reservoir monitoring of eor processes (wag, foam and polymer) using streaming...
TRANSCRIPT
![Page 1: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/1.jpg)
Reservoir Monitoring of EOR Processes (WAG,
Foam and Polymer) Using Streaming Potential
M.Z. Jaafar* , S. Omar, S.M.M. Anuar, S.R Suradi
Faculty of Petroleum and Renewable Energy Engineering
Universiti Teknologi Malaysia
Johor, Malaysia
Abstract— Enhanced oil recovery is an alternative method after
conventional recovery process. After the conventional recovery
process, some amount of conventional and heavy oil will remain
in reservoirs. It is important for oil and gas industry to recover
more hydrocarbons to supply the increasing world energy
demand. The main factors need to be considered during EOR
process is the efficiency of processes toward the increasing of
recovery. Electrokinetic phenomena occur when an electrolyte
flows along charged solid surface. It arise from the interaction
between the rock matrix and the displace water. For several
decades, these phenomena have been of interest to geophysicists
in many subfields. In Oil and Gas industry, this technique not
studies yet as reservoir monitoring in WAG, foam and polymer
but only study in water flooding process. These study focus on
designing the system for testing the effectiveness of streaming
potential measurement in WAG (water alternate gas), FAWAG
(foam assisted water alternate gas) and polymer flooding. The
objectives of this study are to determine: (1) the efficiency of
designed WAG process, (2) detects the foam rupture during
FAWAG process, and (3) detection of polymer adsorption in
polymer flooding.
Keywords— Streaming Potential; Electrokinetic; WAG; Foam;
Adsorption Polymer
I. INTRODUCTION
The study of reservoir monitoring during EOR processes
is important for oil and gas industrial. Oil production
classifies into three phases such as primary, secondary and
tertiary which is known as Enhanced Oil Recovery (EOR). US
Department of Energy finalize that those primary and
secondary recovery of production can leave up to 75% of the
oil in the well. Furthermore, to increase more recovery, the
tertiary or EOR method is implementing to the field. EOR
itself can increase production from a well to up to 75%
recovery [1]. EOR method was the techniques apply to
prevent or minimize the effect of physical and geological
reasons to recover more crude from the reservoir.
In recent years there has been an increasing interest in
Water-Alternating-Gas (WAG) Flooding as one of EOR
method. WAG Flooding is one of the well-established
methods for improving residual oil recovery in a water flooded
reservoir. During WAG process, gravity segregation and
heterogeneity may influence sweep efficiency which can cause
early breakthrough. To overwhelm this problem, WAG
process need to be observed by using streaming potential
signals.
Polymer flooding is the chemical enhanced recovery
which is a well-known method with the low risk and
applicable to wide range of reservoir condition. For many
reservoirs, polymer is an attractive alternative to conventional
waterflooding due to their ability to improve the area of swept
efficiency not only in the macro scale but also in the micro
scale. Basically, polymer flooding was take place after poor
recovery in primary and secondary production stages. Poor
recovery occurred due to geological factor (heterogeneity)
which forms the faster sweep of oil at high permeable zone
and leaves the oil at low permeable zone. Moreover,
application of polymer will cause several problems such as
loss of viscosity by mechanical degradation and loss of
polymer due to adsorption or retention [2].
Polymer adsorption is the main contribution for polymer
losing during polymer flooding processes. As mentioned by
[3], polymer adsorption is the simplest mechanism of polymer
retention which forms the layer on the surface of pore walls by
adsorption of polymer solution. The observation of polymer
adsorption is the important aspect to be considered due to
prevent the large amount of polymer lose in this process.
Basically, the tracer and spectrometer used as the indicator for
the polymer concentration during the dynamic and static test
of polymer adsorption [4].
Foam is a dispersion of gas in a continuous liquid phase
which volumetrically forming a fraction of foam. However,
the gas phase is discontinuously organized in gas bubbles
[5,6]. Besides that, foam can be generated by flowing gas in
the porous medium with the presence of [7]. The gas breaks
into bubbles that are stabilized by the surfactant solution in a
liquid phase [8,9]. The formation of foam makes gas mobility
become drastically decrease [10,11,12]. Foam can be
classified into three classes namely in-depth mobility control
foam (MCF), blocking/diverting foam (BDF) or also known as
* Corresponding author. Email address: [email protected] (M.Z. Jaafar).
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
231
![Page 2: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/2.jpg)
injection profile improvement foam and gas oil ratio (GOR)
control foam [13].
FAWAG technique could improve sweep efficiency
during gas injection while reducing gas oil ratio (GOR) and
maximizing hydrocarbon production rate in the production
tubing [14]. Foam can be used in EOR method in order to
minimize the gravity overriding, viscous fingering and
channeling problem. FAWAG also provides good mobility
control of gas flow by delaying early gas breakthroughs [15]
and has come out as a new method for well flow
improvement.
II. MONITORING RESERVOIR
Implementation of tracer application in the reservoir
system had been applied in various applications throughout
the world. Basically, the tracer have been used successfully on
many oil field systems to monitor and retrieve flow
parameters, inter-well formation heterogeneity such as high
permeability region and inter-zone communication regime.
Basically, tracer has been used to monitor the efficiency and
reservoir changes cause by EOR processes. These types of
method required high amount of chemical and much testing.
So, the faster and simple measurement required for monitoring
the reservoir during EOR processes and the streaming
potential measurement suggested. So far there has not been a
systematic study of streaming potential measurement as a
method of reservoir monitoring during WAG, FAWAG and
Polymer flooding. In this study the focus is on suggest a new
approach of monitoring the reservoir specifically on
measuring efficiency of designed WAG process, foam rupture
during FAWAG and detection of adsorption polymer during
polymer flooding.
III. EOR STRATEGY
A. Water Alternate Gas (WAG)
Water Alternate Gas (WAG) process is a method to
enhanced oil recovery. WAG method was suggested to control
mobility ratio of CO2. In this injection process, water and gas
are injected alternately for the period of time to provide better
sweep efficiency and lessen gas channeling from injector to
producer line.
In most WAG process, water and gas are injected in
small, alternate slugs rather than simultaneously. Three
reasons are given for the application of alternating injection in
the WAG method: (1) gas and water segregate in the well bore
when injected simultaneously, (2) alternating injection is more
convenient operationally than simultaneous injection, and (3)
the injectivity either fluid remains higher than would be in the
case with simultaneous injection. Injectivity remains higher
for alternating injection because the saturation and hence
relative permeability of the fluid being injected are higher near
wellbore region.
B. WAG Classification
WAG injection process end result mainly depends on
reservoir rock and fluid properties because every reservoir has
their own rock and fluid properties. The accessibility of gas
and its composition play a significant parameter in designing a
WAG process. This is due to the gas compositions are the
main key point in order to select the WAG process either
miscible or immiscible under reservoir conditions [16].
Miscible WAG
Miscible WAG process can be describe as an injected gas is mixable with residual oil under certain conditions which creates an oil bank in front of the miscible zone. Gas miscibility makes an oil viscosity decreasing and this scenario offers an additional benefit of trapped oil mobilization up to the production lines. Furthermore, miscible gas injection has excellent microscopic sweep efficiency but poor macroscopic sweep efficiency due to the gravity override and viscous fingering. However, this constraint can be improved by reducing the volume of injected gas.
Immiscible WAG
Immiscible WAG process explained that the injected gas is not mixed with oil in the pore channels in the reservoir. However, this process can be used to makes unswept zones become connected and also to improve water front stability. There are several reservoirs which suitable for this process such as strong heterogeneity reservoir, low dip angle reservoir, specific gas resources reservoir and gravity-stable gas injection reservoir. Besides that, some immiscible WAG process advantages are advance in pressure support, reduced water handling costs and high production rates.
In the applications of WAG injection techniques, the high mobility and low density of the gas lead the gas to flow in channels through the high permeability zones of the reservoir and to rise to the top of the reservoir by gravity segregation. As a result, the sweep efficiency decreases and the residual oil in the reservoir will be more. Other than that, sweep efficiency also influenced by heterogeneity of the reservoir. To overcome this problem, WAG process need to be monitor.
C. Polymer Flooding
Polymer flooding has been used the polymer solutions to
increase oil recovery by increasing the viscosity of displacing
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
232
![Page 3: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/3.jpg)
water in generating more favorable water and oil mobility
ratio. Polymer technologies have shown the possibilities to be
studied because the viscosity of polymer solution will change
the mobility ratio between water and oil in order to overcome
the water flooding problems [17].
Furthermore, water soluble polymer is injected in order to
increase the viscosity of displacing polymer solution to push
the oil towards the production well. The usage of water
soluble polymer in polymer flooding is mainly because of the
hydrogen bonding between water molecules and polymer side
chain. The basic process of polymer flooding which is
commonly implemented at the end of the good life has been
demonstrated in the Figure 1. The injection of polymer will
flush the remaining oil to the production well with the
intention that the well will keep producing and increase the
recovery of hydrocarbon.
Application of polymers will change the fractional flow
curve and at the same time reduce the effective residual oil
saturation and improve sweep efficiency on less permeable
zones. Moreover, polymer flooding will increase the ratio
between viscous to gravity forces and it also has the ability to
reduce the sinking in order to enhance the vertical sweep in
the reservoir. Even in the presence of underlying aquifer,
polymer flooding still effective with restricted water
channeling through the aquifer. It can be simplified that
polymer flooding will turn the oil recovery more efficient by
through the effects of polymers on fractional flow, decreasing
the water and oil mobility ratio and diverting injected water
from zones that have been swept.
D. Adsorption of Polymer
Polymer adsorption refers to an interaction of polymer
molecules with solid surfaces (Figure 2). This interaction will
cause the polymer molecules to be bound to the surface of
solid mainly by physical adsorption which means a relatively
Fig. 1. Polymer flooding illustration (Donaldson, Chilligarian, & Yen, 1985).
Fig. 2: Polymer Adsorption in Porous Media [19]
Fig. 3. Effect of hydrodynamic forces on polymer adsorption [20]
weak bond between the surface absorbent (rock) and the
adsorbed (polymer), and the forces between both of them are
electrostatic forces [18]. The concentration of polymer in the
water flood decreases and thus the viscosity of the displacing
phase decreases.
Adsorption of polymer molecules on rock surface
occurs by virtue of a lower overall free energy. This
phenomenon is due first to an entropic contribution, where
water molecules are previously bound to the polymer or the
rock surface. It is liberated as the polymer is adsorbed causing
an entropy increase. There is also an enthalpy contribution to
the lower free energy of adsorbed polymer which occurs for
ionic polymer. This contribution results from an electrostatic
attraction or repulsion of the polymer depending on the net
ionic charge of the surface. Previous study suggests that the
dynamic forces increase adsorption density and the adsorbed
layer thickness (Figure 3) [20].
The amount of polymer lost from a bank may large or
small, depending on the nature of the polymer and rock
surface. The adsorption is higher from the saline water than
from the fresh water and the higher polymer concentration
leads to higher adsorption. Adsorption isotherms give at a
particular constant temperature, the dependency of amount of
adsorbed in the equilibrium concentration. Due to the
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
233
![Page 4: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/4.jpg)
adsorption, the polymer solution loses its viscosity during
propagations and affected the performance of polymer
flooding. Factor affecting adsorptions of polymer are polymer
concentration, salinity, temperature and injection rate [21].
Dang et al stated that measurement of polymer adsorption
in the laboratory can be done either using the static method or
dynamic method [19]. For static test, the adsorption mass is
determined by the difference of polymer concentrations before
and after mixing the rock sample. The result may not represent
the field values because the exposed surface of unconsolidated
rock is not the same as in the field. Whereas, for dynamic test,
there are two common experimental methods; Whillhite
method and Dawson method.
E. Structure of Foam
In EOR, foam scale in bubble form is considered. The
bubbles connect each other by thin liquid films which are also
known as foam films or lamellae. The foam films are direct
with liquid phase and the neighbouring foam films via Plateau
borders. These are interconnected throughout the foam
channels which create a continuous liquid phase structure [22].
The foam films are thin free staying layers aqueous
solution surrounded by the gas from the both sides [23,24].
Usually, surfactant molecules adsorb on both film sides and
stabilize the film. The thickness of the foam films is only a
few micro-meters but could be even only a few nano-meters
based on the situation. However, for the ―bulk‖ foam in
porous media, the average bubble size exceeds the length of
the system or in other words the foam can occupy more than
one pore space [10,11].
The Plateau borders connecting the lamellae to water films
wetting the rock surface [25]. Therefore, the liquid phase
becomes continuous throughout the porous formation. These
wetting films on water on the rock can be stable only if the
surface of the rock is hydrophilic (water-wet).
F. Foam Injection Techniques
The most important factors in FAWAG process are foam
placement technique in the reservoir (injection of pre-foamed
foam, co-injection foam and surfactant alternating gas (SAG)
foam), reservoir pressure and permeability [25]. Therefore, in
the field, the manner of foam placement is more diverse as
compared to in the laboratory.
The foam placement technique is closely associated with the
way by the foam is generated hence the terms of foam
generation and foam injection mode are interchangeable.
Generally, the foam is generated when a gas passing surfactant
in aqueous solution which creates a stable dispersion of gas
bubbles and lamellae trains in the liquid. There are three types
of foam injection mode which are pre-foamed foam, co-
injection foam and SAG foam.
G. Tracer in EOR Techniques
By using the tracer system, the understandings of fluid
flow and EOR process have been improved [26]. Tracers are
best describes as a unique reservoir compatible species that is
foreign to the system. Once the reservoir has been injected by
any fluid, the tracer will monitor the injected fluid and allows
important information to be retrieved. Tracer can be divided
into three categories which namely as radioactive, chemical
and fluorescent.
Radioactive tracer is the most commonly used system in
the reservoir due to low detection level. Besides that,
radioactive tracer is a molecule which contains one or more
atoms that are radioactive. These atoms may emit radiation in
extremely low energy beta particles. This radiation can be
absorbed by even thin layer of plastic to more penetrating
electromagnetic gamma radiation which can penetrate into
several inches of metal.
Furthermore, halogen is the most widely used in chemical
tracer. Its detection level requires larger volumes as compared
to radioactive tracer. Fluorescent tracer is safe and can be
easily detected visually and affordable to purchase. However,
this tracer can react with reservoir rock and it is limited to the
noticeable fault or channel reservoir.
However, by using tracer, its take too long to know the
performance of WAG process. Since the tracer was injected to
the reservoir, we need to wait the tracer solution comes out at
the producer.The process takes long time to finish since we
need to wait the tracer comes out from the producing well. To
save the time and cost, other alternative method for
monitoring the WAG process is streaming potential signals.
IV. STREAMING POTENTIAL
Spontaneous potential (SP) also called self-potential, is a
naturally occurring electric potential difference in the Earth. It
can be measured by an electrode relative to a fixed reference
electrode. Spontaneous potential usually caused by separation
in clay or other minerals, due to presence of semi-permeable
interface impeding the diffusion of ions through the pore space
of rocks, or by natural flow of conducting fluid through the
rocks. SP is regularly measured during reservoir
characterization using wireline tools. SP signals generated
during hydrocarbon production, in response in water-phase
pressure (relative to hydrostatic), chemical composition, and
temperature [27].
The presence of the electrical double layer at the solid –
fluid interface will resulted eletrokinetic phenomenon
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
234
![Page 5: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/5.jpg)
(streaming potential) in fluid saturated rocks as shown in
Figure 4a. The mineral surfaces become electrically charged
when surface molecules undergo amphoteric reactions with
the adjacent fluid. The surface becomes positively charge if
the fluid pH values less than that of the point of zero charge of
the mineral. The point zero charge for silica occurs at a pH of
2-3, so the mineral surfaces in the sandstone reservoirs are
usually negatively charged. Adjacent to the mineral surface is
a layer of adsorbed counter-ions in the fluid, which have an
opposite charge to that of the surface, termed Stern layer.
These ions are attached to the mineral surface and immobile.
However, there is an excess of counter-ions in the fluid
adjacent to the Stern layer which are mobile; this is termed the
diffuse or Gouy-Chapman layer. Within this layer, the
concentration of excess counter-ions decreases away from the
mineral surface until the fluid becomes electrically neutral;
known as free electrolyte.
Some of the excess counter-ions within the diffuse layer
are transported with the flow if the fluid is induced to flow
relative to the mineral surfaces. At steady state, the advection
of charge within the diffuse layer is countered by conduction
of charge through the fluid (and rock, if it is conductive).
Thus, with an associated electrokinetic potential, a current is
established. Shear plane is a closest plane to the mineral
surface at which flow occurs in the diffuse layer. The potential
at this plane is termed the zeta potential (Figure 4b). The
electrokinetic potential is a manifestation of this zeta potential.
Fig. 4. The electrical double layer formed at a mineral-fluid interface. (a)
Illustration for mineral-fluid interface when the mineral surfaces react with the
fluid. (b) The electrical potential decreases in magnitude away from the mineral surface. The zeta potential is defined at the shear plane [28].
A. Streaming Potential Theory
The electrical double layer which forms at solid
(mineral)-fluid interface was created streaming potentials in
porous media [29]. A diffuse layer in the adjacent fluid
(contains an excess of countercharge) was formed when the
solid surfaces become electrically charged. If more than one
fluid phase is present in the pore space, additional double
layers may format fluid-fluid interfaces [30]. If the fluid is
persuade to flow tangentially to the interface by an external
potential gradient, and then some excess charge within the
diffuse layer is transported with the flow, giving rise to a
streaming current. Streaming potential is an accumulation of
charge associated with divergence of the streaming current
density establishes an electrical potential.
Measurements of streaming potential by using electrodes
permanently installed downhole have recently been proposed
as a promising new reservoir monitoring technology [28,30].
There are still significant uncertainties associated with the
interpretation of the measurements, particularly concerning the
magnitude and sign of the streaming potential coupling
coefficient at high salinity (Saunders et al., 2008). The
coupling coefficient (C) is a key petrophysical property which
relates the fluid ( P) and electrical ( V) potentials gradients
when the total current density is zero [30,31].
V=-C P (1)
and can which can be used to predict the magnitude of the
streaming potential generated by a given fluid potential. The
coupling coefficient depends upon the electrical conductivity
of the brine (σw) and brine-saturated rock (σrw), the
permittivity (ɛw) and viscosity (μw) of the brine, and the zeta
potential (ζ), which the microscopic electrical associated with
the excess charge in the double layer. It can be expressed as
(Hunter, 1981)
C = (2)
where F is the formation factor (=σw/ σrw) and the Fois the
intrinsic formation factor, measured when the surface
conductivity is negligible (typically with a very saline brine).
Values of the coupling coefficient have been measured
experimentally in several published studies , but only samples
saturated with relatively low salinity brine (less than seawater)
[33]. Formation and injected brine in hydrocarbon reservoirs is
typically more saline than this [30]. According to [32],
coupling coefficient falls to zero at approximately seawater
salinity, rise from extrapolating data obtained at low salinity
into the high salinity. If this is the case, then streaming
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
235
![Page 6: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/6.jpg)
potential signals will be very small in most hydrocarbon
reservoirs [32,34].
Streaming potential measurements have been proposed as
a method to characterize flow in the fractures adjacent to a
borehole, and the pressure response of a reservoir during
transient production test.
V. MATERIALS AND METHODS
Glass bead and sand pack will be used as porous media.
The range selected for the glass bead is 90 – 150 µm. The
advantage using glass beads is enhancing visual observation
and providing consistent permeability and porosity. Other than
that, glass bead also provide clear visual observation of
displacement front. The shape of glass beads is spherical and
has smooth surface. The linear model will be designed to
simulate flow in a horizontal cross section of the reservoir.
The model will be made of glass and Perspex which permits
visual observation of the displacement behavior. Figure 4
shows the picture of the model and its design respectively.
It consisted of a syringe pump, valves, model, pressure
transducer, and collectors. The syringe pump can be used to
set any desired injection rate. A few non-polarizing Ag/AgCl
electrodes will be used to measure the voltage across the
model. The electrodes will be installed along the WAG model.
This electrode will record the flow-rate, voltages and which
can mask the streaming potential signal. Streaming potential
signals will be measured by using NI Data Acquisition
Software (NIDAS).NIDAS is the process of measuring an
electrical or physical phenomenon such as voltage, current,
temperature, pressure, or sound. For this research, NIDAS will
measure the voltage across the model. A pair of pressure
transducers will be measured the pressure difference across
the WAG model and the voltage across the model will be
measured by using Ag/AgCl electrodes.
Fluids system has to be chosen so as to avoid the
necessity of a high pressure and temperature, but then each
phase of reservoir fluid system must be presented by the
substitute fluids. The liquid system used in this study is
refined oil (paraffin), viscous water to represent oil, water and
CO2 respectively at reservoir condition. Scaling requirements
established that the viscosity ratio and density difference of
the various fluids in the model were the same as those in the
reservoir. In this study, these properties of CO2 were kept
constant while the properties of water and oil were changed.
The refined oil was a mixture of paraffin and kerosene. The
kerosene was used to increase the viscosity of the paraffin oil.
In addition, the viscous water was a mixture of glycerol and
brine. The glycerol was used to increase the viscosity water
and density as well. For the polymer adsorption test, The
polymer that applies in these studies is hydrolyzed
polyacrylamide and Polyacrylamides. Then, the polymer
solution will be mixing with calcium chloride (CaCl2) or
sodium chloride (NaCl) with salt concentration up to 20wt %.
Specification detail on linear model using in the polymer test
is cylinder shapes with 10cm long and 3.4cm diameter. The
diagram for polymer flooding testing illustrate as figure 5.
Fig. 4. Schematic diagram of WAG model with streaming potential measurements
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
236
![Page 7: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/7.jpg)
Fig. 5. Schematic diagram of Polymer flooding model with streaming potential measurements
Fig. 6. Schematic diagram of Foam Assisted Water Alternate Gas (FAWAG) model with streaming potential measurements
CONCLUSION
This study is significant because monitoring the
progress of water and gas in a WAG process is key in the
effectiveness of this enhanced oil recovery method.
Measurement of the streaming potential provides another
method besides using tracers to monitor the WAG, foam
and polymer profile. Better monitoring will lead to more
efficient displacement and great benefits in term of
economy and environment. Expected finding for streaming
potential as adsorption detection shows the lower voltage at
the high adsorption condition due to the less free ion in the
solution. High adsorption and lower voltage will occur for
additional CaCl2 compared to NaCl.
Pump
Surfactant
Solution
Pump
Surfactant
Solution
Sampling
P
Pressure
Transducer
P
2
P
1
Sand pack
NIDAS
Electrode
P2 P1
Confining
Pressure
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
237
![Page 8: Reservoir Monitoring of EOR Processes (WAG, Foam and Polymer) Using Streaming Potentialeng-scoop.org/papers2014/IWCPE/9.MohdAnuar.pdf · 2014-09-03 · Water-Alternating-Gas (WAG)](https://reader034.vdocuments.us/reader034/viewer/2022042202/5ea2ecc23a60636b5c1a6902/html5/thumbnails/8.jpg)
ACKNOWLEDGMENT
This work has been made possible to funding by Universiti
Teknologi Malaysia Grant Programme. We would also like
to thank Dr Wan Rosli and PM. Abdul Razak for their
continuous help in preparing the manuscript.
References
[1] M. K. Memon, M. T. Shuker, ―Oil Recovery by WAG Injection
Process: An Overview‖, UniversitiTeknolgiPetronas, 2012.
[2] S.K. Choi, M.M. Sharma, S.L. Bryant and C. Huh, ―Ph-Sensitive Polymers for Novel Conformance-Control and Polymer-Flood Applications,‖ SPE International Symposium on Oilfield Chemistry. USA, April 2010.
[3] H.H. Al-Sharji, C.A. Grattoni, R.A. Dawe, ―Disproportionate Permeability Reduction Due to Polymer Adsorption Entanglement,‖ SPE European Formation Damage Conference, Netherlands, SPE-68972-MS, May 2001.
[4] R. Masoud, S. Sigmund, B.A. Marit, and S. Arne, ―Static and Dynamic Adsorption of Salt Tolerant Polymers,‖ European Symposium on Improved Oil Recovery, Frances, April 2009.
[5] Exerowa, D., and Kruglyakov, P. M. (1998). Foam and Foam Films. Elsevier Science.
[6] Weaire, D., and Hutzler, S. (1999). The Physics of Foams. Oxford:Oxford University Press.
[7] Simjoo, M., Dong, Y., Andrianov, A., Talanana, M., and Zitha, P. L. J. (2011). Novel Insight into Foam Mobility Control. Paper IPTC 15338 presented at the International Petroleum Technology Conference held in Bangkok, Thailand, 7-9 February 2012.
[8] Holm, L.W. (1998). The Mechanism of Gas and Liquid Flow Through Porous Media in the Presence of Foam. SPE Journal. 8(4), 359-369.
[9] Schramm, L.L., and Wassmuth, F. (1994). Foams: Basic Principles in Foams: Fundamentals & Applications in the Petroleum Industry. Schramm, L.L. (ed.). American Chemical Society, Washington, D.C.
[10] Kovscek, A. R., and Radke, C. J. (1994). Fundamentals of Foam Transport in Porous Media in Foams: Fundamentals and Applications in the Petroleum Industry. Schramm, L. L. (ed.). Advances in Chemistry Series, American Chemical Society, Washington, D.C.
[11] Rossen, W. R. (1996). Foams in Enhanced Oil Recovery in Foams: Theory, Measurements and Application. Prud’homme, R. K., and Khan, S. (eds.). New York: Marcel Dekker.
[12] Zitha, P.L.J., Nguyen, Q. P., Currie, P. K., and Buijse, M. A. (2006). Coupling of Foam Drainage and Viscous Fingering in Porous Media Revealed by X-ray Computed Tomography. Transport in Porous Media. 64(3), 301-313.
[13] Turta, A. T., and Singhal, A. K., Petroleum Recovery Institute (PRI)/Alberta Research Council (ARC) (2002). Field Foam Applications in Enhanced Oil Recovery Projects: Screening and Design Aspects. Journal of Canadian Petroleum Technology. 41(10).
[14] Tunio, S. Q., and Chandio, T. A., Faculty of Geosciences and Petroleum Engineering, Universiti Teknologi PETRONAS, Malaysia (2012). Recovery Enhancement with Application of FAWAG for a Malaysian Field. Journal of Applied Sciences, Engineering and Technique. 4(1), 8-10.
[15] Skauge, A., Aarra, M. G., Surhuchev, L., Martinsen, H. A., and Rasmussen, L. (2002). Foam-assisted WAG: Experience from the Snorre Field. Paper SPE 75157 presented at the 2002 SPE/DOE Improved Oil Recovery Symposium, Tulsa, Oklahoma, 13-17 April.
[16] M. K. Zahoor, M. N. Derahman, and M. H. Yunan, ―WAG Process Design- an Updated Review‖, Brazilian Journal of Petroleum and Gas, vol. 5, no.2, 2011.
[17] Wassmuth, F. R., Green, K., Arnold, W., and Cameron, N., 2007. Polymer Flood Application to Improve Heavy Oil Recovery at East Bodo. Volume 48, No. 2, February 2009.
[18] R.F. Mezzomo, P. Moczydlower, A.N. Sanmartin, and C.H.V. Araujo, ―A New Approach to the Determination of Polymer Cooncentration in Reservoir Rock Adsorption Tests,‖ SPE 75204, Tulsa, Oklahoma, April 2002.
[19] C.T.Q. Dang, Z. Chen, N.T.B. Nguyen, W. Bae, and T.H. Phung, ―Development of Isotherm Polymer/Surfactant Adsorption Models in Chemical Flooding,‖ SPE 147872, Jakarta, Indonesia, Sept 2011.
[20] G. Chauveteau, and A. Zaitoun, ―New Insight on Polymer Adsorption Under High Flow Rates. SPE 75183, Tulsa, Oklahoma, April 2002.
[21] M.M. Amro, ―Investigation of Polymer Adsorption on Rock Surface of High Saline Reservoir,‖ SPE 120807, Alkhobar, Saudi Arabia, May 2008.
[22] Farajzadeh, R., Andrianov, A., Krastev, R., Hirasaki, G. J., and Rossen, W. R. (2012). Foam–oil Interaction in Porous Media: Implications for Foam Assisted Enhanced Oil Recovery. Advances in Colloid and Interface Science. 183–184(2012), 1-13.
[23] Bergeron, V., Fagan, M. E., and Radke, C. J. (1993). Generalized Entering Coefficients: A Criterion for Foam Stability Against Oil in Porous Media. Langmuir. 9(7), 1704-13.
[24] Farajzadeh, R., Krastev, R., and Zitha P. L. J. (2008). Properties of Foam Films Stabilized by AOS Surfactant. Colloids and Surfaces A: Physicochemical and Engineering Aspects. 324 (2008), 35-40.
[25] Turta, A. T., and Singhal, A. K., Petroleum Recovery Institute (PRI)/Alberta Research Council (ARC) (2002). Field Foam Applications in Enhanced Oil Recovery Projects: Screening and Design Aspects. Journal of Canadian Petroleum Technology. 41(10).
[26] Z. Z. Abdullah, Z. M. Zain, N. A. Anua, and S. Bhd, ―Application of Radioactive and Chemical Tracer for Offshore WAG Pilot Project‖,SPE 143391, 2011.
[27] M. D. Jackson, M. Y. Gulamali, E. Leinov, J. H. Saunders, and J. Vinogradov, (2010). ―Spontaneous Potentials in Hydrocarbon Reservoirs DuringWaterflooding: Application to Water-front Monitoring‖. SPE 135146 presented at the SPE Annual Technical Conference and Exhibition, Florence, Italy, September 20-22.
[28] M. D. Jackson, J.H. Saunders, E. A. Addiego-Guavera, (2005). ―Development and Application of New Downhole Technology to Detect Water Encroachment Toward Intelligent Wells‖. SPE 97063 presented at the SPE Annual Technical Conference and Exhibition, Dallas, Texas, U.S.A, October 9-12.
[29] R. J. Hunter. (1981). ―Zeta Potential in Colloid Science‖. Academic Press, New York, 1981.
[30] M. Z. Jaafar, J. Vinogradov, M. D. Jackson, J. H. Saunders, C.C. Pain, (2009) ―Measurement of Streaming Potential for Downhole Monitoring in Intelligent Wells‖. SPE 120460, presented at the SPE Middle East Oil & Gas Show and Conference, Kingdom of Bahrain, March 15-18.
[31] W. R. Sill, (1983). ― Self-Potential Modeling From Primary Flows. Geophysics 48 (1), 76-78.
[32] J. H. Saunders, M. D. Jackson, and C. C. Pain, (2006).―Fluid Flow Monitoring in Oil Fields Using Downhole Measurements of Electrokinetic Potential’. Geophysics 73,5.
[33] S. X. Li, D. B. Pengra and , P. Z., Wong (1995). ―Onsager’s Reciprocal Relation and the Hydraulic Permeability of Porous Media‖. Physical Review 51 (6), 5748-5751.
[34] B. Wurmstich and F. D. Morgan, (1994). ―Modeling of Streaming Potential Responses Caused by Oil Well Pumping‖.Geophysics 59, 46.
[35] Wassmuth, F. R., Green, K., Arnold, W., and Cameron, N., 2007. Polymer Flood Application to Improve Heavy Oil Recovery at East Bodo. Volume 48, No. 2, February 2009.
Scientific Cooperations International Workshops on Engineering Branches 8-9 August 2014, Koc University, ISTANBUL/TURKEY
238