CN215678199U - Water lock injury testing device - Google Patents
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- CN215678199U CN215678199U CN202121549218.4U CN202121549218U CN215678199U CN 215678199 U CN215678199 U CN 215678199U CN 202121549218 U CN202121549218 U CN 202121549218U CN 215678199 U CN215678199 U CN 215678199U
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- 238000012360 testing method Methods 0.000 title claims abstract description 120
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- 230000006378 damage Effects 0.000 title claims abstract description 82
- 208000027418 Wounds and injury Diseases 0.000 title claims abstract description 8
- 208000014674 injury Diseases 0.000 title claims abstract description 8
- 239000007788 liquid Substances 0.000 claims abstract description 85
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Abstract
The water lock injury testing device comprises a geological environment simulation module, a water lock damage testing module and a water lock damage monitoring module, wherein the geological environment simulation module is used for placing a sample and providing a simulated geological environment; a liquid phase injection module for injecting liquid into the sample; the gas phase injection module is used for injecting gas into the sample; the test module comprises a resistivity test unit for obtaining sample resistivity data and an acoustic wave test unit for obtaining longitudinal and transverse wave data of a sample; the test module is connected with the geological environment simulation module, the liquid phase injection module and the gas phase injection module and used for determining water lock damage data of the sample according to resistivity data and longitudinal and transverse wave data measured in different environments. The water lock damage testing device provided by the utility model can simulate the geological environment where the sample is located, the injection and flowback process of fracturing fluid, obtain resistivity data and longitudinal and transverse wave data of the sample in different environments, further determine the water lock damage data of the sample, improve the accuracy of evaluating the water lock damage degree of the sample, and provide more reliable support for the exploration and development of a reservoir stratum.
Description
Technical Field
The utility model relates to the technical field of oil exploration, in particular to a water lock damage testing device.
Background
The geological resource amount of shallow coal bed gas within 2000 meters buried depth in China reaches 36.81 trillion cubic meters, the recoverable resource amount is 10.87 trillion cubic meters, and the method has a resource foundation for large-scale development. The development of coal bed gas is improved by fracturing, but the coal bed usually contains a large amount of organic matters and has strong capability of adsorbing or absorbing various organic liquids and gases, so that the interaction between a fracturing fluid polymer entering the coal bed and the coal bed is strong, and the coal bed is easily damaged by water lock.
The water lock damage refers to damage to a reservoir stratum caused by liquid phase retention in a porous medium, is the most common damage of a coal bed gas reservoir, and the damage occurrence rate is as high as 70-90%. After the coal bed is fractured, the connectivity of pores of the reservoir is improved, external fluid can easily enter the micropores of the coal bed, and the water saturation of the reservoir is increased; and when the gas-water interfacial tension is higher, the viscosity of the invaded fluid is higher, the time required for liquid drainage is longer, the water lock problem is more serious, and the fracturing effect is greatly reduced. Water lock damage, the most prominent type of damage to coal seam gas reservoirs, is difficult to completely remove once it occurs, and can seriously affect the discovery, evaluation and development of gas reservoirs. Therefore, it is very important to accurately evaluate the damage degree of the reservoir water lock.
However, in the prior art, the testing and evaluating device for coal bed gas water lock damage can only evaluate the degree of water lock damage from the macroscopic water lock damage result, namely the permeability. However, the method for evaluating the water lock damage through the permeability cannot directly reflect the degree of liquid phase retention, and the change of the permeability is not only influenced by the water lock, but also obviously influenced by other factors such as clay expansion and the like, so that the evaluation of the water lock damage by using the permeability is not scientific and accurate.
Aiming at the defects in the prior art, the water lock damage testing device is provided, so that the water lock damage can be tested and evaluated more accurately, and more accurate technical support is provided for the exploration and development of the coal bed gas.
SUMMERY OF THE UTILITY MODEL
In view of the above problems in the prior art, an object of the present disclosure is to provide a water-lock damage testing apparatus to solve the problem of inaccurate water-lock damage testing of a core sample in the prior art.
In order to solve the technical problems, the specific technical scheme is as follows:
there is provided herein a water-lock injury testing device comprising:
a liquid phase injection module for injecting a liquid into the sample;
a gas phase injection module for injecting gas into the sample;
the test module comprises a resistivity test unit and an acoustic wave test unit, wherein the resistivity test unit is used for loading charges to obtain resistivity data of the sample, and the acoustic wave test unit is used for obtaining longitudinal and transverse wave data of the sample; the test module is connected with the geological environment simulation module, the liquid phase injection module and the gas phase injection module and used for determining water lock damage data of the sample according to resistivity data and longitudinal and transverse wave data measured under different environments.
Specifically, the geological environment simulation module comprises:
a holder for placing the sample;
a pressure control unit for pressing the clamper;
a temperature control unit for controlling the temperature of the holder.
Further, the holder comprises a holder body, a top cover and a bottom cover, wherein the holder body, the top cover and the bottom cover enclose a space for accommodating the sample;
a rubber sleeve is arranged in the holder and is in contact fit with the inner wall of the holder body, and the sample is placed in the rubber sleeve;
the testing module comprises a rubber sleeve, a testing electrode, a sound wave receiving unit, a power supply electrode and a sound wave transmitter, wherein the rubber sleeve is internally provided with the testing electrode and the sound wave receiving unit, the top cover is provided with the power supply electrode and the sound wave transmitter, and the testing electrode and the power supply electrode as well as the sound wave receiving unit and the sound wave transmitter are connected with the testing module.
Further, the pressure control unit comprises a confining pressure control subunit and an axial pressure control subunit, the confining pressure control subunit is connected with the side wall of the gripper body, and the axial pressure control subunit is connected with the top cover and/or the bottom cover.
Specifically, the liquid phase injection module includes:
the liquid storage tank is used for accommodating the liquid storage liquid;
a first intermediate container for connecting the liquid storage tank and the holder;
and the first temperature control device is connected with the first intermediate container and is used for heating the first intermediate container.
Further, the liquid phase injection module further includes:
the first waste liquid tank is connected with the liquid storage tank;
and the second waste liquid tank is connected with the holder and is used for recovering the waste liquid storage and collection liquid in the holder.
Still further, the liquid phase injection module further comprises:
the first pump body is connected with the liquid storage tank and is used for pumping the liquid storage in the liquid storage tank into the clamp holder;
and the first flow meter is connected with the test module and the second waste liquid tank and is used for monitoring the flow of the liquid storage and collection returned to the second waste liquid tank.
Specifically, the gas phase injection module includes:
the gas storage tank is used for containing stored gas;
a second intermediate container for connecting the gas storage tank with the holder;
and the second temperature control device is connected with the second intermediate container and is used for heating the stored gas in the second intermediate container.
Further, the gas phase injection module further comprises:
and the humidifying device is arranged between the air storage tank and the second intermediate container and is used for humidifying the reservoir air flowing to the second intermediate container.
Specifically, the test module includes:
and the monitoring unit is connected with a first pressure sensor, a first temperature sensor and a second flowmeter, the first pressure sensor is connected with the pressure control unit, and the first temperature sensor is connected with the temperature control unit.
By adopting the technical scheme, the water lock injury testing device comprises a geological environment simulation module, a water lock injury testing module and a water lock injury testing module, wherein the geological environment simulation module can simulate the geological environment of a core sample; the liquid phase injection module and the gas phase injection module can be used for simulating the injection and flowback processes of the fracturing fluid; the test module comprises a resistivity test unit and a sound wave test unit, can acquire resistivity data and longitudinal and transverse wave data of the sample in different environments, can further synthesize the resistivity data and the longitudinal and transverse wave data to determine water lock damage data of the sample, improves accuracy of evaluating water lock damage degree of the sample, and provides reliable support for exploration and development of a reservoir stratum.
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
Drawings
In order to more clearly illustrate the embodiments or technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a schematic diagram illustrating a water-lock damage testing apparatus according to an embodiment of the present disclosure;
FIG. 2 shows a schematic structural view of a gripper;
FIG. 3 shows a schematic structural view of a top cover of the holder;
FIG. 4 is a schematic view showing the structure of the rubber sleeve matched with the top cover of the holder;
FIG. 5 shows a plot of the fit of sample aspect ratio to water saturation.
Description of the symbols of the drawings:
100. a liquid phase injection module;
101. a first pump body;
102. a fracturing fluid storage tank;
103. a formation water reservoir tank;
104. a first waste liquid tank;
105. a first intermediate container;
106. a first flow meter;
107. a first temperature control device;
108. a second temperature sensor;
109. a second waste liquid tank;
200. a geological environment simulation module;
201. a pressure control unit;
2011. a first pressure sensor;
202. a temperature control unit;
2021. a first temperature sensor;
203. a holder;
2031. a holder body;
2032. a top cover;
2033. a bottom cover;
204. a rubber sleeve;
205. a power supply electrode;
206. a test electrode;
207. an acoustic wave emitter;
208. an acoustic wave receiving unit;
209. a sample;
300. a test module;
301. a power source;
302. a resistivity test unit;
303. an acoustic wave test unit;
304. a monitoring unit;
400. a gas phase injection module;
401. a second pressure sensor;
402. a second temperature control device;
403. a humidity control device;
404. a gas storage tank;
405. a second intermediate container;
406. a third temperature sensor;
407. a second flow meter;
408. a second pump body;
409. an off-gas tank.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments herein without making any creative effort, shall fall within the scope of protection.
It should be noted that the terms "first," "second," and the like in the description and claims herein and in the above-described drawings are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments herein described are capable of operation in sequences other than those illustrated or described herein. Furthermore, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, apparatus, article, or device that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed, but may include other steps or elements not expressly listed or inherent to such process, method, article, or device.
The coal bed gas mainly adsorbs the surfaces of coal matrix particles, and part of the hydrocarbon gas is dissociated in coal pores or dissolved in coal bed water, is an associated mineral resource of coal, and is a clean and high-quality energy and chemical raw material which rises internationally in nearly twenty years. The development of coal bed gas is improved by fracturing, but the coal bed usually contains a large amount of organic matters and has strong capability of adsorbing or absorbing various organic liquids and gases, so that the interaction between a fracturing fluid polymer entering the coal bed and the coal bed is strong, and the coal bed is easily damaged by water lock.
The water-lock damage refers to damage to a reservoir bed caused by liquid phase retention in a porous medium, is the most common damage of a coal bed gas reservoir, has the damage occurrence rate of generally 70-90%, is difficult to completely remove once occurring, and can seriously affect the discovery, evaluation and development of the gas reservoir. Therefore, it is very important to accurately evaluate the damage degree of the reservoir water lock.
However, in the prior art, the testing and evaluating device for coal bed gas water lock damage can only evaluate the degree of water lock damage from the macroscopic water lock damage result of permeability. However, the method for evaluating water lock damage through permeability cannot directly reflect the degree of liquid phase retention, and the change of permeability is not only influenced by water lock, but also obviously influenced by other factors such as clay swelling and the like, so that evaluation of water lock damage by using permeability is not scientific and accurate.
In order to solve the above problems, embodiments herein provide a water-lock damage testing apparatus, which can overcome the above problem of the prior art that is inaccurate in evaluating and testing coalbed methane water-lock damage. Fig. 1 is a schematic structural diagram of a water-lock damage testing apparatus provided in an embodiment herein, as shown in fig. 1, the apparatus includes:
a geological environment simulation module 200 for placing a sample 209 to be tested and providing a simulated geological environment for the sample;
a liquid phase injection module 100 for injecting a liquid into the sample;
a gas phase injection module 400 for injecting gas into the sample;
the testing module 300 comprises a resistivity testing unit 302 and an acoustic wave testing unit 303, wherein the resistivity testing unit 302 is used for loading charges to obtain resistivity data of the sample 209, and the acoustic wave testing unit 303 is used for obtaining longitudinal and transverse wave data of the sample; the testing module 300 is connected to the geological environment simulation module 200, the liquid phase injection module 100 and the gas phase injection module 400, and is configured to determine water lock damage data of the sample 209 according to resistivity data and longitudinal and transverse wave data measured in different environments. In the embodiments of the present specification, the longitudinal and transverse wave data may include a longitudinal and transverse wave speed ratio, a longitudinal and transverse wave time difference ratio, and the like.
The water lock damage testing device provided by the embodiment of the specification, wherein the geological environment simulation module can simulate the geological environment of a core sample; the liquid phase injection module and the gas phase injection module can be used for simulating the injection and flowback processes of the fracturing fluid; the test module comprises a resistivity test unit and a sound wave test unit, and can acquire resistivity data and longitudinal and transverse wave data of the sample in different environments, and further determine water lock damage data of the sample according to the resistivity data and the longitudinal and transverse wave data. Compared with the mode of obtaining the water lock damage result according to the permeability in the prior art, the water lock damage testing device provided by the utility model can more directly and accurately evaluate the water lock damage degree, and provides more reliable support for coal bed gas exploration and development.
In addition, the water lock damage testing device provided by the embodiment of the specification can be used for measuring the resistivity data of the sample and can also be used for measuring the longitudinal and transverse wave data of the sample, so that the damage to the sample caused by repeated disassembly due to the joint measurement of different experimental equipment is avoided, and the uniformity of the experimental sample is ensured.
Further, in this embodiment, the geological environment simulation module 200 includes:
a holder 203 for placing the sample 209;
the pressure control unit 201 is used for applying pressure to the clamp 203 so as to simulate the pressure environment of the reservoir where the sample 209 corresponds to;
and the temperature control unit 202 is used for controlling the temperature of the clamp 203 so as to simulate the temperature environment of the reservoir where the sample corresponds to.
It should be noted that, when the sample 209 is placed in the holder 203, the placement direction of the sample in the holder 203 should be consistent with the direction of the sample in the actual reservoir.
Preferably, a first pressure sensor 2011 is further connected to the pressure control unit 201, and a first temperature sensor 2021 is further connected to the temperature control unit 202. The test module further comprises a monitoring unit 304, and the first pressure sensor and the first temperature sensor are connected to the monitoring unit 304 and used for monitoring the environment where the sample 209 is located.
In the embodiment of the present specification, the geological environment simulation module 200 can provide an accurate geological environment for a sample to be tested, so that a water lock damage test is performed in the environment, and a more accurate test result can be obtained.
Further, as shown in fig. 2, in the embodiment of the present specification, the holder 203 includes a holder body 2031, a top cover 2032, and a bottom cover 2033, where the top cover 2032 and the bottom cover 2033 are used for closing the holder body and forming a space for accommodating the specimen 209; a rubber sleeve 204 is arranged in the holder, the rubber sleeve 204 is in contact fit with the inner wall of the holder body 2031, and the sample 209 is placed in the rubber sleeve 204.
A test electrode 206 and a sound wave receiving unit 208 are arranged in the rubber sleeve 204; the top cover 2032 is provided with a power supply electrode 205 and a sound wave emitter 207; the test electrode 206 and the power electrode 205, and the acoustic wave receiving unit 208 and the acoustic wave transmitter 207 are connected to the test module 300.
Specifically, the power supply electrode 205, the test electrode 206 and the resistivity test unit are connected through a multi-core cable to realize data transmission; the acoustic wave transmitter 207, the acoustic wave receiving unit 208 and the acoustic wave testing unit are also connected through a multi-core cable.
It should be noted that, in the embodiments of the present disclosure, the power supply electrode, the test electrode, the acoustic wave transmitter, and the acoustic wave receiving unit are divided into the address environment simulation module according to their positional relationships, and in some feasible embodiments, the above components may also be divided into the test module according to their functions. Therefore, the scope of the embodiments of the present description should not be limited by the manner in which the modules and units are divided.
As shown in fig. 4, the test electrodes 206 are arranged in two groups and are symmetrically arranged, each group of test electrodes 206 includes at least 3 electrode pieces (in this embodiment, each group of test electrodes includes preferably 5 electrode pieces), and the test electrodes 206 belonging to the same group are uniformly distributed along the axis direction of the gripper, that is, the distances between each electrode piece in the same group and the power supply electrode 205 are unequal, so as to obtain resistivity data of the sample 209 at different positions. The acoustic wave receiving unit 208 is disposed in a similar manner to the test electrode 206, and is not described in detail here. The test electrode 206 and the acoustic wave receiving unit 208 can be respectively arranged on the rubber sleeve 204, and the test electrode and the acoustic wave receiving unit can be integrated into a whole, so that the device building efficiency can be improved.
As shown in fig. 3, which is a schematic structural diagram of the top cover 2032, the acoustic wave transmitter 207 is arranged at the center of the top cover so that the distances of the emitted acoustic wave information transmitted to the two acoustic wave receiving units 208 located at the same horizontal level are equal; the power supply electrode 205 is disposed on the periphery of the acoustic wave transmitter 207. Of course, the relative positioning between the acoustic transmitter and the power supply electrode is merely exemplary, and other arrangements are possible.
The top cap 2032 is further provided with a connection structure, which is connected to the test electrodes and the resistivity test unit to connect the multi-core cable. The two connecting structures are respectively connected with the two groups of test electrodes and are made of conductive materials.
Preferably, the pressure control unit 201 includes a confining pressure control subunit connected with the holder body 2031 and an axial pressure control subunit connected with the top cover 2032 and/or the bottom cover 2033. The pressure-confining control subunit is used for simulating the confining pressure of the reservoir where the sample is located, and the axial pressure control subunit is used for simulating the axial pressure of the reservoir where the sample is located, so that the axial pressure and the confining pressure of the sample are increased to the reservoir pressure, and the sample is provided with an accurate pressure environment.
As shown in fig. 1, in the embodiment of the present disclosure, the liquid phase injection module 100 includes:
a reservoir, a first intermediate container 105 and a first temperature control device 107;
the liquid storage tank is used for accommodating liquid storage liquid; preferably, in the embodiment of the present specification, the fluid reservoir includes a fracturing fluid reservoir 102 and a formation water reservoir 103, that is, the water lock damage testing apparatus provided in the present specification may inject not only fracturing fluid but also formation water into the sample 209 in the holder, so as to simulate a liquid phase environment during a fracturing process of the reservoir and a flowback environment during gas production of the reservoir.
The first intermediate container 105 connects the reservoir and the gripper 203; namely, the reservoir liquid in the liquid storage tank is injected into the holder 203 after passing through the first intermediate container.
The first temperature control device 107 is connected with the first intermediate container 105, and the first temperature control device 107 is used for controlling the temperature of the reservoir liquid in the first intermediate container 105, so that the reservoir liquid injected into the sample is matched with the liquid phase fluid temperature at the reservoir where the sample is located, and the fluid injected into the holder cannot damage the geological environment state provided by the geological environment simulation module. Therefore, the accuracy of the liquid phase environment of the sample is improved, and the accuracy of water lock damage assessment is further improved.
In the embodiment of the present disclosure, the temperature control of the first temperature control device on the liquid stored in the first intermediate container includes not only heating treatment, but also cooling of the liquid stored at a higher temperature.
In the embodiment of the present specification, the first temperature control device 107 is used to control the temperature of the reservoir liquid in the first intermediate container 105, and compared with a method of directly controlling the temperature of the reservoir liquid in the liquid storage tank, the temperature control with a large volume of the liquid storage tank requires more time, so that the efficiency of temperature control can be improved; simultaneously, liquid is difficult to maintain in the liquid storage tank and when the circulation is in the pipeline, and makes liquid heated or cool down in first intermediate reservoir, can make liquid temperature more even.
Preferably, a second temperature sensor 108 is further connected to the first intermediate container 105, the second temperature sensor 108 is used for monitoring the temperature of the liquid stored in the first intermediate container 105, and the second temperature sensor 108 can be further connected to a monitoring unit 304.
Further preferably, the liquid phase injection module 100 further comprises a first waste liquid tank 104 and a second waste liquid tank 109; the first waste liquid tank 104 is connected with the liquid storage tank, a control valve is arranged between the first waste liquid tank 104 and the liquid storage tank and used for controlling the on-off of a pipeline between the liquid storage tank and the first waste liquid tank, and after the test is finished, the control valve is opened so as to enable the reservoir liquid in the liquid storage tank to be recovered into the first waste liquid tank 104; the second waste liquid tank 109 is connected with the gripper 203 and is used for recovering waste liquid storage in the gripper; in other words, in the embodiment of the specification, the reservoir liquid in the liquid storage tank and the waste reservoir liquid at the clamp holder are classified and recovered, so that the recovered reservoir liquid can be conveniently treated, and the resource utilization efficiency is improved.
Further, in this embodiment, the liquid phase injection module 100 further includes a first pump body 101 and a first flow meter 106;
preferably, the first pump body 101 is a constant-pressure constant-flow pump, and the first pump body 101 is connected with the liquid storage tank and used for simulating the pressure of liquid phase fluid in the reservoir to pump the reservoir in the liquid storage tank into the holder;
a first flow meter 106 is provided between the clamper 203 and the second waste liquid tank 109, and the first flow meter is connected to a monitoring unit for monitoring the flow rate of the reservoir liquid that is reversed at the time of the reversal.
In the embodiment of the present specification, the top cover and the bottom cover of the holder 203 are both connected to the liquid storage tank through pipes, so as to facilitate forward injection or reverse injection of the liquid storage tank. The pipelines for circulating the liquid and the gas can be provided with control valves to control the on/off of the pipelines.
The gas phase injection module 400 comprises a gas storage tank 404, a second intermediate vessel 405, and a second temperature control device 402; the gas storage tank 404 is configured to contain stored gas, and in this embodiment of the present disclosure, the stored gas in the gas storage tank 404 is the same as the gas in the reservoir where the sample is located, so that the gas phase injection module provides a gas phase environment equivalent to the reservoir for the sample.
The second intermediate container 405 is used to connect the gas tank 404 and the clamper 203.
A second temperature control device 402 is connected to the second intermediate container 405 for controlling the reservoir temperature in the second intermediate container 405; that is, in this embodiment of the present specification, the second temperature control device 402 can heat and cool the reservoir gas in the second intermediate container 405, so that the temperature of the reservoir gas injected to the sample 209 matches the temperature environment of the formation where the sample is located, thereby avoiding the influence on the environment caused by the temperature difference between the reservoir gas and the environment where the sample is located, and thus improving the accuracy of the simulation of the gas phase environment where the sample is located and further improving the accuracy of the evaluation of the water lock damage.
In the embodiment of the present specification, the efficiency of temperature control can be improved by controlling the temperature of the reservoir gas in the second intermediate container 405 by the second temperature control device 402; at the same time, the temperature of the gas injected into the holder can be made more uniform. A third temperature sensor 406 is connected to the second intermediate container 405, the third temperature sensor 406 being connected to the test module 300 and the monitoring unit 304, the third temperature sensor 406 being adapted to monitor the temperature of the stored gas injected into the sample 209 in the holder and to transmit it to the monitoring unit.
Preferably, in this embodiment, the gas phase injection module 400 further includes a humidity control device 403;
the humidity control device 403 is disposed between the gas storage tank 404 and the second intermediate container 405, and the humidity control device 403 is configured to perform humidity control on the reservoir gas flowing to the second intermediate container 405, so as to avoid that the humidity of the reservoir gas injected into the holder affects the current water saturation of the sample 209, and affects the water lock damage evaluation test precision. It should be noted that the humidity control device can not only humidify the dry gas, but also dry the high-humidity reservoir gas, so that the humidity of the injected gas is equivalent to that of the gas phase environment of the reservoir where the sample is located.
The gas phase injection module 400 further comprises a second flow meter 407, a second pressure sensor 401, a second pump body 408 and an exhaust gas canister 409; the second pump body 408 is preferably a constant pressure constant flow pump providing pressure for reservoir gas injection into the geological environment simulation module and the waste gas tank 409 is used to collect the waste gas displaced from the holder to avoid environmental pollution.
A second pressure sensor 401 is arranged between the holder and the second intermediate container 405, the second pressure sensor 401 being further connectable to a monitoring unit, the second pressure sensor 401 being adapted to monitor the gas pressure of the reservoir gas injected into the holder at the sample 209.
A second flow meter 407 is arranged between the holder and the offgas tank 409, and the second flow meter 407 may also be connected to a monitoring unit for monitoring the flow rate and velocity of the offgas.
The test module 300 further comprises a power supply 301, and a monitoring unit 304; the power supply 301 is used for supplying power;
the monitoring unit 304 is connected with a first pressure sensor, a second pressure sensor, a first temperature sensor, a second temperature sensor, a third temperature sensor, a first flowmeter and a second flowmeter to obtain various monitoring data;
the monitoring unit 304 is connected with the resistivity testing unit and the acoustic testing unit, and is used for controlling the voltage loaded on the sample by the resistivity testing unit and controlling the acoustic signal of the data of the acoustic testing unit; and the method is also used for determining the water lock damage of the sample under different environments according to the resistivity data and the longitudinal and transverse wave data.
In summary, the water lock damage testing device provided in the embodiments of the present description can accurately simulate the water saturation change condition of the reservoir where the sample is located during fracturing and flowback, obtain resistivity data and longitudinal and transverse wave data corresponding to each water saturation condition through testing, evaluate and test the water lock damage degree of the sample according to the resistivity data and the longitudinal and transverse wave data, and provide support for evaluating the water lock damage condition of the reservoir where the sample is located.
In order to more clearly illustrate the water-lock damage testing device provided by the embodiment of the present specification, a simple description will be given below of a using method of the water-lock damage testing device provided by the embodiment of the present specification and an implementation principle of a sample water-lock damage test.
S10: and determining a curve of sample related parameters, the time difference ratio of longitudinal and transverse sound waves and the water saturation.
S11: and measuring the porosity and the pore volume of the sample. The volume of formation water required for the sample at different water saturations is determined.
S12: the sample is loaded into the holder.
Specifically, as shown in fig. 2, the sample is loaded, the metal connection structure on the top cover is connected with the corresponding test electrode and the acoustic wave receiver, and the power supply electrode and the acoustic wave transmitter are in close contact with the sample. Meanwhile, for better simulating the field situation, the placing direction of the sample in the holder 203 should be consistent with the direction in the actual coal seam.
S13: simulating the temperature and pressure of a reservoir where the sample is located through a geological environment simulation module 200; in particular, the pressure control unit 201 and the temperature control unit 202 can be adjusted according to different pressure and temperature conditions of different depths of the stratum.
S14: quantitative formation water is injected in a forward direction using the liquid injection module 100.
Specifically, the injection direction is divided into forward injection and reverse injection, wherein the forward injection is injection from the upper part of the clamp holder so as to simulate the injection direction of the fracturing fluid; the reverse injection is the injection from the lower part of the clamp holder, and the process of gas recovery by the backflow of the fracturing fluid can be simulated. And quantitatively injecting the injected formation water at the speed of 0.1mL/min, ensuring that the saturation of the water in the sample is 10% after the formation water is injected for the first time, and standing for 30min after the injection is finished so as to uniformly distribute the formation water in the sample.
S15: the resistivity and the longitudinal-transverse sound wave time difference ratio of the sample at the corresponding saturation are obtained by the testing module 300.
Specifically, after the power supply 301 is connected, a test current passes through the multi-core cable, the power supply electrode 205 and the acoustic wave transmitter 207 at the top cover 2032 are energized to load a current to the sample and transmit an acoustic wave, the current and the acoustic wave pass through the sample and are transmitted to the test electrode 206 and the acoustic wave receiving unit 208 on the surface of the rubber sleeve, and the detection module 300 is used for storing the acquired longitudinal-lateral acoustic wave time difference ratio, the resistivity data and the water saturation by 10%.
It should be noted that the specific test is the water lock damage degree of the whole sample, so the analog detection subsystem may only need to record the signals of the fifth group (from top to bottom, i.e. located at the bottom of the sample) of test electrodes and the acoustic receiver. If the water lock damage degree of different parts of the sample needs to be recorded, the electroacoustic signal of the corresponding position is recorded.
And repeating the steps S103 and S104, and injecting a certain amount of formation water forward again by using the liquid phase injection module 100 so that the saturation of the sample is changed and the electroacoustic signal under the corresponding saturation is obtained.
Specifically, the sample is saturated with 20% of formation water at a speed of 0.1mL/min, and the sample is allowed to stand for 30min after saturation, so that the formation water is uniformly distributed in the sample.
And the test module 300 is used again to obtain the time difference ratio of the resistivity and the longitudinal and transverse sound waves of the sample at the current saturation, and the acquired time difference ratio of the longitudinal and transverse sound waves, the resistivity data and the water saturation are stored by 20%.
The above steps are repeated in the same way, and the electroacoustic signals with water saturation of 30%, 40%, 50%, 60%, 70%, 80%, 90%, 100% are measured and recorded in the test module.
The resistivity at this time is resistivity data at the corresponding water saturation as shown in table 1.
TABLE 1
| Water saturation/% | Resistivity/(Ω. m) |
| 10 | 762 |
| 100 | 235 |
The data in table 1 are substituted into the aldrich formula:
Sw＝(ρo/ρt)1/β
wherein is, SwThe water saturation;
ρoresistivity when the medium is completely saturated with water;
ρtis the resistivity of the medium at the current water saturation;
beta is a parameter related to the characteristics of the medium, such as the particle size, compactness and the like of the medium;
β is obtained as 0.5109;
further, an Archie's formula is derived for the current sample:
Sw＝(ρo/ρt)1.95733 (1)
then, a curve of the time difference ratio of the longitudinal and transverse acoustic waves to the water saturation is made according to the time difference ratio of the longitudinal and transverse acoustic waves and the corresponding water saturation, and the data is shown in table 2:
TABLE 2
| Saturation of water | 10％ | 20％ | 30％ | 40％ | 50％ | 60％ | 70％ | 80％ | 90％ | 100％ |
| Longitudinal and transverse acoustic time difference ratio | 0.64 | 0.635 | 0.63 | 0.61 | 0.6 | 0.605 | 0.595 | 0.59 | 0.58 | 0.578 |
A graph of the longitudinal to lateral acoustic wave time difference ratio versus sample water saturation can be fit from the data in table 2 as shown in fig. 5.
The fitting gives the formula:
y＝-13.256x+8.5872 (2)
R2＝0.9504，
wherein, R is a correlation coefficient and is used for expressing the coincidence degree between the test data and the fitting function.
S20: the water saturation of the sample before it is damaged by the water lock is determined.
S21: forward injection of formation water through the liquid phase injection module 100 saturates the sample.
Specifically, the formation water is injected forward at a rate of 0.1mL/min, and the injection is stopped after the first flow meter 106 at the outlet is stabilized.
S22: the stored gas is injected back into the sample through the gas phase injection module 400.
Specifically, for better simulation of the flowback process, the injection pressure of the coal bed gas is equivalent to the pressure injection of the on-site gas, and the injection of the coal bed gas can be stopped when no liquid flows out from the first flowmeter 106 at the outlet end and the gas flow is stable.
S23: the resistivity of the sample at this time is tested by the test module 300 against the longitudinal and transverse acoustic wave time difference ratio.
Specifically, after the power supply 301 is connected, the current passes through the multi-core cable, then the current starts to work through the power supply electrode and the sound wave transmitter on the top cover, so that the sound wave and the current penetrate through the sample, then the test electrode and the sound wave receiver on the surface of the rubber sleeve are used for collecting electric and sound signals, and the electric and sound signals are transmitted to the resistivity test unit 302 and the sound wave test unit 303, and the resistivity and the longitudinal-transverse wave time difference ratio of the sample under the water saturation degree is obtained.
S24: and calculating the first water saturation before the sample water lock damage at the moment by using an Archie formula, and calculating the second water saturation before the sample water lock damage by using a longitudinal and transverse acoustic wave time difference-water saturation fitting formula.
In particular, the current resistivity, ρ, to be measuredt1Substituting 485 Ω · m into equation (1) to obtain a first water saturation of Sw1＝27.09％。
Measuring the current wave length-to-width ratio RΔt1The second water saturation is obtained by substituting the formula (2) with 0.631w1'＝22.26％。
S30: and determining the water saturation of the sample after the sample is damaged by the water lock.
S31: the forward injection of formation water through the liquid phase injection module 100 re-saturates the sample.
Specifically, the formation water is injected into the holder 203 at a forward direction by the liquid phase injection module at a speed of 0.1mL/min, and the injection is stopped after the first flow meter at the outlet is stabilized.
S32: simulating the temperature and pressure of a reservoir where the sample is located through a geological environment simulation module 200;
s33: the fracturing fluid is injected forward through the liquid injection module 100 into the sample.
Specifically, in order to better simulate the damage of the fracturing fluid to the reservoir stratum in the fracturing process and reduce the errors of other factors, the injection speed of the fracturing fluid is controlled to be 0.1mL/min, the injection time is controlled to be 36min and is matched with the size and the pore structure of the sample, and all valves are closed after the injection is finished, so that the fracturing fluid acts on the sample for 2 hours under high pressure.
S34: formation water is injected back into the sample through the liquid phase injection module 100.
Specifically, after the reservoir is fractured and transformed, a water and gas drainage and production process can exist, a large amount of stratum water in the reservoir can firstly flow into a shaft from the reservoir, and therefore the liquid-phase injection module 100 can be used for reversely injecting the stratum water, fracturing fluid in sample pores is displaced out of a sample, the water drainage process can be simulated, redundant fracturing fluid in the sample can be discharged, and errors in subsequent water saturation measurement are reduced. The reverse injection speed of the formation water is 0.1mL/min, and the displacement can be stopped after the first flowmeter at the outlet end is stable.
S35: the stored gas is injected back into the sample through the gas phase injection module 400.
Specifically, the gas phase injection pressure is equal to the field gas pressure, and the gas injection can be stopped when the first flowmeter 106 at the outlet end shows no liquid flowing out and the gas flow is stable.
S36: the resistivity of the sample at this time is measured by the test module 300 against the shear-wave transit time difference.
S37: and (3) calculating the third water saturation and the fourth water saturation of the sample damaged by the water lock at the moment according to the formula (1) and the formula (2).
Specifically, the current resistivity ρ is measuredt2Substituting 431 Ω · m into equation (1) to obtain a third water saturation of Sw2＝30.5％。
The measured current longitudinal and transverse sound wave time difference ratio RΔt2Substituting 0.625 into equation (2) to obtain a fourth water saturation of Sw2' de ═ 30.22%.
S40: the water lock damage was calculated according to the following formula (3), and the degree of influence of the water lock damage on the liquid phase retention was evaluated.
Wherein,
gamma is the water lock damage rate;
the water lock damage rate is calculated to be 23.04%.
In summary, the method highly restores the coal seam fracturing flowback process, and obtains the resistivity and the vertical and horizontal acoustic wave time difference ratio of the sample under different water saturation conditions by using a voltage and acoustic wave test method; determining an Archie formula parameter and a longitudinal and transverse sound wave time difference-water saturation fitting function suitable for the sample, and testing the water saturation of the sample before and after the sample is damaged by water lock; finally obtaining the water saturation damage rate; the evaluation of the water lock damage is more scientific, and the accuracy of the water lock damage simulation is improved.
While the foregoing is directed to embodiments of the present invention, other and further embodiments of the utility model may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow. The present embodiments are, therefore, to be considered in all respects as illustrative and not restrictive. In view of the above, the present disclosure should not be construed as limiting the present disclosure.
Claims (10)
1. A water-lock injury testing device, comprising:
the geological environment simulation module is used for placing a core sample to be tested and providing a simulated geological environment for the sample;
a liquid phase injection module for injecting a liquid into the sample;
a gas phase injection module for injecting gas into the sample;
the test module comprises a resistivity test unit and an acoustic wave test unit, wherein the resistivity test unit is used for loading charges to obtain resistivity data of the sample, and the acoustic wave test unit is used for obtaining longitudinal and transverse wave data of the sample; the test module is connected with the geological environment simulation module, the liquid phase injection module and the gas phase injection module and used for determining water lock damage data of the sample according to resistivity data and longitudinal and transverse wave data measured under different environments.
2. The apparatus of claim 1, wherein the geological environment simulation module comprises:
a holder for placing the sample;
a pressure control unit for pressing the clamper;
a temperature control unit for controlling the temperature of the holder.
3. The apparatus of claim 2, wherein the holder comprises a holder body, a top cover, and a bottom cover, the holder body, the top cover, and the bottom cover enclosing a space for containing the sample;
a rubber sleeve is arranged in the holder and is in contact fit with the inner wall of the holder body, and the sample is placed in the rubber sleeve;
the testing module comprises a rubber sleeve, a testing electrode, a sound wave receiving unit, a power supply electrode and a sound wave transmitter, wherein the rubber sleeve is internally provided with the testing electrode and the sound wave receiving unit, the top cover is provided with the power supply electrode and the sound wave transmitter, and the testing electrode and the power supply electrode as well as the sound wave receiving unit and the sound wave transmitter are connected with the testing module.
4. The apparatus of claim 3, wherein the pressure control unit comprises a confining pressure control subunit and a shaft pressure control subunit, the confining pressure control subunit being connected with the side wall of the holder body, the shaft pressure control subunit being connected with the top cover and/or the bottom cover.
5. The apparatus of claim 2, wherein the liquid phase injection module comprises:
the liquid storage tank is used for accommodating the liquid storage liquid;
a first intermediate container for connecting the liquid storage tank and the holder;
and the first temperature control device is connected with the first intermediate container and is used for heating the first intermediate container.
6. The apparatus of claim 5, wherein the liquid phase injection module further comprises:
the first waste liquid tank is connected with the liquid storage tank;
and the second waste liquid tank is connected with the holder and is used for recovering the waste liquid storage and collection liquid in the holder.
7. The apparatus of claim 6, wherein the liquid phase injection module further comprises:
the first pump body is connected with the liquid storage tank and is used for pumping the liquid storage in the liquid storage tank into the clamp holder;
and the first flow meter is connected with the test module and the second waste liquid tank and is used for monitoring the flow of the liquid storage and collection returned to the second waste liquid tank.
8. The apparatus of claim 2, wherein the gas phase injection module comprises:
the gas storage tank is used for containing stored gas;
a second intermediate container for connecting the gas storage tank with the holder;
and the second temperature control device is connected with the second intermediate container and is used for heating the stored gas in the second intermediate container.
9. The apparatus of claim 8, wherein the gas phase injection module further comprises:
and the humidifying device is arranged between the air storage tank and the second intermediate container and is used for humidifying the reservoir air flowing to the second intermediate container.
10. The apparatus of claim 7, wherein the test module comprises:
and the monitoring unit is connected with a first pressure sensor, a first temperature sensor and a second flowmeter, the first pressure sensor is connected with the pressure control unit, and the first temperature sensor is connected with the temperature control unit.
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