Upload
karen-giraldo-londono
View
213
Download
0
Embed Size (px)
Citation preview
7/24/2019 SPE-95090-MS.pdf
1/13
Copyright 2005, Society of Petroleum Engineers Inc.
This paper was prepared for presentation at the SPE International Symposium on Oilfield
Scale held in Aberdeen, United Kingdom, 1112 May 2005.
This paper was selected for presentation by an SPE Program Committee following review ofinformation contained in a proposal submitted by the author(s). Contents of the paper, aspresented, have not been reviewed by the Society of Petroleum Engineers and are subject tocorrection by the author(s). The material, as presented, does not necessarily reflect anyposition of the Society of Petroleum Engineers, its officers, or members. Papers presented atSPE meetings are subject to publication review by Editorial Committees of the Society ofPetroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paperfor commercial purposes without the written consent of the Society of Petroleum Engineers isprohibited. Permission to reproduce in print is restricted to a proposal of not more than 300
words; illustrations may not be copied. The proposal must contain conspicuousacknowledgment of where and by whom the paper was presented. Write Librarian, SPE, P.O.
Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435.
AbstractDownhole scale inhibitor (SI) squeeze treatments are acommon feature of the scale control plans of many oil
operators. However, reservoir formations are large,
heterogeneous rock bodies in which fluid flow is strongly
determined by the permeability structure. Thus, when a slug
of scale inhibitor is injected into the formation, fluid
placement is an important issue. To design successful squeezetreatments, it is necessary to know where the injected fluid
goes or, even better, we would like to control where the fluid
package is placed in the near-well reservoir formation.In this paper, we go back to basics, in that we re-derive
the analytical expression that describe placement in linear and
radial layered systems for unit mobility and viscous fluids. Initself, this is not new since these equations are well known.
However, we apply them in a novel manner to describe scale
inhibitor placement. We also demonstrate the implications of
these equations on how we should analyse placement both in
the laboratory and by numerical modelling before we apply a
scale inhibitor squeeze. We present an analysis of viscosifiedSI applications for linear and radial systems both with and
without crossflow between the reservoir layers.
Visualisation experimental results are also presented of
simple and viscosified slug placement in layered bead packswith crossflow between layers. It is shown that these agree
very well with the numerical predictions. Additional
calculations on near well placement in radial systems are also
presented showing how the theory carries over into real field
near-well, heterogeneous systems. Some novel ideas are
presented on the application of viscosified scale inhibitor
treatments.
Background and IntroductionChemical scale inhibitors have been applied for many years in
downhole squeeze treatments. The objective is to have an
aqueous phase scale inhibitor (SI) return concentration, [SI],
above some minimum inhibitor concentration (MIC) for as
long as possible [1-8]. The squeeze lifetime is a strongfunction of the SI/rock interaction e.g. by adsorption. In a
homogeneous reservoir layer, adsorption may be the only
retention mechanism governing the SI return from the well.
However, reservoir formations are rarely homogeneous but are
made up of highly heterogeneous rocks which may have a
layered or more complex structure as determined by varioussedimentological, structural and diagenetic factors [9]. Here
we will consider only layered systems where the variouslayers have different permeabilities, k (and porosities, ) in thenear-well formation. In such systems, SI placement within the
formation is an additional aspect of a squeeze treatment that
must be considered since this may affect the SI returns.
In most cases, scale inhibitors are applied as aqueous
solutions at concentration, typically in the range 10,000
150,000 ppm. These solutions usually have a viscosity ()close to that of a normal injection brine; i.e. ~1 cP at 20
oC and
0.3 cP at 100oC. Therefore, apart from a slight temperature
effect, the injected brine displaces formation water (FW) at
unit mobility. Also, for lighter oils, a unit mobility
displacement is often involved although viscosity and relative
permeability effects may be more important in heavier oils. Inunit mobility injection into a heterogeneous layered linear or
radial system, as shown schematically in Fig. 1, the fluid
placement into layer i is governed solely by the (kh)iproduct.
That is, injecting fluid at a total volumetric flow rate of QT
into an N-layer system of the type shown in Fig. 1, then flow
into layer i, Qi, is given by:
( )
( )1
ii N
ii
khQ
kh=
=
(1)
It can easily be shown that this is true for unit mobilitydisplacement in a linear or a radial system with or without
crossflow. However, this well established result might foster
the belief that linear and radial systems are also very similar
under viscous slug injection with and without crossflow and
this is notthe case.
In recent years, the use of viscosified slugs of SI has been
proposed in order to change the placement pattern in a
favourable manner [10 - 13]. In this context, favourable
may mean to place the SI slug entirely in the high permeability
layer from which the water is being produced. However, it
may also mean that we wish to place the inhibitor slug in the
lower permeability layers where it may be stored and flow
back to the well more slowly because of the reduced flows
from these layers. Whatever, our intention, we must clearly
understand the fluid mechanics of viscous slug placement in
SPE 95090
Scale Inhibitor Placement: Back to BasicsTheory and ExamplesK.S. Sorbie and E.J. Mackay, Heriot-Watt U.
7/24/2019 SPE-95090-MS.pdf
2/13
2 SPE 95090
heterogeneous systems to achieve the effect we are after i.e.
most of the SI slug in the high k or low k layer.
At this point, we note that viscosified solutions or othertype of divertor may also be injected to modify the relative
flows in the wellbore and near-well formation in long
horizontal wells [10 - 13]. Viscous fluids are also used in a
similar manner in viscous acidising. However, we will not
consider wellbore effects in this paper. It is the fluidmechanics in layered heterogeneous formations both with andwithout crossflow for linear and radial systems we will
consider here. These layered systems may have N-layers but
for simplicity we consider only 2, as in the simple schematics
in Fig.1. All the analytical results here can be generalized
quite easily to multi-layer systems.
Problem Statement
The linear and radial layered systems considered in this work
are shown schematically in Fig. 1. We will consider the
various combinations in the following order:
(a) L inear heterogeneous systems no crossflow: Analyticalexpressions will be used to show the level of diversion that
occurs when viscous fluid is injected into a layered system.
(b) Radial heterogeneous systems no cr ossflow: Analytical
expressions for viscous injection into no-crossflow radial
systems are also known and are compared with linear results.
(c) L inear heterogeneous systems with crossflow: For this
case, experimental results are presented showing clear viscous
crossflow. Both viscous over-stable cases (p/w> k1/k2) andunstable cases (injected < in situ viscosity) are considered.
(d) Radial heterogeneous systems with cr ossflow: This
case is only amenable to numerical solution and results are
presented following on from the results of case (c) above.
For both linear and radial heterogeneous no-crossflow
cases, analytic expressions for the flows and relative
penetrations of injected fluid have been derived by Seright and
co-workers [14 - 18]. Flow in layered systems with crossflow
has also been studied previous by several workers [19 -23].
Linear Heterogeneous Systems No Crossflow
Formulation: As noted, the flow of a unit mobility fluid is
simply governed by the layer (kA)i. For viscous fluid
placement, we use the notation in Figs. 1 and 2, where 1 and 2
label the high and low k layers, respectively. For constant
volumetric fluid injection rate, QT, of the (viscous) fluid of
viscosity, p(p> w), the cumulative volume injected at timet is given by:
( ) .inj T q t Q t = (2)
The layer flow ratio, ( )1 2Q Q , can be shown to be given by:
( )
1 1 1
2 21 1 1
2 2 2 1
. ( ( ) ).
. .
p w
w inj
w p w
L q t x AAQ k A
Q k A L x
+ = +
(3)
Using the constraint that,1 2TQ Q Q= + , the rate of advance in the
high k layer 1 is given by:
( )
( )
. 1 11
2 21 1 1 1
1 1
;
;
TQ f x t dx
dt k AA f x t
k A
=
+
(4)
where
( )1 1;x t is the expression in the large bracket on the
RHS of Eq. 3. The advance rate in the low k layer can easily
be found by material balance. The following simple algorithm
was used to solve the viscous placement equations above:
1. At t =0, f1= 1 calculate (dx1/dt)
2. Integrate Eq. 4 over t3. Update => x1(t+t) = x1(t) + t.(dx1/dt)4. Calculate (Q1/Q2) from Eq. 3
5. Update t = t + t go to Step 2
Resul ts linear system, no crossflow: Physically, it is clear
that at t = 0, the ratio of flows (Q1/Q
2) will simply be the
permeability ratio since the system is full of fluid of viscosity,
w. Likewise, in the very long time limit, when both layers arefull of the viscous fluid ( =p), then the flow ratio must returnto this original value. However, the final pressure drop across
the system will now be, Pf= (p/w)Pi, where Pi is theinitial pressure drop. It is intuitively clear that the flow ratio
will decrease on injection of viscous material and that the
minimum flow ratio will be reached when the high k layer just
fills with viscous fluid. An example calculation is shown in
Fig. 3 for a permeability contrast of (k1/k
2) = 10 which shows
that increasing p to 10 (w=1) causes the flow ratio (Q1/Q2)to decrease from 10 to ~3.5 at ~0.6 PV injection. The effect of
viscosity ratio, (p/w=5, 10, 50, 100), on the layer flow rate
ratio is shown in Fig. 4 which shows four important features.Firstly, the fact that injecting a viscous fluid does cause
diversion of injected fluid into the low k layer is demonstrated.
Secondly, and unsurprisingly, it is seen that (Q1/Q
2) drops
more rapidly for higher viscosity injected fluids. Thirdly, the
minimum flow ratio is approximately the same (between 3 and4) for all viscosity ratios from 5 to 100, although it is reached
more rapidly for the higher viscosity cases. Fourthly, there is
very little difference in the 50 and 100 viscosity ratio results
suggesting that there is some critical viscosity ratio, (p/w)c,above which little difference is seen in the flow ratio. The
degree of fluid diversion can be seen in Figs. 5 and 6 which
show plots of x2 (penetration into the low k layer), when the
high k layer just fills with viscous fluid, i.e. at x1= L (see Fig.5). Fig. 6 shows quantitatively the penetration of fluid into the
low k layer for viscosity ratios, (p/w) = 1, 20 and 100; thepenetration goes from 0.1 (p= w= 1) to ~0.31 (p20).
Summary:The results for viscous placement in a no crossflow
layered linear heterogeneous system are as follows:
(i) The analytical calculations indicate that using viscous
fluids looks attractive for placing SI in the lower k layer.
(ii) There is a critical viscosity ratio for a given permeability
ratio above which there will be very little additional diversion.
It can be shown that this is given approximately by:
7/24/2019 SPE-95090-MS.pdf
3/13
SPE 95090 3
1
2
2p
w c
k
k
(5)
(iii) Furthermore, as (p/w) increases indefinitely, it can beshown that the flow rate ratio limits as follows:
1 1
2 2as
p
w
Q k
Q k
(6)
(iv) Given the above, it seems reasonable to investigate
viscous placement further by experiment e.g. in parallel cores.
Radial System No Crossflow
Formulation: Now consider the very similar problem in
radial (no crossflow) systems to that in linear layered systems.
We pose the question: regarding placement, are there any
important differences between radial and linear systems?
The radial two-layer system is shown in Fig. 1. We might
suspect that there are differences between the linear and radial
cases because of the logarithmic pressure drop that arises fromthe radial Darcy law [24], shown schematically in Fig. 7,which also gives the notation for the developments below. For
unit mobility placement (p= w) in a radial system, the flowrate ratio is the same as in a linear system:
1 1 1
2 2 2
Q k h
Q k h
=
(7)
However,unlikethe linear system, the radial advance ratio,
(r1/r2), (equivalent to (x1/x2), is given by:
1 1
2 2
r k
r k= (8)
and this is also shown inset on Fig. 7. Using the notation in
Figs. 1 and 7, it can be shown that the flow rate ratio during
viscous placement in a no crossflow radial system is given by:( 1)
max 1
1 1 1
( 1)2 2 2 max 2
ln
.
ln
w
w
R r
rQ k h
Q k h R r
r
=
(9)
where is the viscosity ratio, = (p/w).The algorithm for solving for the frontal advance in each
layer, i.e. r1(t) and r
2(t), is outlined below, where = (Q
1/Q
2):
1. Calculate ( )1 2Q Q from Eq. 9; where initially (t = 0),
( ) ( )1 2 1 1 2 2Q Q k h k h= .
2. Calculate, Q1 as:( )1 1
TQ
Q
=
+ and then calculate,
2 1TQ Q Q=
3. Calculate, ( ) ( )1/ 2
211 1
1 1
.new old
Q tr r
h
= +
and calculate ( )2 newr from a similar expression.
4. Set ( ) ( )1 1old newr r= ; ( ) ( )2 2old newr r= and t = t + tand go to Step 1 above.
Results: The flow ratio, (Q1/Q
2) vs. time, is shown in Figs. 8
and 9 for a no crossflow radial system for viscosity ratios, =(p/w)= 2, 5, 10, 20, 50 and 100. The longer (0 80t ) andshorter ( 0 20t ) time behaviour is shown in Figs. 8 and 9,respectively (t in arbitrary units). System data is: Rw=0.5; Rmax
= 10; k1= 10; k2= 1; h1= h2= 5; 1= 2= 0.2;QT= 2;=(
p/
w) = 1 , 2, 5, 10, 20, 50, 100 (
w = 1). Another way of
representing this fluid diversion in the radial system for thesame data is shown in Figs. 10 and 11. Figure 10 shows the
penetration distance, r2, in the low k radial layer and ratio(r1/r2) when the high k penetration depth is, r1 = 5, as a
function of the viscosity ratio, . Fig. 11 shows the penetrationratio (r1/r2) vs. time for viscosity ratios, = 1 and 10. A closestudy of the results in Figs. 10 and 11 as measured by theactual value of r2 in Fig. 10 or by (r1/r2) indicates that thedegree of diversion in a radial system is much lessthan that in
a linear system. For example, for the (k1/k2) = 10 case, then p> 5 makes little difference since at r1= 5, the value of r2goes
from 1.7 to a maximum of r22.1 as p increases. The mostdirect way to plot the results is to show the actual penetrationin each layer after scale inhibitor slug injection in both linearand radial two-layer systems as shown in Figs. 12(a) - 12(d).
Summary and comparison of no-crossfl ow linear and r adial
systems:The conclusions to this point are as follows:(i) Viscous fluid injection into a layered linear or radial no
crossflow system causes diversion of fluid to the low k layer;
(ii) This diversion is muchlarger in a linear system than ina radial system where it is not very significant;(iii) Implications from these points are: (a) results from
no-crossflow linear systems (such as parallel coreexperiments) are actively misleading in terms of radial
placement; and (b) we should use modelling to examineplacement - using data from 1D core flood experiments tosupply parameters (e.g. on effective viscosities etc.)
Linear Layered System With Crossflow
Uni t mobili ty placement:Fig. 13 shows a schematic two-layer
heterogeneous system withcrossflow but under unit mobility
injection (p=w), showing the (constant) pressure profiles,
P(x), along the layers. This case is essentially identical to
7/24/2019 SPE-95090-MS.pdf
4/13
4 SPE 95090
the no-crossflow case as the frontal advance, rates are constant(x1(t) and x2(t) are linear with time in each layer). This is
shown for the experimental unit mobility flood in Fig. 14
where a blue dyed brine (p=1cP) displaces a clear brine(w=1cP) in a two-layer beadpack. The pack in Fig. 14 is 56cm long by 5.5 cm in vertical height and ~1.3 cm thick; fulldetails are given in Table 1 and ref. [22]. Confirmation of the
linear flows for this unit mobility flood is shown in Fig. 15where x
1(t) and x
2(t) are plotted from Fig. 14 as functions of
PV injected (constant rate). The results in Fig. 15 show thatthe permeability contrast is:
1 1
2 2
13 135 71
2 30
.= .
.
x k
x k= =
(10)
We note that this behaviour is well known but such floods
are necessary to establish the (k1/k2) ratio in Eq. 10 for use inthe viscous slug placement calculations below (Table 1). Fig.16 shows a direct simulation of the unit mobility flood in Fig.
14 using the permeability contrast in Eq. 10 which, as
expected, reproduces the experimental results very well.
Vi scous stable slug in jection: We now consider the injectioninto the two-layer beadpack described above (k1/k2 = 5.71) of a
slug of viscosity, p, greater than that of the resident fluid(brine viscosity, w). A schematic of viscous stable slugplacement is shown in Fig. 17 where the pressure profiles ineach layer at a given time are shown. In this case, the pressure
profiles are evolving as the viscous fluid advances through thesystem. Fig. 18 shows the injection of a viscous slug of clear
fluid (p 10cP) into a blue brine (w=1cP) in the two-layerbeadpack. It is clear by comparison with the unit mobilityresults in Fig. 14 that significant amounts of injected fluid are
diverted into the low k layer [22]. Indeed the layer pressureprofiles for the viscous case in Fig. 17 indicate that: (a)crossflow of viscous injected material occurs behindthe frontfrom high k low k layer; and (b) corresponding crossflowof low viscosity (blue) fluid must occur from the low highk layer in front of the interface. Fig. 19 shows a direct
simulation of the viscous stable flood in Fig. 18. Very goodagreement is seen between the experimental and modelledresults indicating that the crossflows are well predicted.
Fig. 20 shows the experimental and numerically simulatedfrontal advance ratio, (x1/x2) vs. PV injected for the viscousstable slug injection in Fig. 18. This figure also shows some
similar repeat floods from ref. [22]. Fig. 21 shows the
numerically simulated fractional layer recovery vs. PVinjected for this flood. Note that this confirms the direction ofcrossflow shown schematically inset in Fig. 21 as explainedabove, since we see that more fluid is recovered through thewell at the end of layer k
1than was in the layer originally.
This is due to a strong viscous crossflow mechanism asdescribed previously [20 - 22, 25].
Viscous unstable slug i njection: We now take the finalviscous slug placement in the two-layer pack after injection of0.36 PV (Fig. 18) as initial conditions for an unstable
displacement. Fig. 22 shows the injection of a slug of red
brine (w 1 cP) to displace the viscous clear slug (p 10cP). The in situ blue brine has the same viscosity as the
injected red brine (w = 1cP). Viscous fingering of the redbrine into the clear viscous fluid is observed and the (clear)viscous slug is displaced into the low k layer. Fig. 23 shows asimulation of this slug breakdown experiment in Fig. 22. Inthe numerical calculation, fluids are not distinguished bycolour as in the experiment. However, the location of the(clear) viscous slug is evident and it is predicted to be
displaced into the low k layer, as found in the experiment
Summary of stable viscous slug placement and unstable slug
breakdown: The main conclusions for the linear layeredheterogeneous system with crossflow are:
(i) A viscous overstable flood is described here where
(p/w)>(k1/k2), which leads to extensive crossflow in layeredsystem where free communication between layers is allowed.
On increasing the injected fluid viscosity significantly abovethe over stable condition, no further crossflow occurs ratherlike the degree of diversion in no crossflow systems.
(ii) The direction of crossflow in the stable displacement isthat viscous injected fluid is diverted into the low k layer andthere is crossflow of in situ low viscosity fluid from the low to
the high k layer.(iii) There is excellent quantitative agreement between the
experimental observations and numerical simulation for theviscous slug placement and the levels of crossflow.
(iv) The behaviour for viscous slug placement is quitedifferent from that observed for a no crossflow layered system.
Thus, this type of information is only accessible by performinglayer pack studies of the type described here or by carrying outnumerical simulations (which agree with such experiments).
(v) When a viscous slug is further placed into the layeredsystem with crossflow by an unstabledisplacement, fingeringthe high k layer occurs and the viscous slug is displaced into
the lower k layer.
Radial Layered System With Crossflow
Finally, we consider a radial heterogeneous layered systemwith free crossflow between layers. Performing experimentsin radial layered beadpacks with crossflow is not feasible
routinely. For such a system, the best approach is to performdirect numerical simulations. This has been done for a radial
system of laboratory dimensions as described in Table 1.However, the viscous forces scale linearly to real fielddimensions as described elsewhere [22]; i.e. the same resultswould be found by considering a model of the radial formation
with Rmax
= 4.82m etc. Fig. 24 shows the unit mobility andviscous slug placement with and without crossflow at 0.5 PV
of injection. Fig. 25 shows the same cases after a further
0.3PV overflush with = 1 cP fluid in all cases. A summaryof the percentage of the main slug injected which ends up inthe low k layer is given for the radial cases at various stages inTable 2, where a comparison with the linear system is also
given. Placement in the low k layer is the same (17.4%) forthe radial and linear systems both with and without crossflow
for the unit mobility ( = 1cP) main slugs. Table 2 also showsthe % increase in the amount that ends up in the low k layercompared with the unit mobility case (always 17.4%). .
7/24/2019 SPE-95090-MS.pdf
5/13
SPE 95090 5
Summary of radial cases and comparison with l inear system:Taking all cases together, we summarise as follows:
(i) The no crossflow radial 10cP 0.5PV main slug increasesplacement in low k layer by ~36% compared with a ~70%increase for the linear flood;
(ii) The with crossflow 10cP 0.5PV main slug increasesplacement in low perm by ~ 68% for the radial case compared
with a ~125% increase for the corresponding linear case;(iii) The with crossflow 10cP 0.5PVmain slug followed by
a further 0.5PV of 1cP (unstable) overflush increasesplacement in the low k layer in the radial case by ~ 106%
compared with a ~223% increase for the corresponding linearcase.
(iv) The results in Table 2 support and emphasise thosedescribed above The % increase in the amount of diversiongoing from unit mobility viscous floods increases by afactor of ~2 going from a radial to a linear system, for all cases
(figures in parenthesis in Table 2).
Discussion and Conclusions
In this paper, we have revisited the issue of viscous slugplacement in layered linear and radial systems both with andwithout crossflow between the layers. The use of viscosified
slugs for scale inhibitor (SI) placement has been suggested inorder to divert the inhibitor into a given favourable layerwithin the formation. Favourable may either mean to placethe SI slug entirely in the high k or low k layer. Whatever theobjective, we must understand the fluid mechanics ofplacement in heterogeneous systems. In addition, it is
necessary to understand the differences between linear andradial systems as well as between systems with and withoutfree crossflow between layers. This paper does not consider
the effect of shear-thinning systems, which will be discussed
in a future publication.Specific findings and conclusions for each of the 4 cases
(a d) listed in the Problem Statement section are presented inthe appropriate sections above. Here, we summarise the mainbroad conclusions of this work as they apply to placement
using viscosified slugs of scale inhibitor, as follows:1. There are clear differences between linear and radial
heterogeneous systems in that viscous placement results in
more diversion in a linear system. This is the case when thereis either no crossflow or free crossflow between thepermeability layers. More viscous material enters the low k
layer in the latter case. For the cases studied here, the %increase in the amount of diversion from unit mobility viscous floods increases by a factor of ~2 going from a radial
to a linear system.2. When crossflow is present and an unstable postflush
follows a viscous SI slug placement, this results in fingering in
the high k layer and further subsequent diversion of theviscous SI slug into the lower permeability layer. If theobjective is to place the SI in the lower permeability layers,
then this mechanism will do this. However, if the intention isto place all the SI in the high k layer, then the viscosified slugshould contain no SI, and the SI should be present in the low
viscosity post flush.3. In order to assess the levels of diversion caused by a
viscosified SI slug (or indeed a viscosified preflush or
postflush) in a heterogeneous reservoir system, numerical
simulationshould be carried out for a (usually radial) systemwith the correct layer properties and levels of layer-layer
communication (vertical permeability).4. We should avoid performing erroneous assessments
such as carrying out linear parallel core experiments as a
means of assessing levels of viscous fluid diversion. For thereasons detailed in this paper such assessments are actively
misleading. Core flooding in 1D cores should be used simplyto measure the input properties for the simulations describedabove e.g. in situ effective rheology in the porous medium[25], adsorption levels of SI etc.
Acknowledgements
The authors would like to thank the sponsors of the FlowAssurance and Scale Team (FAST) at Heriot-Watt University:FAST I sponsors - Baker Petrolite, BioLab, BP,ChampionServo, ChevronTexaco, Clariant Oil Services,
ConocoPhillips, Exxon/Mobil, Halliburton, Kerr-McGee,Marathon, MI Production Chemicals, Norsk Hydro, Nalco,Petrobras, Rhodia, Saudi Aramco, Schlumberger, Shell,
Statoil, Total and Yukos. We also thank Oscar Vasquez forpreparing Fig. 12.
References1. Kerver. J.K. and Heilhecker. J.K.: Scale Inhibition by the
Squeeze Technique, J. Can. Pet. Tech., 8, No. 1, pp. 15-23,1969.
2. Miles, L.: New Well Treatment Inhibits Scale, Oil and Gas J.,
pp. 96-99, June 1970.3. Vetter, O.J.: The Chemical Squeeze Process Some New
Information on Some Old Misconceptions, SPE3544, J. Pet.Tech, pp. 339-353, March 1973.
4. Meyers, K.O., Skillman, H.L. and Herring, G.D.: Control of
Formation Damage at Prudhoe Bay, Alaska by Inhibitor
Squeeze Treatment, SPE12472, J. Pet. Tech., pp. 1019-1034,June 1985.
5. King, G.E. and Warden, S.L.: Introductory Work in ScaleInhibitor Squeeze Performance: Core Tests and Field Results,
SPE18485, presented at the SPE International Symposium onOilfield Chemistry, Houston, TX, 8-10 February 1989.
6. Yuan, M.D., Sorbie, K.S., Todd, A.C., Atkinson, L.M., Riley,H. and Gurden, S.: The Modelling of Adsorption andPrecipitation Scale Inhibitor Squeeze Treatments in North Sea
Fields, SPE 25163 presented at the SPE International
Symposium on Oilfield Chemistry, New Orleans, LA, 2-5March 1993.
7. Breng, R., Sorbie, K.S. and Yuan, M.D.: "The Underlying
Theory and Modelling of Scale Inhibitor Squeezes in Three
Offshore Wells on the Norwegian Continental Shelf",Proceedings of the Fifth International Oilfield ChemicalsSymposium, Geilo, Norway, 20-23 March 1994.
8. Sorbie, K.S., Yuan, M.D., Jordan, M.M. and Hourston, K.E.:
Application of a Scale Inhibitor Squeeze Model to Improve
Field Squeeze Treatment Design, SPE28885, Proceedings ofthe SPE European Petroleum Conference (Europec 94), London,UK, 25-27 October 1994.
9. Weber, K.J.: Influence of Common Sedimentary Structures on
Fluid Flow in Reservoir Models, SPE9247, J. Pet. Tech., pp.665-672, March 1982.
10. Mackay, E.J., Matharu, A., Sorbie, K.S., Jordan, M.M. andTomlins, R.: Modelling of Scale Inhibitor Treatments in
Horizontal Wells: Application to the Alba Field, SPE39452,
SPE International Symposium on Formation Damage, Lafayette,LA, 1998.
7/24/2019 SPE-95090-MS.pdf
6/13
6 SPE 95090
11. Feasey, N.D., Jordan, M.M., Mackay, E.J. and Collins, I.R.:The Challenge that Completion Types Present to ScaleInhibitor Squeeze Chemical Placement: A Novel Solution
Using a Self-Diverting Scale Inhibitor Squeeze Process,
SPE86478, SPE International Symposium on FormationDamage, Lafayette, LA, 18-20 February 2004.
12. Mackay, E.J. and Al-Mayahi.: What Controls Scale Inhibitor
Placement?, presented at the 14th International OilfieldChemical Symposium, Geilo, Norway, 24 26 March 2003.
13. Jordan, M.M., Edgerton, M.. and Mackay, E.J.: Application ofComputer Simulation Techniques and Solid Divertor to Improve
Inhibitor Squeeze Treatments in Horizontal Wells, SPE50713,SPE International Symposium on Oilfield Chemistry, Houston,TX, 16 - 19 February 1999.
14. Seright, R.S.: Placement of Gels to Modify Injection Profiles,
SPE17332 presented at the SPE Enhanced Oil RecoverySymposium, Tulsa, OK, 17 20 April 1988.
15. Seright, R.S.: Effect of Rheology on Gel Placement,SPE18502, SPE (Reservoir Engineering), May 1991.
16. Seright, R.S.: Impact of Dispersion on Gel Placement forProfile Control, SPE20127, SPE (Reservoir Engineering), pp.343-354, August 1991.
17. Liang, J.-T., Lee, R.L. and Seright, R.S.: Gel Placement inProduction Wells, SPE20211, SPE (Production and Facilities),
pp. 276 286, November 1993.18. Seright, R.S.: Improved Techniques for Fluid Diversion in Oil
Recovery, First annual report Contract No. DE-AC22-92BC14880, US DOE, October 1993.
19. Root, P.J, and Skiba, F.F.: Crossflow Effects During anIdealized Displacement Process in a Stratified Reservoir, SPEJ., pp. 229-237, September 1965.
20. Zapata, V.J. and Lake, L.W.: A Theoretical Analysis of
Viscous Crossflow, SPE10111, presented at the 58th SPEAnnual Fall Conference, San Antonio, TX, 5 7 Oct. 1982.
21. Sorbie, K.S., Wat, R.M.S., Hove, A., Nilsen, V. and Leknes, J.:
Miscible Displacements in Heterogeneous Core Systems:Tomographic Confirmation of Flow Mechanisms, SPE18493,
presented at the SPE International Symposium on OilfieldChemistry, 8-10 February 1989.
22. Sorbie, K.S., Sheb, M., Hosseini, A. and Wat, R.M.S.: ScaledMiscible Floods in Layered Beadpacks Investigating ViscousCrossflow, the Effects of Gravity and the Dynamics of Viscous
Slug Breakdown, SPE20520, presented at SPE Annual Fall
Conference, New Orleans, LA, 23-26 Sept. 1990.23. Sorbie, K.S. and Seright, R.S.: Gel Placement in
Heterogeneous Systems with Crossflow, SPE/DOE24192,presented at the SPE/DOE 8thSymposium on EOR, Tulsa, OK,
22-24 April 1992.24. Dake, L.P.: Fundamentals of Reservoir Engineering,
Developments in Petroleum Science No. 8, Elsevier,
Amsterdam, 1978.25. Sorbie, K.S.:Polymer Improved Oil Recovery, CRC Press, Boca
Raton, FL, 1991; discussion of viscous crossflow p. 274ff.
7/24/2019 SPE-95090-MS.pdf
7/13
SPE 95090 7
Table 1: Properties of the two-layer beadpack [22] and thesimulation model for both the beadpack and the radial model.
Linear Pack Details
Pack Length = 56.0 cm x-Grid: 122 cells; x = 0.5 cmPack Width = 1.3 cm y-Grid: 1 cell; y = 1.3 cm
Pack Height = 5.5 cm z-Grid: 22 cells; z = 0.25 cmLayer 1(2.5 cm): High permeability; Average k1= 9707 mD(uniform random distribution - range +/- 4500 mD)
Layer 2(3.0 cm): Low permeability; Average k2= 1700 mD
(uniform random distribution - range +/- 500 mD)
Permeability contrast, (k1/k2) = 5.71
Porosity, =0.38Total pore volume (PV) = 152.2 cm
3
Total fluid injection rate, QT= 60 cm3/hour
Key to experimental floods:
Fig. 14:Unit mobility flood:Injected blue fluid, = 1 cP; In situ clear fluid, = 1 cP
Fig. 18:Viscous stable slug injection:
Injected clear fluid, = 10 cP; In situ blue fluid, = 1 cP
Fig. 22:Viscous unstable slug breakdown flood:
Injected red fluid, = 1 cP; In situ clear fluid, = 10 cP; Insitu blue fluid, = 1 cP.
Radial Model Details
Radius, Rmax= 4.82 cm; 122 cells increasing logarithmicallyAngle = 360o 2 cells x 180o
System Height = 5.5 cm 22 cells, z = 0.25 cm)Layer 1(2.5 cm): High perm same properties as linear pack
Layer 2(3.0 cm): Low perm same properties as linear pack
Porosity (), Pore volume (PV) and Flow rate (QT) as forlinear pack.
Table 2: Percentage of the injected slug in low k layer, k2, atvarious stages after 0.5PV of injection and after a further
0.5PV of (= 1 cP) overflush. Simulated for both the linearand radial systems; data in Table 1.
Radial System Linear System
NoCrossflow
WithCrossflow
NoCrossflow
WithCrossflow
Unit mob.0.5 PVslug inj.
17.4%1 17.4% 17.4% 17.4%
Viscousstable 0.5
PV sluginjected
23.6%
(35.6%)2
29.3%
(68.4%)
29.6%
(70.1%)
39.2%
(125.3%)
Unit mob.0.5PV inj.+ 0.5PV
overflush
17.4% 17.4% 17.4% 17.4%
Viscousstable 0.5PV sluginj.+
0.5PVunstableoverflush
23.6%(35.6%)
35.9%(106.3%)
29.5%(70.1%)
56.2%(223.0%)
Notes: 1. The 17.4% value for all unit mobility cases is a simulated number;
the theoretical exact answer is 17.37%; 2. The numbers in parenthesis refer to
the % increase ending up in the low k layer relative to the unit mobility case.
7/24/2019 SPE-95090-MS.pdf
8/13
7/24/2019 SPE-95090-MS.pdf
9/13
SPE 95090 9
Penetration (X2) when high perm (k1) just fills
0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0 10 20 30 40 50 60 70 80 90 100
VIscosity ratio (m_p/m_w)
X2(atX
1=L)
p=1
p=20
p=100
Viscosity ratio (p/w)
Penetration (X2) when high perm (k1) just fills
0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0 10 20 30 40 50 60 70 80 90 100
VIscosity ratio (m_p/m_w)
X2(atX
1=L)
p=1
p=20
p=100
p=1
p=20
p=100
Viscosity ratio (p/w)
Fig. 6:Penetration into the low k layer, x2, when the high k
layer just fills with viscous fluid (i.e. at x1= L) as a function of
viscosity ratio, (p/w). Inset shows quantitatively thepenetration of fluid into the low k layer for the 3 viscosity
ratios, (p/w) = 1, 20 and 100. Data as in Fig. 4 caption.
rw r
P(r)
Q
Pw
fP(r) = Pwf- P(r)
1 1 1
2 2 2
Q k h
Q k h
=
p=
w- tracer
For UNIT MOBILITY case
1 1
2 2
r k
r k=
In radial system (1= 2)=>(tracer inj. ) cf. linearcase
rw
Rmax
r
r1
r2
tracer
NO CROSSFLOW
rw r
P(r)
rw r
P(r)
Q
Pw
fP(r) = Pwf- P(r)
1 1 1
2 2 2
Q k h
Q k h
=
p=
w- tracer
For UNIT MOBILITY case
1 1
2 2
r k
r k=
In radial system (1= 2)=>(tracer inj. ) cf. linearcase
rw
Rmax
r
r1
r2
tracer
NO CROSSFLOW
rw
Rmax
r
r1
r2
tracer
NO CROSSFLOW
Fig. 7:Slug placement in a radial layered system showing the
schematic of the radial pressure profile, P(r) and the resultsfor a unit mobility injection; additional notation in Fig. 1.
(Q1/Q2) vs. time for various viscosity ratios
0
2
4
6
8
10
12
0 20 40 60 80
Time
(Q1/Q2)
= ( p/ w)
= 2
= 5
= 10
= 20
= 50 100
= (p/w)
(Q1/Q2) vs. time for various viscosity ratios
0
2
4
6
8
10
12
0 20 40 60 80
Time
(Q1/Q2)
= ( p/ w)
= 2
= 5
= 10
= 20
= 50 100
= (p/w)
Fig. 8: Volumetric flow ratio, (Q1/Q2) vs. time, in a radial
system with no crossflow for various viscosity ratios, =
(p/w) = 2, 5, 10, 20, 50 and 100. Longer time behaviour, t inarbitrary units, 0 80.t System data: Rw= 0.5; Rmax= 10;k1= 10; k2= 1; h1= 5; h2= 5; 1= 2= 0.2; QT= 2;= 1 ,2, 5, 10, 20, 50, 100 (w= 1).
(Q1/Q2) vs. time for various viscosity ratios
0
2
4
6
8
10
12
0 2 4 6 8 10
Time
(Q1/Q
2)
= 2
= 5
= 10
= 20
= 50
= (p/w)
= 100
(Q1/Q2) vs. time for various viscosity ratios
0
2
4
6
8
10
12
0 2 4 6 8 10
Time
(Q1/Q
2)
= 2
= 5
= 10
= 20
= 50
= (p/w)
= 100
Fig. 9: Volumetric flow ratio, (Q1/Q2) vs. time, in a radial
system with no crossflow for various viscosity ratios, =(p/w) = 2, 5, 10, 20, 50 and 100. Shorter time behaviour, t inarbitrary units, 0 10.t System data: as in Fig. 8.
7/24/2019 SPE-95090-MS.pdf
10/13
7/24/2019 SPE-95090-MS.pdf
11/13
SPE 95090 11
PV= 0.00
PV= 0.0629
PV=0.171
PV= 0.306
PV= 0.441
PV= 0.540
PV= 0.607
PV= 2.00
PV= 0.00
PV= 0.0629
PV=0.171
PV= 0.306
PV= 0.441
PV= 0.540
PV= 0.607
PV= 2.00
Fig. 14: Unit mobility displacements in a 2-layer pack; detailsin text and ref. [22].
Dist. along high perm vs. time
y = 13.127x + 0.1256
R2= 0.9984
y = 2.2982x - 0.0574
R2= 0.9959
0
1
2
3
4
5
6
7
8
0 0.5 1 1.5 2 2.5
PV injected
Dist.along
layer
High perm
Low perm
X1(t)
X2(t)
Distance travelled along each layer vs. timeX1(t) vs. time (PV) .. X2(t) vs. time (PV)
Dist. along high perm vs. time
y = 13.127x + 0.1256
R2= 0.9984
y = 2.2982x - 0.0574
R2= 0.9959
0
1
2
3
4
5
6
7
8
0 0.5 1 1.5 2 2.5
PV injected
Dist.along
layer
High perm
Low perm
X1(t)
X2(t)
Distance travelled along each layer vs. timeX1(t) vs. time (PV) .. X2(t) vs. time (PV)
Fig. 15: Frontal advance in each layer, x1(t) and x2(t), vs. PVinjected in the unit mobility flood shown in Fig. 14.
Fig. 16:Simulation of the unit mobility floods in Fig. 14.
LINEAR SYSTEM WITH CROSSFLOW
Q2
P
k2 (w)
x2
(p)
QTQ1
k1
p > w
(w)
x1
FIXED(p)
0 L
P(x)
LAYERPRESSUREPROFILES(at t1)
High perm layer 1
Low perm layer 2
VISCOUS FLUIDINJECTION, p > w
LINEAR SYSTEM WITH CROSSFLOW
Q2
P
k2 (w)
x2
(p)
QTQ1
k1
p > w
(w)
x1
FIXED(p)
0 L
P(x)
LAYERPRESSUREPROFILES(at t1)
High perm layer 1High perm layer 1
Low perm layer 2Low perm layer 2
VISCOUS FLUIDINJECTION, p > w
Fig. 17: Schematic of a two layer heterogeneous system with
crossflow under viscous stable injection (p>w) showing the
(now evolving) pressure profiles, P(x), along the layers at afixed time.
PV= 0.065
PV= 0.00
Viscous Stable Floods in Layered Pack
PV= 0.225
PV= 0.157
PV= 0.36
PV= 0.065
PV= 0.00
Viscous Stable Floods in Layered Pack
PV= 0.225
PV= 0.157
PV= 0.36
Fig. 18:Injection of a viscous slug of clear fluid (p 10 cP)
into a blue brine (w= 1cP) showing that significant amountsof injected fluid are diverted into the low k layer, k2. Detailsin text and ref. [22].
PV= 0.065
PV= 0.157
PV= 0.225
PV= 0.36
Fig. 19: Direct simulation of the viscous stable flood in the
two-layer bead pack in Fig. 18. Details of the pack and fluidproperties in text and ref. [22].
PV= 0.0629
PV= 0.306
PV= 0.54
PV= 2.00
PV= 0.0629
PV= 0.306
PV= 0.54
PV= 2.00
7/24/2019 SPE-95090-MS.pdf
12/13
12 SPE 95090
1
2
10
= 5.71
p
w
k
k
Frontaladvanceratio,(x1/x2)
PV fluid injected
k2
x2
k1
x1
1
2
10
= 5.71
p
w
k
k
Frontaladvanceratio,(x1/x2)
PV fluid injected
k2
x2
k1
x1
Fig. 20: Experimental and numerically simulated frontaladvance ratio, (x1/x2) vs. PV injected for the viscous stableslug injection in Fig. 18 also showing some similar repeatfloods from ref. [22].
PV fluid injected
Layerfractionalrecovery
k1
k2
PV fluid injected
Layerfractionalrecovery
k1
k2
Fig. 21: Numerically simulated fractional layer recovery vs.PV injected for the viscous stable slug injection in Fig. 18.
PV= 0.00
PV= 0.0168
PV= 0.0508
PV= 0.1384
PV= 0.1924
PV= 0.2498
PV= 0.3511
PV= 0.00
PV= 0.0168
PV= 0.0508
PV= 0.1384
PV= 0.1924
PV= 0.2498
PV= 0.3511
Fig. 22:Injection of a slug of red fluid (w 1 cP) to displacethe viscous clear slug (p 10 cP). The blue brine has thesame viscosity as the red brine (w= 1cP). Viscous fingeringof the red brine into the blue is observed and the (clear)viscous slug is displaced into the low k layer, k2. Details intext and ref. [22].
PV= 0.017
PV= 0.05
PV= 0.14
PV= 0.19
PV= 0.25
PV= 0.35
Fig. 23: Simulation of the slug breakdown experiment inthe layered beadpack experiment in Fig. 22. The injected
blue brine has the same viscosity as the resident brine (w =1cP); they are not distinguished by colour as in theexperiment. The (clear) viscous slug is predicted to be
displaced into the low k layer, k2. Details in text and ref. [22].
7/24/2019 SPE-95090-MS.pdf
13/13
SPE 95090 13
(a) Unit mobility - with/without crossflow, 0.5PV
(b) 10 cP viscous slug no crossflow, 0.5PV
(b) 10 cP viscous slug with crossflow, 0.5PV
Fig. 24: Unit mobility and viscous slug placement with andwithout crossflow at 0.5 PV of injection (Table 1).
(a) Unit mobility - with/without crossflow, 0.8PV
(b) 10 cP viscous slug no crossflow, 0.8PV
(c) 10 cP viscous slug with crossflow, 0.8PV
Fig. 25: Unit mobility and viscous slug placement with and
without crossflow at 0.8 PV of injection (Table 1).