CN118128489B - Fracturing fluid flowback control method and device for coalbed methane well - Google Patents
Fracturing fluid flowback control method and device for coalbed methane well Download PDFInfo
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- CN118128489B CN118128489B CN202410272664.7A CN202410272664A CN118128489B CN 118128489 B CN118128489 B CN 118128489B CN 202410272664 A CN202410272664 A CN 202410272664A CN 118128489 B CN118128489 B CN 118128489B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
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- E21B—EARTH OR ROCK 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
- E21B43/006—Production of coal-bed methane
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- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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Abstract
The invention provides a fracturing fluid flowback control method and device for a coal-bed gas well, and belongs to the technical field of production control of the coal-bed gas well. The fracturing fluid flowback control method of the coal-bed gas well comprises the following steps: acquiring wellhead pressure in real time in the process of flowback of fracturing fluid of a coal-bed gas well, and intensively determining a current fracturing fluid flowback control stage in a preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages, and the rate of fracturing fluid flowback is controlled based on the control strategy corresponding to the current fracturing fluid flowback control stage. The time node of the fracturing fluid flowback can be defined, the on-site production flow and measures can be systematically arranged, and the effect of dredging the stratum seepage channel can be achieved, so that the stable seepage of the coalbed methane reservoir is maintained, the stratum pressure can be dredged, and the depressurization and gas production efficiency can be improved.
Description
Technical Field
The invention relates to the technical field of production control of coal-bed gas wells, in particular to a fracturing fluid flowback control method of a coal-bed gas well, a fracturing fluid flowback control device of the coal-bed gas well, a machine-readable storage medium and electronic equipment.
Background
Coalbed methane is an important unconventional natural gas resource, and the gas production process is significantly different from that of conventional natural gas. The coal bed gas reservoir is a coal stratum, the natural permeability of the reservoir is low, and underground water is formed in the hole cracks. In the development of coal bed gas, a subsurface fluid seepage channel is required to be established through reservoir fracturing modification, and the pressure of the reservoir is reduced by discharging groundwater so that the coal bed gas is desorbed and produced.
Because the physical properties of the coal bed reservoirs are complex, the natural permeability is low, the sensitivity is high, and the abnormal conditions such as reservoir injury, stratum blockage, water lock and the like easily occur in the development process, the permeability of the coal bed gas well reservoirs is low, the desorption is insufficient, the productivity is reduced and the like are caused, and the efficient production and development of the coal bed gas are restricted.
At present, the field control of the coal bed gas well mainly surrounds the liquid production amount, the working fluid level descending rate, the bottom hole pressure change and the like in drainage, and aims to keep stable production and avoid reservoir damage, but the time of the flow back of fracturing fluid and the flow back rate cannot be clarified at present, the field construction organization has no unified standard, the well is braised for too long after the fracturing of part of the wells, the flow back efficiency is too low, coal dust sedimentation and reservoir damage are caused, and the gas-seeing efficiency and the yield standard rate of the coal bed gas well are greatly influenced.
Disclosure of Invention
The embodiment of the invention aims to provide a fracturing fluid flowback control method of a coal-bed gas well, a fracturing fluid flowback control device of the coal-bed gas well, a machine-readable storage medium and an electronic device, according to the fracturing fluid flowback control method for the coal-bed gas well, different control strategies can be adopted in different fracturing fluid flowback control stages to control flowback rate, so that time nodes of fracturing fluid flowback can be defined, on-site production flow and measures can be systematically arranged, formation pressure can be dredged, and depressurization and gas production efficiency can be improved.
In order to achieve the above object, a first aspect of the present application provides a fracturing fluid flowback control method for a coal-bed gas well, including:
Acquiring wellhead pressure in real time in the process of flowing back fracturing fluid of a coal-bed gas well;
Based on the wellhead pressure, the current fracturing fluid flowback control stage is intensively determined and obtained in a preset fracturing fluid flowback control stage;
controlling the rate of fracturing fluid flowback based on a control strategy corresponding to the current fracturing fluid flowback control stage;
The preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the fracturing fluid flowback control stages.
In the embodiment of the application, each control strategy comprises the size of a nozzle tip;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
And controlling the open flow of the coal-bed gas well based on the size of the choke in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In an embodiment of the present application, each control strategy includes a maximum flow rate;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
And controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In an embodiment of the application, each control strategy includes a nozzle size and a maximum flow rate;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
performing open flow control on the coal-bed gas well based on the size of a choke in a control strategy corresponding to the current fracturing fluid flowback control stage;
And controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In the embodiment of the application, the open flow level is set in each fracturing fluid flowback control stage, and the method further comprises the following steps:
Under the condition of sand discharge at a wellhead, adjusting a current control strategy based on the open flow level of the current fracturing fluid in the flowback control stage to obtain an updated control strategy;
And controlling the rate of the fracturing fluid flowback based on the updated control strategy.
In an embodiment of the present application, the method further includes:
Judging whether the wellhead pressure reaches a first threshold value;
And under the condition that the wellhead pressure is determined to reach a first threshold value, controlling artificial lifting and drainage by adopting a staged control strategy.
In the embodiment of the application, the artificial lifting drainage is controlled by adopting a staged control strategy, which comprises the following steps:
Acquiring bottom hole pressure in real time;
Determining a current artificial lift drainage stage based on the desorption pressure and the bottom hole pressure;
and controlling the pressure drop rate based on the current artificial lift drainage stage.
In an embodiment of the present application, the method further includes:
judging whether the coal-bed gas well enters the later development stage;
and under the condition that the coal-bed gas well is determined to enter the later development period, controlling the wellhead pressure to reach a preset pressure threshold range.
In the embodiment of the application, the judging whether the coal-bed gas well enters the later development stage comprises the following steps:
acquiring bottom hole pressure in real time, and judging whether the bottom hole pressure is stable or not;
and under the condition that the bottom hole pressure is stable, determining that the coal-bed gas well enters the later development period.
The second aspect of the application provides a fracturing fluid flowback control device of a coal-bed gas well, comprising:
the acquisition module is used for acquiring wellhead pressure in real time in the process of flowing back the fracturing fluid of the coal-bed gas well;
The determining module is used for intensively determining and obtaining the current fracturing fluid flowback control stage in a preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages;
and the first control module is used for controlling the rate of the flowback of the fracturing fluid based on a control strategy corresponding to the current flowback control stage of the fracturing fluid.
In the embodiment of the application, each control strategy comprises the size of a nozzle tip;
The first control module includes:
And the open flow unit is used for controlling the open flow of the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In an embodiment of the present application, each control strategy includes a maximum flow rate;
The first control module includes:
and the flow rate unit is used for controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In an embodiment of the application, each control strategy includes a nozzle size and a maximum flow rate;
The first control module includes:
The blowout control unit is used for performing blowout control on the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage;
and the flow rate unit is used for controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In the embodiment of the application, the open flow level is respectively set in each fracturing fluid flowback control stage, and the device further comprises:
The adjusting module is used for adjusting the current control strategy based on the open flow level of the current fracturing fluid flowback control stage under the condition of sand production of a wellhead, so as to obtain an updated control strategy;
and the second control module is used for controlling the rate of the fracturing fluid flowback based on the updated control strategy.
In an embodiment of the present application, the apparatus further includes:
The first judging module is used for judging whether the wellhead pressure reaches a first threshold value or not;
And the drainage and production module is used for controlling artificial lifting and production by adopting a staged control strategy under the condition that the wellhead pressure is determined to reach a first threshold value.
In an embodiment of the present application, the drainage module includes:
the first pressure acquisition unit is used for acquiring the bottom hole pressure in real time;
The extraction stage determining unit is used for determining the current artificial lifting extraction stage based on the desorption pressure and the bottom hole pressure;
and the pressure drop control unit is used for controlling the pressure drop rate based on the current artificial lifting and extraction stage.
In an embodiment of the present application, the apparatus further includes:
the second judging module is used for judging whether the coal-bed gas well enters the later development stage;
And the third control module is used for controlling the wellhead pressure to reach a preset pressure threshold range under the condition that the coal-bed gas well is determined to enter the later development period.
In an embodiment of the present application, the second judging module includes:
the second pressure acquisition unit is used for acquiring the bottom hole pressure in real time and judging whether the bottom hole pressure is stable or not;
and the determining unit is used for determining that the coal-bed gas well enters the later development period under the condition that the bottom hole pressure is determined to be stable.
A third aspect of the present application provides an electronic apparatus comprising:
At least one processor;
A memory coupled to the at least one processor;
The storage stores instructions which can be executed by the at least one processor, and the at least one processor realizes the fracturing fluid flowback control method of the coal-bed gas well by executing the instructions stored by the storage.
A fourth aspect of the application provides a machine-readable storage medium having instructions stored thereon that, when executed by a processor, cause the processor to be configured to perform the method of controlling flowback of fracturing fluid for a coal-bed gas well as described above.
According to the technical scheme, the wellhead pressure is obtained in real time in the process of flowback the fracturing fluid of the coal-bed gas well, and the current fracturing fluid flowback control stage is intensively determined and obtained in the preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages, and the rate of fracturing fluid flowback is controlled based on the control strategy corresponding to the current fracturing fluid flowback control stage. By determining the current control stage of the flowback of the fracturing fluid, different control strategies can be adopted in different control stages of the flowback of the fracturing fluid to control the flowback rate, so that the time node of the flowback of the fracturing fluid can be clarified, on-site production flow and measures can be systematically arranged, the control measures of the flowback production of the fracturing fluid can be clarified through the corresponding control strategies, the flowback speed can be accelerated by using the formation pressure rising caused by the formation energy supplemented by fracturing, the flowback efficiency can be improved, the near-well pollution zone can be flushed, the effect of dredging the stratum seepage channel can be achieved, the stable seepage of the coal bed gas reservoir can be maintained, the formation pressure can be dredged, and the depressurization and gas production efficiency can be improved.
Additional features and advantages of embodiments of the invention will be set forth in the detailed description which follows.
Drawings
The accompanying drawings are included to provide a further understanding of embodiments of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain, without limitation, the embodiments of the invention. In the drawings:
FIG. 1 schematically illustrates a flow diagram of a fracturing fluid flowback control method for a coal-bed gas well according to an embodiment of the application;
FIG. 2 schematically illustrates a choke size versus wellhead pressure value graph in accordance with an embodiment of the present application;
FIG. 3 schematically illustrates a schematic diagram of drainage and drainage gas production control of a dredged coalbed methane fracturing fluid in accordance with an embodiment of the application;
FIG. 4 schematically illustrates a schematic structural diagram of a fracturing fluid flowback control apparatus for a coal-bed gas well according to an embodiment of the present application;
Fig. 5 schematically shows an internal structural view of a computer device according to an embodiment of the present application.
Description of the reference numerals
410-An acquisition module; 420-determining a module; 430-a first control module; a01-a processor; a02-a network interface; a03-an internal memory; a04-a display screen; a05-an input device; a06—a nonvolatile storage medium; b01-operating system; b02-computer program.
Detailed Description
The following describes the detailed implementation of the embodiments of the present invention with reference to the drawings. It should be understood that the detailed description and specific examples, while indicating and illustrating the invention, are not intended to limit the invention.
It should be noted that, if there is a description of "first", "second", etc. in the embodiments of the present application, the description of "first", "second", etc. is only for descriptive purposes, and is not to be construed as indicating or implying relative importance or implying that the number of technical features indicated is indicated. Thus, a feature defining "a first" or "a second" may explicitly or implicitly include at least one such feature. In addition, the technical solutions of the embodiments may be combined with each other, but it is necessary to base that the technical solutions can be realized by those skilled in the art, and when the technical solutions are contradictory or cannot be realized, the combination of the technical solutions should be considered to be absent and not within the scope of protection claimed in the present application.
Referring to fig. 1, fig. 1 schematically shows a flow chart of a fracturing fluid flowback control method of a coal-bed gas well according to an embodiment of the application. The embodiment provides a fracturing fluid flowback control method of a coal-bed gas well, which comprises the following steps:
step 210: acquiring wellhead pressure in real time in the process of flowing back fracturing fluid of a coal-bed gas well;
In the embodiment, after the pump-stopping pressure drop test of the fracturing construction of the coal-bed gas well is completed, the fracturing fluid flowback operation is immediately carried out, namely the fracturing fluid flowback stage of the coal-bed gas well is entered. The wellhead pressure can be obtained according to data acquired by a wellhead pressure sensor in real time.
Step 220: based on the wellhead pressure, the current fracturing fluid flowback control stage is intensively determined and obtained in a preset fracturing fluid flowback control stage; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages;
in this embodiment, the number of the fracturing fluid flowback control stages may be determined according to the situation of an actual coalbed methane well, different control strategies are adopted in different fracturing fluid flowback control stages, different pressure ranges are corresponding to different fracturing fluid flowback control stages, and when determining the current fracturing fluid flowback control stage, the determining of which pressure range is located may be performed by comparing the wellhead pressure with each pressure range, where the fracturing fluid flowback control stage corresponding to the pressure range is the current fracturing fluid flowback control stage. Such as: the preset fracturing fluid flowback control stage is concentrated and comprises a, b, c, d stages, the pressure range corresponding to the a stage is more than 10MPa, the pressure range corresponding to the b stage is 5-10 MPa, the pressure range corresponding to the c stage is 2-5 MPa, the pressure range corresponding to the d stage is less than 2MPa, the wellhead pressure is 3MPa, and the current fracturing fluid flowback control stage is determined to be the c stage through comparison. The fracturing fluid flowback control stage set can be preset, wherein each fracturing fluid flowback control stage corresponds to a corresponding control strategy, the control strategy is used for controlling the rate of fracturing fluid flowback, and the corresponding control strategy can be obtained by comparing the wellhead pressure with each pressure range to match the current fracturing fluid flowback control stage.
Step 230: and controlling the rate of the fracturing fluid flowback based on a control strategy corresponding to the current fracturing fluid flowback control stage.
In this embodiment, different control strategies are provided for different control stages of the fracturing fluid flowback, and the control strategies are used to control the rate of fracturing fluid flowback.
In the implementation process, different control strategies can be adopted in different fracturing fluid flowback control stages by determining the current fracturing fluid flowback control stage, namely, the time node of fracturing fluid flowback is determined in the current fracturing fluid flowback control stage, so that the on-site production flow and measures can be systematically arranged, the flowback production control measures can be determined by the corresponding control strategies, the flowback speed can be accelerated by using the formation pressure rising caused by the formation energy supplemented by fracturing, the flowback efficiency can be improved, the near-well pollution zone can be flushed, the effect of dredging the formation seepage channel can be achieved, the stable seepage of the coalbed methane reservoir can be maintained, the formation pressure can be helped, and the depressurization and gas production efficiency can be improved.
In some embodiments, to be able to control the rate of fracturing fluid flowback, it may be controlled from the size of the choke, i.e., each control strategy includes the choke size; the control strategy corresponding to the current fracturing fluid flowback control stage is used for controlling the rate of fracturing fluid flowback, and the control strategy comprises the following steps: and controlling the open flow of the coal-bed gas well based on the size of the choke in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In this embodiment, the size of the nipple may be empirically preset, and may be a range. Such as: as shown in FIG. 2, FIG. 2 schematically shows a graph of the size of a nipple and wellhead pressure according to an embodiment of the present application, wherein the nipple size may be between 7mm and 8mm at a wellhead pressure of 5-10 MPa, and between 10mm and 12mm at a wellhead pressure of 2-5 MPa. It should be noted that, for convenience of operation, a fixed value may also be directly obtained, for example, in the above example, the average value may be directly obtained, that is, 7.5mm. After the current fracturing fluid flowback control stage is determined, the corresponding size of the oil nozzle can be obtained, and then the corresponding size of the oil nozzle is adopted to carry out open flow control on the coal bed gas well, so that the rate of fracturing fluid flowback is controlled.
The size of the oil nozzle is set in each control strategy, so that the speed of the fracturing fluid flowback is controlled through the size of the oil nozzle, and the fracturing fluid flowback is more universal and is convenient for each coal-bed gas well to use.
In some embodiments, to be able to control the rate of the fracturing fluid flowback, it may be that the rate of the fracturing fluid flowback is controlled by the maximum flow rate, i.e. each control strategy includes a maximum flow rate; the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps: and controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In this embodiment, the maximum flow rate may be preset empirically, for example, the maximum flow rate is controlled to 20m 3/h in the (a) stage when the wellhead pressure is >10 MPa; the wellhead pressure is 5-10 MPa, the stage (b) is carried out, and the maximum flow rate is controlled at 15m 3/h; the wellhead pressure is 2-5 MPa, the stage (c) is adopted, and the maximum flow rate is controlled at 10m 3/h; and (d) the stage is carried out when the wellhead pressure is less than 2MPa, and the maximum flow rate is controlled to be 5m 3/h.
By setting the maximum flow rate in each control strategy, it is more convenient to control the rate of fracturing fluid flowback by the maximum flow rate.
In some embodiments, to be able to better control the rate of fracturing fluid flowback, it may be to control from both the choke size and maximum flow rate, i.e., each control strategy includes choke size and maximum flow rate; the control strategy corresponding to the current fracturing fluid flowback control stage is used for controlling the rate of fracturing fluid flowback, and the control strategy comprises the following steps:
Firstly, performing open flow control on a coal-bed gas well based on the size of a nozzle in a control strategy corresponding to the current fracturing fluid flowback control stage;
and then, controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
Such as: when the wellhead pressure is more than 10MPa, the step (a) is adopted, a 5mm oil nozzle is adopted for open flow, and the maximum flow rate is controlled at 20m 3/h; the wellhead pressure is 5-10 MPa, and the stage (b) is that an 8mm oil nozzle is adopted for open flow, and the maximum flow rate is controlled at 15m 3/h; the wellhead pressure is 2-5 MPa, and the step (c) is that a 10-12mm oil nozzle is adopted for open flow, and the maximum flow rate is controlled at 10m 3/h; the wellhead pressure is (d) stage when <2MPa, oil have a loose tongue is sprayed open, and the maximum flow rate is controlled at 5m 3/h.
The rate of the fracturing fluid flowback can be better controlled by controlling the production control measures of the two fracturing fluid flowback from the size of the oil nozzle and the maximum flow rate.
In some embodiments, to avoid sand production during open flow, the control strategy may also be adjusted in time based on the sand production conditions. Specifically, each fracturing fluid flowback control stage is respectively provided with a blowout grade, and the method further comprises the following steps:
firstly, under the condition of sand discharge at a wellhead, adjusting a current control strategy based on the open flow level of the current fracturing fluid in the flowback control stage to obtain an updated control strategy;
In this embodiment, when the blowout level is set, the blowout level may be set according to the size of the nozzle, that is, the smaller the size of the nozzle in the control strategy corresponding to the fracturing fluid flowback control stage is, the larger the maximum flow rate is, and accordingly, the higher the blowout level is, in the above example, the highest the blowout level in the stage (a), followed by the stage (b), followed by the stage (c), and finally followed by the stage (d). When adjusting the current control strategy, the open flow level may be sequentially adjusted to a lower level, for example, the current control stage of the fracturing fluid flowback is the stage (a), sand is discharged when the wellhead open flow is performed, the control strategy corresponding to the stage (b) may be adjusted, and if sand is still discharged, the control strategy corresponding to the stage (c) is continuously adjusted until no sand is discharged.
Then, based on the updated control strategy, the rate of fracturing fluid flowback is controlled.
In this embodiment, after the current control strategy is adjusted, the rate of the fracturing fluid flowback can be controlled according to the updated control strategy, so as to avoid sand production during open flow.
Through timely adjustment of the open flow grade when the wellhead discharges sand, the sand discharge during open flow can be effectively avoided, and smooth proceeding of fracturing fluid flowback is ensured.
In some embodiments, because the implementation time and the drainage rate of the drainage process after the fracturing fluid flowback are not guided by a specific method, part of the well flowback is not timely drained after completion, the pressure of a well liquid column is high, so that a reservoir is suppressed, continuous flow is not formed, and reservoir damage is easy to occur. Therefore, after the completion of the fracturing fluid flowback, the fracturing fluid can be immediately lowered into a drainage pump and a drainage pipe column to carry out artificial lifting drainage. The method further comprises the steps of:
Firstly, judging whether the wellhead pressure reaches a first threshold value;
In this embodiment, the first threshold may be a value set according to an actual situation, where the first threshold may be 0, and the determining whether the wellhead pressure reaches the first threshold may be determining whether the wellhead pressure is 0, that is, when the wellhead has no self-injection drainage capability, the fracturing fluid flowback is ended.
Then, under the condition that the wellhead pressure is determined to reach a first threshold value, controlling artificial lift drainage by adopting a staged control strategy.
In this embodiment, when the wellhead has no self-injection drainage capability, the fracturing fluid flowback is ended, and then artificial lifting drainage is performed, which may specifically be controlled by adopting a staged control strategy. The phased control strategy may be a pre-divided plurality of phases, each phase corresponding to a different control strategy.
It should be noted that, the process of continuous operation of flowback and artificial lifting drainage is carried out in advance by selecting drainage equipment and preparing construction, and the construction waiting time after flowback should not appear, so as to avoid the sedimentation of static pulverized coal of reservoir fluid, ensure continuous and stable output of stratum fluid to the maximum extent, dredge stratum pressure and avoid reservoir pollution.
In some embodiments, to better control artificial lift drainage, the bottom hole pressure drop rate may be controlled in stages during artificial lift drainage, in particular, the artificial lift drainage is controlled using a staged control strategy, comprising the steps of:
firstly, acquiring bottom hole pressure in real time;
in this embodiment, the bottom hole pressure may be obtained by reading a value of a bottom hole pressure gauge at the time of manually lifting the drainage.
Then, determining a current artificial lift drainage stage based on the desorption pressure and the bottom hole pressure;
In the present embodiment, the desorption pressure mentioned above refers to a critical desorption pressure, and may be obtained in advance. The determining of the current artificial lift drainage stage may be comparing the desorption pressure with the bottom hole pressure to obtain different stages, such as: the bottom hole pressure is (a) when the desorption pressure is greater than or equal to the bottom hole pressure, and (b) when the bottom hole pressure is less than or equal to the desorption pressure.
Finally, controlling the pressure drop rate based on the current artificial lift drainage stage.
In this embodiment, different pressure drop rates may be employed for different artificial lift drainage stages. For example, when the bottom hole pressure is higher than the desorption pressure, the pressure drop rate is controlled to be 0.05-0.10 MPa/d, single-phase water flows at the moment, and reservoir fluid continuous flow is controlled according to the bottom hole pressure; and when the bottom hole pressure is less than or equal to the desorption pressure, the pressure drop rate is controlled to be less than 0.01MPa/d, at the moment, the adsorption gas starts to desorb, the stratum is in multiphase flow, the bottom hole pressure is kept to be slowly reduced, the smooth transition between the water phase flow and the gas phase flow is facilitated, and the stratum is continuously dredged to prevent water lock.
By determining the current artificial lifting drainage stage based on the desorption pressure and the bottom hole pressure and controlling the corresponding pressure drop rate, the continuous flow of reservoir fluid can be controlled according to the bottom hole pressure when the bottom hole pressure is higher than the desorption pressure; when the bottom hole pressure is not greater than the desorption pressure, the bottom hole pressure is kept to be slowly reduced, so that the smooth transition between the water phase flow and the gas phase flow is facilitated, the stratum is continuously dredged, and the occurrence of water lock is prevented. Therefore, the time node and production control measures for drainage and gas production can be defined, the on-site production process and measures of the system are arranged conveniently, the stable seepage of the coalbed methane reservoir is maintained, the stratum pressure is dredged, and the depressurization gas production efficiency is improved.
In some embodiments, because of formation energy shortage in the later stage of development of the coal-bed gas well, produced water is unstable and discontinuous, and formation pressure cannot continuously and stably drop, enhanced drainage and production can be performed at this time, that is, a wellhead is additionally provided with negative pressure drainage equipment so that wellhead pressure reaches a preset pressure threshold range. The method further comprises the steps of:
firstly, judging whether a coal-bed gas well enters a later development period;
In this embodiment, the above-mentioned determination process may be to determine whether the bottom hole pressure is stable, and indicate that the coalbed methane well enters the later development stage under the condition that the bottom hole pressure is stable. Namely, judging whether the coal-bed gas well enters the later development stage or not, wherein the judging comprises the following steps: acquiring bottom hole pressure in real time, and judging whether the bottom hole pressure is stable or not; and under the condition that the bottom hole pressure is determined to be stable, determining that the coal-bed gas well enters the later development stage.
And then, under the condition that the coal-bed gas well is determined to enter the later development period, controlling the wellhead pressure to reach a preset pressure threshold range.
In this embodiment, in the later development stage of the coalbed methane well, enhanced drainage is performed at this time, that is, the wellhead is additionally provided with a negative pressure drainage device, so as to control the wellhead pressure to drop to a preset pressure threshold range, where the preset pressure threshold range may be preset according to actual conditions, for example: the pressure threshold range is-1 to-3 MPa, and the wellhead pressure is controlled to be reduced to be-1 to-3 MPa, so that the production pressure difference can be further established to dredge the formation pressure, the continuous and stable flow of reservoir fluid is promoted, and the reservoir fluid potential is released.
And when the coal-bed gas well enters the later development period, controlling the wellhead pressure to reach a preset pressure threshold range, further establishing a production pressure difference to dredge the formation pressure, promoting the continuous and stable flow of reservoir fluid, and releasing the reservoir fluid potential.
Referring to fig. 3, fig. 3 schematically illustrates a schematic diagram of drainage and gas production control of a dredged coalbed methane fracturing fluid according to an embodiment of the application, and the whole control process includes the drainage of the fracturing fluid, manual lifting drainage and enhanced dredging drainage and production. By designing systematic and comprehensive drainage and drainage gas production control programs of the drainage type coal bed gas fracturing fluid, as shown in the following table 1, table 1 is the drainage and drainage gas production control program of the drainage type coal bed gas fracturing fluid. The control standard in table 1 indicates a corresponding control strategy, the control node indicates that the control of each stage is a time node, and the whole process comprises fracturing fluid flowback, artificial lifting drainage and enhanced dredging drainage, wherein the fracturing fluid flowback corresponds to four stages, and the artificial lifting drainage corresponds to two stages. The control program guides the continuous flowback and drainage of the coal-bed gas well site, so that the depressurization desorption efficiency is greatly improved, the pollution of a reservoir is avoided, and the development effect of the coal-bed gas well is improved. The method is applied to production of key basin for developing coal bed gas such as a water-clearing basin, approximately 207 times of vertical wells and 150 times of horizontal wells are comprehensively implemented, the average fracturing fluid flowback rate of the implemented wells is improved by 5% -10%, the gas-finding time is shortened by 30%, and the development efficiency of the coal bed wells is greatly improved.
Table 1: drainage type coalbed methane fracturing fluid flowback and drainage gas production control program
Taking a basin Anze block well 1-XX well:
Immediately blowout through an oil pipe after fracturing pressure drop is finished, and installing an oil pumping unit at a wellhead, and conveying a tubular pump to a well site for later use; the fracturing fluid flowback comprises four stages (a), (b), (c) and (d), manual lifting and drainage operation is carried out after flowback is carried out for half a day, a pipe column is quickly lifted and lowered, continuous operation is carried out, and the pipe pump is quickly started and pumped after being installed in place; the bottom hole pressure is controlled according to two stages (a) and (b) of artificial lifting drainage, gas is rapidly seen after 35 days of drainage, the whole flowback and drainage depressurization construction are consistent, the liquid production is stable and continuous, the flowback rate reaches 45%, the single-well peak capacity is 2350 square/day, and the older well is improved by 30%.
In the implementation process, the wellhead pressure is obtained in real time in the process of flowback the fracturing fluid of the coal-bed gas well, and the current fracturing fluid flowback control stage is intensively determined and obtained in the preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages, and the rate of fracturing fluid flowback is controlled based on the control strategy corresponding to the current fracturing fluid flowback control stage. By determining the current control stage of the flowback of the fracturing fluid, different control strategies can be adopted in different control stages of the flowback of the fracturing fluid to control the flowback rate, so that the time node of the flowback of the fracturing fluid can be clarified, on-site production flow and measures can be systematically arranged, the control measures of the flowback production of the fracturing fluid can be clarified through the corresponding control strategies, the flowback speed can be accelerated by using the formation pressure rising caused by the formation energy supplemented by fracturing, the flowback efficiency can be improved, the near-well pollution zone can be flushed, the effect of dredging the stratum seepage channel can be achieved, the stable seepage of the coal bed gas reservoir can be maintained, the formation pressure can be dredged, and the depressurization and gas production efficiency can be improved. Through timely adjustment of the open flow grade when the wellhead discharges sand, the sand discharge during open flow can be effectively avoided, and smooth proceeding of fracturing fluid flowback is ensured. After the completion of the flowback of the fracturing fluid, the artificial lifting drainage is controlled by adopting a staged control strategy, so that the time node and production control measures of drainage and gas production can be clarified, the on-site production process and measures of the system are arranged, the stable seepage of the coal bed gas reservoir is maintained, the stratum pressure is dredged, and the depressurization gas production efficiency is improved. And when the coal-bed gas well enters the later development period, controlling the wellhead pressure to reach a preset pressure threshold range, further establishing a production pressure difference to dredge the formation pressure, promoting the continuous and stable flow of reservoir fluid, and releasing the reservoir fluid potential. The control method for drainage and drainage gas production of the dredged fracturing fluid is realized, so that the control method can guide the time and the speed of drainage and drainage of the coal-bed gas well, the depressurization desorption efficiency is improved, the damage to a reservoir is avoided, and the purpose of improving the on-site development effect of the coal-bed gas is achieved.
FIG. 1 is a schematic flow diagram of a fracturing fluid flowback control method for a coal-bed gas well in one embodiment. It should be understood that, although the steps in the flowchart of fig. 1 are shown in sequence as indicated by the arrows, the steps are not necessarily performed in sequence as indicated by the arrows. The steps are not strictly limited to the order of execution unless explicitly recited herein, and the steps may be executed in other orders. Moreover, at least some of the steps in fig. 1 may include multiple sub-steps or stages that are not necessarily performed at the same time, but may be performed at different times, nor do the order in which the sub-steps or stages are performed necessarily performed in sequence, but may be performed alternately or alternately with at least a portion of other steps or sub-steps of other steps.
Referring to fig. 4, fig. 4 schematically illustrates a schematic structural diagram of a fracturing fluid flowback control apparatus for a coal-bed gas well according to an embodiment of the present application. The embodiment provides a fracturing fluid flowback control device of a coal-bed gas well, which comprises an acquisition module 410, a determination module 420 and a first control module 430, wherein:
an acquisition module 410, configured to acquire wellhead pressure in real time during a fracturing fluid flowback process of the coal-bed gas well;
The determining module 420 is configured to intensively determine and obtain a current fracturing fluid flowback control stage in a preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages;
the first control module 430 is configured to control a rate of flowback of the fracturing fluid based on a control policy corresponding to the current flowback control stage of the fracturing fluid.
Wherein each control strategy includes a nozzle size;
The first control module 430 includes:
And the open flow unit is used for controlling the open flow of the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
Wherein each control strategy includes a maximum flow rate;
The first control module 430 includes:
and the flow rate unit is used for controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
Wherein each control strategy includes a nozzle size and a maximum flow rate;
The first control module 430 includes:
The blowout control unit is used for performing blowout control on the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage;
and the flow rate unit is used for controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
Wherein, each fracturing fluid flow-back control stage is provided with the open flow level respectively, the device still includes:
The adjusting module is used for adjusting the current control strategy based on the open flow level of the current fracturing fluid flowback control stage under the condition of sand production of a wellhead, so as to obtain an updated control strategy;
and the second control module is used for controlling the rate of the fracturing fluid flowback based on the updated control strategy.
Wherein the apparatus further comprises:
The first judging module is used for judging whether the wellhead pressure reaches a first threshold value or not;
And the drainage and production module is used for controlling artificial lifting and production by adopting a staged control strategy under the condition that the wellhead pressure is determined to reach a first threshold value.
Wherein, the drainage module includes:
the first pressure acquisition unit is used for acquiring the bottom hole pressure in real time;
The extraction stage determining unit is used for determining the current artificial lifting extraction stage based on the desorption pressure and the bottom hole pressure;
and the pressure drop control unit is used for controlling the pressure drop rate based on the current artificial lifting and extraction stage.
Wherein the apparatus further comprises:
the second judging module is used for judging whether the coal-bed gas well enters the later development stage;
And the third control module is used for controlling the wellhead pressure to reach a preset pressure threshold range under the condition that the coal-bed gas well is determined to enter the later development period.
Wherein, the second judging module includes:
the second pressure acquisition unit is used for acquiring the bottom hole pressure in real time and judging whether the bottom hole pressure is stable or not;
and the determining unit is used for determining that the coal-bed gas well enters the later development period under the condition that the bottom hole pressure is determined to be stable.
The fracturing fluid flowback control device of the coal-bed gas well comprises a processor and a memory, wherein the acquisition module 410, the determination module 420, the first control module 430 and the like are stored in the memory as program units, and the processor executes the program units stored in the memory to realize corresponding functions.
The processor includes a kernel, and the kernel fetches the corresponding program unit from the memory. The core can be provided with one or more cores, and the timing of the flowback of the fracturing fluid and the rate of the flowback are clarified by adjusting the parameters of the core.
The memory may include volatile memory, random Access Memory (RAM), and/or nonvolatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM), among other forms in computer readable media, the memory including at least one memory chip.
The embodiment of the invention provides a machine-readable storage medium, and a program is stored on the machine-readable storage medium, and when the program is executed by a processor, the fracturing fluid flowback control method of the coal-bed gas well is realized.
The embodiment of the invention provides a processor which is used for running a program, wherein the fracturing fluid flowback control method of the coal-bed gas well is executed when the program runs.
In one embodiment, a computer device is provided, which may be a terminal, and the internal structure of which may be as shown in fig. 5. The computer apparatus includes a processor a01, a network interface a02, a display screen a04, an input device a05, and a memory (not shown in the figure) which are connected through a system bus. Wherein the processor a01 of the computer device is adapted to provide computing and control capabilities. The memory of the computer device includes an internal memory a03 and a nonvolatile storage medium a06. The nonvolatile storage medium a06 stores an operating system B01 and a computer program B02. The internal memory a03 provides an environment for the operation of the operating system B01 and the computer program B02 in the nonvolatile storage medium a06. The network interface a02 of the computer device is used for communication with an external terminal through a network connection. The computer program when executed by the processor A01 is used for realizing the fracturing fluid flowback control method of the coal-bed gas well. The display screen a04 of the computer device may be a liquid crystal display screen or an electronic ink display screen, and the input device a05 of the computer device may be a touch layer covered on the display screen, or may be a key, a track ball or a touch pad arranged on a casing of the computer device, or may be an external keyboard, a touch pad or a mouse.
It will be appreciated by those skilled in the art that the structure shown in FIG. 5 is merely a block diagram of some of the structures associated with the present inventive arrangements and is not limiting of the computer device to which the present inventive arrangements may be applied, and that a particular computer device may include more or fewer components than shown, or may combine some of the components, or have a different arrangement of components.
In one embodiment, the fracturing fluid flowback control device of the coal-bed gas well provided by the application can be implemented in the form of a computer program, and the computer program can be run on computer equipment shown in fig. 5. The memory of the computer device may store various program modules, such as the acquisition module 410, the determination module 420, and the first control module 430 shown in fig. 4, that make up the fracturing fluid flowback control device of the coal-bed gas well. The computer program formed by the program modules enables the processor to execute the steps in the fracturing fluid flowback control method of the coal-bed gas well according to the embodiments of the application described in the specification.
The computer apparatus shown in fig. 5 may perform step 210 by an acquisition module 410 in a fracturing fluid flowback control apparatus of a coal-bed gas well as shown in fig. 4. The computer device may perform step 220 by determining module 420. The computer device may perform step 230 through the first control module 430.
The embodiment of the application provides electronic equipment, which comprises: at least one processor; a memory coupled to the at least one processor; the storage stores instructions which can be executed by the at least one processor, and the at least one processor realizes the fracturing fluid flowback control method of the coal-bed gas well by executing the instructions stored by the storage. The processor when executing the instructions implements the steps of:
Acquiring wellhead pressure in real time in the process of flowing back fracturing fluid of a coal-bed gas well;
Based on the wellhead pressure, the current fracturing fluid flowback control stage is intensively determined and obtained in a preset fracturing fluid flowback control stage;
controlling the rate of fracturing fluid flowback based on a control strategy corresponding to the current fracturing fluid flowback control stage;
The preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the fracturing fluid flowback control stages.
In one embodiment, each control strategy includes a nozzle size;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
And controlling the open flow of the coal-bed gas well based on the size of the choke in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In one embodiment, each control strategy includes a maximum flow rate;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
And controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In one embodiment, each control strategy includes a nozzle size and a maximum flow rate;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
performing open flow control on the coal-bed gas well based on the size of a choke in a control strategy corresponding to the current fracturing fluid flowback control stage;
And controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback.
In one embodiment, each fracturing fluid flowback control stage is provided with a blowout rating, respectively, the method further comprising:
Under the condition of sand discharge at a wellhead, adjusting a current control strategy based on the open flow level of the current fracturing fluid in the flowback control stage to obtain an updated control strategy;
And controlling the rate of the fracturing fluid flowback based on the updated control strategy.
In one embodiment, the method further comprises:
Judging whether the wellhead pressure reaches a first threshold value;
And under the condition that the wellhead pressure is determined to reach a first threshold value, controlling artificial lifting and drainage by adopting a staged control strategy.
In one embodiment, the controlling artificial lift drainage with a phased control strategy includes:
Acquiring bottom hole pressure in real time;
Determining a current artificial lift drainage stage based on the desorption pressure and the bottom hole pressure;
and controlling the pressure drop rate based on the current artificial lift drainage stage.
In one embodiment, the method further comprises:
judging whether the coal-bed gas well enters the later development stage;
and under the condition that the coal-bed gas well is determined to enter the later development period, controlling the wellhead pressure to reach a preset pressure threshold range.
In one embodiment, the determining whether the coalbed methane well enters a later stage of development includes:
acquiring bottom hole pressure in real time, and judging whether the bottom hole pressure is stable or not;
and under the condition that the bottom hole pressure is stable, determining that the coal-bed gas well enters the later development period.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In one typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include volatile memory in a computer-readable medium, random Access Memory (RAM) and/or nonvolatile memory, etc., such as Read Only Memory (ROM) or flash RAM. Memory is an example of a computer-readable medium.
Computer readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of storage media for a computer include, but are not limited to, phase change memory (PRAM), static Random Access Memory (SRAM), dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), read Only Memory (ROM), electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape disk storage or other magnetic storage devices, or any other non-transmission medium, which can be used to store information that can be accessed by a computing device. Computer-readable media, as defined herein, does not include transitory computer-readable media (transmission media), such as modulated data signals and carrier waves.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article, or apparatus that comprises an element.
The foregoing is merely exemplary of the present application and is not intended to limit the present application. Various modifications and variations of the present application will be apparent to those skilled in the art. Any modification, equivalent replacement, improvement, etc. which come within the spirit and principles of the application are to be included in the scope of the claims of the present application.
Claims (14)
1. The fracturing fluid flowback control method for the coal-bed gas well is characterized by comprising the following steps of:
Acquiring wellhead pressure in real time in the process of flowing back fracturing fluid of a coal-bed gas well;
Based on the wellhead pressure, the current fracturing fluid flowback control stage is intensively determined and obtained in a preset fracturing fluid flowback control stage;
controlling the rate of fracturing fluid flowback based on a control strategy corresponding to the current fracturing fluid flowback control stage;
The preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages;
wherein each control strategy includes a maximum flow rate;
the controlling the rate of the fracturing fluid flowback based on the control strategy corresponding to the current fracturing fluid flowback control stage comprises the following steps:
based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage, performing flow rate control on the coal-bed gas well to control the rate of fracturing fluid flowback;
each control strategy also includes a nipple size;
the control method for controlling the rate of the flowback of the fracturing fluid based on the control strategy corresponding to the current flowback control stage of the fracturing fluid further comprises the following steps:
and controlling the open flow of the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage.
2. The fracturing fluid flowback control method of a coal-bed gas well of claim 1, wherein each fracturing fluid flowback control stage is provided with a blowout rating, respectively, the method further comprising:
Under the condition of sand discharge at a wellhead, adjusting a current control strategy based on the open flow level of the current fracturing fluid in the flowback control stage to obtain an updated control strategy;
And controlling the rate of the fracturing fluid flowback based on the updated control strategy.
3. The method for controlling flowback of fracturing fluid of a coal-bed gas well of claim 1, further comprising:
Judging whether the wellhead pressure reaches a first threshold value;
And under the condition that the wellhead pressure is determined to reach a first threshold value, controlling artificial lifting and drainage by adopting a staged control strategy.
4. A fracturing fluid flowback control method of a coal-bed gas well according to claim 3, wherein said controlling artificial lift drainage with a phased control strategy comprises:
Acquiring bottom hole pressure in real time;
Determining a current artificial lift drainage stage based on the desorption pressure and the bottom hole pressure;
and controlling the pressure drop rate based on the current artificial lift drainage stage.
5. A fracturing fluid flowback control method of a coal-bed gas well according to claim 3, further comprising:
judging whether the coal-bed gas well enters the later development stage;
and under the condition that the coal-bed gas well is determined to enter the later development period, controlling the wellhead pressure to reach a preset pressure threshold range.
6. The fracturing fluid flowback control method of the coal-bed gas well of claim 5, wherein the judging whether the coal-bed gas well enters a later development stage comprises:
acquiring bottom hole pressure in real time, and judging whether the bottom hole pressure is stable or not;
and under the condition that the bottom hole pressure is stable, determining that the coal-bed gas well enters the later development period.
7. The utility model provides a fracturing fluid flow back control device of coal bed gas well which characterized in that includes:
the acquisition module is used for acquiring wellhead pressure in real time in the process of flowing back the fracturing fluid of the coal-bed gas well;
The determining module is used for intensively determining and obtaining the current fracturing fluid flowback control stage in a preset fracturing fluid flowback control stage based on the wellhead pressure; the preset fracturing fluid flowback control stage set comprises a plurality of fracturing fluid flowback control stages and a plurality of control strategies respectively corresponding to the plurality of fracturing fluid flowback control stages;
the first control module is used for controlling the rate of the flowback of the fracturing fluid based on a control strategy corresponding to the current flowback control stage of the fracturing fluid;
wherein each control strategy includes a maximum flow rate;
The first control module includes:
The flow rate unit is used for controlling the flow rate of the coal-bed gas well based on the maximum flow rate in the control strategy corresponding to the current fracturing fluid flowback control stage so as to control the rate of fracturing fluid flowback;
each control strategy also includes a nipple size;
the first control module further includes:
and the blowout unit is used for performing blowout control on the coal-bed gas well based on the size of the oil nozzle in the control strategy corresponding to the current fracturing fluid flowback control stage.
8. The fracturing fluid flowback control apparatus of a coal-bed gas well of claim 7, wherein each fracturing fluid flowback control stage is provided with a respective open flow rating, said apparatus further comprising:
The adjusting module is used for adjusting the current control strategy based on the open flow level of the current fracturing fluid flowback control stage under the condition of sand production of a wellhead, so as to obtain an updated control strategy;
and the second control module is used for controlling the rate of the fracturing fluid flowback based on the updated control strategy.
9. The fracturing fluid flowback control apparatus of a coal-bed gas well of claim 7, wherein said apparatus further comprises:
The first judging module is used for judging whether the wellhead pressure reaches a first threshold value or not;
A drainage and production module for adopting step by step under the condition that the wellhead pressure is determined to reach a first threshold value
And the section control strategy controls artificial lifting drainage.
10. The fracturing fluid flowback control device of a coal-bed gas well of claim 9, wherein said drainage and production module comprises:
the first pressure acquisition unit is used for acquiring the bottom hole pressure in real time;
The extraction stage determining unit is used for determining the current artificial lifting extraction stage based on the desorption pressure and the bottom hole pressure;
and the pressure drop control unit is used for controlling the pressure drop rate based on the current artificial lifting and extraction stage.
11. The fracturing fluid flowback control apparatus of a coal-bed gas well of claim 9, wherein said apparatus further comprises:
the second judging module is used for judging whether the coal-bed gas well enters the later development stage;
And the third control module is used for controlling the wellhead pressure to reach a preset pressure threshold range under the condition that the coal-bed gas well is determined to enter the later development period.
12. The fracturing fluid flowback control device of a coal-bed gas well of claim 11, wherein said second determination module comprises:
the second pressure acquisition unit is used for acquiring the bottom hole pressure in real time and judging whether the bottom hole pressure is stable or not;
and the determining unit is used for determining that the coal-bed gas well enters the later development period under the condition that the bottom hole pressure is determined to be stable.
13. An electronic device, characterized in that, the electronic device includes:
At least one processor;
A memory coupled to the at least one processor;
wherein the memory stores instructions executable by the at least one processor, the at least one processor implementing the fracturing fluid flowback control method of the coal-bed gas well of any one of claims 1 to 6 by executing the instructions stored by the memory.
14. A machine-readable storage medium having instructions stored thereon, which when executed by a processor, cause the processor to be configured to perform the fracturing fluid flowback control method of a coal-bed gas well according to any one of claims 1 to 6.
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN108119119A (en) * | 2017-12-06 | 2018-06-05 | 中国石油天然气股份有限公司 | Control method and system for fracturing horizontal well flowing stage |
| CN117307111A (en) * | 2022-06-21 | 2023-12-29 | 中国石油天然气股份有限公司 | Method and device for determining oil nozzle system in shale gas horizontal well flowback stage |
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