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

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.


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. e 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 back ow in gas storage, quite a number of scholars at home and abroad have studied sand production in gas well production and proppant back ow 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][3][4][5][6] believed that proppant particles would also form a hemispherical "support arch," and proppant settlement would form in the packing zone. e early stages of stabilizing the structure lead to the formation of small irregular channels on the top and interior of the crack. As the uid velocity in the fracture increases, the free grains outside the pack continue to erode the sand body until back ow occurs. e instability of sand arch and the erosion of proppant particles were observed through experimental study, and the critical ow rate was determined. Javier, Tooseh [7,8] established a theoretical model. When the ow rate is steadily increased until a certain point is reached, the proppant particles no longer remain stationary, but " uidize" under the action of the uid ow 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][10][11][12][13].
Domestic Aspects. Li et al. [14][15][16][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.

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 highspeed 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. is 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) e 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) e 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.
e 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 Figure 1.
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. erefore, the critical condition for proppant backflow is where P drag is the drag force of gas, σ , c is the equivalent capillary force strength, and f n is the strength of static friction force.

Force Analysis of Proppant Particles
(1) Drag force of gas is where d p is the proppant diameter, m.
(2) Strength of static friction force f n is where f n is the static friction force, μ is the static friction coefficient, and P c is the closing stress.
During the production process of fracturing gas wells, the change of stress state and the deduced e ective stress principle [23,24] provide a reference for this article. When the uid breaks through the capillary force, proppant particles are initiated by forces and drag forces that are consistent with the direction of ow, as seen from the action and reaction forces. is force is called the equivalent capillary force.

Critical Velocity at Which Proppant Cannot Be
Transported. From the previous analysis, the mechanical conditions expressed in (1) must be satis ed for the proppant to back ow. e critical condition for proppant back ow is Substitute Equations (2), (3), and (4) in (5) to obtain According to the non-Darcy ow model of gas, Among them, β 5.5 × 10 9 /k 1.25 φ 0.75 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, T i is the formation temperature, K; μ gi is the viscosity of natural gas in the formation, MPa · s; ρ a is the air density, kg/m 3 , c g is the relative density of natural gas, dimensionless, P wf is the bottomhole ow pressure, MPa, k g is the absolute fracture permeability, μm 2 , β is the inertial resistance coe cient, 1/m, and v is the gas velocity, m/s. e negative sign indicates that the direction of the uid 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: Formula (8) can be simpli ed into e critical ow rate of proppant that does not start is If the ow velocity is less than the proppant critical ow rate, the proppant in the pressure fracture will remain static. e width of the fracture is assumed to be ω f and the height of the fracture h. According to the ow 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 ow rate, take the velocity of the fracture in the wellbore wall as the standard and assume that all gas ows into the wellbore through the fracture. So, the production of the gas well is where ω f is the width of the fracture; h is the height of the propped fracture, m; B g is the volume coe cient of natural gas, m 3 ; and Q is the natural gas production, m 3 /d. Substitute the critical velocity in (11) to obtain the critical ow.

Critical Conditions under Which Proppant Is
Not Discharged under Recovery Conditions e 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.
Airflow direction f f F c Figure 1: Schematic diagram of proppant stress.

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 Figure 2. e proppant particle radius is set as r, and the static proppant particles in the uid are mainly subjected to pressure gradient force, gas impact force, and the gravity of the proppant particles themselves.
(1) Pressure gradient force F P is

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. e 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. at is, where L x and L y are the hindrance moment arm and the main force moment arm, respectively. Its moment arm can be obtained from geometric relations. When the gas ow rate meets (15), proppant particles will roll. Substitute the above force expressions (13) and (14) in Equation (15) to obtain the following: Similarly, a quadratic equation with one variable about gas velocity v is obtained: Make Formula (18) can be simpli ed into erefore, the proppant velocity of the produced gas should meet the following requirements: erefore, the critical velocity of proppant particle rolling is

Rolling Start-Up Conditions under Di erent Proppant
Arrangements. In the actual gas production channel, proppant particles are not necessarily arranged in the gas production channel as shown in Figure 2, some proppant grains may be submerged, and some may be embedded in other grains. e 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 de ned as the coverage depth h r . e 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 be ds, and the distance between the center of the next two particles is ds + δ, where 0 ≤ δ ≤ ds: When δ 0, the proppant is arranged in the form shown in Figure 4  arranged in the form shown in Figure 4(c), and the maximum coverage depth of proppant particles is h r 0.5 ds.
Di erent proppant particle coverage will a ect the moment arms of each force when the particle rolling starts. After considering the proppant particle coverage, the moment arms of each force are 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 di erent proppant shapes.
Substitute the critical velocity in (12) to obtain the critical ow formula as follows: us, as long as the production rate of the gas well is less than Q qc , the gas well will not destroy the supporting sand in the fracture, so that the fracture can maintain long-term e ectiveness.

Calculation Model of Proppant Migration Fluid Velocity
When the proppant is sheared or stretched by the uid, the proppant particles fall o from the surface of the rock skeleton. After the particles fall o , the force of the proppant in the pore uid is di erent under di erent uid conditions, which determines whether the proppant particles can be taken away by the uid or remain in place after falling o from the surface of the rock skeleton. e research of scholars in other elds can provide us with some references. [26][27][28] When proppant particles migrate, deposit, and plug in pores, they will cause changes in reservoir physical parameters, especially porosity and permeability, and then a ect reservoir productivity.
Before the reservoir rock is deformed, its original porosity is where V f is the total volume of rock, m 3 , V p is the pore volume, m 3 , and V r is the volume of rock skeleton, m 3 .
In the stable production stage of the gas storage, the bottom hole pressure remains unchanged and the resulting pressure drop remains constant. e pressure at any point of the gas storage can be regarded as unchanged, and the in uence of pressure on it can be ignored. When most mobile proppant particles stop migration, the permeability will gradually stabilize.  Advances in Civil Engineering en, the porosity of proppant after being carried out of gas storage by liquid is Substitute equation (26) in where W is the liquid volume flow. e above formula is the velocity of proppant migration. e determination of proppant carrying fluid velocity aims at improving the single well production of gas storage wells, and the single well production formula is Q � khΔp 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 p j 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: By 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.

Basic Parameters.
e 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 m 3 , an average thickness of 10.1 m, and a porosity of 4.1 ∼ 8.3%, and the average porosity is 6.4%. e permeability is 0.1 ∼ 20.3 mD, belonging to low porosity and low permeability gas reservoir. e 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/m 3 , natural gas volume coefficient of 0.0041, natural gas relative density of 0.625 kg/m 3 , 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/m 3 , and proppant apparent density of 2.2 g·m −3 . e 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.

Crack Width.
It can be seen from Figure 5 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. e 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. Figure 6, the greater the closure stress, the more stable the proppant filling layer, and the greater the critical flow rate of reflux. e 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.

Closure Stress. As shown in
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. ere is an obvious linear relationship between the critical flow rate and the closure stress. Figure 3, the influence of water irreducible saturation on the stability of the filling layer is very obvious. e smaller the S w is, the greater the critical air velocity is, and the more stable the filling layer is. On the contrary, the larger the S w is, the lower the critical gas velocity is, and the more likely the proppant is to reflux.

Saturation. As shown in
At the initial stage of gas storage well production, S w 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.

Production Differential Pressure.
e 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. 6 Advances in Civil Engineering

Advances in Civil Engineering
As shown in Figure 7, with the increase in production di erential pressure, the production of gas wells increases. However, the greater the di erential pressure, the lower the critical ow rate and production of proppant back ow in gas wells. In other words, if the production pressure di erence is too large, it is easy to cause proppant back ow, resulting in the reduction of fracture conductivity.

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 back ow 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 eciency 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 e ciency and improve the gas production. (3) With the increase of closure stress, the critical gas ow and critical gas velocity of proppant back ow gradually increase, and the proppant lling layer is more stable. e critical ow rate and critical ow measured at the closure stress point have an obvious linear relationship with the closure stress, which has a strong regularity. (4) e smaller the thickness of the lling layer is, the greater the critical gas ow and critical gas velocity of proppant back ow, the more stable the proppant lling layer is, and the chance of back ow is reduced. ere is a consistent relationship between the critical velocity and critical ow and the fracture width. (5) e in uence of irreducible water saturation on the stability of the lling layer is very obvious; the greater the production di erential pressure, the lower the critical velocity of proppant back ow, and the more unstable the support fracture, which is prone to proppant back ow. e production di erential pressure should be controlled within a reasonable range during gas well production.

Force analysis of proppant particles
(1) Drag Force of Gas. In the actual production process of a gas well, the high-speed ow of gas in the proppant fracture is linear non-Darcy two-phase ow, and the pressure changes along the fracture length with a parabola. For uniform pressure gradient, the ow pressure changes linearly with distance, and then   Advances in Civil Engineering where the P(x) is the fluid pressure, P 0 is the uniform pressure gradient，and x is the strength. When calculating the drag force acting on a single proppant, the gas-liquid two-phase flow in the propped fracture is considered. For both gas-phase flow and liquidphase flow, the total pressure drop of the entire joint length is assumed to be dP/dx, and the fluid pressure drop produces drag force. e wet phase surface is projected on the plane normal of the flow direction, as shown in Figure 8.
A segment of microelement distance dx on a single proppant particle is taken, and the drag force acting on this segment is where F drag(x) is the drag force at the distance between the proppant particles; A wp is the P(x) applied to the area at the distance between proppant particles, m 2 ; and P(x) is the pressure, MPa e unit stressed area on the proppant particle at x is

Substituting Equations (A.1) and (A.3) in Equation (A.2), we can get
Equation (A.4) describes the drag force acting on a segment of the proppant particle. e total drag force acting on the entire proppant particle can be viewed as a proppant particle composed of an infinite number of such segments: Integrate Equation (A.5) to obtain As the fluid flows through the propped fracture, the flow pressure drop generates a drag force, the action of which is shown in Figure 9. e drag force F drag is applied to the shaded area shown in the figure. It can be seen from the figure that the stressed area A p is half of the spherical area of proppant particles, A p � 2πR 2 . e intensity of drag force acting on A p is where P drag is the strength of drag force, MPa. Substituting Equation (A.6) in Equation (A.7), we can get [18] If the diameter of proppant particle is d p , then R � d p /2 is substituted into Equation (A.8) to obtain where d p is the proppant diameter, m.
(2) Strength of Static Friction Force f n . e value of static friction force is proportional to the product of closing pressure, particle contact area, and static friction coefficient. e larger the closing pressure, the larger the particle contact area, the rougher the particle surface, and the greater the static friction force. e less likely the proppant is to start (Figure 10). e maximum static friction force can be expressed as where f n is the static friction force, μ is the static friction coefficient, and P c is the closing stress.
(3) Equivalent Capillary Force σ , c Strength. During the production process of fractured gas wells, there are multiphase fluids in fractures, including working fluid residual in fractures and formation fluid. e flow in fractures is gasliquid two-phase. With the flow of natural gas, capillary resistance occurs, and the direction is opposite to the flow direction of the fluid, hindering the flow of the fluid. When the fluid breaks through the capillary force, it can be seen from the acting and reaction forces that the proppant particles are started by a force consistent with the flow direction and a drag force. is force is called the equivalent capillary force, which is equal to the capillary force and opposite to the capillary force, as shown in Figure 11. Assuming that the proppant particle size is uniform, tangential contact capillary force of particles with uniform size can be expressed as Among them, where θ c is the contact angle, α c is the angle between the radius of the solid-liquid boundary on the proppant particle and the vertical axis, σ is the interfacial tension between fluids, N/m, and d p is the diameter of the proppant. Since there is no difference in particle size, the capillary force strength in tangential contact of particles can be expressed as where d p is the diameter of proppant, so R � d p /2. Put in the above equation to obtain the following: Advances in Civil Engineering (A.14)

B. Critical Conditions under Which Proppant Is Not Discharged under Recovery Conditions Part Formula Derivation
(1) Pressure Gradient Force F p . e fluid flows under the action of pressure gradient, within which the force on the surface of proppant particles is different, and the resultant force on the surface is the pressure gradient force of proppant particles, which can be expressed as where r is the radius of the proppant particle, zP/zx is the pressure gradient, and its direction is consistent with the movement direction of the proppant particle. Under a certain pressure gradient, the liquid will flow. According to the non-Darcy seepage formula, it can be seen that Substitute the above equation in Equation (B.2), and the force generated by the pressure gradient can be expressed by fluid velocity as follows: (2) Gravity F G . e gravity of proppant particles in the gas is the gravity after considering the buoyancy force, and its relationship is where ρ s is the density of proppant and ρ q is the density of gas. e gas density ρ q � 28.97c g P/RTZ is substituted in equation (B.4):

C. Calculation Model of Proppant Migration Fluid Velocity Part Formula Derivation
Before the reservoir rock is deformed, its original porosity is where V f is the total volume of rock, m 3 , and V p is the pore volume,m 3 , and V r is the volume of rock skeleton, m 3 .
(1) Effect of Pressure Change. In the process of gas storage injection and production, when the formation conditions change from initial state (P 0 , t 0 ) to state (P, t 0 ), the volumetric strain coefficient of rock in this process is ε v . en, the total volume change of rock is (C.2) (2) Influence of Proppant Separation, Deposition, and Blockage. e separation of proppant, deposition on pore surface, and blockage in throat are attributed to the change of rock skeleton volume, which makes the skeleton volume decrease to negative and increase to positive. erefore, the change of rock skeleton volume can be expressed as where R r is the mass separation amount of skeleton proppant on unit volume rock, kg/m 3 ；R d is the mass deposition of proppant on the pore surface per unit volume of rock, kg/m 3 ；R p is the mass retention of proppant in pore throat blockage on unit volume rock, kg/m 3 . R r is determined by the skeleton stripping constitutive equation as follows: where λ is the liquefaction coefficient of rock, which is determined by experimental test; q is the volume of fluid and proppant mixture flowing through unit area in unit time; and C s is the volume concentration of proppant. R d is determined by the pore surface deposition equation as follows: where K d1 and K d2 are surface deposition rate constants.
where K p is the pore throat plugging rate constant. When t � 0, R p � 0, so the porosity of rock under pressure and after proppant separation, deposition, and plugging at pore throat is Substitute equation (C.1) and equation (C.2) into equation (C.7): where R c is the discharge amount of particles per unit volume of rock with liquid, kg/m 3 . en, the porosity after proppant is carried out of the reservoir by liquid is In the stable production stage of the gas storage, the bottom hole pressure remains unchanged and the resulting pressure drop remains constant. e 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.
en, the porosity of proppant after being carried out of gas storage by liquid is Data Availability e data (data type) used to support the findings of this study are included within the article.

Conflicts of Interest
e authors declare that they have no conflicts of interest.