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167-063
12/21/04 16:38 FA~ 43268708~~--- -- ITa ENERGY-MIDLAND -"-'.-"----'-'--..') - 141001 ) I)EC. ...... 2,..~ COVER PAGE I~t7¡;.Ð'ð PLEASE DELIVER THE FOLLOWING PAGES TO~ NAME: ~o~ .f (J);.fc.¡;z~;~ .- NUMBER: FROM: raul Figel. Sr. Produçtìon En~eer, XTO .Energy Inc. MESSAGE:. . >& Y ~ðl't:J(.~. -{or C 31-2'='.. ' DATE: I ~ 7-1 -tJ ¥". IF YOU DO NOT RECEIVE 3 PAGES, IN"CLUDING THE COVER PAGE, PLEASE CALL BACK @ 432.620-6743. SCANNED.JAN 11 20£]5 _"_I 12/21/04 16:38 FAI 4326870862 -,~ -- )--.- ITa ENERGY-MIDLAND ---- - °- 141 002 ) ;[tR XTO Energy, tnc.,slot #1-5 Platform C, Middle Ground Shoal,took Inlet, Alaska Wenbqre: 031..26 WeUpath: PGMS <O..350'>MSS <361 - 99351> Oate Printed: 21-Dec-2004 B.. BAKER HUGHES INTEQ - \~ 1 " óG3 II II " ' ,I,':. :'¡,'" ,.:r:'/'~ '.', ':' ":. ',I ,/;:I'i"e"II:b'oirle"":' ,;:"':,'1 I"", I ',. <,':~",','1'" ,',:' , :. I ~ " I, I \ I I , \ I I' . '1(V' I. . I. /.: I I . . ; " , I II A ,\ I I I ¡ ~'N¡;¡me ' "",}~;,''''' 1/'-'_) ',' , , >', CreétëJJ'" t,':' ",,J.:Governme.!!tlllL, :, ' J.a$t'Rè~sed C31.26 15-NOV=2002.l~, J1.Ncv-:20.Q4 .."~J. \ ~\ \.. ,,~.~\";'(þ~'t' \;('1 :I)I~\~ \/jYI¡ 111t/1.:r, "'~ \'Itt~~ II... ~ , , , ,J,'\, ~. f~~ \ ,:, i\ ~v ""III: ,,:,~ ";;,~~":::~,;\'''''' ,'",,,1'.,",',,,;,, ;":':\' ,",;.'" I'Ns'''''~''':j' '~., ,:,:, 'i ...\'.' I \ Jtlgo '.., "\ I 1 I I. . C31-26 . I I J It I (..18.: ''"w'' 'III" 'I' :",1 e ',,,.,'.:' .:Gci~mment I~: ::~ ' , " - :~: ::: ::: '¡" ,: ' ~.~t:,", 'I; "";,,:' ',. ::~11'~1::;:,::;í:~p:~ ~~~I:~ , le:as,t Re\lnl1ièð I,~,; I 10,: ",,~.' !', ' 'II< ¡t,,, 31.A!lQ~2004 'I ' _J , -, , " ,I, 't I ,1,'''. III. I ",I , J ' :'d",' 'Slot., ,,',": ",~ ", "",. '"~,;''' ~~:.::~'.". '.'.."," I,"~',' .:'.",1"", <.;,.J!I/"\I,'I",~ ':'~'~\;i;fi ~~~~~d~ó..;;~5' 'r' '':"¡'~~:d:~'8~'~.3~!'' ':"4~~~~~" "l"I"':~;~:.Ó~~ ,. .. ",Når;,@~ ; ',' I -~~~~ '. ~" "I' 'G"ij" N ''''''¡'I-'''' '1'" t:"!iiI."d.C-..ti". ,'" '¡ '! 'A' OHI!, no'" ',,' '''<'JII '¡,o,.¡;IS na; ~2474224.~O 23.1362.8410 1,11 . ,I I :.111\ i' .,'; 1",, ,I I \," - I . .t't'd" J J : I 11 t I _P~~:D~~' ~~': Õ, ""l"';, I', '~~~~~~B33 ,- , I 11.\,:1 t 1',.,1 t" "'" " ,""'\ ,'" I" ,';",", ,I ::"", {::":' ,,",.-' , 'y ns, a, a, Ion "',' ", "" ,,' ,\" " " "Ir, ,f.," , .: ", NOrthinCl," , I,' , ,~. 'CoOrd 'fivstem' Name, I' I, , , ~hrtn 'Alfnhme,1!1G 2478.929.9B20' AK-40p NORTH AM~RICAN DÞ,..TUM 192.7 datum 'TrLlê' ," -." ,~I,',' "'1",,',,;,1\,, ,,,,,':,;',,,, ,,: ,:,,:¡~,:,,!,,:,' "',,,',' :'" \, ~''',;,' F~äld,¡,,,' ",,~:':, .. "'~':;",,,I',:, ,:",:.:',,:, i' ,.::', '¡"'~'::'l:i' ~~iddle'~~~~~ ~h~a~:'~' ',' "'f' , "~~~~:~~8~',' !I,' . 2$Õ;~~~~~29ð' I, I 'AK~'~n"~oRT~~:;~~~'~~~~~'19~; d~~~~! '"J~ofth~:niP~ ¡r/'I.';'\ .i~r~~' "'~.:íI,: -. I,.I' ~I~.~ A':~~:~~~:~6\ . ..;' ?,;'" Top Perforation: 8742 MD TO : 9927 MD \~g.!!f~~r:':~" - ~'IÎ'!"-"~ "l,Hl.I'''~' 1'~~,~,~e~~L¿:~~~~:";:¡!~~Æ'~:!!:lr: ''':arWII:: ' ,'''''...." ,,"'.T¡', ,fl" " III: J". ':~if->.'''~.':f t '<;r, .~~.¡ .~:''"JJ Ji'' . rri'«ß'í:" ,I ."Ji}¡''{¡f1l1J.; 'V!W''A' ~',IV'\'J i' ~~\W.~~ :1r1b,,~~ír~ '::'~I\:x::\,,:"i~?'~' ,Ù?,~":::'!;):,I~~\~~t;,'~t:;L.:I:i;:;:~~, !t~J# /i,~~~~\ií.~~,ì,:¡f~,,' ,:', tl~\~~,:):\)~3~~~,:,;,~,.Û" ,~I..' 'i All data is in FaQt unless otherwise 5tated Coordinata~ are from Slot MD's :ara ftom Rig and TYD's are from Rig ( Actual Da'b.Jm 1 O!5.0ft above mean sea lavel ) Vertical Sêctlon is from O.OON O.OOE on a~muth 165.13 degl'ées Bottom hOle distance i~ 1622.50 Feet 01"1 azimuth 186.13 degrees from Wellhead Calculliiltion method uses Minimum CtlM;¡b,tre method Prepared by BaKer Hughes Incorporated ',--' 12/~.1/04_~~,9 FA~, 432687086~,~..----. . ITa ENERGY-MIDLAND ) 141 003 ') ~TO ANkRGY XTO Energy, Inc.,slot#1.S Platform C, Middle Ground Shoal,Cook Inlet, Alaska Wellbore: 031..26 Wellpath: PGMS <O--3501>MSS <361 - 9935"> Date Printed:. 21.Cèc-2004 B.8 "''''u INTEQ f~7'" 0&>3 '; "",~,:', < ,:',' ",," ,i,', ,",' ':,,;(,'~".; ':' ' ,":',': :, :,:( . '; ;':I~D[ft] ;, :. ' . "!~ë[deg]' 'I ;,,~[degl , >rv1D[~j ':'; ~~ ' I \ 111'\ !I\: ) I ( I I II II I I 1 ~. \ \ lltl I \ II I I:' ì \1 ~ I) I . --rP'.L J742.00 12.75 208.66., - ,ß538.31 , -r p _~.927 .00 ,11,00 258.00, 9699.92- ',"/ ':We11;i:ath,tGr¡d)i.:f~eøørt\, ',,' ,,", '~:I;~'- ':, Noith[ft:(' ". ' 'East[ft]'-",' ~'..::Do,gleg , ,:.~ \ Vertical r~.- .. ",;', "I ,; '..:.. ' . ,.\'" " 'l'r'd~n/1QdRl" L:'~ectionrft'l<',' 1488.59S, 25.QaE ,...Q,OO 1460.47 , 1615,69$ 143..4SW 0.84 1822.05. , . , . , . . . 'I '. . t -' l ':I~" 'II. III \1 ~\ I': ff>. '';;')0, "', I' ,'/ ". "4~ " "Eastins{: ...' , : i' -:, ',;,',Nörthirí,Û\" ,/. ' ....r, I :'n' /111., /~ {¡II . H't7.~\'" Y~¡Al1~~'I:A/\!t,:rr{" I(~~. 231.3ß4.12 23:1162.24 , 241?7JiS.80 247~S12.59 All data Is in Feet unless othel'Wlse staied Coordinates are from Slot MD's are from R.lg amliVO's are from ~lg ( Actual Dawm 105.0ft above meal'! sea level) Vertical section is from o.oON O.OOE on azImuth 185.13 degrees Bottom ho1e dÏ$t.al'lce Is 16V-.50 Feet on ezimutt11 85.'3 degrees from Wellheaò Calculation method use~ Minimum Curvature method Prepared by Baker Hughe~ incorporated " ) ) ..,j6.~\. ~TO ilNkRGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) December 10, 2004 RECEIVED DEC 162004 AI.aka 011 & Ga. Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission Attn: Mr. John Nonnan 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C31-26 P&A Dear Mr. Nonnan, XTO Energy, Inc, hereby submits its Well Completion Report (Fonn 10-407) for the work perfonned to plug and abandon well C31-26 on Platfonn C, in the Middle Ground Shoal Field of Cook Inlet, AK. In the process of plugging the well, an injection rate could not be established at 5,000 psi below the cement retainer into the perforations, As per AOGCC instructions, a 412' cement plug was spotted on top of the retainer. After the abandonment of the lower portion of the wellbore, the well was sidetracked as the C31-26RD. The completion report for the C31-26RD was mailed on November 16,2004, Please find attached the following infonnation for your files: 1. F onn 1 0-407 Well Completion 2. Daily Operations Report 3. Post P &A Wellbore Schematic If you have any questions or require additional infonnation, please contact me at (432) 620-6743, Sincerely, 9J øf. Y Paul L. Figel Engineering Manager SCANNED JAN 11 20.05 Cc: Doug Marshall Tim Smith O~\G\N.\L ALASKA )L AND ~:~T¿g~S~~~A~ON COMMISb.JN WELL COMPLETION OR RECOMPLETION REPORT AND LOG OilD Gas U Plugged 0 Abandoned ~ Suspended U WAG 0 1 b. Well Class: 20AAC 25,105 20AAC 25,110 Development 0 Exploratory 0 No. of Completions 1 Other Service 0 Stratigraphic Test 0 5. Date Comp., Susp., or 12. Permit to Drill Number: / Aband.: A: 9/7/04 167-063 6. Date Spudded: 13. API Number: October 22, 1967 50-733-20052-00 7. Date TO Reached: 14. Well Name and Number: December 4, 1967 C31-26 8. KB Elevation (ft): 15. Field/Pool(s): 116' Middle Ground Shoal 9. Plug Back Depth(MD+ TVD): 9935',1079' FNL, 1742' FEL, Sec. 26, T8N, R13W, S.M. 9849' + 9623 4b. Location otWell (State Base Plane Coordinates): . 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 231363 y- 2474225 ~ zyne- AK4 9935' + 9708' ADL-18756 TPI: x- ..23 Issf.!'¿ .AI y-/}'Ilj.7SS-¡ 'fI'''2.one- Lj 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x-~/9:l.f).'f TV y-J.,t./ljl:i1}. .þ Zone- 1 N/A 18. Directional Survey: Yes 0 No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: 73 feet MSL ~ 1a. Well Status: GINJD WINJD WDSPLD 2. Operator Name: XTO Energy Inc. 3. Address: 200 North Loraine, Suite 800, Midland, Texas 79701 4a. Location ot Well (Governmental Section): Platform C,Leg 1 Surface: . Cond 5, 537' FSL, 1593' FEL, See 23, T8N, R13W, S.M. Top of Productive Horizon: 8742',931' FNL, 1572' FEL, Sec. 26, T8N, R13W, S.M. Total Depth: 21. Logs Run: NA Gamma Ray, Resistvity, Compensated Neutron 22. CASING WT. PER GRADE FT. 40.5 J55 23,26,29 N80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE Surf 1895' Surf 1894' Surf 9927' Surf 9700' CEMENTING RECORD AMOUNT PULLED 0 0 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Gas lift Oil-Bbl: -+ Oil-Bbl: -+ 10-3/4" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom ~:erval, Size and Number; ifREeEIVE D DEC 1.62004 Alaska Oil & Gas Cons. Commission Anchorage 26. Date First Production: Date of Test: Hours Tested: Production for Test Period Casing Press: Calculated 24-Hour Rate Flow Tubing Press. 15" 1600 sxs 1350 sxs 9-7/8" 24. TUBING RECORD DEPTH SET (MD) PACKER SET (MD) SIZE 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7426'.7839' 76sx Class G cmt. Gas-MCF: Choke Size: Gas-Oil Ratio: Water-Bbl: Gas-MCF: Water-Bbl: Oil Gravity. API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). J Submit core chips; if none, state "none". 74.£æ ~~. r1-...w""-"'" ...:: . NA RBDMS 8FL DEC 2 1 2DD4G~1:ý L~-:... ORIGINAL Form 10-407 Revised 12/2003 (~¡: CONTINUED ON REVERSE NAME GEOLOGIC MARKE: .-) MD TVD 29. ) FORMATION TESTS ~ Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. NA NA 30. list of Attachments: Wellbore Schematic, Daily Operations Report 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ;:>"&1' F'*1--' Printed Name: Paul Fiqel Title: Engineering Manager Signature: 90.1 ri.£¡1 Phone: 432/682-6743 Date: 12/12/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50.029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ) ) 1 XTO ENERGY INC. C31-26 Daily Operations Report Objective: P&A Well for Sidetrack 8/28/04 ND Tree @ 0', MW 12.3, Vis 45, PV 12, YP 27, Gels 8/12, pH 10.0, WL 8.0, Cake 1.0, Alk 0.6, CI16,000, Ca 1,400, Solids 16,0, Added 2sx caustic soda, 20sx Flo-Vis Plus, 1,980 Mi- Bar, 9sx Polypac Supreme UL, Circ 7-1/2 hrs, Build Mud Vol/Wt 7-1/2 hrs, Circ out Kick on Choke 7 hrs, NU/ND Tree 1 hr, Monitor W ell 1 hr, Built mud vol & weighted up pit voL Disp well w/FIW, Taking rtns to production, Pmpd @ 1 BPM. Monitored well, 900 psi SIP, Circ 12,3 ppg mud dwn tbg. Disp well to prod @ 1 BPM. Circ thru choke to pits. Monitored welL Set BPV, Std to ND tree, 8/29/04 Testing BOP's @ 0', MW 12.3, Vis 45, PV 12, YP 27, Gels 8/12, pH 10,0, WL 8,0, Cake 1.0, Alk 0,6, CI16,000, Ca 1,400, Solids 16.0, NU/ND BOP/Diverter 18 hrs, NU/ND Tree 4 hrs, Testd BOPS/Diverter 2 hrs. ND tree. Set riser. NU BOPE & flowline, RU to press tst BOPE to 250-1,000 psi. 8/30/04 LD 3-1/2" Tbg @ 0', MW 12.3, Vis 45, PV 12, YP 27, Gels 8/12, pH 10.0, WL 8,0, Cake 1.0, Alk 0.6, CI16,000, Ca 1,400, Solids 16,0. LD/PU Drill Pipe/Tbg 10-1/2 hrs, Test BOPS/Diverter 6 hrs, Perf'd 3-1/2 hrs, RU/RD Service Tools 2 hrs, Circ 2 hrs, Press tstd BOPS to 250-1,000 psi (John Crisp w/AOGCC waived witnessing the BOP tst), Pulled BPV. Backed out tbg hgr lock dwn studs. Pulled tbg hgr out of tree. Attempted to reI pIa w/60K over pull (no success). Circ tbg, well taking fluid, RU APRS WL, RllI w/jet cutter. Cutter stopped @ 7,872', Shot jet cutter & cut tbg @ 7,849' (WLM). POOH w/WL, Left jet cutter tool string in hole (23), RD APRS WL, RU Weatherford tongs, ramp, catwalk & pipe rack. Std TOOH LD 3-1/2", 9.3#, 8rd, L-80 tbg. 8/31/04 9/1/04 RllI wiT' Csg Scraper @ 0', MW 11.4, Vis 40, PV 12, YP 28, Gels 12/15, pH 10.0, WL 8.2, Cake 1.0, Alk 0,6, CI16,000, Ca 1,400, Solids 12.5, Added 14sx Flow-Vis Plus, 770sx Mi- Bar & 4sx Polypac Supreme UL. LD/PU Drill Pipe/Tbg 16-1/2 hrs, Other 4-1/2 hrs, PU/LD BHA & Tools 2 hrs, Circ 1 hr, Fin LD 254 jts of 3-1/2" tbg. Ck'd for norm, Lots of scale on btm 1,000'. Cleaned scale off of rig floor. RD tbg tongs. Back loaded boat w/tbg & misc items. Set wear ring. PU 7" csg scraper w/6" bit & 2 - 4-3/4" DC's, PU & TIH w/3-1/2", 15,50#, S-135 DP. Circ hole @ 6,400'. Cont'd TIH & PU 3-1/2" DP, ~~L..;...~- PU Isolation PIa For Csg Tst @ 0', MW 11.1, Vis 42, PV 11, YP 28, Gels 10/13, pH 10.0, WL 9.0, Cake 2.0, Alk 0,6, CI16,000, Ca 1,200, Solids 12,5, Added 2sx Flow-Vis Plus, 220sx Mi-Bar, 1sx Polypac Supreme UL & 1sx Soda Ash. Trip 12 hrs, Circ 4 hrs, Slip & Cut Drill Line 2 hrs, Press Inject/Lot/Fit 2 hrs, LD/PU Drill Pipe/Tbg 1-1/2 hr, W & R 1 hr, Tstd Csg 1 hr, Serviced Rig 1 hr. TIH wIT' csg scraper, PU 3-1/2" DP. Washed fr 7,787'- 7,850', Circ btms up. Mixed & pmpd dry job. TOOH wIT' csg scraper. RIH w/Baker drillable cmt retainer. Circ thru retainer. Set retainer @ 7,839', Pulled out of retainer & circ above retainer. Held pre-job safety mtg, Stung into retainer. Attemted to establish an inj rate. Press up twice to 4,000 psi, could not establish inj. Repeated process @ 5,000 psi, 9/2/04 ) ) 2 could not establish inj, Closed pipe rams, Press tstd csg above retainer w/BJ pmps. Established inj rate into csg lk@ 0,5 BPM @ 720 psig, 1 BPM @ 790 psi, 1.5 BPM @ 900 psi, Opened rams & circ above retainer. Slipped & cut drlg line, Serviced rig. TOOH LD Baker retainer running tool. PU Baker isolation pkr. ~.ø'IðII'IñYt~!;;d.",,,J;,iHi,,,,),,,,"""';;;;;;;;',)m'f~wmm¡;;;;;;;;;;ÏÑÆ;"m,,,mWØ)nm;¡nHlM@lmøl'fYIIðÆmmllt""IWI",)""""")',,,¡iil'lÍí' ~IMf'A;;~-'-'-'-.¡;Z;;;;;..""..'If.mmnmoom~ Prep To Spot Cmt Plug @ 7,839', MW 11.0, Vis 39, PV 8, YP 17, Gels 5/7, pH 9,5, WL 10.0, Cake 2.0, Alk 0.4, CI16,000, Ca 1,200, Solids 12.0, Added 24sx Durogel. Trip 10 hrs, Circ 9 hrs, Tstd Csg 3-1/2 hrs, Cmt'd 1 hr, PU/LD BHA & Tools 1/2 hr. RIH w/Baker isolation pkr to 3,720', Press up below pkr to 1,000 psi. Injected above pkr @ 1 BPM & 400 psi. Std moving pkr up hole & tstg csg, Hole was isolated between 3,440'-3,471'. TOOH w/isolation pkr, LD Baker isolation pkr, PU 3-1/2" muleshoe. TIH w/3-1/2" DP to 7,839', Circ hole, Prep to spot cmt plug on top of retainer @ 7,839' per AOGCC instructions. Held pre-job safety mtg, Tstd lines to 2,000 psi. Std mixing cmt. Mixing pmp cplg broke on BJ unit. Parts to be on 1st chopper in the a.m. Circ well. Unloaded boat. Cleaned cellar & lwr deck, Working on drains to production. 9/3/04 ~##If~~ 9/4/04 Rill W/Clean Out Assembly @ , MW 10,7, Vis 31, PV 5, YP 12, Gels 2/3, pH 8.5, WL 15,0, Cake 3,0, CI15,000, Ca 2,500, Solids 9,0, Oil 0,5, Added 6sx bicarbonate of soda, 20sx citric acid & 36sx Durogel. Circ 9-1/2 hrs, Trip 8-1/2 hrs, Cmt Plug 4 hrs, Service Rig 1 hr, PU/LD BHA & Tools 1 hr. Circ well. Worked on drains to production, Relp cplg on BJ's cmt mixing pmp. Held pre-job safety mtg, Pmpd 8 BFW, press tstd lines to 2,000 psi, tstd OK. Cmt retainer @ 7,839' (could not inj below retainer). Batch mixed & pmpd 76sx (15,5 bbls)of CI "G" cmt containing 0,3% CD-32, 0.25% R3 & 0,05% FL63, Disp w/2 BFW & 45 bbls mud, Cmt in place @ 11 :45 a.m. 9/2/04. POOH to 7,333', Circ btms up @ reduced rate, monitored rtns, Fin TOOH, PU & TIH w/cmt retainer. Set retainer @ 3,503'. C & C mud for cmt job, Held pre-job safety mtg, Sqz'd csg lk @ 3,440'-3,471' w/95sx (18.6 bbls) of CI "G" cmt containing 0.4% CD-32, 1 % CaCl2 & 1 GPS FP (16,2 ppg, 1.10 cuft/sx). Disp w/2 BFW & 16.3 bbls mud. CIP @ 0030 hrs 9/3/04, Press climbed to 860 psi during cmt placement, dropped to 300 psi & stabilized. TOOH to 2,911', Circ DP vol. Closed rams & BJ sqz'd 12,5 bbls of cmt. Circ to clean pipe, monitored rtns. TOOH & LD setting tool. PU clean out assembly, Till w/clean out assembly, 'ì~/fI"'.'h""",¡}¡m!Wmttlmmr¡¡ ;.¡;;;;;:,"",;;;;'mí,m~_ÑiWlII'fnn!ñmiwli¡;ø;;mm"';;;JhWIHÑ¡¡~"k7_""""","lfmiIIW#IIf_~mH.\<' Circ w/Scraper Assembly @ 7,350', MW 10,9, Vis 34, PV 7, YP 9, Gels 2/3, pH 11.0, WL 15.0, Cake 3.0, Alk 6.0, CI15,000, Ca 2,500, Solids 10.0, Oil 0.5, Added 60sx Barite & 22sx citric acid. Trip 10-1/2 hrs, Other 5 hrs, WO Cmt 4-1/2 hrs, Circ 3-1/2 hrs, Tstd Csg 1/2 hr. Till w/clean out assembly to 2,910', Circ & WOC, Cleaned pits & trip tnk. Cleaned out turbos on 398 top drive CAT, organized decks. TIH & tagged cmt @ 3,360'. Drld cmt. Hard cmt fr 3,394'-3,500', Circ btms up. Press tstd csg to 500 psi for 30 min, tstd OK. Cont'd drg cmt & cmt ret fr 3,500'-3,505'. Washed dwn to 3,595'. Circ btms up, TIH w/clean out assembly, Tagged up @ 7,330'. Washed dwn fr 7,330'-7,427', At 7,427', cmt held 15,000# wt & confirmed cmt plug. Circ btms up. TOOH w/clean out assembly. PU 7" scraper assembly & Till to 7,350'. Circ btms up. 9/5/04 Build Mud, Rig Up J-Tube, MW 8.5, Vis 27, CI16,000, Added Isx Clean Up. Circ 18 hrs, Build Mud V ol/Wt 6 hrs. Circ hole. Prep & inject old mud, Cleaned pits. Build new mud, Cleaned out mud line. Removed cuttings augger. RU J-tube. ,,,.....,,..:;.'-.......-~'~i .._~ .."" ~","""""",-""-,',ç¡¡;;;;;;"""""m,, 9/6/04 ') ) 3 Testing BOPS, MW 9,5, Vis 45, PV 17, YP 24, Gels 8/12, pH 9,0, WL 5.4, Cake 2,0, Alk 0.6, CI12,000, Ca 120, Solids 6,0, MBT 5.0, Added 380sx Barite, 2sx bicarbonate of soda, 12sx Flo-Vis, 40sx Mi Gel, 12sx Polyac, 24sx Resinex & 4sx soda ash. Build Mud VollWt 12-112 hrs, Test BOPS/Diverter 6-112 hrs, Disp 3 hrs, Trip 2 hrs. Mixed new mud, RU J- tube, Disp hole w/9.5 ppg mud. TOOH w/dean out assembly. Pulled wear ring. RU test assembly, Press tstd BOPS/Hydrill to 250-2,500 psi, rams & valves to 250-5,000 psi. Chg'd door seal on BOP, I 9/7/04 POOH wlWindow Mills @ 7,315', MW 9.5, Vis 78, PV 20, YP 41, Gels 14/20, pH 9.0, WL 5.4, Cake 2,0, Alk 0.4, CI12,000, Ca 90, Solids 6,0, MBT 6,0, Added 20sx Bore-Plate, 10sx Flo- Vis & 2sx soda ash. Mill/Cut Sect or Window 9 hrs, Other 5 hrs, Trip 5 hrs, PU/LD BHA & Tools 2 hrs, Circ 1 hr, Orient Tool Face 1 hr, Tst BOPS/Diverter 1 hr. Fin tstg BOPS. Tstd gas alarms & accumulator. Set wear ring. RD tst assembly. RU APRS WL. Held pre-job safety mtg. PU bridge plug. RIH w/bridge plug on WL. Set bridge plug @ 7,296'WLM. RD WL. PU Baker Oil tools whipstock assembly. Oriented face w/MWD & UBHO sub. Surf tstd MWD, Rlli w/whipstocck to 7,255'. Oriented whipstock face 40 deg right while working dwn bridge plug, Tagged bridge plug @ 7,309'DP measurement Set anchor & sheared off whipstock. Milled window fr 7,291'-7,315', Circ btms up, Ck'd flow, Pmpd dry job. Std TOOH w/window mill assembly. MGS C31-26 Cook Inlet, Alaska Leg 1 Conductor 5 API No. 50-733-20052 Spud:Oct 1967 Surf Csg: 10 3/4", 40.5 Ib, J55. Set @ 1,895'. Cmt wI 1,600 sk. SQZ Leak 3,440-71' wI 95 sk. (9-3-04 ) 7" CMT Retainer @ 7,839' (9-1-04) Spot 76 sk cmt plug on top of BP. TOC @ 7,427'. Longstring: 7" N80 BTC. Set @ 9,927'. 23# : Surf - 5,600' 26# : 5,600 - 8,100' 29# : 8,100 - 9,927' Cmt wI 1,350 sk. TOe by CBL @ 6,260' Top of Fill @ 9,640' Fish: 3+ WL strings @ 9658' PBTD: 9,849' MD (9,621' TVD) TD: 9,935' MD (9,707' TVD) ) Abandoned Status ~ . "". I r ~. r --.r- ~ --- ) PLF 12-14-04 KB: 35' Water Depth: 73' MSL GR-GS: 8742-8780' HC-HD: 9037-9069' HE-HF: 9144-9194' HI-HK: 9258-9297' HK-HN: 9311-9448' HN-HR: 9471-9610' HR-HZ: 9640-9700' ~ ~ ~1r~1rŒ illJ~ ~~~~æ~ AI,ASIiA OILAlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 8, 2004 Bobby Smith Drilling/Operations Manager XTO Energy, Inc. 3000 North Garfield, Suite 175 Midland, Texas 79705 ~ \ 61- 0 Re: Middle Ground Shoal C31-26 Sundry: 304-343 Dear Mr. Smith: Enclosed is the~approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure ~ STATE OF ALASKA ~ AlA~,.r\ Oil AND GAS CONSERVATION COMMh.J;:)ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ø;,~ ~. ~. ~ ~ A~ 1. Type of Request: Abandon D Suspend U Operational shutdown U Perforate D Waiver U Annular Dispos. U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy, Inc. Development 0 Exploratory 0 167-063 3. Address: Stratigraphic 0 Service 0 6. API Number: 3000 North Garfield, Suite 175, Midland TX 79705 50-733-20052-00 7. KB Elevation (ft): 9. Well Name and Number: 105' ASL MGS C31-26 8. Property Designation: 10. Field/Pools(s): ADL-18756 Middle Ground Shoal 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): 9,935' 9,707' 9,640' 9,345' Fill @ 9,640' WL Fish @ 9,658' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,895' 10-3/4" 1,895' 1,894' 3,130 psi 1,580 psi Intermediate Production 9,927' 7" 9,927' 9,504' 6,340' psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,742' - 9,700' 8,538' - 9,477' 3-1/2" N-80 9,465' Packers and SSSV Type: See attached schematic. Packers and SSSV MD (ft): See attached schematic 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/212004 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: 9/21] ~ WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Tom Maunder ,... ,~ 10" J~ 17. I hereby certify that the foregoing is true and correct to the be~t of my krfowllfd)e. Contact Bill Penrose 258-3446 Printed Name /} , ........øobby Smith Title Drilling/Op~rations Manager Signature 9(JlIl L '- ~d Phone (432) 620-6718 Date :i7:i764/ I COMMISSION USE ONLY , Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ..3 o¡"- 3 tf 3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Ongt'-ú.\ ~\\\'ð"~ * 3c)4-d-<6~ osrry\ , RECEIVED ~ ï SEP- 82004 S"""q"'ffid' 0-,> ~\ """<'\:i ~G\'~ Alaska Oil & Gas Co.s. Conrnissio. ~ 0 R I I NA L Anchorage 'w°w,"by 7 ~ ~OMMISSIONER :~;~::~:'ON Date 9/f/olfV/ Form 1 0-403 R~ 12/200~ INSTRUCTIONS ON REVERSE SUb~i in ¿uPlicate .... BF L SEP 0 9 20Ò4 ;{t9v MGS C31-26 Cook Inlet, Alaska Leg 1 Conductor 5 API No. 50-733-20052 Spud:Oct 1967 Well SI Oct 1999 Surf Gsg: 103/4", 40.51b, J55. Set @ 1,895'. Gmt w/1 ,600 sk. Longstring: 7" N80 BTG. Set @ 9,927'. 23# : Surf - 5,600' 26#: 5,600 - 8,100' 29#: 8,100 - 9,927' Gmt w/1 ,350 sk. TOC by GBL @ 6,260' Tbg patch @ 9,266- 9,311' Top of Fill @ 9,640' Fish: 3+ WL strings @ 9658' PBTD: 9,849' MD (9,621' TVD) TD: 9,935' MD (9,707' TVD) ~ Proposed P&A """";'0 'I~~~-o .' , 0" 1', . ;-'--'{ j"",~,:",:,,- ~ WJP 9-3-04 KB: 35' Water Depth: 73' MSL Hole in 7" casing at :t3,440' MO (squeezed wI cement). Cement retainer at 7,839' with a minimum of 150' of cement on top. 7" Baker HB Retr pkr (47B2) @ 8614' Otis X nipple @ 8651' ( 2.813" 10) Baker GBH-22 80-40 Seal Assy & PBR @ 8684' Otis XO Sliding Sleeve @ 8705' Guiberson Uni VII pkr @ 8713' GR-GS: 8742-8780' HC-HO: 9037-9069' Cameo KBM Gas Lift Mandrel @. 9080' Otis XO Sliding Sleeve @ 9086 Guiberson Uni VII pkr @ 9095' HE-HF: 9144-9194' Cameo KBM Gas Lift Mandrel @ 9195' Otis XO Sliding Sleeve @ 9201' Guiberson Uni VII pkr @ 9219' HI-HK: 9258-9297' Cameo KBM Gas Lift Mandrel @. 9283' Otis XO Sliding Sleeve @ 9288 Guiberson Uni VII Þkr @ 9298' HK-HN: 9311-9448' Cameo KBM Gas Lift Mandrel @ 9441' Otis XO Sliding Sleeve @ 9446' Guiberson Uni VII pkr @ 9456' Otis X nipple @ 9464' Otis Q nipple @ 9465' HN-HR: 9471-9610' HR-HZ: 9640-9700' ~ ~ ~TO ~kRGY September 3,2004 RECEIVED SEP - 8 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage RE: Application for Sundry Approval; Change of Approved Program for J\1IGS W{~H C31-26, Cook Inlet, Alaska Dear Mr. Norman, XTO Energy, Inc. hereby applies for Sundry Approval for changes to its plan to permanently abandon the perforations existIng in Middle Ground Shoal Well C31-26 and sidetracking of that well to drill C31-26RD. The originally approved plan called for recoVt';rinð the production tubing above the existing six packers in the well, setting a cement retainer above the top p~cker and injecting cement below the retainer to cover and isolate all of the perforated intervals. The well would then be sidetracked from the 7" casing above the retainer and a 5" liner run to allow production of the sidetrack. However, upon recovering the tubing and setting the retamer as planned it was discovered that a) the perforations will not take fluid at pres:mres up to the maximum safe equipment capacity of 5,000 psi and, b) there is a hole in the 7" ca~ing at :t3,440' MD, above the top of the cement in the 7" X open-hole annulus. ~(:,~~\~, dC)~c.~S, \ \~ c.~\<. \\(è.) 9<.E) XTO Energy proposes to abandon the perforate~ interval (which l'e entirely in the ~?JVl c;,(~ Hemlock Reservoir) by placing a cement plug a mini 1.1 5 on top of the cement retainer at 7,839' MD. The hole in the T' casing will be squeeze~th cement to allow safe drilling of the sidetrack to TD. After theydetrack is drilled, the previously planned 5" liner wilJ be replaced by a 5" long string.(n order to keep gas lift pressure off of the squeezed 7" casing. As the two problems discussed above were identifi.¡rl( they were verb. ally relayed to and discussed with the AOGCC's M1 Tom Maunder\!rid solutions agrel--d upon. This Sundry Notice is a follow-up to those discussions and verbal approvals. Pertinent information attached to this application includes the following: 1) 2) 3) Form 10-403 Application for Sundry Approval A summary of the proposed abandonment procedure (this letter) A schematic shoWIng the proposed abandonment xro Energy Inc. . 3000 N. Garfield. Suite 175 . Midland, Texas 79705 . (915) 682-8873 . Fax: (915) 687-0862 .~ .~ Mr. John Nonnan Page 2 If you have any questions or require additional infonnation, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. f4L~ Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose . ~lf~lfŒ lID~ ~~i%~~!Æ AI,ASIiA. ORAND GAS CONSERVATI ON COMMISSION , . ! / / FRANK H. MURKOWSKI, GOVERNOR í I f ! / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bobby Smith Drilling Operations Manager XTO Energy 3000 N. Garfield, Suite 175 Midland, TX 79705 ~~ ~~ I fø 7- C?~3 Re: Middle Ground Shoal Unit C31-26RD XTO Energy Permit No: 204-140 Surface Location: 542' FSL, 1596' FEL, SEC. 23, T8N, R13W, SM Bottomhole Location: 1571' FSL, 1851' FEL, SEC. 26, T8N, R13W, SM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above development well. In your application you note that due to the platform construction and the lack of sufficient headroom, it is only possible to employ 1 set of pipe (or variable) rams rather than the 2 sets required by 20 AAC 25.035(e)(I)(B)(i). You have requested a waiver as allowed by 20 AAC 25.035(h)(1). A waiver is allowed provided that the equipment employed provides "...an equally effective means of well control." Such a waiver was granted for your most recent operations between 2000 - 2002 and it is appropriate to continue the waiver. Operational test records indicate that the equipment showed a high degree of reliability. It is also likely that the maximum anticipated surface pressure calculated for this operation is conservative since the formation pressure is elevated due to waterflood and the Hemlock formation does not have high gas content. BOP tests during operations on this well should be conducted at an interval not to exceed 7 days. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska . . Permit No: 204-140 July 30, 2004 Page 2 of 2 Administrative Code, or a Commission Order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission itness any required test. Contact the Commission's petroleum field inspector at (907) 65 3 ager) c .ely, BY ORDER QE THE COMMISSION DATED thisÆday of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill Penrose, Fairweather E&P w/encl . . XTO Energy, Inc. Middle Ground Shoal Unit BOP Waiver Request XTO Energy requests a variance from 20AAC25.035(e): Blowout Prevention Equipment and Diverter Requirements for its workover and drilling operations on Platforms A and C in Cook Inlet. This variance is being requested per 20AAC25.035(h) and is the same as the one requested and approved for XTO's 2000 - 2002 drillinglworkover program at Middle Ground Shoal. Request XTO Energy requests authorization to utilize a 5,000 psi WP BOP stack that consists of an annular preventer, one blind ram preventer and one pipe or variable bore ram preventer for wells with calculated Maximum Anticipated Surface Pressures between 3,000 and 5,000 psi in lieu ofthe annular preventer and three rams required in the AOGCC's regulations. The pipe ram will be sized to fit around the pipe being run into and out of the hole. The variable bore rams will always be used for tapered stings but may be used for un-tapered strings. Rationale This variance is being requested because the lack of vertical space in the rigs' sub-bases on these small platforms does not permit the installation of a three-ram stack. Only a two-ram stack is short enough to fit. Background XTO Energy found at the commencement of its 2000 - 2002 drilling program, its first since purchasing Platforms A and C from Shell Oil Company, that a standard 3-ram BOP stack was too tall to fit in the platforms' rig substructures. The Commission was contacted and it was agreed that a 2-ram stack could be used as long as one ram was a blind ram and the other was a pipe ram that always had rams that fitted to the pipe being run into and out of the hole. Further, it was agreed that, if a tapered string was being used in the hole, a variable bore ram would have to be substituted for the pipe ram. The attached BOP schematic indicates the BOP stack arrangement proposed by XTO. If this is approved by the Commission, XTO requests that the Commission place this approved BOP Waiver Request and BOP Schematic on file as it is intended to apply to all workover and drilling projects on these platforms. ~TO ~kRGY XTO Energy Inc. BOP's for MGS Platform A & C 13 5/8" 5,000 PSI WP. HYDRIL GK ANNULAR PREVENTER W/ COMPANION FLANGE TO BELL NIPPLE DOUBLE 13-518" 5.000 PSI WP. SHAFFER SL BOP WI BUND RAMS ON TOP It PIPE RAMS OR VARIABLE RAMS ON BOTTOM 2. 5,000 PSI WP MANUAL GATE VALVE 2. 5.000 PSI WP MANUAL GATE VALVE 3. 5,000 PSI WP w/ HYORAUUC ACTUATOR GATE VALVE . 3. 5,000 PSI WP MANUAL GATE VALVE 13 5/8. 5,OOÖ PSI WP ORIWNG SPOOL W/ TWO 3. 5101 PSI WP OUTLETS ," 5,000 PSI WP RISER OSA 13 5/8. 5,000 PSI WP X 11. 5,000 PSI WP - .. BOP COMPONENTS MIDDLE GROUND SHOAL FIELD PLATFORM "A. -1- 8 - e CN88 11m""" 011 Compe", ... . 100-:AK-P1003 Prepared By: Paul Figel 7-21-04 ~!9 July 26. 200~ iIo1-t'03 I\..h. John Norman. Chair Alaska Oil and Gas Consen ation Commission 333 \Vest 7lh Ave.. Suite 100 Anchorage. Alaska 9950 I , I " i ~, RE: Application for Sundry Appro\,1!: P&A of l\IGS 'Veil C31-26. Cook Inlet. Alaska Dear 1\lr. Norman. XTO Energy. Inc. hereby applies for Sundry Approval of its plan to permanently abandon the perforations ex.isting in 1\.liddle Ground Shoal \Vell C31-26 to allo\\' the sidetracking of that \\ell to drill C31-26RD. The Application for Permit to Drill C31-26RD is submitted under separate CO\ er. The anticipated commencement date of this \\'ork is approx.imately August 15. 200~. The ex.isting tubing \\ill be pulled and the six. ex.isrlng packers left in the \\ell. A retainer will be set approximately 1-1-0 feet above the topmost perforation and a sufficient volume of cement will be squeezed through the retainer to fill the wellbore belo\\ it to PBTD. Additional cement will then be placed on top of the retainer. The cement plug integrity will then be verified with pressure and the \\'ell sidetracked to a new location in the reservol r. Pel1inent information attached to this application includes the following: 1 ) 2) 3) ~) Form 10-~03 Application for Sundry Approval A summary of the proposed abandonment procedure A schematic sho\\ing the CUITent condition of the \\ellbore A schematic showing the proposed abandonment If you ha\'e any questions or require additional information, please contact me at (~32) 620-6718 or Bi II Penrose at (907) 258-3-1-~6. OR'GINAL \TO Energy Inc. . 3000 N. Garfield. Suire 175 . l\1idland. Texas ï9705 . (915) 682-8873 . Fax: (915) 687-0862 1\1r. John Norman Page .2 Sincerely, XTO ENERG'{, INC. AL~ Bobby L. Smith Dri lIing/Operations 1\lanager enc losures cc: Bi II Penrose " I I . , Abandon LJ Aller casing 0 Change approved program 0 2. Operator Name: 1. Type of Request. XTO Energy, Inc. 3. Address: STATE OF ALASKA ! ALASKA OIL AND GAS CONSERVATION COMMI::;SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New PaolO 4. Current Well Class: kdV Suspend U Repair well 0 Pull Tubing 0 Perforate U Waiver U Annular Dispos. U Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Development Stratigraphic 0 0 6. API Number: Exploratory 0 0 167-063 Service 3000 North Garfield, Suite 175, Midland TX 79705 7. KB Elevation 1ft): 105' ASL 8. Property Designation: ADL-18756 11 . Total Depth MD (ft : Total Depth TVD 1ft): 9,707' 9,935' Casing Length Structural Conductor Surface Intermediate 1,895' Production Liner 9,927' 9. Well Name and Number: 50-733-20052-00 RE:CEiV'ED MGS C31-26 10. Field/Pools(s): .JUl 2 ij 2004 Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Effective Depth MD 1ft): Effective Depth TVD (ft): ,\Iai*a Oil & GaG CcN.~! Plugs (measured): Junk~ttJl: Fill @ 9,640' WL Fish @ 9,658' Burst Collapse 9,640' 9.345' Size MD TVD 10-3/4 " 1,895' 1,894' 3,130 psi 1,580 psi 9,927' 9,504' 6,340' psi 3,830 psi Tubing Size: Tubing Grade: Tubing MD (ft): 7" Perforation Depth MD (ft): 8,742' - 9,700' Packers and SSSV Type: Perforation Depth TVD 1ft): 8,538' - 9,477' See attached schematic. 9,465' See attached schematic 3-1/2 " Packers and SSSV MD (ft): N-80 12. Attachments: Description Summary of Proposal L:J Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 8/1 5/2004 Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Abandoned WDSPL 0 0 0 Service 0 Plugged 0 WINJ 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best ot my knowledge. Title Contact Bill Penrose 258-3446 Drilling/Operations Manager '-'/"~::h/ 1/' ~ 'j c.:/~/ Printed Name Bobby Smith Signature ~ t b;,.(/ Phone (432) 620-6718 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~\-\ -d-~t Mechanical Integrity Test 0 Location Clearance 0 Dlher: SOoO ~ ~ ß'í:Ji?!w.<A 0-".> ~\ o.t'-,,~, ~\ ~ 1" "'i'.K~" ~'ù \ ~ \- ~ "> '\ .:., \-\<-0.. \ \e;. \- '-' '1""'<>" 'i '0 rc \N, -\ ('..«:.<> sJd. 'òO \' ~<;. \\ I'\~ \'-1 Ú. \ ~,,-\ \ù ." W ()" \<.- t\~ -\ ""-O"Œ -\ "-ü ~ '- i:h 'f :~~UJ.:\ ç\ Plug Integrity ~ BOP Test ~ Approved - ~ ~ I '.', '. ~ ì.~; .'.~ !,~,¡,; ~~' :.' I ! , .1- .L - , Date: ~/ ð$' ./ Submit in Duplicate COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE XTO Energy, Inc. MGS C31-26 . 1- ~ hI/DO P&A Procedure 1. RiU slickline, Rill to GLl'vl #7 at 8,564' and pull orifice from pocket. POH and RID slickline but do not release slickline unit. 2. rvlo\'e rig over we]]. l'vlix a 10.8 ppg water-base lnud system. Kill we]] by circulating n1ud down the tubing, through the open pocket at 8,564' and up the aIIDulus. (Reservoir pressure is expected to be in the range of 10.3 to 11.5 ppg EMW. While circulating, weight up the lTIud in sman incren1ents until it is heavy enough to kill the wen.) Ifkilling the well offbottOln in this 111alUler becomes difficult, use the slickline unit to set a plug in the x-nipple at 8,651 ' to isolate the perforations. 3. Install BPV, N/D tree, N/U BOPE. Test BOPE to 5,000 psi. [Note: at the discretion of the Drilling Super\'isor and AOGCC Inspector (if present), blind rams win be tested after tubing is pulled frOln hole if there is a chance a gas bubble will settle under BPV, nlaking it difficult or dangerous to release.] Pull BPV. 5. If a plug was set in the x-nipple at 8,651', use the slickline unit to remove it. RID and release the slickline unit. 4. rvl/U landing joint to tubing hanger, back out lock-down scre\vs and pull hanger to drill floor, un-stinging the seals from the PBR at 8,684'. Circulate mud until returns are clean and unifo1l11. \>Gèti\Q: ~<:ø \ y I.. 5. Ensure wen is dead and POH with tubing, checking for NORl\.1 while POH. LID tubing and completion je,velry and send to shore. 6. lVUlJ aT', 29# casing scraper on 3-112" drill pipe, and RIH to the top of the PBR at 8~684'. CBU and POH. 7. rvl/U cement retainer for T', 29# casing, RIH and set retainer at 8,600' (-142' above top perforation). 8. Establish injection into the perforations below the retainer. Un-sting fro111 retainer. 10. l\1ix and punlp 10 bbls of fresh water followed by 40 bbls of celnent as follows: Cement to consist of 195 sx Class G + 0.3% bwoc CD-32 + 0.6% bwoc FL-33 + 1 gaL' 1 OOsx FP-6L + 43.7%) fresh water: Slurry Wt. 15.8 ppg Slurry 'field 1.15 cf/sk ìvlix Water 4.94 gps Displace cement to the stinger. Sting into the retainer and squeeze 39 bbls below retainer and into perfs. Un-sting from retainer and place the last barrel of cement on top of the retainer. POH. 12. l'vffU a casing scraper for T', 26# casing and RIH to 7,350'. Pressure test the T' casing and cement plug to 3,000 psi. 13. POH and proceed with sidetrack procedure to drill C31-26RD. ;[19 MGS C31-26 Cook Inlet, Alaska Leg 1 Conductor 5 API No. 50-733-20052 Spud:Oct 1967 Well SI Oct 1999 Surf Csg: 103/4", 40.51b, J55. Set @ 1,895'. Cmt wI 1,600 sk. Longstring: 7" N80 BTC. Set @ 9,927'. 23# : Surf - 5,600' 26# : 5,600 - 8,100' 29# : 8,100 - 9,927' Cmt wI 1,350 sk. TOC by CBL @ 6,260' Tbg leak @ 9,266 - 70' Top of Fill @ 9,640' Fish: 3+ WL strings @ 9658' PBTD: 9,849' MD (9,621' TVD) TD: 9,935' MD (9,707' TVD) Present Completion \ ) :::o:I >< ~ J J Wi J J J J J J ~ ~1 ~- 8'"""'.8 .. <: J ~~- ::II: ~~ .....,...--- PLF 8-7-03 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2" 9.3# N80 8rd EUE @ 9,465' String below 8,675' packoff set in 1973. String above 8,675' packoff set in 1993. GLM 1 2 3 4 5 6 7 Port Pso 16 999 16 957 16 915 16 895 16 865 16 831 3/16 Orifice MO 1866' 3527' 4944' 6085' 7048' 7883' 8564' TVO 1855' 3519' 4906' 5996' 6908' 7705' 8365' Baker FV-6 SSSV wI X profile (2.813" ID) @ 336' Tbg Patch (set on SL): 3 1/2" RCP pkr (1.31" ID) 9,266' 3-10' pups, 1 1/2" 2.3# NUE 10R 1.38" ID NoGo locator Seal Assy wI MS btm 31/2" RCP pkr (1.31" ID) @ 9,311' F Stop @ 9325' 7" Baker HB Retr pkr (47B2) @ 8614' Otis X nipple @ 8651' (2.813" 10) Baker GBH-22 80-40 Seal Assy & PBR @ 8684' Otis XO Sliding Sleeve @ 8705' Guiberson Uni VII pkr @ 8713' GR-GS: 8742-8780' HC-HO: 9037-9069' Cameo KBM Gas Lift Mandrel @ 9080' Otis XO Sliding Sleeve @ 9086 Guiberson Uni VII pkr @ 9095' HE-HF: 9144-9194' Cameo KBM Gas Lift Mandrel @ 9195' Otis XO Sliding Sleeve @ 9201' Guiberson Uni VII pkr @ 9219' HI-HK: 9258-9297' Cameo KBM Gas Lift Mandrel @ 9283' Otis XO Sliding Sleeve @ 9288 Guiberson Uni VII-pkr @ 9298' HK-HN: 9311-9448' Cameo KBM Gas Lift Mandrel @ 9441' Otis XO Sliding Sleeve @ 9446' Guiberson Uni VII pkr @ 9456' Otis X nipple @ 9464' Otis Q nipple @ 9465' HN-HR: 9471-9610' HR-HZ: 9640-9700' XTO Energy MGS C31-26RD Inlet Drilling Rig Middle Ground Shoal Field Alaska July 13. 2004 Well Recommendation Prepared for: Bill Penrose Project Drilling Engineer Fairweather E&P Services Inc. !£j Proposal No: 100185186A Prepared by: J. Jay Garner Manager. City Sales Kenai, Alaska Bus Phone: (907) 349-6518, Anchorage Email: jgarner@bjservices.com Mobile: (907) 229-6536 POW E R \' I S ION:M Service Point: Kenai. AK Bus Phone: (907) 776-4084 (907) 659-2329 (907) 776-4087 Fax: Service Representatives: J. Jay Garner Manager. City Sales Kenai, Alaska Bus Phone: (907) 349-6518. Anchorage Email: jgarner@bjservices.com Mobile: (907) 229-6536 Gr.J 1ÜS ;{t9 MGS C31-26 Cook Inlet, Alaska Leg 1 Conductor 5 API No. 50-733-20052 Spud:Oct 1967 Well SI Oct 1999 Surf Csg: 103/4",40.5 Ib, J55. Set @ 1,895'. Cmt w/1 ,600 sk. Longstring: 7" N80 BTC. Set @ 9,927'. 23# : Surf - 5,600' 26#: 5,600 - 8,100' 29# : 8,100 - 9,927' Cmt w/1 ,350 sk. TOC by CBL @ 6,260' Tbg patch @ 9,266- 9,311' Top of Fill @ 9,640' Fish: 3+ WL strings @ 9658' PBTD: 9,849' MD (9,621' TVD) TO: 9,935' MD (9,707' TVD) Proposed P&A % .~ WJP 7-21-04 KB: 35' Water Depth: 73' MSL 7" Baker HB Retr pkr (47B2) @ 8614' Otis X nipple @ 8651' (2.813" ID) Baker GBH-22 80-40 Seal Assy & PBR @ 8684' Otis XO Sliding Sleeve @ 8705' Guiberson Uni VII pkr @ 8713' GR-GS: 8742-8780' HC-HD: 9037-9069' Cameo KBM Gas Lift Mandrel @ 9080' Otis XO Sliding Sleeve @ 9086' Guiberson Uni VII pkr @ 9095' HE-HF: 9144-9194' Cameo KBM Gas Lift Mandrel @ 9195' Otis XO Sliding Sleeve @ 9201' Guiberson Uni VII pkr @ 9219' HI-HK: 9258-9297' Cameo KBM Gas Lift Mandrel ~ 9283' Otis XO Sliding Sleeve @ 9288 Guiberson Uni VII pkr @ 9298' HK-HN: 9311-9448' Cameo KBM Gas Lift Mandrel @ 9441' Otis XO Sliding Sleeve @ 9446' Guiberson Uni VII pkr @ 9456' Otis X nipple @ 9464' Otis Q nipple @ 9465' HN-HR: 9471-9610' HR-HZ: 9640-9700' Operator Name: XTO Energy Well Name: MGS C31-26RD Job Description: Cement Plug Date: July 13. 2004 JOB AT A GLANCE Casing SizelWeight : Pump Via Total Mix Water Required Spacer Water Density 1st Tail Slurry Abandonment Plug Density Yield Displacement Drilling Mud Density ~ .;,,~,,:.rr ¡:,,"'.'I-=-''J .jr, )1.Jlr I) '::(II)J : :.~ ¡:. rJ !£j Proposal No: 100185186A 7 in, 29 Ibs/ft Drill Pipe 3 1/2" 0.0. (2.764" .1.0) 13.3 # Page 1 961 gals 10 bbls 8.4 ppg 195 sacks 15.8 ppg 1 .15 cf/sack 73 bbls 13.2 ppg ,:;r.LIi)':t Operator Name: XTO Energy Well Name: MGS C31-26RD Job Description: Cement Plug Date: July 13, 2004 FLUID SPECIFICATIONS Spacer PLUG NO. 1 VOLUME CU-FT 224 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) VOLUME FACTOR 1.15 !£j Proposal No: 100185186A = 10.0 bbls Water @ 8.42 ppg AMOUNT AND TYPE OF CEMENT = 195 sacks Class G Cement + 0.3% bwoc CD-32 + 0.6% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.7% Fresh Water = 73.1 bbls Drilling Mud @ 13.2 ppg PLUG NO.1 15.80 1.15 4.93 4.94 1. Final system designs are subject to adjustment based on results of pending pilot blend testing. ~.:,r,,":"1 P,"II",Ir.''] jr, Jul, I:. "I)(¡J ;. 2-:' ¡:. Page 2 (,1.11:)1 Operator Name: XTO Energy Well Name: MGS C31-26RD Date: July 13, 2004 !£j Proposal No: 100185186A PRODUCT DESCRIPTIONS ASA-301 Additive used to reduce or eliminate free water and settling in cement slurries. Barite A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 Ibs/gal. Bentonite Commonly called gel, it is a clay material used as a cement extender and to control excessive free water. CD-31 A free flowing high molecular weight dispersant used to lower slurry viscosity and help provide turbulent flow properties at reduced pump rates. CO-31 also assists in fluid loss control. CD-32 A patented, free-flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial cementing. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures. FL-33 A patented cement fluid loss additive that provides exceptional fluid loss control across a wide range of temperatures, salinity conditions, and remedial cementing applications at low to high temperature ranges. FL-63 A non-retarding, non-viscosifying fluid loss additive particularly suited for use with coil tubing and/or close tolerance liner cementing. FL-63 is effective from low to high temperatures. Concentrations of 0.2% to 1.0% BWOC are typical. FP-6L A clear liquid that decreases foaming in slurries during mixing. MCS-4 A turbulent flow spacer system that prevents water and oil-base mud and cement contamination and water-wets the casing to increase bonding. MCS-AG A surfactant used in cement spacer systems to prevent mud incompatability and improve bonding. R-3 A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening time. R~,r:..~. l ¡j ' ¡",lto'J .j(, .lul, 1) ':(II:IJ ;.. :.~ ¡:r,' Page 10 I~r"¡ 1~.j XTO APD Subject: XTO APD From: Bill Penrose <bil1@{airweather.com> Date: 1\'1011, 26 Jul 2004 10:54:21 -0800 To: tom_maunder@'admin.state.ak.us Tom, I just dropped off some permitting documents to the Commission for approval. They are: Sundry Notice to P&A the existing C31-26 well bore APD for drilling the C31-26RD sidetrack, containing... ... a BOP waiver request When/if these get approved, would you please send me copies of the approvals (including the waiver approval) when you send the originals to XTO? That way I can make sure that everything gets to the platform for reference when the inspectors arrive for their duties. Thanks! Regards, Bill 1 of I 7/26/200..J 2: 11 PIVI Cross Timbers Operating Company August 23, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: MR. BLAIR WONDZELL SUBJECT: SUBMISSION OF FORM 10-404 REPORT OF SUNDRY WELL OPERATIONS - LOG, ACID TREAT & REPAIR M.G.S. WELL NO. C31-26. Attached, in duplicate, is the Report of Sundry Well Operations for MGS Well No. C31-26. The workover included logging, acidizing and an attempt to install a new packer. Unfortunately, the new packer would not set thus this well is temporarily shut in pending rig work to correct the problem. Mr. Marshall, Field Superintendent, will be meeting with Cross Timbers management to discuss the anticipated rig mobilization date which will allow for repair to be completed on C31-26. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 www. crosstimbers.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging-- Perforate ...... Pull tubing __ After casing_ Repair well X Other 2. Name of~peFator Cross llmDers Operatinq Compan,y 3. Address 52260 Shell Road Kenai, AK 99611-9704 5. Type of Well: Development X Exploratory Stratigraphic Service __ 4. Location of well at surface Leg 1, Cond. 5 @ 537'FSL&1593'FEL of Sec. 23,TSN,R13W,SH At top of productive interval @8742', 931' FNL&1572' FEL of Sec. 26,T8N, R13W, SM At effective depth At total depth @9935', 1079'FNL&1742'FEL of Sec. 26,T8N,R13W,SH 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9935 feet 9708 feet 9849 feet 9623 feet Plugs (measured) 6. Datum elevation (DF or KB) ~10' KB 7. Unit or Property name Middle Ground Shoal feet 8. Well number C31-26 9. P~.rmit number/approval number 67- 63/399-127 .. APl number 5o- 733-20052 -' O(~ 11. Field/Pool MGS "G" Pool Junk (measured) Wi rel i ne junk @ 9658' Casing Structural Conductor Surface. Intermediate Production Liner Perforation depth: Length Size 1895' 10-3/4" 9927' 7" measured 8742' - 9700' true vertical 8538' - 9476' (7 intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9465' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 1600 sx 1895' 1894' 1350 sx 9927' 9700' ORIGINAL Baker HB @8614'. Guiberson@8713',9095',9219',9298'@9456'.SSSV@327'. 13. Stimulation or cement squeeze summary Intervals treated (measured) 8592' - 9700' Treatment description including volumes used and final pressure Log, acid wash & attempt to ~eplace packer. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 0 0 0 0 Casing Pressure Tubing pressure 0 0 0 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended ,, Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title 0ffice Hanager Date 08/23/99 ~ SUBMIT IN DUPLICATE~ Form 10-404 Rev 06/15/88 - 44 - DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS PLATFORM C C31-26 AFE #: 99397 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING # : CLASSIFICATION: RUN PRODUCTION LOG TO LOCATE TUBING FAILURE DESCRIPTION: PLATFORM C CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 4/30/99 05/01/99 08/10/99 FIRST REPORT. Objective: Run Production Log to Locate Tubing Failure. Date First Report 04/30/99 Well was SI prior to survey. Put well on production and test 4pm day before running tests. Flowing 996 BFPD (cut .5% oil) w/ input of 550 MCF/D gas lift gas. FTP 130#. CP 430%. RU CTOC slickline and Schlumberger memory production logging tools (Pressure, Temperature, GR, CCL, Spinner). Press test lubricator. RIH to 9040' wlm. POOH @ 50 ft/min. Stop at 8350' wlm. RIH @ 50 ft/min. Stop @ 9040' wlm. POOH @ 100 ft/min to 8350'. RIH @ 100 ft/mi to 9040' wlm. POOH @ 150 ft/min to 8350'. RIH @ 150 ft/min to 9340' wlm. POOH and made 5 min stops @ 9360', 9220', 9110', 8800', 8660', 8500' wlm. POOH. RD Schlumberger. Preliminary results show tubing leak is at the gas lift mandrel @ 9283'. Objective: Pull & Replace GLV @ 9283' & Test Well. SI. RU CTOC WL. Press test lubricator. RIH w/3" "N" kickover tool & 1 1/4" pulling tool. Attempted to find gas lift mandrel @ 9283' md. Could not locate mandrel. Worked for 1 hr. POH & ckeck tools - OK. Extend arms on kickover tool & reran. Worked 2 hrs to locate mandrel @ 9283' md. POH. Located gas lift mandrel @ 9170' & 9050' md. RD WL equip. Left well SI. DCC: $4500 (Schlumberger Log) TEMPORARILY DROP UNTIL FURTHER ACTIVITY RETURN TO REPORT. Previous Production: SI last test 5 BOPD, 962 BWPD, 0 MCF/D. Test prior to leak 74 BOPD, 156 BWPD, 98 MCF/D. Objective: Repair Downhole Tubing Failure. Date First Report: 04/30/99. DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS PLATFORM C C31-26 AFE #: 99397 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING # : CLASSIFICATION: RUN PRODUCTION LOG TO LOCATE TUBING FAILURE DESCRIPTION: PLATFORM C CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 08/11/99 RU Dowell. Held safety mtg. Press test CT to 4500 psi & BOP to 4500 psi. Make up BHA: Grapple connector, check vlv, x-over, hydraulic disconnect, pec circ vlv, dwnhole filter, swvl jr, 2.625" gauge ring, rotating nozzle head (2 side jets @ 125" & 1 dwn jet @ 093"), total length 8.145". TIH @ 70 fpm while pmpg 1.2 BPM FIW. SD @ 8585'. Broke thru. Work CT thru tight spot. Pmp on CT @ 3770 psi w/surf press @ 140-165 psi. Surf press went to 0 psi. Worked CT thru tight spot. Surf press went to 530 psi. Had a small amount of gas to surf. Continue in hole to 8592'. SD. Bkr pkr @ 8614'. Work CT. Pmp 2 bbl xylene, 2 bbl of 10% HCl, 2 bbl xylene, 2 bbl of 10% HCl. Displaced w/33 bbl of FIW. Jet btm. Broke thru. Work in hole to 8607'. Unable to work deeper. Circ out xylene & acid H2S 100 ppm. Acid was spent to pH of 6.5. POH. LD Dowell BHA. Make up BHA to drill up scale. Bkr grapple connector, XO, Bkr DFV, Hyd disconnect, XO, circ sub. Bkr Mach 1 motor, XO, 2.70" OD 3 bladed drag bit. SD @ 8600'. Drill thru @ 0.3 fpm. Drill out @ 8627'. RIH @ 20 fpm to 9326' & SD. Drill @ 5 fpm. Drill out @ 9330'. Continue in hole to 9508'. EOT @ 9466' SD solid. Drill out to 9509'. Unable to make additional hole. POH. Perfs below btm pkr 9471-9700'. DCC: $38,000 CCC: $38,000 Make up BHA: External Grapple connector, XO, check vlv, XO, XO, hydraulic disconnect, pce circ vlv, dwnhole filter, swvl jr, 2. 625" gauge ring, rotating nozzle head (2 side jets @ .125" & 1 dwn jet @ .093"), total length 9.445". TIH 75 fpm slowing to 20 fpm @ 8600'. Pmp 28 bbl of 10% HCl & jet across perfs & pkr setting depths. Circ out of hole w/FIW. Pmp H2S scavenger into flow stream. H2S DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME' MGS PLATFORM C C31-26 AFE #: 99397 ESTIMATED TD' PBTD: COUNTY/STATE' Cook Inlet, AK ACCOUNTING # · CLASSIFICATION' RUN PRODUCTION LOG TO LOCATE TUBING FAILURE DESCRIPTION' PLATFORM C CONTRACTOR' OPERATOR' CROSS TIMBERS OPERATING COMPANY GL' KB' DF' 4000 ppm. Circ btm up. Spot 20 bbl xylene on btm. Sqz into formation. Up & spot 50 bbl FIW w/5 gal corr inhibitor. POH. DCC' $74,500 CCC' $112,500 08/12/99 PU Baker inflatable pkr assembly- Item OD ID Length Btm: Inflatable pkr w/pmp out plug 2.625 1.0 9.55 Expansion Jt 2.625 1.25 1.64 X-over 2.125 1.0 .48 1 3/4" CT connector 2.25 1.0 1.38 1 3/4" Coiled Tbg 1.75 1.532 841.6 HS80, 2.77#/ft, 0.109" wall, Yield 43800, 90% burst 8300 psi, 9000 psi collapse 1 3/4" CT connector 2.25 1.0 1.38 X-over 2.125 1.0 .67 Top: Inflatable pkr 2.625 1.0 9.82 On pkr running assembly. Made up & ran btm Bkr inflatable pkr assembly & 843.6' of 1 3/4" CT. Close BOP's & set slips. ND lubricator. Cut CT. Unable to get CT connector on. OD of CT 1.78". ID of connector 1.75" Send connector to onshore to grind out to 1/78". Installed top pkr assembly & pkr running assembly. NU lubricator. RIH w/btm pkr & 843.6' of 1 3/4" CT. Install top inflatable pkr & running assembly. RIH to 9445' (btm pkr @ 9445' & top pkr @ 8584'). Pmp 1/2" ball to setting tool. DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS PLATFORM C C31-26 AFE #: 99397 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING # : CLASSIFICATION: RUN PRODUCTION LOG TO LOCATE TUBING FAILURE DESCRIPTION: PLATFORM C CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: Press increased 500 psi & began setting pkrs. Still had circ to surf, indicating a BHA failure. Increase rate to try to seat ball. No success. Press bled off. POH w/BHA. Cut out BHA. Lost 2' of CT. Top pkr had started to set & btm pkr had not. Send pkrs & setting tool to the beach for repairs. SD for 7 hfs to repair pkrs. Make up new BHA w/o inflation vlv. TIH as before. Attempt to set pkrs w/EOT @ 945' Press up to set pkrs. CT & wellhead press came up together & fell off together. Pkr would not take weight. POH w/BHA & LD. RD Baker & Dowell. Leave well SI. DCC: $9000 CCC: Corrected $125,000 08/13/99 Well SI. DCC: $-0- CCC: $125,000 08/14-16/99 Well SI. DCC: $-0- CCC: $125,000 TEMPORARILY DROP UNTIL FURTHER ACTIVITY Cross Timbers Operating ComRany ~ Present Completion MGS Platform C C31-26 Cook Inlet, Alaska Leg 1 Concluctor 5 APl No. 50-733-20052 Spud:1967 Surf Csg: 10 3/4", 40.5 lb, J55. Set @ 1895'. Cmt'd wi TOC @ Proa Csg: 7". 23.26 & 29 lb N80. Set @ 9927'. Cmt wi PBTD: TD: BHL: 9849' MD 9621'TVD 9935' MD 9707'TVD 134'W& 1614'S 4119~99 cdp .... ~ on nuc~abee 4/29193 KB: 105' Water Depth: 73' MSL Tubing:3 1/2' 9.3# NS0 8R EuE (sotne ABMod) GLM MD TVD Port P$o 1 1866' 1855' 16 999 2 352;" 3519' 16 957 3 4944' 4906' 16 915 4 6085' 5996' 16 895 5 7048' 6908' 16 865 6 7883' 7705' 16 831 7 8564' 8365' 3/16 Orifice Baker HB pkr ~} 8614' Otis X nipple ~} 8651' ( 2.813" ID) Baker GBH-22 80-40 Seal Assy & PBR ¢~ 8684' Otis XO Sliding Sleeve ~ 8705' Guiberson Uni VII pkr ~ 8713' GR-GS: 8742-8780' (holes) HC-HD: 9037-9069' (holes) Camco KBM Gas Lift Man~lrel ~ 9080' Otis XO Sliding Sleeve ~ 9086' Guiberson Uni VII pkr ~ 9095' HE-HF: 9144-9194' (holes) Camco KBM Gas Lift Mancirei ~ 9195' Otis XO Sliding Sleeve @ 9201' Guiberson Uni VII pkr (~ 9219' HI-HK: 9258-9297' (holes) Camco KBM Gas Lift Manclrel ~ 9283' Otis XO Sliding Sleeve ¢~ 9288' Guiberson Uni VII pkr ~ 9298' HK-HN: 9311-9440' (holes) Camco KBM Gas Lift Mandrel ¢~) 9441' Otis XO Sliding Sleeve ~ 9446' Guiberson Uni VII pkr ~ 9456' Otis X nipple ~) 9464' Otis Q nipple ~ 9465' HN-HR: 9471-9610' (holes) HR-HZ: 9640-9700' (holes) Fish: 3+ WL strings ~) 9658' ID: . ~ Cross Timbers Operating Company JUL 12'55 No.O02 P.04 ,1 uly 19, 1999 Alaska Oil & Oas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: MR. BLAIR WONDZEI.[, SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO ACID TREAT & REPAIR M,O.S. WEI.I. NO. C31-26. Attached is the revised procedure lbr the acid job for (:31-26. Please accept this fhxed copy as a replacement for tl~e procedure which was submitted with the original application. Operations are expected to begin August 1, ] 999, If you have any questions, please don't hesitate to call me at (907) 776-2511. Thaidc you! Sincerely, Bill Miller Office Mana.ger Attad~mcnts HG01 Box 485, Did Wlk Road, Kenal, AK 990114)704 C)nghom phone: (907) 776-2511, Onshore fax: (,007) 776-2547 776-?o32 Plalform A fax: lg0r) 776-257P, Platform C fax: (907) '" ' www.erosstimbers.~om ID: 3Ut i 99 CROSS TIMBERS OPERATING COMPANY MGS C31-26 COOK INLET, ALASKA 12'55 No.O02 P.O$ ELEVATION: 105' KB 73' MSL WELL DATA SURFACE CASING: 10 3/4" 40.5# J55. Set ~ 1895'. Cmt w/. INTERMEDIATE CASING; None PRODUCTION CASING: 7" 23/26/29# NS0. Set at 9927', Cmt w/, LINER: None TUBING: 3 ½" 9.3//NS0 8R EUE (~ _, 9465' PERFORATIONS: GR-GS 8742-8790' SS closed HC-HD 9037-9069' SS closed HE-HF 9144.9194' SS closed HI.I-IK 9258-9297' SS closed HKqiN 9471-9610' producing HR-HZ 9640-9700' producing OBJECTIVE: Repair tubing failure (3 · 9270'using straddle packers on coiled tubing RECOMMENDED PROCEDURE MIRU Dowell Coiled Tubing Unil and Acid Pumper. Test Io 5000#. TIH w/ combination side blasting/bottotn blasting jetting tool on 1%" coiled tbg. Jet tbg clean to EOT (~, 9465' using FIW. Scale build up has been observed at +_ 8540' (btm GLV). Continue in hole to PBTD. Acid wash pert~ using 500 gal 0f7 ~A% HCI to remove scale. Displace w/FIW. Spot 50 bbl of FIW w/10 gal per 100 bbl of corrosion inhibitor from EOT to 3700'. Do not displace acid into perfs. If hole will not circulate, gas lift well to gain circulation. Note: 3 strings of WL tools are in the rathole, recorded top of fish at 9658'; tubing leak depth is ~. 9270'. ID: CROSS TIMBERS OPEl 'lNG COMPANY MGS C31-26 COOK INLET, ALASKA JUL 12:56 No.O02 P.06 = RU CT unit w/pressurized window. Test lines to 5000#. RIH w/3 ½" Baker Inflatable pkr assembly as follows: Top: Btm: 3 ½" Baker Inflatable retrievable packer (size 2 5/8", 2.625" running OD, 1,00" ID, length 11 '). 1.75" x 1' coiled tbg connector 873'of 1%" Coiled Tbg (1.75" OD, 1.532" ID, rain yield 45000//, tensile 49500#, mia internal yield 9400 psi, capacity 2.28 bbl/1000 ft displacement 0.97 bi/1000 f~) 1.75" x 1' coiled tbg connector 3 W' Baker Inflatable retrievable packer (size 2 5/8", 2.625" rurming OD, 1.00" ID, length 11 '). Pump offplug Run pkr assembly w/a hydraulic shear offtool on I SA" CT. PU to obtain assembly wt .just prior to setting depth. Set inflatable pkr per Baker instructions. Pump offplug and shear off pkr. POOH w/CT and setting tool. RD CT. 3. Put well on test. Test for 12 hrs per day until well is final reported. ID: Cross Timbers O~~' -attng company MGS Platform C C31-26 Cook Inlet, Alaska Leg I Conductor 5 APl No. 50-733-20052 Spud:1967 Present Completion Surf Csg: 10 3/4", 40.5 lb, J55. Set @ 1895'. Cmt'd wi TO(; @ Procl Csg: 7". 23, 26 & 29 lb NS0. Set @ 9927'. Cmt wi PBTD; 9849' MD 9621' TVD TD: 9935' MD 9707' 'TVD BHL: 134' W & 1614' S JUL ~l~,' 99 12'56 No .002 b~ on nucKGbee 4129/95 KB: 105' Water Depth: 73' MSL P .07 Tubing:31/2- 9.3~ NS0 8R EuE (same ABMod) GLM MD TVD Pelt 1 1866' 1855' 2 3527' 3St9' 16 3 4944' 4906' 16 915 4 ~' ~' 16 695 5 T~' 6~8' 16 6 7883' 7705' 16 7 8~4' 83~5' 3/18 Or~ Baker HB pkr I~ 85t4' Otis X nipple @ 8651' ( 2.813" ID) Baker GBH.22 80-40 Seal Assy & PItR l~18084' Otis XO Sliding Sleeve ~ 8705' Gulbemon U~i VII pkr ~ S713' GR-GS: 8742.8780'(holes) HC-HD: 9037-9069' (holes) Cam~ KBM Gas Lift Mandrel ~ 9080' Otis XO Sliding Sleeve ~ 9086' Guiberson Uni VII pkr ~ 9095' HE-HF: 9144-9194'(holes) Camco KBM Ge; I. ift Mandrel {~19195' Otis XO Sliding Sleeve ~ 9201' Guibsrson Uni VII pkr {~ 9219' HI-HK: 9258-9297' (holes) Camco KBM Gas Lift Mandrel ~ 9283' Otis XO Sliding Sleeve I~ g288' Guiberson Unl VII Ncr ~ 9298' HK-HN: 9311-9440' (holeS) Camco KBM Gas Lift Mandrel l~19441' Otis XO Sliding Sleeve tt~ 9446' Guibarson Uni VII pkr II~ 94,56' Otis X nipple I~ 941~' Otis Q nipple i~l 9485' HN-HR: 9471-9610'(holes) HR-HZ: 9640-9700' (holes) Fish: 34, WL strings {~ 965§' Cross Timbers Operattng Company July 12, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO ACID TREAT & REPAIR M.G.S. WELL NO. C31-26. Enclosed in triplicate is the Application for Sundry_ Approval, Form 10-403, to stimulate MGS C31-26 utilizing 7-1/2% HC1 and then install a new Baker "FA" Permanent packer. Operations are expected to begin August 1, 1999. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments RECEIVED JUL 15 t9B9 AJaska 0ii & Gas Cons. Commission Anchorage HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 www. crosstimbers.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation shutdown Re-enter suspended well...... After casing ~ Repair well X Plugging Time extension Stimulate X Change approved program. Pull tubing Variance Perforate ~ Other 2. Name of Operator Cross Timbers Operatinq Company 3. Address 52260 Shell Road Kenai, AK 99611-9704 5. Type of Well: Development X Exploratory Stratigraphic Service ,,, 4. Location of well at surface "C", Leg 1, Cond. 5 ca 537'FSL & 1593'FEL of Sec. 23,T8N,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 At top of productive interval ca8742', 931'FNL & 1572'FEL of Sec. 26,T8N,P,13W,SM At effective depth At total depth ca9935', 1079'FNL & 1742'FEL of Sec. 26,T8N,R13W,SM 9. Permitnumber 67-63 ~O. APInumber 50- 733.20052 11. Field/Pool MGS/"G" Pool · 12. Present well condition summary Total depth: measured true vertical 9935 feet Plugs (measured) 9708 feet feet Effective depth: measured true vertical 9849 feet Junk (measured) 9623 feet Wi reline Junk Ca 9658' Casing Length Structural Conductor Surface 1895' Intermediate Production 9927' Liner Perforation depth: Size Cemented 10-3/4",40.5#,J-55 1600 sx 7",23-29#,N-80 1350 sx measured 8742' 9700' true vertical 8538' - 9476' (7 intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.3/f, N-80 EUE ca 9465' Measured depth True vertical depth 1895' 1894' 9927' 9700' RECeiVED JUL 15 19;99 L Naska 0il & Gas C0r~, Commission Anchorage Packers and SSSV (type and measured depth) S Baker "HB" PackerCa8614'. Gui ber on PackerCa8713', 9095', 9219', 9298'&9456'. SSSVCa327' 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 08/01/1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended __ 17. I hereby certify that th_~e foreooir~ is true and correct to the best of my knowledge. Signed _ ~/~,/~.,'~~ Title Office Manager FOR COMMISSION USE ONLY Date 07/12/1999 Conditions of approval: Notify Commission s?~rcpresentative may witness Plug integrity . BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 1'-~'- ~;r~' ORIGINAL SIGNEDBY Approved by order of the Commission ROI3ert N. Chdstenson Form 10-403 Rev 06/15/88 [Approval No. J~;;;~ ¢,/f~.~ 7 Commissioner Date "~' "'",~ ¢-- ~"',~ SUBMIT IN TRIPLICATE Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 April 29, 1993 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C31-26; 10-403 Approval #93-076 Enclosed are duplicates of the Subsequent Report for the recently completed workover operations on Middle Ground Shoal Well C31-26. The work was completed on April 7, 1993. If you need additional reports or information, please contact me at (907) 263-9646. Yours truly, P. T. Huckabee Staff Production Engineer Alaska Producing Operations PTH/maj Enclosures RECEIVED Alaska Oil & Gas Cons. Commissior) Anchorage _~ STATE OF ALASKA ~ A~, A OIL AND GAS CONSERVATION COMMI~[, ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging Perforate Pull tubing X Alter casing Repair well X Other 5. Type O! Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc Developmenl X 116'KB feet Exploratory 7. Unit or Property name 3. Address 601 West 5th Avenue, Suite 810 Anchorage, Alaska 99501 Stratigraphic Middle Ground Shoal Service 8. Well Number 4. Location of well at surface Platform C, Leg 1, Conductor 5 @ 537'FSL, 1593'FEL, Sec. C31-26 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval @ 8742', 931 'FNL and 1571'FEL, Sec. 26, T8N, R13W, SM 67-63/93-076 10. APl number At effective depth 50-733-20052 11. Field/Pool At total depth @ 9935', 1079'FNL and 1742'FEL, Sec. 26, T8N, R13W, SM Middle Ground Shoal/G Pool 12. Present well condition summary Total depth: measured 9935 feet Plugs (measured) true vertical 9708 feet Effective depth: measured 9849 feet Junk (measured) Wireline Junk @ 9658' true vertical 9623 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1895' 10-3/4", 40.5~, J-55 1600 sx 1895' 1894' Intermediate Production 9927' 7", 23-29#, N-80 1350 sx 9927' 9700' Liner Perforation depth: measured 8742'-9700' true vertical 8538'-9476' (7 Intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE @ 9465' Packers and SSSV (type and measured depth) Baker "HB" Packer @ 8614', Guiberson Uni-VII Packers @ 8713', 9095', 9219', 9298', & 9456', Baker "FV6" SSSV @ 336' nr rl l D !13. Stimulation or cement squeeze summary ~, [~ I~ r.. i! v L Intervals treated (measured) N/A M AY - 5 Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons. C0mm'tss%~ Annhnrag~ 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 280 300 Subsequent to operation 49 0 607 950 80 15. Attachments: MIT test form 16. Status of well clasSification as: Copies of Logs and Surveys run Daily Report of Well Operations -k-- Oil X_~_ Gas__ Suspended__ Service 17. I hereby certify tl3at tl3e foregoing is true an(~ correct to tl3e best of my I(nowle(~ge Slgned..~,.,''0 ~r Title Staff Production Engineer Date ~/0~/~ r-_"_~ ,t _.. ,,~#~ ~ ,,-, ~, ,~..,~ ,. ........ ". __ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ATTACHNENT DAZLY REPORT OF HELL OPERATIONS HELL HGS C31-26 HELL: C31-26 4/2/93 - RIG UP - MIX CACL2 COMPLETION FLUID 4/3/93 - HAVE SAFETY/OPERATIONAL MEETINGS FOR KILL OPERATIONS - TEST TUBING PUMP-IN LINE TO 1500 PSI - KILL WELL W/10.2-10.3 PPG CACL2 FLUID. PUMPED ± 360 BBL @ 2.0 BPM. RETURN FLUID SHIPPED TO ONSHORE - TRANSFER REMAINING FLUID IN MUD TANKS TO 2 COMPARTMENTS - CIRC. WELL - NO APPARENT FLUID LOSSES TO HOLE - CHECK FOR FLOW - NO FLOW ON EITHER TUBING OR ANNULUS - INSTALL BPV W/LUBRICATOR - WELL APPEARED TO BE TAKING SOME FLUID - RIG DOWN CIRCULATING VALVES & LINES - N.D. & REMOVE UNI-TREE, NU RISER, SPOOL AND BOPE 4/4/93 - FINISH NIPPLE UP BOPE. INSTALL 3-1/2" + BLIND RAMS - HOOKUP TEST PUMP, FLOW, CHOKE AND KILL LINES - TEST BOPE, ALL TO 250 PSI AND 2500 PSI. INSIDE BOP, FLOOR SAFETY VALVE, KILL LINE AND VALVES, CHOKE MANIFOLD VALVES AND LINES, PIPE RAMS AND HYDRIL, ACCUMULATOR PERFORMANCE TEST - PULL BPV - TOOL NOT MAKING UP PROPERLY - RIG UP TO PUMP THROUGH B.P.V. - SMALL AMOUNT OF GAS UNDER BPV. CHUNK OF PLASTIC STUCK IN BPV - PULL TUBING HANGER AND SEAL ASSY. PULLED 130,000# STRING WT. TO PULL OUT. LAY DOWN HANGER & PUP JTS. - SPOT XANVIS PILL ON BOTTOM, STRING OUT OF BALANCE AND BACKFLOWING OUT TUBING. SLUG PIPE W/HEAVY CACL2 PILL - STILL BACKFLOWING OUT TUBING - PULL 7 STANDS TO GET OUT OF XANVIS PILL - CIRC TO CONDITION FLUID TO EVEN OUT WEIGHT - CHECK FOR FLOW (OK). P.O.O.H. 4/5/93 - FINISH POOH W/ PRODUCTION STRING - L/D GLM - INSTALL TBG HANGER W/ SAFETY VALVE & TEST BLIND RAMS TO 2500 PSI. TESTED OK - M/U MILL & CASING SCRAPER, T.I.H. AND TAG TOP OF SEAL BORE ASSY 8671. RIG UP TO CIRC. - CIRCULATE, BOTTOMS UP CONVENTIONALLY - PUMP HIGH VIS SWEEP CONVENTIONALLY - SWITCH TO REVERSE CIRCULATION AND CIRCULATE HOLE - CLEAN BOXES ON "NEW" PRODUCTION STRING - CHECK FLOW (OK) - PUMP SLUG. - RIG UP EQUIPMENT TO LAY DOWN TUBING AND HAVE SAFETY MTG. - P.O.O.H. LAYING DOWN "OLD" TUBING & STRING. NOTE: CONDUCTED "NORM" SURVEY ON PRODUCTION STRING. NO READINGS ABOVE BACKGROUND. RECEIVED M AY - § 199 ) Alaska Oil & Gas Cons, Commission Anchorage ATTACHHENT DAZLY REPORT OF NELL OPERATIONS NELL HGS C31-26 PAGE 2 4/6/93 - P.O.O.H. LAYING DOWN 3-1/2" BUTTRESS TGB & SCRAPER - HELD OPERATIONAL/SAFETY MEETING, R.I.H. W/PRODUCTION EQUIPMENT + 3-1/2" 9.3# N-80 EUE TBG AS PER PROGNOSIS - SEE ATTACHED SHEET - MAKE UP SSSV W/CONTROL LINE AND TAG TOP OF SEAL BORE @ 8684 - RIG UP AND PUMP DOWN TBG. WORK-SEAL ASSY INTO SEAL BORE AND MARK SPACE OUT. PICK UP AND INSTALL TBG HANGER. TEST CONTROL LINE THROUGH HANGER TO 3000 PSI. STING BACK INTO SEAL BORE AND STOP HANGER 1" OFF SPOOL. - RIG UP SLU AND TEST LUBRICATOR TO 1500 PSI - RUN 2.80" GAGE RING TO OTIS X-O SLEEVE @ 8709~ - SET 2.81" PX PLUG BODY @ 8652' SET PRONG IN PX PLUG BODY. - PRESSURE UP ON TBG TO 3000 PSI TO SET BAKER MODEL "HB" PACKER. TEST TUBING INTEGRITY TO 5000 PSI. TESTED OK. 4/7/93 - DRAIN STACK & RISER, LAND TBG HANGER - RUN IN TIE DOWN SCREWS - RIG UP SLU, TEST LUBRICATOR TO 1500 PSI & RIH & PULL DUMMY FROM GLM @ 8568' - RIG DOWN SLU - PRESSURE DOWN TBG TO TEST CASING, PACKER & LOWER HANGER SEALS - PULL LANDING JOINT & SET BPV - NIPPLE DOWN BOPE, PULL & LAY DOWN RISER - NIPPLE UP UNI-TREE, TEST FLANGE & VOID AREA TO 3000 PSI. MAKE UP PRODUCTION VALVES AND FLOW LINE - RIG UP CIRCULATING LINES, PREPARE PITS FOR DISPLACEMENT - DISPLACE 10.3 CALC KILL FLUID W/ FIW - RU SLU, TEST LUBRICATOR TO 1500 PSI. RIG UP TO PUMP KILL FLUID DOWN DISPOSAL - PUMP KILL FLUID DOWN DISPOSAL - PULL PRONG & PLUG W/ SLU - SET GLV 2W/ 3/8" ORIFICE IN GLM #7 @ 8568' - RIG DOWN NOTE: CAMERON SERVICE MAN REPLACED ALL THREE GATE & SEAL ASSEMBLIES IN UNI-TREE. {INSTALLED NEW PARTS) RECEIVED MAY - 5 199 ) Alaska Oil & Gas Cons. 6ommiSS~U~'~ Anchorago MGS C31-26 CURRENT WELLBORE DIAGRAM - 4/29/93 xxx } {Ixxxx [= =] I $ XXXX BAKER "FV6" TRSCSSV w/ "X" Profile e 336' 24" Conductor Casing @ 370' 10-3/4" 40.5# J-55 Surface Casing @ 1895' 3-1/2", 9.3#, N-80, EUE 8rd Tubing (some Mod) GLM MD TVD PORT Ptro Psc Pso GAS 1 1866' 1855' 12 995 920 999 673 2 3527' 3519' 12 974 890 957 688 3 4944' 4906' 12 945 860 915 693 4 6085' 5996' 16 985 810 895 1246 5 7048' 6908' 16 974 790 865 1240 6 7883' 7705' 16 958 770 831 1108 7 8564' 8365' 24 ORIFICE (3/8") 1800 BAKER "HB" Packer @ 8614' OTIS "X" Nipple e 8651' BAKER "GBH-22" 80-40 Seal Assy/PBR @ 8684' < XXXX G S XXXX <--- $ XXXX <-- S XXXX < GR-GS HC-HD · HE-HF HI-HK HK-HN .-' - HN-HR ????????? := HR-HZ 9640- 9700' Junk @ 9658'1 < 3+ Strings of Wireline Tools -------------I< PBTD = 9849' .\ 7" 23/26/29# N-80 Production Casing @ 9927' TD = 9935' OTIS "XO" Sliding Sleeve @ 8705' Guiberson UNI-VII Packer @ 8713' 8742- 8780' MD 9037- 9069' MD CAMCO KBM Gas Lift Mandrel @ 9080' OTIS "XO" Sliding Sleeve @ 9086' Guiberson UNI-VII Packer @ 9095' 9144- 9194' CAMCO KBM Gas Lift Mandrel @ 9195' OTIS "XO" Sliding Sleeve @ 9201' Guiberson UNI-VII Packer ~ 9219' CAMCO KBM Gas Lift Mandrel @ 9283' OTIS "XO" Sliding Sleeve @ 9288' 9258- 9297' Guiberson UNI-VII Packer @ 9298' 9311- 9440' CAMCO KBM Gas Lift Mandrel @ 944r~'~ OTIS "XO" S1 iding Sleeve P 9446'~ [~ ~ E )V [ D Guiberson UNI-VII Packer @ 9456' OTIS "X" Profile Nipple @ 9464' OTIS "Q" Profile Nipple @ 9465' UAY-§ 199) 9471 - 9610' Alaska 0i~ & Gas Cons. Commissio~ Anchorage P T Huckabee C3126CUR. WBD HARCH 23, 1993 Shell Western E&P Inc. An affiliate of Shell Oil Company 601 West Fifth Avenue'~ai~§00 Anchorage AK 99501 State of Alaska Alaska Oil & Gas Conservation Commission ATTN: R. A. Douglass, Commissioner 3001 Porcupine Drive Anchorage, AK 99501-3192 Gentlemen' SUBJECT' SUBMISSION FOR APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed in triplicate is the application for Sundry Approval to pull tubing and repair mechanical integrity of the tubing/packer on MGS well C31-26. The workover is anticipated to begin on March 31, 1993. If you have any questions, please call me at 907-263-9646. - _ Yours truly, P. T. Huckabee Staff Production Engineer Alaska Producing Operations PTH/maj Enclosures MAJ04\032293. WP5 A[~sKA OIL AND GAS CONSERVATION COMMF.,..,,ON APPLICATION FOR SUNDRY APPROVALS 1. o~ ~u,~t: A~ S~ ~a~ ~~ R~ ~~ 5. Type o! Well: 6. Datum elevation (DF or KB~e~t~ 116' KB 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Development X Exploratory Stratigraphic Servi~e 4. Location of well at sudace At top of productive interval At effective depth At total depth Platform C, Leg 1 ,Conductor 5 @ 537' FSL, 1593' FEL, Sec. 23, T8N, R13W, SM 8742', 931' FNL and 1571' FEL, Sec. 26, T8N,R13W,SM @ 9935', 1079'FNL and 1742'FEL, Sec. 26, T8N, R13W, SM 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 9. Permit number 67-63 10. APl number ~e~.~ 11. Field/Pool Middle Ground Shoal/"G" Pool 12. Present well condition summery Total depth: measured true vertical Effective depth: measured true vertical 9935 feet Plugs (measured) 9708 feet 9849 feet Junk (measured) 9623 feet Wireline junk @ 9658' Casing Length Structural Conductor Sudace 1895' Intermediate Production 9927' Liner Perforation depth: Size Cemented 10-3/4', 40.5~,J-55 1600 sx 7",23-29#, N-80 1350 sx measured 8742'-9700' true vertical 8538'-9476' (7 Intervals) Measured depth True vertical depth 1895' 1894' 9927' 9700' RECEIVED MAR 2 2 199 Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE @ 9465' Alaska 0il & Gas Cons. Com~tss'to~ Anchorage Packers and SSSV (type and measured depth) Guiberson UNI-Vll Packers @ 8713', 9095', 9219', 9298', & 9456' Offs "AC" SSSV @ 327'. 13. Attachments Description summary of proposal X~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 03/31/93 115. Status of well classification as: Oil X Gas Suspended 16. If proposal was verbally approved -- -- Service Name of approver Date approved 17. I her,e~b~.certifyt~egoing is true and correct to the best of my knowledge Signed~ -~...-~~'~r--JZ,..-..~ Title Staff Production Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.~ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 1 O- ~'.o.'f ,. ~,i.": ~F':~ Approved by order of the Commission David W. johnston ioner IApproval No. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C31-26 MGS C31-26 was shut-in January 5, 1992 because the well was determined to be capable of "unassisted flow" with known mechanical integrity failure of the tubing/packer. A plug was set in the "X" profile of the "XO" sleeve at 9446' on April 1, 1992 and the well was killed with 10.3 ppg CaC12 brine April 6, 1992. Pressure has risen since this time to 300 psi on the tubing and 285 psi on the casing. A rig workover to repair integrity of the tubing/packer is proposed as follows. Proposed Operations Summary 1. Mobilize Platform "C" rig and mud system. 2. Kill well with 10.3+ ppg NaC1/CaC12 brine. 3. ND Tree/NU 5000 psi BOPE and test per API RP 53. 4. PU to release seal assembly from seal bore at~~'. Spot viscous pill on top of seal bore assembly to prevent debris 'from falling into p-~l~er assembly and/or on top of "PX" plug in "XO" sleeve at 9446'. 5. POOH with 3-1/2", 9.3#, N-80, Buttress tubing and Baker seal assembly. 6. Run casing scraper with integral wash stinger to clean casing wall for packer setting and ensure seal bore assembly is clear of scale debris. 7. Pump polymer sweep to clear debris from scraper run. "X 8. Run 3-1/2", 9.3#, N-80 tubing; SCSSSV; GLM's; packer assembly; " F~l~ nipple, and Baker seal assembly. Engage seal bore assembly at 8666'. )?~[~¢, 9. Run slickline gauge ring run to ensure tubing/seal assembly is ~r 10. ND BOPE/NU Tree and test each tree component to 5000 psi. 11. Retrieve "PX" prong/plug from "XO" sleeve at 9446' via slickline. 12. Circulate FIW to replace kill fluid. 13. Return well to production via gas lift. 14. Demobilize rig. January 16, 1992 Shell Western E&P In 30MM RES ENG 601 West Fifth Avenue · Suite 800 ~ ~--N--~ - Anchorage, Alaska 99501 - 3R ENG ~NG ASST Alaska Oil and Gas Conservation Commission ATTN: Lonnie Smith 3001 Porcupi ne Drive Anchorage, AK 99501 ,'ENG ASST I ':~R GEO~ TAT TECHI Gentlemen: SUBJECT: MIDDLE GROUND SHOAL WELL C31-26 - NOTIFICATION OF STATUS The purpose of this correspondence is to inform you of a change in the status for Middle Ground Shoal (MGS) producer well C31-26. In summary, the well has been identified to be capable of unassisted outflow at a rate of approximately 1.3 bbl per hour (30 BPD). The well is currently shut-in and will remain shut-in until well conditions are in compliance with AOGCC regulations. During annual gas lift compressor maintenance, this well was shut-in because of lift gas constraints. The production line from this well was diverted to the test separator under shut-in conditions to determine if the production status of the well had changed following a recent coiled tubing clean-out and acid stimulation. After 104 hours of shut-in time, the separator pressure was bled to approximately I psig. The well was then determined to be capable of unassisted outflow at a rate of approximately 1.3 bbl per hour (30 BPD). The gas lift assisted water production rate increased from 133 BPD before the coiled tubing clean-out/stimulation to 445 BPD following stimulation (the corresponding water cuts are 52% and 87% respectively). Excessive water inflow from communication with a higher pressured interval is the suspected cause of the changed outflow condition. By letter dated September 10, 1991, we have previously informed the AOGCC that the top packer is not effectively isolating the tubing-casing annulus from produced fluids.* The above mentioned outflow condition indicates we are not in compliance with the Alaska Administrative Code Regulation 20 AAC 25.200 (d) which states: "All wells capable of unassisted flow must be completed with ... a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless otherwise specifically approved by the commission." * Prior to the coiled tubing workover, we were given approval to continue production operations on the condition of the well not beJ~capable of unassisted flow. I(ECEIVED JAN 2 4 '1~9~ .011 & 6as Cons. Commisslen The well is currently shut-in and will remain shut-in until the unassisted outflow is corrected. We are currently evaluating alternatives to eliminate the excessive inflow causing the outflow problem. An application for sundry approvals (Form 10-403) to correct the outflow problem will follow via - separate correspondence. If you wish to discuss or have additional questions, feel free to contact Paul Huckabee of our staff at {907} 263-9646. Very Truly Yours, Ro G. Blackburn Manager Alaska Operations Shell Western E&P Inc. PTH Shell Western E&P Inc.~ ~ ~ J ~ ~ [ % 601 West Fifth 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 C31-26 Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C31-26. The operations were completed on October 18, 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 S BBM~121691F . WP5 j' .... STATE OF ALASKA ',. . ,, A ..-~ OIL AND GAS CONSERVATION COMMI~,. REPOR'COF SUNDRY WELL OPERA'T )/i i G IN/t, [ 1. Operations pedormed: Operation shutdown __ Stimulate X Plugging__ Perforate __ Pull tubing __ Alter casing__ Repair well m Other X 5. I-ype ot Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc DevelopmenlX 116'KB feet Exploratory 7. Unit or Property name 3. Address 601 West 5th Avenue, Suite 810 Anchorage, Alaska 99501 Stratigraphic Middle Ground Shoal Service 8. Well Number 4. Location of well at surface Platform C, Leg 1, Conductor 5 @ 537'FSL, 1593'FEL, Sec. C31-26 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval @ 8742', 931'FNL and 1571'FEL, Sec. 26, T8N, R13W, SM 67-63/91-300 i10. APl number At effective depth 50-733~296(1~.-00 11. Field/Pool At total depth @ 9935', 1079'FNL and 1742'FEL, Sec. 26, T8N, R13W, SM Middle Ground Shoal/G Pool 12. Present well condition summary Total depth: measured 9935 feet Plugs (measured) true vertical 9708 feet Effective depth: measured 9849 feet Junk (measured) Wireline Junk @ 9658' true vertical 9623 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1895' 10-3/4", 40.5#, J-55 1600 sx 1895' 1894' Intermediate Production 9927' 7", 23-29#, N-80 1350 sx 9927' 9700' LinerRECEIVED Perforation depth: measured S742'-9700'DEC 2 0 1991 true vertical 8538'-9476' (7 Intervals) AJas~. 0ii & Gas Cons. m issi.sn Anchorage Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9465' Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456', Otis SSSV 327' 13. Stimulation or cement squeeze summary Intervals treated (measured) Tubing (Wireline Fish) & Perfs Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 116 bbls.. Squeeze ISIP -- 2175 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 126 /r-' 143 133 550 80 Subsequent to operation 67-./~"~ 22 445 760 90 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Oil X Gas Suspended Service Daily Report of Well Operations X -- ~ -1' 7. I hereby certity that the toregoing ~s true and correct to the best ot my Knowledge Signe~''-'0' ~--'~'~ Title ~-~,1-,~,,c,c ~'~,e..,~.:3~,.c~,J ~,'-I~,,--~/-z~_.Date Form 10-404 Rev 08/15/~8 SUBMIT IN DUPLICATE D~ILY REPORT ELL: C31-26 DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs) 10/14/91 - ASSIGN CT OPERATION TO WELL @ 2200 hrs, 10/13/91. - R/U & PRESSURE TEST BOPE. RIH W/2.5" DOWNWARD & SWIRL JET WASH NOZZLE, DBLCV, AND HYDRAULIC DISCONNECT ASSEMBLY. - TAG TOP OF FILL @ 8571'. JET WASH FILL WHILE MOVING CT 20' UP & DOWN 20'. - TAG TOF (TOP OF FISH) @ 8592' (WASH 21' OF FILL ABOVE TOF) - OBSERVE INCREASE IN CT DRAG (WT), WORK CT ON TOF WHILE JET WASHING. HOIST CT UP TO 8400' TO CONFIRM NO WIRELINE SNARE HAS OCCURRED. - PUMP 5 bbls ACID, 5 bbls FIW, 5 bbls POLYMER SWEEP, 15 bbls FIW, 5 bbls SWEEP TO CLEAR TUBING ABOVE FISH OF SUSPENDED SCALE FOR WL ACCESS TO FISH. - CONDUCT PIT (PRESSURE INTEGRITY TEST). PUMP 10 bbls FIW. NO COMMUNICATION OBSERVED BETWEEN TBG & CSG. - CLOSE IN WELL TO POSITION ACID AROUND & BELOW FISH. PUMP 5 bbls 7.5% HCL SOLUTION, FOLLOWED BY 20 bbls FIW TO SOAK 2 bbls AROUND FISH @ 30 mins. CSG @ 130 -215#, PTbg @ 550 -2250# W/ISIP @ 2200#. DATA INDICATES TOP PACKER IS HOLDING AND "HOLE IN TUBING" IS (AT LEAST) BELOW TOP PACKER. - TAG TOF @ 8599' (GAINED 7'). WORK CT ON TOF TO MONITOR MOVEMENT OF FISH. NO MOVEMENT OBSERVED, SUSPECT FISH STUCK IN GLM #6 AT 8642'. - PUMP/SQUEEZE 3.5 bbls TO DISPLACE REMAINING ACID OUT OF CT TO FISH AREA. HOIST CT UP 60' W/O PUMPING. - POH CT WHILE CIRCULATING TO FURTHER CLEAR TBG OF SUSPENDED SOLIDS IN PREPARATION OF WL WORK. 10/15/91 - RIGGED UP WIRELINE AND PRESSURE TESTED. - RAN IN HOLE WITH 2.5" IMPRESSION BLOCK TO 8571' WLM. - PULLED OUT OF HOLE, SHOWED WIRE. - RAN IN HOLE WITH CENTER SPEAR TO 8571' WLM. POOH. LOST SOME WIRE COMING OUT OF HOLE. - RAN I HOLE WITH 3 PRONG WIRELINE GRAB TO 6092', LATCHED WIRE, AND POOH WITH 11' OF WIRE. - RAN IN HOLE WITH 2-1/4" JDC TO 8578', LATCHED AND PULLED CUTTER BAR. POOH. RECEIVI D DEO 2 0 '1991 Alas Oil .& Gas Cons, .Comm%ss on Anchorage DAILY REPORT WELL: C31-2 6 10/15/91 - RAN IN HOLE WITH 2" JDC TO 8584' BUT COULD NOT (CONTID) - LATCH FISH. POOH. 1" PIECE OF WIRE HOLDING DOGS UP. - RAN IN HOLE WITH 2" JDC TO 8587' BUT COULD NOT LATCH FISH. POOH. TOOL LOOKED LIKE IT WAS HITTING ROPE SOCKET AND WIRE. - RAN IN HOLE WITH 2" JDC WITH BELL GUIDE TO 8587' BUT COULD NOT LATCH FISH. POOH. PULLING TOOL SKIRT BEAT UP PRETTY BADLY. 10/16/91 - RAN IN HOLE WITH 3 PRONG GRAB TO 8587', LATCHED WIRE AND POOH WITH 13' OF WIRE. - RAN IN HOLE WITH 2" JDC TO 8592' BUT COULD NOT LATCH FISH. POOH. - RAN IN HOLE WITH 3 PRONG GRAB TO 8591' WLM. GRABBED WIRE AND POOH WITH THREE PIECES OF WIRE FOR 3' TOTAL. - RAN IN HOLE WITH 2" JDC TO 8591' WLM AND LATCHED FISH. JARRED FOR 45 MINUTES UP TO 2000 LBS. PULLED FISH OUT OF HOLE. - RIGGED DOWN SECURED AND CLEANED ALL EQUIPMENT AND WELL. 10/18/91 - RELOCATE TO LEG #1, C31-26 IN 7 hrs. - RIG UP ON C31-26. PRESSURE TEST WELL CONTROL EQUIPMENT. - RIH W/2.5" 3 LOBE MILL, 2.0625" PDM & DBLCV WITH HYDRAULIC DISCONNECT. - OBSERVE SMALL OBSTRUCTION @ 8643'. - MILL "SCALE" BRIDGE @ 8784' TO 8792'. - NO SIGNIFICANT SCALE FOUND IN PERFORATED ZONES. - TAG BOTTOM @ 9653'. - POH WITH MILL ASSEMBLY. - RIH W/2.5" JET SWIRL NOZZLE, DBLCV AND HYDRAULIC DISCONNECT WASH MANDRELS ON WAY DOWN. - SET NOZZLE @ 9653' WHILE PUMPING 6.5 bbls OF 7.5% HCL SOLUTION, FOLLOW WITH 5 bbl XCD POLYMER GEL SWEEP, AND SPOT F/9648' T/9465'. NO OBSERVED PROGRESS IN WASHING DOWN. HOIST NOZZLE TO 9648' & SOAK PERFORATIONS FOR 30 mins. - RIH W/NOZZLE T/9648'. JET ACID WASH PERFORATIONS WITH 8 bbls 7.5% HCL ACID F/9648' T/9466' @ 20 fpm, 42 gpm. - PERFORM PRESSURE INTEGRITY & INJECTIVITY TEST. CSG @ 1450# PTbg @ 1150# RATE @ 56-60 gpm COMMUNICATION BETWEEN CSG & PTbg IS CONFIRMED. DE(; 1991 ^lasl~.Oil .& ~as Cons. DAILY REPORT WELL: C31-26 10/18/91 - SPOT 85 bbls 7.5% HCL ACID TO EOCT. CLOSE IN (CONT~D) WELL, AND SQUEEZE HCL ACID, PUMP 110 bbls FIW TO DISPLACE ACID TO FORMATION. MONITOR & MAINTAIN POSITIVE PRESSURE WITH FIW IN CSG TO AVOID FLUID MIGRATION (due to pressure differential) WHILE SQUEEZING ACID. - SQUEEZE DATA: CSG# CT# PTbg# GPM LOW 700 4800 2275 46 HIGH 2250 4950 2475 62 ISIP = 2175# 5m SIP = 2100# 10m FSIP = 1900# - POH WITH JET WASH NOZZLE @ REPORT TIME. RECEIVED DEC 2 0 '1991 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION October 9, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Mr. R G Blackburn Manager Alaskan Operations Shell Western E & P Inc. 601 'W 5th Ave, Suite 800 Anchorage, AK 99501 Re: No Flow Status Shell Platform "C", Well No. C31-26, MGS De,,~ M'x. B!ackb~n: After reviewing data submitted and the current condilion of well C31-26 and with the knowledge that the well is being produced 'with gas lilt, it is the conclusion of the Commission that this well is no longer capable of unassisted flow of hydrocarbons 'to the surface. ~o,,m.~,.-a,,a hereby authorizes removal of the subsurface safety valve from Well No. C31-26, on condition that should any subsequent operations be performed that may alter the unassisted flow condition of lhe 'well, another flow' 'test would 'be conducted to verify continued no-flow status for that well. Commissioner BY ORDER OF ~[IIE COMMISSION dIt':MTM CC: SWEPI Production foreman/ ~ea Supt Attn: Shell Platform "C" tICO 1 BOx 48S Kenai, AK 99611 Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 October 1, 1991 Alaska Oil and Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment, workover on MGS Well No. C31-26. The workover is anticipated to begin on October 13, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Division Drilling Engineer Alaska Division VEU/slm Enclosures RECEIVED OCT - 4 1991 Alaska .Oil & Gas Cons. Com,l[~t~ ~,m~horag, AOGCC\SUNDRY.DOC ' AL STATE OF ALASKA 0 R I · KA OIL AND GAS CONSERVATION COMMIS~,~ON APPLICATION FOR SUNDRY APPROVALS GINAL 1. Type of Request: :2. Name of Operator Shell Western E&P Inc. Abandon Suspend__ OperaUon shutdown Re-enter suspended well Alter casing __ Repair Well Plugging__ Time extension Stimulate X Change approved program __ Pull tubing __ Variance Perforate __ Other 6. Datum elevation (DF or 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 4. Location of well at sudace At top of productive interval At effective depth At total depth 5. Type o! Well: Development X Exploratory StraUgraphic Service Platform C, Leg1, Conductor 5 @ 537'FSL, 1593'FEL, Sec. 23, T8N, R13W, S.M. @ 8742', 931'FNL & 1571'FEL Sec. 26, T8N, R13W, S.M. @ 9935', 1079'FNL & 1742'FEL Sec.26, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured Effective depth: true vertical measured 9849 feet true vertical 9623 feet Length Size Casing Structural Conductor Sudace Intermediate Production 9935 feet Plugs (measured) 9708 feet Liner Pedoration depth: 1,895' 10-3/4",40.5#,J-55 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 9. Permit number ~1-088 10. APl number 50-733o20502-00. 11, Field/Pool MGS/"G" Pool 9,927' 7",23-29,N-80 Junk (measured) Wireline Junk @ 9658' measured 8742-9700' Cemented Measured depth True vertical depth 1600sx 1895' 1894' 1350sx 9927' 9700' RECEIVED OCT - 4 1991 true vertical 8538.9476' Tubing (size, grade, and measured depth) (7 Intervals) 94~aska 0il & Gas Cons, CommlSS%en 3-1/2", 9.3#, N-80 EUE @ ' N'~chorage Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456'. Otis SSSV @ 327' 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 10/13/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knoWledge ~'a,~i~gned V.~--(3.. ~ Title Division Drilling Englneer ~Notify FOR COMMISSION USE ONLY Conditions ofapproval' Commission so representative may witness Date 10/02/91 Plug integrity._ BOP Test__ Location clearance Mechanical Integrity Test-- Subsequent form require--d 10- Approved by order of the Commission ORIGINAL SIGNED BY LONN!5 C. SMITH Form 10-403 Rev 06/15/88 Date /0.-~ ~---/~' / SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL WELL NO. C31-26 COILED TUBING CLE]~N OUT / ACID TREAT PRESENT STATUS: Active Production Well Last Test 9/26/91 - 121 BOPD, 252 GROSS, 52% H20 Cut Wireline fish stuck in tubing @ 8603' Gas lift depth is below top packer GR-GS is in communication with Hemlock Wireline junk at 9658' covering 132' of HR-HZ perfs OBJECTIVES: 1) Remove wireline fish from tubing (8603') 2) Clean out scale from tubing and to top of junk @ 9658' 3) Acid Treat Hemlock perfs via 7.5% HCl soak/ jet wash/squeeze. NOTES: - 3-1/2" 9.3# N-80 tubing, EOT @ 9465' - Minimum restrictions - Otis "Q" nipple @ 9465' (2.635" ID) - Other Restrictions - 2.750" ID Otis "X" nipple @ 9464' and SSSV @ 327' Otis "XO" sleeves @ 8705', 9086', 9201', 9288', & 9446' - Baker overshot seal assembly @ 8666' - Wireline fish stuck in tubing @ 8603' including a 2.70" gauge ring, 1.75" x 3' cutter bar, and ~ 33' of wire. - Wireline junk at 9658' covering lower 132' of HR-HZ perfs - Hard scale was encountered during 11/90 CTU clean out beginning at 6900'. A flat bottom mill and PDM was required to clean out scale. - Tubing/Casing communication was observed during CTU acid squeeze operations in 11/90 and is expected again. RECOMMENDED PROCEDURE: (Refer to Attachment No. 1 for mechanical equipment details) 1. One week prior to scheduled rig-up, test mechanical integrity 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. 2. 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/SWEPI CTU Supervisor Wireline Log Book - Wireline Operator/Operations Foreman MIDDLE GROUND SHOAL No. C31-26 COILED TUBING CLEAN OUT / ACID TREATMENT 3. The SWEPI CTU Supervisor 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. · · 4. If the SSSV has not been removed, RU Slickline Unit and retrieve SSSV from 327'. · · NOTE: · · · 10. 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. HZS concentrations of 150 - Z$0 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 115+ bbls 7-1/2% HCl 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. 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. Ensure surface handling equipment is installed to Safely and efficiently handle return acid and H2S for either disposal into C44-14RD or treatment and transfer to Production (see ATTACH. 2). page 2 MIDDLE GROUND SHOAL No. C31-26 COILED TUBING CLEAN OUT / ACID TREATMENT 11. 12. 13. 14. RECOVER WIRELINE FISH FROM TUBING If the wireline fish is not recovered via Slickline efforts in progress, RIH-with 2-1/2" downward directed jet wash nozzle, double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing to the top of fish @ ~ 8560'. Close coiled tubing x production tubing annulus and pump/squeeze 5 bbls 7-1/2% HCl acid (with above additives) followed by 20 bbls FIW to jet wash 2+ bbls acid across fish. SD and let acid soak for 30 minutes. PU coiled tubing 100' and pump/squeeze an additional 3.5 bbls to inject the remaining acid from the coiled tubing across the fish. POOH with coiled tubing. RD CTU and RU CTU on C24-23 while wirelining on C31-26. RU Slickline Unit with lubricator and test to 1500 psi. RIH and fish wireline tools from tubing (wireline fish stuck in tubing @ 8603' includes a 2.70" gauge ring, 1.75" x 3' cutter bar, and ~ 33' of wire). RD Slickline Unit. When CTU is available, RU on C31-26 as outlined above. CLEAN OUT & ACID SOAK PERFORATIONS 15. RIH with 2-1/2" mill, 2-1/16" Positive Displacement Motor (PDM), double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing. Clean out scale from tubing and any fill across perfs to wireline junk at 9658'. NOTE: CTU milling operations were aborted at 9624' 11/90. If hard scale is again encountered at or near this depth, do not try to clean out any deeper without approval of Manager Alaska Operations. 16. 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 & mill. 17. RIH with 2-1/2" swirl type jet nozzle, double check valves, and hydraulic disconnect sub on coiled tubing to the wireline junk at - 9624'. page 3 MIDDLE GROUND SHOAL No. C31-26 COILED TUBING CLEAN OUT / ACID TREATMENT NOTE: Coiled tubing length = 14200~ 1-1/2" coiled tubing capacity = (1.597 bbls/1000')*14200, · . = 22.68 bbls CT x 7" capacity 9624, - EOT = (9624'-9465') * 0.034960 = 5.6 bbls CT x Wellbore annulus capac, = 0.00651 bbl/ft * 9465' + = 0.03496 bbl/ft* 9624-9465' = 67.2 bbls 18. 19. 20. Conventionally circulate 6.5 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 junk at 9624' to the end of tubing (EOT) @ 9465'. SD pump and let acid soak for at least 30 minutes. 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. 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. 2A for Disposal Guidelines and record disposal operations data. 21. JET WASH PERFORATIONS WITH ACID Locate EOCT at top of junk ~ 9624'. Pump circulate at 1 BPM, while reeling coiled tubing at 20 feet/min, to jet wash the perforations and wellbore from ~ 9624' to the EOT @ 9465' (will require ~ 8 bbls 7-1/2% HCL). Additionally, wash all scale indications observed in the tubing during clean out. Displace circulate with 100 bbls FIW to clear contaminated fluid from coiled tubing and wellbore. Divert all contaminated returns to the surge vessel for disposal. RECEIVED OCT - 4 1991 page 4 Naska Oil & Gas Cons. Commission Anchorage MIDDLE GROUND SHOAL NO. C31-26 COILED TUBING CLE_~N OUT / ~CID T_~Ra_TMRNT 22. 23. ACID SQUEEZE STIMU~TION RU choke from FIW injection header (or Halliburton pump) to increase backpressure on tbg x csg annulus as needed during squeeze operations to prevent acid from migrating into tbg x csg annulus. Tubing/Casing communication was observed during CTU acid squeeze operations in 11/90 and is expected again. RIH and locate EOCT at top of junk ~ 9624'. 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 62.3 bbls additional acid (85 bbls acid total) followed by 110 bbls FIW to overdisplace the acid into the perforations (by ' 85 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. 24. POOH. RD CTU. Return well to production via gas lift and test. NOTE: TOC at SURFACE ATTACHMENT I C31-26 PRESENT STATUS /- TOC (CBL) at 6290' · !~ i ~ I.~ PROBABLY UNBEATED. ~.~/ I'OP ~CKER HE-HF 9144' - 9194' ~~~ . . . ,~~ HK-HN 9~11 9440 3-1/2' 9.3~ N-80 EUE TBG EOT at 9465' G~' HR-HZ 9640' - 9700' PBTD at 9849' ~ ~ ~; TD at 9935' ~M/C3126PRE.CHT OTIS BALL VALVE at 327' 24' CONDUCTOR at 370' CAMCO KBUQ MANDREL at 1871' 10'3/4' CSG, 40.5#, J-55 at 1896' w/1350 8x CEMENT CAMCO KBUG MANDREL at 3510' CAMCO KBUQ MANDREL at 4962' CAMCO KBUQ MANDREL at 6092' CAMCO KBUQ MANDREL at 72E?' CAMCO KBUG MANDREL at 7991' CAMCO KBUG MANDREL &! 8642' BAKER OVERSHOT SEAL BORE A88EMBLY at 8666' OTIS 'XO' SLIDING SLEEVE at 8705' GUIBERSON RH-1 PACKER at 8713' CAMCO KBM DUMMY MANDREL at gO,O' OTIS 'XO' SLID'lNG SLEEVE at 9086' GUIBERSON RH-1 PACKER at 9096' CAMCO KBM DUMMY MANDREL at 9195' OTIS 'XO' SLIDING SLEEVE at 9201' GUIBERSON RH-1 PACKER at 9219' CAMCO KBM DUMMY MANDREL at 9283' OTIS 'XO' SLIDING SLEEVE at 9288' QUIBERSON RH-1 PACKER at 9298' CAMCO KBM DUMMY MANDREL at 9441' OTIS 'XO' SLIDING SLEEVE at 9446' QUIBERSON RH-1 PACKER at 9456' OTIS 'X' NIPPLE at 9464' OTIS 'O' NIPPLE at 9466' 7' PRODUCTION CASING at 9927' O - 5350' 23# N-80 BTC 5350' - 7917 26# N-80 BTC 7917' ° 9927' 29# N-80 BTC MIDDLE GROUND SHOAL No. C31-9- 6 COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 2 CTU SURFACE HANDLING EQUIPMENT FOR RETURN FLUID TREATMENT OR DISPOSAL .. 1. RU 250 bbl, 120 psi pressure contained surge tank for containment of contaminated fluid returns. · 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. · 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. ZA for Disposal Guidelines and record disposal operations data on the attached foz~n. · 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. · 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. · 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. · 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. page 6 MIDDLE GROUND SHOAL NO. C31-2 6 COILED TUBING CLF2~N OUT / ACID T _I~_ATMENT 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 7 MIDDLE GROUND 8HO]%L NO. C31-26 COILED TUBING CLEAN OUT / ]%CID TNE~TME~ ]%TTACHMENT NO. 2]% C44-14RD DISPOS]%L PROCEDURE GUIDELINES le · · · · · 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 8 M'rDDLE GROUND 8HOi%L No. C3 3.-2 6 COXL~D TUBING CLE~N OUT / i%CTD TREi%THE~ ATTACHMENT NO. ZA (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 9 MIDDLE GROUND SHOAL No. C31.-2 6 COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 3 PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS FOR DISCH~RG~ 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 C31-26 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 = ....................... x 24 hrs = Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) hrs Onshore Facility 1000 bbl Delay = ........................... x 24 hrs = Gross Daily Prod "A" "C" and "Baker" (bbl) hfs 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 10 ?r /o Shell Western E&P In 601 West Fifth Avenue · Suite 800 Anchorage. Alaska 99501 September 10, 1991 Alaska Oil and Gas Conservation Commission / ~ ~.~ ATTN: Lonnie Smith ~ 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: .~j,,,~j.~ SUBJECT: MIDDLE GROUND SHOAL WELL C~1-26 - NOTIFICATION OF "NO-FLOW" AND PRODUCTION EQUIPMENT STATUS Further to the telephone discussion between Paul Huckabee and Lonnie Smith on September 3, 1991, we are submitting a Sundry Notice to inform you of the current production status of the SWEPI operated Middle Ground Shoal well C31-26. The purpose of this correspondence is twofold. First we are submitting verification that C31-26 is not capable of unassisted flow, and secondly, we have learned that a packer is not effectively isolating the tubing-casing annulus from produced fluids. This information is submitted to ensure compliance with the Alaska Administrative Code Regulation 20 AAC 25.200 (d) which states: "Ail wells capable of unassisted flow must be completed with ... a packer which effectively isolates the tubing- casing annulus from fluids being produced, unless otherwise specifically approved by the commission." Attachment No. 1 illustrates the current mechanical configuration of C31-26. A flowing pressure survey indicates we are injecting gas lift gas past the top packer and through the gas lift mandrel at 9080'. It is acknowledged that a packer does not effectively isolate the tubing-casing annulus from fluids being produced. However, a test performed August 29, 1991 confirms the well is not capable of unassisted flow. The results of the test are included as Attachment No. 2. In summary, the well did not sustain unassisted flow to the test separator for greater than one hour after the gas injection gas was shut-off. The initial flow and subsequent gas blowdown to the flare resulted primarily from decompression of the lift gas in the system. RECEIVED S E P t 2 t991 Alaska Oil & Gas Cons. C;ommission Anchorage Please call me at (907) 263-9634 or Paul Huckabee at 263-9646 if you wish to discuss, or have any further requirements concerning production operations from this well. Very Truly Yours, Division Drilling/Production Engineer Shell Western E&P Inc. PTH/VEU SEP 1 t t991 Alaska 0il & Gas 6ohs. L;omCss'~of~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program Suspend__ Operation shutdown Re-enter suspended well Repair Well Plugging __ Time extension Stimulate Pull tubing Variance Perforate __ Other X 2. Name of Operator Shell Westem E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 4. Location of well at 5. Type ot Well: Development X Exploratory Straligraphic Platform C, Leg1, Conductor 5 @ 537'FSL, 1593'FEL, Sec. 23, T8N, R13W, S.M. surface At top of productive interval At effective depth At total depth @ 8742', 931'FSL & 1585'FWL NE Corner, Sec. 26, T8N, R13W, S.M. @9935', 1062'FSL & 1767'FWL NE Corner of Sec.26, T8N, R13W, 6. Datum elevation (DF or 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 9. Permit n~~1 ~" ' ' -088 10. APl 50-733-20502-00 11. Field/Pool MGS/"G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9935 feet Plugs (measured) 9708 feet 9849 feet Junk (measured) 9623 feet Wireline Junk @ 9658' Casing Length Structural Conductor Surface 1,895' Intermediate Production 9,927' Liner Size Cemented 10-3/4",40.5#,J-55 1600sx 7",23-29,N.80 1350sx Measured depth True vertical depth 1895' 1894' Perforation depth: measured 8742-9700' true vertical 8538-9476' Tubing (size, grade, and measured depth) (7 Intervals) 3.1/2", 9.3#, N-80 EUE @ 9465' S EP 1 2- 1991 Alaska 0ii & Bas Cons. C0mm'~ss~o~ Anchorage Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456'. Otis SSSV @ 327' 13. Attachments Description summary of proposal Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 115. Oil X Gas 16. If proposal was verbally approved ~. : <"~' i.,~.,~ ~ +'~'~ '- ~ /~ /~ ' Service Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ C. /.,~.,~~ Title Division Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: I~otify Commission so representative may witness Plug integrity._ BOP Test._ Location clearance__.,/~/.~ C,o~"J Mechanical Integrity Test._. Subsequent form required 10- Status of well classification as: Suspended IApproval No. Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NO~'E: TOC at SURFACE ATTACHMENT I C31-26 PRESENT STATUS REC£1V£D S'EP 1 1991 Alaska. 0il & Gas Cons. Comm'tss'to~ 'Anchorage Toe (CBL) at 6290' ?'OP IlyiCKER IS PROBABLY UNBEATED. GR-GS 8742' - 81'80' ifC-liD 9037' - 9069' HE-HF 9144' - 9194' OTIS BALL ~LVE at 327' 24' CONDUCTOR at 370' CAMCO KBUG MANDREL at la71' 10-8/4' CBG, 40.5#, J-55 mt 1896' w/1350 ax CEMENT CAMCO KBUG MANDREL at 3510' CAMCO KBUQ MANDREL at 48a2' CAMCO KBUQ MANDREL it 6099' CAMCO KBUG MANDREL it 7267' CAMCO KBUG MANDREL at ?eel' CAMCO KBUG MANDREL at aa49' BAKER OVERSHOT SEAL BORE AS8EMBLY at 8666' OTIS 'XO' SLIDING SLEEVE ~t 8T06' QUIBERBON RH-1 PACKER at 8718' CAMCO KBM DUMMY MANDREL a~ 0080* OTIS 'XO' SLIDING SLEEVE at ecsc' QUIBERBON RH-1 PACKER at 9096' CAMCO KBM DUMMY MANDREL it 91g~' OTIS 'XO' SLIDING SLEEVE at 9201' iii-ilK 9258' - 929T' HK-HN 9311' - 9440' 3-1/2' 9.3# N-80 EUE TBG EOT at 9465' lIN-HR 9471' - 9610' liR-liZ 9640' - 9?00' ~UNK It GSSS' PBTD It ~84e' TD at 9935' ~M/C3126PRE.CHT GUIBER8ON RH-1 PACKER at 9219' CAMCO KBM DUMMY MANDREL at 9983' OTIS 'XO° SLIDING SLEEVE at 9288' GUIBERBON RH-1 PACKER at 9298' CAMCO KBM DUMMY MANDREL at 9441' OTIS 'XO' SLIDING SLEEVE at 9446' GUIBERBON RH-1 PACKER at 9456' OTIS 'X' NIPPLE at 9464' OTIS 'Q' NIPPLE at 9466' 7' PRODUCTION CASING at 9927' 0 - 6360' 23# N-80 BTC 5850' - 7917 26# N-80 BTC 7917' - 9927' 29# N-80 BTC ATTACHMENT NO. 2 Included are: 1) The Production Operators notes documenting the testing sequence and events. 2) The gas chart for the Production Separator. 3) The gas chart for the blow down to the flare. RECEIV£D SEP i 2 t991 Alaska Oil & Gas Cons. Anchorage ~c0% 0..--- ., C? 2-oo '/'F 14,5' %~ Ho .,I ':" ,0.. P :'.1GPI-~,' TW . ¢. pRIN~-ED IN U.S.A. I I I Shell Western E&PInc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 August 13, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL TO~~ MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed in triplicate is the application for sundry approval to replace tubing and the top packer in Well No. C31-26. The sundry operations are expected to begin August 19, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Division Production Engineer Alaska Division VEU/PTH/wam Enclosures RECEIVED AU G 1 5 1991 Alaska Oil & Gas Cons. commiss~en Anchorage STATE OF ALASKA APPLICATION FOR SUNDRY APPROVALS 161NAL 1. Type of Request: Abandon Suspend__ Operation shutdown Re-enter suspended well Alter casing __ Repair Well Plugging m Time extension Stimulate Change approved program m Pull tubing X 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 o! Well: Development X Exploratory Straligraphic Service 4. Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg1, Conductor 5 @ 537'FSL, 1593'FEL, Sec. 23, T8N, R13W, S.M- @ 8742', 931'FSL & 1585'FWL NE Corner, Sec. 26, T8N, R13W, S.M. @9935', 1062'FSL & 1767'FWL NE Corner of Sec.26, T8N, R13W, 6. Datum elevation (DF or KB3 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 9. Permit number ~~91-088 ~/,~/,, .,~, 10. APl number 50-733-20502-00 11. Field/Pool MGS/"G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9935 feet Plugs (measured) 9708 feet 9849 feet Junk (measured) 9623 feet Wireline Junk @ 9658' Casing Length Structural Conductor Surface 1,895' Intermediate Production 9,927' Liner Size Cemented 10-3/4",40.5#,J-55 1600sx 7",23-29,N-80 1350sx Measured depth True vertical depth 1895' 1894' Perforation depth: measured 8742-9700' true vertical 8538-9476' Tubing (size, grade, and measured depth) (7 Intervals) 3-1/2", 9.3~, N-80 EUE @ 9465' AUG 1 5 I[191 Alaska 011 & Sas Cons. nchorage Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456'. Otis SSSV @ 327' 13. Attachments Description summary of proposal X_~ Detailed operations program m BOP sketch 14. Estimated date for commencing operation 08/19/91 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 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test._ Location clearance Mechanical Integrity Test__ Subsequent form require---d 10- ~ Approved by order of the Commission ORIGINAL SIGNED BY RUSSELL A. DOUGLASS IApproval No. Approved Copy Returned Commissioner Date 8-//~:~ _ ~/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE &PPLIC&TION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C31-26 REPLACE TUBING & PACKER/RETURN TO PRODUCTION The Middle Ground Shoal well number C31-26 is currently producing approximately 130 BOPD but is experiencing severe scaling problems due to mechanical failure of the packer isolating the GR-GS from the Hemlock. The following operations are proposed to repair the communication. PROPOSED OPERATIONS SUMMARY 1) Fill well via the annulus with Filtered Inlet Water (FIW). 2) Jet cut 3-1/2" tubing at ~8950' (~130' above the Camco KBM dummy mandrel at 9080'). See ATTACHMENT I. 3) Install and test 5000 PSI BOP Equipment per API RP 53. 4) Pull out of hole with 3-1/2" tubing, Baker overshot seal bore assembly. 5) Fish Otis "XO" sliding sleeve and the top Guiberson RH-1 packer. 6) Run a flat-bottom mill, junk baskets, and casing scraper to clean through GR-GS perforation interval. 7) Isolate "G" intervals from Hemlock by setting a retrievable packer between the GR-GS and the HC-HD, and another retrievable packer above the top GR-GS perforation @ 8742'. See ATTACHMENT II. 8) Run 2-7/8" tubing, gas lift equipment and accessory equipment. 9) Remove BOPE. Install tree and test to 5000 PSI. 10) Return well to production and test. RECEIVED AUG 1 § 1991 Dii & Gas Cons. COrniness%eh ,~mchomge TOC at SURFACE RECEIVED ATTACHMENT I C31-26 PRESENT STATUS AU6 1 5 1991 0il & Sas Cons. Comm'~s$~n ~ ~,horage TOO (CBL) at 6290' */- NOTE: TOP PACKER 18 PROBABLY UNSEATED. GR-GS 8742' - 8780' NC-HD 9057' - 9069' HE-HF 9144' ' 9194' HI-HK 9258' - 9297' HK-HN 9311' - 9440' 3-1/2' 9.8# N-80 EUE TBG EOT at 9465' HN-HR 9471' - 9610' HR-HZ 9640' - 9700' NOTE: 3 8TRINOm OF IVIRELINE TOOL8 IN RATNOLE. JUNK at 9658' PBTD at 9849' TD at 9935' WAM/C8126P RE.CH T OTIS BALL VALVE at 327' 24' CONDUCTOR al 370' CAMCO KBUQ MANDREL at 1871' 10-3/4' CSG, 40.5#, J-56 at 1895' w/1350 sx CEMENT CAMCO KBUG MANDREL at 3510' CAMCO KBUG MANDREL at 4962' CAMCO KBU(3 MANDREL at 6092' CAMCO KBUG MANDREL at 7257' CAMCO KBUG MANDREL at 7991' CAMCO KBUG MANDREL at 8642' BAKER OVERSHOT SEAL BORE ASSEMBLY at 8666' OTIS 'XO' SLIDING SLEEVE at 8706' GUIBERSON RH-1 PACKER at 8718' CAMCO KBM DUMMY MANDREL at 9080' OTIS 'XO' SLIDING SLEEVE at 9086' GUIBER$ON RH-1 PACKER at 9095' CAMCO KBM DUMMY MANDREL at 9195' OTIS 'XO' SLIDING SLEEVE at 9201' GUIBERSON RH-1 CAMCO KBM DUMM OTIS 'XO' SLIDIN GUIBERSON RH-1 CAMCO KBM DUMM OTIS 'XO' SLIDIN GUIBERSON RH-1 OTIS 'X' NIPPLE OTIS 'Q' NIPPLE PACKER at 9219' Y MANDREL at 9283' G SLEEVE at 9288' PACKER at 9298' Y MANDREL at 9441' G SLEEVE at 9446' PACKER at 9456' at 9464' at 9465' 7' PRODUCTION CASING at 9927' 0 - 6350' 23# N-80 BTC 5350' - 7917 26# N-80 BTC 7917' - 9927' 29# N-80 BTC ATTACHMENT II C31-26 PROPOSED STATUS RETRIEVE FISH & REPLACE TUBING TOC at SURFACE RECEIVED AU6 1 5 1991 Alaska, 0il & Sas Cons. Commissiet~ 7~.nchorag~ 2-7/8' 6.6# L-80 EUE 8rd TBG at 8980' GR-GS 8742' - 8780' HC-HD 9037' - 9069' HE-HF 9144' - 9194' HI-HK 9258' - 9297' HK-HN 9311' - 9440' ;3-1/2' 9.3# N-80 EUE TBG 8980' - 9465' HN-HR 9471' - 9610' HR-HZ 9640' - 9700' NOTE: 3 8TRING8 OF WIRELINE TOOL8 IN RATHOLE JUNK at 9658' PBTD at 9849' WAM/C3126PPS.CHT OTIS BALL VALVE at '300' 24' CONDUCTOR al 370' 10-8/4' 080, 40.5#, J-55 at 1895' w/1850 ex CEMENT GAS LIFT EQUIPMENT PER ENGINEERING DESIGN TOC (CBL) at 6290' */- RETRIEVABLE PACKER at 8680' RETRIEVABLE PACKER at 8910' OTIS 'X' NIPPLE at 8950' OVERSHOT SEAL BORE ASSEMBLY at 8980' OTIS 'XO' SLIDING SLEEVE at 9086' GUIBERSON RH-1 PACKER at 9095' OTIS 'XO' SLIDING SL.EEVE at 9201' GUIBER$ON RH-1 PACKER at 9219' OTIS 'XO' SLIDING SLEEVE at 9288' GUIBERSON RH-1 PACKER at 9298' OTIS 'XO' SLIDING SLEEVE at 9446' GUIBERSON RH-1 PACKER at 9456' OTIS 'X' NIPPLE at 9464' OTIS 'Q' NIPPLE at 9466' 7' PRODUCTION CASING at 9927' 0 - 5350' 23# N-80 BTC 6360' - 7917 26# N-80 BTC 7917' - 9927' 29# N-80 BTC Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 April 12, 1991 Alaska Oil and Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed in duplicate is the report of Sundry Well Operations for MGS Well No. C31-26. The workover included a removal of scale obstruction from wireline tools and fish recovery. Operations were completed March 24, 1991. If you have any questions, please call Ms. Susan Murnan at (907) 263-9614 or Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures AOGCC\SUNDRY.DOC RECEIVED APR 1 6 199t Alaska Oil & Gas Cons. Comm'~ss~on Anchorage REPORT OF SUNDRY WELL OPE ATION ! J 1. Operations pedormed: Operation shutdown __ SUmulate Plugging__ Perforate __ Pull tubing __ Alter casing__ Repair well __ Other 2. Name of Operator Shell Western E&P Inc 3. Address 601 West 5th Avenue, Suite 800 Anchorage, Alaska 99501 5. Type O! Well: Devek~prnenl X Exploratory StraUgraphic 4. Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg 1, Conductor 5 @ 537' FSL, 1593' FEL, Sec. 23, T8N, R13W, SM (_~ 8742', 931' FSL & 1585' FWL NE Corner, Sec. 26, T8N, R13W, SM @ 9935', 1062 FSL & 1767' FWL NE Corner of Sec. 26, T8N, R13W, SM 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner 9935 feet true vertical 9708 feet measured 9849 feet true vertical 9623 feet Length Size Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) 116'KB feet ~'. Unit or Property name Middle Ground Shoal 3, Well Number C31-26 9. Permit number/approval number 67-63/91-088 10. APl number 50-733-20502-00 11. Field/Pool Middle Ground Shoal/G Pool Wireline Junk @ 9658' Cemented Measured depth 1,895' 10-3/4", 40.5~, J-55 1600 ex 9927' 7", 23-29~, N-80 1350 sx Perforation depth: measured 8742'-9700' true vertical 8538'-9476' Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE @ 9465' True vertical depth 1895' 1894' 9927' 9700' RECEIVED APR 1 6 1991 Alas~.Oii & Gas Cons. CommiSsion NIch'orage Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456', Otis SSSV @ 327' 13. Stimulation or cement squeeze summary Removal of scale obstruction from wireline tools and fish recovery. Intervals treated (measured) Tubing (Wireline Fish) Treatment description including volumes used and final pressure 1000 gallons 7-1/2% HCL acid. Final Pressure 3500 psi. 14. Prior to well operation Subsequent to operation OiI-Bbl 98 106 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 181 865 100 63 134 570 90 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X '17. I hereby certity that the torego~ng ~s true an, i Signed ~ ~ 'F~rm 10.40~'~5/88'' ~'<~'~ 16. Status of well classification as: Oil X Gas __ Suspended__ Service correct to the best ct my Knowledge Title ,4. ~'F:zq/,'"~ ~ Date SUBMIT IN DUPLICATE DAILY REPORT OF OPERATIONS C31-26 March 24, 1991 Test lines to 5200 psi. Release and S/D. Make ready for acid job. Pump 1000 gallons 7-1/2% HCL. Switch to water. Pressure up, S/D. Pump up to 3500, release. Pump up again and release. Rig down. \misc\O40391b RECEIVED APR 1 6 199} Alaska Oil & Gas Cons. Commission Anchorage RECEIVEI [~,.~AR ! 4 199i Alaska Oil & Gas Cons. bommission Anchorage Shell Western E&P In 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 March 14, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVALS MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed in triplicate is the Application for Sundry Approvals for well No. C31-26, Middle Ground Shoal. The surface location is Platform C, Leg 1 Conductor 5. Estimated date for commencing operation is March 15, 1991. If you have any questions regarding this report, please contact Paul Huckabee at (907) 263-9646 or Susan Murnan at (907) 263-9614. Very Truly Yours, R. G. Blackburn Manager, Alaska Operations Alaska Division WFS/wm Enclosure AOGCC.WAM cc: C. M. Kidwell - WCK 1178 B. N. Osborn - Kenai R. R. Wagner - Anchorage P. T. Huckabee - Anchorage S. B. Brown-Maunder - Anchorage V. E. Unger - Anchorage SEC Files - 5.6120 A42-14 Correspondence File - 5.91 Production - WCK 4100 Reading File - Anchorage Reading File - Houston ECEIVED Alaska Oil & Gas Cons. Commission Anchorage A( STATE OF ALASKA ,.,KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing Change approved program 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Suspend Operation shutdown Re-enter suspended well Repair Well Plugging 4 Time extension Stimulate Perforate Other X 4. Location of well at sudace At top of productive interval Pull tubing Vadance 5. Type Of Well: Development X Exploratory Stratigraphic Service At effective depth At total depth Platform C,Leg 1, Conductor 5 @ 537' FSL, 1593' FEL, Sec. 23, TeN, R13W, SM [CORRECTED] @ 8742'. 931' FSL & 1585' FWL NE Corner, Sec. 26, T8N, R13W, SM @9935' 1062' FSL & 1767' FWL NE Comer of Sec. 26, T8N, R13W, SM 12. Present well condition summary 6. Datum elevation (DF or KB~ 116' K B feet 7."Unit or Property name Middle Ground Shoal 8. Well number C31.26 9. Permit number 67-63 10. APl number 50-733-20502-00 11. Field/Pool ' cc'EIVED Total depth: Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner measured 9,935 feet true vertical 9,708 feet measured 9,849 feet true vertical 9,623 feet Length Size 1,895' 10-3/4", 40.5#, J-55 9,927' 7", 23-29#, N-80 Plugs (measured) Junk (measured) Wireline UunkA~Sk,~ Gas Cons= Commission chora I Cemented Measured depth /rue v~,~a depth 1600 SX 1895' 1894' 1350 SX 9927. 9700' Perforation depth: measured 8742'. 9700' true vertical 8538'- 9476' Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 eue@ 9465' Packers and SSSV (type and measured depth) Guiberson Packer @ 8713', 9095', 9219', 9298', & 9456', Otis SSSV @ 327' 13. Attachments Description summary of proposal X__ Detailed operations program BOP sketch 14. Estimated date for commencing operation 03/15/91 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 foregoingq~;~~orrect to the best of my knowledge Signed,/~, ~ _---------Title Manager Alaska Operations '" ~ ' FOR COMMISSION USE ONLY Date 03/14/91 Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test Location clearance Mechanical Integrity Test___ ---Subsequent form requi-~d 10- ORIGINAL SIGNED BY LONNIE C, Approved by order of the Commission Form 10-403 Rev 06/15/88 Aooroved Copy ' 'Returned I [ Approva~(~ Commissioner SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL No. C31-26 RECEIVEb Alaska.Oil & Gas Cons. Commission AnChorage The Middle Ground Shoal well no. C31-26 is currently producing 112 BOPD at a water cut of 60%. Wireline tools are stuck in the tubing resulting from operations to clear scale with a gauge ring cutter. Attempts to recover the fish with wireline have been unsuccessful to date. We plan to pump 1000 gallons 7-1/2% hydrochloric acid down the tubing to clear the scale obstruction from the wireline tools. Subsequent wireline operations will attempt to recover the fish. If the fish cannot be recovered, it is suspected that production will decline sharply from additional scaling restriction in the tubing at the fish. 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMPLETION EQUIPMENT DETAIL SHEET MGS C31-26 7/21/87 NO. ITEM 1. OTIS SAFETY BALL VALVE 2. CAMCO KBUG MANDREL #1 3. CAMCO KBUG MANDREL #2 4. CAMCO KBUG MANDREL #3 5. CAMCO KBUG MANDREL #4 6. CAMCO KBUG MANDREL #5 7. CAMCO KBUG MANDREL #6 8. CAMCO KBUG MANDREL #7 TVD. MD. 327 327 1870 1871 900 3/16 3501 3510 905 3/16 4921 4962 910 3/16 6001 6092 915 3/16 7104 7257 965 1/4 7808 7991 965 1/4 8441 8642 OR 3/8 9. BAKER OVERSHOT SEAL BORE ASSY. 8464 8666 10. OTIS "XO" SLIDING SLEEVE(CLSD) 8502 8705 11. GUIBERSON PACKER RH-1 8510 8713 12. CAMCO KBM MANDREL #8 8869 9080 DUMMY 13. OTIS "XO" SLIDING SLEEVE(CLSD) 8875 9086 14. GUIBERSON PACKER RH-1 8884 9095 15. CAMCO KBM MANDREL #9 8981 9195 DUMMY 16. OTIS "XO" SLIDING SLEEVE(CLSD) 8987 9201 17. GUIBERSON PACKER RH-1 18. CAMCO KBM MANDREL #10 19. OTIS "XO" SLIDING SLEEVE 20. GU[BERSON PACKER RH-1 21. CAMCO KBM MANDREL #11 22. OTIS "XO" SLIDING SLEEVE 23. GUIBERSON PACKER RH-1 24. OTIS "X" NIPPLE 25. OTIS "Q" NIPPLE 9005 9219 9068 9283 DUMMY 9073 9288 9082 9298 9223 9441 DUMMY 9228 9446 9238 9456 9245 9464 9246 9465 CASING 10 3/4", 40.5#, J-55 @ 1895' w/1600 sx 7" 23-29#, N-80 BUTTRESS @ 9927' w/1350 sx PBTD = 9658' TD = 9935' TUBING 3 1/2" 9 3# N-80 EUE @ 9465' PERFORATED ZONE GROSS INTERVAL GR-GS 8742-8780' HC-HD 9037-9069' HE-HF 9144-9194' H[-HK 9258-9297' HK-HN 9311-9440' HN-HR 9471-9610' HR-HZ 9640-9700' NOTE: 3 STRINGS OF WIRELINE TOOLS IN RATHOLE. TOP PACKER (#11) IS PROBABLY UNSEATED. Shell Western E&P In 601 West Fifth Avenue * Suite 8Q~ Anchorage, Alaska 99501 November 27, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS MIDDLE GROUND SHOAL WELL NO. C31-26 Enclosed, in duplicate, is the report of Sundry Well Operations for MGS Well No. C31-26. The workover included Coil Tubing Unit Acid Treatment. Operations were completed November 3, 1990. If you have any questions, please call Ms. Susan Brown-Maunder at (907) 263-9613 or Mr. Paul Huckabee at (907) 263-9646. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures RECEIVED DEC - ,5 1990 AI~I,~ 011 & Gas Cons. commisS'tol~ Anchorage \LETTERS~AOGCC\112790. DOC STATE OF ALASKA .( O.LOON ,V^T. ON REPORT OF'SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown 2. Name of Operator Pull tubing ~ Alter casing .Shell Western E&P Inc 3. Addre~ 601W-. 5th Ave. Anchorage, AK 99501 Slimulate _.~ Plugging __ Perforate ~ Repair well ..._ , Other ,5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface Platform C, Leg 1, Conductor 5 .@ 474'S & 340'S from Center of Leg 1 N top of productive intervai @ 8742'.931' FSL & 1585' FWL NE Corner, Sec 26, T8N, R13W SM At effective depth At total depth Sec 26r T8N 12. Present well condition summary Total depth: measured true vertical @ 9935' 1062" FSL & 1767' FWL of NE Corner of Effective depth: measured true verticai 9,935 feet Plugs (measured) 9,708 feet 9 ', 849 feet 9,623 feet Datum elevation (DF or KB) 116' 'KB feet 7. Unit or Property name Middle Ground Shoal & Well number C-SI 9. Permit number/approval number 90-786 10. APl number .~00 33.- O0 50-- 733_ L~=~=~ 11. Field/Pool G-Pool Junk(measured) Wirel ine Junk @ 9658' Casing Structural Conductor Surface Intermediate Production 9,927 ' Liner Pedoration depth: measured Length Size Cemented Measured depth True vertical depth 1,895' 10-3/4", 40.5#, J-55 1600 sx true vertical 1,895' 1,894' 7" 23-29# N-80 8,742 - 9,700' 8~538 - 9,476' 1350 sx 9,927' 9,700' RECEIVED DEC - ,5 1990 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9,465' Alaska Oil & Gas Cons, C0.m~ss|0tl Packers and SSSV (type and measured depth) nt.i ra 327' 13. Stimulation or cement squeeze summary ch0rage Guiberson Packer @ 8713' 9095' 9219' 9298' @ 9456' Intervalstreated(measured) 8742' - 9700' 14. Treatment description including volumes used and finai pressure 49 bbls wash soak w/7-1/2% HCL. 43 bbls 7-1/2% HCL ,let wash. 22 bbls 7-1/2%'HCL squeeze @ 1600 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 32 10 57 770 100 Subsequent to operation 173 0 307 570 15. Attachments J16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations ~ OiltX Gas ~ Suspended · 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~- F .~~ Form 10-404 Rev 06/15/88 100 Service Title ""w.,A'NA~'e~"~' ,,~E-G~ ~..,47-o/¢,/.' .AF'F,4~.,,~S Date/~-.,-'~- ~ SUBMIT IN DUPLICATE DAILY REPORT OF WELL OPERATIONS C31-26 DATE 10/31/90 11/01/90 DESCRIPTION Begin rig up at 0030 hrs. Pump to production system 152 BBLS of neutralized 7.5% HCL from ondeck surge tank. Pressure test flow lines at 300# & HP TBG/BOPE at 5000#. RIH w/jet wash nozzle ASMY, encounter scale at 6900'. Jet wash scale w/FIW with no significant progress. Pump 5 BBLS of 7.5% HCL w/add to test acid jet wash. Washed 119' at 1 BPM pump rate w/5 BBLS : 23.8'/BBL. Pump 20 BBLS HCL, 5 BBLS FIW, 5 BBLS polymer sweep for test. This indicated 108' of scale washed at 20 BBLS = 5.4'/BBL. The penetrat- ion rate w/7.5% HCL jet wash did not appear economic in view the hard scale encountered and anticipated displace and isolate acid to deck surge tank. POH w/jet wash nozzle ASMY F/7218'. R/U 2.25" carbide modified flat mill to a slimdrill pd 1.75 hydraulic drill motor. Test motor on surface. RIH w/drill motor ASMY, drill scale W/motor ASMY F/7250' T/7868 at 35'/FPM. Encounter slower P-rate at 7869'. Continue to mill scale w/2.25" OD mill and slimdrill hydraulic drill motor F/7869' T/9646'. Observe hard pack scale at GLM's # 6, 7, 8; sliding sleeve and tubing tail- pipe area. Scale was not clearly present in 7" liner through the perforated intervals. Pump 5 BBL sweeps as required to lift solids. POH w/motor ASMY. Secure well and coil tubing equipment. Release 3900 crane to drilling/production OPNS for 4 hrs use. P/U 2.504" jet wash nozzle. Press test at 300#/5000# BOPE. RIH w/jet wash ASMY, wash down at 1.5 BPM w/FIW. Make several passes at GLLM's #5, 6, 7; tailpipe jewelry. Pump sweeps at 9500', 9570', and 9624' Could not go beyond 9624', suspect stop is top of sliJk line fish. Per prog item #12: Pump 24 BBLS of 7.5% HCL w/additives and displace w/22 BBLS FIW to soak perforations and tubing interval to top of scale at 6900'. S/I and soak for 35 min. Pump 5 BBL sweep to clean and displace acid solution to ondeck surge tank for isolation. Prepare to jet acid wash per items #14 and #15 at report time. RECEIVED -1- DEC - 1990 .Oil ~& Gas Cons. Commission 11/02/90 Jet wash perforations and tubing jewelry F/6900' T/9624' w/43 BBLS of 7.5% HCL + additives. Required 5.5 hrs to isolate and neutralize HCL acid displaced from jet wash job. Acid solution appeared "strung out" with increased volume. Pumped 221 BBLS of neutralized HCL to production system. Begin acid squeeze stimulation. Pump 22 BBLS 7.5% HCL w/add at 9624'. Observe increasing pressure in 3 5" TBG x 7" liner annulus to 1600#. Stop squeeze operation. Observe apparent communication between THG and annulus. R/U to fill TBG/CSG annulus w/FIW. Displace neutralized HCL from TEG while POH w/coil tubing. POH w/ tubing to release crane for use of onloading 9 5/8" CSG. Neut. displaced acid in ondeck tank, ship t/prod at 1.5 bpm. Begin displacing 3.5" x 7" annulus containing gas and HCL acid w/FIW by pumping down tubing through uniden- tified access in tubing, taking returns at CSG valve, fluids displaced to production header or ondeck isolation tank defending pH values. Reactivity of HCL to soda ash when neutralizing requires a maximum of 110 BBLS HCL be isolated and processed at any one time. Therefore the annulus displacement process is 5+ hrs. Continue dis- placing and neutralizing annular fluids at report time. 11/03/90 Continue circulating/displacing well fluid down tubing. Through TBG/CSG communication spot at 1.5 BPM (actual depth unknown), receiving returns from CSG valve. Observe pH 7 FIW s/HCL "Hot Spots" of 0-3 pH. Isolate and neut- ralize "Hot Spots" in ondeck tank, pump to production as required. Circulate 1.8 times annular volume, observe continued low pH spot values of 0-3 pH. Shut in CSG valve. R/U and pump 18 BBLS FIW to displace 7.5% HCL acid w/additives in 7" and 3.5" TBG (spotted squeeze acid) estimated top at 8642", bottom at 9700' to perforations. ISIP at 1100#, FSIP at 600#. Pump FIW down 3.5" THG to displace 3.5" x 7" annular volume through communication spot. Monitor and direct flow return to production or ondeck tank to balance pH. Observe cleare change in pH value at 205 BBLS pumped. This would indicate the commun- ication spot is at/or between GLM #6 or #7, calculated depth at 7884'. Pump/displace net additional volume of 40 BBLS to confirm annular fluids are at 7 pH. R/D coil tubing equipment from wellhead. Well released to prod- uction at 1700 hrs, 11/03/90. Equipment and operation re- leased to C32-23 at 1800 hrs. -2- ~'~' SKA OIL AND GAS CONSERVATION COMI~I~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator Shell Western E&P Inc Abandon __ Suspend__ Operation shutdown __ Re-enter suspended well Alter casing __ Repair Well __ Plugging __ Time extension __ Stimulate ~ Change approved program __ Pull tubin~l __ Variance Perforate __ Older 6. Datum elevation (DF or KB} 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 4. Location of well at surface 5. Type of Well: Development X Exploratory Stratigraphic Service Platform C, Leg 1, Conductor 5 @ 537' FSL, 1593' FEL, Sec. 23, 'I'8N, R13W, SM [CORRECTED] @ 8742'. 931' FSL & 1585' FWL NE Corner, Sec 26, T8N, R13W SM At top of productive interval @ 9935' 1062' FSL & 1767' FWL of NE Corner of Sec 26, T8N, R13W, SM At effective depth At total depth 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C., "..~ J '- ,3..1o 9. Permit number 67.63 10. APl number ~OOv~.,q.- o o 50-733-2~=~t3 ~'rvl :11. Field/Pool "G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9,935 feet Plugs (measured) 9,708 feet 9,849 feet Junk (measured) 9,623 feet Wireline Junk @ ~ 9658' Casing Length Size Structural Conductor Surface 1,895' 10-3/4", 40.5#, J-55 Intermediate Production 9,927' 7", 23-29#, N-80 Liner Perforation depth: measured 8,742-9,700' true vertical 8538 - 9476' Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 1600 sx 1895' 1894' 1350 sx 9927' 9700' RECEIVED OCT 2 2 1990 3-1/2", 9.3#, N-80 EUE @ 9,465' jlj~!lSjijj.0il & ~as Cons. .Ca, ss n Packers and SSSV (type and measured depth) Guiberson Packer @8713', 9095', 9219', 9298' & ~,,~~ SSSV @327' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 10/25/90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~///~ ~.. "~ ~'A ;l'itle" Manager Alaska Operations Date 10/22/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test.__ Subsequent form required 10- J Approva, No.~. '7 ~ ~ Approved by order of the Commission Approved Copy Returned Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner SUBMIT IN TFIIPLIOATE MIDDLE GROUND SHOAL WELL No. C31-26 COILED TUBING CLEAN OUT, ISOLATE G, & ACID TREAT PRESENT STATUS:. Well producing from HI-HK, HK-HN, HN-HR, and HR-HZ. Last Test 10/01/90; 32 BOPD + 57 BWPD Communication with the GR-GS suspected. Acid soluble scale observed in the tubing. OBJECTIVES: 1) CTU Acid wash tubing to prep for RBP and PKR. 2) Set Baker thru-tbg RBP and PKR via CTU. 3) Establish injection into GR-GS/HC-HD. 4) Squeeze GR-GS/HC-HD to shut-off water. 5) Retrieve RBP and PKR. ~ 6) CTU Acid Treatment to remove Hemlock scale damage. COST ESTIMATE: $ 60,000 EXPECTED PRODUCTION INCREASE: 30 BOPD CURRENT PERFORATIONS: See attached wellbore diagram MECHANICAL DETAILS: See'attached weilbore diagram Wireiine fish in hole. Top of fish @ 9658'. RECOMMENDED PROCEDURE 1. SI gas injection. Close crown valve. RU Slick!ine Unit to recover SSSV. Test lubricator to 1500 psi. RIH and retrieve Otis Ball Valve from safety valve nipple at 327'. POOH. RD Slickline. 2. Hold safety meeting with Arctic Recoil' and all other platform personnel to discuss the proposed operations and concerns with H2S during acidizing operations. H2S concentrations of 150 - 250 ppm are not uncommon in spent acid returns during MGS acid treatments. 3. RU Arctic Recoil CTU with 1-1/2" coiled tubing and CTU assist pump. Test CTU stack to 5000 psi. 4. Call out 50+ bbls ?-1/2% HCL via Doweil-Schlumberger (D-S) with the following additives: - 0.4% A-250 Corrosion 'Inhibitor, - 0.5% W54 Non-Emulsifying Agent, - 0.2% F75N non-Ionic Surfactant, - 20#/lO00ga! L-58 iron sequestering agent An~o~ ~" )LE GROUND SHOAL No. C314~ COILED TUBING CLEAN OUT, ISOLATE G, &~ACID TREAT 5. Also from D-S, call out materials for 20 bbls PERMABLOK including 168 gallons D?5, and 55 gallons D140'Hardener to be mixed in freshh water. 6. RU circulation return line manifold to allow injection of NALCO Visco 3631H2S scavenger into the return fluids at (or near) the wellhead.. ?. RU return line manifold to take returns to an enclosed, isolated, pressure contained vessel capable of venting gas to the flare in a controlled manner. 8. RU holding tank between the pressure contained returns vessel and the Platform backflow system. The holding tank will be used to neutralize any unspent acid before entering the SWEPI facilities. In the holding tank, add 5 gals D-S D47 Antifoam additive per 1000 gallons of tank capacity (DO NOT put this additive in,the acid system to be pumped downhole!). 9. RU monitoring/alarm equipment to monitor H2S at the returns vessel and holding tank. 10. RU Filtered Inlet Water (FIW) source line to access FIW downstream of CUNO cartridge filters. Clean OUt & Acid Soak Weiibore 11. Fill 3-1/2" tubing by 7" casing annulus with FIW. 12. RIH with 1-1/2" coiled tubing with standard wash nozzle and check valve. Clean out scale to PBTD at '9658' (9654' during CTU clean out 5/07/89). Scale clean out may require acid wash to clean out with wash nozzle. Refer to Attachment No. 1 for guidelines on return fluid handling. If acid is used, take returns to the pressure contained vessel. Monitor return fluid for H2S and treat with NALCO Visco 3631 as needed. Neutralize return acid in the holding tank. Add D-S D47 Antifoam additive to the holding tank as needed to prevent foaming overflow. Ensure acid is spent/neutralized before sending to the production facilities. NOTE: Wireiine fish in hole. Top of fish @ ~9658'. 13. Mix and pump/circulate a 5+ bbl "XC" polymer sweep pill to clean up the welibore. NOTE: Coiled tubing length = 13800' (via Alvin Walker) 1-1/2" coiled tubing, capacity = (!.597 bb!s/iO00')*13800' = 22.04 bbls Am~ular capacity to 9658' = 0.00651 bbi/ft * 9465' + 0.03496 bbi/ft*(9658-9465) ' = 68.36 bbl page 2 M~" )LE GROUND SHOAL No. C31~ COILED TUBING CLEAN OUT, ISOLATE G, & 'ACID TREAT 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Conventionally circulate 12 bbls 7-1/2% HCL followed by 22 bbls FIW to displace the acid out of the end of the coiled tubing (EOCT). The acid volume should cover the interval from 9658' to above the top packer @ 8713' (lead acid @ 8665'). SD pump and let acid soak for at least 30 minutes. Mix and pump/circulate a 5+ bbl "XC" polymer sweep pill to clean up the weilbore. Take returns to the pressure contained vessel. Monitor return fluid for H2S and treat with NALCO Visco 3631 as needed. Neutralize return acid in the holding tank. Add D-S D47 Antifoam additive to the holding tank as needed to prevent foaming overflow. Ensure acid is spent/neutralized before sending to the production facilities. Refer to Attachment No. ! for guidelines on return fluid handling. POOH. Squeeze GR-GS & HC-HD RIH with 2-1/2" gauge ring/cutter on coiled tubing to 9200'+ to ensure the tubing.is clear for the Baker Retrievable Thru-Tubing Inflatable Bridge Plug (RTTI-BP) and Packer (RTTI-PKR). POOH. RIH and open Otis "XO" sliding sleeve @ 9086'. POOH. RIH with RTTI-BP on' coiled tubing, and set at 9145'. POOH. RIH with RTTI-PKR on coiled tubing and. set at 8900'. Establish 1BPM in3ection rate with FIW into GR-GS/HC-HD perforations via open sliding sleeve. Monitor and maintain pressures on coiled tubing/tubing annulus and tubing/casing annulus (we suspect the top packer is unseated). Do not exceed 3000 psi on tubing/casing annulus. Shut down pumps and measure ISIP. RU FIW line to the tubing/casing annulus to maintain a "positive" back pressure on the tubing/casing annulus while pumping the following PERMABLOK squeeze step. "Positive" back pressure is intended to mean - Maintain a low rate of injection (~ I gai/min or less) to ensure no PERMABLOK material is displaced above the top packer. Initial pressure should be ~100 psi'above the ISIP measured above. Mix and pump/squeeze down the coiled tubing 20 bbis D-S PERMABLOK (sodium silicate) followed by 34 bbis FIW. Maintain a "Positive" back pressure on the tubing/casing annulus to ensure no PERMABLOK material is displaced above the top packer. NOTE: The 34 bbis FIW flush volume is calculated to overdispiace the perforations by 0.18 bbls. Release RTTI-PKR. POOH. page 3 ADDLE GROUND SHOAL No. C31-26 COILED TUBING CLEAN OUT, ISOLATE G, & ACID TREAT 24. RIH and retrieve RTTI-BP. POOH. 25. RIH and close Otis "XO" sliding sleeve ~ 9086' POOH. Jet Acid Wash PerforaTions 26. RIH with "jet wash'~ nozzle and check valve on 1-1/2" coiled tubing to the bottom perforation ~ PBTD ~ -9658' 27. Pump/circulate, while reciprocating coiled tuDing, to jet wash the perforations from PBTD - 9471' with i0+ bbis Doweii 7-1/2% HCL to remove perforation damage. Take returns to the pressure contained returns vessel. Monitor return fluid for H2S and treat with NALCO Visco 3631 as needed. Displace wash acid from the weiibore. Ensure acid is spent/neutralized before sending to the production facilities. POOH. Acid Squeeze Stimulation 28. RIH with check valve on 1-1/2" coiled tubing to PBTD % ~9658'. 29. Spot circulate 22 bbis 7-1/2% HCL (with above additives) to the EOCT @ 9658'. Close annulus and pump/squeeze 50 bbls FIW into the perforations at a pressure not to exceed 2500 psi surface pressure with an acid hydrostatic. Do not exceed 3000 psi 'surface pressure with a FIW hydrostatic. NOTE: Pump acid at the maximum rate possible without exceeding the pressure constraints. NOTE: The FIW volume has been calculated to overdisuiace the ~ perforations by 21.5 bbis FIW. 30. POOH. RD D-$. RD CTU. Open well to production. 31. RU Slickline Unit. Test lubricator to 1500 psi. RIH and install Otis Ball Valve in safety valve nipple at 327'. POOH. RD Slicktine. 32. After well performance stabilizes, production test well via the test separator. PTH 10/15/90 Recommended: ~-~ _~.J~-- ~of~%-/~ Concurred work ph # 263-9646 home ph # 344-5857 Date: page 4 t''''~ )LE GROUND SHOAL No. C31~ . COILED TUB~NG CLEAN OUT, ISOLATE G, & ACID TREAT cc: ANCHORAGE Manager Alaska Operations - R. G. Blackburn Division Drilling/Production Engineer - V. E. Unger Kenai Production Office - B. N. 0sborn Platform "C" Operations Foreman - Vickerson/Dunckle¥/Tracy Environmental Technician - S. S. Brown-Maunder Anchorage Engineering File Room - Category (6) HOUSTON WOODCREEK C. M. Kidwell - WCK 1178 R. G. Lippincott - WCK 1140 S. M. Logan - WCK 1162 E. W. Kitchen - WCK 1136 ORIGINAL TO: Woodcreek File Room - WCK 4100 page 5 RECEIVED OCT 2 ~- 1990 Alaska 0il & Gas Cons. Gommissio~ ~' )LE GROUND SHOAL No. C31~" . COILED TUBING CLEAN OUT, ISOLATE G, & ACID TREAT ATTACHMENT NO. I PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS All backflowed and circulated fluids 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 bbis 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 C31-26 acid 'treatment - lO/xx/90". Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. Pipeline Delay = 2660 bbi -- x 24*hrs = Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) hfs Onshore Facility Delay = 1000 bbi Gross Daily Prod "A" "¢" , , and "Baker" (bbl) x 24 hrs = hfs Total time between slug shipment and sample time = hfs NOTE: The Onshore Operator should be notified and instructed to divert the transferred fluid to the holding tanks. This will allow dilution of the workover fluid prior to processing through the plant. page 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMPLETION EQUIPMENT DETAIL SHEET MGS C31-26 7/21/87 NO. ITEM ,, , 1. OTIS SAFETY BALL VALVE 2. CAMCO KBUG MANDREL #1 3. CAMCO KBUG MANDREL #2 4. CAMCO KBUG MANDREL #3 5. CAMCO KBUG MANDREL #4 6. CAMCO KBUG MANDREL #5 7. CAMCO KBUG MANDREL #6 8. CAMCO KBUG MANDREL #7 APPROXIMATE TVD. MD. PSI OR 327 32i -- 1870 1871 900 3/16 3501 3510 905 3/16 4921 4962 910 3/16 6001 6092 915 3/16 7104 7257 965 1/4 7808 7991 965 1/4 8441 8642 OR 3/8 9. BAKER OVERSHOT SEAL BORE ASSY. 8464 8666 10. OTIS "XO" SLIDING SLEEVE(CLSD) 8502 8705 11. GUIBERSON PACKER RH-1 8510 8713 12. CAMCO KBM MANDREL #8 8869 9080 DUMMY 13. OTIS "XO" SLIDING SLEEVE(CLSD) 8875 9086 14. GUIBERSON PACKER RH-1-' 8884 9095 15. CAMCO KBM MANDREL #9 8981~9195 DUMMY 16. OTIS "XO" SLIDING SLEEVE(CLSD) 8987 9201 17. GUIBERSON PACKER RH-1 18. CAMCO KBM MANDREL #10 19. OTIS "XO" SLIDING SLEEVE 20. GUIBERSON PACKER RH-1 21. CAMCO KBM MANDREL #11 22. OTIS "XO" SLIDING SLEEVE 23. GUIBERSON PACKER RH-1 24. OTIS "X" NIPPLE 25. OTIS "Q" NIPPLE 9005 9219 9068 9283 DUMMY 9073 9288 9082 9298 9223 9441 DUMMY 9228 9446 9238 9456 9245 9464 9246 9465 CASING · 10 3/4", 40.5#, J-55 @ 1895' w/1600 sx 7" 23-29#, N-80 BUTTRESS @ 9927' w/1350 sx PBTD = 9658' ( c~654.' 'o,~.,~i ~'r",.,. cc, _ 5'/~"//8,i' ]) TO = 9935' TUBING 3 1/2", 9.3#, N-80 EUE @ 9465' PERFORATED ZONE GROSS INTERVAL GR-GS 8742-8780' HC-HD 9037-9069' HE-HF 9144-9194' H[-HK 9258-9297' HK-HN 9311-944~.' HN-HR 9471-9610' HR-HZ 9640-9700' NOTE: 3 STRINGS OF WIRELINE TOOLS IN RATHOLE. TOP PACKER (#11) IS PROBABLY UNSEATED. Shell Western E&P Inc. 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 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: 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells 1 location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, 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 RE '¢EIVED JUN 1 Alaska Oil & Gas Cons. 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 LEG 2 1 C23-23 2 C32-23 3 C34-26 4 C24-26RD 5 C31-26 6 C34-23 7 C23-26 8 C22-26RD CONDUCTOR LEG 3 LEG 4 9 10 11 12 13 14 15 16 CONDUCTOR 25 26 27 28 29 30 31 32 DISTANCE FROM SE CORNER NORTH WEST 547.10 1599.00 547.25 1594.46 544.25 1591.06 540.57 1590.68 536.91 1593.01 535.88 1597.22 538.03 1600.98 542.18 1602.22 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.].5 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 C42-23 C31-23 C43-23 C41-23 .C33-26 C-LINE C44-14RD C24-23 509.00 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 Z/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 I)LATfOGM ,- i H[L[ I,I '[CC'"' · L 0 ~..AT ION COOK IN L.ET' ,'-' ALASKA L'~Lf I'. ~'000' lialrck IN7 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 January 17, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: CANCELLATION OF OUTSTANDING REPORT OF SUNDRY WELL OPERATIONS FOR MGS WELL NOS. A33-14, A12-12, A23-OIRD, A34-11, A34-14RDII, A44-11, A13-12RD AND C31-26 Enclosed are two copies of the Report of Sundry Well Operations for MGS well nos. A33-14, A12-12, A23-O1RD, A34-11, A34-14RD II, A44-11, A13-12RD and C31-26. These workovers were all cancelled and none of the work was performed. If you have any questions concerning these reports, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/raf Enclosures SBBL/aogcc. 011790 REPORT OF SUNDRY WELL OPERATIONS OIL AND GAS CONSERVATION COM SION Pedorate __ OtherX_.. CANCELLED 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing ~ Alter casing t Repair well __ 2. Name of Operator Shell Western E&P Inc· 5. Type of Well: Development -X-- Exploratory __ Stratigraphic __ Service t. 3. Address 601 West Fifth Avenue, Suite 810 Anrhnrao~' AK qq%N1 4. Location of well at surface Platform "C" Leg 1 Conductor 5 @ 340' E from Center of Leg 1, At top of productive interval ~ 8742', 931' FSL & 1585' FWL NE Corner Sec, 26, T8N, R 13W, S,M, At effective depth At total depth ~ 9935' 1062' FSL & 1767' FWL of NE Cc.".-.c.-- cf Eec. 25, T~N, R 13W, 12. Present well condition summary Total depth: measured 9935 ' feet Plugs (measured) true vertical9708, feet 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number C:~1 9. Permit number/approval number 67-69 / 9-530 10. APl number 50-- 7RR-?N~,N?-NN 11. Field/Pool Pool Effec!ive depth: measured 9849' feet Junk(measured) true vertical9623, feet Length Size Cemented Measured depth True vertical depth 1895 ' 10-3/4", 40.5#, J-55 7", 23'29#, N-80 measured 9,471'-9,700' 2 intervals t 5-rue ,. er a l s c 1 osed) ver[ical 1600sx 1350 sx Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 3-1/2", 9.3#, N'80 EUE @ 9,465' Tubing (size, grade, and measured depth) 1895' 9927 ' , ']':...~'-' '--- ~ .7' ~ ;'~ .. Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf wateroBbl Casing Pressure Service 16. Status of well classification as: Oil x__ Gas ~ Suspended Dme 01/17/90 SUBMIT IN DUPLICATE 17. I hereby certify that. the foregoing is true and correct to the best of my knowledge. Signed ~jj 0~ ~~~ Title DIVISION OPERATIONS MGR. Form 10-404 Rev 06/15/88 SBBL/r swo .011590C3126/1 feet 601 West Fifth Avenue · Suite 810 ~ Anchorage, Alaska 99501 June 15, 1989 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING WORKOVER ON MIDDLE GROUND SHOAL (MGS) WELL C31-26 Enclosed are three copies of the Application for Sundry Approval for the upcoming workover on MGS well C31-26. The workover will include perform- ing acid clean out. These operations are expected to commence around June 16,1989. If you have any questions concerning this application, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/raf Enclosures RECEivED 41a~ka Oil & Gas Cons. CommiSsion Anchorage SBBJ / a s a. 061589 STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging ~ Time extension __ Stimuta-T~.,~. Change approved program __ Pull tubing __ Variance ~ Perforate ~ Other 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorege, AK 5. Type of Well: Development _~. Exploratory __ Stratigraphic __ 99501 Service __ 4. Location of well at surface Platform "C", Leg 1, Conductor 5 (~74'S & 340' E from Center of Leg 1. At top of productive interval ~8742'. 931' FSL & 1585' FWL NE Corner Sec. 26, T8N, R13W SM At effective depth @ 9935' 1062' FSL & 1767' FWL of NE At total depth corner of Sec 26, T8N, R13W, S.M. 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoe1 8. Welt number C31-26 9. Permit number 67-63 10. APl number 50-- 733-20502-00 11. Field/~l Pool feet 12. Present well condition summary Total depth: measured 9935 ' feet true vertical feet 9708' Effective depth: measured feet true vertical 9849 ' feet 9623 ' Casing Length Size Cemented Structural Conductor Surface Intermediate 1895' 10-3/4", 40.5#, J-55 Production 7", 23-29#, N-80 Liner Perforation depth: measured 9471-9700' 2 intervels (5 intervels closed) true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE ~ 9465' Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal Plugs (measured) Junk (measured) Measured depth True vertical depth 1600 sx 1895' 1350 sx 9927' RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Detailed operations program __ BOP sketch __ 14. Estim. ated,d~ate,fo~Lc~ommencing operation June / b, / ~'~ 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~-'~'~ Title::Z'A~ /ct./..., ~ oo~,,v ~"'~ ,~,/,~.,~.,~.~r~ Division Operetions Meneger Signed c/ FOR COMMISSION USE ONLY Date June 15, 1989 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED LONNIE C. S~.~m4 J Approval No. Approved Copy Beturned Commissioner SUBMIT IN TRIPLICATE Form lO§j~ J~] ~esVeO. ~/~ ~8~j ~ RCV 0Y:Xer0x Telecopier ?020 ; 6-14-B9 ; 1:22PM ; 0422?4 = 90727gO211;,t 2 PRO~ltO$I$ OPERATION: Dissolve scale with acid. WELL DATA: See attached completion equipment detail sheet, STATUS; A CTUAT was done on 05/O7/89., After that Job, well produced [84 BFPO (74 BOPD). on 00/]3/89. gross Z3Z BFPD (48 BOPD]. CgP tnceeased free .450 pst to 850_pst. On 06/Ii:/89, caul(I not get below go3g' with wtrel~ne tools. PROCEDURE: 2. 3. 7~ g~ Shut off gaslift gas. Shut in flowltne. Rig up O.S, with single pump skid. Hold safety meeting. Test all line to 5000 psi. Test sable of acid. PumR [000 gal, 15% h~drochlortcjacld with inhibitor, surfactant, anti-~lu~ge and anti-foam, Inhibitor designed fop 30 hrs, 0 [65 degrees F. Follow with 10 ~bls diesel Observe pressures. Do not exceed 4500 psi Bleed of~ pressure ~o lO00 psi. Rig down D.S. equipment. Let well soak for 4 h~., flow well fo~ 1 hr., ~hut in well fo~ 2 hrs. Place well on ~roductton. Che~k PX frequently and neutralize with caustic if PH less than 7. Attachment ECV BY:Xerox Telecop~er ~020 ~ ~-14-~ ; I:~P~ ; g lo 14 16 18 COMPLETION EQUIFI4£NT DETAIL SHEET OL. lTr GUIgERSON OTIS 6UIGER$ON CAMCO KM OTIS 6UJBERSON CAMCOKBH GUXB£RSON CAMCO KBM OTIS 0715 SAFETY BALL VALVJ ¢~¢0 KBUO #ANOREL CAMO0 KDLI6 MANPREL C;AHC;O KBUOtdJANDREL #4 CAI~O KB~ IWlANDREL CAMCO KBUGP. ANDREL CANCO KitU6 MANDREL #? BAKEROVERSHOT SEAL 80RE A$SY. OTIS "XO" $LIDIH6 SLE£VE(CLSO) PACKER RH- ! ~NDREL ge SLIDXN$ SLEEVE(CLSD) PACKER RH-J IqN~DREL SLIDING SLE[¥[(CLSO) PACKER RH-J MMIOREL #10 SLIOI~tG SLEEVE PACKER MRNOREL #11 SLIOINO SLEEVE SO [eER$Ofl PACKER OTIS "X" NIPPLE OHS "Q" NIPPLE t, 3, 4, 5. B, 7. 8. 14. 25. APPROII~?! 1010 1871 gO0:1/16 $60t SBIO tO$ 3/16 7104 7~B7 JOt J/4 7800 7~91 866 3/4 ~l ~q~ OR 3/8 8~2 8705 861o ITt3 ~7t- 8~' toil see7 90~ 9263 D~ 9013 o~se 9283 9441 o~y 9~36 9460 gZ46 6405 10 3/4", 40.$#, j-SS O 1895' w/1600 ex ?" ~3-29#, N-BO'BUTTRESS 9 99~1' #/1350 IX TUBZNO 3 2/2", 9,3#, R-80 EU£ 6 [1465' P_ERr.O_RATED ZONe. )H.T, nVAL. HC°HOJ 0031-9069' HI-HK 5~ etna ~ 9258-9297~ HK-HN $ ¢ ¢.,J~ , 9311-B440' HN-HR~ o~,e,,, g471'g610~ 9640'0700' ""'"U ' NOTE: 3 ~,TRIN;$ OF WIRELINE TOOLS IN RATHOLE. TOP PACKER (W21) IS PROBABLY UNSEATED, + RECEIVED 1 5 ]989 · 'iUaSka OiJ & Oas Cons. Commiss; Anchoraoe May 26, 1989 Shell Western E&p Inc00 1N A L 60'1 West Fifth Avenue o Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska 0i7 & Gas Conservation Commission 3001 Porcupine Drive Anch°rage, Alaska 99501 Gent 1 emen: SUBJECT: REPORT OF SUNDRY I~ELL OPERAT/ONS ON IffIDDLE GROUND SHOAL (t4GS) WELL C31-26 EncTosed are two copies of the Report of Sundry Welt Operations for d~GS well C31-26. The workover included Performing acid Clean out with coiled tubing unit. The operation was complete on Nay 7, 1989. If you have any questions concerning this report, p~ease contact Susan Bro~n-Naunder at (907) 263-9613. · Very truly YOurs, W. F. Simpson Hanager, Regulatory Affairs Alaska Division ~/FS/SBBN/ra f Enclosures RECEIVED MAY 3~ o ]98:9 Alaska Oil & 6as Cons. Commissiori Anchorage SBBJ/asa.051989 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPEP. ATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging ~ Perforate Pull tubing ~ Alter casing ~ Repair well __ Other 2. Name of Operator .qh~ll Western: E&P. Inc. 3. Address 601 W. Fifth Ave. Suite 810 Anchoraqe~ AK 99501 4. Location of well at surface P1 atform "C", Leg 1, S.E. Corner of Section 23, T8N, R13W At top of productive interval 8742', 931' S & 1585' Corner of Sec. 26, T8N, R13W @ S.M. At effective depth A~otal de~oth .t. corner of 5. Type of Well: Development Exploratory Stratigraphic Service 'Conductor 5, W from N.E. @ 9935'. 1062' S & 1767' W from Sec. 26, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured true vertical 6. Datum elevation (DF or KB) 116' DF 7. Unit or Property name Middle Ground Shoal 8. Well number C31-26 9. P_ermi[.n..umber/approval number bi-b3 ?" ~,,l o 10. APl numbs3- 50- 20052-00 11. Fi~lmclg~)O 1 9935' feet Plugs (measured) 9708' feet feet Effective depth: measured true vertical 9849 ' feet Junk (measured) 9623' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1895' 10-3/4" 40.5# measured true vertical 9471' 9700' 2 Intervals (5 Intervals Closed) Tubing (size, grade, and measured depth) 3-1/2" 9.3# N-80 Measured depth True vertical depth RECEIVED MAY :] o ]989 Alaska 0il & Gas Cons. C0mmissio~ Anchorage EUE @ 9465' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Acid Wash tubing with 38 bbls. of Intervalstreated(measured) 9311 ' - 9654' with coiled tubing 10% HC. 1. unit from 9057' to 9654 Treatment description including volumes used and final pressureFinal pressure while pumping; 500 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 46 14 68 765 43 8 71 435 Tubing Pressure 70 75 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certi/f~hat the foregoing is true and correct to the best of my knowledge. Signed_ ~~.~~~.~,~ Title Division Operations Manager Form ~ 8J48,~ t~ev 06/1,~¢8-0 Date 05/26/89 SUBMIT IN DUPLICATE 7 DAILY JOB SUMMARY WELL NO' OPERATION' DATE' C31-26 COILED TUBING ACID SCALE REMOVAL 05/07/89 Rigged up Otis coiled tubing unit and Dowell acid pumping equipment. RIH and washed scale from tubing at 9057' to 9654' with 10% HC1. RECEIVED ~AY 3 0 1989 Alaska Oil & Gas Cons. Commissio~ Anchorage SBBJ/djs.051989 Nay 5, 1989 Shell Western E&I= 601 West Fifth Avenu Anchorage, Alas Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT- AREA INJECTION ORDER NO. 9 (CENTRAL PORTION ~ FIELD), RULE 6 As part of the requirements, of Area Injection Order (AIl schedule for performing radioactive tracer surveys (RTS! to and approved by the commission. During conversation! your staff it was indicated that the Commission may acc( even though the commission representatives did not have witness the surveys. By way of this letter, SWEPI is si schedule for performing RTS's on in,iection wells and re( accept the recent surveys as satisfying the requirementl on the enclosed RTS logs. (See Attachment 1 for list o~ Attachment 2 is a table showing the mechanical integrib MGS in,iection wells. Also shown is the proposed testin~ those wells for which we are asking .your acceptance of; surveys. Your early review of this proposal would be greatly appl can be of further assistance, please do not hesitate to Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs SBBM/hr Enclosures Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 April 26, 1989 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT: APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING WORKOVER ON MIDDLE GROUND SHOAL (MGS) WELL C31-26 Enclosed are three copies of the Application for Sundry Approval for the upcoming workover on MGS well C31-26. The workover will include perform- ing acid clean out with coiled tubing unit. These operations are expected to commence around May 1, 1989. If you have any questions concerning this application, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/hr Enclosures GTK 1/050489 SBB I / asa. 042689 Attachment 1 LIST OF ENCLOSED LOGS Well No. ~ AII-I2 ~ Al1-13 RD II ~ A12-12 ~ A33-14 v'A34-14 RD II ~ A44-11 - C23-26 ~ C24-23 ~ C34-23 V' ~ C41-23 Log(s) RAF - 6/17/87 NFL - 1/17/86 NTL - 3/4/88 NFL - 3/5/88 RAT - 6/17/87 NFL - 9/5/86 RTS - 3/26/88 NFL - 1/26/87 NFL - 2/12/87 NFL - 1/27/87 NFL ~ 2/10/87 NFL - 2/12/87 NFL - 10/24/87 GTK1/050489 STATE OF ALASKA (: ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown m Re-enter suspended well Plugging __ Time extension __ Stim ula-'~' X Pull tubing ~ Variance __ Perforate __ Other __ 2. Name of Operator Shell Western E&P Inc. &Address 601 W. 5th Avenue, Suite 810 Anchorage, Alaska 99501 4. bocation of well at surface "C", Leg 1, 40 'E from center of Leg 1 M ' At t'cJpbf productive interval @ 8742'. Sec. 26, T8N, R13@, S.M. At effective depth 931'S 5. Type of Well: Development _X_ Exploratory __ Stratigraphic __ Service __ Conductor 5. Conductor @ 474'S SE corner of Sec 23, T8N R 13 W & 1585'W from NE corner of At total depth @ 9935'. 1062'S & 1767'W from NE corner Sec. 26, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured true vertical 9,935 ' feet Plugs (measured) 9,708' feet 6. Datum elevation (DF or KB) 116' DF 7. Unit or Property name Middle Ground Shoal feet 8. Well number C 31-26 9. Permit number 67-63 10. APl number 5o- 733-20052-00 11. Field/Pool "G" Pool Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 18 9 5 ' Production Liner Perforation depth: measured true vertical 9,849' feet Junk (measured) 9,623' feet Size Cemented Measured depth True vertical depth 10-3/4", 40.5#, J-55 1600 sx 7", 23-29#, N-80 1350 sx 9471-9700' 2 intervals (5 intervals closed) Tubing (size. grade, and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9,465' Packers and SSSV (type and measured depth) 1895' 9927' 13. Attachments Description summary of proposal ..[. Detailed operations program X BOP sketch __ 14. Estimated date for commencing operation 115. Status of well classification as: May 1, 1989 16. If proposal was verbally approved Date approved Service Name of app_r0/~ 17' I hereby/l~,~rtif~/t/~e,f°~reg~/~g i~ true and c°rrect t° the best °f mY kn°wledge' Signed ¢//~ Title Division Operations Manaqer FOR COMMISSION USE ONLY Oil ~ Gas __ Suspended __ Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance m/TLcZ.,L' Mechanical Integrity Test __ Subsequent form required 10-. ~,pproved Copy Returned ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner I Approval No. ¢_.. ~¢,~ O Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE C31-26 PROGNOS I S C31-26 OPERATION: Clean out tubing with CTUAT. WELL DATA: 7" 23/26/29 # N-80 Buttress @ 9,927'. TUBING: 3-1/2" 9.3# N-80 EUE 8rd. For additional information see attached completion equipment detail sheet. STATUS: Producing 50 BO + 94 BWPD 3/25/89 PERFORATED INTERVAL: GR/GS HC/HD HE/HF HI/HK HK/HN HN/HR HR/HZ 8,742 9,037 9,144 9,258 9,311 9,471 /8,780' ............ XO @ 9,086' closed /9,069' ............ XO @ 9,086' closed /9,194' ............ XO 0 9,201' closed /9,297' ............ XO 0 9,288' closed /9,440' ............ Open to production. /9,610' ............ Open to production. 9,640 /9,700' ............ Open to production. ×0 open Tbg. open Tbg. open RECOMMENDED PROCEDURE lo RU Wireline and lubricator. Test lubricator to 3,000 psi. Pull ball valve. RD wireline. 2, RU CTU and acidizing equipment Test all lines and equipment to 5,000 psi. Test sample of acid from top and bottom of tank using the titration and hydrometer method {service company to provide test equipment). If more than a 1% difference exists between samples, roll the tank and retest. With well lifting, RIH with CTU circulating with injection water at 1/4 BPM. Do not allow well to stop flowing. If well does stop flowing, stop circulating and allow well to unload. , Scale was found to be present from 9,030' to 9,050'. Therefore, wash slowly with acid if scale is found above 9,030'. Continue RIH to 9,465' and pump 1,500 gal of 10% HC1 containing emulsion breaker and Oil & Oas Cons. Anchorage AFE/HAVS021789 C31-26 Attachments' inhibitor. Acid wash by moving coiled tubing between 9,300' and PBTD while pumping acid at 0.25 BPM. When all acid has been displaced with injection water, POOH. 1, Completion EQuipment Detail Sheet Production Performance Curves 1988 Well Work Log RECOMMENDED' DATE' APPROVED: '7~,-y~, ~>-i~7~r~. DATE' HAVS/jlm AFE/HAVS021789 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMPLETION EQUIPMENT DETAIL SHEET MGS C31-26 7/21/87 NO. ITEM 1. OTIS SAFETY BALL VALVE 2. CAMCO KBUG MANDREL #1 3. CAMCO KBUG MANDREL #2 4. CAMCO KBUG MANDREL #3 5. CAMCO KBUG MANDREL #4 6. CAMCO KBUG MANDREL #5 7. CAMCO KBUG MANDREL #6 8. CAMCO KBUG MANDREL #7 APPROXIMATE TVD. MD. PSI OR 327 327 1870 1871 900 3/16 3501 3510 905 3/16 4921 4962 910 3/16 6001 6092 915 3/16 7104 7257 965 1/4 7808 7991 965 1/4 8441 8642j OR 3/8 9. BAKER OVERSHOT SEAL BORE ASSY. 8464 8666 10. OTIS "XO" SLIDING SLEEVE(CLSD) 8502 8705 11. GUIBERSON PACKER RH-1 8510 8713 12. CAMCO KBM MANDREL #8 8869 9080 DUMMY 13. OTIS "XO" SLIDING SLEEVE(CLSD) 8875- 9086 14. GUIBERSON PACKER RH-1 8884, 9095 15. CAMCO KBM MANDREL #g 8981 9195 DUMMY 16. OTIS "XO" SLIDING SLEEVE(CLSD) 8987 9201 17. GUIBERSON PACKER RH-1 9005 9219 18. CAMCO KBM MANDREL #10 n 9068 9283 DUMMY 19. OTIS "XO" SLIDING SLEEVE C~ 9073 9288 20. GUIBERSON PACKER RH-1 21. CAMCO KBM MANDREL #11 22. OTIS "XO" SLIDING SLEEVE 23. GUIBERSON PACKER RH-1 24. OTIS "X" NIPPLE 25. OTIS "Q" NIPPLE 9082 9298 9223 9441 DUMMY 9228 9446 9238 9456 9245 9464 9246 9465 CASING 10 3/4", 40.5#, J-55 @ 1895' w/1600 sx 7" 23-29#, N-80 'BUTTRESS @ 9927' w/1350 sx PBTD = 9658' TD = 9935' TUBING 3 1/2" 9 3#, N-80 EUE @ 9465' PERFORATED ZONE GROSS INTERVAL GR-GS ~ S'L HC-HD HE-,HF .~ ~ HI-HK $ 4 ¢1 ~;~ ? HK-HN $ ¢ HN-HR ~ HR-HZj 8742-8780' 9037-9069' 9144-9194' 9258-9297' 9311-9440' 9471-9610' 9640-9700' NOTE' 3 STRINGS OF WIRELINE TOOLS IN RATHOLE. TOP PACKER (#11) IS PROBABLY UNSEATED. ATTACHMENT 1 PAGE 111 PRODUCTION UNIT 851 (UNIT NAIVE ) FIELD 5099 (MID.GR.SHOI:IL) LEASE 50233 {I"IIDOLE OROUND SHOAL ) RESERVOIR OOtO0 (EAST FLANK HELL {C 3!-26] · , · t ' --: - ' ' ; ~ - -: .'~ ' . · ' : .*' - :'. --.-::.: -: ............... : :.~:'*. .... ' ; .--. : '. : ..~.:1' :: : .... i -' ::.::~-..~*. -:~'...: *I _~. -: ~ . :=~ . . .... . .... #ell Work In 1988 c31-26 3/14/88 I~4DE 2.625 SCALE RUN (ALL CLEAR) 7/21/88 PERCISION WIRELINE PAN BALL VALVE. 8/12/88 MADE 2.625 SCALE RUN (FOUND A SMALL AMOUNT OF SCALE AT 9050. TAGGED BOTTOM AT 9635. RAN BALL VALVE 9/7/88 CH~NGED SPOOL OUT ON INJECTION LINE. CHEMICAL ERROSION. STOPPED INJECTING CHEMICAL. 9/22/88 PRECISION WIRELINE SHOT FLUID LEVEL FLUID IN CASING AT 8642. SEEMS TO INDICATE THAT GAS IS NOT GOING THROUGH BOTTOM ORIFICE. 9/28/88 MADE SCALE RUN, BRIDGE AT 9030'. RAN 2.625 STAR BIT. TAGGED BOTTOM AT 9623 11/21/88 MADE SCALE RUN WITH 2 1/4 BAR, NO SCALE MADE SCALE RUN WITH 2.625, NO SCALE 11/22/88 RAN IN BALL VALVE 12/30/88 PULLED~DID DRIFT RUN WITH 2,25, 2.50 AND 2.625.(~OUND SCALE AT 9030 TO 9050~. 12/31/88 RAN BALL VALVE BACK IN ATTENTION HANK VAN SCHELT: ORIGINAL COPY IS IN THE MAIL MEMORAND(uM THRU: State('of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION .. Lonnie C. Smith,S' Commissioner ~/ ~ Michael T. Minder Sr. Petroleum Engineer D^TE: August 8, 1988 F,LE,O: D.BDF. 008 TELEPHONE NO: SUS~EC~ 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 10t30 ai'~"."With 10 Pilots, 10 SSSV s and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. Thi%~ill 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. Attachment PilotS Tested 10' Pilots Failed 0 SSSV's Tested 10 SSSVI§ Failed 1 SSV's Tested 10 SSV's Failed 0 02-00lA (Rev. 8185) AOGCC SAFETY VALVE TEST REPORT PAGE · · PRESSURES - PSIG. FIELD: HIDDLE GROUND SHOAL SHELL C PLATFORM ] OPERATOR: I WELL I I NU~IBER I NU, BER I I I c44-14~ 177 -oo 7 9-o ' Ic-2~.-2~.... 68-oo,o-o ~{J.-31723 ~ 68-0069-0 I ' I C-43-23 ~ 68-0060-0 IC22-26~ 76-0065-0 I I ~fi~-4~2~:~ 79-0062-0 , ::,:.'. 67-0063-0 SHELL WESTERN E&P REPRESENTATIVE: PER. IT Isv TSTIPILOT[ rLGI SI I _ssv I DUE I (LOW) I TBG I~1~1~ I~1 ....... I I I I I z,j: I I I I I I I I I I I I I I , __1 SSVl _ sssv I sss INI ITS, TI IP I rP ITSTITI... I_.1 ~1 _1,,., I I ..... I_1. bo ,, IL_l_l .... I~1_1 ,, I_1' IP, IP" ..... I_1 II 1'1 . I I. '1 I . .1~1,, ,1_ ,,,I . ~ .... I, .~_ Shell Western E&P Inc. A Subsidiary of Shell Oil Company P.O. Box 576 Houston, TX 77001 June 18, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99510 Attn' John Boyle Dear Mr. Boyle' SUBJECT: DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA Work Order No. Enclosed you will find data pertaining to the Middle Ground Shoal Well listed above. Please return a signed copy of this transmittal letter to acknowledge recei pt. C. C./~i 11 i ams A1 as a~j~/Division Shell Western E&P Inc. CCW:mh Enclosure Received by: Alaska 011 & Gas Cons. Commission Anchorage CRCT8701303 SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECT!ON DATE :February 9, 1987 COMPANY :Shell Western E&P Inc. LEASE : WELL ~O.:C31-26 API NO. :50-733-20052 FIELD :Middle Ground Shoal STATE :Alaska COMMENTS: Sample No. Depth Grain Atm Air Density Porosity Permeability ft gm/cc % md 5 9053.0 2.646 13.5 12.1 5-1 9053.0 2.645 13.5 11.1 6 9410.0 2.644 8.49 NT 6-1 9410.0 2. 637 6.69 NT Grain density determined by Archimedes principle . Page Shell Develo~ Compauy Petrophysical r~.~es Bection Core Analyses Data Date : DECEMBER 29, 1986 Company : SHELL WESTERN E&P INC. Lease : Well No. : C31-26 Field : MIDDLE GROUND SHOAL State : ALASKA Eomments : WHITE CHERT PEBBLE POR AUTOPORE TEST Samp 1 e No. Depth Identifier Porosity Air Perm. md Grain Density g/qc 1 94o9' 0" 1 15.1 2.654 .cC SHELL D£¥ELOPMENT PETROPHYSI~L SERVICES SECTI~d STRESS MERCURY CAPILLARY PRESSURE DATA SI'RES~ PRESSURE: 4500 PSI , .... ~ , , -~ j Ala~ka C ~l & las ~ , 1000 100 100 90 80 70 60 50 40 30 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : FEBRUARY 20, 19B7 COMPANY; SHELL WESTERN EJrP INC. LEASE : WELL NO: C$1-26 APl NO: 50-75&-20052 FIELD,: MIDDLE GROUND SHOAL 5'TATE : ALASKA SAMPLE NO. : $-1 LAB' NO. : A,-49~9 DEPTH (FT) : 9053.0 ATU POROSITY GRAIN DENSITY STR E.~ POROSITY: 10004 SHELL DEVELOPMENT COMPA( PL'rRO~ICAL SERVICES SECTION STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 4500 PSI 1000- Ld 1 100 10 MERCURY SATURATION DATE : FEBRUARY 20, 1987 COMPANY- ,~Hrl t Wr,'r-D, -, - % BULK VOLUME OCCUPIED 0.1 DATE :February 20, 1987 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal. WELL NO:C31-26 API NO :50-733-20052 STATE :Kenai County, Alaska SPL NO.:5-1 LAB NO.:A-4969 DEPTH :9053.0 ft STRESS :4500 psi SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTION STRESS ANALYSIS DATA PORE VOL. :2.24 cc GRAIN VOL. -:16.445 cc BULK VOL. :18.685 cc POROSITY :12.0 % GRAIN DEN. :2.645 gm/cc WT. OF SPL :43.496 gm ATM POROSITY: 13.5 % AIR PERM. : 6.17 md @ STRESS 200 psi AIR PERM. :2.89 md . @ STRESS 4500 psi PS I A PUMP BLANK MERCURY READING INTRUSION VOL. CORR. % PV % BV VOL. OCCUPIED OCCUPIED 41 .237 .237 0.000 0.000 51 .352 .241 .111 .11I 4.96 .59 76 .713 .246 .467 .467 20.8 2.50 10! .913 .254 .659 .659 29.4 3.53 131 1.049 .257 .792 .792 35.4 4.24 161 1.153 .267 .886 .886 39.6 4.74 201 1.257 .273 '.984 .984 43.9 5.27 251 1.332 .277 1.055 1.055 47.1 5.65 301 1.405 .282 1.123 1.123 50.1 6.01 401 1.510 .298 1.212 1.212 54.1 6.49 601 1.657 .319 1.338 1.338 59.7 7.16 801 1.770 .340 1.430 1.430 63.8 7.65 1001 1.851 .367 1.484 1.484 66.3 7.94 1251 1.938 .388 1.550 1.550 69.2 8.30 1501 2. 020 .412 1. 608 1. 608 ?1.8 8. E1 1751 2.083 .437 1.646 1.646 73.5 8.81 2001 2.150 .458 1.692 1.692 75.5 9.06 With the initial injection pressures the volume of intrusion mercury will var This is due to mercury filling open spaces around the sample,(between sample frit,and or sample and viton rubber), which can't be taken into account with blank. As the injection pressure increases, the blank volume will increase wh the sample volume might remain constant, or increase with a smaller change in volume. W W 100. 000 · $ 4 · · S 4 8 · S 4 lO0 ! · S 4 · 10 S · · 100 SHELL DEVELOPMEci~ COMPRNY Ir'+ETROPHYSICRL SERVI $ LRBORRTORY MERCURY CRP!LLRRY PRESSURE DRTR 90 80 '70 80 SO 40 SC) 20 1 O 0 MERCURY SRTURRTION- PERCENT PORE VOLUME OCCUPIED DRTE COMPRNY LERSE WELL NO. FIELD STRTE DEPTH SRNPLE :FEBRUARY 1~ 2~B7 :SHELL WESTERN E&P ZNC. : :MIDDLE DROUND SHDAL : 0~53' El" NO.:5 HERSURED VRLUES ~ =1~.5 ~ ' " K8 m 12. I MD YRLUES EST. FROM CURYE Kw-est =. ~2 MD ~8-ost =2. O MD ~. D. ost = ' PA~E '1 · o. ooo · 7 · · COMPRNY MERCURY CRPILLRRY PRESSURE DRTR HERCURY SRTURRT!ON- PERCENT SRNPLE NO. :s DEPTH :Desk' e" · · · · · · · · BULK VOLUME OCCUPIED LERSE : I~ELL NO. :c~2 FIELD :MIDDLE GROUND SH AL PAGE 2 OF ~ UJ n.' n W lO · · S 4 · 1,0 O.O O,S O, 4 0, O2 0.01,0 O. Om · ' O. OOS 0.0O4 O. 008 O. 002. PORE S!ZE D!STRIBUTION + 100 90 80 70 80 SO 40 SO 20 10 PERCENT RELRTIVE PORE SIZE DISTRIBUTION SRMPL£"No. '=5 ' ' LE~SE = "' DEPTH :9e5~' e" VELL NO. DGTE :FEBRUARY 18. 1987 FIELD :MIDDLE GROUND ~HO^L e^~£"~ DATA PROCESSING--A~OPORE MERCURY CAPILLARY P~SURE COMPANY: 'SHELL WESTERN E&P INC. LEASE: FIELD : MIDDLE GROUND SHOAL STATE: ALASKA DEPTH : 9053' O" SAMPLE NO.: 5 PERCENT CUMULATIVE POINT # PRESSURE INTRUSION VOLUME INTRUSION VOLUME WELL NO.: INCREMENT INTRUSION VOLUME , ,, psia % cc's 1 O. 9 O. O O. 0000000 2 1.2 O. 3 O. 0054736 3 1 . 5 1 . 7 O. 0273680 4 - 1 . 9 2.3 O. 03831 52 5 2.5 3.2 O. O51 9992 6 3.1 3.5 0.0574728 7 4.0 3.7 O. 0602096 8 5.1 3.9 O. 0629464 9 6.5 4.0 0.0656832 10 9.3 4.4 0.0711568 11 10.5 4.5 O. 0738936 12 13.4 4.9 0.0793672 1 3 17.3 5.0 O. 0821 O40 14 22.0 5-9 0.0957880 1 5 24.4 6.4 O. 1 039980 1 6 25.O 6.5 '0. 1067350 17 27.3 7.0 0.1149460 18 29.8 7.7 0.1258930 19 32.9 9.0 O. 1477870 20 36.2 IO.4 O. 1696820 21 45.7 17.6 0.2873640 22 58.1 25.3 0.4132570 23 74.4 33- 5 O. 5473600 24 96.3 40.5 0.6623060 25 1 22.7 46.6 O. 7608300 26 155.2 51.8 O.8456710 27 1 98.5 56.6 O. 9250390 28 255.1 61 .0 O.9961 950 29 334- 1 65.2 1 · 0646200 30 420.0 68.3 1 · 1166100 31 539.1 71 · 5 1 · 1686100 32 684.6 74.4 1 · 21 51 400 33 876.9 77.2 1 · 26166OO 34 1136.7 80.2 1.31093OO 35 1439.4 82.9 I · 3547200 36 1 841.8 B5.6 1 . 3985000 37 2331 · 1 87.9 1.4368200 38 2972.9 90.3 1 · 4751 400 39 3802.3 92.3 1. 5079800 40 ~ 4875.2 94. t 1 · 5380800 41 6231.3 95.6 1. 56271OO 42 7959.9 96.8 1 · 581 8700 43 1 0090.9 97.7 1 · 5955500 44 1 2832.8 98.3 1 · 6065000 45 1 6722.3 99.2 1 · 6201 900 46 21 222.7 99.5 1 · 6256600 47 2691 5.3 99.8 1.63113OO 48 34753- 7 100.0 I . 6338700 4 9 44499.7 1 OO. O 1 · 6338700 50 56153.1 100.O 1. 6338700 o. 0000000 o.oo54736 o. o218944 O.O1O9472 O.O13684O O.OO54736 0.0027368 0.0027368 0.0027368 0.0054736 0.0027368 0.0054736 0.0027368 O. 01 36840 O. 00821 04 0.0027368 O. 00821 04 0.0109472 0.0218944 0.0218944 O. 11 76820 0.1258930 0.1341030 0.1149460 0.0985248 O. 0848408 0.0793672 0.0711568 0.0684201 0.O51 9991 O. 051 9992 0.0465256 0.0465256 0.0492624 O. 0437888 0.0437889 0.03831 52 O. O3831 52 0.032841 6 0.0301049 0.0246311 O.0191576 0.0136839 0.0109472 O. 01 36840 0.0054736 0.0054736 0.0027368 O. 0OO0000 O. 0000000 031 - COMPUTER PICKED .O656832 CC'S AS CLOSURE VOLUME. APPROX. POROSITY = 13.3 % APPROX. PORE VOLUME = 1.661 cc's ESTIMATED Kair = 2.9 md APPROX. BULK VOLUME = 12.004 cc's ESTIMATED Kbrine = .92 md GRAIN DENSITY = 2.646 gms/cc Iii. QO0 · · · · S 4 43: · LLI · CZ: · ::3 s U) 4 r'r ::::) 1120 (.3 12: LLI · r 4 SHELL DEVELOPMENt: COMPRNY TROPHYSICRL SERVIC LRBORRTORY MERCURY CRPILLRRY PRESSURE DRTR 10 · 4 · 100 90 MERCURY SRTURRTION- PERCENT 40 $13 2O 10 0 PORE VOLUME OCCUP:IED DRTE COMPRNY LERSE WELL NO. FIELD STRTE :FEBRUARY 18. :SHELL WESTERN : :C~1-2~ :NIDDLE GROUND :ALASKA 1987 E&P INC. SHOAL DEPTH SRMPLE :941e' NO.:s MERSURED VRLUES ~ -,8.49 I(:a G- D.~ 2. 84,4. C~MS/~C VRLUES EST. FROM Kw-est -7.7 MD ~8-est = 3~ MD G. D. est = III CURVE I0, 000 m, 000 tO, 000 ~ooo looo SOOO 14)0 8O 8O I0 8O SO 10 · 'I · · MERCURY CRPXLLRRY PRESSURE DRTR MERCURY_ SflTURRTION-PERCENT BULK VOLUME OCCUPIED SRNPLE NO. :8 DEPTH :G41B' B" DRTE =FEBRUARY LERSE i 1 WELL NO. cal-2e FIELD MZDDI..E GROUND SH A~ W I-- W s-- CZ: I-- -'r I0 · · · 4 · 1.0 0.8 O,S O, 4 O.I SHELL ?ZZLELOPHENT_ C PORE SIZE DISTRIBUTION W 0 I-. Z W ..J C~ 0 W O. tO 0.08 0.08 O. OS O. O4 0.02 O. OlO 0.008 O,O~S 0.0O4 0.002 0,001 tO0 90 80 '/0 80 .SO 40 SO 20 10 PERCENT RELRTIVE PORE SIZE DISTRIBUTION SRMPLE NO. : DEPTH : 04 DRTE : FEBRUARY 1 OB? LERSE : I~ELL NO. : c31-2s FIELD : MZDDLE GROUND SHOAL PETR.0?HYSICAL SERVICES SECTION FEBRUARY 16, 1987 DATA PROCESSING· . -- AU~PORE. MERCURY CAPILLARY PRK.~ellYI:tE COMPANY: SHELL WESTERN E&P INC. LEASE: FIELD : MIDDLE GROUND SHOAL STATE: ALASKA DEPTH : 9410' 0" SAMPLE NO.: 6 PERCENT CUMULATIVE POINT # PRESSURE WELL NO.: INCREMENT INTRUSION VOLUME INTRUSION VOLUME psla % cc' s 1 O. 9 O. O O. OOOO000 2 1 . 2 O. 6 O. 00401 28 3 1 . 5 1 · 1 O. 0080256 4 -1.9 1.7 O.O120384 5 2.5 2.2 0.O160512 6 3.1 2.8 O. 0200640 7 4.0 3.7 O. 0260832 8 5.1 6.5 O.046! 472 9 6.5 9.0 O. 0642048 10 9.3 16.3 0.1163710 1 1 10.5 18.5 0.1324220 12 13.4 24.7 0.1765630 1 3 1 7.3 30.9 O. 2207040 14 22.0 35.7 0.2548130 1 5 24.4 37.6 0.2688580 1 6 25.6 38.2 0.2728700 1 7 28.1 39.6 O. 2829020 18 31.2 41 -3 0.2949410 1 9 34.5 42.7 O. 3049730 20 44.1 46.9 O. 3350690 21 56.6 50.6 0.361!520 22 72.9 53.9 O. 3852290 23 94.9 57.0 0.4072990 24 121.3 59.8 0.4273630 25 153.9 62.4 0.4454210 26 1 97.2 64.9 O. 4634780 27 253.9 67.1 0.4795300 28 332.9 69.7 0.4975870 29 418.8 71.6 0.5116320 30 537.9 73.9 O. 5276830 31 083.4 75.8 O. 5417280 32 875.8 77.8 O. 5557730 33 1135.6 79.8 O.5698180 34 1438.3 81 . 5 O. 5818560 35 1840.7 83.4 0.5959010 36 2330. O 85.1 O. 6079390 37 2971.8 87.1 0.6219840 38 3801.2 88.8 0.6340220 39 " 4874.1 90.7 O. 6480670 40 6230.2 92.4 O. 6601060 41 7958.8 94.1 0.6721440 42 10089.7 95.5 O. 6s21760 43 12831 . 7 96.6 O. 6902020 44 16721 . 1 9'[. 8 O. 6982270 45 21 221 · 5 98,6 O. 7042470 46 2691 4.1 98,9 O, ?062530 4? 34?52,5 99-4 0,?102660 48 444 98.5 99 -4 O. 71 02660 49 561 51 · 9. 99 -4 '0,71 02660 50 36883.5 99.4 O. 7t 02660 c31 -; INTRUSION VOLUME O. 0000000 0,0040128 O,OO4O128 0,0040128 0,0040128 0,0040128 O, 00601 92 0,0200640 O. O! 80576 O.O52!664 0.0160512 0.0441408 0.0441408 0.0341088 O. 0140448 O. 00401 28 O. 0100320 O. 0120384 0.0100320 0.0300960 0.0260832 0.0240768 0.0220704 0.0200640 O.O1 80576 0.0180576 0.0160512 O. O1 80576 0.O140449 O. O1 6051 2 0.0140448 O.O! 40448 0.0140448 O. O1 20384 0.0140448 O. O1 20384 0.0140448 O. O1 20384 0.0140448 O. O1 20384 O. O1 20$84 0.0100320 O. 00802 56 O. 0080256 O. 00601 92 0.0020064 O. 0040i 28 O. 0000000 O. 0000000 O. 0000000 COMPUTER PICKED .0120384 CC'S AS CLOSURE VOLUME. APPROX. POROSITY = 8.6 % APPROX. PORE VOLUME = 0.730 cc'e ESTIMATED Kair = 16 md APPROX. BULK VOLUME = 8.318 oc'e ESTIMATED Kbrine = 7.7 md GRAIN DENSITY = 2.644 gms/cc I00. 000 l l S 4 tO, 000 I · · 4 LJJ · CZ: · ::> · C~ 4 · ::::) ,too C.) · fr' · ILl · r' · lO · · S 4 · 100 ~0 ~IERCURY SHELL DEVELOPHENT. COHPRNY 'TROPHYSICRL SERV!C(~; LRBORRTORY NERCURY CRPILLRRY PRESSURE DRTR 80 70 ~0 ~0 40 30 20 1'0 0 SRTURRTION-PERCENT PORE VOLUHE OCCUPIED DRTE CONPRNY LERSE ~ELL NO. FIELD STRTE :SHELL WESTERN E&P ZNC. :CS1-28 :MTDDLE GROUND SHOAL :ALASKA DEPTH SRNPLE , ,, :g4~g' ~" NO.:t;white chert pebble HERSURED VRLUES I~ -:tS.t * ' I(a - G. D." 2. 854 GMS/CC VRLUES EST. FROH CURYE ~ -14.7 X Kw-est -.8s~ MD Ka-est =, ~ MD G, D, est= ' ' PAGE -i OF a ~O, OOO · O. OOO aCCO ~O 1o · · ./ · · MERCURY ClIP!LLRRY PRESSURE DRTR O0 ate MERCURY SRTURRTION-PERCENT BULK VOLUME OCCUPIED JSRMPLE NO..' DEPTH DFtTE ~/ELL NO.: ieee FIELD E LU I,,,U I,,,U 0 I0 · · 4 · i.O O.S 0.4 O. lO 0.00 0.01 O. OS O. O4 O. OB O. OO4 -O, OOt .o.£ s zz£ ozs .z.u zo. 100 ~ O0 ?0 eO SO 40 PERCENT RELRT]VE PORE SIZE SRHpLE"'NO. :t .... LERSE DEPTH :e4ee' e" VELL NO. DRTE :DEC£MBER ~e, teee FIELD SO 2O 10 D]STRIElUTIC)N _ J MZDDLE OROUND SHOAL ,, DATA PROCESSING -- AUTOPORE MERCURY CAPILLARY PRESSURE . ~ FIELD :'MIDDLE GROUND SHOAL STATE: ALAS DEPTH : 9409' O" SAMPLE N0.: 1 PERCENT CUMULATIVE POINT # PRESSURE INTRUSION VOLUME INTRUSION VOLUME ....... psia % cc's 1 I, O' 9 0 ~10 omm"(m~"O000000 2 I · 2 O. 2 O. 000771 9 3 1.5 O. 3 O.OO1 5438 4 1.9 O.5 0.O023157 5 2.4 O. 5 O. 00231 57 6 - 3.1 O. 7 O. O030876 7 4.0 O. 7 0.0030876 8 5.1 O. 8 O. 0038595 9 6.4 O. 8 O. 0038595 10 9-2 ! · 1 O.OO54033 1 1 10. 5 1 · 1 O. 0054033 12 13.4 1.3 0.0061752 1 3 1 7.2 1 · 5 0.0069471 1 4 21 · 9 1 · 6 O. 00771 90 1 5 24.5 1 · 8 O. 0084909 1 6 25.5 1.8 O. 0084909 1 7 27. O 1 · 8 O. 0084909 1 8 30.2 1 · 8 O. 0084909 1 9 33- 3 1 · 8 O. 0084909 20 36.5 1 · 8 O. 0084909 21 46.7 1 · 8 O. 0084909 22 59.8 2.0 0.0092628 23 77.5 2.0 O. 0092628 24 96.5 2.1 O. 0! 00347 25 125.6 2.5 0.0115785 26 160.0 2.6 0.0123504 27 199.1 2.8 0.0131223 28 258.4 3.1 0.0146661 29 326.8 3.8 0.0177537 30 41 9.6 4.4 O. 02084 ! 3 31 543.6 5.6 0.0262446 32 683.3 6.7 0.0316479 33 875.7 8.7 0.0409107 34 1111.0 12.4 O.O586644 35 1435.2 19.3 0.0910842 36 !8t2.1 28.6 O. 1350830 37 23~,8.7 43-3 0.2045540 38 2963.5 56.4 0.2663060 39 3788.4 67.2 0.3172510 40 4831 · 3 75.8 O. 3581 620 41 621 7.1 81 · O O. 3828620 42 7901 .O 84.8 O.400'61 60 43 10076.6 88.2 O. 41 68260 44 1281 8.5 91 · 3 O.431 4920 45 16648.3 94.3 O. 4453860 46 21118.9 96.7 0.4569650 47 26811.5 98.4 0.4646840 48 34247.6 99-3 0.46931 50 49 43904.1 1OO.O 0.4724030 50 56064.2 100. O O. 4724030 WELL NO.: INCREMENT INTRUSION VOLUME O0'S o.oooo00o 0.0007719 0.0007719 O.O007719 O.0000000 O.00077!9 0.0000000 0.0007719 O.0000000 0.0015438 O.00000OO 0.0007719 0.00077!9 0.0007719 O.00077~9 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 O.0000000 0.0007719 0.0000000 0.0007719 0.0015438 0.0007719 0.0007719 0.0015438 0.0030876 0.0030876 . 0.0054033 0.0054033 0.0092628 0.0~77537 0.0324198 0.0439983 0.O694710 0.0617520 0.0509454 O.O409!O7 0.0247008 0.0177537 0.0162099 0.0146661 O. 0138942 O.0115785 O.0077190 0.0046314' 0.O030876 0.OOOOOOO ¢31 -, COMPUTER PICKED .OO69471 CC'S AS CLOSURE VOLUME. APPROX. POROSITY = 14.7 % APPROX. PORE VOLUME = O.511 cc's ESTIMATED Kair = .O1 md ~ APPROX. BULK VOLUME = 3.419 cc's ESTIMATED Kbrine = .OO1 md GRAIN DENSITY = 2.654 gms/cc June 30, 1987 Shell Westem E&P Inc. Q 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 NUMBER C 31-26 Gentlemen' Enclosed, in duplicate, is the Report of Sundry Well Operations for the stimulation performed on Middle Ground Shoal well number C 31-26. If you have any questions, please contact Susan Brown at (907) 263-9613. v~e~ truly yours, ~ -/O'~''. Alas~(~' Division I Manager Regulatory Affairs SBB/kka Enclosures RECEIVED JUL- 6 i987 Alaska Oil & Gas Cons. CornmJssio,,~ Anchorage SBBE/aogcc.5b A(" STATE OF ALASKA ~i. AL ..-~ OIL AND GAS CONSERVATION CO ~,!SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulat~ [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P ;[nc. 116' DF Feet 3. Address 6. Unit or Property name 60! West Fifth Ave., Suite 810, Anchorage, AK 9950! Middle Ground Shoal VVe , 4. Location of well at surfac~Platform "C", Leg 1, Conductor 5. Cond. @ 474'S & 340'E from center of Leg 1. SE corner of Sec 23, At top of productive interval T8N, R 13 W, S.M. @ 8742'. 931'S & 1585'W from NE corner of Sec. 26, TSN, At effective depth R13W, S.M. At total depth @ 9935'. [062'S & !767'W from NE corner Sec.26,TSN,R[3W,SH. 8. Approval number 6-186 9. APl number 50-- 733-20052-00 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate ~ ].895' Production 1228' Liner Perforation depth: 9,935' feet Plugs (measured) 9,708' feet 9,849 feet feet 9,623' Size 10-3/4" 40 5# 7" 23-29# measured 9,700'-8,742' true vertical 9,475' -8,538' Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9465' Packers and SSSV (type and measured depth) Junk (measured) Cemented Measured depth J-55 1600sx 1895' N-80 1350sx 9927' True Vertical depth RECEIVED JUL- 6 ]987 Alaska 0il & Gas Cons. Commission , Anchorage 12. Stimulation or cement squeeze summary Stimulation. Intervals treated (measured) 8760'-9465' Treatment description including volumes used and final pressure 1000 gal 15% HCl 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 72 33 133 530 Prior to well operation Subsequent to operation 115 0 188 470 @ 450 Psig 70 90 Tubing Pressure 14. Attachments v Daily Report of Well Operations~ [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge SBBE/asa.5b Production Superintendent Title Date ~/~ ~,A? Submit in Duplicate DAILY JOB SUMMARY Date' Wel 1 No.' Operation' 25 June 1986 C 31-26 Stimulation 0700 0730 1400 1415 1530 1800 Held Safety meeting with crews. Rig up Dowell and Arctic coiled tubing. Pressure test to 4500 psig. Run in hole pumping .19 BPM filtered sea water @ 180 psig pump discharge, 60 psig tubing pressure. Pumped 1000 gal 15% HCl @ 1/4 BPM @ 450 psig max. Shut in well when acid hit nozzle. Hit top of scale @ 8760', hard bridge @ 9100' to 9107'. Ran to end of tubing @ 9465'. Pulled out to 8760' pumping remainder of acid while displacing coil with sea water. Pulled out of hole and rigged down. RECEIVED JUL- 6 1987 Alaska Oil & Gas Cons. Commission Anchorage SBBE/asa.5b " STATE OF ALASKA ALA,SKA(, L AND GAS CONSERVATION COMM~ ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown I-1 Stimulate I~. Plugging [] Alter Casing [] Other [] 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 4. Location of well at surface Platform "C", Leg 1, Conductor 5. Cond @ 474'S & 340'E from center of Leg 1. SE corner of Sec 23 At top of productive interval T8N, R 13 W, $.M. @ 8742'. 931'S & 1585'W from NE corner of Sec. 26, T8N, At effective depth R13W, S.M. total depth A@ 9935'. 1062'S & 1767'W from NE corner Sec.26,TSN,R13W,SM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 1895' Production 1228' Liner Perforation depth: measured 9,935' feet Plugs (measured) 9,708' feet 9,849 feet feet 9,623' Size Junk (measured) Cemented 10-3/4" , 40.5#, 7" 23-29# J-55 N-80 Perforate [] Pull tubing [] 9,610'-8,742' 5. Datum elevation (DF or KB) 116' DF Feet 6. Unit or Property name Middle Ground Shoal 7. Well nu~b~'_26 8. Approval number 7-215 9. APl number 50-- 733-20052-00 10. Pool "G" Pool · Measured depth 1600sx 1350sx True Vertical depth 1895' 9927' true vertical 9,388' -8,538 ' Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 EUE @ 9,465' Packers and SSSV 1~1~ and measured depth) Packer @ ', 9095', 9219', 9298', 9456' RE'CEIVED 6 1987 Ala~ 011 & Gas Cons. C0mml~lon Anchorage 12. Stimulation or cement squeeze summary y, drob la .t . , Intervalstreate~(measure~) scale 8700-9400' Stimulate w/1000 gal 10% HCl 15bbl filtered 9471-9645.' seawater,' and 30 bb! diese]. Treatment descriptibh ' '"' "': ' ' ~ncl'ud~ng volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 93 46 151 490 70 101 70 151 455 70 14. Attachments Daily RePort of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 SBBE/asa.5 Title Production Superintendent , , Date Submit in Duplicate DAILY REPORT OF OPERATIONS Well · C 31-26 Date' 04/05/87 Operation- CTU Acid Stimulation Foreman- T.L. Pritchard 1400-200 Rig up ACT and Halliburton SBBE/asa.5a DAILY REPORT OF OPERATIONS Well: Date: Operation: Foreman: 0600-0615 0700-1030 0900-1030 1030-1145 1145 C 31-26 04/06/87 CTU Acid Stimulation T. L. Pritchard Pressure test to 5000 psig R. I. H. Hydroblast scale zone from 8700' to 9400' using Otis indexing wash tool pumping filtered seawater @ I BPM at 2900 psig. Appeared to clean scale. Pumped 1000 gal 10% HC1, 15 bbl filtered seawater, and 30 bbl diesel across perforations from 9471'-9645'. Diesel to help well back on gas lift and displace coiled tubing. Pull out of hole and rig down. RE.CEIVEI) APR 1 6 1 87 Alaska Oil & Gas Cons. Commission SBBE/asa.5a March 30, 1987 Shell Westem E&P Inc. Q 601 West Fifth Avenue · Suite 810 AnchoraGe, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT' Gentlemen- SUBMITTAL OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NUMBER C 31-26 Enclosed, in triplicate, is an Application for Sundry ApproN~,ml for an upcoming stimulation of Middle Ground Shoal well number C 3~[L26. · The work is scheduled to begin around April 5, 1987. If you have any questions regarding this application, contact Susan Brown at (907) 263-9613. Ve~ truly yours, ~ Aias~ivision / Manage'~ Regulatory Affai rs SBB/kka Enclosures SBBE/aogcc.5 Sill STATE OF ALAS KA li'r,.qSlO N ALA , OIL AND GAS CONSERVATION COM APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other E] 2. Name o.f Operator Shell Western E&P Inc. 3'6A~r~S~st Fifth Ave., Suite 810, Anchorage, AK 99501 4. Location of well at surfacePlatform "C" Leg I Conductor 5 Cond , , ·· @ 474'S & 340'E from center of Leg 1. SE corner of Sec 23, At top of productive interval T8N, R 13 W, S.M. @ 8742'. 931'S & 1585'W from NE corner of Sec. 26, TSN, At effective depth R13W, S.M. [~t~t~¢.ePtlho62'S & 1767'W from NE corner Sec.26,T8N,R13W,SM. 11. Present well condition summary Total depth: measured true vertical 9,935' feet Plugs (measured) 9,708' feet 5. Datum elevation (DF or KB) 116' DF feet 6. Unit o.r .Prpp, erty,,name, mi (]a~ e ~rouna Shoal 7. Well number C 31-26 8. Permit number 67-63 9. APl number 50-- 733-20052-00 lO. Pool "G" Pool Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate 1895' Production 1228' Liner Perforation depth: measured Length 9,849 feet Junk (measured) 9,623' feet Size Cemented Measured depth 10-3/4" 40.5# J 55 1600sx 1895' 7" 23-29# N-80 1350sx 9927' 9,610'-8,742' true vertical 9,388' -8,538' Tubing (size, grade and measured depth) 3-1/2!', 9.3#, N-80 EUE @ 9,465' Pack s nd S S ~ ~r~c~er ~ ~.~t~§ and meatsu , , , 9095 , r~l(:;Iz~l~l~t,h) 9298 , 9456 True Vertical depth RECEIVED APR O 1 1987 Anchorage 12.Attachments Description summary of proposal X; Detailed operations programX[] BOP sketch [] 13. Estimated date for commencing operation April 5, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-~~ ~~ Title Pr°ducti°n Superintendent Commission Use Only Date 3/27/87 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel 7 '"' ~,:~'~ ~ '~ ' ~ ' on,om No D~ ~, by order'of ' ~ ~. ~:i;~ Commissioner the commission Date Form 10-403 Rev 12-1-85 SBBE/asa.4 Submit in triplicate PROGNOS I S C31-26 OPERATION: CLEAN OUT TUBING WITH CTUAT WELL DATA: 7" 23/26/29 # N-80 BUTTRESS @ 9927'. TUBING: 3 ½" 9.3# N-80 EUE 8rd. FOR ADDITIONAL INFORMATION SEE ATTACHED DETAIL SHEET. STATUS: Producing 86 BO + 141 BWPD 3/25/87 PERFORATED INTERVAL: GR/GS 8743/8780 HC/HD 9037/9069 HE/HF 9144/9194 HI/HK 9258/9297 HK/HN 9311/9448 HN/HR 9471/9610 HR/HZ 9640/9700 RECOMMENDED PROCEDURE: le RU WIRELINE AND LUBRICATOR. TEST LUBRICATOR TO 3000 PSI. PULL BALL VALVE. RD WIRELINE. e RU CTU AND ACIDIZING EQUIPMENT. TEST ALL LINES AND EQUIPMENT TO 5000 PSI. TEST SAMPLE OF ACID FROM TOP AND BOTTOM OF TANK USING THE TITRATION AND HYDROMETER METHOD (SERVICE COMPANY TO PROVIDE TEST EQUIPMENT). IF MORE THAN A 1% DIFFERENCE EXISTS BETWEEN SAMPLES, ROLL THE TANK AND RETEST. 3~ WITH WELL LIFTING, RIH WITH CTU CIRCULATING WITH INJECTION WATER AT ¼ BPM. DO NOT ALLOW WELL TO STOP FLOWING. IF WELL DOES STOP FLOWING, STOP CIRCULATING AND ALLOW WELL TO UNLOAD. me RECOMMENDED: APPROVED: AT 9465', START PUMPING 1000 GAL OF 10% HCl CONTAINING EMULSION BREAKER AND INHIBITOR. IF DEBRIS (SCALE) IS ENCOUNTERED ABOVE 9465', WASH WITH ACID AND CONTINUE RIH. BEGIN ACID WASH BY MOVING COILED TUBING BETWEEN 9400' AND PBTD WHILE PUMPING ACID AT ~ BPM. WHEN ALL ACID IS DISPLACED WITH INJECTION WATER, POH. DATE- DATE- ~/~o/,~'~ R .CFIV£D JHFA/afe2.1 APR 0 1 1982 DEPTHS C 31-26 Revised Tubing Detail 11 14 17 2O I tern 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Description (MD) Otis Safety Ball Valve N. Camco KBUG Mandrel - BK 900# 3/16" Camco KBUG Mandrel - BK 905# 3/16" Camco KBUG Mandrel - BK 910# 3/1 6" Camco KBUG Mandrel - BK 91 5# 3/1 6" Camco KBUG Mandrel - BK 965# 1/4" Camco KBUG Mandrel - BK 965# 1/4" Camco KBUG Mandrel - 3/8" Orifice Valve Baker Seal Bore Assy. Otis "XO" Sliding Sleeve (Closed) Gui berson Packer RH-1 Camco KBM Mandrel Otis "XO" Sliding Sleeve (Closed) Guiberson Packer RH-1 Camco KBM Mandrel Otis "XO". Sliding Sleeve (Closed) Gui berson Packer RH-1 Camco KBM Mandrel Otis X-O Sliding Sleeve Gui berson Packer RH-1 Camco KBM Mandrel Otis X-O Sliding Sleeve Gui berson Packer RH-1 Otis X Nipple Otis Q Nipple 327 1871 3510 4962 6092 7257 7991' 8642' 8666' 8705' 8713' 9080' 9086' 9095' 9195' 9201 9219 9283 9288 9298 9441 9446 9456 9464 9465 Tubi n~) Detail 3 1/2", 9.3#, N-80 EUE C~sing Detail Perfs 7", N-80, Buttress 23# O/5OOO 26# 5600/8100 29# 8100/9927 GR-GS 8742-8780 HC-HD 9037 -9069 HE-HF 9144-9194 HI-HK 9258-9297 HK-HN 9311-9448 HN-HR 9471 -9610 HR-HZ 9640-9700 Note: 3 strings of wireline tools in rat hole 23 June 17, 1986 Shell Western 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: APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING WORKOVER ON MIDDLE GROUND SHOAL, WELL NO. C 31-26. Gentlemen: Enclosed for your review is the Application for Sundry Approval for the Middle Ground Shoal Well No. C 31-26. The workover, a tubing clean out, is scheduled to begin June 19, 1986. The Sundry notice is submitted in triplicate. If you have any questions concerning this matter, contact Susan Brown at (907) 263-9613. Very truly yours, I-%~' L. Yesland Sr. Staff Environmental Engineer Alaska Division DLY/pap RECEIVED JUN 1 7 1986 K~ STATE Of ALASKA ALAS OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate © Other E3 2. Name of Operator Shell Western E & P Inc. 3. Address 601 West Fifth Ave., Suite 810; Anchoraqe, AK 99501 4. Location of well at surface Platform C, Leg 1, Conductor 5. Conduc, tor @ 4.74' S & 3 40' E from center of Leg 1. SE corne ^t togfo & vJ a i3u, @ 8742' 931'S & 1585'W from NE corner of Sec. 26, TSN 1 W At ef~J[C~lV~. At totaldepth @ 9935' 1062'S & 1767' from NE corner of Sec. 26, T8N, R13W, S.M. 11. Present well condition summary Total depth: measured 9935' true vertical 9708' feet Plugs (measured) feet 5. Datum elevation (DF or KB) 116' DF 6. Unit or Property name Hidd le Ground Shoal 7. Well number C 31-26 8. Permit number 67-63 9. APl number 50-- 733-20052-00 10. Pool "G" Pool feet Effective depth: measured 9849' true vertical 9623' feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate 1895' Production 9927' Liner Perforation depth: measured 9610' -8742' true vertical 9388' -8538' Size Cemented 10-3/4", 40.5#, J-55 7" 23-29# N-80 Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 EUE at 9465' Peckers and SSSV (type and measured depth) packer @ 8713' 9095', 9219', 9298', & 9456' 1600 sx 1350 sx Measured depth True Vertical depth 1895' 9927' RECEIVED JUN 1 7 1986 Alask~ 011 & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation June 19,1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the fore.~oing is true and correct to the best of my knowledge Signed ~ ~.~/~¢¢¢.~=~// Title production Superintendent Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI : ~:: by order of ~,,~:~:~: ,~ .... :,:,~'[~ Commissioner the commission Date /~ -'orm 10-403 Rev 12-1-85 Submit in triplicate PR OGNOS I S C31-26 OPERATION' STATUS: CLEAN OUT TUBING WITH CTUATo AND BATCH SCALE TREAT. DRIFT RUN ENCOUNTERED HEAVY SCALE (CaCO3) WELL DATA: 7" 23/26/29 ~ N-O0 BUTTRESS ~ 9927'. TUBING: 3 ~" 9.3# N-80 EUE 8rd. FOR ADDITIONAL INFORMATION SEE ATTACHED DETAIL SHEET. PERFORATED INTERVAL' GR/GS 8743/8780 HC/HD 9037/9069 HE/HF 9144/9194 HI/HK 9258/9297 HK/HN 9311/9448 HN/HR 9471/9610 HR/HZ 9640/9700 RECEIVED JUN 1 7 1986 Alaska Oil & Gas Cons. Commission Anchorage RECOMMENDED PROCEDURE' . RU WIRELINE AND LUBRICATOR. TEST LUBRICATOR TO 3000 PSI. PULL BALL VALVE. RD WIRELINE. . RU CTU AND ACIDIZING EQUIPMENT. TEST ALL LINES AND EQUIPMENT TO 5000 PSI. TEST SAMPLE OF ACID FROM TOP AND BOTTOM OF TANK USING THE TITRATION AND HYDROMETER METHOD (SERVICE COMPANY TO PROVIDE TEST EQUIPMENT). IF MORE THAN A 1% DIFFERENCE EXISTS BETWEEN SAMPLES, ROLL THE TANK AND RETEST. 3. WITH WELL LIFTING, RIH WITH CTU CIRCULATING WITH INJECTION WATER AT ¼ BPM. DO NOT ALLOW WELL TO STOP FLOWING. IF WELL DOES STOP FLOWING, STOP CIRCULATING AND ALLOW WELL TO UNLOAD. . AT 8730', START PUMPING 24 BBL OF 15% HC1 CONTAINING 0.3% W-35, 14#/1000 GAL L-41, 1.2% A-200 AND 1% U-66. WHEN ACID IS DISPLACED TO WASH NOZZLE,, ~.~-~.!7.~ BEGIN ACID WASH BY MOVING COILED TUBING BETWEEN 8730' AND 9465' WHILE PUMPING ACID AT ~1 BPM. WHEN ALL ACID IS DISPLACED WITH INJECTION WATER, PLACE WELL ON PRODUCTION. TOH. RECOMMENDED' JHFA/afeJ.1 DATE- DATE: January 17, 1986 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 99501 Gentlemen: SUBJECT: SUNDRY NOTICE FOR MGS WELL NO. C 31-26 Please find the enclosed Sundry Notice for Middle Ground Shoal for the work to be performed on Well Number C 31-26. The CTU acidization is scheduled to begin on January 18, 1986. Please note that Susan Brown of our office received verbal approval from Blair Wondzell (AOGCC) on January 17, 1986. The report is submitted in triplicate If there are further questions, please contact me at (907) 263-9617. Sr. S~j(ff EnvirOnmental Alaska' Division Engineer SBB/kka Enclosure SBBC/aogcc. ld STATE OF ALASKA ( ALASKA'OIL AND GAS CONSERVATIONC0' MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. She1! Western E&P Inc. 67-63 3. Address 8. APl Number 601 West Fifth, Suite 810, Anchorage, Alaska 99501 5o-733-20052-00 OTHER [] 4. Location of Well At surface' Conductor 5, Leg 1. 4.74'$ & 1596'W of SE corner of Sec. 23, TSN, R13W, $.M. 5. Elevation in feet (indicate KB, DF, etc.) 116' KB 6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name Middle GroundShoa! 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoa! "G" Poo! 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~l Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made F'] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. NOTE' Blair Wondze11 gave Susan Brown verba! approval for this on January 17, 1986. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign~~, =~ .~-~----~--~-,~---~---- Title Production Superintendent The space below for Commission use Date Conditions of Approval, if any: Approved by 'Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROGN OS I S C31-26 OPERATION: CtEAN OUT TUBING WITH CTUAi STATUS: DRIFT RUN ENCOUNTERED HEAVY SCALE (CaCO3) FROM 9026' -9080'. WELL DATA: 7" 23/26/29 ~ N-80 BUTTRESS ~ 9927'. TUBING: 3 i)" 9.3# N-80 EUE 8rd. FOR ADDITIONAL INFORMATION SEE ATTACHED DETAIL SHEET. PERFORATED INTERVAL: GR/GS 8743/8780 HC/HD 9037/906 9 HE/HF 9144/9194 HI/HK 9258/9297 HK/HN 9311/9448 HN/HR 9471/9610 HR/HZ 9640/9700 RECOMMENDED PROCEDURE: 1, RU WIRELINE AND LUBRICATOR. TEST LUBRICATOR TO 3000 PSI. PULL BALL VALVE. RD WIRELINE. . RU CTU AND ACIDIZING EQUIPMENT. TEST ALL LINES AND EQUIPMENT TO 5000 PSI. TEST SAMPLE OF ACID FROM TOP AND BOTTOM OF TANK USING THE TITRATION AND HYDROMETER METHOD (SERVICE COMPANY TO PROVIDE TEST EQUIPMENT). IF MORE THAN A 1% DIFFERENCE EXISTS BETWEEN SAMPLES, ROLL THE TANK AND RETEST. ® WITH WELL LIFTING, RIH WITH CTU CIRCULATING WITH INJECTION WATER AT ~ BPM. DO NOT ALLOW WELL TO STOP FLOWING. IF WELL DOES STOP FLOWING, STOP CIRCULATING AND ALLOW WELL TO UNLOAD. 4, AT 8730', START PUMPING 24 BBL OF 15% HC1 CONTAINING 0.3% W-35, 14#/1000 GAL L-41, 1.2% A-200 AND 1% U-66. WHEN ACID IS DISPLACED TO WASH NOZZLE, SHUT IN FLOW LINE. BEGIN ACID WASH BY MOVING COILED TUBING BETWEEN 8730' AND 9465' WHILE PUMPING ACID AT ¼ BPM. WHEN ALL ACID IS DISPLACED WITH INJECTION WATER, OPEN FLOWLINE AND PLACE WELL ON PRODUCTION. TOH. DATE: DATE: ~i \~)/~~ ~'~b R E COMM E N D ED: APPROV~-~ i.... RECEIVED 2 0 1988 JHFA/afe2.1 August31, 1985 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' JULY MONTHLY REPORT OF DRILLING AND WORKOVERS Gentlemen' Please find the enclosed monthly report of Drilling and Workover Operations for our Middle Ground Shoal wells. The wells that were worked on during the month of July are' A22-14, C31-26. Each report is submitted in duplicate. DLY/kka Very truly yours, f6r' D. L. Yesland Sr. Staff Environmental Engineer Pacific Frontier Division Enclosures RECEIVED SEP 1 6 1985 Alaska Oil & Gas Cons. Commission Anchorage : SBBB/aogcc8.2 · Monthly Report and Workover Dc' G. J. Anderson D. L. Yesland J. H. Douglas Production Fi les SEC Files Reading File - H Reading File - A RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage SBBB/aogcc8.2 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation ~] 2. Name of operator 7. Permit No. She1! Western E & P Inc. 67-63 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 5o- 733-20052-00 Location of Well at surface Conductor 5, Leg 1, 4.74'S & 3.46'E of Center Leg 1. 542'N & 1596'W of SE Corner of Sec. 23, Twsp 8N, Rge 13W. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 1~5, D;F; ADL !8756 9. Unit or Lease Name Midd !e Ground Shoa! 10. Well No. C 31-26 11. Field and Pool Midd !e Ground Shoa ! "G" Pool Forthe Month of Ju]v ,19 P,~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks There was no change in the depth of the well. 13. Casing or liner ru.n and quantities of cement, results of pressur9 tests None. 14. Coring resume and brief description None. 15. Logs run and depth where run None. 1 6. DST data, perforating data, shows of H2S, miscellaneous data An acid job was performed on July 10 -14, 1985. RECEJVED S EP ~ 6 Alaska Oil & Gas Cons. CommissJon Anch0rag~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. s,~~~roduction Superintendent~ATE S~ptember 5, 1985. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 WORKSHEET FOR MIDDLE GROUND SHOAL C31-2& ACID JOB JULY lB-14, 1905 July 10, 1985 1. Pulled ball valve. 2. Ran in Hole with 2.25 star bit to 902DJ and tagged Cut scale to 9089J and pooh to wait on acid. July 11, 1985 July Rigged up arctic coiled tubing. 12, 1905 scale. July S. Rigged up Dowel I and pressure tested to SOOO psi. 6. Ran in Hole to 8?OO~ and pumped filtered seawater @ 1/4 per min. ?. Pumped IOOD gal Ions of 15% HCI fluid from 8?DD NOTE: Would not pass 91BO~. Acid contained 14#/1DOOgal L-&I, 1.25 A200, & 1% 8. Pumped ,iltered seawater to displace l?bbls. coiled tubing. POOH and rig down. Returned production. 9. Flowed welt to clean up. 14, 10. 11. bbl of acid out of well to Rigged up Oowell and arctic pressure test to SDOD psi. Ran in Hole to 90~7~ and pumped 40 bb~s. of filtered seawmter mixed with 2 drums of 4987 Nalco Scale InHibitor. Oisptaced coil with 17 bbls. of filtered seawater. Pooh and return well to production. RECEIVED $ EP i 6 I!lSg Alaska Oil & Gas Cons.-Commission Anchorag~ Shell Westem E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 July 24, 1985 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Mr. Chat Chatterton 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUBJECT: SUBSEQUENT REPORT ON MGS C31-26 Enclosed is the Subsequent Report for the work recently done on MGS Platform "C", well no. C31-26. If there are further questions, please contact Susan Brown of our staff at (907) 263-9613. SBB/kka Paci ~ruly yours, /~ ~ff Environmental Engineer c Frontier Division Enclosure cc: Greg Molesworth Chevron, U.S.A. P. O. Box 7-839 Anchorage, Alaska 99510 SBBB/aogccl.3 (' 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 Western E & P Inc. 67-63 3. Address 8. APl Number 601 West Fifth AVenue, Suite 819; Anchorage, AK 99501 50- 733-20052-00 4. Location of Well At Surface: Conductor 5, Leg 1, 4.74'5 & 3.46'E of Center Leg 1. 542' N & 1596' W of SE Corner of Sec. 23, Twsp 8N, Rge 13W. 5. Elevation in feet (indicate KB, DF, etc.) 105 D~F~ 12. 6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see attached worksheet for the details of the acid job that removed scales. jUL30~ Alaska 0il & Gas Cons. C0mm'~ss%0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed%r]~~~/~.7~[-~/~j ~.,~/~ le sr Staff Environment. The space'bel°;f;r C°mmissi°~Seconditions of Approval, if ~ ' any: By Order of Approved by COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WORKSHEET FOR MIDDLE GROUND SHOAL C31-26 ACID JOB JULY 10-14, 1985 July 10, 1985 1. Pulled ball valve. 2. Ran in hole with 2.25 star bit to 9020' and tagged scale. 3. Cut scale to 9089' and pooh to wait on acid. July 11, 1985 4. Rigged up arctic coiled tubing. July 12, 1985 5. Rigged up Dowell and pressure tested to 5000 psi. 6. Ran in hole to 8700' and pumped filtered seawater @ 1/4 bbl per min. 7. Pumped 1000 gallons of 15% HC1 fluid from 8700' to 9180'. NOTE: Would not pass 9180'. Acid contained .3~ W-35, 14#/lO00gal L-41, 1.2% A200, & 1% V-66. 8. Pumped filtered seawater to displace 17bbls. of acid out of coiled tubing. POOH and rig down. Returned well to production. 9. Flowed well to clean up. July 14, 1985 10. Rigged up Dowell and arctic pressure test to 5000 psi. Ran ~in hole to 9037' and pumped 40 bbls. of filtered seawater mixed with 2 drums of 4987 Nalco Scale Inhibitor. 11. Displaced coil with 17 bbls. of filtered seawater. Pooh and return well to production. RECEIVED JUL30 Alaska 0il & Gas Cons. Commission Anchorage Shell Westem E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 July 7, 1985 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Mr. Chat Chatterton 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUBJECT: SUNDRY NOTICE ON MGS C31-26 Please find the enclosed Sundry Notice for the work to be done on our MGS Platform "C", well no. C31-26. The acid job to remove scale is scheduled to begin on July 10, 1985 If there are further questions, please contact Susan Brown of our staff at (907) 263-9613. SBB/kka t Paci ~ly you~Bs, ~ al Engineer Frontier Division Enclosure cc: Greg Molesworth Chevron, U.S.A. P. O. Box 7-839 Anchorage, Alaska 99510 RECEIVED J U Alaska Oil & Gas Cons. Commission Anchorage SBBB/aogccl.4 STATE OF ALASKA ALASKA AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Western E & P'Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchoraqe, Ak 99501 4. Location of Well At Surface: Conductor 5, Leg 1, 4.74'S & 3.46'E of Cente~ Leg 1. 542' N'& 1596' W of SE Corner of Sec. 23, Twsp 8N, Rge 13W. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 12. I 6' Lease Desi~t~)tL°nf~ ~e~iaI N°' 7. Permit No. 67-63 8. APl Number 50-733-20052-00 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoal 'IG" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see attached worksheet for the details of the acid job to remove scales. 14.' here~lfyy~:~r~ing is!e Signed / //) .~ The spa~e ~eelow for ~m ission use~ ~' ~ ' Conditions of Appro a~, if any: RECEIVED JUL O Alaska 0il & Gas Cons. Commission Anchorage and correct to the best of my knowledge. Title Sr. Staff Environment. EngineerDate ~ppro'vea Ca.p¥ p,~turned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 July 7, 1985 Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WORKSHEET FOR MIDDLE GROUND SHOAL C31-26 ACID JOB 1. Pull ball valve. 2. Run in hole with 2.25 star bit to 9000' and tag scale. 3. Cut scale to 9000' 4. Rig up coiled tubing. 5. Pressure test to 5000 psi. 6. Pump filtered seawater at 8700' 7. Pump 1000 gallons of fluid, 154 HC1 by volume. 8. Pump filtered seawater to displace acid. 9. Flow well to clean up. 10. Pump 40 bbls. of filtered water mixed with 2 drums of 4987 Nalco Scale Inhibitor. 11. Pump filtered seawater to displace inhibitor. March 20, 1985 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- Please find the enclosed Sundry Notice for work to be done on Middle Ground Shoal, Well No. C31-26. ~The work is scheduled to commence sometime on March 22 or 23 so a verbal approval is needed quickly. Please contact Susan Brown at 263-9613 for further information. Thank you for your cooperation. Very truly yours, J. H. Douglas JHD/bc Attachment 0023BJC1 RECEIVED ~4AR 2 1 1985 Off & G~s Qms. Commission Anchorage ( I STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. Shell Western E & P, Inc. 67-63 OTHER [] 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, Alaska 99501 4. Location of Well At Surface- Conductor 5, Leg 1, 4.74' S & 3.46' E of center leg 1, 542'N & 1596' W of SE Corner. Sec 23-8N-13W 5. Elevation in feet (indicate KB, DF, etc.) ltlS' DF 12. I 6 . Lease Designation and Serial No. 1fl756 8. APl Number 50- 733-20052-00 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforation's [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see the attached prognosis for details of the work to be done. RECEIVED 2 i ]985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~ ,-.~:::~-~._ Title Production Superintendent The space below for Commission use ~J,/-'~. ~-~0 Conditions of Approval, if any: / Approved Cc~p¥ ~®turned SllTII By Order of Approved by COMMISSIONER the Commission Date 3-20-85 Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . PRI;IGNDSZS C3~-E6 H~S FIELD CLEAN OUT SCALE WITH CD]LED TUBING UNIT fiND FISH WZRELINE TO(ILS W]TH W]RELINE aND BRTCH TRERT THE gR/GS ZONE, ~ DRTRI TD:993&~ PBTDI BB40' ¢SClaL£ OR TDDL~) (~qSZN~I 7" ~/~&/E9 ! N-Be BUTTRESS e 9927~ , ' ~i 3 l/a" 9.3# N-Be EUE etd. FOR fODITIONRL BEE RTTI:tCHED DETR/L 6HEET, PERFp.R~I..~EO ~T~J[~J,, ~ R/gS &743/&T80 He/HO 9e37/ge$9 HE/HF 9144/9194 HZ/HK 917.58/9~97 , HK/HN 9311/9448 HN/HR 9471/961e HR/HZ 1. RU WIRELXNE laND LUSRICIqTOR. TEST LUBRX¢laTOR TO 3000 P~I, ., a*RU COILED TUBZNa UNIT RND nCZOZZING EgUZP~NT. TEST .a~ LINES ~ND EGUXPMENT TO ~e PSI. TEgT RCXD CONCENT~TZON 3, R]H WITH MILL ON DYNRDRILL. CONTINUE TO I~Rg LIFT WELL WHILE CIRCULRTIN~ ~ITH ]NSECTION W~TER ~T ~/4 ~PM. DO NDT.RLLON WELL TO STOP .FLOWiNg, ~F H~L ~E5 STOP FLONIN;~ STOP CIRCULATING RND aLLO~ NELL TO UNLORD FL~ID,' .NH~ NELL B~NS TO FLON~CIRCULRTE RT ~ REDUCED RaTE RECIPROCRTE COILED TU~ZNG. CLERN OUT TO TOP OF FISH. .... RECORD ~TH gCRLE ENC~~RED, RT TOP ~ .' *. R'ZH NZTH NRBH NOZZLE TO TOP OF FISH. PUHP le ~BL DF HCL WHILE R~H. SHUT ZN &~S ZN~CT~ON ~N~ PRODUCTION CHOKE, TRG FISH, HOVE COILED TU~ING BETWEEN POINT SCflLE ORIgiNaLLY EN~OLI~TERED DLIR]NG DYNaPR]I.L CLERN OUT RN~ F/SH ~t':]LE PUMP}NF, ~CID ~ 1/4 BPP~ ~...~r ~:~, :,:.rc, c,t:,r LXCE~D ~SG~ P~:]. bI~PL~CC A~Z:~ R]I~: FiLTERCD INJECTION WATER DR D1ESE~ DEPENDING ON TEMPEn~I'URE. ~00 · I00 'ON 9t~ S8/8T/£0 MHEN DiSPLRCEHENT IS COMPLETEt TR6 PBTD liND POOH, BEGIN LIFTING HELL ~ Iq[NUTE$ RFTER LAST flCID LEAVES END OF COILED TUB]NI~, RU HIRELINE RND RTTElilPT TO'FISH TOOLS, UNABLE TO FISH , POOH, · REPERT STEP 4 IF .. 6, PRODUCE kI£LL FOR /~4 HOURS TO REMOVE ALL ACID liND SOLIDI;. SHUT 'IN SRS INJECTION RND PRODUCTION CHOKE. RIH HITH Px 'PLUG liND SET IN 5LID]N~ SLEEVE RT 87e5g. POOH HIRELZNE, ~,..RU'FLEXI~LE LINE FROH 'INJECTION HELL TO TUBINg,' 'FZCC UP TUBING g[TH ZN:ECTION HIITER, HONITOR TUBIN~ PREGSURE THROUGHOUT BRTCH ~NHIB/T[ON TRERTMENT, ~I~NTRZN RT'LEIIST ~8 I~X #ORE PRESSURE ON TUBXNG. THRN~UB,DURING TREATMENT, THIS HILL. ENSURE INJECTION OF CHEHZCI~L DDt~N RNNULU~ ZNTD FOR31~TION, 9, I~ZX RND PUMP 1&5 BILL, OF NRLCO *gG? BCR1,E INHIBITOR H[XED ZN 75 BBL OF ZN,,I'ECTZON I, II:ITER, DI~PI-~CE BC~LE INHIBITOR HITH 35~ BBL OF ZNSECTI'ON I, IRTER(~I ~liL OVERDI~PI..RCE~NT,) i% le. RU H]REI..INE lIND PULL Px PLUG. RD HIREI. INE! CTU 1%, SHUT %N HELL FGR 1~ HOUR~, RETURN TD PRODUCTION BI, OI4LY, .... **~qKE ~RLE .DRIFT RUN t~U I~END .~q~IPLE OF PRODUCED MliTER . .. (FOR SCALE ZNHZB!TO~ RESIDUAL t~LYSZS) TO CHEHZCAL CDH- PRNYI ON ~ MONTHLY I~SZS, REPORT RESULTS DF BCRLE RUNS ~ND INHIBITOR RES~DUIIL$ ON "CONSTRUCTION REPORT", ~liTCH .'.. .INHiBiTOR ~RERTHENTS H~L.,BE REPEIITED AB NEEDED .... · . . · · . . MAR 2 1.1985 .... Anchorage -- B00 '1:00 'ON , . 'le · II. Ipso bl,~p '[ts'/ 7P, z . · ?0?5 ~1 ~00'0N 900 November 3, 1983 Shell Oil Company 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell's Middle Ground Shoal Well A12A-1 and Seal Island Well No. BF-47. Also attached are duplicate copies of Subsequent Sundry Notices for Workover Operations for Shell's MGS Wells C31-23, C34-23, ~~6:and C24-23. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH'mh Attachment C STATE OF ALASKA ALASKA ILAND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELL 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Shell Oil Company 67-63 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 50_733-20052-00 4. Location of Well Conductor 5, Leg 1, 4.74' S & 3.46' E of Center Leg 1, 542' N & 1596' W of SE Corner Sec. 23, T8N, R13W. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name ~S 10. Well Number C 31q26 11. Field and Pool Mi d~lle Ground Shoal "G" Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROPOSAL' Clean out tubing with dynadrill and acid. Acidize lower zones. Isolate GR/GS from lower zones and pump scale inhibitor into zone. 10/20/83 - Rigged up Dowell and Otis Coiled Tubing. Rigged up injection water to coiled tubing for Dyna Drill. Pressure tested to 3500 psig. RIH with 2½" bit and Dyna Drill. Tagged scale @ 8580'. Drilled scale. Tagged fish @ 8920'. 10/21/83 - Flowed well .to clean out Dyna Drill cuttings. RIH Hit scale bridge @ 8200'. Pumped 10 bbls 10% HC1 across scaled tbg from 8200'-8900'. SI and let acid soak. Tagged @ 8924'. Pumped 5 bbls HCL on top of scale & let soak. Tagged @ 8930'. 10/22/83 - Pressure tested to 5000 psig. 10/23/83 - RIH with Dyna Drill and 2½" mill to 9450'. RIH with wash tool to 9450'. Pumped 420 gal Xylene & 420 gal 10% HCL from 8600'-9450'. Flowed well to clean Tagged bottom @ 9671'. Pumped 600 gal Xy-lene from o9,441'-9671'.' Pumpe~ 600 gal HCL 10% across perfs. Pumped 1200 gal 7½-1½% HCl./HF across perfs. Pumped 600 gal 10% HCL. Displaced coiled tubing with 17 bbls diesel. POOH and Rigged down. RTP. 10/24/83 - Flowed well. 10/25/83 - R.U. Dowell. Pumped 500 gal. scale inhibitor solution followed by 30 bblsm3% KCL. Displaced with 210 bbls inj. water. R.D. Dowell. SI 24 hrs. RTP.?~! 14. I hereb/~t~t~~g i,s true and correct to the best of my knowledge. [~ Signed ~/~, ~ ~'~ Title ProdUction Adm. Manager Date 11/3/83 The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /{~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Shell Oil Company 67-63 3. Address John Douglas, P.O. Box 4500, Kena-i, /~ 99611 4. Location of Well Conductor 5, Leg 1, 4.74' S & 3.46' E of Center Leg 1, 542' N & 1596' W of SE Corner Sec. 23, T8N, R13W. 5. Elevation in feet (indicate KB, DF, etc.) 105" D.F. 12. I 6. Lease Designation and Serial No. ADL 18756 8. APl Number 50- 733-20052-00 OTHER 9. Unit or Lease Name MGS 10. Well Number c 31-26 11. Field and Pool Middle- Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please See Attached. RECE ¥EO OCT Aiaska Oil & Gas Cons, Commission ,Anchorage Signed The space below for Commission use Title Mgr. Prod. Admn. Date 9/30/83 Conditions of Approval, if any: 6RIGtNAL 'SIGN[D BY LOfl'NIE C. SMITH Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "IntentiOns" in Triplicate and "Subsequent Reports" in Duplicate . FOR EXPENDITU~ PRODUCTION PACl FIG D IVI$1ON HOUSTON OATI: PllIPAIIIO J DAlaI' IIIGI,ITEI~fD Platform C 9/29/83 J Middle Ground Shoal Field Cook Inlet, Alaska ~s~. LOCATION NUMBER J wORK SHE~L~ ~ S,^RE ORDER TYPE OESCRt~rION . NUMBER 100~ ~ BIJCX~ET N~BU~ R&E Ac~d~ze and place scale 46,000 ]5,300 ]5,300 ~nh~b~t~on ~n C3]-26 Non Operators Approval Not Requ~ red Requested b3' J. H. Doug]as T. S. Burns · u.-~o~ 46,000 ] 5,300 ] 5,300 ' IISI BUDGe' AVAIkABLE IN BUDGET RETIREMENT POSITION ' NEW CAPITAC FUNDS REQUIRED ?Y BUDGET REVISION TOTAC cost - 1 5,300 ~ I JUSTI FlCATI ON: ........ See attached 3ust~f~cat~on. , , s~'" '~ ....... - OCT ~. Alaska Oil & Gas Cons, Sommiss~ua , Anchorage ' ~ONTINUED , OVER ....... RECOMMENDED APPROVA~ ii i i . . Justification Acid Stimulation Scale Inhibition C31-26 Funds totalling $46,000 ($15,300 Shell's 1/3 share) are requested to stimulate and place scale inhibitor in well C31-26, Platform "C", Middle Ground Shoal Field, Cook Inlet, Alaska. The economics are as follows- Shel 1 Net Total Gross Expenditure $ 15,300 $ 46,000 Oil Increase 13 40 P.V.P.A.T. @ 14% 27,000 81,000 % P.V.P.A.T. 176 176 Payout (months) 3 3 Well 31-26 was completed in December 1967 with initial production of 4882 BDO and 0% cut. After recompletion to isolate the watered out HI/HK zone in 1973, the well produced 1750 BDO, 27% cut. After a further decline to a rate of 200 BDO, 16% cut in April 1982, the tubing was cut and pulled to remove a fish and repair a hole in the tubing. After the job, production was established at 70 BDO, 81% cut. From the significant increase in water production, it was evident that the top packer was unseated during the operation. The well was reperforated with marginal results. Production declined to 50 BDO, 80% cut by April 1983. In May 1983, well C31-26 was acidized using coiled tubing. Production stabilized at 180 BDO, 57% cut. In July the well scaled up. Oil production dropped as low as 75 BDO. It is believed that the scaling GR/GS zone is producing behind the top packer and entering the tubing through the bottom gas lift valve. Scale runs have to be made every other week to keep the well producing. Production rates have fluctuated greatly as a result of the scale and scale cutting. In late September, a wireline fishing job resulted from a scale run. It is evident that continued operation will result in a permanent fish caught in the tubing and the well will again have to be pulled. It is proposed that the tubing be thoroughly cleaned out with coiled tubing· The lower zones will again be acidized for there is still evidence of damage caused by the 1982 pulling job. The GR/GS will then be mechanically isolated and a scale inhibitor solution will be bullheaded into the zone. The scale inhibitor is designed for one year protection The well can · presently produce 180 BDO as proven by production test shortly after scale runs· The well has averages only 140 BDO over the last two months. If the formation of scale can be prevented and a sustained rate of 180 BDO can be maintained, a 40 BDO increase over the present average rate is expected. The acid job should increase the current maximum productivity of 180 BDO and additional profits should be realized. Your approval is' recommended. TSB'mh Acid Stimulation Scale Inhibition C31-26 P1 atform "C" W.H. Room #1 Conductor #5 Middle Ground Shoal Field Kenai, Alaska Status: Well gas lifting 426 Gross, 164 Oil. Top packer is believed to be unseated allowing the scaling Gr/Gs to produce. Mechanical Details: See attached schematic Purpose: Clean out tubing with dynadrill and acid. Acidize lower zones. Isolate GR/GS from lower zones and pump scale inhibitor into zone. Procedure: le . M.I.R.U. wireline and lubricator. Test lubricator to 3000 psi. Pull ball valve. Rig down wireline. 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 concentration and compatibility according to acid test procedure. Filter all fluids through a 2 micron filter. e While producing, R.I.H. with coiled tubing and Dyna Drill pumping injection water. Caution: Large quantities of produced solids are expected during tubular clean out. Clean out tubing to 9450'. Do not go out the end of tubing at 9465' with Dynadri 11. I P.O.O.H. with Dynadrill. R.I.H. with wash tool. With coiled tubing at 9465', and the well producing, pump 420 gal. Xylene solvent followed by 420 gal. 10% HC1 with additives. Move coiled tubing uphole to 8600' while pumping. Note: If well starts to load up, cut pump rate and increse gas injection rate. Do not allow well to die. Displace acid to end of coiled tubing with Diesel. !~'~- ~'~ ~'~ ~'~ 5, e 7~ , 9, Produce well until clean returns are obtained at surface. Shut well in at surface. With coiled tubing at 9700', pump fol 1 owing treatment. Stage Fluid Volume i Xyl ene Solvent 600 gal (14.5 bbls) 2 10% HC1 600 gal. 3 7-1/2-1-1/2 HC1-HF 1200 gal. 4 10% HC1 600 gal. Move coiled tubing across entire interval (9700'-9441') during each stage of acid treatment. Displace acid to end of coil with diesel. Over displace by 5 bbls to flush coil. P.O.O.H. Rig down coiled tubing. Place well on production. Let well stabilize for at least 24 hours. Obtain a good production test. Rig up wireline and test lubricator to 3000 psi. Make gauge run to bottom. P.O.O.H.R.I.H. with "Px" mandrel with 5000 psi bombs on 72 hour clocks hung on bottom. Set in sliding sleeve at 9086'. P.O.O.H.R.I.H. with "Px" prong and set in mandrel. Slack off wireline. Bleed off annulus. Reverse circulate hole with 3% KC1. Filter KC1 through 2 micron filter. When KC1 returns are established, close tubing in. Pump 500 gal. inhibitor solution followed by 30 bbls filtered 3% KC1 down annulus. Displace with 210 bbls filtered inlet water. Do not exceed 3500 psi. Pump final 40 bbls of job at 1/4'bbl/min. Rig down service company. Shut-in well for 24 hours. Gas lift tubing down. Establish inflow from GR/GS zone. Pull "Px" prong from mandrel. Pull "Px" mandrel. Read pressure charts and send to T. S. Burns, Houston. Test well frequently until stable. TSB'm~ Date Cost Estimate C31-26 Coiled Tubing Acidization Scale Inhibition lo 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 1000 gal. Xylene 1600 gal. 10% HC1 Acid Additives 1200 gal. 7-1/2-1-1/2 HC1-HF 350 bbls 3% KC1 500 gal. scale inhibitor Pump 2 days Tanks 2 days Lines 2 days Personnel 2 days Coiled Tubing @ $5000/day Miscellaneous Total $ 4,500 1,600 1,200 2,900 2,000 1,800 4,000 1,600 3,300 7,30~ 10,000 2,000 $"42,200 Add 10% Contingencies Say Fluid Additives Composition $46,000 10% HC1 0.3% W-35 (antisludge) 14 lbs/lO00 gal L-41 (iron sequestering agent) 1.2% A-200 (inhibitor) 7-1/2% - 1-1/2% HCl-HF 0.6% W-35 0.4% W-52 (de-emulsifier) 14 lbs/lO0 gal L-41 0.8% A-200 Scale Inhibitor 3% KCl 20% L-49 (Scale Inhibitor) I lb/lO0 gal L-59 (reaction rate agent) 0.2% F-75N (surfactant) 1932 IJi{PTItS C 31.-26 REVISED TUI~IHG DETAIL ITEM // DESCRIPTION ll 1'. Otis Safety Ball Valve N. 2. CAMCO KBUG Mandrel - BK 900.~ 3/1 6" 3. CAMCO KBUG Mandrel - BK 905# 3/16" 4. ,.. CAi,iCG KBUG Mandrel - BK 910# 3/16" 5. CAMCO KBUG Mandrel - BK 915// 3/16" 6. CAMCO KBUG Mandrel - BK 965# 1/4" 7..~' CAMCO KBUG.;,landrel - BK 965// 1/4" 8.. CAMCO KBUG Mandrel - BK 950" 5/1 6" 9'. Baker Seal Bore Assy. ,10. ' Otis "XO" Sliding Sleeve ll. 12, 13. lq. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. osed 25. Gui berson Packer RH-1 CAMCO KBM Mandrel Otis "XO" Sliding Sleeve Gui berson Packer RH-1 CAMCO KBM Mandrel Otis "XO" Sliding Sleeve Guiberson Packer Rlt-1 CAMCO KDM Mandrel Otis X-O Sliding Sleeve Guiberson Packer RH-1 CAMCO KBM Mandrel Otis X-O Sliding Sleeve Guiberson Packer RH-1 Otis X Nipple Otis Q Nipple 14 TUBING DETAIL 3 1/2", 9.3#, N-80 EUE Closed CASING DETAIL 17 7", N-80, Buttress Open 23// 0/5000 26# 5600/8100 29# 8100/9927 20 en GR/GS HC/HD HE/HF HI/HK HK/HN HN/HR HR/HZ PERFS. (MD) DEPTX 327' 1871' 3510' 4962' 6092' 7257' 7991' 8642' 8666 7805 8713 9080 9086 9095 9195 9201 9219 9283 9288 9298 9441 9446' 9456' 9464' 9465' 8742/8780 9037/9069 914q/9194 9258/9297 9471/9610 .... 9640/9700 Pa ge 97 SHELL-ATLANTIC-STANDARD I I I ~4A-o~ I , ~ ~ / ~1~ ', "- *~ ~ ~ . ~ INJECTION WELL , / .,,_~ , I ~ PRODUCING WELl ' 0m~ 0 ~-~' ...... ~i .... 1 ..... .,~;--~'~ ..............: iI ~','$~'K"/;.- , 4ooo:; J ~~ ~t , I SCALE IN FT ~; ) ..... . %., PLUGGED & AI3ND. STATE OF ALASKA C~ ALASKA OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL RE] 2. Name of Operator Shell 0il Company 3. Address John Douglas, P.O. Box 4500, Kenai, AK 99611 4. Location of Well Conductor 5, Leg 1, 4.74'S & 3.46'E of Center Leg 1, 542'N & 1596'W of SE Corner Sec. 23, T8N, R13W. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Lease Designation and Serial No. ADL 18756 7. Permit No. 67-63 8. APl Number 50- 733-20052-00 9. Unit or Lease Name MGS 10. Well Number C31-26 11. Field and Pool Middle C,.round Shoal "G" Pool 12. (Submit in Triplicate) Perforate E] Alter Casing [] Perforations Stimulate E] Abandon [] Stimulation Repair Well E] Change Plans E] Repairs Made Pull Tubing E] Other E] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing )([~ Abandonment E] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Status' Well gas lifting 120 BDO (6'5% cut) from HI-HZ zones. Proposal' Clean out to bottom perforation with coiled tubing, acidize with coiled tubing, and return well to production. 5/6/83 Rigged up Dowell & Otis. Pressure tested to 5000 PSI for 15 min. Tested BOP's. RIH @ lO0'/min, with ¼ BPM filtered sea water flush. POOH. Would not pass GLV @ 6092'. RIH after changing angle of bullet on end of tb~ In- creased injection oas to maintain flow in well. Ran into bridge (scal~i @ 9200'. Increased pump rate to ½ BPM and tried to wash through bridge. Pumped 2 BBLS 10% HCL on bridge. Acid soaked for 45 min. and tried to wash through again. Pumped 4 BBLS 10% HCL on top of bridge. POOH. RIH with 1.75" bit on Dyna-drill. Drilled on bridge at 1'/min. 9200' to 9450'. POOH to change BHA. RIH with bullet. 5/7/83 Tagged bottom @ 9685'MD. Washed fill with filtered sea water @ ½ BPM @ 4500 PSI. Pumped 2 BBLS 10% HCL on top of fill and tried to wash again. Circ to clean hole. Obtained sample from flowline. Began pumping 50 BBLS diesel. Shut well in and let stabilize. Pumped 600 Gal P-20 solvent followed with 600 gal 10% HCL. Pumped 1200 Gal 7½-1½% HCL-HF mud acid followed with 600 gal 10% HCL Reciprocated tbg during pumping from 9685' to 9441'. Dis- placed acid wit~ 15 BBLS diesel. POOH. Rigged down Dowell & Otis and RTP.,~z 14. I hereby certify that~the foregoing is true and correct to the best of my knowledge. Signed ~2~t j ~ Title:Mgr..,P~od., Adm. The space below for Commission use Date 6/3/83 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL r-'l COMPLETED WELL OTHER [] 2. Name of Operator Shel 1 01] Company 3. Address John Oouglas. P.O. Box.4500, 4. Location of Well Kenai: AK .9q61] Conductor 5, Leg 1, 4.74' S & 3.46' E of Center Leg 1, 542' N & 1596' W of SE Corner Sec, 23, T8N, R13W. 5. Elevation in feet' (indicate KB, DF, etc.) 105' D' F.. I 6 . Lease Designation and Serial No. ADL 18756 7. Permit No. 67 -63 8. APl Number 5o- 733-20052-00 9. Unit or Lease Name 10. VVoII Number ¢31-26 11. Field and Pool MIDDLE GROUND SHOAL "G" Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Ca'sing [] Perforations [~ Altering Casing Stimu late ~ Abandon [] S tim u lat ion [] Aba ndonment Repair Well [] Change Plans [] Repairs Made [] Other Pull TuOing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work,, for Abandonment see 20 AAC 25.105-170). See Attached Subsequent Work Deported MAY 0 5 ~,aas 14. I hereby certifv that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title P,roduction Admini'strati'on Date 4/19/83 Conditions of Approval, if any: Appr'oved by. ORIGINAL $1GMEB' BY LOiiNI[ C. SMITII Approved Copy ?,e~rned By Order of COMMISSIONER the Commission ' - ' ' ' __.?_.].L~ ' ' : AUTHORITY FOE EXPENDITU o,.~'. ..... I .,=.~ ~,c~ '" P_RODUCTIQN I PACl FlC DIVI$1QN ii i III i i iI i C31-26 Platform "C" Middle Ground Shoal Fiel~l Kenai, ~A1 aska WORK ORDER NUMBER LOCATION 0ESCRIFI'10N 100~ COb'i' Clean out and acidize using coiled tubing. $47,000 Requested by' J.H. -Douglas T. S. Burns I II _ iii[ iii i I 4/1 9/83 [ ~_ Il _l J II I I I I I I % SHARE $15,700 $15,700 Non Operators Approval Requi red Not POSIT1QN __ sue-'ro'r^~ $47,000 $15,700 TOTAL COSTJ i $15,700 See attached Justification. Justification Clean Out Fill and Acidize C31-26 Funds totalling $47,000 (Shell's 1/3 share $15,700) are requested to circulate fill out of the HR/HZ zone and acidize the HN/HR and HR/HZ zones using coiled tubing. The economics of the job are as follows: Shell Net Total Gross Expense $15,700 $47,000 Oil Increase BDO 50. 50 PVPAT @ 14% $111,~00 $333,000 % PVPAT 713 713 Payou~; (months) 4 4 C31-26 was completed in December of 1967 with initial production of 4882 BDO and 0% cut. After recompletion to isolate the watered out HI/HK zone in 1973, the well produced 1750 BDO and 27% cut. In 1974, a wireline tool became-bridged in the tubing at 5550'. in 1979, a hole was made in the tubing at 5600' while spotting .acid on the fish. In May of this year, the 4½" tubing was pulled without unseating the packers and replaced with a new string of 3½" tubing. In this operation, the formation was damaged by the mud used to kill the well. 'Production, rates dropped from 270 BDO (18% cut) to 100 BDO (72% cut). _ In August of 1982, C31-26 was reperforated in the HN/HR zones in an attempt to establish "undamaged (by mud)" perforation through which the well could flow. At the same time it was determined that the HR/HZ had sufficient potential to be perforated. Upo'n perforating the HR/HZ the well experienced a massive mud inflow which nearly killed the well. The HN/HR was then reperforated but with great difficulty. The operator experienced problems getting the guns through the fill and periodically stuck the tools. After the job production dropped as low as 50 BDO, but cleaned up to the rate of 140 BDO (33% cut). Production has since dropped to the current rate of 120 BDO (65% cut). It is believed that the fill is the remains of the original drilling mud and reservoir pressure in the HR/HZ is insufficient to clean the fill out of the weltbore. It is thus necessary to go in with coiled tubing and circulate out the mud fill. Acid will be used to clean out the perforations in both the HK/HN, HN/HR and HR/HZ zones. Cleaning out and stimulating C31-26 is justified on a 50 BDO increase. This job was previously proposed and approved for the coiled tubing work done last November, but was cancelled due to problems encountered with Arctic Coiled Tubing. ~ ..... ~:i!~.~ ~ Your approval is recommended. Coiled Tubing Acid Stimulation C31-26 Platform ,,C,, W. H. Room #1 Conductor #5 Middle Ground Shoal Field Kenai, Alaska Status: Well gas lifting 120 BDO (65% cut) from HI through HZ zones. Mechanical Details: See Attached Schematic. Purpose: Clean out to bottom perforation with coiled tubing, acidize with coiled tubing, and return well to production. Procedure: 1. :M.I.R.U. wireline and lubricator. .Test lubricator to 3000 psi. Pull ball valve. 2. R.I.H. with gauge run. Clean out tubing, as necessary to ... bottom. Tag and record bottom depth. If fill is present, R.I.H. with wireline bailer and obtain sample. Send sample to Dowell for acid and solvent solubility testing. Rig down wireline. Return well to production. Note: Have copy of all test results sent to T. S. Burns, Houston. 3. Obtain oil sample from flowline and send to Dowell for compatibility test with prognosed acid treatment. 4. M.I.RoU. coiled tubing and Dowell acidizing equipment. Test lines, tree, and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Place well on test separator and monitor production closely throughout operation. 5. With well flowing, open swab valve and pump filtered injection water through system at 1/4 bbl/min to flush system. After system is flushed, filter all fluids through a 2 micron filter positioned immediately before coiled tubing (see attached piping sketch). Cut back pumping rate to a minimum (1/8-1/16 bbl/min). Be prepared to choke pump outflow line if the equipment will not pump at a slow rate. 6. R.I.H. with-coiled tubing (no more than 100 FPM). If well's production interferes with coiled tubing, choke well back at surface. .. . -. Note' DO not pump down coiled tubing at a rate faster than the returns and production rates out the flowline. Attempt to maintain flowing well conditions at all times. An increase in injection gas may be necessary to keepJthe well from loading up. - ~ 7. Tag fill and, record depth. Attempt 'to circulate fill out of hole using filtered injection water. Use 4750 psi maximum. pumping pressure and produce well at maximum rate with minimum back pressure. Note' Keep coiled tubing moving at all times while circulating fill to help prevent bridging which- coul.d stick tubing. 8. !f penetration rate is slow or cannot be established, pump 2 bbls 10% HC1 with additives (see attached for composition). Follow acid with filtered injection water and continue cleaning out operation. Note' Repeat step 8 as needed if successful." ~'If cleanout operation is determined'to be unsuccessful, proceed with acid stimulation across available perforations.. 9. Clean out to below bottom perforation at 9700'. Circulate bottoms up while continuing to move tubing. Circulate until production is clean (no particulate fallout when centrifuged). Pump 50 bbls diesel to displace injection water .out of well, 10. Shut well ~in at surface and allow well to build up and stabilize. Maintain 1000 psi casing pressure. 11. With the coiled tubing on bottom, pump 600 gal P-20 solvent down coiled tubing at 1/4 bbl/min. Move coil uphole to'treat entire interval (9700'-9441'). With coiled tubing on bottom, pump 600 gal (14.5 bbls) 10% HCI with additives down coiled tubing at 1/4 bbl/min. Move coiled tubing up hole while pumping to treat entire interval (9700'-9441'). 12. :~lith the coiled tubing on bottom, pump 1200 gal (29 bbls) /-1/2%-i-1/2% HC1-HF acid with additives at 1/4 bbl/min. Move coiled tubing uphole to treat the entire interval (9700'-9441'). 13. With the coiled tubing on bottom, pump 600 gal (14.5 bbls) 10% HC1 with additives at 1/4 bbl/min. Move coiled tubing uphole- to treat entire interval. Displace acid to end of tubing with diesel and pump an additional 5 bbls of diesel to flush coil. P.O.O.H. with coiled tubing. 1~. Bring well on production on a 12/64" choke. Monitor acidity of produced fluids. Increase choke size every 4 hours and record production rates hourly. When tubing pressure reaches separator pressure, open choke~to 128/64". Take well off test separator, but test daily until stable. . . TSB:~ Date ~--~o ~ .... ¢ Coiled Tubing Specifications Working Depth Max. Working Pressure Tensile Strength Tubing O.D. Tubing I.D. Wall Thickness Capacity (1.255 S,F.) Tubing Weight 16,500" 5,000 psi 15,300 lbs 1.00 in. 0.850 in. 0.075 in. 0.702 bbls/lO00 ft.-' 29.48 gal/lO00 ft. 0.63 lbs/ft. ... Cost Estimate . C31-26 Coiled Tubing Acidization 1, 2. 3. 4. 5. 6. 7. 8. 9. 10. 600 gal P-20 Solvent $ 2,700 1600 gal. 10% HC1 1,600 1200 gal. 7-1/2-1-1/2 HC1-HF 2,900 Acid' Additives 1,200 Pump 2.5~ days 5,000~ Tanks 2.5 days 2,000 Lines 2.5 days 4,200 Personnel 2.5 days 9,200 Coiled Tubing @ $5000/day 12,500 Mi scel 1 aneous 2,000 Tota 1 $4~"~ 300-' Add 10% Contingencies Say $47,000 Acid Additives Composition 10% HC1 (Hydrochloric Acid") O. 3% W-35 (anti s 1 udge ) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 (iron sequestering agent) 1.2% A-200 (inhibitor) 7-1/2% - 1-1/2% HCI-HF (Mud 'AC i'd) 0 4% W-35 (antisl udge) .'~ '~'"i',, O;y :.-.. ~ ...... 0.4% F-75N (surfac~an~) '~ ~ 14 lbs/lO00 gal L-41 (iron sequestering agen%) 4:::"~a~a 0.8% A-200 (inhibitor) 1982 DEPTHS · · . .. ... , .. . · ., ... C 31-26 ' ' 9 · 10. ll.. 12. 13. 14. 15. 16. 18. .20. REVISED' TUB lNG DES CRI'PT I ON DETAIL' -. · · · Otis safety CAMCO KBUG 3/~6" CAMCO KBUG 3/16" CAMCO KBUG 3/16" CAMCO '3/16" 'CAMCO .CAHCO CAMCO 5/16" Bak'er Otis Guiberson CAMCO KBM Otis "XO" Guiberson CAMCO KBM Otis ,"XO" Guiberson CAMCO KBM Otis X-O Guiberson CAMCO KBUG Mandrel ' BK .. KBUG.Mandrel' - BK KBUG Mandrel - BK ,. KBUG Handrel ' 'BK -. .. -.-'. " DEPTH ! . . . . Bal 1 Val ye.' N, · '~ ':" ":,"i" '3'2 7 !'"' ' Mandrel ' B'K.'900'#' '" .... · ' '"'~: .... '":' 1'871 '" Mandrel - BK 905# i ." -"-' ' ." '-,.-- 3510 '" Ma'ndrel -"BK.910 ', '"" '""-":'"' "~ '" I' · ~ ' - · ' "..: 4962.~ 915# '. ..... ' ..... '-' ,,, ' '..' '6092' .. 965#-¼" '.....7257', 965# ¼" '".7991."' Seal Bore Assy. ': "XO" Sliding.'Sle~ve Packer RH-1 · . Mandrel Sliding Sleeve Packer RH-1 Mandrel Sliding sleeve Packer RH-1 Mandrel 95O# · · .. . · Sliding Sleeve · Packer RH-I KBM Mandrel 8642'.' 8666' ,.... '7805" 'BT13 '" 9080 : 9086 9095 '.:.91.95 ,, 9201 .9219 · .9283 :' 9288 9298' 9441 ~ ,~--~ ~11 ., 22. Otis X-O Slid. ing Sleeve ' '""" 9446''' · ' I~ ~, H .'.. .- ..:'." 23 , Guiberson'Packer'RH-1 ~ ,. " :, 9456' '. I' I :tc/,,;¢:.. ~:' o~.,.x ~~.. .,..." ' ,. "', ~,. ! ~, ,3~ · '. ~D. Otis q Nippl'~. '. · ~ ' ' 9465'"' ~'" .... '1 "F~ C/~ ____NG DETAI'L ' · ".' . i'. ~~ ..'".:'.. 3~,, ~.3~, ,,~0 ~,~ ~ .. ' i~ ~.. ~", '.. , I~I ~ ~L~7 . CASINO' OETAIL' '' '. PERFS..-". ' '. . · ' 23¢ .'0/5000 ' HO/HO 9037/9069 " .~1' .~'20 ' 26¢ .5600/8100 ,. ," HE/HF' 9146/9194. ' ~~ :~ _' , "z9¢ 8~oo/9~z~: R;;~;~]'~;;~.?'E'~ HZ/H,~ I"/~~ ~.2~X ~ .' .: ' ¢~;qy ~,,:, ~a,~t~t · HN/HR 9471/961'0 ' .¢&~:.~a o~I & Sas cu,%., Cnm,~,~ ..~.,-.. 50233 iflID.OR~6HL.R..DL 10'7561 RE,~ERVOIR OOlO0 I, KENRJ ZONE · HELL 90033 lC 31-261 -.., ,- · : :"::i' PIPING DIA,_]RAM COILE8 TUBINGI- CLEANOUT AND ACIL':IZAT!L~ A13-12, A43-I1, C31-26 ,, i 10 % HC:L O. 3% W-35 O. 4% F-75N 25 LBS;/1000 G L-41 1.2% A-200 7 1/2%-1 1/2% HCL-HF O. 4% W-35 O. 4% F-75N '~5 L'BS/IO00 G. L-41 O. :=:% A-200 · , P-20 SOLVENT - - Ii i ESEL IN,JECTION WATER FROM WATER PLANT PUMP C H 0 KE M A N I ( IF NECESSARY) ,. . -, HEAD :.':.;.., . . . FLCd,,JLINE TO ( ' .... TE:E;T SEF'ERATORCL - , ( ( WESTERN E&P OPERATIONS FfllDDLE GROUND SHOAL FIELD SHELL-ATLANTIC-STANDARD Ii I II I-IIII I I-I~l L iii J O IS449 ~ Ii, INJECTION WELL PRODUCING WELL' · .~P.~ PLUGGED & ABND, 4000 FT. STATE OF ALASKA ALASKA ~ AND GAS CONSER.V:ATION C~~' 'MISSION DRILLING WELL I-! COMPLETED WELL OTHER [] 2. Name of Operator Shell 0il Company 3. Add,e~ Production Superintendent 601 !.!. 5th Ave., ~.810, Anchorage, AK 99501 4. Loca:ion of Well Conductor 5, Leg 1, 4.74' S & 3.46' E of Center Leg 1, 542'N & 1596't.I of SE Corner Sec. 23, T8N, R13W. 5. Elevation in feet ;indicate KB, DF, etc.) 105' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18756 7. Permit No. 67-63 8. APl Number 5o- 733-20052-00. Unit or Lease Name 10. Well Number C 31-26 1 1. Field and Pool HIDDLE GROUND SHOAL "G" POnL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perfora~ [] Alter Casing [] ~ Perforations [] Altering Casing S~imulate E] Abandon [] Stimulation ~ Abandonment Repair Well E~ Change Plans [] Repairs Made [] Other Pull Tubing {~ Other r"l Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 33. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposed job cancelled.~ RECEIVED DEC 1 3 1982 Alaska 0il & Gas Cons. Commission Anchorage t 14. I hereby c~rtify that the, fore~oing is true and correct to the best of my knowledge, s~.~ Tm, Production Administration The space below for Comm,~sion use Conditions of Approval. if any: Oat, 12/6/82 By Order of Approved by COMMISSIONER the Commission Dale Fo~m 10-403 Rev. 7-1 80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duphcate MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL)~rX OTHER [] 2. Name of Operator SHELL 0IL COHPANY 3. Add-ess ~,'tayne Simpson 601 W. 5th Ave., #810, Anchorage, AK 4. Location of Well 99501 Conductor 5, Leg 1, 4.74' S & 3.46' E of 'Center Leg 1, 542' N & 1596' !.{ of SE Corner Sec. 23, T8N, R13W. 5. Eleva[ion in feet (indicate KB, DF, etc.) 105' D. F. 12, I 6 . Lease Designation and Serial No. ADL 18756 7. Permit No. 8. APl Number ~c.- '7:~3 - Zoo -.CZ - co Unit or Lease Name HGS 10. Well Number C 31-26 11. Field and Pool MIDDLE ('-,ROUND SHOAL "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit ih Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate )~ Abandon [] Stimulation [] Abandonment [] Repair Welt [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: RePort multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED RECEIVED NOV o 4 1982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certfly that th/e fore§cing is true and correct to the best of my knowledge. Signed_~ Title PRODUCTION ADHINISTRATION The space below for Commission use D~te 10/21/82 Conditions of Approval, if any: COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Coiled Tubing Prognosis C31-26 Status' Well currently gas lifting 140 BDO (33% cut) from the HK/HN, HN/HR and HR/HZ zones. Objective' Clean out fill and spot acid across perforations using coiled tubing. Mechanical Details- See attached schematic. Procedure' Note' Check diesel and acid compatibility before~job. · M.I.R.U. slick line unit and lubricator. Test lubricator to 3000 psi. Run in with wireline and retrieve ball valve at 327'. P.O.O.H. Make drift run with 2-1/4" tools and b~iler and tag fill at +9550. Obtain mud sample and send to Dowell for testing, Record dept~-and consistency of fill. Place dummy valves in any open mandrels. Close all sliding sleeves. Run crelab spinner survey to confirm sliding sleeves. P.O.O.H. Test well to determine rate out of lower zones. · e Shut well in at surface - do not bleed casing pressure. M.I.R.U. coiled tubing unit and Dowell acidizing equipment. Test tree and coiled tubing to 5000 psi. Test hYdraulic system and BOP. Run tubing in the hole slowly (no more than 100 FPM). Tag fill at +9550. Open well up and gas lift well down. With well producing, pump diesel and attempt to work through fill. Continue working coiled tubing up and down until hole is cleaned out below 9700'. Be With coiled tubing at 9700' pump diesel and produce over 200 bbls. of liquid at surface to lift fill out of hole. Shut well in at surface and allow pressure to stabilize to reasonable level. e With coiled tubi.ng at 9700', pump 360 gal. of 7% HC1 with 0.3% W-35, 0.2% F-75N, and 1.0% A-200. Move coiled tubing uphole to treat entire perforated interval (9700'-9471') while pumping. e RIH~ tubing to 9700'. Pump 720 gal. of 7-1/2% - 1-1/2% HCl-HF with 0.3% A-200. Move coiled tubing uphole to treat entire perforated interval (9700'.-9471') while pumping. Stop coiled tubing at 9471'. Note' Do not leave mud acid standing in well bore. 8. Pump 15 bb!s. of diesel to displace acid into perfs. 9~ P.O.O.H. and rig down. Leave tubing full of diesel (19 bbls.) pending further use of the coiled tubing unit. RECEIVED NOV 0 1982 Naska Oil & Gas Cons, Commission Anchorage 10. Put C31-26 back on gas lift production. Test well for several days until well is producing at stable rates. Report rates to T. S. Burns in Houston. Further instructions concerning the opening of sleeves will follow. Approved. ~//~ Date ////~.d~/~ RECEIVED NOV 0 4 ~982 Alaska Oil & Gas Cons. Commission Anchorage Spinner Survey Supplement C31-26 Status: Well gas lifting from HN/HR and HR/HZ zone. All sliding sleeves have been closed and the well has dummy valves in all mandrels between packers. Objective: Determine location (if any) of leaky sleeves or mandrels or locate any inadvertently open sleeve. Procedure: · 2~ Rig up spinner survey tool. Make stops at the following locations: Sequence Dep.th Location Time 1 8655' 13' below last gas lift valve and 15 min. · 10' above seal bore assy. 14' below seal bore assy. and 15' above S.S. 50' above mandrel 2 8680' 15 min. 3 9030' 4 9145' 5 9240' 6 9390' 7 9460' 51' above mandrel 14' below S.S. 15 min. 59' below S.S. and 50' above mandrel 15 min. 39' below S.S. and 42' above mandrel 15 min. 15 min. 15 min. All readings should be identical. P.O.O.H. and continue with step 1 of stimulation prognosis. Send data to T. S. Burns, Houston. RE .EIVEj NOV 0 ]982 Alas~ Oil & Gas Cons. Contr~i~lo~ Anchorage Coiled Tubing Stimulation Cost Estimate C31-26 · · · · · · 360 gal. HC1 @ $1.10/gal 1 gal. W-35 @ $33/gal 1 gal. F-75N @ $36/gal 4 gal. A-200 @ $34/gal 720 gal. HCl-HF @ $2.4/gal 2 gal. A-200 @ $34/gal Pump 1.5 days @ $1,300/day Tanks 1.5 days @ $470/day Lines Personnel 1.5 days @ $924/day Mi scel 1 aneous Coiled Tubing- Unit @ $15,000/day Transportation Total Say 396 33 36 136 1,728 68 1,950 705 2,000 1,386 1,O00 22,000 1,100 $32,538 34,000 RECEIVED NOV 0 1 82 Alaska Oil & Gas Cons. Comrnissie~ Anchorage 31 -26 1982 DEPTHS REVISED~ TUBING DETAIL I1 ' 3 · 4 5 ~6 ]8 9 :10 · 14 16 2 25 IT EM · · · · · 10. ll. 12. 13. 14. 15. 16. 17, 18. 19. 20. 21. 22. 23. 24. 25. DESCRI'PTION Otis safety Ball Valve"N. CAMCO KBUG Mandrel - B'K 900# 3/16" ' CAMCO KBUG Mandrel - BK 905# 3/16" CAMCO KBUG Mandrel - BK 910# . 3/16" CAMCO KBUG Mandrel - BK 915# 3/16" CAMCO KBUG Mandrel- BK 965# .CAMCO KBUG Mandrel - BK 965# CAMCO KBUG Mandrel "- BK 950# 5/16" Baker Seal Bore Assy. Otis "XO" Slidingl Sleeve Guiberson Packer RH-lx. CAMCO KBM Mandrel Otis "XO" 'Sliding Sleeve Guiberson Packer RH-1 CAMCO KBM Mandrel Otis ."XO" Sliding Sleeve Guiberson Packer RH-1 CAMCO KBM Mandrel Otis X-O Sliding Sleeve Guiberson Packer RH-1 CAMCO KBM Mandrel Otis X-O Sliding Sleeve Guiberson Packer RH-1 Otis X Nipple -Otis Q Nipple .'(MD) DEPTH 327' 1'871' 351-0 ' · i' 4962' 6092' 7257' 7991' 8642' ,,' 87'13' 9080' 9086' 9095' 9195' 9201' 9219' 9283' 9288' 9298' 9441' 9446' 9456' 9464' 9465' TUBING DETAIL 3½" 9 3# N-80 EUE CASING DETAIL 11 ~ 23# 26# 29# N-80, Buttress 0/5000 5600/8100 8100/9927 PERFS. GR/Gs HC/HD HE/HF HI/HK HK/HN HN/HR 8742/8780 9037/9069 9144/9194 9258/9297 93ll/94481 9471/9610 RECEIVED NOV 0 4 ]982 Alaska 0it & Gas Cons, Anchorage Page 95 wESTERN E&P 'OPERAT.ON5 .. .. [ IDDLE' GROUND SHOAL FIELD. i SHELL-ATLANTIC'. STANDA,RD 2"". / ! ]~44S o I I I j I f '~-lltl° 37:6 ~c. PATTERN: 7"~.1- ....~. ~~. _ L_ i i ! i i i Jl ii - /.~ / · ': , ' / ~14A-O I. · - [ __ /;' e _.-o,/- · - '-I . ~ / ~']~-,~ / " . ,. . [ - ~ ~ ; . . ',~3 / .,' / .I..'- ,, " --. : -- -:. -- _ ~,, · l . "i ~/ .. "~-,~"/ ........ ' ' ~- '" ",~~ = ~ I ~. INJECTION WELt ........ '/::-'~'-"-~ /~ ........ .... ~ "e PRODUCING WEL ' /~Z~~' .k../ ]. +P.~PLUGGED &AB~ . : .... --~~~2;_~_ ~ 1 REEE IVED NOV 0 '- ~&ska 0il & Gas Cons .... Anc~ k - L[ -' _-_ SiS l ...... iii1~ iii I iii + ~,,ss J~ 34 I Page 3 P.O. Box 31.~0 Anchorage, Alaska 99310 ~lephone (907) 248-23~4/~8-201~ " . Actual O.D. Nominal I.D. Wall .thickness Weight Wall area Flow area Tensile: Ultimate Yield Max. Operating i. 2.50 in. i. 084 in. 0.083 in. ~. o~ ~/~t. 0.304 in.2 0.925 in. 2 · 22,800 lbs. 21,300 lbs. 1 ?;' oOo Burst: Ultimate Test press. Max. Operating Collapse: Ultimate Max. Operating 9,960 psi. 6,000 psi. 5,000 psi. 6, lO0 psi. 1,500 psi. Capacity: 1.141 Bbl/1,000 ft. 875 ft./Bbl. Wall displacement 0.377 Bbl/1000 ft. Total displacement 1.518 Bbl/1000 ft. RECEIVED" NOV 0 4 I982 .ZUaska 0il. & Gas Cons. Commission Anchorage " ' STATE OF ALASKA AI'ASKA ~-. AND GAS CONSERVATION CO("' .¢llSSlOU SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL E3 COMPLETED WELL~x OFHER 7. Permit No. 67 -63 8. APl Number 99501 ~o- .133-20052 2. Name of Operator Shel 1 Oil Company .3. Address 601 W. 5th Ave. #810~ Anchora.qe, AK 4. Location of Well 9. Unit or Lease Name Conductor 5, Leg I 542'N & 1596' W of SE Corner Sec. 23-8N-13W, Sec. 26 T 8N R 13W 6. Lease Designation and Serial No. ADL 18756 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 12. 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoal Field "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [-1 ~ Perforations [X] Altering Casing Stimulate [] Abandon I-'] Stimulation [] Abandonment r-I Repair Well [] Change Plans I-'1 Repairs Made [~ Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completi0n.~ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. Signed Titie Production Administration The s~)ace below for Commission use D.te 9/14/82 Conditions of Approval, if any: B'I Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7.1 80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RECOMPLETjON RE~URT SHELL OIL COUPANY -Middle Ground Shoal $~.,..~I 0.,,. 8/28/82'_ 8/31/82 t~,-,~,, 105' D.F. -- m~ ~ · ?,~ ~a 9927' IV~rker Horizons · · ~__ Il I _1 I III' I IIIII I II i ii Ilmlll i ..... '"-- II I i I III iii i!I I -- iiii ii ii ii i i ii i Production Data D e.z:r'd~ Initial Production U.nchan~qed · Ill_ Ill Illl III I! · ii-- iii ii ii 8742 - 9700 @ intervals 7 '-"~'S 2,3# H-80 7 -~,~ 26# 7 --~-, 29# 5000 8100 9927 III II ~ II _v. s.o..~ ,, , - 8¢4228780 nR/~s .......... ltC/HB 9037-9069 '~ H~tH[ .... 914'4-~i94 ....... - - HN/.~ 9471-9610 ..... - HR/ilL Ubbb-9/U0 _ , ~_ ~,,, Il Il - ,, i __ _ Illl Ill Il II jim -- -- Il Adotl. Pred. D~--~ Calculaled Potential Cleaned out-to 9725'. Perforated the HR/HZ zone and reperforated-the liN/HR zone. '_' Middle. Ground Shbal C 31-26 _ Kenai'~ Alaska 8/28/82 8/31/82~ Platform C ii iiiii i ii 111 I II II I I II III o STATUS- ~.lell gas li'fti'n.n 100 BDO with a 72% cut. PROPOSAL- Perforate the HR/HZ zone and reperforate the Hrl/HR zone. 8/28/82 Dresser Atlas rigged up on C 31-26 for reperforation. Pressure tested to 3500 psig for 15 minutes' R.I.H. with 10' gun @ 4:00PM. · 8/29/82 Perforated 35' of the i~R,/UZ in C 31-26, from,~665~--to,-97~9~. Could not get down with 3rd gun to.perforate. Junk or scale in hole from 9598' down· Shot 3rd gun in ~N/H~fr~~~~-5~ Had mud' entry after shot· Tools stuck for 2 hours· Klowing well from 3:00AM to 4:00PM to clean out mud from perfs. Rigged up .092 wireline unit to clean out C 31-26. Found scale ~ 9220' and mud ~ 9575' to 9585'. Had bottom zone bridged'off. Cleaned out to 9725'. ~/30/82 Perforated top 15' of~R~ fr~~~~68~.; Could not get down to 9665' and could not pull out got stuck ~ 9608' Tools free after shot. Tried to run 5th gun, hit mud brSdge ~ 9570'. ~.O.O.H. & ran in with .092 wireline unit. Cleaned out bridge from 9570' to 9580'.' Tagged ~ 9700' .ran in with Dresser and perforated fro~54~ 8/31/82 Tried to run 6th gun into the HN/HR, but hole had bridged off ~ 9490'. Well BS&W increased during the night, had Dresser rig down and sent the crew & unit to Platfom "A". . II I II III i II II , STATE OF ALASKA ALA~K,,q/',.. IL AND GAS CONSERVATION ~ .vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator Shell Oil Company 7. Permit No. 67-63 3. Address 8. APl Number P.'0. Box 527, Houston, Texas 77478 so-133-20052 4. Location of Well Conductor 5, Leg 1 542'N & 1596' 14 of SE Corner Sec. 23-8N-1314, Sec. 26 T 8N R ]314 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Lease Designation and Serial No. ADL 18756 12. 9. unit or Lease Name- MG$ 10. Well Number C-3] -26 11. Field and Pool Middle Ground Shoal Field "G" pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: {Submit in Triplicate) (Submit in Duplicate) Perforate I~ Alter Casing r'l ~ Perforations r-1 Altering Casing r-I stimulate [] Abandon [] Stimulation [] Abandonment r-! Repair Well [] Change Plans [] Repairs Made r-1 Other [] Pull Tubing [] Other I'-! Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. Plan to start activities 8/27/82. RECEIVED AUG 2 ? 982 Alaska 0il& Gas Cons. Commission Anchorage Date, 8/,27/82 14, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ F~ TitleProducti on Superintendent The space below'for Commission use Conditions of Approval, if any: BY LO!{[~IE C. S~IITH Approved Copy Returned By Order of COMMISSIONER the Commission Approved by Form 1 O-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate o , ' [-31-~6 Middle Ground Shoal Field, Alaska Perforation Worksheet Status: Well gas lifting /~OBDO with a 73% cut. TD: 9935' P.B. YD: 984.5' Mechanical Details: see Attached' $che~nati¢ Proposal Perforate the )iR/HZ zone and re. perforate the ZO~'le, Proced ute'. MIRU Dresser Atlas with lubricator and grease injection head_ Pressure test lubricator to 3000 psi. Perforate selected intervals with 4 holes per foot using a 2-5/8' hollow carrier gun loaded with lZ gm charges ~nd positioned with a magnet at the bottom of the gun asSeni~ly. Del)th5 refer-antes to Schlumbe)'ger DIL survey dated ZONE DIL DEPTHS 9640/9700 '~ 9471/9610 HR/HZ (0° phased) -~ HN/HR [1800 phased) Casing Coll'ar~: 9489.5, 9534, 9578, 9614.5, 9657, 9701.5, and 97.42. (All casing colla~ taken off .of CBL/GR/CCL dated 12/7/67 and adjusted to D)L depths, i.e., collars are Ott depths). -4. Keep well "gas lifted down" whlle perforating. Establish inflow rate with 12+ hour (or until rate stabiI(zes) flow test after perforating each z~ne, i.e., perf. HR/HZ, test, parr, HN/HR, test. Send these rates to T. S. Burns, Houston. . Rig down Dresser Atlas. RECEIVED TSB:)4H ~.."z'~ - £ "- AUG 2 ? )982 ~,laska Oil & Gas Cons. '~=- :-~"'-- .... Anchorage ~ Date IT i /~'~ ~b?sr $7~z. Oil & G~ ZO ;Cons. Commission ~/e./~ 1144dr · .[ · · o · i . · · · i · · : 1' ' AUG 2 ? )982 Alaska Oil & Gas Cons. Co~'nmission /~nchora,q~ WESTERN E&P OPE~ SHELL-ATLANTIC-STANDARD I '/_~.._~ ' / - · .~ ,~ ~-~u~, ~,p~. . .... ~ . - , ' r '" - / ~- ' '-. i .... i -. , . . . . /?~. ;----- , al I -, t / ~ ----:~ I' /.;L.'"/' / I .~ I ~1 · ~ ' ' ' ~'~' ' ~! ~ I ~ ,,, ~, ~ : r ' INJECTION WE . - -~,, , t ~.... . , ..... ~ i ~ ~ ~ ~ PRoDucING ~ ~ / ,~*~ , I~ , , ~-~'~ ~ ~ , ~ PLU~ED & A I · =! / z--. =J~ " · , ,., .~~] t . ! t.-.. ~ · I '' / ea~ ,/ . ~ ..... . T------~ ~ ~,,~ ' ~ /~ 'r. , J ~ ~ ! ~ ~ / , ' Naska~il & Gas Con~ : ~ .... ~.'~ /.t ~ _. ........ ~ , I ' lo 4,oop i . J , ge 3 STATE OF ALASKA ALAS~ ~' )IL AND GAS CONSERVATION ( MMISSION SUNDRY' NOTICES AND REPOR'rS ON WELLS DRILLING WELL [] COMPLETED WELL 1. OTHER [::] ' 2. Name of Operator 7. Permit No. Shell Oil Company 67-63 -/ 3. Address 8. APl Number P.O. Box 92047 Worldway Center, Los Angeles, CA 90009 5o- 133-20052 4. Location of Well Conductor 5, 4.74' South, 3.4' East from center ot= Leg 1 at 541.65' North and 1596.41' West from Southeast corner of Section 23, TSN, R13W, $.M. 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 31-26 11. Field and Pool Middle Ground Shoal Fld 5. Elevation in feet ,indicate KB. DF. etc.) IADL /1 6. No. "G" Pool 105' D.F. 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing r'l Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment r~l Repair Well [] Change Plans I-'l Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [:~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. RECEIVED JUN 2 8 1982 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign~~~ Title Mqr.,'Production Administratio§ate The.p~e%elow for Commission;se For: B. Nevi l 1 6/2/82 Conditions of Approval, if any By Order of Approved by COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate end "Subsequent Reports" in Duplicate WELL SHELL OIL COMPANY ( RECOMPLETiON REPORT C 31-26 _ SHELL OIL COMPANY _ Middle Ground Shoal Unchanged. _ i iim mi 5/3/82 5/18/82 105' D.F. 9927' ~rker Horizons · · -- i _ Illll Ill IlI II II Il -- -- __ -- ii i ii i ii i iiiiii ii _ ii ]1111 _ J iiii _ ii ii i ~ i · i ii i ]11 - iiI i iiii i iiii i i i ~1 i ~111 ii iiii i i ii ~. ii i ii Production Data emmmmmmmmmll~ _ S-',-'ry, ~ NsC3 (t e~ z) , _ Slut TubLuf: -- -- __ 7 :~,~[ _23# N-80 -- 7 "c=en~ 26# m.~4 ~ 0-5000 -- . , -*-,~.,d -, 5600-[5100 7 -..~.. ~9# ....... . .. c,=,~ .~ 8100-992%. - i il , i ii ~ Ill I~ , ,.~ ~ ..... __ __ __ __ GR-GS _ _ _ _ m, _ i ii Initial Produdlon m i ii~Jl _ _ _ _ ii I] __ iiii m~l iiii i __ -- i i mi . __ I I __ --HC-HD 9037-9069 .... HE-He 914'4-91~ ...... .... HI-HK ~258'9297 : - - __ '"HK-HN 9311-9448 ........ _ HN-HR 3471-9610 _ i _ _ ~ i i i i lll iii i ~ i i ii i i i ii i nl mi I m Ad~l. Prcd. D~ C~lculated Potential iii _ mi · mi · -- · mi i III _ j i ii i! i i n l - ~ lmm ~ Imm l ii I II~ ~'' ' - - ii I1~ · ii iu i I I iiii II · ~]1 ii -- il _ _ _ _ ii il __ I~ r' ~-~ .......... ......... '~ ~. ~. C l V if. l}_ · iii -- m~ _ i i iii ii __ ......... JuN 2 "g' 19n:~ ' " iii1 ii ~ ilmlm i ........... '-,zUaSa ,.t;°rls' Corrl~is.~in. _ -- mil m ~1 m ~~- Remove fish. in tubing by replacing 4-1/2" tubing string (above packer), mandrels and GL valves with new 3-1/2" tubing, mandrels and valves. MIDDLE GROUND SHOAL' P.~::N: ~ITiCNIi~(~ ' C 31-26 ' -- _ Kenai, Alaska 5/~/82 ~~"'1' 5/18/82 Platfom C I I II L m ml i mlmll _ I iiiiiii II llmll ~1111 J l ii i iml i iim i · , S~ATUS' Producing 220 BPD gross, 176 BPD oil, 20% cut, GOR 136, 24 MCF production gas, 893 MCF injection gas. 'Fish consisting of one piece of Mallory'item and sliding sleeve shifting tool stuck in 3-1/2" tubing at 5594' (rotary table.) Hole in tubing approximately · 5600' from subsequent acid job to remove fish. PROPOSAL' Remove fish in tubing by repla~ing.4-1/2" tubing string (above packer), mandrels and GL valves with new 3-1/2" tubing, mandrels and valves. · .. · · · 5-3-82 5-4-82 Finishing rigging up rig. Installed choke and kill line. Test lines to 1700 psi. Preparing to kill well with 11.2 lb mud. Report as of 12 midnight. Kill well with 11.4 lb/gal mud. Nad to increase mud weight from 11.2 lb/gal. Preparing to remove Xmas tree. 5/5/82 Remove christmas tree, nipple up B.O.P.E. Test choke line, kill line, and hydrill to 3000 psi for l0 minutes. Circulate well preparing to rig up "GO" wire line unit to chemical cut tubing. L_ 5/6/82 Rig up "GO" International wireline. Ran 2.75" drift to 5605' KB. P.O.O.H. Ran 2.25 drift to 5605' KB. Tagged fish on both runs. Well started to flow on annulus side. 8.1 annulus. Well started to flow on tubing side. Shut in tubing for pressure build up. After one hour, observed 450 psig on tubing and 650 psig on annulus. Circulate and condition mud. Raised n~d weight to ll.5 lbs/gallon. Shut well in for pressure build up. Observed 550 psig on tubing and 760 psig on annulus. Building mud weight to ll.6 lbs/ gallon with 350 psi backpressure on annulus. Mud contains 8% oil in mud pits. Shut ~ll in for pressure build up after 1/2 hour tubing pressure was 150 psi and annulus was 250 psi. Began raising mud weight to 12.0 lbs/gallon. Shut doWn waterflood to help lower bottom hole pressure. mi iiiiii ii Ill I I III I _ i m iii III II iii i RECEIVED JUN 2 8 ]982 aska Oil & Gas Cons. Comm) Anchorage m J _ MIDDLE GROUND SHOAL C 31-26 - Kenai, Alaska · 5/3/82 ~°l~r 5/18/82 Platfom c _ _ mm i i i i mil ii mi ii iii iii [] II iim III i I I im III I II II II IIII II I m m iii 5/8/82 'Ran chemical #2 (GO), failed to cut tubing. P.O.O.H. Circulate and condition mud. Rig up {GO) wireline. R.I.H. with jet cutter. Made cut at 4840'. P,O.O.H. with wireline. Rig down wireline unit. Pulled and laid down 4840' of tubing. Driller observed small flow of mud in flow line. R.I.H. with 51 stands of 3 1/2 blank drill pipe. Condition mud and raised weight to 12.2 lbs/gal. Had. 9 bbl increase while weighting up mud to 12.4 lbs/gal. P.O.O.H. Change pipe rams to 3 1/2". Pick up overshot and bumper sub. R.I.H. Circulated : and condition mud. Holding 250 lbs back psi while circulating. 5/9/82 R.I.H. with .5 3/8" overshot dressed with 3 1/2" grapple and mill control, bumper sub and 3 1/2" D.P. Circulate and condition mud at 5 A.M. start to mill over fish at 4840'. Was unable to ingauge fish. P.O.O.H. Remove hollow mill control. R.I.H. Circulate and condition mud. Ingauge fish, attempted ~nual back off 3 1/2" DP, backed off at 3000'_+. Made up 3 1/2" DP, released fish. Circulate and condition mud, cutting from 12.4 ppg to 8.8 ppg. ll% oil. Gained 80 bbls mud from 6:00 A.M. to 12 midnight. While weighting up to 12.6 ppg from 12.4 ppg gained 20 bbls.in 3 hours. 12% oil mud cutting from 12.4'~ to 12.1 ppg through complete system. Closed hydrilic bull headed bull headed 48 bbls mud down tubing to 8712'. Top of first packer. Continue to weight up to 12.6 ppg coming out 9.3 ppg with no fluid gain at 12 midnight. 5 /10/82 Continue to circulate and condition mud. 1-O0 A. mud going in at 12.8 lb/gallon, coming out 10.7 lb/gallon. P.O.O.H. R.I.H. with 5 3/8" overshot, bumper sub dressed with 3 1/2" grapple. 8:00 A. ingauge fish at 4840'. Attempted manual backoff, ll,O00 ft/lbs 5 1/2 rounds lefthand torque, twisted off at chemical cut, 36' fish 2 half joints 1 mandrell. Top of fish now 4876' R.I.H. with hollow mill control. 5 3/8" overshot,, bumper ~ub. Torque D.P. lO,O00 lbs. Hook up kelly, circulate and condition mud bottoms up.. Mud weight in 12.6 lb/gallon, coming out ll.7 lb/gallon. Milled and ingauge fish, 22 rounds lefthand torque, manual backoff, 25,000 to 30,000 lbs ove~eight string, circulated and condition mud. RECEIVED~.0.0.,. Fish in rotary table at 12'00 M. No fluid gain over last 24 hours. JUN 2 8 i982 Note: 5/11/82 Out of hole with fish at 0500 hours. Top of fish at ' 7638 . Backed out bottom of mandrel mandrel split up A)~sl ,a 0il & Gas Cons. Commission , Anchorage in body, only hole in the string so far. -- ii mi im ii iml I I I I I IL I aT i O~ MIDDLE GROUND SHOAL Kenai, Alaska 5/3/82 Im.~:)~ 5/18/82 C 3]-26 latform C 5/11/8~ Fish in rotary, wireline fish found inside 4 l/t:" x 3 1/2" cross over sub, 5570' - 5574'. Laid down tubin~ 77 joints 4 1/2" EVE BRD, 7 joints 3 1/4" EVE BRD, 4 mand.rels. Total footage 2762'. Top of fish at 7638', l' pup brd thread up on top of 3 1/2" EVE BRD tubing. R.I.H. with a crew in sub on 3 1/2" D.P. tagged fish at 7634' D.P. measurement, circulated and conditioned mud, mud cutting at 1216 ppg to 7.2 ppg. Ingauged fish at 1530 hours. Ran {GO) wireline 1 ll/16" sinker bar with 100 grain backoff shot, largest O.D. 1 3/4" on tool. Ran wireline in 9060' atoped unable - to pass. Pulled back to 8675' shot chg. make backoff, circulated and conditioned mud, mud cutting 12.2 ppg to ll.7 ppg 2130 hours. P.O.O.H. AFE #: 225807 AFE amount: $500,000 Cost to Date: $301,438 5/12/82 O001 hours. Continued to P.O.O.H. OlO0 hours. Tubing fish in rotary. Laid down drill pipe fish, 6 joints 3 1/2" EVE BRD tubing, 26 joints 4 1/2" EVE BRD tubing, 2 gas lift mandrels, top of 3 1/2" tubing at 8675' collar looking up, picked up 3 1/2" EVE tubing thread to 5" change over sub, Baker Seal Bore 5" O.D. 4 1/2" I.D. 5" L.N. Thread to 3 1/2" IF, Bumper Sub. R.I.H. 81 stands and 1 single 3 1/2" D.P. Picked up 35 joints D.P. circulated and conditioned mud. Mud cutting 12.2 ppg to 8.8 ppg, Set 3 1/2" EVE BRD PIN in fish at 8875'. 1300 hours. Rigged up wireline 3/4" spear, jars, 1 7/8" sinker bar, R.I.H. at 9157', couldn't pass, P.O.O.H. Ran in hole with star cutter, more sinker bar 9270', stopped, couldn't pass. P.O.O.H. Left approximately 3" piece cutter in hole, closed rams, pumped 48 bbls mud down, tag with rig pump, surface 2100 psi, 12.2 ppg mud 8980' TVD, @184' MD, XO - sleeve open, gradient .857 - to 16.5 ppg mud. R.I.H. with wireline star cutter and sinker bars, 812M 9381'. NOTE: Released GO wireline service at 9:00 A.M. and back off specialist. AFE #: 225807 AFE amount: $500,000 Cost td Date: $345,324 5/13/82 0001 hours. Ran star cutter on wireline. Pressure. Tubing to 2100 psi (could not pump out plug). Ran star cutter'to 9383' (W.L. measurement) circulate through choke to condition mud. Screw into 3 1/2" EUE tubing at 8675' with seal bore assembly. Failed to make back off. 0730 hours. Call out wire ~'~,~) . line company to run string shot for back off. Ran three string shots in attempting to make back off on top of seal bore at .8666'. 2000 hours. After third string shot we noticed if we Jt'J~V~sJ,,Q82 would put about 10 rounds right hand torque in Pipe and then work up and down we would only get 7 or 8 rounds back - this Oil & Gas Con,j. Con~rni,jsioa procedure was continued until we had 15 rounds right anchorage turn and pipe came loose- 2300 hours. Pull up 60', handcirculate and condition hole. MIDDLE GROUND SHOAL -- , · Kenai, Alaska F~POR~ 5/3/82 5/18/82 C 31-26 Platf~m C.. I I II IIIII II I I IIIm 5/14/82 0001 hours. Continue circulating and conditioning hole. (no gas cut mud to surface). S.L.M. out of hole. Lay down tools and equipment from fishing/back off job. Pick up 1022' of 2 1/16" Hydril CS tubing with saw tooth bit. '(34 joints). R.I.H. to 8643' (lay down 21 joints 3 1/2" D.P. i~hile -~ running in hole). 1400 hours. Hook up circulating hole and circulate .while entering Baker seal bore at 8666'. Ran . inside bottom hole assembly with 2 1/16" Hydril to 9360' before hitting fill. 1730 hours. Wash and ream to 9507'. 5/15/82 0001 hours Wash and ream to 956B'. Pull back to 8622' Circulate ~ole. No gas. Pull and stand back 20 stds. ~ay down remainder of 3 1/2" D.P. and 1022' of 2 1/16" Hydril CS tubing. 'Run Halliburton sub sea control valve and set mt BS' with lg stds. Drill pipe below. Nipple down B.O.P. assembly to retrieve tubing hanger sleve from well head. Nipple back up and lay down Halliburton equipment and 20 stds 3 1/2" D.P. 2300 Hours. Begin picking up and running 3 1/2" Butt N-80 production tubing. 5/16/B2 O001 hours. Finish picking up and running 3 1/2" buttress N-80 production tubing. Tag top of and star into top of Baker seal bore (product #499-40) at B666'. Determine correct measurement for tubing hanger. Pull to ball valve (approximately 300'). Install and test 1/4" control line to 5000 psi. Run in hole. Install tubing hanger. Stab into seal. bore and land tubing. Stacked lO,O00# {4') and hung tubing in hanger with 75,000#. Nipple down and pull B.O.P. and riser system. Install well head and test to 5000 psi. Rig up wireline unit to pull dumy gas lift valve at 8650'. 5/17/82 0001 hours. Pull dumy valve from mandrel at B642'. Circulate' down tubing with filtered injection water .until returns were clean. Rin down circulating line. Hook well up for production testing. Begin injecting gas at · 12:00 midnight $/17/82. 5/18/B2 Clean rig. Clean and preserving mud pumps, load out as- sorted tools. Release rig at 8:30 A.M. 5-18-82. Moving ~ rig from Leg 4 to Leg 2. AFE # 227457 AFE a~unt: $500,000 Est. Cost to Date: $497,742.00 ? JUN 2 8 J§82 A)aska Oil & Gas Cons. Comm~o~ ~- -- ! m iiii iii i ii I~/ i~ , mlllll, II '1' ~1 I STATE OF ALASKA ALASKa"' .:IL AND GAS CONSERVATION C( MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL F'I COMPLETED WELL [] OTHER Eisa' ~ 2. Name of Operator 7. Permit No. Shell Oil Company 67-63 3. Address 8. APl Number P.O. Box 92047 Worldway Center, Los Angeles, CA 90009 s0-133-20052 4. Location of Well Conductor 5, 4.74' South, 3.4' East from center ot= Leg 1 at 541.65' North and 1596.4]' West from Southeast corner of Section 23, T8N, R13W, S.M. 5. Elevation in feet {indicate KB, DF, etc.) 105' D.F. 12. I 6 . Lease Designation and Serial No. ADL ] 8756 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C31-26 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations r"l Altering Casing Stimulate [] Abandon F-I Stimulation [] Abandonment · Repair Well [--t Change Plans [] Repairs Made [] Other Pull Tubing [] Other I--I Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Field 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any oroposed work, for Abandonment see 20 AAC 25.105-170). See attached. Subsequent Work Reported on Form No. ~ Date¢l RECEIVED, JAN- ~ 1982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig'.,edJ ~ ./~~ Title Mrg., Prod. Administration Thesp~cebe~owforComm~ss~onuse For' B. Nevill Date ...... 12/30/81 Conditions of Approval, if any: Approved by ' Approved Copy i Returnad By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in TriPlicate and "Subsequent Reports" in Duplicate C31-26 JUSTIFICATION Funds totalling $500,000 ($166,667 Shell's 1/3 share) are requested to replace the current production string (above the top packer) in C31-26 with new tubing, GL mandrels and valves. The economics for the workover are as follows: Workover Expense: Oi 1 Increase: PVP~AT ~ 14%: % PVP: Payout (AT): Ps: $500,000 ($166,667 Shell Share) 175-BPD (Total Gross) $560,000 (Shell Share) 340% 8 Months 1.0 With A Ps = 0.5 PVP: ($560,000)(0.5)- ($166,667)(:0.5)(0.5): $238,000 C31-26 was drilled and completed as the second well on Platform "C" in December, 19~7. I, nitial production rates' were 4887 BPD gross, 4887 BPD oil, 0% cut, 35.7 API 1725 MCF produced gas with a GOR of 353. The well was completed in the GR/GS through HN/HR zones. By January, 1973, the well was producing about 2000 BPD oil with a total gross fluid of around 2400 BPD. A few months later, after reperforating HC/HR zones, the well went wet. The water cut rose from 17% to 65%. An inflow survey indicated that'moSt of the water was coming from the HI/HK zone, a confirmed thief zone in the south part of the field. The single packer completion 'was pulled and replaced with a 5 packer completion in order to isolate water productive zones.. By January, 1974, the cut had cleaned up from 65% to 27% and produced oil Was back around 1750 BPD. In June, 1974, during wireline operations, a sliding sleeve shifting tool and one piece of Mallory stem became bridged in the ~tubing at about 5550'. Attempts to fish the tools over the next 3 years were unsuccessfUl. During this time production dropped from 1400 to 500 BOPD (21%/Year). In late 1977, an attempt to remove the fish with a snubbing unit and. dynadrill also failed. All subsequent fishing operations have failed as well. In January, 1979, while spotting acid on the fish, a hole was made in the tubing at about 5600'. At that time' the well was making 270 BPD oil with an 18% cut. Since 1979, the well has been lifting 2520' (TV) above the bottom gas lift valve. If the well could lift from the bottom valve, usi.ng a PI of 0.3 BPD/psi (conservative), an additional 175 BPD of oil could 'be recovered (assuming a constant water cut of 20%). For this reason and others' we propose to replace the 4-1/2" tubing string above the top packer with a new String of 3-1/2" tubing. The new tubing will allow us to run production logs, detect and remove scale (if any exists), evaluate and attempt to shut-off water producing zones as well as test potentially productive zones, and reperforate the HN/HR and/or perforate the HR/HZ (if warranted). Because of high rig costs at MGS and a 5 packer completion in C31-26, we believ~e that replacing the tubing abOve the top packer (vs. pulling tubing and packers), will be less costly ($200,000+ less) and involve less risk. In addition, if we are successful, this typ~ of workover procedure might be incorporated in other well work in the MGS field. RECI IVED JA N- 4 1982 Alaska Oil & Gas Cons. Commissior~ Anchom~P. ~ C31-26 ( PLATFORM "C" MGS FIELD STATUS: Fish consisting of one piece of Mallory stem and sliding sleeve shifting tool stuck in 3-1/2" tubing at 5594' (rotary table). Hole in tubing approximately 5600' from subsequent acid job'to remove fish. Current well test- 220 BPD gross, 176 BPD oil, 20% cut, GOR 136, 24 MCF production gas, 893 MCF injection gas. OBJECTIVE: Restore tubing integrity above packers by replacing 3-1/2" - 4-1/2" string with 3-1/2" string. A.successful operation should 1.) increase production, 2) remove scale in tubing above packers (if any exists), 3) allow production logging to evaluate current well conditions, 4) allow us to shift sliding sleeves-to open productive zones or exclude wet ~zones and 5) allow us to reperforate HN/HR and/or perforate HR/HZ (i f warranted). MECHANICAL DETAILS: See attached diagram. PROPOSAL: 1. Install and test lubricator to 3000 PSI. Retrieve ball valve at 325'. Run in with wireline and sinker bar and tag fish to verify depth. If scale is found above fish, remove with cutters before proceding with worksheet. Pull gas lift valve from mandrel at 4856'. . M.I.R.U. on conductor 5, leg. 1. Shut well in. Bleed tubing and casing pressure. Kill well by circu- lating 11.2 ppg lignosulfonate mud down tubing. e Set BPV in tubing hanger. Remove tree and install BOP. Test to 3000 PSI. Remove BPV. ' . Rig up G.O. ~ Run .in with chemical tubing cutter. Tag top of fish and pull up 10' (.into joint of 3-1/2" tubing aboye gas lift mandrel #4). Cut off tubing and POOH with wireline. See attached schematic. Ge . Stab into tubing hanger and circulate. Back out hold down screws and POOH with top half of tubing string. R.I.H. with drillpipe, jars, 1 joint of 5-3/4" wash pipe and Tri-State 6" x 5" rotary shoe. Mill over Camco KBM mandrel at 5604' (5.562" OD) to reduce OD to 5". P.O.O.H. . R.I.H. with drillpipe, jars, 1 joint of 5-3/4" wash pipe and Tri-State 6-1/8" x 5-1/8" outside cutter. Swallow 3-1/2" tubing stub and 3-1/2" Camco mandrel. Cut off tubing in 3-1/2"' joint below mandrel. P.O.O.H. Inspect 3-1/2" tubing and mandrel to check for fish. . RIH with drillpipe and overshot. Latch onto 3-1/2" tubing. Make wireline run to check tubing clearance past overshot. Run in with G.O. chemical tubing cutter to 8675'+ (rotary table). Cut 3-1/2" tubin~f~r_P~OH wi th wi rel i ne. KI:Li:Iyru JAN- 4 1982 Oil & Gas Cons, Commlssior~ lC. POOH with tubing laying down. Inspect bottom of tubing to see if cut is uniform qF' if tubing end is round. If ~F ing is out of round, run in withl,,,ll and polish off. Run in witfl,mpression block to check tubing. ll. Lay down drillpipe. 12. Run 3-1/2" tubing and production equipment as follows: ITEM DEPTH (MD) A. 3-1/2", 9.3#, N-80, EUE tubing B. 3-1/2", KBUG Mandrel with dummy 8652' C. 3-1/2", KBUG Mandrel with valve 7982' D. 3-1/2", KBUG Mandrel with valve 7251' E. 3-1/2", KBUG Mandrel with valve 6089' F. 3-1/2", KBUG Mandrel with valve 4938' G. 3-1/2", KBUG Mandrel with valve 3507' H. 3-1/2", KBUG Mandrel with' valve 1850' I. 3-1/2" tubing as above J. Otis "XEL" ball valve nipple (2.313 ID) w/dumn~y 300' 13. Tag poliShed-off 3-1/2" tubing, stub with production string and space out. 14. Rerun production string with Otis 3-1/2" overshot packoff. Run in tubing with 1/4" hydraulic'control lines attached to ball valve nipple. Ae Install Otis ball valve nipple 300'+ below tubing hanger. Install dummy in nipple and run in place. Be Before running 1/4" line, flush complete coil with hydraulic fluid and test to 5000 psi. C. When 1/4" line is made up to tubing hanger, pressure test to 5000 psi. 15. Stab pack-off over polished-off tubing above packer. Pick up on tubing with 10,000 lbs. to engage slips and expand packing element. Slack-off 2'. Land tubing hanger in wellhead 'and lock down hanger with hold down screws. Open annulus and pressure on tubing with 1000 psi to test pack-off. Close annulus 16. Install back pressure valve in tubing and remove BOP. Install and test tree to 5000 PSI. Remove back pressure valve from tubing hanger. 17. Install lubricator on tree and test to 3000 psi. Run in with wireline and pull dummy from'mandrel at 8650' (MD). Circulate mud out of hole with filtered inlet water by pumping down tubing, Circulate until returns are clean. 18. Retrieve dummy and replace with bottom gas lift valVe. 19. Put the well on (GL) production. After well cleans up, test frequently to monitor production and then test as per regular test rotation. KJE-ckk JAN-' ~ 1982 Alaska Oil & Gas Cons. Commissior~ Anchorage APPROVED DATE C31-26 GAS LIFT DESIGN VALVE NO. DEPTH TVD MD 1850 3500 4900 6000 7100 7800 8450 1850 3507 4938 6089 7251 7982 8652 SET PRESSURE 900 905 910 915 965 965 950 VALVE TYPE CAMCO BK CAMCO BK CAMCO BK CAMCO BK CAMCO BK CAMCO BK CAMCO BK ORIFICE SIZE 3/16" 3/16" 3/16" 3/16" 1/4" 1/4" 5/16" RECEIVED JAN- 4 1982 OJJ & Gas Cons. Coj~]rnis$ior~ ~chorage C31-26 R&R COST ESTIMATE OPERATION Break out tree, flange up BOP Cut and retrieve upper tubing Back off and/or cut off lower Run new tubing Break out BOP, flange up tree. tubing and retrieve Activate rig 12 rig days @ $20,000 8700' of.3-1/2", N-80 Production Equipment 7 KBUG mandrels @ $1800 7 BK valves @ $700 Otis ball valve and pack Mud Di a-Lo g Tri-State per day tubing @.$10.75/ft. off overshot Contingenci es @ 10% SAY RIG DAYS 1 2 6 2 1 12 · $ 2o,ooo 240,000 93,525 12,600 4,900 5,000 50,000 lO,O00 lO,O00 $446,025 44,6O2 $490,627 $5oo,ooo Shell's 1/3 share = $500,000 : $166,667 KJE:ckk JAN- 4 ]982 Oil & Gas Cons, Commission C 31- 26 "' DATUM Item # Description 15 16 17 18 ' 22 · 2, 3, 4, 5, 6. 7.' 8, 9, .lO, ll, 12, ~ 13, 14,' 15, 16, 17, 18, 19, 20, 21, 22, 23, .24, 25, 26, Safety Ball Valve Nipple Camco KBM Mandrel Camco KBM Mandrel Camco KBM Mandrel. Camco KBM Mandrel Camco KBM Mandrel Camco KBM Mandrel Camco KBM Mandrel Camco KBM Mandrel Camco KBM Mandrel Otis Type "XO" Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel Otis Type "XO" Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel Otis Type "XO" Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel Otis Type "XO" Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel Otis Type "XO" Sliding Sleeve Guiberson RH-1 Packer Otis Type X Landing Nipple Otis Type Q Landing N~pple Tubing Detail 3½" 9,3#/ft EUE (43 joints) 4½" ll.3#/ft LT&C R-2 (246 joints) CaSing Detail 7" N-80 Buttress 23#/ft 0-5000 26#/ft -5600-81 O0 29#/ft 8100-9927 JAN- 4 1982 Al~s~ Oilk & Gas Cons. Commission Anchorage Page 95 325 2486 3816 4856 56O4 6194 6720 7632 8543 8639 8705 8712 9075 9081 9090 9190 9196 9207 9278 9283 9301 9436 9441 9451 9460 9462 Perforations GR-GS HC-HD HE-HF HI-HK HK-HN HN-HR 8742-8780 9037-9069 9144-9194 9258-9297 9311-9448 9471-9610 q~o ~/~o ?/~ ZO - JAN- z~ 1982 -Alaska 0ii & (las Cons. Commissio. Anchorage ~1~ lq, G4 Ob fo ~.oo JAN- z, 1982 Alaska Oil & Gas Cons. Commiss[o~? Anchorage .. IL2-E A.P.I. CODE · 50-133-2~0052 OM-12 Release Date _ 1-_9-_?0 ..... State of Alaska Dep~rtment of Natura! Resources DIVISION OF MINES AND MINERALS Petroleum Branch Sec._ _~(_ 2] T. , Operator Shell Oil Co. Lease or Ow.er ...... Meridian INDIVIDUAL WELL RECORD _ S Permit No. Issued 10-.20-67 Conductor 5, Leg. 1 Location (Surfac~)536.91 FSL & 1593.01 FEL, Sec. 23 Loc. (Bottom) 1062' ~L' &:1767' F,~L~ Sec. 26 __ _: ~ , i _~,, ~ ~:~. _ , ,,,L _ _ ~ , ,~ .... ,. Wel I No. C-31-26 Area M.G.S. ............. - ................. ! --- i .............. ....... ' ........ ' ' -""""~'~zu 9849' 5pud Date 10-27-.67 Drilllng Ceased 12-4.-67 Total Depth 9935' : Sus~n~d ~ndoned E I evat i on 105 ' Completed (F-Ctt~IP/), 12'9~-67 __ IP 4887 B/D, Grav 35.7° APl Cut 0.0 % Gas 172S.._.._._....HCF/O, Bean !28_ .... /64 CP 0 .......psl, TP 130 ._ psi Casi.ng: _ SIze. 10 3/4"-40.5~; ' Comb. 3~" & 43~" GEOLOGIC FOR~TI~S PRODUCTI:VE XORIZ~$ Surface , ~S~ ,T,ested Na~ __ Depth Contents WELL STATUS Year Jan Feb', Nar Apr May_ June July Aug., Sept Oct Nov Dec ~ ..... SHRLL OIL COMF'ANY 430 'TTH AVENUE ANCHORAGE, ALASKA 995~1 1967 Confide-.:; t !.c ! !-~:~ te:,:i.,, ! / Very truly yours, R.D. Allen Division Exploitation ~'~ bce: Standard Oil Company of Calif., attn J. Cloidt Atlantic Richfield Oil Company, attn S.Wo Kingsbury Pan 2~ar%can Petroleum Corp., attn. J.H. McKeever U.S.G.S., attn W.J. Linton Area Production State of Alaska, Division of Lands, attn Pedro Denton RECEIVED FEB 2 0 19DB DIVISION OF MINES & MINEIb~8 k~3HORAGE SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 JAN - 4 I9~8 Ve:ey truly R. D. R.D. Allen Division Enclosures bec: Standard Oil Company of Calif., Attn J. Cloidt Atlantic Richfield Oil C~mpany~ Attn S.W. Kingsbury Pan American Petroleum Corp., Attn J.H. McKeever U.S.G.S., Attn W.J. LLnton Area Product ion State of Alaska, Division Of Lands, Attn Pedro Denton SHZLL OIL COMPANY 430 7TH AVENUE ANCHORAGE, ALASKA 99501 January 4, 1968 Confidential Material STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention ToR. Marshall~ Jro Gent lemen: Enclosed are the Monthly Report of Operations (2 copies each) for December~ 1967, for our Middle Ground Shoal wells, A-14-1, A-33-14, C-23-26 and C-31-26. Very t~uly yours, RoDo Allen Division Exploitation Engineer Enclosures Form Ne. P--4 P,~'V. 9-30-67 O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL ~ GAS WELL ~ WELL SUBMIT I/~ DEPLICATE 2. NAME OF OPERATOR 8hell Oil Company 3'. ADDRE~JS OF 0PEI:~ATOR OTHER 430 Seventh Avenue~ Anchorage~ Alaska 99501 LOCA~ON OF ~ Conductor 5~ 4o74'S & 3.40'E from center of Leg 1 @ 541. 65'N & 1596.41'W from SE corner, Section 23, T8N~ R13W, S.M. -~. AP1 NUJ. IERICA_L CODE 50-133- 20052 6. LF.,ASE DESiGNA'fION A%-D SE'iRIAL Iklo. ADL 18756 7. IF INDIAN, ..%LOTTEE OR TRIBE NAAIE None 8. LqX'IT,F.~:CM OR LEASE NAAIE Middle Ground Shoal 9. WELL NO. C-31-26 10. lfllil_,D Jk.N'D POOL. OR WILDCAT Middle Gzound Shoal 11. SEC., T., R.. AiL. /BO~i'O.M HOLE OBJECTIVEI Sec. 26, T8N, R13W __ 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING 19.. P]KR/ViIT NO. 67-63 JOBS INCLUDING DEPTH SET A/ND VOLU1VIES USED, PE/:LFO.RATIOiN~S, TESTS ANT) 1R~ESULTS. FISHING JOBS, JLrNK I_N HOLE AND SIDE-/q:LACKED HOLE AND WY OT~IER SIGNIFICANT 'C'H. ANGES IN HOL~ COi%rDITIONS. Drilled and cored 9-7/8" hole to 9875'. Cored the following intervals: 9718- 97 45 ' 9745- 977 5 ' Ran Logs. Drilled 9-7/8" hole to 9935', Ran Log. Cemented 7" casing at 9927' with 1350 sacks. Ran Log, Ran combination 3-1/2" & 4-1/2" tubing to 8687' packer at 8607' Perforated with 4 jets/ft, 8742-8780'~ 9037-9069' 9471-9610'. Placed well ,on production Released rig 9:00 p.mo 12-9-67 :, 9144-9194', 9258-9297' , 9311-9448' RECEIVED ANCHORAGE hereby certify ~/hg~if~ is/~a~ ~rec~ .... ,stoma /s-,~ ~/-///z.~ ~u~ Division Exploitation En~.~ /-- 9z--ffZ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~tise directed. SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 December 28, 1967 CONFIDENTIAL MATERIAL STATE OF ALASKA Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gentlemen: Attached are two copies of the Well Completion Report for our SAS Middle Ground Shaol C-31-26. Included with the report are the following data: Composite Log (Sepia & Pring) Directional Survey (2) Well History (2) ..Core Summary (2) Very truly yours, R.D. Allen Division Exploitation Engineer WH/mm Attachments RECEIVED DIVISION OF MINES & MINERAb,.~ ANCHORAGE Form P--7 _.ATE OF ALASKA '~Se~ structions on OIL AND GAS CONSERVATION COMMITTEE reYe,'se side, ' L WELL cOMPLETION OR RECOMPLETION REPORT AND OG* WELL TYPE OF COMPLETION: WELL OVER ES BACK nESVR. Other 2. NAME OF OPERATOR SHELL 0IL COMPANY . a. A.DSZSS Or O~aATOa ARC1 .qo. von t_h Avenue_ Anchorage. Alaska 99501 ~. LOCATION OF WELL~Rep0rt lOOgtiO~ {~lesr?u ~tlSd i~$¢~O~'d~Og With tl~ll ~t~tg requ{rements)* At surface_ Conductor 5 4.7~~ S & 3.40' E from center Leg i @ 541,65' lq & 1596.41~ ~ £~m S.E. corner Sec. 23, T8lq, ~13~, S.~ At top prod. interval reported below (8~"42') 931' S '~& 1585' ~ from lq.E. corz sec. 26 T8N, R13~, S.M. At total depth (9935') 1062' S & 176~' ~ from N.E. corner Sec. 26, T8N, R13W, 0BlGIItk 13. API NITMF_,RZCAL CODE 50-133-20052 s. ,.~SE D~S~NX~ON ~mD 'h~ ~o. ~ ADL- ~8756 9. WELL NO. C-31-26 10. FIEI_,D ~ POOL, OR WII-~CAT MIDDLE.. GROUND SHOAL 11. SEC., T., R., M., (BOTTOM HOLE · OBJF_~IVE) er Sec. 26: TSN, R13W, S.~. 19.. PER1VIIT BrO. S.M. · . 67-63. 17. ELE~. CASINGHEAD ]~.~EVATIONS (DF, RKB, RT, GR, 10/22/67 12/4/67 12/9/67 105' D.F. .. ~ ----- DRILLED BY (9 ) 99 sow iViA/NIY* CABLE TOOI, S 708' 9849' (9623:) ~OTA~ ~OOLS 9935' 22. PRODUCING INTERVAL(S), OF THIS CO,1ViPLETIOffq--TO~, BOTTOM, NA1VIE (MD AND TVD)* 23. WAS DIREC~rIO,NAL SURVEY 1VIAD E 8742~ F. Pool 8742~ (8538~) 9610' G P0ol 9'610' (9389') .I yes 24. TYPE EI~ECTRIC AND OTHER LOGS RUN ~!:;,~.:~.' ~ BHC, PML, FDC, GR-CBL. ; DIL .... ~': cxsm~ RECORD (Report all strings se{ in we{i) ' ' ' " i 1 .o= I -j,,, C~S~G SIZ~ 7 ~}, 26'~. 29 ~ ..[ 1895"'1600 sacksnone S~Zm,.~_~ '[[, F TOp (~D) ~ ] [ BOTTO~ (~D) [ ~m{ o bination } 1/2" &[ '3- 4-1/2" 8687" i 8607 ', ~8. PE~O,~TIONS OP~ TO P~OD~O~ (inte~a], size and number) MD. ACID, SHOT, F~CTU~, C~IENT SQUEEZE, Perforated 1/2" holes, 4' jets/foot, 8742~ 8780~ 9037-9069; 9144-9194; 9258-9297; 9311-9448; 9471'-96-10. i i 30. PI%ODUCTION I AMOUNT PULLED DATE FIR,ST PIioDuCTION 12/10/67 DATE OF TEST, ~I-iOT~S TESTED '[C~'IOI{E SIZE PROD'N FOl~, ! ' ,. [ T~S'r PE2~OD _%2/13/67, [- 24.'" 1128/64" ~' FLOW, ~B~G [~S~G ~SU~ [CALC~ OI~BBL. ~. ' . [ , 'tm-~°UR ~ 1 1~0 psi. I -0 psi.. ! > [ 4887 31. DISPOSITION OF GAS (8old, used.for ]uel, vented, etc.) , Vented ~- 32. LIST OF ATTACHMENTS PRODUCTIO'N METHOD (Flowh~.g, gas lift, pamping--size and type of pump) F 1 ow i n g OIL--BBL. ] 4887 ...l 1725 WELL .STATUS (Producing or ~t-~n~ Pr oduc ing G~S--MCF. WATE1R~BBI~. [ GAS-O~ ~O j I o i a a. WA~B~. ! OIL GR~VITY-~I (CO~.) ]0 ~ 35.7° TEST WITNESSED BY Well H~storv. Directional Survey, Sepia & Print of Composite, DIL, Core Summary. 33. I hereby certify hht the'f.oregoing d .ttached information is complete and correct as determined from alUavallable records sto~mm ~-~ *(SeelnStructio"s I~'wtWt,m Div. Ex.ploitation Engineer mawE and Spaces for Additional Data on Reverse Side) DEk-~IX{ INTERVAL (MD) 2tMOUNT .~ND 'KiND O,F ~IATER/AL USED INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of tan. Js and lea'scs in Alaska.: Item. 16. Indicate which elevation is used as reference (where-no, otherwise shown)for depth measur;-a~V~4, mentsgven in cther spaces on this form and in any ~ttach~ents. ''~ lt~m~ ]~, ~J 2].' If th s we s cempeted for separatc.~ Product.on from more than one nterv~one?[~2 (multiple completion), so, state in item 20, and in item 22 show the prc~uc~ng interval, or in~rv~ls, ~, ~,~ ~ ~:~ top(s), bottom(s) and name (s)(if any) for on y the interval reported in item 30. Submit a separate ~t (page) on th s form, adequately dent f ed for each ad6itional inte~ va[ to be seperately produc~ sho~ . .. . . : ,. . , ~ng the a~ltlonal data pertinent to s~ch ~ntervat. · It~m2~: "Sacks Cement": Attached- supplemental recOrds for this well should show the details of any m~l- - tiple sta~'e cementing an~ the Iocation~ of the cementing tool. Item 2~: Submit a separate completion re~rt on this form for each interval to ~ separately produ~. (~e instruction for items 20 and 22 above). . : 34. SUMI~'ARY OF Ii'ORMATION TESTS INCLUDING INTERVAL TF-,STED,. P~UR~ DAT~'~ ~OV~I~, : , OF 8IE~' G~,- [ "' ~ G~GiCi :'* ' ' WA~ AND MUD ' : ~ ~ 'x -~:; ~.. . ' . . ,: . . -,'_ , ~ ~; ~.': _. , . .. . ' : ~ Po°l ' 8780' , 857~' . ~ Pool 9037~ -: 8827 ~ : _ ' . : . ., 30. COIT.E DATA, A~ACIi .BRIEF D~CRIPI~ONS OF LITHOLOGY, POROSITY. FRAC~R~, APP~NT DIPS - ' AND DE'PECTEI) SHOWS OF OIL, GAS OR WA~. '~ See . . , , PD 4A (Reu. ~-63) Prin~ed in U.S.A. I~DDLEiGROUND SHOAL KENAI (COUNTY} DAY -j' DF. PYH$ 1967 361 7OO 1925 196Z 5388 ., 18-1/2 15" 9-7/8 8127' 8255 700 1925 1925 5734 C~ 8127 Sec. 26 (s,,mr~o~ or~ ~.~.~) ~8~ R13W (rowNsm~ o~ '~,~Nc~ o) 8255 9718 .' 361 J 390 i 390 J1925 10-3/4" '1925 19718 DRILl., PIPI-'- 5" REMARKS Location- Conductor 5, 4.74' S & 3.40' E from center Leg 1 @ 541.65' N & 1596.41' W from S.E. corner section 23, T8N, R13W, S.M. Elevation- Derrick floor 105' (MLLW) Spudded 7:00 A.M. 10/22/67 drilled 18-1/2" hole to 390'. Drilled 15" hole to 700' turbodrill #1 390-450' faced S15E. Drilled 15" hole to 1925'. Circulated hole for casing. Cemented 10-3/4" Casing at 1895' with 1600 sacks. Ran 10-3/4", J-55, 40.5#, seal lock casing with shoe at 1895' and fill up collar at 1851' Pumped in 100 cu ft of water ahead of 1400 sacks of class G cement (96 pcf slurry) mixed with 10% Bentonite. Followed by 200 sacks class G cement (118 pcf slurry) mixed with inlet water. Displaced with 1050 cu ft mud. Bumped top of plug with 1000 psi. Flanged up BOPE. Tested BOPE and blind rams with 2000 psi tested Hydril with 1500 psi. Drilled with 9-7/8" hole to 5388'. Mud 71-73 pcf. TURBODRILL #2 2991-3109 Faced S15E TURBODRILL #3 4193-4228 Faced S73E Reamed 5340-5404' Drilled 9-7/8" hole to 8127' Mud 73-75 pcf[. TURBODRILL #4 6402-6412 Faced S83E Conditioned hole for logs. Ran Dual Inducti-on Laterolog. Run 1~ 1899-8114'. Drilled 9-7/8" hole to 8255'. Drilled 9-7/8" hole to 8440' Mud 72 pcf. )NDITiON AT BEGINNING OF PERIOD DEPTH SET '1895' CORE NO. 1. 8440-8454' RECOVERED 6' CORE NO.. 2. CORE NO. 3. 8454-8457' 8758-8761.5' RECOVERED 0~ RECOVERED 3.5' CORE NO. 4. 8761.5-8788' RECOVERED 26.5' ., CORE NO. 5. 9050-9080' RECOVERED 30' CORE NO. 6. 9165.-9188 RECOVERED 6.3' · PD 4A (Rev. ~ ,~-oo/ Printed in U.S.A. MIDDLE GROUND SHOAL $,HBig OIL CO~IPANY ]3RI ING RBPORT ~O~ PER/OD December 6, 1967 Sec. 26 (~=-¢T~O~ O~ L~) T8N R13W (?ow,s.m =- j: D;~PTH$ DAY ~o~ TO 9718 9875 9875 9875 9935 ' PBTD 9 8~ 9 REMARKS CORE NO. 7 CORE NO. 8 CORE NO. 9 CORE NO. 10 CORE NO. 11 CORE NO. 12 CORE NO. 15 CORE NO. 14 CORE NO. 15 CORE NO. 16 CORE NO. 17 CORE NO. 18 9188-9206 9270-9280 9378-9403 9403-9463 9463-9497 9508-9545 9545-9585 9615-9622 9622-9629 9629-9635 9660-9686 9688-9718 RECOVERED 31' (13' from cor~ #6) RECOVERED 9.5 ' RECOVERED 25 ' RECOVERED 57 ' RECOVERED 37' (3' from core RECOVERED 37' RECOVERED 18' RECOVERED 6 ' RECOVERED 4 ' RECOVERED 7' (1' from core #1o) RECOVERED 26 ' RECOVERED 30 ' November 11-30 continued Drilled 9-7/8 hole 8255-8440', 8457-8758', 8788-9050', 9080-9165', 9206-92/70', 9280-9738', 9497-9508', lost iron off core barrel #13, Ran in With bit and junk sub. Drilled 9585-9615' recovered small amount iron in sub. Drilled 9-7/8" hole 9635-9660', 9686-9688' mud 74 pcf. CORE NO. 19 CORE NO. 20 9718-9745' 9745-9775' RECOVERED 22' RECOVERED 30' ,, Drilled 9-7/8" hole 9775-9875' Mud 74 pcf. Circulating to ru~ logs. Ran Dual Induction Laterolog Run 2 7900-9846' Borehole Compen - sated Sonic Log~ ,Run !,7000'-9840'; Proximity-Microlog Run 1~ ,7 ~000-9850' . ! :' Drilled 9-7/8" hole to 9935'. R~n__C0mpensated. F.o. rmatiq~_Dsn_s~ity Log Ru._q _1 7000~-9888' Cemented 7" Casing at 9927' wi~h 1350 Sacks. Ran 7" (23#, N-80, . .~-rface-5;.3%0~ 76~.,~-_~ , 5,350-7,917'; 29E N-80 1917-9927) Casing / .o~.~ ~ ~,~'-;~ ~,,'r,s~ I ! 390 ~925 .10-3/4 '1895' ~ PD 4A (Rev. 5-6S) Printed in U.S.A. · $~T~,.U. OIL CO~ANt¢ DRILLING REPORT EOR P~,IOD L~,iDI~G December 9, 1967 w~u. ~o 6 - 31 - 2,j__. Sec. 26 (S£CTIO~ om T8N, R13W (?OWNSl-liP oR i~.ANCHO). DAY DEPTHS FROM PBTD PBTD PBTD 9849 9849 9849 CONDITION AT BEGINNING OF PERIOD HOLE CASINO SlZ~ DEPTH SET _ SlZg [ FROM, I TO,, 18-1/t';361! 390 I 3611 1925 9-7/8 '1925 9935 ,[. uomDln DRILL PIPE mz~ 3 - 1/2 , ,,, , . 10-3/4 7~t tion of ~ 4-1/2" REMARKS with shoe at 9927' and fill-up collar at 9849'; Cemented with 200 cu ft water ahead of 1350 sacks class G (118 slurry) mixed with 1% CFR-2 . Displaced with 2154 cu ft Inlet water. Bumped plug with 2500 psi. Float shoe did not hold. Held pressure 7 hours. Installed well head and tested to 2500 psi. Ran Gamma Ray - Collar - Cement -Bond log run 1, 5700-9818'. Ran combination 3-1/2" and 4-1/2" tubing to 8687', packer at 8607; Installed and tested tree with 4000 psi. Perforated with 4 shots/ft 8742-8780' 9037-9069' 9144-9194' 9258-9297', 9311-9448', 9471-9610. Placed well on production. Released rig 9:00 p.m. 12/9/67. 1895' 9927' rub ing CORE # 10 11 12 13 14 15 16 17 18 19 20 INTERVAL 8440-8454 8454-8457 8758-8761.5 8761.5-8788 9050-9080 9165-9188 9188-9206 9270-9280 9378-9403 9403-9463 9463-9497 9508-9545 9545 -9585 9615-9622 9622-9629 9629-9635 9660-9686 9688-9718 9718-9745 9745-9775 3.5 27.5 30 6.3 31 9.5 25 57 37 37 18 6 26 30 27 30 M.G.S. C-31-26 CORE SUPR~ARY Sd, no shows Oil sand, good P&P, good shows Oil sand & conglomerate good P&P, good shows Oil sand, good P&P, good shows Oil conglomerate, good P&P, good shows (13' from core 6) Oil sand & conglomerate, good P&P good shows Oil sand & conglomerate as above Oil sand and conglomerate as above Oil sand & conglomerate, as above (3' from core 10) Oil sand & conglomerate, as above Oil sand & conglomerate, as above Oil sand & conglomerate, as above 5' oil sand & conglomerate, as above 1' siltstone, no shows Sandy siltstone, no shows (1' from core 15) sandstone & siltstone, no.shows Oil sand & conglomerate, fair P&P, fair shows 2' siltstone (9680-82), no shows Oil sand & conglomerate, fair P&P, fair shows. Interbeds of sand, conglomerate & siltstone, no shows Oil sand & conglomerate, fair P&P, fair shows, interbeds of sand and conglomerate, no shows 3' o~1 sand, fair P&P, fair shows 27' sand, poor P&P, none to trace shows. SH~LL. O~L CO. i~ ~,~i~ i iii i i IN'cA, VERTICAL DEPTH CUM. BEARING LATITUDE: DEPARTURE 'TOTAL ~:.EAS.I$-i.,A.,ANGLE , OF · LATITUDE"· DEPARTURE SECTION' NoRTH'II'sOUTH EAST' WEST )EPTH IDIST. COURSE TOTAL LOSS DEVIATION ., ,. NORTH': SOUTH EAST WE'ST.... o ¢_. t.=.~' ~. , , :, ' , ... --- "~'-,".' 0 ~ C >~DC c..- 'oi~ ~ ' ~ ~ · 4 74 :."~"~, 40 · 7~; "/~ o°oc~ ?~;oo ..."/5o:~ . ' . ' . ' . .. 4~:?4: ..~,~ · I~-O 'l-go°os' 2g mo ' 15ooo · ~ ~ 7~ E · ol - i - ' ...... : ..... .," · ~75~Zg ooo$' ~oo 17~' U Z~. E o3 cZ ~ 7~ 3 SI' . 200 2~ o°ld ~s ~ 200 co uSt~z ct_ . o7 ., 4?s "~~ . Zz,¢ z~ oood zs~z2~ sso w~ , . .. cz o~ ~ w~ ~ 4~, " 3~oz~, 0%0, Z~ .~~ ,,,:~ · ' 4 ~o ~s~ ' , . ~61 I~ o°os' I~oo 3~ ~ ~ 95~ oO o~ '"4 ~o 'B ~ ', I ' . .... .~ ' , ~ ' · . . ", ~ ,,, . azo~9~%8, $~ 08,~9'9~cz5 so ~ .. 99,,,--~ ~e.. ',. ~5,... 4 69 , ,, 5 Ce~ ,442cod 45 97 ~.gs . o~ 5 ~oE , ...~1 .z7. ... '7to .. 49& 7..lo~ 3~8 ZI7 .1°3o'Zl69~ ,85~7S: ,,, Z~iS~ 15 E, ............. S. 4~ 1.48. .t~ , . 18-S~ 8¢g -',,~,', '18.,35,,, 'F_,LLi C- '51- 7..G; ....... SPUD DATE: AIoV.:'zZ, lOG.7 ELEV:'i 105' O,.l:', CAL:CuLATED. 'BY:.. . .... ..S SHE. LL CO. BEARING I LATITUDE DEPARTURE · TOTAL . ,:','~-~, VERTICAL DEPTH CUM, DEPARTURE · SEcTiON! ': 'lAS' I STA.I ANGLE OF , LATITUDE ~I:PTH DIS-F.~ COURSE TOTAL LOSS DEVIATION NORTH I SOUTH EASTr WEST NORTH, -SOUTH EAST WEST ', , - ' ' i . . ·., .E. ~IS7 6~ ~00' 62~9 51849~ Z04 5 ~ ~' 873 7~ ' &l 7S 1~4~ .. . 54~9,157 IZ°o8 134 ~ 7o,5 'Z s .Z8'47,, , I oo ., SO7 93, ' ;, '. l&.O~ Io7 ~8~ I~S 80~d 153 ~0' ~4Z ~9 1481 5 ..' , , 2Z91, . ' 19oGc 'l.~ ~ 1.9o 302.0~Z 9'45' GIJ!l. 4oo~ J51~875 Z ,W lo49~ , , 57 , ZI644 ' I~'&4 'II'G 44 ~z~o~ ~oZ,,!l*o8 lOO IZ 4Z57 9) ZZo75 IS E ,.188c 5o4 Z~717 ' 16,SZ Z~7'17: 3~z~z9~8G~ ,e 4~,~osZ29z 5Z4E ~~s 41~. zT~.sz . il ~ zT~.st~ $4~ 51 II%d 5o4544~8o7 'Z49~ 5Z E ,SOZ 3 15:~, ,~945° .i I.~ -. ~2~ Go I1'1;' ~8~5 44%9Z ,26 o~ S Z9 E ,,I,o'Z4 b-G$ . , 504 74 G 86 ~sS4~ lZOodggG~ 4~s~S Z74Z5 ~ E~. lo~7 ~g~ .5~1 15~9. ., , +~l' 'gZ~i~'J~,88 7& 47~1 ~Z ~4S 5 24 S., "ZZ JI '9S4 5~S~ ~Z94, · ', , ELL C' ~%' ~ ~ .... SPUD DATE: ktOq'' Z'Z.,.' le~7 ELEV: J. ~ t,'. I-.. 'CALCULATED By.:~ sHEET: J SM LL 0 CO. =,~.^~ h,.,~At G I VERTICAL DF-PTH BEARING I LATITUDE .DEPARTURE TOTAL '"-'"'.'. tl.q'¢,~ CUM · :)SPTH/!;,.~r~ AN L.E ' OF .LATITUDE. 'DEPARTURE SECTION llL)lbl COURSE ·TOTAL LOSS DEVIATION NORTH SOUTH EAST 'wEST ~NORTH t SOUTH. EAST WEST ' ,,, ' ~ ,,,, , ·, , ,, ., , ~9¢,"/ 94- 1"/°o51 8,9 8,9' 4'9 IG 27 4o '15 $ '7..0 E 2'¢, ,~Z 9 4'0 " 4.0¢ "/?.- 5z'"/8 405 7? 3o5~_95 17°4¢' 9~48 5o°G.7~ 4~; 5, 16 .E. ?.7.$& "7 98 '. 540~z7 ~7°oc~ I?-I 4S 5~4o58 (,~, 4zS IZ a ~:~Z 7 5773 ,14z17°od lES79 S69~ 47 76 ~5 s ~ E ;, ~.l Se 590¢ I%Z~S'o~IZ~SSZ~oZ 8Z98 ~ ~ ~ '4o74 '2 1,4 ~So44 9~5 ' ~8o44 ~oS5 ~so ~7~,5' 17~ 9o ~99~9zl,, 9~ 08 5 ., 5~'~7 ........ 7~s~9995 , 1'~~sl - . ~e~ ~9 ~°4g ~,~~l~%~ o5 9~97 5 4 ~ 399& ~ 2 79 · ~73~.7797 16 " n7577 ' ~ ' b44¢ 74 18°o~ 7o 5~ ~7 41 1ol 59 S 4 ~W 2Z B1 , . .~ '' , be~t 14~ ZO°l¢ ~'3~o4~559Z~ IZl 7Z S 8 ~ 49 7J~'] ...~ '~. '9Z°77 9971 ~9~ 171Jg~d I~l~Se~94Sl 1~619S G e J, ",56:77 lls~IZ6: 18'~¢~,1,9 49t 1o~ 141 145 I,E ....... 399~ I 7~ 14~ 17~5' 159oS~7z4~oS 15~9ZS 4 W ~~ ] ..... . ~ ._- . . ~sTo ~,,1~%4 ~1 9 i4o2$1 ~7 J~ S ~'W 4So~ 4~2J. -. ~2oo , ,,, ",,, i i i i ~ i ~ iii ' i ' , , ' , ,E. LL C: '5 ! - '?., (o SPUD DATE t4o'v'. 'J9~7 EL : J 0 S P. F'. CALCULATED ' ' . , ...... _ .... ; ....... · Y: HE. -- i i I ii iii I ~ '. i J" I i i I MEA. VERTICAL DEPTH CUM. B,-ARING. LATITUDE' DEPARTURE' ' · TOTAL. !SE(; tON EAS. STA, ANGLE, OF ~ LATITUDE DEPARTURE T 2'PTHiDI$'i'. ..C.:0URSEI! TOTAL LOSS DEVlATION'I NoRTR SOUTH EAST WEST NORTH I1 SOUTH- EA.~T" II WE$'~' , · ~-, _ . ..... ' )~l, llt~ll'l'5~ IIZ ~>9 SScZ~?.i Z~ 85t5 5~ ~v. l~b¢ ,, ~ ,~*~,-, ' ' '~- -A~.*'-"-: m I I I [ I ml I lmm I) ) i ml m j , I ...... [ m 'm m .. ..L -..t .... )_,........,,. · ...... . .... It-t ~ , ) .~... /! I I . I , ' ' ,, . I .I" t~~':,~ . ~ ~' "' ' ' . ' '.-~, i , ' . ! ._. i~-,'._.Z. .- ..... : :_ ,, ~ ' '. . ' . · . ~ -" : .. ' , ' '", ,', ,," ~' '~ SPUD D~TE: NoV' Z?o~ t9¢~7 EL[V:.IO$'D'F'., . C~LCuLATED aY.' SHE T: : ' , .... .' : ' _'" ----- Form No. P--4 STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT EN DEPLICATE 1. 0IL ~--~ GaS ~ WELL ~ WELL~ OTHER NbdViE OF OPEP~TOR Shell 0il Company 3. ADDRESS OF OPERATOR 430 Seventh Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Conductor 5, 4.74'S & 3.40'E from center leg 1 @ 541.65' N & 1596.41'W from SE corner, Section 23, T8N, R13W, S.M. CODE API 50-133-20052 6. LF~a~SE DESIGNATION AND SEI~tAL NO ADL 18756 7. IF INDIAN, ALOT%FEE OR TRIBE NAAIE ,.,---- 8. LL~'IT,Fbd~M OR LEASE NA-ME Middle Ground Shoal 9. WELL NO C-31-26 10. FI~ AND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE ~ ,, Sec. 26, T8N} R13W, SoM. 12. PEiR2VIIT NO. 67-63 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ANI) VOLUATES USED, PER~ORATIONS, TESTS A_NY) RESULTS. FISHING JOB~, JUNK IN HOLE AND SIDE-TRACKED HOLE AND A_NY OTHER SIGNIFICAI~T CI-I3kNGES IN HOI~ CONDITIONS. Drilled 9-7/8" hole to 8255'. Ran logs. Drilled and cored 9-7/8" hole to 9725'. Cored the following intervals: 8440-8457' 9270-9280' 9660-9686' , 8758-8788' 9050-9080' 9165-9206' , 9378-9497' 9508-9585' 9615-9635' , 9688- 9718' 14. I hereby certify SIGNED Division Exploitation En§r~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. SHELL OIL COM, PANY 430 7TH AVFNUF' ANCHORAGE:, ALASKA 99501 October 24, 1967 Subject: Middle Ground Shoal Field Well C-31-26 State of Alaska Division of Lands 344 Sixth Avenue Anchorage, Alaska Attention Mr. Pedro Denton Gert t leme n: As provided in our State of Alaska oil and gas lease ADL 18756~ we hereby advise you that on October 22,. 1967, Shell spudded the subject well on said lease from Platform C. The well will be bottomed under the NE/4 of Section'26, T8N-Rt3W. ' ~ We have previously called to your attention that both of our leases in the Middle Ground Shoal field (ADL 18754 and ADL 18756) are held by production from a number of wells; We ask that you consider relieving us of the obligation of advising you each time a well is spudded on either 'of these leases. We will appreciate your con~nents. Yours very truly, ...... · < ...... . ..... ".;' ~;'"' .~'2~ ./~.-'2 ~o So C~te Division Land Manager SHELL OIL COMPANY 430 7tH AVENUE ANCHORAGE, ALASKA 99501 November 1, 1967 Confidential Material STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gentlemen: Enclosed are the Monthly Report of Operations (2 copies each) for October, 1967, for our Middle Ground Shoal wells, A-12-12, C~34~23, and C-31-26. Very truly your~s, R.D. Allen Division Exploitation Engineer WH/mm Enclosures RECEIVED NOV 2 1967 gll¥1$1ON OF MINEB ~ MINI~ ANCHOP, AQE Form No. 1~--4 A_PI #50-133- 20052 Effective: July 1, 1964 ~ -~.~ ~L 18756 ~ =~ =~,~ ~ MGS OIL AND GAS CONSERVATION COMMITTEE LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and production (includinff drillinff and producin~ wells) for the month of ..... .0_ .c_ .t;_ 9.b_ _e__r_ ........................ 19_6__7___, ............................................................................ ....... ....................... _ ......... .a~o~:~,__~~_9.9.soz ..................................... si ~. ned __/d ._C__~/_~~ ................... ehone ....... _2_7_7__'_7__6_Z~ ............................................................ .~ ~ en t' s title .... _D___i__v__i__s__i_°__n____E__x_E_l.P__i_?__a_.t__i_p_.n____E_D_~ineer SEC. AND ~o~ ~ SAS E Spudd Drill Drill Tw~,. S Cl31-~ d 7~00 ~ d 15" hr d 947/8' m. [10- 22 e t~ 192 holI to BARRELS O~ OIL .67 ' Cemen 800'. GRAVITY :ed 1( Cu. F~. o* GAs (In thousands) -3/4" casi OALLONS OF OASOLINE RECOVERED ag at 18', BARRELS OF WA?ER (If none, so state) 15' with REMARKS (If ¢LrilHn~, depth: if shut down, cause; date and reeult of test for gasoline content, of I~as) 1600 sacks. NOTE.--There were ................................................ runs or sales of oil; ................................................ M cu. ft. of gas sold; ............................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mont~ l~tl~"s directed. NOV DIVISION OF: MINES & MINERAI,,S ANCHORAGE FORM SA- lB : 125.5M 8/67 {~ MEMORANDUM State of Alaska FROM: DATE : SUBJECT~ FORM SA - I B 125.5M 8/67 MEMORANDUM State of Alaska TO: F- DATE FROM: SUBJECT, SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 October 17, 1967 PRIVATE & CONFIDENTIAL STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gent lemen: Enclosed for your approval is our Application for Permit to Drill well S.A.S.M.G.S. C-31-26 from our Platform "C". Also enclosed is our check in the amoUnt of $50.00 for the filing fee. JDM/mw Very truly yours, R.g. A1 len Division Exploitation Engineer Enclosures: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Blowout Prevention Program (3) RECEIVED OCT 19,1967 Dt¥i$10N OF MINES & MINE~ F~rrn P--1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL ~ DEEPEN l--I PLUG BACK I-I b. TYPE OF WELL O.L [] OAS I--1 SINGLE I--~ .ULT.PLE [] WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Shell 0il Company 3. ADDRESS OF OPERATOR 430 Seventh Avenue 4. LOCATZoN OF WE~.L (Report location clearly and in accordance with any State requirements.* ) Atsurface Conductor 5, 4.74'S & 3.40'E from center leg 1 @ 541.65' At Nproposed & 1596prod.Oz4onle'W from SE corner section 23, T8N, R13W, SoM. , .q o.o~ Bm]mw 16. NO. OF ACRES IN LEASE 5120 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 miles NW Kenai, Alaska 15. DISTANCE FROM PROPOSED* LOCATION To NEAREST PROP"ET, OR LEASE LZNE, FT. ,.,-~,.,.,~,~nn' (Also to nearest drlg. unit line, if any) APl 50-133-20052 DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL, DRILLING, COMPLETED, OR APPLIED FOR, ON THIS LEASE, FF. 1850' ~.. PROPOSED DEPTH 100,050 ' Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO APL 18756 6. IF INDIAN, ALLOTTEE OR TRIBE NAME None 7. UNI~ AGREEMENT NAME None 8. FARM OR LEASE NAME M.G.S. 9. WELL NO. C-31-26 10. FIELD A.~-v~ POOL, OB WILDCAT Middle Ground Shoal 11. SEc., T,, R., M., OR BLK. AND SffRVEY OR ARgA Sec. 26, T8N, R13W,. S.M. 12. BOROUGH SHJ 13. STATE RenalI Alaska 17.NO. OF ACRES ASSIGNED TO THIS WELL 80 20. ROTARY OR CABI,E TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GE, etc.) 105 ' D.F. 221 APPROX. DATE WORK WILL START* October 24, 1967 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 15" 9-7/8" I *Top 8400+' SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMEN~ 10-3/4" 40.5 19~0' 1600 sacks 7" 23-26-29# 10~050 ' 1200 sacks (~ 8225~~) 8~0~S & ~5~0~ ~om ~ oo~e~ Seo~o~ 26~ ~8~ Bottom 10,050+-' (TVD 9820+') 1200+'S & 1760+'W from NE corner, Section 26, T8N, R13W, SoM. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal ts to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depthS. Give blowout preventer program, if any. 24.1 hereby cer,~f~t~m~~o~j~i~g is True and Correct. SIGNED ////J//~//~/'W'/'"~~//~ -~ TITLE Div. Exploitation Engineer (This space for Federal or State office use) PERMiTNO. [~ ~' ~'-~ APPROVED BY ~ .... CONDITIONS OF APPROVAL, IF ANY: APPROVAL DATE THOMAS R. MARSHAl:L, JR, Executive ,Secretary TITLE Alaska Oil & Gas Conservation Committee ! RECEIVED API 50-133-20052 *See Instructions On Reverse Side , OCT 19 1967 O1¥151ON OF MINES & MINERAI~ T. 8 N., R.13 W., S.M. III i ADL 18756 I / C-3 4-? 3 '2 / · I ~.:.-*~/ 2324 ........ ~ ......... .~.~'.. , ~,~ ~ ................. 2~25 / I LOCATION Ot: COi~DUCT.OR 5 , LEG ~ 1 PUBLIC LAND LOCATION OF PRODUCING DESCRIPTION ZONE WELL C-31-2G ~-'ON[}UC'~OR 5 LEG No 1 LOCATED 4.74'S 1200'S AND 1760'W AY-~D 3.40'W FROM CENTER OF LEG N~ 1 FROM IHE N.E COR. CEN-:"~'~ tEG N~o t lOCATED 541.65'N AND OF SEC. 26, T8N, R13W, S.M. ~1596.41'W FROM THE SE COR. OF SEC. 23 ?SN, R~3W ~' : , '. - ...... 7 7 IIII1' II II ]1 III II I IIIII 11 ~DRAWN BY: N.L.B. , -- ~ ' ~ SCALE :,,1": ~1,,~;, SHELL OIL COM NY ~T'~"~ ........ 'LOCATION OF SHELL-ATLANTIC-STANDARD WELL C'31.26 tN SEC, 26 T 8N~, R.13W. $~M.- COOK INLET -STATE OF ALASKA ~:~-~'~,,:~~ · , ' _ ' ' ' ~ . ...... ~ ..... L..::_~ L-:-' '~ ~ ........ CONFID'EI .T.I-AL DRILLING~ CASING~ AND BLOWOUT PREVENTION PROGRAM WELL C-31-26 '"MIDDLE GROUND SHOAL - PLATFORM "C" COOK INLET~ ALASKA 1. Move rig over 24" conductor 5, Leg 1. Install 20", '2000 psi Hydril preventer. 2. Drill 15" hole to 1900,+ '+ -. Run 1900 - of 10-3/4" 40.5# J-55 Seal-Lock . casing. Cement with 1600 sacks API.cement, (1400 sacks gel cement and 200 sacks neat cement.) 3. Land casing and flange up 12" 3000 psi preventer stack consisting of Double Shaffer Gate and G.K. Hydril. 4. Drill 9-7/8" hole to 10,050'+ Run logs at 8100,+ and TD. Run 10,050'+ -. - - of 7" 23#, 26#, and 29# Buttress casing. Cement with 1200 sacks API cement. 5. Run 3-1/2" 9.3# J-55 and N-80 EUE tubing string'equipped with packers. Displace annulus above packers with inhibited Inlet water and displace tubing and annulus below packers with diesel oil. Set packers. 6. Perf~rat~ productive zone with 4 shots per foot at selected intervals. Place well on'production. RECEIVED · OCT 1'9 1967 DI¥1SlON OF MINES & MINERAI~
