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Home My WebLink About179-062 Imag,_ ?roject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. D Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by [] Poor Quality Originals: large scanner [] Other: OVERSIZED (Non-Scannable) NOTES: D Logs of various kinds [] Other BY: BEVERLY BREN~SHERYL MARIA LOWELl. DATE: /(~,/~),~0~.S' Project Proofing BY: G~REN VINCENT Scanning Preparation '~ SHERYL MARIA LOWELl_ x 30 : C/O + /~0 : TOTALPAGES ~/~e BY: EV~BREN VINCENT SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: YES ~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: BEVERLY'"-~EEN f~C~SHERYL MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALrr~, GRAYSCALE OR COLOR IMAGES) /si YES ~ /S/~//~.~ ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE' /si General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd STATE OF ALASKA RECEIVED ALA.OIL AND GAS CONSERVATION COMMON SEP 12 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U , Plug Perforations U Perforate U Other [QiiCaC Performed: Alter Casing Is • Pull Tubing 0 . Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other El• Re-enter Suspended Well❑ 2.Operator XTO Energy 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory ❑ 179-062 • 3.Address: 9127 S Jamaica St,Englewood,CO 80112 Stratigraphic❑ Service 0 6.API Number: 50-733-20078-01-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0018756 • Middle Ground Shoal C24-26RD • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MGS E, F, G Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 11,216 feet Plugs measured NA feet true vertical 9,686 feet Junk measured 9,419 feet Effective Depth measured 11,160 feet Packer measured 8,610 feet true vertical 9,640 feet true vertical 7,405 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1875' 10-3/4" 1875' 1782' 3130 psi 1580 psi Intermediate 9100 7" 9100' 7823' 6340 psi 3830 psi Production Liner 2317' 5" 8881 -11198' 7633'-9672' 10140 psi 10490 psi Perforation depth Measured depth 9589-11096 feet 1\10 K n True Vertical depth 8259-9671 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5#,L-80,EUE,8rd;EOT @ 9,384'MD 8,070'TVD Packers and SSSV(type,measured and true vertical depth) 5"AS1-X Ret Pkr @ 9,331'MD 8,024'TVD 7" FH Pkr©8,610'MD,7319'MD;SCSSV @ 304'MD,304'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Conducted staged acid stimulation by spotting 10%HCI acid across the perforations to cleanout. 13. Representative Daily Production Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 285 psi 840 psi Subsequent to operation: 400 520 600 940 psi 140 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service _ Stratigraphic ❑ Daily Report of Well Operations Yes 16.Well Status after work: Oil is . Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-261 / /?_ a` t I I 5/3 -J7...7- Contact Sandra Haggard Email Sandra Haaaardc xtoenergy.com Printed Name Title Regulatory Analyst Signatu�.+ .�i: /� _ Phone midS� '97" t9/,„,2 Date 9� �� Sif to•i743 �,4/ i�6, Form 10-404 Revised 10/2012 Dmssitrigin6 TO • ENERGY August 28, 2013 Alaska Oil and Gas Conservation Commission Attn:John Norman,Commissioner 333 W.7th Ave.,Suite 100 Anchorage,Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Pull tubing, replace wellhead and convert to injector Middle Ground Shoal#C24-26RD Production Well Middle Ground Shoal Field E, F&G Oil Pool Cook Inlet, Alaska API 50-733-20078-01-00 XTO Energy hereby submits the report of sundry well operations to pull the tubing, acidize, replace wellhead and run new gas lift string. Initial objective was to convert well to injector;well was retained as _ _a producer due to higher than expected oil production realized during workover. Enclosed are the following attachments: 1. Form 10-404 Report of Sundry Well Operations 2. Workover Daily Activity Report 3. Current Wellbore Diagram If additional information is required, please contact me at 303-397-3672 Sincerely, Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer, Office: 303-397-3606 III ■ I TOAAA 6-10-13 ENERGY PROPOSED MGS C24-26RD % KB:35' Cook Inlet,Alaska % Water Depth:73'MSL Leg 1,Conductor 4 - j Tbg:2-7/8"6.5#L80 8rd EUE @ 8647' API No:50-733-20078-01 f f0 2-3/8"4.7#L80 8rd EUE @ 9353' Spud: 1/18/68 Original Well �/0 0 Item Length,ft Top Bottom Sidetrack RD:10-2-79 2-7/8°6.5#L80 8rd EUE tbg 300 0 300 19 4'Pup Jt,2-7/8"6.5#8rd EUE 4 300 304 /J o Baker TE5 SCSSV 1 304 305 4'Pup Jt,2-7/8"6.5#8rd EUE 4 305 309 Surf Csg: 10 3/4"40.5#J55 BTC. 2-7/8"6.59 L80 8rd EUE tbg 8,286 309 8,595 Set @ 1,875'.Cmt w/1,550 sk. 4'Pup Jt,2-7/8"6.5#1%Cr 8rd EUE 4 8,595 8,599 Top Job w/100 sk.Tot cmt: 1,650 sk 2-7/8"XNipple(2.213"ID)8rd 9Cr 1 8,599 6,600 4'Pup Jt,2-7/8"6.5#1%Cr 8rd EUE 4 8,600 8,604 6'Pup Jt,2-7/8"6.5#8rd EUE 6 8,604 8,610 7"FH Retrievable Packer(supplied by Tripoint) 4 8,610 8,614 2-7/8"6.5#L80+1%Cr 8rd EUE tbg 30 8,614 8,644 4'Pup Jt,2-7/8"6.5#1%Cr 8rd EUE 4 8,644 8,648 2-7/8"XNipple(2.213"ID)8rd 9Cr 1 8,648 8,649 ■ i 4'Pup Jt,2-7/8"6.5#8rd EUE 4 8,649 8,653 JJ 22jt 2-7/8"6.5#L80+1%Cr 8rd EUE tbg 669 8,653 9,322 r e 6'Pup Jt,2-7/8"6.5#8rd EUE 6 9,322 9,328 ►TT/ / X-Oeer2-7/8"8rd to 2-3/8"8rd 1 9,328 9,329 , 2-3/8"X5"T-2 On-Off Tool(with XProfile) 2 9,329 9,331 j0#1 t�//J 5"18-20.8#AS1-XRenuable Packer(Tripoint) 7 9,331 9,338 Intermediate Csg:7"23-29#N80 BTC. 1 / Crossover 2 7/8 8rd x 2 3/8 8rd 1 9,338 9,339 Set @ 9,1 OO'.Cmt W/500 sk. 1)1 2 7/8 6.5#L80 8rd Tbg 30 9,339 9,369 l: ,/�/� Crossover 2 7/8 8rd x 2 3/8 8rd 1 9,369 9,370 Surf-4,047':23# r/ 6'Pup Jt,2-3/8"6.5#1%Cr 8rd EUE 6 9,370 9,376 4,047-7,688':26# /� 2-3/8")0J Nipple(1.791"ID)8rd 9Cr 1 9,376 9,377 7,688-9,100':29# / 6"Pup.8,2-3/8 8rd EUE 6 9,377 9,383 ' Crossover2 7/6 8rd x 2 3/8 8rd 1 9,383 9,384 04 Guide Skirt(stab into 2-7/8"tubing stub) 3 9,384 9,387 / 9,387 ►, 6ft pupjt above and 2ft pupjt belowthe mandrels GLM M D(ft) TV D(ft) PORT PSC PSO Sqz 2 @ 9,010'w/100 sk. �/ #9 2050 2195 16 892 1000 lr #8 3400 3884 16 865 932 Sqz 1 @ 9,025'w/150 sk. I i i *, ,/.♦ #7 4300 4952 16 841 884 !!i #6 4900 5659 16 815 849 !er A -1,, , +l.'/ /+!♦4 #4 5900 6874 16 764 7798 / \ j .3 6400 7450 16 738 772 /�! #2 6900 8023 16 711 745 „,,p, � #1 7400 8612 14 Orifice / I." GN-GO:9,589-9,619' Prod Liner:5"18#N80/P110 Hydril FJ. �, 1 1 Fs - GR-GS:9,917-9,966' Set @ 11,198'. TOL @ 8,881'. //J HC-HD: 10,231 -10,243' Cott W/242 sk. TOC @ 9,370' I/ HC-HD: 10,278-10,284' Fish in Hole 5"TIW HB-BP Permanent Pkr @ 9419 ft and BHA - HD-HE: 10,342 10,358' 5"TIW HB-BP Permanent Pkr @ 9486 ft and BHA 1 /:/ /�_ HK-HN: 10,692-10,742' HN-HR: 10,770-10,820' HN-HR: 10,878-10,964' 40, HR-HZ: 10,986-11,036'iir /0 .0#9 HR-HZ: 11,096' TD: 11,216'MD(9,686'TVD)D) 4:AreM0 • Daily Activity and Cost Summary_se t: I K(;Y Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 i 1/18/1968 2/17/1968 , Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Slickline 2/15/2013 00:00 2/15/2013 00:00 Objective Pre workover prep Summary • Daily Operations . ''''Y� 3 Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 2/15/2013 2/15/2013 -Rig up wireline and pressure test lubricator. -Run in hole with 2.875"gauge ring to 275'WLM tag SV.No problems.Pull out of hole. -Run in hole with 3"JDC&prong to 275'WLM.Latch and pull 3-1/2"Otis AO ball valve.Pull out of hole with safety valve. -Rig down wireline. NOTE:Original prog steps were to drift tubing for e-line to be able to shoot off tubing.Was learned from previous wireline reports that the tubing already has scale issues approximately 1600'above where tubing shot was to occur.Tentative plans are for CTU or similar type of clean out. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/1 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_se ENERGY Well Name: Middle Ground Shoal C24-26RD APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) .KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date COMPLETIONS Convert to Injection 3/12/2013 00:00 4/28/2013 00:00 Objective Convert to waterflood injector to support C34-26 Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 3/12/2013 3/13/2013 Skid rig over C24-26RD. NU Baker CTU BOPs and test(AOGCC witness). Changed out stem on portable choke and cleaned seat. MU injector head and test. Connect poorboy return line to pits.Clean up rig&cellar.Build&filter 10.5ppg CaCl2 brine. Remarks#2 Daily cost is allocated daily cost for rig move from Leg 4 to Leg 1 &rig maintenance. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 3/13/2013 3/14/2013 Finish building 10.5ppg CaCl2 brine and filter to 1 micron.Clean up around rig. Open wellhead and RIH w/Baker CT,motor and 2.70"concave mill, circulating FIW at 1.5 bpm. Mill thru scale @ 5,083'and 7,300'.Cont.clean out to 9,615',tagged solid.No scale or asphaltine in returns. Pump 20 bbl Hi-Vis sweep and displace hole w/10.5ppg CaCl2 brine while POOH.Mill had no signs of wear. Start RD CT and BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 3/14/2013 3/14/2013 ND CT BOPs and lines.Install tree cap and pressure gauge on annulus valve.Finish RD Baker CTU. Prep and skid rig to C34-26. Rig released from C24-26RD on 03/12/2013 at 1200 hours. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 3/30/2013 3/31/2013 Skid rig to hole.Install handrails and refit 4"and 6"choke flow lines.Make up high pressure mud line to rig.Fix all lines from the choke manifold and cut penetration in sub base wall for 10"flow line and install the same.Nipple down Cameron tree and inspect and function lockdowns on tubing hanger.Nipple up BOPE on riser and prepare to test. Plan forward:Jim Regg of AOGCC waived witness.Test BOPE.RU Pollard,RIH with tubing cutter and cut 3 1/2"tubing at 8778'.10'above packer.RU slips and tongs for 3 1/2"tubing and POOH and lay down the same.PU mill and scraper for 7"and TIH to clean out to cut off tubing stub.POOH and PU Howco RTTS to test 7"casing. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/7 Report Printed: 9/10/2013 Daily Activity and Cost Summary_se ENERGY Well Name: Middle Ground Shoal C24-26RD APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 T08N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) 'KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily Operations ..: . Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 3/31/2013 4/1/2013 Continue to nipple up BOPE.Function test,change out bleeder valves on test pump.Trouble shoot iron roughneck switch.Pull BBV,fill stack with 14 bbls of 10.4 ppg CaCl2.Gas alarm(production),Crew mustered up.Test BOPE at 250 psi low and 5,000 psi high for all functions except the annular which was 250 psi low and 2,500 psi high.All tests passed.Make up landing joint to tubing hanger and spot e-line unit on catwalk.Back off lock down and pull hanger,take gas bubble(diesel),shut in well and monitor.Crew mustered in camp.Checked for type of gas and cleared area prior to clean up procedure. Circulate through choke tubing volume with 10.5 ppg MW in and 8.4 to 9.7 ppg MW out.Shut down with well shut in and monitor well while building 10.5 ppg MW. Plan forward:After getting well under control,Set up e-line and tubing cutter and cut tubing at 8,778. Pull tubing.MU mill and scraper and trip in to 3 1/2"stub.MU RTTS and TIH to test 7"casing. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 4/1/2013 4/2/2013 Continue to circulate 10.5 ppg MW around the annulus.RU Pollard e-line to cut 3 1/2"tubing at 8,778'. RD Pollard and POOH and lay down 3 1/2"tubing.Pull out and recover 21 band clamps.At report time we have laid down 230 joints with an average of 30.4'length.A total of 6,992'.Each joint has required to be broke out with rig tongs. Plan forward:Finish POOH and lay down 3 1/2"tubing,PU Mill and Scraper and trip in with DP to 8,778'to clean out hole.POOH and pick up RTTS and TIH to set at 8,778 to test 7"casing. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 4/2/2013 4/3/2013 Continue to lay down 3 1/2"tubing,recovered 286 joints plus 1 cut joint(NORM readings 1.0 mR/hr)(each joint has required to be broke out with rig tongs).Top joints looked good,farther down hole looked worse for corrision.Bottom 25 joints had numerous holes up to 1-1/2". M/U 6"mill and casing scraper&RIH,wash and ream(hard scale)f/8,674'-t/8,749(Top of Fish).Circ. Hi-Vis sweep. Minimal scale and asphaltine over shakers.Up wt 150k.Dn.wt.95k,Rot.wt 110k,Tq 6500 ft/lbs,2150 psi @ 6.3 bpm. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 4/3/2013 4/4/2013 POOH w/mill and scraper. RIH w/wash pipe,wash&ream f/8749'-U 8764'(top of packer). Up wt 165k,Dn wt. 110k,Rot wt 130k,TQ 6k,1900psi @ 6.3 bpm. Circ Hi-Vis sweep.POOH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 4/4/2013 4/5/2013 Finish POOH&LID Washpipe. RIH w/overshot w/hollow mill,mill on top of tubing,could not grab fish. Up wt 165k,Dn wt. 110k,Rot wt. 130k,Tq 6k,350psi @ 2.8 bpm.POOH.Mill was worn out.Cut&slip drlg line.Service rig.Change out hollow mill&RIH. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/7 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_st 1F1k:HGV Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 T08N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) 'Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily trations Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 4/5/2013 4/6/2013 RIH w/overshot w/hollow mill,mill on top of tubing,latch onto fish.Up wt 165k,Dn wt. 110k,Rot wt. 130k,Tq 6k,350psi @ 2.8 bpm.Pull packer loose w/35k over-pull.Circ.bottoms-up,no gas,monitor well(static). POOH w/packer slow.UD packer&tubing tail(Tubing is full of holes).R/U&Test annular&rams w/ 2-7/8"Tbg. M/U 4-1/8"mill&motor assembly,P/U 2-7/8"DP,RIH and lay down 3-1/2"DP to wash&ream liner. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 4/6/2013 4/7/2013 Cont.RIH and lay down 3-1/2"DP to wash&ream liner.Could not work into top of liner @ 8881'. POOH.Mill showed signs of junk in hole&liner top damaged(sides of mill scared).Repair Iron-Roughneck. M/U Tapered mill assembly&RIH.Work into top of liner @ 8881'.Up wt.145k,Dn wt 100k,Rot wt 115k,TQ 5.5k,1500psi©175 gpm.Clean out to 8918'. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 4/7/2013 4/8/2013 Cont.Cleaning out casing w/Tapered mill to 10,560(Circ out gas in 2 places)Up wt.145k,Dn wt 100k, Rot wt 115k,TQ 5.5k, 1500psi©175 gpm. Circ liner clean.POOH out of liner.Test BOPs Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 4/8/2013 4/9/2013 Finish testing BOPS.X-O below test plug to drill string stuck in casing.Attempt to pull free.Get bigger tools from town.Jar loose.Inspect derrick.Lay down tools&test plug.RIH t/10,560.Cont.Cleaning out casing w/Tapered mill to 11,060'.Mill was torquing and not making any hole. Up wt. 175k,Dn wt 120k,Rot wt 145k,TQ 6k,2250psi @ 200 gpm. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 4/9/2013 4/10/2013 Cleaned out liner to 11,090'.POOH with tapered mill.RIH w/Con-Cave mill&casing scraper.Did not tag top of liner.Wash from 11,070'to 11,090'. Mill t/11,093'(3'from lowest pert).Circ Hi-Vis sweep.POOH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 4/10/2013 4/11/2013 Cont.POOH w/mill and scraper.LID BHA.Mill showed signs of being on loose junk.M/U 5"RTTS& RIH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 4/11/2013 4/12/2013 Cont.RIH w/5"RBP&7"RTTS to test liner lap&7"casing.Could not get RBP into liner.Set RTTS @ 8721'and Test 7"casing to surface,2200 psi,75 psi drop off in 10 minutes,held solid at 2200 psi for next 30 minutes.POOH.RBP was in set position and seals were out of position.Re-dress RBP,M/U guide on bottom of RBP&RIH,Set RBP at 8907',Set RTTS at 8721',Test liner lap,No good.Set RTTS at 8812'.Test 7"casing to surface,2100 psi for 30 minutes,held solid.Unseat RTTS,retrieve RBP&POOH 10 stands.Cut&Slip Drlg line.Cont.POOH Remarks#2 Construction Summary#3 www.xtoenergy.com Page 3/7 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_slis° t'.N HGY Well Name: Middle Ground Shoal C24-26RD APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 17.0 4/12/2013 4/13/2013 Cont.POOH w/5"RBP and 7"RTTS.Move 2-7/8"DP in derrick.M/U 7"RBP and RIH.RBP would not set in 23#casing.RIH and set RBP @ 4257'(26#csg). Spot 500#of sand on RBP and POOH.M/U 7"casing cutter and cut csg @ 67'.L/D cutter.Monitor well(static).N/D BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 18.0 4/13/2013 4/14/2013 Cont.N/D BOPs.Change out casing spool.N/U BOPs.Set Inflatable Pkr.Test lower casing spool t/ 2000 psi for 30 minutes.OK.L/D Pkr..Install 7"pipe rams.Test rams to 250/3000 psi.M/U casing spear and catch casing.Back-off casing-pull 10k over,put 3500 fUlbs lefthand torque&fire string shoot.Broke loose. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 4/14/2013 4/15/2013 Finish back-off on 7"casing.R/D E-line.L/D spear&casing.Backed off©147'.P/U skirted casing joint&RIH.M/U swivel and screw casing together w/6500 ft/lbs torque.Test casing to 2000 psi.,bled down 50 psi.in 10 minutes.Torque casing to 8000 ft/lbs..Retest to 2000 psi.,no pressure loss in 30 minutes. N/D and raise BOPs to set csg.slips.Set casing slips w/130k.Cut casing and set out same.Break down fishing tools for load out.Set out BOPs.Pull riser.Install tubing spool&test to 3000 psi(OK). Nipple up BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 4/15/2013 4/16/2013 Finish N/U BOPs.Install VBRs.Test BOPs to 250/5000 psi w/state witness.Set wear ring.RIH to retrieve 7"RBP©4,257'.Circ out sand.Un-seat RBP&POOH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 21.0 4/16/2013 4/17/2013 Continue to RIH to 7394',MD.Service Iron roughneck.RIH to top of liner @ 8893',MD.attempt to work through with RBP packer unsuccessfully.TOOH to check RBP.Rubbers were folded back over RBP body.Redressed RBP and made up RBP and packer assembly.RIH to 8970',MD and clean going through liner top.Continue RIH to 10,973'MD,could not go any deeper,unit started to hang up. Displace string with filtered brine at 2.1 BPM,620 psi.Rig up BJ for acid treatment program.Test surface lines to 7,000 psi. Plan forward:Finish acid job with BJ according to plan forward.Retrieve RBP.Continue with well procedure to run production string according to plan. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 417 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_sls t:NI:;HGY Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 4/17/2013 4/18/2013 Wait on tech for repairing BJ PSI recorder on pump.Pressure test BJ iron to 7,000 psi,pump 18 bbls 10%HCL,chase with 68 bbls 10.7 ppg CACL2.TOOH ro 9,990'MD.Let acid soak on perfs for 60 additional minutes.TIH to 11,038'MD.Reverse out acid and balance out hole,rig down circulation iron. TOOH to 10,878'MD.set packer at 10,840',test lines to 7,000 psi.Attempt to establish injection rate, returns came back in annulus at 1.5 BPM and 3,800 psi.Move packer up 7'.reset and retry with similar results while injecting.Discussed problem with XTO Superintendent and decided to relocate packer and try again.Pulled up to 10,755'MD and repeated with same results.at 1.5 BPM,1,200 psi.Called XTO engineer and decided to trip to bottom and spot 9 bbls acid across peas,TOOH to 10,490'MD,reset packer,rig up BJ to establish injection rate at 2 bpm and 2,500 psi.No retums came up annulus and test was good.Transfer mud to pits and weight up to 10.7 ppg MW.Begin stage 1 and 2 for revised acid planned. job lanned. Plan forward:Finish acid injection,POOH with RBP and RTTS and get ready to run production tubing as per procedure. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 4/18/2013 4/19/2013 Continue and complete stage 1 and 2 on revised plan forward on lower perforations.Release RTTS and set RBP at 10,490'MD,Set RTTS at 10,121'MD.Build brine for stage#3.Pump stage#3 acid job on upper perfs with BJ,reverse out the same.Reverse acid to PTS tank.Rig down BJ surface lines. Release RTTS,RIH and retrieve RBP.Flow check,Hole is taking 2.5 BPH.TOOH to 7,487'MD,service rig,relocate collars and HWDP in derrick,continue to TOOH to BHA. Plan forward:Finish TOOH.Pick up 5"Packer with DP and TIH to set the same.POOH and lay down 2 7/8"DP.Get ready to run production string. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 4/19/2013 4/20/2013 Continue TOOH,stand back 8 stands 2 7/8"DP.Lay down 2 7/8"DP and collars,lay down BHA. Determined that the bar would not go through crossovers to the 2 7/8"DP,laid down the remainder of the 2 7/8"DP and loaded it on the work boat.Pulled wear bushing and started to pick up 5"packer assembly and 27 joints of 2 7/8"EUE tubing.TIH to 9473'to set packer. Plan ahead:Set packer and back off of same.POOH with DP and 2 7/8"tubing.Install 7"TIW HB-BP permanent packer.TIH with new packer and 2 7/8"EUE tubing. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 4/20/2013 4/21/2013 Set TIW HB-BP Permanent packer by dropping bar.Set packer at 5,300 psi.Attempted to release drill string from packer,attempt failed.The end results was the packer and string would turn without releasing the packer.Discussed the problem with XTO operations engineer and decided to wait on slick line and E-line to cut above the packer and install another packer.We are currently waiting on the work boat for the E-line to make a radial cut of the 2 7/8"production liner.While waiting on E-line equipment, preforming maintenance on rig and repairs where needed. Plan forward:When slick line operator arrives,RU slick line and pick up bar.RU E-line and make pass with gage ring.PU radial equipment and make cut in the center of the first full 2 7/8"joint.RD E-line and POOH.Make up new packer assembly and TIH with new assembly. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 5/7 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_si?" Aglill°1:XFAMY Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) iGr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date ,Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 DaiiyOperationsf, s~ Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 4/21/2013 4/22/2013 Waiting for work boat with E-line equipment.Off load E-line equipment from boat.RU slick line to retrieve bar.RIH to latch the same.Attempted to retrieve bar without any results.Released from bar andPOOH.Talked to XTO operations engineer and decided to go in with tubing punch and radial cut to cut tail pipe below packer.RU E-line equipment and RIH with RTC and attempt to cut below packer at 9,479'.The RTC did not work.POOH and redress RTC.RIH and attempted to cut again and the RTC did not work again.Loaded the wireline equipment on the boat and we are now waiting on the boat.It is scheduled to be here at 05:00 hrs this morning. Plan ahead: Finish running RTC on E-line.Cut below packer at 9,479'and above packer at 9,443'. POOH with cut 2 7/8"tail pipe.Test BOP's.PU production assembly with a 5"packer and a 7"packer. Prior to connecting with the 2 7/8"stub,pickle the production assembly twice.Connect the 2 7/8"stub and set both packers. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 4/22/2013 4/23/2013 Waiting on boat with E-line equipment.RU slick line.RIH and retrieve bar.Bar won't go back down. Decided to pump down string and clean off XN nipple.Pumped 1/2 bbl/min with 500 psi,2 bbls/min with 1850 psi and 2.8 bbls/min with 2,000 psi.Pumping 15 bbls away we had no returns in the annulus,no pressure on annulus.RIH with impression block,impression looked good.RIH and retrieved prong.RD slick line.RU E-line unit.RIH with RTC and attempt to cut©9,443'.RTC failed two times,POOH each time and redressed tool.The third time we changed everything and TIH,cut was good on third run.RD E-line unit and equipment.No over pull on pick up,9 bbls to fill hole.TOOH from 9,443 to 2,815'MD. Continue to stand back tubing in derrick.Cut on 2 7/8"tubing was jagged.Rig up testing equipment for BOPE test. Plan forward:finish BOP test and RIH with production string with mill to dress up 2 7/8"stub.POOH and TIH with production string with two packers.Pickle string prior to hanging off.Put packer fluid between packers.Hang string and follow completion procedure. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 28.0 4/23/2013 4/24/2013 Test BOPE,change pipe ram 4-way on koomy unit,continue to test BOPE.Test BOPE 250 psi low and 3,500 on annular preventer;250 psi low and 5,000 psi high for all other tests.Finish testing BOPE,rig down and blow lines down,set wear bushing and pick up new BHA to go in with overshot guide and mill with mud motor to dress up stub on 2 7/8"tubing.TIH to 7,510'MD,hole out of balance,set up circulating swedge and circulate.Continue to RIH to 9,420,MD.Get over stub at 9,444'MD and start milling procedure.When finished started circulating bottoms up at 1 bpm and 300 psi. Plan forward:POOH,lay down BHA,pick up bottom hole tools to go over 2 7/8"stub as per Olgoonik representative.RIH with same.Space out to hang.Pickel with BJ.Hang the production string,set packers and test at 4,000 psi for 30 minutes. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 29.0 4/24/2013 4/25/2013 POOH with mill assembly from 9,444 MD to 2,190 MD.lay down 25 joints of 2 7/8"DP.Pull wear bushing.Pick up completion assembly:overshot,Packer,2 7/8"tubing,sliding sleeve,rig up for 3 1/2" tubing handling equipment.Pick up and TIH with 3 1/2"9.3#L80 EUE tubing. Plan ahead:finish running tubing.Space out to set in hanger.Prior to hanging,RU BJ and procede with pickle procedure.Next fill the backside with 20 bbls packer fluid.Set down on hanger and lock down. Drop bar and set packers.Test integrity of production string to 4,000 psi for 30 minutes.Chart the same. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 6/7 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_se 11kH( Y Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily Operations r4- , . Rpt No. Report Start Date Report End Date Operation Summary#1 x„ FaAw 30.0 4/25/2013 4/26/2013 Continue to run completion string.Service rig.Finish running completion from 8,510'to 9,41OMD. Space out as per Olgoonik consultant.Pick up hanger,make up the same as per Cameron representative.RU BJ to start pickle procedure.Test lines and pump 500 gallons acid and follow with CaCl2,reverse out and send acid to PTS tank.Repeat process,inject retums from PTS tank.Spot 20 bbls packer fluid between packers.Drain stack and set hanger.Lock down the same.Drop bar and set packer at 3,600 psi.Test tubing to 4,000 psi,bleed off and rig up to test annulus to 2,000 psi.both tests was good.Set BPV and start nippling down BOPE. Plan ahead:Finish nipple down and nipple up tree.RU slick line and TIH and open sliding sleeve. Reverse out existing CaCl2 and replace with FIW packer fluid.Move rig to C34-26 Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 31.0 4/26/2013 4/27/2013 Nipple down BOPE;inject neutralized acid returns from acid and pickle job.Nipple up tre.Test tree to 5,000 psi.Test was good.Rig up slick line and TIH,open sliding sleeve,POOH with wire line and rig down slick line unit.Rig up hose and pumps to tree to displace well with 225 bbls FIW with corrosion inhibitor in annulus and FIW in production string.Rig down circulating Manifold from tree.Rig up slick line and close sliding sleeve.Test tubing to 4,000 psi for 30 minutes and annulus to 2,000 psi for 30 minutes.Chart both tests. Plan ahead:Finish slick line work on well.Start moving rig to C34-26. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 32.0 4/27/2013 4/28/2013 Test annulus at 4,000 psi and tubing at 2,000 psi fo 30 minutes.Chart the same.Both tests was good. RU slickline to pull bar and XN plug.POOH with plug.Rig down slick line tools.Move rig off of well and center MGS to C34-26.Secure rig,reinstall handrails and all safety equipment.Release rig to new well. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 7/7 Report.Printed: 9/10/2013 • Daily Activity and Cost Summary_ FNlliLiy Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 T08N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 kibbs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Rpr Failed Pkr Leakage Tst 6/5/2013 12:00 Objective Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 6/5/2013 6/6/2013 Skid rig over well,Rig up service lines,R/U slick-line to set plug in X-Nipple Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 6/6/2013 6/7/2013 RIH w/slick-line&set plug&prong in X-Nipple @ 9461'WLM.Test tubing t/2500psi for 30 min.No bleed off. Pull prong&Plug.Open sliding sleeve©8,669',R/U lines&kill well w/10.5ppg CaCl2(@ 75 bbls of oil in returns),Monitor well(static),Set BPV.N/D well-head,N/U BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 6/7/2013 6/8/2013 N/U BOPs,Pull BPV,Circ out gas.Monitor well(static),Set BPV.Test BOPs,Pull BPV.Cut Tbg @ 9,388', Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 6/8/2013 6/9/2013 P/U on tubing,anchor seal pulled free at 111k(15k over-pull),UD tubing.(7"Packer&2-7/8"Tbg came out down to cut @ 9,388'((Pkr showed no signs of setting),Test Rams&Annular with 2-7/8"Tbg,P/U Overshot BHA&RIH-P/U Drillpipe,Service Rig,Cont.P/U Drillpipe Hole Currently taking 1/2 bbl per hour Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 6/9/2013 6/10/2013 RIH with overshot and grapple,PU single joints of 3.5"DP,to 9,373'.Kelly up and circulate surface to surface.Tagged fish at 9,388',Swallowed 4',rotated as directed by Baker tool representative.Could not get tool to release.Jarred 5 times and then rotated 18 turns to the right,PU 30K over.Repeated this procedure again and PU 65K over.Jarred loose the third time at 100K over.Gained 5K to 6K over string weight.POOH.When out of hole,fish was not on and grapple was broke.Called XTO engineer and decided to go back in with cut lip overshot and new packer.Waited from 20:00 hours to 04:00 for new packer assembly that was brought out by boat,since XTO superintendent stopped any sling loads brought by helicopter.The lost time due to the dropped sling load was 2 hours of investigation and written testimonies by those who were involved in comunication with helicopter pilot and saw the packer assembly dropped from between 30'to 50'.There was three individuals involved in writing testimonies of first hand visual witness of the dropped sling load.Both XTO representative and Tool pusher evaluated damage.Tri-Piont packer hand made a piece by piece evaluation of his tool. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 6/10/2013 6/11/2013 Waiting for overshot.Cleaning and scrubbing rig,pump room,wellhead room,UD 9 joints DC and replace with DP.Organize parts connex,clean and paint rig entry.R?D 2"hardlines F/C34-26-T PTS tank.Change out middle swab on#1 MP,Cleaned and scrubbing cellar.M?U packer assembly BHA. Off-load 2 7/8"tubing F/boat.RIH with packer and tagged stub at 9,388'.R/U slick line W/.70 drift to confirm over stub.R/U to test annulus.Drop bar to set packer. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/3 Report Printed: 9/10/2013 •ail Y Activity Activi and Cost Summary_s 40161.°ENERGY Well Name: Middle Ground Shoal C24-26RD APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 i 2/17/1968 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 6/11/2013 6/12/2013 RIH with 1.7 guage on slick line and make sure packer is lined up with tubing stub.Slick line went to 8,720 with no problem.POOH and rig down slick line.Set 5"packer at 9,639',MD.Released from packer and pull out of hole and lay down packer running tool.Pick up RTTS BHA and run in hole and tag packer.Circulate DP volume at 2.5 BPM and 204 psi.Set RTTS 30'above packer and pressure up and chart at 3,500 psi for 30 minutes.Test was good.Bleed off test,release RTTS and TOOH laying down drill pipe to BHA and prepare same for backhaul. Plan forward:Finish laying down DP and BHA.Pull wear ring and start running 2 7/8"6.5#L80 tubing with Baker FH Packer as per running procedure with 9 GLM. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 6/12/2013 6/13/2013 Trip out of hole with RTTS and lay down the same.Lay down Kelly:and prepare rig floor to run completion.Make up Tri-Point Latch assembly and packer.RIH on 2 7/8"completion and latch into 5" packer for space out.Attempted to unlatch from packer.Tri-Point latch would not unlatch,pulled up 30K and backed out of the top of the SSSV.POOH with 247.73'of tubing.Called for Baker shop foreman to get a overshot and grapple for the 3 1/2"stub looking up from the fish.Called the XTO expeditor to get the tools out to us.The tools will be brought out on the first helicopter at 08:00 hours.Picked up 3 1/2" Drill pipe to fish for completion string.We already have a fishing consultant on location from Baker. Plan forward:Pick up fishing tools,TIH with grapple and overshot,catch fish and back out Tri-Point Latch.POOH with fish and determine condition of threads on SSSV.Screw in the pup joint if threads are okay.Trip in hole and space out with existing marks.Finish completion procedure and release rig to Platform A. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 6/13/2013 6/14/2013 Waiting for Grapple.Continued Servicing rig while waiting on tools:pick up 3 stands DP,rack back in derrick.RIH with overshot to 253'MD,latch on SSSV.Attempted release from packer,backed off from SSSV at pup,pulled out of hole and layed down fish.Continued waiting in tools due to weather.Tools received from boat at 20:00 hours.RIH with over shot and latched onto fish.Released from packer and POOH while layiong down DP.Removed overshot and pup.Picked up new SSSV.Installed SSSV and control line with Pollard and RIH with completion.Spaced out as per Baker representative and set packer and land hanger.Locked down hanger. Plan forward:Set BPV and nipple down BOPE.Set WH,RU slick line and open bottom GLM,circulate out weighted fluid and replace with FIW.Pull bar and release rig to A33-14. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/3 Report Printed: 9/10/2013 • Daily Activity and Cost Summary_sts E w E H(;Y Well Name: Middle Ground Shoal C24-26RD API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200780100 TO8N-R13W-S23 Middle Ground Shoal 179-062 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/18/1968 2/17/1968 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 6/14/2013 6/15/2013 Pressure up on tubing to set packer.Baker representative acknowledged the packer was set.Started tubing test and realized pressure in the annulus.Continued to test both annulus and tubing to 2500 at the same time.XTO engineer wanted to have slick line operator to set plug above the 7"packer to test the integrity of the tubing with the GLM.Waiting on weather before slick line operator could be flown out.Rig up slick line and RIH with plug body and prong to 8,610'WLD.Test tubing to 2,500 psi for 30 minutes to verify all GLM are shut.Test was good.Tested annulus to 500 psi with 1,000 psi on tubing. Charted both tests and both was good.Pulled plug and prong and got ready to run body and prong below packer.While waiting for wireline operator to redress tools,decided to pressure up on bar.The results was the same and the annulus pressured up with the tubing.RIH with body and prong at 9,362' MD,the prong was sticky through the packer. Plan forward:Since the packer is not set,we will pressure up to 2,000 psi and see if there is any pressure in the annulus with the new plug being placed between packers.The decision will be made with XTO engineer about the plans forward. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 6/15/2013 6/16/2013 Locate communication between tubing and annulus on slick line.Located leak between 8,625'and 8,670'WLD,it was at 7"packer.Went in to pull mbar and could not pull due to debrie around bar. POOH.TIH with bailer and removed debrie.TOOH.TIH and recovered bar.Unlocked hanger.unseat 5" retrievable packer and POOH with completion string and layed down GLM's in order and marked the same.Layed down 7"packer and found 40K shear ring was sheared.Will send 7"packer to town and determine why it was leaking.Layed down 5"packer and the rest of the assemblies.RU to test BOPE's.Witness was waived by Jim Regg of AOGCC. - Plan forward:Finish BOPE test,Pick up new 7"and 5"Tripoint packers and TIH with GLM's in order. Space out and set packers.Test tubing and annulus to make sure packers are set.Lock down hangar. Set BPV.Nipple down BOPE and set WH.Finish completion as outlined,Release rig to A33-14 Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 6/16/2013 6/17/2013 Test BOPE's 250 psi/5,000 psi;250 psi,2,500 on Annular Preventer for 2 7/8"tubing.Rig down testing equipment and prepare to run 2 7/8"6.5#180 8 rd EUE completion string as per XTO engineer.RIH with completion string to SSSV.RU Pollard and test control line to 5,000 psi,good test.RIH and space out as per Tripoint Representative.Make up hanger and lock down as per Cameron representative.Test void to 5,000 psi.Good test.Drop bar and set 5"Tacker then test well bore to 500 psi for 30 minutes_ Good test.Set 7"FH at 1,200 psi,and continued to pressure up to 2,500 psi for 30 minutes.good test. Test tubing annulus to 500 psi maintaining 1,000 psi on tubing.Good test.Rig down testing equipment; pull landing joint,set BPV. Plan ahead:Finish completion procedures,circulate out kill fluid and replace with FIW packer fluid. Release rig toA33-14 Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 6/17/2013 6/18/2013 Rigging down BOPE,Breaking down in pieces to send to platform A putting pieces on deck.Work boat hauling back mud products and 3 1/2"drill pipe.Nipple up tree and test to 5,000 psi for 30 minutes.All tests on tree was good.Continue to rig down and organize platform and get ready to mobilize and stack out.Release rig to A33-14 Remarks#2 Construction Summary#3 www.xtoenergy.com Page 313 Report Printed: 9/10/2013 UP • ,„ \ \ I % %r- s ?4, THE STATE Alaska Oil and as ® f Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue of Q. Anchorage, Alaska 99501 -3572 LASY' Main: 907.279.1433 Fax: 907.276.7542 Bola Adeyeye Operations Engineer SCANNED JUN 13 2013 6 7? XTO Energy 9127 S Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, and G Oil Pool, Middle Ground Shoal C24 -26RD Sundry Number: 313 -291 Dear Mr. Adeyeye: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Trt Commissioner DATED this 2day of June, 2013. Encl. . N • tip, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Fool ❑ Repair Well El • Change Approved Program Cil Suspend ❑ Rug Perforations ❑ Perforate ❑ Pull Tubing isi „ Tine Extension ❑ Operations Shutdow n ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: XTO Energy 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development Ej 179 -062 • 3. Address: 9127 S Jamaica Street Stratigraphic ❑ Service ❑ 6. API Number: Englew ood, CO 80112 50- 733 - 20078 -01 -00 • 7. If perforating: 8. VVell Name and Number: What Regulation or Conservation Order governs w ell spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C24 -26RD • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756 • MGS E, F, G Oil Pools - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Rugs (measured): Junk (measured): 11,216' 9,686' • 11,160' 9,640' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,875' 10 -3/4" 1,875' 1,782' 3,130 psi 1,580 psi Intermediate 9,100' 7" 9,100' 7,823' 6,340 psi 3,830 psi Production Liner 2,317' 5" 8,881' - 11,198' 7,633' - 9,672' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,589' - 11,096' • 8,529' - 9,671' 3 -1/2" N80 8,660' Packers and SSSV Type: HB-BP Permanent Packer / Otis Ball SSSV Packers and SSSV MD (ft) and TVD (ft): 7 "Pkr@ 8,690' MD, 7,467' TVD; 5" Pkr@9419' MD, 8094' TVD, SSSV @ 304' MD &TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for March 2013 15. Well Status after proposed w ork: Commencing Operations: Oil ❑ ! Gas ❑ VVDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: rj -f... f ? WIND g , -I' iNJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 4 S r Y GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and orrect to the best of my know ledge. Contact Bola Adeyeye Email giibola adeyeye@xtoenergv.com Printed Name Bola Adeyeye Title Signature f Phone 303 - 397 -3606 Date 06/03/13 t COMMISSION USE ONLY Conditions of approval: Notify Conmission so that a representative may w itness Sundry Nurmber: 3; -3q Pug Integrity ❑ BOP Test [i Mechanical Integrity Test [V Location Clearance ❑ Other: { � , 6C 9P l s / RBDMS JUN 13 201, Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /6_ y 0.1 APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: 61/4 MGS C24-26: Procedure to mill out existing 7 "packer and re -run 5" & 7" packers 3 ORIGINAL 24 y p \'N') ` (1.0 • • n•y_ _. ,..� ,. - . Leah. . ENERGY June 3, 2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W 7`" Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, Application for Sundry Approval Objective: Replace Injection Packer Middle Ground Shoal C24 -26RD Cook Inlet, Alaska API: 50- 733 -20078 XTO Energy herby submits its Application for Sundry Approvals to replace injection packer in the Middle Ground Shoal C24 -26RD. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval 2. Summary Page 3. Job Procedure 4. Wellbore Diagram If you require additional information, please contact me at (303) 397 -3606. Sincerely, f Bola Adeyeye, OpeAttions Engineer CC: Sandra Haggard, Regulatory Analyst, (303) 397 -3672 MGS C24-26: Procedure to mill out existing 7 "packer and re -run 5" & 7" packers 1 • • 4 .4 . ter X ERGY >:;1_ June 3, 2013 To: John Norman Guy Schwartz Victoria Ferguson CC: Romeo Perez Scott Griffith From: Bola Adeyeye RE: MGS C24 -26RD Cook Inlet, Platform C Replacement of packer from original workover program (Sundry #312 -261) AOGCC previously approved XTO's Application for Sundry Approval (Sundry #312 -261) to workover the MGS C24 -26RD and convert the well to a waterflood injector well. Pressure was noticed on the tubing- casing annulus while conducting injection test, indicating packer or tubing leak. Plug will be set in the XN- nipple via slickline to ascertain integrity of the tubing. XTO is requesting approval to rig up and replace packer in this well. Appended is sundry application, workover procedure for packer replacement and proposed wellbore diagram. If you require additional information, please contact me at 303 - 397 -3606. Sincerely, Bola Adeyeye Operations Engineer MGS C24 -26: Procedure to mill out existing 7 "packer• and re -run 5" & 7 packers 2 • • ;(1 NERGY XTO ENERGY INC. MGS C24 -26RD COOK INLET, ALASKA — EAST FLANK Repair Packer June 3 2013 WELL DATA: SURFACE CASING: 10- 40.5# J55 BTC. Set @ 1875'. Cmt w/ 1550 sk. Top Job w/ 100 sk. INTERMEDIATE CASING: 7" 23, 26 & 29# N80 BTC. Set @ 9100'. Cmt w/ 500 sk. Surface — 4047': 23# 4047 — 7688': 26# 7688 — 9100': 29# PRODUCTION LINER: 5" 18# N80/P110 Hydril FJ. Set @ 11,198'. TOL @ 8881'. Cmt w/ 242 sk. Sqz liner top @ 9,025' w/ 150 sk & 9,010' w/ 100 sk. TUBING: 3-Y2" 9.3# N80 8rd EUE @ 8857'. Total 287 Jts. PACKER: 7" TIW HB -BP Permanent Packer (13Cr) @ 8690; 5" TIW HB -BP Permanent Packer (13Cr) @ 9419' 5" TIW HB -BP Permanent Packer (13Cr) @ 9480' PERFORATIONS: GN -GO: 9589 — 9619' GR -GS: 9917 — 9966' HC -HD: 10,231 — 10,243' & 10,278 — 10,284' & 10,342 — 10,358' HK -HN: 10,692 — 10,742' HN -HR: 10,770 — 10,820' & 10,878 — 10,964' HR -HZ: 10,986 — 11,036' & 11,083 — 11,096' TOP OF FILL: 11,082' (1991) BHST: 170 Deg F BHP: 4350 psi (SI WHP = 800 psi) SMALLEST ID: 2.313" ID X Nipple @ 9442' PRESENT STATUS: Well SI after tubing communication with TCA, during injection test OBJECTIVE: Pull tubing, millout 7" permanent packer, run 5" & 7" Baker FH permanent packer MGS C24 -26: Procedure to mill out existing 7-packer and re -run 5" & 7" packers 4 • • • AFE # 1200483 Sundry #312 -261 • 10.8 ppg kill weight fluid should kill the well, 300 psi expected SI WHP. The kill fluid from C34- 26 will be weighed up to 10.8 ppg and used on this well. Required Tools and Suppliers • Fishing tools: 2 -7/8" overshot and bumper sub — Baker Oil Tools • 5" Baker FH Permanent Packer — Baker Oil Tools • 7" Baker FH Permanent Packer — Baker Oil Tools • Anchor seals or on/off tool for 7" packer — Baker Oil Tools • Movable seal for 5" packer — Baker Oil Tools • X -Over 2 -7/8" 8rd to 2 -3/8 8rd — Baker Oil Tools • 10' Millout Extension for 5" packer — Baker Oil Tools • 10' Millout extension for 7" Permanent Packer — Baker Oil Tools • 6' Pup Jt, 2 -3/8" 6.5# 8rd EUE — Baker Oil tools • 2 -3/8" XN Nipple (1.791" ID) 8rd — Baker Oil Tools • 4' Pup Jt, 2 -3/8" 6.5# 8rd EUE — Baker Oil Tools • 4" X 2 -7/8" Alignment Stub — Baker Oil Tools • 7" RTTS Test Packer — Halliburton • 5" RTTS Test Packer — Halliburton PROCEDURE: 1. Bleed -off pressure on tubing and tubing- casing annulus. 2. Rig up slickline and lubricator. Pick up plug, RIH to XN- nipple (2.205" ID) and set. Pull slickline out of well. 3. Pressure test tubing to 2500 psi for 30 minutes. If pressure drop is greater than 50psi, call Bola Adeyeye to further discuss. RIH with retrieving tool, pull plug in XN- nipple. 4. RIH tool on slickline to open sliding sleeve located at 8678', above the 7" permanent packer. POOH with slickline, rig down lubricator. 5. Weigh up 400 bbl CaC12 kill fluid from last workover to 10.5 ppg. RU mud pumps to tubing and open the tubing- casing annulus. Circulate kill fluid through the sliding sleeve while taking returns up the tubing- casing annulus. Record net volume of 10.8 ppg CaCl2 required to kill the well 6. Monitor returns for weight consistency to ensure FIW is circulated out. Check tubing and production casing pressure to insure well is dead 7. Set BPV, ND wellhead. Install riser and NU BOP, including 2 -7/8" & 3 -1/2" VPR. Pull BPV and set two way check valve. Pressure test BOP to 250 psi and 5000 psi. 8. Latch onto tubing hanger and pull out of spool, right turn rotate on tubing as recommended to unset the packer anchor seal. Pull up hole while monitoring weight to verify anchor is unset. POOH with completion string. .11GS C74 -26: Procedure to mill out cx i . 6 ' iit7 ; 7 " packer and r ' -ruse 5 " c4 7" packers 5 • • 9. POOH with completion string, lay down the BHA. RIH mill assembly on 3 -1/2" drill pipe to 8660 ft (30 feet above 7" permanent packer). 10. Bullhead 17 bbl of 10.8 ppg kill fluid into the wellbore to allow same volume of FIW into the formation. This will allow a more viscous fluid interface above the 2 -7/8" tubing stub, minimizing packer shavings drop off into the stub ` (' pit 11. Proceed downward to packer at 8690 ft. Tag packer and resume milling operation; perform periodic high viscous sweeps to insure adequate circulation of packer shavings. Monitor returns for cleanout consistency, make sweep adjustments as needed. 12. Continue tripping down with mill assembly to mill packer, monitor torque for signals of complete milling of the packer and some of the mill -out extension. Verify depth and correlate to packer location in the original completion string tally. 13. POOH with drill pipe, lay down mill assembly. Inspect the mill assembly for external wear, indicating possible damage to casing. 14. RIH with 2 -7/8" overshot, bumper sub and appropriate fishing assembly. Engage tubing stub and pull out of the well. 15. Pick up 5" Baker FH permanent packer, with BHA and RHCP in the 1.791" ID XN- nipple. RIH with 3-1/2" workstring while latching into the seals with 2 -3/8" sting pipe. The 2-7/8" X 4" alignment stub at end of string should land closely on top of the existing packer downhole. 16. Run 5" permanent packer t 936(60 feet above the topmost 5" TIW HB -BP packer). Once on p depth, rig up slickline unit and lubricator. RIH with 1.8" gauge ring to end of tubing (wireline re- f entry guide at 9508 ft). Ensuring packer shavings did not clog the tail -pipe. 17. POOH with slickline, ND lubricator. Drop bar, pressure up and gradually step -up as 5 r J recommended by Baker tool representative to set the packer. S P 18. Nipple up check valve on the drill pipe and run flowline to take returns to the trip tank. Pump into annulus while monitoring drill pipe for returns. If no return is observed up the workstring, this will indicate successful setting of the packer. Do not exceed 800 psi pump pressure during this test. Note: There is a leak in the liner top, therefore the annulus will not be able to hold pressure test. Successful test will be identified by "no fluid return" out of the drill pipe while pumping into the annulus 19. Unlatch anchor seal from the packer, POOH with 3 -1/2" drill pipe, laying down the anchor seal /stinger MGS C24 -26: Procedure to mill out existing 7 packer and re -run 5'° & 7" packers 6 • • 20. Pick up 5" RTTS test packer, run into well to - 30 ft above the 5" permanent packer. Set packer and pressure test down the tubing to 2000 psi test 5" RTTS packer. Unset RTTS test packer, POOH Si 4 624, Pa- . 21. Pick up 7" Baker FH permanent packer and 3 -1/2" completion string. Run packer to 8660 ft. BHA will include movable seal that will sting into the 5" Baker FH packer that is set in step 19. RIH with 7" packer and engage bottom stinger into the 5" packer. Run the completion string as follows: Do not run RHCP with this string Item Length, t Top Bottom 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 300 304 3 -1/2" X Nipple (2.813" ID) 8rd 9 Cr 1 304 305 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 305 309 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 8,276 309 8,585 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 8,585 8,589 X -over 3 -1/2" 8rd Box X 2 -7/8" 8rd Pin 13 Cr 1 8,589 8,590 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 60 8,590 8,650 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 8,650 8,654 2 -7/8" XU Sliding Sleeve (2.213" ID) 8rd 9 Cr 1 8,654 8,655 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 8,655 8,659 Anchor w/ Seals 8rd EUE or on /off tool 1 8,659 8,660 7" Baker FH Permanent Packer 4 8,660 8,664 10' Millout Extension 10 8,664 8,674 X -Over MOE to 2 -7/8" 8rd 1 8,674 8,675 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 696 8,675 9,371 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,371 9,375 2 -7/8" X Nipple (2.213" ID) 8rd 9 Cr 1 9,375 9,376 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,376 9,382 X -Over 2 -7/8" 8rd to 2 -3/8" 8rd 1 9,382 9,383 Anchor w/ Seals 8rd EUE or Overshot 4 9,383 9,387 5" Baker FH Perm Packer with movable seals 10 9,387 9,397 10' Millout Extension 1 9,397 9,398 6' Pup Jt, 2 -3/8" 6.5# 1% 8rd EUE 6 9,398 9,404 2 -3/8" XN Nipple (1.791" ID) 8rd 1 9,404 9,405 4' Pup Jt, 2 -3 /8" 8rd EUE 4 9,405 9,409 8' Alignment Stub 4" X 2 -3/8" 8 9,409 9,417 22. Nipple -up slickline lubricator. RIH with 1.8" gauge ring to 9380 ft, this confirms access into the 5" Baker FH permanent packer. Pull slickline out of hole, lay down BHA and ND lubricator. MGS C24-26: Procedure to mill out existing 7-packer and re -run 5 & 7" packers 7 • • 23. Drop bar to seat in the RHCP located in the 1.791" ID XN- nipple. Pump down to pressure up on the drill pipe and set the 7" permanent packer. Follow Baker tool representative direction to set the packer. 24. Pressure test tubing- casing annulus to 2000 psi for 20 minutes. Notify Bola Adeyeye of any leak off while performing the pressure test. 25. Unlatch anchor and seals from packer, space out tubing, engage anchor seals back into the packer and land tubing hanger. Pressure test tubing- casing annulus to 2000 psi for 30 minutes, chart and record pressure. 26. Set BPV, ND BOP. NU wellhead, pull BPV and install two way check. Pressure test wellhead to 5000 psi. Pull 2 -way check. 27. Nipple -up slickline lubricator, RIH with tool to open sliding sleeve above the 7" permanent packer. POOH with slickline. 28. Mix 235 bbl FIW with 20 gal corrosion inhibitor. Pump down 10 bbl of spacer down the tubing while taking return up the annulus, follow with 235 bbl of packer fluid and 80 bbl of FIW. Monitor returns to insure proper displacement of the CaC12 kill fluid. 29. RU slickline and lubricator. RIH with tool to close sliding sleeve. Close sliding sleeve and pull out slickline. 30. Pick up pulling tool to pull rod. RIH on slickline and latch onto rod. POOH 31. Pick up RHCP retrieving tool, RIH on slickline, disengage RHCP and pull out of hole. Lay down tools. ND lubricator and RD slickline unit. 32. Return well to injection. -4"-r -Q,X 1114 i - 1 l Bola Adeyeye Operations Engineer 11GS C24- ?c5 :.Procedure to 111111 out e.vi,tingr 7 "11ackcr and re-run 5" c packers 8 • • XTO AAA 6 -3 -13 FRGY PROPOSED MGS C24 -26RD ` J KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 4 API No: 50- 733 - 20078 -01 Tbg: 3 -1/2" 9.3# L80 + 1 /o Cr 8rd EUE @ 8615' Spud: 1118168 Original Well 2 -7/8" 6.5# L80 +1% Cr 8rd EUE @ 9371' Sidetrack RD: 10 -2 -79 Ian Lexpit it Tap gin 31/2'93t1,93+1 %Q8dElEtt7g 307 0 330 Surf Csg: 10 3/4" 40.5# J55 BTC. 4 Rp,l, 31/2'9.3k1 %Q aid RE 4 an 304 Set @ 1,875'. Cmt w/ 1,550 sk. 31 /2'xNgie(2813' 1 304 315 Top Job w/ 100 sk. Tot cmt: 1,650 sk 4Rp,1,31/2'9.3 1 °,aadaE 4 an 309 31/2'9.3h£13+ 1 %t adREttx,1 $276 303 $55 4RpJ,3-1/2'9.3t1 %a ad RE 4 8,535 $539 Xoa31 /2' ad Bat X2- 7/8'adFin 137 1 $533 $510 27/8'65#1,3111 ° / adREtbg $530 $653 4 RN, 2-7/8' 6.5x` 1 %aad RE 4 86E0 8,664 2- 7 /8'XNp;ie(2213' 1 $64 $665 E d re j Ed 4 $655 $653 Or Aduvv Sada ad4.E 1 6693 $637 , II 7' 132ca RH Flan Padce' 4 $683 $664 Intermediate Csg: 7" 23 -29# N80 BTC. 10MIlat6daeim 10 $e64 $674 Set @ 9,100'. Cmt w/ 500 sk. XQa W "to27/8' ad 1 $674 $675 Surf - 4,047' : 23# 27/8'6511,3011 ° /QadElEtbg 636 $675 $371 4,047 - 7,688' : 26# 17''' 4Rp,l,27 /8'6511 %0i adf.E 4 9371 9,373 7,688 - 9,100':29# � __ 27 /8'XNAde(2213' 1 9,375 9,36 ` __ - R 6 4,1, 2-7 /8' 6511 %O ad RE 6 9,376 9,3'32 XOs27/8'adto2-3'8' 1 9,362 9,383 ( Th A M /' MduWthsmisad 4 9,383 9,387 5'RicaRiR tPaker -m d:tes�s 10 9,337 9,337 Sqz 2 @ 9,010' w/ 100 sk. raw 10 Mllat Exteem 1 9,397 9333 Sqz 1 @ 9,025' w/ 150 sk. //f ii 1 ri. 4 6 Rp.1, me 6311 %0 6 9,338 9404 C ? R 23'8')NNi:0(1.791 " IC) ad9Q 1 9,404 9,405 46 ` � . AI ' 4 4 Rp,1, 23(88rd RE 4 9,405 9,408 li ffil■Mil 03.31P 8Aigm:t 8 5439 $417 • ►� I GN -GO: 9,589 - 9,619' Prod Liner: 5" 18# N80/P110 Hydril FJ. di GR -GS: 9,917 - 9,966' Set @ 11,198'. TOL @8,881'. y HC -HD: 10,231 - 10,243' @ Cmt w/ 242 sk. TOC 9,370' I r •Z r -1 HC -HD: 10,278 - 10,284' Fish in Hole os 5" TIW HB -BP Permanent Pkr @ 9419 ft and BHA �_ HD -HE: 10,342 - 10,358' 5" TIW HB- BP Permanent Pkr @9486 ft and BHA HK -HN: 10,692 - 10,742' pa HN -HR: 10,770 - 10,820' HN -HR: 10,878 - 10,964' F, HR -HZ: 10,986 - 11,036' p HR-HZ: 11,083 - 11,096' PBTD: 11,160 MD (9,640' ND) TD: 11,216' MD (9,686' ND) ,/ Ai MGS C24 -26: Procedure to mill out existing 7' packer and re -run 5" & 7" packers 9 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20AAC25.280 1. Type of Request: Abandon ❑ Rug for Redrill ❑ Perforate New Pool ❑ Repair Well ISI Change Approved Program 0 Suspend ❑ Rug Perforations ❑ Perforate ❑ Pull Tubing 0 Time Extension ❑ Operations Shutdow n ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: • ❑ 2. Operator Nacre: XTO Energy 4. Current Well Gass: 5. Permit to Drill Number: Exploratory ❑ Development ISI 179 -062 3. Address: 9127 S Jamaica Street Stratigraphic ❑ Service ❑ 6. AR Number: Englewood, CO 80112 50- 733 - 20078 -01 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs w et spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C24 -26RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 18756 MGS E F, G oil Fools 1 1. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Rugs (measured): Junk (measured): 11,216' 9,686' 11,160' 9,640' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,875' 10 -3/4" 1,875' 1,782' 3,130 psi 1,580 psi Intermediate 9,100' 7" 9,100' 7,823' 6,340 psi 3,830 psi Production Liner 2,317' 5" 8,881' - 11,198' 7,633' - 9,672' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,589' - 11,096' 8,529' - 9,671' 3 -1/2' N80 8,660' Packers and SSSV Type: HB-BP Permanent Packer / Otis Ball SSSV Packers and SSSV MD (ft) and TVD (ft): 7"Pkr© 8,690' MD, 7,467' TVD; 5" Pkr ©9419' MD, 8094' TVD, SSSV @ 304' MD &TVD 12. Attachments: Description Summary of Proposal 151 13. Well Gass after proposed work: Detailed Operations Program ❑ BOP Sketch ploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for March 2013 5. Wet Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of cry know ledge. Contact Bola Adeyeye Email ajibola adeyeye@xtoenergv.com Printed Name Bola Adeyeye Title Signature Rione 303 - 397 -3606 Date 06/03/13 COMMISSION USE ONLY Conditions of approval: Notify Conmission so that a representative may witness Sundry Number: Rug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: MGS C24 -26: Procedure to mill out existing 7 "packer and re -run 5" & 7" packers 3 • • Schwartz, .Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 06, 2013 11:03 AM To: 'Adeyeye, Ajibola' Cc: Griffith, Scott; Duggin, Greg; Perez, Romeo; 'Regg, James B (DOA) (jim.regg @alaska.gov)'; DOA AOGCC Prudhoe Bay Subject: RE: XTO Energy: MGS C24 -26RD (PTD # 179 -062) Bola, I have reviewed your proposed RWO sundry application to repair leaking packers in the Injector C24 -26RD. You have verbal approval to proceed with the procedure as written. You indicated hard copies of the sundry have already been mailed to the Commission. Good luck with the workover. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 -793 -1226 office From: Adeyeye, Ajibola [n ola Adeyeye j_x:toenergycorn] Sent: Wednesday, June 05, 2013 8:17 AM To: Schwartz, Guy L (DOA) Cc: Griffith, Scott; Duggin, Greg; Perez, Romeo Subject: XTO Energy: MGS C24 -26RD (PTD # 179 -062) Guy- As per our earlier conversation, we observed pressure on the tubing- casing annulus during injection test on C24 -26RD, suspecting the packers on this well failed. However, we will be performing a tubing test today to confirm its' integrity. This well was converted to injection April 2013 under approved sundry # 312 -261. In preparation for workover to replace the packer, requesting verbal sundry approval to rig -up on the well and conduct repair work. Attached is the sundry package for the workover. Included in the package is detailed procedure, proposed schematic and sundry application. Hard copy of this sundry will be Fedex Overnight to AOGCC office in Anchorage. Here is the work plan summary: - Run plug on slick line to XN- Nipple, pressure test tubing to confirm integrity - Attempt to pull out completion string, if packer anchor seal doesn't release, go in with wireline and cut tubing above 7" packer and pull out tubing - Mill out 7" permanent packer, periodically pump sweep to ensure shavings aren't falling off onto the tubing stu b - Run overshot into well and fish anchor seal out of 5" permanent packer - Run 5" permanent packer and set below leaking liner top, sting out of packer to pull drill pipe (5" packer set at 9360 ft) 1 • - Run in with 5" test packer, pressure test to confirm sealed elements on permanent packer - Run 7" permanent packer, sting tail pipe movable seals into 5" packer and set 7" packer. Land completion string (packer set at 8660 ft) 5" packer will be engaged with movable seals stinger while seals on the 7" packer will be anchored. Regards Ajibola (Bola) A. Adeyeye XTO Energy — Subsidiary of ExxonMobil Operations Engineer — Western Division Office: 303 -397 -3606 Cell: 720 -539 -1660 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 22, 2013 9:12 AM To: 'Bridge, Alexander' Cc: Griffith, Scott Subject RE: XTO - MGS C24 -26RD - completion change(PTD 179 -062) Alec, The changes to the completion as outlined below are approved. It still meets UIC regulations for packer placement. Good luck with the rest of the workover operation. Guy Schwartz Senior Petroleum Engineer A ©GCC 907 -444 -3433 cell SCANNED APR 2 3 2013 907- 793 -1226 office From: Bridge, Alexander [;;ailto:AIeYanae:r BrdgeL,gt;oenerg,r.cam] Sent: Monday, April 22, 2013 5:21 AM To: Schwartz, Guy L (DOA) Cc: Griffith, Scott Subject: XTO - MGS C24 -26RD - completion change(PTD 179 -062) Guy, As per our discussion earlier regarding the MGS C24 -26RD, we set the 5" packer at 9,473' on a 3 -1/2" drill pipe x 2 -7/8" tubing tapered string. We could not release the anchor /seal assembly after setting the packer. We will cut the 2 -7/8" tubing at 9,443' and POOH with the drill pipe and the rest of the tubing. We will then RIH with a 5" packer and 7" packer on our completion string. The tail -pipe for the 5" packer will have an overshot on it that will slide over the 2 -7/8" tubing stub on the 5" packer that's already set. We will have a X- profile nipple below the 5" packer; we will use this profile to set a plug to set both packers in tandem and verify tubing integrity. The second 5" packer will be set at +/- 9,410'. The 7" packer will be set at 8,720' (no change to this depth). I know we have already discussed these changes verbally, but will you please confirm that you approve of the changes. Please let me know if you need more information. Regards, Alec Bridge Operations Engineer XTO Energy — Western Divison 303 - 397 -3608 (0), 720 -244 -9083 (C) i • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 15, 2013 9:59 AM To: 'Bridge, Alexander; Ferguson, Victoria L (DOA) Cc: Drilling, Alaska; Griffith, Scott Subject: RE: XTO -MGS C24 -26RD - Request for variance from 20 AAC 25.412 (b) (PTD 179 -062) Alec, XTO's request to place upper packer >200' above the injection zone is APPROVED. An additional packer will be placed in the 5" liner within 200 ft of the perforations. Monitoring this annulus will be from the upper packer depth of 8720' to surface. In your proposed procedure also chart the tubing test (4000 psi) in step 39 for 30 min . This will give us a record that the tubing between the packers has been tested as well. The TCA (MIT —IA) in step 40 test doesn't verify integrity in this part of the tubing string. Guy Schwartz SCANNED JUL 0 8 2013 Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Bridge, Alexander [piailto; }Thdcje,?; xto< rq Sent: Monday, April 15, 2013 7:38 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Drilling, Alaska; Griffith, Scott Subject: XTO - MGS C24 -26RD - Request for variance from 20 AAC 25.412 (b) Guy and Victoria, XTO is requesting variance for the well MGS C24 -26RD from Rule 20 AAC 25.412 (b), which requires the top packer in an injection well to be set within 200' MD of the top perforation. The previously approved procedure (Sundry 312 -261) called to set one packer inside the 5" liner 116' MD above the top pert (packer set at 9,473' MD). During workover operations, we discovered a leak in the 5" x 7" overlap. The 7" casing pressure tested OK from 8,821' to surface. We could not perform a successful test between 8,821' and 8,907' (5" liner top is at 8,881'). If we were to complete the well as per our approved procedure, the well would not pass a MIT due to the leak at the liner lap. Rather than attempt to repair the liner lap again (previously squeezed in 1979), we propose setting a second packer in the 7" casing above the liner lap at 8,720'. This will ensure that there is no pressure on the annulus from 8,720' to surface. We will still set the 5" packer at 9,473' as originally planned. I have attached a proposed wellbore diagram, a proposed completion procedure, and the previously approved and updated (10 -5 -12) procedure for your reference. Please let me know at your earliest convenience if you approve the variance request. I am out of the office, so please call me on my cell phone if you have any questions or concerns. Please copy Joe Steiner (AItl ka C)rillirw ' toenergy.cwm) and Scott Griffith (Scott C r f(ithr xtoc.rIergy_.c._u n) on any response to this email. Thanks. • Regards, Alec Bridge Operations Engineer XTO Energy — Western Divison 303 - 397 -3608 (0), 720 -244 -9083 (C) 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, April 13, 2013 2:25 PM To: 'Bridge, Alexander; Ferguson, Victoria L (DOA) Cc: Drilling, Alaska; Griffith, Scott '��" �e L. Subject: RE: XTO - MGS C24 -26RD - proposed completion Alec, You will also have to request a variance for the change in upper packer depth. The Top packer is supposed to be within 200ft of the injection zone per 20 AAC 25.412 (b) for an injector. You can do that by email and will need to justify it in writing as you outlined below in your email. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Bridge, Alexander [n aiiroAiexdndt,r ?i`F ge x or c r: , Orr] Sent: Friday, April 12, 2013 4:07 PM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Drilling, Alaska; Griffith, Scott Subject: XTO - MGS C24 -26RD - proposed completion Victoria, Please find the attached proposed completion and proposed WBD for MGS C24 -26RD. I also attached a copy of the previously most updated complete version of the workover procedure (10- 5 -12). Per our conversation earlier today, we found a leak in the 5" x 7" overlap (7" pressure tested OK from 8,821' to surface, no test between 8,821' and 8,907'). If we were to complete the well as per our approved procedure, the well would not pass a MIT. Rather than attempt to repair the liner lap again (previously squeezed in 1979), we propose setting a second packer in the 7" casing above the liner lap at 8,720'. This will ensure we have no pressure on the annulus from 8,720' to surface. Please let me know at your earliest convenience if you approve the changes to the procedure. Please call me on my cell phone with any questions or concern. Please copy Joe Steiner (Alaska D; 3 i n @)xtoen_ ergy_c.o n) and Scott Griffith (y ( ,qtr„ tfii;;; toeners y ,co on any response to this email. Thanks for your time. Regards, Alec Bridge Operations Engineer XTO Energy — Western Divison 303 - 397 -3608 (0), 720 -244 -9083 (C) 1 ) TO ENERGY XTO ENERGY INC. MGS C24 -26RD COOK INLET, ALASKA — EAST FLANK P Updated Completion Procedure — 04/12/2013 Please replace steps 33 — 41 in the procedure dated 10 -5 -12 with the following procedure: 33. RIH with TIW 5" HB -BP chrome permanent packer on 3 -1/2" x 2 -7/8" drill pipe (packer setting depth is 9,473'). Drop bar down tubing (bar will seat in RHCP in XN nipple at 9,494') and pressure up on drill pipe to set packer per TIW's instructions. Bleed off tubing pressure. Pump down drill pipe x casing annulus and pressure up to 2,000 psig and maintain pressure; monitor drill pipe and check for flow. If there is no flow, the packer is set. NOTE: Annulus will pressure up when pumping into it, but it will not hold pressure due to the leak in the 5" x 7" overlap. If the packer is set, there will be no circulation out the drill pipe when pressure is applied to the annulus. 34. Release anchor and seals on 5" packer and POOH with drill pipe. RIH with 7" HB -BP chrome permanent packer on 3 -1/2" x 2 -7/8" tubing (with 5" anchor and seals on tail pipe) as outlined below: Item Length, h Top Bottom 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 300 304 3 -1/2" X Nipple (2.813" ID) 8rd 9 Cr 1 304 305 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 305 309 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 8,336 309 8,645 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 8,645 8,649 X-over 3 -1/2" 8rd Box X 2 -7/8" 8rd Pin 13 Cr 1 8,649 8,650 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 60 8,650 8,710 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 8,710 8,714 2 -7/8" X Nipple (2.213" ID) 8rd 9 Cr 1 8,714 8,715 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 8,715 8,719 Anchor w/ Seals 8rd EUE (13 Cr) 1 8,719 8,720 7" TIW HB -BP Permanent Packer (13 Cr) 4 8,720 8,724 10' Millout Extension (13 Cr) 10 8,724 8,734 X -Over MOE to 2 -7/8" 8rd (13 Cr) 1 8,734 8,735 T • • 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 726 8,735 9,461 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,461 9,465 2 -7/8" X Nipple (2.213" ID) 8rd 9 Cr 1 9,465 9,466 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,466 9,472 Anchor w/ Seals 8rd EUE (13 Cr) 1 9,472 9,473 5" TIW HB -BP Permanent Packer (13 Cr) 4 9,473 9,477 10' Millout Extension (13 Cr) 10 9,477 9,487 X-Over MOE to 2 -7/8" 8rd (13 Cr) 1 9,487 9,488 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,488 9,494 2 -7/8" XN Nipple (2.205" ID) 8rd 9 Cr 1 9,494 9,495 ✓ 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,495 9,499 2 -7/8" WL REG 1 9,499 9,500 35. Prior to engaging anchor and seals on 5" packer, pump 1,000 gal pickle acid job. RU BJ. RU PTS tank and put 1,000 lbs soda ash inside. Pressure test all lines to 2,000 psi. Establish circulation down tubing with FIW at 2 - 3 BPM. Pump 500 gal 10% pickle acid. Under - displace 500 gal from EOT. With the rig pumps, reverse circulate the acid to PTS tank with FIW. Repeat with the remaining 500 gal acid. RD BJ. Send acid returns to disposal well C44 -14RD. 36. Mix 280 bbls FIW with 60 gal EC1447WR (corrosion inhibitor) and reverse circulate to spot packer fluid (volume contains 30 bbls excess). 37. Engage anchor and seals on 5" packer. Pressure up on tubing to set 7" packer per TIW's instructions. 38. Release anchor on 7" packer. PU landing joint. MU new stainless steel tubing hanger. Space out tubing and engage anchor and seals on 7" packer. Land tubing. Run in new lock screws to energize hanger seal. 39. Pressure up on tubing to 4,000 psi and hold for 15 minutes. Monitor fall off. tA_C T 3 o w. 40. Perform MIT on the TCA with a chart recorder. With 7" packer set at 8,720' MD (7,494' TVD), pressure up on TCA to 1,900 psi (7,494' TVD x 0.25 psi/ft =1,874 psi). Hold test for 30 minutes. 41. RU slickline. RIH and retrieve drop bar and RHCP in XN nipple at 9,494'. POOH. RD slickline. 42. Set BPV. ND BOPs and riser. NU new SS WH. Pull BPV. Set 2 -way check and test WH to 5,000 psig. Release rig. Install SSV on WH. 43. PWOI. Schedule post - injection MIT once rates and pressures stabilize. " s • E N 0 1 ) uIO ACB 4 -12 -13 PROPOSED ENERGY MGS C24 -26RD % KB 35' Cook Inlet, Alaska • • Water Depth: 73 MSL Leg 1, Conductor 4 o API No: 50- 733 - 20078 -01 % ' Tbg: 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE @ 8650' Spud: 1/18/68 Original Well 2 -7/8" 6.5# L80 +1% Cr 8rd EUE @ 9500' Sidetrack RD: 10 -2 -79 / Set: Surf Csg: 10 3/4" 40.5# J55 BTC. Item Length, tt Top Bottom Set @ 1,875'. Cmt w/ 1,550 sk. 3-1/7' 9.3# L80 + 1% Cr 8rd EUE tbg 300 0 300 Top Job w/ 100 sk. Tot cmt: 1,650 sk 4' Pup Jt, 3-1/2" 9.3# 1% Cr 8rd EUE 4 300 304 3-1/2" X Nipple (2.813" ID) 8rd 9 Cr 1 304 305 4' Pup Jt, 3-1/2" 9.3# 1% Cr 8rd EUE 4 305 309 3-1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 8,336 309 8,645 4' Pup Jt, 3-1/2" 9.3# 1% Cr 8rd EUE 4 8,645 8,649 X-over 3-1/2" 8rd Box X 2 -7 /8' 8rd Pin 13 Cr 1 8,649 8,650 2 -7/8" 6.5# L80+1 %Cr 8rd EUE tbg 60 8,650 8,710 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 8,710 8,714 2 -7/8" X Nipple (2.213" ID) 8rd 9 Cr 1 8,714 8,715 0" 00ii 4' Pup Jt,2 -7/8 "6.5#1 %Cr 8rd EUE 4 8,715 8,719 Anchor w/ Seals 8rd EUE (13 Cr) 1 8,719 8,720 7" TIW HB-BP Permanent Packer (13 Cr) 4 8,720 8,724 10' Millout Extension (13 Cr) 10 8,724 8,734 Intermediate Csg: 7" 23 -29# N80 BTC. // X-o'er MOE to 2 -7/8" 8rd (13 Cr) 1 8,734 8,735 Set @ 9,100'. Cmt w/ 500 sk. / 2 -7/8" 6.5# L80+1%Cr 8rd EUE tbg 726 8,735 9,461 Surf 4,047' : 23# 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,461 9,465 4,047 - 7,688' : 26# /� 2 -Ir8" X Nipple (2.213" ID) 8rd s Cr 1 9,465 9,466 7,688 9,100' : 29# 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,466 9,472 Anchor w/ Seals 8rd EUE (13 Cr) 1 9,472 9,473 5" 11W HB-BP Permanent Packer (13 Cr) 4 9,473 9,477 10' Millout Extension (13 Cr) 10 9,477 9,487 X -O er MOE to 2 -7/8" 8rd (13 Cr) 1 9,487 9,488 ►, �, 6' Pup Jt, 2 -7/8" 6.581% Cr 8rd EUE 6 9,488 9,494 2 -7/8" XN Nipple (2.205" ID) 8rd 9 Cr 1 9,494 9,495 All to 1.r Sqz 2 @ 9,010' w/ 100 sk. # 4' Pup Jt, 2-7/8" 6.58 1% Cr 8rd EUE 4 9,495 9,499 Sqz 1 @ 9,025' w/ 150 sk. "7.1.- . 4 t 2 -7 /8" WL REG 1 9,499 9,500 I GN -GO: 9,589 - 9,619' , - GR -GS: 9,917 - 9,966' Prod Liner: 5" 18# N80/P110 Hydril FJ. rI 9 Set @ 11,198'. TOL @ 8,881'. Cmt w/ 242 sk. TOC @ 9,370' i� HC -HD: 10,231 - 10,243' ._ HC -HD: 10,278 - 10,284' ' HD -HE: 10,342 - 10,358' r Mk HK-HN: 10,692 10,742' ' HN -HR: 10,770 - 10,820' HN -HR: 10,878 - 10,964' i HR -HZ: 10,986 - 11,036' � r HR -HZ: 11,083 - 11,096' PBTD: 11,160 MD (9,640' TVD) TD: 11,216' MD (9,686' ND) �/ J /�, • • P'th f o6 Regg, James B (DOA) From: Alaska_Drilling @xtoenergy.com Sent: Tuesday, April 09, 2013 5:02 AM 4 (9 ( To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: Re: Shut -in Well # C24 -26RD We used the annular preventer to SI well. We done a complete BOP test since then. --- The test form and charts will be sent today. Joe Platform C 907 - 776 -2534 SCANNED JUL 10 L013 "Regg, James B (DOA)" <jim.regq(thalaska.gov> To Alaska Drilling /KEN /CTOC, DOA AOGCC Prudhoe Bay < doa. aogcc.prudhoe.bayAalaska.dov> 04/08/2013 10:58 PM cc Subject Re: Shut -in Well # C24 -26RD What was used to SI the well? You must test used BOP equipment on next trip to surface. "Alaska Drilling@xtoenergy.com" <Alaska Drilling(thxtoenergy.com> wrote: Gentlemen, XTO Energy Platform C Well # C24 -26RD On 4 -7 -13 at 07:30 hrs. at a depth of 9814' during liner clean -out operations the well was shut in, due to gas percolating out of the work -over fluid. The well pressure was less than 20 psi on the casing and 0 on the drillpipe, a 2 bbl gain was recorded. The gas was circulated out thru the choke manifold and poorboy degasser. The well was checked for flow(static). No mud weight increase was needed. We had cleaned out a bridge in the liner at 9630'. Regards, Joe Steiner DrIg Supervisor XTO Energy Platform C 907 - 776 -2534 1 • • y w \� oF A THE STATE Alaska Oil and Gas °f Conservation Commission A LASKA GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Ed^ Fax: 907.276.7542 Sandra Haggard SaN� H1 � Regulatory Analyst 0 6 XTO Energy I 9127 S Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, and G Oil Pool, MGS C24 -26RD Sundry Number: 313 -127 Dear Ms. Haggard: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this /0 of of March, 2013. Encl. . • 3 RES: ! STATE OF ALASKA '�j'1 17? 3 ! 1? ! ALASKA OIL AND GAS CONSERVATION COMMISSION "" 'i.' 1 ..' +4' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ lime Extension ❑ Operations Shutdown p. ❑ ❑ Casing ❑ CT - (U 12/ p ❑ Re - enter Sus We ll Stimulate Alter Casin Other: � 2. Operator Name: XTO Energy 4. Current Well Class: 5. Permit to Drill Number. )1 3 44 Exploratory ❑ Development Ei • 179 -062 " 3. Address: 9127 S Jamaica Street Stratigraphic ❑ Service ❑ 6. API Number. Englewood, CO 80112 50 - 733 - 20078 - - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C24 - 26RD • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756• MGS E, F, 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): 11,216' • 9,686' 11,160'• 9,640' NA NA Casing Length Size MD TVD Burst Collapse Structural . Conductor Surface 1,875' 10 -3/4" 1,875' 1,782' 3,130 psi 1,580 psi Intermediate 9,100' 7" 9,100' 7,823' 6,340 psi 3,830 psi Production Liner 2,317' 5" 8,881' - 11,198' 7,633' - 9,672' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,589' - 11,096' • 8,529' - 9,671' 3-1/2" N80 8,857' Packers and SSSV Type: Guiberson UniPacker VII / Otis Ball SSSV Packers and SSSV MD (ft) and TVD (ft): Packer © 8,788' MD, 7,552' TVD; SSSV © 314' MD, 314' TVD 12. Attachments: Description Summary of Proposal 0 . 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for March 2013 15. Well Status after proposed work: Commencing Operations: Oil [ / Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ , V GINJ ❑ WAG ❑ Abandoned ❑ � I Commission Representative: I1°15 GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard Email Sandra Haggard(xtoeneray.com Printed Name Sandra Haggard Title Signature 777 eoro Phone 303 - 397 -3672 Date 03/08/13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 3-12-1 Plug Integrity ❑ BOP Test d Mechanical Integrity Test ❑ Location Clearance ❑ Other: -A 5 -616(- p se_ &A° l s P i PRIBMS MAR 18 2013 Spacing Exception Required? Yes ❑ No Subsequent Form Required: C / G — c.�6 It G APPROVED BY Approved by: , / / / COMMISSIONER THE COMMISSION Date: 3 -/' e - / 3 Submit Form and r Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • ;(710 A E E D ' = 2013 March 8, 2013 AOGCC Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, request for Sundry Approval Objective: Clean out the 3 /2 tubing string with coiled tubing prior to workover. Middle Ground Shoal #C24 -26RD Water Injection Well Middle Ground Shoal Field, E, F & G Oil Pools Cook Inlet, Alaska API 50- 733 - 20078 -01 -00 XTO Energy Inc. herby submits its Application for Sundry Approvals to pull tubing and repair well. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval 2. Cover Page 3. Summary Page 4. Job Procedure 5. Wellbore Diagram If you require additional information, please contact me at (303) 397 -3672 Sincerely, i Sandra M. Haggard, Regulatory Analyst Copy To: Alec Bridge, Operations Engineer @ (303) 397 -3608 XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An ExxonMobil Subsidiary TO ENERGY To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Romeo Perez From: Alec Bridge RE: MGS C24 -26RD Cook Inlet, Platform C Addition to previously approved workover program (Sundry #312 -261) The AOGCC previously approved XTO's Application for Sundry Approval (Sundry #312 -261) to workover the MGS C24 -26RD and convert the well to a waterflood injector well XTO is requesting approval to clean out the 3 -1/2" tubing string with coiled tubing prior to proceeding with the previously approved workover. If you require additional information, please contact me at 303 - 397 -3608. Sincerely, 3 4A..ty 03/0 i Z o /3 Alec Bridge Operations Engineer • • TO ENERGY XTO ENERGY MGS C24 -26RD - EAST FLANK PRODUCER COOK INLET, ALASKA COIL TUBING CLEAN OUT PROCEDURE WELL DATA SURFACE CASING: 10 -3/4" 40.5# J55 BTC. Set @ 1,875'. Cmt w /1,550 sx. Top out job w /100 sx. INTERMEDIATE CASING: 7" 23 #, 26# & 29# N80 BTC. Set @ 9,100'. Cmt w /500 sx. Surface - 4,047': 23# 4,047' - 7,688': 26# 7,688' - 9,100': 29# PRODUCTION LINER: 5" 18# N80/P110 Hydril FJ. Set @ 11,198' & TOL @ 8,881'. Cmt w/242 sx. Sqz liner top @ 9,025' w /150 sx & 9,010' w /100 sx TUBING: 3 -1/2" 9.3# N80 8rd EUE @ 8,857'. Total 287 jts. PACKER: 7" Guiberson Uni- Packer VII @ 8,788'. Set in 1980. PERFORATIONS: GN -GO: 9,589' - 9,619' GR -GS: 9,917' - 9,966' HC -HD: 10,231' - 10,243' & 10,278' - 10,284' & 10,342' - 10,358' HK -HN: 10,692' - 10,742' HN -HR: 10,770' - 10,820' & 10,878' - 10,964' HR -HZ: 10,986' - 11,036' & 11,083' - 11,096' TOP OF FILL: 11,082' (1991) BHST: 170 Deg F BHP: 4,300 psi (SI WHP = 360 psi) SMALLEST ID: 2.75" ID X Nipple @ 8,826' PRESENT STATUS: SI w/360 psi WHP & 910 psi Csg Press. OBJECTIVE: Clean out 3 -1/2" tbg prior to performing CTI workover NOTE: This job will be performed prior to prior to the previously approved workover to convert this well to a waterflood injector (Sundry #312 -261, AFE #1200483). After performing the coiled tubing clean out procedure, we will proceed with the CTI workover as planned. • • EQUIPMENT & MATERIALS REQUIRED: • 1.75" CTU • 2 -1/2" motor & tapered mill • 1 -3/4" Roto -Jet washing nozzle • Filter Skid w/2 — 10 micron filters • 2 gpt FRW -16A friction reducer • 10 bbl gel pill (2# /bbl FloZan + 3 gal Greencide) PROCEDURE: 1. MIRU Baker Hughes 1.75" CTU, riser, BOPE, and injector head. Install pressure gauges on CT, CT x 3 -1/2" tubing annulus, and 3 -1/2" tubing x 7" casing annulus. Notify AOGCC 24 hours prior to BOPE test. MU motor and mill on EOT. Caliper all tools before RIH (smallest ID = 2.75 ", X Nipple at 8,826'). Pressure test treating lines to 5,000 psig. Maximum treating pressure is 4,000 psig. 2. Hold pre job safety meeting. 3. Open WH for circulation. RIH with CT at 60 FPM while pumping FIW at 1 BPM. Slow RIH rate as necessary when encountering fill and passing gas lift mandrels (see attached WBD). Continue RIH and clean out to EOT at 8,857'. 4. Circulate a 10 bbl gel pill followed by 80 bbls FIW. 5. Open CT annulus. POOH with coil tubing @ 100 FPM. Bleed off pressure. RD CTU. 6. Proceed with CTI procedure (Sundry #312 -261, Approved 08/29/2012). • • WELL SI `92 PLF 8 -10 -04 ;(1 NERGY Current Completion MGS C24 -26RD % L KB: 35' Cook Inlet, Alaska 0 Water Depth: 73' MSL Leg 1, Conductor 4 API No: 50- 733 - 20078 -01 , Tbg: 3 1/2" 9.3# N80 EUE 8rd @ 8,857'. Spud: 1/18/68 Original Well I Total 287 Jts. Set on 1 -3 -80. Sidetrack RD: 10 -2 -79 �� Surf Csg: 10 3/4" 40.5# J55 BTC. Item MD TVD Psc Port Set @ 1,875'. Cmt w/ 1,550 sk. KBM #1 2,229 2,079 12 Top Job w/ 100 sk. Tot cmt: 1,650 sk KBM #2 4,304 3,753 12 KBM #3 5,803 4,344 16 KBM #4 6,963 6,004 Orifice 24 Holes in tbg KBM #5 7,728 6,646 Dummy KBM #6 8,342 7,171 Dummy KBM #7 8,684 7,462 Dummy KBM #8 8,751 7,519 Dummy F fr Otis Ball SSSV @ 314" 7" Guiberson UniPkr VII @ 8,788' r 1 Jt 3 1/2" 9.3# N80 EUE 8rd @ 8,796' Intermediate Csg: 7" 23-29# N80 BTC. / 3 1/2" X Nipple (2.75 ID) @ 8,826' Set @ 9,100'. Cmt w/ 500 sk. ' � 1 Jt 3 1/2" 9.3# N80 EUE 8rd Surf - 4,047' : 23# 3 1/2" Shear Sub w/ Mule Shoe Guide @ 8,857' 4,047 7,688' : 26# _ 7,688 9,100' : 29# ►i� Sqz 2 @ 9,010' w/ 100 sk. fr. ° Sqz 1 @ 9,025' w/ 150 sk. % //� * ► * : * i0i' GN -GO: 9,589 - 9,619' - Prod Liner: 5" 18# N80/P110 Hydril FJ. GR GS: 9,917 - 9,966' Set @ 11,198'. TOL @ 8,881'. Cmt w/ 242 sk. TOC @ 9,370' % HC -HD: 10,231 10,243' HC -HD: 10,278 - 10,284' r - HD -HE: 10,342 - 10,358' / _ HK -HN: 10,692 - 10,742' / __. _ , HN -HR: 10,770 - 10,820' _ _ HN -HR: 10,878 - 10,964' Top of Fill @ 11,082' (1991) r r HR -HZ: 10,986 - 11,036' / ..... HR HZ: 11,083 - 11,096' PBTD: 11,160 MD (9,640' TVD) ................. TD: 11,216' MD (9,686' TVD) % • R c v, SCd a o ra ll� pr0eedv✓'Z to / pTD t X9 -1 Sic f c e p5 /3 _ /7- TO z E NERGY ViF / 5 -1 f XTO ENERGY INC. MGS C24 -26RD COOK INLET, ALASKA — EAST FLANK Convert to Injection Procedure WELL DATA: SURFACE CASING: 10-%" 40.5# J55 BTC. Set @ 1875'. Cmt w/ 1550 sk. Top Job w/ 100 sk. INTERMEDIATE CASING: 7" 23, 26 & 29# N80 BTC. Set @ 9100'. Cmt w/ 500 sk. Surface — 4047': 23# 4047 — 7688': 26# 7688 — 9100': 29# PRODUCTION LINER: 5" 18# N80/P110 Hydril FJ. Set @ 11,198'. TOL @ 8881'. Cmt w/ 242 sk. Sqz liner top @ 9,025' w/ 150 sk & 9,010' w/ 100 sk. TUBING: 3 -' /z" 9.3# N80 8rd EUE @ 8857'. Total 287 Jts. PACKER: 7" Guiberson Uni- Packer VII @ 8788'. Set in 1980. PERFORATIONS: GN -GO: 9589 — 9619' GR -GS: 9917 — 9966' HC -HD: 10,231 - 10,243' & 10,278 — 10,284' & 10,342 — 10,358' HK -HN: 10,692 — 10,742' HN -HR: 10,770 — 10,820' & 10,878 — 10,964' HR -HZ: 10,986 — 11,036' & 11,083 — 11,096' TOP OF FILL: 11,082' (1991) �� BHST: 170 Deg F S ►,NNED APR Q $ BHP: 4300 psi (SI WHP = 360 psi) SMALLEST ID: 2.75" ID X Nipple @ 8826' PRESENT STATUS: SI w/ 360 psi WHP & 910 psi Csg Press. OBJECTIVE: Pull tbg, CO Will, acidize perfs and run new injection tbg. • AFE # 1200483 Sundry #312 -261 • 10.5 ppg Salt mud should kill the well with 360 psi SI WHP. The mud will be used from the C24 -23 workover. • There are possible holes in tbg (unknown depth). Therefore, NO attempt will be made to release & retrieve the 31 year old Guiberson packer. It will be milled out. 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55\C24 -26RD CTI Procedure 10- 5- 12.docx • • 2 • The GN -GR will NOT be acidized. Materials Rqd: • 7000 gal (6000 spz + 1000 pickle) Acid System to contain these additives: ➢ 10% HCL ➢ 10% mutual solvent ➢ gpt Corrosion Inhibitor ➢ ppt Iron Reducing Agent ➢ 2 gpt Surfactant • 100 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 1,000 lbs Soda Ash (MI) • 30,000 lbs CaC12 (124 lbs/bbl FIW to build 10.5 ppg) Maintain MW from last well. • 60 gal EC1447WR Corrosion Inhibitor (Nalco) 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55\C24 -26RD CTI Procedure 10- 5- 12.docx • • 3 PROCEDURE: 1. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ pulling tool to GLM #8 @ 8751'. Latch & POOH the dummy valve. RD lubricator. 3. Mix 400 bbl 10.5 ppg CaC12 mud (Use from last job). RU mud pumps to tubing. Open the tbg annulus. Circulate to kill well from GLM #8. Take wellbore fluids to disposal well and recover /maintain the 10.5 ppg Salt mud. Check to make sure well is dead. 4. MI 11,400' 2 -7/8" 10.4# X95 drill pipe & 6 ea 3 -1/8" DC's. 5. Notify the AOGCC 48 hrs prior to the BOP test. Set BPV's and ND the WH. Install riser & NU BOP's. Pull BPV's & set double check valves. Ensure BOP has 3 -1/2" VPR pipe rams. Press test BOP's to 250 psi & 5000 psi. Send in WH to Cameron. New WH to have SS valves. 6. MIRU Pollard WL. RIH w/ tbg cutter & CCL. Cut the tbg @ 8778', 10' above the packer. POOH & RD WL. 7. RU slips & tongs for 3 -1/2" tbg. POOH & LD 3 -1/2" tbg while checking for NORM. Send tbg to onshore to be sold for scrap. Casing Cut for Csg Spool Removal: 8. MI 4 jts 7" 29# L80 BTC. 1 jt to have Guided Skirt welded by pin end (Olgnoonik). 9. RIH w/ HOWCO 7" 23# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 10. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 11. ND BOP's. l 12. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 13. NU the new Cameron 11" 3K x 13 -5/8" 5K casing head. Weld landing hub to 10 -3/4" csg. 14. RIH w/ 4 -1/4" x 7 -3/8" TAM Inflatable Pkr as per Attached TAM Running Procedure to ±100'. Inflate & release from the pkr. POOH w/ DP. ` cy. 15. NU 13 -5/8" 5K flange with connection for test port. RU line. 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55\C24 -2613D CTI Procedure 10- 5- 12.docx l.� • 4 O 16. Using a chart recorder, press test the weld & new clamp on the bottom of the new Casing Head to 2000 psi for 30 min against the inflatable pkr. 17. ND the 13 -5/8" flange. RIH & deflate the ph. POOH w/ pkr. 18. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's w/ 7" casing rams. Press test BOP's to 250 psi & 5000 psi. 19. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg. 20. RU Casing Crew. PU Guided Skirt jt followed w/ 3 reg jts of 7" 26# L80 BTC -M. Slip skirt over the collar from previous step & MU threads. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the new 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 21. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's with VPR's for 2 -7/8" & 3 -1/2 ". Set WH test plug in tbg spool. Press test BOP's to 250 psi & 5000 psi. 22. RIH and wash off sand & retrieve the 7" RBP @ 500'. POOH & LD DP. 23. RIH w/ OS assembly & attempt to release the Guiberson packer. POOH & LD ph. 24. If packer fails to release, RIH w/ 7" Packer milling BHA. RIH to top of pkr @ 8788'. Establish string weight. Mill packer per packer milling procedures. After the pkr falls, circ bottoms up w/ 20 bbl gel sweep followed w/ FIW. Push ph to 5" TOL @ 8881'. POOH w/ mill. RIH with spear & grapple to retrieve the packer. POOH slowly w/ pkr & LD BHA. 25. RIH w/ 4 -1/8" bit, 51 jts DP (1580' minimum) & casing scraper for 5" 18 #. (Keep scraper above the top perf @ 9589'.) Cleanout fill to 11, 160' PBTD. Minimize DP rotation w/ scraper. Circ 20 bbl gel sweep followed w/ FIW. POOH & LD bit & scraper. Contact the Midland office if problems are encountered in the perforated sections preventing settings for the RBP & Pla- in Step #27. 26. MI BJ w/ 7000 gal 10% HCL. Install pressure transducer on tbg annulus. RU PTS flowback tank. Put 1000 lbs soda ash in tank. 27. RIH w/ Halliburton 5" RBP & RTTS Pkr w/ by -pass. Set RBP @ ±11,130'. PUH 10' w/ ph. 28. Press test acid lines to 7,000 psi. Spot 18 bbl 10% HCL from 11,120' to 10,100'. PUH w/ ph to 9473'. Set packer. Perform a "pre" MIT on the tbg annulus to 2100 psi for 30 min as per Step #38 to verify casing integrity. 29. RIH w/ ph to 11,120'. Rev out acid to PTS tank w/ 10.5 ppg FIW until clean & PH is 6 -7. 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55\C24 -26RD CTI Procedure 10- 5- 12.docx • • 5 30. Est inj rate with FIW. Perform 3 stg acid job w/ 6000 gal acid @ ±2 BPM (PMAX = 6000 psi) as follows: Stage Perfs Pkr Depth RBP Depth Acid Vol, bbl Flush, bbl 1 10878 -11096 10,860 11,130 62 60 2 10692 -10820 10,600 10,860 43 60 3 10231 -10358 10,130 10,400 14 55 Have Pkr by -pass open while acid is going DH. Close by -pass with acid ±10 bbl above pkr. Flush to be 10.5 ppg FIW. 31. Acid equip to standby for pickle job on Step #34. Rel pkr. RIH & retrieve RBP. POOH & LD the tools & DP. 32. MI 900' 3 -1/2" 9.3# L80 +1% Cr 8rd EUE & 775' 2 -7/8" 6.5# L80 +1% Cr 8rd EUE tbg (incl 3% excess). 33. RIH w/ TIW 5" HB -BP Chrome Permanent Packer on 3 -1/2" x 2 -7/8" tbg and land as follows: Item Length, ft Top Bottom 9 p 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 300 304 3 -1/2" X Nipple (2.813" ID) 8rd 9Cr 1 304 305 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 305 309 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 8,470 309 8,779 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 8,779 8,783 X-over 3 -1/2" 8rd Box X2 -7/8" 8rd Pin 13Cr 1 8,783 8,784 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 677 8,784 9,461 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,461 9,465 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 9,465 9,466 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,466 9,472 Anchor w/ Seals 8rd EUE (13Cr) 1 9,472 9,473 5" TIW HB -BP Permanent Packer (13 Cr) 4 9,473 9,477 10' Millout Extension (13 Cr) 10 9,477 9,487 X Ober MOE to 2 -7/8" 8rd (13 Cr) 1 9,487 9,488 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,488 9,494 2 -7/8" XN Nipple (2.205" ID) 8rd 9Cr 1 9,494 9,495 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,495 9,499 2 -7/8" WL REG 1 9,499 9,500 34. RU BJ w/ 1,000 gal 10% Acid. Press test all lines to 2,000 psi. Est circ down the tbg w/ FIW. Pickle the injection tbg with 500 gal acid @ 2 -3 BPM. Underdisplace the acid with FIW by 500' from the end of the tbg. Reverse circ the acid into the PTS flowback tank with the rig pumps. Repeat a 2 pickle sweep with the remaining 500 gal of acid. Reverse out acid with the rig pumps until returns are clean. Pump spent acid into disposal well C44 -14RD & record all volumes injected. RD acid co. 10 -5 -12 C:\ Users \vlferguson\AppData \Local \Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55 \C24 -26RD CTI Procedure 10- 5- 12.docx • • 6 35. Prior to setting the packer, fill the backside w/ packer fluid by reverse circ 280 bbl (inc130 bbl excess) packer fluid containing 60 gal Nalco EC1447WR in 280 bbl FIW. 36. PU landing jt. Space out & MU and land new SS tbg hanger. Run in new lock screws to energize hanger seal. 37. RU Slickline & press test lubricator to 4,000 psi. RIH w/ "N" test tool plug and seat on XN nipple @ 9494'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Con't to press up to ±3,500 psi to set packer. Hold a 4,000 psi press test on the tbg for 15 min. Bleed off the tbg press. 38. Perform the MIT on the 2 -7/8" tbg annulus w/ a chart recorder. With the 5" Packer set @ 9473' MD, press test the annulus to 2100 psi (8156' TVD x 0.25 = 2043 psi) and hold for 30 minutes. 39. POOH w/ test tool. RD Slickline. 40. Set BPV. ND BOP's & riser. NU new SS WH & pull BPV. Set 2 way check & test WH to 5,000 psi. Pull out 2 way check. Release Rig. PWOI. 41. Install SSV on wellhead as per AOGCC. Paul Figel Engineering Manager 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content .Outlook \GTCWFQ55\C24 -26RD CTI Procedure 10- 5- 12.docx • • TifELE ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Maria Perez �-- Regulatory Analyst + "' XTO Energy, Inc. f 200 N. Loraine, Suite 800 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, 8s G Oil Pool, MGS #C24 -26RD Sundry Number: 312 -261 ` DV r i,..tki414ED AUG Dear Ms. Perez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of August, 2012. Encl. • RECEIVED / To ERGY a subsidiary of ExxonMobil JUL 1 6 2012 July 12, 2012 AOGCC Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 Re: Form 10 -403, request for sundry approval Objective: Reactivate this shut -in producer and convert to water injection, Middle Ground Shoal #C24 -26R0 Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50- 733 - 20078 -01 -00 XTO Energy Inc. hereby submits its Application for Sundry Approval to reactivate this shut -in producer and convert to water injection. ` Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval. 2. Cover Page 3. Summary Page. 4. SSSV Test 5. Deviation Survey. 6. Job Procedure. 7. Current Wellbore Diagram. 8. Proposed Wellbore Diagram. 9. Current Wellhead Schematic. 10. Proposed Wellhead Schematic 11. BOP Schematic. If you required additional information, please contact me at A/C 432 - 620 -4325. Sincerely, Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager A/C 432 - 620 -6743 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 . • � ECEIVED STATE OF ALASKA JUL 16 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ A Perforate ❑ Pull Tubing 0 7.. iL Time Extension 10 Operations Shutdown El Susp. Well 0 • i� S timulate Alter Casing 0 ' Oth g --'1 ti t ( (16 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: il XTO Energy Inc. Development 0 Exploratory ❑ 179 -062 3. Address Stratigraphic ❑ Service ❑ 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50- 733 - 20078 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ Middle Ground Shoal #C24 -26RD 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756 • MGS E, F, & 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): 11216' 9686' 11160' 9640' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1875 10 -3/4" 1875' 1782' 3130 psi 1580 psi Intermediate 9100 7" 9100' 7823' 6340 psi 3830 psi Production Liner 2317 5" 8881- 11198' 7633 -9672' 10140 psi 10490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9589'- 11096' 8259' -9671' 3 -1/2" N80 8857' Packers and SSSV Type: Guiberson UniPacker VII /Otis Ball SSSV Packers and SSSV MD (ft) and TVD (ft): Pkr @ 8788' (7552' TVD), SSSV @ 314' (314' TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch El Exploratory ❑ Development ❑ Service El 14. Estimated Date for 11/1/2012 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel, Engr 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature _ „ J Phone 432 - 620 -4325 Date 7/12/2012 S "----- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3' ... -2 (0 ' Plug Integrity ❑ BOP Test Mechanical Integrity Test V Location Clearance El y Other: at 3? PS. App F t t�. '!1 A � � (A �l r-e rp - 1.4.1 4-i kk,_ -4_ o p .44. ors v._.. t„...- u-.c- x.oY°z' `•...,( lEid 1 - SVS 1 D ALL 2,0 AAfC 15 Z4,3 (b) Subsequent Form Req ed: /0 _Lbw APPROVED BY e( - 21 1 � .2_, , Approved by: COMMISSIONER ! THE COMMISSION Date: 1 Form 10 -403 Revised 1/2010 O R I V 1 1 A L 7- gc/ Z Submit in Duplicate w TO 0 July 7, 2012 To: John Norman Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C24 -26RD (179 -062): Reactivate Shut -in Producer & Convert to Inj ection Objective: The workover proposed for the C24 -26, located on Platform C, Cook Inlet, is to reactivate this shut - in producer and convert it to water injection. The scope of the work entails pulling the existing completion, acidizing the HC -HZ zones, and installing new tubing with an injection packer. This well is currently equipped with an outdated product (Type D Uni- Compact Head) that Cameron no longer supports nor has adapter parts to allow for a new tubing hanger to be installed. Therefore, the entire existing wellhead will be removed and replaced with a conventional multi - compartment wellhead. This will be done as outlined in the procedure requiring that the 7" Longstring be cut below the deck to allow the removal of the lowermost casing head section. Approximately 150' of the 7" casing will be replaced and brought back to surface and hung off in a new casing head with slips. This will allow a new tubing spool to be installed. Well History: The original well, C24 -26, was completed in the East Flank in 1968. The well IP'd @ 3200 BOPD, 65 BWPD & 1323 mscf /d. The production declined rapidly over the next 3 years due to scale and lack of water injection support. A workover in 1972 was performed to pull the completion, clean out the fill, and set isolation packers over the wet zones. A surfactant wash job, consisting Neodol in diesel, performed in 1973 severely damaged the formation by creating an emulsion that dropped production from 619 BOPD to 71 BOPD. Attempts to fix this problem with mutual solvent treatments were unsuccessful, which lead to the well being redrilled 6 years later. The well was sidetracked as C24 -26RD in 1979, which did not prove successful as the hole was only 200' away from the original damaged wellbore @ the HC marker. The present completion was set in 1980 with initial production sharply declining over 2 years from ±300 BO & 300 BW to 25 BO & 150 BW. In 1983, a BHP test showed the average reservoir pressure to be 3900 psi which indicated severe reservoir skin damage. Efforts to remediate the damage with coil tubing proved unsuccessful. In 1986, the HD -HE was perforated and tested for a substantial gain from 30 to 1,953 BO but dropped to 100 BOPD within 6 months without having any pressure support. The well was shut -in from 1988 making 43 BO & 400 BW. In 1991, wireline tagged fill @ 10,707' covering the HK -HZ perfs. Following a marginal coil tubing treatment in 1991, the well was shut -in in 1992. • • 2 MISC: XTO Energy has been granted a waiver since 1999 concerning the BOP stack since the rig sub structure can only fit a double ram configuration (as seen in the attached BOP Schematic) versus the 3 ram stack. XTO was grandfathered a variance due to the depleted reservoir pressure and the extensive knowledge of the Middle Ground Shoal over the past 45 years. Therefore, XTO is requesting the same variance for this project. /V l " < 3pa cy 5 The anticipated date for operations start up is November 2012. Please contact me at 432 - 620 -6743 with any questions or concerns. Sincerely, r ;; O rd Paul Figel Engineering Manager l t� 74,E 64t( ("I- fi/ct/ d� ff`v/a if45 ,'r �(�Cv�' p�ba�vC � N /Of'I) p WC, ,T gcrva� / 'C o�vcool ( 7 A d Acton b e i "6 s�vr� n -IF,' ro (e y , API rGGti � r n j 54,10/ */rove lP cove /0i► (7P ftD/ ill r o Qn r • • WORKOVER SUMMARY for C24 -26RD Scope of work: The main objective is to reactivate this shut -in producer and convert it to water injection. The scope of the work entails pulling the existing completion, acidizing the HC -HZ zones, and installing new tubing with an injection packer. The current lowermost casing head section will be replaced with a new conventional casing head that will allow for the installation of a new tubing spool and tubing hanger. Current Well Status: Shut -in since 1992 with 360 psi WHP. Well Info: See Attached Procedure & TVD Survey. SSSV test – see attachment. MASP & Kill Weight: BHP = 4300 psi: (8.4 ppg FIW x 8958' Midperf TVD x 0.052) 360 SIWH = 4272 psi. Kill weight: 4300 psi = (0.052) (8262' Top Perf TVD) (x, ppg) �— P 0z 7iS frk x = 10.0 ppg + 0.5 ppg = 10.5 ppg mud Mud Recipe will be 8.4 ppg FIW + 124 lb/bbl CaC12 MIT Info: NA as a producer BOP Ram Configuration: VPR for 2 -7/8" to 5 ". Schematic Attached. Workover Rig: XTO derrick is a permanent rig on Platform C. Requested Waiver: XTO Energy has been granted a waiver since 1999 concerning the BOP stack since the rig sub structure can only fit a double ram configuration (as seen in the attached BOP Schematic) versus the 3 ram stack. XTO was grandfathered a variance due to the depleted reservoir pressure and the extensive knowledge of the Middle Ground Shoal over the past 45 years. ?ASP 3 0 p-« 2 j e fA A 5=reEc_K 0 Contact Info: • Operations Engineer: Paul Figel, XTO Energy, 432 - 620 -6743, �'" '�" ZS Zs') Ccx0) P aul figel@,xto g enery.com • Superintendent: Scott Griffith, XTO Energy, 907 - 776 - 2506, scott griffithna,xtoenergy.com Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: XTO Energy Submitted By: Barney Phillips Date: 5/20/2012 Operator Rep: Barney Phillips Field/Unit/Pad: MGS XTO C Platform AOGCC Rep: Matt Herrera Separator psi: LPS 68/68 HPS Well Permit Separ Set LIP Test Test Test Date Passed Retest Oil, WAG, GM, Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, SI PSI PSI PSI C12-23 1900200 68 37 38 P P P OIL 100 Yes No C13-13LN 2022130 1/1/2006 SI No No C13-23 1880990 68 37 38 P P P OIL 95 Yes No C13A-23 1901060 P P OIL 90 Yes No C21-23 1890870 P P OIL 95 Yes No C21-26 1890040 P P OIL 100 Yes No C21A-23 1910440 P P OIL 95 Yes No C22-23 1880160 12/19/2004 SI Yes No C22-26RD 1760650 5/5/2012 SI Yes No C22A-26LT 2041820 P P OIL 85 Yes No C24-26RD 1790620 4/1/1992 SI Yes No C31-26RD 2041400 P P OIL 90 Yes No C32-23LW 2020340 P P OIL 75 Yes No C34-26 1680190 11/1/1988 SI Yes No C42-23 1780240 P P OIL 95 Yes No C43-14 1881320 P P OIL 3425 No No Wells: 11 Components: 24 Failure 0 Failure Rate: 0 00% EnDaw Remarks: • PLB 01/26/11 Page 1 of 1 SVS MGS C Platform 5-20-12.xls itill BMW C Platform, Well C24 -26RD INTEQ _ Alaska State Plane Coordinates Measured Angle Azimuth TVD -RKB TVD X Y N / -S E / -W DLS Vert. Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg /100 ft ft Tie -In 0.00 0.00 0.00 0.00 - 105.00 231364.64 2474224.49 0.00 0.00 0.00 0.00 1 75.00 0.17 289.00 75.00 -30.00 231364.53 2474224.53 0.04 -0.11 0.23 -0.11 2 100.00 0.08 31.00 100.00 -5.00 231364.51 2474224.56 0.06 -0.13 0.81 -0.14 3 I 125.00 0.17 162.00 125.00 20.00 231364.53 2474224.53 0.04 -0.11 0.92 -0.12 4 150.00 0.17 80.00 150.00 45.00 231364.57 2474224.50 0.01 -0.06 0.89 -0.06 5 175.00 0.25 163.00 175.00 70.00 231364.63 2474224.46 -0.03 -0.01 1.14 0.01 6 200.00 0.42 137.00 200.00 95.00 231364.70 2474224.34 -0.15 0.07 0.90 0.14 7 , 225.00 0.25 134.00 225.00 120.00 231364.80 2474224.23 -0.26 0.17 0.68 0.28 8 ' 250.001 0.50 108.00 250.00 145.00 231364.94 2474224.15 -0.33 0.31 1.19 0.44 9 275.00 0.33 118.00 275.00 170.00 231365.11 2474224.08 -0.39 0.48 0.74 0.62 10 300.00 0.25 119.00 300.00 195.00 231365.22 2474224.02 -0.46 0.59 0.32 0.74 11 325.00 0.25 108.00 325.00 220.00 231365.32 2474223.98 -0.50 0.69 0.19 0.85 12 350.00 0.17 98.00 350.00 245.00 231365.40 2474223.95 -0.52 0.78 0.35 0.94 Tie -In 359.00 0.17 102.00 359.00 254.00 231365.43 2474223.95 -0.52 0.81 0.13 0.27 1 432.00 1.75 112.00 431.98 326.98 231366.56 2474223.48 -0.97 1.95 2.17 0.37 2 463.00 3.00 108.00 462.96 357.96 231367.76 2474223.02 -1.39 3.16 4.07 0.44 3 , 493.00 4.50 104.00 492.89 387.89 231369.64 2474222.45 -1.92 5.04 5.07 0.41 4 525.00 6.25 107.00 524.75 419.75 231372.50 2474221.58 -2.73 _ 7.93 5.54 0.37 5 556.00 6.501 123.00 555.56 450.56 231375.55 2474220.06 -4.18 11.01 5.77 0.88 6 588.00 7.75 130.00 587.31 482.31 231378.67 2474217.61 -6.56 14.19 4.75 2.25 7 619.00 7.50 141.00 618.04 513.04 231381.48 2474214.63 -9.47 17.06 4.77 4.23 8 650.00 7.00 151.00 648.79 543.79 231383.59 2474211.36 -12.70 19.25 4.37 6.70 9 ' 790.00 8.75 191.00 787.57 682.57 231385.29 2474193.39 -30.63 21.36 4.01 23.29 10 853.00 10.50 195.00 849.68 744.68 231382.66 2474183.19 -40.87 18.96 2.97 33.79 11 944.00 12.25 197.00 938.89 833.89 231377.30 2474166.07 -58.12 13.99 1.971 51.74 12 1036.00 9.75 157.00 1029.32 924.32 231377.11 2474149.54 -74.65 14.18 8.53 67.53 13 1099.00 11.00 153.00 1091.29 986.29 231381.69 2474139.17 -84.91 18.99 2.29 76.00 14 1162.00 13.00 150.00 1152.91 1047.91 231387.70 2474127.53 -96.41 25.26 3.32 85.24 15 I 1225.00 15.00 153.00 1214.04 1109.04 231394.64 2474113.97 - 109.81 32.51 3.38 96.03 16 1319.001 15.25 168.00 1304.82 1199.82 231402.21. 2474090.85 - 132.75 40.60 4.16 115.72 17 1347.00 15.50 174.00 1331.81 1226.81 231403.20 2474083.50 - 140.07 41.76 5.75 122.41 18 1410.00 19.00 174.00 1391.97 1286.97 231404/3 2474064.89 - 158.65 43.71 5.56 139.66 19 1568.00 27.00 178.00 1537.30 1432.30 231407.27 2474003.29 - 220.18 47.66 5.16 197.52 20 1694.00 33.25 177.00 1646.23 1541.23 231408.65 2473940.10 - 283.32 50.47 4.98 257.26 21 , 1825.00 36.00 177.00 1754.02 1649.02 231410.85 2473865.71 - 357.64 54.36 2.10 327.40 22 1900.00 36.00 178.00 1814.70 1709.70 231411.77 2473821.64 - 401.68 56.29 0.78 369.08 23 2118.00 37.25 179.00 1989.65 1884.65 231412.20 2473691.59 - 531.69 59.67 0.64 492.75 24 2339.00 38.50 178.00 2164.10 2059.10 231412.68 2473555.92 - 667.31 63.24 0.63 621.75 25 2561.00 38.50 179.00 2337.84 2232.84 231413.16 2473417.73 - 805.46 66.86 0.28 753.17 26 2750.00 37.25 178.00 2487.02 2382.02 231413.54 2473301.70 - 921.45 69.88 0.74 863.50 27 2792.00 36.75 182.00 2520.57 2415.57 231412.97 2473276.45 - 946.72 69.89 5.85 887.72 28 2843.00 35.00 189.00 2561.91 2456.91 231409.47 2473246.81 - 976.43 67.07 8.74 917.01 29 2906.00 35.50 193.00 2613.37 2508.37 231401.72 2473211.30 - 1012.10 60.12 3.75 953.18 30 2938.00 36.50 195.00 2639.26 2534.26 231396.75 2473193.17 - 1030.35 55.57 4.82 971.97 31 3030.00 37.25 194.00 2712.85 2607.85 231381.72 2473140.05 - 1083.79 41.75 1.04 1027.14 32 3250.00 37.25 192.00 2887.98 2782.98 231348.83 2473011.03 - 1213.53 11.80 0.55 1160.04 33 3562.00 36.75 195.00 3137.17 3032.17 231300.90 2472829.54 - 1396.07 -31.99 0.60 1347.49 34 3669.00 36.50 191.00 3223.06 3118.06 231285.13 2472767.71 - 1458.23 -46.35 2.24 1411.17 35 3700.00 35.75 194.00 3248.10 3143.10 231280.77 2472749.97 - 1476.07 -50.30 6.20 1429.40 36 3733.00 35.50 195.00 3274.92 3169.92 231275.54 2472731.48 - 1494.68 -55.12 1.92 1448.61 37 3764.00 34.50 198.00 3300.32 3195.32 231270.11 2472714.55 - 1511.73 -60.16 6.42 1466.38 38 3918.00 32.50 203.00 3428.76 3323.76 231238.65 2472635.66 - 1591.31 -89.81 2.21 1551.12 39 . 4137.00 32.75 202.00 3613.20 3508.20 231191.01 2472527.64 - 1700.39 - 134.99 0.27 1668.54 40 4359.00 32.75 203.00 3799.91 3694.91 231142.54 2472417.76 - 1811.35 - 180.95 0.24 1787.98 41 4549.00 33.25 203.00 3959.26 3854.26 231099.95 2472323.45 - 1906.60 - 221.38 0.26 1890.81 42 4801.00 32.00 203.00 4171.50 4066.50 231044.03 2472199.64 - 2031.66 - 274.46 0.50 2025.80 Page 1 • • Measured Angle Azimuth TVD -RKB TVD X _ Y N / -S E / -W DLS Vert. Sec _ SVY# Depth deg deg ft Subsea ft ft ft ft deg /100 ft ft 43 5020.00 30.50 204.00 4358.72 4253.72 230996.40 2472096.50 - 2135.85 - 319.74 0.72 2138.57 44 5160.00 29.00 204.00 4480.26 4375.26 230966.71 2472033.70 - 2199.31 - 348.00 1.07 2207.44 45 5374.00 32.25 203.00 4664.39 4559.39 230921.02 2471934.74 - 2299.29 - 391.42 1.54 2315.64 46 5598.00 35.00 203.00 4850.89 4745.89 230869.98 2471821.71 - 2413.46 - 439.88 1.23 2438.88 47 5786.00 36.75 203.00 5003.22 4898.22 230824.64 2471721.31 - 2514.87 - 482.93 0.93 2548.34 48 5846.00 36.75 205.00 5051.30 4946.30 230809.30 2471688.85 - 2547.66 - 497.53 1.99 2583.94 49 5909.00 37.00 205.00 5101.70 4996.70 230792.54 2471654.96 - 2581.92 - 513.51 0.40 2621.33 50 6067.00 36.25 205.00 5228.50 5123.50 230750.78 2471570.47 - 2667.35 - 553.34 0.47 2714.56 51 6193.00 35.75 204.00 5330.44 5225.44 230718.54 2471503.80 - 2734.74 - 584.06 0.61 2787.90 52 6218.00 35.50 204.00 5350.76 5245.76 230712.31 2471490.63 - 2748.04 - 589.98 1.00 2802.34 53 6307.00 34.75 205.00 5423.55 5318.55 230690.03 2471444.53 - 2794.64 - 611.21 1.06 2853.05 54 6399.00 34.00 204.00 5499.48 5394.48 230667.42 2471397.77 - 2841.90 - 632.75 1.02 2904.49 55 6523.00 33.00 207.00 5602.89 5497.89 230636.58 2471336.69 -2903.67 - 662.19 1.56 2972.07 56 6581.00 32.75 205.00 5651.60 5546.60 230622.14 2471308.72 - 2931.96 - 675.99 1.92 3003.12 57 6702.00. 32.00 205.00 5753.79 5648.79 230593.43 2471250.64 - 2990.68 - 703.37 0.62 3067.21 58 6770.00 32.00 207.00 5811.46 5706.46 230576.91 2471218.63 -3023.06 - 719.17 1.56 3102.74 59 6892.00 31.25 207.00 5915.35 5810.35 230546.58 2471162.30 - 3080.06 - 748.21 0.61 3165.65 60 7030.00 30.75 208.00 6033.64 5928.64 230512.34 2471100.02 - 3143.10 -781.02 0.52 3235.42 61 7199.00 30.25 209.00 6179.25 6074.25 230469.71 2471025.59 - 3218.48 - 821.94 0.42 3319.33 62 7298.00 28.00 199.00 6265.78 6160.78 230449.05 2470982.24 - 3262.30 - 841.61 5.41 3366.93 63 7314.00 27.75 195.00 6279.92 6174.92 230446.70 2470975.14 - 3269.45 - 843.80 11.79 3374.41 64 7422.00 27.50 195.00 6375.61 6270.61 230432.64 2470927.08 - 3317.82 - 856.76 0.23 3424.47 65 7517.00 26.50 198.00 6460.26 6355.26 230419.48 2470886.02 - 3359.17 - 868.99 1.78 3467.58 66 7644.00 28.00 199.00 6573.16 6468.16 230399.77 2470831.32 - 3414.30 - 887.45 1.23 3525.69 67 7761.00 30.00 199.00 6675.49 6570.49 230380.09 2470778.13 - 3467.93 -905.92 1.71 3582.36 68 7821.00 30.00 198.00 6727.45 6622.45 230369.92 2470749.90 - 3496.38 - 915.43 0.83 3612.34 69 7917.00 31.00 200.00 6810.17 6705.17 230353.01 2470704.22 - 3542.44 - 931.31 1.48 3661.01 70 8060.00 32.25 201.00 6931.93 6826.93 230325.15 2470634.61 -3612.67 - 957.58 0.95 3735.81 71 8213.00 32.25 200.00 7061.33 6956.33 230294.83 2470558.81 - 3689.14 - 986.17 0.35 3817.26 72 8338.00 32.00 199.00 7167.19 7062.19 230271.22 2470496.67 - 3751.79 - 1008.36 0.47 3883.64 73 8647.00 31.00 200.00 7430.65 7325.65 230213.90 2470345.75 - 3903.99 - 1062.23 0.37 4044.86 74 8778.00 29.25 201.00 7543.96 7438.96 230189.49 2470284.71 - 3965.57 - 1085.24 1.39 4110.45 75 8936.00 29.25 200.00 7681.81 7576.81 230160.82 2470213.03 - 4037.88 - 1112.28 0.31 4187.46 76 9092.00 30.50 200.00 7817.08 7712.08 230132.59 2470140.64 - 4110.90 - 1138.85 0.80 4265.03 Tie -In 9176.00 28.25 191.00 7890.31 7785.31 230120.60 2470101.33 - 4150.47 - 1149.94 5.89 4303.36 1 9231.00 28.00 188.00 7938.82 7833.82 230115.74 2470075.87 - 4176.03 - 1154.22 2.61 4329.23 2 9280.00 27.00 190.00 7982.28 7877.28 230111.70 2470053.61 - 4198.38 - 1157.76 2.78 4351.79 3 9371.00 26.00 185.00 8063.73 7958.73 230105.46 2470013.53 - 4238.60 - 1163.08 2.69 4392.16 4 9394.00 25.75 186.00 8084.43 7979.43 230104.28 2470003.56 - 4248.59 - 1164.04 2.19 4402.11 5 9459.00 24.50 181.00 8143.28 8038.28 230101.94 2469976.09 - 4276.11 - 1165.75 _ 3.79 4429.29 6 9559.00 24.50 181.00 8234.28 8129.28 230100.27 2469934.65 - 4317.57 - 1166.48 0.00 4469.83 7 9574.00 22.50 183.00 8248.03 8143.03 230099.93 2469928.68 - 4323.55 - 1166.68 14.35 4475.69 8 9632.00 22.50 186.00 8301.62 8196.62 230097.69 2469906.61 - 4345.67 - 1168.42 1.98 4497.63 9 9685.00 23.75 185.00 8350.36 8245.36 230095.23 2469885.94 - 4366.39 - 1170.41 2.47 4518.26 10 9741.00 24.75 185.00 8401.42 8296.42 230092.70 2469863.08 - 4389.30 - 1172.42 1.79 4541.02 11 9770.00 25.00 185.00 8427.73 8322.73 230091.36 2469850.95 - 4401.45 - 1173.48 0.86 4553.09 12 9832.00 25.00 185.00 8483.92 8378.92 230088.49 2469824.91 - 4427.55 - 1175.77 0.00 4579.03 13 9925.00 24.00 190.00 8568.55 8463.55 230082.62 2469786.83 - 4465.76 - 1180.76 2.47 4617.37 14 9967.00 24.00 191.00 8606.92 8501.92 230079.13 2469770.11 - 4482.56 - 1183.88 0.97 4634.43 15 10018.00 23.00 187.00 8653.69 8548.69 230075.48 2469750.11 - 4502.63 - 1187.07 3.69 4654.71 16 10048.00 23.25 186.00 8681.28 8576.28 230073.88 2469738.44 - 4514.34 - 1188.40 1.55 4666.41 17 10112.00 24.50 184.00 8739.81 8634.81 230071.05 2469712.69 - 4540.14 - 1190.65 2.33 4692.04 18 1 10204.00 25.00 184.00 8823.36 8718.36 230067.48 2469674.34 - 4578.56 -1193.34 0.54 4730.06 19 10370.00 26.75 183.00 8972.71 8867.71 230061.44 2469602.16 -4650.87 - 1197.74 1.09 _ 4801.47 20 10498.00 28.25 182.00 9086.24 8981.24 230057.53 2469543.19 - 4709.91 - 1200.30 1.23 4859.54 21 10647.00 30.50 178.00 9216.09 9111.09 230055.96 2469470.16 - 4782.96 - 1200.21 2.00 4930.64 22 10832.00 32.50 179.00 9373.82 9268.82 230056.27 2469373.51 - 4879.58 - 1197.71 112 5024.14 23 10948.00 35.00 179.00 9470.27 9365.27 230055.93 2469309.07 - 4944.01 - 1196.58 2.16 5086.62 24 11186.00 36.75 180.00 9663.11 9558.11 230053.94 2469169.62 - 5083.47 - 1195.39 0.78 5222.12 25 11216.00 38.00 180.00 9686.95 9581.95 230053.53 2469151.42 - 5101.68 - 1195.39 4.17 5239.85 Page 2 • • i /TO ERGY XTO ENERGY INC. MGS C24 -26RD COOK INLET, ALASKA — EAST FLANK Convert to Injection Procedure WELL DATA: SURFACE CASING: 10- 40.5# J55 BTC. Set @ 1875'. Cmt w/ 1550 sk. Top Job w/ 100 sk. INTERMEDIATE CASING: 7" 23, 26 & 29# N80 BTC. Set @ 9100'. Cmt w/ 500 sk. Surface — 4047': 23# 4047 — 7688': 26# 7688 — 9100': 29# PRODUCTION LINER: 5" 18# N80/P110 Hydril FJ. Set @ 11,198'. TOL @ 8881'. Cmt w/ 242 sk. Sqz liner top @ 9,025' w/ 150 sk & 9,010' w/ 100 sk. TUBING: 3 -'/2" 9.3# N80 8rd EUE @ 8857'. Total 287 Jts. PACKER: 7" Guiberson Uni- Packer VII @ 8788'. Set in 1980. PERFORATIONS: GN - GO: 9589 — 9619' GR -GS: 9917 — 9966' HC -HD: 10,231— 10,243' & 10,278 — 10,284' & 10,342 — 10,358' HK -HN: 10,692 — 10,742' 11N -HR: 10,770 — 10,820' & 10,878 — 10,964' HR -HZ: 10,986 — 11,036' & 11,083 — 11,096' TOP OF FILL: 11,082' (1991) BHST: 170 Deg F BHP: 4300 psi (SI WHP = 360 psi) SMALLEST ID: 2.75" ID X Nipple @ 8826' PRESENT STATUS: SI w/ 360 psi WHP & 910 psi Csg Press. OBJECTIVE: Pull tbg, acidize perfs and run new injection tbg. • AFE # 1200483 • 10.5 ppg Salt mud should kill the well with 360 psi SI WHP. The mud will be used from the C24 -23 workover. • There are possible holes in tbg (unknown depth). Therefore, NO attempt will be made to release & retrieve the 31 year old Guiberson packer. It will be milled out. • The GN -GR will NOT be acidized. 7 -19 -12 C: \temp \Temporary Internet Files \OLK86 \C24 -26RD CTI Procedure 7- 19- 12.doc III • • 2 Materials Rqd: • 7000 gal (6000 suz + 1000 pickle) Acid System to contain these additives: ➢ 10% HCL, ➢ 10% mutual solvent ➢ gpt Corrosion Inhibitor ➢ ppt Iron Reducing Agent ➢ 2 gpt Surfactant • 100 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 1,000 lbs Soda Ash (MI) • 30,000 lbs CaC12 (124 lbs/bbl FIW to build 10.5 ppg) Maintain MW from last well. • 60 gal WC1447WR Corrosion Inhibitor (Nalco) 7 -19 -12 CAtemp \Temporary Internet Files \OLK86\C24 -26RD CTI Procedure 7- 19- 12.doc • • 3 PROCEDURE: 1. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ pulling tool to GLM #8 @ 8751'. Latch & POOH the dummy valve. RD lubricator. 3. Mix 400 bbl 10.5 ppg CaC12 mud (Use from last job). RU mud pumps to tubing. Open the tbg annulus. Circulate to kill well from GLM #8. Take wellbore fluids to disposal well and recover /maintain the 10.0 ppg Salt mud. Check to make sure well is dead. 4. MI 11,400' 2 -7/8" 10.4# X95 drill pipe & 6 ea 3 -1/8" DC's. 5. Notify the AOGCC 48 hrs prior to the BOP test. Set BPV's and ND the WH. Install riser & NU BOP's. Pull BPV's & set double check valves. Ensure BOP has 3 -1/2" VPR pipe rams. Press test BOP's to 250 psi & 5000 psi. Send in WH to Cameron. New WH to have SS valves. 6. MIRU Pollard WL. RIH w/ tbg cutter & CCL. Cut the tbg @ 8778', 10' above the pac er. POOH' l j &RD WL. 7. RU slips & tongs for 3 -1/2" tbg. POOH & LD 3 -1/2" tbg while checking for NORM. Send tbg to onshore to be sold for scrap. Casing Cut for Csg Spool Removal: 8. MI 4 jts 7" 29# L80 BTC. 1 jt to have Guided Skirt welded by pin end (Olgnoonik). 9. RIH w/ HOWCO 7" 23# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 550 lbs (25') of sand on top of RBP. 10. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 11. ND BOP's. 12. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 13. NU new Cameron clamp x flange casing head. 14. NU BOP. 15. Press test the new clamp against the RBP to 3000 psi for 30 min. toe 7 -19 -12 C: \temp \Temporary Internet Files \OLK86\C24 -26RD CTI Procedure 7- 19- 12.doc ID • 4 16. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoffcasing at collar. POOH & LD ±3 jts csg. 17. RU Casing Crew. PU Guided Skirt jt followed w/ 3 reg jts of 7" 29# L80 BTC. Slip over collar from previous step & MU threads. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the new 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. p0 h< 1 . Notify the AOGCC 48 hrs prior to BOP test. NU BOP's. Set WH test plug in tbg spool. Press test BOP's to 250 psi & 5000 psi. Gaoir 19. RIH and wash off sand & retrieve the 7" RBP @ 500'. POOH & LD DP. a i 20. RIH w/ OS assembly & attempt to release the Guiberson packer. POOH & LD pkr. 21. If packer fails to release, RIH w/ 7" Packer milling BHA. RIH to top of pkr @ 8788'. Establish string weight. Mill packer per packer milling procedures. After the pkr falls, circ bottoms up w/ 20 bbl gel sweep followed w/ FIW. Push pkr to 5" TOL @ 8881'. POOH w/ mill. RIH with spear & grapple to retrieve the packer. POOH slowly w/ pkr & LD BHA. 22. RIH w/ 4 -1/8" bit, 51 jts DP (1580' minimum) & casing scraper for 5" 18 #. (Keep scraper above the top perf @ 9589'.) Cleanout fill to 11,160' PBTD. Minimize DP rotation w/ scraper. Circ 20 bbl gel sweep followed w/ FIW. POOH & LD bit & scraper. Contact the Midland office if problems are encountered in the perforated sections preventing settings for the RBP & Pkr in Step #27. 23. MI BJ w/ 7000 gal 10% HCL. Install pressure transducer on tbg annulus. RU PTS flowback tank. Put 10001bs soda ash in tank. 24. RIH w/ Halliburton 5" RBP & RTTS Pkr w/ by -pass. Set RBP @ ±11,130'. PUH 10' w/ pkr. ° 25. Press test acid lines to 7,000 psi. Spot 18 bbl 10 % HCL from 11,120' to 10,100'. PUH w/ p to ( 54 9473'. Set packer. Perform a "pre" MIT on the tbg annulus to 2100 psi for 30 min as per Step #36 to verify casing integrity. 26. RIH w/ pkr to 11,120'. Rev out acid to PTS tank w/ 10.5 ppg FIW until clean & PH is 6 -7. )'V27. � Est inj rate with FIW. Perform 3 stg acid job w/ 6000 gal acid @ ±2 BPM (PMAX = 6000 psi) as e follows: Stage Perfs Pkr Depth RBP Depth Acid Vol, bbl Flush, bbl 1 10878 -11096 10,860 11,130 62 60 2 10692 -10820 10,600 10,860 43 60 3 10231 -10358 10,130 10,400 14 55 Have Pkr by -pass open while acid is going DH. Close by -pass with acid ±10 bbl above pkr. Flush to be 10.5 ppg FIW. 7 -19 -12 C: \temp \Temporary Internet Files \OLK86\C24 -26RD CTI Procedure 7- 19- 12.doc i • 5 28. Acid equip to standby for pickle job on Step #32. Rel pkr. RIH & retrieve RBP. POOH & LD the tools & DP. 29. MI 900' 3 -1/2" 9.3# L80 +1% Cr 8rd EUE & 775' 2 -7/8" 6.5# L80 +1% Cr 8rd EUE tbg (incl 3% excess). 30. RIH w/ TIW 5" HB -BP Chrome Permanent Packer on 3 -1/2" x 2 -7/8" tbg and land as follows: Item Length, ft Top Bottom 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 300 304 3 -1/2" X Nipple (2.813" ID) 8rd 9Cr 1 304 305 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 305 309 3 -1/2" 9.3# L80 + 1% Cr 8rd EUE tbg 8,470 309 8,779 4' Pup Jt, 3 -1/2" 9.3# 1% Cr 8rd EUE 4 8,779 8,783 X -over 3 -1/2" 8rd Box X 2 -7/8" 8rd Pin 13Cr 1 8,783 8,784 2 -7/8" 6.5# L80 +1 %Cr 8rd EUE tbg 682 8,784 9,466 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,466 9,472 Anchor w/ Seals 8rd EUE (13Cr) 1 9,472 9,473 5" TIW HB -BP Permanent Packer (13 Cr) 4 9,473 9,477 10' Millout Extension (13 Cr) 10 9,477 9,487 X -Over MOE to 2 -7/8" 8rd (13 Cr) 1 9,487 9,488 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,488 9,494 2 -7/8" XN Nipple (2.205" ID) 8rd 9Cr 1 9,494 ✓ 9,495 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,495 9,499 2 -7/8" WL REG 1 9,499 9,500 31. Notify AOGCC 48 hours prior to MIT. 32. RU Acid Co w/ 1,000 gal 10% Acid. Press test all lines to 2,000 psi. Est circ down the tbg w/ FIW. Pickle the injection tbg with 500 gal acid @ 2 -3 BPM. Underdisplace the acid with FIW n SPI by 500' from the end of the the. Reverse circ the acid into the PTS flowback tank with the rig c pumps. Repeat a 2 pickle sweep with the remaining 500 gal of acid. Reverse out acid with the t1 X rig pumps until returns are clean. Pump spent acid into disposal well C44 -14RD & record all volumes injected. RD acid co. 33. Prior to setting the packer, fill the backside w/ packer fluid by reverse circ 280 bbl (inc130 bbl excess) packer fluid containing 60 gal Nalco WC1447WR in 280 bbl FIW. 34. PU landing jt. Space out & MU and land new SS tbg hanger. Run in new lock screws to energize hanger seal. 35. RU Slickline & press test lubricator to 4,000 psi. RIH w/ "N" test tool plug and seat on XN nipple @ 9494'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Con't to press up to ±3,500 psi t set packer. Hold a 4,000 psi press test on the tbg for 15 min. Bleed off the tbg press. 7 -19 -12 C: \temp \Temporary Internet Files \OLK86\C24 -26RD CTI Procedure 7- 19- 12.doc ID sa 6 36. Perform the MIT on the tbg annulus with s. With the 5" Packer set @ 9473' MD, press test the annulus to 2100 psi (8156' TVD x 0.25 = 2043 psi) and hold for 30 minutes. 37. POOH w/ test tool. RD Slickline. 38. Set BPV. ND BOP's & riser. NU new SS WH & pull BPV. Set 2 way check & test WH to 5,000 psi. Pull out 2 way check. Release Rig. PWOI. Paul Figel &1 ( 1- Engineering Manager ,w i rJA J 1 k f 7 -19 -12 CAtemp \Temporary Internet Files \OLK86\C24 -26RD CTI Procedure 7- 19- 12.doc • • PLF 7 19 12 X T0 ERGY PROPOSED MGS C24 -26RD ■ • Water 5 Depth: 73' MSL Cook Inlet, Alaska Leg 1, Conductor 4 API No: 50- 733 - 20078 -01 Tbg: 3 -W 9.3# L80 + 1% Cr 8rd EUE @ 8779' Spud: 1/18/68 Original Well 2 -7/8" 6.5# L80 +1% Cr 8rd EUE @ 9500' Sidetrack RD: 10 -2 -79 �j Set: �f l, 4' Pup Jt3Y2 "9.3 #1 %Cr8rd EUE @ 300' Surf Csg: 10 3/4" 40.5# J55 BTC. 3 -'/" X Nipple (2.813" ID) 8rd 9 Cr @ 304' Set @ 1,875'. Cmt w/ 1,550 sk. 4' Pup Jt 3- 9.3# 1% Cr 8rd EUE @ 305' Top Job w/ 100 sk. Tot cmt: 1,650 sk ±273 jts 3 -'/" 9.3# 1% Cr 8rd EUE 4' Pup Jt3- % "9.3 #1 %Cr 8rd EUE @8779' X-over 3.5" 8rd Box X 2 -7/8" 8rd Pin 13Cr @8783' 22 jts 2 -7/8" 6.5# 1% Cr 8rd EUE 6' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 9466' Anchor w/ Seals 8rd (13 Cr) @ 9472' 5" TIW HB -PB Perm Pkr (13 Cr) @ 9473' 10' MOE (13 Cr) @ 9477' X -Over MOE to 2 -7/8" 8rd (13 Cr) @ 9487' 6' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 9488' 2 -7/8" XN Nipple (2.205" ID) 8rd 9 Cr @ 9494' Intermediate Csg: 7" 23 -29# N80 BTC. 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 9495' Set @ 9,100'. Cmt w/ 500 sk. � , WL REG @ 9500' Surf - 4,047' : 23# 4,047 - 7,688' : 26# 7,688 - 9,100' : 29# S z 2 @ 9,010' w/ 100 sk. r Sgz1 @ 9,025' w/ 150 sk. et 41 5 Z GN -GO: 9,589 - 9,619' GR -GS: 9,917 - 9,966' Prod Liner: 5" 18# N80/P110 Hydril FJ. Y Set @ 11,198'. TOL @ 8,881'. HC HD: 10,231 - 10,243' Cmt w/ 242 sk. TOC @ 9,370' !� HC -HD: 10,278 - 10,284' HC -HD: 10,342 - 10,358' HK -HN: 10,692 - 10,742' HN -HR: 10,770 - 10,820' HN -HR: 10,878 - 10,964' HR -HZ: 10,986 - 11,036' HR -HZ: 11,083 - 11,096' TD: 11,160 11 ,216' M D (9 (9,640' ND) TD: 11,216' MD (9,686' TVD) % / / /�/ • • TO WELL SI '92 PLF 8 -10 -04 ENERGY Current Completion MGS C24 -26RD KB: 35' Cook Inlet, Alaska f r Water Depth: 73' MSL Leg 1, Conductor 4 API No: 50 -733- 20078 -01 /, // Tbg: 3 1/2" 9.3# N80 EUE 8rd @ 8,857'. Spud: 1/18/68 Original Well «!, Total 287 Jts. Set on 1 -3 -80. Sidetrack RD: 10 -2 -79 p /!✓ Surf Csg: 10 3/4" 40.5# J55 BTC. Ite MD TVD Psc Port Set@ 1,875'. Cmt w/ 1,550 sk. ■ #1 2,229 2,079 12 Top Job w/ 100 sk. Tot cmt: 1,650 sk BM #2 4,304 3,753 12 KBM #3 5,803 4,344 16 KBM #4 6,963 6,004 Orifice 24 Holes in tbg. KBM #5 7,728 6,646 Dummy KBM #6 8,342 7,171 Dummy KBM #7 8,684 7,462 Dummy .- "', KBM #8 8,751 7,519 Dummy ofr Otis Ball SSSV @ 314' 7" Guiberson UniPkr VII @ 8,788' 4 1 Jt 3 1/2" 9.3# N80 EUE 8rd @ 8,796' Intermediate Csg: 7" 23 -29# N80 BTC. 3 1/2" X Nipple (2.75 ID) @ 8,826' ■ Set @ 9,100'. Cmt w/ 500 sk. �'. 1 Jt 3 1/2" 9.3# N80 EUE 8rd Surf 4,047' : 23# 3 1/2" Shear Sub w/ Mule Shoe Guide @ 8,857' 4,047 - 7,688' : 26 # 7,688 - 9,100' : 29# yy M. 7,688 ----- >260 Sqz 2 @9,010' /100sk. / . Sqz 1 @ 9,02 w/ 150 sk. A* EAV Fil ii t4 GN -GO: 9,589 - 9,619' Prod Liner: 5" 1'# N80/P110 Hydril FJ. GR -GS: 9,917 - 9,966' Set @ 11,198'. TOL @ 8,881'. _. -" Cmt w/ 242 s TOC @ 9,370' HC -HD: 10,231 - 10,243' r% HC -HD: 10,278 - 10,284' HC -HD: 10,342 - 10,358' HK -HN: 10,692 - 10,742' HN -HR: 10,770 - 10,820' , W p HN -HR: 10,878 - 10,964' HR -HZ: 10,986 - 11,036' HR -HZ: 11,083 - 11,096' Top of Fill @ 11,082' y PBTD: 11,160 MD (9,640' TVD) • TD: 11,216' MD (9,686' TVD) � „ *��' • • PLF 4 -6 -12 /T0 ERGY PROPOSED MGS C24 -26RD ,i / KB: 35' Water Depth: 73' MSL Cook Inlet, Alaska Leg 1, Conductor 4 y% i API No: 50 -733- 20078 -01 ° Tbg: 3- 9.3# L80 + 1% Cr 8rd EUE @ 8777' Spud: 1/18/68 Original Well y �' 2 -7/8" 6.5# L80 +1% Cr 8rd EUE @ 9000' ` � %� Sidetrack RD: 10 -2 -79 Set: 7 \ 4' Pup Jt 3 -' /z" 9.3# 1% Cr 8rd EUE @ 300' Surf Csg: 10 3/4" 40.5# J55 BTC. 3 -W X Nipple (2.813" ID) 8rd 9 Cr @ 304' Set @ 1,875'. Cmt w/ 1,550 sk. 4' Pup Jt 3 -W 9.3# 1% Cr 8rd EUE @ 305' Top Job w/ 100 sk. Tot cmt: 1,650 sk ±272 jts 3 -Y2" 9.3# 1% Cr 8rd EUE 4' Pup Jt3Y "9.3 #1 %Cr 8rd EUE @8739' V 3 -W X Nipple (2.813" ID) 8rd 9 Cr @ 8743' ♦ I . � . up Jt 3 -%" 9.3# 1% Cr 8rd EUE @ 8744' Anchor w/ Seals 8rd (13 Cr) @ 8750' W HB -PB Pe Cr) @ 8751' ! , 167'; ' X3_-1/20,v, MOE(13Cr) @8755' 3 'h 8rd Cr) :8 "� %�� ' I 6' Pup "9.3 # 1 % Pkr Cr8rd EU@8766' er XN MOE Nipple to (2.666 " ID ) 8rd 9 72' , y, 4' PupJt3- % "9.3 #1 %Cr8rdEUE @8773' Intermediate Csg: 7" 23 -29# N80 BTC. / % X -over 3 -" 8rd Box X 2 -7/8' 8rd Pin 13 Cr Set @ 9,100'. Cmt w/ 500 sk. 49, ; Surf - 4,047' : 23# ' jts 2-7/8" 6.5# 1% Cr 8rd EUE ' 7 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 8995' 4,047 - 7,688' : 26 #'' WL REG @ 9000' 7,688 - 9,100' : 29# /� % I tO � F i 7 ttilPER 7 qz29,o1pw /100sk. y D Sgz1 @9,6- /5'w /150 sk. ,- / Z =2. GN -GO: 9,589 - 9,619' Prod Liner: 5 18# N80/P110 Hydril FJ. GR -GS: 9,917 - 9,966' Set @ 11,1 8'. TOL @ 8,881'. c _ x HC HD: 10,231 10,243' Cmt w/ 24 sk. TOC @ 9,370'' HC -HD: 10,278 - 10,284' A HC -HD: 10,342 - 10,358' 7 HK -HN: 10,692 - 10,742' ,:..; 1/ '�""-- HN -HR: 10,770 - 10,820' 0/y" j HN -HR: 10,878 - 10,964' HR -HZ: 10,986 - 11,036' ,00 HR -HZ: 11,083 - 11,096' PBTD: 11,160 MD (9,640' TVD) e TD: 11,216' MD (9,686' TVD) / , • • e i CAMERON XTO PLATFORM C Well 24 -26 Equipment EXISTING EQUIPMENT 7 -6 -12 t` V' Block Tree - with Integral and additional Pneumatic SSV Wing / 3 -1/8 API 5K Run with 2 -1/16 API 5K Wing !�v Valve on wing use R -24 Ring Gaskets Tubing Hanger has 3 "Type H BPV Profile 1 rmt r � I 00 II laMi — 1 r UR Pneumatic O®0 ' - SSV '"eD© 4/ C ) �Y 7 �� BF , 8' !r 0 Mr O U ` o R -54 • II O • Pneumatic I , i '_ 5' 10 o L , Lowermost Casing Head �---' 11" 3K ( #9 Clamp) Hub x 11 API 5K Hub Top R -53 MODIFIED Ring Gasket Bottom 3.11 •I 2 -1/16 API 5K 4' 4" R -53 Ring Gasket Top it R -24 Ring Gasket Annulus Outlets are 2 -1/16 API 5K —� `" R -24 Ring Gasket ('' Rri I ? / - I II � °i 3' �� 2' 2„ 0 R -53 MODIFIED , 0 • • fe CAMERON XTO PLATFORM C Well 24 -26 INJECTOR REPLACEMENT EQUIPMENT , 2012 �+ Well currently has a Cameron Type D Compact Wellhead Existing 7" Casing will be cut to allow removal of the D Compact Housing. A new Casing Housing will be installed, the 7" tied back and a new Tubing Spool installed. We will also replace the Tubing Hanger, Adapter and Tree Ls *Equipment to be configured as shown Trees configured the same as existing m-u, equipment currently on Wells per photographs un un OO � o J Replacement 11: (f 2 -9/16 5000 Tree � With 2 -1/16 5K Wing : 2 -1/16 5000 Wing HWO Pressure Side to Injection o mm C) C) \ o 81 C) @- J Replacement Tubing Head Adapter 7 -1/16 x 2 -9/16 Stainless Adapter ,. ili „ Replacement Tubing Hanger PN UNKNOWN __ 7 x 2 -7/8 EUE 8rd Stainless PN UNKNOWN fill II III Replacement Tubing Spool I I , o ■IIII'� t . CAMERON N 11 "5K x 7 -1/16 5K Top III_ o , , Replacement Secondary Seal PN Unknown PN UNKNOWN NX Bottom Prep � 11•� Mill - Yj U-W Replacement Slips Replacement Casing Head ENS kJ '" PN UNKNOWN PN UNKNOWN %—�� II NI V $ i • • 5/23/2012 13.625 BOP Schematic.xls XTO - ENERGY KB Elevation • Date: 5/23/2012 "Rig Floor" Flow Flow line Nipple r ElLILECILIIILEH Hydril 13 5/8" 5m 13 5/8" 5m Annular double ram preventer [TT inn mme Ill C) C> A ■ _ 13 5/8" 5m Cameron i I I 1 Pipe rams I ■ • S. ��. • c1 () PI 13 5/8" 5m Cameron i 1= Blind Rams is.. i n II n n m tlI_II •:•`I :: fit . : 1 IUI 2 1/16" Kill Line 3 1/8 "Choke Line 111 11 11 I11 11 MI 2 1/16" 3 1/8" 3 1/8" 5m 5m 5m Hydraulic Manual Manual Valve Valves valve 13 5/8 5m riser 135/8 "5m Iwiuiw Mud Cross with 3 1/8" outlets Page 1 • 0 ri-1 . A 0 R C . / •`N` C41 -26 J I ) C22 6 il ;11 -26 C22 -26RD C22A -26 C33 -26 C23 -26 1 /4 mile II C24 -26RD C34 -26 C24 -26 C -LINE XTO Energy Alaska Project D - 8 D 9 Location Base Map 1/4 Mile Radius Assessment 11-8R 1 Around Proposed Injection Well C24 -26RD D -9 D 0 015 031 MILES // _4 POSTED WELL DATA • Well Name WELL SYMBOLS • Oil Well Dry Hole • Plugged and Abandoned D- T &A'd or SI Injector D 2R , Shut In 011 and Gas P &A Water Injector -2 By. JMKwolek '. r July 30. 2012 p5100 7,30,2012 9 14 25 MA • . a Offset Weilbores to C24 -26RD (Convert to Injection) Auaust 7.2012 C -line Well: • Completed 1969 • Perfs: GR -HR: 10,561- 11,624' MD • CBL TOG Cd.► 10.470' (SLB CBL 3 -9 -69) • P &A for C -Line in 1990. Well was redrilled & renamed as C22A -26 in 1990. Cement Retainer, Ft Size Cement Below Tool Cement Above Tool Comments 10,850' 7" 160 sk ft3t1 9 -bits" SK bU VVbffV flVa araia ff - JV AID rate below tool. 1800' 9 -5/8" Cut & Pulled 9 -5/8" 1Inn' 1679' 13 -3/8" 60 sk 60 sk 600' I 13 I JJL i( C24 -26 Well: • Completed 1968 • Perfs: GR -HZ: 9976 — 11,280' MD • CBL: According to the Well file, SLB ran CBL 3 -3-68 but XTO cannot find a cODV of the Loo. The DOR states that cement circulated on the 5" liner. The 5" TOL is © 9713' & cement was tagged @ 9190' in th 7° 1►±t . i to • P &A for C24 -26 in 1979. Well was redrilled & renamed C24 -26RD in 1979. ➢ 9- 28 -79: RU to P&A C24-26 for C24 -26RD. Shell was not able to release the too Prod °kr,(c 9564'. Cut tbg @ 9491' & tried jarring on fish for 8 days. As per conversation w/ AOGCC on 10- 8-79 (See Attached), the state allowed the setting a cement retainer @ 9485'. Once the retainer was se t a n-iniection rate . could not be established. therefore. a 50 sk cement alua was set on top of the retainer. The cement plug was tagged @ 9190' and cleaned out to 9350'. The window for the C24 -26RD was milled (cD - 9300', C :\tenro \Temoorary Internet FileAOLK86 \Offset- W-- ellboresto C24- 26RD4oc • • C24 -26RD Well: • Completed 1980 • Perfs: GN -HZ: 9589 — 11,096' MD • CBI.: TOC (a7 9350' but poor bond from 8881' (5" TOLL to 9350' (SLB CBL 12- 12 -791 Shot oerfs a� 9025' & sqz'd 150 sk. Shot perfs @ 9010' & sqz'd 100 sk. Press test sqz's to 2000 psi. • Status — Shut -in Producer since 1992 with plans to Convert to Iniection to support well C34 -26. C34 -26 Well: • Completed 1968 • Perfs: GR -HR: 9919 — 11,000' MD • CBL: TOC ( 7900' (SLB CBL 4- 14-68) • Status: Shut -in producer since 1988. Submitting Sundry to return well to production in conjunction with converting C24 -26RD to iniection. Paul Figel Enoineerino Manager CAternp\Temnorary Internet Files \OLKR6lOffset W 4Ihnres try C24- 2SRarinr. f • Form 10-403 t Submit "Intentions" In Triplicate REV. 1-10-73 & "Subsequent Reports" In Duplicate .. STATE OF ALASKA 5. API NUMERICAL Copy OIL AND GAS CONSERVATION COMMITTEE 50- 133 -20078 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS ADL 18756 (0o not use this Corm for proposals to drill Or t0 deepen Use "APPLICATION FOR PERMIT—" for such proposals.) 1 ' OIL n GAS 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL WELL OTHER None 2. NAME OF OPERATOR S. UNIT, FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 601 West 5th Avenue, Suite 810, Anchorage, Alaska C -24 -26 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Atsurface Platform "C" Leg 1, Conductor 4, or 4739.0'S MGS "G" Pool and 1591.0'W of the NE Corner of Section 23, 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) T8N, R13W, SB &M Section 26, T8N, R13W, SB &fit 13. ELEVATIONS (Show whether DF, RT, GR, etc) 12. PERMIT NO. 105' D.F. (M.L.L.W.) 68 -3 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT -OFF PULL OR ALTER CASING WATER SHUT -OFF • REPAIRING WELL ...— FRACTURE TREAT MULTIPLE COMPLETE . —� FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIOIZE ABANDON' SHOOTING OR ACIDIZING ABANDONMENT' ^r REPAIR WELL CHANGE PLANS Ah (Other) • (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. Due to difficulty encountered during abandonment operations, well C- 24 -26, a change in plans has been necessary. Fishing operations attempting to recover production equipment-- below 9502' have been unsuccessful. Further fishing operations will jeopardize the existing useful portion of the hole, above 9502'. As per the 10 -8 -79 telephone conversation between Shell's Mr. M. L. Woodson and State of Alaska Oil and Gas Conser- vation Commissioner, Lonnie C. Smith, we plan to abandon the completion interval, well C -24 -26 as follows: 1. Set a cement retainer at 9485' above the fish. 2. Set a 200' cement plug from 9485'/9285'. 3. Polish the plug to 9350'. 4. Continue redrill operations as described in the "Permit to Drill or Deepen ", #79 -62, submitted 8- 29 -79, approved 9- 10 -79. 16. 1 hereby certify that the foregoing Is true and correct ' �s SiGNEDL / �� 4 dc TITLE ' r !!J . 7•744-6(‘-t. //�- -Q / i✓t G� yam7447• DATE . 74f (This space for State office use) APPROVED BY TITLE DATE CONDITIONS OF APPROVAL. IF ANY: See Instructions On Reverse Side • Page 1 of 3 I Schwartz, Guy L (DOA) From: Paul_Figel©xtoenergy.com Sent: Thursday, July 19, 2012 1:15 PM To: Schwartz, Guy L (DOA) Cc: Roby, David S (DOA); Ferguson, Victoria L (DOA); Michael_Griffith©xtoenergy.com; Maria_Perez @xtoenergy. corn Subject: Re: C24 -26RD RWO (PTD 179 -062) Attachments: C24 -26RD CBL.pdf; C 24 -26RD Current WH 7- 18- 12.PPT; C24 -26 WH Proposed for Injector.ppt; C24 -26 Photo.JPG; C24 -26RD CTI Procedure 7- 19- 12.doc; C24 -26RD Proposed WBD 7-19 - 12.doc; C24 -26RD Drilling Reports.pdf Guy, Here are the answers to your questions. I am only lacking the field map for the 1st part of #3. I should have that when I return from vacation on July 30th. 1) MASP: Last Prod prior to SI well in Feb '92: 500 BW + 30 BO : 94% Wtr cut (see plot) BHP = 4272 psi 28 °API oil = 0.3841 psi /ft 8.4 ppg FIW = 0.436 psi /ft Phyd = (0.06)(0.3841 psi /ft) + (0.94)(.436 psi /ft) = 0.432 psi /ft x 8958'(Midperf) = 3878 psi MASP: 4272 psi — 3878 psi 394 psi FAGS (E) C21 -26RD II IDDLE GROUND SHOAL EFG 8000 . _ {NG S I U C3•,zeFZO 6800 - ` CO_CI ■ CD _C CD_„plaaa 10 00 - Q raal_MC F i�V_A baba - �aai - { Y 6011 - 6 _NICFOAbaRa ..... — .______.... 10 0 fin 10 — fi 11188 110 111 114 Cu m Oil 328046.000 Date 2) With the MASP <3000 psi, the BOP should be NA. 7/19/2012 • Page 2 of 3 • 3) a)Waiting on Geologist for the Field Map. 3) b) CBL & Drilling reports from the time the 5" liner was set on 12 -10 -79 until press test passed after the 2nd sqz job on 12 -31 -79 : 4) WellHead: Let me know if this suffices or if I need to contact Cameron. 5) XTO will install a SSV on the WH as per new regulations. 6) New procedure with 5" packer set within 200' of perfs (please disregard procedure dated 7 -6 -12) : Please advise if there is something else. Thanks. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432- 553 -5217 Fax: 432 -687 -0862 "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov> To Paul_Figel@xtoenergy.com" <Paul_Figel@xtoenergy.com> cc "Ferguson, Victoria L (DOA)" <victoria.ferguson@alaska.gov >, "Roby, David S 07/18/2012 03:02 PM (DOA)" <dave.roby @alaska.gov> Subject C24 -26RD RWO (PTD 179 -062) Paul, I have a couple of comments and questions after going through the sundry application. 1) What is the actual MASP for the surface pressure? Please include calculations and your arguments for the gradient used. 2) I am not familiar with the BOP waiver (2 ram) you are citing. Can you provide documentation? 3) Since you are converting to an Injector an Area of Review is needed.( % mile assessment of all welibores around the proposed injection well / Spider map of area etc..) Also , per 20 AAC 25.402 you must prove the mechanical integrity of the wellbore C24 -36 and an assessment of the cement bond.( Please provide a overview of the cement quality of the 5 " liner and 7" casing using the drilling cement reports and CBL logs. ) 4) Do you have more detail drawings showing how the existing 10 %" surface casing is attached to the new 7/19/2012 Page 3 of 3 • wellhead. I'm not sure how this all ties into the new wellhead and 7" casing hanger. 5) The new production tree doesn't show a SSV (surface safety valve) ... is there one planned? 6) Packer depth is proposed at 8750' md. This is more than 200' from the proposed injection zone as required by 20 AAC 25.412 (b) Is there any reason not to move it closer to the perfed injection interval (ie inside the 5" liner) ? Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 7/19/2012 o u T 13 a.v ,- n -4 f , m v ? -a -0 a - am - ... . o:m a . e • 3Z' ' o a- 5- z s m ; n Field or F.":1 n S, gym, m 9 $ 5 1 (7x2 I I o • 'P 'm LOCATION MIDD_E GROUND 5. • e ER m 3 n to m> n 0 m c' 9 WELL MI OD_E GROUND SHOAL 3 -i 3 . nm mi a2 9r C 24 - REDRI'' -L CO • G 3. a n• m o ll o SI C a -c COMPANY SHELL OIL COMPANY VP , �t n .t n t^ -.4 m o x n to ° O m m 0 1 Ln E -' - 000 N '11 c - : . u1 ii -4 ti -- m Z cT,• _ 00'•x.1 —• l., z c.. , x m A - ,a * a'vs O N 3 i a. :� :.-.t t D ¢'_ 7 lP -i u' v Z O O m m.o.:, :1 * - O 'O D D 4 1' c:•- v m .,, — r tm "FY t- G.,1 y 0 1 ,m m V o T a -n ° z ° _ n n 0 o.:r ^ m u au r- O 0 ro + a C 0 0 rn '- 0 0 n a 3 - x 5 g o • g 0 z Z 0 r'r't 0 -IT. a m 2 g.c 0 0 Z y 3 K m . i 0 o v p m a , 3. z , - m N N N ). _ = re" D � m c ue o o- m m la o o z = 'c D t>� .< F -. ro 3 0 - r.1 m a a Op __I a a Q. L v c ,_ <' 0 0 D r' r- T P. c v m n OCJ an t= C 7 o In n_ I w .D 1 'tl r- ' t (�, r-y-t .- m C 0 D aa..t C— rn D 1 .Z - 0 "i -- L . N r - Jl - - -n o z GI ,n o 1 - z < s r� ro \ Co') O V! D 0 •• - it 1.,- � —1 - 0> Vf 0O � r , m 7 .0 �} -c 1 -- Tm D rt O O 5 .-. Lo ' corn r m - m - Li 3 Et 0 t .- o' 0 0 . I' 0 0 O ^ — an '- 0 0 3 .., _ rata MERE The well name, location and borehole reference dol. were furnished by the customer. PRIMARY CEMENTING DATA REMARK& CASING C0__ARS RECORDED 25' DEER. RJL_ED TIGHT ❑Actual ❑Estimated Hour -pate 9244' , 10395' , AND 104 LEG . LOCATION- CORD Y EG 1 .• 10.8'5 L 5.7 E FROM CENTER LEG 1 5 5416.5,.'N TO 1596,41' Started pumping cement r; FROM SE CORNER Release pressure ' Service Order Number Start Cement Bond Lag Coiling Collar Memory Ofetan. ft. Finish Cement Bond Log Radiation Log Memory Distance ft. Preceding fluid Volume bbls. Pipe reciprocated during Pumping, Ye. Nn Cement pumperl bbls. /minute Pipe reciprocated after plug downs Yes min, N. SQUEEZE JOB DETAIL DOWNHOLE EQUIPMENT SURFACE EQUIPMENT TYPE MOD. S.N. Squeeze number 1 2 R ; - Sonic Panel 822 ' Date CCL Memorizer 45': Depth interval 7 5 C�NP A type cement % ^ SGT CRP 11 I4 Volume of cement OWE Additive 1' - Retarder CCL CME Weight of slurry 8 CRP Intensity . 2 Preceding fluid 260 SLC R9G Intensity 7.5 - Breakdown pressure Logging Speed 30 CME Time Constant 2 Max. pressure -stage 1 Sweep Time ft-sec 1000 " 2 T Amplitude my /cm 100 - le a 3 CME 1586 Final moximum pressure 1 R SLS Casing Centralizer Pattern Joint from to Started pumping cement 167 R Joint from to Released pressure Joint from to Start CBL > CME Casing Scratcher Pattern Finish CBI Joint from to AVERAGE WELL DRIFT: - g e l Fa.O.D. 0 s" Joint from to ° • 1 1. . ° no to Joi 1 • u — to A' ntrprdat .m an ep .ter, "!" an le re e.s icam odrleal ar 0111.. memareuemt On we unmet, on ar ew•••■•• =ms ° carrodnos . any into. prelollens, and we sited not, except in the case of gross or willful negligence on our port, be liable or opondlde for arty fors. m de a , moon earnest's tecud I swtalned by any.. rouhing from any Inierpnfo11on mode by env of ow geirary ggana or employe., Them itnerpretotiont are oho subled w Claus. 4 of ace General Tuna and Conditions at wt eel in au current Price Schedule. 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' Alrz . 1+� 1401,_:: ... lr' ! S,!∎: _.. '"r.'.'1.:Y`.,.' Al f " �'IWM c.. 1� - ' J ... 11- -� : ,. QD —i gpt - �c, 2 1-1 (_' SEAN PARNELL, GOVERNOR ttT t Ai/t/ar►t7srHA t®� 1L � GAS (� 333 W. 7th AVENUE, SUITE 100 CONSEl�VAT`IGNT COA> USS116Y l ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 December 16, 2009 Dale Pittman Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Acquisition of XTO Energy, Inc. Dear Mr. Pittman: Congratulations on your acquisition of XTO Energy, Inc. Attached please find information on three XTO-operated wells in Alaska. The Alaska Oil and Gas Conservation Commission requests that you confirm or update the wells' status and plans. (2) Enclosures Sincerely, /14C-e-4� Cathy. . Foerster Commissioner L.ENERGY July 27, 2009 Ms. Cathy P. Foerster, Commissioner State of Alaska Oil & Gas Conservation Commission 333 W. 7t" Ave, Suite 100 Anchorage, AK 99501 Re: Request for Information — Status of Oil and Gas Wells Dear Ms. Foerster: JUL u 1 2009 �?E�.v} i[ 9N `u� vi:: Crons. •Qi�iiT!ISsir.. �C XTO Energy Inc. (XTO) has received a request dated June 22, 2009, pursuant to 20 AAC 25.300, requesting information about the status of three wells located in the Middle Ground Shoal field of Cook Inlet, which is operated by XTO. Commission records indicating that these wells (A42-14, C24-26RD, C34-26) have been inactive for five years or longer are correct. The A42-14 (167-014) has been inactive since September 1998 when it produced 6 bopd & 294 bwpd. The well was shut-in in October 1998 because it was no longer economic to produce. Since that time it has remained shut-in with production tubing and packers installed in the well. XTO has plans to utilize this wellbore for an east flank sidetrack when economic and budget conditions are sufficient to justify re -activating the drilling rig on Platform A. The C24-26RD (179-062) has been inactive since May 1992 when it produced 24 bopd & 660 bwpd. The well had been active intermittently from 1988 until it was shut-in in May 1992 due to the high water cut. Since that time the well has remained shut-in with production tubing and packers installed in the well. XTO is evaluating this wellbore for its use in drilling a sidetrack well targeting additional reserves in the west flank. The timing of future work will be determined by economic and budget conditions. The C34-26 (168-019) has been inactive since November 1988 when it produced 10 bopd & 80 bwpd. The well was shut-in due to uneconomic production. The production tubing and packers remain installed in the well. XTO is currently evaluating the potential of returning this well to production in the current configuration. In the event that this attempt is not feasible or is uneconomic, the well will likely be suspended during a future drilling program when the rig is available. Should you have any further questions or need additional information you can contact me at 432-620- 6742 or jeff gasch@xtoenergy.com. SWce Jh Operations Engineer XTO Energy Inc. XTO Energy Inc. - 200 North Loraine, Suite 800 - Midland, Texas 79701 - (432) 682-8873 - Fax (432) 687-0862 �� t� Lit' SARAH PALIN, GOVERNOR Li. LF7 T�^c�;� AIARKL Q1 L AND GA / 333 W. 7th AVENUE, SUITE 100 ANCHC1311IT19, LIN71�'!" CIN COME"t�91EG 7 PHONE � 907)279-14339501-3539 FAX (907)276-7542 June 22, 2009 Kyle Hammond Vice President XTO Energy Inc. 200 North Loraine, Suite 800 Midland, Texas 79701 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Hammond: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by XTO Energy Inc. have been inactive for five years or longer. If, for any listed well, XTO Energy Inc. believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i. e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, XTO Energy Inc. agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve XTO Energy Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertr(balaska.go_v. Sincerely, 4hyyFoerster Commissioner Enclosure E;,To GY July 27, 2009 Ms. Cathy P. Foerster, Commissioner State of Alaska Oil & Gas Conservation Commission 333 W. 7`" Ave, Suite 100 Anchorage, AK 99501 Re: Request for Information — Status of Oil and Gas Wells Dear Ms. Foerster: k`1 0('- o CO -2- JUL 3 1 2009 Afss@ao Oi€ G&S C051s. cemrllissi � l XTO Energy Inc. (XTO) has received a request dated June 22, 2009, pursuant to 20 AAC 25.300, requesting information about the status of three wells located in the Middle Ground Shoal field of Cook Inlet, which is operated by XTO. Commission records indicating that these wells (A42-14, C24-26RD, C34-26) have been inactive for five years or longer are correct. The A42-14 (167-014) has been inactive since September 1998 when it produced 6 bopd & 294 bwpd. The well was shut-in in October 1998 because it was no longer economic to produce. Since that time it has remained shut-in with production tubing and packers installed in the well. XTO has plans to utilize this wellbore for an east flank sidetrack when economic and budget conditions are sufficient to justify re -activating the drilling rig on Platform A. The C24-26RD (179-062) has been inactive since May 1992 when it produced 24 bopd & 660 bwpd. The well had been active intermittently from 1988 until it was shut-in in May 1992 due to the high water cut. Since that time the well has remained shut-in with production tubing and packers installed in the well. XTO is evaluating this wellbore for its use in drilling a sidetrack well targeting additional reserves in the west flank. The timing of future work will be determined by economic and budget conditions. The C34-26 (168-019) has been inactive since November 1988 when it produced 10 bopd & 80 bwpd. The well was shut-in due to uneconomic production. The production tubing and packers remain installed in the well. XTO is currently evaluating the potential of returning this well to production in the current configuration. In the event that this attempt is not feasible or is uneconomic, the well will likely be suspended during a future drilling program when the rig is available. Should you have any further questions or need additional information you can contact me at 432-620- 6742 or Jeff gasch@xtoenergy.com. Sincer SWNELI J f asch Operations Engineer XTO Energy Inc. XTO Energy Inc. • 200 North Loraine, Suite 800 • Midland, Texas 79701 • (432) 682-8873 • Fax (432) 687-0862 AYASKA ®IL AND G June 22, 2009 Kyle Hammond Vice President SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 XTO Energy Inc. 200 North Loraine, Suite 800 �1 Midland, Texas 79701 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Hammond: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by XTO Energy Inc. have been inactive for five years or longer. If, for any listed well, XTO Energy Inc. believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i. e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, XTO Energy Inc. agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve XTO Energy Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(�alaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Permit No. Well Name XTO Energy Inc. 167-014 MGS A42-14 XTO Energy Inc. 179-062 MGS C24-26RD XTO Energy Inc. 168-019 MGS C34-26 Shell Western E&P Inc. [{ I G IN A L ~ 601 West F~fth Avenue · Suite 800 Anchorage, Alaska 99501 December 16, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C24-26RD Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C24-26RD. The operations were completed on October 13, 1991. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, R. G. Blackburn Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~121691E.WP5 RECEIV£D DEC 2 0 Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA COMMI~( N AIL~ .A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATI 6 IN A I. 1 Operations pedormed: operation shutdown __ Stimulate X Plugging__ Perforate X Pull tubing __ Alter casing__ Repar well __ Other 5. lype of Well: 2 Name of Operator Shell Western E&P Inc. Developmenl X Exploratory 3 Address 601 West 5th Avenue, Suite 800 Anchorage, Strat~graphic AK 99501 Service ~4. Location of well at surface Platform C, Leg 1, Conductor 4, 541'N and 1591'~/from SE Corner of Sec. 23, T8N, R13W, SM At top of productive interval At effective depth At total depth (.q~J587' (8258'TVD) 3786'$ and 2695'W from SE Comer of Sec. 23, T8N, R13W, SM @11,216' (9686"FVD), 4560'S and 2791'W from SE Corner of Sec. 23, T8N, R13W, SM 6. Datum elevation (DF or KB) 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C24-26RD 9. Permit number/approval number 79-0062/91-302 10. APl number 50-733-20078-01 11. Field/Pool MGS/"E,F, & G" Pools 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 11,216 feet Plugs (measured) 9686 feet 11,160 feet Junk (measured) 9614 feet Size Cemented Measured depth True vertical depth 1875' 10-3/4",40.5#,J-55 1550 sx 1875' 1782' 9100' 7",26-29#,N-80 500 sx 9100° 7823' 2317' 5",18~,N-80 242 sx 8881 '-11,198' 7633-9672 Perforation depth: measured 9587-11,096'(11Intervals) RECEIVED true vertical 8259'-9671' Tubing (size, grade, and measured depth) 3-1/2",9.3#,N-80 EUE 8rd @ 8858' DEC 2 0 99! Packers and SSSV (type and measured depth) Guiberson Unipacker @ 8788', Otis SSSV @"~liz~~ka 0il & Gas Cons. Commiss' Anchorage 13 Stimulation or cement squeeze summary Intervals treated (measured) 8665'- 11,080' Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 149 bbls. Squeeze ISIP = 1850 psi. 14 Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15 0 229 810 80 25 ¢'~ 0 589 950 110 15 Attachments 16. Status of well classification as: Copies of Logs and Surveys run Oil X Gas Suspended__ Service Daily Report of Well Operations ~ -- -- '~17 I hereby certity that the torego~ng ~s true an J correct to the best ot my Knowledge S,gned~---(2¢4-~'-~2'~ Title ~3-3~AFF ~;~iZoO,.,.c.~,,:,,~ '~4~,,,u.,:~...~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DAILY REPORT WELL: C24-26RD DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs today) 08/28/91 - SKID RIG OVER WELL AND ARRANGE HATCH COVERS FOR ACCESS. - SET WESTERN ATLAS UNIT AND SHELL SLICKLINE UNIT. RUN IN HOLE WITH SLICKLINE AND RETRIEVE BALL VALVE AT 307'. RUN IN HOLE WITH 2.70 GAUGE RING TO 10,000'. NO OBSTRUCTIONS. 08/29/91 - PERFORATE GN-GO/GR-GS WITH 2 5/8" JUMBO JET SCALLOP GUNS. 4 JSPF 0 DEGREE PHASING. - RUN NO. 1 9964-9945 19' 2 9946-9915 31' 3 9617-9587 30' 80' TOTAL - PUT WELL IN TEST, RIG DOWN WESTERN ATLAS AND MOVE RIG TO C34-23. 10/13/91 - COIL TUBING OPERATION ASSIGNED TO THIS WELL @ 1200 hrs 10/12/91. - PRODUCTION DEPT BLED DOWN CSG PRESSURE AND FLOODED CSG WITH FIW PRIOR TO RIG UP. - PRESSURE TEST LUBRICATOR AND SYSTEM PIPING. - RIH W/2.5" 3 LOBE MILL, 2.0625" PDM & DBLCV. TAG BRIDGE @ 9,900' - 9,904'. - TAG & MILL BRIDGE @ 10,702 - 706'. MILL 4' BRIDGE. SUSPECT "HN" INTERVAL MAY BE GENERATING SCALE. NO SIGNIFICANT SCALE OBSERVED IMMEDIATELY BELOW THIS POINT. CONTINUE RIH. - WASH DOWN TO 10,800'. OBSERVE TUBING WEIGHT INCREASE ON SCHEDULED PICKUP. WORK TUBING, PUMP 5 bbl SWEEP AND HOIST INTO TAILPIPE TO CONFIRM NO WIRELINE SNARE. ASSUME PROBLEM IS DRAG INCREASE DUE TO DOG LEG SEVERITY IN KICKOFF AREA @ 8,900'. - WORK COIL TUBING TO REDUCE INCREASED DRAG. PUMP 5 bbl POLYMER SWEEP WITH HOWCO FRICTION REDUCER. - ENCOUNTER HARD PACK MILLING @ 11,066' @ < 2 fph. POH DUE TO LOW P-RATE & HIGH DRAG CONDITIONS. - POH WITH MILL & PDM ASSEMBLY AT REPORT TIME. 10/14/91 - POH W/MILL & PDM ASSEMBLY. - PRESSURE TEST BOPE. RIH W/2.5" SWIRL JW NOZZLE & DBLCV. R ¢EIVED DEC 1991 Ala~ 0il & Gas Cons. Commission Anchorage ( D&ILY REPORT WELL: C24-2 6RD 10/14/91 - MONITOR DRAG WHILE RIH. TAG HARD BOTTOM @ (CONTID) 11,082'. WORK CT & JET WASH, NO PROGRESS. OBSERVE OVERPULL, SUSPECT OBJECT IS PERF GUN OR WL TOOL. WITHDRAW NOZZLE FROM AREA TO AVOID BECOMING STUCK IN 5" LINER. - PUMP 37.6 bbls 7.5% HCL FOR 30 min ACID SOAK OF PERFORATED INTERVAL FROM 11,080' TO 8,665'. CHASE WITH 5 bbl POLYMER SWEEP, DISPLACE 32 bbls OF HCL CONTAMINATED RETURN FLUIDS TO DECK SURGE TANK. NO SIGNIFICANT H2S RECORDED IN RETURNS. - JET ACID WASH PERFORATED INTERVAL F/10,231' T/11,077 @ 1 bpm, 20 fpm WITH 44 bbls 7.5% HCL SOLUTION. - PUMP 5 bbl POLYMER GEL SWEEP TO DISPLACE ACID. CAPTURE HCL CONTAMINATED FLUIDS TO DECK SURGE TANK. - RUN PRESSURE INTEGRITY & INJECTIVITY TEST. CSG STABLE @ 505#. INJECTING @ 1650# 50 gpm, TEST VOL OF 15 bbls FIW. TEST GOOD. PREPARE TO SQZ. - SPOT 22.7 bbls 7.5% HCL SOLUTION TO EOCT. CLOSE IN WELL. SQUEEZE 90 bbls (TOTAL) OF ACID TO FORMATION, DISPLACE ACID TO FORMATION WITH 115 bbls FIW. - SQUEEZE DATA: CSG LOW 510 HIGH 590 CT# PTbg# GPM ISIP 1850 4700 1850 50 5 SIP 1500 4800 2100 52 10 SIP 800 - POH W/NOZZLE. - SECURE WELL. RELEASE TO PRODUCTION @ 2200 hrs. 10/13/91 MOVE TO C31-26. RECEIVED DEC 20 1991 .Oil & Gas Cons, CommisSion horage ( Shell Western E&P 601 West F~fth Avenue · Suite 800 Anchorage, Alaska 99501 October 1, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C24-26RD Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment workover on MGS Well No. C24-26RD. In addition, a detailed operations program for the stimulation treatment is enclosed. The workover is anticipated to begin on October 11, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, E. Division Drilling Engineer Alaska Division VEU/slm Enclosures AOGCC\SUNDRY.DOC IL~i STATE OF ALASKA Si~ A KA OIL AND GAS CONSERVATION COMMI ~oN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend__ Operalx)n shutdown __ Re-enter suspended well Alter casing m Repair Well Plugging __ 'lime extenmon Stimulate X Change approved program __ Pull tubing __ Variance Perforate __ Other 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 5. Type et Well: Development X Exploratory Stratigraphic 4. Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg 1, Conductor 4, 4739'S & 1591'W from NE corner of Sec. 23, T8N, R13W, S.M. @ 958T (8258' TVD) 3786'S & 2695'W of SE Corner of Sec. 23, T8N, R13W, S.M. @11,216' (9686' TVD), 4560'S & 2791 'W from SE corner of Sec. 23, T8N, R13W, S.M. 6. Datum elevation (DF or KB3 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C24-26RD 9. Permit number 7,e-a'~.. .ee.e 10. APl number 50-733-20078 11. Field/Pool MGS/"E, F, & G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,216 feet 9,686 feet 11,160 feet 9,614 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor Surface 1,875' 10-3/4",40.5#,J-$5 1550sx Intermediate 9,100' 7",26-29#,N-80 500sx Production Liner 2,317' 5",18~,N-80 242sx Measured depth True vertical depth 1,875' 1,782' 9,100' 7,823' 8,881 '-11,1 98' 7,633'-9,672' Perforation depth: measured 9,587'-11,096' (11 Intervals) true vertical 8,259'-9,671' Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE 8rd @ 8,858' RECEIVIJD OCT - 1991 Packers and SSSV (type and measured depth) Guiberson Unipacker @ 8,788', Otis SSSV @ 314' '~laska 0Il & Gas Cons. Anchorage] 13. Attachments Description summary of proposal __ Detaded operations program X_~ BOP sketch 14. Estimated date for commencing operation 10/11/91 16. If proposal was verbally approved Name of approver 15. Status of well clasmfication as: Oil X Gas Suspended Service Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge ;,~S~.,nod K C.. Title Division Drilling Engineer Date 10/01/91 Conditions of approval: Notify Commission so representative may witness Plug integntym BOP Test__ Location clearance~ Mechanical IntegrityTesL Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 JApproval No~//_ ~ Appro.vect _C;~oPY Returneu _., - / Date /~).~ ~?-~/ SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL WELL No. C24-26RD COILED TUBING CLEAN OUT / ACID TREAT PRESENT STATUS: Production Well Last Test 9/25/91 - 35 BOPD, 292 GROSS, 88% H20 Cut Scale fill obstruction in 5" 18# Production Liner @ 10707' covering 234' of perfs including 70% of the HK-HN. Scale is only 34% soluble in HC1. OBJECTIVES: Clean out fill to PBTD and Acid Treat Hemlock perfs via: Coiled Tubing Unit (CTU) Clean Out (CO) with Positive Displacement Motor; and Acid Treatment (AT) with 7.5% HCl soak/j et wash/squeeze. NOTES: - 3-1/2" 9.3# N-80 tubing. - Minimum restrictions - Otis "X" nipple @ 8826' and SSSV @ 314'(2.750" ID) - Scale fill obstruction in csg @ 10707', tagged 9/07/91 w/ Slickline. - Completed January 1980:11 year old wellbore. - No indications of junk left in hole via review of Anchorage files. - 2.70" gauge ring drift run to 10000' 8/27/91 (EOT @ 8857'). RECOMMENDED PROCEDURE: (Refer to Attachment No. 1 for mechanical equipment details) · One week prior to scheduled rig-up, review MIT of all critical components (ie., swab valve, wing valve, tubing spool valve, etc.). Pressure test all critical components to 3500 psi. Replace or repair defective components. · Prior to CTU Rig Up, review all data files for information on junk in hole, fill indications, tubing blockages, and tubing ID restrictions. The following responsibilities are identified. Anchorage Well Files - Production Engineering Platform Well Files - Operations Foreman/PIC(*) Wireline Log Book - Wireline Operator/Operations Foreman (*) PIC is the SWEPI Person In Charge of the CTU operations. · The PIC should ensure all equipment to be run in the hole is calipered for both ID and OD, and that a complete dimensional drawing of each component is on file. RECEIVED OCT - 4 t991 Alaska Oil & Gas Cons. Comm'tss%o~ Anchorage MIDDLE GROUND SHOAL No. C24-26RD COILED TUBING CLEAN OUT / ACID TREATMENT · · · NOTE: No drift run is required on this well - A 2.70" gauge ring drift was run to 10000' 8/27/91 (EOT @ 8857'). The Anchorage files indicate the SSSV ball valve is out. 24 hours before CTU is scheduled for RU on this well, ensure annulus is filled with Filtered Injection Water (FIW). Take returns via circulation to production. Do not inject more than 350 bbls FIW without contacting Production Engineering or Manager Alaska Operations to discuss. Do Not access FIW directly downstream of the waterflood DE filter. Access FIW from downstream of the CUNO cartridge filters. Hold safety meeting with Arctic Recoil, Halliburton, and all other service company and platform personnel to discuss the proposed operations. Emphasize safety concerns with the chemicals to be used and with H2S during acidizing operations. H2S concentrations of 150 - 250 ppm are not uncommon in spent acid returns during MGS acid treatments. · · Ensure crown valve is closed. RU Arctic Recoil CTU with 1-1/2" coiled tubing and CTU assist pump. Install double check valves and hydraulic disconnect on coiled tubing. RU BOPE and flow "T". (NOTE: Equip CTU BOPE stack with blind rams, shear rams, and pipe rams.) Test CTU BOPE and coiled tubing to 5000 psi against swab valve and CTU stripper rubbers. Bleed coiled tubing pressure to negative test the double check valves. RU Halliburton with 150+ bbls 7-1/2% HC1 acid. Include the following additives in the acid. Ensure all hazardous materials are properly manifested in accordance with Department of Transportation Regulations. - 0.5% HAI-85 Corrosion Inhibitor, - 0.2% LoSurf-300 Non-Emulsifying Agent/Surfactant, - 20#/1000 gal FERCHEK-A iron chelating agent. · 10. RU valve manifold so the CTU assist pump can quickly access both the acid and the FIW independently. Filter all fluids pumped downhole through the 3 micron cartridge filters on the Arctic Recoil CTU assist pump. RU 250 bbl, 120 psi pressure contained surge tank for containment of contaminated fluid returns. page 2 MIDDLE GROUND SHOAL No. C24-26RD COILED TUBING CLEAN OUT / ACID TREATMENT 11. RU return line choke manifold to take returns from the flow "tee" to either the 250 bbl surge tank or the group production separator. RU a sampling valve at the choke manifold to monitor pH of the returns fluid. All uncontaminated fluids can go directly to the group production separator. Divert all contaminated fluid to the surge tank for processing. 12. RU an injection pump to transfer contaminated fluid from the surge tank to the C44-14RD disposal well at an expected injection rate of 3 BPM @ 1500 psi. Manifold pump intake with FIW access, in addition to the surge tank access, to overdisplace all contaminated fluid with a minimum of 100 bbls FIW flush. NOTE: Halliburton Operator must keep a detailed record of date, time, shut-in pressure before injection, injection rate, fluid type, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Refer to Attachment No. 2 for disposal guidelines. 13. RU H2S monitoring/detection equipment at the circulating choke and surge tank. Coordinate with SWEPI Production Operator to sample and monitor fluid returns and treat if necessary. 14. Install emergency blowdown lines for the surge tank. One from the pressure relief valve to blowdown fluids to the group production separator and one via a burst plate relief to the flare. 15. RU a gas flare line from the gas vent and burst plate relief of the surge tank to the platform flare. Install a flame arrester in the gas flare line. 16. RU instrumentation to monitor injection rate, coiled tubing injection pressure, coiled tubing (CT) x injection tubing (tbg) annulus pressure, and tbg x casing (csg) annulus pressure. For acid squeeze operations, the CT x tbg annulus and tbg x csg annulus should be monitored via a two pen chart recorder. Send annotated charts to Production Engineering in Anchorage. NOTE: Refer to Attachment No. 3 and follow the "Guidelines for Handling Backflowed and Circulated Fluids For Discharge" for all returns not disposed of in C44-14RD. The Onshore Operator should be notified and prepared to divert any transferred contaminated fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. page 3 MIDDLE GROUND SHOAL No. C24-26RD COILED TUBING CLE~N OUT / ACID TREATMENT 17. 18. 19. CLEAN OUT & ACID SOAK PERFORATIONS RIH with 2-1/2" bit, 2-1/16" Positive Displacement Motor (PDM), double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing to the top of fill (~ 10707'). Clean out fill, to PBTD. (Note: PBTD indications are not consistant in the Anchorage well files. Be careful! Bottom HR-HZ perforation is at 11096'. PBTD is ~ 11160'.) Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. POOH with PDM & bit. RIH with 2-1/2" swirl type jet nozzle, double check valves, and hydraulic disconnect sub on coiled tubing to the bottom perforation @ 11096'. NOTE: Coiled tubing length = 14200, 1-1/2,, coiled tubing capacity = (1.597 bbls/1000')*14200, = 22.68 bbls CT x 5" capacity 11096-10231, = (11096'-10231') * 0.015574 btm HR-HZ - top HC-HD = 13.5 bbls CT x Wellbore annulus capac, = 0.00651 bbl/ft * 8857' + = 0.01557 bbl/ft*ll160-8857' = 93.5 bbls 20. 21. Conventionally circulate 15.0 bbls 7-1/2% HCL followed by 22.6 bbls FIW to displace the acid out of the end of the coiled tubing (EOCT). The acid volume should cover the interval from the bottom perforation @ 11096' to above the top HC-HD perf @ 10231'. SD pump and let acid soak for at least 30 minutes. Continue in hole to PBTD. Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. Divert all acid returns to the surge vessel. Monitor vessel for H2S escapement. page 4 ( MIDDLE GROUND SHOAL No. C24-26RD COILED TUBING CLEAN OUT / ACID TREATMENT 22. Pump contaminated fluid to C44-14RD disposal well to ensure adequate surge vessel capacity for continuing coiled tubing operations. Flush disposal well with a minimum of 100 bbls FIW to overflush perforations. Refer to Attachment No. 2 for Disposal Guldelines and record disposal operations data. 23. JET WASH PERFORATIONS WITH ACID PU to bottom perf @ 11096'. Pump circulate at 1 BPM, while reeling coiled tubing at 20 feet/min, to jet wash the perforations and wellbore from 11096' to the top HC-HD perf at 10231' (will require ~ 44 bbls 7-1/2% HCL). Displace circulate with 120+ bbls FIW to clear contaminated fluid from coiled tubing and wellbore. Divert all contaminated returns to the surge vessel for disposal. 24. 25. ACID SQUEEZE STIMULATION RIH to bottom perforation at 11096'. Spot circulate 22.7 bbls 7-1/2% HCL (with above additives) to the EOCT. Close coiled tubing annulus at the flow "tee". Pump/squeeze 67.3 bbls additional acid (90 bbls acid total) followed by 115 bbls FIW to overdisplace the acid into the perforations (by ~ 90 bbls). Do not exceed 3500 psi surface pressure on the coiled tubing x injection tubing annulus. Coordinate with Production Operator to monitor tbg x csg annulus during squeeze operations. NOTE: Pump acid at the maximum rate possible without exceeding the pressure constraints. POOH. RD CTU. Return well to production via gas lift and test. RECEIVED OOT- ¢ 1991 Alaska Oil & Gas Cons. commisS'~oT~ Anchorage 1 O ATTAC MGS C24-26RDo8HMENT P._EQP-j;)i~ED STAT U S /19/91 ~-oP ~o..~ ,~~ 120 ax ' ' FROM 167' TO SURFACE 10-3/4' SURFACE CA81NG at 1876' 40.6# J-SE BTC CEMENTED w/ 1350 ax 'Q° · 35 ax GEL FOLLOWED BY 200 ax 'G' 3-1/2'. g.3#. N-80 EUE 8RD at 88E7' 5' LINER at 11,198' 18#, N-80 HYDRILL FJ LINER -- ~ [0707' ~l~ I~,O V~M/C24-2 e,ff2.CH T TO l! 11.218' 2~° CONDUCTOR at 370' CAMCO KBM MANDREL #1 at 2229 CAMCO KBM MANDREL ~2 It 4304' CAMCO KBM MANDREL CAMCO KBM MANOREL #4 It 1918' CAMOO KBM MANDREL #6 It 7?28 CAMCO KBM MANDREL CAMCO KBM MANDREL #? at 8684' CAMCO KBM MANDREL #8 at 8761' QUIBERSON UNI-Vll PACKER at 8?88° 3'1/2' JOINT EUE aRD 30' 9.3' OTIS 'X' NIPPLE at 8826 SHEAROUT 8ua WITH UULE-SNOE GUIDE ,t 8857' Liner Top · 8881' QN-GO 9689' - 9619' GR-G8 9917' - 9966' NC-HO 10281' - 10243' NC-HO 10278' - 10284' HO-HE I0342' - 10:3S8' NK-HN 10882' - 10742' HN-HR 10770' - 10820' HN-HR 10878' - 10964' HR-HZ 10988' - 11036' HR-HZ 11088' - 11096' N~DDLE GROUND SHOAL No. C24-26RD COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 2 C44-14RD DISPOSAL PROCEDURE GUIDELINES · · · · · Pump Operator must keep a detailed record of date, time, fluid description, shut-in pressure before injection, injection rate, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Complete the attached Disposal Record Form (on following page) to document all disposal activity. Establish Filtered Inlet Water (FIW) injection into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi without consulting Engineering or Manager Alaska Operations. If injectivity is acceptable, close FIW access and open pump intake to disposal fluids. Pump disposal fluids into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi unless injectivity drops below 2 BPM. If injectivity drops below 2 BPM at 3500 psi, increase pressure up to 4500 psi maximum injection pressure. Shut down pumps immediately if pressure exceeds 4500 psi or ,,screen-out,, conditions are apparent! Close disposal fluid access and open pump intake to FIW to flush disposal fluid with a minimum of 100 bbls FIW (over-flush wellbore capacity by a minimum of 25 bbls). Shut down disposal operations, record ISIP, and monitor C44-14RD fall-off pressure for 30 minutes. Record all data on attached C44-14RD Disposal Record Form. Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. page 7 MIDDLE GROUND SHOAL No. C24-26RD COILED TUBING CLE]~N OUT / ACID TREATMENT ATTACHMENT NO. 2 (continued) C44-14RD DISPOSAL RECORD FORM Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. 30 MIN PRIOR BEGIN END AFTER FLUID SI INJ. INJ. INJ. INJ. SI DATE TIME DESCRIPTION PRESS RATE PRESS VOLUME PRESS ISIP PRESS (psi) (BPM) (psi) (bbls) (psi) (psi) (psi) page 8 M'rDDLE GROUND SHOAL No o C2 4-2 6RD COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 3 PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS FOR DISCW_aRG~ Ail backflowed and circulated fluids, and not disposed of via C44-14RD, must be routed through the test separator prior to being sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. Note: Ensure any acid treatment fluids that are circulated or backflowed are neutralized prior to sending to the production separator. To satisfy EPA requirements, if the amount of fluid exceeds 250 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from C24-26RD acid treatment - 10/xx/91". Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. 2660 bbl Pipeline Delay = ............. Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) x 24 hrs = hrs Onshore Facility 1000 bbl Delay = ............. Gross Daily Prod "A" "C" and "Baker" (bbl) x 24 hrs = hrs Total time between slug shipment and sample time = hfs NOTE: Because the operations may result in a significant quantity of contaminated return fluids, the Onshore Operator should be notified and prepared to divert the transferred fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. page 9 ( Shell Western E&P IncQ 601 West F~fth Avenue · Suite 800 Anchorage, Alaska 99501 September 25, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT: SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS TO OPEN ADDITIONAL PAY ZONES IN MIDDLE GROUND SHOAL WELL NO. C24-26RD Enclosed in duplicate is the report of Sundry Well Operations for MGS Well No. C24-26RD. The workover included opening additional pay zones by perforating GN-GO/GR-GS. The sundry operations were completed on August 29, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263 -9646. Very Truly Yours, V. . Unger~ Division Drilling Engineer Alaska Division VEU/slm Enclosures RECEIVED AOGCC\SUNDRY.DOC i.( STATE OF ALASKA ~ A A OIL AND GAS CONSERVATION COMMI ,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ m Stimulate Plugging__ Perforate X Alter casingB Repair well __ OIJ3er 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 5. Type ot Well: Development /~. Exploratory Stra~raphic $1vt 4. Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg1, Conductor 4, 4739'S & 1519'W from NE comer of Sec. 23, T8N, R13W, S.M. (.g~,587' (8258"1'VD) 3786'S & 2695'W from SE corner of Sec. 23, T8N, R13W, S.M. @11,216' (9683'TVD), 4560'S & 2791'W from SE comer of Sec. 23, T8N, R13W, S.M. 6. Datum elevation (DF or KB) 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C24-26RD ,, 9C'~ermit num~__~fapproval number~,.=_, ~~0062/91-246 10. APl number 50-733-2007801 11. Field/Pool MGS/"E,F, & G" Pools 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner true vertical measured true vertical Length 11,216 feet 9,686 feet 11,079 feet 9,576 feet Size Plugs (measured) Junk (measured) Cemented 1,875' 10-3/4",40.5#,J-55 1550 sx 9,100' 7",26-29#,N-80 500 sx 2,317' 5",18~,N-80 242 sx Measured depth True vertical depth 1,875' 1,782' 9,100' 7,823' 8,881 '-11,198' 7,633-9,672 Perforation depth: measured 9,587-11,096' (11 Intervals) true vertical 8,259'-9,671' Tubing (size, grade, and measured depth) 3-1/2",9.3~,N-80 EUE 8rd @ 8,858' Packers and SSSV (type and measured depth) Guiberson Unipacker @ 8,788', Otis SSSV @ 314' 13. Stimulation or cement squeeze summary Open additional pay zones by perforating. Intervals treated (measured) 9,587' - 9,617' & 9,915' - 9,964' Treatment description including volumes used and final pressure Perforated zones using 2-5/8" Jumbo Jet Scallop Guns. 4 JSPF 14. Prior to well operation Subsequent to operation Representative Daily Averaae Prgduqtion or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15 18 229 810 110 19 0 257 790 80 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X__ -17. I hereby certify that the torego~ng ~s true an Form 10-404 Rev 6. Status of well classification as: Oil X Gas Suspended Service correct to the best ot my Knowledge Title.~lVl~lO~'J Pi~.OZ)Uc'TI~'J ~[k/~IAI~E'~ Date SUBMIT IN DUPLICATE DAILY REPORT OF ACTIVITIES C24-26RD DATE 082891 082991 ACTIVITY SKID RIG OVER WELL AND ARRANGE HATCH COVERS FOR ACCESS. SET WESTERN ATLAS UNIT AND SHELL SLICKLINE UNIT. RUN IN HOLE WITH SLICKLINE AND RETRIEVE BALL VALVE AT 307'. RUN IN HOLE WITH 2.70 GAUGE RING TO 10,000'. NO OBSTRUCTIONS. PERFORATE GN-GO/GR-GS WITH 2-5/8" JUMBO JET SCALLOP GUNS. 4 JSPF, 0 DEGREE PHASING. RUN NO. I 9964-9945 19' 2 9946-9915 31' 3 9617-9587 30' 80' TOTAL PUT WELL IN TEST, RIG DOWN WESTERN ATLAS AND MOVE RIG TO C34- 23. AOGCC/O92591DR Shell Western E&P Inc.~ 601 West FIfth Avenue * SuIte 800 Anchorage, Alaska 99501 August 19, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL TO PERFORATE ADDITIONAL PAY ZONES IN MIDDLE GROUND SHOAL WELL NO. C24-26RD Enclosed in triplicate is the application for sundry approval to open additional pay in the GN-GO and GR-GS sands of Middle Ground Shoal Well No. C24-26RD. The sundry operations are expected to begin August 26, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646 or Mr. Bill Miller at (907) 263-9633. Very Truly Yours, E. Division Production Engineer Alaska Division VEU/WAM/PTH Enclosures RECEIVED AU G 2 1 1991 Alaska Oil & Gas Cons. Comm. tsste~ N~chorage bc: R. G. Blackburn W. F. Simpson R. G. Lippincott P. T. Huckabee S. M. Logan D. L. Marshall - Kenai SEA File 5.6120 C24-26RD Correspondence Fi 1 e Reading File Product i on F i 1 e Cons. SL STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COMMISSI ,~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation shutdown Re-enter suspended well Alter casing __ Repair Well __ Plugging t Time extension Stimulate Change apfxoved program __ P~ate X O~ 2. Name of Operator Shell Weetem E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Pull tubing Variance -- -- 5. lype o! Well: Development X Exploratory SffaUgraphic 4. Location of well at surface At top of productive interval Platform C, Leg 1, Conductor 4, 4739'S & 1591'W from NE corner of Sec. 23, T8N, R13W, S.M. @10,232' (8848' TVD) 4049'S & 2795'W from SE comer of Sec. 23, T8N, R13W, S.M. At effective depth At total depth @11,216' (9686' TVD), 4560'S & 2791 'W from SE corner of Sec. 23, T8N, R13W, S.M. 6. Datum elevation (DF or KB1 116' KB feet 7. unit or Property name Middle Ground Shoal 8. Well number C24-26 9. Permit number 10. APl number 50-733-20078--~/ 11. Field/Pool MGS/"E, F, & G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,216 feet 9,686 feet 11,079 feet 9,576 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor Surface 1,875' 10-3/4",40.5~,J-55 1550sx Intermediate 9,100' 7",26-29~,N-80 500sx Production Liner 2,317' 5",18~,N-80 242sx Perforation depth: measured 10,232-11,096' (12 Intervals) true vertical 9,274'-9,671' Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE 8rd @ 8,858' Packers and SSSV (type and measured depth) Measured depth True vertical depth 1,875' 1,782' 9,100' 7,823' 8,881 '-11,198' RECEIVED AUG 2 1 1991 Alaska Oil & Bas Cons. Commissli Guiberson Unipacker @ 8,788', Otis SSSV @ 314' jlEicJlorag8 13. Attachments Description summary of proposal X__ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 08/25/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed y.d. !.,Jf/~~v/ Title Division Drilling Engineer Date 08/10/gl FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical 1n-~grity Test._ --Subsequent form require--d 10- Approved by order of the Commission ORIGINAL $1GNEO BY LONNIE C, SMITH _,~ I Approval No? · ,, Commissioner Sate ~~c~.-.--~'// Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ( ( MIDDLE GROUND SHOAL C24-26RD PERFORATION OF GN-GO/GR-GS STATUS: C24-26 was drilled and completed in February 1968. Initial production was 3230 BOPD, 1% cut. C24-26 was redrilled and completed in December, 1979 due to formation impairment caused by emulsions and compatibility problems from previous stimulation attempts. The redrill was not kicked sufficiently away from the old well and penetrated the impaired formation. This was evidenced by an alcohol smell in the mud returns and a very high production decline rate upon completion. In December 1986, a ten foot section of the HD-HE was perforated which increased production to over 2000 BOPD. The HD-HE zone is not under direct pressure support and went on a rapid decline. By June 1987, production had dropped off to 100 BOPD after producing over 110,000 BO from this zone. By October 1987, production had declined further to 65 BOPD, 78% cut. Following perforation of additional pay in the HC-HD and HD-HE, production increased to 108 BOPD, 72% cut, but never reached levels accomplished after the 1986 remedial work. Finally, in December 1988, C24-26 was shut in due to 84% water cut and a low production rate of 43 BOPD. The well was returned to production August 6, 1991 and was tested August 13, 1991, at 540 BPD fluid at 99% water cut (5 BOPD). OBJECTIVE: Open additional pay in the GN-GO and GR-GS sands. COST ALLOCATION: Charge all costs to Work Order No. ~. ATTACHMENTS: I Present Status II Proposed Status NOTE: Place well in test 24 hours before commencing perforating operations to establish a production baseline for comparison following perforation of the proposed zones. PROCEDURE: 1. RU slickline and lubricator on wellhead. With a slickline gauge ring make a 2.7" drift run to EOT. POOH and RD. AUG 2 1 1B91 Alaska 0ii & Sas (;OHS. Gomm~ssle~ Anchorage ¢ HGS C24-26RD Perforation of GN-GO/GR-GS 2. After production is stable, and gas lift operation is satisfactory, RU Atlas Wireline Services to perforate with 2-5/8" Jumbo Jet (4JSPF, 0 degree phasing}. Ensure that phasing is such that the magnet is in-line with the projected perfs. Include GR tool for correlation. 3. Choke back well or SI before RIH as deemed necessary by Operations Foreman and RIH. Once the tools are below EOT place well back on full production. It is important that SI time, if any, be minimized. 4. With well on test, gas lift well until operation is stable and consistant with normal lift depth {normal casing pressure}. Correlate GR to Schlumberger CBL/GR log dated 12/14/79. 5. Perforate the following depth intervals: .Gun Run # DIL Log Interval CBL Log Interval Gun Length 1) GR-GS 9917' - 9966' 9915' - 9964' 49' 2) GN-GO 9589' - 9619' 9587' - 9617' 30' NOTE1: CBL Log Interval was determined using 12/14/79 CBL. NOTE2: Flow well for I hour before POOH. While POOH choke well back or SI as deemed necessary. 6. RD Atlas Wireline. 7. Test well until stable {for a minimum of 24 hours) taking hourly water cuts and production rates. FAX summary of hourly test results to P.T. Huckabee in Anchorage and Bob Lippincott in Houston on daily basis. 8. After production is stabilized, test well every third day and report results via daily production reports. WAM/PTH 8/19/91 120 sx ' ° FROM 167' TO SURFACE 10-3/4' SURFACE CASING at 1876' 40.6# J-66 BTC CEMENTED w/ 1360 ex 'G° * 36 ex GEL FOLLOWED BY 200 ax 'G° 3-1/2', 9.3#, N-80 EUE 8RD at 8867' 7' PRODUCTION CASING at 9100' 0-7688' 26# N-80 BTC 7688'-9105' 29# N-80 BTC 5' LINER at 11,198' 18#, N-80 HYDRILL FJ LINER ATTACHMENT I MGS C24-26RD PRESENT STATUS 08/19/91 PBTD at 11,105' 24' CONDUCTOR at 370' CAMCO KBM MANDREL #1 at 2229 CAMCO KBM MANDREL #2 at 4304' CAMCO KBM MANDREL #3 at 5003' CAMCO KBM MANDREL #4 at 6963' CAMCO KBM MANDREL #5 at 7728 CAMCO KBM MANDREL #6 at 8342' CAMCO KBM MANDREL #7 at 8684' CAMCO KBM MANDREL #8 at 8751' GUIBERSON UNI-Vll PACKER at 8788' 3-1/2' JOINT EUE 8RD 30' 9.3# OTIS 'X' NIPPLE at 8826 SHEAROUT SUB WITH MULE-SHOE GUIDE at 8857' Liner Top · 8881' HC-HD 10231' - 10243' HC-HD 10278' - 10284' HD-HE 10342' - 10358' HK-HN 10692' - 10742' HN-HR 10770' - 10820' HN-HR 10878' - 10964' HR-HZ 10986' - 11036' HR-HZ 11083' - 11096' TD at 11,216' WAM/C24-26.CH T ATTACHMENT II MGS C24-26RD PROPOSED STATUS TOP JOB: 120 ex 'G' FROM 167' TO SURFACE .a 10-3/4' SURFACE CASING at 1876' 40.6# J-66 BTC CEMENTED tv/ 1360 ex 'G' * 36 ex GEL FOLLOWED BY 200 ex 'G' 3-1/2', 9.3#, N-80 EUE 8RD at 8867' 7' PRODUCTION CASING at 9100' 0-7688' 26# N-80 BTC 7688'-9105' 29# N-80 BTC LINER at 11,198' 18#, N-80 HYDRILL FJ LINER 08/19/91 I PBTD at 11,106' 24' CONDUCTOR et 370' CAMCO KBM MANDREL #1 at 2229 CAMCO KBM MANDREL #2 at 4304' CAMCO KBM MANDREL #3 at 5003' CAMCO KBM MANDREL #4 at 6963' CAMCO KBM MANDREL #5 at 7728 CAMCO KBM MANDREL #6 at 8342' CAMCO KBM MANDREL #7 at 8684' CAMCO KBM MANDREL #8 at 8751' GUIBERSON UNI-Vll PACKER at 8788' 3-1/2' JOINT EUE 8RD 30' 9.3# OTIS 'X' NIPPLE at 8826 SHEAROUT SUB WITH MULE-SHOE GUIDE at 8867' Liner Top · 8881' GN-G0 9589' - 9619' GR-GS 9917' - 9966' HC-HD 10231' - 10243' HC-HD 10278' - 10284' HD-HE 10342' - 10358' HK-HN 10692' - 10742' HN-HR 10770' - 10820' HN-HR 10878' - 10964' HR-HZ 10986' - 11036' HR-HZ 11083' - 11096' TD at 11,216' WAM/C24-26#2.CH T ( Shell Western E&P Inc. O 601 West FIfth Avenue * Suite 800 Anchorage, Alaska 99501 June 11, !990 Alaska 0il and Gas Conservation Commission ATTN: Elaine Johnson 300! Porcupine Drive Anchorage, A1 aska 9950! SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED JUN 1 I990 Alaska Oil & Gas Cons. Anchora~ PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. CONDUCTOR WELL DISTANCE FROM SE CORNER NORTH WEST 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 LEG 2 CONDUCTOR LEG 3 LEG 4 9 10 11 12 13 14 15 16 CONDUCTOR 25 26 27 28 29 30 31 32 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612.65 1550.46 C24A-23 614.85 1554.26 C13-23 619.15 1555.66 Centered 582.42 ft. North and 1489.90 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C4 C3 C4 C4 C3 C- C4 C2 2-23 1-23 3-23 1-23 3-26 LINE 4-14RD 4-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -0.70 -3.80 -4.50 0.50 -5.90 West West DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 ',U~,, · . 8LUFF 1GILX 1'.2o0o' klen~k IN? AOGCC SAFETY VALVE TEST REPORT FIELD: HIDDLE GROUND SHOAL PAGE PRESSURES - PSIG OPERATOR: SHELL WESTERN E&P WELL I~BER PERI, IT NUHBER 77-0079-01 68-0030-01 68-0069-01 ~ ,, 75-oo35-ol 78-0024-01 e8-oo6o-ol 76-oo65-ol '79-oo62-ol 67-0063-01 68-oo19-ol I I I SHELL C PLATFORI~ DATE .k, c~ .~,_ I REPRESENTATIVE: 'C~, I IC44-14RD I ssv Issvl.. ,sssv Isss I IP I FP ITS, TI IP I FP ITST Isv TSTIPILOTI I:'I,G I SI I DUE I(I, OW)I TBG I TaG I~1~1 I I I ~ J/~o, Jzv0 I I I ,/o le3 I ' I I I I~1~1~ I I I I !~1~1~1~ I I I I I~1~1~1~ I I I I I ..... I~1~1~ I I I I I~1~1~1~ I I I I~1~1~ I I I I I~1~1~1~ I I I I I ..... I~1~1~ I I I I I~1~1~1 .... · ,,1_1 P I'-/* 17o IF),,'',_, P l ~o I~o IP ",_, , II f l~° , I~o,, ,IP ,_, I I I I I I J~J~ II INSPECTOR i -MEMORAND(uM State(of Alaska ALASKA OIL AND GAS CONSERVATION COI~IISSION TO: Lonnie C. Smith~!~~ Commissioner DATE: August 8, 1988 FILE NO D. BDF. 008 THRU' Michael To Hinder Sr. Petroleum Engineer TELEPHONE NO: SUBJECT Safety Valve Tests Shell-MGSU Platform C MGS Oil Pools / FROM' Bobby D. Fost er ~~~, Petroleum Inspector Thursday, August 4 ~ 1988.. The tests began at 7~30 a.m. and were concluded at 10..30 a.m. With 10 Pilots, 10 SSSV s and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. This will be repaired and the AOGCC Office notified, ,, Comment by Mike Minder~ Richard Vickerson called August 8, 1988, to notify Commission that the SSSV in C42-23 has been replaced and tested OK. L Attachment Pilots Tested 10 Pilots Failed 0 SSSV's Tested 10 SSSVl§ Failed 1 SSV's Tested 10 SSV's Failed 0 · 02-001A (Rev 8185) Shell Westem E&P Inc. O 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 August 17, 1988 Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT- SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL NO. C24-26 RD As discussed on Auqust 15, 1988, with Blair Wondzell by S. B. Brown, enclosed (in duplicate) is the Report of Sundry Well Operations for perforations of Middle Ground Shoal Well No. C24-26 RD. If you have any questions, please call Ms. Susan Brown (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBB/ljm Enclosures' Report of Sundry Well Operations (2) SBBH/aogcc. 081688 ALAS OIL AND GAS CONSERVATION COM ,oSlON REPORT OF SUNDRY WELL OPERATIONS I Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~( Pull tubing [] Alter Casing [] Other [] 2 Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB Feet 3. Address 6 Umt or Property name 601 West Fifth Avenue, Suite 810, Anchorage, AK 99501 Niddle Ground Shoal 4. Location of well at surface Platform "C", Leg 1, Conductor 4, 4739.0'S 7. Well number and 1591.0'N from NE corner of Section 23, T8N, R13W, S.M. C24-26RD At top of produchve ~nterval 4327'S and 1176' W of surface location 8. Approval number B. Wondzel 1 , At effective depth 5085' S and 1205' W of surface location 9. APl number 50-- 733-20078 At total depth 5101'S and 1205'W of surface location 10 Pool "G" Pool 11. Present well condition summary Total depth, measured 11,216' feet Plugs (measured) true verhcal feet Effective depth measured 11,079' feet Junk (measured) true vertical feet Casing Length S~ze Cemented Measured depth True Vertical depth Structural Conductor Surface 1,875' 10-3/4",40.5#,J-55 1550sx 1,875' Intermediate 9,100' 7",26-29#,N-80 500sx 9,100' Production Liner 2,317' 5", 18#,N-80 242sx 8,881 '-11,198' Perforation depth measured 10,231-11,095' (12 intervals) true vertmal 9,274'-9,671 ' Tubing (s~ze, grade and measured depth) 3-1/2", 8,858' (MD) Packers and SSSV (type and measured depth) Packer set at 8,788' '~, 12 Stimulation or cement squeeze summary Perforated 2 holes, one at 9939' and one at 9947' Intervals treated (measured) 4 JSPF: 9951' - 9944' and 9955'-9963' Treatment description ~ncluding volumes used and f~nal pressure 13. Representative Daily Average Producbon or Injecbon Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 60 272 No Change No Change Subsequent to operahon 14. Attachments Daily Report of Well Operahons ~ Copies of Logs and Surveys Run [] 15 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Title Division0perationsNanager _.Dat. e. ~//'"/~.~ Form 10-404 Rev. 12-1-85 Submit ~n Duplicate DAILY REPORT OF OPERATIONS DATE: 8/12/88 WELL NO: C24-26RD FOREMAN: M.G. Dunckley OPERATION: Perforate GR-GS 24 HR SUMMARY: Rigged up. Fired two test shots; one at 9939' one at 9947' Perforated 8 ft at 9955'-9963' and 7 ft at 995~'-9914' using'4 JSPF. Rigged down. No change in production. SBBH/aogcc. 081688 STATE OF ALASKA ALA~'.., OIL AND GAS CONSERVATION CaMel" .SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed. Operahon shutdown [] Stimulate [] Plugging [] Perforate [~ Pull tubing [] Alter Casing [] Other [] 2 Name of Operator 5. Datum elevahon (DF or KB) She11 Western E&P I nc. 116' KB Feet 3. Address 6 Unit or Property name 601 West Fifth Avenue, Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4 Location of well at surface Platform "C", Leg 1, Conductor 4, 4739.0'S 7. Well number and 1591.0'N from NE corner of Section 23, T8N, R13W, S.N. C24-26RD At top of productive interval 4327'S and 1176' W of surface location 8. Approval number 7-832 , At effechve depth 5085' S and 1205' W of surface location 9. APl number 50-- 733-20078 At total depth 5101'S and 1205'W of surface location 10 Pool t'G" Pool 11 Present well cond~hon summary Total depth' measured 11,216' feet Plugs (measured) true vertical feet Effective depth: measured 11,079' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 1,875' 10-3//+",/+0.5#, J-55 1550ex 1,875' Intermediate 9,100' 7",26-29#,N-80 500ex 9,100' Production Liner 2,317' 5", 18#,N-80 2/+2ex 8,881 '-11,198' Perforation depth' measured 10,231-11,096' (10 intervals) true vertical Tubing (size, grade and measured depth) 3-1/2", 8,858' (MD) ~/~,~ 0 .,~ '(:}~ A/asks 0ii & Gas Cons. Packers and SSSV (type and measured depth) Packer set at 8,788' ,~lCh0rag$ 12. Stimulahon or cement squeeze summary Perforated /+ JSPF: 10,3/+2 '-10,3/+5 ' 10,355'-10-358' 10,278'-10,28/+' 10,231 '-10,2/+3' Intervals treated (measured) Perforated 2 JSPF: 10,235'/10,281 ' Treatment description ~nclud~ng volumes used and final pressure 13 Representative Da~ly Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 72 76 Subsequent to operabon 103 72 14 Attachments Daily Report of Well Operahons ~ Cop~es of Logs and Surveys Run [] 15 I hereby cert.fy that the foregoing .s true and correct to the best of my knowledge ~~'o /~ ~_~ Division Operations Manager Signed Title Date ¢.~' ~-' 2~' Form 10-404 Rev. 12-1-85 SBBG/ros. 030188~.. Submit in Duplicate DAILY REPORT OF OPERATIONS MIDDLE GROUND SHOAL C24-26RD 10/25/87 10/28/87 11/05/87 Rigged up. Perforated with 4 JSPF. HC-HD 10,342'-10,345'. HC-HD 10,355' -10,358'. Perforated with a 2 JSPF. HC-HD 10,235'. HC-HD 10,281'. Perforated with 4 JSPF. HC-HD 10,278'-10,284'. HC-HD 10,231 '-10,243'. SBBG/ros.0229c Shell Westem E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 October 23, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: SUBJECT: SUBMISSION OF AN APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL C 24-26RD Enclosed, in triplicate, is the Application for Sundry Approval for an upcoming workover on Middle Ground Shoal well C 24-26RD. The work in- cludes perforating the HC-HD, and GR-GS zones. The work will commence Saturday, October 24, 1987. If you have any questions, please contact Susan Brown at (907) 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/kma SBBG/asa.1023 A~ STATE OF ALASKA ~. AL .,A OIL AND GAS CONSERVATION CO .,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operabon Shutdown [] Re-enter suspended well [] Alter casing [] TIme extension ~ Change approved program [] Plugging [] Sbmulate [] Pull tubing [] Amend order [] Perforate ¢(-1 Other 2. Name of Operator Shell Western E&P Inc. 3 Address 601 West 5th Avenue, Suite 810, Anchorage, AK 99501 4 Locabon of well at surface Platform C, Leg 1, Conductor 4.. 4739.0'5 & 1591.0'N from NE corner of Sec. 23, T8N, At top of produchve interval R13W, S.M. 4327'5 & 1176'W of surface location At effective depth 5085'5 & 1205'W of surface location At total depth 5101~S & 1205'W of surface location 11. Present well condihon summary Total depth, measured true verhcal 11,216 ' feet Plugs (measured) feet Effective depth measured 11 ,079 true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production L~ner Perforation depth. 10,69 9,274 Tubing (s~ze, grade Length Size Cemented I ,875 ' 9,100' 10-3/4", 40.5#, J-55 7", 26-29#, N-80 2,317' 5", measured 2-11 ,096' true vertical -9,671 ' and measured depth) I 8#, N-80 5 intervals 3-1/2", 8858' (MD) Packers and SSSV (type and measured depth) packer set at 8788' 1 550 sx 500 sx 242 sx 5 Datum elevation(DF or KB) 116' KB feet 6 UnitorProperty name Middle Ground Shoal 7. Well number ¢ 24-26 RD 8. Permit number 6-610 9. APl number 507,33 -20078 10. Pool "G" Pool Measured depth 1 ,875 ' 9,100' 8,881 -11 ,1 98 ' True Vertical depth Go[tS. 12 Attachments Descrlphon summary of proposal ~ Detailed operat~ns program [] BOP sketch [] 13 Eshmated date for commencing operation OCTOBER 24, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing ~s true and correct to thee. best of my knowledge Signed ¢~_~ Title Production Superintendent Date Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval.. No. ~ ~ ~ Plug integrity ~ BOP Test ~ Location clearanceI / / ~ ~", ~ ~ .~,~;~~ by order of Approved by ,,.,, ~ ,: .[ ~, ~[~[~ Commiss,oner the comm,ssion Date Form 10-403 Rev 12-1-85 SBBF/as a. 1023a Submit ~n tnpl~c~ ( PROGNOSIS C24-26RD OBJECTIVES: INCREASE PRODUCTION TO AT LEAST 100 BOPD BY OPENING REMAINING PAY IN HC-HD(2), HC-HD(2) AND GR-GS. STATUS: PRODUCING 64 BO + 228 BWPD 10/10/87 TUBING: SEE ATTACHED TUBIN~ DETAIL SHEET PERFORATIONS: ZONE HC-HD(2) HK-HN(U) HN-HR(U) HN-HR(L) HR-HZ(U) HR-HZ(L) REFERENCE LOG: SOS CBL 12-14-79 INTERVAL 10345-10355 10692-10742 10770-10820 10878-10964 10986-11036 11083-11096 P R 0 C E D U R E: ~%~ Oil & G~5~r~ G0%%$. Comiil'isslf~? 1. PLACE WELL IN TEST 24 HOURS BEFORE THE START OF_.._ .---~hO[5~ THROUGHOUT THE OPERATION. 2. RU SLICKLINE AND PULL SSSV. MAKE 2.7" DRIFT RUN TO EOT. POOH AND RD. 3. RU ATLAS AND PRESSURE TEST LUBRICATOR WITH 1" LINE FROM OFFSETTING INJECTION WELL TO 3500 PSI. 4. RIH WITH 2 5/8" HOLLOW CARRIER LOADED 4 JSPF SWITCHED TO PERFORATE THE FOLLOWING INTERVALS: HC-HD(2) 10342-10345 ( HC-HD ( 2 ) 10355- 10358 SHOOT. POOH. LEAVE WELL ON TEST FOR MINIMUM OF 8 HOURS BEFORE GOING TO STEP 5. IF PRODUCTION INCREASES TO GREATER THAN 100 BOPD RD ATLAS. 5. RIH WITH 2 5/8" HOLLOW CARRIER SWITCHED TO PERFORATE TWO SHOTS AT THE FOLLOWING DEPTHS: HC-HD(1) 10,235',10280' SHOOT. POOH. PLACE WELL ON TEST FOR AT LEAST 8 HOURS. MONITOR FOR INCREASING WATER CUTS. 6. IF NO INCREASE IN WATER CUTS ARE SEEN, RU TO PERFORATE THE FOLLOWING 4 JSPF: ~,~-'~ HC-HD(1) 10278-10284 HC-HD(1) 10231-10243 SHOOT. POOH. PLACE WELL ON TEST FOR AT LEAST 8 HOURS. MONITOR FOR INCREASING WATER CUTS. IF PRODUCTION INCREASES TO GREATER THAN 100 BOPD RD ATLAS. IF NO PRODUCTION INCREASE IS NOTED CONTINUE TO STEP 7. 7. RIH WITH 2 5/8" HOLLOW CARRIER SWITCHED TO PERFORATE TWO SHOTS AT THE FOLLOWING DEPTHS: GR-GS 9942' ,9980' SHOOT. POOH. PLACE WELL ON TEST FOR AT LEAST 8 HOURS. MONITOR FOR INCREASING WATER CUTS. 8. IF NO INCREASE IN WATER CUTS ARE SEEN, RU TO PERFORATE THE FOLLOWING 4 JSPF: GR-GS 9958-9966' GR-GS 9917-9954' CLOSELY MONITOR FOR ANY INCREASE IN PRODUCTION BETWEEN RUNS. A AS. APPROVED: _.._~~ "~b* ~~ DATE: 1~ laola'v 5 6 7 8 9 10 11 12 13 14 COMPLETION EQUIPMENT DETAIL SIIEET MGS C24-26RD 8/11/87 NO. ITEM APPROXIMATE TVD. MD. PS[ OR 1. OTIS BALL VALVE NIPPLE 2. CAMCO KIIM MANDREl, #1 3. CAMCO KBM MANDREL #2 4. CAMCO KBM MANDREL #3 5. CAMCO KBM MANDREL #4 6. CAMCO KtlM MANDREl, #5 7. CAMCO KBM MANDREL #6 8. CAMCO KBM MANDREL #7 9. CAMCO KBM MANDREL #8 10. GIIIIIERSON UNIPACKER VII 314 314 2079 2229 935 3753 4304 945 3/16 4344 5003 945 3/16 6004 6963 945 3/16 6646 7728 940 3/16 7171 8342 985 1/4 7462 8684 975 1/4 7519 8751 OR 3/8 7552 878R 11. 3 1/2" JOINT EUE 8RD 30' 9.3# 7559 8796 12. OTIS "X" NIPPI,E 7585 8826 13. 3 1/2" JOINT EUE 8RD 30' 9.3# 7586 8827 14. S{{EAROUT SUB w/MUI,E-S{IOE GUIDE 7612 8857 CASING 10 3/4", 40.5#, J-55 @ 1875' w/1550 sx 7" 26-29#, N-80 BUTTRESS @ 9t00' w/500 sx 5" 18#, N-80 IlYDRII,L FJ LINER @ 888]-11198' w/242 sx PBTI) ~ ]1,079' TD = 11,216' TUBING 3 1/2", 9.3#, N-80 EUE 8RD @ 8857' PERFORATED ZONE GROSS INTERVAL HK-HN HN-IIR HN-IIR IIR-tIZ HR-HZ 10692-10742' 10770-10820' 10878-10,q64 ' ]0986-11036' 11083-11096' PAGE 103 July 2, 1987 ( Shell Westem E&P Inc. ~ 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL NO. C 24-26 RD Gentlemen- Enclosed, in duplicate, is the Report of Sundry Well Operations for the perforation performed on Middle Ground Shoal well number C 24-26 RD. If you have any questions, please contact Susan Brown at (907) 263-9613. Ve~ truly yours, ~ 1.:) / (, anag~ Regulat~)ry Affairs Alask~ Division SBB/kka Enclosure SBBF/aogcc. 04a RECEIVED JUL- a 1D,R, 7 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ' A~L .,A OIL AND GAS CONSERVATION CO,v, MISSION REPORT OF SUNDRY WELL OPERATIONS I Operahons performed: Operahon shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2 Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB Feet 3. Address ' 6 Umt or Property name 601 West 5th Avenue, Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4 Location of well at surface P1 atform C, Leg 1, Conductor 4.. 4739.0'S & 1591.0'N from NE corner of Sec. 23, T8N, 7. Well number C 24-26 RD Attopofproducbve~nterval R13W, S.M. 4327'S & 1176'W of surface location Ateffect~ve depth 5085~S & 1205,w of surface location At total depth 5101'S & 1205'W of surface location 8. Approval number 6-610 9. APl number 50-~33- 2007 8 10. Pool "G" Pool 11 Present well cond~hon summary Total depth, measured true vertical 11 , 21 6' feet feet Plugs (measured) Effective depth' measured I I ,079 ' true vertical feet feet Junk (measured) Casing Length S~ze Structural Conductor Surface 1,875 ' Intermediate 9,100 ' Production Liner 2,317 ' 5", Perforation depth, measured 10,692-11,096' true verhcal 9,274-9,671 ' Tubing (size, grade and measured depth) 3-1/2", 8858' (MD) Packers and 8SSV (type and measured depth) packer set at 8788' Cemented 10-3/4", 40.5#, J-55 7", 26-29#, N-80 1 8#, N-80 5 interval s Measured depth True Vertical depth 1550 sx 1,875' 500 sx 9,100' 242 sx 8,881-11,198' RECEIVED JUL- 6 1987 Alaska 0il & Gas Cons. Commission Anch0ra.qe 12. Stimulation or cement squeeze summary Perforated 10,345'-10,355' Intervals treated (measured) Treatment description ~nclud~ng volumes used and final pressure 4JSPF. 13 Prior to well operation Subsequent to operation Representahve Da~ly Average Production or Injechon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 29 0 123 790 Tubing Pressure 70 1953 636 92 920 110 14. Attachments Daily Report of Well Operations ~ Cop~es of Logs and Surveys Run [] --~~5 I hereby certify that the foregoing ~s true and correct to the best of ~- my knowledge S~gned Title Production Superintendent Form 10-404 Rev. 12-1-85 SBBF/roswoolb Date ?,~,(~I~ Submit ~n Duplicate DAILY JOB SUMMARY DATE' WELL NO' OPERATION' 12/17/86 C24-26 RD Perforate HD - HE Perforated middle of HD-HE sand with 2 test shots at 10,348' and 10,352'. Tested for 12 hours. Production increased to 318 BOPD + 90 BWPD. RECEIVED JUL- 6 1987 Alaska Oil & Gas Cons. Commission Anchorage SBBF/djs .0lb DAILY JOB SUMMARY DATE- WELL NO' OPERATION' 12/19/86 C24-26 RD Perforate HD - HE Perforated middle of HD-HE sand from 10,345'-355' w/SOS 2-1/8" Enerjet loaded 4JSPF. Gun was run w/surface readout pressure and temperature detectors. Survey while RIH indicated well was lifting from bottom GLV. Pressure prior to perforation was 1,171 psi at HD-HE. After perforating, pressure built to 2,201 psi in 4 hours. Survey out indicated that zone was flowing w/ very little gas lift support. 24 hour test after perforating was 1,953 BO + 92 BWPD. GOR = 326. REC[IVED JUL- 5 1 87 Alaska Oil & Gas Cons. Ancho;~ge SBBF/djs.Olb SCHLUMBERGER OFFSHORE SERVICES A Divirdon of Schl~r Limited January 27, 1987 Shell Western E&P, Inc. 601W. Fifth Avenue, Suite 810 Anchorage~ AK 99501 Att~nti~: Hr Joe Fram ,P. O. Box 1001 Kenai, AK 99611 Attention: Shelley Ramsey ~ckaed are_ 2 BLprin~softhe IdI~PT (12/20/86} & Perforating Record (12/20/861m: Compony Sl~PI .,Well. liiddle Ground Shgal 'C" ~2A-26 RD , Field Niddle Ground Shoal ,County Kenai Stat, Alaska Additionolprin~ am beir~sentto: I BL ~rin~ , original film ShellrWestern E&P~ Inc. P. O. Box 527 Houstonp TX 77001 .Attn:..Log Files, WCK 4147 I BL prin~, I Reverse Folded Sepia State of Alaska Oil & Gas Conservation /.~ Commissio~ 3OO1 Porcupine Drive Anchorage. AK 99501 Attn: H. W. Kugler I BL.~ri~ts Shell Yestern E&P, Inc. P. O. Box 527 Houstonf TX 77001 Attn: R. J. Vallejo, WCK 1134 I BL .~rints Shell Platform "C" c/o Shell Kenai Office North Star Route #1 P. O. Box 485 ~ik Road Kenai~ AK 99611 I BL~rin~ , 1Nylar ARCO Alaska, .Inc.. P. O. Box 100360 Anchorage, AK 99501 Attn: H. F. Blacker prints 2 BL prints , 2 Reverse Rolled Sepia Chevron U.S.A.~ Inc. P. O. Box 107839 Anchora~e~ AK 99510 Attn: J. L. ~eaver The film is returned ~o Shell, Houston. We appreciate the privilege of serving you. prints PLEASE SIGN & RETURN ONE COPY OF THIS TRANSHITTAL. RECEIVE~ SCHLUMBERGER OFFSHORE SERVICES Ro~er H. Theis '-' DISTRICT MANAGER Decembe~ 4, 1986 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 for: State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: TWO UPCOMING WORKOVERS ON MIDDLE GROUND SHOAL WELL NO. 's C 24-26RD AND C 42-23 Enclosed are two Applications for Sundry Approval for perforations to be performed during upcoming workovers on Middle Ground Shoal (MGS) wells C 24-26 RD and C 42-23. Each application is submitted in triplicate. The estimated date for beginning the work is December 9, 1986. If you have any questions concerning this application, please contact Susan Brown at (907) 263-9613. Very truly yours, D. L. Yes land Manager, Regulatory Affai rs Alaska Division SBB/kka Enclosures RECEIVED 1986 Alaska 0il & Gas Cons. Commission Anchorage SBBD/aogcc.5a STATE OF ALASKA ~ ALAS .. OIL AND GAS CONSERVATION COM ,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request' Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter casIng [] T~me extension C Change approved program ~ Plugging [] Stimulate ~ Pull tubing [] Amend order ~ Perforate ~ Other [] 2 Name of Operator 5 Datum elevation (DF or KB) SI-ELL I~:STERN F__&P INC. 105 ' DF feet 3. Address 6 Umt or Property name 601 ~est Fifth Avenue, Suite 810, Anchorage, Ataska 99501 Midd]e Ground Shoal 4 Locahon of well at surface Platform "C", Leg 1, ~uctor 4. 4739.0'S & 1591.0'N of NE corner of Section 23, TSN, R13W. S.M. 7. Well number £ ?&-26 Rn At top of productive interval 4327 S& 1176 N of surface ]ocatJon At effechve depth 5085S& 1205 W of surface location At total depth 5101 S & 1205 W of surface location 8. Permit number 68-3 9 APl number 50-733-20078 10 Pool "G" Poo! 11 Present well cond~hon summary Total depth: measured true vertical 11,216 feet Plugs (measured) feet Effective depth, measured 1 1,079 true vertical feet Junk (measured) feet Camng Length Structural Conductor Surface 1875' Intermediate 9100' Produchon 2317' L~ner Perforation depth, measured S~ze Cemented 10-3/4", 40.5#, J-55; 7", 26-29#, N-80; 5", 18#, N-80; Measured depth 1550 sx 500 sx 242 sx 10,692-11,096' (5 intervals) True Vertical depth 1875' 9100' 8881-11,198' true vertical 9,274- 9,671' RECEIVED Tubing (size, grade and measured depth) 3-1/2" 8858' (MD) Packers and SSSV (type and measured depth) packer @ 8~/88' C 0 z,. 1986 ~.,,~ ,,m,SSiOrl Alaska 0il & Gas Con's "","~ Anch0rafie 12 Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] 13 Esbmated date for commencing operation December 9, 1986 14 If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoLng is true and correct to the best of my knowledge Signed ¢;~'~ ~'-. ~ Title P~.nH,,c-l-inn c;,,n~r, in'I'~nH~n-I- Commission Use Only Date Cond)tlons of approval Approved by Notify commlss)on so representative may witness [] Plug ~ntegnty [] BOP Test [] Location clearance Commissioner Approval No ~ / ~ by order of /,~/ the commission Date //~¢~r "~'"'- Form 10-403 Rev 124-85 Subm)t in triplicate PROGNOSIS PERFORATE OR-OS and HD-HE NGS C24-26RD STATUS: Producing 29 BOPD, 81% water 152 BFPD 10-13-86. SCHEMATIC: See attached. PERFORATIONS~ ZONE HK-HN (U) HN-HR (U) HN-HR (L) HR-HZ (U) HR-HZ (L) INTERVAL £C£1v£D 10770-10820 ' 10878-10964 "- 10986-1103~,/a~'~ 0fl ~ ~,~ ~?~,,,~ 11083 11096 '~c~or~,'ci~ C°'~mis~ion NOTE: Place well in test 24 hours before commencing perforating operations. Leave well in test throughout operation. PROCEDUREs 1. RU slickline and pull SSSV. With slickline make a 2.7" drift run to EOT. POOH and RD. 2. RU service company and pressure test lubricator to 1000 psi using a 1" high pressure line from an ad3acent injector wellhead. 3. RU service company to perforate with two shots on a 2-1/8" bar gun with the shots spaced 4' apart. These two charges should be mounted in the center of a 10' perforating strip. Place one weight bar above gun and decentralize with a magnet. This configuration should allow easy movement within the tubing and casing. 4. Choke well back or SI before RIH as deemed necessary by Operations Foreman and RIH. Once the tools are below EOT place well back on full production. It is important that SI time, if any be minimized. ~ 5. With well on test, gas lift well until it is operating close to its normal lift depth (normal casing pressure). Normal casing pressure is 765 psi. 6. Perforate HD-HE with two shots at 10348' and 10352'. Use CBL (cement bond log) ran 12-14-79 for casing collar tie in. 7. Flow well for 1 hour before POOH. Wh~le POOH choke well back or SI as deemed necessary. 8. RD service company. 9. Test well for 12 hours taking hourly water cuts and production rates. 10. Production Engineering will consult with Production Foreman to determine if additional testing or perforating is warranted. Datum 34' C 24-26 R.D. Item 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Description PSI Otis Ball Valve Nipple 3 1/2" Camco KBM Mandrel 3/16" 3 1/2" Camco KBM Mandrel 3/16" 3 1/2" Camco KBM Mandrel 3/16" 3 1/2" Camco KBM Mandrel 3/16" 3 1/2" Camco KBM Mandrel 3/16" 3 1/2" Camco KBM Mandrel 1/4" 936 945 945 945 940 985 3 1/2" Camco KBM Mandrel 1/4" 975 3 1/2" Camco KBM Mandrel 3/8" valve (Empty} 7"X3 1/2" Guib. 29# Unipacker VII MD +314 ~229 4304 5003 6963 7728 8342 8684 8751 8788 3 1/2" Joint EUE 8 rd 30' 9.3# 8796 3 1/2" Otis X-Nipple 2.875" I.D. w/standing valve 8826 3 1/2" Joint EUE rd 30' 9.3# 8827 3 1/2" Shearout Ball Sub {3000#} w/Mule shoe guide 8857 Fishing neck bent or broke 3/8" Orifice Valve Tubi 3 1/2" EUE 8 rd 9.3# N-80 Total joints 287 0-8858 CasinO Detail 10 3/4" 7" N-80 Buttress 23# " 26# " 29# 5" Hydrill FJ (liner) 18# 0-1875 Tubin(] Weight on Hook _ 0-4047 4047-7688 UP - 105,000# 7688-9100 DOWN - 70,000# 8867-11198 HK-HN HN-HR HR-HZ PZ, TD lll60' 10692-10727 (35' g 4 holes/ft.) 10727-10742 (13' @ 8 holes/ft.) 10770-10820 (50' @ 4 holes/ft.) 10878-10964 (86' @ 4 holes/ft.) 10986-11036 (50' ~ 4 holes/ft.) 11083-11096 (13' ~ 4 holes/ft.) (' 11. If additional perforating is warranted, perforate the entire interval by repeating steps 2 thru 8 perforating the zone from 10342 to 10358' 4JSPF with one 16' gun. 12. Leave well on test for 12 hours taking water cuts and total fluid production measurements every two hours. Based on 12 hour test Productzon Engineer and Production Foreman will determine if more perforatzng should be done. 13. If further perforating is warranted test the GR-GS zone as done in steps 2 thru 10 with two shots at 9946' and 9950. 14. If additional perforating is warranted the GR-GS will be perforated 4JSPF in two runs from 9917' to 9954' and from 9958' to 9966' as in steps 2 thru 8. Flow well for one hour between runs. 15. Test well for 12 hours taking water cut and total fluid production measurements every two hours. Based on 12 hour test Production Engineer and Production Foreman will determine if additional perforating is warranted. 16. If additional perforating is necessary the HN-HR (1) zone will be reperforated from 10928' to 10964' 2JSPF with one 36' gun as done in steps 2 thru 7. 17. Place well in test for 24 hours and report results to S. Mo ~\~¥ Logan. Recommended: February 23, 1984 Shell Western E&P Inc. A Subs~d~aryof Shell Od Company 200 N Dairy Ashford P O Box 527 Houston, TX 77079 Mr. C. V. Chatterton Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501-3192 Commission Dear Mr. Chatterton- Enclosed for your information are the following eleven reports submitted in duplicate' Middle Ground Shoal Field Well No. A12A-01 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations Well Completion Report Middle Ground Shoal Field Well No. C24-26RD Sundry Notice-Subsequent RePOrt of Stimulation & Stimulation Middle Ground Shoal Field Well No. C34-26 Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. A13-12RD Sundry Notice-Subsequent Report of Stimulation Seal Island Wildcat Well BF-47#1 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations Sundry Notice-Subsequent Report of Abandonment Well Completion Report & Testing Seal Island Wildcat Well OCS Y-181 #1 Sundry Notice-Notice of Intention to Change Plans (in Please maintain the confidentiality of this information. triplicate) RGH'mh R. G. Hollis Manager Production Administration Pacific Frontier Division RECEIVED Attachments FEB 2 7 1984 Gas Coqs. C0m,~ssbm STATE OF ALASKA ALASKA('~,L AND'GAS CONSERVATION (3~r AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I:] COMPLETED WELL OTHER [] 2. Name of Operator Shell Western E&P, Inc. 3 Addre~ 601 West 5th St., #810, Anchorage, Ak 99501 4. Locat,on of Well Platform C, Leg 1, Conductor 4, or 4739.0' $ & 1591.0' N of NE Corner Sec. 23, T8N, R13W, SB&M m 12. I6. Lease Des,_qnat,on and Serial No. ADL 18756 7. Permit No. 68-3 8. APl Number so- 733-20078-01 9. Unl~tGo~ Lease Name 10. V~ell Number 24-26 RD 11. Field and Pool MGS "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Tr,phcate) (Submit in Dupl,cate) Perforate [] Alter Casing [] Perforat,ons [] Alter,ng Casing [] Stimulate [] Abandon [] St,mulation ~ Abandonment [] Repa,r Well [] Change Plans [] Repairs Made [] Other [] Pull Tubmg [] Other [] Pulling Tubing [] (Note: Report muir,pie complet,ons on Form 10-407 w,th a subm,tted Form 10-407 for each complet,on.) 13. Describe Proposed or Completed Operations (Clearly state all pert,nent details and g,ve pert,nent dates, including est,mated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposal' Acid Stimulate 1/13/84 1/14/84 1/15/84 Rigged up Artic Coiled Tubing and Dowell on C-24-26. Ran in with CTU. Spotted 2000 gal xylene across perfs @ 11096-10692'. Spotted 600 gal 10% HCL, 1200 gal Mud Acid and 600 gal 10% HCL across same interval. POOH with CTU. CTU parted on surface with 4600' left in hole. Rigged up welder to fix tubing. Completed repairs on CTU. POOH Rigged down and RTP.~ RECEIVED FEB 2 ? ]984 Alaska 0ii & Gas C,,n:~ Commission Ar, r;horage 14. I hereb/~rt,fy that.the foregmng ,s true and correct to the best of my knowledge. S,gned f/,'}~/~--~ T,tleDiv. Prod. Adm. Hgr. The space below for Corem,ss,on use 2/9/84 Cond~t,ons of Approval, if any Approved by By Order of COMMISSIONER the Commmss,on Date Form 10-403 Rev. 7-140 Submmt "lntentmons" in Tr,phcate and "Subsequent Reports" in Duphcate STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No Shell 0il Company 68-3 3 Address 8 APl Number Wayne Simpson, 601 West 5th St., #810, Anchorage, AK 99501 50- 733-20078-01 4 Location of Well Platform C, Leg 1, Conductor 4, or 4739.0' S & 1591.0' N of NE Corner Sec. 23, T8N, R13W, SB&M 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 105' DF 6. Lease Des,gnat,on and Serial No ADL 18756 9 Umt or Lease Name NGS 10 Well Number C 24-26 RD 11 Field and Pool MGS "G" Pool 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF (Submit m Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altermg Casing Stimulate f~X Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each compleuon ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, mclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See Attached. o~ Fom~ No. RECEIVED JAN ! 9.1984 & Gas Cons. Comr~is,~lo~ A.".chcrago 14 I hereby c.,p~t~fy that~the foregoing ~s true and correct to the best of my knowledge S,gned u\f~ ~/~Y' T,tle Mgr. Prod. Adm. The space below for Commission use Date 1/4/84 CondItions of Approval, ~f any Approved by BY LONNi[ C. SJil'llj Approved CoP7 Returned By Order of COMMISSIONER the CommIssion Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duphcate Solvent Wash Acid Stimulate C24-26Rd Platform C Middle Ground Shoal Field Status: Well shut in. Capable of producing 16 BDO, 85% cut. Mechanical Details: See attached schematic. Purpose: Solvent wash and acidize C24-26Rd. Procedure: le Rig up wireline. Test lubricator to 3500 psi. Make drift run to bottom and record depth. P.O.O.H. and rig down. e Shut well in for 12 hours prior to acidizing. M.I.R.U. coiled tubing and acidizing equipment. Test lines, tree and coiled tubing to 5000 psi. Test hydraulic system and B.O.P~ Test acid concentrations and compatibility according to acid test procedure. Filter all fluids through a 2 micron filter. e R.I.H. with coiled tubing while pumping diesel at minimum rate to 11,096'. Pump following acid treatment. Stage Fluid Volume I Xylene Solvent 2000 gal. 2 10% HC1 600 gal. 3 7½% 1½% HC1 HF 1200 gal. 4 10% HC1 600 gal. Pump treatment at ~ Bbl per minute. Move coiled tubing across entire interval (11,096'-10,692') during each stage of acid treatment. e Displace acid to end of coil with diesel. Over displace by 5 Bbls to flush coil. P.O.O.H. Rig down. Be Place well on production. Produce at least 48 hours or until well cleans up. Obtain good 12-hour production test after well cleans up. Approved Date RECEIVED JAN 1 91984 Oil & Gas Cons. Commission A~:,hc;ago C 24 - 26 R,D, DATUM 34' Item # Descri'ption -- 1. Otis Ball valve nipple 2. 3½" Camco KBM Mandrel 3. 3½" Camco KBM Mandrel 4. 3½" Camco KBM Mandrel 5. 3½" Camco KBM Mandrel 6. 3½" Camco KBM Mandrel 7. 3½" Camco KBM Mandrel 8. 3½" C~mco KBM Mandrel 9. 3½" Camco KBM Mandrel 10. 7"X3½" Guib. 29// UniPacker VII 11.. 3½" Joint EUE 8 RD 30' 9.3# 12. 3½" Otis X-Nipple 2.875" I.D. 13. 14. PSI MD +-314 3/16" 936 2229 3/16" 945 4304 . 3/16" 945 5003'' 3/16" 945 6963 3/16" 940 7728 1/4" 985 8342 1/4" 975 8684 3/8"val Ye 8751 8788 8796 8826 3½" Joint EUE 8 RD 30' 9.3# '8827 3½" Shearout Ball sub (3000#) w/Mule shoe guide 8857 Tubin9 Detail 3½" EUE 8 RD 9.3# N-80 Total joints 287 0-8858 Casing Detail 10-3/4" 0-1875 7" N-80 Buttress 23// 0-4047 " 26// 4047-7688 " 29// 7688-9100 5" Hydrill Fj (liner) 18// 8867-11198 Tubing Weight on Hook UP - 105.000// DOWN - 70,000// HK-HN 10692-10727 (35' @ 4 hole/ft) 10727-10742 (13' @ 8 hole/ft) HN-HR 10770-10820 (50' @ 4 hole/ft) 10878-10964 (86' @ 4 hole/ft) HR-HZ 10986-11036 (50' @ 4 hole/ft) 11083-11096 (13" @ 4 hole/ft) PBTD ll,160' Page 103 C ¢ ( WESTERN E&P OPERATIONS MIDDLE:GROUND SHOAL FIELD PATTERN POS 1144! ADL 1175S Sl2lk. SHELL-ATLANTIC-STANDARD SIS I I I I I I · INJECTION WELL PRODUCING WELL P.A. PLUGGED & ABND. i to 4o,oo t___SC"'"-AL-~ IN FT.: RECEIVED 1984 2vPCO~ Oil & Gas Cons. Commis,~ion Ap, chcrago A /3 -tz- ~p ) ,,4 ~zA--ol Vi'. F. SIMPSON 1982 Wo 1~o l~rshall Divi sion Production Marmoer Pacific Frontier Division Shell 0tl Company P.O. Box 527 Houston, Texas 7700! Dear #r. Narshal 1 ~ We have received your letter o£ September 16, 1982 concerning a waiver of Sec. 20 AAC 250240 for the C24-26RD well in the Middle Ground Shoal Field. ~he Ce~etsston has revtMd the tn~ection and production histories in the area of the subject well in response to your request. By this letter, the Alaska Oil and Gas Conservation ¢onmtsston acknowledges your application for waiving the lO00-1 gao-oil ratio limitation for the C24-26RD wll in the )ttddle C~ound Shoal Field and hereby waives the limitation imposed in Sec. 20 AAC 25.240 since this ~ell is producing from a pool that has an approved additional recovery project. Yours vsry truly, BY OI~DER OF T~E CO~MZSSION Shell Oil ~y Alaska Operations SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON, TEXAS 77001 PLEASE REPLY TO February 11, 1982 500 W. International Airport Rd. Anchorage, Alaska 99502 601 W. 5th Avenue Suite 810 Anchoraqe, Alaska 99501 Attention: Production Superintendent Gentlemen: Enclosed are 1 BLprintsof the Company Shell Oil Company Field Middle Ground Shoal ENG~ PRODUCTION DOG , Well Middle Ground Shoa~.. C,24-26 RD ~ , County Kenai St6te Alaska on: Additional prints are being sent to: 1 BL prints ~qh~l I Oi ! Ccxnpany/Pacific Division P:O: ~ox 831 ~ ~.~n; T~_w~ ~ 7700]' A±tent i on :- v_~_ .Scott 1 RFolded Sepia 1 BL prints Atlantzc Richfield Ccmpany P.O. Box 360 Anchorage, Alaska 99510 Attention: J.W. Hart 1 BL prints Shell Oil Ccmpany North Star Route 1 Box 485 Kenai, Alaska 99661 1 BL prints Amoco Production O2mpany P.O. Box 779 Anchoraqe, Alaska 99510 Attention L. A. Darsow 1 BT, prints Shell Oil Company Western E&P Re~ion P.O. Box 576 Houston: Texas 7700~ Attention: E & P Files 1 RRolled Sepia ~rlnts ~]n~Ton U.R.A. P-_O: l~ 7-Rqq Anchorag~ A] ask~ 995]0 S.ta.te of Alaska Div_ision of Oil & _ Gas Conservation 300_1 Porcupine Drive ~Anchora~ge, Alsska 99510 prints The film is..returned to Shell Western E & P Region We appreciate the privilege of serving you. Date N3s~ Oil & Gas Cons. Commission Anchorage Very truly yours, SCHLUMBERGER OFFSHORE SERVICES SOS--! 565-A DISTRICT MANAGER September 23~ 1980 State of Alaska Alaska Oil and Gas Conservation Commision ATTN Mr. H.W. Kugler 3001 Porcupine Drive~ Anchorage,.Alaska 99 Shell Oil Company Gentlemen: Attached are the necessary reports for wells C-24-26 (redrill), A 12-1 (reperforate), and A 34-14 (convert to injection). Forthcoming are reports on A 11-13 (P&A) and A 14 A-1. Please excuse the delay. Yours very truly, G.L. Sauer Division Production Engineer Pacific Division EDS:crj Attachments SUBMIT IN DUP STATE OF ALASKA ',See other OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* TYPE 0F WELL: ozt, "ELL~ WELL ~ V~V ~ Other TYPE OF COMPLE~ON: ~[~ ~ ~o~ ~ o~,- Redri 11 BACK EE~VR NAME OF OPERATOR - Shell 0il Company .... 601 W. 5th Ave., Suite 810, Anchorage, Alaska' LOCATION OF WELL (Report location clearly and sn accordance with any State requirement·)* At,u~,c, Platform "C" leg 1 conductor 4, or 4739.0'S & 1591.0'N At top prod ,Bter~,, report~ be,o, of NE corner Sec 23-T8N R13W SB&M 12/8/79 : 1/8/80 05' DF MLLW , :ri. ROTARY TOOL8 13 DATE SPUDDED 9/27/79 18 TOTAL DEPTH, M_D & TVD [lg PLUG B~a. CK MD & ~O~. ~ ~LT~ ~L., 11,216J ~ ll 160 PRODUCING ~'r~VAL(S), O~ ~S ~MP~TI~~, ~M, 10692-10727 10770-10820 10906-11036 10727-10724 10878-10964 11083-11096 ~ ' ' TVD)* ~ ORIGINAL AP1 NU~F. kIC~AL CODE 50- ~3t 20078 -o~ ~ = LF4,.SE D~IGNATION AND SERIAL NO ADL 18756 iF INDIA.N, ALLO-A-r~:;,~ OR TRIBE NA.M~ None UNIT.FA.H.M OR LEASE NA_M.E Middle Ground Shoal WEI~ NOo ~ C-24-26~ 10 Fr~.n A.ND POOL, OR wrI-~.AT MGS "G" Pool 11 SI/~C., T., R , M , (BOTTOM HOLE OBJECTIVE) Sec 26 T8N R13W 12 PER2VIIT NO. RT, GR, ~PC)* [17. ELEV CASINGHEA.D . - INTERVALS DRILLED - - [ ' CABLE T00L~ ~. ]~. W~ DI~ON~ - .. SURV~ Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN . BHC/GR DIL/SP CASING SIZE 10-3/4" 7" CBL" '" _ i II CASING RECOP,.D (Report all strmgs set in w~ll) 40,5 J-sS/ 1875' 15" LINER R~COI:~D SIZI~ TOP (MD) BOTTOM (MD) [ SACI(S CEM~qT* I 5"' " 8867' 11,1"98 ! 242 ! ~ i ~~~T,~U~(~5 ~~, ~~ o~c~O~l e}~7, .i, size and number) - . 0 10727-10742 (]3' @:8 hole/ft) 10770-10820 (50' @ 4 hole/ft) 10878-10964 186' ii hole/ft1 10906-11036 50' hole/ft · ll0R3-ll09§ _13' hnl¢/ft. · o C~~G RECOP. D I AMOtrNT PULLED 1650 sacks t Nnne 500 sacks None ' 27 TUBING R]DOORI) SIZE [ DEPTH S~T (Mm) j PACKER SET (lVI'D) I III I ·111 ACID, SHOT, F2.A.C-I'O'RE, C'EJVII~NT SQUEEZE, ETC D]~>'I'H nTTERVAL (MD) A~OUN'r ram m-m~or, ~,~A_L us~:o !980 DATE FIRST PRODUCTION 1/8/80 30 PRODUCTION -_ f'~[~'q Ot' (~, -- [l~RODUCTl°N ME'IHOD (Fl°wLr~'gaSh/t' pumping-size andtype°f punlp)Gas_ Lift D~[ 0~ ~[ar, HO~S T~ '[~OXE SIZ~ [PROD'N FOR O~BB~ G~MCF. WA~B~ [ G~-O~ ~O 1-14-80 8 hours 1128/64 ] ~ 310 432 - 1395 31 DISPOSITI0~ OF GAS (Sold, used ]or ~ueI, vented~ etc.) _ I lJ?ed_~ nrr~.~ l~r T.C. 0doms , *(See Instructions and S~ces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is des,gned for submitting a i:omplete and correct well complet,on report and log on all types of lar~::ls and leases ,n Item: 16: Indicate wh~ch~elevation is used as'~eference (where not otherw,se shaven) for depth measure- ments given in ctber spaces on th~s for'm and in any attachments. -' , ~ ~ ' ' ' ~¥ ~eparato productior~ from more[ than one ~nterval zone Items 20, a~d 22':: If th,s well is completed. ,fc~?" (mulhple complehor~). 'so state. ~n item 20, and in item 22 show the prc.~uc~ng interval, or ~ntervals, lop(~), bottom(s) and name (s) Of any) for only~the interval reported in 'item 30. Submit a sepaiate [eport (page) on this form, adequately idenhfied, for'each' additional interval to be seperately produce:l, show- ~ng the additional data perhnent to such, interval. Item26: "Sacks Cement": Attached supplemental re/cords for this well shbul.~~show the details of an~ mul- tiple stage c. ementing 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 instrbction for items 20 and 22 above). 34 SUMMAHY OF FORMATION TESTS iNCLUDIN(~ INTERVAl., ~O. PRESSURE DATA AND RECOVERIES OF OIL. ~ ' G~I~ MAR~ WA'I~ AND MUD ~ - . _. . t c N~ ; ~ , , ~,' ' E Po 9588' 8225' , None Si n~e Redri 11 ~ -- ' F Pool 9976' 8553' : 8848 , ~ G Pool 10322' ~6 CO~E DATA. A~ACII BHIE~ ~CRIPI~O~S OF L1THO~GY., ~ROSITY. FRA~R~. APP~T DIPS ,~D DKPEC~'EI) SIIOWS OF OIL, G~ OR n i None .: - ~ , , ( t co,,?~ ,+,- ^,t-,'*' (?''' I I Shell Oil Company September 8, 1980 I-I co^,~~ 196 South Fir Street I 4 ENG ' ' Ventura, Cahforma ~ ~GSOL . o ~ox .~04~ wo, ~w~ ~-~ Los Angeles, Cahfor _.1 STAT TEC Telephone (805) ~8-2751 ~ STATTEC I CONFER- ' FILF: Mr. H. W. Kugler State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Kugler~ Enclosed are sepias from Shell Middle Ground Shoal C-24-26 Redrill as per your request. Sincerely, C. H. Soule Evaluation Coordinator CHS:smh cc: G. L. Sauex HO 41:2 (S,4~ P~lnll4 in U.S.A. ~.M~ and/or No, C24-26 RD SHELL OIL COMPANY WELL COMPLETION REPORT __ Platform ENG. SWS SUR. ~- PETRO. CSG. DTL. --- corolla1' Field Alaska Shell Oil Company MIDDLE GROUND SHOAL SL~ud&nS Date Core,Intron Date Elevauon Tatal Delsth ptugged Back De~h. ~rker Horizons 9/27/79 1/8/80 105' K.B. 11,216 iiii Depth lnterv&l Produced · "casI, nS 5 "liner '*tubmf w.s.o.~ S~ueem ~ Pedo~o~ cementad at , cemented at t cemented at 0 laude d/htme at ,,, ' cemented thru~erfL at ' ~d/h"-'i at ,11: 91 8, ' to~ at .... ' n~ ~ m 10~386'/11~096' Production Data Gross FlmdoB/D ii ii iiiii1! Clean Od-l/O Cuto~ Gtaviryo°A. P. L Wate~-B/D Salimty. ~ NaCl(t ~ r) fill S~H Tubml ~hce C~in[ .......... Tubm[ C~s~nf ~,ma,~: G P oo 1 Initial Production __ _ Zones Addtl. Prod. Data Calculated Potential Sire_ed ,q,': ¢; 2 2 PO 4A (l~v. ~ I~int~l in U.S.A. M! DDLE GROUND SHOAL D:ILIIJ. D4'G :II.EPOV,.'X' PLATFORM C 24-26RD ¢~m.~ ~ I'~JO0 ~ " (~n~, o, r.~ ' KEN A...! 9/27/79 to 1/8/80 , I ii i~ ~ CREWS ARRIVED ON P~RM 9-27-79. HAD MEETING WITH CREWS ' ON SHELL POLICIES AND PLATFORM SAFETY. HOOKING UP WATER, AIR AND STEAM LINES. ELECTRICIAN WORKING WITH CREWS ON RIG START UP. RIGGED UP DRILL FLOOR. HOOKED UP MUD LINES AND MIXING MUD.RIGGING UP. PICKED UP KELLEY. REPAIRED PUMPS PULLED GAS LIFT VALVE AT 9511'. RIGGED UP TO KILL WELL. MIXED 10.0# MUD. BLED GAS OFF ANNULUS AND TUBING. DISPLACE WELL WITH MUD GOING THRU SEPARATOR. CLOSED WELL IN AND BUILD MUD VOLUME. CIRC. GAS CUT MUD THRU DEGASSER SYSTEMS TO KILL WELL AT 9511' FINISHED KILLING WELL. INSTALLED B.P. NIPPLED DOWN TREE. NiPPLED UP B.O.P.'S. HOOKED UP ACCUMULATOR LINES. INSTALLED 3-1/2" PIPE RAMS. WORKED ON HYDRILL UNIT. REPAIRED CYLINDER ON HYDRILL. OPEN AND CLOSED LEVER. PULLED B.P.V. SET BALL VALVE AT 300' WITH WIRELINE. INSTALLED BLANK PLUG IN HANGER. TESTED BLIND RAMS, PIPE RAMS, CHOKE AND KILL LINES AND CHOKE MANIFOLD TO 3000 PSI. HYDRILL TO 1500 PSI. CHECKED VALVE AND CENTER VALVE ON CHOKE MANIFOLD HAD SMALL LEAK {WILL REPAIR). RETRIEVED BALL VALVE WORKING TUBING AND TRYING TO FREE PACKERS. CIRCULATED AND CONDITIONED MUD. RIGGED UP DIA-LOG FREE POINT. RAN FREE POINT - TOOL STOPPED AT 9531' PO'H FO TUBING CUTTER. RIH WITH CUTTER. TOOL STOPPED AT 95i7'. PULLED UP AND CUT OFF AT 9491'. RIGGED DOWN DIA-LOG. RIGGED UP AND LAID DOWN 3-1/2" TUBING. TUBING COMING WET. MIXED SLUG AND LAID DOWN TUBING.CHANGED OUT TUBING TONGS. LAID DOWN TUBING. PICKED UP HANDLING TOOLS. MADE UP FISHING TOOLS. P.U. 3-1/2" DRILL PIPE. FINISHED OUT OF HOLE. DRESSED OVERSHOT AND CHANGED OUT JARS. RIH TO 3000'. PACKED SWIVEL AND REPAIRED STD. PIPE LINE. RIH LATCHED ONTO FISH, JARRING ON FISH. PIPE PULLED FREE. CIRCULATED UP FROM BOTTOM. NO GAS. POH. LEFT GUIDE flILL CONTROL AND OVERSHOT ON FISH. PU OVERSHOT AND RIH AT DRILL PIPE. RIH U/DIALOG CELLAR LOCATORSTRING SHOT. TOOLS STOPPED AT 9514'. TRIED TO MAKE STRING SHOT BACKOFF AT 9513', WORKED TORQUE OUT OF PIPE AND TRIED TO GET BACKED OFF U~HO SUCCESS. MADE UP SWAGE TOOL AND JARS ON WIRELINE. RIH AND TRIED TO BEVEL OUT TOP OF FISH AT 9491' COULD NOT BEVEL ENOUGH TO GET DIA-LOG SHOT THROUGH, OVER SHOT ~AI1E. LOOSE FROM FISH WHILE TRYING TO UNLATCH FROM SAME. POH. · CONDITION AT ~IE:GINNINQ OFf PERIOD , HOLE C&IINe ~IZE DI3ffTH I,g'r ii 1 6" 9100 11,~16 5" 8881'/11,198' liter DRILL PIPE STRAPPED OUT OF HOLE. (lB' DIFF) RECOVERED l- 7' KBii MANDRAL AND 20' OF 3-1/2" TUBING. LEAVING TOP OF FISH AT 9502'. P.U. 5-3/4" OVERSHOT AT 3-3/4 GRAPLES AND DIA-LOG, WASH OUT SUB. RIH TIGHTENING LODSE JOINTS ON 3-1/2" DRILL PINE. TRIED TO GET OVER FISH. INDI- CATION OF FILL. COULD NOT GET OVERSHOT' TO TAKE HOLD. PLACED OVER- SHOT OVER FISH WHILE DIA-LOG RUNS WASH OUT TOOL. COULD NOT GET TOOL IN TOP OF FISH. REPAIRED BUTTERFLY VALVES ON PUMP SUCTION AND M~ED MUD. FINISHED MIXING 500 BBLS 10.2 MUD. CIRCULATED UP FROM BOTTOM. NO GAS . POH FOR WASH PIPE. OPERATED BOP'S - P.U. WASH PIPE AND TOOLS. RIH WORKED OVER FISH. WASHED OVER FROtl 9502'/9534' (32') WASH OVER SHOE STOPPED GOING. CIRCULATED UP FROM BOTTOM. NO GAS SHOWN. PULLED WASH PIPE OUT OF HOLE TO 5561'. LOST POWER TO DRAU WORKS. ARMATURE AND BRUSHES BADLEY BURNED. WAITED ON MACHINIST TO EVALUATE EXTENT OF DAMAGES . REMOVED ONE MOTOR AND REPAIR SECOND MOTOR WHILE WAITING ON REPLACE- MENT OF MOTOR BEING REMOVED. WAITING ON MOTOR FOR DP. AW WORKS. CIRCULATED MUD AT 6300'. REMOVED MOTOR FROM PLATFOKM "A" AND INSTALLING ON RIG "C". CIRCULATED HOLE AT 6300' WHILE INSTALLING DC MOTOR ON DRAWWORKS. FOUND LARGE CRACK ON DERRICK I~O ON DRILLERS SIDE. CLOSED IN WELL. REPAIRED DERRICK LEG. RIH. CIRCULATED TOP OF FISH AT 9502'. HAD GAS AND OIL CUT MUD. CIRCULATED AND CONDITIONED MUD. CIRCULATED. POH, LAID DOWN WASH PIPE. MADE UP FISHING TOOLS WITH 3 1/2" WASH OVER MILL AND 3 1/2 GRAPPLE. RIH. MILLED OVER FISH. COULD NOT GET HOLD OF FISH. POH. ~AID DOWN FISHING TOOLS. MADE UP 6" USED BIT AND 6" CASING SCRAPER. RIH TO 9502'. PULLED UP. CIRCULATED AT 9470'. CIRCULATED, POH WITH CASING SCRAPER. MADE UP BAKER CEMENT RETAINER. RIH, SET RETAINER AT 9485' PRESSURED UP TO 2000 PSI BELOW RETAINER- NO BREAKDOWN. PULLED OUT 6F RETAINER. DOUELL CEMENTERS CEMENTED UITH 50 SACKS "G" WITH .08 GAL PER SACK D-B1 PLUS .125 GAL PER SACK D-80. CIP AT 4:45 P.M. 10-12-79. POH CHANGED VALVE ON CHOKE MANIFOLD AND INSTALLED CHECK VALVE IN KILL LINE. TESTED CASING B.O.P. CHOKE MANIFOLD UPPER AND LOITER KELLEY COCK TO 2000 PSI, TEST OK. MADE UP DRILLING ASSEMBLY. RIH TO 3000'. TESTED HYDRILL TO 1500 PSI, PIPE RA~S TO 2000 PSI. ACCUMULATOR FAILED, WOULD NOT HOLD NITROGEN WILL RE,PAIR SAM, E ASAP. D.O.G. WITNESSED AND APPROVED ALL OTHER TESTS. RIH TAGGED TOP OF FIRM CEMENT AT gl90'. CLEANED OUT TO 9350". CIRCULATED AND CONDITIONED MUD. POH. CLEANED FLOULINB MADE UP SERVCO 5-1/2 to $-5/B SECTION HILL 6 EACH 4-3/4" DRILL COLLARS AND PICKED UP 12 JOINTS OF HEAVY UALL DRILL PIPE. RIH TAGGED TOP OF CEMENT AT 9350' PICKED-UP 50' TO 9300'. STARTED CUTTING SECTION. MILLING 7" CASING. MILLED TO 9314'. MIXING HIGH VISCUS PILL TO CARRY OUT CUTTING BUT DIDN'T GET ANY CUTTINGS UP WHILE MILLING. WORKED PIPE 2 HRS. GETTING MILL BACK UP IN 7" CASING. PULLED TIGHT AGAIN AT 9220' AND DRUG OFF AND ON FOR l0 STDS. POH. MILL HAD GOOD HEAR PATTERN CUTTING CASING. MADE UP 6" USED BIT, RIH. STOPPED AT 9250'. WORKED AND ROTATED DOWN TO 9342' WASHED DOWN TO 9344'. CIRCULATED AND UORKED PIPE 9270/9300' WIPED HOLE 4 STDS. CIRCULATED AND NORKED PIPE. STILL DIDN'T GET ~P ANY IRON CUTTINGS. POH. MADE UP SERVCO SECTION MILL ~2. RIH STARTED MILLING AT 9314'. MILLING NOW AT 9338'. CUT SECTION TO 9343'. CIRCULATED. REAMED SECTION. POH, PULLED TIGHT FROM 8410' TO 7050'. RIH WITH JET SUB ON 3-1/2" DRILL PIPE. JETTED SECTION FROM 9300'/9343'. CIRCULATED AND CONDITIONED MUD. HUNG DRILL PIPE AT 9347' DOWELL CEtIENTERS PUMPED 10 bbls. PRE-FLUSH AHEAD OF 65 SACKS GTW .~3 GAL PER SACK D-BO t~. 17.2 PPG. C IP AT 12:45 A.M. 10-17-79. POH. W/O CEMENT. SLIPPED DRILLING LINE, WORKED ON KELLY SPINNER. BRAKES ON SANDLINE REEL. CHANGED BLADDER'S IN ACCUMULATOR CHAMBER. TESTED CASING TO 2000 PSI, TESTED OK. INSTALLED TEST PLUG TESTED BOP CHOKE LINES, VALVES, UPPER AND LOWER KELLY COCK, CHECK VALVE AND 3-1/2" PIPE RAMS TO 3000 PSI. TESTED HYDRILL TO 1500 PSI. TESTED ACCUMULATOR FUNCTIONS. ALL TESTED OK. MADE UP 6" BIT AN~ DRILLING ASSEMBLY. RIH. LOCATED TOP OF FIRM CEMENT AT 9220' CLEANE~yOUT~ TO 9305'. CIRCULATED AND CONDITIONED MUD FOR ~YRO SURV . CIRCULATED HOLE CLEAN. POH RIGGED UP SCIENTIFIC EYE GYRO, GYROED WELL. I~ADE UP DYNA DRILL ASSEMBLY AND PICKED UP ~8 JOINTS MORE OF 3-1/8" H.W.D.P. RIH. BROKE CIRCULATION. RIGGED UP STEERING TOOL RIH TOO[. STOPPED AT 820D'. CIRCULATED TRYING TO WORK STEERING TOOL DOWN. WORKED STEERING TOOL DO~..-.HOLE ACTING TIGHT. POH WITH EYE TOOL. WORKED PIPE AND CIRCULATED. PULLED UP WORKING PIPE AND CIRCULATED. STUCK PIPE (BIT AT 9195') WORKED STUCK PIPE AND CONTINUED CIRCULATING. RANDI. A-LOG ON EYE TOOL WIRE LINE BACKED OFF FISH AT 9144'. RIGGED DOWN DIALOG. CIRCULATED STARTED ~UT OF HOLE ~3 & 6 GENERATORS WENT DOWN. REPAIRED SAME. POH. LAID DOWN 1 EA. 4-3/4" x 24" MONEL. FISH IN HOLE. (6" DIAMOND BIT 5" DYNADRILL 2 ° BENT SUB 1 Ex. 4-3/4" MONEL) PICKED UP BRONW OIL TOOL FISHING TOOLS. RIH SCREWED INTO FISH. JARRING ON FISH. JARRED ON FISH WORKED FISH DOWN TO 9178'. BIT AT 9230' COULDN'T WORK ~ISH UP OR DOWN, NOR CIRCULATE. RIGGED UP ~IA LOG ON EYE WIRELINE. RIH. BAC[ED OFF FISH AT 9208' POH, LAID DOUN 30' OF FISH (I ea. 4-3/4 x 30' MONEL). LAID DOW~ FISHING TOOLS. MADE UP 6" BIT CASING SCRAPER. RIH TO TOP OF FISH AT 9208'. CIRCULATED ANDCONDITIONED MUD. APPEARS NOTHING ON TOP OF FISH. POH LAID DOWN CASING SCRAPER. MADE UP BROWN OIL TOOL HYDRAULIC PULLING TOOL. RIH SCREWED INTO FISH AT 9208'. PRESSURED UP TO 4750 PSI WITH DO~ELL CEMENTERS. ESTIMATED HYD. PULL 380,000# PULLED FISH TO 5' PULLED SAFETY JOINT INTO. POH, LAID DOWN F~SHING TOOLS (FISH IN HOLE 6 DIAMOND BIT - 5" DYNA DRILL 2~ BENT SUB SCREWED IN SUB-XOVER- PART OF SAFETY JOINT, 25' OF FISH, TOP AT 9199') RIGGED DOWN DOWELL SCIENTIFIC WIRE LINER AND DIA LOG TOOLS. MIXED PIT OF HIG~VIS. MUD FOR MILLING. RIH WITH SERVCO SECTION MILL TO 9100' NOW WAITING ON ORDERS WHERE TO START SECTION. STARTED MILLING AT 9100'. MILLED TO 9125', GETTING SOME IRON CUTTINGS UP. POH. CHANGED CUTTERS IN MILL. ~IH 15 STDS, SLIPPEDAND CUT DRILLING LINE. DOWN 6-1/2 ,RS REPAIRING ROTARY MOTOR. RIH REAMED SECTION FROM 91~!' TO 9125'. MILLED TO 9140'. ~OH MADE UP RR BIT. RI CIRCULATED WORKPIPE 91q0'/9140 CIRCULATED SWEEP PILL. POH. RIH WITH JET SUB-DRILL PIPE. JET FR~M 9100 to 9160' DOWELL ,,IXED 10 BBLs CHEM WASHED FOLLOWED WITH 100 CU.FT. {~7 SACKS)DENSIFIED CLASS "G" CEMENT WITH .23 GAL/SACK DBO 17 PPG. DISPLACEDWITH 2 BB1 WATER 60 BBLs MUD. CIP AT 0050 HR. PULLED l0 STD. REVERSED OUT. POH. ¢ 6 HRS. WHILE HOC. CHANGED OUT CONTROL VALVES ON DRILLER CONSOLE. SLIPPED AND CUT DRILLING LINE. LAID DOWN 15 STDS. DRILL PIPE - 6 HRS; TEST BOP - 3-1/2 HRS; MAKE UP DRILLING ASSEMBLY - RIH, TOP CEMENT AT 8755'- 3 HRS ; CIR. - 2 HRS. DRILL FIRM CEMENT -9-1/2 HRS. DRLG. CEMENT TO 9105 - 5 NRS; POH - 3 HRS; P/U DYNA-ORILL B.H.A, RIH - 4 HRS; RIG UP S.D.C. ORIENT. 2-1/2 HRS: DRILLING WITH DYNA DRILL - 7 HRS; DIRECT WORK - PULLING S.D.C. CABLE - 2-1/2 HRS: FACE D.D. EAST TRIP FOR BIT CHANGE (BRIDGE AT 8280') - 8 HRS: RUN S.D.C. - 2-1/2 HRS: DYNA-DRLG. - 11 -1/2 HRS; DIRECTION WORK - 2 HRS. DYNA-DRILLING - 21-1/2 HRS; SURVEY-ORIENTING - 2-1/2 HRS. DYNA-DRLG. - 8-1/2 HRS; SURVEY RIG DOWN S.D.C. - 1-1/2 HRS; PON LAID DOWN DYNA DRILL MADE UP DRILLING ASSEMBLY NIH - 7 HRS; SLIP DRLG LINE - 1/2 HR. STARTED REAMING FROM 9155/9240' 2 HRS; UNSCREWED FROM KELLY TOP OF FISH AT 15', SCREWED INTO FISH PULLED 6 STDS - TOP OF FISH AT $33' - 4-1/2 HRS. TRIED MILLING OVER FISH. POH. RIH SCREWED INTO FISH, WORK PIPE, JARS NOT WORKING. WAITED FOR DIALOG. MADE UP 2 SHOTS AT lO11' WITH 6 TURN-IN PIPE. COULD NOT BACK OFF. MADE UP AND SHOT RIH TO 2992'. BACKED OFF PIPE. POH LAID DOWN 4 SINGLES. NIH SCREWED INTO PIPE AND UNPLUGGED BIT. JARS.WORKING UP AND DOWN. ELECTRIC CABLE TO R.C. SHORTED OUT - REPAIRED SAME - 3 HRS; SPOTTED 25 BBLS DIESEL, 1BBL EZ SPOT BOOST 1BBL - 15 MIN. WORKED PIPE JARRING UP. CBO SPOT 25 BBLs DIESEL/1BBL EZ SPOT BOOST 1BBL/30 MIN. JARRING UP. JARRING - CB.U. RIM WITH BACKOFF SHOT AND FREE POINT/STOPPED AT TOP OF HWDP. PON. RIH WITH BACK OFF SHOT AND COLLAR LOCATOR. BACKED OFF AT 9056'. DRESSER ATLAS WIRELINE MEASURE MEASUREMENT (FISH) (BIT STAB, 2 MONELS, STAB, 2-4-3/4 DC, STAB, ~-4-3/4 DC.) RIM WITH SCREW IN SUB - SUB, BUMPER JAR, OIL JAR SUB, 2 4-3/4 DRILL COLLARS, SUB ACEL. JAR SUB (~7.36) 3-1/2" DRILL PIPE. RIH SCREWED INTO FISH. (CIRC. AND JAR. - 5 HRS). REDUCED MUD WEIGHT TO 9.7. MIXED 25 BBLS DIESEL 1BBL E-Z SPOT. DISPLACED E-Z SPOT TO STUCK DRILL COLLAR. JARRING AND BOOSTING DIESEL, RIGGED AND RAN FREE POINT. BIT STAB 2 tIONELS,STAB STUCK. WILL TRY TO BACK OFF ON TOP OF STAB ABOVE MONELS 9179. BACKED OFF AT 9179'. BIT,STAB,2 MONELS~STAB IN HOLE. RIGGED DOWN DIA LOG. POH. LAID DOWN DC,STAB. MAGNAFLUX SAqE. CALLED DOG TO ADVISE THEM OF PLUGBACK AND TESTED B.O.P. (RUSS DOUGLAS) RIH OPEN ENDED. CRICULATED~STRAP IN. CHECKED TOP OF FISH. DOWELL CEMENTED WITH 10 BBLS WATER AHEAD, MIXED 50 SACKS "G" CEMENT WITH .23 GAL/SACK D-80 DISPLACED WITH 1BBL HATER, 64 BBL tIUD. 17 PPG SLURRY ¢~? 2130 HRS. POH 12 STDS. REVERSED OUT. PO~. LAID DRILL PIPE. TESTED B.O.P. f~DE UP BOTTOM-HOLE 5 HRS. TIH 8880 SOFT CEMENT B~94' 4 HRS - t~C. WASHED SOFT CEMENT TO 9030'~ 5 HRS - HOC. (TOTAL 24 ~RS. WOC)~1-1/2 HRS - DRILLED CEfIENI TO 910~', 5 HRS - CIRCULATED SLUG PIPE, 3-1/2 HRS - POH MADE UP DYNADRILL. SAFETY MEETING. CUT DRILLING LINE - l-l/2 HRS; RIH - 3 HRS; REPAIR GENERATOR MOTOR (WATER PUMP) - 4 MRS; ORIENT DYNA DRILL - l-l/2 HRS; DYNA DRILLING - 6 HRS; PULL DRESSER IJIPELINE AND PUMP SUIG - l-l/2 HRS; TRIP FOR BIT CHANGE, PICKED UP MONEL - 6-1/2 HRS. 2 HRS. TRIPPING IN HOLE ~,qTH DYNA-qRILL l-l/2 HRS. RIGGING tip DRESSER AN9 RIH WITH WIRELINE 1 HR. ORIENTING DYNA-HRILL 9 HRS.DYNA-DRILLING 2-1/2 HRS. SURVEY AT 9218'. POH WITH DRESSER NIRLINE AND MADE CONNECTION. RIH HAD 4 HRS. DYNA-DRILLING 1/2 HR. REPAIRS ON PUMP #l, HEPLACED ? VALVES & 1 SEAT. 3-1/2 HRS. DYNA-DRILLING. SURVEY AT 9218' WAS AN INCnRRRECT REA~ING POSSIBLY 9UE TO BEING TO CLOSE TO LAST FISH AT 9184' DRILLING POH WITH STEERING TOOL. POH WITH 9.D. CHANGED BITS. RIH WITH D.D. RIGGED UP SAND LINE. RIH WASHED Tn BOTTOM. ORIENTED D.D. DRILLING SURVEY AT 9292'. POH WITH STEERING TOOL (BIT STOPPED DRILLING). LOST POWER T~ DRILLING RIG. P~NER SKID UNIT #5 DnWN WITH PISTON THRU BLOCK HAD A SHORT ALSO IN ~R UNIT UNABLE TO CIRCULATE AT THIS TIME. PRESENTLY W~RKING DRILL PIPE APPR~XIt~TELY 35' OFF BOTTOM. WAITING FOR ELECTRICAL CONTRACTOR TO ARRIVE. WORKING DRILL PIPE. PULLED DYNA DRILL. BACKED UP INTO 7" CASING. WORKING ON PDWER TO RIG. POH WITH DYNA DRILL. LEFT NO. 1 CONE POINT AND NA. 2 CONE AND BEARINGS IN HOLE. CHANGEq OUT 6" KELLY FOR 4-1/4" KELLY. WAITED ON WIND TO DIE DOWN. .MADE UP B.H.A. RIH TO 5090', BREAK CIRCULATION. SLIP & CUT DRILLING LINE. RIH TO 9020'. WORKED nN ELECTRICAL SYSTEM TO MUD PUMP. REAMED FROM g100/9292'. CIRCULATED, POH. LAID DAWN MONEL. t~DE CON-CAVE 6" HILL ON'BOD,T BASKET AND BHA. RIH TO QqEO' BREAK CIRCULATION. RIH HIT TIGHT SPOT AT g200'. STUCK HILL, CIRCOLATEn WORKED PIPE. PULLED 300,000. JARRED FREE. PULLED UP INTO ?" CASING WlT~MILL. REPAIRED MUD PUMP 82. REAMED FROM 9158'/9292'. ~ILLI~:D ON ~.4dCD CUT 2 lr~ET OF HOLE ?0 g294', PO~ LAID DOWN 27 JOINTS OF "E" PICKED UP SAME OF "G" D~ILL PIPE. MADE UP 6" BIT. RIH. BROKE CIRCULATION AT 9030'. RIH REAMED AND DRILLED. POH. REPAIRED RIG ELECTRIC SYSTEM. PICKED UP DYNA-DRILL AND RIH. SLIP AND CUT DRILLING LINE. BREAK CIRCULATION AT 5000'. RIH TO BO50', BREAK CIRCULATION. RIH WITH DRESSER STEERING TOOL AND ORIENTED. DYNA-DRILLING AT REPORT TIME. DRILLING AT 9318'. POH WITH STEERING ~.OOL, TOH, TESTED BOPE. LAID DOWN DYNA DRILL, MADE UP DRILL BIT AND RIH TO 9050' AN~ CIRCULATED. W.O. REPAIR TO SKID ENGINE. POH LAID DOWN BAD DRILL PIPE. POH, LAID DOt'IN BAD DRILL PIPE. HI'DP - PC's. MAKE tip BIT # ll RIH PICKED UP REPLACED DRILL PIPE AND RIH. REAMEQ FRO'~ q268/q318'. DRILLING. POH, RIGGED UP SAND LINE. PICK UP DYNA DRILL. RIH ANn BROKE CIRCULATION AT 5000'. SLIP AND CUT DRILLING LINE. RIH. RIH WITH STEERING TOOL. DYNA-DRILLING. REPAIRED GEN. 3 & 6. ~YNA-DRILLING AT 9371'. POH WITH STEERING TOOL. LAID DOWN 60 J~INTS OF GRADE "E" DRILL PIPE. PICKED UP EXTRA MONEL. RIH, PICKED UP 69 JOINTS qF GRADE "G" DRILL PIPE. RIH TP 9050', BROKE CIRCULATION. SLIPPED AND CUT DRILLING LINE. RIH TO 9386". RIH WITH STEERING TOOL AND ORIENTED. RE~AED FROt~ . q'/q412'. DRILLING WITH DYNA-DRILL. AT 9394' POH ~JITH STEERING TOqL TOH, LAIr1 DOWN BIT #13. PICKED UP (.~) 4-3/4" DRILL COLLARS. AND (5) 3-1/2" HWDP. PRESENTLY TIH. RIH BROKE CIRCULATION AT 5r)O0 and 9100. REAt~ED FROM q34q/q447' DRILLINC. WORKED ON CLUTCH ON SAND LINE. DRILLING AT q503' DRILLING AT 9507' RIH WITH SPEERY SUN ON DRESSER UIRELINE AT 9507'. CIRCULAtE.q, POH. CHANGED MITS AND B.H.A. TRIPPING IN HOLE. RIH, BRC~KE CIRCULATION AT 5qr)rl' end 91qr)'. SLIP DRILLING LINE ' DRLLING RIG ELKCTRI Pfl~.IER Dn~,~N .r)RILLIf~G RIH, DRILLING AT 9559 .... ~ .... AT 9631'. RAN KUSTER SINGLE-SHOT AT q559'. 2,5'" S3OW. SIIRVEY AT 9631' 23° S15W, DIRECTION INCORRECT IN BOTH ) s. RIC~ SPERRY S~N SINGLE SHOT, RIH WITH DRESSER ATLAS. ~) AT 9631' WITH SPERRY SUN SINGLE SHOT. CIRCULATED. POH TO 5446', SECURED DRILL PIPE IN DERRICK. SHUT DOWN OPERATIONS WAITING ON HIGH WINDS TO DIE DOWN - 70-75 t, IPH. POH. TESTED BOPE, CHOKE tIANIFOLD, UPPER AND LOWER KELLY COCK INSIDE BOPE AND STAND PIPE BACK TO HUD PUMPS 3000~ AND HYDRILL TO 1300~ ALL OK. PULLED UP DRILL PIPE -/~ 19 BIT. RIH, CIRCULATED. RIGGED UP EASTftAN GYRO AND RIH, SURVEY STATIONS AT 9587' - 9487' - 9387' - 9287' - 9187' - 9100'. PRESENTLY WAITING ON GYRO RESULTS. CALCULATING GYRO RESULTS, GYRO CONFIRMED SPEERY SUN SINGLE SHOT SURVEYS - RIG UP AND R.I.H. W/STEERING TOOL AND ORIENT - TOP TOOL JOINT LEAKED P.O.H. W/ S.T. AND TIGHTEN LEAK. R.I.H. W/S.T. ORIENT - DYNA DRILLING - POH W/S.T., PICKED UP 60' DRILL PIPE, RIH W/ STEERING TOOL. PI)H, IWlADE UP 60' KELLY - RIU W/ STEERING TOOL AND ORIENT DYNA-DRILLING - SINGLE SHOT AT 9695'. POH W/ STEERING TOOL. POH - REPAIR PUMP #l - W.O. WEATHER TO FLY IN 20 BENT SUB AND DIABIT - RIH W/ 20 BENT SUB ON DYNA DRILL. RIH W/ STEERING TOOL AND ORIENT. DYNA DRILLING - POH W/ STEERING TOOL - POH AND CHANGE OUT DYNA- DRILL AND 20 B.~. FOR 1 1/20 B.S. ORIENT SUB - TIA W/ NEW DYNA- DRILL AND 1 1/2" B.S. TIH W/ D.D.#6 BREAK CIR. AT ~000' /U~ID 9100'. R.I.H. W/ STEERING TOOL AND ORIENT. DYNA DRILL - 9737'/9744' - POH ADJUST BREAKS, POH - L/D DYNA DRILL AND I*,AKE UP NEW DRILLING ASSEMBLY AND RIH TO HWDP. RIG UP AND RAN 1 3/4" ) INST. TO CHECK CLEARANCE IN JARS - OK: SLIP DRILLING LINE - TIH BREAK CIR. AT SO00' - gl00'. RIH TO 9630'. REAM 9630'/9744'. DRILLING, SURVEY, DRILLItlG, CIRCULATING, SURVEY, DRILLIIlG, CIRCULATING. POH CHANGED BITS, TIH I'~ITH BIT #17. DRILLED AND SURVEYED TO 9955'. POH TO RUN DYNA DRILL. TESTED B.O.P., CHOKE t%ANIFOLD, UPPER AND LOWER KELLEY COCK, INSIDE B.O.E. TO 3000 PSI. HYDRILLED TO 150O PSI, TEST OKAY. ~IADE UP DYNA-DRILL. RIH. RIGGED UP DRESSER-ATLAS AND SPERRY SUN TOOLS. IRIENTING AND DYNA-DRILLING. GAS AND OIL CUT MUD WITH,,BOTTOMS UP. TESTED BflE 3 HRS' MAKING UP TOOLS AND RIH 4-1/2 HRS; SLIPPING DRLG. LINE - 1/2 HR; RU DRESSER ATLAS & SPERRY SUN RIH WITH UIRELINE - 4-1/2 HRS; SURVEY - 3 HRS' DD 8-1/2 HRS; StIRVEY NO GOOD. ORIENTED AND DYI~,. DRILLED TO lq,012'. SI~RVEY£1') Ir' .IILE BACK IN HOLE WITH STEERINg, TOOL, TOOL STOPPED I~~ARS. WORKrD WIRE LINE, PARTED WIRE LiNE AT SURFACE. PIJLLE') TOOL LOOSE WITH RIG BLOCK'S. SPOOLED WIRELINE tip ON DRESSER UI'IIT. I:IRCI~LATED. POH WITH DYNA DRILL IqADE UP DRILLING ASSEHBLY. RIH, REAMED DYNA DRILL RUN 9920 TO 10,012. DRILLING AND SURVEYED TO 10,074'. CIRC. POH. NADE UP DYNA DRILL ASSEMBLY, RIH. REAM 30'. RIGGED UP DRESSER AND SPERRY SUN EYE TOOL· RIH ORIENTATED AND OYNA DRILLED TO 10,086'. POH MADE UP DRILLING ASSEMBLY. RIH REAMED DYNA DRILL RUN DRILLING TO 10,142'. SURVEYIFIr~. $~lJCI( SUl~V£¥ ?oo]. ZN J~RS, I~L~I) OUT 0¥ ROI~E $OCY~?. I~OH $UR¥~'~$ ~ OU~ OT J~S, ~Y~D ~ J~S. ~CK~D BIT. D~I~G. ~CO~ B~ 21.5~. G~ V~S~S T~ID O~ OT D~IL~ ~I~ ~ ~UL~ OUT OB BOL~ ~T W/ SURV~ ~L S~CK IN J~S. D~I~ZNG ~ S~V~ ~ 10~297~. ~OH~ ~ ~ 12 JOINS G ~T ~6 GB~. ON ~. SU~V~ AT 10,297* NO G~D. D~~ ~ S~V~ TO 10,528' SURVEYED, POH. TESTED PIPE R~HS BL~N~ RAftS, CHOKE f~NIFOL~, UPPER AND LOWER KELLEY COCK, ~NSIDE BOE AND STAND PIPE TO 3~0 PSI. HYDRILL TO 150~ PSI. TEST OK. CHANGED BITS AND DRILLING ASSEfIBLY. RIH REAMED BO~O~I 45', HAD 2' FILL. DRILLING TO lg,677', BIT STARTED TORQUING UP, NO~9 C~RCULATING. SURVEYED. POH. CHANGED B~TS AND DRILLING ASSEMBLY. RIH. REAMED BOTTOM 30' HAD 5' FILL. ~1 GENERATOR ACTED UP, DOt.JN 1 HR. DRILLING AND SURVEYED TO 10,978'. HEASURED OUT OF HOLE. CHANGED BITS AND BOTTOM STABILIZER. RIH. RE~ED BOSOM 30', DRILLING TO 11,216' SURVEYED, WIPED HOLE TO SHOE OF 7" 9100' RIH, CIRC. CLEAN POH. RIGGED UP SCHLU~ERGER L~GERS. L~GERS ~N DIL-SP, BHC-GR RI~ED ~N LOGGERS. RIH TO 11,216' CIRC. & COND. HOLE FOR LINER. BAKER & HYDRIL MAN CHECKED OUT FLOAT EQUIP. SAID OK. POH, RI~ED UP TO RUN LINER. SHOE & LINER HANGER H~ WRONG THREADS. FLOAT COLL~ WAS OK. 5 HRS. GETTING NEW THREADS ~T ON BAKER HANGER AND GETTING NEW FLOAT SHOE. NADE UP LINER AS FOLLOWING, BAKER FLOAT SHOE 2 JOINTS ~' OF 5" 18~ P-110 HSFJ, BAKER FLOAT COLLAR 50 ~OINTS ~62' OF 5" 18f N-80 HSFj 3 ~OINTS 121' 5" 18~ P-110 HSFd AND 1 JOINT 42'5" 18~ N-80 HSF~ & BAKER LINE NODEL DAL LINER HANGER ON TOP. B&W CEMENT 10' UP FR~ SHOE AND EVERY 3rd ~OINT FOR TOTAL ~ 6. PIPE LOCKED BOTT~ 5 JOINTS, B&W LAP LUG'S ON 1st & 2~ ~OINT BELOW HANGER· RIH W/LINER ON 3 1/2" DRILL PIPE STOPPED AND CIRC. AT 9200'. RIH LINER STOPPED AT 11,198' CIR~. COULDN"T WORK LINER· CIRC. CLEAN. SET LINER HANGER SHOE,AT 11 198' FLOAT COLLAR AT 11,110'· TOP OF ~NGER ~T 8881 , 219~ OF ~INER LAP. DOWELL CEMENTERS PUMPED 50 CU. FT. WATER AHEAD OF 242 sx G W/.23 GAL. PER sx D-80, .03 GAL PER sx D-81 AND .4 GAL PER sx D-108 DISP. W/ 600 CU. FT. MUD B~4PED PLUG W/ ~00 PSI. RELEASED TO 0 PSI, FLOAT HELD CIP AT 3:40 ~ 12-9-79. SET LEAD SEAL, POH, CLOSED BLIND R~'S PRESSURED UP ANNULUS AND CASING TO 300 PSI. HELD UNTIL 2 ~. LAID DOWN 30 JOINTS HWDP AND EXCESS ~ILL COLLARS· RIH WITH 6" BIT AND CASING SCRAPER. BROKE ClRCULA ON AT 8600'. LAID DOWN 39 JOINTS OF 3-1/2" DRILL PIPE WHILE WAITING ON CEMENT. RIH, TAB TOP OF LINER AT 8881'. FOUND NO CEMENT, CIRCULATED. TEST LAP WITH 2100 PSI PRESSURE BLED OFF TO 1400' PSI IN 5 MINUTES AND CONTINUED TO DROP OFF. CIRCULATED, POH. PU FLATBOTTOM MILL AND CASING SCRAPER. (6) 3-5/8" DRILL COLLARS AND 74 JOINTS 2-7/8" DRILL PIPE. RIH, TAGGED SOLID AT 11108'. FLOAT COLLAR CEMENT AT llllO' ATTEMPTED TO CIRCULATED. PUMPED 25 BBLS OF MUD WITH NO RETURN~ TO SURFACE. PULLING OUT OF LINER. SLUGED WET DRILL PIPE, WHILE IN LINER HAD CIRCULATION RETURNS TO SURFACE DRILL PIPE PLUGGED OFF BEFORE FINISHING PUMPING SLUG. PULLED WET DRILL PIPE TO 8700'. UNPLUGGED DRILL PIPE WITH 2100 PSI - CIRCULATED, POH. (2) RUNS WITH DIA-LOG 7" CASING CALIPER TO 8700' TOOL MALFUNCTION BOTH TIMES. RAN SCHLUMBERGER CBL & CALIPER FOR 5" CASING, UNABLE TO GET INSIDE WITH CALIPER TOOL. POH, RAN CALIPER IN 7" CASIN~ WHILE COMING OUT, RESULTS WERE VAUGE ON 7". REMOVED CALIPER ON TOOL, RIH WITH CBL, UNABLE TO SET TOOL BELOW 10,775' (NO STICKING PROBLEM) LOGGED FROM 10,775'/ 8871'. POH WITH CABLE AND RIG DOWN SAME. EVALUATED CBL. TOP OF CEMENT AT 9330', POOR BOND FROM 8871'/9350'. PICKED UP BAKER 5" MODEL EA 43B. .~IADE UP, RIH TO 500'. ~HUT DOWN OPERATIONS DUE TO WINDS 60-75 MPH WITH TEMPERATURE 3~. RIH, REPAIRED ROTARY TABLE CLUTCH AIRLINE. THAW OUT ROTARY TABLE, SET BAKER PACKER AT 8942'. THAWING OUT KILL LINE - ROTARY HOSE AND STAND PIPE. TEMPERATURE 1v. WIND 20-3~ MPH at 5'0q A.M. FINISHED THAWING LINES. PRESSURE TESTED 7"CASING AND 5" LINER LAP 2000 PSI 30 MIN. HELD TIGHT. PRESSURE TESTED 5" LINER ANNULUS 2000 PSI - 30 MIN. HELD TIGHT. PRESSURE TESTED 7" & 5" CASING ANNULUS AND LAP TO 2000 PSI - 30 MIN. HELD TIGHT. CIRCULATED POH AND LAID DOWN BAKER PACKER. PICKED UP 4" FLAT BOTTOM MILL AND CASING SCRAPER RIH ON 3-3/8" DRILL COLLARS AND 2-7/8" DRILL PIPE. SLIPPED AND CUT DRILLING LINE. RIH BROKE CIRCULATION AT 5002~ and 8880' & lllO5'. CIRCULATION{HAD NO FILL IN 5" CASING} POH. TEMP. 2~. WIND lO-15 MPH AT 5: A.M. 12-14-79. POH, CIRC., POH L/D MILL AND SCRAPER AND 3 5/8" DRILL COLLARS. RAN CBL. TOOL, FAILED. FLEW OUT ANOTHER TODL, RAN CBL TO ll,105', FOUND CEMENT TOP AT 9350', BOND APPEARED TO BE THE SAME AS FIRST CBL. ON 12-12-79. RIG DN. SCH. - LAID DOWN 6 4 3/4" DRILL COLLARS PICKED UP 6 JOINTS 2 7/8" DRILL PIPE AND RIH TO ll,105'. CIRC. & RIG UP TO DISPLACE MUD CIRC. & WAITING ON TURBINE PUMP REPAIR AND THAWING OUT FILTERED SALT WATER LINE TO METER PROVER TO PROVIDE SALT WATER TO MUD PUMP. PUT 20 BBLS. FRESH WATER SPACER AHEAD OF SALT WATER. DISP. AT 2 BPM FOR 30 MIN. PERIODS W/ 5 MIN. FLOW CHECKS. CIRC. TOTAL VOL. DISP. WATER NOT CLEANING UP - CIRC. 4:30 AM. FLOW CHECK, WELL FLOWED 3/4" STREAM - SHUT WELL IN W/ 75 psi ON DRILL PIPE. PRESSURE TESTED 7" ANNULUS W/ 200 psi, LOST 150 psi IN 30 MIN. TESTED STAND PIPE BACK TO MUD PUMP. LEAK OFF FOR 2000 TO 1850 psi IN 15 MINS. OPEN HYDRILL WELL TRICKLED BACK, ALLOWED WELL TO TRICKLE BACK, TEMP OF WATER PUMPED 32o. POSSIBLE THERMAL EXPANSION HAND TRICKLE OF 0IL AND GAS TO SURFACE. SHUT WELL IN, NO PRESSURE BUILD UP. RIGGED UP TO DISPLACED SALT WATER - OIL - GAS INTO PRODUCTION HEADER, DISPLACED W/ 364 BBLS. OF ll.O PPG MUD, RAN OUT OF MUD. WELL FLOWING 3/4" STREAM - SHUT WELL IN AND MIXED 170 BBLS. OF ll.O PPG. MUD, HAD HARD TIME GET WATER AT 32o TO HEAT ENOUGH AS GEL WOULD YIELD. CIRC ll PPG, CHECKING RETURNS FOUND A SPDT OF lO.O PPG SHUT DOWN PUMP, HAD WELL FLOWING. SHUT IN WELL 100 psi DRILL PIPE PUMPED THRU CHOKE & GAS BUSTER - MUD UP, COMING ARDUND. SHUT WELL IN, NO PRESSURE. OPENED WELL, NO FLOW. PRESENTLY BUILD IqUD VDLUME IN MAIN MUD PIT, SO AS TO UTILIZE SUNOCO DE-GASSER. ' BUILD MUD VOL. TO '~00 BBLS. TOTAL SURFACE SYSTEM. I~IR. OUT GAS CUT MUD - CHECK WELL FOR FLOW, NO FLOW. HAVE ll.1 PPG MUD AROUND ON TOTAL SYSTEM. MIXED 29 CU. FT. OF CEMENT SLURRY, DISPLACED W/ 71BBLS TO PUT CEMENT PLUG AT ll 105'. POH, DRILL PIPE PULLING W~T, PULLED 25 STANDS, TRIE~ TO REVERSE CIR. 2000 PSI, UNABLE TO DO SO. FOUND CEMENT IN 2 7/8" DRILL PIPE, 53 JOINTS CEMENTED UP, CEMENT NEVER LEFT DRILL PIPE. LAID DOWN SAME, PRESENTLY TIH W/ OPENENDED DRILL PIPE TO CIR. WHILE WAITING ON MORE 2 7/8" DRILL PIPE TO ARRIVE. TIH O.E. DRILL PIPE, CIRC., POH. PULLED WET FOR 5 STANDS, PUMP SLUG, POH. PICKED UP 3JOINTS OF 2 7/8" DRILL PIPE RABBIT EACH ONE REPAIR CAT LINE. TIH O.E SLM TO 11,10~: CIRC., LAID 25 ~ACKS OF CLASS 'G", PLUG AT li,lO0', POH.r,~E PULLED DRY. POH TO 44-67' PIPE PULLED WET. REVERSE CIRC. SAW NO CEMENT RETURN. CIRC. POH. REPAIRED CAT HEAD. TRIPPED IN HOLE WITH BAKER MODEL 47B 7' RETRIEVE-OMATIC PACKER. BROKE CIRCULATION AT 5000'. TRIPPED IN HOLE AND CIRCULATED. RU SCHLUMBERGER. MADE 3 RUNS WITH 2-1/8" INNER JET GUN. SHOOT 5 1/2" HOLES FIRST TWO RUNS WERE MISRUI4S DUE TO BLASTING CAP FAILURE TO FIRE IGNITION PRIMER C~RD. SET PACKER AT 8834'. EST. BREAK DOWN RATE AT 2 BBLS PER/MIN. AT 2750 PSI. CALCULATED CEMENT VOLUME PUMPED 20 BBLS OF WATER AHEAD OF 1SO SACKS OF "G" PLUS .23 GALS PER SACK OF D-80 PLUS .03 GALS PER/SACK OF D-S1 PLUS 4 GALS PER SACK DF D 108. NIXED AT 15.6# PER GAL FOLLOWED BY 5 BB OF WATER DISPLACED WITH 396 CU.FT. OF MUD AT 2500 PSI. HIGHEST RATE PRESSURE REACHED DURING SQUEEZE 3800 PSI. PUMP CALCULATED VOLUME SHUT IN 30 MIN/WITH 1600 PSI ON DRILLPIPE. RELEASED DRILLPIPE PRESSURE FLOWED BACK THRU DRILL PIPE 26 C~I.FT. CLOSED IN AND PUMPED BACK 2B CU.FT. HELD 15 MINS. RELEASED DRILL PIPE PRESSURE AND 7" CASING ANNULUS PPESSIJRE. UNSEATED PACKER. STILL FLOWED THRU DRILL PIPE. CLOSEQ HY~RILL AND REVERSED OUT. HAD ll BBLS OF CONTAMINATED MIJQ AND CEHENT BACK, SLUG DRILL PIPE AND POH. PICKED UP 6" BIT AND CASING SCRAPER. TIH TO 8881' HIT NO CEMENT, CIRCULATED, POH. LAIq .r)owN 7" CASING SCRAPER. PICKED UP 5" FLAT STEAM HILL AND 5" CASING SCRAPER AND TIH, CIRC. AT 5000'. TIH, TAGGED CEMENT AT 9040'. CIRC., TEST 5" LINER LAP AND PERFS TO 2000 psi FOR 3q MIN., OK. DRILLING CEMENT STRINGERS, HIT FIRM CEHENT AT 10,122' CIRC DISPLACED HUD W/FILTERED SEA WATER, PRESSIlRE TEST 5" ~INER L~ AND PERFS 2000 psi HELD OK. DRILLING CEMENT, HIT HARD CEMENTAT 10,470'. CEMENT SWIVEL PACKING, CHECK FOR FLOW. NO FLOW. DRILLING CEMENT TO lr)4BO', CHECK FOR FLOW, WELL FLOW 1/4" STREAM. DRILLIMG CEMENT, CHECK FOR FLOW 1/4" STREAM, CIRC. BOTTOMS IJP, HAD GAS BACK TO SURFACE. SHUT IN AND CIRC. THRU CHOKE ANq GAS BUSTER. SHUT IN WELL, TAKE PRESSURE READING. DRILL PIPE 350, CASING 40~ IN 15 MIN. SHUT IN. DISPLACED SEA WATER W/ll.O ppg HUD. CIRC. & COND. MUD FOR SQUEEZE JOB. CIRC., POH, TIGHT SPOT AT 9544'. CIR~ PULLED FREE, CIRC. BOTTOMS UP. POH, LEFT HILL AND CASING SCRAPER IN.~ HOLE AT 10,475' TOP OF FISH, W/O FISHING TOOLS. PICKED UP FISHING TOOLS, RIH ON STAND OF 3-5/8" DRILL COLLARS WHILE LEANING STAND OF 3-5/B" OUT TO LOAD ELEVATORS TOP SINGLE POPPED PIN, FALLING TO RIG FLOOR, STRIKING FLOOR HAND IN HEAD, TRANSPORTED VICTIM TO ANCHORAGE BY HELICOPTER. LAID DOW~! 3-5/B" DRILL COLLARS, SLIP DRILLING LINE, RIH OPEN ENDED W/2-7/B" DRILL PIPE AND 3-1/2" DRILL PIPE TO 10,4~0', CIRC. W/O DRILL COLLARS INSP. CIRCU. LATED- CH~,.,,~ED 3~/8' DRILL COLLARS ~r.~CKED OKAY P..O.O.H. TESTED L CHOKE MANIFOLD ~I AND PUMP LINE5 TO STAND PIPE. UPPER AND LONER KELLY COCKS VALVES INSIDE BOPE AND PIPE RAMS AND BLIND RAMS TO 3000 PSI. HYDRILL TO 1500 PSI CHECKED OK, REPAIR SPINNER HAWKS. MAKE UP BURNISH SHOE - BUMPER - ,JARS ON 3-5/8" DRILL COLLARS. MADE UP 2ND DRILL COLLAR, PIN POPPED ON TOP DRILL COLLAR. LAY DOWN 4 DRILL COLLARS MADE UP FISHING TOOLS(TRI-STATE) ON 2-7/8" DRILL PIPE. RIH. MILL ON FISH ~ 10,475'. CIRCULATING. P.O.O.H. FOUND CHUNK OF WHAT APPEARED TO BE A PIECE OF BX RING LODGED IN END OF BURNISH 5HOE. DRESSED NEW SHOE. RIH. MILL ON FISH ~ 10.,475' CIRCULATED. P.O.O.H. P/U MODEL TO SHORT CATCH OVeR SHOT. RIH. WORKED OVER FISH, PULLED AS THOUGH FISH WERE DRAGING. P.O.O.H. NO FISH. LOOKED LIKE WE CAUGHT A HOLD OF ABOUT 1/2" UP INTO THE GRAPPLES. IWlAKE UP BURNISH SHOE W~BOOT BASKET, RIH, SLIP DRILLINK. LINER. RIH TO 10475', CIRC. MILL OVER FISH, CIRC., POH. PART OF BURNISH SHOE I/AS FLARED OUT W/ A PIECE MISSING ABOUT 2-1/4" x 1/2" LONG OFF THE SKIRT OF SHOE. HAD SqALL AMOUNT OF JlJNK IN BOOT BASKET. W.O.O. MADE lip MODEL 70 SHORT CATCH W/ GRAPPEL. RIH W/2-7/8" rJRILL PIPE ANt) 15 STANr)s OF 3-1/2" DRILL PIPE. SPINNER HAWKS BROKE I)OWN, RIH W/ ROPE. WORKF~ OVER FISH. CIRC., PULLED FISH FREE IT APPEARS. POH DRAGGING. 15/25,r)r)O~s. POH W/ROPE JUST PULLED CLEAR OF $" LINER NOW PI'LLING REGULAR STRING WT. OF 150 M. POH, RECOVERED ALL OF FISH (HILL AND CASING SCRAPER), PICKED lip 5" RET-A-MATIC BAKER PACKER. SLM IN THE HOLE. SET PACKER AT 0127'. TESTED 7" ANNULUS 5" LAP AND PERFS AT .qr)25' TO 2000 PSI. TESTEr) 5" CASING ANNULUS TO 2r)o0 PSI. ALL HELD OK. RELEASEr) PACKER, PIILLEr~ TO 5945', SET PACKER, PRESSURED UP TO 2q~)r) PSI. PACKER WOI!Lr)N'T HOLD EVEN AFTER SEVERAL SETTINGS. POH. L.D. SA~IE. PICKED UP 7" RET-A-MATIC, RIH ON 3-1/2" DRILL PIPE. SET PACKET AT B70q' PRESSURE TESTED 3000 PSI. BLED OFF 200 PSI in 10 MIN. REL~SEr) PACKER. SPOTTED 20 BBLS. WATER AN~ SPOTTED AT B70g'. SET PACKER, PRESSURE TESTED 3500 PSI, 30 MINS. DROPPE~ 2r)0 PSI. SPOTTED 20 BBLS OF WATER AT 5709', SET PACKER PRESSURE 3000 PSI UNABLE TO GET 100 PSI DROP-OFF- REVERSE CIRCULATE WATER. RIH WITH SCHLUMBERGER. SHOT 5 .40 HOL AT gOlO', EST. INITIAL BRRAR OOWN RATE AT 1/3 BBL. AT 4000 PSI WITH ll.2 PPG MUD. FINAL l-l/2 BBLS AT 3750 PSI PUMPED WATER AWAY INTO FORMATION. UNSEAT PACKER. PUMPED 20 BLLS WATER AHEAD OF 100 SACK[; OF #G" PLUS 25 GAL/SACK OF i)-80 + .03 GAL/SK D-S1 + .2 GAL/SACK OF D-lO8. FOLLOWED BY 5 BBLS WATER. DISPLACED WITH 123 SACKS MUD, SEAT PACKER. DISPLACED ALL OF CEMENT INTO FORMATION WITH MAX. BUILD UP. 4650 PSI. FINAL PRESSURE 3830 PSI, SHUT IN AT DRILL FLOOR. WOC. 7 HRS. BLED OFF PRESSURE. REVERSED OUT , NO CEMENT, NO CONTAIMIMATED MUD. POH WITH PACKER. L~.~ RIH WITH 7" BIT AND CASING SCRAP'ER TO TOP OF 5"/~ AT 8867'CIRCULATED BOTTOMS UP AND CONDITIONED MUD POH. RIH WITH 5" FLAT BOTTOM MILL TO CLEAN UP CEMENT IN HOLE. FOUND TOP OF CEMENT AT 904' (31' BELO)'~ 5'-.40 SHOT HOLES) PRESSURE TEST TO 2000 PSI WITH HOLE FULL OF ll.1 PPG MUD. HELD 15 MIN. O.K. CLEANED OUT CEMENT, BOTTOM AT 0088'. RAN TO 10470', ( CIRCULATED AND CONDITIONED MUD, CLEANED OUT JUNK ON ? OF CEtIENT. PLUG AT 10480', CLEANED OUT TO t0,493', CIRCULATED BOTTOMS UP. HOLE APPEARDTO BE FREE OF IRON, CHANGED OVER SYSTEM TO TREATED COOK INLET WATER, SAVE ALL HUD, HAVING FREEZING PROBLEMS ON ALL EXPLOSED LINE. PRESSURE TESTED TO 2000 PSI WITH SALT WATER IN HOLE, HELD 30 MIN. O.K. BLED OFF AND WATCHED BOTH SIDESFOR 15 MIN. FOR FLOW, CLEANED OUT CEMENT. POH WITH 5" CASING SCRAPER. RIGGED UP AND RAN 3-1/2" TUBING STRING AND JEWELRY. FINISHED RUNNING 3-1/2" TUBING AND JEWELRY. LANDED TUBING AT 8858" krT. ON HOOK-UP 105,000~ DOWN 70,000~. NIPPLE DOWN B.O.P. NIPPLE UP AND TEST X-MAS TREE TO 3000 PSI FOR 30 MIN. HELD OK. STARTED GAS LIFTING SALT WATER AT 5:P.M. RIGGED UP SCHLUMBERGER TO PERF. FINISHED GAS LIFTING WELL DOWN TO BOTTOM. GAS LIFT VALVE AT B756'. RECOVERED 304 BBLS WATER. TEST,SCHLUMBERGER, LUB. TO 3000 PSI. PERF INTERVAL 10,692'/10,702 · GAS LIFT AND TEST WELL FOR 7 HRS. REC. 6 BBLS. SALT WATER. PERF. INTERVAL 10702'/10,722' GAS LIFT AND TEST WELL FOR 6 HRS. REC. 1 BBL SALT WATER. PERF. INTERVAL 10,722'/10,742' HK-HN. RIG UP AND LAY DOWN DRILL PIPE, ~LLY, I~DUSE HOLE, ETC. RELEASED (ONE) 6 IqAN DRILLING CREW A1 12 HIQNIGHT 1-4-B0. RIG UP SCHLUMBERGER TEST LUB. TO 1500 PSI, RUNNING IN HOLE WITH (;UN #4, PREPARING TO PERF. HR-H2 INTERVAL llOB3/llOg6'. PERFORATED W/GUN #5 SCHLUMBERGER. PERF INTERVAL 11086 - llO06 (20'). RELEASED LAST 6 I~IAN DRILLING CREW AT 12 NOON 1-5-80. GIIN 45 MISFIRE, RERUN ~fS. ~N MISFIRED AGAIN, ORDER OUT NEW IGMITION CAPS. RERU:~ 6UN ~5. FIRED O.K. RUN GUN ~6 AND SHOT INTERVAL 11006-10386. PUl WELL ON B HOUR PRODUCTION lES1. SHELL OIL COMPANY WEST COAST OPERATIONS _DATA SURVEY SHEET WELL .. C- ';L~- ~b.., ¥'., x,J, SHEET "-- / LOCATION ELEVATION. DATE SPUDDED_ MEASUREr COURSE VERTICAl. DEPTH DIRECTION COL~RSE TOTAL OEPTH LENOTN ANGLE COURSE OF LATITUDE ,t'. DEPARTURE LATITUDE DEPARTURE COURSE TOTAL DEVIATION DEVIATION , r ' NORTH, SOUTH EAST WE~T NORTH BOUTH EAgT ' ~5.~15 3.5 ' 3~.1~ - I ' 3G.~'f5 .5 - I , ~7~ , ,,, , ~ , ill PAl Pill ATI:~ I~V. SHELL OIL COMPANY WEST COAST OPERATIOHS DATA SURVEY SHEET · i I i WELL .. c LOCATION ELEVATION DATE SPUDDED .. SHEET I / i i i i i i i MEASUREO COURSE VERTICAL DEPTH DIRECTION COURSE TOTAL DEPTH LENOTH ANGLE COURSE OF LATITUDE ~'. DEPARTURE LATITUDE DEPARTURE COURSE TOTAL DEVIATION DEVIATION NORTH SOUTH EAST WEST NORTH SOUTH EAST WEST ii i i i i i i ii / ~?_ -n.~ ~'.~,',', .~ X 2o ~ , . ~/ ,~ ~7~ 2q.~75 ~.5 ~. ~5 q ,5 ~q. S ~.o ,, 2~. ~5 ~ 3. C 24.5 ~ ;3.5 3 ~. ~ 5,5 , , , flb~ ~):, z~045 q~ '1& A'~.~,~.,~ ~o ~2. 5 5 ~ ~o , 2-c,O ' I ', .,~ (.) ~.~ %3.5 q ' CALCULATED BY: Form ~qo 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRIL fd ,. AND WORKOVER OPERATIONS'- WELL WELL OTHER 2. NAME OF OPERATOR Shell 0i 1 Company Alaska 0,~ .I. , ~,¢.t'; ,. , 3. ADDRESS OF OPERATOR 601 West 5th St., Suite 810, Anchora§e, ^k. 5. AP! NUMERICAL CODE 50-133-20078--OI 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 7. IF INDIAN-ALOTTEE OR TRIBE NAME NONE 4 LOCATION OFWELL Platform 'C' Leg l, Conductor 4, or 4739.0' S and 1591.0' W of the NE corner of Section 23, T8N, R13W, S.B.& M. 8. UNIT FARM OR LEASE NAME I~iddle Qround Shoal 9. WELL NO. C-24-26 RD 10. FIELD AND POOL, OR WILDCAT MGS 'G' Pool 11 SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 26, T8N, R13W, 12. PERMIT NO. 7 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. SB&M 1. Drilled a 2. Ran DI L/S 3. Ran 5", 1 4. Cemented 5. Tes ted 1 a 6. Ran mi 11 7. Ran 7" ca 8. Ran cemen 9. Ran 5" pa pressure 0, Ran mi 11 1400 psi. nd Surveyed to 11,216' P and BHC/GR logs 11,2i6' - 9100' 8# Liner 8881'/11,198'. liner with 242 sacks cement. p, pressure bled off from 2100 psi - and casing scraper to 11,108'. sing caliper - tool failed. t bond log, 10,775' 8871' - , unable to get deeper. cker. Tested 7" casing and 5" liner to 2000 psi for 30 minutes, held. and scraper to 11,105' POOH 11. Ran CBL, 11,105' - 8871'. 12. Circulated hole over to salt water. Well flowed with drillpipe shut in. 13. Circulated back over to mud. Got small amount of gas and oil back. 14. Mix 25 sacks cement to spot on.]bottom. Displaced with mud. Cement set up in drillpipe. 15. Spotted 25 sacks cement at 11,105'. 16. Perforated 5 holes at 9025'. 17. Set packer at 8834' and squeezed 'away 150 sacks of cement at 2500 psi. 18. TEsted casing to 2000 psi - Held pressure. Changed over to salt water. Drilled cement stringers 9040' - 10,480'. 19. Well Flowed. Circulated over to mud to kill well. 20. POOH. Lost mill and casing scraper in hole. 21. Fished mill and casing scraper. 22. Shot 5 holes at 9010' 23. Squeezed away 100 sac~s cement at 4650 psi, max. pressure. 24. Cleaned out cement 9041' - 9088', 10,480' - 10,493'. Changed over to slat water. 25. Pressure tested to 2000 psi - held ok. 26. Began cleaning' out cement. 14 I hereby cert~'~a~~~_e a~nd correct SiGNEDw.a._F~# A[i~,~.~.__ T1TLEDiV. Prod. Engrg. ,DATE 1/8/80 NOTE-Report on this form is required for each calendar month, regardless of the status of operatior=, and must be filed mn duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SCHLUMBERGER OFFSHORE SERVICES a Div,slon of Schlumberger Limited January 4, 1980 REP~Y TO HLU OFFSHORE Shell Oil Company/Alaska Oper. 601 W. 5th Ave. Anchoraae, Alaska 99501 A,ention. Production Superintendent 500 W. International Anchorage, Alaska Gentlemen: Enclosed are 1BL prints of the BHC/DIL CBL 12/12 CBL 12/14 Company Shell Oil Company ,Well MGS C 24 26 Redrill Field Middle Ground Shoal , County Kenai £tote Alaska Additional prints ore being sent to: _lBL_prints Shell Oil Company North ,qtar ~'1-~_, ] R~ 4R5 Kenai. Ala~k~ 99~11 lB1 prints Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska q95nl _/BL_Drints gh~]l 0il Cnmpany - Fousto. n/ Texas 770nl A'l-:l-Ani-'~ on -' C = ~ -_ T!×~ er ~rints She-l] P_-O_- Box 576 1RRolled Sepia 1BL prints Chevron U.S.A. Inc. P.O. Box 7-839 Anchoraoe~ Alaska 99502 Attention CF ~irkvo]d 1RFolded Sepia l~L~prints Atlantic Richfield ComDanv P.O. Box 360 Anchorage! Alaska 99501 Attention: J.W. Hart _lBL_prints ~h~l] O~l Company P.O. Row 92047 WnrlSway Center Too~Angelos; Ca,if= 90009 Attention W.F.A!!man 1BL prints Amoco Production Company P.O. Box 779 Anchoraget Alaska _99510 Attention :L.A. Darsow The film is. :Re~ed ~ Shell (E & P , Houston) / We appreciate the~r~viJ~g.~ of serving you. so~--,.s-A ~chorage Received By: Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANAGER Form No 10-404 REV. 3-1-'/0 ( ~ SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5 AP! NUMERICAL CODE 50-133-20078-4t 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 7. IF INDIAN'ALOTTEE OR TRIBE NAME None WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 601 West 5th St, Suite 810, Anchorage, Ak 4. LOCATION OF WELL Platform 'C' Leg l, Conductor 4, or 4739.0' $ and 1591.0' W of the NE Corner of Section 23, T8N, R13W, S.B.&M. 9. WELL NO. C-24-26 10. FIELD AND POOL, OR WILDCAT MGS 'G' Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec.26, T8N, R13W SB&M 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT 'END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 1. Recovered Fish to 9179'. 2. Spotted 50 sacks cement at 9179', top of plug 8880'. 3. Drilled cement to 9102'. 4. Drill ahead 6" hole to 9292'. 5. Lost and milled up cones at 9292'. 6. Drill ahead to 10,142'. knel'~or'a,f.l~ .,,, 14. I hereby certlf~~e~rrec t SIGNED ~l- ~ a n n ..... TITLE 1 2 - 4- 79 W , I" . /'5 I I IIIU !1 NOTE--Report on th,s form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Div. Prod. Engrg. DATE Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. Aiq NUMERICAL CODE 50-133-:>0078 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 O,L k-il GAS [--] N o n e ~ELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERXTOR 9. WELL NO. 601 West 5th St, Suite 810, Anchorage, Ak C-24-26 i0. FIELD AND POOL, OR WILDCAT MGS 'G' Pool 4 LOCS, TION OF ~ELL Platform 'C' Leg 1, Conductor 4, or 4739.0' S and 1591.0' W of the NE Corner of Section 23, T8N, R13W, S.B.&M. I I SEC. T R. M. (BOTTOM HOLE OBJECTIVE) Sec.26, T8N, 12. PERMIT NO. 68-3 R13W SB&M 13 REPORT TOTAL DEPTH ~T END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SiDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. , 2. 3. 4. 5. 6. Recovered Fish to Spotted 50 sacks Drilled cement to 9179'. cement at 9179', 9102'. Drill ahead 6" hole to 9292'. Lost and milled up cones at 9292'. Drill ahead to 10,142'. top of plug 8880'. 14 I hereby certlf~a~~~l! ~'~~-~-~1~ t[J~e and correct SIGNED IAI. r. A 1 ,iiiO ii TITLE Div. Prod. Engrg. DATE 12-4-79 NOTE-Report on this form ms requ.red for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unle~ otherwise directed. ,~\' )~ S,-;.--LL O;L ~OP, ACCUMULATOR & CH~;(.- MANI~LD TEST ~tViSION ~"RtG ~~ B~OC~/~IE~O ~ ~ASE & W~ NUMbeR ]T~RATION 2. U N IT APPLIE~ TIME HELD BLEED OFF SCREWS mamfoi~ use~ as · $topl 5 ~GW OUT, Bima ~nms are empmye~ use~ as a stop~ PRESSUR~ - ' P~ Rams ~ Loc~mg w~eels mstallea-- es ~ No P~pe Rams C. Safety Valve Kelt In o~e~ ~osltion7 ~Yes No PRESSURE ~ In.,ae Preventer ~00~ ~ ~ ~ ~ A ' ~, ~ST STRING TOP JOINT S~ze Weight CSG ~ OF CASING CASi NG Pressure on casmg/casmg annulu~ PRESSURE TEST ~y = PSi ........ By = : CLASS TEST PRESSURE VALVES TESTED [ VALVE POSITION -' J XYes ~No ] USED~ Yes VALVE OPERATORS TESTED J ACCUMUCATOR TESTED REMOTE CON~-STA. TESTED P~SS~ R~~,A~, FO ~TEST ~Ye, ~'0~ AS I" "F" ~ yes ~ NO AS ''"6" ~y__ 2E;;TIGHTENED 'DATE) ~. ACCUMU~TOR VOLUME & TYPE I BOTT~ P~R~E PRESSURE . REDUCING & ~EGULA7 VA~V ACCUMULATOR ~~~ _ ~~ .... ........ ~Ye~ ~No ~Y.~ '- H~DRAULIC PUMPS , FLUID OPERATING PRESSURE ~AIR INLET PRESSURE ~ ~o~ com'~o~~,, ~ x~ .~/~,-~_ATM a ~o ~.~ ...... MAN~FOLD ~PERATING FLUID J~OW PRESSURE NO. OF STA~S BLIND RAM CONTROL GUARG Last ChecKeR ~.~ __~ MANUFACTURER Date Yes ~ ~o i CONTRO~ LIN~ TESTED PRESSURE ON LiNE FLOOR ~ Yes [ ' ~ Accumulator & Pump Accumulator Only ' ' Pump'Only ACC~MULATOA ....... ~ RECHARGE ACCdMU LATOR J Pressure Pressure Pressure , .... --., . JINtTiAL FINA~l PERFORMANCE '~yar.' ~, Time INITIA~INA~ ~ Time INI~IA~"FINA~ Time ..... ;'~ST ~q ..... J ~ ~'lt%~~t~'; _ _ ' ....... 1 '' ' Blma Rams · o~.,....~.X ~5~.~~' -_:" 4- .... ~ Bottom Rams [ j ,~-,,,~,..,,c.,,~ ~ ~ ~ / .............; ~-~ ~/I j operateOequip, one X I X I X j ~ I ~ i ~ iD React,ont,me , ~ W~sl ~o/ I~[sl NO I ..... &Gb,PM ENT ~rculat~ng nero on floor Flowhne momtor installed & wet,in our-way valve locke ........ , ,nsme BOPs on floor ~ j IF,l, Up L,ne & Kill Line J J J Wear Bus~ing ~ level l~lct~or mstallea &wor~m Pump stroke counter rip Tan~ ,, ~A~S ........ ' CONTRACT FOREMAN ISHE~ REP~~TIVE Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL ~ GAS [~] 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTHER None 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 601 West 5th, Suite 810, Anchorage, Alaska 4 L~ATION OFWELL Platform 'C' Leg 1, Conductor 4, or 4739.0' S and 1591.0' W of the NE Corner of Sec. 23 TSN, R13W, SB&M. 5. APl NUMERICAL CODE 50-133-20078-al ~ 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 ~ 8. UNIT FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. c-2 -2 10. FIELD AND POOL, OR WILDCAT MGS 'G' Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec.26, TSN, R13W, SB&M 12. PERMIT NO. 6-8'3 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 9-28 to 10-1 Rig up, kill well install & test BOPE. 10-2 Cut tubing and began fishing at 9491'. 10-3 to 10-13 Fishing at 9491' 10-13 Set Cement retai~er at 9485'. Pressured to 2000 psi below retainer with no breakdown. Set 50 sack cement plug at 9485'. 10-14 Tagged cement plug at 9190'. Cleaned out cement to 9350'. Began milling window in 7" casing at 9300'. 10-15 to 10-17Milled window to 9343'. Set 65 sack cement plug at 9347. 10-18-to 10-19Tagged cement plug at 9220'. Cleaned out cement to 9302'. Prepared to kick off through window. 10-20 Stuck pipe at 9195'. Backed off, fish at 9144'. 10-21 to 10-22Fishing. Recovered 30' of fish. Top of fish at 9208'. 10-23 to 10-24Milled window in 7" casing from 91~140'. 10-25 Set 87 sack cement plug at 9160'. 10-26 to 10-27Cleaned out cement 8755'-9105'. 10-28 to 10-29Began drilling out window. Drilled 9100'-9321' with 6" bits. 10-30 Drill pipe unskrewed at kelley. Fish at 533'. Began fishing. 14. I hereby certify th~,.~e~,n~.~:~l~ correct SIGNED?.. ~ 4nh---~'~/~'''-'''v'''F'~''-- TITLE Div. Prod Enqrq. DATE 11-7-79 V"/ · ~ · Z'X.I..I. AtU~/AA " - NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duphcate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No 10-404 · REV 3-, ,70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ( 5 APl NUMERICAL CODE 50-1~3-20078 6 LEASE DESIGNATION AND SERIAL NO ADL 18756 I OIL ~ GAS O 7. IF INDIAN ALOTTEE OR TRIBE NAME ~ELL WELL OTHER None 2 N%ME OF OPERATOR Shell Oil Company 3 XDDRFSS OF OPER-~TOR 601 West 5th, Suite 810, Anchorage, Alaska 4 L~TIO% OF~ELL Platform 'C' Leg 1, Conductor 4, or 4739.0' S and 1591.0' W of the NE Corner of Sec. 23 TSN, R13W, SB&M. UNIT FARM OR LEASE NAME Middle Ground Shoal 9 WELL NO. C-24-26 I0. FIELD AND POOL. OR WILDCAT MOS 'G' Pool II SEC. T R U (BOTTOM HOLE OBJECTIVE} Sec.26, TSN, R13W, SB&M 12 PERMIT NO 68-3 13. REPORT TOTAL DEPTH S.T END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND %OLI. MES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE S, ND s, Ny OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 9-28 to 10-1 Rig up, kill well install & test BOPE. 10-2 Cut tubing and began fishing at 9491'. 10-3 to 10-13 Fishing at 9491' 10-13 Set Cement retai~er at 9485'. Pressured to 2000 psi below retainer with no breakdown. Set 50 sack cement plug at 9485'. 10-14 Tagged cement plug at 9190'. Cleaned out cement to 9350'. Began milling window in 7" casing at 9300'. 10-15 to 10-17Milled window to 9343'. Set 65 sack cement plug at 9347. 10-18 to 10-19Tagged cement plug at 9220'. Cleaned out cement to 9302'. Prepared to kick off through window. 10-20 Stuck pipe at 9195'. Backed off, fish at 9144'. 10-21 to 10-22Fishing. Recovered 30' of fish. Top of fish at 9208'. 10-23 to 10-24Milled window in 7" casing from 9100'-9140'. 10-25 Set 87 sack cement plug at 9160'. 10-26 to 10-27Cleaned out cement 8755'-9105'. 10-28 to 10-29Began drilling out window. Drilled 9100'-9321' with 6" bits. 10-30 Drill pipe unskrewed at kelley. Fish at 533'. Began fishing. 14 I hereby certify ,~~,n~~ cTec, SIGNED · · ~ TITLE Div. Prod. En ~_~_~_.q~~DATE, 11-7-79 NOTE-Report on this form is rOClUir~d for each calender month, r~qlardlm of the status of ol}~ration~, and must bo filed in dUl~iOate with ,ha oil and gas conservation ¢ommltt~ by ,ha 15th of tho su¢¢~Kling month,unlm Form 10-403 REV. 1-10-73 Subml t "1 ntentlons' in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 601 West 5th Avenue, Suite 810, Anchorage 4. LOCATION OF WELL Atsurface Platform "C" Leg 1, Conductor 4, or 4739.0'S and 1591.0'W of the NE Corner of Section 23, TSN, R13W, SB&M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' D.F. (M.L.L.W.) 14. Check Appropriate Box To Indicate NaCre of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ( 5. APl NUMERICAL CODE 50-133-20078-ol 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 7. IF INDIAN, ALLOTTEE OR TRIBE NAME None 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. C-24-26 ~ D 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool 1]. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 68-3 3ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WEI-L FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) , Rc-drill (NOTEz Report results of multiple completion on Well Com~:_-t_lon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Per the 10/22/79 telephone conversation between Shell's M. Woodson and your H. Krueger, a change in our drilling plans has become necessary for our C24-26 redrill. While attempting to sidetrack at 9300', pipe became stuck. Fishing operations were unsuccessful, leaving a 6" diamond bit, a dynadrill, a 2° bent sub, a cross-over sub, a screw in sub, and a safety joint in the hole. (Top of fish at 9199') Our plans are now as follows: a. Mill a section from 9100'/9150'i. b. Lay a cement plug on top of the-fish to the top of the milled section. c. Sidetrack at 9100'~ and redrill per our original proposed plans. An~urage 16. I hereby certify that the foregoing Is true and correct SIGN~ TITLE Production Supt. 23October79 DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE , DATE See Instructions On Reverse Side ~15, 1979 Harold R. To Witness BOP ~ Shell Oil Co. Platfem "{2" C-24-26 Redril 1 ~ 13,. 1~9.79 - I finished safety val~e tests on mhtfom ~" and a B.O.P.E. test on C-24-26 redrill ~as due. B.O.P.E. test'$ ~ at 2z30 AM. ~he sW~xvisor f~ She1! 'C" on the redrill ~as Dan Webster. ~he ~sor on the B.O.P.E. tests ~as Jerry Collir~. The tear's run frcm 2;30 AM t.o 6100 AM. In ~: I witmessed the B.O.P.E. te~t on platfom ~" for Shell Oi/. The feet's were satisf~ with the eweption of the ~lator failure. Shell is to oall our offioe within four days ~ repa/red. .ATTA~$~¥¢ ~0/2~/79 - Dan Webseer called and accuamlat~r wu repaired, two elements ~a~ in~talle~ in the spheres. ( . Alaska Oil and Gas Conservation Ccmmission Field Inspection of Blc%~ut Prevention Equipment Inspector HA Operator ~ation: S~ T R N Drilling Con~a~or Date /~//3/7~ Represen~atiQe ~.~J~y ~'~8~ ~ Permit # ~. Casing Set @ ~/00 ft. Location, General ~.~. Well Sign 0 ~ General Housekeeping ~.~'. Res~_r~ pit Test Pressure BOPE Stack ACCUMULATOR SYSTEM Full Charge Pressure A ? _~-._~ psig Pressure After Closure ~'O~ psig 200 psig Above Pred%arge Attained:__ Ful 1 Charge Pressure Attained: / ConSols: Master Remoto. Kally and Floor Safety Valves Annular Preventer Pipe Rams Blind Rams Choke Line Valves I Upper Kelly 0'(~' Lower Kelly (~ Ball Type 0 rt' Inside BOP ~ Test Pressure Test Pres sL~.-e Test Pressure Test Pressure H. C.R. Valve Kill Line Valves Check Valve Choke Manifold ,@/~; Test Pressure No. Valves 7 No. flanges ~' Adjustable Chokes HydraL~ically operatax~ al'Joke rain z~,~'sec. min sec , · Test Results: Failures . / Test Time ~ Repair or Replacement of failed equipmen~ to be made within Inspector/Commission office notified. hrs. ~ 0 days and Dis~ution orig. - AO~C cc cc - Field Operator/Supervisor - Drilling Dept. Superintendent September 10~ 1979 Re ~ Middle (:;round Shoal C-24-2 $ Shell Oil Company Per, it No. 79-62 Sur. Loc.~ Pl&t£orm "C", I~g 1, conductor 4, 4739.0'S, O£ the Nl ocr Bec 23, TSN, RX3W, SB&N. Bottonhole.~Loc.r Proposed loc. at T.D. 89944*S, 2737eW of NE cot sec 23, TSN, R~3W, SB&H. ~r. H. L. Woodson Shell Oil Co~pany 601 Wo Fifth aunue, Suite 810 Anchorage, Alaska 99S01 Dear I~'. Woodson~ Enclosed is the approved application for per, it to drill the above referenced wel 1. Well samples, core chips and a mud log are not required. A direc- tional survey is required. If available, a tape containing the digitized log info~ation on all logs shall be submitted for eopy~n9 except exper~ntal logs, velocity surveys and dipa~ter ~any rivers in Alaska and their drainage syst~s have been classified as .haportant for the spawning or migration of anadromous fish. Operations in these areas are sub~ect to AS 16.50.870 and the re~lations promulgated thereunder (Title Alaska A~inistrative Code). Prior to commencing operations Fou may be contacted by the Habitat Coordinatores office, DepaEt~ent of Fish and Ga~e. Pollution of any waters of the State is prohibited by tS 46, Chapter 3, Article 7 and the requlations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ed. Prior to oom~encing operations you may be contacted t~f a representative of the Department of Environmental Conservation. Hr. M. Lo Woodson Middle Ground Shoal C-24-26 -2- September 10, 1979 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 drll 1. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of tbs c~mBission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notif~&tion os that we may have a wi thee s present. Very truly yours, Harry W. augler ..... ..,. Commissioner of =.,, u.u,:. OF THE COMMISSION Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. DepartsMnt o£ Laborl Supervisor, Labor Law Compliance Division w/o enol. L A Darsow D~stnct Supenntendent September 5, 1979 File: LAD-746-986.511 Amoco Production Compan Post Offmce Box 779 Anchorage, Alaska 99510 907 - 272-8471 CC, '~ RE,' ..... 2 ENG 3Sx_, 4 ENC- 1 GEOI~ - .... 2 GEOL 3 GEOL ~STAT TEC-- STAT TEC CONFER -J:::ILF: .... Mr. Hoyle Hamilton, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Redrill of Shell Oil Company's Wel 1 MGS-C-24-26 This is to advise that Amoco Production Company has examined the direc- tional plats of Shell Oil Company's Well MGS-C-24-26 proposed redrill and has no objection to the proposed well. Very truly yours, L. A. Darsow District Superintendent RJR/klt cc: M. L. Woodson- Shell Oil Company Shell Oil Company 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 August 30, 1979 Subject: Middle Ground Shoal Cook Inlet, Alaska Platform "C" Well C-24-26 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. H. H. Hamilton Gentlemen' We would appreciate administrative approval for the redrilling of the subject well as a producer in the "G" pool. Enclosed is a "Sundry Notice" covering the abandonment of the lower portion of C-24-26 and a "Permit to Drill" covering the proposed redrill. Also attached are copies of the worksheet, direc- tional maps, and our check number 299352 in the amount of $100.00 to cover the permit fee. If you need any further information, please contact me. M. L. Woodson Division Production Superintendent Alaska Operations MLW/rrp attachments Form 10-401 REV. 1-1-71 reverse rode) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN TYPE OF WORK DRILL ~] DEEPEN [] TYPE OF WELL WELLOIL ~] WELL [DGAS OTHER SINGLEzoNE ~] ZoNEMULTIPLE ~ [f~l NAME OF OPERATOR Shel 1 Oil Company ADDRESS OF OPERATOR cnrn~v gPc~l_ TRN R!3W, SB&M 13. DISTANCE IN MILES AND DIRECTION FI~6M-NE~R~E~T T'O~'(~R POST OFFICE* 17 miles NW of Kenai, Alaska 601 W. 5th Ave., Suite 810, Anchoraqe, Alaska 99501 LOCATION OF WELL Atsuaaceplatfom "C", leg ] , conductor 4, 4739.0'S, 159l 'W of NE corner Sec. 23, T8N, RI3W, SB&M.~t6°/V At p,oposed prod zoneproposed location at T" ~ "'c .~.,,., · u.: :~:~'~-~ o, ~/,.,/ ....... ~3~/F~ 14. BOND INFORMATION API #50-133-20078-01 5 API No 50-133-2007R 6 LEASE DESIGNATION AND SERIAL NO ADL 18756 7 IF INDIAN, ALLOTTEE OR TRIBE NAME None 8 UNIT FARM OR LEASE NAME Midd]e Ground Shoal C-24-26A{*See below) 10 FIELD AND POOL,'OR WILDCAT MGS "G" Pool 11 SEC, T , R., M , (BOTTOM HOLE OBJECTIVE) Sec 26, T8N, R13W, SB&M 12 68-3 tee Oil & GaSsmetya.d/orNo. TIC 136503 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, Fr. (Also to nearest dng, umt, ff any) 616I+ DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 750 ' + 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 105' D.F. (M.L.L.W.) 23 16 No OF ACRES IN LEASE 5120 19 PROPOSED DEPTH 11,280' PROPOSED CASING AND CEMENTING PROGRAM ~ount $100,000 17 ND.ACRES ASSIGNED TO THIS WELL 80 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START 9-15-7g SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quannty of cement 15" 10-3/4" 40.5# O 1875' 1600 sacks (in Dlace~ 9-7/8" 7" 23#~ 26# N 9798' 500 sacks (in place. ~ee helow~ and 29# N 6" 5" 18# N 11280'_+ 280 ft3 *Plan to abandon lower portion of MGS C-24-26 as indicated by separate Sundry Notice on well. Plan to mill window in 7" casing at 9,300' (7994' TVD) to kick well off and re- drill as C-24-26 RD (See attached Drilling Worksheet and Proposed Directional Plan). .t,izska Oi~ & G." ~'~N)~O~ SPACE DESCRIBE PROPOSED PROGRAM If proposal is to deepen g~ve data on present producttve zone and p~j~0 fa§O / n~w productive zone. If proposal ~s to drill or deepen chrect~onally, give pertinent data on subsurface locations and measured and true ]e j~rtlcal depths. Give blowout preventer program. SIGNED ~ DATE ~.~, -~ q ,$ /qT¢ TITLE . SAMPLES AND CORE CHIPS REQUIRED I MUD LOG OTHER REQUIREMENTS raND I []yES DIRECTIONAL SURVEY REQUIRED A.P I NUMERICAL CODE [~YES [-~NO 3~'-/~3 - 2. oD 7~'-o I PERMIT NO. ! "~/' APPROVAL DATE Sept_~n_her !0, !979 APPOVEDBY ~~ ~ ~ ~ TITLE ~'"~,~,,J.~ZC';.,.CV,'"',,.,.C DATE 9/10/79 *See Instruction On Reverse Side ~Y ORDER CF THE CO,~3~$~O~ rt]~LD: MIDDLE OROUND SHOAL LOCATION: PLATFOBM G-LEG ,dr, l-CONDUCTOR ~4 DBJ~C'I'IVB: 6 POOL ZONES DRILLING WORXSH£ET WlCLI,: C 24-26 RD lCLICYA?IOH: 105' KO AFK ._ rl~[ ;IOIfAI g! 0t OGlt Orlnl)l IDC$ lOPS ............. t~.~l~ ~ lEi, Ill IISIN$ #Oil ino Sill Il Ill III .. -o SINGLE SHOTS ,. · Mitt 60% WINDOW IN 7 .... IB300'193~0'! KOP 9300' HC 10,310' 1-8.780') OIL/L(e/Sl~' FDG/GR/CAL BHC/GR - CBL/GR/CCL HK 'i0,310' I-9.OSO') HR 11,107' I-e.4SO'! HZ 11,251' l-9.575'l q '5",lilrd~, N-BO, 'IlSFJ ' CEMEflTED - Tp ' LAP PER ATTAC#E1 TARGET LIGNOSULFONATIE M MUD W/CLORIOES - ' -c3000 PPM . AND Wt ,,,c Redrill Worksheet C-24-26 RD Middle Ground Shoal Kenai, Alaska Location: Elevation: Target: Status: Redrill: Program: l) 2) 3) 4) 5) 6) 7) 8) Platform C - Leg #1 - Conductor #4 105' KB See attached target map See attached present condition sketch 9300' to 11,280' MD Shut-in the following injectors 10+ days prior to pulling production equipment: C23-26, C33-26 and C-line. Pull Otis Ball Valve and Install dummies to (but not including) lower most gas lift mandrel (9511'). Kill well with fresh water mud. Install Cameron BPV. Remove tree. Install and test BOPE to 3000 psi. Pull production equipment. Pull on tubing and packer is not to exceed 200,000# hook load. If production equipment cannot be pulled without exceeding 200,000# run Freepoint Indicator and run in with a tubing cutter and cut above freepoint. Pull tubing and pick up 3-1/2" D.P. jars, and fishing tools. Pull not exceeding 275,000# with 15.5#/ft. drill pipe. If fish does not come free, run in with tubing cutter and cut between first (9564') and second (9667') packers. Continue with above procedure until entire fish is recovered. Run in with 6" bit and clean out to 50' below bottom perfs (11,280'). Strap out of hole. Make casing scraper run in 7" and 5". Run in hole with retainer and 3-1/2" drill pipe. Set retainer at 11,120' and pull out drill pipe. Displace cement plug to within 100' of bottom of drill string. Stab back into retainer and displace plug to top of retainer. Release from retainer and reverse out excess c§ment. Plug to be as follows: 20 ft3 H20 preflush, followed by 80 ft of Class "G" retarded for 3 hours pumpabllity at 170° BHSTo Do not exceed 3500 psi when displacing cement. Monitor annulus during squeeze. Run in hole with second retainer and set at 10,870', following the same procedure as in 6. Plug to be as follows: 20 ft3 H20 preflush, followed by 100 ft3 of Class "G" retarded for 3 hours pumpability at 170° BHST. Run in hole with third retainer and set at 10,630', following the same procedure as in 6. Plug to be as follows: 20 ft3 H20 preflush, followed by 90 ft3 of Class "G" retarded for 3 hours pumpability at 170° BHST. REDRILL WORKSHEET C-24-26 RD 9) lO) 11) 12) 13) 15) 16) 17) 18) 19) 2o) 21) 22) 23) Run in with fourth retainer and set at 10480', following the same procedure as in 6. Plug to be as follows: 20 ft3 H20 preflush, followed by 60 ft3 of Class "G" retarded for 3 hours pumpability at 170° BHST. Run in with fifth retainer and set at 10310', following the same procedure as in 6A Plug to be as follows: 20 ft3 H20 preflush, followed by 70 ft~ of Class. "G" retarded for 3 hours pumpability at 170° BHST. Run in with sixth retainer and set at 9960', following the same procedure as in 6. Plug to be as follows: 20 ft3 H20 preflush, followed by 80 ft3 of Class "G" retarded for 3 hours pumpability at 170° BHST. Run in with seventh retainer and set a~ 9600', following the same procedure as in 6. Plug to be as follows: 20 ft Ho0 preflush, followed by 80 ft3 of Class "G" retarded for 3 hours pumpabi~ity at 170° BHST. Lay cement plug from top of seventh retainer to 9250'. Plug to be as follows: 20 ft3 H20 preflush, followed by 80 ft3 of Class "G" plus 2% CaC12. Test casing to 2000 psi. Polish off plug to 9350' and mill casing section from 9300' to 9350' (50' long window). Open section to 13" using underreamer. Spot kick-off plug of densified Class "G" plug 2% CaC12. (17ppg). Polish off plug to 9305'. Run in with dynadrill and 6" bit and orient per attached target map. Drill 6" hole to 11,280' MD (9705' TVD) per attached target map. Use lignosulfonate mud with less than 3000 ppm Cl. Maintain water loss less than 10 cc's and solids content as low as practical. Run logs: DIL/LLB/SP, FCD/GR/CAL, BHG/GR. Coordinate with field duty coordinator, Ventura. Run and cement 5" production liner 9200'/TD per attached casing/cementing prognosis. (Use 280 ft3 slurry). Clean out cement to top of liner hanger. Test lap to 2000 psi. Clean out cement to 5" shoe. Run CBL/CCL/GR. Coordinate with field duty coordinator, Ventura. Allow 24 hours. WOC prior to running log. A separate completion worksheet will follow letter. Recommended: Div. Drlg. Eng. Approved: Div. Prod. Supt. Date: -Descrlpt Ia.n_ Otis Bo-IA' Valv~-N$'pPl~- Camco XBMil~5-ndvwJ -- · Camco KRM Itundrcl Camco. gar H~ndreX-7..- -.. CBmco-XB~ Handr~! ". , C~o K~ Hand. el -- Ca_m_co KBH Handrel OtiLX0 Sl~dln8 $l.e_.ev. e-.3.-1]2 Guiberson UnlP~¢ker Vll .... · 2.3&?"- -- ,lt,2~9-' :" . ~.Z99. -'" - . .. 6,213, '~ 7,079 - __ __ -- '7,8S4. -- __.. B,~q7- - -- 9,149' 9,~' --90564' -- 13 O~fs--AO SILd'J.ns_~_Lq.1._e~ve'"3'*J~irZ_. 9,663. -- -- X5 -----_ 3-172 x 2-718 Crossover-- " 10,608. .... 18 .... 10,Gq~q' 10,728, Cl~-Go - 20 9618-9640 - 21 9646-06.5~. .5" @ 9713 @ 9798 CuXberson RH-1 Packer 2-315 10,749' 22 Otis X Nipple - 2-3/8 10,712' 23 otis N NIpple -2-3/8 10,771. 2A ~lbersop Shear Our Sub 10,772. PO~: ~l Jewelry belou #17 have 2-7/8 x 2-31B x overs on each G$ 991.6-10,03~ - 'fub~ng D.e. taiA ~ ·__ De.scrtpt_J°n _ ~ #E' 10.~93-10.533' 10.324-10332 ' 10.372-10-386' 0-7477 10.445-10.456' 7477-9686 9686-10,749 HI 10,607-10.620. 10.6~8-10--737. ' 1~Y, 762-828. 10,838-858 · 3-112", 9.3#/fi, N~80. Butt. 2-718", 6.5tilft, ~-80, *t~ltb seFcAal cleaFance couplings. 10,748-10,722 2-318", 4.7#1ft., 1~80, ~.u.$. · C__B_SAnS Detail 7", NoSO. Buttress v/reAch, ts of:. 23#/fi O' to &O&7', 2&ll/ft.,&O&7'to 7688', 29#/it 7688'to Liner Detail ~", 18fl/fi,HydrA1 Plvsh Joint. L~ / )'Target Map iC-24-26 RD , Middle Ground Shoal ! Kenai, Alaska lO, 000 Note- 1. All distances referenced from SE corner Section 14, T8N, R13W. 2. SW corner of HC target is 9520'S & 2800'W. .SW corner of HR target is 9900'S & 2840'W Consult USGS or Directional Company for dJgree of magnetic declination. / // A KO~ ~ ~gS~'S ~ Z~, 's · , i 'PLANt UI E~,J - C. 24', 2 6 'R (~ID'I:::C M..L. , C-24-26 RD Middle Ground Shoal Kenai, Alaska i , KOP: 9300' MD l (7994' TVD) From KOP turn hole at 5 degrees/lO0' to a bearing of S5 degreesE and drop hole angle at 1.5 degrees/lO0' to 30 degrees. Do not exceed a dogleg severity of 3 degrees/lO0'. / Note: All displacements shown are referenced from XOP (9300') along AA' Section Li ne. 'T:D. 1 IT. gO ( ~ ~ os' HC TAR&£T A"l" Cea~' ..rvx::,) 765' Cee.~' 800' &oo 400 zoo 8~o~o ~-.-- 0 ! CHEf~ LIST FOR N~ ~ELL PEI~4ITS Yes No 1. Is the pexmit fee attached ................ i..iii...ii...i.ii.ii...ii~/~ ..... 2. Is well to be locate~ in a de. fined pool ................ 3. Is a registered survey plat attached ................................ 4A~ 4. Is well located proper distance frcm property line .............. .. .. 7. Is mi1 to be deviated ..................................... 8. Is operator the only affected party ................................. ~ e 10. ii. 12. 13. 14. 15. 16. 17. 18. 19. L, ,. Can permit be approved before ten-day wait .......................... ~ / Does operator have a bond in force ................................... ~ / Is a conservation order needed ...................................... Remarks Is administrative approval needed ................................... Is conductor str~g provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Lease &Well No. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give a~equate safety in collapse, tension and burst.. Does BOPE have sufficient pressure rating - Test to 3000 psig .. ~ Approval Recommended: It~u (1) Fee (2) Loc. (3) Admin./~ / (5) BOPE Enginee~ring: Additional Requirements: rev: 06/21/7