阅读说明：本技术 一种用于疏松砂岩油气储层的防砂增产方法及其应用 (Sand prevention and yield increase method for unconsolidated sandstone oil and gas reservoir and application of sand prevention and yield increase method ) 是由 董长银 刘亚宾 宋洋 赵益忠 张雷 李常友 皇凡生 王力智 周博 于 2020-03-18 设计创作，主要内容包括：本发明属于油气井开发和开采的技术领域,具体的涉及一种用于疏松砂岩油气储层的防砂增产方法及其应用。该种用于疏松砂岩油气储层的防砂增产方法,包括以下步骤：(1)拟防砂增产模式与充填形态；(2)目标储层适应性判别；(3)工艺参数的优化设计；(4)设计泵注施工程序。该方法提供了全套解决方案,评价优选和优化后的防砂增产方案能够最大化发挥其优势,实现最大幅度的增产效果,同时保证防砂效果。(The invention belongs to the technical field of development and exploitation of oil and gas wells, and particularly relates to a sand prevention and yield increase method for a loose sandstone oil and gas reservoir and application thereof. The sand control production increasing method for the unconsolidated sandstone oil and gas reservoir comprises the following steps: (1) simulating a sand control production increasing mode and a filling form; (2) judging the adaptability of the target reservoir; (3) optimizing and designing process parameters; (4) and designing a pump injection construction procedure. The method provides a complete set of solution, and the optimized and optimized sand control yield-increasing scheme is evaluated to give play to the advantages of the scheme to the maximum extent, so that the yield-increasing effect to the maximum extent is realized, and the sand control effect is ensured.)

1. A sand control production increasing method for a loose sandstone oil and gas reservoir is characterized by comprising the following steps:

(1) simulating a sand control production increasing mode and a filling form: plastically extruding the near wellbore zone to form an annular columnar packed gravel layer existing around the wellbore; extruding a far well zone outside the annular columnar filling gravel layer to form a crack filling zone;

(2) judging the adaptability of the target reservoir: judging whether the target reservoir stratum is suitable for the sand control production increasing mode and the filling form in the step (1); the reservoir conditions were adapted as follows: the initial failure mode is plastic extrusion failure, and along with the continuous pumping, the bottom hole pressure can reach reservoir fracture pressure along with the time change;

(3) optimization design of process parameters: according to the characteristics of the simulated sand control production increasing mode and the filling form, optimizing process parameters including the type and the particle size of a propping agent material, the thickness of a plastic filling layer, the width and the length of a fracture and the using amount of the propping agent are designed by combining the geology related to a target reservoir and the production condition;

(4) designing a pump injection construction procedure: firstly, pumping a pad fluid; then carrying out plastic extrusion filling, stopping adding sand when the pump pressure rises sharply, and continuing injecting the sand-carrying liquid by a large-discharge pump to ensure that the construction pressure rises steadily; when the pressure drops suddenly after a peak value, continuing pumping for 5-10 min, then starting sand pumping, maintaining the discharge capacity, stopping sand pumping after the total design sand amount calculated according to the sum of the volume of the plastic extrusion filling layer and the volume of the crack filling zone is pumped, and starting pumping displacement liquid, wherein the consumption of the displacement liquid is the sum of the volumes of the ground pipeline and the shaft pipe column; and finally, stopping the pump to release the pressure, and finishing the construction.

2. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs according to claim 1, wherein the specific operations identified in the step (2) are as follows:

firstly, calculating the compressive strength, the cohesion, the internal friction angle, the elastic modulus and the Poisson ratio of reservoir rock according to density logging and acoustic wave time difference logging information; calculating the original vertical principal stress, the original horizontal maximum principal stress and the original minimum horizontal principal stress of the reservoir according to the density logging information;

② calculating the fracture pressure P of the reservoir according to the conventional hydraulic fracturing mode based on the calculated data_fc，MPa；

③ the initial failure mode of near-well reservoir under high-pressure squeezing condition of well shaft is judged by firstly calculating the critical bottom hole pressure P generating plastic squeezing failure according to the following formula_cc；

P_cc＝σ_hmin+S_c

In the formula S_c-reservoir rock compressive strength, MPa;

σ_hmin-minimum horizontal principal stress of virgin formation, MPa;

P_cc-critical bottom hole pressure, MPa, producing plastic extrusion failure;

then the obtained P is_ccAnd P_fcMaking a comparison if P_cc<P_fcThe initial failure mode is plastic extrusion failure and the process continues to step ④ where if P is_cc≥P_fcIf the initial failure mode is fracture cracking extension, the target reservoir layer cannot implement a simulation sand control production increasing mode and a filling form, and the judgment is finished;

④ simulating and calculating the change rule of bottom hole pressure with time as the pumping is continued under the condition that the initial failure mode is plastic extrusion failure, and the reservoir fracture pressure P can be reached when the bottom hole pressure changes with time_fcThe target reservoir adapts to the simulated sand control production increasing mode and the filling form; when the bottom hole pressure changes with time and is always lower than the reservoir fracture pressure P_fcThe target reservoir is not suitable for the proposed sand control production increasing mode and filling form.

3. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 1, wherein the proppant material in step (3) is solid-phase proppant gravel, and the selection criteria of the type are as follows: firstly, for offshore oil and gas fields, artificial ceramsite is used; secondly, for land oil and gas fields, when the depth of a reservoir exceeds 2000m, using artificial ceramsite; when the depth of the reservoir is lower than 2000m, the high-yield well uses artificial ceramsite, and the medium-low-yield well uses quartz sand gravel.

4. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 3, wherein the specific design of the gravel particle size in step (3) is as follows: determining the median particle size of the gravel according to the median particle size of the formation sand, wherein the calculation formula is as follows:

D_g50＝K∙d₅₀

in the formula d₅₀-median particle size, mm, determined from formation sand sieve analysis curves;

D_g50median particle size, mm, of the proppant (gravel) used;

k is a design proportionality coefficient and is dimensionless;

the determination method for designing the proportionality coefficient K comprises the following steps: under general geological and production conditions, K is 5-6, and preferably 5.5; under the conditions that a thick oil reservoir or asphaltene in a non-thermal recovery oil reservoir is high in content and has a precipitation phenomenon, K is 7-8, and preferably 7.5; performing steam huff-puff thermal recovery on the heavy oil reservoir, wherein the value of K is 4-5, and preferably the value of K is 4.5; a high-yield oil well with the liquid production strength of more than 30t/d/m or a gas well with the gas production strength of more than 4 ten thousand square/d/m, wherein K is 4-5, and preferably 4.5; in a reservoir with the argillaceous content exceeding 25%, K takes 6-8, and preferably K is 7.0; k is 3-5, preferably 4.0, of medium-coarse formation sand with the median particle size of more than 0.2 mm; if the shaft and the ground equipment have strict sand control requirements, the K value is limited; otherwise, taking the average value or the upper limit; if multiple conditions occur simultaneously, taking the average value of the preferred K values of each individual condition;

after the median particle size of the gravel to be used is determined, the corresponding standard gravel size is selected according to the standard closest to the median particle size, and the minimum and maximum particle sizes are determined.

5. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 1, wherein the thickness of the plastic packing layer in step (3) is not less than 0.2 m.

6. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 5, wherein the thickness of the plastic packing layer in the step (3) is 0.2m to 1 m.

7. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 1, wherein the fracture packing zone in step (1) is a double-wing packing zone.

8. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs of claim 7, wherein the fracture width in the step (3) is 15-30 mm; the length of the single wing of the crack is 20-40 mm.

9. The sand control stimulation method for unconsolidated sandstone oil and gas reservoirs according to claim 1, wherein the pumping and injection construction procedure in the step (4) is specifically operated as follows:

① pump and inject pad fluid, the pad fluid consumption is the pore volume in the range of single wing crack length designed by near well radius, the discharge capacity is 0.8-1.0 m³/min；

② plastic extrusion filling, the pump sand injection ratio is 4.5-5.5% low sand ratio, the discharge capacity is more than 2.0m³Min; when the thickness of the reservoir is more than 10m, the thickness is 2.5-3.0 m³Construction at a discharge capacity of/min;

③ when the pump pressure rises sharply, stopping adding sand, continuing to pump the sand-carrying liquid according to step ② or increasing the displacement by 0.5m based on step ②³Pumping for min to ensure the construction pressure to rise stably;

fourthly, when the pressure drops suddenly after a peak value appears, continuing pumping for 5-10 min, then starting sand pumping, and maintaining the discharge capacity; the sand ratio is gradually increased according to three steps of 15%, 20% and 25%; the continuous pumping time of each sand ratio is determined according to the following principle: the sand adding amount in the continuous pumping time of each sand ratio is the same, and the continuous pumping time of each sand ratio is calculated according to the equal sand adding amount and each different sand ratio;

after the total design sand amount calculated according to the sum of the volume of the plastic extrusion filling layer and the volume of the crack filling zone is pumped, stopping adding sand, and starting pumping to inject a displacement liquid, wherein the usage amount of the displacement liquid is the sum of the volumes of the ground pipeline and the wellbore tubular column;

stopping pumping and releasing pressure to finish construction.

10. The use of the sand control stimulation method of claim 1 in unconsolidated sandstone oil and gas reservoirs where the petrophysical properties are between plastic and brittle.

Technical Field

The invention belongs to the technical field of development and exploitation of oil and gas wells, and particularly relates to a sand prevention and yield increase method for a loose sandstone oil and gas reservoir and application thereof.

Background

Among oil and gas reservoirs, unconsolidated sandstone and low permeability reservoirs are two major classes of hydrocarbon reservoirs. The loose sandstone reservoir is easy to produce sand due to loose cementation, and a sand prevention and control measure is needed during exploitation; the low permeability reservoir rock is compact in cementation, low in permeability and low in natural productivity, and hydraulic fracturing production increasing measures are needed during exploitation. Along with the aggravation of energy requirements, a fracturing filling sand control technology is gradually introduced into a sand control technology of a unconsolidated sandstone reservoir, namely, a hydraulic fracturing technology originally applied to a low-permeability reservoir is applied to a medium-high permeability unconsolidated sandstone reservoir, and meanwhile, the effects of preventing sand and increasing production are achieved.

At present, in loose sandstone reservoirs, gravel packing is taken as a mainstream sand control process technology for severe sand production reservoirs, and the technology mainly comprises two technologies of plastic extrusion packing and end desanding fracturing packing. The plastic extrusion filling is to extrude the weakly consolidated reservoir stratum to generate plastic fracture by a high-pressure extrusion injection mode, and fill gravel into a near-well stratum around a wellbore, wherein the failure mode of reservoir rock is plastic extrusion failure. While end-pack is a hydraulic fracture similar to low permeability formations, fracturing the reservoir and gravel packing, the failure mode of the reservoir rock is fracture cracking and extension packing.

At present, the damage modes of loose sandstone oil and gas reservoirs under the high-pressure squeezing condition are generally considered to be two types: plastic extrusion filling and crack extension filling. Obviously for very unconsolidated reservoirs, the plastic squeeze pack mode is both factually present and reasonable; fracture cracking extended pack patterns are also well recognized and accepted for reservoirs with better bond strength and for low permeability reservoirs. In other words, plastic squeeze filling and fracture crack extension filling are two extreme modes of rock failure, the former occurring in plastic rock reservoirs and the latter occurring in brittle rock reservoirs.

However, the plastic extrusion packing sand control and the fracturing packing sand control on unconsolidated sandstone oil and gas reservoirs in actual oil and gas fields have the following problems:

(1) for unconsolidated sandstone oil and gas reservoirs, under the condition of high-pressure squeezing and injecting solid-liquid mortar into the stratum, the rock failure mode of plastic extrusion filling or the rock failure mode of fracture cracking extension filling cannot cover all actual failure forms of the stratum as an extreme mode.

(2) For hydrocarbon reservoirs with reservoir rock properties between plastic and brittle, the reservoir may experience a combination of both plastic crush failure and fracture propagation failure modes. But the problems that still remain are: that is, the prior art is merely a very general assumption that there is a certain possibility of the coexistence of the two modes, and there is no clear definition and mechanism description of such coexistence mode; no clear method for judging whether the target reservoir layer can generate the concurrent damage mode is provided; the filling construction of the composite mode is difficult, the sand blockage is easy to cause construction failure in advance, and a corresponding process design method is lacked.

(3) For oil and gas reservoirs between plasticity and brittleness, the plastic extrusion filling sand control method or the fracturing filling sand control method is not consistent with the actual filling form of formation sand. Due to the disjunction of theory and practical application, the damage mode after high-pressure extrusion cannot be accurately grasped and judged, so that the theoretical model for optimizing design parameters is supported wrongly, further, the design and calculation data and the field actual data have huge deviation, the process technology and the construction parameters are not reasonable, and the actual final sand prevention effect is influenced.

Disclosure of Invention

The invention aims to provide a sand prevention production increasing method for a unconsolidated sandstone oil and gas reservoir and application thereof, aiming at the problems that the two existing extreme modes of the unconsolidated sandstone oil and gas reservoir cannot cover all actual damage forms of strata, and particularly the actual filling forms of stratum sand cannot be accurately judged for part of reservoirs with rock physical properties between plasticity and brittleness. The method provides a complete set of solution, and the optimized and optimized sand control yield-increasing scheme is evaluated to give play to the advantages of the scheme to the maximum extent, so that the yield-increasing effect to the maximum extent is realized, and the sand control effect is ensured.

The technical scheme of the invention is as follows: a sand control production increase method for a loose sandstone oil and gas reservoir comprises the following steps:

(1) simulating a sand control production increasing mode and a filling form: plastically extruding the near wellbore zone to form an annular columnar packed gravel layer existing around the wellbore; extruding a far well zone outside the annular columnar filling gravel layer to form a crack filling zone;

(2) judging the adaptability of the target reservoir: judging whether the target reservoir stratum is suitable for the sand control production increasing mode and the filling form in the step (1); the reservoir conditions were adapted as follows: the initial failure mode is plastic extrusion failure, and along with the continuous pumping, the bottom hole pressure can reach reservoir fracture pressure along with the time change;

(3) optimization design of process parameters: according to the characteristics of the simulated sand control production increasing mode and the filling form, optimizing process parameters including the type and the particle size of a propping agent material, the thickness of a plastic filling layer, the width and the length of a fracture and the using amount of the propping agent are designed by combining the geology related to a target reservoir and the production condition;

(4) designing a pump injection construction procedure: firstly, pumping a pad fluid; then carrying out plastic extrusion filling, stopping adding sand when the pump pressure rises sharply, and continuing injecting the sand-carrying liquid by a large-discharge pump to ensure that the construction pressure rises steadily; when the pressure drops suddenly after a peak value, continuing pumping for 5-10 min, then starting sand pumping, maintaining the discharge capacity, stopping sand pumping after the total design sand amount calculated according to the sum of the volume of the plastic extrusion filling layer and the volume of the crack filling zone is pumped, and starting pumping displacement liquid, wherein the consumption of the displacement liquid is the sum of the volumes of the ground pipeline and the shaft pipe column; and finally, stopping the pump to release the pressure, and finishing the construction.

The specific operation of the discrimination in the step (2) is as follows:

firstly, calculating the compressive strength, the cohesion, the internal friction angle, the elastic modulus and the Poisson ratio of reservoir rock according to density logging and acoustic wave time difference logging information; calculating the original vertical principal stress, the original horizontal maximum principal stress and the original minimum horizontal principal stress of the reservoir according to the density logging information;

② calculating the fracture pressure P of the reservoir according to the conventional hydraulic fracturing mode based on the calculated data_fc，MPa；

③ the initial failure mode of near-well reservoir under high-pressure squeezing condition of well shaft is judged by firstly calculating the critical bottom hole pressure P generating plastic squeezing failure according to the following formula_cc；

P_cc＝σ_hmin+S_c

In the formula S_c-reservoir rock compressive strength, MPa;

σ_hmin-minimum horizontal principal stress of virgin formation, MPa;

P_cc-critical bottom hole pressure, MPa, producing plastic extrusion failure;

then the obtained P is_ccAnd P_fcMaking a comparison if P_cc<P_fcThe initial failure mode is plastic extrusion failure and the process continues to step ④ where if P is_cc≥P_fcIf the initial failure mode is fracture cracking extension, the target reservoir layer cannot implement a simulation sand control production increasing mode and a filling form, and the judgment is finished;

④ simulating and calculating the change rule of bottom hole pressure with time as the pumping is continued under the condition that the initial failure mode is plastic extrusion failure, and the reservoir fracture pressure P can be reached when the bottom hole pressure changes with time_fcThe target reservoir adapts to the simulated sand control production increasing mode and the filling form; when the bottom hole pressure changes with time and is always lower than the reservoir fracture pressure P_fcThe target reservoir is not suitable for the proposed sand control production increasing mode and filling form.

The proppant material in the step (3) adopts solid-phase proppant gravel, and the selection criteria of the type are as follows: firstly, for offshore oil and gas fields, artificial ceramsite is used; secondly, for land oil and gas fields, when the depth of a reservoir exceeds 2000m, using artificial ceramsite; when the depth of the reservoir is lower than 2000m, the high-yield well uses artificial ceramsite, and the medium-low-yield well uses quartz sand gravel.

The specific design of the gravel particle size in the step (3) is as follows: determining the median particle size of the gravel according to the median particle size of the formation sand, wherein the calculation formula is as follows:

D_g50＝K·d₅₀

in the formula d₅₀-median particle size, mm, determined from formation sand sieve analysis curves;

D_g50median particle size, mm, of the proppant (gravel) used;

k is a design proportionality coefficient and is dimensionless;

the determination method for designing the proportionality coefficient K comprises the following steps: under general geological and production conditions, K is 5-6, and preferably 5.5; under the conditions that a thick oil reservoir or asphaltene in a non-thermal recovery oil reservoir is high in content and has a precipitation phenomenon, K is 7-8, and preferably 7.5; performing steam huff-puff thermal recovery on the heavy oil reservoir, wherein the value of K is 4-5, and preferably the value of K is 4.5; a high-yield oil well with the liquid production strength of more than 30t/d/m or a gas well with the gas production strength of more than 4 ten thousand square/d/m, wherein K is 4-5, and preferably 4.5; in a reservoir with the argillaceous content exceeding 25%, K takes 6-8, and preferably K is 7.0; k is 3-5, preferably 4.0, of medium-coarse formation sand with the median particle size of more than 0.2 mm; if the shaft and the ground equipment have strict sand control requirements, the K value is limited; otherwise, taking the average value or the upper limit; if multiple conditions occur simultaneously, taking the average value of the preferred K values of each individual condition;

after the median particle size of the gravel to be used is determined, the corresponding standard gravel size is selected according to the standard closest to the median particle size, and the minimum and maximum particle sizes are determined.

And (3) the thickness of the plastic filling layer in the step (3) is not less than 0.2 m.

The thickness of the plastic filling layer in the step (3) is 0.2-1 m.

And (2) the crack filling belt in the step (1) is a double-wing filling belt.

The width of the crack in the step (3) is 15-30 mm; the length of the single wing of the crack is 20-40 mm.

The pump injection construction procedure in the step (4) is specifically operated as follows:

① pump and inject pad fluid, the pad fluid consumption is the pore volume in the range of single wing crack length designed by near well radius, the discharge capacity is 0.8-1.0 m³/min；

② plastic extrusion filling, the pump sand injection ratio is 4.5-5.5% low sand ratio, the discharge capacity is more than 2.0m³Min; when the thickness of the reservoir is more than 10m, the thickness is 2.5-3.0 m³Construction at a discharge capacity of/min;

③ when the pump pressure rises sharply, stopping adding sand, continuing to pump the sand-carrying liquid according to step ② or increasing the displacement by 0.5m based on step ②³Pumping for min to ensure the construction pressure to rise stably;

fourthly, when the pressure drops suddenly after a peak value appears, continuing pumping for 5-10 min, then starting sand pumping, and maintaining the discharge capacity; the sand ratio is gradually increased according to three steps of 15%, 20% and 25%; the continuous pumping time of each sand ratio is determined according to the following principle: the sand adding amount in the continuous pumping time of each sand ratio is the same, and the continuous pumping time of each sand ratio is calculated according to the equal sand adding amount and each different sand ratio;

after the total design sand amount calculated according to the sum of the volume of the plastic extrusion filling layer and the volume of the crack filling zone is pumped, stopping adding sand, and starting pumping to inject a displacement liquid, wherein the usage amount of the displacement liquid is the sum of the volumes of the ground pipeline and the wellbore tubular column;

stopping pumping and releasing pressure to finish construction.

The sand control production increase method is applied to loose sandstone oil and gas reservoirs with rock physical properties between plasticity and brittleness.

The invention has the beneficial effects that: the sand control production increase method is different from the conventional fracturing filling and the plastic extrusion filling, and has great difficulty in the practical construction process, and the specific difficulty lies in that: because the pressure for generating the cracks is different from the pressure for plastic extrusion, the pressure condition for generating the cracks is higher than the pressure condition for plastic extrusion in terms of condition requirements, so that the problem of how to ensure that the plastic extrusion layer and the crack filling zone are perfectly connected and the far well crack filling zone and the near well plastic extrusion layer are completely and compactly filled is a great construction problem under the requirements of different pressure conditions. If the construction mode of the traditional fracturing filling is adopted, the construction with large discharge capacity and high pressure is directly adopted, although cracks can be formed, a larger-size near-well plastic filling layer is difficult to form, and the advantages of the near-well plastic filling layer cannot be exerted; if the conventional plastic extrusion filling construction mode is adopted, cracks cannot be formed.

In order to achieve the perfect connection and coexistence of the crack and the plastic extrusion mode and the complete compact filling, the method of the invention innovatively provides a new pump injection program design and construction method: beginning to construct in a plastic extrusion filling operation mode to form a plastic failure layer; after the plastic extrusion reaches a certain degree, the large displacement is continuously adjusted and controlled according to the time points to compact the plastic damage layer, so that the construction pressure is ensured to be stably increased, and conditions are provided for the crack cracking pressure. The crack is cracked and extended, and the originally filled gravel enters the crack again under the carrying of the large-discharge sand-carrying fluid; and adjusting and controlling the discharge capacity according to the time points, changing the sand ratio, and improving step by step to densely fill the far well fracture zone and the near well plastic failure layer from far to near. The construction mode can realize dense filling of all areas and can form perfect coexistence of a plastic filling layer and a crack filling zone.

According to the sand prevention production increase method, through high-pressure squeezing operation, a composite destruction mode that the reservoir generates plastic squeezing filling firstly and then perfectly links to generate crack extension filling is realized under the construction condition of reasonable innovative design, an effective sand blocking barrier is formed, the circulation capacity of the near-well reservoir is improved, and the dual purposes of sand prevention and production increase are realized; meanwhile, an adaptability evaluation judgment method, a parameter optimization design method and a pump injection construction method are provided, a complete-system efficient sand prevention production increasing method is provided for unconsolidated sandstone reservoirs, particularly reservoirs between plasticity and brittleness, and efficient development of a sand production well is realized. The method has the following advantages:

1. the sand control production increase methodBy means of a specific operating procedure, an annular columnar packed gravel layer existing around the wellbore is formed in the near wellbore region, and a fracture packing zone, preferably two packing zones of double wings, is formed outside the packed gravel layer. The fracture filling zone of the far well (outside the filling gravel layer) has the effects of increasing production and preventing sand, and has higher permeability and seam width firstly, so that the fracture conductivity (the product of seam width and permeability) is higher, the fluidity of the fracture filling zone is far higher than that of the original stratum, the resistance of reservoir fluid flowing to a shaft is greatly reduced, and the production increasing effect is achieved; and the quartz sand gravel or the artificial ceramsite filled in the cracks can block formation sand in the fluid. The near-well plastic extrusion filling layer can effectively reduce the near-well flow resistance while playing a role in blocking sand, because the closer to a shaft, the flow area of the reservoir converged and flowed to the well is sharply reduced, the fluid flow rate is increased, and the pressure loss is increased. The permeability of the plastic extrusion filling layer can be kept between 20 and 40 mu m²About, far higher than the original formation permeability (generally lower than 0.5-1.0 μm)²) The flow resistance can be greatly reduced, and the yield of the oil-gas well is improved. Therefore, the sand control and production increase mode and the filling form which are combined by the far well fracture filling zone and the near well plastic extrusion filling layer can realize high-efficiency sand control and production increase simultaneously, and the sand control effect and the production increase effect are superior to those of the existing pure plastic extrusion filling sand control and fracturing filling sand control.

2. The method for preventing sand and increasing the yield overcomes the defects of the existing method system for preventing sand of the unconsolidated sandstone reservoir, solves the problem that the sand prevention mode of the partially unconsolidated sandstone reservoir with the petrophysical property between plasticity and brittleness is difficult to define, and avoids the problem of poor comprehensive sand prevention effect caused by singly performing sand prevention design and implementation according to plastic extrusion filling (suitable for plastic strata) or fracturing filling (suitable for brittle strata).

3. The sand control production increase method simultaneously provides adaptive conditions and judgment thereof, parameter optimization design and construction pump injection, and particularly provides a complete set of solution for unconsolidated sandstone reservoirs with physical properties between plasticity and brittleness. The optimized and optimized sand control scheme is evaluated, so that the advantages of the optimized and optimized sand control scheme can be played to the maximum extent, the yield increasing effect to the maximum extent is realized, and the sand control effect is ensured.

4. The sand control production increase method has the advantages of simple and easy links, convenient operation and reduced design and construction cost.

Drawings

FIG. 1 is a schematic diagram of a pseudo sand stimulation mode and packing configuration in an embodiment.

FIG. 2 is a schematic diagram of sand control of existing plastic extrusion packing and fracturing packing;

FIG. 3 is a graphical illustration of a target reservoir suitability determination chart in accordance with an embodiment;

FIG. 4 is a graph of the crack size optimization layout and feasible crack width-crack length combinations for case 1.

Detailed Description

The present invention will be described in detail below with reference to examples.