CN111322040B - Water-producing gas well full-life-cycle drainage gas production method and system - Google Patents
Water-producing gas well full-life-cycle drainage gas production method and system Download PDFInfo
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- CN111322040B CN111322040B CN202010183894.8A CN202010183894A CN111322040B CN 111322040 B CN111322040 B CN 111322040B CN 202010183894 A CN202010183894 A CN 202010183894A CN 111322040 B CN111322040 B CN 111322040B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
Abstract
The application relates to a water-producing gas well full-life-cycle water drainage gas production method and a system, and the water drainage gas production method comprises water drainage gas production equipment, a gas-water flow dividing device, drying equipment, a gas generator and a compressor. A first branch of an outlet pipeline of the water and gas drainage equipment is connected to an external pipeline network; the second branch is connected with a gas-water shunting device. The gas flowing out of the top of the gas-water shunting device passes through a regulating valve and is dried by drying equipment and then is divided into two branches, one branch flows into a gas generator through a flow regulator, the other branch flows into a compressor, and the gas generator supplies electric energy to the compressor by burning natural gas; the compressor pressurizes the natural gas to enable the natural gas to start the multistage pressure regulator, accumulated liquid in a shaft is removed section by section, and continuous production of a gas well is guaranteed. The gas-lift gas production device is suitable for water-producing gas well full life cycle drainage and gas production, one-time construction is realized, the gas-lift gas production device is effective for a long time, the gas-lift opening pressure is low, the energy consumption is low, external electric energy is not needed, the gas-lift gas production device is safe and reliable, can be repeatedly used, and is simple to manage and low in maintenance cost.
Description
Technical Field
The application relates to a water-producing gas well full-life-cycle water drainage gas production method and system, which are applicable to the technical field of gas well water drainage gas production.
Background
In the exploitation process of a natural gas well, the phenomenon of liquid accumulation at the bottom of the well can be frequently encountered, if the liquid accumulation can not be timely drained out of the well, the yield of the gas well can be greatly influenced, the ultimate recovery ratio of the gas well can be influenced, and therefore a certain drainage measure is required to be adopted, and the liquid accumulation at the bottom of the well can be drained in thousands of square meters. The liquid in a gas well is primarily condensate of gaseous hydrocarbons and formation water, which are distributed in the gas phase in the form of droplets, and the liquid is usually carried to the surface in the form of droplets by the gas phase. If the gas phase fails to provide an effective flow rate greater than the critical fluid-carrying flow rate, the fluid in the wellbore cannot be delivered to the surface, thereby forming a fluid accumulation. The accumulated liquid can increase the back pressure of a gas layer, reduce the production capacity of a gas well, even cause flooding of the gas well and finally lose the production capacity.
In addition to methods of directly discharging the accumulated liquid in the shaft to the ground by pumping, an electric submersible pump, a plunger and the like, other methods generally need to ensure that the gas flow velocity in the vertical pipe flow is larger than the critical liquid-carrying gas flow velocity, so that the accumulated liquid in the shaft bottom is prevented from being generated, and the influence of the accumulated liquid in the shaft bottom on the production of a gas well is eliminated or weakened. Common drainage gas recovery methods include foam drainage gas recovery, velocity string drainage gas recovery, plunger drainage gas recovery, and gas lift drainage gas recovery. The foam drainage gas production method is characterized in that a foaming agent is injected into a shaft and then mixed with accumulated liquid, a large amount of low-density water-containing foam is generated by means of stirring of natural gas flow, and the critical flow rate required by carrying liquid is reduced, so that the aim of discharging the accumulated liquid in the shaft is fulfilled under the condition that the flow of a gas well is not changed. The speed pipe column drainage gas production method is characterized in that an oil pipe with a small pipe diameter is hung at a well head to serve as a production pipe column, so that the gas flow rate is improved, the critical liquid carrying flow is reduced, the liquid carrying production capacity of a gas well is improved, and drainage gas production is realized. The plunger drainage gas production method is characterized in that a plunger is used as a gas-liquid separation interface, and the accumulated liquid at the bottom of a well is lifted to the ground by utilizing stratum energy to realize drainage gas production.
The gas lift drainage gas recovery is a drainage gas recovery mode which is characterized in that high-pressure gas is injected into a shaft and mixed with produced fluid of a production zone in the shaft by means of an external high-pressure gas source or a compressor, so that the density and hydrostatic pressure of the fluid in the shaft are reduced, the bottom hole flowing pressure is reduced, and the produced fluid flows into the shaft and is lifted to the ground. When high-pressure gas enters the oil sleeve annulus, the liquid level in the annulus is squeezed to fall, if liquid is not considered to be squeezed into a stratum, the liquid in the oil sleeve annulus completely enters an oil pipe, the liquid level in the oil pipe rises, and the pressure of the compressor is continuously increased in the process. When the liquid level in the oil sleeve annulus drops to the oil pipe shoe, the pressure of the compressor reaches the maximum, and the pressure is called the opening pressure. The injected gas enters the oil pipe to be mixed with the liquid in the oil pipe, the liquid level continuously rises until the injected gas is sprayed out of the ground, the bottom hole pressure is greater than or equal to the formation pressure before the injected gas starts to be sprayed out, the gas still continues to enter the oil sleeve annulus after the sprayed gas is sprayed out, the liquid in the oil pipe continues to be sprayed out, the density of the liquid mixed with the natural gas is further reduced, the bottom hole pressure is correspondingly reduced, the pressure of a compressor is reduced, and when the bottom hole pressure is lower than the formation pressure, the formation fluid flows into the well. The density of the mixed gas in the oil pipe is slightly increased due to the formation effluent, so that the pressure of the compressor is increased and tends to be stable after a period of time, and a stable production state is achieved, and the pressure of the compressor is called as working pressure at the moment. If the compressor stops working at the moment, part of liquid in the oil pipe falls back, the stratum carries out short-term follow current of the shaft, the liquid level rises again, after the compressor is restarted, the liquid recovered in the period of time needs to be discharged again, when the liquid level is reduced to a certain height, the machine is stopped again, and the residual liquid level still exists. Therefore, the repeated stopping and starting of the machine has limited accumulated liquid discharged from the bottom of the well, the working efficiency of the compressor is greatly reduced, the position and the productivity of the recovered production are limited, and the repeated stopping and starting of the machine is too frequent, so that the compressor reaches the maximum pressure repeatedly, the loss and the energy consumption of the compressor are increased, and the operation cost is increased. Under the condition of low later-stage gas output, the compressor can not be used for draining water and producing gas generally in consideration of energy consumption and output ratio, so that the waste of gas well resources is caused.
In addition, the existing drainage gas production methods are all used singly, the application range is greatly limited, and the drainage gas production requirements of the whole life cycle of a gas well are difficult to meet; not only the overall operating cost is increased, but also the exploitation effect of the gas well is influenced. Therefore, a drainage gas production technology suitable for the whole life cycle of a gas well is urgently needed, and the problem of liquid accumulation of the gas well is solved.
Disclosure of Invention
The invention aims to overcome the defects in the prior art and designs a water-producing gas well full-life-cycle drainage gas production method and system.
The water and gas production system comprises water and gas production equipment, a gas and water distribution device, drying equipment, a gas generator and a compressor, wherein an outlet pipeline of the water and gas production equipment is divided into two branches, and the first branch is connected to an external pipeline network; the second branch is connected with a gas-water distribution device; the external transmission pipe network is connected to the upstream of the gas-water diversion device through a one-way valve;
the gas flowing out of the top of the gas-water shunting device passes through a regulating valve and is dried by drying equipment and then is divided into two branches, wherein one branch flows into a gas generator through a flow regulator, the other branch flows into a compressor, and the gas generator supplies electric energy to the compressor by burning natural gas;
the water drainage and gas production equipment comprises underground equipment and ground equipment, wherein the underground equipment comprises a sleeve, an oil pipe and a small oil pipe, the oil pipe is placed in the sleeve and forms a first annular space with the sleeve, and the small oil pipe is placed in the oil pipe and forms a second annular space with the oil pipe; the small oil pipe is provided with a plurality of pressure regulators, and the bottom of the oil pipe is provided with a sealing element; at least one liquid level sensor is arranged in the second annular space; an outlet pipeline of the compressor is connected to a second annulus of the water and gas drainage and production equipment through a flow regulator and a barometer in sequence;
the ground equipment comprises three four-way pieces, wherein the upper four-way piece is communicated with an outlet pipeline, the middle four-way piece is communicated with an inlet pipeline, and the lower four-way piece is communicated with a first annulus; the top end of the upper four-way piece is provided with a pressure jacking piece, the middle four-way piece is provided with a small oil pipe fixing piece, and the small oil pipe is fixed on the small oil pipe fixing piece; the small oil pipe is communicated with the outlet pipeline, and a second annulus between the small oil pipe and the oil pipe is communicated with the inlet pipeline.
Preferably, the liquid level sensor comprises an upper liquid level sensor and a lower liquid level sensor, the upper liquid level sensor is arranged at a position higher than the uppermost pressure regulator, the lower liquid level sensor is arranged at a position lower than the lowermost pressure regulator, and at least one liquid level sensor is arranged between the upper liquid level sensor and the lower liquid level sensor. Preferably, the main part of gas-water diverging device is the radius circular truncated cone type, goes up the lateral wall and is equipped with the tangential entry, and the top is equipped with gas outlet, and gas-water diverging device's bottom still is equipped with liquid collector, and its lateral wall is connected with level sensor, and the gaseous top of following gas-water diverging device after the reposition of redundant personnel flows out, and the liquid after the reposition of redundant personnel flows in the bottom and collects, when collecting certain liquid level degree of depth, thereby the valve of bottom is opened and is discharged liquid.
In another aspect, the present application relates to a full-life cycle drainage gas production method for a water producing gas well, which utilizes the full-life cycle drainage gas production system for the water producing gas well as described above, and includes the following steps:
(1) preparation of work
(1.1) measuring the pressure, the temperature distribution and the liquid level height in the well;
(1.2) exhausting air of the ground pipeline by using pump truck equipment, and carrying out graded pressure test on the ground pipeline, wherein the highest pressure test pressure is stabilized for 10 minutes, and the pressure drop is less than 0.5MPa, and the ground pipeline is qualified;
(1.3) after the ground pressure test is normal, hoisting the equipment to a wellhead one by one for installation;
(1.4) pulling out a small oil pipe with enough length according to the distance between the small oil pipe and a well head, guiding the small oil pipe to enter an upper four-way piece, clamping the small oil pipe in a pipe clamping box, controlling the pressure regulator on the small oil pipe to be at the underground fixed point position according to the gas lift operation depth and the liquid level height in the well, and calculating the opening pressure of each pressure regulator;
(1.5) pressing the small oil pipe, opening a sealing element and preparing for gas lift operation;
(2) gas lift operation
(2.1) opening a compressor and a one-way valve connected to an external pipeline network, slowly opening a flow regulator between the compressor and the drainage gas production equipment, and injecting gas into the second annular space by adopting small displacement in the initial stage, wherein the gas injection pressure increase value does not exceed 0.8MPa every 10 minutes;
(2.2) closing a regulating valve of a first branch on an outlet pipeline of the water drainage gas production equipment, so that the natural gas which is initially produced is preferentially supplied to a gas generator to provide energy required by automatic operation for a compressor;
(2.3) gradually reducing the liquid level of the liquid in the second annulus, reaching the opening pressure after energy storage, gradually starting a pressure regulator arranged on the small oil pipe to lift the accumulated liquid in the shaft, and enabling the gas injection pressure to reach a preset pressure range and be stable for a period of time until high-pressure gas enters from the bottom of the small oil pipe;
(2.4) after the compressor can normally operate, opening the regulating valve of the first branch, and enabling the system to enter a normal automatic operation stage;
(2.5) detecting the liquid level position in the second annulus through a plurality of liquid level sensors, and correspondingly adjusting flow regulators arranged on each pipeline, so that the system can automatically and stably operate; when the liquid level is higher, the natural gas flow rate flowing into the second annular space is increased, and when the liquid level is lower, the natural gas flow rate flowing into the second annular space is reduced.
Wherein, in the step (2.3), the step of starting the pressure regulator arranged on the small oil pipe step by step may include:
1) the injected gas enters the second annulus through the inlet, the liquid level of the annulus descends along with the rise of the pressure, and the liquid level in the small oil pipe rises;
2) after the first-stage pressure regulator is exposed, gas enters the small oil pipe from the first-stage pressure regulator, is mixed with liquid in the small oil pipe, the density is reduced, and the gas-liquid mixture is discharged out of the ground;
3) the gas continuously enters the annular space, and the liquid level of the annular space continuously drops until the second-stage pressure regulator is exposed;
4) the injection pressure drops to the closing pressure of the first stage pressure regulator, and gas is injected from the second stage pressure regulator;
5) and (4) continuously injecting the gas, and repeating the process until the gas enters from the bottom of the small oil pipe, so that the continuous production of the gas well is realized.
The beneficial technical effect of this application includes:
(1) the gas generator is arranged, so that electric energy can be provided for the compressor by burning natural gas, the redundant equipment and the extra electric energy loss caused by an external power supply are avoided, and the self-sufficiency of a gas well gas production system is realized;
(2) the gas-water shunting device is arranged, so that the shunted liquid flows into the bottom to be converged, when the liquid is converged to a certain liquid level depth, a valve at the bottom is opened to discharge the liquid, and the gas at the shunting position enters a gas compressor and a compressor after being dried, so that natural gas fuel required by the operation of the gas generator is provided and the recovered natural gas is recycled;
(3) by arranging the drying equipment, liquid drops mixed in the dried fuel gas are removed, the scaling of the inner wall of the compressor caused by the fact that moist natural gas enters the compressor is avoided, the loss of the compression efficiency of the compressor is avoided, and more importantly, the damage of the compressor and the shutdown of a gas well caused by excessive scaling are avoided; meanwhile, the efficiency loss of the generator and the short circuit fault of the line caused by the wet natural gas entering the generator are avoided, and a plurality of fault problems in the prior art are solved;
(4) the external transmission pipe network is connected to the upstream of the gas-water diversion device through a one-way valve so as to inject compressed gas into the second annular space during the initial operation of the system to obtain natural gas required by the normal operation of the compressor, after the system operates stably, the one-way valve connected to the external transmission pipe network can be closed, and the produced natural gas is used as circulating carrier gas of the compressor;
(5) by arranging the pressure regulator, the gas lift pressure is reduced, and the energy loss is reduced. Other functions of the pressure regulator include: the depth of a gas injection point can be flexibly changed to adapt to the liquid supply capacity of the well; the second annular space is used as a gas injection channel for providing compressed gas into the small oil pipe; the pressure regulator is a one-way channel and can prevent liquid in the well from flowing back from the second annular space;
(6) by adopting the full-life-cycle water drainage and gas production method, the system can quickly enter a normal automatic operation stage, the compressor can perform continuous operation, and the required energy can be automatically supplied by natural gas after being mined and dried in a shunting way, so that the compressor can work in a stable production state for a long time, the stable working pressure and load are kept, and the loss is reduced; meanwhile, the method can automatically adjust the flow regulator on the external pipeline according to the liquid level detected underground, so that the system can maintain balance, and the maximum efficiency of exploitation is realized by spending minimum energy.
Drawings
Fig. 1 shows a schematic diagram of the overall arrangement of a full-life drainage gas production system of a water-producing gas well according to the present application.
Fig. 2 shows a schematic structural diagram of the water drainage and gas production equipment of the present application.
Detailed Description
To make the objects, technical solutions and advantages of the present application more apparent, embodiments of the present application will be described in detail below with reference to the accompanying drawings. It should be noted that the embodiments and features of the embodiments in the present application may be arbitrarily combined with each other without conflict.
Fig. 1 shows a schematic diagram of the overall arrangement of a water-producing gas well full-life cycle drainage gas production system of the present application. As shown in the figure, the drainage gas production system comprises drainage gas production equipment 1, a gas-water flow dividing device 2, drying equipment 3, a gas generator 4 and a compressor 5. An outlet pipeline of the water drainage and gas production equipment 1 is divided into two branches, wherein the first branch is connected with a regulating valve 6, a flow regulator 8 and a barometer 7 and is finally connected to an external transmission pipe network 51 of natural gas; the second branch is connected with a gas-water diversion device 2 for diverting gas and liquid transmitted in the second branch. The main body of the gas-water distribution device 2 is in an inverted circular truncated cone shape, and a tangential inlet is formed in the upper side wall of the gas-water distribution device, so that gas mixed with liquid is introduced from the tangential direction, and liquid drops with larger inertial centrifugal force are thrown to the outer wall surface by utilizing the rotary motion caused by the tangential introduction of the gas, so that the gas and the liquid are separated. The gas after the reposition of redundant personnel flows out from the top of gas-water diverging device 2, and the liquid after the reposition of redundant personnel flows into the bottom and gathers, and when gathering to certain liquid level degree of depth, the valve of bottom is opened thereby discharges liquid. Therefore, the top of the gas-water diversion device 2 is required to be provided with a gas outlet, the bottom of the gas-water diversion device 2 is also provided with a liquid collector, a certain height of the side wall of the gas-water diversion device is connected with a liquid level sensor 201, and when the separated liquid exceeds a set liquid level, an adjusting valve at the bottom of the gas-water diversion device is opened to discharge the liquid collected in the liquid collector. The gas-water separation device separates the produced gas and water, provides natural gas fuel meeting the requirement of the operation of the gas generator 4, and enables the produced natural gas to be recycled as compressed carrier gas.
The gas that flows out from the top of gas-water diverging device 2 divides into two branches through the governing valve and after drying by drying equipment 3, and one of them branch passes through flow regulator 8 and flows into gas generator 4, and another branch flows into compressor 5, and gas generator 4 is through burning the natural gas in order to provide the electric energy to compressor 5 to the equipment that external power source caused has been avoided long and tedious and extra electric energy loss. It is well known that gas well operations are in a field environment where it is difficult to connect to an on-site power source, and it is clearly a great contribution to the art if self-sufficiency of the gas well system can be achieved. Preferably, at least one energy storage battery 9 can be communicated with the gas generator 4, so that redundant electric quantity can be stored in the energy storage battery 9 to be used as a standby power supply for a compressor or other equipment. The liquid drops mixed in the fuel gas dried by the drying equipment 3 are removed, so that the scaling of the inner wall of the compressor caused by wet natural gas entering the compressor is avoided, the loss of the compression efficiency of the compressor is avoided, and more importantly, the damage of the compressor and the shutdown of a gas well caused by excessive scaling are avoided; meanwhile, the efficiency loss of the generator and the short circuit fault of the line caused by the wet natural gas entering the generator are avoided, and a plurality of fault problems in the prior art are solved. The outlet pipeline of the compressor 5 is connected to the oil pipe annulus of the drainage and gas production equipment 1 through a flow regulator 8 and a gas pressure meter 7 in sequence.
The external delivery pipe network 51 is connected to the upstream of the gas-water separation device 2 through the one-way valve 50, so that compressed gas is injected into the underground through natural gas in the external delivery pipe network 51 when the system is initially operated, and natural gas required by normal operation of the compressor is extracted. When the system is operating stably, the check valve 50 may be closed as appropriate, at which time the circulating carrier gas required for normal operation of the compressor is provided by the natural gas produced from the surface. The compressed gas may be an inert gas such as nitrogen.
As shown in fig. 2, a schematic structural diagram of the drainage gas production equipment 1 of the present application is shown, including underground equipment and surface equipment. The subsurface equipment includes casing 20, tubing 21, and small tubing 22, where casing 20 is used to support the formation wall, and tubing 21 is placed within casing 20 and forms a first annulus with casing 20. A small oil pipe 22 is placed inside the oil pipe 21 and forms a second annulus with the oil pipe 21. The small oil pipe 22 is provided with at least one pressure regulator 24, and the pressure regulator 24 is provided with an air inlet and is communicated with the small oil pipe and the second annular space. The bottom of the oil pipe 21 is provided with a seal 25 and a receiving chamber 26, and the receiving chamber 26 is used for recovering the seal after the seal 25 is opened. The receiving chamber 26 is provided with a through hole so that the interior of the tubing 21 can be put into communication with the first annulus after the seal 25 has been opened. An upper liquid level sensor 27 and a lower liquid level sensor 23 are arranged in the second annular space, the upper liquid level sensor 27 is arranged at a position higher than the uppermost pressure regulator 24, the lower liquid level sensor 23 is arranged at a position lower than the lowermost pressure regulator 24, and at least one liquid level sensor can be arranged between the upper liquid level sensor 27 and the lower liquid level sensor 23 according to needs to monitor the liquid level in the oil pipe in real time.
The ground equipment comprises three four-way pieces, namely an upper four-way piece 13, a middle four-way piece 14 and a lower four-way piece 15. The upper four-way piece 13 is communicated with the outlet pipeline 12, the middle four-way piece 14 is communicated with the inlet pipeline 11, and the lower four-way piece 15 is communicated with the first annulus. The top end of the upper four-way component 13 is provided with a pressure top component 10 to prevent the gas in the equipment from overflowing. The middle four-way component 14 is provided with a small oil pipe fixing component, the small oil pipe 22 is fixed on the small oil pipe fixing component, and the oil pipe is fixed on the lower four-way component 15. The small oil pipe 22 communicates with the outlet line 12, and a second annulus between the small oil pipe 22 and the oil pipe 21 communicates with the inlet line 11. It should be noted that the small oil pipe in the present application is a common technical term in the art, and refers to a smaller oil pipe relative to the size of the oil pipe 21, and does not need to limit the range of the size. In addition, the apparatus of FIG. 2 is intended to be illustrative, and not to be limiting of its specific construction.
The detailed steps of the water-producing gas well full-life-cycle water drainage gas production method by using the water drainage gas production system of the application are described as follows:
1. preparation of work
1.1 measuring the pressure, temperature distribution and liquid level height in the well;
1.2, exhausting air of the ground pipeline by using pump truck equipment, and carrying out graded pressure test on the ground pipeline, wherein the highest pressure test pressure is stabilized for 10 minutes, and the pressure drop is less than 0.5MPa, and the ground pipeline is qualified;
1.3 after the ground pressure test is normal, hoisting the equipment to the wellhead one by one for installation;
1.4, pulling out a small oil pipe with enough length according to the distance between the small oil pipe and a well head, guiding the small oil pipe to enter an upper four-way piece, controlling the position of a pressure regulator on the small oil pipe at an underground fixed point according to the gas lift operation depth and the liquid level height in the well, and calculating the opening pressure of each pressure regulator; wherein, the small oil pipe can be clamped in the pipe clamping box, and the bending degree of the pulled small oil pipe is not more than 5%;
in the gas lift production process, the higher opening pressure requires the rated output pressure of the compressor to be higher, but the working pressure of the gas lift system is much lower than the opening pressure during normal production, which inevitably causes waste of the power of the compressor. In order to reduce the difference between the opening pressure and the working pressure of the compressor, the opening pressure must be reduced. The main function of the pressure regulator is to reduce the opening pressure of the compressor to reduce energy losses. Other functions of the pressure regulator include: the depth of a gas injection point can be flexibly changed to adapt to the liquid supply capacity of the well; the second annular space is used as a gas injection channel to provide compressed gas into the small oil pipe, so that the liquid level in the second annular space is forced to rise into the small oil pipe and is discharged; the pressure regulator is a one-way channel and can prevent liquid in the well from flowing back from the second annular space;
1.5, pressing the small oil pipe, opening a sealing element and preparing for gas lift operation;
2. gas lift operation
2.1 opening a compressor and a one-way valve connected to an external pipeline network, slowly opening a flow regulator between the compressor and the drainage gas production equipment, and injecting gas into a second annular space by adopting small discharge capacity at the initial stage, wherein the gas injection pressure increase value does not exceed 0.8MPa every 10 minutes;
2.2 closing the regulating valve of the first branch on the outlet pipeline of the water and gas drainage and production equipment to ensure that the natural gas which is produced at the beginning is preferentially supplied to the gas generator and the compressor;
2.3 gradually reducing the liquid level of the liquid in the second annulus to reach the opening pressure after energy storage, gradually starting a pressure regulator arranged on the small oil pipe to lift the accumulated liquid in the shaft, and enabling the gas injection pressure to reach a preset pressure range and be stable for a period of time until high-pressure gas enters from the bottom of the small oil pipe;
2.4 after the compressor can normally operate, closing the one-way valve connected to the external transmission pipe network, opening the regulating valve of the first branch, and then the system enters a normal automatic operation stage;
2.5 detecting the liquid level position in the second annulus through a plurality of liquid level sensors, and correspondingly adjusting flow regulators arranged on each pipeline, so that the system can automatically and stably operate; when the liquid level is higher, the natural gas flow flowing into the second annulus is increased, and when the liquid level is lower, the natural gas flow flowing into the second annulus is reduced; when the liquid level is higher than the position of the upper liquid level sensor, the situation that the liquid accumulation in the second annular space is more and the requirement cannot be met only by the compressed and circulated natural gas is shown, and at the moment, the one-way valve connected to the external transmission pipeline network can be opened to increase the amount of the injected compressed gas.
By adopting the full-life-cycle drainage gas production method, the system can quickly enter a normal automatic operation stage, the compressor can perform continuous operation, and the required energy can be automatically supplied by natural gas after being exploited and dried in a shunting way, so that the compressor can work in a stable production state for a long time, the stable working pressure and load are kept, and the loss is reduced; meanwhile, the method can automatically adjust the flow regulator on the external pipeline according to the liquid level detected underground, so that the system can maintain balance, and the maximum efficiency of exploitation is realized by spending minimum energy.
In a preferred embodiment, the depth of the pressure regulator downhole may be calculated using the following equation:
the top pressure regulator has a depth of
The depth of the ith stage pressure regulator is
Wherein, PkeDenotes the opening pressure (MPa), PwhIs the flowing pressure (MPa) in the wellhead oil pipe, Pso[i]Injection pressure (MPa) of ground gas for the ith pressure regulator, dsThe severity of the well fluid, GgIs the pressure gradient (MPa/m) of the second annular air inner gas column, Pt[i]Is the gas layer pressure (MPa) at the ith pressure regulator. By adopting the formula, the calculation is simple, and the depth of the obtained pressure regulator can meet the requirement of actual gas production operation.
Preferably, the specific step of starting the pressure regulator arranged on the small oil pipe step by step in step 2.3 of the present application may include:
1) the injected gas enters the second annulus through the inlet, the liquid level of the annulus descends along with the rise of the pressure, and the liquid level in the small oil pipe rises;
2) after the first-stage pressure regulator is exposed, gas enters the small oil pipe from the first-stage pressure regulator, is mixed with liquid in the small oil pipe, the density is reduced, and the gas-liquid mixture is discharged out of the ground;
3) the gas continuously enters the annular space, and the liquid level of the annular space continuously drops until the second-stage pressure regulator is exposed;
4) the injection pressure drops to the closing pressure of the first stage pressure regulator, and gas is injected from the second stage pressure regulator;
5) and (4) continuously injecting the gas, and repeating the process until the gas enters from the bottom of the small oil pipe, so that the continuous production of the gas well is realized.
The water-producing gas well full-life-cycle drainage gas production method and system can be suitable for water and gas production of a gas well in a full-life cycle, gas lift starting pressure is low, energy consumption is low, self circulation can be achieved during normal water and gas production, external electric energy does not need to be used, safety and reliability are achieved, reuse can be achieved, management is simple, and maintenance cost is low.
Preferably, the gas saturation of the reservoir can also be detected before water and gas production. The framework of the reservoir is generally considered incompressible, where the fluid is compressible. Under the action of the invasion pressure difference, the elastic fluid in the reservoir is compressed, a certain volume is squeezed out and filled with mud filtrate to form an invasion zone, and the invasion zone can be calculated according to the following empirical formula:
wherein R is the intrusion radius of the intrusion zone, R is the outer boundary radius of the intrusion zone upon which the differential pressure is acting, Δ P is the differential pressure of the intrusion, θwIs the water fluid compressibility factor, SwTo the degree of water saturation, theta0Is the compression factor, S, of oil or gas0Is the saturation of oil or gas. According to the above formula, when R, R, Δ P, θ are knownw，θ0In the case of the parameter values, S can be measured experimentallywAnd S0Reservoir information is obtained based on the water saturation, oil or gas saturation of the mineral seam.
Specifically, the step of experimentally testing the reservoir gas saturation may comprise:
(1) selecting at least three test points in a region to be mined, and drilling a hole to a reservoir at each test point;
(2) injecting slurry into the reservoir under pressure, recording the invasion pressure difference at the moment, and keeping the pressure constant for at least 24 hours;
(3) measuring the widths of a reservoir flushing zone and a filter zone at the moment in a stratum punching mode to obtain R and R in the formula; the flushing zone refers to that rock pores are flushed by mud filtrate, original fluid is squeezed away, and mud filtrate and residual formation water or oil gas are in the pores; the filter belt is a position which is away from the well wall for a certain distance, the radial direction of the slurry filtrate is gradually reduced, the original fluid is increased, and the flushing belt and the filter belt are jointly called as an invasion belt; in the above formula, R is the width of the washing belt, and R is the sum of the widths of the washing belt and the filter belt;
(4) continuously injecting slurry into the reservoir under pressure, recording the invasion pressure difference after pressurization, and keeping the pressure constant for at least 24 hours;
(5) measuring the widths of the pressurized reservoir flushing belt and the pressurized filter belt to obtain new R and R;
(6) and calculating the water saturation and the gas saturation of the reservoir according to the results of at least two measurements.
Although the embodiments disclosed in the present application are described above, the descriptions are only for the convenience of understanding the present application, and are not intended to limit the present application. It will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the disclosure as defined by the appended claims.
Claims (5)
1. The water drainage and gas production method is characterized in that a water drainage and gas production system of the water producing gas well in the full life cycle is utilized, the water drainage and gas production system of the water producing gas well in the full life cycle comprises water drainage and gas production equipment, a gas-water flow dividing device, drying equipment, a gas generator and a compressor, an outlet pipeline of the water drainage and gas production equipment is divided into two branches, and the first branch is connected to an external pipeline network; the second branch is connected with a gas-water distribution device; the external transmission pipe network is connected to the upstream of the gas-water diversion device through a one-way valve;
the gas flowing out of the top of the gas-water shunting device passes through a regulating valve and is dried by drying equipment and then is divided into two branches, wherein one branch flows into a gas generator through a flow regulator, the other branch flows into a compressor, and the gas generator supplies electric energy to the compressor by burning natural gas;
the water drainage and gas production equipment comprises underground equipment and ground equipment, wherein the underground equipment comprises a sleeve, an oil pipe and a small oil pipe, the oil pipe is placed in the sleeve and forms a first annular space with the sleeve, and the small oil pipe is placed in the oil pipe and forms a second annular space with the oil pipe; the small oil pipe is provided with a plurality of pressure regulators, and the bottom of the oil pipe is provided with a sealing element; at least one liquid level sensor is arranged in the second annular space; an outlet pipeline of the compressor is connected to a second annulus of the water and gas drainage and production equipment through a flow regulator and a barometer in sequence;
the ground equipment comprises three four-way pieces, wherein the upper four-way piece is communicated with an outlet pipeline, the middle four-way piece is communicated with an inlet pipeline, and the lower four-way piece is communicated with a first annulus; the top end of the upper four-way piece is provided with a pressure jacking piece, the middle four-way piece is provided with a small oil pipe fixing piece, and the small oil pipe is fixed on the small oil pipe fixing piece; the small oil pipe is communicated with the outlet pipeline, and a second annulus between the small oil pipe and the oil pipe is communicated with the inlet pipeline;
the method comprises the following steps of detecting the gas saturation of a reservoir before water drainage and gas production, and calculating according to the following empirical formula:
wherein R is the intrusion radius of the intrusion zone, R is the outer boundary radius of the intrusion zone upon which the differential pressure is acting, Δ P is the differential pressure of the intrusion, θwIs the water fluid compressibility factor, SwTo the degree of water saturation, theta0Is the compression factor, S, of oil or gas0Is the gas saturation;
the step of testing the reservoir gas saturation comprises the following steps:
(1) selecting at least three test points in a region to be mined, and drilling a hole to a reservoir at each test point;
(2) injecting slurry into the reservoir under pressure, recording the invasion pressure difference at the moment, and keeping the pressure constant for at least 24 hours;
(3) measuring the widths of a reservoir flushing zone and a filter zone at the moment in a stratum punching mode to obtain R and R in the formula;
(4) continuously injecting slurry into the reservoir under pressure, recording the invasion pressure difference after pressurization, and keeping the pressure constant for at least 24 hours;
(5) measuring the widths of the pressurized reservoir flushing belt and the pressurized filter belt to obtain new R and R;
(6) calculating the water saturation and the gas saturation of the reservoir according to the results of at least two measurements;
the water drainage gas production method comprises the following steps:
(1) preparation of work
(1.1) measuring the pressure, the temperature distribution and the liquid level height in the well;
(1.2) exhausting air of the ground pipeline by using pump truck equipment, and carrying out graded pressure test on the ground pipeline, wherein the highest pressure test pressure is stabilized for 10 minutes, and the pressure drop is less than 0.5MPa, and the ground pipeline is qualified;
(1.3) after the ground pressure test is normal, hoisting the equipment to a wellhead one by one for installation;
(1.4) pulling out a small oil pipe with enough length according to the distance between the small oil pipe and a well head, guiding the small oil pipe to enter an upper four-way piece, clamping the small oil pipe in a pipe clamping box, controlling the pressure regulator on the small oil pipe to be at the underground fixed point position according to the gas lift operation depth and the liquid level height in the well, and calculating the opening pressure of each pressure regulator;
(1.5) pressing the small oil pipe, opening a sealing element and preparing for gas lift operation;
(2) gas lift operation
(2.1) opening a compressor and a one-way valve connected to an external pipeline network, slowly opening a flow regulator between the compressor and the drainage gas production equipment, and injecting gas into the second annular space by adopting small displacement in the initial stage, wherein the gas injection pressure increase value does not exceed 0.8MPa every 10 minutes;
(2.2) closing a regulating valve of a first branch on an outlet pipeline of the water drainage gas production equipment, so that the natural gas which is initially produced is preferentially supplied to a gas generator to provide energy required by automatic operation for a compressor;
(2.3) gradually reducing the liquid level of the liquid in the second annulus, reaching the opening pressure after energy storage, gradually starting a pressure regulator arranged on the small oil pipe to lift the accumulated liquid in the shaft, and enabling the gas injection pressure to reach a preset pressure range and be stable for a period of time until high-pressure gas enters from the bottom of the small oil pipe;
(2.4) after the compressor can normally operate, opening the regulating valve of the first branch, and enabling the system to enter a normal automatic operation stage;
(2.5) detecting the liquid level position in the second annulus through a plurality of liquid level sensors, and correspondingly adjusting flow regulators arranged on each pipeline, so that the system can automatically and stably operate; when the liquid level is higher, the natural gas flow flowing into the second annulus is increased, and when the liquid level is lower, the natural gas flow flowing into the second annulus is reduced;
wherein the depth of the pressure regulator downhole is calculated using the following formula:
the top pressure regulator has a depth of
The depth of the ith stage pressure regulator is
Wherein, PkeIndicating opening pressure, PwhIs the flow pressure in the wellhead tubing, Pso[i]Injection pressure of gas into the ground of the ith pressure regulator, dsThe severity of the well fluid, GgIs the pressure gradient, P, of the second annular column of airt[i]Is the pressure of the gas layer at the ith pressure regulator.
2. The water-producing gas well full-life cycle drainage gas production method as claimed in claim 1, wherein in the step (2.3), the step of starting the pressure regulator arranged on the small oil pipe step by step comprises the following steps:
1) the injected gas enters the second annulus through the inlet, the liquid level of the annulus descends along with the rise of the pressure, and the liquid level in the small oil pipe rises;
2) after the first-stage pressure regulator is exposed, gas enters the small oil pipe from the first-stage pressure regulator, is mixed with liquid in the small oil pipe, the density is reduced, and the gas-liquid mixture is discharged out of the ground;
3) the gas continuously enters the annular space, and the liquid level of the annular space continuously drops until the second-stage pressure regulator is exposed;
4) the injection pressure drops to the closing pressure of the first stage pressure regulator, and gas is injected from the second stage pressure regulator;
5) and continuously injecting the gas, and gradually starting the pressure regulator arranged on the small oil pipe until the gas enters from the bottom of the small oil pipe, so that the continuous production of the gas well is realized.
3. The water-producing gas well full-life cycle drainage gas production method as claimed in claim 1 or 2, wherein the liquid level sensors comprise an upper liquid level sensor and a lower liquid level sensor, the upper liquid level sensor is arranged at a position higher than the uppermost pressure regulator, the lower liquid level sensor is arranged at a position lower than the lowermost pressure regulator, and at least one liquid level sensor is arranged between the upper liquid level sensor and the lower liquid level sensor.
4. The water-producing gas well full-life cycle drainage gas production method as claimed in claim 1 or 2, wherein the main body of the gas-water flow dividing device is in an inverted truncated cone shape, the upper side wall of the gas-water flow dividing device is provided with a tangential inlet, the top of the gas-water flow dividing device is provided with a gas outlet, the bottom of the gas-water flow dividing device is further provided with a liquid collector, the side wall of the gas-water flow dividing device is connected with a liquid level sensor, the divided gas flows out of the top of the gas-water flow dividing device, the divided liquid flows into the bottom of the gas-water flow dividing device to be collected, and when the divided liquid is collected to a certain liquid level depth, a valve at the bottom of the gas-water flow dividing device is opened so as to discharge the liquid.
5. The water and gas producing well full-life-cycle drainage gas production method as claimed in claim 3, wherein the main body of the gas-water flow dividing device is in an inverted truncated cone shape, the upper side wall of the gas-water flow dividing device is provided with a tangential inlet, the top of the gas-water flow dividing device is provided with a gas outlet, the bottom of the gas-water flow dividing device is further provided with a liquid collector, the side wall of the gas-water flow dividing device is connected with a liquid level sensor, the divided gas flows out of the top of the gas-water flow dividing device, the divided liquid flows into the bottom of the gas-water flow dividing device to be collected, and when the divided liquid is collected to a certain liquid level depth, a valve at the bottom of the gas-water flow dividing device is opened so as to discharge the liquid.
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| CN114183099A (en) * | 2022-02-15 | 2022-03-15 | 东营云起石油科技有限公司 | Negative pressure lifting shaft liquid operation method |
| CN116104456B (en) * | 2023-04-14 | 2023-06-30 | 陕西航天德林科技集团有限公司 | Drainage gas production system and drainage gas production method |
| CN117722163A (en) * | 2024-02-08 | 2024-03-19 | 山东科瑞油气装备有限公司 | Mobile rapid moving equipment for gas lift drainage of natural gas and use method thereof |
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