The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude
According to the different proportion of making up solution of the binary combination system which use of hydrophobic associating polymer and Sulfonate Gemini Surfactant, determinating of its viscosity and interfacial tension before injection. Simulation of the bohai suizhong 36-1 oilfield actual si...
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| Цитувати: | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude / Ya-nan Wang, Ji-hong Zhang // Functional Materials. — 2017. — Т. 24, № 4. — С. 615-620. — Бібліогр.: 10 назв. — англ. |
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| author | Ya-nan Wang Ji-hong Zhang |
| author_facet | Ya-nan Wang Ji-hong Zhang |
| citation_txt | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude / Ya-nan Wang, Ji-hong Zhang // Functional Materials. — 2017. — Т. 24, № 4. — С. 615-620. — Бібліогр.: 10 назв. — англ. |
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| description | According to the different proportion of making up solution of the binary combination system which use of hydrophobic associating polymer and Sulfonate Gemini Surfactant, determinating of its viscosity and interfacial tension before injection. Simulation of the bohai suizhong 36-1 oilfield actual situation, the constant speed nonsteady state method is used for the determination of permeability ratio curve of water drive and binary combination drive, and the experimental data were processed by J.B.N. Method. Analysis of the pros and cons of existing several kinds of the viscosity processing methods for non-Newtonian fluid flow in the core, put forward a new method of viscosity processing, and compared the binary combination drive relative permeability curve which use of the different viscosity processing method. Laboratory findings show that the binary multisystem flooding in oil relative permeability is higher than water flooding, the water relative permeability is lower than water flooding, SOR is lower than water drive; Mass fraction of surfactant and polymer concentration of the binary multisystem have influence on the permeability ratio curve modality.
|
| first_indexed | 2025-12-01T19:51:51Z |
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Functional materials, 24, 4, 2017 615
ISSN 1027-5495. Functional Materials, 24, No.4 (2017), p. 615-620
doi:https://doi.org/10.15407/fm24.04.615 © 2017 — STC “Institute for Single Crystals”
The study on permeability ratio curve
of polymer/SAA binary system and two-phase
of viscous crude
Ya-nan Wang, Ji-hong Zhang
Key Laboratory on Enhanced Oil and Gas Recovery of the Ministry of
Education, Northeast Petroleum University, Daqing, Heilongjiang, China
Received September 8, 2017
According to the different proportion of making up solution of the binary combination system
which use of hydrophobic associating polymer and Sulfonate Gemini Surfactant, determinating
of its viscosity and interfacial tension before injection. Simulation of the bohai suizhong 36-1 oil-
field actual situation, the constant speed nonsteady state method is used for the determination
of permeability ratio curve of water drive and binary combination drive, and the experimental
data were processed by J.B.N. Method. Analysis of the pros and cons of existing several kinds
of the viscosity processing methods for non-Newtonian fluid flow in the core, put forward a new
method of viscosity processing, and compared the binary combination drive relative permeability
curve which use of the different viscosity processing method. Laboratory findings show that the
binary multisystem flooding in oil relative permeability is higher than water flooding, the water
relative permeability is lower than water flooding, SOR is lower than water drive; Mass fraction
of surfactant and polymer concentration of the binary multisystem have influence on the perme-
ability ratio curve modality.
Keywords: Offshore viscous crude field; Binary combination flooding; Ultra low interfacial
tension; Viscosity processing; Permeability ratio curve
Исследовано влияние бинарной комбинированной системы, в которой используется
гидрофобный связывающий полимер и сульфонатное Гемини поверхностно-активное
вещество на свойства раствора для заводнения пластов нефтяного промысла, его вязкость,
и межфазное натяжение. Предложен новый метод анализа вязкости и проницаемости
ньютоновской жидкости непосредственно в потоке просачивания. Лабораторные результаты
показывают, что влияние бинарного многосистемного заводнения для относительной
проницаемости масла больше, чем просто заводнение воды, относительная проницаемость
воды ниже, чем затопление воды, SOR ниже, чем приток воды. Массовая доля поверхностно-
активного вещества и концентрация полимера в бинарной мультисистеме оказывают
влияние на коэффициент проницаемости бинарного раствора.Проведено моделирование
нефтяного промысла методом нестационарного состояния с использованием J.B.N. метода.
Дослідження коефіцієнта проникності полімеру / SAA подвійної системи і
двофазної в’язкої нафти. Ya-nan WANG, Ji-hong ZHANG
Досліджено вплив бінарної комбінованої системи, в якій використовується гідрофобний
полімер, що зв’язує і сульфонатна Геміні поверхнево-активна речовина на властивості розчину
для заводнення пластів нафтового промислу, його в’язкість, і міжфазний натяг. Запропоновано
новий метод аналізу в’язкості і проникності ньютонівської рідини безпосередньо в потоці
просочування. Лабораторні результати показують, що вплив бінарного багатосистемного
заводнення для відносної проникності масла більше, ніж просто заводнення води, відносна
проникність води нижче, ніж затоплення води, SOR нижче, ніж приплив води. Масова частка
поверхнево-активної речовини і концентрація полімеру в бінарній мультисистемі впливають
на коефіцієнт проникності бінарного розчину. Проведено моделювання нафтового промислу
методом нестаціонарного стану з використанням J.B.N. методу.
616 Functional materials, 24, 4, 2017
Ya-nan Wang, Ji-hong Zhang / The study on permeability ratio curve ...
1. Introduction
The Bohai SuiZhong36-1 oilfield with high
crude oil viscosity, high pore permeability, rel-
atively high salinity and so on, is a typical off-
shore viscous crude field in our country. With
the ongoing of water drive, it has gradually en-
tered the high water cut stage, in order to ex-
pand offshore field after polymer flooding, poly-
mer/SAA binary combination drive reservoir
engineering calculation, numerical analogue
and other works, we should understand binary
multisystem effluent seepage law in the reser-
voir. Therefore, relative permeability curves of
polymer/SAA binary combination drive need to
be measured under the actual conditions of vis-
cous oil reservoir.
Currently there are many abroad stud-
ies about polymer flooding permeability ratio
curve, such as [1] measured the relative per-
meability curves of polymer flooding using the
steady-state method. There are also a lot of
research on chemical flood permeability ratio
curve, for instance, [2] measured the oil-water
relative permeability curve of low interfacial
tension surfactant system. There are many lit-
eratures about determination of the polymer
flooding relative permeability curve adopting
astable method, for example, [3] measured the
permeability ratio curve of surfactant system
and polymer system, comparing with the water
flooding relative permeability curve.
As non-Newtonian fluid, the polymer and
binary compound solution’s viscosity is chang-
ing when flow in the reservoir porous media, so
how to deal with the viscosity has been the key
whether the resulting curve can represent the
actual seepage flow characteristics. This paper,
on the basis of analysis and summary of vari-
ous existing methods, proposes a new approach
to deal with viscosity, and demonstrates its jus-
tifiability.
2. Experimental
Simulation of total salinity water used in
the experiments was 9374.13 mg/L, ion content
of simulation of water in Table 1.
The kind of preparation binary multisystem
polymer is hydrophobic associative polymer
HNT300, provided by CNOOC Research Insti-
tute, a molecular weight of about 1600´104;
The kind of surfactants are Sulfonate Gemini
surfactant BH-M2 [4], provided by Southwest
Petroleum University.
The simulation of oil, used in the experi-
ment mix by crude oil and kerosene by a cer-
tain percentage, under 65°C condition viscosity
70 mPa×s.
The gas experimental permeability of the
artificial core measured about 2500´10–3μm2.
The physical properties of the core used in the
experiments are similar, so it has good repeat-
ed comparative.
There are some apparatus to appraisal phys-
ical and chemical properties of binary multisys-
tem. For example, BROOKFIELD, the digital
viscometer of DV-III, Model TX500C interfacial
tensiometer. The relative permeability curve of
binary multisystem is measuring by advection
pump, air gauge, core holder, Pistons container
and so on. Apparatus except advection pump,
other instruments are placed in an incubator
65°C.
2.1 The measurement of the viscosity
and the interfacial tension before the bi-
nary multisystem injection
To the polymer/SAA multisystem, viscosity
and the interfacial tension have a huge influ-
ence on the relative permeability when the two-
phase of the system have a relative flow. Thus
we measure the viscosity and the interfacial
tension of this composite system to analyze the
influence of these two thing to the relative per-
meability curve in the test.
Viscosity measurement: use the BROOK-
FIELD DV-III to get the viscosity. First use the
NO.0 rotor work for 30 s at the speed of 100rpm,
after asiding for 90 s while perteating, we start
to measure the viscosity; Experiment condition:
NO.0 rotor, 6r/min, g = 7.35 s–1, stay 65°C.
Interfacial tension: use Model TX500C to
get the viscosity of the composite system and
the imitated oil(viscosity of 70mPa∙s); Experi-
ment condition: temperature at 65°C, speed at
6000 r/min.
2.2 The method of viscosity processing
In this study, we use the following method
to deal with the viscosity of the binary multi-
system in the porous media: in the process of
the experiment, the produced liquid is saved after
water appears, and do the separation of oil and
water. Then test the viscosity of the binary mul-
tisystem. As the water just appears, the produced
oil is much more than water, the water separated
is not enough to do the test, so we need to accumu-
late the liquid from several produced times and
make it as the sample in the average PV number.
Then use the different viscosity under different
average PV numbers to fit a curve that viscosity
changes as PV number moves. Then put the PV
number needing to calculate back to the egres-
Table 1 The ion composition and content of
the experimental simulation water
Ionic composition Ion content/mg×L–1
Na+
3091.96
K+
Ca2+ 276.17
Mg2+ 158.68
Cl- 5436.34
CO3
2– 14.21
HCO3
– 311.48
SO42- 85.29
Total salinity 9374.13
Functional materials, 24, 34 2017 617
Ya-nan Wang, Ji-hong Zhang / The study on permeability ratio curve ...
sion formula and get the viscosity at the different
water saturations. Last, calculate the average
number of the viscosity of the injection side and
the delivery end, then you can know the average
viscosity of the binary multisystem in the rock at
different water saturations.
2.3 The determination of the injection
rate
To fit the transfusion of SuiZhong 36-1 oil-
field, the experiment use the speed of
3m/d (0.3m/min). After calculation, the speed
can fit the demand of the test:
m´L´v ≥ 1 (1)
in the formation:
µ – viscosity of the displacing fluid, mPa·s;
L – the length of the test, cm;
v – transfusion rate, cm/min.
So in this test, we use this rate of flow.
2.4 The determination of the binary
combination drive permeability ratio
curve and data processing
Binary multisystem of relative permeability
experimental process and steps of determina-
tion of reference to SY/T5345-2007 rock two-
phase relative permeability in the latest indus-
try standard for measuring method, the experi-
mental data according to the basic formula of
J.B.N. method [5] for sorting and calculated.
2.5 Experimental scheme
For contrast in the binary multisystem of
polymer and surfactant on the influence of the
relative permeability curve, set the following
four experimental schemes, shown in Table 2.
Determination of the static viscosity and the
interfacial tension of the four kinds of binary
multisystem above, using the binary compound
displacement system until no oil produced.
Then the relative permeability curve of the four
kinds of binary combination drive is obtained
by computing.
3. Results and discussion
3.1 Comparison of several different vis-
cosity processing method of relative per-
meability curve
At present, there are many methods for
determination of polymer or polymer sheet bi-
nary compound system flowing in the porous
medium viscosity: the first is the direct use of
fluid into the porous medium before the bulk
viscosity instead; Second is the outlet end dis-
placement stable viscosity fluid; Third category
is obtained from the relation the shear rate and
flow of power law fluid velocity, or demanding
for flow velocity and shear rate and viscosity,
the viscosity of equation transformation, ef-
fectively [6-7]; The fourth kind of method is by
definition the Darcy formula and the resistance
coefficient and residual resistance coefficient,
by the transformation to find the effective vis-
cosity of binary composite system [8-10]. Treat-
ment methods of relative permeability curve as
shown in Figure 1.
Analysis of several methods of the above:
the first kind of processing method is without
considering the non-Newtonian fluid in porous
media, such as the role of the residual shear
viscosity, so the whole is too large, so that the
water phase relative permeability is calculated
systematically larger; While the second meth-
ods only take the drive outlet viscosity for close
to flooding agent for the final state, ignoring
the fluid with viscosity changes and changes
in displacement process in rock, so that the
viscosity is the real viscosity is too large, then
small, also ledding to the aqueous phase calcu-
lated relative permeability changes presenting
the first large then small; The theory of rela-
tionship between viscosity, shear rate and the
flow velocity of the three through third meth-
ods, then transform to get the effective viscos-
ity, rheological equation by the method without
considering the displacement fluid loading on
the rock; Fourth kinds of method to get the ef-
fective viscosity of fluid in rock flowing through
theoretical derivation, to a certain extent, the
retention of binary multisystem in porous me-
dium and the non Newtonian effect, but still
believing that the viscosity of fluid in different
water saturation is the same, which cannot
reflect the two element complex viscosity with
Table 2. Experimental schemes of two ele-
ment composite system
Concentration of
polymer/mg×L–1
mass fraction of
surfactant/%
1 1000 0.05
2 1750 0.05
3 1750 0.2
4 2000 0.2
Fig. 1. Different viscosity approach can obtain
binary compound flooding relative permeability
curve (option 3)
618 Functional materials, 24, 4, 2017
Ya-nan Wang, Ji-hong Zhang / The study on permeability ratio curve ...
the core saturation changes, and the experi-
ment was carried out in oil rock, which cannot
represent the actual reservoir conditions.
The first, second, fourth kinds of method are
in accordance with the viscosity of a constant
into relative permeability calculation formula
of water, so that the relative permeability of
water showed a "Hump" trend, and the actual
process of binary ASP flooding are different,
the seepage law of two element composite sys-
tem were more accurate in in porous media.
But the viscosity method used in this study
considers this point, which can more realisti-
cally rendered the vary of the binary relative
permeablity of oil-binary multisystem in the
reservoir seepage.
3.2 The interfacial tension and viscos-
ity of binary compound system
Table 3 shows three kinds of program about
the results of measuring the interfacial tension
and the viscosity of binary complex system:
compared with Scheme 1, 2 and Scheme 3, 4
can be found, within a certain range, the inter-
facial tension of binary compound system with
the surfactant mass fraction increases while
decreases. Moreover, when the surfactant mass
fraction is 0.2% of the binary compound system
can reach10–3 mN/m magnitude of the ultra-low
interfacial tension; Surfactants on the viscosity
of binary compound system is not obvious.
3.3 Binary combination flooding rela-
tive permeability curves
Figure 1, 2 and Figure 3 is the comparison
between binary combination flooding relative
permeability curves and relative permeability
curves. From the overall analysis can be seen,
relative permeability of flooding phase is small-
er. Analyze the causes, from the computational
point of view, JBN method to calculate the wa-
ter phase relative permeability of the formula
is:
K S K S
f S
f Srw w ro w
w
o
w w
o w
( ) ( )
( )
( )
= ×
µ
µ
(2)
Due to the large heavy oil viscosity, result-
ing in less water, oil viscosity, thus relative
permeability of displacing phase is low. From
the microscopic flooding point of view, due to
the high heavy oil viscosity, flow difficulties,
flooding agent flooding process requires a large
force, but with heavy flooding on a larger flow
resistance also cause flooding agent flow abil-
ity deteriorates. The following analysis of bi-
nary combination flooding relative permeabil-
ity curves characteristics, and the binary com-
pound system of surfactant and polymer effects
on the relative permeability curves.
From the comparison of the water flooding
relative permeability curves and binary com-
bination flooding relative permeability curves
in Figure 2, 3 and 4, we can discover that in
the same water saturation oleic phase relative
permeability of water flooding is inferior to it
of binary combination flooding relative perme-
ability, but it is opposite of the aqueous phase.
The residual oil saturation of binary combina-
tion flooding is inferior to it in water flooding.
From the comparison of the water flooding
relative permeability curves and binary com-
bination flooding relative permeability curves
of scheme 2 and 3 in figure 2, we can discover
that:
– In scheme 2 oil and binary composite sys-
tem relative permeability is somewhat larger
than them in scheme 3, that is along with bi-
nary composite system’s interfacial tension
letting up, oil and binary composite system
relative permeability are larger. This shows a
reduction in interfacial tension, results in the
oil phase and binary composite systems flow ca-
pabilities are enhanced.
– The irreducible oil saturation in scheme 3
is less than it in scheme 2, that is residual oil
saturation in a certain range with decreasing
interfacial tension decreases.
– Two-phase relative permeability largen
analysis: when binary composite system reach-
ing to 10-3 mN/m magnitude ultra-low interfa-
cial tension, that it will drive more oil cannot
flow during high interfacial tension displace-
Table 3. The viscosity and interfacial tension of binary multisystem
polymer
concentration,
mg×L–1
Surfactant mass
fraction, %
static state
viscosity,
mPa×s
interfacial
tension,
mN×m–1
coefficient of
resistance
residual
resistance
factor
1000 0.05 10.1 0.0521 26.2 9
1750 0.05 26.3 0.0436 49.53 12.34
1750 0.2 27.2 0.0047 43 11.06
2000 0.2 33.4 0.0041 56.36 13.58
Functional materials, 24, 34 2017 619
Ya-nan Wang, Ji-hong Zhang / The study on permeability ratio curve ...
ment. Therefore in the same number of im-
mitting PV, interfacial tension reduction, in-
creased oil production and oil production speed.
Result in the oleic phase relative permeability
increases. For binary composite system, on the
basis of capillary pressure formula:
P
rc
ow ow=
2σ θcos (3)
We can get to know capillary pressure is in
direct proportion to interfacial tension. When
binary composite system reaches to ultra-low
interfacial tension capillary pressure is also in-
finitesimally small, the resistance of displacing
phase trail off, it is more beneficial to flowing in
porous media.
Residual oil saturation decreasing analysis:
interfacial tension letting down would result in
oil-water interface fade away, when it reaches
to ultra-low interfacial tension, two types phase
states will interdiffuse, result in miscible flow-
ing, therefore some water film of caecum re-
sidual oil surface would be destroyed, more re-
sidual oil would flow, microscopic oil displace-
ment efficiency enlargement, so the residual oil
saturation in core will reduce.
Figure 3 is water flooding relative perme-
ability curves and binary combination flooding
relative permeability curves of scheme 1 and 2
(surfactants mass fraction both is 0.05%), figure
4 is water flooding relative permeability curves
and binary combination flooding relative per-
meability curves of scheme 3 and 4(surfactants
mass fraction both is 0.2%), contrasting scheme
1 and 2, scheme 3 and 4, we can see:
In the same water saturation, binary com-
bination flooding relative permeability of
scheme 2 and 4 are respectively below scheme 1
and 3. That is the concentration of binary com-
posite system higher, the mobility lower, as in
the figure binary combination flooding relative
permeability reduces; Oleic phase relative per-
meability of scheme 2 and 4 are respectively
high scheme 1 and 3, but change is not obvious.
That is oleic phase relative permeability rises a
little with the increasing of the concentration of
binary composite system.
The residual oil saturation of scheme 2 and
4 are respectively below scheme 1 and 3. That
is for binary composite system, the residual
oil saturation decreases with the increasing of
polymer concentrations.
Two-phase relative permeability changing
analysis: polymer molecules in solution produce
adsorption, mechanical trapping and hydrody-
namic trapping effect in the minds of the rock
pores, roared the wall, and then stranded in the
core, resulting in the flow channel binary com-
posite system narrow down, reduces the fluid
ability of binary composite system in the core;
At the same time, polymer molecule generate
stronger role hydrogen bond with water mol-
ecules, resulting in the absorption of adsorbed
layer to water molecules strengthen and bina-
ry combination flooding relative permeability
significant reductions. Polymer concentration
in the binary composite system higher, these
two functions more intense, reduction of bina-
ry combination flooding relative permeability
larger polymer molecule cannot have much of
an effect on oleic phase flowing, and forming
adsorption layer in the rock wall of the hole, re-
sulting in the pore wall more smooth, the flow
resistance of oil phase flowing in the core lower
to a certain degree, thus resulting in relative
permeability of oil phase become larger.
Analysis for residual oil saturation decreas-
es: polymer molecule mutually could effectively
improve the fluidity of binary composite system,
resulting in the microscopic sweep efficiency in-
creased; On the other hand, because of polymer
viscoelasticity, its stretch elastic deformation
would fill out the partial pressure in the core,
resulting in more residual oil flowing. As a re-
sult, the enlargement of polymer concentrations
would render residual oil saturation lower.
4. Conclusions
Binary compound flooding prepared by use
of hydrophobic associating polymer with sul-
fonate Gemini surfactant in surfactant mass
fraction of 0.1%-0.2%, interfacial tension can
reach the magnitude of 10-3 mN/m.
Analysis of the several current processing
advantages and disadvantages of non-New-
tonian fluid flow in porous medium viscosity,
found that viscosity method introduced in this
paper is more accurate and reasonable.
The oil phase relative permeability of binary
combination drive is higher than water flood-
ing, the water phase relative permeability is
lower than water flooding. Residual oil satu-
ration of binary compound drive is lower than
water flooding.
Fig. 2. Binary combination flooding relative per-
meability curves at different surfactants mass
fraction
620 Functional materials, 24, 4, 2017
Ya-nan Wang, Ji-hong Zhang / The study on permeability ratio curve ...
With the increase mass fraction of surface
active agent in the system of binary compound
flooding, both the additional composite and oil
phase are relatively increased while the resid-
ual oil saturation decreased. With the increase
of polymer concentration in the composite sys-
tem, relative permeability will decrease and re-
sidual oil saturation will be reduced.
Acknowledgements
Project supported by the National Natural
Science Foundation of China (No: 51274070).
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Fig. 3. Binary combination flooding relative per-
meability curves at different polymer concentra-
tions (Mass fraction of surfactant is 0.05%)
Fig. 4. Binary combination flooding relative per-
meability curves at different polymer concentra-
tions (Mass fraction of surfactant is 0.2%)
|
| id | nasplib_isofts_kiev_ua-123456789-136876 |
| institution | Digital Library of Periodicals of National Academy of Sciences of Ukraine |
| issn | 1027-5495 |
| language | English |
| last_indexed | 2025-12-01T19:51:51Z |
| publishDate | 2017 |
| publisher | НТК «Інститут монокристалів» НАН України |
| record_format | dspace |
| spelling | Ya-nan Wang Ji-hong Zhang 2018-06-16T17:14:41Z 2018-06-16T17:14:41Z 2017 The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude / Ya-nan Wang, Ji-hong Zhang // Functional Materials. — 2017. — Т. 24, № 4. — С. 615-620. — Бібліогр.: 10 назв. — англ. 1027-5495 DOI: https://doi.org/10.15407/fm24.04.615 https://nasplib.isofts.kiev.ua/handle/123456789/136876 According to the different proportion of making up solution of the binary combination system which use of hydrophobic associating polymer and Sulfonate Gemini Surfactant, determinating of its viscosity and interfacial tension before injection. Simulation of the bohai suizhong 36-1 oilfield actual situation, the constant speed nonsteady state method is used for the determination of permeability ratio curve of water drive and binary combination drive, and the experimental data were processed by J.B.N. Method. Analysis of the pros and cons of existing several kinds of the viscosity processing methods for non-Newtonian fluid flow in the core, put forward a new method of viscosity processing, and compared the binary combination drive relative permeability curve which use of the different viscosity processing method. Laboratory findings show that the binary multisystem flooding in oil relative permeability is higher than water flooding, the water relative permeability is lower than water flooding, SOR is lower than water drive; Mass fraction of surfactant and polymer concentration of the binary multisystem have influence on the permeability ratio curve modality. en НТК «Інститут монокристалів» НАН України Functional Materials Characterization and properties The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude Article published earlier |
| spellingShingle | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude Ya-nan Wang Ji-hong Zhang Characterization and properties |
| title | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude |
| title_full | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude |
| title_fullStr | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude |
| title_full_unstemmed | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude |
| title_short | The study on permeability ratio curve of polymer/SAA binary system and two-phase of viscous crude |
| title_sort | study on permeability ratio curve of polymer/saa binary system and two-phase of viscous crude |
| topic | Characterization and properties |
| topic_facet | Characterization and properties |
| url | https://nasplib.isofts.kiev.ua/handle/123456789/136876 |
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