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Home My WebLink About175-035February 24, 2003 XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Mr. Randy Ruedrich 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C32-23 P&A Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits its Well Completion Report (Form 407) for the work performed to plug and abandon well C32-23 on XTO Platform C in the Middle Ground Shoal Field of Cook Inlet. After the abandonment of the bottom portion of the wellbore, the well was sidetracked as the C32-23LW. Please find attached the following information for your files: 1. Form 10-407 Well Completion 2. Well Operations Summary 3. Post-P&A Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc: Doug Schultze Doug Marshall Tim Smith STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL Q GAS F-~ SUSPENDED ~ ABANDONED r~ SERVICE ~ 2. Name of Operator 7. Permit Number ~ ~ :i:nc. 75-035 3. Address 8. APl Number 3000 N. GarEield, S'ce 175, Mid.laz'~, TZ 79705 5o- 733-20251-01 4. Location of well at surface 9. Unit or Lease Name Leg 1, ~ctor 2, 547' FSL, 1594' FE~, Sec. 23, T8N, R13W, E~ Micklle Ground Shoal At Top Producing Interval 10. Well Number 2044' FNL, 2553'FEL, Eec. 23, TSN, R13W, ~ C32-23 At Total depth 11. Field and Pool 1783' FN[~, 2673' F/iL, Sec. 23, TS~, R13W, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. tv/_~.~e G:L'Ol,Zz'~ 105 D[~I AD~ 18756 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Sus/p. or Aband115. Water Depth, if offshore I 16. No. of Completions 7/31/1975 9-30-1975 3/1/2002~' I 73 feet MSLI 1 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 120. Depth where SSSV set I 21. Thickness of Permafrost 9831, + 9073 9725'+ 8976, YES [~] NO[~I [~l~feetMDI 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-:~/1~" 61 [:F~5 b"~;~ 2431~' 17-1/2" 2550 s~ O 9-5/1~" 40-43.5 NSQ ~%L~"f~ 40Oil' 12_1/4.. 1140 SX Q 7" 26 S95 Surface 9778 ' 8-1/2" 1620 :s,lr. 0 ,., ,, 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD/ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8160' 230 SX cm~ P&A 3340' 73 S~ ca'dc 27. PRODUCIION/EST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD D 0 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE D 0 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 ORiGiNAL Submit in duplicate CONTINUED ON REVERSE SIDE AUG [ (} 20D3 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and NAME MEAS. DEPTH TRUE VERT. DEPTH time of each phase. 31. LIST OF ATTACHMENTS Wellbore Schematic, D~ily ~rillir~ Re~orbs 32. I hereby cer~the foregoing is~l,~ and correct to the best of my knowledge / Signed \ ~'/~z~, ~ Title St' Pr(:X;:]~t~t:[(::~ ]~iz%eer Date 9-/24/2003 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ' ' r'~ . ,,~ I~ :..~ii Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump," Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 - 50 - MIDDLE GROUND SHOAL C, WELL #32-23 AFE #:. 200096 Objective: Rig Move 02/20/02 RD flow line. Cleared decks for move. FIRST REPORT: 2/20/02 Prep for back load. RD top drive elec. Dumped vac tnk to solids unit. Unloaded & reloaded boat. Cleaned out solids unit. Disconnected koomey remote. Split solids unit. RD centrifuge. Moved mud dock. Transferred cutting bbls. Loaded racks w/bbls. Cleared deck for rig move. Unwired solids unit. 02/21/01 Injected fluid fr/solids & slop tnk. Pulled elec cables. Moved top drive, gen, VFD house & centrifuge to pipe deck. Cleaned btm deck. RU jacking system. Jacking rig fr/Leg #4 to Leg %1. At present rig is half way between the two legs. 02/22/02 Rigging Up. Trouble shooting moving system. Repr jacking plate. Repl jack on skid base (RU surface tnk on C13A-23LN). Fin skidding rig over C32-23LW. Pulled elec wires & hooked up. Set solids unit, mud dock & centrifuge. Prep for boat. 02/23/02 Rigging Up, Trouble With Drains. MIRU 24 hrs. Set top drive & vac equip. RD jacking system. Hooked up service loop for top drive. Hooked up air, steam & wtr to rig. Off loaded boat. Set catwalk, drlg line spool & walk way. Moved 6" & 4" choke lines. RU mud line & 10" flowline. Attempted to CO 'drains (very plugged). 02/24/02 Building More Kill Wt Mud Vol, MW 11.0, Vis 4~, PV 15, YP 23, Gels 12/2.5, Added 640sx Barite, 5sx caustic soda, 180sx Durogel & 9sx Flo-Vis. MIRU 24 hrs. Installed slop tnk & block valve to deck drains. Installed flowline & 4" mud line. RU solids unit & brake wtr rtn. RU slickline & RIH. Stopped ~ 4,398' POH w/valve. RIH & stopped. Pulled valve 8 7,714' WLM. RIH several times & attempted to re-install valve 8 4,398', no success. Mixed kill wt mud to 11.6 ppg. Bldg more vol. 02/25/02 Monitoring Well After Bullheading KW Mud, MW 11.5. Vis 42, PV 9, YP 20 Gels 10/16. Other 1/4 hr, MIRU 23-3/4 hrs. Mixed kill wt mud vol. Fin RU slop tnk. RU 6" & 4" choke lines. RU to bullhead tbg w/mud. Tbg press 350 psig, annulus press 400 psig @ start of bullhead. Bullheaded dwn tbg w/104 bbls 8 10 SPM (0.7 BPM). Final pmp in press was 3,060 psig on tbg & 3,550 psig on annulus. SD pmp, tbg press dropped to 2,100 psig & annulus press dropped to 2,950 psig. SD for 2 hrs. SITP 500 psig, .SICP 890 psig. RU to bullhead dwn annulus. Bullheaded 246 bbls dwn annulus @ 0.4 BPM ~ 3,680 psig (tbg press 3,740 psig). SD pmp. Annulus press dropped to 3,500 psig & tbg press dropped to 3,300 psig. Monitored well. Tbg press 2,500 psig, annulus press 2,750 psig. Cont'd to bleed into fmt. Monitored well. Tbg press 2,050 psig, annulus press 2,425 psig. 02/26/02 NU BOP, MW 11.6, Vis 42, PV 10, YP 18, Gels 10/18, Added 120sx Barite,. lsx caustic soda, 18sx Durogel & lsx Flo-Vis. Monitored Well 11-1/2 hrs, NU/ND BOP/Diverter 6 hrs, NU/ND Tree 4 hfs, Other 2-1/2 hrs. Monitored well & let press bleed to fmt. Tbg press bled fr/2,500 psig to 710 psig, annulus press fr/2,425 psig to 550 psig. Monitored well. Bled press off thru choke to 0 psig. Well dead. RD lines & blew dwn choke manifold. Installed back press valve. ND tree (had bad body seals on tbg hanger). NU riser & BOP. 02/2'7/02 POH w/APRS & 2.7" GR from 8,190' WLM, MW 11.6, Vis 40, PV 10, YP 18, Gels 10/18. N-U/ND BOP/Diverter 10 hrs, Other 5-1/2 hfs, Tstd BOP/Diverter 5 hfs, LD/PU Drill Pipe/Tbg 1-1/2 hr, Circ 1-1/2 hr, Monitor Well 1/2 hr. NU BOP & pollution pan. Tstd BOP 250 - 5,000 psig, tstd OK. Tst witnessed by AOGCC rep. RU & pulled back press valve. RU & pulled tbg/hanger loose. Well back flwg (U-tube). Circ well to balance U-tube. Monitored well. RU APRS E-line unit. Well back flwd (U-tube) 8 2 BPH. RU APRS & RIH w/2.7" gauge ring. Set dwn ~ 4,400' & 7,700' (GLM's). RIH & set dwn ~ 8,190' PU "sticky" POH. 02/28/02 POH & LD 3-1/2" Tbg (Cut @ 8,170'), MW 11.6, Vis 52, PV 7, YP 28, Gels 13/14, pH 8.0, WL 20.0, Cake 3.0, Alk 0.1, C1 16,000, Ca 1,080, Solids 13.0. LD/PU Drill Pipe/Tbg 10-1/2 hrs, Other 6 hrs, Circ 6 hrs, Ppd Pill 1 hr, Monitored Well 1/2 hr. Fin POH w/2.7" gauge ring. Held safety meeting. PU & armed APRS 2.7" jet cutter. RIH, stopped @ 8,185' WLM. Cut tbg ~ 8,170'. POH & RD APRS WL. Pulled on tbg & worked free. LD landing joint. Broke out tbg hanger. Circ well thru choke. Mud wt dwn to 10.5 ppg (Barite falling out). Cird"well & incr mud wt to 11.5 ppg. Monitored well. Ppd pill. Blew dwn stand pipe & choke lines. Std LD 3-1/2" tbg (wet after GLM 03/01/02 Circ well fr/8,067', MW 11.5, Vis 43, PV 7, YP 17, Gels 10/14, pH 8.0, WL 20.0, Cake 3.0, Alk 0.1, C1 16,000, Ca 1,080, Solids 13.0, Oil 0.0, Added ll0sx Barite, lsx Caustic Soda, 2sx Durogel & 2sx Flo-Vis. Other 9 hrs, LD/PU Drill Pipe/Tbg 4-1/2 hfs, Cementing 4- 1/2 hrs, Trip 4-1/2 hrs, Circ 1-1/2 hr. Unloaded cmt equip off of boat. Fin POH & LD 3-1/2" tbg (266'its & CO + 8 GLMs w/pups). TIH w/5.718" junk basket on APRS WL to 8,170' WLM. POH & RD WL. TIH w/cmt ret, stinger & circ sub to 8,160' Stung in & injected 14 bbls of mud ~ 2.6 BPM & 4,900 psig. Form broke dwn, ppd in ~ 1.5 BPM & 4,250 psig. Set retainer, injected 9 bbls @ 2.45 BPM & 5,370 psig. Unstung fr/ret, mixed & ppd 47 bbls (230sx) of Class "G" cmt w/0.2% CD32, 0.4% FL33, 0.3% R3 & 1 gal/100sx FP6L. Mixed ~ 15.8 ppg. Held 1,600 psig on annulus, stung in to ret, ppd 4 bbls H20 & 51.5 bbls mud to displace final pmp in rate 2.64 BPM ~ 4,200 psig. Cmt in place @ 3:30 am 3/1/02. Unstung fr/ret, pulled 1 stand, dropped dart/wiper, ppd wiper dwn & seated same to open circ sub. Circ well through circ sub. 03/02/01 Prep To Run 7" Csg Cutter, MW 11.5, Vis 38, PV 5, YP 25, Gels 12/27, pH 11.0, WL 20.0, Cake 3.0, Alk 0.2, C1 16,000, Ca 1,080, Solids 13.0, Added 40sx Barite. NU/ND BOP/Diverter 14-1/2 hrs, LD/PU Drill Pipe/Tbg 5 hrs, Circ 2 hrs, Other 1-1/2 hr, Tstd BOP/Diverter 1 hr. Circ well & repl back up jaw & stabbing guide on top drive. Loaded boat. Stood back 43 stds of 3-1/2" DP (4,000'). LD 168 its of 3-1/2" DP. ND BOP. Removed tbg spool & DSA. Installed spacer spool & DSA. Welded slips to 7" csg. NU BOP. Shell tstd hole & flanges to 3.,000 psig for 15", tstd OK. Prep to PU & run 7" csg 03/03/02 Building Volume Prior To Pulling 7" Csg, MW 11.5, Vis 41, PV 5, YP 25, Gel 12/27, pH 10.0, WL 20.0, Cake 3.0, Alk 0.1, C1 16,000, Ca 1,080, Solids 13.0, Oil 1.0, Added 100sx Barite, lsx caustic soda, lsx citric acid, 40sx Durogel & 4sx Flo-Vis. Other 9 hrs, Trip 6- 1/2 hrs, PU/LD BHA & Tools 3-1/2 hrs, Monitor Well 3 hrs, Circ 1-1/2 hr, LD/PU Drill Pipe/Tbg 1/2 hr. PU & MU 7" hyd csg cutter. TIH w/cutter assbly to 4,000' C & C mud. Cut 7" csg @ 4,000'. Circ & monitored well. Ppd dry job. POH w/cutter assbly. Broke dwn cutter & chg'd out blades. PU & MU cutter assbly. TIH. & cut 7" csg ~ 60' RKB. POH & broke dwn cutter asbly. MU csg spear. TIH w/spear. Pulled csg & slips free w/225K. P0H & LD 7" csg cut/off, slips & pack off. TIH & speared csg 8 60' Attempted to pull csg, no success. RU APRS WL unit. RIH w/free point indicator, showed 7" csg free to 2,076' Called Bill Penrose & Bobby Smith & concluded that the cut will have to be made ~ 2,076' Csg will then have to be milled to kick off point (+/-600' to approx 2,676' to get below 13-3/8" csg shoe ~ 2,438'). LD spear & PU cutter assbly. TIH w/csg cutter to 2,075'. Cut 7" csg @ 2,075' Monitored well. Hole took 29 bbls of fluid when cut, then gave it back. Monitored well. POH w/csg cutter. Engaged spear & pulled csg free fr/2,075' w/100K. Monitored well & built mud vol prior to pulling csg. 03/04/02 Prep To LD +/-600' of 7" Csg, MW 11.1, Vis 38, PV 7, YP 13, Gel 7/18, pH 10.8, WL 20.0, Cake 3.0, Alk 0.1, C1 16,000, Ca 680, Solids 14.0, Oil 1.0, Added 270sx Barite & lsx Flo-Vis. LD/PU Drill Pipe/Tbg 9-1/2 hfs, Circ 5 hrs, Other 4-1/2 hrs, Trip 4-1/2 hrs, PU/LD BHA & Tools 1/2 hr. Built mud vol. C & C mud. Circ between 7" & 9-5/8" csg strings. P0H & LD 7" csg. Rec 51 its & 2 cut off its. PU mech csg cutter & TIH. Cut 7" csg ~ 2,675' TOH (wet). LD cutter & PU spear/grapple & TIH. Caught fish @ 2,075' & pulled free. Did not have to jar. Circ btms up. Got cmt contaminated mud back. Ppd pill. TOH to csg ~ surf. Unloaded boat & cleaned rig floor, wellhead room & cellar. Will back load boat w/all mill/metal munching equip. Broke out spear/grapple assbly. Back loaded boat. Prep to LD +/-600' of 7" csg. Top of 7" csg ~ 2,675' 03/05/02 T0H w/9-5/8" Csg Scraper, MW 11.2, Vis 39, PV 7, YP 14, Gels 8/18, Ph 10.5, WL 20.0, Cake 3.0, Alk 0.1, C1 12,000, Ca 680, Solids 14.5, Oil 1.0, Added 40sx Barite. Trip 9 hrs, LD/PU Drill Pipe/Tbg 5 hrs, PU/LD BHA & Tools 4 hrs, Other 3-1/2 hrs, Circ 2-1/2 hrs. LD 7" csg (15 its & cut off). TIH w/csg spear assbly. Engaged csg @ 2,675'. Attempted to jar & pull (cut ~ 4,000'), no success. Rel spear & POH. LD jars & spear assbly. Stood back DC's. PU & re- dressed csg cutters. TIH w/mechanical cutters. Cut 7" csg ~ 3,350' Ppd dry job & POH. LD cutter assbly. PU spear & jarring assbly. TIH. Engaged csg @ 2,675'. Pulled free w/o jarring. Circ btms up & ppd dry job. POH to spear assbly. Stood back DC's. LD spear & jars. LD 7" csg. Unloaded cmt, mud, etc. fr/boat. LD remainder of 7" csg. Top of 7" csg stub now ~ 3,350' DPM. PU & MU 9-5/8" csg scraper assbly. TIH & tagged up on 7" csg stub. Circ hole clean. Ppd dry job. Std TOH w/9-5/8" csg scraper. 03/06/02 Prep To Test BOP, MW 11.0, Vis 36, PV 7, YP 17, Gels 10'/30, pH 11.8, WL 20.0, Cake 3.0, Alk 0..6, C1 12,000, Ca 880, Solids 14.0, Oil 1.0, MBT 10.0, Added lsx citric acid. RU/RD Service Tools 7-1/2 hfs, LD/PU Drill Pipe/Tbg 5 hrs, Cmt Plug 3 hrs, Trip 3 hrs, Circ 2 hrs, Cmt'd 1-1/2 hr, Tstd BOP/Diverter 1 hr, Service Rig 1 hr. TOH. LD 9-5/8" csg scraper. RU APRS WL unit. Ran 9-5/8" cmt retainer on wireline & set ~ 3,340' TIH w/3-1/2" open ended DP. Circ. Ppd 10 bbls fresh wtr pre-flush, followed by 15 bbls (73sx) of C1 "G" cmt containing 0.2% BWOC CD-32, 1 gal/100sx FP-6L. Disp w/1 bbl FW & drlg mud. Pulled DP up to 3,030' Ppd dwn DP wiper plug. Opened circ sub & circ DP vol. Serviced top drive. Cleared deck. Prep to LD 3-1/2" DP. LD all 3-1/2" DP. Chg'd out saver sub, pipe handler, stabbing guide, jaws on ruffneck and rams in BOP fr/3-1/2" to 5" Chg'd out small bell nipple. Prep to tst BOP. ENEBGY MGS C32-23 Cook Inlet, Alaska Leg 1, Conductor 2 APl No.: 50-733-20251-01 Spud: 7-30-75 Surf Csg: 13 3/8", 61# K55 BTC. Set @ 2,438'. Cmt'd w/2,550 sx. P&A 'f" PLF 3-15-02 KB: 116' Water Depth: 73' MSL Set 9 5/8" Cement Retainer @ 3,340'. Cement w/73 sk. TOC plug @ 3,231'. Cut 7" Csg & Pulled from 3,350' Intermed Csg: 9 5/8" N80 BTC @ 4,005'. 40# from Surf - 3,632'. 43.5# from 3,632 - 4,005'. (Original 9 5/8" set @ 8,883'. Cmt w/ 1,140 sk for the C24-14) Prod Csg: 7", 26# S95. Set @ 9,778'. DV Tool @ 4,219'. Stg 1 Cmt w/1,120 sx. TOC @ 8,370' Stg 2 Cmt w/500 sx. Cmt b/w 3,590 - 4,700' (Poor Bond) PBTD: 9,725' MD (8,968' TVD) TD: 9,831' MD (9,073' TVD) Baker Cement Retainer @ 8,160' Cement w/230 sk. Cut 3 1/2" 9.3 tbg @ 8,170' Guiberson Uni-Packer VII @ 8,992' MD (8,253' TVD) HC-HD: 9020'-9053' (SQUEEZED) iii,'_ .. i '! i~' Otis "XO" Sliding Sleeve @ 9,030' MD (8,290' TVD) :il!i. ':.,.-:::-.;q · !i!! :.'.~ ~:.~ Guiberson Uni-Packer VII @ 9,064' MD (8,324' TVD) (;)tis "X" Nipple @ 9,102' MD (8,361' TVD) Guiberson Shear Out Sub @ 9,134' MD (8,392' TVD) HK-HN: 9336'-9404' HN-HR: 9426'-9479' HN-HR: 9509'-9564' HR-HZ: 9579'-9690' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [x] Abandon [ ] Suspend [X] Plugging [ ] Time Extension [ ] Perforate [ ] Alter Casing [ ] Repair Well [ ] Pull Tubing [ ] Variance [ ] Other [ ] Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [ ] Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) XTO ENERGY, INC. [X] Development 105' DF [ ] Exploratory 3. Address [ ] Stratigraphic 7. Unit or Property Name 3000 NORTH GARFIELD, SUITE 175, MIDLAND, TEXAS 79705 [ ] Service Middle Ground Shoal 4. Location of well at surface 8. Well Number 547' FSL, 1,594' FEL, Sec. 23, T8N, R13W, SM C32-23 At top of productive interval 9. Permit Number 2,044' FNL, 2,553' FEL, Sec. 23, T8N, R13W, SM 175-035~ At effective depth 10. APl Number 1,804' FNL, 2,667' FEL, Sec. 23, T8N, R13W, SM 50-733-20251-01 v~ At total depth 11. Field and Pool 1,783' FNL, 2,673' FEL, Sec. 23, T8N, R13W, SM Middle Ground Shoal 12. Present well condition summary Total depth: measured 9,831 feet Plugs (measured) None true vertical 9,073 feet Effective depth: measured 9,725 feet Junk (measured) None true vertical 8,968 feet Casing Length Size Cemented MD 'I'VD Structural Conductor Surface 2,322' 13-3/8" 2,200 sx 2,438' 2,213' Intermediate 3,889' 9-5/8" 1140 sx 4,005' 3,548' Production 9,662' 7" Stg 1: 1200 sx, Stg 2:500 sx 9,778' 9,035' Liner RECEIVED Perforation depth: measured 9,020' - 9,053 (Squeezed), 9,336' - 9,690' (4 intervals) True vertical 8,293' - 8,325' (Squeezed), 8,603' - 8,950' (4 intervals) Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80, EUE 8rd at 9,135' Rla~a0~&GasCo08. C~_ Packers and SSSV (type and measured depth) Otis Ball Valve at 297', 7" Guiberson Uni-Packet Vii at 8,992' and 9,064' MD 13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [X] BOP Sketch 14. Estimated date for commencing operation 15. Status oi well classification as: 2/19/02 16. If proposal was verbally approved . [X] Oil [ ] Gas [ ] Suspended Name of approver Date Approved Service: Contact Engineer Name/Number: Bill Penrose (907) 258-3446 Prepared By Name/Numbec Bill Penrose (907) 258-3446 17. I hereby certifjbthat the foregoing is true and correct to the best of my knowledge Signed ~"/~Z ~ Title: Bobby L. Smith, Operations/Drilling Manager Date Z / ~ ~ Commission Use Onlyr~ Conditions of Approval: Notify Commission so representative ma}~witness ~~:K~ '~..~,~- c~.~.~Approyal No. Plug integrity ~ BOP Test ~, Loc~.tion Clearance Mechanical Integrity Test~ Subsequent form required 10- Original $~necl By~ /~//~ Approved by order of the Commission Cammv fl~c.h._~!! Commissioner Date_ Form 10-403 Rev. 06/15/88 riplicate ORIGINAL XTO Energy, Inc. MGS 32-23 P&A Procedure Use slickline to pull the dummy valve from the GLM at 8,834', leaving the pocket empty. Move rig over well. Kill well as follows: With the annulus shut in, bullhead 10.5 ppg water-base mud down tubing to perfs. Then, switch over to the 3-1/2" x 7" annulus and, with the tubing shut in at the surface, bullhead one annulus volume of 10.5 ppg water- base mud to the perfs. Install BPV, N/D tree, NFLI BOPE. Test BOPE to 5,000 psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. RIH with a jet cutter and cut 3-1/2" tubing at 8,850' (between the GLM at 8,834' and the topmost packer at 8,992'). M/U landing joint to tubing hanger, back out lock-down screws and pull hanger to drill floor. Circulate until returns are clean and uniform. Ensure well is dead and POH with tubing, checking for NORM while POH. LO tubing and completion jewelry and send to shore. P/U a 7" cement retainer on 3-1/2" drill pipe, RIH and set the retainer at 8,840' MD (10' above the tubing stub). Establish injection into the perforations. Mix and pump sufficient cement to extend from at least 100' below the lowermost perforation to the retainer. POH. M/U a 7" casing-cutting BHA, RIH, and cut the 7" casing at 4,000' (Note: the CBL shows no cement bond at or above this depth). POH. Dress cutters and cut the 7" casing just below the wellhead. M/U a 7" spear and pull the 7" stub along with the slips and packoff. Engage the spear in the 7" casing and attempt to pull casing. Run freepoint. Disengage and L/D spear. P/U casing-cutting BHA, RIH, cut casing at free point. Pull and L/D casing. ,., If cut-off depth is too shallow for sidetracking the well (goal is to kick off well at +3,900'), M/U casing-milling assembly, RIH, and mill 7" casing to acceptable KOP. POH. RIH w/a 9-5/8" cement retainer and set it 10' above the top of the 7" casing stub. Pressure test below the retainer with 3,000 psi to verify the cement seal between the 7" and 9-5/8" casing. P/U out of the retainer and spot a 200' cement plug on top. POH. ~,~ \t.~ ~\,~ Qn,~ WOC, then RIH with an 8-1/2" bit and dress the cement plug, leaving at least 100' of ~1.((° firm cement above the retainer. POH and proceed with sidetrack procedure to drill C32-23LW. ' ' E~N~ERGY MGS C32-23 Cook Inlet, Alaska Leg 1, Conductor 2 APl No.: 50-733-2025t-01 Spud: 7-30-75 Surf Csg: 13 3/8", 61#. Set @ 2,438'. Cmt'd w/2,200 sx. Present Completion PLF 12-28-01 KB: 116' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE 8rd @ 9,135' Set 10-24-75. Otis Ball Valve @ 297' Item TVD MD KBM #1 2001' 2175' KBM #2 3795' 4398' KBM #3 5202' 5885' KBM ~ 6247' 6952' KBM #5 6997' 7714' KBM #6 7490' 8215' KBM #7 7884' 8617' KBM #8 8098' 8834' Ptro Port 92O 12 910 12 5/16" Odfice Broken Intermediate Csg: 9 5/8", 40-43.5# N80. Set @ 4,005'. Prod Csg: 7", 26# S95. Set @ 9,778'. DV Tool @ 4,219'. Stg 1 Cmt wi 1,120 sx. TOC @ 8,370' Stg 2 Cmt wi 500 sx. Cmt b/w 3,590 - 4,700' (Poor Bond) Guiberson Uni-Packer VII @ 8,992' MD (8,253' TVD) HC-HD: 9020'-9053' (SQUEEZED) Otis "XO" Sliding Sleeve @ 9,030' MD (8,290' TVD) Guiberson Uni-Packer VII @ 9,064' MD (8,324' TVD) Otis "X" Nipple @ 9,102' MD (8,361' TVD) Guiberson Shear Out Sub @ 9,134' MD (8,392' TVD) HK-HN: 9336'-9404' HN-HR: 9426'-9479' HN-HR: 9509'-9564' HR-HZ: 9579'-9690' PBTD: 9725' MD (8968' TVD) TI'3' .clRRI' MI'3 (.ClI37R' TVI')~ ",1'O ' E~N~ERGY MGS C32-23 Cook Inlet, Alaska Leg 1, Conductor 2 APl No.:' 50-733-20251-01 Spud: 7-30-75 Surf csg: 13 3/8", 61#. Set @ 2,438'. Cmt'd w/2,200 sx. Proposed Abandonment TOC @ ,-,3,890' __: Cement Retainer @ -3,990' KB': t t6' ' Water Depth: 73' MSL 7" Csg cut off @ ~4,000. Intermediate Csg: 9 5/8", 40-43.5# N80. Set @ 4,005'. Prod Csg: 7", 26# S95. Set @ 9,778'. DV Tool @ 4,2 lg'... Stg 1 Cmt wi 1,120 sx. TOC @ 8,370' Stg 2 Cmt w/500 sx. Cmt b/w 3,590 - 4,700' (Poor Bond) Cement Retainer @ -8,840' Tbg: 3-1/2", 9.~, N~0 EUE 8rd :Cut off @ -8,850' Guiberson Uni~Packer Vii @ 8,992' MD (8,253' TVD) HC-HD: 9020'-9053' (SQUEEZED) Otis "XO" Sliding Sleeve @ 9.,030' MD (8,290' TVD) Guiberson Uni-Packer Vii @ 9,064' MD (8,324' TVD) Otis "X" Nipple @ 9,102' MD (8,361' TVD) ' Guiberson Shear Out Sub @ 9,134' MD (8,392' TVD) HK-HN: 9336'-9404' HN-H R: 9426'-9479' HN-HR: 9509'-9564' HR-HZ: 9579'-9690' PBTD: 9725' MD (8968' TVD) TI')' .ClRR'I' MI"} (.C1{37R' TVI3~ 'O Cross January 30, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7m Ave., Suite 100 Anchorage, Alaska 99501 Request for Variance BOP Arrangement Dear Commissioner Heusser, Cross Timbers Operating Company 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). Request Cross Timbers requests authorization to utilize a BOP stack that consists of an annular preventer, one blind ram and one variable bore ram in lieu of the annular preventer and three rams required in the AOGCC's regulations. The approved BOP arrangement currently on file with the Commissi°n is for a 5,000 psi WP annular preventer, one set of 5,000 psi WP blind rams and 2 each sets of 5,000 psi WP pipe rams. The requested stack arrangement would contain a 5,000 psi WP annular preventer, one set of 5,000 psi WP blind rams and one set of 5,000 psi WP variable-bore rams. The proposed BOP components and arrangement provide an equally effective means of well control as the currently permitted arrangement. Rationale This variance is being requested because the lack of vertical space in the rigs' subbases on these small platforms do not permit the installation of a 3-ram stack.- Only a two-ram stack is short enough to fit. Background Cross Timbers began planning to work over wells on Platform C and re-drill others on Platform A shortly after the platforms' purchase from Shell Oil Company in October 1998. Rig work was permitted and commenced in the summer of 2000. The BOP stack arrangement that was submitted to the Commission and approved prior to the start of work was a standard 3-ram stack. Upon attempting to install the stack under the rig on Platform C, it was found to be too tall to fit. The Commission was contacted and it was verbally 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 fitted to the pipe being mn into and out of 2t 0 Park Avenue, Suite 2350, Oklahoma City, Oklahoma 73102-5605 (405) 232- 4011 Fax (405) 232- 5538 Ms. Julie Heusser 1/31/01 Page 2 the hole. This worked well as no tapered strings were used during the workovers on Platform C. When the workovers were finished, operations and equipment, including the BOP stack, were moved to Platform A to commence the drilling program there. The same BOP arrangement was used since the same headspace constraints apply as on Platform C and there were initially no tapered strings used. However, on the current well a tapered drilling string is necessary and Commission representatives pointed out that the stack no longer meets requirements. We made inquiries as to how Shell operated when they last drilled on this platform in the mid-90's and found that they used a single set of variable- bore rams in lieu of 2 single pipe rams. Cross Timbers' has now installed variable-bore rams with the verbal concurrence of the Commission, but a formal review and approval of this BOP arrangement by the Commission is necessary. Also, we would like to have the new stack arrangement diagram placed on file with the Commission, to replace the one currently on file. Please find enclosed a new BOP diagram, Which, if approved, should replace the diagram currently on file with the Commission. If you have any questions or require additional information, please contact me at (405) 319-3213 or Bill Penrose at (907) 258-3446. Sincerely, CROSS TIMBERS OPERATING COMPANY Susan I. Sudduth Sr. Engineering Technician Mid-Continent Division enclosure CC: Bill Penrose Doug Marshall Doug Schultze ~ROS$ TIMBERS OIL coMI~ANY BOP COMPONENTS MIDDLE GROUND SHOAL FIELD PLATFORMS "A" AND "C" KILL LINE ", 5000.PSI WP MANUAL GATE VALVE 2.", 5000 PSI WP MANUAL GATE VALVE 5000 PSI WP RISER ! ,DSA: 13-5/8",. 5000 PSI WP 'X 11", 5000 PSI WP 13-5/$'; 5000 PSI WP HYDRIL GK ANNULAR PREVENTER W/ COMPANION FLANGE TO BELL NIPPI L_ DOUBLE 13-5/8", 5000 PSI WP SCHAFFER SL BOP. W/ BLIND RAMS ON TOP ~ ,,t.~...~-~2-7/8" X Y' VARIABLE BORE RAMS ON BOTTOM · · \ \ 'r, sooo PSi wP OA~ vm, v~ w~. ~ ~ HYDRAULIC ACTUATOR . ·~\. 3:; 5000 PSI WP MANUAL GATE VALVE 13-5/8,; 5000 PSI WP DRILLING SPOOL W/ TWO 3", 5000 PSI WP OUTLETS TO E~N~E R G y February 4, 2002 Ms. Cammy Oechsli-Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval; P&A of MGS Well C32-23, Cook Inlet, Alaska RECEIVED FEB 0 4 200'~ Dear Ms. Oechsli-Taylor, XTO Energy, Inc. hereby applies for Sundry Approval of its plan to permanently abandon the perforations existing in Middle Ground Shoal Well A32-23 to allow the sidetracking of that well to drill A32-23LW. The Application for Permit to Drill A32-23LW is submitted under separate cover. The anticipated commencement date of this work is approximately February 19. The perforations will be abandoned by cutting and recovering the tubing below the bottom gas lift mandrel and above the topmost of the two existing packers, then pumping sufficient cement via drill pipe through the tubing tailpipe and across the perforations to be abandoned. The packer and plug integrity will then be verified and the well sidetracked to a new location in the reservoir. XTO Energy requests continuation of the variance from the BOPE requirements of 20AAC25.035(e) as requested in our letter of January 30, 2001 (copy attached). The rationale is the same as was set out in that letter. Pertinent information attached to this application includes the following: 1) Form 10-403 Application for Sundry Approval 2) A summary of the proposed abandonment procedure 3) A schematic showing the current condition of the wellbore 4) A copy of the January 30, 2001 BOPE variance request If you have any questions or require additional information, please contact me at (915) 620-6718 or Bill Penrose at (907) 258-3446. ORIGINAL XTO Energy Inc. · 3000N. Garfield · Suite175 · Midland, Texas79705 · (915)682-8873 · Fax: (915)687-0862 Ms. Oechsli-Taylor Page 2 Sincerely, XTO ENERGY, INC. Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7TH AVE, SUITE 100 ANCHORAGE, AK 99501.-3539 FACSIMILE TRANSMITTAL SHEET FAX NUMBER: TOTAL NO. OF lXA~ES INCLUDING COVER: PHONE NUMBER: SENDER'S REFEI(ENCE NUMBER: YOUR REFERENCE NUMBER: [] URGENT [] FOR REVIEW [] PLEASE COMMENT [] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: PHONE NO. (907) 279-1433 FAX NO. (907) 276-7542 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 __ Plugging Time extension __ Stimulate__ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Cross Timbers Operatinq Company 3. Address 210 PARK AVE., SUITE 2350 OKLA. CITY, OK. 73102 5. Type of Well: Development Exploratory Stratigraphic Servioe 4. Location of well at surface Platform "C" ,Leg 1, 547'FSL & 1594' FEL of Sec. 23,T8N,R13W.SH At top of productive interval At effective depth ORiGiNAL At total depth ca9,831' HD FSL & 2,693' 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 C32-23 9. Permit number 75-35 10. APl number 5o- 733-20251-01 11. Field/Pool MSG "G" Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9,831' feet Plugs (measured) 9,073' feet 9,722' feet Junk (measured) 8,966' feet Casing Length Structural Conductor Surface 2,438' Intermediate4,006' Production Liner 9,778' Perforation depth: Size Cemented 13-3/8",61#,K-55 BT 2200 sx "G" 9-5/8",40-43.5~,N80 7", 26~, S- 95 450 sx measured 9,336' - 9,690' 4 intervals true vertical 8,589' - 8,936' Tubing (size, grade, and measured depth) 3-1/2",9.3~,N-80 EUE 8RD Ca 0' - 9,134'. Packers and SSSV (type and measured depth) Gui berson Packer Ca 8992' & 9,064'. Otis SSSV Ca 300'. Gyro Tool Ca 9,630' Measured depth True vertical depth 2,438' 2,212' 4,006' 3,461' 9,778' 9,022' RECEIVED SEP 1 1 2000 Aiaska( & Gem C ns." ' ' A d] age 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 09/15/2000 Oil X Gas ~ 16. If proposal was verbally approved Name of approver Date approved Service 17.1 herexl~' ce~ifythat~l'f~going is true and correct to the best of my knowledge. Signed ~C,~-.,-/v --' ~,-~,---r.,,~o~ Title Sr. Engineering Tech Suspended __ Date 08/24/2000 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- Approved by order of the Commission Form 10'403 Rev 06/15/88 ...)GtiGINAL SIGNED BY D Taylor Seamount Commissioner JApproval No.,,~O O- ~5~-.- Date SUBMIT IN ~yRIPLICATE Contact person: Brent Roberson Phone #: (405) 232-4011 CROSS TIMBERS OPERATING COMPANY MGS C32-23 COOK INLET, ALASKA WELL DATA SURFACE CASING: INTERMEDIATE CASING: PRODUCTION CASING: TUBING: PERFORATIONS: OBJECTIVE: 13 3/8" 61#. Set ~ 2438'. Cmt w/2200 sx. 9 5/8" 40-43.5# NS0. Set ~ 4005'. 7" 26# S95. Set at 9778'. Cmt w/450 sx. 3 1/2" 9.3# LB0 8R EUE ~ 9134'. HC-HD 9020-9053' Sqz'd HK-HN 9336-9404' HN-HR 9426-9479' HN-HR 9509-9564' HR-HZ 9579-9690' Clean out with coiled tubing and open additional pay RECEIVED SEP 1 ! 2000 _Alaska O~ & Gas Con~. ~mmissior~ Note: GLM #4 ~ 6952' MD has a broken GLV and attempts to pull it w/WL have been unsuccessful. This well has major scale problems. This well should no-flow. If well control is needed, FIW will control this well. Have mud and weight material on location during workover operations. The fluid level in the annulus will rise when shut in - indicating a leaking mandrel or a possible tubing failure (top pkr failure or a possible casing leak are also possible but are not believed to have occurred). Install PTI flowback tank. a) b) c) d) MIRU Dowell CTU and pump. Test lines to 5000#. TIH w/2.72" drag bit and 2 1/8"motor on 1%" CT to PBTD ~ +_9722'. POOH. TIH w/underreamer for 7" csg and 2 1/8" motor on 1%" CT. Start circulation ~ 9134' to engage underreamer. Underream to PBTD. POOH. Jet well clean using FIW. TIH w/Jetting tool. Wash perfs using 500 gal of 7 ½% HCI. Work CT across perfs. Circ well clean. Obtain samples of all fluids for Dowell to analyze for live acid. Spot xylene across perfs. Up to 9020'. Close surface valves. Displace 1500 gal ofxylene into perfs. Pump 25 bbls diesel. Displace to EOT using FIW. POOH w/CT. RD CTU. Use gel sweeps as needed to clean the hole. Use GLV by-pass tool to protect the damaged GLV #4 @ 6952' MD on all trips. Notify onshore prior to start of work to prevent system upsets. Pump returns to disposal well. 2) RU Schlumberger WL. Test lubricator. Make a GR/JB run to 9722'. Perfthe Hemlock as follows: HR 9708-9718' EL (10') 4 SPF, 40 holes, 60° phased (if unable to get to this depth, shoot the HR from 9618-28' EL) HI 9218-9255' EL (37') 4 SPF, 148 holes, 60° phased HK 9263-9332' EL (69') 4 SPF, 276 holes, 60° phased using a 2 ½" HSD (Schlumberger 31J: 10.6g charge, .29" EHD, 17.3"TTP). POOH. RD Schlumberger. Note: This well was reperf'd on 9/6/85 w/a 2 5/8" HSC. The Otis X nipple probably has a 2.75" ID. PBTD per Schlumberger CBL (dated 10/7/75) is 9708'. Coiled tubing may be able to cleanout to perf the lower perfs. 3) RU SL. Run GLVs based on a 1200 psi operating pressure system per attached design sheet. If gas lift system is 950 psi, keep valves the same as before. Put well on production. Submit daily tests until the well is final reported (1st 2 days should have hourly test data). 8/29/00 .~~ Cross Timbers ~;rating Company Present Completion MGS C32-23 Cook Inlet, Alaska Leg 1, Conductor 2 APl No.: $0-045-J0310 Spud: Surf Csg: 13 3/8", 61 lb. Set @ 2438'. Cmt'd w/2200 sx. Intermediate Csg: 9 5/8", 40- 43.5 lb, N80. Set @ 4005'. Prepared by: jm 5113199 Checked by: KB: 105' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE 8rd @ 9134' Item TVD MD Otis Ball Valve 300' 300' KBM Mandrel #1 2001' 2175' KBM Mandrel #2 3795' 4398' KBM Mandrel #3 5202' 5885' KBM Mandrel #4 6247' 6952' KBM Mandrel #5 6997' 7714' KBM Mandrel #6 7490' 8215' KBM Mandrel #7 7884' 8617' KBM Mandrel #8 8098' 8834' Ptro Port 920 12 910 12 5/16" Orifice Broken Or. RECEIVED SEP 1 ! 2000 Alaska Oii& Gas Co~s. ~mmissio~ Prod Csg: 7", 26 lb, S95. Set @ 9778'. Cmt w/450 sx. Guiberson Uni-Packer VII @ 8992' MD (8253' TVD) HC-HD: 9020'-9053' (SQUEEZED) Otis "XO" Sliding Sleeve @ 9030' MD (8290' TVD) Guiberson Uni-Packer VII @ 9064' MD (8324' TVD) Otis "X" Nipple @ 9102' MD (8361' TVD) Guiberson Shear Out Sub @ 9134' MD (8392' TVD) PBTD: 9722' MD (8968' TVD) TD: 9831' MD (9073' TVD) HK-HN: 9336'-9404' HN-HR: 9426'-9479' HN-HR: 9509'-9564' HR-HZ: 9579'-9690' Cross Timbers O~--rating Company MGS C32-23 Cook Inlet, Alaska Leg 1, Conductor 2 APl No.: 50-045-J0310 Spud: Proposed Completion Surf Csg: 13 3/8", 61 lb. Set @ 2438'. Cmt'd w/2200 sx. Intermediate Csg: 9 5/8", 40- 43.5 lb, N80. Set @ 4005'. Prepared by: cdp 811612000 KB: 105' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE 8rd @ 9134' Proposed GL Design for 1200 psi operating system Item TVD MD Port Pso Psc Otis Ball Valve 300' 300' GLM 1 2001' 2175' 12 1200 1132 GLM 2 3795' 4398' 12 1169 1115 GLM 3 5202' 5885' 16 1234 1100 GLM 4 6247' 6952' Broken GLM 5 6997' 7714' 16 1117 1083 GLM 6 7490' 8215' 20 1115 1068 GLM 7 7884' 8617' 20 1079 1055 GLM 8 8098' 8834' 24 Orifice Mandrels are KBM type Prod Csg: 7", 26 lb, S95. Set @ 9778'. Cmt w/450 sx. Guiberson Uni-Packer VII @ 8992' MD (8253' TVD) HC-HD: 9020'-9053' (SQUEEZED) Otis "XO" Sliding Sleeve @ 9030' MD (8290' TVD) Guiberson Uni-Packer VII @ 9064' MD (8324' TVD) Otis "X" Nipple @ 9102' MD (8361' TVD) Guiberson Shear Out Sub @ 9134' MD (8392' TVD) Proposed Perfs: HI 9218-9255' EL (4 SPF, 60o phased) HK 9263-9332' EL (4 SPF, 600 phased) PBTD: 9722' MD (8968' TVD) TD: 9831' MD (9073' 'I'VD) HK-HN: 9336'-9404' H N-H R: 9426'-9479' HN-HR: 9509'-9564' HR-HZ: 9579'-9690' Proposed Perfs: HR 9708-18' EL (4 SPF, 60 phased) (if unable to get deep enough, reshoot 9618-28') Shell Western E&P Inc. 601 West Fifth Avenue · Suite 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. C32-23 Enclosed, in duplicate, is the report of Sundry Well Operations for MGS Well No. C32-23. The workover included Coil Tubing Unit Acid Treatment. Operations were completed November 4, 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 Alaska 011 & Gas Cons. Commission Anchorage ~LETTERS\AOGCC~112790.D0C SrATE OF ALASKA OIL AND GAS CONSERVATION C~I~ION REPORT OFSUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown w Stimulate ..~ Plugging __ Perforate Pull tubing __ Alter casing ~ Repair well ~ . 2. Name of Operator i' 5. Type of Well: ' Development X · Shell Western E&P [rl~ I Exploratory__ 3. Address Stratigraphic_ 601 W.. 5th Avenue, Anchorage, AK 99501 Service~ 4. Location of well at surface Platform C, Conductor 2, Leg I @ 547' FSL, 1594' FEL, SEC 23, T8N, R13W, SM (Corrected) At top of productive interval At effective depth At total depth 3522' FSL & 2693' FEL Sec 23, T8N, R13W ; Other m I.. 6. Datum elevation (DF or KB) 106' KB Z.Unit or Property name Middle Ground 'Shoal 8. Well number C32-23 9. Permit number/approval number 90-789 10. APl number 50- 733-20251-01 11. Field/Pool G-Pool feet 12. Present well condition summary Total depth: measured true vertical 9,831 feet Plugs (measured) 9,073 feet. Effective depth: measured true vertical 9,722 feet 8,966 feet Junk(measured) Gyro Tool @ 9,630' Casing Structural Conductor Surface Intermediate Production Liner Pedoration depth: Length Size Cemented Measured depth True vertical depth 2,438' 4,006' 13-3/8", 61# ' 22.00 SX 9-5/8"', 40-43.5#, N-80 9,778' 7", 26#, S-95 measured 9,336 - 9,690' 4 true vertical 8,589 2,438' 4,006' - 8,936' 450 SX 9,778' Intervals Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8RD Packers and SSSV (type and meesured depth) Guiberson Packer @ 8992' 2,212' 3,461' 9,022' R EIV£D DEC - 5 1990 Com~ss~o~1 9,13~iaska 0ii & Gas Cons. Ancho~ge & 9064' Otis sssv @ 300' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 93 3 6' - 9 6 9 0' Treatment description including volumes used and final pressure 18 bbls 7-1/2% HCL wash/soak. HCL ,iet wash. 41 bbls 7-1/'2% HCL squeeze @ 2750 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 21 bbls 7-1/2% Tubing Pressure Prior to well operation Subsequent to operation 49 140 105 730 120 74 1076 ·900 80 100 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations --X-- Oil .Z_ Gas ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~-', ~ Title ~/1'~' A ~,~' Form 10-404 Rev 06/15/88 16. Status of well classification as: Suspended · Service .Zt~ I,,'~;5 Date SUBMIT IN DUPLICATE DAILY REPORT OF WELL OPERATIONS C32-23 DATE 11/03/90 11/04-90 DESCRIPTION Service and equipment transfered from C31-26 to this AFE at 1700 hrs 11/10/90. Well status: casing bled down to 60#, tubing at 50#. R/U on wellhead and align CTU epuip- ment. Neutralize 60 BBLS HCL acid/transfer to production F/31-26. Pressure test LP lines at 300#, HP lines at 5000#. Perform maintenance and repair on CTU equipment. RIH w/2.5" jet wash nozzle, stop at 8585' (near GLM #7). Wash obstruction w/FIW, no results, pump 5 BBLS 7.5% HCL to EOT, pump HCL acid out TBG at 0.25 BPM while washing down on obstruction F/8567'. Work through cleared section. Continue washing tubing while RIH. No obstruc- tions observed through tailpipe section or in perforated intervals. Tag top of fish or fill at 9647'. Wash fill and proceed to 9670'. Work coil tubing to assure movement while washing. Continue washing at 9655' with gel sweep being pumped at report time. Pump 5 BBL polymer sweep to clean well prior to acid soak. Pump 13 BBLS of 7.5% HCL acid w/additives, chase w/22 BBLS of FIW to displace acid out of tubing w/jet nozzle at 9647'. Soak HCL acid F/9647' T/8508' in perforated inter- val at 30 minutes. Mix and circulate out 5 BBL polymer sweep to displace soak acid and scale material. Take returns to ondeck tank. Pump and spot 21BBLS of HCL at EOT. Jet wash perforations F/9647' T/9336' at 1BPM pulling tubing through the interval at 20 FPM. Stop pump, continue into tubing, wash 3 BBLS at GLM #8 at 8834'. Stop pump, pull up hole to GLM #7 at 8617', wash 3 BBLS acid. RIH slowly to 9647' w/pump off. Pump 5 BBL polymer sweep to displace acid form well. Take returns to ondeck surge tank. Close rams on coil tubing, moniter CSG pressure at 65#. Pressure up to 3000# on well tubing to confirm tubing/casing integrity. Bleed off pressure. Pump and spot 22BBLS of 7.5% HCL w/additives to EOT. Close annulus on CT and pump squeeze 19 additional BBLS of HCL through tubing, chase w/74 BBLS FIW to displace acid to formation. BEGIN END RATE ISIP Injection # 2600 2750 38 GPM 2750 FSIP S/I 1700 15min. POH w/coil tubing, close wellhead at 1130 hrs. Neutralize recovered HCL acid in ondeck surge tank. Pump 92 BBLS of -1- completion fluids to prod, pH of 7. Wash and blow down all hoses and tanks. R.D. Dowell-Schlumberger equipment. R/D arctic recoil CTU equipment. All crews released at 1800 hrs, 11/04/90. Project was completed safely w/no accidents. RECEIVED DEC -- 5 ]990 Oil & Gas Cons. Commission AnChorage -2- Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 October 22, 1990 Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Gentlemen: SUBJECT: SUBMITTAL OF APPLICATION FOR SUNDRY Enclosed is an Application for Sundry Approval Tubing Acid Treat). Operations are estimated to If you have any questions, please contact Susan 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBBM/amt Enclosures APPROVAL for Well No. C32-23 (Coiled begin October 25, 1990. Brown-Maunder at (907) \AOGCC\102290 ORIGINAL STATE OF ALASKA : ~ ~~KA OIL AND GAS CONSERVATION COM~'~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Alter casing __ Change approved program 2. Name of Operator Shell Westem E&P Inc. 3. Address 601 West Fifth Avenue, Suite 800 Anchorage, AK 99501 Suspend__ Operation shutdown ~ Re-enter suspended well Repair Well __ Plugging __ Time extension __ Stimulate X~ 4. Location of well at surface At top of productive Interval At effective depth At total depth Pull tubing __ Variance __ 5. Type of Well: Development X Exploratory Stratigraphic Service Platform C, Conductor 2, Leg I @ 547' FSL, 1594' FEL, Sec. 23, T8N, R13W, SM [CORRECTED] 3522' FSL & 2693' FEL Sec 23, T8N, R13W Perforate __ Other 6. Datum elevation (DF or KB} 106'KB feet "G" Pool 7. Unit or Property name Middle Ground Shoal 8. Well number C32-23 9. Permit number 75-35 10. AP! number 50-733-20251-01 11. Field/Pool 12. Present well condition summary Total depth: measured true vertical 9831 feet Plugs (measured) 9073 feet Effective depth: measured 9722 feet true vertical 8966 feet Casing Length Size Structural Conductor Surface 2438' 13-3/8", 61# Intermediate 4006' 9-5/8", 40-43.5#, N-80 Production Liner 9778' 7", 26~, S-95 Junk (measured) Gyro Tool @ ~9630' Cemented 2,200 sx Measured depth True vertical depth 2438' 2212' 4006' 3461' 450 sx 9778' 9022' Perforation depth: measured 9336 - 9690' 4 Intervals true vertical 8589 - 8936' Tubing (size, grade, and measured depth) 3-1/2', 9.3#, N-80 EUE 8RD @ 9134' Packers and SSSV (type and measured depth) Guiberson Packer @ 8992' & 9064', Otis SSSV @ 300' 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 15, Status of well classification as: Oil X Gas Suspended Service Date approved 17. I hereby certify that]he foregoing is true and correct to the best of my knowledge Signed ~/"'"~'//~~'"~- .~/4 o · Title Manager Alaska Operations FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrityM BOP Test___ Location clearance__ Mechanical Integrity Test.__ Subsequent form required 10- ~ Original S?~,",,'?,d By David W. ,Junnston Approved Oopy Returned Commissioner Date 10/22/90 lAppr°val No.2 ~- ~ ~' Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL WELL No. C32-23 COILED TUBING ACID TREAT PRESENT STATUS:. Well producing from HK-HN, HN-HR, and HR-HZ. Last Test 10/11/90; 49 BOPD + 105 BWPD Fill tagged @ 9630' (12/18/88), 60' above the bottom perforation. OBJECTIVES: Coiled Tubing Unit Acid Treatment to remove fill and damage. COST ESTIMATE: $ S0,000 EXPECTED PRODUCTION INCREASE: S0 BOPD CURRENT PERFORATIONS: 93S6' - 9690' (See attached wetlbore diagram) MECHANICAL DETAILS: See attached wellbore diagram Gyroscope tool fish @ ~9630' RECOMMENDED pROCEDURE 1. SI gas injection. Close crown valve. RU Slickline Unit to recover SSSV. Test lubricator to 1500 psi. RIH and retrieve Otis Ball Valve from safety valve nipple at $00'. POOH. RD Slickline. 2. Hold safety meeting with Arctic Recoil and all other platform personnel to discuss the proposed operations and concerns with HIS during acidizing operations. HIS concentrations of 150 - 250 ppm are not uncommon in spent acid returns during MGS acid treatments. S. RU Arctic Recoil CTU with 1-1/2" coiled tubing and CTU assist pump. Test CTU stack to 5000 psi. 4. Call out ?0+ bbls 7-1/2% HCL via Doweii-Schiumberger (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#/lO00gal L-58 iron sequestering agent 5. RU circulation return line manifold to allow injection of NALCO Visco 3631H2S scavenger into the return fluids at (or near) the wellhead'. ~LE GRouND SHOAL No. -C~LED TUBING ACID TREATMENT 6. 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. ?. 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!). 8. RU monitoring/alarm equipment.to monitor H2S at the returns vessel and holding tank. 9. RU Filtered Inlet Water '(FIW) source line to access FIW downstream of CUN0 cartridge filters. Clean Out Scale/Fill & Acid Soak Wellbore 10. RIH with 1-1/2" coiled tubing with standard wash nozzle and check valve to the top of fill. Clean out scale to top of gyroscope fish @ '9630'. 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 S631 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: Top of gyroscope~ish ~ @ ~9630' . Mix and pump/circulate a 5+ bbl "XC" polymer sweep pill to clean up the welibore. If scale is washed below 9690', PU wash nozzle to the bottom perforation @ 9690'. NOTE: Coiled tubing length 13800' (via Alvin Walker) 1-1/2" coiled tubing capacity = (1.597 bbis/1000')*13800' = 22.04 bbls Annular capacity to 9690' = 0.00651 bbl/ft * 9134' + 0.03607 bbl/ft*(9690-9134)' = 79.52 bbl Annular capacity across perfs = (9690-9336)'*0.03607 bbi/ft = 12.?? bbls page 2 ' =~=~_~,LE GROUND SHOAL No. C32~-..._....~ COILED TUBING ACID TREATMENT~'' 12. Conventionally circulate 13 bbis 7-1/2% HCL followed by 22 bbis FIW to displace the acid out of the end of the coiled tubing (EOCT). The acid volume should cover the. interval from the bottom perforation @ 9690' to above the HK-HN perfs. SD'pump and let acid soak for at.least 30 minutes. 13. 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. Jet Acid Wash Perforations 14. RIH with "jet wash" nozzle and check valve on 1-1/2" coiled tubing to the bottom perforation @ 9690' or top of fish (TOF), whichever is shallower. 15. Pump/circulate, while reciprocating coiled tubing, to jet wash the perforations from 9690'(TOF) - 9336' with 10+ bbls Doweli 7-1/2~ HCL to remove perforation damage. Take returns to the pressure contained returns vessel. Monitor return fluid for H2S and treat with NALC0 Visco 3631 as needed. Displace wash acid from the wellbore. Ensure acid is spent/neutralized before · sending to the production facilities. .POOH. Acid Saueeze Stimulation 16. RIH with check valve on 1-1/2" coiled tubing to the bottom perforation @ 9690' or TOF (whichever is shallower). 17. Spot circulate 22 bbls 7-1/2% HCL (with above additives) to the EOCT. Close annulus and pump/squeeze i? bbls additional ?-1/2~ HC1 followed bY 74 bbls FIW into the perforations at a pressure not to exceed 2500 psi surface pressure with an acid hydrostatic. Do not exceed SO00 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 overdisplace the perforations by 39.2 bbls FIW. 18. POOH. RD D-S. RD CTU. Open well to production. 19. RU Slickline Unit. Test lubricator to 3500 psi. RIH and install Otis Ball Valve in safety valve nipple at 300'. POOH. RD Slickline. page 3 COILED TUBING ACID TREATMENT 20. After well performance stabilizes, production test well via the test separator. PTH 10/16/90 Recommended ' work 63-9646 home ph # 344-5857 cc: ANCHORAGE Manager Alaska Operations - R. G. Blackburn Division Drilling/Production Engineer - V. E. Unger Kenai Production Office - B. N. Osborn Platform "C" Operations Foreman - Vickerson/Dunckley/Tracy Environmental Technician - $. $. 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 - WOK 4100 page 4 C 0 LE GROUND SHOAt. No. LED TUBING ACID TREATMENT 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 HIS 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 CS2-2S 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 bbl Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) x 24 hfs = hfs Onshore Facility Delay = 1000 bbl Gross Daily Prod "A", "C" 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 pl an t. page 5 Alaska Oil & Gas Cons, Oommiss~"og L COMPLETION EQUIPMENT DETAIL SHEET MGS C32-23 7/27/87 NO. ITEM ,, APPROXIMATE TVD. MD. PSI OR 1. OTIS BALL VALVE 2. KBM MANDREL #1 3. KBM MANDREL #2 4. KBM MANDREL #3 5. KBM MANDREL #4 6. KBM MANDREL #5 7. KBM MANDREL #6 8. KBM MANDREL #7 9. .KBM MANDREL #8 10. GUIBERSON UNI-PACKER VII 11. OTIS "XO" SLIDING SLEEVE 12. GUIBERSON UNI-PACKER VII 13. OTIS "X" NIPPLE 14. GUIBERSON SHEAR OUT SUB 300 300 2001 2175 1015 3/16 3795 4398 1000 3/16 5202 5885 985 3/16 6247 6952 970 3/16 6997 7714 1015 !/4 7490 8215 995 1/4 7884 8617 990 1/4 8098 8834 OR 8253 8992 8290 9030 8324 9064 8361 9102 8392 9134 CASING 13 3/8", 61#, @ 2438' w/2200 sx 9 5/8", 40-43.5#, N-80 @ 4005' 7" 26#, S-95 @ 9778' w/450 sx PBTD = 9722' TD = 9831' TUBING 3 1/2', 9.3#, N-80 EUE 8RD @ 9134' PERFORATED ZONE GROSS INTERVAL HC-HD HK-HN HN-HR HN-HR HR-HZ 9020-9053' (SQUEEZED) 9336-9404' 9426-9479' 9509-9564' 9579-9690' Shell Western E&P Inc. Q 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, A1 aska 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' location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. [f 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\06 ] ] 90. DOC RECEIVED JUN ! 3 1990 Alaska Oil.& Gas Cons. !lnchora~ . 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 1 C23-23 2 C32-23 3 C34-26 4 C24-26RD 5 C31-26 6 C34-23 7 C23-26 8 C22-26RD LEG 2 CONDUCTOR 9 10 11 12 13 14 15 16 LEG 3 LEG 4 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 C2 C2 C4 C4 C2 C2 C2 C1 2-23 623.65 1552.66 4A-14 624.15 1548.36 3-14 622.65 1544.76 1-26 618.25 1543.86 1-23 613.85 1546.26 1-26 612.65 1550.46 4A-23 614.85 1554.26 3-23 619. ].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 C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 DISTANCE FROM SE CORNER NORTH WEST 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 ~1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG . N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/S E/W 5.00 '2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -0.70. -3.80 -4.50 '0.50 -5.90 West West DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 · , s* iii ;;j ~,,,, L 0 ~..~T ION COOl( I N L..ET' "" ALASKA SC~L~' I'* ~000' Morc)l IN? MEMORANDr)M Stat · . e of Alaska ALASKA OIL AND GAS CONSERVATION COI~ISSION TO: THRU: FROM: ., Lonnie C. Smith~-t~//~ Commissioner ~/ O Michael T. Minder Sr. Petroleum En§ineer DATE: AugusC 8, 1988 F,LE NO: D. BDF. 008 TELEPHONE NO: SUBJECT,' Safety Valve Tests Shei1-MGSU Platform C MGS Oil Pools Bobby D. Foster~-~~, Petroleum Inspector · "¥ ! ?,,,~ _. Thursday, August_4, 1988.. The tests began at 7..30 a.m. and were concluded at 10..30 a.m. with 10 Pilots, 10 SSSV's and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. This will be repaired and the AOGCC Office notified. ., .'Comment by Mike Mindert 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' SSSV' s Tested 10 SSV' s Tested 10 Pilots Failed 0 SSSVI§ Fat 1 ed 1 SSV's Failed 0 02-00lA (Rev. 8~85) AOGCC SAFETY VALV~ TEST REPORT PAGE _ ., PP,~SSURES - PSI6- [FIELD: HIDDLE GROUND SHOAL SHELL C PLATFORI~ · I [OPERATOR: SHELL WESTERN E&P { WELL I PER. IT I N~BER I NU. BER I lC4~-14RDl77-0079-0l 1C-31-23 168-oo69-o1 68-oo6o-ol 76-oo65-ol lC24'26R~179-0062-01 1C-31-26 67-o063-0l I I I IU~HARKS: I I SV TSTIPILOTI FLOI SI I__SSV _iSSV{ SSSV DUE I I IsSSl~l I(LOW)I T~G I TI30 I IP I FP ITS, TI Iti I FP ITSTITI., I ' II I. loll PO,,I~I_I ,~ .... l~l~"'~l~ol~0l l~o"l~olP" I .... II I ,., I_1 I ',//..,,'"/-~/I~ I"~t,~I"V/o'IP_ .. l~ l~l~l_I ' ... u~l~v~.lPl~ I l_, I I I "'1 ' I "'1 I I I I I I I I I I I I I I__1__1__1, '_ I__1 I I I I I I' I I. I I I I _ I I~1 I I .I I I I I I I I' I I I .... I__1~1 · ,,1__1 I__ I I I I. I I I I I I I I. I I I I I. I_1 I I.I I I_1 I II I, I_1 I- II '1,, I_1 I II I I_1 I II I II I.'1_1 I II I.II I . I ~ I RE .-. RETAIN THIS SECTION FOR YOUR RECORDS M G S~3~2'~'3 r d (SHELL) GAMHA RAY 1 0 1 PRINTS NEG.. ~ PRINTS NEG. PRINTS NEG. PRINTS NEG. ABOVE RECEIVEDFROM: / i. ". :.:' i~:' ti"! .i: D ATT' JOHN BOY SIGNED DATE ':' '-. 19 SEPIA SEPIA SEPIA SEPIA ,'-~LA;:::)I~A ' "L AINU I,.,iAb I,.~UNbI'"~VA I IUN ~OMMI~ION SUb, DRY ITICES AND R POR WELLS DRILLING WELL [] COMPLETED WE LL)C2 OTHER :2. Name of Operator '. SBE1[ OTI_COHPAtlY 3. Addr,,s ATTN: PRODUCTION SUPERINTENDENT !'/ayne Simpson, 601.W 5th Ave., ..#810, Anchorage, AK 99501 4. Lo(at;on of Well Conductor 2, Leg I at 5.67'N, 1.35' E from Center Leg 1 at 541.65'N and ~596.41'W from SE Corner Sec. 23, T8N, R13W. 5. Elevation in feet (indicate KB. DF. etc.) 106' K.B. 105 D.F. 12. I 6 . Lease Designation and Serial No. ADL 18756 7. Permit No. 75-35 8. APl Number so- 733-20251-01 9. Unit or Lease Name MGS 10. Well Number C 32-23 11. Field and Pool Middle Ground Sh0al G Pool Check Appropriate Box To Indicate Nat~J.'re of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: {Submit in Triplicate) {Submit in Duplica.~e) Per*orate O Alter Casing O · Perforations ~[]X AIt'ering Casing Stimulate C~ Abandon I-1 Stimulation C] - 'Abandonment Repair Well [] Change Plans [] __ Repairs Made [~' Other Pull Tubing [] Other [] Pulling Tubing [] (l~3ze: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) · Describe Proposed or Ccmpleted 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- 12/17/82 12/18/82 Reperforate the HR/HZ, HN/HR(]L) and HK/HN(L) z~nes to increase production. Rigged up Dresser. Shot first i'nterval from 9648' to 9678'. Reperforated 9610-9640". Could not get well to stabilize after, lowing for 12 hours and did not complete prognosi's. Rigged down. ~~ ~,4. I hereby certify That the fore~Joing is true and correct to the best of my knowledge. $i~,,~__ Title. Production ^dm. inistration The space below for Ccmm:uion use ___ Cor~d,tsons of Ap13~oval. il any: I B¢ O, oef of ADi3foveel by COMMISSIONER the Commission Dale Fctm 10-403 Rev 7-14~0 Submit "lnlentions" in Triplicate and "Subsec3uent Reports" in Duplicate m, I2 %'ame .3f Ope'ator DRILLING WELL[] 7. Permit No. 75 -35 8. APl Number 5o- 733-20251-01 Unit or Lease Name MGS COMPLETED WE L L;>Qi: j~ __S B [ LI__O. IL~?~O HPAtl Y ..=d~,e,, ATTN' PRODUCTION SUPERINTENDENT L_!._/a~ne S~mDson, 601 t'l 5th Ave., ?f. 8].O, AncJltp_r_a_~e. AK 9950_1 ~ 4 Location of Well · Conductor 2 Leg ! at 5 67'N, !.35' E from Center Leg ! at 54].65rN and ~596.41;W from SE Corner Sec.23, T8N, R!3W. 10. Well Number C 32-23 11. Field and Pool Middle Ground' Shoal 5. Elevation in feet [indicate KB. DF, etc.) J 6. Lease Designation and Serial No. G Pool · 106' K.B. 105 D.F. I ADL 18756 12. Check Appropriate Box To Indicate Nature of Notice. Report. or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) iSubmit in Duplicate) P-r'orate ~ Alter Casing [] · Perforations E] Altering Casing S:;mulate [] Abandon [] St;mulet;on [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other E~ Pulling Tubing o o o Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completJon.) 13. Ces.-,ibe Propcsed or Ccmple~ed Operations (Clearly state all pertinenl details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25,105-170). I ! See Attached. 5 i982 Alaska 0~i ,~ u.s Corm, Com~is2ic,3 34. I hereby certify =hat the/or~.oing is lrue end correct to the best of my knowledge. lSL~n~ /~,~ Title Produc.t. ion Administration The t3ace below for Corem:trion ule D,,, 12/6/82 Fc-or, d,t~ons of App,oval. i! any: ! , A:~p~oved by SIGNED i. OHNIE C. SMITH COMMISSIONER Approved Copy Returned B ¢ O, oef of ~he Corr. rnlssion Fc.'m 10-403 P. ev. 7-1 ~0 Subm,t "ln~entions" mn Tripl;cate and "Subsequent r~eDorts" in Duphcate C32-23 Middle Ground Shoal, Alaska Reperforation Worksheet Status- Well gas lifting 500 BDO with a 35% cut. Mechanical Details- See attached schematic. Proposal · Reperforate the HR/HZ, HN/HR(L) and HK/HN(L) zones to increase production. · MIRU Dresser Atlas with lubricator and grease injection head. Pressure test lubricator to 3000 psi. Note: Dresser Atlas and equipment is only used as a base case. If equivalent services can be obtained by other service companies at a lower price, it would be favorable. · Perforate selected intervals with 4 holes per foot using a 2-5/8" hollow carrier gun loaded with 12 gm charges (90°-2 direction - symmetrically magneted phasing would be favorable, 0° phasing would be acceptable) and positioned with a magnet at the bottom of the gun assembly. ,Sequence Zone DIL Depths Total 1 HR/HZ 9650-9680 30 ~ 9610-9640 30 z~ 2 HN/HR(L) 9505-9535 30 3 HK/HN(L) 9340-9400 60 ~ 150 Casing Collars: 9671, 9632, 9594, 5958, 9521, 9481, 9442, 9402, 9364, 9324 . 5. Rig down Dresser Atlas. (All casing collars are adjusted to DIL depths dated 9/30~.75). Keep well "gas lifted down" while perforating. Establish inflow rate with _+12 hour (or until rate stabili~) flow tests after perforating each sequence. Send these to T. S. Burns, Houston. Date oOJ-lOL-]I34 ALASK,~ DPIL[ INC STATISTICS ro~ JgLY ~g75 28/05/75 . PE~JT ]SSbCn BOTTOM H~LE PBJFCTIV~ FIELD ~ND POOL 5)_28t_2)3~9-g.~ 5T~NO~RD f]IL CO nF C~LJFr°NI~ -BELUG~ RIVE~ 212-18 DEVELOPMENTAL 75-03t~ ' ISOOFT FNL ~ND [3OFT ~kL~ SEC [8~ Tj]Nt ROOSt, SM. COOK INLET B&SIN 7/[5/75 [80OFT ~NL ~N~ lC. OFT ¢~L, SEC [8~ T[3N~ POOg~ S~. BELUG~ RIVER~ UNDEFINED GAS POOL 5)-I33-2025[-0 SHFL[ OIL CD o ~GS T N R ~ ~ C ~ ' ~ ~ND IS.5~T FFL, SEC 23, 08 ~ 0 3 ~ S · . ~ 75-~336 1255FT ~NL ~ND 154qFT F~L, SEC )8, TIO~, ~015[, U~. 7/11/75 l~20~T ~NL *~ [323~T ~l, S~C Og, TION, ~015~, OM. ~g_133_Z~D6O-g2 ijNl~'t, JIL CO m~ Ce.L[rgGt, ln TRA~;ING BAY uKJT D-2A~D 75-~0~ ~.f~r ~5~ ~NO 1~12~~ ~, ~C D6, I08N, RO1Z~, S~. 71~I'7R 2~35F~ ~SL A'~~' 77D~~ =~L, SEC ~5, TJ~N, ~C~13~, ''TR-~ )~-~ I~71~T =SL ~N.~ O15' * r~, 5~L )5, T~TN, k,5'0g~, 5~- 7/39115 ~OOr'r ~SL ,~7~ !ID(rt ~t, SEC ~'~, TC7~, ~rjOG~, : DE VF LOPMFNT AL AmCTIC SLOPF P~UDHOE BAY, PRUOHOE ]IL POOl CCDK INL BASIN MCAPTNUR KIVER, HEMLOCK OIL POOL [-;E v E L !)P~ F-NT AL INLET B~SI N S~NSON RIVER, HEMLOCK OIL POCIL . ~Et.F,~C,A~L~ iNF"p~TICN LqN RECENTLY C]~PLFTCD WELLS API NLJ'~RE° mPEPATO~ NA~5 WELL PERMIT ~UM~r~ SUg, FACE LOCATION CO'~P. DA~ BOTTOM HOLE LOCAT inn 5D-133-2)262-0:) M~RATnJN ]IL CO BFAVER C~[K UNIT 5 74-))1q 1267FT FNL AN~ I~oSFT FWL, SEC ~, T07h, POI0~, S~.. 3/22/75 7eGFT ESL aND ~317FT FWL, SEC 53'02g-2)157-00 ATLAhTIC RICHFIELU CC) PRUOHOE E',A¥ DS1-7 75-C317 qO1FT ~NL AND 1485FT FWL, SEC 08, T10N, P. O15E, O~. 6/g2/75 1225ET FSL ~N[) 710FT FWL, SEC CL,~SSIFIC~TION AND STATUS TOTAL DEPTH GFC."LOGIC ~REA T. Vo DFPTH FIEL? AND PDq_L DEVE-LgPHFNTAL, [ OIL ].6~'r-7F:T COCK. INLET BASIN 15,624FT ~FAV~. CREEK~UNDEFINED OIL POOL DEVELnPI~NTAL, SUSP A~-CTIC SLOPE DRUDHLqF BAY, PRUDHOE ]IL POOL 12,~3FT (,~ , 9,/,41F T ' 53_07a-2n14~,-C~ BP ALASKA INC. ~ PUl' RIVF:~. D-6 - ~:, 2:~P')FT ;NL AN") 1 67FT FEL, SEC'23, TllN, P013F, U~. 74-] .'. ~ · 5/iq!7) 506~r :NL '~N-r' 1978FT EEL, S~C 23, TilL, kO13F, d'~. DE V['LOP~ENTAL, SUSP A~CTIC SLOPE PRUDHOE BAY, PRUDHOE OIL POOL 9,603FT 9,253~T pAGE 3 A~ ! NLJMBER PERM IT NUMBER PER~4IT ISSUED 0PEI~A TOR NAME SURFACE LOCATION BOTTOM HOLE 0BJE~.TIVE NAME AND N~JMBER 50--13~--20~_84--00 MARATHON 01L CO BEAVER CREEK UNIT 76--0006 1800FT FNL AND 20S0FT FEL, SEC 04, T06N, R0t01e [/30/76 IBO~T FNL AND 2OS~T FEL. SEC 0~, TOSNe ROlO~e 53-02g-201c)0-00 BP ALASKA INCe PUT R[VER GC-I-8 76-0007 22..34.FT FSI_ AND lgIOFT FilL, SEC 13, TIIN, E013E, UM,, !/05/76 225~FT FSL AND IgIOFT F~IL~ SEC 13, Ttlh, ROI JE, JM, C_ASSIFIC~T 13q GEOLOGIC A;~EA FIE~.O AN~) aOOL DEVEL3PMENTAL COOK INLET BASIN BEAVER CREEK,UNDEF [NE) OIL POOL BEAVER C:~EEK, UNDEFIN=D GAS POOL SERVICE ARCTIC SLG~E UNDEFINED 0IL POOL 53-029-20193-00 ATLANTIC RICHFIELD CO PRUDHOE 76--0010 208FT FSL AND 6iBFT FELe SEC 1/22/76 1320FT ~ AN) 132OFT FEL, SEC 53--099--20002--00 COPPER VALLEY MACHINE WORKS ALICIA 76--0012 23~lFT FSL AND 1671FT FWL, SEC 23, T0aNa R00aW, CI~. 1/29/76 2341FT ~SL AND 1671FT- FWLe SEC 23, T]~N, RODale DEVELOPMENT A~. AI~CT IC SLO3E PRUDHOE ~AY, PRUOHOE 0IL POOL EXPLORATORY COPPER RIVER BASIN · -~ELEASAFJLE [NFDRMAT[0N ON RECENTLY COMPLETED [ NUMBE~ PERM [T NUMBER COMP. DATE OP~ f~ATOR NAME SURFACE LOCATION C~OTTOt'4 HOLE LOCATION WELL "¢A~E AND NUMBER 53--133-20086-01 AMOCO PRODUCTION CO $OUT-~ ~4GS UNIT 75--003~ 7&3FT FSi. AND tBiBFT F~L, SEC 35~ TORN, ~013t~ 8/18/75 1240FT =~IL AND 2551FT FEL, SEC 35, T3~N, R013W, SHe CLASSIFICATI3N AND STATUS GEOL OG LC AREA FIELD AND POOL TOTAL DEPTH T. Ve DEPTH DEVEL0P~I EN TAL., I-OIL I 0,5SCFT COOK INLET I:iASI N c) ,7g2FT MIDDLE G;~OUND SHOAL~ --'_. F, AND G OIL POOL 53-133-10112-01 STAN(~AR0 OIL CO OF CALIFORNIA SOLDCT~A C~EEK tJNIT 21A-16 DE Vt" L'DP~ EN T AL, I-OIL i0egIOFT ~f~ COOK INLET BASIN tO,BgtF St~ANSON ,tIVE~ , HEMLOC( OIL POOL 53-133-20276-00 STANOAWC) OIL. CO OF CALIFORNIA SOLOC?.~ C~EEK UNIT 33-5 DEVELOP~ENTA_, I-0IL I 0,870FT 75--003g 1896FT F~ ANO b26~r FEL, SEC 05. TOTN, R2OOb. SMe COOK INLET BASIN tO,T58FT 10/25/75 iOg~FT rSL AND tOR3FT FELe.SEC 05, T3rN, ROOqde ~Me S~A~SO~ ~[VE~e HENL{)C< OIL POOL . '10/26/75) 353~FT =SL AN} 268~T FEL, SEC 23. TDgN, ROIJd, S~. '~[OOLE GNOUN) SHOAL, E, F, AND G OIL P00~/ 5D-I33--20Z78-00 STANDARD OIL C0 0F CALIFORNIA SOL~OTNA CREEK UNIT 13-3 DEVELOPMENTAL, SUSP t0,~30FT PA GE .,3 .. SCHLUMBERGER QFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON., TEXAS 77001 PL=^s= "=P-j October 20, 1980 ..Shell Oil Company - Alaska Operations 601W.'5th Avenue - Suite 810 Anchoraqe, Alaska 99501 A~ention: Production Superintendent SCHLUMBERGER OF'FSHO .500 W InternatiOnal A - Anchorage, Alaska 9! " Gentleme:n:. Enclosed are 1 ...J~rints of the CompanyShe11 0i 1 Company Field Middle Grouncl Shoal - Additional prints are being sent tO: 1, B~rin~t,s' Snell ui~ Compan~v North Star Route 1 Box 485 Kenai, Alaska 99611 ~..]. COMM'-~./! ~LRES- EN~=-i~ ~l.' ENO ! t 3GEO~ --l' STAT TEC-- ~',' STAT TEC--'~ t CONFER: FILF: Engineered Production Logs (12) on: ,Well MGS C32-23 (9/22/80):. A33-14 (9/24/R0), , C6~nty Kenai .... ' State Alaska 1 RFolded Sepia ]__B_k_~prints Atlantic Richfield Company P.O. Box 360 ' Anchoraqe, Alaska 99510 Attention- J.W. Hart 1 Bl~rints Shel'l' Oil Company / Pacific Division P.O. BOx 831 Houston, Texas 77001 /Tt-~n-h-~ion' Ed Scott I BLuri t Sherl ~1 Company Western E & P Region P.O. Box 576 Houston, Texas 77001 Attention' E & P Files 1 RRolled Sepia I BL~rints CheVron U.S.A., Inc P.O. Box 7-839 Anchorage, Alaska 99510 Attention: C.F. Kirkvold 1 BL prints Amoco Production Company P.O. Box 779 Anchoraqe, Alaska 99510 Attention- L.A. Darsow 1 RFo~f~sSepia State of Alaska - Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99510 Prints fil-is Returned to Shell The ([~estern E &P - Houston) lease return one copy of this letter for our files- Thanks, We appreciate the privilege of serving you. Da te :/a/) /~ Ve~ truly yours, SCHLUMBERGER OFFSHORE SERVICES SOS---! ~,6 $-A DISTRICT MANAGER V~ July 24, 1979 Amoco Production Company Attn: M.L. Alexander Expl. Dept. Rm. 166 Securtty Ltfe But ldt ng Denver, Colorado 80202 M.L. Alexander: Thank you for you.r inquiry of July 19, 1979 concerning Shell Oil's nd MGS C 32-23. Your confusion is understandable. Yes, these two wells are the same one. Shell Oil Company requested that C-24-14R0 be renamed C-32-23. In the July 1975 bullettn C-24-14R0 was llsted as a new permit with the issue date of 07/23/75." In'b~e January 1976 bulletin, this same well was completed on 10/26/75 as C-32-23 (the difference in dates). The surface locatton of the well is ttsted the same but the bottomhole locatton often changes from what is proposed or projected on the permit and what is actually completed and surveyed. We hope this clarifies these differences. S t ncere ly, . ,.,'/ j ~/..."',. ::~". -... :y ' ... -" ~, ~ ~ ;' ,~', Barbara Rodrlguez BAR :emi Amoco Production Company Security Life Building Denver, Colorado @0202 July 19, 1979 State of Alaska Dept. of Natural Resources Div. of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Gent 1 emen: Enclosed you will find copies of pages from your monthly Drilling Statistics Bulletins for July, 1975 and January 1976. Shell Oil's MGS C 24-14RD and MGS C-32-23 reflect the same API'~ same permit numbers but different permit issue dates and different footages. Is it the same well, etc? We would appreciate a clarification of these differences so that we may correct our records accordingly. Your prompt attention to the above is greatly appreciated,. Thank you. Sincerely yours, M. L. Alexander Expl. Dept. Room JUL 3 3 1979 Alaska 0il & SHELL OIL COMPANY 601 W. 5TH AVENUE, SUITE 810 ANCHORAGE, ALASKA 99501 February 5, 1976 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AlaSka 99501 ,CONFER: Gentlemen: Attached for your approval is Form 10-403, Sundry Notices and Reports on Wells for the redrilland change.of !0.ca~ion and~e.~,for our well C-24-14. ~e request that it be renamed ,~- 32-23~ ..... ~ ~ Yours very truly, K. W. LaGrone Production Superintendent Form 10-403 REV. 1-10-.73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 133-20251-00 6. LEASE DESIGNATION AND SERIAl NO. ADL 18756 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL ---- 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 601 W. 5th, Suite 810, Anchorage, Alaska 99501 Rename C-24-14 to C-32-23 4. LOCATION OF WELL Atsurface conductor 2, leg 1, Platform "C" 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105 ' DE Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT 524114 11. SEC., T.; R., M., (BOTTOM HOLE OBJECTIVE) 23, 8N, 13W 12. PERMIT NO. 75-35 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) change well name MULTIPLE COMPLETE ABANDON* CHANGE PLANS. SUBSEQUENT REPORT OF: WATER SHUT'OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) redrillinq (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. C-24-14 was redrilled from Section 14 to Section 23. Because Shell's well numbering system corresponds to the section number and the Well's location within the section at the HC marker, we are requesting that C-24-14 be renamed to C-32-23. FFB 1 !197fi DIVISION OF OIL AND GAS 16. I hereby certify that the foregoing is true and correct K. W.. LaGr~e ~, TITLE Div. Production Supt. DATE 2-1-76 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY'- TITLE DATE See Instructions On Reverse Side TELEPHONE (805) 648-2751 SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 January .9, 1976 MAILING ADDRESS P. O. BOX 92047 WORLDWAY CENTER LOS ANGELES, CA 90009 State of Alaska Division of Oil and Gas 3001 Porcupine'Drive Anchorage, Alaska 99501 Attn: O. K. Gilbreth,~Jr. Gentlemen: Enclosed foryour infOrmation'are.thecompletion.data~for~Our Shell-Atlantic-Standard Middle'Ground~Shoal.C~24~14~Redrill.'~InclUded are the following: 1. Completion~Report.(FOrm P~7) in:duplicate, 2. Well History. 3. Two sepias and. two 'prints i of. all. electric ~ logs. '- 4. Directional ~Survey. JDM:sas .Very'truly yours, Division -Operations Engineer Enclosures cc - w/enclosures Atlantic Richfield Company Standard Oil Company.of California 'Amoco Production Company United States Geo!ogical~Survey Files Vorm '%--'"-~ ~ SUBMIT IN DI~m~.-.CATE* STATE OF ALASKA (See other tn- st ructions on OIL AND GAS CONSERVATION COMMITTEE reve,-s~ side, i i i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la, TYPE OF WELL: OIL,,.ELL [5~GASwELL [~] DRY ~] Other b. TYPE OF COMPLETION: w EZ, L OV ~R. £.~ n*CK : nESVR. Other NAME OF OPKRATOR SHELL OIL COMPARY ADDRESS OF OPERATO~ P.O. BOX 92047 WORLDWAY CENTER, LOS ANGELES CA 90009 LOCATION OF WELL (~ef;or~ ~o~o~ c~e(~r]~ ~l~(~ ~ (~ccorda~e, M;{i}% a~y At.u~ace CONDUCTOR 2, LEG 1 AT 5.67' N, 1.35' E FROM CENTER LEG 1 AT 541.65' at to, ,roa, tnt.rv~ ~,,o,t~a b~oNwAND 1596,41' W FROM SE CORNER SECTION !3 2883' N AND 1064' W OF SURFACE At total depth 2985' N AND 1085' W OF SURFACE ~. API N~CAL CODE ~50-133-20251-01 LEASE DESIGNATION AND SERIAL NO. ADL. 18756 IF INDIA.N, AiJ~O~ OR TRIBE NA1Vi~ NONE 8. UNIT,FA/%M OR LEASE NAME MIDDLE GROUND SHOAL SECTION 23~ T8N, R13W 12. PERA~IT NO. 75-35 18. T(YrAL DEPwH, 1ViD & TVD ' ' 9831' (9075') 9725.' (8972') HOW~V'40/~0~OT*R' ~OOLSto 9831' ~. PRODUCING IN'r~VAL(S), OF ~IS COM~"r/O~, BOSOM, N~E (~ A~ ~)* ,~. W~ DIRE~ON~ ~ SURV~ ~ADE 9336' (8274')to 9690' (8938') j 24. TYPE ELECTRIC AND OTHail% LOGS BUN DIL, BHC, FDC~ CBL · CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, DF_,P'I~ SET (M.D) HOLE SIZE 9- ~ i~- .5~ 26# 97 8-1/2" CF~%~E~NTING RECORI) ] AiVIOUNT PULLET) NOI~ 1620 CU.FT. NON~ TUBING RECOP~D SIZE DEPT~ SET (MD) [ PACKER SET (MT)) LINER RECOl%D SIZIi] TOP (MD) 27. SCREEN (B/ID) BOTTOM (MD) SACKS Ck--WIk-'NT* 28. PERFORATIONS OPF2N TO. (Interval, size and number) 9336/9404', 9426/9479', 9509/9564' 9579/9690', four 1/2" jets per foot fi-' , 30. ~ . , ') ~ODU~ON DATE FIRST PgODUC~ON ~ ~ODUCTION ~ETHOD (Flowhug, gas lift, pump~g--size and type of pump) 11/5/75 J 24 . 1128/64 J 1986 j ~ssi30 1o o. F 1986 I 753 31. DISPOSITION Or GAS (Sold, used for ]uel, vented, etc.) S OLD ' 32. LIST O~' ATTACHMENTS 29. ACID, SiIOT, FP~CI'GtLE, CF~,VLE:NT SQUEEZE, ETC. DlilPTH Ilq'TlilRVAL (MD) A~IOUN'£ ;d~ID I'LIND OF NfATER/AL USED J WELL STATUS (Producing or shut-in) PRODUCING WATER--BBL. J GAS-OIL R~%TIO 753 [ 30 i 368 WATEB~BBL. J OIL GRA. VITY-A/:~ (COi%R.) I 30 { 35.5 J TEST WITNESSED BY WELL HISTORY, SURVEY~ DIL) BHC~ FDC? C~L LOGS SIGNED ~ ~"~/ * ~%_~'~~TITLE DIVISION OPERATIONS ENGR. DATE 1/9/76 ~" , , · (See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete arid correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise show~) for depth measure- ments given ~n cther spaces on this form and in any attac?~:nen:ts. Items :20, and 92:: If this well is completed for separate prcduclion from mo,c than one ~nterval zone (mulliple completion), so state ~n item 20, and in item 22 show the prcJucir~9 interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30 Submit a separate report (PaOe) on this form, adequately identified, for each additional interval to be seperately produce.'J, show- ing the ackJitional data pertinent to such interval. Item'S6: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item :28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,, 34. ,~L~MMAIIY (IF' I,'OltMA'I'IC)N T~S'I'S IN('I.IJ'I)IN(; INTEItV~'L T~S'FED. I~I?E~SURE DATA ~C()VERI~ OF OIL GAS. WAl'~t AND MUD NAM~ , re,mm m mm ,, E POOL 8410' 7682' F POOL 8750' 7819' G POOL 9013' 8274' SHELL OIL COMPANY WELL COMPLETI ON REPORT I ~NAMEand/o,~o. Q-24-14 ~F.T)RTT,T. Company .,,SHELL O.IL COMPANY" Field MIDDLE GROUND SHOAL ~c,t,o, CONDUCTOR 2, nE9 .1 AT. 5..6. 7~. N, 1.35' EAST FROM CENTER LEG 1 AT 541.65' NORTH AND 1596.41' WEST FROM THE SOUTHEAST CORNER ~ SECTION 23 ~ TOWNSHIP 8 NORTH, RANGE 13 WEST, S.M. Spudding D_~te 7/31/75 Completion Date 10/26/75 105' D.F. Total, ,Dejmh 98 31 ' plussed ,Back,Depth. 972 5 ' Marker Horizons HD HE HF III HI( ,, HN HR i _ Il I I~,,terval Produced 9336/9690' AT. ,INTERVALS 9- 5/8 ,,casins cemented at 4000' 7 ,,casins . cemente,d at 9778, ' , "casin~ ce/merited at "c, asin~ landed/hun~ at. ,, "casin[~ cemented thru peris, at ,, "liner !.ande4/humi~ at " " t. op , , at ,,?ub'ms hun~ .., at Depth _w.s.o.~ , . 9013' S uee~ @ 902 0/9053' 9051' Perforations: 7" CASIN~ AT 9336/9404~ , ,. 9111' 9426/9479' 9509/9564', AND 9579/9690' '. ~ ~ , __~, ..... 9154' WITH FO~JR JSPF 9218 ' 9283' INEFFECTIVE PERF IN THE 7" CASING 9020/~'-~ '9420' , (SQUEEZED OFF). , , , , 9558' 9721' Initial Production ,,, Addtl. Prod. Data Date , , Calculated Potential Date , , i i Production Data D,,, -11 - 5- 7 5 ,. Manner of ?mduein]~ GAS LIFT G~oss Fluid-B/D ' ' 2'016 .... Clean Oil-B/D 198 6 ,. , Cut-'~ 1,7 G~vity-OA. P.I. ,,,. 35.5 Wste~-B/D _, 30 S~linity, ppm NaCl (t or r) ,, Gas-M. C.F. 753 i ! ' Gu Oil Ratio 368 i i i ill O~sol~e-Gallom/M. C.F. . ...... Size Tubin~ 128 ./64 Orifice Casing i I Ill Tubinl~ 130 l~m 930 Culn[_ · ii i i Remuks~ INJECTING 1287 MCF/D GAS " DRILLED AND COMPLETED TO PRODUCE IN THE G POOL PD 4A (Rev. ,5-63) I~inted in U.S.A. DRILLING REPORT MIDDLE GROUND SHOAL C-24-14 RD. I,,.LD) (..CT,a'. o~ L'*.~ ' ' COOK INLET, ALASKA 7./31/75. TO 10/26./.75 .SE.C 23, T8N, R13W .-. (COUNTY,) (TOWNSHIP OR IRANGHO) DAY DEP'I'HI , ,, REMARK~ . FROM I . TO ,. ' ,, 7/31 10,805 Pumped.72Pcf mud down tubing to kill well. PBTD 8/1 Installed back pressure valve. Removed well head Flanged up riser and BOPE. Pressure tested Hydril, rams, kill line and mud line okay to 1500 psi. Pulled packer loose, worked· string up hole about 200" 8/2 The 3-1/2" tubing parted at 430+' while pUlling. Top 430' fish fell thru down hole beside completi.on stri~ng. Ran grapple, worked On completion 8/4 string fish. Ran freepoint indicator, found free at 9653' Wireline tools PUlled off rope socket. Cut tubing at 9465'. Pulled tubing and top 430' tubing fish retrieved also. 8/5 Took hold of tubing fish at 9431', worked fish 15' up hole. Repaired thru weight indicator. Jarred 6n fis~h, unable to work loose. Ran wash- 8/10 pipe and mill. Found top of fis[+ at 9429'. Milled (two mill rahs) over number one packer. Ran overshot, jarred on fish. Freepoint stopped at 9432'. Jarred 2 hours, grapple pulled off. Reran over- shot and grapple, latched onto fish. Ran Dialog jet cutter, tool stopped in drill pipe. Pulled, laid down one joint drill pipe with internal restriction. Ran fishing tools, took hold of fish. Ran let cutter and stopped in top of fish at 9429'. Ran 2-3/8" swage on wire- line, swaged out top of tubing. Ran in cutter, cut 3-1/2'" tubing at 9561'. Pulled, recovered ~/1 packer and 132! of 3-1/2" tubing fish. 8/11" Ran washpipe, worked over top of fish at 9561', cleaned out to 9~604', thru could not mill below 9604'. Ran overshot, latched onto fish. Ran 8/13 sinker bar and jars on wireline, found inside wireline fish at 9631', una61e to moue down hole. ~ulled wireline, circulated down pipe and fish. Ran wireline fishing tools, hooked onto wireline fish, jarred 50' up hole in 2 hrs. Line parted and broke socket. Ran new string onto fish, worked wireline fish up into drill.pipe - sheared off fish at socket, pu.lled out wireline. Released drill pipe from tubing fish, pulled and recovered wireline fish. 8/14 Ran overshot, hooked onto fish at 9588' (corrected depth), circulated · thru through sliding sleeve at 9653'. Ran sinker bar on wireline sPudded 8/16 9663/9665'. Pulled wireline. Reverse circulated through sliding · sleeve valve at 9653'. Reran'wireline tools, unable to spud p.ast 966{ , ' HOLE; CASINO S~Zt DEPTH SKI* ,, _ , · ,z~ ~,o, To 9-5/8"~ C 4000' 8~1/2~r 4000"' 9778' 7" c 9778' PERFS: EFFECTIVE: 9336/9564 AT INTERVALS INEFFECTIVE: ,, Dmr.t. J,P~ 902 0 / 9053 ' · BIZ~m ........... , ...... -; ; ~ ,~ , ,r ,,,, , ,,r,, PL~ 4~ (Rev. 5-63) P~Inted in U.S.A. ~ 2. DRILL G I PORT _ MIDDLE GROUND SHOAT, (I'll;L0) ~.OO~C .lNr,~,'r. ALASKA ,,, (COUNTY) 7/31/75 TO . . ¢-24rl/~ RD. ;SEC 23, TSN, R13W g tools. Ran in, tools slipped off fish. hot on drill pipe only. Hooked onto fish at with 2-1/4" junk ring - okay to 9695' Free- fish free to 9695'. Cut fish at 9690' ( 6' led, recovered 95' of fish. Top fish at 9683'. macaroni stinger and 2-3/8" flat bottom mill. g from 9683/9700' (below i~2. pa~ker). Pulled e tubing. Ran overshot, hooked onto fish. below packer. Freepoint indicator showed shot, fired at 9707'. Did not part on four 5th shot. )acker and 17-1/2' tubing. Top fish 9701'. milled over f/sh to 9835'. Ran outside cutter to recovered~128' of fish. Ran washpipe, milled 7'. Ran out-~ide cutter and washpipe. Cut off ' of fish including slidl~'g sleeve valve. Ran Dialog, cleaned out inside of tubing wed packers free. Shot off tubing at 10,037'. ble to pull loose, released from fish. Ran in and accelerator to.top of fish at: 9871'. Jar- able to circulate. Pulled, recovered one top section of #3 packer ( just below slip includes remainder of #3 packer, one ~oint 3-1/2" g sleeve valve, one joint 3-1%~" tubing, #4 cker VII), one joint 3-1/2" tubing, Otis X /2" tubing, Otis X nipple; one joint 3-1/2"; t Sub. Total length 174 ft. retainer, set at 9895' (top fish at 9900'). broke down formation with 1400 psi at 30 cu. cu. ft. water ahead of 250 cu. ft. AP1 class .75% water loss additive. Displaced to retain- _ i . -, i i il ] ~ . ~dl ,.,,, .,,, ~ _ REMARI'~ DAY DI'PTHI ' 'REM iiii i[ i ii 8/14 lC),805 Pulled ..to'change fish thru PBID Pulled, reran oversb 8/16 9588'. Ran wire line cont , point iadicator above #2 pa cker). Pu Ran in with 17' of ma, Cleaned out inside t.,ul left 10" of mill Ran 2-1/4" drift to 4~ packer free. Ran ~et shots. Pipe parted 8/117 Pulled, recovered #2 thru Ran washover shoe, mi] 8/21 cut at 9805'. Pulled, over fish from 9835/9~ pulled and recovered Top of fish at 9871'. 10,046'. Freepoint sh Worked on fish - unab with jars, bumper.-sub red on fish 2 hrs. - u ~oint 3-1/2" tubing an and mandrel). Top fish at 9900' inc . tubing, Otis XO slidin packer (Guiberson Unip. nipple, one joint 3-1/: and Guiberson Shear ou 8/22 8273' PBTD Ran Halliburton' cement Stabbed into retainer, ft./min. Pumped in 50 G cement blended with er with mud. .... · , ~ ,,, . ,. ,. ,, . . ., , , , ,. · ... , GIZEO ii 10126/75 ' ' (,gWN,,,,OR~,¢,O) " ' Pi:), 4A (Rev. 5-63) Printed in U.S.A. MIDDLE GROUND SHOAL DR.-tING REPORT . . m~. ~,~.~o~ m~m~ c- 2 4-14 ~ o. CO0~, INLET, A~S~ ~: 7/31/75 TO 10/26/75 g~C 23, Tgi, ~13W ' DAY DEPTHS -- .O. I ' ~' , REMARK,~ 8/23 Ran Halliburton 7" cement retainer, set at 9750'. Broke down formatf0n with 1600 psi at 28 cu. ft./min. Pumped 50 cu. ft. water ahead of 150 cu. ft. API class G cement blended with 0.757° water loss ,additive. Final pressure 2000 psi' Pulled stinger to 8996', circ- ulated c. lean. Mixed and equalized in 228 cu. ft. API class G cement with 0.757o friction reducer. Pulled 10 stands, reversed out. 8/24 3938' Laid down 3-1/2" drill pipe. Ran in with bit, found firm cement at PBTD 8273'. Ran in and jet shot four 1/2" holes at 4000' Ran HallibUrton 9-5/8" cement retainer, set at 3938'. Broke down formation with 1400 psi at 28 cu. ft./min. Pumped t00 cu. ft. water ahead of 400 cu. ft. API class G cement with 0.75% water loss additive. DisplaCed cement \ to top of retainer at 3938'. Final pressure 1000 Psi. Pulled, laid' down 4500' of 5" drill pipe. Raa 8-1/2" bit, located retainer at 3938 8/25 8273' Drilled out retainer and hard cement to 4002'. Singled in to 4100', & no cement. Circulated up. Pressure tested ho~e's to 4000' with 1500 8/26 psi, held okay. Made up 9-5/8" Tri-state section mill and 180' of 6-3/4" D.C's Started section 4005' milled to 4047' (42' in 14 hrs Milled section in 9-5/8" casing to 4062' (total section 57'). Circ- ulated clean. Pulled 5 stands, stuck tools, worked free. Circulated up. Laid down mill. Made up let sub. Ran in and jetted section from 4005/4062'. Circulated clean. Mixed and equalized 200 cu. ft. class G cement with 20% sand and 3/4 of 17o friction reducer. CIP. 8/27 8273' 8905' Located firm cement at 3773'. Cleaned out hard cement to 4010'. thru 4010' Circulated clean. Conditioned mud. Drilled and surveyed to 8831'. 9/17 KOP 9/18 8905' 9136' Drilled to 9044', lost circulation. Pulled 15 stands. Mixed pit & of LCM. Ran in to 8800'. Pumped in LCM and regained full circulation 9/19 Lost approx. 900 bbls. mud. From 0/9136' well started flowing back. 9/20 9136' 9150' Raised mud weight to 74~/. Circulated around okay. Drilled to 9143', & got salt water flow 8000 ppm Cl. Weight cut to 64f/. Weighted mud 9/21 pit to 76~/. Pumped in, returns back at 64f/. Pulled up to 8840'. Weighted mud in pits to 77~/. Pumped back, pumped in hole and returns came back at 67~/. Ran out of mud material. Unloaded supply boat. ....... HOLE c.s,No .,z~ ' D,.PTH SET __ · IZ~ FROM 'TO , .. . ~ ..... DRILL PiPE . PD 4A (Rev. 5-63) Printed in U.S.A. DAY DEPTHS . , REMARK~ I~ROM I TO 9/20 9150' Mixed 800*bbls. of 77# mud. Pumped down the drill pipe. Had returns & back at 62# with one interval of approx. 200 bbls. salt water at 9/21 14,000 ppm Cl. Mixed 400 bbls. of 80# mud with LCM. Pumped in, con't ' the returns back were at 75#. Ran in and cleaned out fill 'from 9037/ 9143'. Drilled to 9150'. 9/22 9150' 9162' Drilled to 9162' mud returns started coming back at 66#. Circulated add weight material, going in at 80#, returns back at 66-69#. Shut well in. Had ~.ero'psi on drill pipe, 100# on casing annulus. Unload- ed weight materials and supply boat. Mixed 650 bbls 82# mud and LCM 9/23 9162' 9669' Mixed and pumped 82# mud down LCM. Returns back at 76#. Stuck drill thru pipe, worked free in one hour. Pulled up to 8220'. Circulated 9/28 around 81# mud, returns back at~.l#. Found .fill at 8971'. Started cleaning out fill and started lo~'in~g circulation. Mixed LCM. Clean- ed out fill to 9162,. Drilled to 9335', adding w, eight material and LCM. Drilled to 9509'. Circulated up. Pulled~ut 70 stands. Well started to flow in annulus. Ran back in to 8900'. Circulated out through choke, gas cut mud at approx. 200 bbls. salt water. Weighted mud to 84#. Ran in to 4000'. Cut off approx. 250' drilling line. Ran in and reamed from 9470/9509'. Started losing mud at 9509' Lost approx. 200 bbls. mud. Mixed and added LCM. Regained full circulation. Drilled to 9669'. 9/29' 9669' 9831' Drilled to 9831'. Circulated bottoms up. Circulated and conditioned & mud. Ran DIL and SP-Sonic logs. ..9/30 10/1 Lost blower belly spring off tool. Ran in hole with drilling assembly and pushed fish to bottom. Lost complete returns after circulating 30 minutes. Mixed pit of LCM. Built mud volUme. Circulated and retained full returns. Ran FDC log. · 10/2 Ran in hole with Howco RTTS tool. Set tool at 1460'. Nippled down riser, BOP's and well head. Installed Cameron iron works 7" casing hanger spool. Reinstalled tubing hanger spool. Removed spacer spool from riser. Nippled up BOP's. Tested BOP's to 1000 psi - okay' Released RTTS tool. Circulated and conditioned mud to run 7" casing. COHDITIONATeEOIHU~UaOFP~RIOD Lost 55 bbls. mud while circulating bottoms up. " Mud system holding okay. ' HOLE C~IIN~ IIz~ DEPTH i , IlZl~ FROM TO ,i · DRILL PlPg SlZ~.- , U iiGNED , PD 4A (Rev. 5-63) Printed in U.S.A. _ MIDDLE QROUND SHOAL DP, ILL~G R~PORT c-24-14 C~K INLET. A~S~ . , . 7/31/75 TO. 10/26/75 ~Re 2~, Tgi, RI2U i I I I i (~OU~ CTOWNIHIP OR DAY DEPTHS , REMARK~ ",~o. I .'to 10/3 9695' Circulq.ted and conditioned mud. Rigged up and ran 151 joints PBTD (9799.65') of 7", 26#, SO0 95, LT & C new casing. Casing stopped at 9778'. Shoe at 9778', float collar at 9695', D.V. collar at 4219'. · Circulated 7" casing volume. Had partial returns after pumping 80 bbls' Lost full returns after pumping 210 bbls. Lost a total of 155 bbls. mud. · 10/4 Cemented 7" casing with 520 cu. ft. class G with 14% salt, 4% gel, 0.75% D-31. Followed by 600 cu. ft. class G, .2% R-5, ~.75% D-31. Displaced with 376.5 bbls. 84#/cu..ft. 3 bbls. over displacement. , Did not bump plug. Had approx. 80% returns while mixing cement. Had intermittent partial returns after displacing cement with 65 bbls. mud. CIP. Dropped D.V. bomb. Opened D.V. tool. Circulated with full returns for 3 hours. Cemented through D.V. collar with 400 cu. ft. class G, .75% D-31. Followed"by 100 cu. ft. class G neat cement, 2% CaC12. Displaced with 165 bbls. ~-84# mud. Closed D.V. tool with 2500 psi, held for 30 minutes. Lost complete r~'~urns with annulus fluid level after displacing 336 cu. ft. cement through D.V. collar. CIP. WOC 3 hours. Nippled down well head. Cu~t 7" hanger spool. Set Cameron iron works CA slips. Installed and tested X-bushing to 300 psi, held okay. Nippled up well head. 10/5 Ran .in hole with 3-1/2" tubing. Tagged D.V. plug at 4220'. Drilled through D.V. collar. Ran in hole with tubing, tagged plug at 9625'. " Tested casing and pipe rams to 1500 psi, held okay. Drilled plug and cement to 9680'. 10/6 9725' Drilled firm cement to 9698'. Tagged float °collar. Drilled float & PBTD collar and 27' of cement to 9725'. Circulated hole clean. Ran Sperry- 10/7 Sun Gyro-survey from 3800/9700'. Also ran CBL-GR-CCL log. Ran in hole with 7" casing scraper to 9725' Circulated bottoms up. Dis- placed mud with injection water. Displaced injection water with diesel 10/8 Ran 290 joints 'plug one 10' and 8' pup, 3-1/2", 9.3#, N-80 EUE tubing. End of tubing with Guiberson shear sub at 8895', Otis X nipple at 8862'. Guiberson Uni-packer VII at 8824'. Eight KBM mandrels located at 8808' 8621' 8222' 7697' 9663' 5869' 4409' & 2164' Otis ball valve at 282'; Set packer with 1650 psi. Pressure tested tubing · ' '" ' to 200 psi for 10 minutes - held okay. CONDITION AT BEGINNING OF PERIOD " HOLE OABIHO ~IZE DEPTH GET , , Ilig FROM TO , ,_ DRILL PIPI I~IZE~ · , · , ...... - I~IONED PD 4A (Rev. 5-63) Printed in U.S.A. ~,~"]~,.~ MIDDLE GROUND SHOAL D~~G ~PORT c-2~-14 RD. '" (fl~L~)' ' ~R ~ ~O (.Icao. o~ ~ ..... COOK INLET, A~S~ , 7/31/75 TO , 10/~6/75 ~EC, 23~,TSN; Ri3w DAY DEPTHS REMARK~ FROM I - TO 10/9 Sheared shear-out sub with 2850 psi. Bled off pressure. Landed tubing;' Nippled down BOP's and drilling riser. Nippled up Christmas tree with ball valve closed. Tested-tree to 4000 psi -held okay. Gas lefted 240 bbls. diesel to KBM mandrel #4 at 6993' Tested lubricator to 3450'psi against swab valves. Ran in hole with 2" sinker bar to 9717', Pulled out of hole with sinker bar. Went in hole with perforating gun. Perforated HC-HD interval from 9020/9053' (33'). Well flowing at 600 bbls./day rate, 100% water. Released rig on 10-9-75. . . 10/11 Production tested well. lO/12 10/16 Pulled gas lift valve at 9725'. '.~.Rigged up tubing riser and high & pressure return line. Started pumping 84 pcf mud down tubing. Pdmped 10/17 approx. 305 bbls. mud and had returns to the surf. ace. Pumped an additional 80 bbls. mud and returns back were cut to 65 pcf. Mixed 84 pcf mud. Killed well. Observed well for 1/2 hour after dead. Installed 3" Cameron back pressure valve and tubing hanger. Removed Christmas tree. Installed riser and BOP stack. 'Tested with 2500 psi, okay. Unseated Guiberson Uni-packer VII and pulled out of hole with:tubing jewelry. Packer unseated at 150,000# hook load. 10/18 Cleaned out 8' of fill.. Circulated and built mud volume Conditioned & mud for squeeze job on HC-HD perforations from 9020/9053'. Ran in 10/19 hole with 7" Howco EZ-drill cement retainer and set at 8870'. Tested drill pipe to 2500 psi and tested annulus to 2000 psi - okay. 'Pulled out of retainer and spotted 100 cu. ft. of fresh water at end of tool. Established breakdown at 16.6 cu. ft./min, at 1600 psi Pull. ed out of retainer and pumped 30 cu. ft. fresh water, 285 cu. ft. of 118# class G cement, 10 cu. ft. fresh water and 45 cu. ft. mud. Stabbed into retainer and squeezed cement at HC-HD perforations at 9020/9053' by pumping 315 cu. ft. of 84 pcf mud. Waited 1/2 hour and staged in 27 cu. ft. more mud. Final rate 4 cu. ft./min, at 2600 psi. CIP. Pulled out of retainer and pulled 10 stands of pipe. Could not revese out. Pulled out of hole wet with plugged pipe Found 26 ~oints plug- ged with cement contaminated mud. Found top of cement at 8833' (37' . ' ' above the retainer). Drilled out cement and CONDITION AT ~;ammt;a OF PERIOD retainer. Took 1-1/2 hours to drill up retaine HOLE WINO IlZl[ DEPTH 8ET · IZ~ FROM TO , , , ,, DRILL PiPE 81ZEI; ,, ........ ,iGN~ 7~ · PO. 4A (Rev. 543) P~lnted in U.S.A. ~,,...,,~ ~L[, O11'- COl~:I),~lNTIL'' ~m~cg sao~o SHOAC DR~*T-~G ~PORT C'24-14 RD. _coot _~NT,~?. A~S~ ::~ 7/31/75 TO 10/26/75 ....... (C~U~) CTOWNIHIF ON ~NCHO) DAY DF.J~I'H8 RfMARI(~ FROM I TO ~ .... 10/20 Drilled..out cement, bottom of cement at 9406' Circulated bottoms up. & Conditioned mud. Closed rams and pressure tested casing to 1000 psi, 10/21 no test. Tried to get pressure up to 1500 psi and broke down. ,Squeeze job #2. Set retainer at 8820' and pumped in 200 sacks (220 cu. ft.)' cement. Final pres.sure was 1900 psi, final rate 1-1/2 cu. ft./min. CIP. Ran in hole to clean out retainer and cement. Found top of cement at 886~7'. Cleaned out firm cement at 9007'. 10/22 Pressure tested casing and squeezed HC-HD perforations at 9020/9053' thru with 84 pcf/cu, ft. mud in the hole and 1000 psi surface pressure. 10/26 HC-HD perforations are TVD=8300' With 84 pcf mud plug 1000 psi surface pressure equals 5825 psi.or gradient of 0.7. Cleaned out to bottom at 9725'. Circulated and conditioned mud. Made short scraper run to 8800' then back to bottom, Changed over to salt Water In- stalled gauge and drill pipe. Mdnitored drill pipe and annulus for one hour. Closed in pressure is 34-psi. Displaced salt water with. 84 pcf mud. Circulated bottoms up. Perforated~the HK-HN lower zone from 9336/9341' (5') and 9341/9404' (63'). Perforated the HN-HR intervals from 9426/9479' (53') and 9509/9564' (55'). Perforated the · HR-HZ interval from 9579/9690' (111'). Perforated all..intervals with four jet shots per foot. Released rig 10-26-75. ,,, CONDITION AT BEGINNING OF PERIOD HOI. B WINO llZl DEPTH , , IIZR FItOM - i i DRILl,. PIP[ BIZE~ ............. .... , ,,,,, , , · ' ' IIIONII) c. ,'i~ .EL VERTICAL. DEPTH O.~ L~A T£ ; il ~ALCULAT£O ~Y :__ CO. ~ - TOTAL W~s'r z-dg~5 · SHgLL OiL CO. I E. ou~s~ ............ -I"'I~ 't 1.,~ " .... i ~ .....i ([ iii 'Z~'"'/4'"':'"" ! ~,. ?..."~SE, t'z(,, '5"-/'- lot:, ""L~O'",L '].V:[ "zr,;,- JIG ":'24t~ ":t~ "q,%5 Y,/ '~'~' '~"" :..,::..., _ "':.m ,"-',...; ,..:, ~ Zg~[ '-~"t-- 2'Z¢ - · .... ,- _ ,, ,, -.,, ,w too '. ,".... -' ,?¥-., Zt0¢ ZO°~o ]% ]]6..,'7,1 ,,'- '- ~t ."" ,,, T ' ' =--,-: i,,..,.: >--,-05 , '-':It .-. ,.,,qAt L L O /L · . , v- ~.4 7'£: ~ -' '- 73 .SAt£~ T: --v ,~ ME^SU~ M[^s. VERTICAL. DEPTN CouRsE TNU~" J iL~~ TOT/kL - ,, No~ Sou~I ~ST W~ST No.~. ,~ ScuT. E~T ] W~ST ~ ~ m m .... mmm -- 4¢ O: ..... - ' ', ,,, ~ t~ .... ,, , .... M~^suacm M~^s. VERTICAL DEPTH Sw.. A.e~E Cosmt! SiNE '' , .. ~40-- ~4Z 7~.7e~e ': J [ , . ,,, 1 .... TELEPHONE (805) 648'2751 SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 NOVember:12, I975' O. K. Gilbreth Jr. State of Alaska Division of Oil and Gas 3001 Porcupine~Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: MAILING ADDRESS ~. o. ,,ox ~o,~ LOS ANG .~0CL0~ ~-,~x-J ~.'. .~, ~"["2 O~OL Attached are two copies each of the Monthly.RepOrtof Oper~c_._ These reports'are for the'month.ofiOctober, I975om.the' followingwellS: Shell-Atlantic-Standard Middle'Ground Shoal"'C-24=14Redrill Shell-Arco-Standard Middle GrOund.Shoal'A-34~14.Redrill ¥ours.verytruly, G. T, K~rnes ' VJV:sas Division.Operations Engineer Attachments cc - w/attachments Atlantic Richfield Company Standard Oil Company Amoco SUBMIT IN DU?LICATE ~ STATE OF ALASKA GAS CONSERVATION COMMITTEE !,!flu 't ~ 1~9.1~L Y REPORT C)F DRILLING WORKOVER OPERATIONS I. OIL [~ GAS r'-] WELL WELL OTHER 2. NAME OF OPERATOR SHELL OIL COMPANY 3. ADDRESS OF OPERATOR P.O. BOX 92047 WORLDWAY CENTER: LOS ANGELES: CA 90009 4. LOCATION OF WELL CONDUCTOR 2, LEG 1 AT 5.67' N, 1.35' E FROM THE CENTER LEG 1 AT 541.65' N.~AND 1596.41' W FROM SE CORNER, SEC 23 5. AP! NUMERICAL CODE #50-133-20251-01 ,. 6. LEASE DESIGNATION ~D:sERIAL NO. ADL 18756 7. IF INDIAN'ALOTTEE OR TRIBE NAME NONE 8. UNIT FARM OR LEASE NAME MIDDLE GRO~D SHOAL 9. WELL NO. MGS C-24-14 REDRILL 10. FIELD AND POOL, OR WILDCAT MGS G POOL 11. sEc. T. R. M. (BOTTOM HOLE OBJECTIVE) SECTION 23, T8N, R13W 12. PERMIT NO. 75-35 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE,~ CASING AND CEMENTING JOBS INCLUDING DEPTH - SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. REPORT FOR OCTOBER, !:9_75, WELL: MGS C-24-14 Redrill Ran logs: DIL, BHC and FDC Cemented 7" 26# casing at 9778' with 1120 cu ft class G Open6d DV collar at 4219' , · · . , cemented with 500 cu. ft. class G. Ran Gyro-survey and GR-CCL--CBL log. Ran 3-1/2" tubing to 8895' o , set packer at 8824' Perforated from 9020/9053' (33') with four holes per foot. Well flowed approx. 600 bbls./day water. Killed well with 84 pcf mud. Pulled tubing. Set retainer at 8870', squeezed from 9020/9053' with 285 cu. ft. class G cement. Drilled cement 8833/9406'. Pressure tested perforations, broke down at 1500 psi. Set retainer at 8820' squeezed with 220 cu ft 'class G cement Drilled cememt from 8867/9015'. Pressured testbd casing okay at 1000 psi using 84 pcf mud. Ran tubing to 9134', set packers at 8992' and 9064'. Perforated four holes/ft, at 933~/9404', 9426/9479', 9509/9564' and 9579/9690'. Released rig 10/26/75~ 14. I hereby cettir~l'at t]~fotegoit~jMl~e and correct . . SIGNED. ~/,'~/- d/~~'TLE~)TV~.STON OP]~I:~AT.T. OI~g ~..NCR. DATE 11-12-75 NOTIZ-Raport on this form is required for each calendar month,-regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. TELEPHONE (805) 648-2751 SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 October' 8, ~1:975 MAILING A P. O. BOX ' 92047 WOJ LOS ANGELES,! ~ O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine .Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of 'the Monthly Report of Operations for our Shell-Atlantic-Standard Middle-Ground Shoal_.C-24'14 Redrill-Well', This report is for the month of September, 1975. VJV:sas Yours very' truly, Division OPerationS Engineer Attachments cc - w/attachments Atlantic Richfield Company Standard Oil COmpany Amoco Form No. P-4 ~n~=~,. REV. 3-1-70 SUBMIT IN DUPLICATE ~%,~,~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OPERATOR SHELL OIL COMPANY 3. ADDRESS OF OPERATOR P.O, BOX 92047, WORLlY~AY CENTER, LOS ANGE~S, CA 90009 ~. tOCA~O~ O~ W~tt CO~IOR 2, ~ 1 AI 5.67' N, 1.35' g ~ ~ CE~R ~G 1 gI 561.65~ ~ ~ 1596.61~ ~ ~R~ 8g C~R, Sg~. 5. APl NUMERICAL CODE ~50-133-20251-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME MIDDLE GROUND SHOAL 9. WELL NO. MGS C-24-14 REDRILL 10. FIELD AND POOL, OR WILDCAT MC'.g ~ PClCtT. 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) SECTION 23, T8N, R13W 12. PERMIT NO. 75-35 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. qx'o, .,T F,o ,.SE, z 9,7, 5 WELL: MCS C-24-14 Redrill Drilled 8-1/2" hole from 5370/9831'. 14. I hereby certify SIGNED correct &ff~ TiTL~DIVISION OPERATIONS ENGR. DATE 10/9/75 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 oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. TELEPHONE (805) d48-2751 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA Attached are two copies of.theMonthly.Report'of'Operations-for'our Shell-Atlantic-Standard Middle'Ground Shoal-C-24~14.Redrill.well. .ThiS.report is for the month of August, :I975t. JDM: sas Yours. very' truly Attachment cc - w/attaChment Atlantic Richfield Company Standard Oil Company Amoco Form No. P-4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ~/ 5. AP1 NUMERICAL CODE #50-133-20251-01 6. LEASE DESIGNATION AND SERIAL NO. 1. WELL WELL OTHER 2. NAME OF OPERATOR SHELL OIL COMPANY 3. ADDRESS OF OPERATOR P.O. BOX 92047, WORLDWAY CENTER, LOS ANGELES, CA 90009 4. LOCATION OF WELL CONDUCTOR 2, LEG 1 at 5.67' N, 1.35' E FROM THE CENTER LEG 1 at 541.65' N AND 1596.41' W FROM SE CORNER, SEC. 23 ADL 18756 7. IF INDIAN'ALOTTEE OR TRIBE NAME NONE 8. UNIT FARM OR LEASE NAME 'MIDDLE GROUND SHOAL 9. WELL NO. MGS C-24-14 REDRILL 10. FIELD AND POOL, OR WILDCAT MGS G POOL 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) SECTION 23, T8N, R13W 12. PERMIT NO. 75-35 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING SOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. REPORT FOR AUGUST, 1,,9,7~,5 WELL: MGS 0-24-14 Redrill Pulled and recovered tubing and production equipment to 9900'. Left tubing with one packer fish at interval 9900/10,074'. Cemented through retainer at 9895' with 250 cu. ft. API class G cement. Cemented through retainer at 9750' with 150 cu. ft. API class G cement. Cemented 8996' to 8273' with 228 cu. ft. API class G cement. Shot four holes at 4000', cemented through retainer at 3938' with 400 cu. ft. API class G cement. Milled window in 9-5/8" casing 4005/4062'. Directionally drilled 8-1/2" hole from 4010/5370'. 14. I hereby c.~t, ff~,~Tg is true,~ F,d~~ ~' NOTE--Raport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. July 23, 1975 Re: Middle Ground Shoal MGS_C-2414 RD Shell 0tl Company 75-35 Mr. N. G. McKlm Shel I Ot 1 Company P. O. Box 92047 Worldway Center Los Angeles, California 9O009 Oear Sir: Enclosed is the. approved application for permtt to drt11 .the above referenced well at a location in SectiOn 23, Township 8N, Range 13W, SM. Well samples, core chips, and a mud log are not requi~. A dlrect!o~.l survey ts requt red required. Many rivers in Alaska and their drainage- systeas have ,been classified as important for the spawning or migration of anad~ fish, Operations in these areas are subject to AS 16..50,870 and the regulations, promel~.geted under (Title 5, Alaska Administrative Code). Prior to ~qcing operati~s you may be contacted by the Habitat Coordtna~'s office, Department of Fish and Game. Pollution of any waters of tl~e .State is prohibited by .AS 46, Chapter 03, Article 7 and the regulations, promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Fed~ral Hater Polluti.on Control Act, as amended. Prtor to commencing operations you ~ ~be contac-t~ by a representative of the Oepartment of E~viron~l Cens~att~. In the event of suspension or, abandonment plea.se.glve this off(ce ~ate advance notification so that.~we may have a witness present. Ye_fy true,yours, Chairman Alaska 0tl and Gas Conservation Committee OKG:be Enclosure cc: Department of' Fish and Ga~, Habitat Secttoa w/o Linc1. Depa~nt of Envt~mn~tal Conservation ~o eric1. Department of Labor, Supervisor, Labor Law-Compliance Otvtston w/o eric1. TELEPHONE (805) 648-2751 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 93501 Attention Mr. O. K. Gilbreth C ha ir ma n Gentlemen: SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 Alaska Oil and Gas Conservation Committee MAILING ADDRESS P. O. BOX 92047 WORLDWAY CENTER LOS ANGELES, CA 90009 July 11, 1.975 Subject: Middle Ground Shoal Redrill C-24-14 Further to your telephone conversation of July 10, 1975 with Mr. Jay H. Smith of our staff, this is to confirm our plans to .squeeze cement the 9-5/8 inch protective casing prior to milling a window and redrilling C-24-14 Middle Ground Shoal Field, Cook Inlet, Alaska. As noted in the outline of proposed work included with our application for Permit to Drill, we plan to mill a window in the 9-5/8 inch casing at 4000 feet. Based on our cementing records, the casing is unsupported by cement through this interval. We plan to perforate the casing in the vicinity of our proposed window and squeeze the 9-5/8 inch annulus with sufficient cement to secure the casing. If there are any further questions regarding our plans, please contact myself or Mr. Smith. JHS:jcs Very truly yours, N. g. McKim Agent JUL '1. ? lg?5 DiVISiON OF OIL AND GAS AN£HI)RAGt TELEPHONE (805) 648'2751 SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 June 30, 1975 MAILING ADDRESS P. O. BOX 92047 WORLDWAY CENTER LOS ANGELES, CA 90009 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 93501 Attn: O. K. Gilbreth Gentlemen: Further to our letter of June 23, 1975 regarding permit to redrill MCS C-24-14, enclosed is our check in the amount of $100.00 which we failed to include with the above-mentioned letter. Very truly yours, jcs Enclosure N. G. McKim Agent DIV~S!ON OF OIL AND GAS ANCHORAGE TELEPHONE (805) d48-2751 SHELL OIL COMPANY 196 SOUTH FIR STREET VENTURA, CALIFORNIA 93001 June,'3, 19751 MAILING ADDRESS P. O. BOX 92047 WOP, LDWAY CENTER LOS ANGELES, CA. 90009 State of Alaska Division.of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska '93501 Attn: O. K. Gilbreth Attached are two requests"concerningour Middle'Ground Shoal C-24-14 well. The first, Sundry. Notice.10-403 in triplicate,.is.our.request for abandoning the existing.perforated interval'preparatory to.redrillingthe.well. The second is our request, in'triplicate, to redrill MGS C-24'14 to a new bottom hole location. Included with the request to drillare thefollowing: 1. Program Outline 2. Target Map 3. Location Plat 4. Filing Fee Check for $100.00. KJH:sas Yours very · truly, N. G' McKim Agent Attachments cc - w/attachments Atlantic Richfield Company Standard Oil Company of California Amoco Production Company United States.Geological:Survey DI,,-,~ION OF OIL AND GAS ANCHOR~GE Form 10-401~ REV. 1-1-71 la. TYPE OF WORK b. TYPE OF WELL OIL WELL [~ SUBMIT IN TIN__~CATE (Other instrueW,~,s on STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [] GAS WELL J~] reverse side) 2. NAME OF OPERATOR DEEPEN r-J SINGLE MULTIPLE I---! OTHER ZONE [~ ZONE I I shell Oil Company 3. ADDRESS OF OPERATOR P.O. Box 92047: Worldway Center_. Los Angeles: Calif. 90009 4. LOCATION OF WELL mtsurfaceconductor 2, leg 1 at 5.,67' N, 1.35'..E from center leg 1 at.541.65' N and .1596.41' W from SE corner, Section '23, At proposeo proa. zone ~3322' N, 2596' W from SE comer_, Section 23 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* API #50-133-20251-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18756 7. IF INDIAN, ALLOTTEE OR TRIBE NAME None 8. UNIT FARM OR LEASE NAME Middle 'Ground ShOal 9. WELL NO. MGS C-24-14 Rb 10. FIELD AND POOL, OR WILDCAT MOS 'O PooL. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section '23_. T. 8N. R.'13W. 12. 17 miles NW of Kenai, 14. BOND INFORMATION: Statewide 0il and Gas TYPE Surety and/or No. Alaska TIC '136503 IS. DISTANCE FROM PROPOSED * LOCATION TO NEAREST 7200 ' PROPERTY OR LEASE LINE, FT~ (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 110o 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 105' D.F, 16. No. OF ACRES IN LEASE 5'120 ~. · 19. PROPOSED DEPTH ,98'31 Amount $100,000 17. NO.ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TooLs Rotary '- 22. APPROX. DATE WORK wILL START 1975 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH ,. Quantity of cement 8-3/4" ' 7" 26# · .,895' ' 9831' -Sufficient_'amount to .. ~ cement' 500' above unna'r znn~_ . Please see attachedProgramoutline. DIV!SlON OF OIL AND GAS ANCHORAGE IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby qe$tify~th_at the ~o~egoing is True and Correct TITLE JO~V. {)pernrinns En?,ineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ NO DIRECTIONAL SURVEY REQUIRED YES [] NO MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 2o2 1- o~ 0 PERMIT NO. APPOVED BY APPROVAL DATE Cha i rman TITLE. *See Instruction On Reverse Side July 23, 1975 DATE July 23, 1975 Purpose: OUTLINE OF PROPOSED WORK REDRILL OF WELL NO. 24-14 SHELL-ARCO-SOCAL PLATFORM C MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA Recover production equipment. Abandon present'production interval. Redrill from 4000' measured depth to a new bottom hole location at 9831' total measured depth. Proposed Pro~r.am: 1. Install BOPE as per attached sketch. Test to 3000 psi. 2. Kill well with mud and recover existing production equipment. 3. Set cement plugs across perforations at 9884' to 10,749'. 4. Fill well with heavy mud. Mill a window in 9-5/8" casing at 4000'. 5. Set cement Plug above and below window. 6. Kick out of old hole and drill an 8-3/4" hole to a total depth of 9831' as per attached target map. Use water base mud con- taining 5000 ppm NaC1 and with a fluid loss of 5 cc. 7. Run SP-DIL, SP-BHC, GR-FDC logs. 8. Run 9831' of 7", 26#, S95, LT&C. ~Cement with sufficient quantity to obtain annuluar fill 500' above upper zone. 9. Run GR-CBL log. 10. Perforate and complete as indicated by log results. RECOMMENDED: Approved: ~~? ~"~ ~~ KJH:Sas Ventura, California June 3, 1975 DIVISION OF O[~ AND GA.~ A~k'~CHORAGI~ IA~qG- ET. Il/lAP t_, -~ q~ - lq- F L~ K~c/< OFF POINT ~~' ~4~' .qUR. LOC. . ......~oz~ AN~Z'~_ ..... ' ' · . '~ ._.~ -='~D 4~43~ .'5312 .I s~. ll'A~L~ N~ .... ~ '" --'- -- ~AIIlT~Ig ro ~ .. '~ ...... ~--~-- . -" TAR~'7 HC G, K. HYDRIL 12"- 3000 II DOUBLE SH A_F,~'ER GATE 12 - $000 12"- $000 TO KILL LINE ~3 5/8 - 30o0 CIW RX 57 TO CHOKE MANIFOLD RISER I 2"- 3000 12"- 3000 DOUBLE STUDDED A~,APTER I0 - 5OOO 12"-3000 MIDDLE DECK ] 24" CONDUCiOR ~ 13 $/8 CASIN6 L.T ~ ~/""c~,~ L DRAWN BY CHECKED BY DATE 5 - 30 -75 SHELL OIL COMPANY SCALE NONE Z-V- 149 :5000 PSI BLOWOUT PREVENTER STACK PLATFORM C M.G.S., COOK INLET, STATE OF ALASKA DiETERICHoPO~,T CLEARPRINT IOOOH 15 22 27 T8 N,RI3W, S.M. 0 14 5 23 24 C-41-25 0 ADL 18756 C-24-14 RD. (~-- ..... 259E C-2Z-26 0 C-31-26 0 26 25 D!V:SIOIq OF OIL AND GAS A]:x'~CHORAGE LOCATION OF CONDUCTOR 2, LEG I LOCATION OF PRODUCING ZONE WELL C-24-14 RD PUBLIC LAND DESCRIPTION CONDUCTOR 2 LEG I LOCATED 5.67'N AND 1.35'E FROM CENTER LEG I :5:522'N. AND 2596'W. FROM THE S,E. COR. CENTER LEG I L. OCATED 541.65'N. AND 1596.41'W. SEC. 14, T. SN.,R.i:5 W., S.M. FROM THE S.E. COR. OF SEC. 23 T. SN.,R. 13W,, S.M. DRAWN BY c. CKEO SHELL OIL DATE 5-15-75 COMPANY SCALE I"= 2000' Z-V- 147 LOCATION OF SHELL -ARCO-STANDARD WELL C-24-14 RD. IN SEC. 23 T. SN.,R, ISW,, S.M.-COOK INLET- STATE OF ALASKA (,~tVl O C June 9, 1975 Shell Oil Company P. O. Box 831 Houston, Texas 77001 Attn: P. J. Carroll Amoco ProduCtion Company SDecurity Life Building enver, Colorado 80202 , P. J. Early Division Production Manager A. M. Roney Assistant Division Production Manager T. M. Curtis D. D. GilJiam District Superintendents File.: LAD-252-538.9 A 34-14 and C 24-14 Redr~l!o Middle Ground Shoal Field In reply, to your letter' of May 26, 1975 this is to furnish' our concurrence with your plans to redrill A 34-14 to the 24-14 location and redrill C24-14 to the 22-23 location in the Middle Ground Shoal Field. WEP/keb 627 290 --% UN IT 197% J W£STERI~ PR~DU'lteN DIVISION J i ~O,.. ,,cd~,,. ~DIv. '.,'. M,,.I ~ my. Bus. ~rd. ~ Kc.. I J ANCHORAGE Form ! 0-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELI. I i OTHER ~- NAME OF OPERATOR Shell 0±1 Corn?an7 3. ADDRESS OF OPERATOR P.0. Sox 92047, Worldwa¥ Center, T.os A~geles, ca.90009 4, LOCATION OF WELL Atsurface Conductor 2, leg i at 5.67' N, 1.35' E from center leg 1 at 541.65' N and 1596.41' W from SE corner, Section '23 13. ELEVATIONS (Show whether DF, RT, GR, etc.) D.F. at 105' Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L__J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS _ (Other) 5. APl NUMERICAL CODE 50-:!:33-20251 6. LEASE DESIGNATION ANO SERIAL NO. ADL 18756 7. IF INDIAN, ALLOTTEE OR TRIBE NAME None 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. MGS C-24-14 10. FIELD AND POOL, OR WILDCAT MGS EFG Pools 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section '23 ~ T.8N. ~ R.13W. 12. PERMIT NO. 73-12 3ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Proposal: le 2. 3. 4. 5. 6. To abandon existing C 24-14 hole preparatory to redrilling. Install andtest BOPE equipment. Pull 3-1/2" tubing and packer. Cementover perforations at 9884'/10,.749'. Fill with heavy mud to 4000'. Mill window in 9-5/8" casing at 4000'. Cement.across window in'preparation for redrill. 16. I hereby certify th.at the foregoing Is true and correct (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE ..... DATE See Instructions On Reverse Side CHECK LIST FOR NEW WELL PERMITS · Is the permit~ fee attached ................... Company Yes No-Rema¢'kS .... - .............. .. Is well to be located' in a defined pool ............... ). Is a registered survey plat attached ................ .tm~K t. Is well 1.ocated proper distance from proper.,ty line ......... ~K i. Is well located proper distance from other wells .......... 2. Is sufficient undedicated acreage available in this pool ...... ,ts well to be deviated ........... x~ -) ............ :t. Is operator the only affected party ................ x~:?.~ 9. Can permit be approved before ten-day wait ............. ~ /v~v'~ ~e ¥ ~,>?. O. Does operator have a bond in force ................. , ~< 1. Is a conservation order needed ...... - ........... ~ . ~x~ 2. Is administrative approval needed ................. ~ 3. Is conductor string provided ................. · .... 4. Is enough cement used to circulate on conductor and surface .... 5. Will cement tie in surface and intermediate or'production strings ~6. ~ill cement cover all known productive horizons .......... ,7. Will surface casing protect freshwater zones ........... I8. Will all casing give adequate safety in collapse, tension & burst 19, Does BOPE have sufficient pressure rating ............. Add~t~ona! Requirements: . ~~.~ ~.~~ C/J/7: ~ '- ~ - . ~ - , Approval Recommended- Engineering: OKG HHH _~ LCS ~ dCM Revised 1/15 5 Geol og~v TRM JAL HWK