Ijciet 10 02_049

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International Journal of Civil Engineering and Technology (IJCIET)
Volume 10, Issue 02, February 2019, pp. 485-492, Article ID: IJCIET_10_02_049
Available online at http://www.iaeme.com/ijciet/issues.asp?JType=IJCIET&VType=10&IType=02
ISSN Print: 0976-6308 and ISSN Online: 0976-6316
© IAEME Publication Scopus Indexed
INVESTIGATION OF SELECTIVE PROPERTIES
OF THE GEL-FORMING COMPOSITION FOR
THE LIMITATION OF WATER INFLOW TO
CARBONATE RESERVOIRS CONDITIONS
A.M. Shagiakhmetov*, I.R. Raupov, A.V. Terleev
Saint Petersburg Mining University, St. Petersburg, Vasilyevsky Island, 21 Line 2, Russia
*Corresponding author
ABSTRACT
The article is devoted to the problem of limiting water inflow in a production well.
The authors consider the main features of the reservoir, which contribute to
premature flooding. This paper presents the basic classification of plugging selective
compositions, outlines the advantages and disadvantages of each type. Gel composed
of carboxymethylcellulose, chromium acetate and copper sulfate was developed for
water production restriction. An alternative way was offered to determine the optimal
concentrations of plugging compositions on the change of the total porosity and x-ray
density measured in the x-ray tomograph. Dynamics of the effective viscosity on the
magnitude of the gap, simulating the fracture was obtained – the viscosity decreases
logarithmically. Filtration experiments confirmed the selective properties of the gel-
forming composition
Keywords: work over, gel-forming composition, rheological properties, selectivity,
carboxymethyl cellulose, water production restriction, x-ray density, carbonate
reservoir.
Cite this Article: A.M. Shagiakhmetov, I.R. Raupov, A.V. Terleev, Investigation of
Selective Properties of the Gel-Forming Composition for the Limitation of Water
Inflow to Carbonate Reservoirs Conditions, International Journal of Civil
Engineering and Technology, 10(2), 2019, pp. 485-492.
http://www.iaeme.com/IJCIET/issues.asp?JType=IJCIET&VType=10&IType=02
1. INTRODUCTION
The modern period of oil production is characterized by the rapid transition of the key oil and
gas fields to the final stage of development, which differs from previous stages by reducing
the rate of extraction, low production rates and high water cut. According to this fact, in the
last decade, oil and gas fields with inhomogeneous reservoirs, high-viscosity and high-sulfur

A.M. Shagiakhmetov, I.R. Raupov, A.V. Terleev
oil have been increasingly developed (Gavrilov and Grunis, 2012; Korobov and Podoprigora,
2018). The development of hard-recover oil and gas fields is difficult both a technically and
often is economically unprofitable. In some cases, it is advisable to eliminate the problems
arising the development of «old» reservoirs. Premature water breakthrough and, in
connection with this, high water cut is one such problem. The solution of this complication is
an urgent challenge for oil production.
This problem is especially relevant for heterogeneous fractured-porous reservoirs, that are
often represented by carbonate rocks. In such oil and gas reservoirs, because of high
conductivity, fractures tend to be the key filtration pathways of formation fluids, while most
of the hydrocarbon reserves can be concentrated in the matrix with a relatively low
permeability (Blazhevich et al., 1981; Basargin et al., 2000; Basargin et al., 2002).
To reduce the increased water cut in well production, repair- insulation work is often
performed. Basically, in the justification of the technology of work over lies the choice of
plugging materials. Recently, when water flow is restricted, methods based on selective
isolation of water saturated intervals are often used. This method consists in a selective
modification of the phase permeability (hydrophobization) of the reservoirs, due to which the
phase permeability through water channels is significantly reduced while maintaining the
phase permeability for oil or gas. There are several classifications of reagents with a selective
method of limiting the inflow of water. According to this classification, the compositions are
divided into hardening, precipitating and gel forming. The disadvantages of the first two
types are high cost, short supply, small mixing zone and poor stability in fractures. To limit
the inflow of water in heterogeneous and fractured-porous reservoirs, the injection of gel-
forming compounds is most often used (Korobov and Raupov, 2017; Tananykhin and
Saychenko, 2017).
Gel-forming composition is based on the combined action of two or more reagents
performing a different function (crosslinker, catalyst, destructor). Gels based on organic
reagents (polyacrylamide, carboxymethylcellulose and "Hypan") allow the creation of large
waterproofing screens, allowing the isolation of fractured layers (McLeod and Coulter, 1966;
Nikitin, 2012; Altunina et al., 2014).
The object for the study is the Tourney-Famen complex of the Menzelinsky oil field. This
object is composed of carbonate reservoirs characterized by high stratification factor, high
heterogeneity and fracturing. A distinctive feature of this reservoir is the high mineralization
of the reservoir water ((Mendonça & Andrade, 2018: Jaramillo, 2018).
2. METHODOLOGY
As a solution to the problem of high water cut, a gel-forming composition consisting of
carboxymethylcellulose, an organic chromium (III) salt and an aqueous solution of copper
sulfate was developed at the Saint Petersburg Mining University. These reagents are non-
toxic, generally available and have a low cost.
Experimental studies of determining the optimum concentrations of reagents, as well as
the rheological, selective and filtration properties of the gel-forming composition were
carried out on the modern and unique equipment of the oil recovery enhancement laboratory
at the Mining University. In this paper, the following parameters were determined: X-ray
density, overall porosity of the gel-formed composition, the dynamics of the effective
viscosity, the residual resistance factor, and selectivity (Podoprigora and Korobov, 2017;
Raupov and Podoprigora, 2017; Raupov and Korobov, 2018).

Investigation of Selective Properties of the Gel-Forming Composition for the Limitation of Water
Inflow to Carbonate Reservoirs Conditions
To determine the optimum copper sulfate concentration in the composition, an
experiment was carried out to determine the X-ray density and the overall porosity of the
composition. The studies were carried out using a Skyscan 1174 X-ray scanner. The scanner
has a closed metal-ceramic X-ray source with a long service life, a scintillation screen, a
CCD camera, zoom lens, a manipulator for positioning and rotating an object with an
electronic system for supplying an X-ray source and a camera and for controlling the
manipulator. It is possible to investigate a three-dimensional model of the studied samples
(core, gel, etc.) and to study the structural characteristics of gel-forming compositions on this
tomograph (Roschin, 2014; Singh and Mahto, 2016).
As for the laboratory experiment, the solution was prepared and poured into a plastic
vessel of 20 ml volume. Further, the composition was scanned, a three-dimensional model of
the gel was created throughout the volume of the vessel. Then, based on the three-
dimensional model, the program calculated the exponent of open porosity. Also, the program
determined the upper and lower limits of light absorption and the number of Hausfield was
calculated as their difference. After cross-linking of the composition, the actions were
repeated.
3. RESULTS
The Hausfield number is used to quantify the X-ray density of substances. In the physical
sense, the Hausfield number indicates a weakening of the X-ray radiation with respect to
distilled water. The results of the studies for determining the optimum copper sulfate
concentration are presented in Figures 1, 2.
Figure 1 Dependence of the difference between the upper and lower limits of the Hounsfield numbers
vs the concentration of copper sulfate
As can be seen from Figure 1, the largest change in the Housefield index between the
prepared composition and the cross-linking is achieved at a copper sulfate concentration of
0.7% by weight. Therefore, it can be assumed that at a given concentration of copper sulfate,
the composition will have the greatest plastic strength.
550
570
590
610
630
650
670
690
710
730
0 0,1 0,2 0,3 0,4 0,5 0,6 0,7 0,8 0,9
TheHausfieldnumber,HU
Concentration of copper sulfate, % by weight
Before cross-linking After cross-linking

Figure 2 Dynamics of total porosity during gel crosslinking
The indication of the total porosity directly affects the density and strength of the gel - the
lower the porosity, the higher the strength, since in the entire volume space of the gel there
will be the least amount of air globules, thereby the gel will be more integral. As can be seen
from Figure 2, with an increase in the concentration of copper sulfate, the porosity index
decreases and reaches its lowest value at a concentration of 0.7% by weight. Further increase
in porosity is due to the supersaturation of copper sulfate, which indicates the optimality of
copper sulfate concentration equal to 0.7% by wt. for a composition with a
carboxymethylcellulose content of 5.5%, chromium acetate 1.0-1.2%.
For the possibility of predicting rheological properties in real fractures and pores, an
experiment was conducted to study the dynamics of the effective viscosity from the size of
the gap to be set. The studies were carried out on Anton Paar's unique MCR 102 rheometer,
which is highly accurate when studying the properties of various liquids. The device is
described in detail in works (Strizhnev, 2010; Coil, 2015; Shagiakhmetov et al., 2018). With
the help of this device, it is possible to change the gap in the "plate-plate" system to simulate
the flow of liquid in a fracture with a gap clearance up to 1 mm. In our case, this possibility
was used to study the behavior of the gel-forming composition in the fractures of the
formation of various gap clearance.
The experiment was carried out as follows. A sample of the gel-forming composition was
placed on the plate, a certain gap and a reservoir temperature of 25° C was set. Next, a shear
rate of 5 s-1
, characterizing the velocity of movement in the formation, was set and the
effective viscosity was measured. During the experiment, the following gaps were
established: 0.2; 0.3; 0.5; 0.7; 1.0; 1.5 and 2.8 mm.
Figure 3 shows the dynamics of the effective viscosity from the size of the gap.
0
5
10
15
20
25
0 0,1 0,2 0,3 0,4 0,5 0,6 0,7 0,8 0,9
Totalporosity,%
Concentration of copper sulfate, % by weight
АC 1,2 Before cross-linking АC 1,2% after cross-linking АC 1,1% before cross-linking
АC 1,1% after cross-linking АC 1,0% Before cross-linking АC 1,0% after cross-linking

Figure 3 Dynamics of the effective viscosity from the size of the gap clearance
The presented graph shows the logarithmic dependence of the effective viscosity on the
gap size. The reliability of the approximation is more than 99%, which indicates a high
probability of predicting parameters such as the induction period of gelling and the effective
viscosity for real dimensions of the formation.
The proposed waterproofing composition consists mainly of water, hence the likelihood
that the gel will penetrate into the highly permeable interlayers, creating an irresistible screen
there, thereby involving a low-permeability part of the reservoir saturated with oil. To
confirm this theory, a filtration experiment was performed to evaluate the selective properties
of the composition. The studies were carried out on a bench consisting of two parallel-
connected core holders and a filtration unit FDES-645 (Coretest System). In the core holders
were placed two cores of the Tournai-Famenian reservoir of the Menzelinsky oil field. One
core was saturated with oil, the other - with formation water (Coil, 2015; Podoprigora, 2017).
The study was carried out in several stages: the determination of phase permeability for
water and oil, the total injection of waterproofing composition in the amount of 5 pore
volumes, holding the cores at rest for 24 hours, remeasuring the phase permeabilities for oil
and water, injecting the destructor and final measurement of the oil permeability and water.
At the end of the experiment, the following parameters were calculated: residual resistance
factor, selectivity coefficient and permeability deterioration (Gaivoronsky et al., 2000;
Podoprigora et al., 2016, Rogachev and Kondrashev, 2016)
The results of the filtration tests are presented in Figures 4, 5 and in Table 1.
Figure 4 Dependences of pressure gradients vs pore volumes when water injecting during an
experiment to assess the selectivity
y = -0,906ln(x) + 1,7878
R² = 0,9906
0
0,5
1
1,5
2
2,5
3
3,5
0 0,5 1 1,5 2 2,5 3
Effectiveviscosity,Pa•s
Size of the gap, m•10-3
0
200
400
600
800
1000
1200
1400
0 2 4 6 8 10 12 14
Pressuregradient,Pa/m•105
Porevolume, unit
Injection of the
composition,
Q = 1 ml / min
Filtration of
water, Q = 0.5 ml
/ min
Filtration of
water,
Q = 0.5 ml / min
Injection of the
destructor,
Q = 0.5 ml / min
Filtration of water,
Q = 0.5 ml / min

Figure 5 Dependence of pressure gradients vs pore volumes when oil injecting during an experiment
to assess the selectivity.
For the oil-saturated core sample, the residual resistance factor after injection of the gel
was 1.24 units, for a water-saturated core sample it was 19.83 units. Thus, the gelling
composition greatly reduces the permeability of the water-saturated fractured core sample,
which confirms its selectivity (Podoprigora et al., 2015; Tananykhin and Shagiakhmetov,
2016; Podoprigora and Raupov, 2018).
Table 1 Results of the filtration experiment for the assessment of the selective effect of waterproofing
composition
Parameter
Unit of
measurement
Before
injection of
the
composition
After
injection of
the
composition
After
injection
of
destructor
Gradient of oil injection
pressure
MPa/m
76,82 95,59 81,7
Gradient of water injection
pressure
4,10 81,25 54,47
Permeability for oil
×10-3
mkm2 0,16 0,12 0,15
Permeability for water 3,62 0,18 0,27
Residual resistance factor for
oil-saturated core sample
units
- 1,24 1,04
Residual resistance factor for
water-saturated core sample
- 19,83 13,30
Factor of selectivity - 16,00 12,78
The factor of selectivity after injection of the composition is 16 units, after destruction of
the gel – 12.78. This once again confirms the selective ability of the waterproofing
composition.
4. CONCLUSION
As a result, it can be concluded that the proposed plugging composition significantly affects
the watersaturated interlayers, reducing the phase permeability for water. Based on the
studies performed, it is possible to draw the following conclusions:
1. An alternative method for determining the optimum concentrations of the reagents of
the gelling agent is proposed, based on the dynamics of the total porosity and the X-
0
200
400
600
800
1000
1200
1400
0 2 4 6 8 10 12 14
Pressuregradient,Pa/m•105
Porevolume, unit
Injection of the
composition,
Q = 1 ml / min
Filtration of oil,
Q = 0.5 ml / min
Filtration of oil,
Q = 0.5 ml /
min
Injection of the
destructor,
Q = 0.5 ml / min
Filtration of
water,
Q = 0.5 ml / min

ray density, depending on the ratio of the components concentrations of the
composition.
2. The dependence of the rheological properties of the gel-forming compositions vs the
size of the gap simulating the fracture is established. The dynamics of the change in
the effective viscosity of the composition vs the size of the gap is logarithmic with a
high confidence.
3. The selectivity of the waterproofing composition was confirmed. The gel reduces the
phase permeability in the water-saturated interval of the reservoir to a greater extent
than in the oil-saturated layer.
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