The Effect of Clay Fraction Quality and Quantity on Petro Physical Characteristics: Smulated Case Study Investigation
Nada Achi*, Benzagouta Mohamed Said, Khodja Mohamed, Lateef Akendji
Department of Geology, University of OEB, Algeria
*Corresponding author : Nada Achi, Department of Geology, University of OEB, Algeria. Tel : +213770259557 ; Email: nadaachi@yahoo.fr; msbenzagouta@gmail.com
Received Date : 17
April, 2018 ; Accepted Date : 19 June,
2018 ; Publisher Date : 25 June,
2018
Citation : Achi N, Said BM, Mohamed K, Akendji L (2018) The
Effect of Clay Fraction Quality and Quantity on Petro Physical Characteristics
: Smulated Case Study Investigation. Arch Pet Environ Biotechnol : APEB-134. DOI
: 10.29011/2574-7614.100034
1. Summary
Reservoirs rocks can be of high economical interest. The porous mediums are allocated to fluid storage and circulation. They can be under the control of diverse parameters when they are found at reservoir conditions. Involvement of clay fraction and type, filling pores, is of high contribution towards the reduction of pore volumes. Similar situation is responsible for the creation of micro barriers, bridges and occlusion. In the case study, investigation based on laboratory experiments has revealed, that, reservoir is mainly controlled by compaction in addition to the type and fraction of simulated cement. It has been found that impact on petro physical characteristics was down to the type of clay, beyond burial pressure, grain-to-grain degree of contact related to grain textural type. The overall results reveal that sandstone with illite clay fraction is better concerned with permeability and porosity development and preservation. Thus, similar statement leads to efficient fluid circulation and better recovery.
2. Keywords: Artificial Cores; Permeability; Porosity;
Reservoir
1.
Introduction
It is known that reservoir
systems can be made of different types of essentially sedimentary lithology, composed
of types of mineralogy, grain sizes, pores, pore throats and their geometry. Investigation
in that purpose has been led by different researches [1-2]. Control on detailed
reservoir characterization and, for better understanding, can be approached
through its physical properties: formation testing, and laboratory analysis services
[3-5]. Introduction and investigation on artificial reservoir rock behavior and
fluid circulation can be an issue for the optimization of the reservoir
lifetime performance prior to a real and natural reservoir [6]. Previous investigations
have focused on the combined effects of fluid saturation, potentials and Petrophysical
characteristics required in achieving the desired reservoir quality [7].
However, the inter-relationship between the complex reservoir rock
morphology and fluid circulation potential, in relation to variation of
textural and physical properties, is yet to be entirely understood. Thus,
the purpose of this research is to establish the degree to which the
permeability of synthetically generated sandstone samples varies based on clay
cement injection. The selected sandstone was of a mixture of different textural
and physical properties. Complex geological internal arrangement with grain
size distribution, composition, morphoscopy, injected clay mineral types and
fraction, compaction and pressure and the degrees of heterogeneity of material,
are the most considered parameters in this investigation. Focus on other in
situ parameters controlling fluid circulation such as, the shape factor,
tortuosity coefficient and pore radius and pore shape geometry are equally involved
in the change of fluid circulation potential.
In this case study, locally selected quartz dominant
sand quarries were obtained on the basis of textural and physical properties. The
configuration and physical properties of the artificial model are similar to
Berea Sandstone, Dundee Samples, Split Rock - Liver Rocks or Ohio Sandstone
Samples (USA). Beyond the obtained results, the adopted procedure can be faster
and less expensive prior to natural reservoir cores analysis use.
2.
Equipment and Methods
Materials were identified on the basis of textural
particle size analysis by sieving fraction distribution and sedimentometric
analysis for dispersed sediments: detrital sediments with quartz dominant
minerals (Figure 1).
Collection of sands from different Algerian sites (Table
1) in addition to well-known clay minerals (bentonite, kaolinite and illite)
Chemical analysis and cleaning was also achieved in the laboratory for the purpose of expelling undesired compounds prior to the mixture step. This cleaning process is targeting material less than 2μm using sedimentometric sieving [8].
2.1 Morphoscopic Grain Analysis was also Made
2.1.1 Cores preparation
Sand
mixed with each type and amount of clay was prepared. The overall is
pressurized progressively up to normal reservoir conditions pressure around
8000ft, thus, artificial compaction corresponding to natural reservoir burial
was generated. Cores are obtained according to the cylindrical odometer core
holder (Figure 2)
2.2
Experimental Procedure
Grain Size Analysis and
Grain Size Distribution (GSA and GSD) and sedimentometric process worked out
from collected material were restrained to some parameters calculation e.g.
uniformity coefficient (CU), Фd (grain diameter) and fine grains fraction. This
procedure was aimed to better characterization of the material. Analysis was
made using French norms (NF P94-056). Results are illustrated through a semi logarithmic
graph, designed to screening the dispersion spreading grain size intervals versus
cumulative weight percent. Oute comes were illustrated graphically as shown in Figure
1. Sedimentometric analysis was also brought out. Its application was conducted
to fine grains less than 80µm analysis according to the French norms (NF
P94-057). This method is mainly based on Navier-Stockes equation where fine
material movement and settlement is related to particle density, particle
diameter, fluid viscosity, gravity and velocity. However, the overall of this
process was to assess the Particle Size Distribution (PSD) which can greatly
affect the efficiency of fluid circulation prior to any clay injection. This
extra amount of clay might introduce an additional out of control obstacle,
when it consists on the filterability of the liquid versus the mentioned
particle size present. Tools used for
that purpose are mainly at sedimentometric scale measurement set in the Geotechnical
Laboratory (Figure 3) (Table 2)
Data analysis in that
use has revealed the expanded curves outcomes where material is fluctuating
from sand dominant amount to silt fraction with a lesser amount of clay portion
(Figure 2). Based on the obtained graph, it is known that, once mixed, similar
material will result on any required heterogeneity statement. Subsequently, similar
material with related extending intervals will affect petro physical
characteristics in dissimilar ways. Obtained
results (Figure 2) allow, as mentioned previously, the calculation of
parameters such as coefficient of uniformity based on d60 and d10
(in mm) and Curvature factor according to the formula
Cc= (d30)2
/ (d10.d60)
Cu: The Hazen Coefficient of Uniformity
Cc: The coefficient of curvature
di: diameter
corresponding to i% of percentage of cumulated sieve
These material parameters calculation are carried out to view the gradation impact versus permeability (K) and porosity determination beside heterogeneities effect. These factors express also the particles size distribution, which has a direct impact on the considered material physical properties.
2.3 Permeability Measurement
Regardless both petro
physical characteristics which were targeted in this investigation, our action
in this research is focusing mainly on the permeability or the hydraulic
conductivity changes based on the process of consolidation (load or
discharges). We have to stress that cores preparation was made by system of
consolidation: air expulsion in a vacuum prior to water saturation. Thus,
behavior of rocks on subsurface can be similar to the soil but under certain pressure
and temperature conditions [9].
In the case study,
permeability was measured at ambient temperature (20°C). The
permeability measurement was made according to the following operating mode and
under the experimental norms XP CEN ISO/TS 17892-11. The modal type is an œdometer
consisting of:
-
Œdometer host Graduated Piezo metric tube, Water
disposal feeding with 3 spot water,
-
Œdometric cell for drainage (flow rate)
-
Oedometric ring and chronometer
Related principle is allowing the variation in porous medium and expulsion of certain fluid. The flow rate change can be noticed through the variation of water column head feeding. Ability and variation in sample hydraulic conductivity performance is up to the sample physical and petro physical attributes under the set conditions of pressure, clay type and fraction. Thus, results under these conditions reveal the reservoir behavior: reservoir characterization and changes.
3. Results
3.1 Permeability Results
3.1.1 Review on permeability measurement
More details in that
purpose can be from the use of hydraulic conductivity where calculation of K
using statistical parameters determination can be stated on the basis of Graphic
Geometric Mean (GMe), effective grain size (C) [10] Permeability
calculation or hydraulic conductivity can be deduced from:
K: intrinsic permeability (Darcies)
Gmd: geometric mean grain diameter
σ: standard deviation
Thus, most poorly, moderate or well-sorted particle size distribution with a lesser or greatest size distribution classes is directly affecting the petro physical properties. It will reveal the mixture distribution and then the heterogeneity system. Similarly, the porosity can be calculated from statistical grain size distribution method thus [11]
For permeability calculation, diverse equations can be used essentially for soil drainage, engineering properties seepages [12-14]. Several empirical equations have also been proposed for the evaluation of the coefficient of permeability. One of the earliest method is that proposed by [15]. He developed the well-known empirical equation:
K=C(d10)2
K: coefficient of permeability “conductivity” (Cm/s)
d10: effective size (mm)
C: constant, varying from 1.0 to
1.5
Support for the evaluation of permeability measurement
and evolution can be from the determination of porosity with the involvement of
grain size distribution, mean, and median [16-18]. In related approach, the Kozeny
and Carmen equation, (1939) where permeability determination, in a single
phase, cannot be established without grains properties such as: Grains Volume
(gv), Specific Surface Area (SSA) and porosity determination. The equation can
be set as:
In the case study, the experimental investigation and
k determination were defined according to the method XP CEN ISO/TS 17892-11 and
Hazen (1937):
A: piezometric tube
section (Cm2)
S: pipe section (Cm2)
H: pipe thickness (Cm)
h: reading of
peizometric tube level changes “differential head of water changes” (Cm)
t: time changes in readings
(s)
Under different types
of clay injection and their rate, the permeability measurements results were (Table
3). The obtained results were depending on each statement we scheduled: clay
injection type and rate, pressure effect and grain characteristics.
However, these Permeability
laboratory results according to pressure effect have indicated diverse gradient
decreasing changes. These petro physical transformations are ascribed to the
level of burial. Pressure gradient was a principal factor in that purpose [19].
Another significant in that cause is from the type and fraction of clay
injection.
4.
Discussion
Variation of
permeability versus clay types and fraction is not similar according to the
variation in depth. According to the following obtained model: clay fraction,
type and depth versus petro physical parameters, (mainly permeability), we set
up that, permeability change is relatively erratic versus each involved
parameter (Figure 4,5 and 6). However, the general tendency is towards the
decline of the permeability (k) but, respectively to each type, amount of clay and
considered depth. This decrease is in harmony with the increase of each depth
and clay fraction. The most harmful clay type is bentonite, with a lesser extent
to illite with regard to kaolinite effect.
Using similar records
and with reference to Boursier graphic adapted to the case study results. (Figure
7).
However, the focus on
the permeability changes can be related to clay properties where their
hydrophilic and hydrophobic properties play an essential role in that principle.
It is known that clay minerals are composed structurally by alumino-Silicate hydrates,
which are associated with some cations (Ca, Na, Mg, K and Fe) on the surface.
The presence of similar ions can be responsible for the properties changes of
the minerals. In the presence of water, similar ions will be hydrated leading
to a considerable increase of their diameter. This increase is up to the
cations concentration and also to the specific Surface Area of the Grain (SSA) [20].
The change occurring is associated to the Cations Exchange Concentration (C.E.C).
Similar occurrence conducts to the adsorption phase. Occurrence is more important
with bentonite Clay (SSA 800m2/g) rather than illite (SSA 100m2/g)
or kaolinite with (10 to 20 m2/g). For sands sample specific area, we
know that it cannot exceed 5m2/g. Similar process is encouraged by
the typical structure of clay as phyllosilicates or interlayers arrangement
leading to differential swelling process. Thus, this swelling becomes
responsible for the reduction of pore spaces and impeding fluid circulation.
The clay growth plays an important role in creating bridges and occlusion
resulting on the inhibition of fluid circulation [3,6]. In addition to this,
simulated cores with material physical properties, starting from particle size distribution
(PSD) up to the pore size distribution. These parameters are also involved in
the permeability control regarding the different rock measurable and determined
properties: shape factor, tortuosity coefficient, pore radius, and textural
grain parameters including consolidated grains degree. The overall is issued
mainly from the compaction factor, which is the main source in that regard. All
these parameters are implicated in the effect of the flow pattern and fluid
circulation within the porous medium [21-26].
In our case study, the artificial material arrangement
with the synthetic cement filling pores cannot certainty reveal the real
reservoir. They can be representing the host of H-C reservoirs storage and
circulation, under some reserves. We approached this simulation without
including the diagenetic effect responsible for occlusion and secondary pores
generation. Similar processes are able, and up to a certain degree, to change
the reservoir porous medium characteristics. The simulation is intended to
investigate in the field and to build up any reservoirs with some essential
records, allowing better understanding, and saving massive real material prior
to consuming authentic reservoir cores. However, and in the case study, advantage
in hydraulic conductivity simulated discrepancy can be receptive since detailed
changes in the artificial model, we build up, can be under control. But, we can
be convicted that, the led investigation is not reflecting a real reservoir since;
we are not able to control the real in-situ parameters behavior.
5. Conclusion
Reservoirs rocks and porous
medium can be of high economical interest. The porous mediums are allocated to
fluid storage and circulation. They can be under the control of diverse
parameters when they are found at reservoir conditions. Involvement of clay
fraction and type, filling pores, is of high contribution towards the reduction
of pore volumes. It is responsible for the creation of micro barriers and
occlusion for fluid accumulation and mobility. In the case study, investigation
based on laboratory experiments has revealed, in that regards, that reservoir
is mainly controlled by compaction in addition to the type and fraction of
simulated cement. It has been found that impact on petro physical
characteristics was down to the type of clay, beyond pressure and grain texture
type. Kaolinite clay mineral type was the less harmful with regard to the
permeability and porosity in comparison to illite and mainly bentonite.
However, in the presence of aqueous solution, swelling intensity was higher with
bentonite mineral in comparison to kaolinite and illite. During drainage and
essentially the imbibition, impact from the wettability (soaking and suction) system
was defined. Results were in harmony with the imbibition rather than drainage
at atmospheric conditions. Within the diphasiques phases, imbibition supports
the hydrophilic character of the bentonite illite clay minerals, whereas the
kaolinite was as hydrophobic. Thus, and regarding the reservoir, sandstone
reservoirs with the presence of kaolinite are better reservoir characteristics
but hydrphobe. Reservoirs with bentonite clay fraction are less petro physical characteristics
development; even so, it is important to mention that bentonite is hydrophilic type.
The overall results reveal that
sandstone with illite clay fraction is the better concerned with permeability
and porosity development or preservation leading to efficient fluid circulation
and recovery.
Figure 1: Indicating the sampling versus Particle Size
Distribution (PSD) at different located areas.
Figure 2: Indicating the sand - samples preparation and mixture
with clay injection type.
Figure 3: Showing the used material in the
laboratory for the purpose of measuring the less than 2μm fraction contained in
the selected samples.
Figure 4: Indicating the effect of clay
type and fraction versus depth on permeability decline (case of bentonite).
Figure 5: Indicating the effect of clay
type and fraction versus depth on permeability decline (case of kaolinite).
Figure 6: The effect of clay type and fraction versus depth on permeability reduction(Case of illite).
Figure 7: Illustrating results on the
decline of petro physical characteristics based on overload pressure and clay
type -injected fraction.
Sampling |
Situation |
Lambert
coordinats |
||
Y |
X |
Z(m) |
||
P1 |
Sand
quarry Hamma Bouziane - Constantine, Algeria |
6°33’44.70’’E |
36°25’40.72’’N |
387 |
P2 |
PK224 Zighoud Youcef - Constantine, Algeria |
6°43’16.34’’E |
36°31’13.77’’N |
606 |
P3 |
Sand quarry Elma Labiod - Tebessa, Algeria |
8°05’50.21’’E |
36°25’40.72’’N |
1089 |
P4 |
Sand quarry Cheria - Tebessa, Algeria |
7°58’10.31’’E |
35°14’40.27’’N |
1191 |
P5 |
Sand quarry Boussaâda - M’sila, Algeria |
4°07’01.16’’E |
35°15’04.86’’N |
671 |
Table 1: Localization
of collected samples.
Size |
P1 |
P2 |
P3 |
P4 |
P5 |
D
max (mm) |
5 |
5 |
2 |
1 |
0.4 |
2mm |
96% |
85% |
98% |
99% |
100% |
80µm |
15% |
13% |
4% |
5% |
2% |
60µm |
13% |
13% |
/ |
/ |
/ |
2µm |
6% |
7% |
/ |
/ |
/ |
Cu |
6.66 |
15.71 |
3.33 |
4.58 |
1.83 |
Cc |
19.26 |
2.29 |
1.04 |
0.60 |
0.96 |
Curve
Classification |
Expanded
and continuous |
Expanded
and discontinuous |
Tight
curve |
Tight
curve |
Tight
curve |
Table 2: Results of Pore Size Distribution (PSD)
analysis supporting the outcomes of Figure 2 with Cu coefficient of conformity
and Cc curvature coefficient.
1-1 |
6.5 |
Low |
35%
bentonite |
1-2 |
6.1 |
Low |
|
1-3 |
6 |
Low |
|
2-1 |
10.5 |
Very
low |
25%
bentonite |
2-2 |
9.5 |
Low |
|
2-3 |
8.2 |
Low |
|
3-1 |
88.6 |
Moderate |
15%
bentonite |
3-2 |
78.3 |
Moderate |
|
3-3 |
76 |
Moderate |
|
4-1 |
91 |
Moderate |
35%
kaolinite |
4-2 |
82.5 |
Moderate |
|
4-3 |
76.5 |
Moderate |
|
5-1 |
160.5 |
Moderate |
25%
kaolinite |
5-2 |
104 |
Moderate |
|
5-3 |
90 |
Moderate |
|
6-1 |
272 |
Well |
15%
kaolinite |
6-2 |
247.8 |
Well |
|
6-3 |
219.3 |
Well |
|
7-1 |
79.6 |
Moderate |
35%
illite |
7-2 |
76 |
Moderate |
|
7-3 |
73.6 |
Moderate |
|
8-1 |
157.5 |
Moderate |
25%
illite |
8-2 |
90.2 |
Moderate |
|
8-3 |
83.2 |
Moderate |
|
9-1 |
213.7 |
Well |
15%
illite |
9-2 |
207.8 |
Well |
|
9-3 |
180.5 |
Moderate |
Table 3: Permeability
Results with K classification and clay type in addition to clay type and rate.
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