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8/20/2019 cementing pratices for thermal wells.pdf
http://slidepdf.com/reader/full/cementing-pratices-for-thermal-wellspdf 1/5
Jc PTbr o
3 3
C e m e n t i n ~ g Practices for Thermal Wells
By R
W.
POLLOCW ,
W.
H BEECROFT*
and
L. G, CARTER*
(17th
Annual
TechnicaL
Meet ing, The
Pet rn[eum SfJciety
oj
C.L.U_. Edmontoll,
May,
19(6)
ABSTRACT
The
introduction
of steam
as a
means of stimulation
fo r oil
production has
p re sent ed many problems in oil
u ell cOffi ll letions.
Some
of
th e
difficulties
experienced
haH
been
c a s i n ~ failures. pipe g rowth , c emen t f ail ur e
and cem ent
bond breakdown.
Data are presented
on
cementing compositions and cas
ing e m e n t i n ~ techniques which maJ help
build
a
sound
steam
injectIon
well
or one
which
can
w iths tan d th e
stresses and
strains
of
intermittent
steam injection
and
production.
INTRODUCTION
P
RODUCTION of low-gravity, high-viscosity
c.rude
oil has
been increa:;ed in recent
years by
o w n ~
hole electric heaters, in-. : itu combustion and s team sti
mulation 1 . Of these
methods,
steam stimulation ap
pears
to
be the most
promising
and
is
being used
by
many producers
in
th e
oil field::; of \Vestern Canada.
Steam
injection, b) either of two systems, has become
a
complex
problem.
The
displacement or
flood
tech
nique is
considered
to be less troublesome once
the
field has been
prepared
for it, bu t
th e
necessary flow
line ';
and
permanent
stearn
generating equipment
makes
the
initial expem;e
very
high,
Most
of the Ca
nadian pl oducers have utilized
the
second
steam
stimu
lation
tec.hnique, that of
intermittent
steam injection
,. ith portable equipment - or, as
it
is
more
com
monly
called,
Huff and Puff. Although this
second
approach is
less
costly
than
the
use
of the permanent
generating
station,
most of
th e
problems inherent
with s team stimula tion
s ti ll exist .
The most common
problems em:ountered
are
those
of ca sing failure
and/Ol-
cement
failure_
As long as
steam
injection
t empera tu res remain below 400
c
F,
these
problems
seem to be
at
a minimum; however, as
injection p r e s s u r e ~
increase,
,,:ith
th e
corresponding
i n c r e a ~ e in temperature, the quality of the
casing,
cement and cemen t placement
become
important
fac
tors
in
th e
success or
failure
of
the
treatment.
1\iost of
the Huff and Puff
projects in Canada
to
date have been
in
th e temperature range of 550
c
to
620
F
(1,200
to 1.800 psi),
although equipment
is
available to
raise
these conditions
to 670
c
F and 2,500
psi, respectively. Many treating f ail ures have been
reported at the
lo, ·e r treating levels and many more
failures
are expected to occur when
the equipment is
u ti li zed to
th e
maximum extent.
The four
main
causes of well treatment
failure
have apparent ly
been:
I . -Cement deterioration
because
of the
strength
re
trogl e8sioll and permeabil ity increm;e of conven
t ional cements
used
in
the past.
·:fHuU1 bu.l tOfZ Oi l
Tf ell
Ceil/cnti11Y Co_ Ltd_ Edmon-
tun Alta.
r.: :f[{alllfmrfoll COlnlJany Duncan Oklahoma.
2.-8I eak-down
of cement
bond
to
formation and
pipe
becau::;e of
pipe
finish,
lack
of adequat e mud l'e
moval 01 surface ,
etability.
;3.-Poor placement techniques.
,L-Failure of casing and cement by overstre: ;Hing
during high temperature and preHsure steaming,
In this
paper.
we
will
attempt
to
suggest
placement
techniques
and
cementing materials
which
will tend
to minimize
th e
chance
of failure.
GENERAL
PROPERTIES
OF i\:IATERIALS
Laboratory
illYestigations conducted thl oughouL the
.rears
have studied the effect of heat on cementing
compositions.
has been reported that, above 230
c
F,
there
s
a
pronounced decrease
in c o m p r e s ~ ; i \ e
strength
and inc rease in
the p e l m e b i l i t ~ r
of man.\' commonly
llsed eementing m ~ l t e r j a ] s (2, 3). Additives
which
are
not chemically reactive with
th e
cement and which
re
quire a high water to cement. ratio
produce
a
cement
of
POOl
temperature
stabil ity. Bentoni te
is
probably
the
wors t o ffender
and should no t
be
u ~ e d
in any
composition
in
excess
of 4 per cent by weight of the
cement.
The
limitation of
Portland cements
at ele atec\
t emperatures has
been
stressed
in many
p r e v i o u ~
pa
penL The advantages of silica flour as a . -itabilizing
additive at t he se elevated
temperatures
have been
eva luated with a
variety
of cementIng
c o m p o ~ i t i o n
l2, 3, 4. 5, 6, 7, 8) _ The l'esLlltg of
th e
tests indicate
that
a
maximum of
60
per cent or
a minimum
of
80
pel' cent gilica flour by weight of the cement was re
quired
t.o
obtain
temperature
stability.
The
most com
mon quantity being used at the
p resent t ime 40
pe r cent_
Table
I presents t h t ~ slurry p rope rtie s of
compositions
having application in thermal p r o j e c t ~
Table
II
indicates the
effects
of temperature upon
th e
compressive
strength of the set materiaL
Cemellting
blends being used in thermal projects,
where
strength
retrogression is
critical, are discl1s.5iefl
in detail below_
L-Blends of API Class B eement with 30-40
PCI
cent
silica flour are designed to ha\ e
a slurry densit.y
of 15.7 to 15_9
pounds
per
gallon
and
may
be
accelerat
eeL
retarded
or densified to
achieve
the desired place
ment
and drill-out time. They
develop
excellent
strength.5i with respect to
compression and
shear
bond
ing_ They
can
be anticipated 1.0 have good tempera
ture
stabilitJ
r
to
460
c
F or higher_
2.-Pozzolan cements,
consi st ing of 0.5
cubic foot
of API Cla::;s B cement with 0.5 cubic foot of pozzolan.
30-40 per cent silica flour and 0-2 per cent bentoni te
by weight of the
pozzolan
cement mixture,
are
used.
Pozzolan cements
normal ly can
be mixed at slurry
densities of 14.5 to 15.3
pounds
pe r
gallon and call
a lso be accelel a ted, retarded or densified aH
th e
paL'-
ticular well condition8
require.
Pozzolan
cements
de-
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.1
T BLE
I
SLURRY PROPERTIES OF S IL IC A F LO UR CEMENT
Per Cent
Water Ratio Slurr Volume
Slurry
Wefght
Cement
Silica Flour gal./sack
cubic foot/sack
pounds/gallon
API Class B.
30
5.5
1.34 15.9
40 6.1 1.48
15.7
50 50 Class B - Pozzolan
..
30 4.3
1.16
15.2
40
4.5
1.23
15.3
Calcium Aluminate -
40
5.88
1.45
15.8
T BLE
COMPRESSIVE STRENGTH OF CEMENTING COMPOSITIONS
Strength
-
psi
80 F
Days
Cured 1 Then Heated 7 Days
PeT Cent
Cement
Silica
Fluur
8O F WO F
400 F
500 F
600 F
Class B
. . . .
30
1400
1985
6600
4450
2600
Class B
40
1215
W
6550 6300 5020
1:
1 C lass B - Pozzolan
..
_. 30 560 1225
4200 4850
6000
1:
1 C lass B - Pozwlan.
40
775
[240
3400
4200
5850
Calcium Aluminate ..
40
2900 3700 620
[230
1575
velop excellent shear bond with the pipe.
They
ar e
slower
than Clas s B silica f lour cements
in
develop
ing
compressive strength, bu t are temperature stable
to
600 F
or
higher.
3.-Calcium
Aluminate
cement a
refractory cement
used
with
or
without
silica flour, is
particularly
suit
able
for
use
in
wells
where
temperatures ar e expected
to
exceed
700°F.
It s
temperature stability
is
in
excess
of
2 OOO°F. Calcium
Aluminate
cement
,ith
30-50
pe r cent silica
flour
is
mixed at
slurry densities of
14.7 to 15.8 pounds pe r gallon and develops good com
pressive
strength
and bonding properties. t
can be
accelerated or
retarded,
bu t i s s om et im es
variable
in
it s
performance
and
s hou ld be
tested
in
the labora
tory
prior to use.
4.-Salt
cements
containing
10 to 18
per
cent salt
by
weigh t o f the mixing
water to
both
Class Band
pozzolan
cement mixtures,
have been very
successful
in increasing
the
expansion of
th e
se t cement to im
prove the bonding properties
to
the casing and for
mation both before and after
steaming
(0).
Other
materials
ar e available to
increase
th e expansion of
the
cement bu t
these show little advantage
over
salt
and ar e
general ly more
expensive.
In
addition
to compressive
strength
and permeabili
ty
other
factors
attributing
to the
success
or fai lu re
of a thermal cement ar e the
bonding properties
of
the cement and
a
proper cementing
t ec hn iq ue . C e
ment slurries, when cur ed in
a
moist atmosphere,
ex
hibit
expansion upon setting.
Under these curing
con
ditions pozzolan cements produce
greater
expansion
than do Cla ss B c em en ts .
Further expansion
is exhi
bited
by th e
addition of salt to
these
fresh-water
slurries.
This
aids in
th e development of bonding
strength
bo th to
the
pipe and to th e forma ti on . The
use
of an expansive cement can int en si fy the ini ti al
bonding
strength
of
th e s et cement.
Sodium
chloride
added
to one of
the basic cementing
compositions
in
concentrations of
from
10 to 18 per cent by
weight
of
Technology, July-Sepf en1ber
1966, Montreal
t he miX in g water, will p ro du ce a cement
which
exhi
bits
a
linear
expansion of as much as 0.17 per cent.
I n s team injection wells where high-level
stresses
ar e
built up in the pipe
and
th e c emen t s he at h, t he h igh
est
pO::isible b on d b et we en
the pipe
and cement
and
the
cement
and
formation
is necessary_ Failure of the
b on d c an allow fluid communication and possible pipe
grm\ th
the ultimate being p ipe failure
by
buckling
or
telescoping
(10).
The
pipe finish
and surface condition of the
pipe
and
the formation
have a
profound
effect on the de
ve[opment of bond strength (11) . Fai[ure of th e bond
can
be minimized
by
proper mud
removal
with
th e
cement or
preferably
by a c he mic al
wash
ahead of th e
cement
slurry.
The chemical washes should
contain
a good mud
thinner and
a surfactant
which
is a
,vater
wetting agenL
These washes
normally
water based
are
easily pu t
into
turbulence
and
do an effective job
of
sweeping the mud ahead of the cement
s lur ry. Be
cause o f the variat ion in the mud sys tems which ar e
used the
best
chemical
wash should be
selected
for
the
particular mud system.
Placement of
the cement
slurry in
turbulence
vill
further
assist in
mud
removal
resulting in
more
com
plete filling of
the
annular space with
cement
and
better bonding of cement to formation and pipe. The
addition
of
a
frict ion-reducing dispersant addit ive
assists
in producing a slurry to a ch ie ve this condi
tion
at
minimum pumping
rates.
ApPLICATION
OF LABORATORY AN D
TEST WELL DATA
Laboratory studies
have b ee n c on du ct ed to better
understand the various physical properties of cement
ing slurr ies for these
applications.
The coefficient of
thermal expansion
for cement
containing
40
per
cent
silica
flour
was found to be approximately 6.0 x 10 6
illches/inch/ F. The coefficient of thermal expansion
for
s te el will
vary slightly
over
different tempera
ture
ranges
for dif ferent
grades o f cas ing;
however
131
··
·
\ :
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Pigu l e
a
value
of
6.7 x
inches/inch/oF
ha d
been con
sidered as an
appropriate
value to use in making cai
c u l a t i o l l ~ o f e xp an si on d ue to
t em p er at ur e. T h e d if fe r
ence ill thermal
expansion
valueg, an d
th e earl.}r tem
p er at ur e g ra d ie n t
across
th e cem en t sheath
du e
to
relatively
low
heat conductivity, indicate
'I/hy
longi
tudinal compressive
stresses are created in th e c a ~ i n g
and buth radial
an d
l on g it u di n al t ens i le stresses in
th e c em en t
sheath
during
steaming.
The
heat transfer across
a
cement sheath
ha.::;
been
determined while
:;teaming
t hr ou gh e it he r casing or
tubing with
th e
annulus filled with an inert gas.
The
data indicate
that it
takes
about 8 hours for the ce
ment sheath
to
reach th e casing
temperature
while
steaming down 5 ~ ~ - i n . casing. This haE> been verified
in tw o test wells
and
is i n a gr ee me nt w ith
t he m et ho d
of calculation suggested by
Ramey
13). FiguTe 1
d ep ic ts t he temperature
gradient atrog::; A PI
Class
G
cement
Ia basic Portland
type)
containing 40 pe r
cent silica
flour while
i nj ec ti ng 6 0 0° F steam. On the
left is
th e
condition
f or s te am i ng
down
tubing
where
th e
low heat
t ra ns fe r r at e of t he a nn ul us
reduces the
actual
temperature a t the casing to about 200°F
below steam temperature in 1
hour
- t hi s g ra du al ly
increases to
100°F
after
24
hours. Th e curves on
th e
right indicate t he t em pe ra tu re g ra di en t
after
~ t m
injectiun through th e
casing,
132
The effect of pressure
an d
temperature ha s alfl'l
b ee n e va lu at ed in
a well
ce me nted t o
s ur fa ce . T hi s
showed
that
an
increase in either pressure
or
tempe
rature
inside
th e c as in g r es ul te d in a corresponding
i n c r e a ~ e in
th e
radial
an d
l on gi tu di na l e xp an si on o f
the
casing.
The amount
of
r ad ia l c as in g
expansion
caused
by
an
increase in
e i th e r p r es s ur e
Equation
o r t em pe ra tu re
Equation
2) inside th e
casing for
5:, S.-.
7- an d 8 r } ~ - i n . c as in g w ei gh in g 15.5 , 26.0
an d
36.0
Ib:i./fL
respectively, are
shown
in igltre 2
an d
i[lw e
l
At
th e
present time, th e following equations appeal
to be
appropriate
f or c al cu la ti ng
th e
radial
casing
c h an g e c r ea te d by t em p er at ur e o r pressure.
However.
these
calculations
a isume that t he ca si ng is
not sup
ported on the
outside
by
cement.
P
E
, , , - 1 - - -2 -)
-'fl,,,,, \
(2,
To calculate
th e
p r e S ~ l l r e
equivalent in sid e t he
cas
in g to
r:reate equal
lateral ~ t r e s . s
du e
to
a
thermal
change,
Equation 1 is
equated to Equation
2 Lo de
r iv e E q ua ti on 3
when
th e ca:)ing is
no t
supported al l
th e out iide by cement.
Preliminary
labol atory cbta indicale that th e
of thick-shell stress equations
foL
both
th e ca::;ing
and
t he c em en t sheath ca n
be
uti li ze d to
calculate
stress
conditions
in the cement due to differentials, or to
calculate:
maximum
pressure
or
t em p er at ur e w it hi n
the
limits
of
th e
s t r c s ~
capability of the
cement.
T h i ~
information. ho we ve r, h as n ot ye t been fulb
r
developed
to d e ~ i g n statu:;, an d
there
still rem ains the
difficult
evaluation
of th e ef fect of Lhe formation a.s a sup
portilLg cement for
th e
cement sheath.
Laboratory
tests
on casing supported by only
sheath
of cement
sho\'\:ed good
con elation b e t w e ~
th e calculated and actual t es t t em p er at ur e required
to crack
th e
cement ~ h e a t h both ra dia lly and
longitu
dinally.
\Vhen a similar
specimen was tested
with
th e cement
being
supported by
steel
ea. ing to simu
late formation bac.k-up, th e cement sheath di d
no t
crack at h i gh e r t e m pe r at u re
differentials,
which
in a gree me nt w ith
c a l c u l a t i o l l ~ .
Therefore.,
in
cement-
The Journal of C a na d io n P et ro le um
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ing wells fo r steaming i t is very important to remove
the
dri ll ing mud from th e annulus so
that
the
cement
ca n
be
supported by the form ation to help
prevent
damage to either
th e cas ing or
cement.
Prior
to cementing a well
for
thermal use,
the
bore
hole should be calipered
to
determine
if
the hole is in
gauge or
if
washouts exist. Thorough mud removal
f rom these areas is necessary to help prevent prema
ture cement and casing failure. Where excessive
washed-out areas have
been
encountered during dril
ling,
it
is
advisable to
repair these zones by plugging
with a temperature-stable
cement
before
further
dril
ling. Once the cement
has
set,
drilling
can be resumed,
leading to
improved
support of
the
cement
sheath in
a section of the hole where
mud
removal would have
been difficult
during
th e primary job.
RECOMMENDATIONS
A typical new
Canadian well should be cemented in
the
following manner
fo r
use as a steam injection
well:
SU1 jace ca sing
-
Either
9 -in_
casing
in a 12IA,-in.
hole
or
1 0 ~ 4 i n
casing
in
a 151,1.i,-in.
hole would be ce
mented
with Class
B cement containing
30-40 per
cent silica flour
and
0-3
pe r
cent calcium chloride.
P1·odiwtion
sing - Either 5lf2-in.
casing
in a
7Vg-in. hole or 7-in.
casing
in a 9-in. hole would be
cemented
with one
of the
following: l
Class B
cement
plus 40
per
cent silica f lour and 0.75
per cen t
friction-reducing additive; 2 1:1 Class B
cement
- pozzolan plus 30-,10 pe r
cent
silica fl ou r and 0.5
to 0.75 per cen t f ri ct ion reducer.
In o rde r
to
minimize possible failure during steam
ing,
th e
well should
be
thoroughly circulated bl ' th e
well operator
prior
to cementing.
A
chemical wash,
tailored for the
mud s:r stem in use, of at least 1,000
linear feet of
annulus should precede the
cementing
of
the production casing.
Recent ly, a modification to the above cementing
program
has
been
introduced
to
attempt
to minimize
cas ing and
cement failures by pre-stressing the
pro
duction casing.
The
primarJr casing,
which
might be 51J2-in. or 7
in. N-80 Grade material , is equipped with a Conven-
tional
multiple-stage co ll ar p laced at 150-300 ft_ off
bottom. The lower s tage o f casing is cemented with a
fast-setting,
temperature-stable
cement.
When this
cement has developed
sufficient
tensile
strength to
res train the
casing while th e pre-stl-essing is
carried
out, the operator mechanically stresses th e
pipe
in
t ension unt il it has reached a condition calculated
to provide opt imum protect ion
for
th e anticipated
temperature and pressure conditions which will de
velop
during
steaming
operations.
Stress
is
held
while
the second stage of cement is placed
through
th e
stage collar. Tension is maintained
until
th e cement
has se t
long
enough to attain sufficient
strength
and
bond to hold tb e pipe under th e stressed
condition
when forces
are
released at surface. In
this
case,
the
upper stage
is
brought to surface
using a
temperature
stable
cement.
Table II I indicates
th e
elongation
of
tubing
or casing
due to temperature
change.
This
anticipated e longat ion is used in
calculating
the stress
applied to th e cas ing
prior
to
cementing
th e final
stage.
For reconditioning old wells in an exis ti ng s te am
drive, additional considerations fo r
cementing
a fun
string inside the original string ( th e mos t common
method of repai r) are: (1) to
determine an
accurate
bottom-hole
temperature to
attain
sufficient slurry
pumping t ime; 2 sandblasting
of
the inner
string
and
scraping or scratching
of
the inner surface of th e
outside string f01 better bond;
and
(3 ) selection of
the new
casing
size
which
will allow about
-in.
or
more of cement sheath .
The recommended cementing
materials would be similar to tho se used on the pro
duction casing of
a new well.
Nm.·IENCLATURE
.6.R
dmr
Change
in
mean radius of steel,
inches.
Internal pressure at steel, psi.
r ~ m ~
I vlean
radius
of
steel.
inches.\'8 Poisson's
Ratio
for steel,
0.3
E
8
Tvlodulus
of
elasticity [or steel,
psi.
t
d
Steel wall thickness, inches.
lX,
Coefficient
of
expansion for steel,
inches/inchI F.
T
Temperature
change
at
steel
mean
radius,
OF.
...
Tr'I.BLE
ELONGATION DUE TO
TEMPERATURE CHANGE
Eloflga1ion oj Tubing or Casing due Temperature Clra lge
in of.
Length of
I
-
Pipe 50 ' 100°
150 200
250· 300
350 400
450
0
500
Feet
Inches
500 . . . . . . . . .. . 2.07
4.14 6.21 8.28 10.35
12042
14.·19
16.56
18.63
2070
-
1000.
-1.14
8.28 12 12
1656
20.70
24.84
28.98 33.12
37.26
41.40
1500. 6.21
12.42
18.63 24.84 31.05
37.26
43.47 49.68
55.89 62.10
-
2000 . .
8.28 16.56
24.84 33.12 41.40 49.68 57.96 66.24
74.52 82.80
2500
. . .
1035 20.70 31.05
-lIAO
51.75 62.10
72.45
82.80 93.15 103.50
3000 . . .
.. .
12.42 24.84 37.26
49.68 62.10
7<1.52
86.9·1 99.36 111.78 124.20
3500
. .
14.49 28.98 43.47 57.96 72.45
86.94
101.43 11592
130.41
144.90
4000
. .
16.56 33.12
49.68 66.24 82.80 99.36
11592
132.48
159.04 165.60
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TechnDIDgYr
July-September
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133
8/20/2019 cementing pratices for thermal wells.pdf
http://slidepdf.com/reader/full/cementing-pratices-for-thermal-wellspdf 5/5
ACKNOWLEDGMENT
BEECROFT
R. W. «(job) Pol lock
attended
the UniverSIty of Alberta.
graduating
in 1959
with
0 B.Sc, in petroleum
engineering.
~
wes emp loyed
by Halliburton
Oil Well Cementing
Ca.
Ltd.
dUring
the
summers
of 1956,
1957
and 1958, and began
permanent employmer:t with t he Hal li bu rt on
Compony
in
1959 as district enginee,r in
Estevan, Saskatchewan.
In O c t o ~
ber,
1965, he was transferred to Edmonton as district
engi
nee r. Mr . Pollock is a member of A.I.M.E an d the Association
o f Pro fes siona l Enginee rs o f A lber ta ,
7)
Ostroot, G.
lValTcn,
and Shryodc, Stanlel f, Cement
in g
Geothermal Steam 'Wells, Jaw . Pet.
Tech.
(Dec_, 1964),
p.
1425_
(S ,
lFalkc1 , TVayne
A
.• Cementing Compositions
for
Thermal Recovery Wel ls , ' Jaw . Pet. Tech. (Feb ..
1962), p_ 139_
9)
CU1·tC1·,
L. G., H ltg g 0 1 W/ , H. F .•
and Gcorge,
CIW-l lC8.
Expanding Cements for Primary
Cementing,
Jour. Pet. Tech.
i.\by
1966).
10) Humphrey,
H.
C
.• Casing
L ailures
Caused
by Thel'
mal
Expansion, World Oil (Nov.,
1960),
p
105.
l l Cartel , L.
G and
ElJall.<;.. G.
W .• A
Study
of
Ct
ment-Pipe Bonding; ' /010
Pf t. TI clt.
Feb, 19l j· l
p_
157_
12 )
Caill,
./ E Shryock. S and Cal lCl·. L. G_ Cc.
menting fo r S team Inj ec ti on \Vells
in
Cnlifamia.
J O/ I .
Pf:t
Tech. (April , HI6G).
13) Ramey,
H . ./
./1 .•
Wellbore
Heat Transmission.
.}ow·_
Pet.
Tech. (April.
1962), p.
127
Williom
(Bill)
Harvey Beecrof t graduated from the Univer
sity of
Alberta
in 1947 with a B.Sc in Arts an d SCIence.
After
working for two years in Eastern Canadian Pharrnaceutical
Laborator ies, he returned to Western
Canada
ond wos em
p l o ~ e d for over five y ~ a r s as a chemist with Chemica l
Geological
Laboratories. In
1956,
Mr. Beecroft Joined the
staff
of
the
Holliburton
Oil
Weir
Cementing
Co.
Ltd., and
he
is
presently employed by
tho t Company division chemi st.
Greg Corter
received his B.Sc, degree
chemlslry an d
mathematics
from Southeostern State
College
In
Durant, Okla·
homo, in
1954.
He held a teaching position for one year
prior
to
joining Halliburton
Company in
1955.
He
now serves
as
a
senior
chemist
in
th e
Research
and
DeveloDment
group
of the Cement Section, Chemica l Research an d ·Development
Department, of Hal liburton Company ,
REFERENCES
OweHS,
If .
D
.• and
SutCI ,
YaHI ;
E.,
Steam
Stimu
lation
- e w e ~ t Form
of Seconda ry Pet ro le um
Recovery, Th e Oi l
Ga s
Jonnral (4-26-65).
p 82_
LHdwig, N. C_. and Pence, S. A .•
Propert ies
of
Portland Cement
Pastes Cured
a t Elevated Tempe
ratures
and P re ssur es , Jou,rnal of American COH-
crete Institute (Feb., 1956). V-27. No.6 .
Ca,.ter. G1 Cg. and
SmitlL,
D. Ie, P r o p e r t i e ~ of Ce
menting COITIllOsitions a t
Elevated
Temperatures and
Pressures,
.}o/{I
Pe t, Tc ch.
(Feb.,
1957),
p.
20.
KaloHsck. G. L. , The
Reac-tions
of Cement Hydra
tion
a t Elevated
Temperatures. Paper
No. 11,
Thh d 11de1·nati-rrllal Symposillm 01 / Chemistry
of CI
1JIcnts, 1952.
Patchen, P. D .• Reaction and P rope rt ie s of Silic.a _
Port land
Cement i\'1ixtures
Cured
a t Elevated Tern.
pcratures, Jour. P et. Tech.
(Nov.,
1960), p. 281.
O ~ t . o o t G. Wa n cli . and
Walker,
Wayne
A
hIm.
proved Composit ions
f or Cemen ti ng \Vells with
treme
Tempera tures : ' .low·.
P( t.
Tl ch. (Mar.,
1961),
p_
1425_
(
I)
(3 )
(2 )
(6 )
5
(4)
CONCLUSIONS
There is
more thought
and
planning
being put into
drilling
and completing an
oil well
which
is a steam
injection candidate than there ,vas a year
ago.
Good
dri ll ing and
cementing
practices. an anly.si ; of the
weight
and
grade of casing
t h ~ l t should be
used, pro
per join t
selection
and
th e
usage of new methods of
inject ing steam
into
th e
wells is prevalent.
Prope l' selec tion by
the
veil
operator
of a cement
in g c o m p o ~ i t i o n
to
perform
sui tably under
the
condi
t ions anticipated is necessary. Don't expect the cement
to perform
miracles.
t
has
limitations,
just as
casing
has.
and should be
used
,
r ithin i ts
limitations. Labora
tory
work is currently being done to more thoroughly
def ine these limi ta tions and
to
obtain
more
complete
data. thus permitting the
better
adaptation of cement
to it s ta3k.
Employ
th e
best
po.ssible cementing
practices.
tak
ing :ldvantage of additives and techniques which will
benef it the
placemp.nt and distribution of the cement.
Bottom plugs,
chemical
·ashes. movement of the
casing. excess
cement and
good
annular
space clear
ance
beh
een
the
casing and hole
are
factors
which
should not
be
overlooked.
The
authors wish to express their appreciation
tl l
the
Halliburton
Company
fo r granting permission to
prepare and publish this
paper_
Special t h a n k ~ are
also extended
to
those in
t he l aboratory and
field
whll
a s s i ~ t e d
in
it s prepi l.ration.