SPE-4030-PA Consideration on gravel packing
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7/25/2019 SPE-4030-PA Consideration on gravel packing
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onsiderations
in
Gravel
Pack
esign
R. J. Saucier,
SPE-AIME, Shell Oil Co.
Introduction
Gravel packs have been used extensively along the
Louisiana Gulf Coast in an effort to reduce or avoid
sand production from unconsolidated formations.
Statistics show,l however, that through 1966, gravel
packs were only about 70 percent successful.
The early literature on gravel pack design
is
based
primarily on the work of Coberly and Wagner2 and
of Hill.
3
Coberly's work in essence suggested that a
gravel pack having granular particles of diameter 10
times the formation grain size at the IO-percent
cqarse point on a cumulative sieve analysis would
provide effective sand control. Numerous failures of
this criterion were noted, especially in the Gulf Coast
sands. Hill suggested that the ratio of lObe reduced
to 8. Failures were still noted in many applications.
t least one writer suggested concentrating on the
fines end of a cumulative sieve analysis. Winter
bum
4
states that actual experience in the field has
shown that sand entry can virtually be eliminated by
the use of gravel which is approximately 10 times
the grain size of the 10 percentile of the finest sand
to be screened. Clearly a finer gravel will be more
effective in screening formation particles. However,
it must be evaluated in the light of how the finer
gravel affects permeability and reduces production.
Depending upon the writer, recommended ratios
of gravel to the IO-percent-coarse point may range
from 4 to 13. Other suggestions appear in the litera-
Some liberty is taken with Mantooth s statistics; nevertheless,
the
value
is
indicative of the problem.
ture; see, for example, the paper by Tausch and
Corl
ey 5
for a summary of earlier gravel pack in
vestigations.
In more recent literature, Sparlin6 has discussed
gravel placement rate and fluid viscosity in his recom
mendations for a slurry pack. Schwartz
7
recom
mends a size ratio of 6 at the 10-percent-coarse point
and at the 40-percent point for uniform and non
uniform sands, respectively. Williams
8
uses Schwartz's
grain-size ratio of 6 and finer and discusses well pro
ductivityas a function of perforation size and density.
In addition to the apparent disagreement on the
geometrical basis for gravel pack design, a more
subtle lack seems to exist. Few writers have explored
the influence of flow parameters on the functioning
of gravel packs. Sage and Lac
y
9
appear to be the first
authors who attempt to take hydrodynamic (and
other) factors into consideration. We supposed that
under certain conditions, hydrodynamic factors could
possibly outweigh geometric factors in the function
ing of gravel packs. This investigation, begun in 1967,
proceeds from that basic premise.
Laboratory
Test and Evaluation Program
A large number of variables are involved both di
rectly and indirectly in gravel pack behavior. Five
were considered to be most significant and funda
mental to the stUdy Therefore, the study was de
signed to explore the following functional depend
ence:
Tests with physical models have shown that sand production and pack impairment are
minimized when the ratio
of
pack median grain size to formation median grain size is
between 5 and 6. n a study of the inertia and viscosity effects of flow in gravel packed
wells it was found that increasing the size and the density
of
the perforations should
increase productivity
FEBRUARY, 1974 205
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DAMPER
Fig. l Luci te linear flow model and flow schematic.
T
'
,
7 '
CASING
206
INTENSIFIER
ELEVATION
' ' '--+-_+,-F OR.:..::M TI ON
PLAN
Fig. 2-Gravel pack model.
1)
where Y may be sand concentration, C or pack pres
sure drop,
D.p
and
t
= median formation grain size
d
p
= median pack grain size
w
= mass flow rate of fluid
.
w
=
time rate of change of w
P
g
= gas/liquid ratio
The median grain size of the formation, was
selected because in practice this value may be more
readily available than other extreme values e.g., 10-
percent-coarse fraction). The latter are subject to
sand sorting and hence not so readily estimated.
Two physical models were employed to evaluate
the influence of the selected variables on gravel pack
operation. A linear flow model of Lucite was de
signed to simulate a severe limiting case of sand
production through a packed perforated casing. This
model and flow schematic are shown in Fig.
1.
A
full-scale gravel pack model representing a section
of 7-in. casing, a packed perforation, and a forma
tion segment was used to verify the results from the
linear flow model. This model is shown in Fig. 2.
Fluids used in the tests were I-micron filtered de
ionized water and CO
2
to simulate gas evolution from
the liquid. The gravel was from commercial stocks
sieved to size and the formation sands were taken
from recent Miocene sands of the Brazos River. The
river sands were washed clean of clay particles as
well as particles 10 microns) and blended in appro
priate proportions to reflect typical formation-grain
size distributions.
The models were packed mechanically in small
I
85 9
Fig. 3-Concentration vs time-l inear model.
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increments, and the cells were tamped and tapped
until the material reached an apparent minimum vol
ume. During flow through the models, sand was col
lected from the gravel effluent over 5- to 10-minute
intervals, samples were weighed, and average sand
concentrations (C) were computed by weight. Flow
rates were 16 cc/sec
(r- 8.7
B/D/perforation or 26
cc/sec (r- 13.5 B/D/perforation).
Typical examples of test results are shown in Fig.
3 for the linear flow model with 3 in. of pack length.
Both a sharp increase and a sharp decrease in
flow
rate
(w)
caused a temporary increase in sand pro
duction.
I f
the rate was held uniform after the change,
the concentration of outflowing sand decreased con
tinuously.
Controlled surges in the flow were generated to
simulate artificial lift. Surge was on the order to 70
psi and noticeable increases in sand production were
observed; a tenfold increase for
F
p
= 6.7 and a
hundred-fold increase for
F
p
= 9.4.
Gas evolution from the flowing fluid had the most
significant effect on sand production. For F
p
=
6.7,
sand production increased about 60 times as a result
of gas evolution in the pack.
For F
p
= 9.4, gas evol
ution caused a 2,000-fold increase in sand produc
tion. I t was also noted that by reducing the fluid rate
and thus allowing the gas/liquid ratio
F9L
to become
very large, sand production decreased. I t should be
noted that virtually the same results were obtained
using consolidated packs and hence this behavior
was not the result of pack fluidization.
From the preceding, it appears that rate changes
affect pack behavior more significantly than. does the
magnitude of the
flow
rate. Generally,
flow
distur
bances caused by rate changes, surging, and gas evol
ution all have a pronounced effect on gravel pack
behavior and could be grouped as w the principal
distinctions among these three causes are the a lpli
tude and the frequency of the disturbances. Thus, it
appears that for a given flow condition, primary and
secondary sand bridges form that are stable for the
existing geometries and hydrodynamic forces. As fluid
forces are altered, instabilities occur, bridges break
down, and more sand
is
produced until, if possible,
new bridges form under new conditions of stability.
Further evidence of the effects of grain-size ratios
under such disturbed (but realistic) flow conditions
is given in Table 1. As illustrated, previously advo
cated grain-size ratios (for example, 10.7 and 7.4)
failed to constrain formation sands under disturbed
flow conditions.
The
final body of test results indicated that under
the tested conditions of operation, F
p
must be less
than 6 to minimize sand production under disturbed
flow conditions. Because the ratio of pack grain size
to pore size for hexagonal packing of spherical par
ticles is 6.46, this result suggests an absolute stoppage
criterion rather than a bridging criterion for gravel
pack design.
Other notable observations from the test data: (1)
'These results
were
similar to
the
results
of verification
tests
in the
fullscale model and hence were typical.
Eposand consolidation.
FEBRUARY, 1974
T BLE
I TYPICAL TEST RESULTS
Ratio
of
Pack
Median Grain Ratio
of
Pack
Size to
10%
Coarse
Formation Point to
Median
Formation
Grain Size,
10% Coarse
F
p1
Point
Results
of
Test
14.3 10.7
Failed
to
constrain
formation
14.3
7.4
Failed
to
constrain
formation
5.7
4.5
Retained formation
5.7
3.2
Retained
formation
pack length or thickness from 1 to 3 in.
had
a negli
gible effect on sand retention; (2) slight increases in
effective stress simulated by mechanical loading on
the sands during tests caused slight decreases in sand
production; (3) high starting rates caused higher initial
quantities of sand production and greater pack
impairment.
ravel Pack Impairment
Pack permeability was noted in all tests. TypicaJ
observations are shown as Fig. 4 for linear model
tests. The test with the median-grain-size ratio of 9.4
had an initial permeability of 600 darcies, and the
test with the median-grain-size ratio of 6.7 had an
initial permeability of 300 darcies. Fig. 4 shows, how
ever, that during the test the finer pack maintained
the highest permeability. Thus, if pack grain size is
too large, formation sand particles may enter the
pack and reduce the effective pack permeability k
e
to a value less than that of a finer gravel pack that
undergoes less impairment. Further evidence of this
is reflected in the perforation pressure drop data from
the wellbore model (Table 2). Perforation pressure
drops for the coarse pack
k
i
c-:::: 700 darcies) are about
10 times those for the fine pack (k
i
c-:::: 150 darcies).
The degree of pack impairment is illustrated
in
Fig. 5, which shows the ratio of effective to initial
pack permeability ke/k
i
vs median-grain-size ratio
F
1
,f).
The data points are average values from multi
ple tests of the linear model at the two rates (8.7 and
13.5 B/D/perforation). For
F
p
less than 6, there is
6 0 0 ~
3 r;j --
Fpf =6.7
250
~ 3 6
--------.
\
~ '
~
/
~
00
33
O ~ o ~ 0 3 3 Fpf =94
6 0
p o_o_o_o_ /0_0_ '0206 Fpf =94
I O O ~ 6
-/o-o__o_
~ \
r
27
--
0 0
___
-027 F
p
f=94
50
I I I I I I I I I I I j .1 .1 I I I
o 5 10 15 20 25 30 35
40
45
50
55 60 65 70 75 80
85
90
t, MINUTES
Fig.
4-Permeabil ity
vs
time-l inear
model.
207
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-
o ~ L - ~ L - T - L - T - L - T - L - ~ , o - L ~ - L - , - L - , ~ - , ~ ~
'pI
Fig.
5-Pack impairment
vs median-grain-size ratio.
100 -- ,
140
130
120
110
.
>
100
:0
:x; 90
80
o
:i 70
o
60
u
o
o
50 -
4
20
10
;
,
___ a-f=O.Z
12
13
p
Fig. 6--Permeability ratio vs median-grain-size ratio.
J O ~ - - - - - - - - - - - - - - - - - - _ _ _ _ _
a 20-40 us MESH SAND
o
OTTAWA FUNT
o ..
GLASS SPHERES
x
TEST
POINTS fROM
PREV.
GRAVEl.
PACK TESTS
k
(dorcies)
Fig.
7-lnert ia
coefficient for sandstone.
208
virtually no impairment. As
F
pf
increases from 6 to
10.5, formation sand enters the pack, reducing the
effective pack permeability significantly.
For
ratios
greater than 10.5, the behavior would be of only aca
demic interest since, as already discussed, the forma
tions sands would not be adequately constrained
Relative pack impairment is not an adequate cri
terion by which to evaluate well performance. In
deed, as will be shown later, if pack grains are the
same size as formation grains, pack impairment will
be negligible, but so will well productivity.
The ratio of the effective pack permeability
to
the
formation permeability is related to production.
To
define this ratio, we consider Krumbein and Monk's'O
expression for permeability*
(2)
where C
is
a function of the particle shape, packing,
and skewedness. Assuming that C for the pack and
formation may be taken as a constant average value
over a range of analysis, then the desired ratio is
a
= ke/k
f
= ~ ; r e
l
(a1>f-
a
fp) Z:), . (3)
where the function
ke/k
i
may be obtained from
Fig.
5_
Using
lI >f
=
0.7 and 0.2, and
lI >p
=
0.2 in Eq. 3
results in Fig. 6. To maintain the highest pack-to
formation permeability ratio and
to
minimize sand
production, the median-grain-size ratio, F
pf
,
should
be between 5 and 6.
Well Productivity
The
nature of the flow through gravel packed per
foration tunnels (casing and cement thickness) is of
primary importance in the performance of gravel
packed wells. The pressure drop through gravel
packed perforations may often be considerably
greater than that predicted by Darcy's law.
The limit of applicability of Darcy's law is for
Reynolds number
(N
Re
= ud
p
/ f-t
less than
or
equal
to 10.** For N
Re
>
10, inertia effects
as
well as vis
cous effects of
flow
must be accounted for.
For
one
dimensional
flow,
Greenberg
et
l
l
suggest the fol
lowing relationship between pressure gradient and
volumetric
flow
rate:
- dp/dx =
Sf-t q/
A)
+ 3p q/A)
.
4)
(viscous) (inertia)
On integrating Eq. 4, equating the first term with
Darcy's law, and using convenient units, we obtain
for one-dimensional flow through a perforation,
t lPpf
=
0.888 L: + 9.1 X
1O-
,3
/1Lp( )"
(5)
Values of the inertia coefficient,
/1,
extrapolated
from data by Tek
et
l
l3
are shown in Fig. 7, along
This
relationship is oversimplified
but
is
nevertheless assumed
to
be valid.
Apparently. transit ion from laminar f low in porous
media
may
occur for NRE between 1
and
10 (see, for example, Ref. 11).
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with coefficients calculated from the previously dis
cussed test data. The multicycle extrapolation
is
suf
ficient cause for the lack of complete agreement.
Fig. 8 is a graphical display of Eq. 5 for typical
values of perforation size. The significant difference
between Darcy's law and actual perforation pressure
drop is evident. Fig. 8 also illustrates how great the
pressure drop can be across formation-filled perfora
tions; this emphasizes the necessity of placing gravel
in the perforations.
From
the foregoing, the productivity from gravel
packed wells compared with that from open holes
may now be calculated. For unconsolidated sands,
the perforation depth into the formation is assumed
to be negligibly small. I f we further assume that the
pressure drops in a gravel packed well are due only
to the packed perforations ( ~ P p f ) and the formation
( ~ P f m ) then the productivity ratio is
l
- / -
~ P f m ~ P f m
1 0 -
fac tua l l open
hole
-
A + Ap
=
~
UP m U pf up
6)
where
~ P p f
is from Eq. 5 and
_
q,u
In re/re)
Pfm - 7.08 k
f
h
Fig. 9 shows 1 1 vs
p
for typical production in
terval data and various perforation sizes and densi
ties.
I t
is evident that increases in perforation size or
density should result in substantial increases in pro
ductivity. From Fig. 9 for the conditions assumed
we
see that for a drawdown of 500 psi and four -in.
diameter perforations per foot only 46 percent of
open-hole productivity is available. Increasing the
perforation size to lh-in. diameter provides 63 per
cent of open-hole well productivity, and increasing
it
to -in. diameter provides 86 percent. Assuming no
casing or cement damage would result, 95 percent of
open-hole productivity could be obtained with eight
-in.-diameter perforations per foot.
A previous evaluation by Muskat
14
has indicated
that the flow resistance through perforated casing is
greater than the flow resistance of an open-hole com
pletion. Thus, if in addition to
~ P p f
and ~ P f m we
assume the perforated casing resistance of Muskat,
then Fig. 10 may be generated.
I t
must
be
pointed
out that Muskat's relation for perforated casing is a
function of the perforation radius, whereas our analy
sis includes radius to the second power (area) hence
it is not completely consistent to combine the two.
However, it illustrates possibly the relative influence
of gravel packs on well productivity, assuming there
is some reduction due to perforated casing.
In
the preceding examples, typical values were
used. I t should be pointed out that for increasing
formation permeability (i.e., permeability greater than
the 0.5 darcies used) the curves of 1
o
indicate a
lower percentage of open-hole productivity available.
Nevertheless, this still may be overcome to a large
degree by increasing perforation size and density, and
From the
tests, pressure
drops through the
gravel
annulus
and
the
screen are
indeed
negligibly small.
The
effects
of
per
forated casing alone on well productivity is discussed in the
followi ng pa ragra
phs.
FEBRUARY,
1974
T BLE 2 PERFORATION PRESSURE DROP
Median-
Grain-
Perforation
Size
Flow Rate
Pressure
Ratio,
Drop,
Test
p
,
cc/sec
B/D/perforation
t.p
p
, (psi)
Fine
Pack 6 0
15.5
8.2
k
i
:::::;
150 darcies
27.0 14.0
15.6 8.2
Fine
Pack 6.0
15.5
8.2
(Repeat)
26.6
13.8
15.5 8.2
Intermediate Pack
8.5 14.8
7.7
k
i
:::::; 270 darcies
25. l3.
14.8
7.7
Coarse Pack
12.8 15.7
8.3
k, ; 700 darcies
21.6 11.2
15.5
8.2
900 --------------------
i
800i
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40
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also were installed improperly (that is, they were cir
culated in place instead of being squeezed into the
interval).
Fig. 12 shows the probability of failure
vs
median
grain-size ratio based upon the uncorrected sidewall
cores and also after
an
empirically defined correction
was applied. No failures occurred for F
pf
less than 6,
with the probability of failure increasing with increas
ing
F
pf
These data support the laboratory findings
that the median-grain-size ratio should be less than 6
to prevent gravel pack failure.
t
has also been noted that the productivity indices
of more recent wells are greater than those of wells
completed with the older conventional techniques.
However, gravel pack productivity still needs to be
improved, and increased perforation size and density
as well as improved gravel placement techniques are
being used toward that end.
Conclusions
From the preceding, we conclude the following:
1
To
minimize sand prosuction, the ratio of pack
median grain size to formation median grain size
should
be
between 5 and 6 where there is severe
flow disturbance.
2 Bridging, though satisfactory for uniform un
disturbed flow, is unsatisfactory for severe (but realis
tic) flow conditions.
3. Pack permeability impairment is minimized and
hence production is maximized if the median-grain
size ratio is 6 under severe flow conditions and with
given perforations.
4. Rounded grains appear to be better than angu
lar grains for gravel packing.
5. Well productivity may be increased with in
creased perforation size or density.
6. Perforation tunnels must be tightly packed with
gravel to minimize impairment; therefore, squeeze
packing must be employed.
7. Before packing, perforation debris must be re
moved by backsurging or some equivalent method.
8.
t
is mandatory that completions be clean and
that packing fluids be compatible with the formation.
9. Crossover tools should be used in gravel place
ment.
Nomenclature
A =
cross-sectional area of a perforation
C = function of particle shape, packing and
skewed ness
C = concentrat ion of jets per foot
C
=
average sand concentration in gravel
pack effluent in time increment t1t
C
max
= maximum C value during test period
dp
f dx
= pressure gradient
d
= mean particle diameter (general)
d
f
= median formation grain size
d
p
=
median pack grain size
F
g
= gas-liquid ratio
F
pf
ratio f f
rnpd;afJ err;:,; ,,;71'
nf
Dack
to
median grain size of formation
h
= net pertoratlon helgat
FEBRUARY, 1974
J = productivity index
of
gravel pack in per
forated casing assuming flow resistance
due to packed perforations only
J
CSg
= productivity index in perforated casing
after Muskaf1
4
J
g
= productivity index of gravel pack in per
forated casing (J) plus added resistance
of perforated casing (JCSg)
J
o
= productivity index of open-hole interval
k = permeability (general)
k
=
effective total permeability of the gravel
k
f
=
permeability of formation
k
i
= initial unimpaired total permeability of
the gravel
L
=
length
NRe = Reynolds number
pi
= perforation
fi
= probability of failure
t1p
=
pressure drop
t1pcsg = pressure drop due to open perforations
in casing (after Muskat
14
)
t1Pfn = pressure drop in formation
t1Ppf
=
pressure drop through gravel packed
perforation
t1pwf
=
drawdown
q
=
volumetric flow rate
r
= casing radius
r
=
reservoir radius
u = average pore velocity
w
= mass
flow
rate of fluid
IV = time rate of change of mass flow rate of
fluid
Y
=
general response as sand concentration
or pack pressure drop
a
= permeability ratio
kef
k
f
f =
inertia coefficient
y = fluid specific gravity
S = constant assumed to be a function of the
medium matrix
f = fluid viscosity
p = fluid density
O rj>j = logarithmic standard deviation (sorting)
of granular material j
< > =
units used to measure sorting -
< > =
log2
diameter (in mm)
cknowledgment
I express my appreciation to Shell Oil Co.
and
Shell
Development Co. for granting permission to prepare
and publish this paper. I also acknowledge the sub
sequent work by R S Torrest
on
flow through gravel
packed perforations, which expanded this initial effort.
References
1 Mantooth, M. A.: Statistical Analysis of Recent Sand
Control Work,
API
Paper 926-13-G,
API
Committee
on Sand Control
(1968).
2
Coberly, C.
J.,
and Wagner, E. M.: Some Considera
tions in the Selection and Installation of Gravel Packs
for Oil Wells, Pet. Tech. (Aug. 1938) 1-20.
3
Hill,
K.
E.:
Factors
Affecting the Use
of
Gravel in
Oil Wells, Oil Weekly (May 26, 1941) 13-20.
4. Winterburn, Read: Contr ol of Unconsolidated Sands
in Wilmington Oil Field, Drill.
and
Prod. Prac.
API
(1947) 63-79.
211
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7/25/2019 SPE-4030-PA Consideration on gravel packing
8/8
5. Tausch, G., and Corley,
C :
Sand Exclusion in Oil
and
Gas
Wells,
Drill. and Prod. Prac.
API (1958)
66-82.
6. Sparlin,
Derry:
Fight Sand With Sand-A Realistic
Approach
to Gravel Packing, paper SPE 2649 pre
sented
at SPE-AIME
44th Annual
Fall
Meeting, Den
ver, Colo., Sept. 28-0ct. 1 1969.
7. Schwartz, D.
H.:
Successful Sand Control Design for
High Rate Oil
and Water
Wells,
1 Pet. Tech.
(Sept.
1968) 1193-1198.
8. Williams, B. B., Elliott, L. S., and Weaver, R. H.:
Productivity
of
Inside Casing
Gravel Pack
Comple
tions,
1 Pet. Tech.
(April 1972) 419-425.
9. Sage, B.,
and Lacy,
W.:
Effectiveness of Gravel
Screens,
Trans.
AIME (1942) 146, 89-106.
10. Krumbein, W., and Monk, G.: Permeability as a
Function of Size Parameters of Unconsolidated Sand,
Trans. AIME
(1943) 151, 153-160.
11. Hassinger, R. C : Transverse Dispersion in
Porous
Media,
PhD
thesis,
Tulane
U., New Orleans (1967) 22.
212
12. Greenberg, D., Cresap, R., and Malone, T.: Intrinsic
Permeability of Hydrological Porous Mediums: Varia
tion With Temperature, Water Resources Res. AGU
(1968) 4, No.4, 791-800.
13. Tek, M. R., Coats, K. H.,
and
Katz, D. L.:
The
Effect
of Turbulence on
Flow
of
Natural
Gas Through Porous
Reservoirs, 1
Pet. Tech.
(July 1962) 799-806;
Trans.
AIME,225.
14. Muskat, Morris:
Physical Principles of Oil Production
McGraw-Hill Book Co., Inc., New
York
(1949) 216-
219.
15. Maly,
G.
P.:
Improper
Formation
Sampling Leads
to
Improper Selection of Gravel Size,
1 Pet. Tech.
(Dec.
1971) 1403-1414.
PT
Paper
SPE 4030 was
presented at
SPEAIME 47th Annual
Fall
Meeting, held
in San Antonio, Tex., Oct. 811, 1972. Copyright
1974 American Institute of Mining, Metallurgical, and Petroleum
Engineers, Inc.
This paper
will
be printed in
ransactions
volume 257, which
will
cover 1974.
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