阅读说明：本技术 砂岩油藏高含水后期多级稳定长效防砂工艺方法 (High-water-content later-stage multi-stage stable long-acting sand prevention process method for sandstone oil reservoir ) 是由 张煜 汪庐山 李常友 李鹏 赵益忠 刘玉国 姜静 陈刚 王勇 梁伟 于 2019-10-15 设计创作，主要内容包括：本发明提供一种砂岩油藏高含水后期多级稳定长效防砂工艺方法,该砂岩油藏高含水后期多级稳定长效防砂工艺方法包括：步骤1,建立储层失稳模型及失稳程度判别方法；步骤2,进行基于流体流速实时调控的储层失稳预防；步骤3,进行高效化学剂物化耦合储层原位稳定及骨架再建；步骤4,进行储层近井亏空坍塌高强高渗人工井壁重构；步骤5,进行井筒高渗流防堵塞滤砂管防砂；步骤6,进行储层渗流能力恢复处理。该砂岩油藏高含水后期多级稳定长效防砂工艺方法有效降低了高含水期油藏储层骨架砂破坏和出砂程度,解除了水驱及聚驱后油藏近井堵塞,提高了液量水平,实现了油田疏松砂岩油藏高效开发。(The invention provides a process method for multi-stage stable long-acting sand control in a high water-cut later period of a sandstone reservoir, which comprises the following steps: step 1, establishing a reservoir instability model and an instability degree judging method; step 2, performing reservoir instability prevention based on real-time regulation and control of fluid flow rate; step 3, performing efficient chemical agent physicochemical coupling reservoir in-situ stabilization and skeleton reconstruction; step 4, reconstructing a near-well deficit collapse high-strength high-permeability artificial well wall of the reservoir; step 5, performing high-seepage anti-blocking sand control on the shaft through a sand filter pipe; and 6, performing reservoir seepage capability recovery treatment. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand prevention process method effectively reduces the sand damage and sand production degree of the reservoir framework of the reservoir in the high-water-cut stage, removes the near-well blockage of the reservoir after water flooding and polymer flooding, improves the liquid level, and realizes the high-efficiency development of the unconsolidated sandstone reservoir in the oil field.)

1. The process method for the multistage stable long-acting sand control in the high water-cut later period of the sandstone oil reservoir is characterized by comprising the following steps of:

step 1, establishing a reservoir instability model and an instability degree judging method;

step 2, performing reservoir instability prevention based on real-time regulation and control of fluid flow rate;

step 3, performing efficient chemical agent physicochemical coupling reservoir in-situ stabilization and skeleton reconstruction;

step 4, reconstructing a near-well deficit collapse high-strength high-permeability artificial well wall of the reservoir;

step 5, performing high-seepage anti-blocking sand control on the shaft through a sand filter pipe;

and 6, performing reservoir seepage capability recovery treatment.

2. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 1, wherein in the step 1, a loose sandstone strength parameter dynamic model, a well circumferential stress model and a destabilization judgment criterion are coupled, a well circumferential destabilization damage model taking mechanical analysis as a core is established, sand production simulation calculation is performed on the basis of the destabilization damage model, and a destabilization quantitative evaluation standard is formed.

3. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 2, wherein in the step 1, the sand production critical production pressure difference and the destabilization sand production radius are quantitatively calculated, and the reservoir instability levels, namely primary instability, secondary instability and tertiary instability, are determined.

4. The sandstone reservoir high-water-cut later-stage multi-stage stable long-acting sand control process method according to claim 1, wherein the step 2 comprises the following steps:

step 201, calculating sand production indexes of a target reservoir under different production pressure differences by adopting a reservoir dynamic sand production prediction model, and judging the sand production degree of the reservoir according to the sand production indexes;

step 202, calculating the corresponding liquid production amount of the oil well under different production pressure differences;

step 203, adjusting the oil well to continuously produce for 24-72 hours according to smaller pressure difference, monitoring the liquid production amount and sand content under the pressure difference through a wellhead sand production real-time monitoring system, and judging the sand production trend of the oil well under the liquid production amount;

204, adjusting the oil well to continuously produce for 24-72h respectively according to the medium differential pressure, namely 2-5MPa and the larger differential pressure, namely more than 5MPa, monitoring the liquid yield and the sand content under different step differential pressures, and judging the sand production trend of the oil well;

step 205, if the sand production amount under a certain pressure difference or liquid amount is obviously increased and the sand content is more than 0.03-0.05% in the regulation process, the 0.03% sand content corresponds to the liquid amount which is reasonable for the well, the 0.05% sand content is the maximum liquid amount for the well, and the reservoir instability and damage can be caused when the sand content exceeds 0.05%, so that a large amount of sand is produced and the well is laid.

5. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 1, wherein in the step 3, a DX-1 type reservoir deep multi-branched erosion-resistant sand stabilizing system is adopted for a sand-producing light reservoir; the system consists of a rigid backbone and a plurality of functional groups; the phenolic aldehyde-epoxy resin rigid main chain has high thermal stability, the epoxy group has high activity and is easy to open the ring, linear molecules form body-shaped molecules through self-crosslinking, siloxane groups and silicon hydroxyl on the surface of the formation sand generate covalent bonding, NH + groups can be electrically adsorbed with a reservoir, and water-soluble sodium phenolate, hydroxyl and secondary amino and the silicon hydroxyl on the surface of the formation sand generate hydrogen bond bonding; and epoxy groups.

6. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 5, wherein in the step 3, a near-well high-strength high-permeability oil-resistant sand stabilizing system of a GC-1 type reservoir is adopted for a sand-producing medium reservoir; the system is that oleophylic and hydrophilic groups are grafted on an epoxy resin main chain to synthesize an oil-resistant sand stabilizing agent main agent, and a curing agent is added to form a basic formula of the oil-resistant sand stabilizing agent: the mass ratio of the fine quartz sand to the active sand consolidation agent to the gamma-glycidoxypropyltrimethoxysilane to the modified amine curing agent to the softening agent is 100:10:8:10: 15.

7. The sandstone reservoir high-water-cut later-stage multi-stage stable long-acting sand control process method according to claim 6, wherein the step 3 comprises the following steps:

301, carrying out simulation calculation on the use concentration and the use amount of a multi-branched erosion-resistant sand stabilizing system with a sand producing radius and a DX-1 type reservoir deep part and a GC-1 type reservoir near-well zone high-strength high-permeability oil-resistant sand stabilizing system;

302, putting a construction pipe column of a high-efficiency stable system of a reservoir, putting 23/8in, 27/8in and 31/2in oil pipes in a single-layer underground manner, and putting an integrated injection pipe column in a multi-layer underground manner;

step 303, injecting the determined dosage into a sand stabilizing system in a layered mode, wherein the processing radius of the deep multi-branched erosion-resistant sand stabilizing system of the DX-1 type reservoir is 3-5 meters, and the processing radius of the high-strength high-permeability oil-resistant sand stabilizing system of the near-well zone of the GC-1 type reservoir is 1-3 meters;

304, closing the well, reacting, waiting for 24-72 hours, taking out the construction pipe column, and recording the pressure of the well head;

and 305, lowering a sand-washing or plug-drilling pipe column, washing or drilling to the designed well depth, and cleaning the well.

8. The sandstone reservoir high-water-cut later-stage multi-stage stable long-acting sand control process method according to claim 1, wherein the step 4 comprises the following steps:

step 401, collecting basic data of a target block or a target well, wherein the basic data comprises permeability physical property parameters, accumulated sand output, formation sand particle size, liquid production amount, production pressure difference and fluid viscosity;

step 402, determining the optimal sand filling amount, stopping pumping pressure, the particle size specification of each grade of gravel and the thickness of the manually filled well wall through an indoor simulation experiment; by optimizing the construction parameters of the sand ratio and the sand adding time, the sand adding time and the sand amount of the low sand ratio are reduced by 10-30%, the sand adding time and the sand amount of the high sand ratio are increased by 30-60%, and the compactness of the filling layer is improved;

step 403, setting a reconstructed artificial well wall construction pipe column, setting 23/8in, 27/8in and 31/2in oil pipes in a single-layer well, and setting an integrated injection pipe column in a multi-layer well;

step 404, filling small-particle-size quartz sand by using a sand control vehicle group to make up for reservoir vacancy and reduce material cost; filling curable precoated sand near the blast hole, and establishing a high-strength sand blocking barrier to meet the production requirement of large pressure difference;

step 405, in the construction process, sand removal is induced by field control technologies of opening a sleeve in the half process after sand adding, displacement reduction and improvement of circulating filling stop pump pressure, and the compactness of a filling layer in a near-wellbore area is improved;

step 406, closing the well, reacting, waiting for setting for 24-72 hours, taking out the construction pipe column, and recording the pressure of the well head;

and 407, putting a sand-washing or plug-drilling pipe column, performing sand washing or drilling until the designed well depth is reached, and cleaning the well.

9. The sandstone reservoir high-water-content later-stage multistage stable long-acting sand control process method according to claim 1, wherein in the step 5, a high-seepage anti-blocking sand filter pipe is adopted, so that the requirement of low additional differential pressure sand control of a shaft is met; the seepage capability of the sand screen is improved by improving the combination mode of a mechanical sand screen, the hole distribution mode of the base pipe and the liquid inlet mode of the protective sleeve; optimizing a plurality of layers of screens with the same precision into staggered arrangement at different angles from overlapping arrangement in parallel; placing the screens with different precisions according to the inner size and the outer size; the hole distribution mode of the base pipe is improved from square hole distribution to triangular hole distribution; the liquid inlet mode of the protective sleeve is optimized from a perforating straight-flow mode to a lateral punching seam mode.

10. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 9, wherein in the step 5, the cementing strength and the anti-plugging capability of the resin sand screen are improved by optimizing the formula composition and the forming process of the cementing sand-retaining layer of the resin sand screen; the fixed multiple forming of the pin is changed into one-step forming by additionally arranging a supporting longitudinal rib, and an oil passage is reserved between the filter and the central pipe; the resin sand filtering pipe sand blocking layer is prepared by adopting precoated sand through a mold.

11. The sandstone reservoir high-water-content later-stage multi-stage stable long-acting sand control process method according to claim 1, wherein in the step 6, a composite peroxide is adopted, and a softening auxiliary agent with hydroxyl and carboxyl for plugs is added to develop an organic blocking remover; a degradation agent with better depolymerization effect on HPAM is adopted; inorganic solid-phase particles of the high-argillaceous polymer flooding reservoir are removed by adopting inorganic acid liquor, the removal efficiency and the unblocking depth are both considered, and an inorganic composite acid liquor system consisting of earth acid and polyhydrogen acid is formed.

12. The sandstone reservoir high-water-content later-stage multistage stable long-acting sand control process method according to claim 11, wherein in the step 6, the adopted polyhydrogen acid is an organic phosphonic acid, and the basic mixture ratio is 5% polyhydrogen acid, 10-12% hydrochloric acid and 3% hydrofluoric acid.

13. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 11, wherein in the step 6, aiming at the problem of blocking partial blastholes in the perforation section, a high-pressure rotary water jet and a uniform jet flow blocking removal tool are matched to recover the seepage capability of the blastholes and near-well stratums.

14. The sandstone reservoir high-water-cut later-stage multistage stable long-acting sand control process method according to claim 11, wherein in step 6, a blockage removal model is established based on a variable permeability darcy seepage theory, and the blockage removal radius is optimized to be 2-3m, and is enlarged to be 3-4m for a particularly serious oil well.

Technical Field

The invention relates to the technical field of sand control of oil and gas reservoirs, in particular to a high-water-content later-stage multi-stage stable long-acting sand control process method for a sandstone reservoir.

Background

The sand production of oil-gas-water wells is one of the main problems in the development of unconsolidated sandstone reservoirs, so that the high-efficiency sand prevention process technology is one of the basic engineering for ensuring the high-efficiency development of the reservoirs. As the oil and gas field of the unconsolidated sandstone reservoir is developed into a high water-cut period, the stability of the reservoir gradually becomes worse relative to the initial development period, and the content of the cementing agent gradually decreases. Meanwhile, along with the change of the development mode, the sand carrying capacity of the reservoir formation fluid is enhanced after the current polymer flooding, and the migration of formation particles is intensified, so that the sand prevention effect of the reservoir is gradually reduced.

At present, the main development contradiction faced by the oil field loose sandstone reservoir is: along with the oil field entering the later development stage, the water content is increased and the liquid production strength is increased, the sand production of a reservoir stratum is intensified, the stability is poor and the sand prevention difficulty is increased; the blockage is aggravated after polymer flooding and subsequent water flooding sand control, the oil well liquid amount is reduced, and the effective period of sand control is short. The conventional sand control processes such as sand filtering pipes, gravel filling, chemical sand control and the like adopted at present mainly take prevention as main measures, and lose part of the productivity of an oil well while preventing sand, thereby influencing the sand control development benefit of the sandstone reservoir. Therefore, a novel high-water-content later-stage multi-stage stable long-acting sand control process method for a sandstone reservoir is invented, and the technical problems are solved.

Disclosure of Invention

The invention aims to provide a multi-stage stable long-acting sand control process method for a sandstone reservoir in a later period with high water content, which removes the near-well blockage of the reservoir after water flooding and polymer flooding and improves the liquid level.

The object of the invention can be achieved by the following technical measures: the technological method for the multi-stage stable long-acting sand control in the high water-cut later period of the sandstone oil reservoir comprises the following steps: step 1, establishing a reservoir instability model and an instability degree judging method; step 2, performing reservoir instability prevention based on real-time regulation and control of fluid flow rate; step 3, performing efficient chemical agent physicochemical coupling reservoir in-situ stabilization and skeleton reconstruction; step 4, reconstructing a near-well deficit collapse high-strength high-permeability artificial well wall of the reservoir; step 5, performing high-seepage anti-blocking sand control on the shaft through a sand filter pipe; and 6, performing reservoir seepage capability recovery treatment.

The object of the invention can also be achieved by the following technical measures:

in the step 1, a dynamic model of loose sandstone strength parameters, a well circumferential stress model and a destabilization judgment criterion are coupled, a well circumferential destabilization damage model taking mechanical analysis as a core is established, sand production simulation calculation is carried out on the basis of the destabilization damage model, and a quantitative destabilization evaluation standard is formed.

In step 1, the sand production critical production pressure difference and the destabilization sand production radius are quantitatively calculated, and the reservoir instability level, namely primary instability, secondary instability and tertiary instability, is determined.

The step 2 comprises the following steps:

step 201, calculating sand production indexes of a target reservoir under different production pressure differences by adopting a reservoir dynamic sand production prediction model, and judging the sand production degree of the reservoir according to the sand production indexes;

step 202, calculating the corresponding liquid production amount of the oil well under different production pressure differences;

step 203, adjusting the oil well to continuously produce for 24-72 hours according to smaller pressure difference, monitoring the liquid production amount and sand content under the pressure difference through a wellhead sand production real-time monitoring system, and judging the sand production trend of the oil well under the liquid production amount;

204, adjusting the oil well to continuously produce for 24-72h respectively according to the medium differential pressure, namely 2-5MPa and the larger differential pressure, namely more than 5MPa, monitoring the liquid yield and the sand content under different step differential pressures, and judging the sand production trend of the oil well;

step 205, if the sand production amount under a certain pressure difference or liquid amount is obviously increased and the sand content is more than 0.03-0.05% in the regulation process, the 0.03% sand content corresponds to the liquid amount which is reasonable for the well, the 0.05% sand content is the maximum liquid amount for the well, and the reservoir instability and damage can be caused when the sand content exceeds 0.05%, so that a large amount of sand is produced and the well is laid.

In the step 3, aiming at the sand production slight reservoir, a DX-1 type reservoir deep part multi-branched erosion-resistant sand stabilizing system is adopted; the system consists of a rigid backbone and a plurality of functional groups; the phenolic aldehyde-epoxy resin rigid main chain has high thermal stability, the epoxy group has high activity and is easy to open the ring, linear molecules form body-shaped molecules through self-crosslinking, siloxane groups and silicon hydroxyl on the surface of the formation sand generate covalent bonding, NH + groups can be electrically adsorbed with a reservoir, and water-soluble sodium phenolate, hydroxyl and secondary amino and the silicon hydroxyl on the surface of the formation sand generate hydrogen bond bonding; and epoxy groups.

In the step 3, aiming at a reservoir stratum with medium sand production, a GC-1 type reservoir stratum near-well high-strength high-permeability oil-resistant sand stabilizing system is adopted; the system is that oleophylic and hydrophilic groups are grafted on an epoxy resin main chain to synthesize an oil-resistant sand stabilizing agent main agent, and a curing agent is added to form a basic formula of the oil-resistant sand stabilizing agent: the mass ratio of the fine quartz sand to the active sand consolidation agent to the gamma-glycidoxypropyltrimethoxysilane to the modified amine curing agent to the softening agent is 100:10:8:10: 15.

The step 3 comprises the following steps:

301, carrying out simulation calculation on the use concentration and the use amount of a multi-branched erosion-resistant sand stabilizing system with a sand producing radius and a DX-1 type reservoir deep part and a GC-1 type reservoir near-well zone high-strength high-permeability oil-resistant sand stabilizing system;

302, putting a construction pipe column of a high-efficiency stable system of a reservoir, putting 23/8in, 27/8in and 31/2in oil pipes in a single-layer underground manner, and putting an integrated injection pipe column in a multi-layer underground manner;

step 303, injecting the determined dosage into a sand stabilizing system in a layered mode, wherein the processing radius of the deep multi-branched erosion-resistant sand stabilizing system of the DX-1 type reservoir is 3-5 meters, and the processing radius of the high-strength high-permeability oil-resistant sand stabilizing system of the near-well zone of the GC-1 type reservoir is 1-3 meters;

304, closing the well, reacting, waiting for 24-72 hours, taking out the construction pipe column, and recording the pressure of the well head;

and 305, lowering a sand-washing or plug-drilling pipe column, washing or drilling to the designed well depth, and cleaning the well.

Step 4 comprises the following steps:

step 401, collecting basic data of a target block or a target well, wherein the basic data comprises permeability physical property parameters, accumulated sand output, formation sand particle size, liquid production amount, production pressure difference and fluid viscosity;

step 402, determining the optimal sand filling amount, stopping pumping pressure, the particle size specification of each grade of gravel and the thickness of the manually filled well wall through an indoor simulation experiment; by optimizing the construction parameters of the sand ratio and the sand adding time, the sand adding time and the sand amount of the low sand ratio are reduced by 10-30%, the sand adding time and the sand amount of the high sand ratio are increased by 30-60%, and the compactness of the filling layer is improved;

step 403, setting a reconstructed artificial well wall construction pipe column, setting 23/8in, 27/8in and 31/2in oil pipes in a single-layer well, and setting an integrated injection pipe column in a multi-layer well;

step 404, filling small-particle-size quartz sand by using a sand control vehicle group to make up for reservoir vacancy and reduce material cost; filling curable precoated sand near the blast hole, and establishing a high-strength sand blocking barrier to meet the production requirement of large pressure difference;

step 405, in the construction process, sand removal is induced by field control technologies of opening a sleeve in the half process after sand adding, displacement reduction and improvement of circulating filling stop pump pressure, and the compactness of a filling layer in a near-wellbore area is improved;

step 406, closing the well, reacting, waiting for setting for 24-72 hours, taking out the construction pipe column, and recording the pressure of the well head;

and 407, putting a sand-washing or plug-drilling pipe column, performing sand washing or drilling until the designed well depth is reached, and cleaning the well.

In the step 5, a high-seepage anti-blocking sand filter pipe is adopted, so that the requirement of low additional differential pressure sand prevention of a shaft is met; the seepage capability of the sand screen is improved by improving the combination mode of a mechanical sand screen, the hole distribution mode of the base pipe and the liquid inlet mode of the protective sleeve; optimizing a plurality of layers of screens with the same precision into staggered arrangement at different angles from overlapping arrangement in parallel; placing the screens with different precisions according to the inner size and the outer size; the hole distribution mode of the base pipe is improved from square hole distribution to triangular hole distribution; the liquid inlet mode of the protective sleeve is optimized from a perforating straight-flow mode to a lateral punching seam mode.

In the step 5, the cementing strength and the anti-blocking capability of the resin sand screen are improved by optimizing the formula composition and the forming process of the cementing sand blocking layer of the resin sand screen; the fixed multiple forming of the pin is changed into one-step forming by additionally arranging a supporting longitudinal rib, and an oil passage is reserved between the filter and the central pipe; the resin sand filtering pipe sand blocking layer is prepared by adopting precoated sand through a mold.

In the step 6, the composite peroxide is adopted, and the softening auxiliary agent of the blockage with hydroxyl and carboxyl is added to develop an organic blocking remover; a degradation agent with better depolymerization effect on HPAM is adopted; inorganic solid-phase particles of the high-argillaceous polymer flooding reservoir are removed by adopting inorganic acid liquor, the removal efficiency and the unblocking depth are both considered, and an inorganic composite acid liquor system consisting of earth acid and polyhydrogen acid is formed.

In step 6, the adopted polyhydrogen acid is an organic phosphonic acid, and the basic mixture ratio is 5% polyhydrogen acid, 10-12% hydrochloric acid and 3% hydrofluoric acid.

In step 6, aiming at the problem of blocking of partial blastholes in the perforation section, a high-pressure rotary water jet and a uniform jet flow blocking removal tool are matched to recover the seepage capability of the blastholes and the near-well stratum.

In step 6, a blockage removal model is established based on the variable permeability Darcy seepage theory, the blockage removal radius is optimized to be 2-3m, and the blockage removal radius is expanded to be 3-4m for an oil well with particularly serious blockage.

According to the sandstone reservoir high-water-cut later-stage multi-stage stable long-acting sand prevention process method, aiming at the bottleneck problem that the high-water-cut reservoir framework sand damage is aggravated and the reservoir blockage after polymer flooding is serious to restrict the high-efficiency development of an oil field, the researches on the instability mechanism and the stability technical problem of the high-water-cut reservoir are developed according to the concept of ' less migration, slow invasion and multi-discharge ' and the technical thought of ' source prevention, process control and technical thought, and the invention forms the sandstone reservoir high-water-cut multi-stage stable long-acting sand prevention process technology. The invention provides scientific basis for sand control optimization and parameter optimization in the high water cut period, effectively reduces the sand damage and sand production degree of the reservoir framework of the oil reservoir in the high water cut period, removes the near-well blockage of the oil reservoir after water flooding and polymer flooding, improves the liquid level and realizes the high-efficiency development of the loose sandstone oil reservoir in the victory oil field.

Drawings

FIG. 1 is a flow chart of an embodiment of the high water content late stage multi-stage stable long-acting sand control process of the sandstone oil reservoir of the present invention;

FIG. 2 is a schematic diagram of unconsolidated sandstone reservoir cementation with efficient chemical agent physicochemical coupling reservoir in-situ stabilization and skeleton reconstruction technology of the invention;

FIG. 3 is a schematic diagram of severe near-well deficit caused by migration of sandstone reservoir particles in the reservoir near-well deficit collapse high-strength high-permeability artificial well wall reconstruction technology of the invention;

FIG. 4 is a schematic diagram of a gravel-packed sand-prevention sand-production simulation device in the reservoir near-well deficit collapse high-strength high-permeability artificial borehole wall reconstruction technology of the invention;

FIG. 5 is a diagram showing the influence rule of the compaction degree of different types of gravel packing layers on the sand production degree in the reservoir near-well deficit collapse high-strength high-permeability artificial well wall reconstruction technology;

FIG. 6 is a diagram showing the influence law of stratum sand mixed into a gravel packing layer on the permeability of the packing layer in the near-well collapse high-strength high-permeability artificial well wall reconstruction technology of the reservoir of the invention;

FIG. 7 is a schematic molecular structure diagram of an anti-swelling sand-stabilizing sand-carrying fluid system in the reservoir near-well deficit collapse high-strength high-permeability artificial borehole wall reconstruction technology of the invention;

FIG. 8 is a schematic structural view of a graded sand-retaining mechanical high-permeability sand screen in the shaft high-permeability anti-clogging sand screen sand control technology of the invention;

FIG. 9 is a schematic structural view of a high-permeability resin sand screen in the high-permeability anti-clogging sand screen sand control technology for a shaft according to the present invention;

FIG. 10 is a dynamic sand production prediction result of a well ST1-1X112 in a winning oil production plant in the implementation effect of the fluid flow rate real-time regulation and control reservoir instability prevention process of the invention;

FIG. 11 shows the sand control effect of mechanical high-permeability filter tubes of an island oil production plant GD2-32CN520 in the implementation effect of the shaft high-permeability anti-clogging sand filter tube sand control technology of the invention;

FIG. 12 shows the sand control effect of the GDN4-08 resin sand screen in an island oil production plant in the implementation effect of the shaft high-seepage anti-clogging sand screen sand control technology of the invention.

Detailed Description

In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.

As shown in fig. 1, fig. 1 is a flow chart of the high water content later-stage multi-stage stable long-acting sand control process method of the sandstone oil reservoir of the invention.

Step 101, a reservoir instability model and a instability degree judging method are established.

Coupling a loose sandstone strength parameter dynamic model, a well circumferential stress model and a instability judgment criterion, establishing a well circumferential instability damage model taking mechanical analysis as a core, and developing sand production simulation calculation software on the basis of the instability damage model to form an instability quantitative evaluation standard.

By the software and the discrimination method, the sand production critical production pressure difference and the instability sand production radius can be quantitatively calculated, the instability level (primary instability, secondary instability or tertiary instability) of the reservoir is determined, and a theoretical basis is provided for evaluating the instability of the reservoir in different development stages and different development parameters.

Compared with the prior conventional reservoir sand control process optimization method, the initial static logging information of the reservoir at the initial development stage is mainly adopted, the dynamic influence factors such as the water content, the flow velocity, the production pressure difference, the content of the cementing materials and the like at the middle and later stages of oil and gas field development are mainly considered in the newly established instability model, the actual state of the reservoir at the middle and later stages can be matched, the stability of the reservoir can be judged more accurately, and a theoretical basis is provided for reservoir stabilization system and technical selection.

And 102, performing real-time regulation and control on the reservoir instability prevention process based on the fluid flow rate.

The prevention of reservoir instability is the primary task of sand control development of sandstone oil reservoirs, and the development from static sand production prediction to dynamic sand production prediction is realized by improving a sand production prediction method.

The sand production real-time monitoring system is matched to optimize the production pressure difference, regulate and control the fluid flow rate, control the fine sand migration, and avoid the influence on the normal production of an oil well due to unstable sand production of a reservoir caused by overlarge production parameters.

In one embodiment, the method mainly comprises the following steps:

and calculating the sand production indexes of the target reservoir under different production pressure differences by adopting a reservoir dynamic sand production prediction model, and judging the sand production degree (no sand production, slight sand production and serious sand production) of the reservoir according to the sand production indexes.

And calculating the corresponding liquid production amount of the oil well under different production pressure differences.

Adjusting the oil well to continuously produce for 24-72h according to smaller pressure difference (1-2MPa), monitoring the liquid production amount and sand content under the pressure difference through a wellhead sand production real-time monitoring system, and judging the sand production trend of the oil well under the liquid production amount.

The method is adopted to adjust the oil well to continuously produce for 24-72h according to the medium differential pressure (2-5MPa) and the large differential pressure (more than 5MPa), monitor the liquid yield and the sand content under different step differential pressures and judge the sand production trend of the oil well.

If the sand production amount under a certain pressure difference or liquid amount is obviously increased and the sand content is more than 0.03-0.05% in the regulation process, the 0.03% sand content corresponds to the liquid amount which is reasonable for the well, the 0.05% sand content is the maximum liquid amount of the well, and the reservoir instability damage can be caused when the sand content exceeds 0.05%, so that a large amount of sand is produced and laid.

103, efficient chemical agent physicochemical coupling reservoir in-situ stabilization and skeleton reconstruction technology

The sandstone reservoir mainly comprises a cementing material, free sand, consolidated sand (also called skeleton sand) and the like, wherein the sand control mainly comprises skeleton sand prevention, and the free sand is produced along with liquid flow and is favorable for dredging pores of the reservoir and keeping the seepage capability of the reservoir.

Along with the increase of water content and liquid production of an oil well, the content of reservoir cementing materials is gradually reduced, so that the cementing strength is reduced, and the reservoir stability is poor.

The key to maintaining reservoir stability is to ensure that the reservoir framework sand is not damaged.

At present, a chemical agent cementing system is injected to make up and increase the content of cementing materials among skeleton sands, maintain the stability of a reservoir and avoid unstable sand production.

As can be seen from fig. 2, the unconsolidated sandstone reservoir mainly comprises cement, free sand, consolidated sand (also called skeleton sand) and the like, and chemical cementing agent is adopted to ensure the free sand movement and the skeleton sand in-situ stability, which is the key for realizing the reservoir seepage capability stability.

The resin cementing agent commonly used in the market at present mainly comprises a cation quaternary ammonium salt sand inhibitor and a resin sand fixing agent.

The cationic group of the quaternary ammonium salt sand inhibitor and the negatively charged reservoir layer reduce the ZeTa potential of the reservoir layer through physical adsorption, realize the stabilization of reservoir layer particles and reduce or avoid sand production.

The resin sand consolidation agent mainly comprises phenolic aldehyde, epoxy resin, a curing agent and the like, and is used for consolidating linear resin into body type reticular resin through chemical reaction, consolidating and fixing skeleton sand and improving the stability of a reservoir stratum.

The resin sand consolidation agent has high strength but has great damage to the permeability of a reservoir. Cationic quaternary ammonium salts have little effect on permeability but have poor wash-off resistance.

Aiming at the problems existing in the application of the two systems at present, a novel efficient and stable reservoir system is developed.

A DX-1 type reservoir deep multi-branched erosion-resistant sand stabilizing system is developed for a sand-producing light reservoir. The system consists of a rigid backbone and a plurality of functional groups. The phenolic aldehyde-epoxy resin rigid main chain has high thermal stability, the epoxy group has high activity and is easy to open the ring, linear molecules form body-shaped molecules through self-crosslinking, siloxane groups and silicon hydroxyl on the surface of the formation sand generate covalent bonding, NH + groups can be electrically adsorbed with a reservoir, and water-soluble sodium phenolate, hydroxyl and secondary amino and the silicon hydroxyl on the surface of the formation sand generate hydrogen bond bonding; and epoxy groups. The system realizes rapid particle aggregation and long-term stability of particles in deep reservoirs by two bond forces of hydrogen bonds and electric adsorption. The damage rate of the system to the stratum is only 13.4 percent, the sand yield is 0.03 percent under 3000mL/h, and the damage rate and the sand yield are due to the conventional system at present.

A GC-1 type reservoir near-well high-strength high-permeability oil-resistant sand stabilizing system is developed for a sand production medium reservoir. The system is that oleophylic and hydrophilic groups are grafted on the main chain of epoxy resin to synthesize the main agent of the oil-resistant sand stabilizing agent, and auxiliary agents such as curing agent and the like are added to form the basic formula of the oil-resistant sand stabilizing agent: the mass ratio of the fine quartz sand to the active sand consolidation agent to the gamma-glycidoxypropyltrimethoxysilane to the modified amine curing agent to the softening agent is 100:10:8:10: 15. After the sand stabilizing system enters a near-well stratum, crude oil on the surface of sand grains is stripped, the consolidation strength of a chemical agent in a bottom hole environment is improved, and the stability of near-well particles of a reservoir is ensured. Under the condition of 10% crude oil adhesion at the bottom of the well, the strength can reach more than 6MPa, the permeability retention rate reaches 92%, the viscosity is lower than 5mPa.s, the fluidity is strong, and uniform and safe consolidation is ensured.

The developed efficient stabilizer system realizes the in-situ stabilization of deep particles of a reservoir and the reconstruction of a near wellbore region framework through physical and chemical actions.

In one embodiment, the method mainly comprises the following steps:

and (3) carrying out simulation calculation on the use concentration and the use amount of a multi-branched erosion-resistant sand stabilizing system at the sand producing radius, the deep part of a DX-1 type reservoir and a GC-1 type reservoir near-well zone high-strength high-permeability oil-resistant sand stabilizing system by adopting reservoir stabilizing system optimization software.

The construction method comprises the following steps of putting a construction pipe column of a high-efficiency stable system of a reservoir stratum, putting oil pipes 23/8in, 27/8in, 31/2in and the like into a single-layer underground well, putting an integrated injection pipe column into a multi-layer underground well, putting the pipe column once, and realizing selective injection of a longitudinal small-layer chemical agent sand stabilizing system, gravel filling or precoated sand and the like.

The determined dosage is injected into the sand stabilizing system layer by layer, the processing radius of the DX-1 type reservoir deep multi-branched erosion-resistant sand stabilizing system is generally 3-5 m, and the processing radius of the GC-1 type reservoir near-well zone high-strength high-permeability oil-resistant sand stabilizing system is generally 1-3 m.

And (4) closing the well, reacting, waiting for setting for 24-72 hours, taking out the construction pipe column (the construction pipe column does not need to be taken out for the single-layer well), and recording the pressure of the well head.

And (3) putting a sand-washing or plug-drilling pipe column, washing or drilling to the designed well depth (the single-layer well adopts the original well construction pipe column to wash sand), and cleaning the well.

And 104, reconstructing a near-well deficit collapse high-strength high-permeability artificial well wall of the reservoir.

The flow velocity of reservoir fluid is far greater than that of deep fluid in a near well and a blast hole, so that the near well is seriously damaged due to the fact that the migration of particles is aggravated in the middle and later stages of developing high water content sandstone reservoirs, even the well wall collapses, the reservoir is seriously unstable, and the casing fracture phenomenon is increased.

The requirement of high-water-content middle and later-period large-pressure-difference production of the sandstone reservoir on a near-well high-strength high-permeability reservoir cannot be met by a pure injection chemical stabilization system.

A high-strength high-permeability artificial well wall reconstruction technology is developed, so that the near-well reservoir is prevented from collapsing again, and the reservoir is supported and kept stable for a long time.

As can be seen from figure 3, in the later period of high water content of the unconsolidated sandstone reservoir, along with the increase of the strength of the produced fluid and the increase of water content, the sand production of the reservoir is aggravated, the near-well depletion is serious, even collapses, and if the filling layer is not compact, the formation sand is easy to invade the filling layer.

Aiming at severe lost circulation and well wall collapse, a gravel packing sand prevention process is generally adopted at present, and gravel such as quartz sand, ceramsite and the like is packed in a near well and a blast hole through a sand prevention vehicle group, so that the aims of preventing sand and supporting a near well reservoir are fulfilled.

On the basis of the conventional gravel packing sand prevention process, in order to slow down the migration of particles to block a packing layer, a slug type graded packing concept is introduced, gravel with small particle size is packed at the far end to block formation sand, gravel with large particle size or precoated sand is packed at the near well, a high-strength high-permeability artificial well wall is reconstructed, invaded sand is discharged, the high permeability of the artificially reconstructed packing layer is ensured, and the requirement of accelerating and improving the efficiency in the later period of high water content is met.

The influence of stratum sand heterogeneity, liquid production strength and the like is considered, a classical Saucier model is developed, a grade I and grade II gravel particle size optimized template for graded filling is established, and breakthrough from single particle size to graded particle size optimization is realized. The particle size and the thickness of the gravel at each stage of the graded pack are shown in tables 1 to 3 below.

TABLE 1 SEGMENTED CLASSIFIED FILLING PARTICLE SIZE PREFERRED-SELECTED PATTERN PLATE FOR CLASS I GRAINES (SMALL GRAINES)

TABLE 2 matching relationship between grade I (small particle size) and grade II (large particle size) gravel particle size

TABLE 3 grading gravel dosage template under different packing strengths

Gravel packing is an effective means for keeping reservoir stability, and currently, related researches on the compaction degree of a packed layer, the interface of formation sand and gravel, compaction of the packed gravel to the reservoir, embedding and mixing and the like are less.

Through indoor experiments, the optimum stop pump pressure of gravel packing is simulated and researched, the excessive compaction of a filling layer to a reservoir is reduced, a compaction zone is avoided, and the effective seepage capacity of the reservoir is reduced.

As can be seen from the figure 4, the developed slug type sand filling experimental device can simulate the filling process, carry out simulation tests on the sand production and permeability of gravels with different types and different particle sizes under different fluid production strengths and water contents, and provide experimental basis for gravel filling sand prevention.

Through a multi-section sand filling test, an artificial well wall compaction zone reconstruction simulation experiment for gravel filling of an orphan-Dong oilfield is carried out, the stratum sand permeability 1867md is obtained by filling quartz sand according to the theoretical filling quantity of reservoir deficit, namely 0.8 time, 1.0 time, 1.2 times, 1.4 times and 1.6 times, when the quartz sand is not densely filled (0.8 time of theoretical filling quantity), densely filled (1.0-1.2 times of theoretical filling quantity) and excessively filled and compacted (1.0-1.6 times of theoretical filling quantity), the gravel sand interface permeability is 8.49md, 16.7md and 12.3md in sequence, and the gravel sand interface permeability can be influenced by excessive filling and non-compaction.

It can be seen from fig. 5 that the filling compaction degree has a great influence on the sand blocking effect, the sand yield of the filling layer is less than 0.3% when the filling compaction is performed, the sand yield of the filling layer is greatly increased when the filling is not compacted, and the improvement of the filling layer compaction degree is the key for ensuring the gravel sand prevention effect.

If the packing compactness is low, the sand passing rate is increased, the sand blocking effect is poor, the gravel is arranged and loosened mainly under the lower packing compactness, particles are rearranged during fluid impact, stratum sand is easy to invade, a sand mixing belt is easy to form, and the seepage capacity of a gravel-sand interface is greatly reduced.

As can be seen from fig. 6, the incorporation of the quartz sand pack into the formation sand results in a substantial decrease in pack permeability, which is as low as 90% when the formation sand is incorporated at a 20% ratio, and therefore, a reasonable gravel median selection for gravel pack sand control is critical.

According to the principles of high sand ratio, less liquid consumption and high pressure rise, the simulation optimization of construction parameters such as discharge capacity, sand ratio, sand adding strength and the like is carried out, and as shown in table 4, the requirements of high-density filling and sand prevention of different thickened oil blocks in spring, le' an and the like are met.

TABLE 4 optimization result table of high-density filling sand prevention construction parameters of different heavy oil blocks

The sand carrying liquid is one of main materials for reconstructing the artificial well wall, and at present, clear water (clean sewage), guanidine gum sand carrying liquid and polymer sand carrying liquid are mainly adopted, so that an agglomerated stable sand carrying liquid system is developed for reducing the damage of the sand carrying liquid system to a reservoir stratum.

As can be seen from figure 7, the sand-carrying liquid is used as a main material for filling and sand prevention, and the anti-swelling group and the sand stabilizing group are grafted on the molecular chain of the sand-carrying liquid, so that gravel filling and formation sand stabilization can be realized while the sand-carrying liquid is filled, and the seepage capability of a filling layer is ensured.

The system is characterized in that a polymer sand-carrying fluid molecular chain is grafted with a cationic quaternary ammonium salt and an organic silicon group, so that the system has the functions of agglomeration and sand stabilization on the basis of ensuring the sand-carrying performance of the sand-carrying fluid, and the seepage capability of a reservoir and a filling layer is kept stable.

And (3) after the cations hydrolyzed by the cation quaternary ammonium salt are adsorbed by the negatively charged sandstone surface, changing the electrical property of the sandstone surface.

The organic silicon and the hydroxyl on the surface of the fine sand grains are subjected to condensation reaction, so that the binding force among the sand grains is enhanced, and the sand stabilizing effect is achieved.

The main principle is that the surface of reservoir sandstone is electronegative, the Zeta potential is low, the repulsive force among sand grains is dominant, and the sand grains are in a dispersed state. The agglomeration sand-carrying liquid system can increase the Zeta potential, the Delaware force (attraction) among sand grains is dominant, the sand grains agglomerate, the stability of reservoir particles is kept, and the seepage capability of a reservoir and a manually reconstructed filling layer is improved.

In one embodiment, the method mainly comprises the following steps:

and collecting basic data of the target block or the target well, wherein the basic data comprises physical parameters such as permeability and the like, accumulated sand yield, formation sand particle size, liquid production amount, production pressure difference, fluid viscosity and the like.

And determining the optimal sand filling amount, stopping pumping pressure, the particle size specification of each grade of gravel and the thickness of the manually filled well wall through an indoor simulation experiment. By optimizing the construction parameters such as sand ratio, sand adding time and the like, the sand adding time and the sand amount of the low sand ratio are reduced by 10-30%, the sand adding time and the sand amount of the high sand ratio are increased by 30-60%, and the compactness of the filling layer is improved.

And (2) putting a reconstructed artificial well wall construction pipe column, putting oil pipes 23/8in, 27/8in, 31/2in and the like into a single-layer well, putting an integrated injection pipe column into a multi-layer well, and putting the pipe column once to realize selective injection of a longitudinal small-layer chemical agent sand stabilizing system, gravel filling or precoated sand and the like.

The sand prevention vehicle set is adopted to fill small-particle-size quartz sand, so that the reservoir vacancy is compensated, and the material cost is reduced; and concretionable precoated sand is filled near the blast hole, a high-strength sand blocking barrier is established, and the production requirement of large pressure difference is met.

In the construction process, the sand removal is induced by field control technologies such as opening a sleeve in the half process after sand addition, displacement reduction displacement, improvement of circulating filling stop pump pressure and the like, so that the compactness of a filling layer in a near wellbore zone is improved.

And (4) closing the well, reacting, waiting for setting for 24-72 hours, taking out the construction pipe column (the construction pipe column does not need to be taken out for the single-layer well), and recording the pressure of the well head.

And (3) putting a sand-washing or plug-drilling pipe column, washing or drilling to the designed well depth (the single-layer well adopts the original well construction pipe column to wash sand), and cleaning the well.

105, adopting a high-seepage anti-blocking sand filtering pipe sand control technology for the shaft.

The sand control of the sand filter pipe is one of the main sand control technologies of the oil field, more than 500 wells are implemented every year, and the adopted sand filter pipe mainly comprises a mechanical sand filter pipe, a resin sand filter pipe and the like and is mainly suitable for sandstone oil reservoirs with slight sand production, large median particle size, good homogeneity and the like.

The following two problems exist in fine silt, high mud and large fluid wells: mechanical sand screen: the strength is high, the erosion resistance is strong, but the powder is easy to be blocked by fine sand, mud and polymer; chemical sand screen: good flow-through properties, but low strength and poor erosion resistance.

A high-seepage anti-blocking sand filter pipe is developed, and the requirement of low-additional-pressure-difference sand prevention of a shaft is met.

The sand filtering pipe can be used as a sand prevention process measure alone, and can also be matched with gravel to form a screen sleeve annular circulation filling sand prevention process measure, so that three-level sand prevention barriers of stratum deep sand stabilization, near well construction of an artificial well wall supporting reservoir stratum and shaft sand filtering pipe supporting artificial well wall are realized, the reservoir stratum, the artificial well wall or a filling layer are kept stable, and the requirements of high-water-content later-stage speed-increasing and efficiency-increasing development are met.

By improving the combination mode of the mechanical sand filtering pipe and the screen, the hole distribution mode of the base pipe and the liquid inlet mode of the protective sleeve.

The multilayer screens with the same precision are arranged in parallel by overlapping and optimized to be staggered at different angles, and the sand blocking precision is improved by 15-25%.

The screens with different precisions are placed according to the sizes of the screens, the additional pressure difference is reduced by 12.5 percent compared with the case that the screens are placed in the sizes of the screens, and the permeability is improved by 13.7 percent.

The hole distribution mode of the base pipe is improved from square hole distribution to triangular hole distribution, and the seepage area is increased by 16% under the condition that the distances among the holes are equal.

The liquid inlet mode of the protective sleeve is optimized from a perforating straight-flow mode to a lateral punching seam mode, so that direct erosion of the sand-containing fluid to the screen is avoided, and the erosion resistance is improved.

As can be seen from the graph 8, the sand blocking precision, the flow area and the erosion resistance of the sand screen are improved by improving the hole patching mode of the base pipe of the screen type sand screen, the combination mode of the screen and the liquid inlet mode of the protective sleeve.

Collar 1 in FIG. 8; 2, base pipe; 3 an upper end ring; 4, an outer protective sleeve; 5, winding a silk layer; 6 a screen layer.

The formula composition and the forming process of the resin sand filtering pipe cementing sand retaining layer are optimized.

The pin fixed multiple forming is changed into one-step forming by additionally arranging a supporting longitudinal rib, an oil passage is reserved between the filter and the central pipe, the seepage area is improved by 1.5 times, the erosion resistance and the permeability of the resin filter and the stability of the resin filter under the damp and hot conditions of the well bottom are improved, the compressive strength of the chemical sand filter pipe is 12MPa, and the permeability is more than 10 mu m²The cementing material can resist the temperature of 200 ℃.

Particles <40um can be expelled and the additional pressure drop created is only 1/8 for the wire-wrapped screen, reducing the additional drag in the wellbore.

As can be seen from fig. 9, the sand-blocking layer of the resin sand-filtering pipe is prepared by using precoated sand through a mold, and the formula and the molding process of the sand-blocking layer are improved, so that the resin seepage-filtering capacity, the erosion resistance and the temperature resistance are improved.

106, restoring the reservoir seepage capacity

In the later development stage of the sandstone reservoir, the near well of part of the high-argillaceous and fine silt reservoir, the heavy oil reservoir and the polymer flooding reservoir is blocked by colloidal polymers and solid-phase particles.

Before carrying out multistage stable sand control such as deep stable sand of a reservoir, construction of a near well manually filled well wall and the like, the blockage is removed by a matched reservoir seepage capability recovery pretreatment process, and the phenomena that the blockage is aggravated and the sand control validity period and the oil well productivity are influenced due to mixing of a blockage, a chemical stabilizing system, gravel filling and the like are avoided.

The organic blocking remover is developed by adopting composite peroxide and adding a softening auxiliary agent of the blockage with hydroxyl and carboxyl, and has high degradation rate on the blockage, wherein the degradation rate is 64.5 percent in 8 hours and reaches 94 percent in 48 hours.

The degrading agent has better depolymerization effect on HPAM, and the viscosity of the HPAM solution can be reduced to about clear water viscosity by 1 percent of the depolymerizing agent at 65 ℃ for 10 hours.

The organic blocking remover can only remove polymer blocking, inorganic solid-phase particles of the high-argillaceous polymer flooding reservoir need to be removed by using inorganic acid liquor, and an inorganic composite acid liquor system consisting of earth acid and polyhydrogen acid is formed for both removing efficiency and blocking depth.

The polyhydrogen acid is organic phosphonic acid, has strong capability of inhibiting secondary precipitation, and is suitable for treating high-argillaceous sandstone reservoirs. The basic mixture ratio is 5% polyhydroic acid, 10-12% hydrochloric acid and 3% hydrofluoric acid, and the acid liquid system is mixed with formation fluid without layering, precipitation and flocculation, and has good compatibility.

Aiming at the problem of blocking partial blast holes in the perforation section, the high-pressure rotary water jet and the uniform jet flow blocking removal tool are matched, so that the seepage capability of the blast holes and the near-well stratum is recovered, and the blocking removal effect of the polymer flooding reservoir is improved.

And (3) establishing a blockage removal model based on a variable permeability Darcy seepage theory, optimizing the blockage removal radius by 2-3m, and expanding the blockage removal radius to 3-4m for an oil well with particularly serious blockage.

The following are the effects of several embodiments of the present invention.

Example 1: implementation effect of reservoir instability prevention process for real-time regulation and control of fluid flow rate

The fluid flow rate real-time regulation and control reservoir instability prevention process is applied to 13 sand two 1-3 units of wells in the victory oil field victory oil production plant victory one-area on site, and the average daily fluid of a single well is increased by 55m after implementation³D, while monitoring the average sand content of a single wellOnly 0.005 percent is added, and the purpose of preventing reservoir instability by optimizing the production pressure difference and regulating and controlling the fluid flow rate in real time is achieved.

As can be seen from FIG. 10, when the sand index is small by 1.4X 10⁴And at MPa, the reservoir is seriously sanded. The sand production degree is increased along with the increase of the production pressure difference, so that the production pressure difference is controlled within a reasonable range, and the influence on production caused by the sand production of a large amount of reservoirs can be avoided.

TABLE 5 statistical table for monitoring sand production before and after extracting liquid

Serial number	Number of well	Sand content in the front of the extract	The sand content after the liquid extraction
				1	ST1-2-73	0.0271	0.0365
2	ST1-1X822	0.0224	0.0329
				3	ST1-2-103	0.0314	0.0402
4	ST1-2-141	0.0353	0.0485
				5	ST1-2-9	0.0234	0.0399
6	ST1-2-94	0.0242	0.0304
				7	ST1-2X104	0.0311	0.0456
8	ST1-2X112	0.0428	0.0129
				9	ST1-3-63	0.0191	0.0235
10	ST1-4-111	0.0220	0.0332
				11	ST1-4-113	0.0432	0.0456
12	ST1-4-153	0.0319	0.0414
				13	ST1-4X136	0.0984	0.0982
Average		0.0348	0.0403

Example 2: implementation effect of efficient chemical agent physicochemical coupling reservoir particle in-situ stabilization and framework reconstruction technology

The reservoir particle in-situ stabilization and skeleton reconstruction technology is based on two-stage high-efficiency sand stabilization in the deep and near-wellbore regions of the reservoir, and improves the effective period and liquid amount of the later sand control in the high water-cut period.

The sand control method is applied to the site for more than 100 wells, the average single-well liquid volume after construction is improved by more than 40%, and the effective period of sand control is prolonged to 460 days to continue to be effective. And statistics are carried out on 21 wells, 1.2508 million tons of accumulated oil are produced, 4786 tons of accumulated oil are produced, the average effective period is 205 days, the maximum effective period reaches 420 days, and the effective period continues to be effective.

TABLE 6 table of effect of reservoir particle in-situ stabilization and skeleton reconstruction technique for partial well implementation

Example 3: implementation effect of reservoir near-well deficit collapse high-strength high-permeability artificial well wall reconstruction technology

The artificial well wall reconstruction technology is implemented for more than 200 times in near-well deficit collapse wells of oil field layers such as islands and eastern solitons, and the good sand prevention and yield increase effects are achieved. After GO3-15-30 well implementation, the daily fluid increase is 35.3m compared with that of the single-specification gravel pack on the upper wheel³The oil is added for 1t every day, and the working fluid level rises up to 457 m.

Table 7 high-strength high-permeability artificial borehole wall reconstruction technique implementation effect table

Example 4: implementation effect of sand control technology of high-seepage anti-blocking sand filter pipe of shaft

The high-permeability sand filter pipe is applied to oil fields such as eastern solitary island and the like for more than 200 times, and the average daily liquid increase of a single well is 28.9m after measures³And the daily oil increment is 2t, so that the requirement of high sand guiding prevention is met. The mechanical high-infiltration sand pipe is popularized and applied to 24 wells on site, and the average daily liquid increase of a single well is 17.5m after the island factory is implemented³The daily oil increase is 1.5t, the accumulated oil is 3200t, the average sand control effective period reaches 150d, and the sand control effect is continued to be effective.

TABLE 8 mechanical sand screen

Island GD2-32CN 520: after the precise microporous sand filtering pipe is used for sand control, the liquid amount is gradually reduced, after the sand control validity period is only 152 days of mechanical high-infiltration sand control, the liquid amount and the oil amount are obviously increased, the validity period reaches 240 days, the effect is continued to be effective, and the yield increasing effect is obvious.

As can be seen from the figure 11, after the mechanical high-infiltration sand pipe is adopted for sand control, the oil well fluid quantity and the oil quantity of the GD2-32CN520 oil production plant of the island are obviously increased, and the yield increasing effect is obvious.

41 wells are applied to the site of the resin sand screen, and the average daily liquid increase of a single well is 17.5m after the implementation of an island plant³Daily oil increase is 1.5t, oil increase is 7600t, average sand control validity period is 170d, and the sand control effect is obvious after continuous effectiveness.

TABLE 9 resin Sand screen implementation Effect

Island GDN 4-08: and in the subsequent water-driven oil well, the liquid amount is gradually reduced after gravel filling and sand prevention are carried out before implementation, the daily liquid in the later period is 33.7t, and the daily oil is 1.1 t. After the resin filtration sand control is carried out, 80t of daily liquid and 7.2t of daily oil are obtained.

As can be seen from figure 12, the liquid amount and the oil amount of the GDN4-08 well in the island oil production plant after the sand control is carried out by adopting the resin high-infiltration sand pipe are greatly increased, and the obvious yield increasing effect is achieved.