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Image' roject Well History' File Cover I~'i je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j_g(~C:L - 0 J-~-- Well History File Identifier Organizing i~o,,~t [] RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~WINDY OVERSIZED (Scannable) '~ Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~-~')'-' x 30 = ~ + BY: BEVERLY ROBIN VINCENT SHERYL(~ WINDY DATE: ~----~~;~)/~/SI TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~' YES NO IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY~ GRAYSCALE OR COLOR IMAGES ) NO RESCANNED B~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IsI Quality Checked 12110/02Rev3NOTScanned.wpd XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687 -0862 (Fax) January 9,2004 Alaska Oil and Gas Conservation Commission Attn: Ms. Sarah Palin 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Report of Sundry Operations: Well C22-23 Dear Ms. Palin, XTO Energy, Inc. hereby submits its Sundry Report (Form 10-404) for the perforating treatment performed on the C22- 23 on Platform C in the Middle Ground Shoal Field of Cook Inlet. Please find attached the following information for your files: 1. Form 10-404 Report of Sundry Operations 2. Daily Operations Report 3. Current Well bore Diagram If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, 9aJ/.Y Paul L. Figel Sr. Production Engineer Cc: Doug Marshall Tim Smith @~iv\¡\~¡r~¡~Jt ~~ÅN 1 4 200r1. ORIGINAL RECEIVED JAN 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage ". STATE OF ALASKA ALASí JIL AND GAS CONSERVATION COMtv1¡ ION REPORT OF SUNDRY WELL OPERA liONS Suspend Repair Well D Pull Tubing D Perforate ..j Waiver Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 88-16 Service D 6. API Number: 50- 773-20397 -00 Other 1 . Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator XTO Energy Inc. Name: Operation Shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development [] Stratigraphic D 3000 N. Garfield, Suite 175, Midland, TX 79705 7. KB Elevation (ft): 35' KB 3. Address: 9. Well Name and Number: Middle Ground Shoal #C22-23 10. Field/Pool(s): MGS/"G" Pool 8. Property Designation: Platform "C", Leg 2, Condo @ 524' FSL, 1553' FEL, Sec. 23, T8N, R13W, SM 11. Present Well Condition Summary: Tubing: (size, grade, and measured depth) Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 10,307 feet true vertical 9,603 feet measured 10,202 feet true vertical 9,501 feet Length Size MD Plugs (measured) Junk (measured) TVD Burst Collapse 1,710' 13-3/8" 1,710' 1,624' 6,047' 9-5/8" 6,047' 5,547' 4,493' 7" 10,220' 9,519' Measured depth: 9,094.10,072' 2,730 6,870 1,130 4,750 7,240 5,410 True Vertical depth: 8,416-9,377' 2-7/8" 6.5#, N80 8,820' Packers and SSSV (type and measured depth) Baker DB Packer, Baker TE5 SSSV 8,788',322' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 5 89 940 40 58 650 15. Well Class after proposed work: Exploratory D Development [] 16. Well Status after proposed work: Oil[] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 1 29 Tubing Pressure 100 95 Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: Contact Paul L. Figel Printed Name Paul L. Figel Title Sr. Production Engineer Signature Date 1/9/04 ~, b J Form 10-404 Revised 12/2003 1 XTOENRGYINC. WELL: MGS C22-23 Daily Report Objective: Coil tbg Perforate 12-5-03 Performed State test on the Baker TE5 SSSV. All Depths are WLM unless where noted. RU WL & press tested lubricator. Rill wI 2.190" tapered gauge ring. Sat down @ 7,667' (EOT @ 8,790' MD). Jarred through to 7,772' but then had to use oil jars to get back above 7,667'. POOH. SDFN. 12-6-03 All Depths are WLM unless where noted. RIH w/1.85" tapered gauge ring. Went past EOT to 8,800' wlo a problem. POOH. RIH wI 1.75" sample bailer & tbg end locator. Located EOT @ 8,785'. Hung up in XN nipple @ 8,777'. Got free & cont'd DH to tag PBTD. Hit fill @ 9,600'. (Perfs @ 9,094 - 10,064' MD & PBTD @ 10,202' MD.) Bailed through bridges @ 9,600', 9,603' & 9,605'. Stopped bailing @ 9,607' when tools got sticky. POOH. Bailer Yz full with oily scale. RD WL. 12-9-03 Offloaded boat wI BJ coil tbg equipment & Halliburton TCP guns. BJ crew arrived 5 hrs late to location due to chopper SD for fog. 12-10-03 Completed RU coil tbg equipment. AOGCC rep on loc to witness BOP test. Conducted pre-job safety mtg. RIH wI wash nozzle @ 100 fpm while pumping slick FIW. Slowed coil tbg rate @ 9,400' to 20 fpm, switched to heated FIW & incr pump rate to 1.5 BPM. Tagged fill @ 9,620'. PBTD @ 10,202'. Made 11' hole in 30 min. Hit hard fill @ 9,633' & could not get DH. PUR 10' & ran back down to 9,633'. Incr pump rate to 2.0 BPM. Spent 50 min trying to get past 9,633' wlo success. Returns coming back solids free wI black oily water. Decided to POOH. Will need to PU motor & mill to cut through hard fill. 12-11-03 Removed inj head & LD wash nozzle. MU Baker NaviDrill mud motor & 2.3" step mill on 1- 3/4" coil tbg. Installed inj head & press tested lubricator to 1,000 psi. RIH wI step mill while circ slick FIW to flowback tank. Tagged XN nipple @ 8,795'. Incr pump rate from 0.25 BPM to 1.5 BPM. Milled out shoulder in profile nipple in 10 minutes. Rill to 8,885' to make sure tbg is clear. PUR to 8,785'. Made 3 passes across XN nipple @ 8,795' with mill. Cont'd DH to tag fill. Tagged fill @ 9,630'. Mud motor stalled out and stacked weight on 1st attempt to mill through fill. PUR 10'. Cont'd DH @ 1 fpm & passed through bridge @ 9,630' wlo any press incr on motor or weight loss on bit on 2nd attempt. Cont'd DH for 25' wlo a problem. PUR 9,620' and made 2nd pass DH wlo any problem. Washed down in 50' stg's & PUR and circ BU. Pumped 20 bbl gel sweeps every 100'. Returns coming back wI iron sulfide. Tagged PBTD @ 10,200'. (2' lower from coil tbg job in Aug 2003.) Circ 20 bbl gel sweep to surface. POOH wI motor & mill. SDFN. 2 12-12-03 Removed inj head & LD Baker motor & mill BHA. MU Baker 1-11/16" Vortex wash tool on coil. Installed inj head. Press tested lubricator to 1,000 psi. Rill wI Vortex wash tool @ 100 fpm while circ @ 0.25 BPM slick FIW to top of perf's @ 9,094'. Incr pump rate to 2 BPM and washed perfs wI slick FIW while Rill @ 15 fpm. Washed DH in 60' stgs & PUR 30'. Tagged bottom @ 10,209'. Circ 20 bbl gel sweep to surface. POOH @ 50 fpm while pumping 2 BPM across perf section 10,064 - 9,094'. Incr tbg rate & slowed pump to 0.25 BPM while pulling to surface. SD coil @ 7,800'. BJ operator spotted bad spot on coil tbg. Tbg was dimpled/kinked beyond usage. Finished POOH. Suspended operations. Blew coil dry with N2. RD coil reel to send to onshore for repairs. Will cut out bad section of tbg, butt weld & x-ray the weld. Should have coil back by Sat. 12-13-03 SD job. Sent BJ coil tbg reel to onshore to be repaired. BJ crew went in chopper. 12-14-03 SIWHP = 640 psi. SI SSSV & bled off press. BJ coil tbg reel & crew back on loco Crew found a crushed cotter pin in the inj head oil pan which appears to be the cause of the dimple in the coil tbg. RU coil tbg reel to inj head. RU external coil connector. Performed pull & press test. Failed press test. Cut off coil connector. Installed 2nd external connector. Failed press test. Cut off coil connector. Installed BJ internal dimple coil connector. Passed pull & pressure test. MU disconnect & tbg end locator. Conducted safety meeting prior to MU TCP guns. MU 11 ea 2" Halliburton Millennium hollow carrier guns loaded @ 4 jspf. Connected guns & firing head wI circ sub to coil tbg. RU inj head on lubricator. Zeroed depth counter with tbg locator @ rig floor. Opened SSSV. WHP = 140 psi. RIH wI TCP guns @ 100 fpm while circ slick FIW @ 0.25 BPM. Slowed coil rate @ EOT. Located EOT @ 8,785'. Cont'd DH. Tagged bottom @ 10,189'. PUR to have lowest shot @ 10,072'. SD. Dropped Yz" ball. Pumped ball DH for 20 bbl @ 1 BPM. Pumped last 9 bbl @ Y2 BPM. Guns fired @ 3,450 psi & SD pump. WHP = 140 psi @ 0 min, 110 psi @ 5 min, & 90 psi @ 10 min. Perf'd HR-HZ from 9,840 - 10,072' @ 4 jspf & 60 deg phasing (232' net wI 928 holes). POOH while circ Yz BPM. SD POOH @ 1,525'. Found pinhole leak in coil tbg. Finished POOH. Held safety mtg prior to RD guns. Stood back injector head. Pulled guns. All shots fired. SI swab valve. BJ blew lines & coil reel dry wI N2 for freeze protection. 12-15-03 BJ made repairs on inj head. Found broken roller. Set dumpster on rig floor. Cut off + 1,550' of coil tbg in 8' sections wi torch. Still have enough tbg on reel for continuing the job. MU internal dimple coil connector. Passed pull & pressure test. MU disconnect & tbg end locator. Conducted safety meeting prior to MU TCP guns. MU 11 ea 2" Halliburton Millennium hollow carrier guns loaded @ 4 jspf. Connected guns & firing head wI circ sub to coil tbg. RU inj head on lubricator. Zeroed depth counter with tbg locator @ rig floor. Opened SSSV. WHP = 65 psi. Rill wI TCP guns @ 100 fpm while circ slick FIW @ 0.25 BPM. Slowed coil rate @ EOT. Located EOT @ 8,790'. Cont'd DH to have lowest shot @ 9,820'. SD. Dropped Yz" ball. Pumped ball DH for 20 bbl @ 1 BPM. Pumped last 8 bbl @ Yz BPM. Guns fired @ 3,600 psi & SD pump. SI wing valve to production header. WHP = 191 psi @ 0 min & 10 min. Perf'd HN-HR from 9,590 - 9,820' @ 4 jspf & 60 deg phasing (230' net wI 920 holes). POOH while circ Yz BPM. SD wI guns @ rig floor. Held safety mtg prior to RD guns. Stood back injector head. Pulled guns. All shots fired. SI swab valve. BJ blew lines & coil reel dry wI N2 for freeze protection. SDFN. 3 12-16-03 Conducted safety meeting prior to MU TCP guns. MU 9 ea 2" Halliburton Millennium hollow carrier guns loaded @ 4 jspf. Connected guns & firing head wI circ sub to coil tbg. RU inj head on lubricator. Zeroed depth counter with tbg locator @ rig floor. Opened SSSV. WHP = 41 psi. Rill wI TCP guns @ 100 fpm while circ slick FIW @ 0.25 BPM. Slowed coil rate @ EOT. Located EOT @ 8,788'. Cont'd DH to have lowest shot @ 9,565'. SD. Dropped Yz" ball. Pumped ball DH for 20 bbl @ 1 BPM. Pumped last 8 bbl @ Yz BPM. Guns fired @ 4,100 psi & SD pump. SI wing valve to production header. WHP = 100 psi @ 0 min & 10 min. Perf'd HK- HN from 9,385 - 9,565' @ 4 jspf & 60 deg phasing (180' net wI 720 holes). POOH while circ Yz BPM. SD wI guns @ rig floor. Held safety mtg prior to RD guns. Stood back injector head. Pulled guns. All shots fired. Released Howco. SI swab valve. MU check valve & jet nozzle onto coil tbg. Stab inj head on lubricator. Opened swab valve. Prime up N2 pump. RIH wI coil averaging 1,000 fph while jetting well @ 350 scf/m. Hole capacity to top perf incl 2-7/8" x 9- 5/8" annulus to the orifice is 592 bbl. Stopped coil @ 5,000'. Recovered 107 bbl water (23 bbl/hr). N2 pump press = 1243 psi & 63 psi WHP. Started staging down in 500' increments every hr @ 275 scflm to 8,500'. N2 pump press = 1,860 psi & 41 psi WHP. Recovered 272 bbl in 12 hrs. Only had 5 hrs left of N2. SD N2 pump for 2.5 hrs to see if fluid would unload from backside. Started up N2 @ 8,500'. PUR to 6,000'. Started getting water @ 32 BPH. Will cont to jet until out of N2 product. 12-17 -03 Cont'd jetting well wI N2 @ 6,000' while waiting on returns. Got 8 bbl in 15 min. Started Rill to 7,000' . Stayed @ 7,000' jetting in water @ 24 BPH. Ran out of N2 product. Recovered 347 bbl with jetting operations. POOH wI coil tbg. RD BJ coil tbg equipment & load on boat. Released crew. Put well on gas lift. 12-18-03 Well in test producing: 14 BOPD, 101 BWPD & 43 mscfld @ 844 mscfld inj gas @ 555 psi Csg press. Orifice is in GLM #5. 12-19-03 Well in test producing: 35 BOPD, 105 BWPD & 61 mscfld @ 953 mscfld inj gas @ 600 psi Csg press. Orifice is in GLM #5. 12- 20-03 Well in test producing: 30 BOPD, 60 BWPD & 36 mscfld @ 921 mscfld inj gas @ 650 psi Csg press. 12-21-03 Well in test producing: 26 BOPD, 86 BWPD & 38 mscf/d. SI well to perform GL V work with moving the orifice from GLM #5 to #8. RU WL & press tested lubricator. All depths are WLM unless where noted. RIH wI N-kick over tool and ML pulling tool. Pulled the following valves: GL V # 5 Orifice (5/16") @ 6,508', GL V # 6 dummy valve @ 6,945', GL V # 7 dummy valve @ 7,291', & GLV # 8 dummy valve @ 7,658'. RIH wI N-kick over tool & following new GLV's: GL V # 5 (lA" port wI 990 psi TRO) @ 6,508', GL V # 6 (114" port wI 975 psi TRO) @ 6,945', GLV # 7 (lA" port wI 965 psi TRO) @ 7,291' & GLV # 8 orifice valve (3/8" port) @ 7,658'. POOH. RD WL. Put well on gas lift. NOTE: GLM's 9-11 contain dummy valves. 4 12-23-03 Well in test producing: 20 BOPD, 113 BWPD & 25 mscfld @ 1,169 mscfld inj gas @ 660 psi Csg press. 12- 24-03 Well in test producing: 17 BOPD, 69 BWPD & 47 mscfld @ 1,169 mscfld inj gas @ 680 psi Csg press. 12- 25-03 Well in test producing: 15 BOPD, 86 BWPD & 39 mscfld @ 1,177 mscfld inj gas @ 685 psi Csg press. Prod fluids are emulsified & extremely thick. Emulsion most likely caused from high volume of lift gas. Reducing the gas rate will cause well to die. 12-30-03 Well in test producing: 34 BOPD, 78 BWPD & 25 mscfld @ 969 mscfld inj gas @ 640 psi Csg press. 1- 2-04 Hooked up chemical line to wellhead tbg annulus to inject emulsion breaker down backside in the lift gas. 1-3-04 Well in test producing: 34 BOPD, 63 BWPD & 25 mscfld @ 959 mscfld inj gas @ 645 psi Csg press. 1-04-04 All depths are WLM unless where noted. RU WL & press tested lubricator. Rill wI single Panex Temp I Press gauge for flowing gas lift survey. Made stops 50' above and below GLM's 1 - 8 (9 - 11 contain dummy valves) & a gradient stop @ 8,153'. Emulsion breaker has been added to lift gas for past 3 days due to a thick emulsion being produced. Panex tool went DH very slowly after 1,200' due to the thick emulsion in the wellbore. POOH. Had good data. Appears that there is a hole in the tbg blw GL V 4&5. RD WL. 1-5-04 Well in test producing: 29 BOPD, 58 BWPD & 40 mscfld @ 873 mscfld inj gas @ 590 psi Csg press. Surf Gsg: 133/8",54.5 - 72#, K55/NT95. Set@1,710'. Gmt wI 500 sx + 341 sx for TOP JOB. Intermediate Gsg: 9 5/81" 47~ 53.5#, N80/S95. Set @ 6,047'. Gmt wI 545 sx. Prod Liner: r L80/N80 @ 5,727-10,220' 26#: 5,727 - 7,867' 29#: 7,867 - 8,148' 32#: 8,148 - 8,622' 35#: 8,622 - 10,220' Gmt wI 1,125 sx. Sqzd TOL wI 250 sx. PBTO: 10,202' (9,501') TO: 10,307' MO (9603' TVO) PLF 1-9-04 KB: 35' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# N80 8rd EUE @ 8,790' Set 6-7-2000. Baker TE5 SSSV @ 322' 2-7/8" X Nipple (2.313" ID) 9Cr @ 8,780' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,781' Baker (80-82) w/10' Seal Assbly @ 8,788' r Baker Model D Perm Pkr (80-32) @ 8,788' 10' Baker Sealbore Ext X-Over 5" Acme X 2-7/8" 8rd EUE @ 8,801' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,802' 4' Pup Jt 2-7/8" 6.5# 8rd @ 8,808' 2-7/8" XN Nipple MO to (2.3" 10) 9Gr @ 8,812' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,813' 2-7/8" WLREG @ 8,820' GR-GS: to be perf'd later HC-HD: 9,094 - 9,129' HE-HF: 9,200 - 9,253' HK-HN:(Reperf'd) 9,385 - 9,565' (720 shots) HN-HR: (Frac'd) 9,658 - 9,790' (35 shots) HN-HR: (Reperf'd) 9,590 - 9,820' (920 shots) HR-HZ: (Frac'd) 9,879 - 10,064' (40 shots) HR-HZ: (Reperf'd) 9,840 - 10,072' (928 shots) Re: C22-23 Perf Procedure Subject: Re: C22-23 PerfProcedure From: Thomas Maunder <tom,maunder~admin.state.ak.us> Date: Tue, 02 Dec 2003 14:16:18 -0900 Thanks Paul, You have answered my questions. I will forward the sundry for approval. Good luck. Tom Maunder, PE Paul Figel@xtoenergy.comwrote: The well has about 300 psi on it due to either charging it up after the sodium per borate treatment we pumped in Sept to clean out the Halliburton water control polymer (WORCON) or the fact we are now connected to the 5,000 psi BHP from breaking up the polymer chain. The problem is that we are playing tug of war with the well trying to get all the polymer out of the well. If you bullhead 100 bbl FIW into the formation & backsurge the well hard, the well will flow water ±100 BPD for days. As soon as you turn the gas lift on, the well dries up. You get a wet mist w/ some slugs of water. I assume the flow velocity is too high for these polymer molecules to file out of the well in an orderly fashion w/o converging on the wellbore & choking off the inflow. The Halliburton water control guru told me these clean ups can takes weeks to months & unfortunately, it cost us a lot of gas to vacate the hole every time we load up to back surge. Tom Reese is supposed to test the SSSV this week before MIRU so we can make up our guns w/o a problem. The TE5 valve is 3 years old & should be in good shape. While jetting the well, we are forced to go to the test tank as the nitrogen would screw up the natural gas in the header system. As soon as the N2 bleeds down we'll go back to the production header. If by chance we do get a good oil cut in the Test Tank after we get bottoms, we can transfer the oil into the header vs disposal well w/ a T at the disposal well going to the header. I hope we get to encounter that problem. Paul Thomas Maunder <tom maunder@admi n.state.ak.us> Paul Figel To 1 of 2 12/2/2003 2:16 PM Re: C22-23 Perf Procedure 12/02/2003 03:34 PM <paul figel@XTOenergy.com> C22-23 Perf Procedure cc Subject Hi Paul, I had a chance to look more at the procedure. It appears that you are using the SSSV as a deployment valve in order to allow you to run "long" gun strings. It would seem appropriate to conduct a test of the SSSV prior to doing your operation?? Is this well presently capable of flowing?? Since it does have a SSSV, it is likely it will. The well should be filled with FIW due to your milling operation. You plan to lift with N2 and dispose of the fluid in the disposal well. Is it possible to recover and recycle the crude oil?? I don't know how the system on the platform works, but it would seem to be in XTO's (and the State's) financial interest to get all the oil You can. I look forward to your reply. Tom Maunder, PE AOGCC 2 of 2 12/2/2003 2:16 PM ¸TO ~E N~ERGY XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687-0862 (Fax) December 1, 2003 Alaska Oil and Gas Conservation Commission Attn: Mr. Randy Ruedrich 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval to Re-perforate: Well C22-23 Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits its Application for Sundry Approval to re-perforate the HK-HN, HN- HR & HR-HZ zones on well C22-23 on Platform C in the Middle Ground Shoal Field of Cook Inlet. This well was originally completed in 1988 with a limited entry perforation scheme on the HN-HR & HR-HZ for a 2 stage fracture treatment. We intend to re-perforate these zones to encompass the entire net interval. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic The start date for this treatment is planned for Monday December 8th. Therefore, please FAX a copy of the Permit to 432-687-0862 & contact me with any questions @ 432-620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc~ Kyle Hammond Doug Marshall Tim Smith ORIGINAL .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /E'/ APPLICATION FOR SUNDRY APPROVAL >' 2O AAC 25.28O 1. Operations performed: Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate []Time Extension [] Other [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter Suspended Well [] 2. Operator 4. Current Well Status 5. Permit to Drill Number: Name:zTO ~ :I:nc. Development [] Exploratory [] 88-16 3. Address Stratigraphic [] Service[] 6. APl Number: 3000 N. Garfield, Ste 175, [~icllancl, TX 79705 50- 733-20397-00 v" 7. KB Elevation (ft): 9. Well Name and Number: 35' I{~ Middle Gz'cxtr~ ~ ~C22-23 8. Property Designation: Platform "C",/,Le~ 2,.~,Cond. 10. Field/Pool(s): ~ 524' F~G, 1553' FEI,, Sec.23,TSN, ~1.3W, ~ tv~.~S/"O', Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft)t Effective Depth MD (ftl: Effective Depth TVD (ltl: Plugs (measured): Junk (measured): 10,307' 9,603' ~ 10,202' ~ 9,501' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,710' 13-3/8" 1,710' 1,624' 2730 1130 Intermediate 6,047' 9-5/8" 6,047' 5,547' 6870 4750 Production Liner 4,493' 7" 10,220' 9,519' 7240 5410 Perforation Depth MD (ft): t Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 9~ 094-10~ 064' 8~ 416-9~ 369 ' 2-7/8" 6 · 5#~ NS0 8~ 790 ' Packers and SSSV Type: Packers and SSSV MD (ft): Baker ~ Dacker, Baker TE5 SSS"¢ 8,758', 322' 12. Attachments: Description Summary of Proposal [] 13. Well Class after proposed work: Detailed Operations Program[] BOP Sketch [] Exploratory [] Development [] Service [] 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/08/03 Oil [] Gas [] Plugge~ Abandoned [] 16. Verbal Approval: Date: WAG [] GINJ [] WIN J[] WDSP[[~ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name P~ul T.. Figel Title Sr. Prodnctio~ Signature ~'¢~.,~/. ~ Phone 432/682-8873 Date 12/01/2003 ' -- ~' Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so representative may witness ._'~ c~ ".:!~ integrity[] BOP Test .'[~ Mechanical Integrity TesD Location clearance [] Plug Subsequent Form Required: ' ' ' ' Odgina~ Signed 8~' Sarah Palir~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 D i E: i k i ^ I Sub, nit i~ duplicate ENERGY XTO ENERGY INC. MGS C22-23 COOK INLET, ALASKA COIL TBG TCP PROCEDURE WELL DATA: SURFACE CASING: INTERMEDIATE CASING: 13 3/8" 54.5, 72# K55/NT95. Set @ 1,710'. Cmt w/841 sx. 9 5/8" 47, 53.5#, N80/S95. Set @ 6,047'. Cmt w/545 sx. PRODUCTION LINER: 7" N80/L80 @ 5,727 - 10,220'. Cmt w/1,125 sx. Sqz liner top w/250 sx. 26#: 5,727 - 7,867' 29#: 7,867 -.8,148' 32#: 8,148 - 8,622' 35#: 8,622- 10,220' TUBING: 2 7/8" 6.5#, N80, 8rd EUE @ 8,790'. PACKER: 7" Baker Model D Permanent Packer @ 8,758'. Set in June 2000. PERFORATIONS: PBTD: HC-I-ID: 9,094 - 9,129' HE-HF: 9,200 - 9,253' HK-HN: 9,385 - 9,436' & 9,442 - 9,5'64' HN-HR: 9,658- 9,790' (35 shots) HR-HZ: 9,879 - 10,064' (40 shots) 10,202' NET PAY: 336' BHST: BHP: SMALLEST ID: PRESENT STATUS: OBJECTIVE: 160 Deg F 5,000 psi 2 7/8" XN Nipple: 2.205" ID @ 8,782'. SI w/400 psi. Last production on 6-2001 was 26 BOPD, 353 BWPD & 18 mcf/d. Reperforate the HK-HN, HN-HR & HR-HZ zones through tbg using TCP guns on Coil Tbg. The well will be jetted in w/N2 after guns are laid down. NOTES: ~ Gq t t-4' ~,~ > There is a hole in the production tbg DH past GLV #6. > RU the 250 bbl PTS tank for the N2 jet job w/XTO flowback iron. > Will use regular FIW for operations. BJ to supply'friction reducer for milling procedure. Procedure 12-1-03 XT0 Energy Inc. MGS C22-23 Cook Inlet, Alaska PROCEDURE: 1. MIRU derrick over wellhead. Bleed-off WH pressure. 2. RU Slickline & press test lubricator to 2,000 psi. RIH w/+2.20" gauge ring to EOT @ 8,790'. Verify depths. POOH & LD gauge ring. PU tbg end locator & 2" drive down bailer. RIH to PBTD @ 10,202' or deep as possible. (Perforation job to follow will be @ 10,072'.) POOH & verify EOT. RD Slickline. e MIRU BJ 1.75" Coil Tbg unit, triplex fluid pump & N2 Unit w/6,000 gal N2. RU riser, BOP's & lubricator. MU Baker 2.30" Step Mill & 2-1/8" mud motor to coil tbg. Press test lines to 4,000 psi with FIW. Function & press test Coil tbg BOP's to 500 & 4,000 psi. Bleed-off press through the XTO flowback iron/HP hose tied into the production header system. Take the necessary measures to prevent static water lines from freezing oVer from RU to RD. Load the coil tbg reel w/diesel every night when SD b/w operations. Flush the diesel w/FIW back into the production header prior to RIH.. 4. Conduct a pre-job safety with all rig personnel. , Open the SSSV. Take returns up the backside into the prod header. RIH w/mill to 2-7/8" XN nipple @ 8,782' while circ slick FIW through the coil tbg. Tag up on the XN nipple & spray paint the tbg for reference on future runs. 6. Mill the shoulder out of the nipple to 2.30". POOH & LD the milling BHA. Hold a pre-job safety meeting before picking up the Halliburton perforating guns. It is NOT. necessary to turn off phones & transmitters with this gun system. Designate the essential personnel allowed on the rig floor while making up the guns. Monitor the well for any pressure during the pre- job safetY meeting and deploying the gun string. The SSSV must closed before der}lo¥in~ the ~un string. 1st Perf Run HR-HZ: 9,840 - 10,072': 8. Using the air hoist, MU the 2" Millennium TCP guns with safety plate. Guns to be loaded @ 4 jspf @ 60 degree phasing. Have solid landing bar available to deploy in gun string to set across the pipe rams if well starts to kick while MU TCP guns. Close pipe rams & kill well through the kill line. 9. Attach the firing head, deployment bar assembly and ball circ sub. Install ,a tbg end' locator for depth control. Connect the guns to coil tbg. RU the CTU injector head. 10. Lower the guns below the BOP' s. Close the pipe rams above the firing head & perform a 1,000 psi press test on the lubricator. Bleed off pressure through line going to header system. Procedure 12-1-03 3 XT0 Energy Inc. MGS C22-23 Cook Inlet, Alaska 11. Open the SSSV. Keep the Coil tbg annulus open. RIH with the TCP guns @ 80 fpm. Keep the pump circulating FIW @ +0.2 BPM through the coil tbg to prevent freeze up. 12. Slow to 20 fpm while the guns pass the packer/nipple section @ 8,870'. Stop & correlate the EOT @ 8,790' with the coil tbg depth. 13. Cont RII-I and tag up @ PBTD @ 10,202'. 14. Pull up hole to have guns correlated @ 9,840 - 10,072' (232' w/928 holes). Drop ball and circ ball down with FIW to the firing head. Press up to +3,000 psi to fire the guns. SD pump and watch press for 10 minutes. 15. POOH with Coil Tbg @ 100 fpm while pumping circ FIW @ +0.2 BPM. 16. Close the SSSV when guns reach the rig flOor. 17. SD operations. Halliburton TCP rep to conduct a safety meeting to address concems about the possibility of pulling live guns. 18. RD the injector head & lubricator. Break out the guns & verify that all shots were fired. 2nd Perf Run HN~HR: 9,590 - 9,820':, 19. Repeat Steps #8-18 (OMIT Step #13 in tagging PBTD). Hold safety meetings before making up and breaking apart the guns. Perforate HN-HR @ 9,590- 9,820' @ 4 spf, 230' w/920 holes. 3na Perf Run HK-HN: 9,385 - 9,565': 20. Repeat Steps #8-18 (OMIT Step #13 in tagging PBTD). Hold safety meetings before making up and breaking apart the guns. Perforate H.K-HN @ 9,385 - 9,565' @ 4 spf, 180' w/720 holes. N2 Jet Job: 21. Take returns through the coil tbg annulus to the 250 bbl test tank. Use the rig mud pump to dispose of liquids into disposal well C44-14RD. Have a 2" vent line going overboard for the N2. 22. Install wash nozzle on end of coil tbg. Install injector head & lubricator & test to 1,000 psi. 23. Open the SSSV. Prime up the N2 unit. RIH while jetting the well @ +350 scf/m. Work coil tbg down hole while maximizing the jetting rate & fluid recovery. 24. Pump all 6,000 gal N2 (558,000 scf) over the next 24 hrs to achieve a test on the new perf's. Record rates & liquid volume recovered in the test tank. Keep the test tank below 2/3 full. 25. POOH. Close the SSSV. RD BJ Coil tbg equipment. Procedure 12-1-03 X'TO Energy Inc. MGS C22-23 Cook Inlet, Alaska 26. Put well on gas lift. Test well 3-5 days recording hourly rates & volumes. Paul Figel Sr. Production Engineer Kyle Hammond VP Alaska Operations Procedure 12-1-03 MGS C22-23 Cook Inlet, Alaska Leg 2, Conductor 9 APl No.: 50-733-20397-01 Spud: 4-10-88 Surf Csg: 13 3/8", 54.5 - 72#, K55/NT95. Set @ 1,710'. Cmt w/500 sx + 341 sx for TOP JOB. Intermediate Csg: 9 5/8", 47- 53.5#, N80/S95. Set @ 6,047'. Cmt w/545 sx. Prod Liner: 7" L80/N80 @ 5,727-10,220' 26#: 5,727 - 7,867' 29#: 7,867 - 8,148' 32#: 8,148 - 8,622' 35#: 8,622 - 10,220' Cmt w/1,125 sx. Sqzd TOL w/250 sx. PBTD: 10,202' (9,501') TD: 10,307' MD (9603' TVD) Present Completion PLF 8-11-03 KB: 35' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# N80 8rd EUE @ 8,790' Set 6-7-2000. Baker TE5 SSSV @ 322' 2-7/8" X Nipple (2.313" ID) 9Cr @ 8,750' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,751' Baker (80-82) w/10' Seal Assbly @ 8,758' 7" Baker Model D Perm Pkr (80-32) @ 8,758' 10' Baker Sealbore Ext X-Over 5" Acme X 2-7/8" 8rd EUE @ 8,771' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,772' 4' Pup Jt 2-7/8" 6.5# 8rd @ 8,778' 2-7/8" XN Nipple (2.205" ID) 9Or @ 8,782' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,783' 2-7/8" WLREG @ 8,790' GR-GS: to be perf'd later HC-HD: 9094'-9129' HE-HF: 9200'-9253' HK-HN: 9385'-9436' & 9442'-9564' HN-HR: (Frae'd) 9658'-9790'(35 shots) HR-HZ: (Frac'd) 9879'-10064'(40 shots) November 3, 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: Report of Sundry Operations: Well C22-23 Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits its Sundry Report (Form 10-404) for the stimulation treatment performed on the C22-23 on Platform C in the Middle Ground Shoal Field of Cook Inlet. Please find attached the following information for your files: 1. Form 10-404 Report of Sundry Operations 2. Daily Operations Report 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 Marshall Tim Smith ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate F-~Time Extension [] Other [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter Suspended Well [] 2. Operator 4. Current Well Status 5. Permit to Drill Number: Name: ~ Energy Inc. Development I-~ ExploratoqE] 88/16 6. APl Number: 3. Address Stratigraphic [] Servic~ 50- 3000 N. Garfield, Ste 175, Midland, TX 79705 733-20397-00 7. KB Elevation (ft): 35' ~ 9. Well Name and Number:Mi,.,lrlle ~ ~/,,'i~,.. _~ 8. Property Designation: ?]_at¢orm "C", Leg 2, Cond 10. Field/Pool(s) @ 524' FSL~ 1553' FEL~ Sec. 23~ T8N~ R13W~ SM MGS/"G" Pool 11. Present Well Condition Summary: Total depth: measured 10.307 feet true vertical 9,603 feet Plugs (measured). Effective depth: measured 10~202 feet Junk (measured) true vertical 9,501 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1710' 13-3/8" 1710' 1624' 2730 1130 Intermediate 6047 ' 9-5/8" 6047 ' 5547 ' 6870 4750 ......... ........ ,i V Production 'l .... i .~ ...... ' ¢i ...... :.~ Liner 4493' 7" 10220' 9519' 7240 !' '"';""~ % ~" ~)~ Perforation depth· Measured depth:: '.~0V 0 4 "~r'~'¢':~"" '~', ' True vertical depth: ':' ';:"' '.*,' ~ :' 'iil}ti~ ;! "' ........ ; ........ "" """ '"" ~" ": ':' ~:'':,;''': ~' ;, ~,: ,~ ~,., ,%~, Tubing (size, grade, and measured depth) 2-7/8" 6.5# ~ '8~790'''~ '"" Packers and SSSV (type and measured depth) :Ba]m~ :E~ ~ 8758'; 322' Baker TE5 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9094-10064' Treatment description including volumes used and final pressure: Pm[x:1 3000 ]261 soditmCJ:xArate solutJ.c~ ~ 3500 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure TubiRg pressure Prior to well operation SI SI SI SI SI Subsequent to operation: 14 32 324 760 80 14. Attachments: 15. Well Class after proposed work: Exploratory [] Development [] Service [] Copies of Logs and Surveys run 16. Well Status after proposed work: Operational Shutdown [] Daily Report of Well Operations X Oil[] Gas [] WAG [] GINJ [] WINJ [] WDSPL [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: Contact Paul L. Fi~elI 303-236 Printed Name ~ul L. Fi~el Title Sr. Productic~ Engineer s, n ure Form 10-404 Revised 4/2003 XTO ENERGY INC. MGS C22-23 OPERATIONS REPORT Objective: Coil Tbg Cleanout & Stim Treatment 8/21/03 MIRU CTU. Held prejob safety mtg. Press tstd BOP's, blind rams & lubricator to 250 psi & 5,000 psi. Press tstd lines to 7,500 psi. Prep to RIH w/Rotojet hydroblaster tool. 8/22/03 Std RIH w/CT @ 40 fpm while pmpg slick FIW @ 1.5 BPM w/pmp press @ 5,500 psi, WHP @ 0 psi & csg press @ 370 psi. Got to 500' & POOH due to higher than normal pmp press to ck Rotojet tool. Found polymer gel plugging the filters in the trtg line & in the filter above the Rotojet tool. Cleaned out filters & ran back in hole. Lost 1.5 hrs dn time. Std back in hole @ 40 fpm w/pmp press @ 3,220 psi @ 1.5 BPM. Washed GLM' s w/2 passes. Slowed CT rate to 10 fpm while passing over the 2-7/8" prod fr 7,760'-8,790' where scale was prev encountered w/slickline. Stopped CT @ 8,790' (EOT) & circ 18 bbls 10% HC1 pickle acid up the 2-7/8" tbg followed w/slick FIW. Switched to 3% KC1FIW & cont'd RIH @ 50 fpm. Tagged up @ 10,198' (PBTD). Circ hole clean w/20 bbls gel pill followed w/slick 3% KC1FIW. Pulled up to 9,500' & SI WH. Performed an inj tst into the fmt w/3% KC1FIW. Inj @ 0.25 BPM @ 2,750 psi, 0.35 BPM @ 3,200 psi, 0.4 BPM @ 3,464 psi. Any rate above 0.25 BPM had steady press incr. Opened WH. POOH w/CT while circ FIW. Fin POOH. SI swab valve & RD BJ Coil tbg equip. Rel BJ crew. 8/23/03 Crane crew std to offioad CT equip fr platform to boat. The 2nd half of the job will resume when the sodium per borate arives in Alaska in mid September. 9/2/O3 All depths are WLM unless where noted. RU WL & press tstd lubricator. RIH w/2.44" scratcher. Cut what appears to be scale fr tbg hanger to 38'. Tools fell free after that, but bobbled due to well flow & possibly cutting light scale while RIH. Cont'd DH & sat dn on scale @ 6,958'. Cut scale to 6,975'. Decided to POOH & not cut scale @ this time due to pending sodium per borate stimulation bullhead job. Changed out 2.44" scratcher w/2.10" gauge ring. 9/3/03 All depths are WLM unless where noted. RIH w/2.10" gauge ring. Had a bobble @ 6,958', but did not sit dn. Cont'd DH w/o any problem. Ran out of EOT @ 8,800' & POOH. RIH w/Panex press temp tool for gas lift survey. Made stops 50' above & below the 8 GLM's w/1 gradient stop (GLM's 9- 11 have dummy valves). POOH. Dnloaded tool. 9/11/03 All depths are WLM unless where noted. RU WL & press tstd lubricator. RIH w/2.285" tapered gauge ring. Hit tight spots in tbg, but able to jar thru @ 7,043', 7,074', 7,106', 7,136', 7,167', 7,197', 7,227', 7,259', 7,302', 7,332', 7,363', 7,395' & 7,457'. Acted as though tbg collars were scaled up. Set dn @ 7,661' near GLM #8 w/more difficulty & did not force tool dn. POOH. RIH w/2-1/2" Daniel's KOT & ML pulling tool. Attempted to latch GLV #6, but tool would not set dn in pocket. Cont'd DH. Latched & pulled GLV #7 fr 7,291'. POOH. Latch had heavy dark scale on it. SDFN. 9/12/03 All depths are WLM unless where noted. Pulled the following GLV's w/N-KOT & ML pulling tool: GLV #7 fr 7,291', GLV # 6 fr 6,945' WLM, GLV # 8 orifice fr 7,658', GLV #5 fr 6,509', GLV #4 fr 5,787', GLV #3 fr 4,846', GLV #2 fr 3,579' & GLV #1 fr 1,962'. Set up tools to run dummy valves. SDFN. Current status: GLM's 1 - 8 are empty & 9 - 11 already contain dummy GLV's. 9/13/03 All depths are WLM unless where noted. RU WL. RIH w/the following dummy valves w/N-KOT: dummy valve in GLM #1 @ 1,962', dummy valve in GLM #2 @ 3,579', dummy valve in GLM #3 @ 4,846', dummy valve in GLM #4 @ 5,787' & dummy valve in GLM #5 @ 6,509'. POOH. SDFN. GLM's #6, #7 & #8 are empty. 9/14/03 All depths are WLM unless where noted. RU WL. RIH w/the following dummy valves w/N-KOT: dummy valve in GLM #6 @ 6,945', dummy valve in GLM #7 @ 7,291' & dummy valve in GLM #8 @ 7,658'. POOH. RD WL. 9/23/O3 Crew back on board to fin workover now that chemicals have arrived. Unloaded chemicals fr boat. Switched out mud Pmp #2 fr 3,500 psi liners to 5,000 psi liners. RU steam lines in pits. 9/24/03 RU treating lines fr mud pmp to WH. Press tstd lines to 5,000 psi. Heated up 500 bbls FIW w/3% KC1 to 120 deg F. Held pre-job safety meeting. Mixed in 10,000# sodium per borate (SPB) into the 500 bbl 3% KC1FIW. Std inj the SPB wtr dwn the tbg @ 1.2 BPM @ 100 psi WHP & Csg Press @ 100 psi. Caught press & inj @ 0.7 BPM w/WHP & CP @ 3,100 psi. Had 96 bbls pmpd @ report time. 9/25/03 Cont'd pmpg sodium per borate (SPB) fluid. Pmpd 1st 500 bbls w/10,000# SPB in 3% KC1FIW @ avg rate of 0.8 BPM @ 3,700 psi. Std 2nd stage of 1,000 bbls 3% KC1 w/10,000# SPB @ 12:00 hrs injecting @ same rate & press. 9/26/03 Cont'd pmpg sodium per borate (SPB) fluid. Fin Stg 2 of 1,000 bbls 3% KC1FIW + 10,000# SPB. Avg inj rate 0.8 BPM @ 3,775 psi WHP & csg press. SD @ 11:15. ISIP 3,450 psi, 5" SIP 3,150 psi, 10" SIP 2,975 psi & 15" SIP 2,775 psi. Let SPB fluid soak for 8 hrs. SIP @ 8 hrs 1,665 psi. Std injecting Stg 3 of 1,000 bbls 3% KC1FIW + 10,000# SPB. Avg inj rate 0.7 BPM @ 3,825 psi WHP & csg press. 9/27/03 Cont'd pmpg 1,000 bbl sodium per borate (SPB) fluid. Avg Inj rate 0.5 BPM @ 3,750 psi WHP & Csg Press. SD @ 22:45. ISIP 3,500 psi, 5" SIP 3,110 psi, 10" SIP 2,980 psi & 15" SIP 2,925 psi. Let SPB fluid soak for 8 hrs. SIP @ 1,775 psi, 8 hrs. 9/28/03 Std inj last 500 bbl stg of SPB @ 0700 hrs. Avg Inj Rate 0.5 BPM @ 3,800 psi WHP & csg press. Flushed SPB to top perf w/100 bbls 3% KC1. SD. ISIP 3,700 psi, 5" SIP 3,250 psi, 10" SIP 3,125 psi & 15" SIP 3,050 psi. Left well SI. Need to replace the dummy valves w/GLV's to put well on prod. 9/30/O3 All depths are WLM unless where noted. RU WL & press tstd lubricator. RIH & pulled the dummy gas lift valves 1-5 w/N-KOT & ML pull tool. RIH w/N-KOT & installed the following GLV' s: GLV #1 w/3/16" orifice & 940 psi TRO @ 1,968', GLV #2 w/3/16" orifice & 935 psi TRO @ 3,582', GLV #3 w/3/16" orifice & 930 psi TRO @ 4,844', GLV #4 w/l/4" orifice & 1,000 psi TRO @ 5,784' & GLV #5 w/5/16" orifice @ 6,508' WLM. RD WL. RU flowback lines to tst tnk. Turned well over to production to flowback sodium per borate fluid. Note: GLM's #6 to #11 are dummied off. 10/1/03 Put well on gas lift. Monitored flowback. Load coming back w/pH @ 10.5. Diverted production into tst tnk. Well is lifting @ orifice GLV #5 w/csg press @ 590 psi. Fluid volume began dropping after btms up. Well blew dry for 9 hrs & csg press dropped to 270 psi w/well producing back into main production header. Csg press is slowly bldg w/small increase in fluid (oil & wtr). 10/2/03 Cont'd flwg back well into tst tnk. Csg press went fr 370 to 800 back to 380 psi over past 24 hrs w/sporadic production rates. Well averaged 100 BPD w/97% wtr cut. The pH has dropped to 9. 10/3/03 Cont'd flwg back well into tst tnk. Well producing only about 80 BPD w/380 psi csg press. Decided to stop trying to flow back w/gas lift & proceed w/trying to surge well by pmpg in wtr to press up well & quickly work the valves to hammer the well. Pmpd FIW to fill tbg annulus. SI backside. Bullheaded 100 bbls 2% KC1 into the fmt displaced w/100 bbls FIW. Prep to surge well @ report time. 10/4/03 Surged back well into tst tnk @ 0500 hrs. Flowback line got plugged w/solids @ 0600 hrs. Switched to tst separator & cont'd to flowback well. Put well on gas lift to increase flowback rate. Well was unloading @ an hourly rate equivalent to + 1,100 BPD. Well was blowing mist @ 2000 hrs w/the csg press falling fr 550 to 380 psi. 10/5/03 Cont'd to gas lift well, getting little fluid over next 9 hrs. SD gas lift & SI well for 34 hrs. 10/6/03 Put well back on gas lift @ 1800 hrs. Did not get much liquid before well std blowing dry. Csg press fell fr 620 to 370 psi over 11 hrs. SD gas lift. SI well. 10/7/03 Std loading tbg annulus w/FIW. Pmpd 450 bbls FIW to load well in prep for more back surging. 10/8/03 Opened WH. Pmpd 100 bbls heated 2% KC1FIW dwn the tbg followed w/100 bbls FIW to displace KC1 wtr into the fmt. SD w/2,700 psi. Back surged well a dozen times. Left well SI to allow press to BU. Press would build 100 psi/min to 1,200 psi. Opened choke & let well cont to flow into the prod header fr 1500 hrs to 0100 hrs (Wed morning). Fluid was solids free w/white tint & pH 7. Estimated rate fr PAM was 800 BPD. Plan is to cont to backflow w/o using gas lift. 10/9/03 Put well in tst. Turbine meter shows the well to be flwg back @ 200 BPD & 100 psi WHP w/o gas lift assistance. Appears sodium per borate load is coming back as pH is 8.5. Well has been flwg steady for 30 hrs as of 2100 hrs. 10/10/03 Took well out of tst for the C13-13LN well tst. Well cont'd to flow unassisted w/a good steady production rate @ 180 psi WHP. The wtr produced contains an oil sheen over the past 12 hrs & still has a pH of 8. The well has also been producing gas over the past 24 hrs. Will cont to flow well without using gas lift for the time being. 10/14/03 Well is flwg wtr w/oil sheen w/o gas lift assistance. Well is producing some gas. 10/16/03 Put well in tst. Production is 102 BWPD + 1 BOPD. Well is continuing to flow w/o gas lift assistance. 10/22/03 Put well in tst. Production is 114 BWPD + 1 BOPD. Well is continuing to flow w/o gas lift assistance. Will put well on gas lift at end of week after compressor overhaul is complete. 10/25/03 Prod Test: 11 BO, 347 BW, 1,150 Inj Gas, 49 Prod Gas. CP @ 760 psi. 10/26/03 Prod Test: 14 BO, 324 BW, 1,165 Inj Gas, 32 Prod Gas. CP @ 760 psi. August 13, 2003 ¸TO ~E N~ERGY 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: Request for Sundry Approval to Stimulate: Well C22-23 Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits its Application for Sundry Approval to perform a stimulation treatment on well C22-23 (HC-HZ zones) on Platform C in the Middle Ground Shoal Field of Cook Inlet. This producer has been shut-in since June 2001 with the last test at 26 BOPD & 353 BWPD. In 1993, a water control treatment was performed that radically dropped oil production from 139 BOPD to 33 BOPD. An attempt will be made to recover this production by performing a matrix treatment With sodium per borate (SPB) to destroy the water control polymer. Prior to bullheading this SPB treatment, coil tbg will be used cleanout the scale in the 2-7/8" production. We anticipate the coil tbg cleanout to commence on Friday August 22nd, following the C42-23 Coil Tbg acid treatment. Since the sodium per borate product will not arrive until mid September, the 2nd half of the treatment will be postponed until that time. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic Please FAX a copy of the Permit to Platform C @ 907-776-2532 and contact me with any questions @ 907-776-2530 during the week Aug 18th, as I will be on location for the C42-23 coil tbg treatment. Paul L. Figel Sr. Production Engineer ORIGINAL Cc~ Doug Schultze Kyle Hammond Doug Marshall Tim Smith STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend After casing __ Repair well __ Plugging.__ Change approved program Pull tubing __ Operation shutdown Re-enter suspended well Time extension Stimulate... X Variance ~ Perforate ~ Other 6. Datum elevation (DF or KB) 35' 7. Unit or Property name t, ti.dd3.e 8. Well number 2. Name of Operator 3. Address 3000 N. C-,arEield, ..~te 175, MJ.c~.a..--~cl, ~ 79705 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface V/ ~ ~' Platform "C', Leg 2, (kax~. 9 @ 524'FSL, 1553'FEL, Sec. 23,T8N, R13W,~ At top of productive interval · 9,094' (8415 TVD), 2,716'FSL & 3541' FE~, Sec. 23,T8N, R13W, S.M. At effective depth At total depth · -10,307'(9603 TV~) 2,809' ~ & 3305' :F~!2,,Sec. 23,T8~,:R.1.3~,S.M. C22-23 9. Permit num~ 88-16 ' 10. APl number 50- 733-20397-00 1. Field/Pool [V~.-.~/"G" PO01 feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical ,/ 10,307' .feet 9,603 ' *¢~'feet Plugs (measured) 10,202 ' feet Junk (measured) 9,501 ' feet Casing Length Structural Conductor Surface 1,710' Intermediate6, 047 ' Production Liner 4,493' Perforation depth: Size Cemented 13-3/8", 54.5/72#,K55/NT95 841sx "G" 9-5/8",47/53.5#, N80/S95 545sx "G" 7",26-35#,N-80,L-80 1,375 SX "G" measured 9,094' - 10,064' true vertical 8,416'-9,369' Tubing(size, grade, and measured depth) 2-7/8", 6.5#, N-80~-lVJl3D;~J~to 8,790' Packem and SSSV(~pe and measured depth) Baker D~Packer@ 8,758' Measured depth True vertical depth 1710' 1,624' 6047 ' 5,547, 10,220' 9,519 ' 13. Attachments Description summary of proposal Detailed operations program BOP sketch 14. Estimated date for commencing operation 08/22/2003 16. If proposal was verbally approved Name of approver 17. I herebyt'E~"~fy that the fore2~ing is rue Signed ~~ ~. ~ Date approved 15. Status of well classification as: Oil x Gas ~ Service and correct to the best of my knowledge. Paul Figel Title Sr. Prcx~tio~ E~0ineer Suspended __ Date 08/13/2003 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission s.,,,q,,representative may witness Plug integrity BOP Test 1¢¢ Location clearance. Mechanical Integrity Test Subsequent form required 10- ~'4~I~ ~ Approved by order of the Commission ~~0 ~""<?:' ':~:" '~''' Form 10-403 Rev 06/15/88 Commissioner JApproval No...~O5' 25(~ Date ~~/~] SUBMIT IN TRIPLICATE XTO Energy Inc. MGS C22-23 COOK INLET, ALASKA COIL TBG CLEANOUT AND STIMULATION PROCEDURE WELL DATA: SURFACE CASING: INTERMEDIATE CASING: PRODUCTION LINER: TUBING: PACKER: PERFORATIONS: NET PAY: BHST: BHP: SMALLEST ID: PRESENT STATUS: OBJECTIVE: 13 3/8" 54.5, 72# K55/NT95. Set @ 1,710'. Cmt w/841 sx. 9 5/8" 47, 53.5#, N80/S95. Set @ 6,047'. Cmt w/545 sx. 7" N80/L80 @ 5,727 - 10,220'. Cmt w/1,125 sx. Sqz liner top w/250 sx. 26#: 5,727 - 7,867' 29#: 7,867 - 8,148' 32#: 8,148 - 8,622' 35#: 8,622- 10,220' 2 7/8" 6.5#, N80, 8rd EUE @ 8,790'. 7" Baker Model D Permanent Packer @ 8,758'. Set in June 2000. ~r HC-HD: 9,094 - 9,129' '~E-HF: 9,200 - 9,253' HK-HN: 9,385 - 9,436' & 9,442 - 9,564' HN-HR: 9,658- 9,790' (35 shots) HR-HZ: 9,879 - 10,064' (40 shots) 336' 160 Deg F 5,000 psi 2 7/8" XN Nipple: 2.205" 1I) @ 8,782'. SI on June 2001. Last Prod @ 26 BOPD, 352 BWPD, & 18 mcf/d as on 6-28-01. Attempt to restore the original productivity by dissolving the polymer from the Water Control Treatment (WORCON) pumped in 1993.~ If successful, it will be recommended to replace the gas lift system with a hydraulic pump to achieve a high drawdown to recover the lost oil production. Before the lift system is changed out, Coil Tbg will be needed to remove the scale from the production tbg prior to bullheading the sodium per borate (SPB) solution to destroy the polymer. Note: The Coil Tbg Clean out treatment will performed behind the C42-23 Coil Tbg acid job. The Sodium per Borate treatment will be pumped mid Sept due to waiting on chemicals. Procedure 8-13-03 XTO Energy Inc. MGS C22-23 Cook Inlet, Alaska NO ACID IS TO BE PUMPED INTO THE PRODUCTION HEADER SYSTEM. A 250 BBL FLOWBACK TANK WILL BE USED TO HANDLE ALL ACID & SODIUM PER BORATE RETURNS. Materials Required for 1st Job: 30 bbl Gel Pill (3#/bbl Flo-Visc + 5 gal/100 bbl Greencide provided by MI Drill Fluids) 1,000 bbl 3% KCL FIW Water (Friction Reducer Supplied by BJ) > 10,000 lbs Powdered KCL (1,000 lbs KCL/100 bbl FIW for 3%) N2 bottles to purge reel after job or N2 Unit 500 lbs Soda Ash (Supplied by MI) · 1,000 gal 10% Pickle Acid (Dowell's acid leftover from C24A-23LN) Equipment Required: · BJ 1 3fi" CTU: Install press gauges on CT, CT annulus and 2-7/8" tbg annulus. · 1 ea HP Triplex Pump · RotoJet Tool · Filter Skid (8 micron) · 250 bbl Flowback Tank ~ Mud Pump to be tied into tank to pump load to C44-14RD Disposal Well ~ Install 2" vent hose on top of tank to vent overboard )~ Add 500# of Soda Ash to tank · Retum line w/choke manifold to 250 bbl Surge Tank & to Production Facilities ~ Manifold to contain a sample catcher to monitor fluids pH ~ Send "clean" returns to Production Facilities ~ Send live acid and or fluids containing scale or solids to Flowback Tank · Have a H2S monitor @ the Flowback Tank Procedure 8-13-03 XTO Energy Inc. MGS C22-23 Cook Inlet, Alaska COIL TBG CLEANOUT PROCEDURE: Put C22-23 on Gas Lift and establish a pre-treatment production rate for 2-3 days. . SD Gas Lift. MIRU 1.75" Coil tbg unit, riser, BOP's & Injector head. MU RotoJet jetting tool. 'RU filter skid upstream of I-[P triplex. Contact AOGCC 24 hr~s prior to BOP test. Press test BOP's to 5,000 psi. Test treating lines to 6,000 psi. Max press is 5,000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.205" @ XN Nipple @ 8,782'. 2. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. . RIH w/Coil tbg @ 40 fpm while pumping @ +1.5 BPM slick FIW. (NO KCL until Step #5.) Slow rate to 5 fpm when passing over the Gas Lift Mandrels (See Attached WBD) and make 2 passes. Continue to RIH @ 40 fpm to 7,760' where scale was encountered with WL. 4. Con't to wash the 2-7/8" Prod tbg from 7,760 - 8,790' (EOT) @ 10 fpm @ _+1.5 BPM w/slick FIW. . Stop the RotoJet @ 8,790'. Pump 500 gal 10% Pickle Acid (Dowell's leftover Acid) up the 2-7/8" tbg at 1 BPM. Flush acid with slick 3% KCL FIW. (1000 lbs KCL/100 bbl FIW). Send acid returns to the Flowback tank. Tank to contain 500 lbs of Soda Ash. 6. Resume RIH @ 50 fpm to maximum 10,200' (PBTD) or as deep as possible while pumping slick 3% KCL FIW. 7. Tag up @ PBTD. Circ hole clean w/20 bbl Flo-Visc pill to surface followed with slick 3% KCL FIW @ 1.5 BPM. 8. Pull up to 9,500'. SI the wellhead. Establish an injection rate into the formation with 50 bbl 3% KCL FIW @ +1 BPM. Note the pump rate & WHP. 9. POOH with coil tbg @ 100 fpm from 10,200 - 8,800'. Slow coil tbg rate to 40 fpm and wash the 2- 7/8" tbg with slick 3% KCL FIW @ 1.5 BPM while POOH. 10. Close the Swab valve. Bleed off press. 11. RD Coil Tbg Unit & release Coil tbg crew. 12. Rig crew to rinse out Dowell acid tank with FIW into Flowback tank. Use the mud pump to unload Flowback tank to disposal well. RD lines & Flowback tank. Send tank to onshore. 13. Start up gas lift and put well into test. Monitor the well for _+5 days taking readings every hour for first 2 days. Take readings every other hour for 3-5 days. Put well back into regular test rotation after 5 days. Procedure 8-13-03 XTO Energy Inc. MGS C22-23 Cook Inlet, Alaska STIMULATION PROCEDURE: Shut down injector wells C24-23, C34-23 & C23-23 24 hrs prior to the Sodium per Borate (SPB) solution treatment. Materials Required: 40,000 lbs Sodium per Borate (SPB) 31,000 lbs 3 % KCL (1,000 lbs / 100 bbl FIW) 10,000 lbs Citric Acid (Neutralize SPB returns) 1. MIRU 250 bbl Flowback tank. RU lines from tbg annulus to the Flowback tank. RU mud pump suction to unload from Flowback tank to the disposal well C44-14RD. RU gas line from top of the Flowback tank into the production header to handle the lift gas. 2. Make sure pits are clean. RU steam lines in the pits. Fill pits with FIW. Heat water to 160°F. All FIW will contain 3 % KCL (1,000 lbs / 100 bbl FIW) 3. RU mud pump to wellhead. Press test lines to 4,000 psi. MAX PRESSURE = 3,500 psi. 4. Open wellhead & bullhead 3,000 bbl SPB solution down the tbg @ _+1 BPM according to the following schedule: Step FIW, bbl SPB, lbs Shutdown, hrs 1 500 10,000 2 1,000 10,000 3 8 4 1,000 10,000 5 8 6 500 10,000 Record pump rates, press and volume pumped at least every hour. 5. Displace the SPB solution to the top perf with 100 bbls of 3% KCL FIW. RD pump lines. 6. Leave well SI for 12 hours. . Start up gas lift. Flow well into the Test Tank and have designated person in control of the tank at all times to check for leaks & keep the produced fluids pumped down to the disposal well. Check fluid pH every _+ 100 bbl. If fluid is neutral after 300 bbl, the well may be diverted into the production header. Once the load has been recovered, put the well into test & take readings every other hour for 2-3 days. (Citric acid will be on location & may be required to neutralize the SBS returns in the Flowback Tank.) Put the injector wells back on line after gas lift is started. Record any use of the Disposal Well with fluid type, volume, and injection rates & pressure. Overflush fluid by 125 bbl FIW. Procedure 8-13-03 XTO Energy Inc. MGS C22-23 Cook Inlet, Alaska Paul Figel Sr. Production Engineer Kyle Hammond Vice President Operations, Alaska Procedure 8-13-03 MGS C22-23 Cook Inlet, Alaska Leg 2, Conductor 9 APl No.: 50-733-20397-01 Spud: 4-10-88 Present Completion PLF 8-11-O3 KB: 35' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# N80 8rd EUE @ 8,790' Set 6-7-2000. Surf Csg: 13 3/8", 54.5 - 72#, K55/NT95. Set @ 1,710'. Cmt w/500 sx + 341 sx for TOP JOB. Intermediate Csg: 9 5/8", 47- 53.5#, N80/S95. Set @ 6,047'. Cmt w/545 sx. GLM MD TVD POrt Psc PSo #1 1970 18563/16 882 950 #2 3580 3295 3/16862 914 #3 4844 4447 3/16844 882 :#4 5787 5221 3/8 Orifice i#5 6506 5951 1/4 802 833 i#6 6914 6311 1/4 781 811 #7 7298 6659 5/16762 815 [~8" 7655 6997 3/8 Orifice #9 8016 7349 durm~ #10 8378 7706 dumr~ #11 8738 8062 durrrny Prod Liner: 7" L80/N80 @ 5,727-10,220' 26#: 5,727 - 7,867' 29#: 7,867 - 8,148' 32#: 8,148 - 8,622' 35#: 8,622 - 10,220' Cmt w/1,125 sx. Sqzd TOL w/250 sx. Baker TE5 SSSV @ 322' 2-7/8" X Nipple (2.313" ID) 9Cr @ 8,750' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,751' Baker (80-82) w/10' Seal Assbly @ 8,758' 7" Baker Model D Perm Pkr (80-32) @ 8,758' 10' Baker Sealbore Ext X-Over 5" Acme X 2-7/8" 8rd EUE @ 8,771' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,772' 4' Pup Jt 2-7/8" 6.5# 8rd @ 8,778' 2-7/8" XN Nipple (2.205" ID) 9Cr @ 8,782' 6' Pup Jt 2-7/8" 6.5# 8rd @ 8,783' 2-7/8" WLREG @ 8,790' GR-GS: to be perf'd later HC-HD: 9094'-9129' HE-HF'. 9200'-9253' HK-HN: 9385'-9436' & 9442'-9564' HN-HR: (Frae'd) 9658'-9790'(35 shots) HR-HZ: (Frae'd) 9879'-10064'(40 shots) PBTD: 10,202'(9,501') TD: 10,307' MD (9603' TVD) 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 A Variance ~ Perforate Other 2. Name of Operator Cross Timbers Operating Company 3. Address 210 PARK AVE. SUITE 2350 OKLA. CITY, OK. 73102 5. Type of Well: Development X Exploratory Stratigraphic Servioe 4. Location of well at surface Platform "6", Leg 2, Cond.10 @ 524'FSL,1553'FEL, Sec. 23,TSN,R13W,SM 6. Datum elevation (DF or KB) 116' DF 7. Unit or Property name Middle Ground Shoal 8. Well number 622-23 At top of productive interval @9,094'(8415 TVD), 2,716'FSL & 3541' FEL, Sec. 23,TSN,R13W,S.M. At effective depth At total depth @10,307'(9603 TVD) 2,809' FSL & 3305' FEL,Sec. 23,TSN,R13W,S.M. 9. Permit number 88-16 10. APl number 5o- 733-20397-00 11, Field/Pool MGS/"G" Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,307' feet Plugs (measured) 9,603' feet 10,202' feet Junk (measured) 9,501' feet Casing Length Structural Conductor Surface 1,710' IntermediateC, 047' Production Liner 4,493' Perforation depth: Size Cemented 13-3/8",54.5~,K-55 500 sx "G" 9-5/8",43.5~,N-80 545 sx "G" 7",26-35~,N-80,L-80 1,375 sx "G" measured 9,094' - 10,064' true vertical 8,416' -9,369' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 AB-HOD EUE to 8,790' Packers and SSSV (type and measured depth) Baker DB Packer @ 8,756' Measured depth True vertical depth 1,710' 1,624' 6,047' 5,547' 10,220' 9,519' RECEIVED APR 04 2000 Ata~ka Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 04/22/2000 16. If proposal was verbally approved Oil X Gas Name of approver ~ Date approved Service 17. I ~,eZif.~a~~i. ng i_s tru~.d correct to the best of my knowledge. ,....v,,..f /)' ,,',,----"r..--~.,r-.----- Title Sr. Engi neeri ng Tech Signe~ Suspended Date 04/03/2000 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- IApp'r°Val N°' 3~'~ Approved by order of the Commission ORl~ SIGNED. BY Robert N. Christenson Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE CROSS TIMBERS OPERATING COMPANY MGS C22-23 COOK INLET, ALASKA ELEVATION: WELL DATA SURFACE CASING: PRODUCTION CASING: LINER: TUBING: PERFORATIONS: OBJECTIVE: KB: TD: 10307' (MD) 9603' (TVD) PBTD: 10202' (MD) ' (TVD) 13 3/8" 54.5-72# K55, NT95. Set ~ 1710'. Cmt w/500 sx, 341 sx Top job. 9 5/8" 47-53.5# N80, SOO95. Set at 6047'. Cmt w/545 sx. 7" 26, 29,32,35 # N80, LB0. TOL ~ 5727'. Set ~ 10220'. Cmt w/1125 sx, Sqz TOL w/250 sx. 2 7/8" 6.5# N80 ABMOD ~ 8790' HC-HD 9094-9129' HE-HF 9200-9253' HK-HN 9385-9436' HK-HN 9442-9564' fiN-HR 9658-9790' 35 SHOTS, Frac'd HR-HZ 9879-10064' 40 SHOTS, Frac'd Replace tubing and bleach treatment to remove WORCON polymer Note: this well will build to 800-900 psi at the surface w/orifice valve 4390' TVD. FIW should control this well. Have mud and weight material on location during workover operations. H2S 0 ppm on 3/30/2000. SL tools stuck in hole- see rig well file for details. 1. RU SL. Test lubricator. Pull ball valve and GLV #3 or as deep as possible. RD SL. , Skid rig and RU. Circ well w/FIW thru GLM from step 1. Install BPV. ND tree and NU BOP's. Test BOP's. PU out ofpkr and load backside w/FIW. POOH w/2 7/8" 6.5# NS0 8R EUE tbg (w/fish should come out of hole w/tbg). LD tbg and send to shore for inspection. Check all tbg for NORM per OIL 1.00(n)-1 (Revised 1/10/92). TIH w/Bkr G Locator seal assembly, 1 jt 2 7/8" 6.5# N80 8R EUE tbg, Otis X nipple 2.313" ID, 2 7/8" 6.5# NS0 8R EUE tbg and GLMs as follows: Existing GL design. Prior to running pipe, check with the Operations Engineer for modified design. Locate Bkr DB pkr ~ 8756' MD. Land tbg. Set BPV. ND BOP NU tree. Pull BPV. Return well to production. Item TVD MD Baker T5 SSSV 297 297 GLM #1 1604 1687 GLM #2 3067 3326 GLM #3 4390 4783 GLM #~ 5525 6023 GLM #5 6487 7110 GLM #6 7320 7987 GLM #7 8004 8680 RECEIVED APR 04 000 Alaska Oil & Gas Cons. Commission Anchornge MIRU Dowell CTU and pump. Test lines to 5000#. TIH w/jetting tool to PBTD ~ + 10202'. Jet well clean using FIW. Wash perfs using 500 gal of 7 ½% HCI. Work CT across perfs. Circ well clean. Pump 2000 gal of xylene across perfs. Displace into perfs using FIW. Pump bleach to dissolve WORCON treatment as follows: Spot 1600 gal of bleach across perfs from 9094 to 10064'; close surface valves; displace a total of 4000 gal of CROSS TIMBERS O1~~ ,TING COMPANY MGS C22-23 COOK INLET, ALASKA REPLACE TUBING AND BLEACH TREATMENT TO REMOVE WORCON 03/31/00 bleach into perfs. Over displace bleach w/100 bbl of FIW into formation. POOH w/CT. RD Dowell. Allow to soak 4 hrs. GL well back. Obtain samples of all fluids for Dowell to analyze for live acid. Doug l~lar~h~ll Date Doug SChultze '~ 'Date RECEIVED .aPR 04 000 Alaska Oil & Gas Coi3s. Commission gnohorage Cross Timbers Operating Company Present Completion MGS C22-23 Cook Inlet, Alaska Leg 2, Conductor 9 APl No.: 50-733-20397-01 Spud: Surf Csg: 13 3/8", 54.5 - 72#, K55/ NT95. Set @ 1,710'. Cmt'd w/ 500 sx., 341 sx. TOP JOB. Prod Csg: 9 5/8", 47#- 53.5#, N80/S00-95. Set @ 6,047'. Crnt'd w/545 sx. a, Liner Csg; 7" 26~, N80 @ 5727'-7867' 7" 29~, N80 @ 7867'-8148' 7" 32'8, L80 @ 8148'-8622' 7" 35~, 8622-10220' w/ 1125 sx. Squeeze Liner Top w/250 sx. .. btr:. 5111/99 KB: 105' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# N80 AB-MOD EUE. EOT @ 8790' Item TVD MD Ptro Por~ Flopetrol Landing Nipple @ 297' 29T Gas Lift Mandrel #1 1604' 1687' 950 12 Gas Lift Mandrel #2 3067' 3326' 935 12 Gas Lift Mandrel #3 4390' 4783' 5/16 orfice Gas Lift Mandrel #4 5525' 6023' "dummy Gas Lift Mandrel #5 6487' 7110' gas lift Gas Lift Mandrel #6 7320' 7987' valves" Gas Lift Mandrel #7 8004' 8,680' Baker "G" Locator w/2 Seal Units, 5' Ext, 2 Seal Units Muleshoe @ 8,755' MD (8078' TVD). Baker "DB" Packer ID = 3.25" wi10 SBE @ 8756' MD (8079' TVD). 10' 2-7/8" EUE PUP @ 8770' MD (8093' TVD) 2-7~8" Otis "XN" Nipple @ 8780' MD (8103' TVD) Otis Wireline Re-Entry Guide @8,790' MD (8113' TVD). GR-GS: to be perf later HC-HD: 9094'-9129° HE-HF: 9200'-9253' HK-HN: 9385'-9436' & 9442'-9564' HN-HR: (Frac Treated) 9658'-9790'(35 shots) HR-HZ: (Frac Treated) 9879'-10064'(40 shots PBTD: 10,202' TD: 10,307' MD (9603' 'I'VD) RECEIVED APR 04 000 Alaska Oil & Gas Co~s. Commission Anchorage .Cross Timbers Operating Company Present Completion MGS C22-23 Cook Inlet, Alaska Leg 2, Conductor 9 APl No.: 50-733-20397-01 Spud: Surf Csg: 13 3/8", 54.5 - 72#, K55/ NT95. Set @ 1,710'. Cmt'd wi 500 sx., 341 sx. TOP JOB. i. btr: 5/11/99 KB: 105' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# N80 AB-MOD EUE. EOT @ 8790' Item TVD MD Flopetrol Lan(ling Nipple @ 29~' 29--~ Gas Lift Mandrel #1 1604' 1687' Gas Lift Mandrel #2 3067' 3326' Gas Lift Mandrel #3 4390' 4783' Gas Lift Mandrel #4 5525' 6023' Gas Lift Mandrel #5 6487' 7110' Gas Lift Mandrel #6 7320' 7987' Gas Lift Mandrel #7 8004' 8,680' Ptro P( 95O 1 935 1 5/16 orfice "dummy gas lift valves" Prod Csg: 9 5/8", 47#- 53.5#, N80/S00-95. Set @ 6,047'. Cmt'd wi 545 sx. RECEIVED APR 04 000 Alaska 0ii & Gas C~s, Cor~mission Anchorage Liner Csg: 7" 26~, N80 @ 5727'-7867' 7" 29~, N80 @ 7867'-8148' 7" 32~, L80 @ 8148'-8622' 7" 35~, 8622-10220' W/ 1125 sx. Squeeze Liner ToD wl250 sx. Baker "G" Locator wi2 Seal Units, 5' Ext, 2 Seal Uni Muleshoe @ 8,755' MD (8078' TVD). Baker "DB" Packer ID = 3.25" wllO SBE @ 8756' M (8079' TVD). 10' 2-7~8" EUE PUP @ 8770' MD (8093' TVD) 2-7~8" Otis "XN" Nil3ple @ 8780' MD (8103' TVD) Otis VVireline Re-Entry Guide ~8,790' MD (8113' TVDI GR-GS: to be perf later HC-HD: 9094'-9129' HE-HF: 9200'-9253' HK-HN: 9385'-9436' & 9442'-9564' HN-HR: (Frac Treated) 9658'-9790'(35 shots HR-HZ: (Frac Treated) 9879'-10064'(40 shot PBTD: 10,202' TD: 10,307' MD (9603' TVD) January 13, 1994 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) for MIDDLE GROUND SHOAL C22-23 REFERENCE: SUNDRY APPROVAL NUMBER 93-197 Enclosed are duplicate copies of the Report of Sundry Well Operations (Form 10-404) for Middle Ground Shoal C22-23. Gas lift optimization efforts are ongoing but we feel it is appropriate to end the sundry operations for reporting purposes as of 12/20/93. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff Production Engineer STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~ ~ REPORT OF SUNDRY WELL OPERATIONS ,. 1. Operations performed: Operation shutdown __ Stimulate X._~_ Plugging__ Perforate __ Pull tubing__ Alter casing__ Repair well __ Other __ 5. ~ype et Well: 6. Datum elevation (DF or 2. Name of Operator Shell Western E&P Inc. Developmenl X 116' DF feet 3. Address 601 West 5th Avenue, Suite 920 Anchorage, Exploratory 7. Unit or Property name AK 99501 Stratigraphic~ Middle Ground Shoal Service ~8. Well Number =4. Location of well at surface Platform "C", Leg2, Conductor 10,524'FSL & 1553'FEL C22-23 Section 23, TSN,R13W, S.M. 9. Permit number/approval number At top of productive interval @9094' (8415' TVD) 2716'FSL & 3541'FEL Section 23, T8N, 88-16/93-197 R13W, S.M. 10. APl number At effective depth 50-733-20397-,0~ · @10,327 (9603' TVD) 2809'FSL & 3305'FEL Section 23, T8N, 11. Field/Pool At total depth R13W, $.M. Middle Ground Shoal, "G" Pool 12. Present well condition summary Total depth: measured 10,307 feet Plugs (measured) true vertical 9,603 feet Effective depth: measured 10,202 feet Junk(measured) 0RIGI~IAL true vertical 9,501 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,710' 13-3/8", 54.5-72#, K-55/NT-95 500 sx 1710' 1624' Intermediate 6,047' 9-5/8",47-53.5#, N-80/SOO-95 545 sx 6047' 5547' Production Liner 4,493' 7", 26,29,32,&35#, N-80/L-80 1375 sx 10220' 9519' Perforation depth: measured 9094'- 10,064' true vertical 8416'- 9369' R E C £ IV E D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80, AB-MOD. EUE @ 8790' JAN ] 8 1994 Packers and SSSV (type and measured depth) Baker "DB" Packer @ 8756' At~s. ka 0ii & G-as Cons. Commissio[ Anchorage 13. Stimulation or cement squeeze summary Jet'wash and acid squeeze treatment folloWed by WORCON treatment. Intervals treated (measured) 9094'- 10,064' Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 181 bbls. Injected 1155 gallons WORCON at 65:1. 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 139 55 557 860 110 Subsequent to operation 33 50 293 925 100 15. Attachments: 16. Status of well classificatio~ as: Copies of Logs and Surveys run Oil X Gas Suspended__ Service Daily Report of Well Operations ~ -- -- 17. I hereby certity tr,at the foregoing ;s true and correct to the best et my Knowlec~ge Signed (?---E <{'/~''~ Title staff Production Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ]Platform C: COiL TUBING PROJECT 26~127 AUTH- $95,000 DAILY REPORT 022-23 DAILY FOREMAN: T.A. REESE CUMULATIVE: DAI YTD: .... 0 TRI YTD: .... ~ DAYS & DAYS E~TIMATED~ COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FIW SPILLS: NO SPILLs REPORTKD TIME AND SUMMARY OF OPERATIONS: ~6:00-8:4§ SAF~T? MEETING. FINISH DETAILS BROUGHT UP IN SAFETY MEETINg. 8:45-11:40 RI~ WIT~ C.T, TAG FILL AT lOOeS. WASH TO 10100 AT 1 GOT HARD. POOM TO 100~5. 11:40-1~:~0 PUMPED 5 BBL$ OF GEL FOLLOWKD BY 117 B~L$ FIW AT I ~B~ F/M. 13:40-~OO TEST INTEGRITY OF TBG & C$~. TEST ~OOD, 4 OF 10 WEIGHT I I 1~:OO-~$:OO PUMP 2 BBL$ FW FOLLOWED BY 3~.5 BBLS 7-1/2~ HOD FOLLOWED BY 21.~ BBLSi FIW TO DISPLACE ACID OUT C.T, SOAK FOR 30 MINUTES, 15:OO-21:00 ~EGIN JET WAS~. PUMPED 5BBLS GEL AT I BBL P/M. STAR~ SET WASHING PERFORATIONS FROM 9094 TQ 10064 GOING IN THE MOLE AT 20FT, ~/M. DIRECTED A~ RETURNS TO SURG~ TANK, STARTED PUMPING FIW. ~TARTED OUT OF HOLE FROM 100~4 WHILE PUMPIN~ AT O~ ~19 ~BLS W~ILE PULLIN~ OUT OF HOL~. ~I~O0-E~;00 R/D COIL TUBINO UNIT ~O0 TO ~:00 PUMF 1~I ~GU$ FROM SUKUE TANK TO DISPOSAL WELL AT 5 BBL$ P/M. PUMP 100 B~LS OF FIW FOR FLUS~ FOR DISPOSAL WELL, ~:OO-a4:OO B~IN ACID SqUK~Z=. FUMF RECEIVED 10/'14/93 10:23 SAEP! NOItGON TRBATMB~ I s~arced pumping the WOKGON treatment, There w~s one proUlem du~lng ~ne opera~1on. A= 3=OOAM a l~ak dov~lopt~ in ~e ~n~fol~ t~ac ~e WORGON was ~elng pumped wt~h. At that ~lme approximately 1ZO gallons o= WOR~ON had been pumped. then st&r~ed ~he pump bac~ up. I ~houg~ ~e pump was primed at that t~me. I ~Aen continued w~n wl~n =ne ~ea~men~. The operator uh~cked ~he pump every hour ~hat and the pump was ot~ll work~ng. A~ a~u~ ~0:oo~ ~ank was s~rapped to verify that the volu~o were ~he p~j~ must have Io~ t~s prime, r assume it happened when ~he laa~ occured a~ 3,00~, By ~0:00~ 750 BB~S of wate~ had achieved. A~ 10:00~ ~ha p~p was p=l~ed. The=e wer~ 2 o~he= small problems wl~h =he pump itself. I~ f~oze o~f duo ~u ~ha supply air bgtng too wit. I unthawed the ~p both ~tmes, I~ dld not effect ~he dilution ra~e that was ~tng p~p~. I turn the injection wa~er off e~ch tt~e I turned the p~p off. ~t was off for about I0 to 15 ~nuteo each After ~ha~ tine ~here we~o no problems with the WOROON ~rea=men~. The pumping of the WORCON went as follows ~n ~he cable found below. The ~able begins after ~he pu~p hRd been reprimed a~ IO:OOAM. The ~mforma~on before was no good bfo~o that tine. 10:00 2700 ~392 7no I l~:o0 2750 1367 1~00 2~00 1~0~ ~60 13~00 ~&o Z&~O0 ~875 ~383 956 ' 1~O0 2900 ~402 16:00 2940 1360 1064 ~ 17:00 2975 1335 l~t00 3000 1320 1172 ' 19t00 3100 1400 20~00 3125 1330 1272 t 21:00 3150 g2~00 3~60 ~38~ 1327 } ~et00 3zee 1300 24~00 ~1~5 1240 14e0 02:00 3~78 ~240 1680 04~00 3200 ~250 1680 09~00 ~200 12~2 1701 ~0;00 322~ 1150 12:00 32~0 1121 2070 14:00 32~0 ~100 2~% I0:00 ~250 107~ 2200 10:00 3250 1065 2~40 20:00 3300 1100 2430 804 013 1011 1319 1428 01~00 3160 1220 1636 03:00 3200 1~60 1626 06:00 3200 1228 1736 o7;o0 ~zoo :.o~ ~e=~ 11:00 0~50 1145 2025 13:00 3200 1107 21t0 10:00 3~0 1000 ~10 17:00 32~0 1000 ~PE ~9:00 327~ 1070 ~07 20~00 3300 ~107 2440 [ ECEIVED Oas Cons. Commissiola 21: O0 3%00 01:00 05:00 09:~5 114~ Z~6~ 07:40 1140 3061 10:20 34~0 This completes ~he WORCON trea~men=. 1~40 IX40 RECEIVED From: EP388TAR--VI~5 To: EP38~RGB--VI~5 EP380LM --V~L35 R G BLACKBURN D L MARSHALL Date and time EP38PTH --V~5 11/08/93 10:54:26 P T HUCKABEE From: TOM REESE Subject: C22-23 ON 11-6-93. CHANGE OUT 1-3 GAS-LIFT VALVES %N ATTEMPT TO GET TO LIFT ~ TO GET RESULTS FOR WORCON TREATMENT. R%H ANO PULLED 1~ GAS-LIFT VALVE FROM 4755 CULM). HAOE 3 ATTEMPTS TO PULL GAS-LIFT FROM 3316 (NLM), BUT COULD NOT STAY LATCHEO ON RIH AND PULLED 1~ GAS-LIFT VALVE FROM 1670 R%H ANO ATTEMPTED TO PULL GAS-LIFT VALVE FROM 3316 CWLM), BUT COULD NOT STAY LATCHEO ON. SHUT OOWN TO WAIT ON NEW TYPE PULLING TOOL. LAST PRODUCT%ON TEST WAS AS FOLLO~IS: GROSS 200; CUT 879; CLEAN 22; %Nd 1368; PRO0 O; GOR O; TBG 100; CSG 870 N2S 12. From: TOM REESE Subject: C22-23 ON 11-7-93. FINISH UP GAS-LIFT CHANGE OUT. RIH WITH NEW DANIELS STYLE PULLING TOOL. PULLED 1~ GAS-LIFT VALVE FROM 3316; RIH WITH 1e~ DANIELS GAS-LIFT VALVE SET AT 950# WITH 3/16~ PORT. SET GAS-LIFT VALVE AT 1670 RIH WITH 1~ DANIELS GAS-LIFT VALVE SET AT 935# WITH 3/16~ PORT. SET GAS-LIFT VALVE AT 3316 (WLN). RIH WITH 1~ OANIELS GAS-LIFT VALVE SET AT 1000# WITH 1/4~ PORT. SET GAS-LIFT VALVE AT 4753 LAST PRODUCTION TEST ~AS AS FOLLOUS: GROSS 200; CUT 89; CLEAN 22; INJ 1368; PRO0 O; GOR O; TBG 100; CSG 870; H2S 12. From: TOM REESE Subject: C22-23 ON 11-23-93. RUN SURVEY TO DETERMIN WHERE WELL IS LIFTING FROM. RIH WITH PANEX PRESS/TEMP INSTRUMENT. MADE STOPS AT O, 1637, 17'~7, 3276, 3376, 4753, 48~3, 597~, 607~, 7060. POON. REAO SURVEY. INSTRUMENT FAILEO. LAST PRODUCTION TEST WAS AS FOLLCYJS: GROSS 329; CUT 90; CLEAN 33; INd 1068; PRO0 62; GOR 188&; TBG 110; CSG 925; SOP 59. From: TOM REESE Subject: C22-23 ON 11-24-93 RUN BALL VALVE. RIH ANO SET OTIS 2.313 BXE BALL VALVE AT 260 LAST PROOUCTION TEST WAS AS FOLLOWS: GROSS 329; CUT 90; CLEAN 33; INd 1068; PRO0 62; GOR 188~; TBG 110; CSG 925; SCP 59. ])ECEIVEO From: EP388TAR--VM35 To: EP383RGB--VM35 EP38DLM --VM35 Date and time R G BLACKBURN EP38PTH --VM35 D L MARSHALL 12/21/93 09:40:21 P T HUCKABEE From: TOM REESE Subject: C22-23 ON 12-20-93. SHOOT FLUID LEVEL ON CASING. SHOT FLUID LEVEL ON CASING. FLUID LEVEL AT 5940 WITH 925# ON CASING. FLUID LEVEL IS BETWEEN #3 AND #4 GAS-LIFT VALVE. IT INDICATES THAT WE ARE LIFTING OFF OF #3 GAS-LIFT VALVE. WAIT ON SURVEY TOOL. LAST PRODUCTION TEST WAS AS FOLLOWS: GROSS 326; CUT 90; CLEAN 33; INJ 1094; PROD 50; GOR 1534; TBG 100; CSG 925; SCP 44. cc: EP388CVW--VM35 EP388MAJ--VM35 C V WILLOUGHBY W A MILLER E P 388MGD- -VM35 M G DUNCKLEY END OF NOTE - 1 - Shell Western E&P Inc. An affiliate of Shell 011 Company 601 West Fifth Avenue Suite 800 Anchorage AK 99501 JULY 20, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL SHOAL WELL NO. C22-23 FOR MIDDLE GROUND Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment workover on MGS Well No. C22-23. The workover is anticipated to begin on August 15, 1993. If you have any questions, please call me at (907) 263-9646. Yours truly, P. T. Huckabee Staff Production Engineer PTH/maj Enclosures MAJ04\072093. WP5 A~ STATE OF ALASKA r'' AL -,,~ OIL AND GAS CONSERVATION COMMIS~ ,I APPLICATION FOR SUNDRY APPROVALS Suspend__ Operation shutdown __ Re-enter suspended well Plugging__ Time extension __ Stimulate X Perforate __ Other 1. Type of Request: Abandon Alter casing __ Repair Well Change approved program __ Pull tubing 12. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Variance 5. Type ct Well: Development X Exploratory Stratigraphic Service 4. Location of well at sudace At top of l)roductive interval At effective depth At total depth Platform C, Leg2, Conductor 10, 524'FSL & 1553' FEL Sec. 23, T8N, R13W, S.M. @9094' (8415 TVD) 2716'FSL & 3541'FEL Sec. 23, T8N, R13W, S.M. @ 10,307'(9603 TVD) 2809'FSL & 3305'FEL Sec. 23, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner 10,307 feet true vertical 9,603 feet measured 10,202 feet true vertical 9,501 feet Length Size 1,710' 6,047' 4,493' Plugs (measured) Junk (measured) Cemented 13-3/8",54.5-72#,K.55/NT-95 9-5/8",47-53.5#, N-80/SOO.95 6. Datum elevation (DF or KB) 116' DF feet 7. Unit or Property name Middle Ground Shoal 8. Well number C22-23 26,26,32,&35#, N-80/L-80 9. Permit number 88-16 10. APl number 50-733-20397-00 Perforation depth: measured 9,094'-10,064' true vertical 8,416'-9,369' Tubing (size, grade, and measured depth) 11. Field/Pool MGS/"G" Pool Measured depth True vertical depth 500 sx 1,710' 1,624' 545 sx 6,047' 5,547' 1,375 sx 10,220' 9,519' 2-7/8", 6.5#, N-80, AB-MOD. EUE @ 8,790' Packers and SSSV (type and measured depth) Baker "DB" Packer @ 8756' RE£E[VED 13. Attachments Description summary of proposal Date approved J U L. g 199: Alaska 0il & Gas Cons. Comm~SS~O' Anchorage 14. Estimated date for commencing operation 08/15/93 Detailed operations program __ BOP sketch 16. If proposal was verbally approved Name of al)prover 15. Status of well classification as: Oil X Gas Suspended Service Commissioner Date 07/20/93 FOR COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L'~_..~~ Title Staff Production Engineer IApproval No. ~pproved Copy Returned Date Conditions of approval: Notify Commission so representative may witness Plug integritym BOP Test__ Location clearance Mechanical Integrity Test~ Subsequent form require--d 10- ~c~ Original Signed By Approved by order of the Commission David We Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C22-23 We recommend a clean out and acid treatment of MGS C22-23 via coiled tubing unit (CTU) utilizing the soak/wash method of stimulation. A Worcon water shut off will also be done during coil tubing unit work (CTU). MGS C22-23 has had a significant oil decline since the last coil tubing work was performed in Oct 1991. The water cut has increased from 60% to 80%. The production decline is suspected to be the combined result of waterflood breakthrough from the more permeable zones, scaling impairment from the 60% to 80% water cut, and gas-lift outflow loading problems. A 150 BOPD production increase is expected from successful stimulation and worcon water shut off treatment of this well via coiled tubing unit. Proposed Operations Summary 1. Fill wellbore via the annulus with Filtered Inlet Water (FIW). 2. Rig up Coiled Tubing Unit (CTU), acid treatment materials & equipment, and return fluid processing materials & equipment. 3. Clean out wellbore to PBTD with downhole motor and bit/mill assembly. 4. Acid treat via CTU with 5 to 7-1/2% hydrochloric (HC1) acid. 5. Inject worcon water shut off via CTU. 6. Dispose of contaminated fluids in C44-14. Neutralize all return fluids that will be sent to production facilities. 7. Return well to production via gas lift. Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 December 16, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C22-23 Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C22-23. The operations were completed on October 15, 1991. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, R. G. Blackburn Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBMk121691.WP5 RECEIVED DE0 20 ~991 & Gas Cons. Commission Anchorage STATE OF ALASKA ALii''~, ~, OIL AND GAS CONSERVATION COMMI~ REPORTOF SUNDRY WELL 1. Operations performed: Operation shutdown __ Stimulate X Plugging__ Perforate__ Pull tubing __ Alter casing__ Repair well __ Other __ 5.1-ype ot Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Developmenl X 116' DF feet 3. Address 601 W. 5th Avenue, Suite 810 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic__ Middle Ground Shoal Service 8. Well Number '4. Location of well at surface Platform C, Leg 2, Conductor 10,624'FSL and 1553'FEL 022-23 Sec. 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval (..~9 9094'(8415'-rVD) 2716'FSL and 3541'FEL Sec. 23, TSN, 88-16/91-304 R13W, SM 10. APl number At effective depth 50-733-20397-0~ At total depth @ 10,307' (9603"T'VD) 2809'FSL and 3305'FEL Sec. 23, T8N, 11. Field/Pool R13W, SM MGS/"G" Pool 12. Present well condition summary Total depth: measured 10,307' feet Plugs (measured) true vertical 9603' feet Effective depth: measured 10,202' feet Junk (measured) true vertical 9501' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1710' 13-3/8", 54.5-72#, K-55/NT-95 500 sx 1710' 1624' Intermediate 6047' 9-5/8", 47-53.5#, N-80/SOO-95 545 sx 6047' 5547' Production Liner 4493' 26,26,32 & 35#, N-80/L-80 1375 sx 10,220' 9519' Perforation depth: measured 9094'- 10,064' true vertical 8416' - 9369' ,., Tubing (size, grade, and measured depth)D Packers and SSSV (type and measured depth) Baker "DB" Packer @ 8756' DEC 199! 13. Stimulation or cement squeeze summary Alaska 0ii & 6as Cons. Commission Intervals treated (measured) 9090' - 10,049' Anchorage Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 210 bbls. Squeeze ISIP = 1650 psi. 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 157 ~" 83 351 850 90 .,. Subsequent to operation 198 39 462 870 90 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X.~_ Gas__ Suspendedm Service '~ 7. I hereby certif:) .that the foregoing ~s true and correct to the best of my I(nowleage Signe~"~---¢ o~---,~ Title.~"~"TA~,c'r'~'¢.~O,..~c~,.=..~ '~4,~6¢-.,.¢&. Date ,'~,/,~f~ll Form 10-404 Rev :)6/15/88 SUBMIT IN DUPLICATE D~ILY REPORT WELL: C22-23 DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs) 10/14/91 - LOCATE NOZZLE @ 10,050'. PREPARE TO SQUEEZE. - COIL TUBING OPERATION ASSIGNED TO THIS WELL @ 0800 hrs, 10/14/91 FROM C31-26. - RELOCATE EQUIPMENT TO LEG #2 FOR WELL ACCESS IN 12 hrs. - VERBAL APPROVAL FOR SUNDRY APPROVAL RECEIVED FROM LONNIE SMITH OF AOGCC TO P.T. HUCKABEE FOR THIS WELL. - RIH W/2.0" JET SWIRL WASH NOZZLE, AND DBLCV. NO SCALE OBSERVED WHILE RIH. UNABLE TO WASH PAST 10,030'. - PRESSURE TEST WELL CONTROL EQUIP. & FLOW LINES. - SET NOZZLE @ 10,030', PUMP 55.1 bbls 7.5% HCL SOLUTION FROM 10,030' TO TOP PERFORATION @ 9,094' FOR ACID SOAK. GAINED 19' TO NEW BOTTOM DEPTH OF 10,049' DURING TIME OF SPOTTING ACID. UNABLE TO JET FURTHER. - SOAK PERFORATIONS IN ACID FOR 30 mins. - PUMP 5 bbl XCD POLYMER GEL SWEEP BEHIND ACID TO DISPLACE ACIDIZED MATERIAL TO SURFACE. DIRECT ACID BLENDED RETURNS TO DECK SURGE TANK. - ACID JETWASH PERFORATIONS F/10,049' T/9,090' WITH 49 bbls 7.5% HCL SOLUTION, PUMPING @ 58 gpm WHILE HOISTING @ 20 fpm - RIH TO BOTTOM FOR SWEEP, FOUND BOTTOM SOFT, CONTINUE TO JETWASH TO 10,090' WHERE P-RATE STOPPED & DRAG INCREASED. PUMP FRICTION REDUCER TO LOWER CT DRAG. HOIST CT TO 10,050' BEGIN JETWASH THROUGH PERFORATIONS WITH FIW WHILE DISPLACING SWEEP @ REPORT TIME. 10/15/91 - LOCATE NOZZLE @ 10,050'. PREPARE TO SQUEEZE. - CONDUCT PIT (PRODUCTION INTEGRITY TEST). CSG @ 580#, PTbg @ 1,100#. GOOD. - SPOT 7.5% HCL SOLUTION @ EOCT. CLOSE IN WELL. SQUEEZE 125 bbls OF ACID, 150 bbls FIW TO DISPLACE ACID TO FORMATION. - SQUEEZE DATA: CSG# CT# PTbg# GPM LOW 540 4700 950 56 HIGH 2100 4900 1650 51 ISIP = 1650# 10m FSIP = 1650# RECEIVED DE(] 2 0 1991 Alaska Oil & Gas Cons. Gore~ss't°n Anchorage DAILY REPORT WELL: C22-23 10/15/91 - NOTE: SQUEEZE DATA INDICATES LOW VOLUME LEAK (CONT'D) BETWEEN PTDg & CSG. SUSPECT CHECK VALVE IN GLV (S) . - JET WASH PTbg, WITH SLOW PASSES @ GLMS, TO ASSURE CLEAN TBG WHILE POH. - RIG DOWN - COIL TUBING EQUIPMENT RELEASED TO STANDBY FOR WL @ 1400 hfs 10/15/91. RECEIVED DEC 20 199'~ Oil & Gas Cons. L;ommission Anchorage ( i GINAL Shell Western EIP Inc. ~ 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 October 7, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- SUBJECT- SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C22-23 Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment workover on MGS Well No. C22-23. The workover is anticipated to begin on October 19, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, . E. Ungef Division Drilling Engineer Alaska Division VEU/slm Enclosures OCT - 9 1991 Alask.'a.0ii & Gas Cons. Ceramist'mn ,Anchorage AOGCC\SUNDRY.DOC '( STATE OF ALASKA (~ A,L,~oKA OIL AND GAS CONSERVATION COMMISsiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing Change approved program 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Suspend Operation shutdown Re-enter suspended well Repair Well Plugging__ Time extension Stimulate X Perforate Other 6. Datum elevation (DF or KB~ 4. Location of well at surface At top of productive interval At effective depth At total depth Pull tubing __ Variance 5. -[ype ot Well: Development X Exploratory Stratigraphic Service Platform C, Leg2, Conductor 10, 524'FSL & 1553' FEL Sec. 23, T8N, R13W, @9094' (8415 TVD) 2716'FSL & 3541'FEL Sec. 23, T8N, R13W, S.M. @ 10,307'(9603 TVD) 2809'FSL & 3305'FEL Sec. 23, T8N, R13W, S.M. 116' DF feet 7. Unit or Property name Middle Ground Shoal 8. Well number C22-23 9. Permit number 88-16 10. APl number 50-733-20397-01 11. Field/Pool MGS/"G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 1,710' Intermediate 6,047' Production Liner 4,493' 10,307 feet 9,603 feet 10,202 feet 9,501 feet Size Plugs (measured) Junk (measured) Cemented 13-3/8",54.5-72#,K-55/NT-95 9-5/8",47-53.5#, N-80/SOO-95 Measured depth 26,26,32,&35#, N-80/L-80 True vertical depth 500 sx 1,710' 1,624' 545 sx 6,047' 5,547' 1,375 sx 10,220' 9,519' Perforation depth: measured 9,094'-10,064' true vertical 8,416'-9,369' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80, AB-MOD. EUE @ 8,790' Packers and SSSV (type and measured depth) Baker "DB" Packer @ 8756' RECEIVED 0 CT - 9 1991 ~Jas~.a .0ii & Gas .Cons, ~C~j~ISS]~) 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 10/19/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service ,7. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~., ~~ /o//~-/~ f Title Division Drilling Engineer ~gned Date 10/07/91 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test Location clearance Mechanical Integrity Test__ --Subsequent form require--d 10- .'J~,q Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH ~"~'~missioner I Appr°val N°¢/......~ ~ ¢ Date / ~) - ~,.._. ¢/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL WELL No. C22-23 COILED TUBING CLEAN OUT / ACID TREAT PRESENT STATUS: Producing via gas lift Last test (10/01/91) - 157 BOPD, 508 GROSS, 69% H20 57% annual oil rate decline OBJECTIVES: Acid Treat Hemlock via 7.5% HCl soak/jet wash/squeeze. NOTES: - 2-7/8" 6.5% N-80 tubing, EOT @ 8790' - 7" 35% liner below EOT, PBTD = 10202' - Minimum restriction - 2.205" ID, Otis "XN" nipple @ 8780' - Other restrictions - 2.313" ID, otis "XO" sleeve @ 8721' & Flopetrol SSSV @ 297' (? ID) - Fill tagged at 10040' during slickline operations 10/12/88. (bottom HR-HZ perf at 10064' so ~ 24' fill) - 2.30" Gauge ring drift to "XN" 12/12/90 - No tbg scale indicated. - HN-HR & HR-HZ fracture treated during completion. - No indications of fish in casing via review of Anchorage Engineering files. RECOMMENDED PROCEDURE: (Refer to Attachment No. 1 for mechanical equipment details) 1. One week prior to scheduled rig-up, test mechanical integrity of all critical components (ie., swab valve, wing valve, tubing spool valve, etc.). Pressure test all critical components to 3500 psi. Replace or repair defective components. 2. Prior to CTU Rig Up, review all data files for information on junk in hole, fill indications, tubing blockages, and tubing ID restrictions. The following responsibilities are identified. Anchorage Well Files - Production Engineering Platform Well Files - Operations Foreman/SWEPI CTU Supervisor Wireline Log Book - Wireline Operator/Operations Foreman 3. Before moving CTU to leg 2, RU Slickline Unit and test lubricator to 1500 psi. RIH and retrieve SSSV from Flopetrol landing nipple @ 297'. RIH with 2-1/8" gauge ring drift and tag fill. Note any scale restrictions in the tubing. POOH. RD Slickline Unit. MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT · 24 hours before CTU is scheduled for RU on this well, fill wellbore via annulus with Filtered Inlet Water (FIW). Take returns via circulation to production. Do Not inject more than 550 bbls FIW without contacting Production Engineering or Manager Alaska Operations to discuss. .Do Not access FIW directly downstream of the waterflood DE filter. Access FIW from downstream of the CUNO cartridge filters. · Hold safety meeting with Arctic Recoil, Halliburton, and al__l other service company and platform personnel to discuss the proposed operations. Emphasize safety concerns with the chemicals to be used and with H2S during acidizing operations. NOTE: H2S concentrations of 150 - 250 ppm are not uncommon in spent acid returns during MGS acid treatments. · · Ensure crown valve is closed. RU Arctic Recoil CTU with 1-1/2" coiled tubing and CTU assist pump. Install double check valves and hydraulic disconnect on coiled tubing. RU BOPE and flow "T". (NOTE: Equip CTU BOPE stack with blind rams, shear rams, and pipe rams.) Test CTU BOPE and coiled tubing to 5000 psi against swab valve and CTU stripper rubbers. Bleed coiled tubing pressure to negative test the double check valves. RU Halliburton with 210+ bbls 7-1/2% HCl acid. Include the following additives in the acid. Ensure all hazardous materials are properly manifested in accordance with Department of Transportation Regulations. - 0.5% HAI-85 Corrosion Inhibitor, - 0.2% LoSurf-300 Non-Emulsifying Agent/Surfactant, - 20%/1000 gal FERCHEK-A iron chelating agent. · · RU valve manifold so the CTU assist pump can quickly access both the acid and FIW independently. Filter all fluids pumped downhole through the 3 micron cartridge filters on the Arctic Recoil CTU assist pump. RU instrumentation to monitor injection rate, coiled tubing injection pressure, coiled tubing (CT) x injection tubing (tbg) annulus pressure, and tbg x casing (csg) annulus pressure. For acid squeeze operations, the CT x tbg annulus and tbg x csg annulus should be monitored via a two pen chart recorder. Send annotated charts to Production Engineering in Anchorage. page 2 MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT 10. Ensure surface handling equipment is installed to safely and efficiently handle return acid and H2S for either disposal into C44-14RD or treatment and transfer to Production (see Attachment No. 2). CLEAN OUT & ACID SOAK PERFORATIONS 11. The SWEPI CTU Supervisor should ensure all equipment to be run in the hole is calipered for both ID and OD, and that a complete dimensional drawing of each component is on file. 12. If scale restrictions were observed in the tubing during slickline operations, RIH with 2-1/8" flat (or wavy) bottom mill, 2-1/16" Positive Displacement Motor (PDM), double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing to clean out scale from the tubing and any fill across the perfs to PBTD 10202'. NOTE: If hard scale is encountered within the HR-HZ perforation interval, do not try to clean out any deeper without approval of Manager Alaska Operations. Top HR-HZ perf at 9879,, bottom perf at 10064t. NOTE: If no scale restrictions were observed in the tubing during slickline operations, consider making clean out trip with wash nozzle to save a trip in the hole. Indications are the fill is 20-40 fracture proppant. 13. Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. POOH with PDM & mill. 14. RIH with 2-1/8" swirl type jet nozzle, double check valves, and hydraulic disconnect sub on coiled tubing to the bottom HR-HZ perf at 10064'. NOTE: Coiled tubing length = 14200 ' 1-1/2" coiled tubing capacity = (1. 597 bbls/1000 ' ) *14200 ' = 22.68 bbls CT x 7" 35# csg (HZ - HC) = (10064 '-9094') * 0.032829 = 31.84 bbls page MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT CT x Wellbore annulus capac, = 0.03283 bbl/ft*(10064-8790) + 0.00360 bbl/ft* 8790' = 73.49 bbls 15. 16. 17. Conventionally circulate 32.5 bbls 7-1/2% HCL followed by 22.6 bbls FIW to displace the acid out of the end of the coiled tubing (EOCT). The acid volume should cover the interval from the bottom HR-HZ perf at 10064' to the top HC-HD perf @ 9094'. SD pump and let acid soak for at least 30 minutes. Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. Divert all acid returns to the surge vessel. Monitor vessel for H2S escapement. Pump contaminated fluid to C44-14RD disposal well to ensure adequate surge vessel capacity for continuing coiled tubing operations. Flush disposal well with a minimum of 100 bbls FIW to overflush perforations. Refer to Attachment No. 2A for Disposal Guidelines and re=ord disposal operations data. 18. JET WASH PERFORATIONS WITH ACID Locate EOCT at bottom HR-HZ perf at 10064'. Pump circulate at 1 BPM, while reeling coiled tubing at 20 feet/min, to jet wash the perforations and wellbore from 10064' to the top HC-HD perf @ 9094' (will require ~ 49 bbls 7-1/2% HCL). Additionally, wash all scale indications observed in the tubing during clean out. Displace circulate with a minimum of 100 bbls FIW to clear contaminated fluid from coiled tubing and wellbore. Divert all contaminated returns to the surge vessel for disposal. 19. ACID SQUEEZE STIMULATION RIH and locate EOCT at the bottom HR-HZ perf @ 10064'. Spot circulate 22.7 bbls 7-1/2% HCL (with above additives) to the EOCT. Close coiled tubing annulus at the flow "tee". Pump/squeeze 102.3 bbls additional acid (125 bbls acid total) followed by 150 bbls FIW to overdisplace the acid into the perforations (by ~ 125 bbls). Do not exceed 3500 psi surface pressure on the coiled tubing x injection tubing annulus. Coordinate with Production Operator to monitor tbg x csg annulus during squeeze operations. page 4 HIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT 20. NOTE: Pump acid at the maximum rate possible without exceeding the pressure constraints. POOH. RD CTU. Gas lift well to production and test. Change out GLV's as necessary to optimize lift operation. RE:¢EI, V I) OCT - 9 1991 Alaska 0il & Gas Cons. CoremisslQt~ Anchorage 9 10 11 12 13 14 COMPLETION EQUIPMENT DETAIL SHEET MGS C22-23 4/21/88 NO. ITEM TVD. MD. PSI OR 1.. FLOPETROL LANDING NIPPLE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL #7 9. 2-7/8" OTIS "XO" SLIDING SLEEVE 10. BAKER "G" LOCATOR W/ 2 SEAL UNITS, 5' EXT, 2 SEAL UNITS, MULESHOE 11 BAKER "DB" PACKER ID = 3.25" W/ 10' SBE 12. 10' 2-7/8" EUE PUP 13. 2-7/8" OTIS "XN" NIPPLE 14. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB 297 297 1604 1687 895 1/8 3067 3326 925 3/16 4390 4783 920 3/16 5525 6023 905 3/16 6487 7110 895 3/16 7320 7987 928 1/4 8004 8680 OR 1/4 8044 8721 8078 8755 8O79 8756 8093 8770 8103 8780 8113 8790 CASING 13 3/8", 54.5-72#,K-55/NT-95 @ 1710' W/500 SX, 341SX TOP JOB 9 5/8", 47-53.5#, N-80/S00-95, @ 6047' W/ 545 SX 7" 26#, N-80 @ 5727-7867' 29#, N-80 @ 7867-8148' 32#, L-80 @ 8148-8622' 35#, 8622-10220' W/ 1125 SX SQUEEZE LINER TOP W/ 250 SX PBTD = 10202' (LANDING COLLAR), 8130', 9130', 9770' TD = 10307' TUBING 2 7/8", 6.5#, N-80, AB-MOD. EUE @ 8790' PROPOSED PERFORATED ZONE INTERVAL GR-GS HC-HD HE-HF HK-HN HN-HR HR-HZ TO BE PERFORATED LATER 9094-9129 9200-9253 9385-9436 & 9442-9564 FRAC TREATED~.9_65.8199790 (35 SHOTS) FRAC TREATED/9879-10064 (40 SHOTS) / MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 2 CTU SURFACE HANDLING EQUIPMENT FOR RETURN FLUID TREATMENT OR DISPOSAL 1. RU 250 bbl, 120 psi pressure contained surge tank for containment of contaminated fluid returns. · RU return line choke manifold to take returns from the flow "tee" to either the 250 bbl surge tank or the group production separator. RU a sampling valve at the choke manifold to monitor pH of the returns fluid. All uncontaminated fluids can go directly to the group production separator. Divert all contaminated fluid to the surge tank for processing. · RU an injection pump to transfer contaminated fluid from the surge tank to the C44-14RD disposal well at an expected injection rate of 3 BPM @ 1500 psi. Manifold pump intake with FIW access, in addition to the surge tank access, to overdisplace all contaminated fluid with a minimum of 100 bbls FIW flush. NOTE: Halliburton Operator must keep a detailed record of date, time, shut-in pressure before injection, injection rate, fluid type, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Refer to Attachment No. ZA for Disposal Guidelines and record disposal operations data on the attached form. · RU H2S monitoring/detection equipment at the circulating choke and surge tank. Coordinate with SWEPI Production Operator to sample and monitor fluid returns and treat if necessary. · Install emergency blowdown lines for the surge tank. One from the pressure relief valve to blowdown fluids to the group production separator and one via a burst plate relief to the flare. · RU a gas flare line from the gas vent and burst plate relief of the surge tank to the platform flare. Install a flame arrester in the gas flare line. NOTE: Refer to Attachment No. 3 and follow the "Guidelines for Handling Backflowed and Circulated Fluids For Discharge" for all returns not disposed of in C44-14RD. The Onshore Operator should be notified and prepared to divert any transferred contaminated fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. page 6 MIDDLE GROUND SHOAL NO. C22-23 COILED TUBING CLEAN OUT / ACID TREATMENT ATTACHMENT NO. 2A C44-14RD DISPOSAL PROCEDURE GUIDELINES · · · · · Pump Operator must keep a detailed record of date, time, fluid description, shut-in pressure before injection, injection rate, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Complete the attached Disposal Record Form (on following page) to document all disposal activity. Establish Filtered Inlet Water (FIW) injection into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi without consulting Engineering or Manager Alaska Operations. If injectivity is acceptable, close FIW access and open pump intake to disposal fluids. Pump disposal fluids into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi unless injectivity drops below 2 BPM. If injectivity drops below 2 BPM at 3500 psi, increase pressure up to 4500 psi maximum injection pressure. Shut down pumps immediately if pressure exceeds 4500 psi or ,,screen-out" conditions are apparent! Close disposal fluid access and open pump intake to FIW to flush disposal fluid with a minimum of 100 bbls FIW (over-flush wellbore capacity by a minimum of 25 bbls). Shut down disposal operations, record ISIP, and monitor C44-14RD fall-off pressure for 30 minutes. Record all data on attached C44-14RD Disposal Record Form. Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. page 7 MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ~CID TREATMENT ATTACHMENT NO. 2A (continued) C44-14RD DISPOSAL RECORD FORM Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. 30 MIN PRIOR BEGIN END AFTER FLUID SI INJ. INJ. INJ. INJ. SI DATE TIME DESCRIPTION PRESS RATE PRESS VOLUME PRESS ISIP PRESS (psi) (BPM) (psi) (bbls) (psi) (psi) (psi) page 8 MIDDLE GROUND SHOAL No. C22-23 COILED TUBING CLEAN OUT / ~CID TREATMENT ATTACHMENT No. 3 PROCEDURES FOR HANDLING B~CKFLOWED AND CIRCULATED FLUIDS FOR DISCI{ARG~ Ail backflowed and circulated fluids, and not disposed of via C44-14RD, must be routed through the test separator prior to being sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. Note: Ensure any acid treatment fluids that are circulated or backflowed are neutralized prior to sending to the production separator. To satisfy EPA requirements, if the amount of fluid exceeds 250 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from C22-23 acid treatment - 10/xx/91". Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. Pipeline Delay = 2660 bbl Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) x 24 hrs = hrs Onshore Facility 1000 bbl Delay = ............ x 24 hrs = hrs Gross Daily Prod "A" "C" and "Baker" (bbl) Total time between slug shipment anQ sample time = hfs NOTE: Because the operations may result in a significant quantity of contaminated return fluids, the Onshore Operator should be notified and prepared to divert the transferred fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. ~ECEIVED page 9 OCT - 9 1991 Alaska Oil & Gas Cons. Commission Anchorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells 1 location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised co.py of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C2]-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190 .DOC RECEIVED JUN ! 3 1990 AnChora~ , PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. DISTANCE FROM SE CORNER CONDUCTOR WELL NORTH WEST 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 LEG 2 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. CONDUCTOR WELL LEG 3 LEG 4 CONDUCTOR DISTANCE FROM SE CORNER NORTH WEST 9 C22-23 623.65 1552.66 10 C24A-14 624.15 1548.36 11 C43-14 622.65 1544.76 12 C41-26 618.25 1543.86 13 C21-23 613 . 85 1546.26 14 C21-26 612 . 65 1550.46 15 C24A-23 614 . 85 1554 . 26 16 CLJ-23 619.15 1555.66 25 26 27 28 29 30 31 32 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, T8N, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C4 C3 C4 C4 C3 C' C4 C2 2-23 1-23 3-23 1-23 3-26 LINE 4-14RD 4-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 O.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 -0.7O -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 P~AT I~Ogld 'A° ~ FOD[LAIID · · · LO,AT ION S, A. $. PI.~TFO~H "C' COOl< INi.~T ,-~ ALASKA SC.iL~ 1',2OOO' i41rt~ IN? '1 ' · Shell Western E&P Inc. 601 West Fifth Avenue ,, Suite 810 Anchorage, Alaska 99501 January 12, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBSEQUENT REPORT OF SUNDRY WELL OPERATION FOR MIDDLE GROUND SHOAL WELL C22-23 PERFORATE Enclosed, in duplicate, is the Subsequent Report of Reperforation of well C22-23. The reperforation was necessary because, when the well was originally completed on July 10, 1988, only part of the HK-HN interval, from 9442' - 9564', was originally perforated. Approval was given for the reperforation by Lonnie C. Smith, (AOGCC) on 3/31/89. If you have any questions regarding this report contact Susan .Brown-Maunder at (907) 263-9613. Sincerely, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBBM/raf Enclosures RECE ,V:ED SBBL/ros.011290 i,' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPOFIT OF SUNDRY WELL OPEFIATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing ~ Repair well __ Perforate X Other 2. Name of Operator 5. Type of Well: She'll Western E&P, Inc. Development..X_ Exploratory __ 3. Address 601 West Fi fth Ave., Suite 810 Stratigraphic__ Anchora.qe~ AK 99501 Servicel 4. Location of well at surface Platform "C", Leg 2, Conductor 10 @ 618.65 FSL, 1549.76' FEL, Sec. 23, T8N, R13W, S.M. At top of productive interval 8407' TVD, 2192.05' N & 1991.52 W of Surf. Loc. Sec. 14, T8N, R13W, S.M. At effective depth At total depth 9603' TVD 2285' N & 1778' W of Surface Loc. $e9, 14. T8N. R13W; S.M. 12. Present well condition summary Total depth: measured 10307 ' feet Plugs (measured) true vertical 9603' feet feet 6. Datum elevation (DF or KB) 105' KB 7. Unit or Property name Middle Crn,,nd ghnnl 8. VVell number f-??-?g 9. Permit number/approval number 88-16 10. APl number 50-- 733-20397-01 11. Field/Pool "G" Pnnl Effective depth: measured 10202 ' feet Junk (measured) true vertical 9502 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1710' 13-3/8" 6047' 9-5/8" 4493' measured Measured depth 54.5&72# K-55/NT-95 841 sx "G" 47&53.5# N-80/S00-95 545 sx "G" 7" 26,29,32&35# N-80/L-80 1375 sx "G" SEE ATTACHMENT + 9385' - 9436' (MD) 4 JSPF True vertical depth 1710' 6047 ' 10220' true vertical Tubing (size. grade, and measured depth) 2-7/8", 6.5#, N-80 ¢8790' Packers and SSSV (type and measured depth) Baker "DB" packer @8756', Flopetrol SSSV @297' RECE VE 13. Stimulation or cement squeeze summary Intervals treated (measu red) NONE Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 03/06/89 343 188 Subsequent to operation 05/02/89 491 156 ' 51 820 301 820 Tubing Pressure 100 120 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas~ Suspended Service 17. I hereby certify/th--alt the foregoing is true and correct to the best of my knowledge. ?g~ned ~_(~~~ Title DIVISIONOPERATIONSMANAGER Form 10-404 Rev 06/15/88 SBBL/a ogcc .011290/1 Date 01/12/90 · SUBMIT IN DUPLICATE WELL NO: OPERATION: DATE: DAILY JOB SUMMARY C22-23 Perforate HK-HN Interval 9380' - 9436' 04/02 & 04/03/89 Place well in test and have production operator take hourly readings throughout perforating operation. Rig up Schlumberber Well Services with lubricator. Run in hole with 2-1/8" Enerjet gun. I SPF at 9390', 9391', 9402', 9416'. 4 SPF from 9436' to 9404'. 4 SPF from 9404' to 9385'. R E C E"I V E D SBBL/djs.rswo C22-23 C22-23 PERFORATION DETAIL SHEET ZONE TOP MD 9087' 9200' 9379' 9590' 9824' TVD PERFORATION INTERVAL 8408' 9094' - 9129' 8519' 9200' - 9253' 8697' 9442' - 9564' 8905' 9658' - 9790' 9135' 9879' - 10064' ZONE BOTTOM MD TVD SIZE & NUMBER 9132' 9255' 9590' 9824' 10127' 8452' 2-1/8" 4JSPF 8574' 2-1/8" 4JSPF 8905' 2-1/8" 4JSPF 9135' 2-1/8" 40 shots 9430' 2-1/8" 40 shots SBBI/033189 SCHLUMBERGER WELL SERVICES DIVISION OF' SC::HLUMBII'II~GE:III TE:CHNOLC)GY CORIIOII~ATION HOUSTON. TE:XAS 7?251-2175 IILEAII RIPt.¥ TO M ay 1 1 ~ 1989 SCHLUMBERGER WELl. SERVICES 500 W. International Airport Rd. Anchorage, Alaska 99518 ATTN: Print Room Inc. Shell Western E&P~ P.O. Box 527 Houston, TX 77001 Attention: Log Fi 1 e s, WCK 4147 EJ PERFORATING RECORD (4/2/89) Inc. on: Gentlemen: Enclosed are 1 BL prints of the Company Shell Western E&P., Well MGS C-22-23 Field Mi ddl e Ground Shoal Additional prints are being sent to: 1 BL_prints Shell Western E&P, Inc. 601 W. Fifth Ave., Suite 810 Anchoraqe, AK. 9..9501 ATTN: Hank Van $chelt; County Kenai State_ A1 aska prints 1 B L prints Shell Westerq E&P. Inc, P.O. Box 527 Houston. TX 77001 ATTN: C.C. Williams WCK prints 1 BL nrints Shellr Western £&P, Inc. Platform "A" or "C" C/O Shell Kenai Office 130 Trading Bay Ave.~ Suite 130 Kenai~ AK 99611 1 RFolded Sepia A~K Oi 1 ~ion Commission 3(kO1 Forcupine Dr. Anc~horaqe, AK 99501 ATTN'~~le The film is returned to Shell (Houston-Log Fi les) We appreciate the privilege of serving you. prints Anchorage Received by:. Date: Very truly yours, SCHLUMBERGER WELL SERVICES Marc Gunther Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 March 31, 1989 Alaska Oil and Gas Conservation Commission ATTENTION: Blair Wondzell 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C22-23 Enclosed, in triplicate, is the Application for Sundry Approval to perforate Middle Ground Shoal Well No. C22-23. If you have any questions, please call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/raf Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance ~ Perforate --X Other __ 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic 99501 Service 4. Location of well at surface Platform "C", Leg 2, Conductor 10 (~ 618.65 FSL, 1549.76' FEL, Sec. 23, T8N, R13W, S.M. At top of productive interval 8407' TVD, 2192.05' N & 1991.52' W of Surf. Loc. Sec. 14, T8N, R13W, S.M. At effective depth At total depth 9603' TVD 2285' N & 1778' W of Surface Loc. Sec. 14, T8N, R13W, S.M. 6. Datum elevation (DF or KB) 105' KB 7. Unit or Property name Middle Ground Shoal 8. Well number C22-23 9. Permit number 88-16 10. APl number 50-- 733-20397-01 11. Field/Pool .,_/::'/', "G" Pool · . feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 1710' Intermediate 6047 ' Production Liner 4493 ' Perforation depth: measured true vertical 10307 ' feet Plugs (measured) 9603 ' feet 10202 ' feet Junk (measured) 9502 ' feet Size Cemented Measured depth 13-3/8" 9-5/8" 54.5&72# K-55/NT-95 841 sx "G" 47&53.5# N-80/S00-95 545sx "G" 7" 26,29,32&35# N-80/L-80 1375 sx "G" See Attachment Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 ¢ 8790' Packers and SSSV (type and measured depth) Baker "DB" packer @ 8756' True vertical depth 1710' 6047 ' 10220' 13. Attachments Description summary of proposal __ X Perforation Detail Sheet Well D~.aqr,~n 14. Estimated date for commencing operation April 1, 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operations program __ BOP sketch __ 15. Status of well classification as: Oil__x Gas__ Suspended__ Service 17. I hereby certify that the foreg.oing is true and correct to the best of my knowledge. Signed ~ ~,/~. ~,~/v Title Division Operations Mana~ler FOR COMMISSION USE ONLY Date March 31~ 1989 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /~/pro'ved CoPY ., .n ,,,~eturn,e~O ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner J Approval No. ¢ ~/./'~--" Form 10-403Rev06/15/88 SBBI/asa.033189 SUBMIT IN TRIPLICATE C22-23 PERFORATION DETAIL SHEET ZONE TOP MD 9087' 9200' 9379' 9590' 9824' TVD PERFORATION INTERVAL 8408' 9094' - 9129' 8519' .,,~200' - 9253' 8697' ~'~442' - 9564' 8905' 9658' - 9790' 9135' 9879' - 10064' . ZONE BOTTOM MD TVD SIZE & NUMBER 9132' 8452' 2-1/8" 4JSPF 9255' 8574' 2-1/8" 4JSPF 9590' 8905' 2-1/8" 4JSPF 9824' 9135' 2-1/8" 40 shots 10127' 9430' 2-1/8" 40 shots SBBI/033189 ReV BY,:Xerox Telecop~er' ?020 ; 3-31-89 ; 8:21AM ; ~EN'T'.'6Y:Xer0x Tolocoplo~' ?0E0 II:" '0-lie; 4:~SPld; 0422'/"* 80'~27802~' 9072760211;I 2 ! , ) , p ,fiXosz$ Oit~3ECTZVE ~ PROCEDURE: Perforate additional tnterv,l tn the HK-HN Interval. When ~he well was originally completed on dul~ 10, 1~88, ~n~. part of the HK.HN 1fire?vi1, fr~ 944S',0M4t, Wal Orlglflal- orlglnally diagnosed II "p~obabl~ w&~er prOduCtiVe", Zt 1S now haltered ~het thls tn~erval w111 tncrea$t otl produc- tton (and.perhaps also water p~oduct4on) but should be per,or&ted a~ thls ttmo, . t 4~ Sk4d rig ove~ C22.23, Plice ~e11 tn test and ha, ve produo~on operl~r tlkl hourl~ readtng$ throughout per~o~&t~Ing operattofl, L REFERENCE LOG: DZL-GR of 6/6/88 CET of 6/13/88 RECOi, IHENI)ED~ ........ _ DATE: .................. , , DATE: AUTHORITY'FOR EXPENDITURE DEeT r-~J~*~ BRANCH OFFICE ORIGINATING OFFICE AFE NO LOCATION OF PROJECT APPROPRIATION NO LOCATION NUMBER WORK, SWEPI'$ % SNARE ORDER I'YPE DESCRIPTION 100% COST NUMBER BUDGET NONBUDGET EXPENSE TOTAL POSITION NEw ~PiTAL FUNDS REQUIRED BY BUDGET REVISION TOTAL COST JUSTIFI~TION: , ,,. ., .... ,, :. ?.%~.,,'....L .......... : ,' ,.. ~L:;:',,'4..L.;',..,.,.,,,: ~ OVER... RECOMMENDED , S?OO/AF£O~ SWEP'0420 MGS C22-23 COST ESTIMATE ADDITIONAL PERFORATING OF HK-HN (9,380'-9,436') lo PERFORATING COST Set up Perforating Surface Pressure Control $ 2,750 880 2-1/8" Enerjet First 10 shots (3,940) (.50) Next 90 shots ($95 x 90) (.50) Next 100 shots ($76 x 100) (.50) Next 24 shots ($38/shot) SUBTOTAL 1,970 4,275 3,800 912 $14,087 2. RIG TIME Move rig, four hours Perforating time, 12 hours SUBTOTAL 4,000 12,000 $16,000 MISCELLANEOUS Transportation, etc. SUBTOTAL $ 5,913 TOTAL $36,000 HAVS/O33089a g 10 11 12 13 14 ? 6 COMPLETION EQUIPMENT DETAIL SHEET NGS C22-23 10/6/88 ITEM .TVD: gu. JrSl OR 1. FLOPETROL LANDING NIPPLE 2. 6AS LIFT MANDREL el 3. GAS LIFT MANDREL e2 4. GAS LIFT MANDREL ~3 5. GAS LIFT MANDREL ~4 6. GAS LIFT MANDREL e5 7. GAS LIFT MANDREL ~6 8. GAS LIFT MANDREL eT 9. 2-7/8" OTIS "XO" SLIDING SLEEVE 10. BAKER "G" LOCATOR #/ 2 SEAL UNJTS. 5' EXT, 2 SEAl, UNITS, MULESHOE 1! BAKER "DB" PACKER ID ' 3.25" #/ 10' SBE 32. 30' 2-7/8" EUE PUP 13. 2-7/8" OTIS "XN" NIPPLE 24. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB CASING 297 297 2604 2687 895 2/8 3067 3326 925 3/16 4390 4783 920 3/36 5525 6023 905 3/16 6487 7110 895 3/26 7320 7987 928 1/4 8004 8680 OR 3/4 8044 872] 8078 8;55 8079 8756 8093 8770 8103 8780 8]]3 8790 13 3/8", 54.5-72#,K-55/NT-95 O 1710' W/500 SX, 341SX TOP JOB' 9 5/8", 4?-53.5#. N-80/S00-95, 0 604?' #/ 545 SX 7" 26#, N-80 0 5727-7867' 29t, N-80 0 7867-8148' 32#, L-80 0 8148-8622' 35#, 8622-20220' #/ 1125 SX SQUEEZE LIXER TOP W/ 250 SX PBTD - ]0202' (LANDING COLLAR), 8230', 9230', 97~0' TD - I0307' TUBING 2 7/8", 6.5#, g-80, AB-MOD. EUE 0 8790.'~. ..... PERFORATED ZONE PROPOSED INTERVAL GR-OS HC-HD HE -IIF HK-HN H.~-HR HR-HZ TO BE PERFORATED LATER 9094-9]29 9200-9253 9442-9564 FRAC TREATED 9658-9?90 {40 SHOT~) FRAC TRFATED 9879-]0064 (40 SIlO;S) /¥ /-/? TELECOPY NO. (907) 276-7542 March 3, 1989 Susan Brown-Maunder Shell Western E & P Inc. 601 West 5th Avenue, Suite 810 Anchorage, AK 99501 Dear Susan: We received correspondence from Mr. Wayne Simpson dated February 17, 1989. Mr. Simpson pointed out that Middle Ground Shoal (MGS) wells C22-23 and C24A-14 were incorrectly designated as "BCD" and "A" pool completions respectively, in our December 1988 bulletin. A review of tha well files confirm that both wells are ~'EFG" pool completions. The MGS C22-23 has been corrected. The MGS C24A'24 was reported to the Commission as an "A" pool completion per Item 11 of Form 407 "Well Completion or Recompletion Report and Log'~. By this letter the Co~nission requests that Shell Western E & P Inc. submit a revised Form 10-407 for MGS well C24A-14 correcting Item 1I to show the well as an ~,IGS "EFG" pool completion. When the new form is received our records will be revised accordingly. We thank you for bringing these items to our attention. dlf: 10.RAD. 1 .... February 27, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99515 Gentlemen: Shell Western E&P Inc. · COMH ,~" 601 West Fifth Avenue Suite 810 ~ I~C--~J?. ~~¢~'' Anchorage, Alaska99501 ~//' t~!_~__~- SUBJECT: PRODUCING ZONES IN MIDDLE GROUND SHOAL WELLS C22-23 AND C24A-14 During a recent review of the December, 1988 Monthly Bulletin published by your office it was discovered that there is apparently some confusion on the producing zones in the above mentioned wells. The pools that are producing in MGS C22-23, and C24A-14 wells are the E, F and G pools. Pl.ease make sure that your records on these wells are in agreement with the actual producing pools. If. you have any questions on this matter, please contact Susan BrOwn-Maunder at (907) 263-9613. Very truly yours, Wayne F. Simpson Manager Regulatory Affairs WFS/SBBM/raf SBB I/aogcc. 022789 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 November 9, 1988 Alaska Oil and Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT' SUBMISSION OF WELL COMPLETION OR RECOMPLETION REPORT AND LOG FOR WELL C22-23 Enclosed, in duplicate, is the Well Completion or Recompletion Report for Well C22-23. If you have any questions, please call Ms. Susan Brown-Maunder or Ms. Arlene Ford at (907) 276-9545. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/SBB/1 jm Enclosures SBBH/aogcc. 072688a STATE OF ALASKA '~ O ~ I [1 I N A L .. , ALASKA ~.~. AND GAS CONSERVATION cd,,. VllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL'~ GAS [] SUSPENDED [] ABANDONED [] SERVICE ~. Name of Operator 7. Permit Number Shell Western E&P Inc. 88-16 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810, Anchorage, Alaska 99501 50- 733-20397-01 4. Location of well at surface Platform C, Leg 2, Conductor 10, @ 618.65' FSL & 9. Unitor LeaseName 1549,76' FEL of Sec. 23, T8N, R13W. Middle Ground Shoal ,.. At Top Producing Interval @ 8/+07'TVD, 2192.05'N & 1991.52'W of surface location 10. Well Number C22-23 AtTotal Depth @ 9603' TVD, 2285'N & 1778'W of surface location, ll. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Middle Ground Shoal "G" Pool 105' KBI' ADL 18756 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115' Water Depth' if offshore 116'N°'°fC°mpletions 04/09/88 06/13/88 07/10/88I 73 ' feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafros't !0,307' + 9,603' 10,202' + 9,502' YES.~F' NO[] 297' feetMDI None . 22. Type Electric or Other Logs Run SHDT/MLT, LDT/GR/AM$, .CET/CCL/GR, DIL/LSS, GR, SP 23. CASING, LINER AND CEMENTING REcoRD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... 13-3/8" '"54'.5&72# K-55/NT-95" 0' 1 ~710' 17-1/2" 500 sx "G" & 34i sx Top Jo;~) 0' 9-5/8" 47&53.5# N-80/S00-95 0' 6,047' 12-1/4" 545 sx "G" + additives 0' 7" 26&29# N-80 5,727' 8,148' 8:1/2" 1125 sx "G" + additives 0' 32&35# L-80 8,1/+8' 10,220' 8-1/2" W/250 sx Top Job 0' ,,, ,,, , 24. Perforations open to Production (MD+TVD of Top and Bottom and 251 TUBING RECORD interval, size and number) SIZE DEPTH sET(MD) . PACKER SET (MD) , 2-7/8",6.5#,N-80 8,790' 8,756' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. SEE ATTACHED DETAIL SHEET DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED '9',658' - 9,790"" ~09'2 bbls total proppant: 65000#" 20-/+0 mesh car'bOlite "~',~75'' - 10,065, YF2'00 fluid + 3000# 100 mesh + 7!..,000# 20-40 mesh carbol 27. PRODUCTION TEST Date First Production . , ' · :1 MethOd .of Operation (Flowing, gas lift, e.tc.) 07/13/88 .... 'I Gas Lift ' :' ' ' 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I'~As-oILRATIO 07/13/88 24 ,TESTPERIOD I~. 727 285 485 128I 392 Flow +ubin~ .Casin9 Pressure ,. CALCULATED '.. :' OIL-BBL GAS-McF"' WATER-BBL.' OIL'GRAVITY-API (corr) Press. '130 . 89.5 , ' 24.Hour RAT~ I~ ......... 35.1 -28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev. 7-1-80 SBBH/wcr.101188 CQNTINUEDON REVERSE SIDE Submit in duplicate 29. . . .:-30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TR[JE VERT. DEPTH GOR, and time of each phase. · . N/A N/A , ,. ....... 31. LIST OF ATTACHMENTS Daily Repor'c ot: 0per'a'c~ons~ Compie'c~'on Equipmen'c De'ca~l 5hee'c~ Perforat:~on De~:a~l Shee'c~ Ac~d & Fr-acl~ur-e Det:a~l Shee~:, 32. I hereby certify th~'~tlhe foregoing is true and correct to the best of my knowledge (~ ' .D'~v, 0prns, Mgr, Signed Title Date ...... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on 'all types of lands and leases in Alaska. 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 cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". SBBH/wcr. I 01 1 88 Form 10-407 DAILY REPORT OF OPERATIONS C22-23 DATE o4/o8/88 04/09/88 04/10/88 04/11/88 04/12/88 04/13/88 DESCRIPTION Move rig on location. Rig up, leg 2, conductor 9. Install 20" riser, 20" annular preventor and 10" diverter valves/lines/controls. Finish rigging up. Function test diverter system. Mr. Blair Wondzell was notified 4/7/88 and declined to witness test. Clean out conductor 5' to 369'. Clean out 24" conductor 11' to 380'. Shoe is at 380' Drill with mud motor, taking gyro surveys each 30', f~r 140'. Drill to 553'. Orient tools. Drill to 934' Survey each 60' with gyro and MWD. Makeup angle building assembly. Circulate thick mud from drilling through cement grout at shoe. Drill to 1040'. Ran gyro survey. Drill to 1163'. Change from building assembly to locked up assembly. Drill to 1710' (TVD 1627'). Surface casing depth 1710' MD (TVD 1627'). Circ/cond. for surface casing. Baker plain guide shoe at 1710', baker float collar at 1670' installed baker model "M" centralizers, 1-10' above shoe, then at 40' 80' 120' 200' and 300' above shoe. Bottom 5 joints are baker-locked. Functioned tested annular/diverter system on shoe joint. Rig up HOWCO cement head, circ/cond for cement. Test HOWCO line to 3000 psi. Drop bottom plug, pumped 50 bbls of fresh water ahead of 500 sx class G cement with 10% gel + 2% CaC12 + .5% CFR-2, 12.8 ppg at 10.8 gal sx. Yield is 1.94 CF/sx. Drop top plug, displace with 260 bbls mud at 10 bbls/min, 5 bbls over, did not bump plug. Float held. CIP at 2245 hrs. Rigging for "Top Job." 04/14/88 WOC for 8 hrs. Tear out diverter system, nipple down 20" annular preventor/riser. Cut 13.375" casing. Installed "WF" casing spool. Test to 800# for 30 mins. Set drill spool, 13-5/8" riser, mud-cross, double gate ram preventor, and annular (hydril) preventor. Test BOPE. SBBH/080288 -1- DATE 04/15/88 04/16/88 04/17/88 04/18/88 04/19/88 04/20/88 04/21/88 04/22/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION 13-3/8" casing was tested to 1500 psi for 30 minutes. Makeup 12.25" BHA, tag cement at 1621' Drill cement, float equipment from 1621' to 1710' ~rilled out shoe and tested formation at 14.9 ppg equivalent. Drill and survey 12.25" hole to 2566'. Drill and survey to 2932'. Change bit service rig. Drill to 3033'. Build mud volume. Dri{1 and survey to 3593'. Drill and survey to 4414. Drill and survey to 4828'. POOH for bit change. Wash and ream from 4714' to 4828'. Drill and survey to 5205'. Drill and survey to 5926'. Drill and survey to 6047' Circ./cond. for logs and casing. Ran DIL/LSS,GR,S~. Pull wear bushing, install test plug, change pipe rams to 9.625" casing. Test rams, bonnet to 250/5000 psi. Retrieve test plug. Rig up to run 9.625" casing. Run 9.625", 40#, N-80, BTC casing. Run 9.625" casing. Total joints = 149. Shoe at 6047', float collar at 5964'. Rig up, circ./cond, for cement job. Pump 28 bbls preflush, test HOWCO cement lines at 3000 psi, pump 100 bbls fresh water ahead, mix and pump 345 sx'"G" + 1.5% prehydrated gel + .5% CFR-2, mixed at 14.2 ppg, followed by 200' sx "G" + .5% CFR-2 mixed at 15.8 ppg, pump 10 bbls fresh water behind, displace with rig pumps with 440 bbls 9.5 ppg mud at 10 bbls/min. Check float equipment. Rig down. N/U "AP" Spool, test same at 1500 psi, N/U riser and BOPE. Test BOPE. Received verbal waiver to witness BOPE test from Mike Minder of AOGCC. Test BOPE, choke and kill line valves, standpipe, upper and lower kelly cock valves, floor valves, choke manifold, inside BOP valve, pipe and blind rams at 250/5000 psi. Test annular preventor at 250/3500 psi, test accumulator, test casing at 3000 psi for 30 minutes. M/U BHA. Tag cement at 5760'. Drill and clean out cement from 5760' to shoe at 6047'. Drilled out shoe and tested formation, leak off at 14.0 ppg equivalent. Drill and survey to 6278'. SBBH/080288 -2- DATE 04/23/88 04/24/88 04/25/88 04/26/88 04/27/88 04/28/88 04/29/88 04/30/88 05/01/88 05/02/88 05/03/88 05/04/88 05/O5/88 05/06/88 SBBH/080288 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION Drill and survey to 6856'. Drill and survey to 7325'. Drill and survey to 7836'. POOH 8 stands for washout in drill pipe. Drill to 7888'. Drill and survey to 8133'. Wash and ream Crom 8070' to 8133'. Drill and survey to 8510'. Drill and survey to 8601' POOH. Test BOPE. Test annular preventer at 250/~500 psi, test all rams,, valves, lines, floor valves, kelly valves, standpipe and rotary hose at 250/5000 psi. Test choke manifold at 250/5000 psi, test accumulator unit. Drill and survey to 8742'. Drill and survey to 8936'. Drill and survey to 9058'. Change BHA. Drill to 9135'. Drill to 9245'. Circ and raise mud weight to 11.1 ppg. Drill to 9344'. Circ and raise mud weight to 11.5 ppg. Circ and raise mud weight to 11.9 ppg. POOH for bit. Circulate bottoms up. Drill to 9712'. Hit bridge at 9544'. Work through bridge. Ream from 9637' to 9677'. Circ, wash and ream from 9677' to 9712'. Drill to 9800' raising mud wt to 12.3 ppg. Circ/cond. Drill to 9902'. Drill to 9925'. Test BOPE: Test annular at 250/3500 psi, test all rams, valves, lines, floor valves, kelly valves, standpipe and rotary hose at 250/5000 psi. Test choke manifold at 250/5000 psi. Test accumulator. Ream from 9895' to 9925'. Circ/cond. Drill to 9995'. Drill to 10052' TD. Circ., pipe stuck at 10036' bit depth. RIH with Dia-log. Free point at 6551'. M/U string shot, shoot and back off at 6522'. Strap out of hole with 6522' of DP. Make up fishing string. Fishing ...... '~' ,~-~' .. · .., DATE o5/o7/88 o5/o8/88 05/09/88 05/10/88 05/11/88 05/12/88 05/13/88 05/14/88 05/15/88 05/16/88 05/17/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION Fishing. RIH with Dia-log. Free point at 7410'. Screw into top of fish at 6480' Fishing. Free point at 7950'. Back-off at 7926'. PO0~ with 1403' of fish. Fishing. Top of fish at 7926' Free point at 8676' Back-off at 8676'. Recovered 756' of fish. Top of fish at 8676'. Free point at top of drill jars at 9&17'. Fishing. Make up string shots and fire at 9814', 9234.', 8983' and 8676'. Circ bottoms up. Change out BHA! pick up. rerun bit for clean out to TOF. Rig up HOWCO, test lines to 3000 psi, pump 35 bbls of sepiolite spacer at 13.2 ppg followed by 175 sx of class "G" + .5% CFR-2 + 1% Nail + .05% HR7, 16.7 ppg, 4.0 gal/sx mix water, 1.02 cf per sx yield, displaced with 154.5 bbls of mud, bumped plug, pulled 12 stands, shear catcher at 2100 psi. Test BOPE' Test annular at 250/3500 psi, test all rams, valves, lines, floor valves, kelly valves, standpipe and rotary hose at 250/5000 psi. Test choke manifold at 250/5000 psi, test accumulator. Permission for side track granted by Blair Wondzell. M/U of BHA. Tag cement at 8304'. Clean out and polish cement from 8304' to 8358'. Circ and condition at 7150'. Circ and cond mud. Orient tools, dynadrill 8.5" hole from 8382' to 8580'. Ream and wash from 8580' to TOF at 8676:. Circ/cond mud. M/U cement diverter, plug catcher. R/U and test HOWCO cement lines at 3000 psi, mix and pump 200 sx "G" cement + .5% CFR-2 + .05% HR7 + 1% NaC1, mixed at 16.7 ppg. Displace with 142 bbls 11.8 ppg mud. RIH to casing shoe 6047'. Attempt to circulate, no returns. POOH to 4152'. C~rc/cond at 4152'. Stage in hole to 6210'. Circ @ 6210 . Stage in hole to 8260', circ/cond mud, tag cement at 8260'. Drill cement from 8260' to 8376'. Circulate bottoms up. RIH to 8355' break circ at 2000' 4000' 6000' and 7200' Wash and Ream from 8355' to 8376' Check for flow ind pump pill. Circ/cond mud. Drili to 8456'. Circ/cond mud. SBBH/080288 -4- DATE 05/18/88 05/19/88 05/20/88 05/21/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION RIH with cementing assembly to 8456'. Circ/cond mud raise mud weight to 12.2 ppg, mix sepiolite spacer a[ 15.0 ppg. Pump 26 bbls sepiolite spacer. Test HOWCO cement lines at 3000 psi. Mix and pump 250 sx "G" + .5% CFR-2 + .05% HR7 + 1% NaC1 mixed at 16.7 ppg, followed by 9 bbls 15.0 ppg sepiolite, displace with 129 bbls 12.2 ppg mud. Estimated TOC at 7800'. Shear out sub at 2100 psi. Test BOPE, test annular preventer at 250/3500 psi, test all rams, valves, lines at 250/5000 psi, test kelly, upper and lower kelly valves and standpipe, rotary hose at 250/5000 psi, test choke manifold. RIH to 7820', tag cement. Wash and ream cement from 7820' to 7928' (cement green). WOC. Circ/cond mud. Clean out soft cement from 7928' to 8114'. RIH with mud motor, fill pipe at 2000', 4000'. Drill soft cement with mud motor from 8114' to 8175'. Drill cement to 8182'. Circ/cond mud. Pump 10 bbls fresh water, test HOWCO lines at 2000 psi, pump 10 bbls caustic spacer mixed at 7#/bbl caustic soda, pump 10 bbls fresh water, mix and pump 250 sx "G" + .75% CFR-2 mixed at 17.0 ppg, followed by 10 bbls fresh water. Displace with 125 bbls 12.2 ppg mud. Estimate TOC at 7604'. WOC. 05/22/88 05/23/88 05/24/88 05/25/88 05/26/88 05/27/88 O5/28/88 05/29/88 WOC. RIH. Tag cement at 7686'. Drill cement from 7686' to 7755'. Circ/cond mud. Drill with mud motor from 7755' to 7780'. Drill with mud motor from 7780' ~o 7943' POOH and M/U BHA. RIH to casing shoe at 6047 . Brid~e at 7333'. Work through bridge. Wash and ream from 7755' to 7943'. Drill to 8250'. Drill to 8480'. Drill to 8747'. Test BOPE. Finish testing BOPE. Drill to 8948'. Drill to 9060'. Drill to 9195'. POOH for bit. Work/ream 105' to bottom. SBBH/080288 -5- DATE 05/30/88 05/31/88 o6/ol/88 06/02/88 06/03/88 06/04/88 06/05/88 06/06/88 06/07/88 o6/o8/88 06/09/88 06/10/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION Drill to 9371'. Wash/ream 68' to bottom at 9371'. Drill.to 9651'. Drill to 9675'. POOH for bit. Reamed 58' to bottom. Drill to 9826'. Drill to 9865'. Circ/cond. POOH for bit. Reamed 35'. Drill to 9968'. Drill to 10115'. Circ/cond. Weight up to 12.2 ppg. BOPE test. Ream through bridges at 9247',9501',9666', and 9742'. Ream out of gage hole from 10050' to 10115'. Drill to 10165'. Drill to 10222'. Circ/cond. R/U Schlumberger, ran DIL/GR/SP/AMS. Log down to 10218'. Top of "HZ" is at 10100'. Logging with sonic tool, rig down Schlumberger. Circ at 3000' ,6000',9000' Ream through bridge at 9773'. Ream from 10192' to 10~22' Circ/cond. POOH for logs. R/U Schlumberger, ran LDT~GR/AMS to shoe. Power supply unit failed. Rig down loggers. Rig up Dia-log. Run 9-5/8" casing caliper with Dia-log. Log LDT/GR/AMS with Schlumberger. Ream/wash from 10182' to 10222'. Drill to 10307'. Circ/cond. Rig up Schlumberger and log SHDT/GR/AMS. Logged DIL/MLT/GR/AMS. Rig down Schlumberger. Circ/cond. Rig up Schlumberger and log RFT. Ran SWS gun with 45 shots, 30 samples recovered. Rig down Schlumberger. Circ/cond. Install 7" casing rams. Remove wear bushing, install test plug, test BOP at 250/5000 psi. Retrieve test plug. Rig up to run 7" liner. Run 117 jts various weights and grades 7" liner. Circ/cond. 11 jts 35# L80 LT&C 9789'-10220', I Flag jt 35# L80 LTC 9770'-9789', 16 jts 35# LBO LTC 9151 '-9770', I flag jt 35# L80 LTC 9130'-9151', 13 jts 35# L80 LTC 8622'-9130', 12 jts 32# L80 LTC 8148'-'8622'. SBBH/080288 -6- DAILY REPORT OF OPERATIONS (continued) C22-23 DATE DESCRIPTION 06/10/88 (cont.) I Flag jt 29# NSO LTC 8130'-8148', 6 jts 29# N80 LTC 7867'-8130', 51 jts 26# N80 LTC 5862'-7867', i XO LTC X BTC 5821'-5862', 2 jts 26# N80 BTC 5738'-5821', Brown Shorty Hanger 5735'-5738', Setting sleeve 5727'-5735'. 06/11/88 Set hanger at 5735', shoe at 10304', float collar at 10261', landing collar at 10220', shear out ball seat in landing collar at 2500 psi. Pump 30 bbls spacer mixed at 13.8 ppg followed by 10 bbls fresh water + 1% NaC1, mix and pump 1125 sx "G" + 0.2% CFR-2 + 0.5% Halad 344 + 1% NaC1 + 0.125% LWL mixed at 15.6 ppg. Displace with 267 bbls 12.2 ppg mud. Test BOPE, test annular preventer at 250/5000 psi, test all rams, valves, lines, manifolds, kelly valves, inside BOP valve, HCR valve, standpipe and rotary hose at 250/5000 psi. 06/12/88 Test liner lap. Started injection at 1000 psi. Service rig. Set RTTS at 5495', RU HOWCO lines, test lines to 3500 psi, establish injection rate. Pump 30 bbls fresh water, mix and pump 250 sx "G" cement mixed at 15.8 ppg followed by 5 bbls fresh water, displace 21 bbls 12.2 ppg mud, close by-pass, displace 80 bbls 12.2 ppg mud at 3 BPM with 500 psi. Final rate I BPM at 300 psi. Clean out cement. 06/13/88 Cement tagged at 5546'. Drill cement from 5546' to 5727'. Close rams, pressure up casing at 3500 psi, test liner lap for 30 minutes. O.K. Set packer at 5631', test liner lap for inflow with 2100 psi drawdown test. O.K. 06/14/88 Top of liner at 5727'. Clean out cement from 5727' to 5826'. RU Schlumberger, run CET/CCL/GR. Run gyro s u rvey. 06/15/88 Run velocity survey. R/D Schlumberger. R/U drill pipe lay down tools. 06/16/88 R/U and run 3.5" 9.3# N80 AB MOD Frac String to 3500'. Reverse out mud. 06/17/88 Reverse circulate well with filtered injection water. Set RTTS packer at 9290'. R/U and test casing at 3000 psi for 30 min. R/U dresser atlas lubricator, test lubricator and 3.5" tubing at 4000 psi. Perforate 10044-10064'. SBBH/080288 -7- DATE 06/18/88 06/19/88 06/20/88 06/21/88 06/22/88 06/23/88 06/24/88 06/25/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION Perforate at 10015' - 9995', 9900' - 9895', 9926' - 9946', 9879' - 9886' Pressure up annulus to 3000 psi, pressure all dowell iines at 10500 psi, test turbine pump shutdown systems. Pump 1000 gals 10% HC1 at 5 BPM ball out at 8600 psi. Rig up dresser atlas lubricator, test at 10000 psi. Pump filtered injection water and 40#/1000 gal gelled water various pressures and rates to determine formation properties of HR-HZ zone. Pressure test dresser atlas lubricator to 10,000 psi. Fracture treat HR-HZ zone with YF200 fluid + 3000# 100 Mesh + 71000# 20/40 mesh carbolite, flush with WF40, Average rate = 17 BPM, Average psi = 7050 psi. Back flow well approximately 200 bbls, pressure build up to 1025 psi. Monitor well. R/U dresser atlas, test lubricator at 5000 psi. Ran temp sonde log 9289'-9783'. Reverse circulate kill brine. Monitor well. R/U and test BOPE, test all RAMS, valves and lines at 250/5000 psi. Test annular preventer at 250/5000 psi. Tag fill at 9746'. R/U HOWCO, test lines at 2000 psi.. Mix and pump 60 sx 20/40/ mesh sand plug. Est. top of sand 9834'. Mix and pump 30 sx 20/40 mesh sand plug. Est. top of sand 9810'. Tag sand at 9800'. Circ and reverse sand to 9810'. Tag sand at 9795'. Clean out sand to 9810' Set RTTS at 9171', pressure test casing to 3000 psi. T~st lubricator and tubing to 3000 psi. Perforate 9770'-9790', 9719'-9739', 9677'-9697', 9658'-9668'. R/U to fracture treat HN-HR. Test lines to 10,000 psi. Hydraulic fracture treat HN-HR. Pump 1000 gals 10% HC1 with 60 7/8" ball sealers, ball out after 114 bbls, displace acid at 10 BPM. Pump in with 100 bbl 40#/1000 gal gel at 20 BPM 7800 psi, ISIP = 5200 psi. Hydraulic fracture treat with 1092 bbls total proppant = 65000# 20-40 mesh carbolite. ISIP= 6450 psi, 5 min ISIP=6270 psi. Back flow well to production. Back flow well to production and reverse out tubing. Preparing to unseat packer. Unseat packer, reverse circa tubing volume to production test separator. Reverse circ. Remove sand. Circ/cond. Shut-in well, psi at 150# in 30 mins. Tagged sand at 9572'. Reversing out sand from 9572'-9875'. SBBH/080288 -8- DATE 06/26/88 06/27/88 06/28/88 07/09/88 07/10/88 DAILY REPORT OF OPERATIONS (continued) C22-23 DESCRIPTION Reverse out sand from 9875'-10220'. Observed well. Shut-in well. Circ/cond. Set DB permanent packer at 8756'. End of re-entry guide at 8790'. Run 2-7/8" BRD EUE AB MOD 6.5# N-80 tubing. Test tubing/packer to 2000# for 30 minutes. Rig released. Rig accepted. R/U slickline unit and lubricator, test lubricator at 1500 psi. Run pressure and temp. survey. Perforate 9534'-9564', 9502'-9534'. Perforate 9472'-9502', 9442'-9472', 9223'-9253', 9200'-9223', 9094'-9129'. R/D dresser atlas wireline and lubricator. Release rig. SBBH/080288 -9- 9 10 11 12 13 1 2 3 4 5 6 7 8 14 COMPLETION EQUIPMENT DETAIL SItEET MGS C22-23 10/6/88 NO. ITEM TVD. MI). PSI OR 1. FLOPETROL LANDING NIPPLE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL #7 9. 2-7/8" OTIS "XO" SLIDING SLEEVE 10. BAKER "G" LOCATOR W/ 2 SEAL UNITS, 5' EXT, 2 SEAL UNITS, MULESHOE 11 BAKER "DB" PACKER ID = 3.25" W/ 10' SBE 12. 10' 2-7/8" EUE PUP 13. 2-7/8" OTIS "XN" NIPPLE 14. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB 297 297 1604 1687 895 1/8 3067 3326 925 3/16 4390 4783 920 3/16 5525 6023 905 3/16 6487 7110 895 3/16 7320 7987 928 1/4 8004 8680 OR 1/4 8044 8721 8078 8755 8079 8756 8093 8770 8103 8780 8113 8790 CASING 13 3/8", 54.5-72#,K-55/NT-95 @ 1710' W/500 SX, 341SX TOP JOB 9 5/8", 47-53.5#, N-80/S00-95, ~ 6047' W/ 545 SX 7" 26#, N-80 @ 5727-7867' 29#, N-80 @ 7867-8148' 32#, L-80 @ 8148-8622' 35#, 8622-10220' W/ 1125 SX SQUEEZE LINER TOP W/ 250 SX PBTD = 10202' (LANDING COLLAR), 8130', 9130', 9770' TD = 10307' TUBING 2 7/8", 6.5#, N-80, AB-MOD. EUE @ 8790' PERFORATED ZONE PROPOSED INTERVAL GR-GS HC-HD HE-IIF tlK-HN HN-HR HR-HZ TO BE PERFORATED LATER 9094-9]29 9200-9253 9442-9564 FRAC TREATED 9658-9790 (40 SHOTS) FRAC TREATED 9879-10064 (40 SHOTS) C22-23 PERFORATION DETAIL SHEET ZONE TOP MD 9087' 92O0' 9379' 9590' 9824' TVD 8408' 8519' 8697' 8905' 9135' PERFORATION INTERVAL 9094' - 9129' 92O0' - 9253' 9442' - 9564' 9658' - 9790' 9879' - 10064' ZONE BOTTOM MD TVD SIZE & NUMBER 9132' 9255' 9590' 9824' 10127' 8452' 2-1/8" 4JSPF 8574' 2-1/8" 4JSPF 8905' 2-1/8" 4JSPF 9135' 2-1/8" 40 shots 9430' 2-1/8" 40 shots SBBH/080288 C22-23 ACID & FRACTURE TREATMENT DETAIL SHEET BALL OUT ACID TREATMENT- (06/18/88) Perforations open (HR-HZ) = 10,044' - 10064', 9995' - 10015', 9895' - 9900', 9926' - 9946' and 9879' - 9886' (40 holes) Treatment used 60 high density ball sealers (S.G. = 1.3). The balls were spaced out in groups of five after pumping the first 5 bbls of the 1000 gallons of 10% HC1. Acid was displaced with filtered injection water. Total ball out occurred after 113 bbl of fluid was pumped. FRACTURE TREATMENT- (06/19/88) After completing the ball out acid treatment, the HR-HZ was fracture treated. YF200 fluid + 3000#, 100 mesh + 71000#, 20/40 mesh carbolite was used. The well was backflowed briefly after 12 hours and then circulated with 9.8 ppg NaC1 brine. Average rate : 17 BPM, Average psi = 7050 psi. Used 90 sx of 20/40 mesh sand to isolate HR-HZ prior to frac treating the HN-HR. BALL OUT ACID TREATMENT- (06/28/88) Perforations open (HN-HR) = 9770' - 9790', 9719' - 9739', 9677' - 9697', 9658' - 9668' (40 holes) Treatment used 60 high density ball sealers (S.G. = 1.3). The procedure was the same as the first one and used 1000 gal of 10% HC1. Ball out occurred after 114 bbl of fluid was pumped. Acid was displaced with 40#/1000 gallon linear gel. FRACTURE TREATMENT Treatment used 1092 bbls total proppant including 65000#, 20/40 mesh carbolite. Average rate : 22 BPM, Average psi = 8000. SBBH/080288 Shell Western E&P, SCHLUMBERGER WELL SERVICES DIVISION OF SCHLUMBERGER TE:CHNOL. O~Y CORF~RATION HOUSTON, TE:XAS 77251-2175 ' PLEASE REPLY TO N o v em b e r 9, 1 9 8 8 SCHLUMBERGER WELL SERVICES 500 W. International Airport Anchorage, Alaska 99518 ATTN: Print Room Inc. P.O. Box 527 Houston, TX 77001 Rd. Attention' L o g F i 1 e s, WC K 4147 ~'~y ~ 2", & 5"~L.SS~RUN'~; _ ~,~ ~ Gentlemen: ~' &~" L~S,~IL,~H~SOR DIL,~L~T/CNL (~);5~LDT/CNL (RAW), Enclosed ~re 1 BL prints of the. RFT, SRDT, GCT,ML, L~T F-LOG, ~NIC F'LOG. CE~ ( RUN2)on: Company Shell Western E&P," Inc. Well C22-23 " Field Mi ddl e Ground Shoal County Additional prints are being sent to: 1 BL prints Shell Western E&P~ Inc. 601 W. Fifth Ave., Suite 810 Anchoraqe, AK 99501 ... ATTN: Hank Van Schel K e__Qn a j f,.Stote A!.a s k a 3 BL prints Shell Western E&P, In¢, P.O. BOX 527 Houston, TX 77001 ATTN: C.C. Williams WCK 1134 prints 1 BL nrints Shell' Western E&P, Inc. Platform "A" or "C" C/O Shell Kenai Office 130 Trading Bay Ave.~ Suite 130 Kenai, AK 99611 1 RFolded Sepia 1 BL nrints S t a t e~...O-f~A'T'=~ S k a AK/O~'~I ~ Gas Conservatibq-Conlmission 3/001 ~KorCupine Dr. ~ ] A~nchoKage, AK 99501 ) A \\T~ohn Boyle~ The film is returned to She! 1 (Houston-Log Fi les) We appreciate the privilege of serving you. SWS - 132";' F ~prints Anchorage Received by' Date: Very truly yours, SCHLUMBERGER WELL SERVICES Marc Gunther DISTRICT M & NAOIIII RETAIN THIS SECTION FOR YOUR RECORDS RE C 22-23 PL$ 1 PRINTS 0 NEG. 1 SEPIA PRINTS __ NEG. __ SEPIA PRINTS __ NEG. __ SEPIA PRINTS __ NEG. SEPIA PRINTS NEG. SEPIA PRINTS_ NEG. SEPIA PRINT ,, . [~ ~, ,~ [ SEPIA PRINN_TT~'~~ ~ SEPIA ABOVE RECEIVED FROM: DRESSER (~L~;~.:~, ~,~ ?~%:,.,, ' JOI~IN BOYLE AITENTION SIGNED DAT~'~chot~3ge 19. Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 August 29, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF DIRECTIONAL SURVEY LOG FOR MIDDLE GROUND SHOAL WELL C22-23 Enclosed, for your information and use is the Directional Survey log for Middle Ground Shoal Well C22-23. If you have any questions, please call me at 263-9613. ~ery truly yours, S. B. Brown Environmental Technician ljm Enclosure' Directional Well Survey (1) RETAIN THIS SECTION FOR YOUR RECORDS RE C22-23 (REVISED 8/88), (SHELL WELL) DiFFTEMP 1 PRINTS 0 NEG. PRINTS NEG. ~ , .~.: '~ PRINTS L__7 "~ ~ ~ PRINTS NEG. NEG. /.':!:::,?,i ;'." " "'~ i,:i,',.:,'~':,~i,i:? PRINTS NEG. · ~: .... '. -' ~ PRINTS NEG. ABOVE RECEIVED FROM: DRESSER ATLAS JOHN BOYLE ATTENTION 0 SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SIGNED DATE 19 "MEMORANduM TO: THRU: FROM: State{ of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smith~¢~J~/ Commissioner ,/ O ,, Michael T. Minder Sr. Petroleum Engineer DATE: August 8, 1988 FILENO: D. BDF. 008 TELEPHONE NO: SUBJECT~ Safety Valve Tests Shell-MGSU Platform C MGS Oil Pools Bobby D. Fost Petroleum Inspector ~,, Thursday August 4, 1988: The tests began at 7~30 a.m. and were '~b'neiude~ at i0~30 a.'m. With 10 Pilots, 10 SSSV s and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. .~ This will be repaired and the AOGCC Office notified.. ,. ~'Comment by Mike Minder~ Richard Vickerson called August 8, 1988, to notify Commission that the SSSV in C42-23 has been replaced and tested OK. Attachment PtlotS Tested 10, SSS¥' s TeSted !0 · SSV' s Tested ~10 Pilots Failed 0 SSSVI§ Failed 1 SSV's Failed 0 02-001A (Rev, 8/85) AOGCC SAFETY VALVE TEST REPORT PAGE ,, .. PRESSURES - PSIG, · I FIELD: MIDDLE GROUND SHOAL OPERATOR: SHELL WESTERN E&P [ WELL [ PERMIT I NUMBER I NUMBER I I 1C44-14RD177-0079-0 ' 1¢-23-23..68-0030-0 IC-31-23 168-0069-0 I ' Ic-32-23'/175-oo35-o ' 4~-oo2~-o Ic-42-23 J C-63-23~ 68-0060-0 C22-26RN 76-0065-0 C26-26RN'79o0062-0 ¢-31-26 67-0063-0 ,j 0434226/ 68-0019-0 SHELL C PLATFORM DATE: c~ · ~ . o~ SS, REPRESENTATIVE : ,~. , 'C, ..)~ Isv TSTIPILOTI FLSI SI I _SSVISSVlSSSV ISSSlNI I DUE I(LOW)I TB~ITB~ I IP I rP I~1 ~P I FP I~SI I~1~1~1~1 ,. I~1, I__1__1' I II I I I II I ' I , ,~,'~-, , , ,, , , , uo'j I~1 ..... I ~I I I I I I I I I I C) iZ'ff I , I~1~1~1 I,' ~1., ,1_1 I ....... . '1~1_1 ..... luoJ,__... ' , Isx ...... ,~J/z "' ,'~, ,~,,j j~o' vojp, ,, I II '' ......... I~1' I I I I I I I I ~1~~1~1~1~1 _ I__ I I_ I I' I I I I I I I, I .... I~ ·I~1 ' I~1',.,I .... .I ..... I_ I I I I I I I I I I~1~ ~1~1~1~1. ,. I~ ~1 .,. I_ I I I I I I I I. I I~1 ..... I~1~1~1 I~, .'1 I_ I I I I I I I I I I~1.. ~1~1 I~1 .1____1 I_ I I I I I, I I II ~1~~1~1~1~1_ '1_ ~1.,,1_1 I I I I I I I I I I~ I~1~1 , ,., I I~ ~1 I_1 I ' I I. I I I I I I ~1~ I~1~1~1 I__ __1--1_1 I I I. I I I I I I ~1~ I~l~k I I__ __1_ ~1_1 I ,I I J . /' I I I I. J REMARKS: I I I I J ' .,, I I INSPECTOR ., · Shell Western E&P Inc. A Subsidiary of Shell Oi~ Company P.O. Box 576 Houston, TX 77001 July 7, 1988 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99510 Attn: John Boyle Dear Mr. Boyle: SUBJECT: DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA Wel 1: C-22-23 Enclosed you will find data pertaining to the Middle Ground Shoal well listed above. Please return a signed copy of this transmittal letter to acknowledge recei pt. C. C.[Wi~l 1 i ams Alask~.~ivision CCW:mh Enclosure Received by: CRCT8818901 - 0001.0.0 Western AtlBs International A Ln~on/Dres~r Company CORE LABORATORIES CORE ANALYSIS FOR SHELL WESTERN EXPL. C-22-23 MIDDLE GROUND SHOAL FIELD ALASKA REPORT & PROD., INC. The analyses, opinions or interpretations contained in this report are based upon o.gservations and material supplied b,l the client for ',',,hose exclusive and confidential use this report has been made. The interpretat OhS or opinions expressed represent the besl judgement of Core Laboratories. Core Laboratories assumes no resoonsibility and makes no warra'nty or representat OhS. express or implied, as to the productivity, proper operat ons. or profitableness however of any oil. gas. coal or other mater/al, property. ,,.,,ell or sand in connection with which such report is used or relied upon for any reason v/hatsoever Company Well Location Co,State CO~E LABORATORIES Western Atlas ~ International ;'~ ~'~ ;? ~'~ ~ ~ ~ ~ A Lrr, on/©resser Company ~-:.:. ~:~ ..~. ..... SHELL WESTERN EXPL & PROD., INC .... -;~_-~ Field : MIDDLE GROUND SHOAL FIELD File No.: 57151-15838 C-22-23 ' .ii.li. '_ ~ -::';"~'~:~ Formation : Date : 14-JUN-88 ALASKA ..... ,-~ ~i?~t ;~r L'~:? ~'~ C,?'~,~i~i~n Coring Fluid : WATER BASE HUD API No. : ?.,?. ~:m .... ~:~:~? 51 evat i on : Analysts: GS-HS SIDEWALL CORE ANALYSIS RESULTS SATURATI ~ SATURATI ON SAMPLE DEPTH PERMEABILITY POROSITY. PROBABLE GAS CRITICAL SILT DESCRIPTION REC. (SIDEWALL) (FLUIDS) (PORE VOLUME) PRODUCTION (BULK VOLUME) DETECTOR WATER & CLAY OIL WATER CODE OIL GAS UNITS SATURATI~ in ft nzl % % % % % % % 0.3 ~528.0 INSUFF O. SD GRY FG SSHY SCALC NO FLU 1.0 6546.0 46.0 21.0 0.3 79.0 krFR 0.1 4.3 O. 53. 31. SD GRY F-MG SSHY SCALC SPTS GLD FLU 1.0 6554.0 150. 24.5 0.7 81.6 WTR 0.2 4.3 O. 45. 34. SD GRY F-MG SSIJY SCALC SPTS GLD FLU 0.3 6564.0 INSUFF O. SD GRY CSG PEBB SSHY SCALC SPTS GLD FLU 1.0 6685.0 15.0 19.5 0.5 79.4 WTR 0.1 3.9 O. 62. 46. SD GRY FG SHY CALC SPTS GLO FLU 1.0 6694.0 24.0 19.4 0.0 88.5 WTR 0.0 2.2 O. 58. 30. SD GRY FG SHY VCALC ND FLU 1.0 6716.0 160. 25.3 0.0 34.0 GAS 0.0 16;7 O. 46. 36. SD GRY FG SLTY SSHY VCALC NO FLU 1.0 6728.0 24.0 20.0 1.0 80.6 WTR 0.2 3.7 O. 59. 35. SD GRY VFG SHY LAM CALC STKS GLD FLU 1.0 8501.0 130. 24.8 0.0 47.9 GAS 0.0 12.9 O. 48. 33. SD GRY VFG SSHY CALC NO FLU O. 3 8510.0 O. MUDCAKE 0.3 8512.0 O. MUDCAKE 0.3 8514.0 ALTERED O. SD GRY F-~ SSHY VCALC NO FLU 0.3 8516.0 INSUFF O. SD GRY M-CSG SHY VCALC NO-FLU 0.5 8518.0 5.30 18.7 0.0 90.0 LOW PERM 0.0 1.9 O. 68. SD GRY FG VSLTY SSHY CALC NO FLU 1.0 8821.0 17.0 21.9 9.6 35.8 OIL 2.1 12.0 O. 65. 51. SD GRY VFG SLTY SHY CALC GLD FLU 1.0 8826.0 26.0 22.2 9.4 42.0 OIL 2.1 10.8 O. 61. 46. SD GRY VFG SLTY SHY CALC GLD FLU 1.0 8836.0 27.0 20.1 7.6 45.3 OIL 1.5 9.5 O. 58. 33. SD GRY FG SHY CALC GLD FLU 0.8 8842.0 18.0 19,1 8.2 49.8 OIL 1.6 8.0 O. 60. 50. SD GRY FG SHY CALC GLD FLU 1.0 8850.0 38.0 23.3 12.5 47.1 OIL 2.9 9.4 O. 59. 45. SD GRY FG SHY CALC GLD FLU 1 -1 The analyses, opinons or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinons expressed represent the best judgemenl of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the produotivitv. Brot'}~.r r~n~r2tinn~ r~r nrr~fif~hlCn~,ee h,-,,~,~, ..... ¢ .... ^;i ...... f -- _,u ....... :-, ..................... Company : SHELL WESTERN EXPL. & PROD., INC. ~el 1 : C-22-23 SIDEWALL CORE LABORATOR'rES Field : NIDDLE GROUND SHOAL FIELD File Ho,: 57151-15836 Formation : Date : 14-~1UN-88 CORE ANALYSIS RESULTS SATURATION SATURATION SAMPLE DEPTH PERMEABILITY POROSITY PROBABLE GAS CRITICAL SILT DESCRIPTION REC. (SIDEWALL) (FLUIDS) (PORE VDLblqE) PRODUCTION (BULK VOLUME) DETECTOR WATER & CLAY OIL WATER CODE OIL GAS UNITS SATURATION in ft nd % % % % % % % 0.3 8857.0 INSUFF O. SD GRY F-MG SSHY CALC GLD FLU O. 3 9098.0 O. MUDCAKE 0.8 9345.0 3.00 16.6 0.7 78.7 LOW PERM 0.1 3.4 O. 67. SD GRY VFG VSHY CALC STKS GLD FLU O. 3 9357.0 O. MUDCAKE 1.0 9414.0 5.10 15.7 0.6 79.5 LOW PERM 0.1 3.1 O. 63. SD GRY FG VSHY SPTS GLD FLU 9474.0 NO RECOVERY 0.5 9483.0 3.20 15.5 1.2 86.5 LOW PERM 0.2 1.9 O. 64. SD GRY H-C VSHY CALC DULL GLD FLU 9604.0 NO RECOVERY ~ ,-; ~ m NO RECOVERY 9683.0 )~ i~ 9730.0 ~]~'80ii & GaS Cons. C. ommiss)on NO RECOVERY 0.5 9773.0 INSUFF O. SD VFG VSLTY SSHY DULL GLO FLU 0.5 9793.0 INSUFF O. SD GRY M-CSG VSHY CALC GLO FLU 9846.0 NO RECOVERY 0.5 9854.0 INSUFF O. SD GRY VFG VSLTY CALC GLD FLU 0.3 9874.0 ALTERED O. MUDCAKE W/TR OF SD GRY ! -2 Company : SHELL IVESTERN EXPL. & PROD., iNC. Well : C-22-23 SIDEWALL CORE LABORATORTES Field :MIDDLE GROUND SHOAL FIELD File tto,~ 57151-15838 Formati on : Date ; 14-0UN-88 CORE ANALYSIS RESULTS SATURATION SATURATION SAMPLE DEPTH PERMEABILITY POROSITY PROBABLE ,,-GAS CRITICAL SILT DESCRIPTION REC. (SIDEWALL) (FLUIDS) (PORE VOL~E) PRODUCTION (BULK VOLUME) DETECTOR WATER & CLAY OIL WATER CODE OIL GAS UNITS SATURATION in ft n~! % % % % % % % 9884.0 NO RECOVERY -!. *'-:* ~-:- 0 1-3 Company : SHELL WESTERN EXPL. & PROD., iNC. We11 : C-22-23 Location : Co,State : ALASKA SIDEWALL CORE LABORATORIES Field :HIDDLEGROUNDSHOALFIELDFileNo.: 57151-15838 Formation : Date : ]4-JUN-88 Coring Fluid : WATER BASE MUO API No. : Elevation : Analysts:GS-HS CORE ANALYSIS RESULTS DEPTH EXTRA COARSE MEDIUM FINE VERY FINESTEXTURE PERMEABILITY POROSITY COARSE GRAINEOiGRAINED GRAINED FINE INDEX (SIDEWALL) (FLUIDS) GRAINED ,GRAINED ft % % % % % % md % 6528.0 6546.0 0 0 28 27 13 31 75 46.0 21.0 6554.0 0 17 16 20 14 33 65 160. 24.5 6564.0 6685.0 0 0 13 22 20 46 85 15.0 19.5 6694.0 0 0 10 35 26 30 81 24.0 19.4 6716.0 0 6 12 25 21 35 65 160. 25.3 6728.0 0 0 7 33 25 35 81 24.0 20.0 8501.0 0 0 8 32 26 32 66 130. 24.8 8510.0 8512.0 8514.0 8516.0 8518.0 5.30 18.7 8821.0 0 0 2 11 36 49 83 17.0 21.9 8826.0 0 0 2 23 28 46 80 26.0 22.2 8836.0 0 0 11 32 23 33 80 27.0 20.1 8842.0 0 0 8 20 22 49 87 18.0 19.1 8850.0 0 0 6 22 28 45 77 38.0 23.3 2- 1 Company : SHELL WESTERN EXPL. & PROD., INC. Well : C-22-23 SIDEWALL CORE LABORATORTES CORE Field Formation : MIDDLE GROUND SHOAL FIELD File No,: 57151-15838 : Date : 14-~1UN-88 ANALYSIS RESULTS DEPTH EXTRA COARSE MEDIUM FINE VERY FINES TEXTURE PERMEABILITY POROSITY COARSE GRAINED GRAINED GRAINED FINE INDEX (SIDEWALL) (FLUIDS) GRAINED !GRAINED ft % % % % % % md % 8857.0 9098.0 9345.0 3. O0 16. $ 9357.0 9414.0 5.10 15.7 9483.0 3.20 15.5 9636.0 9773.0 9793.0 9854.0 9874.0 2-2 SHELL WESTERN EXPLo & PROD. C-22-2~ ALASKA [mATE : 14-JUN-88 FIEL.[m: MIDDLE GROUND SHOAL FIELD FILE NO: 57151-15838 ANALYST: GS'HS DISTRIBUTION OF FINAL REPORTS COPIES TO: 4 cc SHELL WESTERN EXPLo & PROD° ALASKA DIVISION(PRODUCTION) F', O. BOX 576 HOUSTON, TEXAS 77001 ATTN: MR, CLAY C, WILLIAMS TAPES: TA.:::'E, TA?E,, 1 3RIG!NAL TAPE ?.0. 50X 527 '~CUcTuN, '"F'~; 77001 80HLU~BEHGEH WELL 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION · STATE OF ALASKA ~: · ALASKA {)iL & GAS CONSERVATION COMMISSION 3001 PO,CUPINE DR Ai';uHLRAGE AK 99501 JOHN BOYLE COMPUTING CENTER PRINT CENTER WELL NAME SERVICES · · MGS C22-23 1 OH LIS TAPE 1 WELL NAME ' SERVICES · NO. OF BOXES· JOB NO.. ADD~L TAPES WELL NAME ' SERVICES · NO. OF BOXES: JOB NO'. ' ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · · 72809 · *See Above · NO. OF BOXES: JOB NO. · ADD'L TAPES ' WELL NAME SERVICES t'~ ' . · AlaSka, 0it'& Gas Cons', commisSio ADD'L TAPES ' WELL NAME SERVICES NO. OF BOXES' i~\3,5~'3'tjk\ lk¢'~°¢ge" " JOB NO. . ..... · ADD'L TAPES · - ........ ; SCHLUMBERGER COURIER: DATE DELIVERED: ,,.i'? // , TELECOPI ER 295 F R 0 M 8 i 87 4-14-88; t:2., 0;2 PNt; .. .. CONSERVATION ' I 22:59 ·. -., i iii iii il. ~ ~ In.~pecto~ (VERBAL WA!V.~,..R..) PER MIKE Ni~{DER . 2' .-- .... ---- ~. _.... ..... ~:_._--~,., -- ____-._ _ - ..... --_..~ . .....i_-- ~ I, OpeC,tot SHELL WESTERN E~&.P, iNC. ~ gep~,~n~%,e R.V. WELLS --~'":---- ' -.*---m-%i~ .... · ~ ~ ~ ,,,,, "----' ~.~: mi ......... Well --=.- MGS C-22-23_~.~_____._.~___,_., ,._ _P-,',,~ ~~1 ~ ........ 88-I_.~. ~ocaztonz SeC 23 Drilltn Co~trac~o~ GRACE Location, O~a~al~.___Wmll. ~en~al ~OUsmkeepi~~Ri~GOOD '":~. Hud System~ ~ ,~,, Visu,~, Audio " '! ' '" ' 0 T~lp Tank X ~ ..... Pi~ ~auie X .X ~1ov HOnitot ~~ __~..~._ . .', ~iPe t~m~',,.,,: .,. . 3000," , Choke ~i~ ~alves ' 3DO0 .' .,,": :_ ~ r~ ' - ...'~ .... , ,,- - B. O. 2, Valve r"-~ . .. .'. . ', , i '. prm., 200 psi~~i%,~a naa, N~ 6 .~ ' ps~ 2oOO~ ~no~es ~ ~;~ ..... Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 April 1, 1988 Alaska Oil and Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C22-23 Enclosed, in triplicate, is the Application for Sundry Approval for changes to the well plan for Middle Ground Shoal Well No. C22-23. The target location of this well has been changed to the extent that the casing setting depths and the directional plan has been changed. a- " The proposed well plot on the "spider di q~is submitted for your information. If you have any questions, please call Ms. Susan Brown or Mr. Joe Fram at (907)276-2545. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBB/kt Enclosures SBBG/aogcc. 040188 S{' STATE OF ALASKA IV~ ALA ,,.-~ OIL AND GAS CONSERVATION CO ,.,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved programX~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 105' KB feet 3. Address 6. Unit or Property name 601 West Fifth Avenue, Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform C, Leg 2, Conductor 10 at 618.65' FSL and 15#9.76' FEL of Sec. 23, T8N, R13W, At top of productive interval (REVISED) 2,4#5' FNL and 3,365' FEL ot= Sec. 23, T8N, R13W, S.M. At effective depth At total depth (REVISED) 2,392' FNL and 2,786' FEL of Sec. 23, T8N, R13W, S.M. 7. Well number C22-23 8. Permit number 88-16 9. APl number 50-- 733-20397 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface NOT IN PLACE Intermediate Production Liner Perforation depth: measured true vertical Size Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth RECEIVED Naska 0il & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal E~X Detailed operations program x[~ . Revised casing desiqn sheet, qr~ph~g~].prQgRg~is~ and directional pian l~p. Estimated date for commencing operation rll 10, 1988 BOP sketch [] 14. If proposal was verbally approved Name of approver,,, Date approved 15.1 her.el)~ ce, rtify ~a~ t/~)e foreg~ng is true and correct to the best of my knowledge V[~.~. ql,[~ /j,~- l~ Division Operations Hanager Signed ~( ~ S ~ ~ ~ ~~ Title Commission Use Only Conditions of approval Notify commission so representative may witness J Approval ~ Plug integrity ~ BOP Test ~ Location clearanceJ Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned_ Commissioner SBBG/asa .040188 by order of ~.,.~,~' ....~ the commission Date Submit in triplicate C22-23 CASING DESIGN Casing Design Criteria Frac Gradient Pressure Gradient Max Collapse Pressure Max Burst Pressure RECEIVED APR o Size 13-3/8" Alaska Oil & Gas Cons. Commissior~ Anchorage .Depth 0-1662' MD 0-1600' TVD 9-5/8" 0-4350' MD 0-4000' TVD Grade/ Weight Coupling 13-3/8" 11 .57 .47 654 psi (Full evacuation) 856 psi (1/3 BHP @ 9-5/8" csg pt) 9-5./8" .73 .47 2570 psi (Full evacuation) 3600 psi (injection. pressure) ACTUAL DESIGN CONDITION 7" (Liner) 54.5# K-55 BTC 43.5# L-80 LTC 4350-5818' MD 47# L-80 4000-5310' TVD LTC .73 .62 10000 psi (pressure from frac jobs) 3600 psi (injection pressure) ,, ' Tension # Collapse Burst Wt in Mud PSI PSI 75,000 747 856 209,000 1869 3600 60,000 2570 3600 ~'&&& 5818-6031' MD 40# ~,~- 5310-5500' TVD ~T~ 6031-8803' MD 26# L-80 5500-8100' TVD LTC BB03-10677' MD 8100-9805' TVD 32# P-llO LTC 113,000 5255 3600 Casing Rating/Design Factors Tension(m) Collapse Burst 853/11.4 1141/1.53 2700/3.15 825/3.95 3696/1.98 6393/1 47,000 10000 3600 905/15.1 4798/1.87 6733/1.87 737/105 3090/1.20 5750/1.60 519/4.44 897/19.1 5261/1.00 I 6548/1.82 10437/1.0~.~ 12211/3 39 VEU7/040188 ALASKA DIVISION DRILLING PROGNOSIS 3/31/88 WELL: C 22-23 LOCATION: PLATFORM 'C', LEG 2, CONDUCTOR 9 OBJECTIVE: DOWNTHROWN BLOCK OF HEMLOCK EVALUATION GEOLOGY SWEPI INTEREST: 100% AFE NO: 262381 FIELD: MGS EST. ELEVATION: 105' (MEAN LOW LOW TIDE: DRILLING 73') CORES U.I ELEC. MUD SIGNIFICANT SURVEYS LOGGER FORMATIONS o 24' Conductor 370' 13-3/8' Casing 1600' 9-5/8'Casing 5500' WELL CASING DEPTH AND TVD MD CEMENT ! , ! ! 6031' .~ FL 6880' FS 7175' GB 7550' GD 7670' GN 7975' GR 8255 HC 8625' HZ 9605' 7" Liner(TD) 9805' 7566' 7872' 8149' 8369' 8675' 8963' 9360' 10454' 10677' ,,4 HOLE DEV. HOLE AND DIR. SIZE CONTROL 17- /2' 12-1/4' t 8-1/2" 4;::, o~o ob ~Eo MUD PROGRAM 100 ~2000 ,350 .4000 450( · , t r ~50 700{ 75{ 80 i { MGS PLATFORM C 'i , , ? C 22 23 ,: , , ,,. ..... · , · , ~ . . : ;~ ~ ; ',.SCALE: 1'= - 1{ ~ { __I Magnebc Dechnat[on=23.7o(23o42'),'. :~ 'UPPER II, ].'~.., ',] 't~'-~ ~ Net Magnetic SurveyCorrection=250or25onnn ' ~ ; . :. ~¢f~' SECTIO~ T~ ~ 'Vertical Section Azimuth=3 6.9°j , ...... KOP 375'TVD END BUILD i LOWER 'i .! Vertical Section Azimuth=85o 75O $00 85¢ ~ 10000 200'X 50" ORIENTED N3°W 8625'TVD 9314'MD T--'! ........... ;-- ~ ...... .-,-..4.._~_-~-~_ -4,--4- ARGET ¢2 300'X 200' ORIENTED 1~5OE 9605'TVD 1040T'MD , , 9805'TVD I0630'MD 000 1500 2 0 t. '! . ' PLAN VIEW 30,.00 ii 500' 1000 1500 '2000 ., ~ I ~, i ,, · V SECTION · BEGIN DROP '2500 3000 3500 2000 15 1000 ! ! ~i } , ¢ ~i :, :"i' ~ ? ! I! ! I ! i ! I ~':: I DEPART 50o 000' ! 500 ,~ March 22, 1988 Mr. M. L. Woodson Division Operations Manager Shell Western E&P Inc. 601W. Fifth Avenue, Suite 810 Anchorage, Alaska 99501-2257 Telecopy: (907) 276-7542 Re .. Middle Ground Shoal C22-23 Shell Western E&P Inc. Permit No. 88-16 Sur. Loc. 618.65;FSL, 1549.76'FEL, Sec. 23, T8N, R13W, SM. Btmhole Loc. 2127'FNL, 4182'FEL, Sec. 23, TSN, R13W, SM. Dear Mr. Woodson: Enclosed is the approved application for permit to drill the. above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits .required by law from other governmental agencies prior to commencing operations at the well. site. To aid us in scheduling field work, please notify this office 24 hours prior to 'commencing installation of the blowout prevention equipment so that a representative of the .Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COt~{ISSION dlf EnclOsure CC: Department of Fish & Game, Habitat Section w/o encl. DePartment of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux ,¢' STATE OF ALASKA ' ALASK.~ .JIL AND GAS CONSERVATION d,_ ,,tMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenElI Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shel 1 Western E&P I nc. 105'KB feet Middle Ground Shoal 3. Address 6. Property Designation 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 ADL 18756 ~ "G" Pool 4. Location of well at surface Platform "C" Leg 2 Con- 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ductor 10 ~ 618.65'FSL & 1549.76'FEL of Sec.23, T8N, Middle Ground Shoal top of productive interval ~ 2~' FNL and ~85~' 8. Well num er Number 11C 1~650~ FEL of Sec.2~, T8N, RI~W, SM C22-23 ~ Statewide INA-Shell 0084 At total depth ~ 2127' FNL and 4182' FEL Sec.2~, 9. Approximate spud date Amount $100,000 T8N, R13W, SM March 15, 1988 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth (MD and TVD) property line ¢TD 3442' 0' - 1000' from NE corner S.27 feet distance = 100' feet ~746 11~679 and 9564' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 375' feetTVD Maximum hole angle 23.~ Maximum surface 2000 psig At total depth CVD) 6256 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight GCade Coupling Length MD TVD MD TVD (include stage data) 17-1/2" I~-~/R" ~.~ K-~ RTe I~RR~ ~ n ~1 1~1 12-1/4" 9-5/8" 43.5&47 1_-80 LTC 5888~ O O ~88R~ 8-1/2" 7" 26 & 32 L-80& LTC 6040' ~5588' ~5224'~11628' ~10~56' 2050~X "G" + additiv~ P-110 *This is an approximate de~th. A(~tual depth will be determ'ned b~ first d~ll bit be ow 5500' TVD. .. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet ~/~ ~/~ Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner ~ ~- .~.,.." ~ .,?... Perforation depth: measured ~3Zk~ 0~ ~. ~as ~,~..~,,,..~., true vertical .... 20. Attachments Filing fee~ Property plat ~ BOP Sketch ~ Diverter Sketch Drilling fluid program/ ~me vs depth plot ~ Refraction analysis ~ Seabed report 21.1hereby certify t~~fOregOing is true and correct to the best of my knowledge Signed ~~jL ~ ~~~ Title Division 0per at ions Manager Date Commission Use Only Permit Number I API number , Appr~l~/88 See cover letter ~¢-¢ GI 50--7~'- ~O~9~] for other requirements Conditions of approval Samples required ~ Yes ~ No Mud log required ~ Yes '~' No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes C No Required working pEessure for~~ ~2M; _~ 3M; ~ SM; ~ 10M; ~ 15M Other:(~~( ~~ ~/~~'//~ ~~_ by order of Approved by Commissioner the commission Dar Form 10-401 Rev. 12-1-85SBB Submit i ~ triplicate DRILLING PROGRAM MIDDLE GROUND SHOAL C22-23 1. Rig up. 2. Drill out 24" casing shoe w/17-1/2" bit. Continue drilling to 375'. 3. Kick off at 375' and directionally drill to tq-32' MD using 17-1/2" bit. 4. Run and cement 13-3/8", 54.5#, K-55, BTC casing. 5. Nipple up BOP stack. Test all connections, valves, and rams to 3000 psi. Test annular preventer to 2500 psi. Test all kelly, stand pipe, and emergency valves to 3000 psi. Test casing to 1500 psi. All tests performed in accordance with AOGCC regulations. 6. Drill out 10' and perform leak off test. 7. Directionally drill 12-1/4" hole to 9-5/8" casing point. Run wireline logs. 8. Run and cement 9-5/8", 43.5 and 47#, L-80, LTC casing. 9. Nipple up BOP stack. Test all connections, valves, rams, kelly, standpipe and emergency valves to 5000 psi. Test annular preventer to 3500 psi. Test casing to 3000 psi. All tests performed in accordance with AOGCC regulations. 10. Drill out 10' and perform leak off test. 11. Directionally drill 8-1/2" hole to TD. Run wireline logs and casing caliper log. 12. Run and cement 7", 26#, L-80 and 32#, P-110, LTC liner. 13. Proceed with cased hole completion prognosis. SBBG/O202b RECOMMENDED MUD PROGRAM C22-23 Interval: 0 - -t-~433 ' 17-1/2" HOLE Mud Type: Spud Mud (water and gel). Generic mud #2 Recommended * Weight = 8.5 to 9.0 ppg Properties: * Funnel Viscosity = 40 to 50 sec/qt · Plastic Viscosity = 5 to 10 cp · Yield Point = 10 to 20 lb/lO0 sq ft · Fluid Loss = no control · pH = 9.0 to 9.5 Page 2 Interval: Mud Type: Recommended Properties: ~-~4-~3' to 5,888' 12-1/4" HOLE Water and gel. Disperse only if required. Generic mud #2. * Weight = 9.0 to 9.5 ppg (maintain minimum MW of 9.0 ppg in case of pressure from C 41-23 casing leak) * Funnel Viscosity = 36 to 42 sec/qt * Plastic Viscosity = 5 to 12 cp * Yield Point = 10 to 15 lb/lO0 sq ft *API Fluid Loss = 20 cc * pH = 8.5 to 9.5 * MBT = 15 to 25 I nterva 1: Mud Type: Recommended Properties: SBBG/O202b 8-1/2" HOLE 5,888' to 11,628' Poly acrylimide-poly acrylate with 1% NaC1. Generic mud #2. * Weight: 9.3 to 9.8 ppg, or as required to combat waterflood pressure * Salinity = 1% NaC1 * Funnel Viscosity = 40 to 45 sec/qt * Plastic Viscosity: 15-20 cp * Yield Point: 10-20 lb/lO0 sq ft *API Fluid Loss: 10 cc; 5 cc by HC * HTHP FL at 150°: less than 20 cc; 10 cc by HC * pH: 9.5 to 10.5 * MBT: 15-25 PLATFORM °C' SOLIDS CONTROL OPERATING MODE , DRILLING UNWEIGHTED MUD DRILLING WEIGHTED MUD TRIPPING BUILD SLUG GATES CLOSED D,E,G D, E, G E, F, C, G C, D, F MUD FLOW ROUTING 1-2-3-4-5 1-2-3-4-5 4-5-2-3 1-2-3-4 SOLIDS EQUIP. IN USE SS, 4' SS SS, 4' COMMENTS MAY WANT TO OPERATE 4' TURNED OFF w/WEIGHTED MUD , © · .l ~ JlJJ P. ,&Il DERRICK FLO-LINE I I TRW F~ BRANOT EGASSE B,~- ~ 0 SLUG PIT/ "'T '- - I I ~'~ SAND TRAP Legend TOP EQUALIZATION BOTTOM EQUALIZATION AGITATOR Page 4 CASING AND CEMENTING PROGRAM C22-23 1. Run 13-3/8", 54.5#, K-55, BTC from ~' to surface. Casing design criteria are attached. 2. Cement to surface using 20% excess on gaged hole volume from TD to conductor shoe. Lead with 340 sx Class "G" + 10% gel + 2% CaC12 + defoamer and friction reducer as required (12.8 ppg, 10.8 gal/sk, 1.94 cf/sk) followed by 200 sx Class "G" + 2% CaC12 + defoamer and friction reducer as required (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Perform top job within shoe of conductor. 3. Run 9-5/8", 43.5 and 47#, L-80, LTC from TD to surface. See attached casing design criteria. 4. Cement to 4,400' MD using 20% excess on caliper (preferably 4 arm caliper). Lead with an estimated 700 sx (20% excess on a 15" hole) Class "G" + 4% gel + additives for rheologies (14.2 ppg, 7.6 gal/sk, 1.52 cf/sk, 2,000+ psi ultimate compressive strength) followed by 200 sx Class "G" + additives for rheologies (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). 5. Run 7", 26 and 32#, L-80 and P-110, LTC from 11,628' to 5,588'. See attached casing design criteria. 6. Cement with Class "G" + 1% NaC1 + retarder + defoamer + fluid loss agent for WL less than 100 cc @ 150°F as required (15.6 ppg, 5.2 gal/sk, 1.18 cf/sk). Total thickening time between 3 and 4-1/2 hours brought up to temperature in 45 minutes. An estimated 2050 sx of cement will be required (15% excess on an 11" hole and 300' above liner top). SBBG/O202b PAGE 5 C22-23 CASING DESIGN Casing Design Criteria Frac Gradient Mud Gradient Max Collapse Pressure Max Burst Pressure 13-3/8" .67 .46 650 psi (Full evacuation) 850 psi (1/3 BHP @ 9-5/8" csg pt) 9-5/8" .70 .50 2800 psi (Full evacuation) 3500 psi (injection pressure) 7" (Liner) .78 .50 8000 psi (pressure from frac 3500 psi (injection pressure) jobs) Size 13-3/8" 9-5/8" Depth O- 1~b3-~' MD (O-b+O0' TVD) 0-4258' MD (0-4000' TVD) Grade/ Wei~ 54.5# K'55 BTC 43.5# L-80 LTC 4258'-5888' MD (4000'-5500' TVD) 47# L-80 LTC m, 5588' -8874 ' MD (5224'-8253' TVD) 26# L-80 LTC (8874'-11628' MD 32# P-110 (8253'-10956' TVD) LTC ACTUAL Tension # Wt in Mud DESIGN CONDITION 65,000 Collapse PSI 209,000 650 60,000 2050 141,000 28OO 74,000 4200 Burst PSI 85O 350O 3500 3500 35OO Tension(m) Casing Rating/Design Factors Collapse Burst 853/13.1 1130/t-F-7-4- 2730/3.21 1005/4.81 3810/1.86 633.02[~1.81 1086/18.1 4750/1.70 6870/1.96 604/4.28 5410/1.29 7240/2.07 8000 745/10.1 10760/1.35 12460/3.56 SBBG/O202b ATTACHMENT The maximum pressure gradient is expected to be .571 psi/ft. Maximum BHP is expected to be .571 x 10956 = 6256 psi. Maximum surface pressure is expected to be 2,003 psi, assuming a full column of .360 psi/ft oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations issued April 2, 1986. As noted in the drawing of the diverter, both 10" mechanical valves will be kept in an open position until the preventer is closed. The mechanical valves will be wired open and tagged with instructions concerning proper procedures for closing a valve in the event that the preventer is closed. SBBG/O202b WELL: C 22-23 ALASKA DIVISION DRILLING PROGNOSIS 2/11/88 LOCATION' PLATFORM 'C', LEG 2, CONDUCTOR 9 OBJECTIVE' DOWNTHROWN BLOCK OF HEMLOCK EVALUATION GEOLOGY SWEPI INTEREST: 100% AFE NO: 262381 FIELD: MGS EST, ELEVATION: 105' (:MEAN LOW LOW TIDE: DRILLING 73') CORES IJJ ELEC. MUD SIGNIFICANT SURVEYS LOGGER FORMATIONS -~<E 7500' LU (.9 (D O 24' Conductor 370' 13-3/8' Casing 9-5/8'Casing 5500' FL 6861' GB 7431' HC 8545' HZ 9495' 7' Liner{TD) 10956' WELL CASING DEPTH AND TVD MD CEMENT 370 t~$o ,-I 5888' 7366' 7985' o 9174' ! 10138' . 11628' ~1 HOLE DEV. HOLE AND DIR. SIZE CONTROL MUD PROGRA~ 17-1/2' o 12-1/4' 8-1/2' .g CQ O m OLL m OO .. .' i i Magnetic Declination=23.7oC23O42') Grid Correction =1.3°[ ' ' .. Net Magnetic Surve~yo ...... Corlection =25.0 C25 ............. SECTION. ' ' ' KOp '375'TVD ..... 'I.;'. PLAN VIEW ....... SCALE: 1'=1000' ; ~ . ~.' ~.[ ! ALL TARGETS 50' X' ~ - ~ ; 150' OR ENTED N-S ~TD .... . , z il;;.. . I . ·.. 1112/87 · , 1'1 i' J!l ' ',,'' t · · , ............... 41., . I,l;,,.;~ , .;,,. ~ ! i ~TARGET ~2 150 X 50 9495TVD 10138'MD ] : ...... ; i i. ~TARGET ~3 150' X 50' 9945'TVg 10596'MD' i I i ! ; ''T '''?~ '' ' ~' ;'i:'~f. ,I ; , ; : . , ;~TARGET ~4 150 X 50 10760 TVD 11428 MD ' ~"~-T-..TD 10956'TVD 11628'MD _~ ............. I ~ '/ 'iii ....... . ' i :..~ .... ~.l:; ;.. :+~il,,~i I i; ' . , MGS C 22-23 . ii' '1/2' HOLE 2000'PSI S~' OK ~oP OF KELLY BUS.~NO I · i i i ~"" ,..: TOP OF DERRICK FLOOR ~ ' j-. BOTTOM OF ROT A"RY BE~M DRILL NIPPLE r FLOW LINE FILL, UP LINE ~ ANNULAR I,, PREVENTER .. ] ~[~ ;//~20' 2000 PSI FLANGE ~p c:~a/ /---TO BE CONNECTED SO THAT VALVE IS , ~ J / iO.~PEN WHEN THE ANNULAR PREVENTER ~ /IS CLOSED. BOTH 10' MECHANICAL VALVES WILL BE IN AN OPEN POSITION, UPON CLOSING THE ANNULAR PREVENTER THE PROPER DIVERTER LINE IS SELECTED. MAIN DECK 20' 2000 PSI RISER WELLHEAD ROOM FLOOR i iiii i ii 9/10/87 N.T.S. 1.2.-1/4" HOLE ,3000 PS1 STAOK OF' KELLY BU,~HINO BO'ilOM OF ROIAR~ BEAM DRILL [' NIPPLE , FLOW LINE I FILL UP LI~E ANNULAR f --~ ~/8' 5000 PSI FLANGE PIPE RAM 5000 PSI . T~P OF 6000 .... DECK 6000 PSI RISER 8POOL ....... , , mia i i . 9/10/87 13-3/8 SOW X 3000PSI HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 1/2' GAP BETWEEN FLANGES MGS C ,22-23 ( cJ-1/2' HOLE 5000 PS(~ 3TACK tOP OF KELLY BUSHING ' '~ ~LOOFI ........... 'TOP ~F DERRIC II I I I I I I -- I BOTTOM OF ROTARY BEAM · ~' .... ~ i_ ' DRILL NIPPLE FLOW LINE FILL UP LINE~ I" ANNULAR [/1 PR5E0~EoNpT E R ~ ~ANGE 13~~-5/8' 5000 TOP .OF SUBBASE / ./. / / ._JPSI FLANGE 2-1/16.,' KILL INE SPOOL MAIN DECK 5000 PSI RISER ...... . 13-5/8' 5000 PSI FLANGE f I1' 5000 PSI FLANGE j 'AP' SP60L .... ~ .... -'~:~ 13-5/a" 3000 PSI FLANGE .__m_~CASINGI'''-I rn ~ m I-- I --I HEAD F I -~' ~ooo WELLHEAD ROOM FLOOR ~ : 9/10/87 13-3/8' SOW X 13-5/8' 3000 PSI 'WF' HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 1/2' GAP BETWEEN FLANGES I I I I II I II I SH~LL HI#IWI~M BOP i ~l~i~ 7" i Afl'~l~ Pte~fl~t '" , ii iiii i i ,, Two title 0t ~ ~BI hydtUlllCllly i i I O.l'~i~ t~l wH~ 2" ~ ~" rain, i Gs~ vBI~' P~r Oprll~ ~ 1/8" ' Ltm to ~oke m~ifol~ " 3" ~ i i i C~ Vllve 2. f/16" b~;~'s~t .... m i i ViTro Ol~ 1.13/Ir C~o~ p~,~m vM~ 1:.13/1'9" ' ' Kill li~ to,fig ~.mP ~t~Md' ' 2" 2" X 2" X 2" i ~ i iii AIMIINmM .~eelflee~lewl lee AirfOil leevlel let ~ In SNell Mil Cem~'e! ¥11~11, AI)BlalIll ~,I~. OPTIONAl. I 2 Wely,,fll~ (~ bOrl. I~, OtlCtOr 19 Gene vllv~ i 20 Line To mKl~ld, eoflnec~lofl 2" i i 21 i~otetl~l blowout p~efller ' ' i I i i ii I ~e 22 Gste vllvw p~r ~rltff DRAWING & CHECK LIST 104A. SHELL CLASS SM ~URFACE INSTALLATIONS NORMAL AIR/GASe CONFIGURATION A ANN~IiAR PRLfVLINTIR It. mO RAm RAM : OPTI'C)NAL AUXILIARY EOUII~ilI~! ......... ] "~p Or ,~ ~ BOP t~le, With I~ ~lls _, _ ~HELL MINIM~ HYDRAULIC MERATING UNIt ~PECIFICATi(~S ' " i ~1 ii Lines from ol~r~i~ unit lo BOP units 6.0CX) psi Minimum Yield ID Seimleu flexi li~ .~" minimum I.D. ~ ~mless ~I li~ ~ ~i~ ~ Ho~ ~r ~ction 4.32 ~1 ~ntr~s ~lll ~ dearly ml~ed Io ~ unit ~rlled. Blind Iltch ~ d, Sufficient bottled nitrogen or c)thu hick-up st~ slalom Io equi! m:c~mu~tc~r .pecity, m~,~ilcdded to by-plm ~ccu~lltor Ired dose BOP directly. . or vista! indic:Btm lo ShDw when Iccumulmor is shut SHELL MINIMLI~ MUD sYsTEM Flc~ line monitor. JOPTIC)HAL MUD SYSTEM Flow 'tine ps sep~'r~tm. MIS4~ELLANEC)US EOUIPM£NT PECIFICATIC)N$ AND INS:TALLATI0k IltSTIll)CTIC)NS I. All el)mX, Clio)rs ~nts ~ ~i~. 4.32 ~ ~ ~lt Well a 9J~ 1~ MINIMUM ~,,.,OKE MANIFOI. O ORAWtNG NO. 2029 ~.k CL~J ~. SRJRIffACE I~TALLA~ C,m C~eq~ 3",:r'~3"w~.. MtN. I.D. It~h! 3 t fir' IqtOMtNAL RATINO 3~ $.000 2.000 tO.O~O ,o/cmo tO.OeO EOUIPMENT SP~ClIelCATiON9 AM) INSTALLATION INST 1. Alt e~tl~ I~ e~oke m~lf~d ~MI ~ . ~ ~10~ 3. A11 ft,~ ~h~M ~u~fv ~hO,M. ~ ~ke~ ~MI ~ APl ~X M BX. ~' Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Harch 14, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir or Madam' SUBJECT- ADDITIONAL INFORMATION REQUESTED ON THE APPLICATION FOR PERMIT TO DRILL (APD) MIDDLE GROUND SHOAL WELL C22-23 In a recent conversation between M. Minder (AOGCC) and S. Brown (SWEPI) questions on the APD for MGS C22-23 were discussed. Shell Western's response to those questions follows' · In the unlikely event that H2S is encountered, we intend to comply with 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Su 1 fi de". · The proposed well path is such that it is within "close" proximity of existing wells (C32-23 and C24A-14). In order to prevent possible collisions, we have' a. Re-surveyed C32-23 and C24A-14 with a north seeking gyro; be calculated collision cones for existing wells within close proximity of proposed well (if the proposed well enters the collision cone, the existing well will be shut in and bled down ); Ce contracted an accoustical system that detects an increase in sound at the existing well generated while drilling the proposed well; and d. have a directional driller on-site. As requested, a more detailed spider diagram is enclo.~e~~.¥1~ SBBG/031488 3. We are currently preparing justification for setting surface casing shallower than that specified in Conservation Order #44, Rule 7. This will be discussed at the meeting scheduled for March 18, 1988, at 9'00 a.m. ,.. ..~ If you have any outstanding questions concerning the APD for the upcoming MGS well C22-23, please call Ms. Susan Brown at (.907)~263~9613. VerY truly, yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBB/kt Enclosures SBBG/031488 ADDRESS (Include city, state, zip) ...35-60 1130 oo22 o NOT VALI~) FOR MORE SSN/TIN _ ~ . ETA EMPLOYEE NO. _ ~ / Shell Western E&P Inc. .oust-oN. ~-x ,oo, ~-'s,~,~,~ ~u~ ,'O088qo"' ':~3000gOq': ,'O0~O~Bqq~58,' Page 5 · :?'"' ,luly 19, 1967 · .. '""'~::~'. . (a) The conversion to injection purposes of any well 'initially - completed either as a producer of oil or as a dry hole. drilling for injection purposes of a well or wells at '.,(' ' . , any locat'ion. ,,...~,,,:.,.~ ...... . .... ...., '. · -,:, .' .". C.. i'" ,.:.. . ' ', .... ...."' ','. '.".'".'..:'i "i."~"'..','~}i' '.'."'..:: ' " . . .';. ''..i... '.,' , -,,,,', , . , . · '.':~ ~, ~' ' .':~,,. ' i, , ' ','.'' '',' ,',, ' '' . ~ , ~ ' , '"'' , .... ::'.'.::?;,:'..' ,,,'..'/" '?' ,:~,','",:!,~,'/:, ~' .?(c) ':The conversion from injection purposes to producing status' ',~ -'<;'~'.i!~:;,}'~'':~''.' ~.:'~ .'¥ · ' : " ~,~'~" ' ,.., ",'..:',,'.~ ~..',:i". <~.?,:" "" : "?~..: .i . .' ' '.:" · ' i, .... '. '.' . ,: ' :'":.;' '~ ":. ~' ~" .~'( ' j!. ,'. q .';~ '. "~, ', v. 'I i"": ..... ' """ ' ~ .... '.';'..', "~' ,' ' :" ; .. i", .'' . ..' ' - , · ' ' '. ;" .' ' . , .'" ~...." .,. i,}.i.' ' ,. ,.,. ' '~' . ,,, ' , ',.. , ,:, ' · , ~ , ' . . ' . ' ' . , , . i. .~.,~;.:?..~c:.'! .,., :' !.~?':,:.,.;:~: (d) The drilling of add~tzonal wells, i.e. wells not otherwise '.,.,' ... 'i,:'i:~"'.";i.:;,?Ji,'. ·'. aUthorized by these Field Rules,· for producing purposes at any location. !:~!~.'.'. :'. ;. '.,., · , . ,, . ,! ..,', ~., . · . . . .~...,.': .:. :. · '.,:.:', ,. ,,,~ ',,.~,! ,! ',' ,: · ,, · . , ~' · ,. ' , . ?'.'i:'::i',.,'"' :.., ',:".' (e) The commingling in"the well bore. c~ fluid produced by a well .. i~...~.,.., , from any pool defined by Rule 2, with fluid produced by said well from ..... ~,, .'?""i? ": :'. ~':i!' :,'; ':' any other pool or pools defined by Rule 2. ' "·~'·.C,'.~"i !, , , ;. .. '...,' ', l., '. , .... ' ;' . · . . . ','/Ti:.,::~>.i';:L'.;'.~, ,,'.'"'.".' · :"~(f) The .commingling in' the well bore of fluid injected through "i'.~,"??'.??i?.~.}:!.';'..?;; .'a"well into any pool as defined by Rule 2 with fluid injected through !',if..i,,,?.';i:,!'i?.:ii";i:il,,~?.!" 'said~ well into iany other pool or pools as defined by Rule 2. ' ""'."': ':·ii:.".;.:','i:i".;':i";:',,~ -.:i,' :', ..,..,~.',:.".., '..,7,7.; ..... ..,...i,~..'.,, .'.?. .~..i ..~ .' .. - ' ~ .:,.:, ,:~ . i.,.~.,..~'..·'.? ,.,...'.'.;.,·,. :'.";..".;.~'....!';i.."..i;'" ..:i...'/"..'...": ..:; · · ,; .... . ," ' ' .... '· [- :.'"'.,,".' :' · . '~','. ':i '.".i" ,~."~.".;',!:".';"'..,:i....": ...?: '.'.' ,'..' ;' ' ...' . ;':;?"" .. ~' ~:'";;,::.' Rule .7~ Casin~' and 'cementin~ requirements "' ;'"': '· Surface casing must be set and cemented 'to a depth of at least'1600 feet. · ,,,' ~';.:.' Sufficient cement must be used to circulate to the surface. ~',.~.".iY.?i.!- '..,.~ .. ..,.,,, ~ .... . ....... . . : · · ' , ,"..'i'}"." '~.", ,~".', .:." ~;. ' ".""" '. ' ..... · '""',: '" ' '""'"" 'd · ' o · · ' .,;'-.".:,', '.'..:.',' ,....". The pro uct~on str~no must be cemented w~th a sufficient volume of cement to ':'*'.?~?!'}i;';~"..~'4i,." '? ".:' ' · ' ' . '?;k~?i'~,::i.';.' extend at least 500 feet above the shoe or a volume to cover the .uppermost pro- '~'~,~?'.'.!!!i;?',~i'.:.i'i~','ducing' zone 'encountered in the well, whichever is greater. . !i.~:..~:.?:~., ~,,...:..,., .. . ,.. ...... ....... .. . . , . · ,~,'~,~i"..'~":":' ".~.:.;; :: '~"!'.'.': .~.' '. ]".,:'. '.,.', ' ". ' ....' " '.' "' ' ' ' ·" ' ' ~....,~..~.~ ...., .., .:,....,. ..,: .~., . . . · .'. ~,~, ~ ,,,,~: ,~, · ,, . , . , , ;:i~!,.,.:"~:i'.'.'.i"."'.'"'Ru..le 8, Bottom.hole pressure surveys. ' . ~ ~.f,,.,~' :,.,..., - . , . . . . . ~?/'..."','.:'".;i'.:!,' ; .... ,: ,." . , ..~ ' . '. , . . ; '.~:'"';'" ' '' "':An annual key well bottom h°le pressure survey shall be made during the .'"i.i.",' months of January and February with the results to be reported to the Committee -- · ~;i'i' ' .: by the end of March each year, The operators ill the field, with approval of' · ::. the Committee, will determine the datum, the wells to be included, the method . ., ,...~ ',.~ :. ,~' . ":.,,;::.. to be used and the type of information to be secured. Bottom hole pressures ~-.. · V" ',,: ]' '"'-::?'-' obtained by a static build-up pressure survey, a 24 hour shut-in instantaneous , · . test or a multiple flow rate test will be acceptable for this purpose. Survey .. results will be reported on Form P-.12 or other appropriate means agreed to by '" the operators and the Committee. · ,. · · . .. · . , Ii " · .. ., _ · CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ' ee zlteh, 'rs (2 thru 8) 3., 4. .5. 6. 7. 8. (3) Admin ~ '~;I[8/,¢~,~:'.~ 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~.~.~4~. (14 thru 22) (23 thru 28) (6) OTHER (_r/.¢~,- '~/.(&.~%75 (29 thru'31) - (6) Add: Geology: Engineer lng: ,cs rev: 02/17/88 6.011 Company __~/7~.[! Lease & Well No. ,/'~ ..~ YES NO the permit fee attached .......................................... ~r- m REMARKS Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is"well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~L Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ ....... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons'. .................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31 32. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate//~f Are necessary diagrams and descriptions of diverter and BO~E attached.//¢¢ Does BOPE have sufficient pressure rating - Test to ~OOO/~ psig .. Does the choke manifold comply w/API RP-53 (May 84) ..... Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... ~;;;~''/t~ If an offshore loc., are survey results of seabed conditions Additional requirements ............................................. ,~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .5' ~ 4 r : ~,.~ , . p ~.-- u - I o/a ,~zo ,-- 0~¢'/--=- o ~z ~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ~: ...... S CHL U'~8 :E R GE R ..... ;',: L 1: S T A P 'E V~RZFiC~TIO,N L'ZST ZNG ,VP OIO.HOZ V~'~?=IC.aTICN LISr!NG PaSF 1 '"" REEL ~4EAO::? '"~- ERVICE Na'~E : EDI~' ,ATE :88/07/ 6 ,RZGZN : EEL N~ME ''72809 .DNTINU/~.TI gN ~ 'REVZOUS REEL 'D.~'!N:NTS :EDZT LES,SHELL W--s~r=2N "-S C2Z-23,~D~ .... ~, ',,.? ,~. 50-733-203:)7 ;ERViCE NA'aE :EDIT ~ATE :,9,8/07/ 6 IRZGZN :'7280 'APE NAME : ',ONTINUATION ~: : 'REVIOUS TAPE : 'DMMENTS :'EDIT LZS~SHELL ~ESTE:RN.~"S.., C";2-23,API,... 50-733-2039? :ILE NAME ':EDIT ;E.RV!CE 'NAME : rER.SION ~ : )ATE : ~A X I,."~U M LENGTH :ILE TYPE ' 'REV t~t'~ :"g l N F 0 R ?~. A T ! 0 N .031 R E C 0 R O S '~-":~ ~ N E, M C D N 'T =. N T S U N I T 'T Y P E 'C A 'T E S I Z E C O g E ~ ~._,..-~., ~ OOO 000 0!0 0:55 :N : MI'3~LE GROI,.J~'O SHOAL OOO 000 OZO 055 ~ A N G: ~ ] N W ~.~__~// 000 00 O 00 ~ 06 S FO~N: .... 000 000 004 055 ;ECT: Z3 000 000 002 065 ~OUN: ~K E~,IA ] 000 000 005 0,55 ;TAT: AL,~'S K, ~ OOO OOO 006 065 :TRY: US ~ 000 0 O0 004 0,55 ~NEM CONTENt'S IJN ['T TYPE CAT,... SIZ= CODE 'RES VP OlO.H02 VE.oI,~iC~,TISN LISTI",IG °A'SE 2 S CHLUMB_~P,G~' R ~'L:~SK& COMmUTiNG C~'MTER OMP,~NY = SHELL W~STERN ~. ~ P., iNC. 'ELL = ~GS C~2-2'~ :IELO = MIOOLS GROUND SHOAL ,OUNTY : K~N~I .T4TE = lOB NUMBER AT ~KCC'. 72909 .DP: RICK KRUWELL IUN '~I, DATE LOGGE3:20-APR-S8 '.UN .~2, ~4TE LOGGEO: 06-JUN-B~ IUN ! MUD IN~OP~.~T'ION: 'ASING D'RILL~R = 1~.375" 9 1710' - '~IT SI?-E = 12.25" 'TO 6047' 'Y'PE FLUID = ~2 ~ENSITY = 9,.5 L~/G R~ = T.11 ~ 57 OF rISCOS'IT~ : 40 S 'RMF ': 7.54 ~ 46 9~ 'H = 8.9 R~4C = 5.2~ 2 57 OF :LUIO LOSS = !4.2 C3 RM ~T BHT = '~.621 ~ '126 ~UN 2 MUD INCOqM~TION: · ASING O~RILLE'R = 9..525" B 6047' '- BIT SIZ= : 8.5" TO 102Z,2' 'YPE FLUID : mE )ENSITY = 12.Z LB/G RH I!SCOSTTY : 47 S RMF ~H : 9.8 R~C :LUID LOSS : 4.5 C~ R~ AT BHT : .9~ @ 65 D~ = .55 3 65 Dc : 2.02 @ 65 gF = .402 2 163 OF :LZC REM'~RKS: I.)FZL.= EDI".O01 C3N'T.aZNS 9~TA O~ C'H&SOR DUAL INDUCTION (.gTE), LONS 'SP~CCg SONIC (.LSS), LZTHO DENSITY LOG (.LgT)~ AND MICqOLOG (.~qLL) S~,~".PL_=g 2, .5' Z.)F]LE EgZ'T.OO2 CSNTAZNS OATA O= ;qZCROLOG DATA S~MPLE @.16666?' THIS D~T.a HAS BEEN .DEPTH SHIFTED TO PHASOR DUAL INDUC'TI'GN SCHLIJMBERGER LUGS .~NCLIJD..EO WITH THiS MAGN:ET~C TAPE: '~ :PH,~,S!]R DUAL iNDUCTION L~g (.gTE) · g...~Tfi 2VAZLASL.~: 1010~' T0 1712' ~ LONG S,~,~C~g, ~,_ SON~C,. ~ CG,~ C.L:SS) ~ D&T& ~V,~ZLA~L[: 10196" T0 1'712~ '"' L~'THO DENSITY LO,G (.LDT) .~ .Vp 919.HOZ VE,R'I=!C,~TI2N LISTI~IG m,~SE 4 )ATU~,,1 SP"'-'CZFZC~TIO'N '~.LgCKS ~NE,M S~ERVICE S"-P'VICE UNIT API API AP'I ~PZ =ILE SIZE SPL REPR ID QRD,:R ~ LOG TYP5 CL&SS ~O.'g ND. )EPT FT O0 000 O0 0 0 ~ E N S '~ T E t 6 O 0 53 '5 21 0 O 4 [FRE 9T'E HZ OD 000 O0 0 0 4 ; F L U D T rE 0 H "q M 0 O 22 'O O 1 [ L :D O T E '0 H ~"q M O 0 120 45 O 0 4 [LM OTE 9H~'~N O0 120 44 0 0 [DPH 9T~ OH~qM O0 000 ~0 0 0 [MPH 3T'E OHMM O0 000 ; R D T E G A "P ! 00 310 aRES UTE griMM O0 ~23 50 0 9 4 qT~EM gTE 2EGF O0 660 tT~N OT E t3 O0 O0 D gO 0 ;P gTE MV O0 010 O1 0 0 4 r ENS LS S LB 00 635 ,Zl 0 )TL LSS US/F O0 520 )T LSS US/F OO 520 30 0 0 ;R LS,S ,GAP~ 90 3~0 ~P LSS ~V O0 O~g ,IRES LSS OH~M O0 823 ~EO 0 0 4 4'T~N LSS O'EGF O0 ,560 50 0 0 ~T~N LSS L~ ,30 OOO O0 0 0 ) R H 0 L D'T 'G / C 3 0 '0 356 0 ] H 'O 8 L D'T '$ / C 3 00 350 02 0 0 )PH~ LDT DU O0 890 O0 0 0 )EF LDT O0 358 :ALZ LDT IN O0 280 .SHV LOT V O0 OOO O0 0 0 ;SHV LCT V 90 O0 O O0 0 0 }LS LOT O0 000 O0 0 0 PROCESS CODE (OCT,~L) 1 68 00000000000000 1 68 O0000OO000000O 1 68 OOO0000000000g I 68 O00000000gO000 1 ,58 O00000000OO00g I 6~ O0000000000OOO 1 6'~ 00000000000000 ! ,58 00000000000000 1 68 00000000000000 1. 68 O0000OO00DO000 1 68 O000000000000O I 68 00090000000000 1 68 O0000gO0000300 1 68 00000900000000 1 68 00000000000009 1 ,58 O00000000000OO 1 68 O'O0,O00000gO000 1 ,58 00000000000900 I ~8 00000000000000 I !58 OOO00000000000 1, 58 00000000000000 1 58 00000000000000 1 '58 00000000000000 1 63 00090000000009 1 68 00000000000000 ]. ,6~ O'OOOOOO00OO000 1 58 O0000OO0000000 1 ~8 00000000000000 1 68 O000000000000O .VP OIO.HO2 VE'PI~IC~,~ION LISTING )SS LOT ,R LgT 'ENS LDT ITEN LDT )RES LOT ITEM L£T .L LDT .U L DT .S LOT .~TH LET ;S1 LDT ;S2 LDT :ALS MLL ;R MLL FENS MLL ~RES ~LL 4T:EM MLL ~ T E N '4 L L ;P MLL O0 OOO JO. 0 :3 a ~ I 00 310 0 ! 0 L~ O0 63~ Z! 0 L.~ O0 oeo O0 0 OH'",M O0 823 50 0 ~EGF O0 660 '50 CPS O0 35¢ O1 0 ~PS O0 ~54 01 0 CPS 00 354 9! 0 CPS O0 35¢ 01 0 CpS O0 000 O0 0 r... 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