A method for efficient delivery and placement of proppant in tight sand-shale reservoirs

Abstract

This invention provides a method for efficient proppant delivery and placement in tight sandstone and conglomerate reservoirs, belonging to the field of unconventional oil and gas exploration and development technology. The invention includes the following steps: determining the surface roughness of the hydraulic fracture in the sandstone and conglomerate reservoir; determining the effective width of the hydraulic fracture based on the surface roughness; determining the sand transport index of the hydraulic fracture based on the effective fracture width; determining the hydraulic fracturing sand transport capacity index; and optimizing the sand transport parameters using dimensionless sand transport capacity. This invention can rapidly optimize proppant delivery and placement by utilizing hydraulic fracture parameters and hydraulic fracturing construction parameters, combining the sand transport capacity of the fracture itself with the sand transport capacity of the construction conditions. This provides a basis for optimizing fracturing schemes in tight sandstone and conglomerate oil and gas reservoirs, and is beneficial for improving the fracturing effect in tight sandstone and conglomerate oil and gas reservoirs.

Description

Technical Field

[0001] This invention relates to the field of unconventional oil and gas exploration and development technology, and in particular to a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs. Background Technology

[0002] While tight reservoirs in different regions are generally tight, they exhibit strong heterogeneity and significant differences in the content of mobile fluids. Unconventional reservoirs are characterized by diverse lithologies, complex pore structures, and strong heterogeneity, resulting in large variations in single-well productivity and unclear patterns in effective crude oil recovery efficiency. Therefore, effective reservoir stimulation is essential for economical and efficient development. Currently, hydraulic fracturing technology has become a key method for unconventional oil and gas development. Hydraulic fracturing effectively stimulates reservoirs, creating single- or multi-stage transverse fractures or complex fracture networks along the wellbore. Simultaneously, fracturing fluid carries proppant into the fractures. After fracturing, the proppant provides effective support to the fractures, offering highly conductive channels for oil and gas flow, thereby increasing productivity. However, the high surface roughness and gravel embedding characteristics of hydraulic fractures in tight sandstone reservoirs make the effective delivery and placement of proppant a major challenge in hydraulic fracturing operations in tight sandstone. Current research on proppant delivery in the oil and gas development field of the petroleum industry mainly utilizes numerical simulation or physical experimental simulation methods, resulting in a largely qualitative understanding of proppant delivery and a lack of effective methods for proppant delivery in hydraulic fractures of tight sandstone reservoirs. Therefore, a highly efficient proppant delivery and placement method is urgently needed for hydraulic fractures in tight sandstone reservoirs.

[0003] The existing technology has the following shortcomings:

[0004] 1. Studies using numerical simulation or physical experiment simulation methods have yielded mostly qualitative understandings of proppant delivery, lacking effective proppant delivery methods for hydraulic fractures in tight sandstone. Summary of the Invention

[0005] To address the problems existing in the prior art, this invention provides a method for efficient proppant delivery and placement in tight sandstone and conglomerate reservoirs, comprising the following steps: determining the surface roughness of the hydraulic fracture in the sandstone and conglomerate reservoir; determining the effective width of the hydraulic fracture based on the surface roughness; determining the proppant transport index of the hydraulic fracture based on the effective width; determining the proppant transport capacity index of the hydraulic fracture; and optimizing the proppant transport parameters using dimensionless proppant transport capacity. This invention can rapidly optimize proppant delivery and placement by utilizing hydraulic fracture parameters and hydraulic fracturing construction parameters, combining the proppant transport capacity of the fracture itself with the proppant transport capacity of the construction conditions. This provides a basis for optimizing fracturing schemes in tight sandstone and conglomerate oil and gas reservoirs, and is beneficial for improving the fracturing effect in tight sandstone and conglomerate oil and gas reservoirs.

[0006] This invention provides a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, comprising the following steps:

[0007] Determine the surface roughness of hydraulic fractures in sandstone and conglomerate reservoirs;

[0008] The effective width of hydraulic fractures in conglomerate reservoirs is determined based on the surface roughness of the hydraulic fractures.

[0009] The sand transport index of hydraulic fractures in sandstone and conglomerate is determined based on the effective fracture width;

[0010] Determine the hydraulic fracturing sand transport capacity index;

[0011] Dimensionless sand conveying capacity is used to optimize sand conveying parameters.

[0012] Preferably, the roughness of the hydraulic fracture surface of the sandstone and conglomerate reservoir is characterized by the gravel size and gravel density over the fracture length.

[0013] Preferably, the root mean square error of the hydraulic fracture surface roughness in sandstone and conglomerate reservoirs is calculated using the following formula:

[0014]

[0015] In the formula,

[0016] σ Δ This represents the root mean square error of the crack surface roughness.

[0017] d. Average grain size of gravel embedded in the crack surface;

[0018] n1 is the number of gravels protruding one-fifth of the grain size from the crack surface;

[0019] n2 is the number of gravels protruding one-quarter of the grain size from the crack surface;

[0020] n3 is the number of gravels that protrude one-third of the grain size from the crack surface.

[0021] n4 represents the number of gravels protruding from the crack surface by half the grain size.

[0022] Preferably, the effective fracture width is determined based on the surface roughness of the hydraulic fracture in the conglomerate reservoir, the actual fracture width, and the corrected fracture width considering the concentration effect.

[0023] Preferably, the actual seam width is calculated using the following formula:

[0024] w re =w-0.5σ Δ ;

[0025] In the formula,

[0026] w re This represents the actual seam width;

[0027] w represents the dynamic seam width.

[0028] Preferably, the corrected slit width, taking into account the concentration effect, is calculated using the following formula:

[0029]

[0030] In the formula,

[0031] w c Corrected slit width to account for concentration effects;

[0032] ρ v This refers to the bulk density of the proppant.

[0033] Preferably, the effective seam width is calculated using the following formula:

[0034]

[0035] In the formula,

[0036] w eff For effective seam width.

[0037] Preferably, the sand transport index of hydraulic fractures in sandstone and conglomerate is calculated using the following formula based on the effective fracture width:

[0038]

[0039] In the formula,

[0040] I e The sand transport index is the hydraulic fracture transport index of conglomerate reservoirs.

[0041] c represents the proppant ratio;

[0042] D represents the proppant particle size;

[0043] ρ r This is the true density of the proppant.

[0044] Preferably, the hydraulic fracturing sand transport capacity index is calculated using the following formula:

[0045] I a =0.8μV st

[0046] In the formula,

[0047] I a The hydraulic fracturing sand transport capacity index;

[0048] μ is the viscosity of the fracturing fluid;

[0049] V st This refers to the fracturing fluid discharge rate.

[0050] Preferably, after obtaining the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index, the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index are normalized.

[0051] Preferably, the dimensionless sand conveying capacity is calculated using the following formula:

[0052]

[0053] In the formula,

[0054] I D Dimensionless sand transport capacity;

[0055] The normalized hydraulic fracturing sand transport capacity index;

[0056] The normalized sediment transport index of hydraulic fractures.

[0057] Preferably, optimizing sand conveying parameters based on dimensionless sand conveying capacity includes:

[0058] When I D A value greater than 1 indicates that the sand conveying parameters do not need to be optimized.

[0059] When I D When the value is less than 1, it indicates that the sand conveying parameters need to be optimized, and formula I should be changed. a =0.8μV st μ and V in st The value until I D >1, sand conveying parameters optimization completed.

[0060] Based on sandstone reservoir fracture parameters and hydraulic fracturing construction parameters, this invention proposes a method for rapidly optimizing proppant delivery and placement using these parameters. This method combines the proppant transport capacity of the fracture itself with the proppant transport capacity of the construction conditions, providing a basis for optimizing fracturing schemes in tight sandstone and conglomerate oil and gas reservoirs and improving the fracturing effect in tight sandstone and conglomerate oil and gas reservoirs. Attached Figure Description

[0061] Figure 1 A flowchart illustrating a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to an embodiment of the present invention;

[0062] Figure 2 A flowchart illustrating a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to another embodiment of the present invention;

[0063] Figure 3 This is a flowchart of a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, according to another embodiment of the present invention. Detailed Implementation

[0064] The following is in conjunction with the appendix Figure 1-3 The specific embodiments of the present invention will be described in detail below.

[0065] This invention provides a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, comprising the following steps:

[0066] Determine the surface roughness of hydraulic fractures in sandstone and conglomerate reservoirs;

[0067] The effective width of hydraulic fractures in conglomerate reservoirs is determined based on the surface roughness of the hydraulic fractures.

[0068] The sand transport index of hydraulic fractures in sandstone and conglomerate is determined based on the effective fracture width;

[0069] Determine the hydraulic fracturing sand transport capacity index;

[0070] Dimensionless sand conveying capacity is used to optimize sand conveying parameters.

[0071] According to one specific embodiment of the present invention, the roughness of the hydraulic fracture surface of a sandstone-conglomerate reservoir is characterized by the gravel size and gravel density along the fracture length. Since the unevenness of the hydraulic fracture surface of a sandstone-conglomerate reservoir is mainly caused by gravel embedded in the fracture surface, the roughness of the hydraulic fracture surface of the sandstone-conglomerate reservoir is characterized by the gravel size and gravel density along the fracture length.

[0072] According to a specific embodiment of the present invention, the root mean square error of the surface roughness of hydraulic fractures in conglomerate reservoirs is calculated using the following formula:

[0073]

[0074] In the formula,

[0075] σ Δ This represents the root mean square error of the crack surface roughness.

[0076] d. Average grain size of gravel embedded in the crack surface;

[0077] n1 is the number of gravels protruding one-fifth of the grain size from the crack surface;

[0078] n2 is the number of gravels protruding one-quarter of the grain size from the crack surface;

[0079] n3 is the number of gravels that protrude one-third of the grain size from the crack surface.

[0080] n4 represents the number of gravels protruding from the crack surface by half the grain size.

[0081] According to one specific embodiment of the present invention, the effective fracture width is determined based on the surface roughness of the hydraulic fracture in a conglomerate reservoir, the actual fracture width, and a corrected fracture width considering the concentration effect. The hydraulic fracture surface in conglomerate reservoirs has a relatively large degree of unevenness; the actual fracture width is related to the fracture roughness, while the effective fracture width is related to both the actual fracture width and the corrected fracture width considering the concentration effect.

[0082] According to a specific embodiment of the present invention, the actual seam width is calculated using the following formula:

[0083] w re =w-0.5σ Δ ;

[0084] In the formula,

[0085] w re This represents the actual seam width;

[0086] w represents the dynamic seam width.

[0087] According to a specific embodiment of the present invention, the corrected slit width considering the concentration effect is calculated using the following formula:

[0088]

[0089] In the formula,

[0090] w c Corrected slit width to account for concentration effects;

[0091] ρ v This refers to the bulk density of the proppant.

[0092] According to a specific embodiment of the present invention, the effective seam width is calculated using the following formula:

[0093]

[0094] In the formula,

[0095] w eff For effective seam width.

[0096] According to a specific embodiment of the present invention, the sand transport index of hydraulic fractures in conglomerate is calculated based on the effective fracture width using the following formula:

[0097]

[0098] In the formula,

[0099] I e The sand transport index is the hydraulic fracture transport index of conglomerate reservoirs.

[0100] c represents the proppant ratio;

[0101] D represents the proppant particle size;

[0102] ρ r This is the true density of the proppant.

[0103] According to a specific embodiment of the present invention, the hydraulic fracturing sand transport capacity index is calculated using the following formula:

[0104] Ia =0.8μV st

[0105] In the formula,

[0106] I a The hydraulic fracturing sand transport capacity index;

[0107] μ is the viscosity of the fracturing fluid;

[0108] V st This refers to the fracturing fluid discharge rate.

[0109] According to a specific embodiment of the present invention, after obtaining the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index, the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index are normalized.

[0110] According to a specific embodiment of the present invention, the dimensionless sand conveying capacity is calculated using the following formula:

[0111]

[0112] In the formula,

[0113] I D Dimensionless sand transport capacity;

[0114] The normalized hydraulic fracturing sand transport capacity index;

[0115] The normalized sediment transport index of hydraulic fractures.

[0116] According to a specific embodiment of the present invention, optimizing sand conveying parameters based on dimensionless sand conveying capacity includes:

[0117] When I D A value greater than 1 indicates that the sand conveying parameters do not need to be optimized.

[0118] When I D When the value is less than 1, it indicates that the sand conveying parameters need to be optimized, and formula I should be changed. a =0.8μV st μ and V in st The value until I D >1, sand conveying parameters optimization completed.

[0119] Example 1

[0120] According to a specific embodiment of the present invention, the method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs is described in detail below.

[0121] This invention provides a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, comprising the following steps:

[0122] Determine the surface roughness of hydraulic fractures in sandstone and conglomerate reservoirs;

[0123] The effective width of hydraulic fractures in conglomerate reservoirs is determined based on the surface roughness of the hydraulic fractures.

[0124] The sand transport index of hydraulic fractures in sandstone and conglomerate is determined based on the effective fracture width;

[0125] Determine the hydraulic fracturing sand transport capacity index;

[0126] Dimensionless sand conveying capacity is used to optimize sand conveying parameters.

[0127] Example 2

[0128] According to a specific embodiment of the present invention, the method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs is described in detail below.

[0129] This invention provides a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, comprising the following steps:

[0130] Determine the surface roughness of hydraulic fractures in conglomerate reservoirs; characterize the roughness of the hydraulic fracture surface using gravel size and gravel density along the fracture length; calculate the root mean square error of the surface roughness of hydraulic fractures in conglomerate reservoirs using the following formula:

[0131]

[0132] In the formula,

[0133] σΔ represents the root mean square error of the crack surface roughness;

[0134] d. Average grain size of gravel embedded in the crack surface;

[0135] n1 is the number of gravels protruding one-fifth of the grain size from the crack surface;

[0136] n2 is the number of gravels protruding one-quarter of the grain size from the crack surface;

[0137] n3 is the number of gravels that protrude one-third of the grain size from the crack surface.

[0138] n4 is the number of gravels protruding from the crack surface by half the grain size;

[0139] The effective fracture width is determined based on the surface roughness of the hydraulic fracture in the conglomerate reservoir, the actual fracture width, and the corrected fracture width considering the concentration effect. The actual fracture width is calculated using the following formula:

[0140] w re =w-0.5σ Δ ;

[0141] In the formula,

[0142] w re This represents the actual seam width;

[0143] w represents the dynamic seam width.

[0144] The corrected slit width, taking into account the concentration effect, is calculated using the following formula:

[0145]

[0146] In the formula,

[0147] w c Corrected slit width to account for concentration effects;

[0148] ρ v This refers to the bulk density of the proppant.

[0149] The effective seam width is calculated using the following formula:

[0150]

[0151] In the formula,

[0152] w eff For effective seam width.

[0153] The sand transport index of hydraulic fractures in sandstone and conglomerate is calculated using the following formula based on the effective fracture width:

[0154]

[0155] In the formula,

[0156] I e The sand transport index is the hydraulic fracture transport index of conglomerate reservoirs.

[0157] c represents the proppant ratio;

[0158] D represents the proppant particle size;

[0159] ρ r This is the true density of the proppant.

[0160] The hydraulic fracturing sand transport capacity index is determined using the following formula:

[0161] I a =0.8μV st

[0162] In the formula,

[0163] I a The hydraulic fracturing sand transport capacity index;

[0164] μ is the viscosity of the fracturing fluid;

[0165] V stThis refers to the fracturing fluid discharge rate.

[0166] After obtaining the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index, they were normalized. The min-max normalization method was used, and the normalization was performed using the following formula:

[0167]

[0168] In the formula,

[0169] x * These are the normalized sample data values;

[0170] x represents the sample data value;

[0171] min is the minimum value in the sample;

[0172] `max` is the maximum value in the sample.

[0173] The dimensionless sand conveying capacity is calculated using the following formula:

[0174]

[0175] In the formula,

[0176] I D Dimensionless sand transport capacity;

[0177] The normalized hydraulic fracturing sand transport capacity index;

[0178] The normalized sediment transport index of hydraulic fractures.

[0179] Optimizing sand transport parameters based on dimensionless sand transport capacity includes:

[0180] When I D A value greater than 1 indicates that the sand conveying parameters do not need to be optimized.

[0181] When I D When the value is less than 1, it indicates that the sand conveying parameters need to be optimized, and formula I should be changed. a =0.8μV st μ and V in st The value until I D >1, sand conveying parameters optimization completed.

[0182] Example 3

[0183] This embodiment takes the 10 hydraulic fracturing operations of the Upper Urho Formation of the Permian in the Mahu 1 well area of ​​the southern slope of the Mahu Depression in the Junggar Basin as an example. As shown in Table 1, the burial depth of the reservoir is 3434.76 to 3470.83 m, and the average formation pressure in this well section is 52.8 MPa.

[0184] Table 1. List of parameters obtained from each hydraulic fracturing operation.

[0185]

[0186] This invention provides a method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, comprising the following steps:

[0187] 1. Determine the roughness of the hydraulic fracture surface in the sandstone and conglomerate reservoir; use the gravel size and gravel density along the fracture length to characterize the roughness of the hydraulic fracture surface in the sandstone and conglomerate reservoir. Collect gravel particles with a fracture surface size of approximately 2 to 8 cm in this block and calculate the root mean square error of the fracture surface roughness.

[0188] 2. Collect the dynamic fracture width and proppant bulk density of hydraulic fractures formed during fracturing operations in this block. Determine the effective fracture width based on the surface roughness of the hydraulic fractures in the conglomerate reservoir, the actual fracture width, and the corrected fracture width considering the concentration effect.

[0189] The actual seam width is calculated using the following formula:

[0190] w re =w-0.5σ Δ ;

[0191] In the formula,

[0192] w re This represents the actual seam width;

[0193] w represents the dynamic seam width.

[0194] The corrected slit width, taking into account the concentration effect, is calculated using the following formula:

[0195]

[0196] In the formula,

[0197] w c Corrected slit width to account for concentration effects;

[0198] ρ v This refers to the bulk density of the proppant.

[0199] The effective seam width is calculated using the following formula:

[0200]

[0201] In the formula,

[0202] w eff For effective seam width.

[0203] The calculated effective seam width range is 6–15 mm.

[0204] 3. The proportion of 30 / 50 mesh quartz sand proppant used in the fracturing operation of this block ranges from 0.05 to 0.08, the proppant particle size ranges from 0.147 to 0.17 mm, and the proppant true density ranges from 2.4 to 2.8 g / cm³. 3 The sand transport index of hydraulic fractures in sandstone and conglomerate is calculated using the following formula based on the effective fracture width:

[0205]

[0206] In the formula,

[0207] I e The sand transport index is the hydraulic fracture transport index of conglomerate reservoirs.

[0208] c represents the proppant ratio;

[0209] D represents the proppant particle size;

[0210] ρ r This is the true density of the proppant.

[0211] The calculated range of the ten sets of hydraulic fracture sediment transport index values ​​is 5.95 to 222.22.

[0212] 4. The viscosity range of the proppant-carrying fluid collected during fracturing operations in this block is 40–80 mPa·s, and the displacement range is 10–20 m³ / s. 3 To determine the hydraulic fracturing sand transport capacity index, the following formula is used: (The index is calculated based on the given ratio of / min).

[0213] I a =0.8μV st

[0214] In the formula,

[0215] I a The hydraulic fracturing sand transport capacity index;

[0216] μ is the viscosity of the fracturing fluid;

[0217] V st This refers to the fracturing fluid discharge rate.

[0218] The calculated range of the ten sets of hydraulic fracturing sand transport capacity indices is 350 to 1100.

[0219] 5. The ten sets of hydraulic fracture sand transport indices and ten sets of hydraulic fracturing sand transport capacity indices were normalized using the min-max normalization method, and the normalization process was performed using the following formula:

[0220]

[0221] In the formula,

[0222] x* These are the normalized sample data values;

[0223] x represents the sample data value;

[0224] min is the minimum value in the sample;

[0225] `max` is the maximum value in the sample.

[0226] The normalized range of the ten sets of hydraulic fracture sand transport indices is 0.046 to 0.674, and the normalized range of the ten sets of hydraulic fracturing sand transport capacity indices is 0.040 to 0.800.

[0227] 6. The dimensionless sand conveying capacity is calculated using the following formula:

[0228]

[0229] In the formula,

[0230] I D Dimensionless sand transport capacity;

[0231] The normalized hydraulic fracturing sand transport capacity index;

[0232] The normalized sediment transport index of hydraulic fractures.

[0233] The eight dimensionless sand transport capacities obtained after removing the maximum and minimum values ​​are: 1.03, 0.87, 0.94, 1.10, 1.33, 1.64, 1.19, and 0.99. The dimensionless sand transport capacities are basically all around 1.

[0234] 7. The viscosity and displacement parameters in the hydraulic fracturing construction parameters with a dimensionless sand delivery capacity of less than 1 were adjusted to make the dimensionless sand delivery capacity greater than 1. In the end, all ten hydraulic fracturing operations met the requirements for proppant delivery and placement.

[0235] The above description is merely a preferred embodiment of the present invention and is not intended to limit the invention. Various modifications and variations can be made to the present invention by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention are included within the scope of protection of the present invention.

Claims

1. A method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs, characterized in that, Includes the following steps: Determine the surface roughness of hydraulic fractures in sandstone and conglomerate reservoirs; The effective width of hydraulic fractures in conglomerate reservoirs is determined based on the surface roughness of the hydraulic fractures. The sand transport index of hydraulic fractures in sandstone and conglomerate is determined based on the effective fracture width; Determine the hydraulic fracturing sand transport capacity index; Optimize sand conveying parameters by using dimensionless sand conveying capacity; Among them, the roughness of the hydraulic fracture surface of sandstone and conglomerate reservoirs is characterized by the gravel size and gravel density along the fracture length. The root mean square error of hydraulic fracture surface roughness in conglomerate reservoirs is calculated using the following formula: In the formula, This represents the root mean square error of the crack surface roughness. Average grain size of gravel embedded in the crack surface; The number of gravel protruding one-fifth of the grain size from the crack surface; The number of gravel particles protruding one-quarter of the grain size from the crack surface; The number of gravel particles protruding one-third of the grain size from the crack surface; The number of gravel particles protruding from the crack surface by half their diameter; The effective fracture width is determined based on the surface roughness of the hydraulic fracture in the conglomerate reservoir, the actual fracture width, and the corrected fracture width considering the concentration effect. The actual seam width is calculated using the following formula: ； In the formula, This represents the actual seam width; This refers to the dynamic seam width.

2. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 1, characterized in that, The corrected slit width, taking into account the concentration effect, is calculated using the following formula: ； In the formula, Corrected slit width to account for concentration effects; This refers to the bulk density of the proppant.

3. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 2, characterized in that, The effective seam width is calculated using the following formula: ； In the formula, For effective seam width.

4. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 3, characterized in that, The sand transport index of hydraulic fractures in sandstone and conglomerate is calculated using the following formula based on the effective fracture width: In the formula, The sand transport index is the hydraulic fracture transport index of conglomerate reservoirs. The proportion of proppant; For proppant particle size; This is the true density of the proppant.

5. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 4, characterized in that, The hydraulic fracturing sand transport capacity index is calculated using the following formula: In the formula, The hydraulic fracturing sand transport capacity index; The viscosity of the fracturing fluid; This refers to the fracturing fluid discharge rate.

6. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 5, characterized in that, After obtaining the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index, the hydraulic fracture sand transport index and the hydraulic fracturing sand transport capacity index are normalized.

7. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 6, characterized in that, Dimensionless sand transport capacity is calculated using the following formula: In the formula, Dimensionless sand transport capacity; The normalized hydraulic fracturing sand transport capacity index; The normalized sediment transport index for hydraulic fractures.

8. The method for efficient delivery and placement of proppant in tight sandstone and conglomerate reservoirs according to claim 7, characterized in that, Optimizing sand transport parameters based on dimensionless sand transport capacity includes: when A value greater than 1 indicates that the sand conveying parameters do not need to be optimized. when When the value is less than 1, it indicates that the sand conveying parameters need to be optimized and the formula needs to be changed. In and The value, until >1, sand conveying parameters optimization completed.

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