052' feet Junk(measured) 9,760' feet Casing Length Size Structural Conductor Surface 3,127' 13-3/8" Intermediate Production 11,10 O' 9 - 5/8" Liner Perforation depth:measured true vertical Tubing (size. grade, and measured depth) Cemented 24' expended perf strip gun @ 10,945' Measured depth True vertical depth 2,900 sx 3,127' 3,000 sx 11,100' 3,011' 9,805' Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,610' - 10,644' MD 9,364' Bench 4 10,685' - 10,795' MD 9,431' Bench 5 10,815' - 10,928' MD 9,547' Bench 6 10,996' - 10,992' MD 9,683' - 9,337' TVD - 9,394' TVD - 9,529' TVD - 9,648' TVD - 9,706' TVD 4-1/2", 12.6#,.N-80 ASL Tubing @ 10,456' Packers and SSSV (type and measured depth) 2" . Re tR ~/6 ~] ~'1~ ~alve Baker FH Pkr @ 10,415'. SCSSV - Otis 4-1/ DCX Tbg 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons, ~ch'orage 14. ,Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/31/89 341 344 969 1100 235 Subsequent to operation 2/27/89 455 250 1193 1120 15. Attachment~ Cf I ~ 16. Status of well classification as: Copies of Logs and Surveys run ..__. i Daily Report of Well Operations ~ Oil X Gas ~ Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)"Pi.~/¢.,,/_~--). ~/~..~,~;~ Title Environmental Engineer Form 10-404 R/e/v 06/15,8~ Service 120 Date 04/06/89 SUBMIT IN DUPLICATE Attachment Daily Summary of Operations TBU Well D-27 2/20/89 RU E-line and PT lubricator to 2500 psi. OK. RIH w/ 2-1/8" Enerjet, 4 SPF, 0° phased perforating guns. Correlate and perforate B-3 @ 10,610' - 10,640' DIL. POOH. Put well in test. 2/21/89 Make two perforating runs using same guns as before. RIH and perforated B-4 @ 10,690' - 10,710' DIL and @ 10,765' - 10,795' DIL. POOH, and put well in test. Left 24' of expended perf gun in hole. 2/23/89 RU E-line and PT lubricator to 2500 psi, OK. RIH w/ 2-1/8" Enerjet, 4 SPF, 0° phase perforating guns. Correlate and perforate B-1 and 2 @ 10,520' - 10,545' DIL. POOH. 2/24/89 MU perforating guns as before, RIH, correlate and perforate B-5 @ 10,8].5' - 10,845' DIL. POOH. RD. em/63A/DVP2 STATE OF ALASKA AL,"~KA OIL AND GAS CONSERVATION COM M Ib"51'ON 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 x Other 2. Name of Operator ! 5. Type of Well: Uf~OCAI. (Marathon Oil Co - Sub Operator) De._vel.°pm.entX- .............. --4 t-xp~oratory __ 3. Address ! Stratigraphic __ P. O. Box 190247 Anchorage, AK 9~519 Service__ 4. Location of well at surface Leg A--.l_ uond. j~'l UO'i-Ly varden Plak:form 758' FSL, 1,206' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6 - 8N - 13W - SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-27 9. Permit number 75-24 10. APl number 50-- 733-20274 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,101 ' feet Plugs (measured) 9,805 ' feet None Effective depth: measured true vertical 11,052 ' feet Junk (measured) None 9,760 ' feet Size Cemented Measured depth Casing Length Structural Conductor Surface 3,127 ' Intermediate Production 11,1 O0 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 13-3/8" 2,900 sx 3,127' 9-5/8" 3,000 sx 11,100' Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,620' - 10,644' MD 9,373' Bench 4 10,685' - 10,785' MD 9,431' Bench 5 10,828' - 10,928' MD 9,559' Bench 6 10,996' - 10,992' MD 9,683' 4-1/2", 12.6~f, N-80 ASL Tubing @ 10,456' Packers and SSSV and measured depth) Baker FH Y~re @ 10,415'. SSSV - Otis 4-1/2" DCX Tbg. Retrievable Ball 13. Attachment~ " CEIVED :-,la ka.O l & Gas Cons. C0mmi fr%v 3,011' 9,805' - 9,337' TVD - 9,394' TVD - 9,520' TVD - 9,648' TVD - 9,706' TVD Valve @ 334' .[ & Z Description summary of proposal __x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation February 1989 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 istrue and correct to the best of my knowledge. ~Signed ~o~/~).~' ~/¢~''~Roberts Title Environmental Engineer FOR COMMISSION USE ONLY Date2/24/88 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissi~)~,r,~, I1= c..qMITH Form 10-403 Rev 06/15/88 ......... d Copy Returned -'~mmissioner I Approva, No. /~.;?~./,~"-'~ Date SUBMIT IN TRIPLICATE Attachment #1 Well D-27 Procedure 1. RU slickline and PT lubricator. 2. RIH w/ 3.78" gauge ring and tag fill. POH & RD. 4. RU E-line and pressure test lubricator. 5. RIH w/ collar locator and perf. guns loaded at 4 SPF and perforate as follows: 1 3 10,610' - 20' 10' 2 3 10,630' - 35' 15' Test well for 12 to 24 hours. 3 4 10,675' - 690' 15' 4 4 10,690' - 710' 20' 5 4 10,765' - 795' 30' 6 1 10,520' - 545' 25' Test well for 12 to 24 hours. 7 5 10,815' - 845' 30' NOTE: Well beads severely. Pinch back production choke as far as possible to prevent being blown up hole. Open choke before perforating once out end of tubing to increase differential. Pinch back well again before pulling out of · , hole with expended guns. 5. RD E-line. 6. Obtain further test to verify production change due to perforating. Recommend five tests over next 30-day period. 63/DVP2 Attachment fi2 ~LLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) ,, LUBRICATOR MANUALLY OPERATED BOP 4 ~,1/~1,'6~.'5oo0 psi CHISTMAS TREE POSITIVE CHOKE STATE OF ALASKA ALASK-~.cOIL AND GAS CONSERVATION REPORT OF SUNDRY WELL 1. Operations performed' Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] Feet 3,0ti' 9,805' - 9,337' TVD - 9,394' TVD - 9,520' TVD - 9,648' TVD - 9,706' TVD · 100 psi 490 psi Date 5/23/88 Submit in Duplicate 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-1 Cond. #1 Dolly Varden Plat~or~ 758' FSL, 1,206' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6- 8N- 13W- SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6 - 8N - 13W - SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-27 8. Approval number 8-105 9. APl number 50-- 733-20274 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 11,101' feet 9,805 ' feet Plugs (measured) Sand Plug @10,949' Effective depth: measured 11,052' true vertical 9,760' feet feet Casing Length Structural Conductor Surface 3,127 ' Intermediate Production 11,100 ' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Junk (measured) None Size Cemented Measured depth 13-3/8" 2,900 sx 3,127' 9-5/8" 3,000 sx 11,100' Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,620' - 10,644' MD 9,373' Bench 4 10,685' - 10,785' MD 9,431' Bench 5 10,828' - 10,928' MD 9,559' Bench 6 10,996' - 10,992' MD 9,683' 4-1/2'.' 12.6#, N-80 ASL Tubin~ @ 10,456' Packers and ~SSV(type and measured dept~ Baker FH Pkr @ 10,415' True Vertical depth · SSSV - Otis 4-1/2" DCX Tbg. Retrievable Ball Valve 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4/13/88 497 Subsequent to operation 4/23/88 396 707 1160 1100 psi 777 768 1100 psi 14. Attachments 1 & 2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Roy-D.c,~ber~,~.n._- Title Environmental Engieer Attachment #2 TBU Well D-27 Summary of Daily Well Operations 4/20/88 RU CTU. RU injector head and lubricator, fill CT w/FIW and PT to 4000 psi, OK. RIH w/CT and cement nozzle and tag fill @ 11,032' CTM (10,982' WLM). Fill CT w/FIW, 1BPM @ 2800 psi. Hydrate GW-21 polymer is FIW w/3% KCl, mix 12-20, 20-40, 100 mesh sand and silica flour (approx. 2500#) @ 1.5 ppg. Pump 2 bbls FIW and 43 bbls sand slurry. PU @ 10 ft./min, when displacing sand from CT from 11,030' CTM. Initial pump rate ±1BPM @ 1500 psi with a final rate of 1BPM @ 1800 psi. Displace CT w/FIW. Sand plug on bottom @ 10,750' CTM. POH to 10,350' CTM and wait for sand to settle. RIH w/CT and tag sand plug @ 10,995' CTM (10,945' WLM). 37' of sand plug on bottom, 21' of sand above top B-6 perfs. POH w/CT. SI well. 4/22/88 RU slickline and lubricator, PT to 2500 psi OK. RIH w/3.70 gauge ring and tag sand plug @ 10,949 WLM. POH and RD. NEF/63A/Sundr4 9-5/8" 40 & 47# N-80 & 47# P-IlO casing TBU WELL 0-27 ATTAC, HM~NT #3 Completion Schematic (Completed 7/7/75) Depth ID Equipment 40' 3.958" Cameron 4½" 8RD x BUTT tubing hanger 394 3.813 Otis 4½" DCX tubing retrievable bali valve 4½" 12.6# N-80 ASL tubing . 2,534 2,571 3,610 4,687 5,504 6,324 6,975 7,584 8,O63 8,455 8,780 9,136 9,493 9,85) 10,176 10,339 4.000 4½" usI C2F sliding sleeve mandrels with McMurry M-DSVO-LP valves - top sleeve closed 10,377 10,415 3.813 3.992 4½" Otis XA circulating sleeve Baker FH packer Avg. Dev. : 26.4o 10,456 4.000 ' Bell nipple Perforations (DIL) 'Bench 1,2 10,520' - 10,580'.. Bench 3 110,620' - 10,644' Bench 4 10,685 - 10,785' · :Bench 5 10828 - 10928 Bench 6 IO966 - 10992 10,949' To~ .of Sand Plug . ~....'..~i.ll ..tagged @ 10,.985' PBrD ' ' · ' 11,101 TD 4788 8/87 .- NEF 5/88 STATE OF ALASKA ALASr~,~ OIL AND GAS CONSERVATION COMk.--~SION APPLICATION FOR SUNDRY APPROVALS 1~. Type of Request: Abandon E] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension l] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Add ress P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-i Cond. #1 Dolly Varden F±attor~ 758' FSL, 1,206' FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 522' FNL, 2,022' FEL, Sec. 6- 8N- 13W- SM At effective depth At total depth 351' FNL, 1,825' FEL, Sec. 6- 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-27 8. Permit number 75-24 9. APl number 50-- 733-20274 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 11,101 ' feet 9,805 ' feet Effective depth: measured 11,052' feet true vertical 9,760 ' feet Casing Length Size Structural Conductor Surface 3,127 ' 13-3/8" Intermediate Production 11,100 ' 9-5/8" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Plugs (measured) Junk (measured) None ' ~ ~v:nr'r~trd~ Cemented Measured depth ~e'~/~rt'ical depth 2,900 sx 3,127' 3,011' 3,000 sx 11,100' 9,805' Bench 1,2 10,520' - 10,580' MD 9,283' Bench 3 10,620' - 10,644' MD 9,373' Bench 4 10,685' - 10,785' MD 9,431' Bench 5 10,828' - 10,928' MD 9,559' Bench 6 10,996' - 10,992' MD 9,683' 4-1/2", 12.6#, N-80 ASL Tubin~ @ 10,456' Packers and SSSV(type and measured deptS) Baker FH Pkr @ 10,415' - 9,337' TVD - 9,394' TVD - 9,520' TVD - 9,648' TVD - 9,706' TVD · SSSV - Otis 4-1/2" DCX Tbg. Retrievable Ball Valve 12.Attachment~¢ 1 Description summary of proposal [] Detailed operations program [] BOP sketch [] Attachment #2 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~4,~_.':-~.-- D Ro~~' ~¢,cry . ~berts. Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Date 2/20/88 No. Approved by ORIGINAL SIGNED BY LONNI~ C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned Commissioner by order of the commission Date Submit in triplicate Attachment #1 Well. D-27 - Sand Back Hemlock Bench 6 Procedure 1. RU slickline and PT to 2500 psi. 2. RIH w/+_3.7'' gauge ring and tag fill. POH & RD. 3. RU CTU & pump equipment. Pressure test equipment to 4000 psi. 4. RIH & tag fill w/CT. 5. Spot sand/barite mixture in carrier fluid and allow sand to settle. 6. Tag fill and repeat Step #5 until top of sand plug is @ 10,928' (+10'). CTM. 7. POH & RD CTU. 8. Unload and test well. em/PMS / 612/OE27 9-5/8" 40 & 47# N-80 & 47# P-IlO casing Attachment #2 TBu WELL D-27 Pr. oposed. Completion Schematic {Completed 7/7/75} Depth ID Equipment 40' 3.958" Cameron 4½" 8RD x BUTT tubing hanger 334 3.813 Otis 4½" DCX tubing retrievable ball valve 4½" 12.6// N~80 ASL tubing . 2,534 2,571 3,610 4,687 5,504 6,324 6,975 7,584 8,063 8,455 8,780 9,136 9,493 9,851 IO,176 10,339 4.000 4½" USI C2F sliding sleeve mandrels with McMurry M-DSVO-LP valves - top sleeve closed 10,377 3.813 10,415 3.992 4½" Otis XA.circulating sleeve Baker FH packer Avg. Dev. : 26.40 10,456 4.000 - Bell nipple Perforations (DIL) 'Bench 1,2 10,520' - 10,580'.. Bench 3 10,620' - 10,644' Bench q ~ 10,685 - 10,785" Bench 5 10828 - 10928 Bench 6 IO966 - IO992 Top of Sand/barite Mixture @ 10,928' Fi]! ..ta:gg~d @ 10,985' 11,052 PBI'D 11,101 TO (Proposed plug) 8/.87 NEF 2/88 STATE OF ALASKA ALASKA O'fL AND GAS CONSERVATION CO'~rMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L)(;~ OTHER [] 2. Name of Oper~(~r~ Union u]I Company of California* 3. Address P. 0. Box 6247, Anchorage AK 99502 4. Location of Well Surface: Leg A-l, Cond #1, Dolly Varden Platform 758'FSL, 1206'FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 7. Permit No. 75-24 8. APl Number 50- 733-20274 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-27 11. Field and Pool McArthur River Field 12. 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 [] 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). On November 18, 1982, the well was perforated with 2-5/8" Sl imkone guns, 180° phasing, 4 HPF, under drawdown as follows' Bench #4 10,685'-10,785' DIL Benches #1 & #2 10,520'-10,580' DIL Tagged PBTD @ 10,989' DIL on the last run. Production before reperforatinq' 2114 BFPD, 42.5% BS&W, 1216 BOPD, 898 BWPD Production after reperforating' 2736 BFPD, 42% BS&W, 1587 BOPD, 1149 BWPD Reperforated Bench #3' 10,620'-10,644' DIL as above. Production after reperforating' 3192 BFPD, 45% BS&W, 1756 BOPD, 1436 uP E£EIVED * Marathon Oil Company Sub-operator 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~ The space below f~mmission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date ;sion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA E~rL AND GAS CONSERVATION CC~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 75-24 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50- 733-20274 4. Location of Well Surface' Leg A-l, Cond /tl, Dolly Varden Platform 758'FSL, 1206'FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB _~_bove MSL 6. Lease Designation and Serial No. ADT.-18729 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-27 11. Field and Pool McArthur ~River Field 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 [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull 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). It is Marathon's intention to reperforate the well with a 2-5/8" carrier gun at 4 HPF, 180° phasing, under drawdown. Benches #1 and #2 Bench #4 10,520'-10,580' DIL~ 10,685'-10,785 ' DIL h~ ** Bench #3 10,614'-10,644' DIL July 1982 production test averages: 2314 BFPD, 42.50% WC, 1330 BOPD, 984 BWPD. UNION OIL CO. OF CALI~, ANCHORAGE DISTRICT ANCHO~GE, ALAS~ ** Bench #3 will be perforated if Benches 1,2, and 4 do not show a significant increase in production. *Marathon Oil Company - Sub-Operator 14. I ereb t the fore~qoing i~s-true and correct to the best of my knowledge. ¢!'! !qi~?) ~'":: '"- --~ DIST DRI. JS SUPT. Date 08/30/82 Sign ~elow for Commission use -- ~ditions of Approval, if any: BY IONNIE C. Approved by COMMISSIONER Approved Copy Returned By 0~ the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. i'-:L0"73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL 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.) 1. OIL ~ GAS r-] WELIZ/E~_l WELL g-J OTHER 2. NAME OF OPERATOR Union 0il Company of Cai ifornia* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL At surface Leg A-l, Cond #1, Dolly Varden Platform, 758'FSL, 1206~FWL, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2~KB MLLW 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50- 133-20274 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 7. If INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Un it 9. WELL NO. D-27 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO. 75-24 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L----J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL 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. 08-25-79 Perforated roi lowing intervals under drawdown: Benches 1 & 2: lO,521'-10,578'DIL 4 HPF 3-3/8" SOS carrier gun Production Test: Test Before Perforations: Test After Perforations: 2262 BFPD, 7.5% WC 2943 BFPD, 14~ WC *Marathon Oil Company - Sub-Operator 16. I hereby~ that the fo~ Is true and correct (Th~co for State office us~) Dist. Drlg. Supt. DATE 9/19/79 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Attachment I TRADING BAY UNIT WELL D-27 PERFORATION RECORD Following are the perforated intervals in the Hemlock formation presently open to production in Well D-27: Hemlock Perforated Footage Shot Total Bench Interval (MD) Shot Density Holes 10,688-10,784 96' 3 HPF 288 10,828~10,928 100' 3 HPF 300 10,966-10,992 26' 3 HPF 78 Total ..... 222' .......... '~66 Ail of the above holes shot with 3-1/8" jumbO jet casing guns, run thru-tubing which provide a 0.40" diameter hole. Document Transmittal Union 0il Company of California unl®n TO H. lA;. Kugler Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 DATE 5UE)MITTED 2/2/76 ACCOUNTING MONTH FROM R. G. Warthen AP.O. BOX Anchorage, AK 99502 ITELEPHONE NO. TRANSMITTING THE FOLLOWING: I Marathon TBU D-27: GN-FD FDC ~ Synergetic Log Marathon TBU D-34A: 2" DIL 2" Sonic FDG GN-FD Direction, 1 Surve' Gamma Ray VDL (BL only) DATE' FORM 369 (REV 2/70) PRINTED IN U,$.A, Union Oil and Gas r"";,ision: Western Region Union Oil Company-df California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 t DIS .. union A.ugust 22, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS D-27 (31-6) DOLLY VARDEN PLATFORM Dear Mr. Marshall: Enclosed for your files are three (3) copies of the Well Completion or Recompletion Report & Log (Form P-7) and two (2) copies of the Well History for Trading Bay Unit State Well D-27, Dolly Varden Platform. sk Encl. (5) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Phillips Petroleum Skelly Oil Co. Standard Oil Co. USGS - Rodney Smith Very truly yours, Jim R. Callender District Drlg. Supt. SUBMIT IN 12 ~-~tCATE* STATE OF ALASKA st ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL CO~PLETION OR RECO~PLETION REPORT AND LOG* -Is. TYPE OF WELL: I [ Other ~% EI.I. WELL ~ DRY b. TYPE OF COMPLEX@N: WEI,I. ()VEIl 2. NA 51E OF OPERA'rOIt *Union 0il Company of California ADDRESS 0F OPERATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. ],oc,,.'rmx o~~ wm,L (Report location clearly and in accordance with any State requgrements)* 5. AP1 NUIVIERICAL CODE ADL- 17594 6. LEASE DESIGNATION AND SERI2kL l~lO. 7. IF INDIA. N, ALLOTTEE OR TRIBE NA1VIE Trading Bay Unit 8. UNIT,FAtl2VI OR LEASE NAME Trading Bay Unit 9. WELL NO. 9-27 (31-6) 10. FIELD A2qD POOL, OR WILDC&T McArthur River Field, At surface 758' FSL & 1206' FWL of Sec 6, T8N, R13W, Cond. 1, Leg A-i, Dolly Varden Platform At top prod. interval reported below Hemlock Top: 522' FNL, 2022' FEL, Sec 6 @ 10,520' MD At total depth 351' FNL, 1825' FEL, Sec 6 @ 11,101' MD 1:;. DATE SPUDDED [14. i)ATE T.D. I~E, ACHED{is. DA~ COSIP SUSP OR ABAS. 4/25/75 ~ 6/14/75 [ 7/6/75 ItL IOTAL DEI~fft MD & TVD~9. PLUG, BACK MD & ~D~. ~ MULT~LE CO~L., t 21. 11,101' 29 & ~, ~,, aow~. ~,805' TVD bz,u~z ~'~ a 9,76ffTVp Single Comp. 1 ~. PIIODUCiNG !NT~HVAL(S~, OF ~.IS CO~P~TION--TO,P, BOSOM, NAME (MD AND Hemlock Fm. 10,688'-10,784' MD 9,416'-9,519' TVD " " 10,828'-10,928' ~ 9,559'-9,648' TVD ~ ~ ~ ~--1~ OO9~ M~ Q ~q~_O ~ DIL-SP LL8, GR Sonic, FDC, ~L, Caliper, CBL i iii ~. CASING RECORD (Report all strings set in w~ll) Zll. 12. ~"~..?'I'.¥1~'M., (BOTTOM HOLE OBJECTIVE) Sec. 6, TSN, R13W, SM @ TD PE~R~I IT NO, 75-24 Cf~SI~4C; SIZE 13-3/8" 9-5/8" **Squeezed 26 LIN ER Ir~ECOH-D t16.' ELEVATIONS (DF, ]:IKB, RT, GR, ETC)* 17. ELEV. CASINGHEAD +106.2' KB (MSh) I +65.2' (MSL) INTERVALS DRILLED BY CABLE TOOl, 8 ROTARY TOOLS ALL 1#, K-55 I [ 3,1~7" ' 2900 sacks 0 a 47#, N-~0 [ [ I -110 [ I il.100' I 12-1/4" 2 stages...3000 sacks** 53 sacks c{ment t~ru D~ tool l@ 6,485'I None 28. PEiiF~)IiAT/ONS OPEN TO PRODUCTION (interval, size and nurnber) (See Attachment I) 23. '~VAS DIRECTIONAL SURVEY IV}ADE Yes ,i 30. PF~ODUCTION £~5OUNT PULLED None!'? ,, MI) in 7 iobs ] SCi-tEEN iR[D) SIZE ' DEPTH SET (~D) ~ PACKER SET 4-1/2" 10:456' i 10~h22': I ,1 . 29, ACID, Si!OT, FilAC2 URE, CP~'4ENT SQUE~Z-~, ETC. D~T~i INT~V.~ (MD) [ AMOUNt ~D }~!ND OF MATE~3AL US~ l None [ DA'fl:; F'IH>;T [.q;ODLICTION [ PIIODUCTION MEI[{OD (FlowiiNL [.']a3 lif~, parnping--size and type of pump} 7/6/75 [ Gas Lift ,,ATE OF TEST, I}[UURS q ESTD ICI!OXE SiZE Ipp. oD'N FOR OI~BBL. GA~MCF. tTEST PEIL! 7/7/75 [ ~ 2A I Open ~ I 5,669 'l 1,617 FLOXV, TU[I1N(i ICA~;I.N~r PRESSURE ICALC~T~ OI~BBL. mm.ss. 1 [~¢-HOUR ~ I 220 psig I 1100 psig[ >, 5,669 [ 1,617 31. omPosrrloN o~' cas (Sold, u~ed for ]uel, vented, etc.) I ~VELL STATUS (Producing or Producing ~V£ffER--I3BL. I GAS-OIL rLkTIO [ 6 [ 285 Wt~'I'E~--BBL. [OIL GRAVfi'Y-2MPI (COLOR,) [ 6 I 35° tTES~ WITNESSED BY · D. Rams ey Delivered to Marathon-Union Gas Gathering System 32.lAST OF ATTACHMENTS I - Perforating Record II - Directional Survey . :';,2. I herebY' certif.~ that the fore~, 0)~g and attached information is complete ancI correct as determined from all-available records ..?]..:''' Jim---l~..Callender *(See Instructions and Spaces [or Additional Data on Reverse Side) *14arathon 0il Company --- Sub-Operator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log or'~ all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise sho'w,~) for depth measure- merits given in other spaces on this form and in any attachments. Items 20, ancl 22:: If this well is completed for separatc, production from more than one ir~terval zone (multiple completion), so state ~n item 20, and ir~ item 22 show the prcJucir~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce,,"J, show- ing the ackiitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ 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 produced. (See instruction for items 20 and 22 above). 34. SUMMktiY OF' FO~MATION TESTS IN(;LUi)IN(; INTERVAL TF. STED, PR~URE DAT~ ~~OV~I~ OF OIL: GAS,- 35. G~G IC MARK~ WAT~ AND MUD , , NA~ -- -- , Il Ill m d I I .... G-Zone Top - 9,696~ ~ Bottom- 10,520~ ~ Sand, sSlt, coal, & clay G-Zone 9,696~ 8,5~5~ Hemlock Top - 10,520~ ~ Bottom - 11,020~ HD Sand, conglomerate, ~ silt Hemlock Fm. 10,520~ 9,760~ Il Illl I III IIllll I I ...... ' I Il I I I I I I Il i 'l , I' i .i . ,.. i .... i i ii Jill i i i ii .... i .... ii ii i i i ii i i ..... ~i, i i~, i i , i i d · ~ ~OR~ 484 HI:V. :~-~ DAT~Z Aug. 15, 1975 MA ATHON OIL COMPI "NY FIELD MgArthur River HISTORY Of OIL OR GAS W~-I_L ( 31-6 ) BEG~ WELL NO. D-27 LEASE Tradinq Bay Unit SEC. 6 TWP.. 8N r. 13W PAriSh, ' Surf. Loc: Cond. #1-758.1 FSL & STATE Alaska COUNTY Kenai Peninsula Borough 1205.5' FWL, Leg A-1 MEASUREMENTS TAKEN FROM K.B. ELEV. ~06,2 ' MSL fToP OF OIL STRING ELEV TOP OF ROTARY TABLE__ ELEV. GRD. OR MAT. ELEV. HISTORY PREPARED bY K. A. Thoma T,TLE Drilling Engineer 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, ali completion operations and procedure, etc. DATE 1975 _ 4/26 4/27 4/28 .4/29 4/30 WELL HISTORY--D-27 (Marathon AFE #4524) Note: Report is to 7:00 AM for previous 24 hours operation· Skidded Rig #76 from Well D-24A over Conductor #1, Leg A-1. Installed O-C-T adapter over 33" conductor and installed 20" Hydril-Riser. Tested to 500 psi--OK. Picked up 17-1/2" bit and drilling assembly & cleaned out conductor to 400' with gyro surveys at 121', 254', & 346'° Spudded Well D-27 at 12:01 AM, 4/27/75. 546' TD - Drilled to 405' & surveyed. Drilled to 410' when water injection line broke over N-1300 pumps and knocked out blower motors. Repaired blowers (11-3/4 hrs) . Circulated & conditioned mud to 200 + viscosity'. Bit plugged-POH. RIH and drilled to 425'. Bit plugged-POH. RIH and drilled to 546'. Tripped for plugged bit. . 1480' TD - Drilled from 546' to 1480' with surveys at 546', 692' 942' 1189' and 1407' I I I · 1480' TD - While drilling at 1480', the 17-1/2" bit began torqueing. Circ. bottoms up. POH & layed down 17-1/2" bit & BHA. RIH with 12-1/4" bit-no stabilizers-to 1480' & rotated with 2,000# to 7,000# of 20 min. while cheCking Kelly & Well D-20 (Leg B-l) for noise. Circ. up no iron and had no indications of drilling on D-20. Bit torqueing. ~ Shut-in Well D-20 & began bleeding gas lift pressure off 9-5/8" annulus as a precaution. Well D-27 began unloading mud - picke~ up Kelly, shut down pumps, & closed 20" Hydril. Had no pressure on DP or annulus. Circ. & had full returns through choke line for 15-20 min..@ 300 psi - then lost returns. Pumped 850 bbls of 9.7#/gal mud & 650 bbls. Filtered inlet water down DP with no returns on annulus. Shut-in & checked to find no pressure under Hydril. Opened Hydril & found fluid down 100' in conductor (sea level). Had no gas, so POH with DP. RIH to 460' with open-ended DP. Mixed and pumped 2 bbls of dye--could not see in Inlet. Mixed & pumped 1 bbl of soap, but did not see in Inlet. 1480' TD - Mixed & spotted dye through DP & surfaced on Inlet in 30 min. Began mixing mud while waiting for boat with cement. With open-ended DP @ 400', mixed & pumped 500 sx of Class "G" cement with 1% D-31, 15.5#/gal slurry. Hole filled with fluid to surface and circ. out flowline 2 min. Displaced cement with 4 bbls of water & POH. W.O.C. & mixed mud. Filled hole with water--standing full @ surface. Preparing to RIH. WELL HISTORY--D-2 ;- Page 2 -- s/2 $/3 514 5/5 5/6 5/7 5/8 '5/9 774' TD - RIH to 390' with 17-1/2" bit. Drilled out cement to 410'. Displaced Inlet water from hole with 9.4#/gal mud. Cleaned out to 590'. POH to 400" - 33" shoe, & circ. & conditioned mud. RIH to 590'. Cleaned out to 774' & ran Sperry-Sun gyro survey, which indicated drilling new hole, out of previous well course. POH to 546' & re-surveyed. POH to pick up BHA & new 17-1/2" bit. 1174' TD - RIH to 774'. Drilled & surveyed to 1132'. Circ. before POH. Layed down 17-1/2" assembly. Picked. up 12-1/4" bit, 7-3/4" Dyna-drill #1, and 2° bent sub.. RIH to 1,132' & oriented Dyna-drill to direct D-27 to northeast away from D-20. Drilled to 1174' with Dyna-drill, POH and layed down tool. Began picking up 12-1/4" BHA. 1605' TD - RIH to 400' w/12-1/4" assembly. Repaired drawworks electrical control panel-fluid damage from blowout-7-1/2 hours down. RIH to 1174', drilled & surveyed to 1605'. POH & layed down 12-1/4" assembly. RIH w/17-1/2" hole-opener & opened '~. 12-1/4" to 17-1/2" to 1400'. 1742' TD'- Opened hole to 17-1/2" to 1450'. Surveyed before POH to clean bit & stabilizer. RIH & finished opening hole to 1604.'. POH & layed down hole-opener. RIH w/ 12-1/4" bit, 7-3/4" Dyna-drill #2, and 2° bent sub. Oriented tool, Dyna- drilled, & surveyed to 1742'. POH. Dyna-drilled to turn well course from northeast to northwest (to lead well course) and to build angle. 2193' TD - Finished out of hole & layed down Dyna-drill. Picked up 17-1/2" hole-opener &RiH. Opened 12-1/4" to 17-1/2" from 1604' to 1742'. Circ. hole before POH - layed down hole-opener. RIH w/ 17-1/2" bit & 7--7-3/4" DC, S - drilled & surveyed to 2,193 ' . POH. 2,496' TD - Finished out of hole to change BHA & check bit. RIH w/ 17-1/2" bit & drilled and surveyed from 2,193' to 2,449'. POH & layed down 17-1/2" assembly. RIH w/ 12-1/4" bit, 7-3/4" Dyna-drill #3 & oriented tool. Drilled to 2,496' with mud-motor before POH. Picked up 12-1/4" BHA. 3,155' TD - RIH w/ 12-1/4'; BHA, drilled and surveyed from 2,496' to 3,155'. POH & strapped drill pipe. Layed down 30 joints of 5" DP. RIH with 17-1/2" hole-opener. 3,155' TD - Opened 12-1/4" to 17-1/2" hol~ from 2,449' to 3,155'. Circ. before POH. Cleaned stabilizers & hole-opener. RIH, circ. & conditioned hole to run 13-3/8" casing. POH & began running casing at 5:00 AM. 3,155' TD - Ran 13-3/8" casing to 410'--could not get deeper. Pulled and layed down 11 joints of casing & found cement on shoe. RIH with 2--17-1/2" hole-openers (piggy-back) and reamed from 410' to 460'. Finished in hole to 3,155' & circ. hdle. POH. Ran 78 joints of 13-3/8" OD, 61#/ft, K-55, buttress casing with shoe at 3,127' and collar at 3,048' KB. Circ. casing prior to cementing. Casing detail listed below: 13-3/8" Surface Casing. Detail .. Description Length 1 - C.I.W. 13-3/8" Casing Head w/ Buttress Pin Down 1.50' 76- Joints 13-3/8", 61#, K-55, Buttress Csg, Rge.3, Cond.1 3004.29' 1 - Baker Differential Fill Float Collar 1.95' 2'-Joints 13-3/8", 61#, K-55, Buttress csg., Rge.3, Cond.1 74.20' 1 - Baker Differential Fill Float Shoe 2.67' From To ., 42.80' 44.30 ' 44.30' 3048.59' 3048.59 ' 3050.54' 3050.54' 3124.74' 3124.74' 3127.41' WELL HISTORY--D-~--~ Page 3 -- 5/9 (cont.) 5/10 Ran 5--13-3/8" centralizers at following depth: 2,970' 3010' 3060' 3091' & 3 121'. I , , · 3,155' TD - Cemented 13-3/8" casing by pumping 30 bbls of water ahead of 2100 sx of Class "G" cement w/ 6% gel & 0.8% D-31, 13.5#/gal. Tailed in w/ 400 sx of Class"G" Neat w/ 1% D-31, 16.2#/gal. Dropped plug & displaced with 464 bbls of mud w/ rig pump. Had good returns through-out job, but no cement to surface. Bumped plug w/1200 psi - floats held OK. Cement in place at 9:15 AM, 5/9/75. W.O.C. & picked up 20" Hydril & centered 13-3/8" pipe in 33" conductor. Ran 142' of 2-1/16" pipe between 13-3/8" & 33", & tagged cement at 135'. Pumped 5 bbls of water ahead of 100 sx of Class "G" cement with 6% gel & 0.8% D-31 and followed with 335 sx of Class "G" Neat w/l% D-31 & 2% calcium chloride. Broke out landing joSnt and nippled down BOPE. Installed 13-3/8" casing head & began to nipple up BOPE. 5/11 3,155' TD - Finished nippling up 13-5/8" BOPE & riser. Tested stack to-3,000 psi--OK. Tested Hydril to 2,000 psi--OK. Tested choke & kill lines & choke manifold to 3,000 psi--OK. Broke & layed down 17-1/2" BHA. Picked-up & RIH w/ 12-1/4" bit & BHA & tagged cement at 3,017'. Drilled cement to 3,040'. 5/12 3,444' TD - Drilled cement, float collar, & float shoe to 3,131' --tested casing shoe with 500 psi. Surface pressure (equivalent tO 13.0#/gal mud). Drilled from 3,155' to 3,248', circ. & surveyed before POH.. Ran Sperry-Sun gyroscopic survey. Changed BHA & RIH putting rubbers on 5" DP. Drilled & surveyed from 3,248' to 3,444'. 5/13 .4,201' TD - Drilled & surveyed from 3,444' to 4,174'. POH & changed BHA. Cut drilling line. RIH & drilled from 4,174' to 4,201'. 5/14 5/15 4,950' TD - Drilled & surveyed from 4,201' to 4,783'. POH to change bit & check BHA. RIH & drilled to 4,950'. Down 1/2 hr to repair control on EMD. 5,430' TD - Drilled & surveyed from 4,950' to 5,430' with trip for bit #12 at 5,243' - changed reamer. 5/16 5,875' TD - Drilled & surveyed from 5,430' to 5,667'. POH for bit #13 & checked BHA. RIH to 3,100' -- .down 4-1/4 hours to repair hole in cooling water line to EMD's. Finished in hole & drilled from 5,667' to 5,875'. 5'/17 6,198' TD Drilled from 5,875' to 6,198' - , circ., & surveyed prior to POH for bit #14. Down 10-1/2 hours to repair drawworks electrical panel. 5/18 6,530' TD - Finished repairs on drawworks .electrica~ panel & RIH to drill from 6,198' to 6,1530' with surveys at 6,365' & 6,489'. 5/19 6,913' TD - Drilled & surveyed from 6,530' to 6,913' with a trip at 6,613' for bit #15 & to change BHA. 5/20 6,938' TD - Circ. & surveyed at 6,913' before POH. Layed down square stabilizers & roller reamers. RIH with 7-3/4" Dyna-drill #4, slipped drilling line 45' & shut-down 1-1/4 hours to repair AC power failure (short) in EMD cabinet. Ran survey tool to orient Dyna-drill, but instrument barrel backed off leaving instrument in hole. POH - survey instrument destroyed. RIH to 3,357' & had to work Dyna-drill through bridge. Finished in hole, 6riented tool with survey instrument & began Dyna-drilling. Had another AC power failure, replaced plug in EMD cabinet & contin- ued drilling. WELL HISTORY--D-27~' Page .4 ~-- 5/21 5/22 5/23 5/24 5/25' 5/26 5/27 5/28 5/29 5/30 5/31 611 6/2 6/3 6/4 6/5 6/6 6/7 618 6/9 7,200' TD- Completed Dyna-drill #4 run--total tool run from 6,913' to 6,953' (40') to get more right-hand turn (northeast). POH & changed out Dyna-drill for 12-1/4" BHA. RIH to 3,100' & installed new plug in EMD power panel--down 1 hour. Finished in hole & drilled from 6,953' to 7,200' with surveys at 7,016' and 7,109' . 7,502' TD - Drilled & surveyed from 7,200' to 7,502' with trip for bit #18 at 7,222'. 7,650' TD - Drilled & surveyed from 7,502' to 7,650' with trip for bit #19 at 7,530'. Tested BOPE to 3000 psi--OK, changed BHA & cut drilling line. 8,083' TD - Drilled & surveyed from 7,650' to 8,083' with bit #19, HTC--Type J-22. 8,097' TD - Drilled from 8,083' to 8,095'. Surveyed prior to POH. RIH with 7-3/4" Dyna-drill #5 to 3,452', but could not work through bridge (2° bent sub). POH & layed down Dyna- .drill. RIH with 12-1/4" drilling assembly to 3,540'. Circ. & spotted high-visc, gel pill from 3,250' -to 3,540'. POH & RIH w/ Dyna-drill #5--oriented tool & drilled to 8,097'. 8,205' TD - Finished Dyna-drill run from 8,095' to 8,123'-28' to get right-hand turn (NE). Surveyed & POH. RIH with drilling assembly, reamed tool run to 8,123', and drilled to 8,205' with survey at 8,188'. Repacked swivel - 1. hour. 8,375' TD - Drilled & surveyed from 8,205' to 8,375'. Began POH for new bit. 8,506' TD - Finished out of hole. RIH w/ bit 922 and drilled from 8,375' to 8,506', circ. & surveyed before POH for bit change. Started RIH w/ bit #23. 8,670' TD - Finished in hole and drilled from 8,506' to 8,670' w/ survey at 8,626'. 8,902' TD- Drilled from 8,670' to 8,902' w/ trip for bit #24 .. at 8,787' --changed BHA. 9,120' TD - Drilled from 8,902' to 9,120' w/ survey and trip for bit #25 at 8,992'. Cut drilling line 90' and slipped 45'. Honed & cleaned commutators on motor on #2 mud pump. 9,269' TD - Drilled from 9,120' to 9,269' w/ survey and trip for bit #26 at 9,194'. 9,428' TD - Drilled to 9,385'. Sur'veyed. POH for bit change. RIH and drilled to 9,428'. 9,566' TD - Drilled to 9,566'. Surveyed. Tripped for new bit. 9,654' TD - Drilled to 9,654'. Surveyed. Tripped for new bit and changed BHA. 9,79'0' TD - Finish6d RIH with new bit. Drilled and surveyed from 9,654' to 9,790'. Round trip for bit change. o9,940' TD - Drilled & surveyed to 9,940'. Tripped for new bit. Slipped & cut drilling line. . 10,111' TD - Finished in hole with bit. Drilled and surveyed to 10,111'. 10,200' TD - Finished out of hole. 'Tested BOPE--OK. Changed BHA. RIH. Drilled to 10,200'. Surveyed & POH. 10,310' TD - Finished trip for new bit. Drilled to 10,310'. POH. WELL HISTORY--D-27 Page 5, 6/10 10,477' TD - Finished trip. Slipped and cut drilling line. Drilled to 10,477'. Dropped survey and started out of hole· 6/11 6/12 10,574' TD - Finished trip for new bit. Drilled to 10,574'. Tripped for new bit. 10,747' TD - Finished RIH and drilled to 10,747'. Tripped for new bit. 6/13 6/14 6/15 10,940' TD - Finished trip for new bit. Drilled from 10,747' to 10,940'. 11,014' TD - Drilled to 10,960', POH. Worked through tight hole @ approx. 8,200' & 6,800'. Changed BHA. RIH· Drilled to 11,014'. 11,101' TD - Drilled to 11,015'. Tripped for new bit. Drilled to 11,101'. Circ. hole clean. POH to log. 6/16 11,101' TD - Finished out of hole. Rigged up Schlumberger. RaN DIL- SP & LL8 logs from 11,090' to 3,127'. Ran G-R-sonic.-' from 11,090' to 3,127'. Ran FDC & CNL & caliper log from 11,090' to 3,127'. 6/17 6/18 11,101' TD - Rigged down Schlumberger. RIH 'w/ 12¼" bit to 11,101'. Circulated hole clean. POH and layed down B.H.A. Pulled ware ring. Installed 9-5/8" pipe rams. Rigged up to run casing. Running 9-5/8" casing. .. 11,101' TD - Finished running 9-5/8" casing--total 274 jts with shoe @ 11,100' float collar @ 11,016' and D.V tool @ 6,485' , · · 9-5/8" Cas,lng Detail,, _D~s~r_ip~ti on ~ From__ 40.70 0 40.70 .2.00 40.70 42·70 2,910.64 42,70 2,953·34 3,531·91 2,953.34 6,485.25 1.77 6,485·25 6,487.02 2,372·96 6,487.02~ 8,859·98 2,156·00 8,859.98 11,015.'98 1·83 11,015.98 11,017·81 80.05 11,017.81 11,097.86 2.57 1'1,097.86 11,100.43 -- -KB to C.I.W. Tubing Spool Top 1 -C.I.W. 12"-3000# x 10"-5000# Tubing Spool 73 -9-5/8", 40#, Butress Csg, N-80, Rge? 3, Cond. 1 87 -9-5/8", 47#, Butt. Csg., N-80, Rge. 3, Cond.1 1 -9-5/8", Baker DV Stage Collar 59 -9-5/8", 47#, Butt. Csg, N-80, Rge. 3, Cond.1 53 -9-5/8", 47#, Butt. Csg, P-110, Rge. 3, Cond. 1 1 -9-5/8", Baker Differential Fill Float Collar 2 -9-5/8", 47#, Butt. Csg., P-110, Rge. 3, Cond. 1 1 -9-5/8", Baker Differential Fill Float Collar Ran 4 Centralizers at following depths: 6,444' 6 527' 10 793' and 11 058' Filled casing & circ. hole to cond. & clean hole. Cemented casing as follows: 1st stage--30 bbls water, 1000 sx class "G" cement with 4% gel, 1% D-31, 0.3% R-5, 14.5 #/gal slurry, followed with 500 sx class "G" cement with 1% D-31, 0.3% R-5, 15.8 #/gal slurry. Dropped plug. Displaced cement with mud. Bumped plug with 1500 psi. Cement in place @ 8:15 PM. Bled off pressure & plug held OK. Dropped D.V. bomb & pressured to 1100 psi and open D.V. tool @ 6,485'. Circ. mud for 2-3/4 hours--no cement from 1st stage. 2nd stage--30 bbls water, 1200 sxs class "G" cement with 4% gel, additives same as above. Followed with 300 sxs class "G" With same additives as above. Dropped plug & displaced with mud. Bumped plug with 3000 psi & closed D.V. tool. Cement in place @ 1:45 AM 6/18/75. Bled off pressure & D.V. tool held. No cement returns @ surface on 2nd stage. Picked up BOPE & set slips with 260:000 lbs. pUll on casing. Cut off casing & starting installing tubing spool. 6/19 6/20 6/21 6/22 6/23 6/24 WELL HISTORY--D-27 Page. 6 11,101' TD - WOC 24-1/2 hours. Top cement @ 10,994'. Tested tubing spool to 3000 psi. Flanged up riser and BOPEo Tested "pipe rams and blind rams to 5000 psi. Tested Hydril to 2000 psi. Picked up 8-1/2 bit. 9 - 6¼" DC and measured in hole. Hard cement at 6,477. DV tool at 6,485'. Drilled out DV tool. Ran into 6,555 closed pipe rams and tested casing to 3000 psi. Bled off to 1700 psi in 15 min. RIH to 10,994. Cement 22' above float collar. Drilling on cement at 11,000'. 11,101' TD - Drilled cement to 11,015', top Of wiper plug. Drilled plug & float collar. Drilled hard cement to 11,033. Circ. hole clean & POH. Rigged up Sch. & ran CNL-G/R log from 11,026' to 3,127'. RIH with RTTS packer. Set @ 6,505 (20' below D.V. tool) and ~tested 9-5/8 casing to 3000 psi--OK. Reset tool @ 6,475' (10' above D.V. tool). Pressured tool to 3000 psi--bled~off to 1,'800 psi in 15 min. Pressured to '2,900 psi and pumped into formation 3 BPM @ 2,300 psi. Pulled tool to 6,313'. Spotted 150 sxs class "G" cement with 1% D-31 (15.5#/gal). Set packer. Pumped 10 bbls cement through D.V. tool and pressure increased to 5000 psi. Bled off pressure and back flowed 20 bbls. Reversed out 137 sxs cement. ReverSed to clean drill pipe. Pulled 3 stds. & circ. hole clean. POt{ with RTTS. Finished out of hole with RTTS. RIH with 8½" bit and scraper to 6,000'. Circ. mud. Total WOC 12 hours. RIH to 6,46 4'--no cement. Circ. mud 1 hr. Tested 9-5/8" casing. Pumped away @ 3. BPM @ 2,300 psi. POH. RIH with Halliburton cement retainer and~set @ 6,402'. Pumped into formation. @ 3% BPM with 2400 psi. Spotted 150 sxs class "G" cement with 1% D-31o Squeezed D.V. ..... to.ol-~with 115 sxs with max. pressure of 2,200 psi @ ½ BPM. Pulled ~ '~ut'~.~'f'~retainer and reversed out 1½ bbls cement. Cement in. place @ 8:50.PM 6-20-75. Pulled one std. Circ. mud to clean drill pipe. POH. RIH with 8½" bit. Started drilling soft cement @ 6,397. Soft cement to 6,402'. Started drilling on retainer @ 6:00 AM, 6-21-75. 11,101' TD - Finished drilling cement retainer @ 6,402'. Drilled hard .cement to 6,405--soft cement to 6,460' - hard cement to 6,521' . Stopped drilling on hard cement' Pressured casing & pumped through D.V. tool @ 4½ BPM @ 2,700 psi. 'POH. RIH with 19..-...5/8 RTTS packer and set @ 6,313'. Pumped through D:V. tool -.~i"r."~..~..-bf 3½ BPM @ 2 400 psi Mixed and spotted 150 sxs cement· · , ,,--' ' ~ ... · · c-~ass' '"G" with 1% D-31. Squeeze pressure increased from 1900 to 2'300 psi--pumped all cement away and over flushed With 12% bbls mud. Job completed @ 10:00 PM. Held pressure on casing for 6 hours. Bled off pressure and reset packer. 11,101' TD - Finished WOC. Pumped into D.V. tool.@ 2,200 psi @ 1¼ BPM. Released packer and spotted 150 sxs class "G': cement with 1% D-31. Set packer @ 6,313' and' pumped all cement away with max. pressure of 2,500 psi @ rate of ½ BPM. Held 2000 psi for. 5.hours. Bled off pressure and pull one single. Reversed ~.ut~,..' 'Set packer @ 6,283'. Pumped into D.V. tool @ 1½ BPM @ 2~200 psi. Mixed and spotted 150 sxs class "G" cement with 1% D-31. Set tool and squeezed D.V. tool with 115 sxs. Min. pressure--2200 psi. Final and max. pressure 2800 psi. Held pressure 4½ hours. 'Released pressure and POH. WOC 12 hours. RIH 'with 8%" bit and tagged top cement @ 6,340'. Hard cement from 6,463' to 6,490'. Tested casing to 3000 psi. Bled off 200 psi in 15 minutes. Retested--same results. 11,101' TD - Tested D.V. tool to 3000 psi - bled to 2500 psi in 30 min. POH w/bit & RIH w/RTTS pkr. Set pkr @ 6,475'. Broke dwn formation @ 3500 psi @ ½ BPM.. Set pkr @ 6,381'. Mixed and spotted 75 sxs Class "G"cement with 1% D-31. Sqzd D.V. tool with 60 sxs cement. Final press 4200 psi. Bled and held @ 3200 psi. Job complete @ 2:40 PM Bled off press @ 5:30 PM. Reversed out. POH. WOC total of 12 hrs. RIH w/ 8½" bit. Drld hard cmt from 6478' to 6502' (7' above D.V. tool to 17' below). Tested csg to 3000 psi. Bled to 2000 psi in 15 min. Circ. and cond. mud. WELL HISTORY--D-27 Page 7 6/25 11,101' TD - Finished out of hole. RIH w/ Halliburton cmt rtnr and set @ 6,354'. Pumped into D.V. tool @ 3500 psi @ 2% BPM. Mixed and spotted 250 sxs of Class "G" cmt with 1% D-31. Pumped all cmt away and overflushed max. press 3700-psi. Job complete @. 1 PM. Pulled out of rtnr and reversed out. WOC until 9 PM. Set back into rtnr to 4000 psi for ½ hour. Press held. Bled off press & POH. RIH w/ 8%" bit and drld rtnr @ 6,354' and cmt from 6,481' to 6,500'. Circ. hole clean. Tested csg to 3000 psi. 6/26 11,101' TD - Cont'd testing D.V. tool. Held 3000 psi for 1 hr-- OK. Bled off press. Drld cmt to 6,525'. RIH to 11,033' and drld to 11,052'. Circ hole clean. Tested csg to 3000 psi for 30 min - OK. POH. RU Dresser-Atlas and ran CBL from 11,052' to surface. Complete @ 5 AM. S~tarted in hole w/Gyro. 6/27 Finished running gyro from 11,052' to 3100'. RIH m/bit and scraper to 11,052'. Displaced hole w/filtered Inlet water and displaced hole w/ diesel. POH laying down DP. 6/28 Finished POH laying down DP. Started in hole w/ 4%" tbg string. Testing collars to 3500 psi. Tubing detail listed below: No. Jt.s Item Length From T__o - KB to top of CIW 'hanger - CIW hanger.& x-0 9 '4%" OD, 12.6%, N-80 Sealtok Tubing - Otis ball valve 67 4%" tubing - %1 GLV, 4%" valve- McMurry type M-DSVO- LP cont. flow with U..S.I. mandrel 1 4%" tubing - %2 GLV 32 4%" tubing - %3 GLV 33 4%" tubing - %4 GLV 25 4%" tubing - $5 GLV 25 4%" tubing - %6 GLV 20 4%" tubing - %7 GLV 19 4%" tubing - $8 GLV 15 4%"' tubing - %9 GLV 12 4%" tubing - %10 GLV 10 4%" tubing - %11 GLV 11 4%" tubing - $12 GLV 11 4%" tubing - S13 GLV 11 4%" tubing - %14 GLV 10 4%" tubing - S15 GLV 5 4%" tubing - $16 GLV 1 4%" tubing 39.70 0 39 .~70 1.32 39.70 41.02 292.95 41.02 333.97 8.56 333.97 342.53 2,191.27 342.97 2,533.80 4.45 2,533.80 2,538.25 32.57 2,538.25 4.45 2,570.82 1,034.98 2,575.27 4.45 3,610.25 1,072.50 3,614.70 4.45 4,687.20 812.48 4,691.65 4.45 5,504.13 815.39 5,508.58 4.45 6,323.97 645.88 6,328.42 4.45 6,974.30 604.67 6,978.75 4.45 7,583.42 474.34 7,587.87 4.45 8,062.21 387.12 8,066.66 4.45 8,453.78 320.67 8,458.23 4.45 8,778.90 350.53 8,783.35 4.45 9,133.88 _~353.69 9,138.33 4.45 9,492.02 353.87 9,496.47 4.45 .9,850.34 320.67 9,854.79 4.45 10,175'46 159.44 10,179.91 4.45 10,339.35 31.36 10,343.80 2,570.82 2,575.27 3,610.25 3,614.70 4,687.20 4,691.65 5,504.13 5,5.08.58 6,323.97 6,328.42 6,974.30 6,978.75 7,583.42 7,.587.87 8,062.21 8,066.66 8,453.78 8,458.23 8,778.90 8,783.35 9,133.88 9,138.33 9,492.02 9,496.47 9,850.34 9,854.79 10,175.46 10,179.91 10,339.35 10,343.80 10,375.16 WELL HISTORY-TD.-27 Page 8 (Tubing Detail, Cont'd) No. Jts Item .Length From T__o Otis type X-A ¢irc sleeve 4%" tubing Baker type F-H Hydro set packer 4%" tubing Bell nipple 5.65 10,375.16 10,380.81 32.44 10,380.81 10,413.25 9.02 10,413.25 10,422.27 33.35 10,422.27 10,455.62 .59 10',455.62 10,456.21 6/29 11,101' TD - Finished in hole w/tbg string. Dropped ball to set pkr. Pressured to 1800 psi and sheared pins in sub-setting pkr. Pressured to 2800 psi and started circulating. Pkr failed (Baker). POH. Started in hole w/new Baker pkr. Pkr preset @ 900'. Pulled pkr loose w/40,000# and POH. Started in hole w/Otis pkr. 6/30 11,101' TD - Finished in hole w/ Otis pkr. Attempted to set pk'r. Pressured tbg to 1600 psi - sheared out sleeve. Circulated around pkr, POH - 2 of 3 pkr seal rubbers left in hole. RU WL unit and ran 9-5/8" gauge ring and junk basket. Recovered pkr rubbers and Otis pkr setting ball and small pieces of Hydril rubber. RIH w/ 3-%" dummy gun to 10,995' - unable to work deeper. Started in hole w/ gauge ring. 7/1 · 11,101' TD - Rigged D-A and RIH w/ 8¼" gauge ring and junk basket --stopped in collar @ 10,916' (tied in w/collar log). POH. Recovered few small pieces of rubber, junk, etc. RIH w/4%" tbg w/ gas-lift equip., etc. Installed ball valve line and opened BV. Dropped ball to...set.pkr. Pressure up on tbg (1200 psi) and annulus (900 psi) -"~et tbg hgr into tree & set 18,000% on pkr and set Baker pkr.@ 10,422'. (Sheared sleeve w/2100 psi). Tested pkr and tbg to 1800 psi for 30 min. - OK. Backed out landing joint. Installed BPV. Nippled out BOPE. Flanged-up X-mas tree. Tested seals to 5000 psi - OK. 7/2 11,101' TD - Finished hooking up wellhead to production header. Tested flowline to 700 psi - OK. Began gas lifting diesel out of well to make 1st perforating run. (Tested gas lift line to' 1500 psi - OK.) 7/3 11,101' TD - Finished unloading-well down to 5000'. RU Dresser- .;.,."'~'·../" Atlas & perforated lower sec. of Bench 4 from 10,752' to 10,784' -.~w..,-. ~.~"W/ 3-1/8" Jumbo Jet - 3 shots/ft. Unloaded well to separator. · ....... Well produced small amount of water first 2 hrs (11% and 8%). Lost 4 hrs - no water. Producing @ rate of 400 BPD w/csg press. ..... of 850 psi and TP of 110 psi. Gas lifting w/1330 MCFPD. 7/4 11,101' TD - Finished testing lower 32' of Bench 4-no water. RU Dresser-Atlas and perf'd remainder of Bench 4 w/same type of fun under drawdown cond. from 10,720' to 10,752' & 10,688' to 10,720'. Unloaded and started testing Bench 4. TeSted for 4 hrs @ stabilized_rate: 2136 BPD, BS&W - 0.2%; CP - 1020 psi; TP - 140 psi; 35°API @ 70o; lift gas - 1923 MCFPD; GOR - 335. RU WL Unit and ran gradient survey and stopped @ 10,500' for press. build-up test. Shut in well @ 12:45 AM, 7/4/75. 7/5 11,101' TD - Pulled BHP survey tools. Flowing BHP of Bench #4 @ rate of 2,136 BPD--1040 psi. 12 hr. shut-in BHP--2,657 psi. P.I. - approx. 1.3. Rigged up Dresser-Atlas & perforated bench #6 from 10,966' to 10,992' (CBL meas.%. H~d fill or obstruction @ 10,994'. Perforated with same type gun under draw down condi- tions. Unloaded & started testing well. Ran flowing gradient survey. Flowing BHP pressure @ rate of 4,296 BPD--1308 psi; 0.1% cut; lift gas--3,654 MCFPD; C.P.--1060 psi; T.P.--180 psi; operating valves 14, 15, & 16 (bottom valVes). 7/6 7/7 ~WELL HISTORY--D-27 Piage' 9 11,101' TD - Finished rigging down wireline unit. Rigged up Dresser Atlas and perforated Bench #5 from 10,898' to 10,928' under draw down conditions with same type of gun. Cleaned well to separator for 4 hrs. Well producing @ rate of 4,450 BPD with 0.2% mud. Ran in with Dresser Atlas and perforated Bench #5 from 10,868' to 10,898' & 10,848' to 10,868' & 10,828' to 10,848'. Rigged down wireline unit & tested well. Well produced @ rate of 5,500 BPD, 0.1% mud; 1100 psi C.P.; 130 psi T.P.; .gas lift-- 3,690 MCFPD. Rig released @ 6:00 AM 7-6-75 to Well D-20. 11,101' TD - Well produced @ rate of 5,683 BPD 0.2% BS&W; T.P.-- 220 psi; C.P. 1100 psi; lift gas 3.3 MMCFPD. DIRECTIONAL SURVEY REPORT FOR F~RATH0~ OIL CO,ANY TANGENTIAL CALCUEATIC~ TYPE OF SURVEY' SURVEY DEPTH: FROM S~face LE~' Tradin~ ~ Unit n£L~. McXrthur River Gyroscopic Multishot FT. TO 11000 ~L NO. D-27 COUNTY/PARISH. Kenai Peninsula DA~E OF SURVEY June 27, 1975 OFF~CE: J~nchora~e, ~laska STATE' A lask~ JoB NO. SU3-16998 & SU3-16977 27N-6~6 MARATHON OIL COMPANY .:.... ~.,. ;.~:.. ,~:~:~ .~. PAGE D-27 TRADING BAY UNIT .... ~ ........... ' ' .... ...... ...... dUNE 278 1975 SURVEY DATE - ..... <..~..-~-:.~..:~>.<.:~.,~.~r,:. :¢.~'<<~:.:.~; <~:~.;.<. ~:.~:.~:~sr~r~:,*~'.~.:.~,~:.~:.~.~.'~:~.~¢~m.~.A..-:~,.~g:.?~,,e." ~>~ '. ~:~ ,~r~. >,~.~:.::.~m~.~..~':.~x~*.:- - ..... ,~-.' - ..... ,-:*.',~.,:. · , KFNAI PENINSULA BOROUGH · · . MFARURED DEPTH O· 100, 200· RECORD OF suRvEy TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR VERTICAL SUB-SEA SEVERITY VERTICAL COORDINATES 0 99 199 .00 -106.90 ORIGIN AT THE SURFACE 0,00 N 0.00 d ,99 93,09 0 20 N 1.62 ~ 0,09 0,97 1,16 N 0,20 ~ 300, 299· gO0, 399, 500, g99, 600, 599. 700, 699, 800, 900· 899, 1000· 999. 1100, 1099, 1300, 1299, 1~00, 1399· 1500· 1~99· 1600· 1599, 1700; .1699. 1800. 1797, 1900, 1896, 2000, 1992, 99 293,09 0 31 S 1'7,81 W 0,~1 'i../; 0,51 0·86 N O, 99 393,09 0 10 N 78,~8 W 0,52 0,#5 0,91 N O, ;'~:"~':+::':'~::-{:-~:'"~" : : ...... ":' .: ::::~:'~?~:~::~':::'~:~'~: ....... ::':.' ....'' .:' :'::'~: "~:~:~ ' ' .... : ' :~:~.:~;~;,'~=~::~'~.:'g::~ : .... :: :' '~;~'~=:~ A~*~:· 2 ' · :. ". : ~ ::~: ?"~~ ~/; :~: '' 96 ~93,08 0 AO S 89,37 E 0,~9 0·68 0,91 N O, 98 593,08 0 ~ S 55,71 E 0,~9 :'~'"'"'" 0,~6 0,19 N O, . _ . 97 793,07 '0 30 S 56,11 E "::;;;::'? 0,1'8 :~'~;':'":':~"?'::":"': .0,04 0,88 96 993,06 0 50 N 86,90 E 0,5 q ~;:..:,.. ;,../::.~.;.. - 0,18 1,60 S 82 1292.92 I ~5 N 52.51 E 0.17 8.09 ~,26 N 10-. :=.=::'":2~:~/:~:~T$::~A~::~=:::::.: :e.:~. :.:~.::'~: '.. ":: '.:?/~..'.. ~:~:~ ~`<~::::~::T~>>~:~e~:;~:~. :.~:~:~;~: :~:`~.~::~.~}~.~:~T~ ~`~ ~:'~ ..'...'"::;':';.::'~=~.~';~:~:=~:~:: :.', ' ' "'::-::" 7~ ~92.8~ ~ 0 N 51.99 E 0.25 ~.~8 ~.~ N 12. 62 lq92,72 5 0 N 30,99 E 1,3q 16,38 :': 10,89 N 15, ': ..... "'~ 95 1691,05 8 ~1 N O. 3 E 2,86 39,7~ 36,18 N 16, 0 2 .~.. 17 8 9. ~ 2 ::::~.~. ~';~':~?i 6: N':~;~' 0,2 q::~?.'~ '2,5 8: 5 7" 5 6 :.'~=~:~'~'"~'~ ...... ~:.5 5,7 2 N 98 ~886.08 1~ ~0 N ~,8~ E ~.92 80,~7 80,~8 N 17. 37 ~5 7O E 85 E O8 E 77 E 19 E 9~ E 6~ E . 5o E 28 E 2100 2200 2300 · .2O87 . 2181 , 2275 ,71 207~,~1 20 21 N ~.72 E 2·12 ~2,22 1~6,09 N 2..2,18 E ,59' 2168,69 20 9 N 5.17 E '~"- ...... 0.25 17~.75 180,q0 N 25·28 E MARATHON OIL COMPANY D-27 TRADING BAY UNIT '"': ,JUNE 27, 1975 SURVEY DATE KKNAI PENINSULA BOROUGH MFARURED DEPTH 2~00. 2500. 2600. RECORD OF SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR VERTICAL SUB-SEA SEVERITY VERTICAL COORDINATES D E P T H ~.~:.:.]i~:~ii.:::~;..~ii DEP T H. ii~?:?~iDEG~iii~::~'.I.N:i:~:i.~!~i:!~ii'~i'~'D E'G];. :1~11N".:!..;i~:i :~i? D E G / 10 O i!~SE C...T. ION 2369 2555 ,28 2262.38 20 28 ,N 5.~6 E 0.33 207,85 215.20 N 28.6~ K .00 2~8.10 22 51 N 19.L~9 E 2,28 281.57 285.q3 N 52.30 E 2700. 2800. 2900. 3000. 3100, 3200, 26~5 273~ 2821 2906 2989 3070 .68 ;~!:~:.'2538.78 2 ~/:i5 '8.90'~. 12,0.9 !:323'5 325,3111;N '65 ,~+7 2627,57 27 23 N 19.56 E 2.~+5 369,36 368.71 N 81 .L~3 271~,53 29 35 N 18,89 E 2.~1 ~18,50 ~15,~2 N 97 , ~70 86 ~65.26 N ,11 2882.21 3~ 16 N 17.2~ E ....... 2,6~ 526.73 519,03 N 130 ,20 E ,18 E °06 E ,75 E 3300. 3~00. 3500, 3600, 3700. 3800, 5900. ~000. ~200. #300, ~00, 3151 3232 331~ .26 30~.36 36 ~ N 1L~.91 E 0.80 6~2.~0 631,88 N i61.97 E ? '~ IA ~! ~"ii'"~':~.':~~''i~':~':~','''~ ''~ -'~' ~'?~?~~:~: '~':''~ ................... ~ '~ '~: ....... ~?":' ...... ~ h~?~~'~:''~ ~" .08 3207.18 35 20 N 1~.76 E .~::.::..::~: 0,51 757,02 7~,00 N 192,22 E 3395 3~77 3559 · 52~~800 ~" 3 5:i:!N" 1207, .17 3370.27 35 q N 1q,68 E 0.61 ..... 871,16 855,93 N 221,75 E .68 3~52,98 3~ 12 N 1~,37 E 0.88 926,51 9~0,38 N 235,70 E 36L~2,39 3535,~9 3q' 2q' N 1[t.29 E 0,20 982 3725,:13 361_8,23 3~ 10 N 1~+,22 E O,P3 3.037 3807,62 .ii~!iiii.:!3 700.721 3890.59 3783.69 33 56 N 13,35 E 0.59 11~7 ~056,55 39~9,65 33 51 N 12,8~ E 0,~2 1257 ,13 965,13 N 2#9 ,#1 101c~,57 N 263 ,00. 107q: ~ i+ 2:.'i:.: N..: 2 77 .80 1128,73 N 289 ,72ii~ 11i 1.83 ' 09.. N.!~'!iil;:'.:!:~i~': 303 ,30 :L237,~0 N 315 .98 E .47 E ~500. ~600, ~700. q. 22q.,O! q. 117,11 32 58 N ].3,37 E 0,~6 136q.,60 13~3,82 N 3LI. O ~+307.75. L~200.85 33 8 N 12.62 E O.qL~ lq18.11 1397,16 N 352 ,58 E ,52 E MARATHON OIL COMPANY .... PAGE 3 D-27 TRADYNG BAY UNIT ~ ' ....... ' '~' ~ ' JUNE 27e 1'975 SURVEY DATE '"-' ':.'*~ ~:~::~'~:~?~'~'::~i.~'~:'::~°~':~:. :~'~' ~ '~:'~ :~:°~ ~° ~' :~. ~::'~:'~~:~ :~\~.~*~.~':*:~:*~'°'~°'::~::':"~'~:~"~:'~'~-'~: 7 '. '"":':'~. *" ' '. '.:~ ~:~-" · ' "~'."'"~"~.~'~'~."~'-~:!~'~' · ~,--~~V~R.T.~CAL.~,,SECTION,~,,COMPUT~D..,,,,ALONG CLOSURE KFNA! PENINSULA BOROUGH MEARURED DEPTH 4800, ~900. 5000, TRUE INCLINATXON DIRECTION DOG-LEG RECTANGULAR VERTICAL SUB-SEA SEVERITY VERTICAL COORDINATES DEPTH ...... , ~391 ~76 4560 ,78 q284,88 32 50 .N 12,61 E 0,30 1~71,19 1#50,07 N 36q,$~ .-' · 11 ../:ii:~ii..,:.:..:..~, 369.21:1:. :::~:.32'::'..;30~;i i'NL:12.18.:.:E :~::.~:. 0. ~0:..~ ~71525.71~::~ 1502.59. N '..: ~/'::~'::: :..:.:~:. 375.69 .86 ~53.96 52 ~ N 12.85 E 0.56 1575,75 155~,55 N ~87.50 E 5100 5200 5300 5400 5500 56O0 57O0 5800 5900 6OO0 6100 6200 6300 6qO0 6500 ~6~5 4730 4816 4902 ~987 5073 5160 .7.9-..:,:iii:i~;ii!i:"::..~ 538.89.~..,~i!~::::.,~:31:.,~i52.'!i 'Ni:.:l..3...:: 2~i~:':.£;i~-~.. 0. . . .88 4623,98 31 41 N 15,25 E 0,21 1679.02 1656.92 N #11. ,75 ~709,85 30 50 N 12,81 E 0,88' ' 1729,2~ 1706,89 N :: :.:..~.:.::...:..:,~:..:.:.::.:.~:......... ..... :.:.,.,....~:.:... . .....,...:.:.:.:.:.:.::...:,.:.:.::.~:,,:.:~.:..:.:.~:..,: ....:.. · ,..:.:.:~...~.:~.:~:.:.~.~>:~.:..~.::.:,:.......- .,. . ,~:..~:.:~..:.:,.:.:.:,~...;...,.:,., · ..':.~ j}.....~.:~.~.~;~-~;;~.~:.~::~ ~:~ .0[ ~795.~1 ~ ~0 N ~2.6~ E 0.67- 17~0.~9 ~757.88 N . .82 ~880.92 50 5~ N 12.6~ E 0.60 ~R50.67 1807,99 N ~5, .~2 505~.~2 ~0 9 N 1~.~1 E'''~'' 0.50 ......... ~929.92 ~906.57 N 5246.69 .:~i~i:iii. 5' 139.79'~: ~:;~ 0:,,~;:;~:~;.:I 6;~~;;i~;::N.i.i~. 1:3.81.',;~;;~.,;E ~0.:~ 3.7;~! 11979 ..~..:!~;~;:1955.5 i ::;~,,. N:.i: ~ii~: q' 80. 5333 62 5226,72 29 37 N 13,83 E 0,65 .2028,05 2003,50 N 5~21 5508 5595 5681 5766 58~9 .32 5401,q2 29 27 N 1~,2~ E 0,6~ 2123,86 2097,93 N 515, ,q7 5488,57 29 22 N 14,70 E 0,2~ -' ' 2172.20 21q5,37 N 528, ............... ....,........... .......... ,..................... .......... .......,..... ............... ....,....,.......~.....,...,...,.. ,.. , . ,, :...:..:.:.:.:~:.:.~.:~..~:..~.:.~.:,.:,.:..<..::... :::.:.:..~.:..:.:.~.:.:..~:<.:~..:, ...,,,~.. ,.:: .. :..:,.;e,:?~:y,:~:::~?:f:~?:.: ......... ~=~;:,~.'....:~;:.L~:.::..:~.':~..~.":.;,.'~. ~,i:;,;i"~:.~..:~.~:.:'~-:., :~/..~..'~'. :.?:. ~,~:: :..:: .- ' '. '::-;: .".;..~::.....': .'. .~: .1~ 557~.2~ 51 5 N 1~,6~ E 1.68 2223.05 2195.27 N 5~1. .05 5659.15 31 53 N 15.ql E 0.92 2275.21 22q6.19 N 555. .60 ..~'~{;~./~ 57 ~ 2.70 ,5 3:'~:~ 2 O: N'~:~:..16.15~:~:~: ,50 2329.59 ..2298'. 98'::..N 570. q3 E 79 E 22 E 37 E 40. E: ' i::~!:::~ 21 E 93 E 37 E 41 E 44 E 6600 6700 6800 6900 70O0 7100 5932 6014 6097 6182 6267 · 6351 ,03 5825,13 3~ 29 N 16,28 E 1,15 2585,64 2355,32 N 586,60 E ,79 5990,89 33 55 N 16,87 E.~ 0,~8 ~ 2~96,64 2q60,32 N 619,38 E . .89 6160,99 31 24 N 2.5.5~ E 2.61 2601,71 2556,98 N 660,64 E .45. 6244,55 33 19 N 26.41 E 1,97 2656,60 2606,18 N 685,07 E . -~:~.,~?~F.~.i:: .' '{. ~!~~=/~:~'~!'i~i!i~:.L;:.~:..?~,:~ :.. ~::.::::~:~:~!~::-~`~:~?:?;`.??~?~?~Fi~:~`?`...F:~- : ......: MARATHON OIL COMPANY :.~ 0-27 TRADTNG BAY UNIT :. 'i~i~ :: ": PAGE ...... dUNE ~Te 1975 SURVEY DATE .......... -: ~ ~: :~:~:~{:~>: ;~: ~~~V E ~:T:;Z C A L~:~ S E C T Z 0 N :~ :C 0 ~ P U TED:~ A L 0 N G: C L 0 S U R KFNAI PENINSULA BOROUGH ' ' ':' ::~:F7?~?{<~:~:~:`:~:~:~?.~?:~:::::~?~?:~:~~ ~:~;~?~:~`~?~~:?:~::~:~:~*:~::~`?~*:~:~:~:~:~g:~:~:~: '::: ::' ':"::'C::':' :;?:~::<'~':~;~:: "~::':'~:::."' ·;. :~.~:.:: :~-:~;'~:~:~:~.~:~3 P E R R Y;~S U ~:W E-E~3 U RV E~:~ N G :::~:.~: C 0 M P A N Y :::~ ~ :.~ .':-~:~:~.:~:~:~ ~ ~; :~::.:~:~:::<~ :~:~...~ :~;:~:~'~}:. ::: S U ".S - 16998 - 1697 RECORD OF SURV£Y TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR VERTICAL SUB-SEA SEVERITY VERTICAL COORDINATES D E P T H. ~i~i~:.: DEPT D EG':!/~:iR:i:.N .]:i D ~G.:::::: MI N'~'ii?il D E G / 100 SECTION :.::,- ....... MFARURED 7200, 6't~33,87 6326,97 3q 30 .N 26,5~ E 1,18 2713,20 2656,85 N 710e3~ 7300. 651~.78:L?i:.i::6q, 07.88:: i~:.i:i.:::.3.5:/:59::~:i: iilN':<26.68::/..E!i~i.i:;i;i'.:!.'l.qS?,: ii~.:!:.2771,9, i: 2709.35 N :~::::::' ....736.76 7qO0, 6595.70 6~88.80 55 59 N 26,7~ E 0,03 2830,62 2761,82 N 763,20 7500, 6676 7600, 675R 7700, 68~9 7800, 6921 7900, 700~ ~000, 7087 8100. 7172 8200. 7257 8300. 73q0 8~00 8500 8600 8700 8800 8900 7~23 7507 7592 7678 7765 7851 91..,iii~;?::6570.0 li i55'::~:"~2/ N:'~i;i~25' 9iiii;~il:'0 56:~ :!2888 .....~;'~' .10 6651.20 55 q5 N 26,1~ E 0.13 29~7,30 2866,72 N 81~,ql E .68 6732,78 35 20 N 25,87 E 0.~1 5005.11 2918,75 N 859,65 .83 681~,53 ~5 ~0 N 25.~5 E 0,16 ~062,69 2970,59 N 86~,76 E .82 7065, ,72 7233, 92 ;31 q2 N 27,91 E ' 1,96 " 5226 82 33 20 N 33,18 E 1.29 3333 .58 7qO0, ,52 7q85. .::::-~}~;~:~ ~.:.....: ,q9 7571,59 30 ~5 N 36,36 E 1,30 35qq ,26 7658,36 29 50 N 37.15 E 0,96 3592 ,19 :5117,12 N 957,52 E ,80 3208.97 N 995,56 E {:::,..:~:.~.:::~:.~§~:~:~.:.~,.. ......... :...:..: ,: ..... ..,.,....~. :.....:.......~. ~,.............,........ , 68 SS 15 " N 3~,57 E 0,51+ $g~2,~$ :3300,12 N 1057,61 62 31 51 N 35,12 E .... 1,q3 ; 3"9~,28 33q~,28 N 1087,96 3q2~,08 N 11q8,28 ,30.;~J¢:3~ 6'~, 5 ~ ;.'~. N~;~;:;~Yll 78,76; 9000 9100 9200 9~00 9~00 9500 . 79t8.80 7831. , 8112.88 8005, 90 29 q.O N 38.52 E O.qS' 3689 0 Z.ii::!.~i :,: 2.9...i: 2 5;i:!~ ,:N.':~i39.. 66 :ii~; El; iii. O.. 6 I;.:< 13736 98 29 ;55 N q0.57 E O.q7 378~ ,29 3502,27 N 1209,59 E .08 3577.59 N 1273,0~ E . 8287.30 8180.q0 29 20 N 42.41 E 0.46 3877.36 3650,3q, N 1338.47 E , 8371+.20 8267,30 29 60 N q5,Gq E 1,62 3923,q8 368~,95 N 1373,86 E 0-27MARATHON TRADING OIL. BAY COMPANY UNIT i ~ dUNE 27' I T SURVEY DATE MC, A R THUR R I VER ::":~ ............... .......... '-~'~':: ~:~:~':~'~:?~?~:~::~:::'~=~:~?~'~:'::~ ................. '~:'::::~':~:":~:?"~'~,~'~':?~ ............ ~:~'~::'~::~:::~ ....."'. ~' , ~~ ........... ~V~:~..:~:.~.~:,:,~O~.~-Z.~N:~,,~.~UMMU,-~U,,~.~.RLU~. CL OSURE KFNAI PENINSULA BOROUGH RECORD OF SURVEY ..... i ...... :'....:.,; ..... .~...'..: ....... : ...., .:~ TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR MEARURED VERTICAL SUB-SEA SEVERITY VERTICAL COORDINATES DEPTH DEP TH .:::.iiii'::i;i. DEPTH.:..:~i~:ii'.i:? DEG".ii:M]:N'i:ii?'~iii!?DEG:.':::.MI N'i':i.i~i!:ii'~ DE G / ! 0 .... :~i:.SEC.T ! ON.:~ii ::~.~::,.:...,.. .:::::~ ....... :.:.::::: ./. ....... 9600, 8q60,80 8353,90 30 0 N ~5,6q E 0,33 3970,08 ;5719,90 N 1#09,6 9700. 8548.26 ./~:.~:.L:.'. 84 q 1.36.'i~:. !:~=i:::.~ 29 ;!::.~ii:' !:.O.~:~ii ~N:~:i+~6~:~:~`~:~!~i~!~i;~i~:~1~1~:~!`~15~1~ 1:575;3.58 9800, 8635,~ 8528,5~ 29 20 N ~6,76 E O,q9 qO60,q~ 3787,1~ N 1~80,17 E 9900, 872 10000. 881 10100. 890 10200. 899 10300. 908 lOqO0.. 917 3.17 8706.27 25 ~0 N q6.90 E 3.16 ~1~.96 38~9,60 N 15~7 3,7~ 8796,8~ 25 5 N ~7.92 E 0,72 ~183,82 3878,01N 1578 ~,25 8887,35 25 10 N ~8,33 E 0,19 ~22,68 3906,29 N 1610 ~,80 8977,90 25 7 N ~8,19 E 0,07 .... ~261,52 393~,58 N 16~1 10500. 926 10600. 935 10700. 944 10900., 962 11000. 971 .75 ' 43q. 0.50 3991,71 N 1707,25 E :;' · '""!{'Q:!~F~:~ ' ' '. ' :' ' ,25 4421,31 4050,08 N 1774,23 E :::;', ,. L.,.. 3.14 9516.24 26 37 N 49. 2 E 0.22 ~502,q0 4108.51 N 18~1,75 E 3.43 9606,53 25 27 N 49,27 E 1,17 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE'TANGENTIAL OR CHORD METHOD HORIZONTAL DISPLACEMENT= ~5~1,38 FEET AT NORTH 2~ DEG, 22 MINe EAST(TRUE) I ' ' i Dear Mr. Marshall: Union Oil and Gas r' ~sion' Western Region · 1Jnion Oil Company-Wf California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 August 12, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska Enclosed for your files are the following reports: TBUS G-22 (12-32) TBUS G-2 TBUS D-27 (31-6) TBUS D-Z0 (22X-6) TBUS D-ZA (13-5) TBUS K-21 (21-28) Kenai Unit #33-30 Kenai Unit #43-7 99504 Monthly Report (Form P-4) Completion Report (Form P-7) Monthly Report (Form P-4) Formation Test #1 & #2 Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Completion Report Monthly Report (Form P-4) Completion Report I DRAFT Completion reports for TBUS D-27 and TBUS D-20 will be forwarded to you within the next week. ' ........ ..... Very truly yours, David A. Johnson Drilling Engineer sk Encl. cc: Marathon Oil Co. Atlantic Richfield Go. Standard Oil Co. Phillips Petroleum Amoco Production Skelly Oil Co. Mr. Rodney Smith-USGS Form No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT[EE SUBMIT IN DUPLICATE" /VtOI'qTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~'£LL WZLL NAME OF OPERATOR *Union Oil Company of California ~.b~r. ss or o~.~-oa 99501 909 West Ninth Avenue, Anchorage, Alaska 4. LOCATION OF WE/~L Surface: 758' FSL & 1206' FWL of Sec. 6, T8N, R13W, Conductor #1, Leg. A-l, Dolly Varden Platform Hemlock top: 825' FNL & 1950' FEL of Sec, 6, T8N, R13W, SM ~ APf"Nu.%~ERICAJ~ CODE 50-133-20274 LEASE DES:GNA ~--ION AND SEIgIAL NO ADL 18729 ~ IF INDIA)$. ALOT/EE OR IRIBE NAME 8. UNIT. FA_R~I OR LEASE N.k,ME Tradinq Bay Unit 9 WELL .so D-27 (31-6) 10. FIELD A_ND POOL. OR WILDCAT _ McArthur River Field,Hemlock 11. SEC., T.. R., M.. (BO~TO,X! HOI~ OBJE(~rv~ 485' FNL & 1775' FEL of Sec. 6, T8N, R13W, @ TD 12. PEP,~IT NO. 75-24 REPOIIT TOTAL DE~PTII AT ~_~4D OF MONTt{, CHA.XGES IN HOLE SIZE. CASING A~ C~N~NG JOBS INCLUDING DEPTH SET AN~ VOLLD,{}LS USED. P~ORATIONS. ~TS ~ ~SULTS. FISHING JO~. J~K LN HO~ ~D SIDE-~CKED HOLE ~ND ~Y O~R SIGNIFICANT ~NG~ ~ HO~ ~ITIONS. -'2 TRADING BAY UNIT WELL D 7 - DEVELOPMENT WELL' - July', 1975: 7-1 Ran 4-1/2" OD completion tubing string with packer set at 10,422'. Tested packer and tubing to 1800 psi. for 3.0 minutes--OK..Removed BOPE and installed X-mas tree. Tested tree to 5,000 psi.--OK. 7,2-6 Perforated Hemlock Bench 4 from 10,688-10,784'. Ran BHP survey. Perforated Hemlock Bench 6 from 10,966-10,992', Hemlock Bench 5' from 10,828-10,928'. Well produced on test @ initial'rate of 5,672 BOPD w/0.2% BS&W, 220# TP and 1100# CP. *Marathon Oil Company Sub-Operator -- .. , . , , ,. ,, , i , , . ,, , 14. i h~by c~r~ that the foregoLng. L~tru¢ ~J%d ~ / ..... .. _- r '/ .................... . Dear Mr. Marshall: Union Oil and Gas Di,,ision: Western Region Union Oil Company ~.~California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99503 RE: TBUS G-22 (12-32) TBUS K-21 (21-28) TBUS D-Z? (31-6) ,,z.-o~ KU #43-7 Enclosed for your files are two (2) copies each of the Monthly Report of Drilling & Workover Operations (Form P-4) for the above captioned wells. Also enclosed is the Sundry Notice & Reports on Wells (Form 10-403) for KU #21-6 WO. sk CC; Marathon Oil Co. Atlantic Richfield Co. Amoco Production (TBU only) Phillips Petroleum Co. (TBU only) Skelly Oil Co. (TBU only) Standard Oil. Co. USGS - Rodney Smith Very truly yours, District Drlg. Supt. ],~r~ ~'o. P--4 RL'~. ~- 1-70 STATE OF ';' ' SKA DUPLICATE ' OIL AND GAS CONSERVA~ON CO,~,AI~EE t,~ONTHLY REPORT OF DRILLING AND WORKOVER' OPERATIONS wZLL INA.ME O1' OPE:RATOIt *Union 0±1 Company of California 909 West Ninth Avenue, Anchorage, Alaska 99501 ~OCATIOS OF Sur£ace: 758' FSL & 1206' ~2~L of Sec. 6, T8N, R13W, Conductor i/l, Leg A-l, Dolly Varden }Iemlock Top: 825' FNL & 1950' FEL of Sec. 6, T8N, R13W, SM ;U.MEItlCAI- CODE 50-].33-20274 $ LI~,SE.DESiGNATION AND SEI{IAL NO ADL 18729 UNIT FA.I'O-! OR LEASE N.~4E Trading Ba~.. Unit WELL NO D-27 (31-6) 10. }'D:I-~ ~ND t'~L. O~ WILDCAT McA~th.u~ River Field, Hemlock O~~ 485' FNL' & 1775' FEL of Sec. T8N, R13W, ~ TD ~'E2R.M I T NO. 75-2.6 13. REPOtlT TOTAL Dr--~TH AT F~N'D OF .MON2~t. CtlANGF. S IN HOLE SIZE. CASING AN~ C~I~TING JOISS iNCLUDING 5ET A~ VOLL~,IF~ USED. P~'ORATIONS. ~TS ~N~ ~SULTS. FISHING JO~. JL~K LN' HO~ ~D SIDE-T~CKED HO~ AN'D ~Y O~R SIGNIFICANT ~L%NG~ ~' HO~ ~N~ITIONS. · TRADING BAY UNIT WELL D-27 - DEVELOPbfENT WELL - June, 1975: 6/1-6/16 Drilled and surveyed 12-1/4" directional hole from 9,269' to total depth at 11,101 without difficulty, and ran logs. 6/17-6/30 Ran 9-5/8" casing and set at 11,100'. Cemented 9-5/8" casing with 2700 sax, squeezed DV tool '@ 6,584' with 830 sax, and tested casing and DV tool to 3000 psi, OK~ Preparing to run production tubing at month end. *Maratl~__O:[] Company --- Sub-Operator ~,cmm~;~~~~~~. Dist. ~r]g. Supt, .~.., 7/]0/75 oil end eo~ conlervol;on commllfee bylhe 15th Of lbo luCC~ding ~nth,~le~ otherwise directod, Union Oil and Gas Di'"~ion: Western Region Union Oil Company u.~a!ifornia - P.O. Box 6247., Anchorage, Alaska 99502 ' Telephone: (907) 279-7681 J'une 10; 1975 Mr-. Tom Marshall Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99503 RE: TBUS D-27 (31-6) TBUS K-21 (21-28) MONTHLY REPORTS Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Monthly Report of Drilling & Workover Operations (Form P-4) for TBUS D-27, Dolly Varden Platform and TBUS K-21, King Salmon Platform. sk Encl. (4) CC: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Phillips Petroleum Skelly Oil Co. Standard.Oil Co. Rodney Smith - USGS Very truly yours, ~/'Jim R. Callender District Drilling Supt. D!V:SJON OF OIL AND GAS ANCHOItAG~ Z~rm ~o. B.ZY, ~- 1-70 STATE OF OIL AND GAS CONSERVATION COMMITTEE OIL Wl;LL MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W£LL ,. NAJ%I£ OF OPEiIt~TOR *Union Oil Company of California 3 ADDRESS OF OPEP~A~DR 909 West Ninth Avenu~ Anchorage~ Alaska 4. ~CA~ON OF WE~.L 99501 Surface: 758' FSL & 1206' FWL of Sec. 6, T8N, R13W, Conductor JJl, Leg A-l, Dolly Varden Hemlock Top: 825' FNL & 1950' FEL of Sec. 6, T8N, R13W, SM ~-~q=~ U .%~'g tu c A3. CODE 50-133-20274 6 LEASE DESIGNATION AND 5EHIAL NO ADL 18729 IF INDIA~. ^LOT,~EE OE TRIBE NAME 8. L.~IT F.klIAI OR LEASE NAME Tradin~g_Bay' Unit 9 WELL NO D-27 (31-6) 10. FIF~L~ ~k.N'D POKDL OR WILDCAT McArthur River F.ie,..!d, Hemlock ,, s~.. T., R..~, (Borro,~, ~ou~ 485' FNL & 1775' FEL of Sec. 6, T8N, R13W, @ TD 1~.. PE:R.M IT NO 75 -24 13. REPORT TOTAL Dr'2!~T'H AT F~.ND OF MONI'H. CHA~NGF-S IN HOLE SIZE. CASING A~ C~I~N'~NG JOBS INCLUDING DEPTH SET AN~ VOLL~F~ USED. P~ORATIONS, ~TS ~N~ ~SUL~. FISHING JO~ JL~K LN HO~ ~D SIDE-~CKED HOLE ~D ~Y OTt~ SIGNIFICANT ~G~ ~ HO~ ~ITIONS. TRADING BAY UNIT WELL D-27 - DEVELOPMENT WELL - May., 19.7.5: 5/1-5/9 Drilled and surveyed 12-1/4" directional hole from 774' to 3,155' without difficulty. Opened hole to 17-1/2". Ran 13-3/8" casing and set @ 3,127'. Cemented with 2,100 sacks of Class "G" cement and 400 sacks of Class "G" neat cement. Found hard cement 135' below rotary table. Cemented to top of 33" conductor with 100 sacks of Class "G" cement and 300 sacks of Class "G" neat cement. 5/10-5/31 Drilled & surveyed 12-1/4" directional hole from 3,155' to 9,269'. Drilling ahead at month end. DIV:SION OF OIL AND GAS *Marat~on Oil Company --- Sub-Operator ANCHORAGIL: .... N~--Repor{ on thil form il ~eq~J~ed for eoc~ colendor ~t~{ ~eoordle~l of {he etotu{ of operation$, and murat ~ flied {n dupl}cote wi{~ t~e and gas conaervot{on committee by the lSth of the succxdin9 month,unle~ otherwiee directed. l~3rm No. ]il~. STATE Oi~,I-AS KA suBMrr OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS wELL wELL OTItER ~A~E Or oPm~Toa *Union Oil Company of California 909 West Ninth Avenue, Anchora~e~ Alaska 99501 4 LOCATION OF WEI_~ Surface: 758' FSL & 1206' FWL of Sec. 6, T8N, R13W, Conductor #1, Leg A-l, Dolly Varden Hemlock Top: 825' FNL & 1950' FEL of Sec. 6, T8N, R13W, SM 50-133-20274 8 LF.~,SE DESIGNATION AND SERIAL NO ADL 18729 IF INDI^NT AL,OTi-EE OI~ TRIBE NAME 8, L.~IT FAi~{ OR LEAS£ NAME Trading Bay Unit WELL NO D-27 (31-6) 10 FII-;J~D 2~-'qD PC~L. OR \ViI~DCP~? McArthur River Field, Hemlock 11 SEC. T.. R., M. (BO]W©.M HOi~E OB.mCTZVF_~ 485' FNL & 1775' FEL of Sec. 6, T8N, R13W, @ TD 12 Ph-~IT 75-24 13. REPORT TOTAL DEiPTH AT Ir.ND OF MONTH. CHANGF, S IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEP%FH SET A~ VOL~ USED. P~ORATIONS. ~TS ~ ~SULTS FISHING JO~S JL~K IN HOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS TRADING BAY UNIT WELL D-27 - DEVELOPMENT WELL - APRIL~ 1975: 4/26 Moved rig from Well D-24A over Conductor #1 to drill Well D-27. Rigged up & tested riser & Hydril to 500 psi - OK. Cleaned out & surveyed conductor pipe. 4/27-4/28 Spudded well at 12:01 AM, 4/27/75. Drilled to 1,480'. 4/29-4/30 At 1,480' bit torqued up - POH with 17-1/2" bit. Ran in hole with 12-1/4" bit - still torqueing. Well kicked & began unloading mud, closed 20" Hydril- had no pressure on drill pipe or annulus. Pumped mud in drill pipe & circu- lated 15-20 minutes, then lost returns. Pumped in 850 BBLS of 9.7# per gallon mud & 650 BBLS of filtered Inlet water - no returns, Tracer indicated that' formation had broken down around 33"' conductor piling at 395' KB measurement. Pulled out of hole with drill pipe. Ran inhale to 400' with open-ended drill pipe & cemented conductor with 500 sacks of neat cement. On May 1, 1975, we had drilled out to 774' with full returns and plan to drill ahead to approximately 11,083' MD & 9,906' TVD on a course N26°E' Plan to set 13-3/8" OD surface casing at 3,100'. Subsequent pressure testing of the annulus in Well D-20 indicated that the course for Well D-27 had intercepted Well D-20 and damaged both the 13-3/8" and 9-5/8" casing. Well D-20 has been depressured & .temporarily plugged and will remain shutin until completion of Well D-27. *Marathon Oil Company --- Sub-Operator I h;r~by~ce~ify that the ~regging nq *..rue ~ ~ ~. 5/14/75 ~lOTE--Report on this form It required for each calendar month~ regordlea~ of the tltotu~ of operations, and must bo flied In duplicate with t~e oil and gat coniervatlon committee I~y the 15th of the eueceeding month, unle~ otherwlte directed. April 22, 1975 Re: Trading Bay Unit State 0-27 (31-6) Union Oil Company of California 75-24 Mr. R. T. Anderson Union Oil Company of California 909 West tttnth Avenue Anchorage, Alaska 99501 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well, at a location in Section 6, Township 8 N. Range t3 W, S. )4. Well samples, core chips, and a mud 'log .are. not required. A directlonal su~ey is required. ~ny rivers in Alaska and their drainage systems ha~e been classified as important for the spawning or migration of anad~ fish. Operations in these areas are subject to AS-16.50.870 and ~ ~egulations promulgated there- under (Title 5, Alaska Administrative Code). Prier to. commencing operations you may be contacted by the Habitat Coordimtor's office, l)~partment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the 'regulations promulgated theri~J~der (Title IB, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commenci~ operations y(~j may be contacte~ by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to- d~1t. Very truly yours, O. K. Gilbreth, Jr, V Chairman Alaska Oil and Gas Conservation Committee OKG:be Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental 'Conservatt.on w/o eric1. Department of Labor, Supervisor, Labor Law Compliance Division w/o encl. ~,rn~ I0-- 401 I. tE3/, I-I--71 SUBMIT IN (Other mstructto~ reverse side STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL OR DEEPEN i&. T~/PI~ 0~* WOI~K DRILL :~J DEEPEN J~J o,,. °'" E3 "'Nc"" E3 W~LL [~ WELL OTHer, ZON~ ZONE 2 NAME OF OI'ERA'FOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS 09' OPERATOR . 909 West 9thAvenue, Anchorage: Ala.qka 99501 4.LOCATION OF WELL ^ts,rfa~eConductor #1, Leg A-1 Doily Varden Platform. 758'N & 1205'E of the SW corner. Section 6: TSN, R13W, S. M. A~ p,'opo~,, pro,. ~o~e Top Hemlock (10,304'TMD, 9231'TVD) Approx. 825'S & 1950'W of NE corner. Section 6: TS_N, R]3W, S. M. 13. DISTANCE IN MILES AND DIRECT[ON FIiOM NEAREST TOWN OR POST OFFICE* 2]. miles NW of Kenai, Alaska 14. BOND INFORMATION: TYPE Statewidesu,e,y ~a/or No. United Pacific Ins. Co. 15. DISTANCELocATioNFROMTo NEAREsTPROPOSED* 116. NO. OF ACRES IN LEASE. PROPERTY OR LEASE LINE, FT. [ 3 (Also t ..... 'est drig, unit, if any) 485' , 085 . 00 I i". paopb'bm~ D~Th' ' · Ill, 083'TMD 9906'TVD 18. DISTANCE FROM PROPOSED LOCATION' TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. API 50-133-2(0274 6. I_,EA~E DI!ISIGNATION AND SE~:~IAL NO. ADL-18729 7. IF INDIAN, A.L,IaO~ OR TI~BE NA.M~ 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State D-27 (31-6).. 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock ~1. SEC., T.. R.. M., fBO'FTOM HOLE OBJECTIVEs85'S & 1775'W of NE corner. Section 6: TSN, R13W, S. M. s~,o..t $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 80.00 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CH, etc.~ 22. APPROX. DATE WORK WILL START* 106.2' KB aboveMSL. May 1, 1975 PROPOSED CASING AND CEMENTING PROGR.A.1VI '-- i ' SIZE OF I/OLi; SIZE OF CASING WEIGHT PER FOOT GiiZ, Z,;Z SE'i'TIi,~G DEP~{ quontity o{ cement 17 1)2" 13 3/8" 51~Buttress K-55 3 100'z~:-'~' .. ' " '' , ~' ~ )2150_sx,,O'w/6~ge1 .... + 400 sxG'Neai *12 1/4" q q/8" 47~ft~o~ N-gO 11.083'('~'~ ~;:' ::DF..Qoll.~r ..~ 7500'-lst stage use ..... & .~y5 ax G w/ 4% gel & 300 sx G Negt. ~-]10 .... 2nd sta~e..UseaDDrox. 1700 , .~ge! & ,3~0 sx. G,~eat, PLAN OF PROCEDURE: . 2. 3. 4. 5. 6. 7. DYOX. 4-% Sub-operator -- Marathon Oil Company Move rig over Conductor #1, Leg Rm. #A-l; Install & test BOPE's. .. CO Conductor #1 to 395'KB. Drill 17 1/2" directional hole (KOP @ 1500') to 3100'. Run & cmt. 13 3/8" csg. to 3100'. Drill 12 1/4" directional hole to ll,083'TMD. Log as directed. .':',PR "-5 i975 IN ABOVE S?AC~ 9ESC'RIBE FROPOSgD PROGRAM: If l~Oposal is to deepen give data on present productive zone and proposed new pro'duct~ve zone. If .pr_o~>o.~_l ls to cirlll_ or aeel>an (ILrectjonally, give pertinent ~lata' on st/bsurface 10c~ttons and measured, ~nd true 'vertical depths. Glv'e -b{owou[ prev-e.nter program. 24. I hereby certify that thc Foregoing is True. e~an{~ Corr~ct 4-14-75 (Th[s space for State office u~) C~DI~ONS OF ~P~V~, IF A~: SAMPI.F~ AND CORE CHIPS H~UI~ [ MUD ~OG ~ ~UI~~: OYm ~NO I a v~ ~o See Transmittal letter. DI~ION~. SURVEY R~~ ~.~.I. ~~ Dist. Land Manger Pm~mT ~o 7+-r ~?,-, *~m~OV~A= April 22, 1975 Permit to Drill or Deepen TBUS D-27 (31-6) -2- . 9. 10. Run 9 5/8" csg. to 1.1,083' and cmt. as directed. Complete well as a Hemlock Producer with gas lift assy. De-mob and rig off, Estimated Operati!,~g Time: Drilling Time ,,C~mpletion Time TOTAL TIME Forty-Five (45) Days, Twenty-Five (25) Days, Seventy (70) Days, .? *Setting depth for 9 5/8" /47# N-80 Buttress Csg. @ 8900', Setting depth for 13 3/8'!'; 47# P-Il0 Buttress Csg. @ 11,083' ~I (45X-$2) I \ D II // ~G-36 .- . · D'I~I ~l D-7 I (14-32) ' I(34'32) t /-- (14-33) / T9N R 13W '~ ' t ~ ~ ' ' - I "" ' / TVD 9,9o~,~D - 27 ./ / . D -32 ' /Pro..T/,-~/ /~-31 (i2X-5) ; TD ,I,281' / T~0¢04 // /// (52 6) ~ ~ 0-20/ / ~ D- 2 / / ~(g2XF~)/- --'P-3 ~~2-5) ~ - =~. , ---~-- (~3-8) . x b-8 '~, ~ ( 2 4 - 8 ) (11-t7) UNION ~(~2x-~) WELL LOCATION MAP . , MARATHON SUB-OPERATOR 3-22 ;;x-,~) ;~ · TRAIN6 BAY STATE UNIT D.-2Y ~ (31-6) SCALE:t"= 2000' ['~ ' ' ] ' April i0 : . ,,~ -/~x '~O- 14 \ CHECK LIST FOR NEW WELL PERMITS ComPany ......//~fon '~ Yes No Remarksl 1. Is the permit fee attached ...................... /e~o~ 2. Is well to be located in a defined pool ............... 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ........... 5. Is well located proper distance from other wells .......... ~J~ 6. Is sufficient undedicated acreage available in this nool ...... ~c 7. Is well to be deviated ....................... z,~J~' 8. Is operator the only affected party ................ ~K 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ................. Il. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided ................. - .... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ....... 17. Will surface casing protect fresh water zones ............ 18. Will all casing give adequate safety in collapse, tension & burst . Approval Recommended' Geology Engineering.: ,,i~, TRM t/'~ HWK ~/C_ 'OKG~ HHH --:~, .. JAL''! LCS ':~7~ ~:~" JCM ~'~ Revised 1/15/75 19. Does BOPE have sufficient pressure rating .............. . ~ ~ %-...
