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.

1. WATER SHUTOFF & ZONE
TRANSFER IN CAMBAY #15
WELL
ADJEI STEPHEN
MTECH PETROLEUM ENG
INDIAN SCHOOL OF MINES
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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
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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
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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
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5. CAUSES OF EXCESS WATER
PRODUCTION
 CONING OR
CUSPING
 CHANNELING
 VISCOUR FINGERING
 WATER
ENCROACHMENT
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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
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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)
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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
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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
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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
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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
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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
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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)
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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
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15. Thank You!
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