Water shut off ppt
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The Cambay #15 well has experienced 100% water cut due to excess water production. To address this, a squeeze cement job will be performed to seal off the existing open interval between 1400-1404.5m. Cement will be squeezed into this zone and the tubing shoe adjusted upwards to 1395m to perforate a new production zone higher in the formation, transferring production to upper sands with the aim of resuming oil production.
Water shut off ppt
- 1. WATER SHUTOFF & ZONE TRANSFER IN CAMBAY #15 WELL ADJEI STEPHEN MTECH PETROLEUM ENG INDIAN SCHOOL OF MINES 1
- 2. CAMBAY #15 WELL Well was drilled by Cardwell- IX rig. After cumulative oil production of 11853.03 MT on self, water shut off by cement squeeze was carried out in April 2006. After cumulative production of 40000MT again water shut off by polymer gel followed by cement squeeze was carried out and well was put on SRP mode in January 2012. After cumulative production of 42220 MT, well is not operating due to 100% water cut. Drilled Depth; 1502m F/collar 1448 m well type vertical Casing; Conductor- 9 5/’’, 600m, N-80 & J-55, 40 ppf. Cement rise up to surface Production- 5 ½ ‘’ shoe at 1470m N-80, 17ppf cement rise up to 960m F/collar - 1448m Wellbore clear; 1425m Interval open; 1400 – 1404.5m Tubing shoe; 1000.6m Last recorded reservoir pressure; 58.9 KSC at 1185m Last killed fluid; brine of sp. Gr 1.02 2
- 3. High Press Gas Gas Oil Water Oil 5 ½ ‘’Production Casing 9 5/8’’Conductor Casing 1400 – 1404.5m tubing Tubing shoe at 1000.6m c/rise to 960m 950m WELLBORE CLEAR AT 1425M c/rise to surface 3
- 4. PROBLEM STATEMENT & SOLUTION THERE IS 100% WATER CUT FROM THE CAMBAY #15 WELL TO CURB THIS, A SQUEEZE CEMENT JOB WILL BE CARRIED OUT IN THE OPEN INTERVAL AND & ZONE TRANSFERRED TO UPPER SANDS 4
- 5. CAUSES OF EXCESS WATER PRODUCTION CONING OR CUSPING CHANNELING VISCOUR FINGERING WATER ENCROACHMENT 5
- 6. WHY THE NEED TO CONTROL WATER PRODUCTION Corrosion of production facilities Huge costs incurred in treating produced water for disposal Reduction in production rate 6
- 7. NEED FOR WORKOVER workover refers to any remedial operation done on a well to restore, maintain or enhance the recovery from the well Completing for Production from a New Reservoir Equipment failure (pump failure) Wellbore problems ( sanding, formation damage, paraffin accumulation, water and gas coning) Mechanical problems (casing leaks, tubing leaks, cement failure) 7
- 8. SQUEEZE CEMENTING This refers to the process of injecting cement slurry into a zone for purposes such as To abandon a zone To shutoff water or gas coning To repair casing leaks Seal off lost circulation zones 8
- 9. PROCEEDIA FOR SQUEEZE JOB ON CAMBAY #15 1. Well volume was displaced with water and subdued/KILLED with brine of specific gravity 1.02 2. Christmas tree was then nippled down and BOP nippled up 3. Tubing was lowered from initial depth of 1000.6m to wellbore clear (1425m) to confirm the wellbore clear and reverse circulation of brine was carried out 9
- 10. 4. Tubing shoe (Tubing) was then adjusted up by 2m to 1423m 5. Injectivity test was conducted (liter per minute) injectivity test is conducted against the squeeze interval to determine if and at what rate below the fracture gradient, fluid can be placed against the formation. Other reasons; • To ensure that the perforations are open and ready to accept fluids. • To obtain an estimate of proper cement slurry injection rate • To estimate the pressure at which the squeeze job will be performed • To estimate amount of slurry to be used 10
- 11. PUMPING SLURRY 5. Cement slurry was then squeezed into the existing interval and cement top kept at 1380m 6. Tubing was pulled out AND waiting on cement was done for 24hours 11
- 12. 7. TCR bit was then run on 2 3/8’’ drill pipe to tag cement top ,plug was then tested at 100 KSC, then drilled to 1390m and TCR bit pulled out 8. A scrapper was lowered to scrape the casing up to 1390m and well circulated with brine. Casing collar log was recorded for depth control 9. Cement plug was again drilled to 1395m and scrapping done again. TCR bit pulled out 12
- 13. HERMETICAL TESTING & RE-PERFORATION 11. Well was hermetically tested to check for leaks, brine weight increased from 1.02 sp GR to 1.03 sp GR 12. New interval was perforated at 1392- 1391m, 1390- 1388m,1386-1385m & 1381-1379m at 18 SPM (shots per meter) 13
- 14. 13. Tubing was returned with BB shoe up to 1364m. Injectivity test was carried out. Test was less than 250 LPM at 700 psi so a well stimulation job with mud acid was carried out. 14.BOP was nippled down and X-mas tree nippled up. Kill fluid was displaced with water Finally well was activated by air compressor 14
- 15. Thank You! 15