# Stability Evaluation of Proppant in Fractures of Gas Storage in Yulin Gas Field

Authors: Ping Wang; TianLi Gu; Zhanwu Gao; Jiayong Fan; Hai Huang; Zhan Qu; Qiang Han; Zongxiao Ren
Journal: Advances in Civil Engineering
 (2022)

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## Abstract

In nearly a hundred years of construction, underground gas storage has become the main natural gas storage and peak regulation means in the world. For the gas storage, the large production and high flow rate of the gas well in the actual production process will cause the backflow of proppant filled in the supporting fracture, which will bring great harm to the gas field production. In this article, when the proppant fracture reaches a stable state in the process of gas injection and production, the stress of proppant particles is analyzed, the critical velocity of proppant reflux is calculated, and then the critical production model is established; calculate the permeability change during proppant migration, then calculate the fluid velocity and production, and determine the fluid velocity range of injection and production wells in gas storage. The parameter sensitivity of velocity and flow model is analyzed. The results show that with the increase of closure stress, the critical gas flow and critical gas velocity of proppant backflow gradually increase, and the proppant filling layer is more stable. The smaller the thickness and width of the filling layer, the greater the critical gas flow and critical gas velocity of proppant backflow, the more stable the proppant filling layer, and the lesser the chance of backflow. The higher the saturation, the lower the critical gas velocity, and the more prone the proppant to reflux. It has important guiding significance for realizing the optimization of gas well production and maintaining efficient production efficiency.


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## Body

## 1. Introduction

During the gas injection and production process of the gas storage, the reservoir pressure changes rapidly and sharply, and the proppant in a stable state rolls and is brought into the wellbore, which causes the migration of particles in the reservoir and leads to sand production. The production experience of injection-production wells in gas storage shows that sand production will not only cause permanent damage to the reservoir but also cause erosion damage to the tubing. Due to the lack of data on proppant migration and backflow in gas storage, quite a number of scholars at home and abroad have studied sand production in gas well production and proppant backflow during fracturing, which can provide some ideas and inspiration for our research.As early as 1970, Hall proposed the concept of “sand arch” for the problem of loose sand production [1]. Based on this theory, Bratli, Milton Taylor, Gidley, Bybee, Karen, Romero, and Feraud [2–6] believed that proppant particles would also form a hemispherical “support arch,” and proppant settlement would form in the packing zone. The early stages of stabilizing the structure lead to the formation of small irregular channels on the top and interior of the crack. As the fluid velocity in the fracture increases, the free grains outside the pack continue to erode the sand body until backflow occurs. The instability of sand arch and the erosion of proppant particles were observed through experimental study, and the critical flow rate was determined. Javier, Tooseh [7, 8] established a theoretical model. When the flow rate is steadily increased until a certain point is reached, the proppant particles no longer remain stationary, but “fluidize” under the action of the fluid flow or moisture stream. Taking gas storages in low permeability aquifers as objects, experiments on gas-water-rock interaction and factors affecting gas storage capacity were carried out. When the original conditions of the reservoir (pH value, temperature, pressure, etc.) remain unchanged, the reservoir is in a stable state. However, when the pH value of the reservoir fluid changes or the flow rate is too fast, its stable state is destroyed, and it is easy to cause acid sensitivity and particle migration in the reservoir [9–13].Domestic Aspects. Li et al. [14–17] conducted a mechanical analysis of the proppant in gas well production and derived the latest wellbore critical sand-carrying formula that conforms to the actual situation of gas wells. A new formula for the critical production rate of fracture sand production is deduced by proppant stress analysis. Assuming that the proppant accumulates in the fracturing fracture, the relationship between the critical sand production and the bottom hole flow pressure when the gas well fracture is damaged is obtained. Based on the stability similarity and force balance principle between proppant arch and sand arch, Fu and Liu [18, 19] systematically studied the mechanism of proppant backflow during the production process of fracturing gas wells, established a mathematical model of proppant backflow mechanics, and wrote a software for predicting proppant backflow during gas well production. Jin et al. [20, 21] used proppant combinations of different particle sizes to fill fractures to maintain high fracture conductivity. A mathematical model of the movement characteristics of proppant in fractures during fracturing fluid flowback after fracturing is established to simulate the flowback process of fracturing fluid and proppant in fractures when proppant sizes of different particle sizes are combined. Kang [22] conducted an experimental simulation of particle migration caused by rapid changes in gas injection pressure in gas storage wells and revealed the mechanism of particle migration caused by dynamic changes in gas injection pressure in gas storage wells.As the flow rate increases, the resistance increases. When the flow rate reaches a certain value, the proppant no longer maintains a mechanical equilibrium state and is carried and moved by the fluid, resulting in the backflow of the proppant in the gas well. In this article, the force analysis of proppant in artificial fractures under injection and production conditions is carried out, the prediction model of proppant backflow under high-strength injection and production conditions is established, the critical flow rate is determined, the critical production model is established, and the stability of proppant in fractures is optimized and improved.


## 2. Critical Condition for No Rolling of Proppant under Injection

Most scholars at home and abroad focus on the research and analysis on proppant backflow during fracturing but there are few studies on proppant backflow caused by gas flowing down at high speed in gas storage. On the one hand, when the gas is injected and produced in the gas storage, the high-speed flow of the gas in the gas storage causes the proppant, which was in a stable state, to be rolled and carried to the wellbore. Alternate changes in pore pressure lead to changes in effective stress, resulting in particle migration in the reservoir, resulting in sand production. This article analyzes the migration of proppant particles caused by gas flow during gas storage injection and production, which can provide reference value for gas storage to improve gas production efficiency.Model assumptions are as follows:(1)
The supporting seam is a vertical seam, and the height and width of the seam are constant.(2)
Fracture flow is gas-liquid two-phase linear flow.(3)
The size of proppant particles is uniform, and the particles are in point contact, regardless of the deformation of the proppant.(4)
Compared with other parameters, proppant gravity has little effect on backflow, and gravity parameters are not considered in this article.The proppant primarily supports the pressure-opened fracture, preventing it from closing and providing access for gas injection and recovery. In the construction of gas storage using depleted gas wells, when proppant fractures reach a stable state before gas injection, the force analysis of proppant is shown in Figure1.Figure 1
Schematic diagram of proppant stress.On the one hand, as the gas flows down the fracture from the formation, a pressure gradient is formed in the fracture, and this pressure gradient creates a drag force on the proppant propping up the fracture in the direction of the gas flow. On the other hand, in the process of fracturing, the residual fracturing fluid, the formation water, and the formation itself are attached to the surface of the proppant particles by liquid film droplets to produce capillary resistance to the flow of natural gas in the fracture, and the capillary force reacts on the solid particles and becomes the proppant reflux power.Therefore, the critical condition for proppant backflow is(1)Pdrag+σc′<fn,where Pdrag is the drag force of gas, σc, is the equivalent capillary force strength, and fn is the strength of static friction force.


### 2.1. Force Analysis of Proppant Particles

(1)
Drag force of gas is(2)Pdrag=−dp3⋅dPdx,wheredp is the proppant diameter, m.(2)
Strength of static friction forcefn is(3)fn=μPc,wherefn is the static friction force, μ is the static friction coefficient, and Pc is the closing stress.(3)
Equivalent capillary forceσc, strength is(4)σc′=21−φφπσsinαc2dp1f1αc−1fαc.During the production process of fracturing gas wells, the change of stress state and the deduced effective stress principle [23, 24] provide a reference for this article. When the fluid breaks through the capillary force, proppant particles are initiated by forces and drag forces that are consistent with the direction of flow, as seen from the action and reaction forces. This force is called the equivalent capillary force.


### 2.2. Critical Velocity at Which Proppant Cannot Be Transported

From the previous analysis, the mechanical conditions expressed in (1) must be satisfied for the proppant to backflow. The critical condition for proppant backflow is(5)Pdrag+σc′=fn.Substitute Equations (2), (3), and (4) in (5) to obtain(6)−dp3⋅dPdx+21−φφπσsinαc2dp1f1αc−1fαc=μPc.According to the non-Darcy flow model of gas,(7)−dPdx=RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2.Among them,β=5.5×109/k1.25φ0.75 where K is the permeability, φ is the porosity, Z is the natural gas deviation factor, dimensionless, R is the dimensionless Pratt constant of gas, Ti is the formation temperature, K; μgi is the viscosity of natural gas in the formation, MPa⋅s; ρa is the air density, kg/m3, γg is the relative density of natural gas, dimensionless, Pwf is the bottomhole flow pressure, MPa, kg is the absolute fracture permeability, μm2, β is the inertial resistance coefficient, 1/m, and v is the gas velocity, m/s.The negative sign indicates that the direction of the fluid velocity is opposite to the direction of the pressure gradient.Substituting (7) in Equation (6), a quadratic equation with one variable about gas velocity v is obtained:(8)RμgiZTiρadp87Pwfkg1−Swiv+RZTiβγgρa2dp87Pwfv2+21−φφπσsinαc2dp1f1αc−1fαc−μPc=0.MakeA=RZTiβγgρa2dp/87Pwf,(9)B=RμgiZTiρadp87Pwfkg1−Swi,C=21−φφπσsinαc2dp1f1αc−1fαc−μPc.Formula (8) can be simplified into(10)Av2+Bv+C=0.The critical flow rate of proppant that does not start is(11)v=−B+B2+4AC2A.If the flow velocity is less than the proppant critical flow rate, the proppant in the pressure fracture will remain static. The width of the fracture is assumed to beωf and the height of the fracture h. According to the flow characteristics in the fracture, as long as the sand particles along the wall are not pushed, the sand particles throughout the fracture will not be pushed. For this reason, when considering the flow rate, take the velocity of the fracture in the wellbore wall as the standard and assume that all gas flows into the wellbore through the fracture. So, the production of the gas well is(12)Q=2ωfhv86400Bg,where ωf is the width of the fracture; h is the height of the propped fracture, m; Bg is the volume coefficient of natural gas, m3; and Q is the natural gas production, m3/d.Substitute the critical velocity in (11) to obtain the critical flow.


## 2.1. Force Analysis of Proppant Particles

(1)
Drag force of gas is(2)Pdrag=−dp3⋅dPdx,wheredp is the proppant diameter, m.(2)
Strength of static friction forcefn is(3)fn=μPc,wherefn is the static friction force, μ is the static friction coefficient, and Pc is the closing stress.(3)
Equivalent capillary forceσc, strength is(4)σc′=21−φφπσsinαc2dp1f1αc−1fαc.During the production process of fracturing gas wells, the change of stress state and the deduced effective stress principle [23, 24] provide a reference for this article. When the fluid breaks through the capillary force, proppant particles are initiated by forces and drag forces that are consistent with the direction of flow, as seen from the action and reaction forces. This force is called the equivalent capillary force.


## 2.2. Critical Velocity at Which Proppant Cannot Be Transported

From the previous analysis, the mechanical conditions expressed in (1) must be satisfied for the proppant to backflow. The critical condition for proppant backflow is(5)Pdrag+σc′=fn.Substitute Equations (2), (3), and (4) in (5) to obtain(6)−dp3⋅dPdx+21−φφπσsinαc2dp1f1αc−1fαc=μPc.According to the non-Darcy flow model of gas,(7)−dPdx=RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2.Among them,β=5.5×109/k1.25φ0.75 where K is the permeability, φ is the porosity, Z is the natural gas deviation factor, dimensionless, R is the dimensionless Pratt constant of gas, Ti is the formation temperature, K; μgi is the viscosity of natural gas in the formation, MPa⋅s; ρa is the air density, kg/m3, γg is the relative density of natural gas, dimensionless, Pwf is the bottomhole flow pressure, MPa, kg is the absolute fracture permeability, μm2, β is the inertial resistance coefficient, 1/m, and v is the gas velocity, m/s.The negative sign indicates that the direction of the fluid velocity is opposite to the direction of the pressure gradient.Substituting (7) in Equation (6), a quadratic equation with one variable about gas velocity v is obtained:(8)RμgiZTiρadp87Pwfkg1−Swiv+RZTiβγgρa2dp87Pwfv2+21−φφπσsinαc2dp1f1αc−1fαc−μPc=0.MakeA=RZTiβγgρa2dp/87Pwf,(9)B=RμgiZTiρadp87Pwfkg1−Swi,C=21−φφπσsinαc2dp1f1αc−1fαc−μPc.Formula (8) can be simplified into(10)Av2+Bv+C=0.The critical flow rate of proppant that does not start is(11)v=−B+B2+4AC2A.If the flow velocity is less than the proppant critical flow rate, the proppant in the pressure fracture will remain static. The width of the fracture is assumed to beωf and the height of the fracture h. According to the flow characteristics in the fracture, as long as the sand particles along the wall are not pushed, the sand particles throughout the fracture will not be pushed. For this reason, when considering the flow rate, take the velocity of the fracture in the wellbore wall as the standard and assume that all gas flows into the wellbore through the fracture. So, the production of the gas well is(12)Q=2ωfhv86400Bg,where ωf is the width of the fracture; h is the height of the propped fracture, m; Bg is the volume coefficient of natural gas, m3; and Q is the natural gas production, m3/d.Substitute the critical velocity in (11) to obtain the critical flow.


## 3. Critical Conditions under Which Proppant Is Not Discharged under Recovery Conditions

The critical condition of proppant rolling start was obtained by force analysis of proppant particles in the gas production channel, and then the law of proppant migration was analyzed.


### 3.1. Force Analysis of a Single Stationary Proppant Particle

It is assumed that the proppant particles in the gas production channel are spherical, and the packing mode is shown in Figure2. The proppant particle radius is set as r, and the static proppant particles in the fluid are mainly subjected to pressure gradient force, gas impact force, and the gravity of the proppant particles themselves.(1)
Pressure gradient forceFP is(13)FP=43πr3RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2.(2)
GravityFG is(14)FG=43πr3ρs−28.97γgPRTZg.Figure 2
Analysis of proppant stress during gas recovery.


### 3.2. Rolling Starting Conditions of Proppant Particles

In the case of contact point A, the pressure gradient force and the impact force of the gas cause the proppant to roll around A, while the gravity hinders the proppant particle rolling. The moment generated by the interaction force between proppant particles 2 (see the right picture) through point A is zero, and the force generated by proppant particles 1 plays a main role in its rolling. When the proppant particles and proppant particles 1 just get out of contact, the force is zero, and the proppant particles start rolling. According to the principle of torque balance, when the active torque is greater than the retarded torque, the proppant particles will roll. That is,(15)FPLy≥FGLx,where Lx and Ly are the hindrance moment arm and the main force moment arm, respectively. Its moment arm can be obtained from geometric relations.When the gas flow rate meets (15), proppant particles will roll. Substitute the above force expressions (13) and (14) in Equation (15) to obtain the following:(16)43πr3RμgiZTiρa29PwfKg1−Swiv+RZTiβrgρa229Pwfv232r≥43πr3ρs−28.97KgPRTZgr2.Similarly, a quadratic equation with one variable about gas velocityv is obtained:(17)RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2+3328.97γgPRTZ−ρs≥0.MakeA1=RZTiβγgρa2/29Pwf,(18)B=1RμgiZTiρa29Pwfkg1−Swi,C1=3328.97γgPRTZ−ρs.Formula (18) can be simplified into(19)A1v2+Bv1+C1≥0.Therefore, the proppant velocity of the produced gas should meet the following requirements:(20)v≥−B1+B12+4A1C12A1.Therefore, the critical velocity of proppant particle rolling is(21)vg=−B1+B12+4A1C12A1.


### 3.3. Rolling Start-Up Conditions under Different Proppant Arrangements

In the actual gas production channel, proppant particles are not necessarily arranged in the gas production channel as shown in Figure2, some proppant grains may be submerged, and some may be embedded in other grains. The grain arrangement after the gas production channel has the following three forms as shown in Figure 4, and the distance from the contact point of proppant grains to the lower boundary of proppant grains is defined as the coverage depth hr.Figure 3
Influence diagram of saturation under injection-production conditions.Figure 4
Schematic diagram of proppant arrangement during gas recovery.
(a)(b)(c)The proppant particles are spherical particles with equal particle size, and the coverage depth can be calculated based on the geometric relationship. In the proppant arrangement, the particle size of the proppant particles is assumed to beds, and the distance between the center of the next two particles is ds+δ, where 0≤δ≤ds:(22)hr=ds−ds2−ds+δ/222.Whenδ=0, the proppant is arranged in the form shown in Figure 4(a), and the minimum coverage depth of proppant particles is hr=0.067ds.When δ=ds, the proppant is arranged in the form shown in Figure 4(c), and the maximum coverage depth of proppant particles is hr=0.5ds.Different proppant particle coverage will affect the moment arms of each force when the particle rolling starts. After considering the proppant particle coverage, the moment arms of each force are(23)lx=ds+δ4=dshr−hr2,ly=ds2−ds+δ/222=ds2−hr.By substituting the force arm formula (23) into formula (21), the critical rolling velocity of proppant particles considering the arrangement of proppant can be obtained. In addition, the critical rolling velocity considering the arrangement of proppant particles and the shape of proppant particles can be obtained by combining the equivalent particle size formula of different proppant shapes.Substitute the critical velocity in (12) to obtain the critical flow formula as follows:(24)Qqc=2wfhvg86400Bg.Thus, as long as the production rate of the gas well is less thanQqc, the gas well will not destroy the supporting sand in the fracture, so that the fracture can maintain long-term effectiveness.


## 3.1. Force Analysis of a Single Stationary Proppant Particle

It is assumed that the proppant particles in the gas production channel are spherical, and the packing mode is shown in Figure2. The proppant particle radius is set as r, and the static proppant particles in the fluid are mainly subjected to pressure gradient force, gas impact force, and the gravity of the proppant particles themselves.(1)
Pressure gradient forceFP is(13)FP=43πr3RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2.(2)
GravityFG is(14)FG=43πr3ρs−28.97γgPRTZg.Figure 2
Analysis of proppant stress during gas recovery.


## 3.2. Rolling Starting Conditions of Proppant Particles

In the case of contact point A, the pressure gradient force and the impact force of the gas cause the proppant to roll around A, while the gravity hinders the proppant particle rolling. The moment generated by the interaction force between proppant particles 2 (see the right picture) through point A is zero, and the force generated by proppant particles 1 plays a main role in its rolling. When the proppant particles and proppant particles 1 just get out of contact, the force is zero, and the proppant particles start rolling. According to the principle of torque balance, when the active torque is greater than the retarded torque, the proppant particles will roll. That is,(15)FPLy≥FGLx,where Lx and Ly are the hindrance moment arm and the main force moment arm, respectively. Its moment arm can be obtained from geometric relations.When the gas flow rate meets (15), proppant particles will roll. Substitute the above force expressions (13) and (14) in Equation (15) to obtain the following:(16)43πr3RμgiZTiρa29PwfKg1−Swiv+RZTiβrgρa229Pwfv232r≥43πr3ρs−28.97KgPRTZgr2.Similarly, a quadratic equation with one variable about gas velocityv is obtained:(17)RμgiZTiρa29Pwfkg1−Swiv+RZTiβγgρa229Pwfv2+3328.97γgPRTZ−ρs≥0.MakeA1=RZTiβγgρa2/29Pwf,(18)B=1RμgiZTiρa29Pwfkg1−Swi,C1=3328.97γgPRTZ−ρs.Formula (18) can be simplified into(19)A1v2+Bv1+C1≥0.Therefore, the proppant velocity of the produced gas should meet the following requirements:(20)v≥−B1+B12+4A1C12A1.Therefore, the critical velocity of proppant particle rolling is(21)vg=−B1+B12+4A1C12A1.


## 3.3. Rolling Start-Up Conditions under Different Proppant Arrangements

In the actual gas production channel, proppant particles are not necessarily arranged in the gas production channel as shown in Figure2, some proppant grains may be submerged, and some may be embedded in other grains. The grain arrangement after the gas production channel has the following three forms as shown in Figure 4, and the distance from the contact point of proppant grains to the lower boundary of proppant grains is defined as the coverage depth hr.Figure 3
Influence diagram of saturation under injection-production conditions.Figure 4
Schematic diagram of proppant arrangement during gas recovery.
(a)(b)(c)The proppant particles are spherical particles with equal particle size, and the coverage depth can be calculated based on the geometric relationship. In the proppant arrangement, the particle size of the proppant particles is assumed to beds, and the distance between the center of the next two particles is ds+δ, where 0≤δ≤ds:(22)hr=ds−ds2−ds+δ/222.Whenδ=0, the proppant is arranged in the form shown in Figure 4(a), and the minimum coverage depth of proppant particles is hr=0.067ds.When δ=ds, the proppant is arranged in the form shown in Figure 4(c), and the maximum coverage depth of proppant particles is hr=0.5ds.Different proppant particle coverage will affect the moment arms of each force when the particle rolling starts. After considering the proppant particle coverage, the moment arms of each force are(23)lx=ds+δ4=dshr−hr2,ly=ds2−ds+δ/222=ds2−hr.By substituting the force arm formula (23) into formula (21), the critical rolling velocity of proppant particles considering the arrangement of proppant can be obtained. In addition, the critical rolling velocity considering the arrangement of proppant particles and the shape of proppant particles can be obtained by combining the equivalent particle size formula of different proppant shapes.Substitute the critical velocity in (12) to obtain the critical flow formula as follows:(24)Qqc=2wfhvg86400Bg.Thus, as long as the production rate of the gas well is less thanQqc, the gas well will not destroy the supporting sand in the fracture, so that the fracture can maintain long-term effectiveness.


## 4. Calculation Model of Proppant Migration Fluid Velocity

When the proppant is sheared or stretched by the fluid, the proppant particles fall off from the surface of the rock skeleton. After the particles fall off, the force of the proppant in the pore fluid is different under different fluid conditions, which determines whether the proppant particles can be taken away by the fluid or remain in place after falling off from the surface of the rock skeleton. The research of scholars in other fields can provide us with some references. [26–28] When proppant particles migrate, deposit, and plug in pores, they will cause changes in reservoir physical parameters, especially porosity and permeability, and then affect reservoir productivity.Before the reservoir rock is deformed, its original porosity is(25)φ0=VpVf=Vf−VrVf,where Vf is the total volume of rock, m3, Vp is the pore volume, m3, and Vr is the volume of rock skeleton, m3.In the stable production stage of the gas storage, the bottom hole pressure remains unchanged and the resulting pressure drop remains constant. The pressure at any point of the gas storage can be regarded as unchanged, and the influence of pressure on it can be ignored. When most mobile proppant particles stop migration, the permeability will gradually stabilize. Then, the porosity of proppant after being carried out of gas storage by liquid is(26)φ=φ0+1−φ0Rcρs.Seepage velocity is(27)vs=14.4WAφ.Substitute equation (26) in(28)vs=14.4WAφ0+1−φ0Rc/ρs,where W is the liquid volume flow. The above formula is the velocity of proppant migration.The determination of proppant carrying fluid velocity aims at improving the single well production of gas storage wells, and the single well production formula is(29)Q=khΔp1412μβpj+s,where Q is the gas production, k is the reservoir permeability, h is the reservoir thickness, β is the fluid volume coefficient, s is the skin coefficient of wellbore, and pj is the desorption pressure at point j.When the liquid flows slowly in the gas production channel, proppant particles may deposit and block in the channel. When the fluid velocity is too high, it may scour the gas production channel wall, which may cause a large number of proppant particles to discharge and close the crack. In order to prevent deposition, wall scouring, and proppant discharge in the gas production channel, the fluid velocity should not be too large or too small. Under the condition of ensuring the maximum permeability, selecting an appropriate flow rate can improve the production of gas storage and gas production efficiency. Accordingly, the flow rate should be the following:Under injection conditions:vi≪vD1≪vsUnder recovery conditions:vg≪vD2≪vsBy comparing with the production data of 20 wells in the gas storage in the Yulin gas field, critical velocity, critical flow, and fluid flow range all verify the rationality of the calculation results in this article.


## 5. Sensitivity Analysis of Influencing Factors

### 5.1. Basic Parameters

The southwest reservoir of Yulin gas field gas storage has a buried depth of 2850 ∼ 3100 m, a formation temperature of 90°C, and a storage capacity of 177.62 × 108 m3, an average thickness of 10.1 m, and a porosity of 4.1 ∼ 8.3%, and the average porosity is 6.4%. The permeability is 0.1 ∼ 20.3 mD, belonging to low porosity and low permeability gas reservoir. The basic parameters calculated by the model are as follows: formation pressure of 27.7 MPa, reservoir temperature of 364°C, air density of 1.3 kg/m3, natural gas volume coefficient of 0.0041, natural gas relative density of 0.625 kg/m3, natural gas viscosity of 0.02 MPa·s, proppant of 20/40 mesh, deviation factor of 0.78, gas proctor constant of 8.314, relative density of 3.34 kg/m3, and proppant apparent density of 2.2 g·m−3. The bulk density of proppant is 1.59 g m−3, the strength of proppant is 20.7–34.5 MPa, the internal friction angle is 30°, and the uniaxial compressive strength is 12 MPa.


### 5.2. Crack Width

It can be seen from Figure5 that with the increase in the width of the supporting crack, the critical air velocity gradually decreases, the filling layer is more unstable, and the proppant is prone to backflow. On the contrary, the smaller the fracture width, the higher the critical air velocity, the more stable the filling layer, and the more difficult it is to reflow.Figure 5
Influence diagram of fracture width under injection-production conditions.The wider the supporting fracture is, the easier the backflow is, but the higher the critical production of the gas well is. On the contrary, the narrower the supporting fracture is, the less likely the backflow is, but the lower the critical production of the gas well is. In other words, there is a certain contradiction between proppant backflow prevention and gas well production. We must find an optimal fracture width to reconcile the contradiction between the two and achieve optimization.


### 5.3. Closure Stress

As shown in Figure6, the greater the closure stress, the more stable the proppant filling layer, and the greater the critical flow rate of reflux. The closure stress is equal to the formation pressure minus the pore pressure. With the continuous production of natural gas, the pore pressure decreases and the closure stress increases gradually.Figure 6
Influence diagram of closure stress under injection condition.As the closure stress increases, the critical flow rate and critical velocity of proppant reflux gradually increase, and the proppant filling layer becomes more stable. There is an obvious linear relationship between the critical flow rate and the closure stress.


### 5.4. Saturation

As shown in Figure3, the influence of water irreducible saturation on the stability of the filling layer is very obvious. The smaller the Sw is, the greater the critical air velocity is, and the more stable the filling layer is. On the contrary, the larger the Sw is, the lower the critical gas velocity is, and the more likely the proppant is to reflux.At the initial stage of gas storage well production,Sw is large, the fracture flow is gas-liquid two-phase flow, and the pressure gradient is large. At this time, the supporting fracture is the most unstable, so the gas well production should not be too high. With the flow of natural gas, the working fluid flows out together, and the stability of supporting fractures is enhanced, which can appropriately increase the production of gas wells.


### 5.5. Production Differential Pressure

The greater the production pressure difference, the lower the critical velocity of proppant backflow, the more unstable the support crack, and the proppant backflow is easy to occur.As shown in Figure7, with the increase in production differential pressure, the production of gas wells increases. However, the greater the differential pressure, the lower the critical flow rate and production of proppant backflow in gas wells. In other words, if the production pressure difference is too large, it is easy to cause proppant backflow, resulting in the reduction of fracture conductivity.Figure 7
Influence diagram of production pressure difference under production conditions.


## 5.1. Basic Parameters

The southwest reservoir of Yulin gas field gas storage has a buried depth of 2850 ∼ 3100 m, a formation temperature of 90°C, and a storage capacity of 177.62 × 108 m3, an average thickness of 10.1 m, and a porosity of 4.1 ∼ 8.3%, and the average porosity is 6.4%. The permeability is 0.1 ∼ 20.3 mD, belonging to low porosity and low permeability gas reservoir. The basic parameters calculated by the model are as follows: formation pressure of 27.7 MPa, reservoir temperature of 364°C, air density of 1.3 kg/m3, natural gas volume coefficient of 0.0041, natural gas relative density of 0.625 kg/m3, natural gas viscosity of 0.02 MPa·s, proppant of 20/40 mesh, deviation factor of 0.78, gas proctor constant of 8.314, relative density of 3.34 kg/m3, and proppant apparent density of 2.2 g·m−3. The bulk density of proppant is 1.59 g m−3, the strength of proppant is 20.7–34.5 MPa, the internal friction angle is 30°, and the uniaxial compressive strength is 12 MPa.


## 5.2. Crack Width

It can be seen from Figure5 that with the increase in the width of the supporting crack, the critical air velocity gradually decreases, the filling layer is more unstable, and the proppant is prone to backflow. On the contrary, the smaller the fracture width, the higher the critical air velocity, the more stable the filling layer, and the more difficult it is to reflow.Figure 5
Influence diagram of fracture width under injection-production conditions.The wider the supporting fracture is, the easier the backflow is, but the higher the critical production of the gas well is. On the contrary, the narrower the supporting fracture is, the less likely the backflow is, but the lower the critical production of the gas well is. In other words, there is a certain contradiction between proppant backflow prevention and gas well production. We must find an optimal fracture width to reconcile the contradiction between the two and achieve optimization.


## 5.3. Closure Stress

As shown in Figure6, the greater the closure stress, the more stable the proppant filling layer, and the greater the critical flow rate of reflux. The closure stress is equal to the formation pressure minus the pore pressure. With the continuous production of natural gas, the pore pressure decreases and the closure stress increases gradually.Figure 6
Influence diagram of closure stress under injection condition.As the closure stress increases, the critical flow rate and critical velocity of proppant reflux gradually increase, and the proppant filling layer becomes more stable. There is an obvious linear relationship between the critical flow rate and the closure stress.


## 5.4. Saturation

As shown in Figure3, the influence of water irreducible saturation on the stability of the filling layer is very obvious. The smaller the Sw is, the greater the critical air velocity is, and the more stable the filling layer is. On the contrary, the larger the Sw is, the lower the critical gas velocity is, and the more likely the proppant is to reflux.At the initial stage of gas storage well production,Sw is large, the fracture flow is gas-liquid two-phase flow, and the pressure gradient is large. At this time, the supporting fracture is the most unstable, so the gas well production should not be too high. With the flow of natural gas, the working fluid flows out together, and the stability of supporting fractures is enhanced, which can appropriately increase the production of gas wells.


## 5.5. Production Differential Pressure

The greater the production pressure difference, the lower the critical velocity of proppant backflow, the more unstable the support crack, and the proppant backflow is easy to occur.As shown in Figure7, with the increase in production differential pressure, the production of gas wells increases. However, the greater the differential pressure, the lower the critical flow rate and production of proppant backflow in gas wells. In other words, if the production pressure difference is too large, it is easy to cause proppant backflow, resulting in the reduction of fracture conductivity.Figure 7
Influence diagram of production pressure difference under production conditions.


## 6. Conclusion

(1)
When the supporting fracture reaches a stable state in the process of gas injection and production, the range between the critical velocity of backflow and the velocity of proppant migration is determined through the force analysis of proppant, and the maximum permeability of the reservoir is determined, which can improve the gas production efficiency to the greatest extent.(2)
When the proppant is no longer in a stable state, the proppant migrates, which will have a certain impact on the porosity and permeability of the gas production channel. Moderately discharging a certain amount of separated proppant particles can increase the gas production efficiency and improve the gas production.(3)
With the increase of closure stress, the critical gas flow and critical gas velocity of proppant backflow gradually increase, and the proppant filling layer is more stable. The critical flow rate and critical flow measured at the closure stress point have an obvious linear relationship with the closure stress, which has a strong regularity.(4)
The smaller the thickness of the filling layer is, the greater the critical gas flow and critical gas velocity of proppant backflow, the more stable the proppant filling layer is, and the chance of backflow is reduced. There is a consistent relationship between the critical velocity and critical flow and the fracture width.(5)
The influence of irreducible water saturation on the stability of the filling layer is very obvious; the greater the production differential pressure, the lower the critical velocity of proppant backflow, and the more unstable the support fracture, which is prone to proppant backflow. The production differential pressure should be controlled within a reasonable range during gas well production.



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*Source: 2044561-2022-05-28.xml*