Introduction

The primary objective of a hydraulic fracturing treatment is to increase the well productivity by creating a highly conductive path compared to the reservoir permeability. Fracture conductivity has been under investigation since the inception of hydraulic fracturing.

In 1975, Cooke introduced Effect of Fracturing Fluids on Fracture Conductivity, Kozeny model was used by Cooke to measure the residue amount in the proppant pack compared to the permeability predicted. But the temperature and long-term conductivity were not investigated (Cooke 1975). In 1985, the effect of fracturing fluid on proppant conductivity was studied by Kim (1985) using an API cell. Permeability impairment of 30% to 50% was reported for polymer concentrations between 40 and 100 lb/1000 gal. However, the damage associated with the gel at extended time in the proppant pack was not considered. Roodhart (1986), Penny (1987) and McDaniel (1988) introduced a complex experiment to simulate field conditions by allowing fluid leak-off through the core during pumping and closure. However, they did not investigate the effect of all parameters at extended time, and the experiment was very complicated. In 1987, a drop of 85% was observed after introducing Ohio sandstones to replace the steel pistons, temperature was increased to 65 °C or 120 °C, and the closure pressure was applied for 50 h (Palisch 2007). However, the fracturing fluid damage was not taken in consideration. In 1989, the proppant pack conductivity standard procedures were developed by the American Petroleum Institute (API) using Cooke conductivity cell and were documented under (API RP 611989). Generally, 2 lb/ft2 of proppant concentration between two steel pistons maintaining closure pressure for 15 min, pumping 2% KCl at 2 mL/min to measure the proppant conductivity. Nonetheless the procedures did not include the damage associated with the fracturing fluid at extended time. Samuelson and Constein (1996), presented laboratory data of degraded fracturing fluids at temperatures above 80 °C using laboratory fracture conductivity results and residual polymer analysis. The experiments did not include the study of the parameters mentioned at extended time more than one day.

In 2000, proppant conductivity was investigated by Mathew Samuel et al. (2000) using Viscoelastic surfactant fluid, Field results have shown that ~ 85% and 100% retained conductivity for the proppant pack was recorded. However, this type of fluids is very expansive and not usually used in Algeria. In 2006 (International Standard 2006) was published replacing the API RP 16 for long-term conductivity testing, the procedures consist of applying the closure stress for 50 h ± 2 h, when the 2% KCl fluid is forced into the cell the flow rate, proppant width and temperature are measured (Kaufman 2007). But the procedures did not include the effect of fracturing fluid on proppant conductivity. In 2015, a new method of proppant pack permeability assessment was proposed by Lutynski (2014) where proppant is placed into a rock sample with induced fracture. The rock sample was a Tumlin sandstone. Different confining pressure were applied (3–16 MPa). However, this study focused on the damage caused by the stress. In 2018, (Abhinav Mittal 2018) et al. used a conductivity cell made to measure the fracture permeability applying an axial load of 5000 psi using Brine at 120 °C, over extended time (10–60 days). However, the effect of polymer was not investigated. In 2019, (Sterling Richard 2019) et al. improved the proppant conductivity measuring method published by API by adding the vibration for more repeatable grain packing structure and compact structure. But all other procedures were kept the same with no fluid damage.

While significant progress has been made in the effort to realistically evaluate and quantify proppant pack permeability due to gel damage, very little has been disclosed to study the effect of stress, fracturing fluid and temperature at extended time before cleanup on proppant conductivity.

By January 2019, almost 500 wells have been hydraulically fractured in Hassi Messaoud, fracturing treatments performed in this field differ significantly from others. To maintain the current production levels, stimulation treatments are continually performed to improve the reservoir recovery (Soto Maldonado and Aoun 2019), however conventional stimulation technologies such as matrix acidizing and water-based propped fracturing treatments with polymer fluid system often have insufficient results (Table 1, well 1 and 7). This circumstance can be explained by unachieved planed fracture geometry parameters and low retained fracture conductivity due to gel damage from high polymer loading and the time taken between the closure and cleanup operation (Table 1, well 6 and 7), this delay is mainly because of the unavailability of Coiled Tubing units due to high well interventions activity and because of the extra cost of working at night shifts.

Table 1 Data of 10 wells fractured in Hassi Messaoud between 2018 and 2020
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In Hassi Messaoud field, this phenomenon is very commonly observed, below resumed in Table 1 are 10 wells fractured in Hassi Messaoud, the period between the fracturing treatment and the cleanup operation, the production rate before and after the treatment are regrouped as well.

Relatively high viscosity fluids are used to transport proppant into the fracture. Leaving a high viscosity fluid in the fracture would reduce the permeability of the proppant pack to oil and gas, limiting the effectiveness of the fracturing treatment (Penny 1987; Brannon 1992).

The objective of these study is to determine the effect of the fracturing fluid concentration at extended time under fracture stress and formation temperature and what will be the effect of time on fracture permeability under the mentioned conditions.

This paper, therefore, will conduct series of experiments simulation to identify the effect of the mentioned parameters on fracture conductivity under bottom-hole conditions using a self-made cell which is simple, robust and original.

Materials

Proppant

To simulate the effect of pressure, fracturing fluid and temperature two types of proppant were selected: 20/40 bauxite and 30/50 bauxite (Fig. 1) which are the most types used in Hassi Messaoud field.

Fig. 1
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20/40 and 30/50 HSP Proppant used

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According to ISO 13503-2:2006 standard, the sphericity, roundness, mesh size and specific gravity of proppant represented in Table 2 were tested, a microscope Bresser 5,013,000 (300–500 μm) was used to assess the sphericity and roundness for proppant grains using Krumbein/Sloss diagram (Fig. 2). Due to the high stress profile recorded in Hassi Messaoud zones, high strength proppant type was used in the proppant testing.

Table 2 Mesh size, sphericity and roundness results of proppants used
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Fig. 2
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Krumbein/Sloss diagram for visual assessment of sphericity and roundness (International Standard, I. 1.-5 2006)

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Guar

Because of their low cost, high performance and ease of handling, water-base fluids are the most widely used fracturing fluids (Economides 2000), they are the most type used in Hassi Messaoud at concentration between 25 and 40 lb/1000 gal, thus Guar gel powder was used to prepare the linear gel in this experiment. Guar is a long-chain (Figs. 3, 4), high-molecular-weight polymer composed of mannose and galactose sugars (polysaccharides) (Whistler 1959).

Fig. 3
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Guar structure (Economides 2000)

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Fig. 4
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Guar sample used in tests

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It has been estimated that fluid loss during the treatment and during closure increases the polymer concentration in the fracture after closure thus concentrations used to prepare the linear gel as base fluid was between 50 and 200 lb/1000 gal, because the post-closure polymer concentrations can reach 200 lb/1000 gal to 1000 lb/1,000 gal which is 5 to 7 times surface concentration times (Penny 1987) and can reach 20 times (Hawkins 1988) and result in reduced fracture permeability, and therefore fracture conductivity. The fracturing fluid temperature and breakers concentration affects the fracture permeability as well. Crosslinked polymers compounds are difficult to displace, causing significant damage to the proppant pack permeability.

Crosslinker

Several metal ions can be used to crosslink water-soluble polymers (Conway et al 1980). Borate, Ti (IV), Zr (IV) and Al (III) compounds are frequently used crosslinkers. The borate compounds (Deuel 1949) react with guar through cis–OH pairs on the galactose side chains to form a complex, as illustrated in (Fig. 5).

Fig. 5
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Borate crosslinked guar (Barati 2011)

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Boric acid represented in Fig. 6 was used as crosslinker as it is one of the most types used in Hassi Messaoud region, a concentration of 10 gal/1000 gal was used to prepare the crosslinked fluid for proppant permeability testing.

Fig. 6
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Proposed crosslinking mechanism (Menjivar 1984)

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Breakers

Gel breakers are used to reduce the viscosity of the fluid intermingled with the proppant. Breakers reduce viscosity by cleaving the polymer into small-molecular-weight fragments. The increased polymer concentration causes a major increase in viscosity. For example, the viscosity of an unbroken guar fluid containing polymer at 200 lb/1000 gal (20 lb/1000 gal) gel concentrated 10 times because of fluid loss (Pope, 1994). The viscosity of the gel and the molecular weight of the polymer should be significantly reduced to allow rapid cleanup of the sand pack (Almond 1984; Gall 1985).

Inorganic and organic peroxides have been described in the literature (Bielewicz 1998). These materials degrade the polymer chains by oxidative mechanisms, and they are usually used as breakers in Hassi Messaoud area, thus sodium bromate (Fig. 7) were used in the experiments for proppant permeability measurement.

Fig. 7
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Sodium bromate breaker

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Distilled water and gasoil

Deionized water was used to prepare the linear gel, and Gasoil was injected into the cell for proppant permeability measurement.

Sonatrach Gasoil was used to simulate the oil which circulates inside the fracture and which is the responsible for cleanout process. Sonatrach Gasoil viscosity is 0.30 cP.

Methodology

Self-made confinement cell

In order to measure the permeability of the core sample filled with proppant a self-made permeability confinement cell was proposed (Fig. 8). Inox steel piston was constructed to be filled with proppant and fracturing fluid and subjected to a calculated stress under a constant temperature using different gel concentrations and at extended time.

Fig. 8
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Self-made Piston components

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The piston has a diameter of 4 cm, a length of 15 cm, inlet and an outlet of 2 mm. More details are represented below in (Figs. 9, 10, 11).

Fig. 9
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Cylinder of Self-made Piston for proppant permeability measurement

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Fig. 10
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Piston of Self-made Piston for proppant permeability measurement

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Fig. 11
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Plug of Self-made Piston for proppant permeability measurement

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The cell is composed of three parts, the first one is the cylinder which has a thread at its base, the second part is the Piston which is equipped with O rings to insure the sealing and the third part which is the plug with a thread to close the base part of the cylinder. The piston contains also nuts to maintain the pressure applied on proppant inside the cylinder.

Hydraulic press

To simulate the pressure applied on proppant in the fracture, Big Red hydraulic press (Fig. 12) was used with max force of 10 tons. This press was used to apply the pressure required for proppant permeability measurement. This compact press includes a pressure gauge registering the tonnage being applied.

Fig. 12
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Big Red 10 Ton Hydraulic Bench Type Press

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Universal oven UN30

Temperature is a very important parameter in hydraulic fracturing and to ensure that the universally applicable lab oven U which is Memmert’s classic appliance was used for temperature control in proppant tests. This oven can be monitored by selecting the time and temperature desired for tests.

Permeability measurement installation

The installation is composed of pipes, valves, fuel pump and manometers (0 to 35 bars) as represented below (Figs. 13, 14). The injection pump used to measure the proppant permeability is designed to be compatible with fuel injection. To calculate the permeability of the proppant pack, the below installation was used to generate the data.

Fig. 13
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Installation schematic of the permeability measurement of proppant

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Fig. 14
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Installation schematic of the permeability measurement

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Operatory method

The preparation steps are regrouped in the below points:

  1. 1.

    The linear gel fluid was prepared by mixing distilled water and the Guar powder using Overhead Stirrer AM120Z-H mixer for 30 min at 1200 rpm to have the desired concentration (Exp: 4.2 g/L is equal to 35 lb/1000 gal), The pH of the mixture was 7.5 to 8 using Xingweiqiang pH meter, and the viscosity was 34 to 36 cP at 25 °C using Viscosimeter Fann 35.

  2. 2.

    The sodium bromate breaker was added to the linear gel at 20 lb/1000 gal, which is the concentration usually used in borate crosslinked fracturing fluids used in Hassi Messaoud. The breaker concentration was varied from 0 to 25 lb/1000 gal to check the breaker effect on proppant permeability.

  3. 3.

    The proppant and borate crosslinker were added accordingly the linear gel and mixed.

  4. 4.

    The mixture was then put in the self-made confinement cell and pressurized under different stresses between (2000–8000 psi) using the hydraulic press, the nuts were used to maintain the pressure applied on proppant.

  5. 5.

    The confinement cell was put into the oven at 120 °C which is the temperature of the Hassi Messaoud Field reservoir and kept at different time between 12 and 72 h.

  6. 6.

    Finally, the confinement cell was retrieved from the oven and connected to the installation. The permeability was calculated by injecting the Gasoil. In the beginning the gel and Gasoil start outflowing from the confinement cell, the gasoil stable rate is maintained until getting clear Gasoil out. The below table represents the parameters used for proppant permeability measurement (Tables 3, 4).

Table 3 Test conditions for closure pressure effect on 20/40 and 30/50 HSP proppant permeability
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Table 4 Test conditions for fracturing fluid effect on 20/40 proppant permeability under 6000 psi and 120 °C
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During proppant permeability measuring, a steady-state flow method was applied. In order to maintain a constant flow, a needle valve was installed behind the confinement cell to maintain the constant pressure. Pressure in the cylinder is monitored by the manometers, therefore the flow rate can be calculated by measuring the volume out of the confinement cell and the time.

The permeability was measured using Darcy law:

$$K = \frac{ Q.\mu .L}{{A. \left( {P_{1} - P_{2} } \right)}}$$
(1)

K is the proppant pack permeability (Darcy). \(\mu\) is the viscosity of test fluid at test temperature (cP). Q is the flow rate (cm3/s). L is the length between pressure ports (cm). A is the cross-sectional area of the test unit perpendicular to flow cm2. ΔP is the pressure drop (pressure upstream minus pressure downstream) (atm).

Results and discussion

Effect of pressure on proppant permeability

The effect of closure pressure on proppant permeability was investigated using two types of proppant, 20/40 HSP and 30/50 HSP. The confinement cell was filled by the proppant and subjected to a stress values between 2000 and 8000 psi, the proppant was then kept under stress and temperature of 120 °C for 50 h, and finally, the permeability was measured using Gasoil.

The (Fig. 15) shows the variation of permeability of the proppant as function of stress applied after 50 h. A decrease of proppant permeability for both types 20/40 and 30/50 was observed along with pressure increasing. The highest permeability values were reported at 2000 psi with 380 mD using 20/40 HSP proppant type and 225 mD with 30/50 HSP proppant type. These permeabilities reduced by 89% under 8000 psi using 30/50 HSP type, in the other side a drop of 66% was observed using 20/40 HSP type. The rate of permeability impairment was high for both proppant types from 2000 to 6000 psi compared to the interval from 6000 to 8000 psi.

Fig. 15
figure 15

Effect of stress on proppant permeability using 20/40 and 30/50 mesh size HSP proppant

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This phenomenon can be explained by fines generated from the proppant grain crushing in critical zones under compaction accompanied with their rearrangement which reduces the space between proppant grains and as result the permeability reduces. More the compaction pressure applied is increased more proppant is crushed, and more fines are generated (Fig. 16). (Krumbein 1943) discussed the effect of grain size on permeability, the below equation was developed for estimating permeability based on grain size:

$$k = 760d_{{\text{g}}}^{2} \exp ( - 1.31\sigma_{D} )$$
(2)

k is given in Darcies, dg is the geometric mean grain diameter (in mm). σD is the standard deviation of grain diameter in phi units, where phi =  − log2(d) and d is expressed in millimeters.

Fig. 16
figure 16

Effect of grain size on proppant permeability

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In Hassi Messaoud field closure, pressure of fractured reservoir rock variates from 6000 to 9000 psi, and thus, the proppant crushing is severe which will affect the retained proppant permeability. Ultra-high strength proppant is recommended in Hassi Messaoud field to gain more retained permeability by reducing the proppant crushing.

Effect of fracturing fluid at extended time on proppant permeability

The effect of fracturing fluid on proppant permeability was investigated using one type of proppant 20/40 HSP and Guar gel type with borate crosslinker and sodium bromate breaker as mentioned in materials section.

The confinement cell was filled by the proppant and fracturing fluid with different concentrations and subjected to a stress of 6000 psi. The proppant was then kept under stress and temperature of 120 °C at extended time. The permeability was measured by injecting the Gasoil at room temperature to examine the effect of time between closure and cleanup operations and gel concentration on the retained permeability.

Figure 17 represents the permeability of 20/40 HSP proppant as function of extended time, all plots show that more the time is extended more that the permeability impairment is severe.

Fig. 17
figure 17

Effect of Guar gel at extended time under 6000 psi stress on 20/40 mesh size HSP proppant permeability

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As plotted in (Fig. 17) when using no gel concentration, the permeability impairment was low, and the decrease of proppant permeability was due to the pressure applied for long time. When using 50 lb/1000 gal of crosslinked guar gel, the permeability was around 170 mD after 12 h. A drop of 25% was reported after 24 h, this permeability drop will continue to reach 75% after 72 h due to gel damage.

Figure 17 also presents the proppant permeability drop measured at 100 lb/1000 gal of crosslinked guar gel. As presented the permeability was around 100 mD after 12 h, a decrease of 20% in the retained permeability was observed after 24 h, as the time extends the damage increases and the permeability recorded after 72 h was more than 3 times less than the value recorded after 12 h.

Figure 17 shows permeability impairment in the same conditions using 200 lb/1000 gal of crosslinked gel concentration, the proppant pack was totally plugged after 72 h, even though we reported a permeability of 1 mD after 12 h which indicates the severity of the damage associated with gel concentration under bottom-hole conditions. The gel residues were very hard to be removed from the proppant pack, and the permeability was totally damaged.

The results reported from this study proved that the amount of retained permeability that can be achieved is directly related to the time of the fracturing fluid existence inside the proppant pack. This phenomenon can be explained by the gel retention related to time on adsorption of fracturing fluid and the energy required to move the gel molecules (Fig. 18). This was confirmed by (Saurabh Mishra 2014) showing that as time increases more adsorption sites of sand are covered with polysaccharide polymer which causes permeability reduction.

Fig. 18
figure 18

Effect of guar gel at extended time size on proppant permeability

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The pseudo-second-order kinetic model describes the dependency of the adsorption capacity of the adsorbent on time and can be determined based on Eq. (2) expressed as:

$$t/q_{t} = 1/K_{2} q_{e}^{2} + t/q_{e}$$
(3)

where qt and qe are the amounts of gel adsorbed at equilibrium and at time t (minute), respectively, and K2 is the pseudo-second-order rate constant (g/mg/min). The linear plot of t/qt against time is used to determine qe and K2 from the slope and intercept, respectively. This phenomenon which is directly related to the contact time was also the subject of (Shijie Zhu 2021) where the relationship between the adsorption amount and time was established by studying the capacity of quartz sand to adsorb polymer from solution at different periods of contact, the main result was that: as the polymer solution and quartz sand contact period increases, the polymer solution adsorption capacity gradually increases and tends to stabilize after a specific time. The adsorption phenomenon is due to intermolecular electrical effort of Van Der Valls between gel and grain surface.

Effect of fracturing fluid concentration on proppant permeability

Figure 19 represents the permeability of 20/40 HSP proppant as a function of gel concentrations (0, 50, 100, 150, 200 lb/1000 gal) at extended time (12, 24, 36, 48, 72 h), the figure illustrates how permeability is affected when the after-closure gel concentration is increased.

Fig. 19
figure 19

Comparison of Effect of guar gel concentrations on 20/40 mesh size HSP proppant permeability at extended time under 6000 psi

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As an example, 16% drop of permeability was observed when using 50 lb/1000 gal after 36 h compared to proppant permeability with no gel, while 3 times drop of permeability was measured using 100 lb/1000 gal of fracturing fluid. Finally, the retained permeability was approximatively 0 mD using 200 lb/1000 gal of gel.

Another example which shows that the severity of damage increases as the polymer concentration increases using 20/40 HSP Proppant type, a 36% of retained permeability was observed after 72 h when using 50 lbs/1000 gal, and 20% of retained permeability when using 100 lbs/1000 gal. The proppant pack was completely plugged when using 200 lb/1000 gal as gel concentration.

These results reveal that more the fracturing fluid stays in the proppant pores more that it is stuck and difficult to be removed (Fig. 20). This can be explained by Freundlich adsorption model, it is an empirical formula for hetero-geneous adsorption given by the following equation:where KF (mg1−(1/n) L1/n g−1) is a constant correlated to the relative adsorption capacity of the adsorbent, and

$$q_{e} = K_{F} C_{e}^{\frac{1}{n}}$$
(4)

n is a constant indicative of the intensity of the adsorption. As the Freundlich model is an exponential equation, it assumes that the adsorption capacity of the adsorbent increases with increasing concentration of the adsorbate. The values KF and 1/n can be correlated to the adsorption capacity and intensity (Freundlich 1926).

Fig. 20
figure 20

Effect of guar gel concentration on proppant permeability

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(Saurabh Mishra 2014) proved that when polymer concentration increases the thickness of the adsorbed layer increases and the permeability reduces. This is because the probability of interaction between sand surface and polymer molecules increases.

Effect of breaker concentration on proppant permeability

Figure 21 represents the permeability of 20/40 HSP proppant as a function of breaker concentrations (0, 5, 10, 20, 25 lb/1000 gal) after 24 h, under closure pressure of 6000 psi and 120 °C with gel concentration of 50, 100 and 150 lb/1000 gals, the figure illustrates how the permeability is affected when the breaker concentration is increased.

Fig. 21
figure 21

Effect of breaker concentration on proppant permeability after 24 h, under 6000 psi and 120 °C, using 20/40 HSP proppant size and different gel concentration

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The results show that when increasing the breaker concentration, the severity of proppantpack damage caused by concentrated polymers will reduce. The amount of retained permeability that can be achieved is directly related to the breaker concentration &.

As presented in the chart, the retained permeability of proppant is zero when there was no breaker used and the damage was severe, the permeability then increases with breaker concentration increasing. It is important to note that for high gel concentrations more breaker is required to gain more proppant conductivity. The curves tend to stabilize at concentrations greater than 20 lb/1000 gal where the gel is totally broken.

By cutting the long chain of polymer, the breakers reduce the viscosity of the fracturing fluid thus reducing its molecular weight which is considered to be in the range of 2 to 4 million. To eliminate the viscosity of a single guar polymer, it must be cut into approximately 200 small pieces (Acton 2013). Borate crosslinked polymers are known to be reversible thus they are broken by breaking down their molecular weights. However, the degradation of gels does not mean the fluid return because after degradation there are lots of residues left to damage the permeability of cores as illustrated in Fig. 22.

Fig. 22
figure 22

Gel residues after 24 h under 6000 psi at 120 °C with 5 lb/1000 gal breaker concentration

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The mechanism of gel degradation is explained by the process by which the oxidant works. They release free radicals that act on the oxidizable bonds which are susceptible. Free radicals are charged ions with unpaired electrons and are highly reactive because of the natural tendency to form electron pair bonds and can generate free radicals by stabilizing the thermal or catalytic activation of oxidizing species (TjonJoePin 1996).

Effect of polymer concentration at extended time on Fcd and FOI

In 1961, Prats discussed the importance of the dimensionless fracture conductivity Fcd:

$${\text{Fcd}} = \frac{{K_{f} W}}{{KX_{f} }}$$
(5)

Kf is the fracture permeability (md), Wf is the fracture width (ft), K is the formation permeability (md), Xf is the fracture half-length (ft).

This parameter represents the ability of fractures to transmit fluids from reservoir to the wellbore divided by the ability of the formation to transmit fluids to the fractures (Economides 2000). A coefficient C can be multiplied to the Fcd equation to include the effect of pressure applied on proppant, fracturing fluid and damage associated with time before cleanup.

Going back to Table 1, the post-fracturing production rates are directly related to the permeability of the fractures, Prats introduced a critical concept of effective wellbore radius \(r_{w}^{^{\prime}}\) which shows how the wellbore radius can theoretically be increased after fracturing treatment. Cinco-Ley et al. (1978) later integrated this into a full description of reservoir response where they expressed \(r_{w}^{^{\prime}}\) as function of length and Fcd (Economides 2000).

Figure 23 can be used as a reservoir engineering tool to assess possible post-fracture productivity benefits from fracturing treatments. The folds of increase (FOI) can be defined as the post-fracture increase in well productivity compared with pre-fracture productivity:

$${\text{FOI}} = \frac{{\ln \left( {r_{e} /r_{w} } \right) + s}}{{\ln \left( {r_{e} /r_{w}^{\prime } } \right)}}$$
(6)

re is the reservoir radius, rw is the normal wellbore radius, s is pre-fracture skin effect.

Fig. 23
figure 23

Equivalent wellbore radius as a function of dimensionless fracture conductivity and fracture length (Economides 2000)

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Finally, this can significantly explain the low post-fracturing production rate recorded in some fracturing treatments performed in Hassi Messaoud field.

Conclusion

The conductivity of proppants in fractures is one of the essential parameters that condition the success of hydraulic fracturing. This parameter has already been the subject of several studies which have led to the demonstration of the importance of design on the performance of stimulation operations.

In fact, the experimental studies carried out within this research project have shown the influence of properties of the fracturing fluid and the types of proppants as well as the closure pressure and the temperature at extended time, on the proppant permeability.

The installation developed made it possible to measure the permeability of proppants by simulating the bottom-hole conditions of pressure and temperature. An increase in pressure from 2000 to 8000 psi in the confinement cell led to 66 to 89% reduction in permeability caused by the crushing of the Proppant grains under the effect of compaction. Depending on the types of Proppant 20/40 and 30/50 HSP, a 30% difference in permeability was obtained.

Ultra-High strength proppant type is highly recommended in Hassi Messaoud fracturing treatments.

Also, an increase in the gel concentration from 0 to 200 lb/1000 gal showed a huge drop in proppant permeability along with concentration increasing.

Using less guar concentration is a key parameter to avoid additional damage to the fracture permeability.

The extended time between closure and cleanup is very important because more the time is extended more the proppant permeability impairment is severe.

Reducing the time between stimulation and cleanup operations in Hassi Messaoud filed is a key parameter to minimize the proppant pack permeability impairment.

Because of the rapidity of taking the measurements and the ease of handling, the newly designed installation has proven its effectiveness and has made it possible to display measurement reliability as well as data robustness.

Performing Proppant type selection through preliminary performance testing using the HPHT Containment Simulation confinement cell is highly recommended.

Choosing the type of proppants according to the closing pressure is a must which condition the success of the fracturing treatment.

Increasing the breaker concentration will reduce the severity of proppantpack damage caused by concentrated polymers.