Testing device and method for measuring oil, gas and water contents in rock

Abstract

A testing device for measuring oil, gas and water contents in a rock, comprising: a thermal desorption unit (400), comprising a sample chamber (105) used for placing a rock sample (106) under test, a crushing mechanism provided in the sample chamber (105), and a heating mechanism (121), wherein the thermal desorption unit (400) can perform closed crushing and heating on the rock sample (106) to achieve gas analysis and desorption analysis of contained oil and water, so that components to be measured are obtained; a cold trap collection unit (110) communicated with the sample chamber (105) and used for trapping oil and water in the components to be measured and performing separation to obtain primarily separated components to be measured; a light hydrocarbon trapping unit (113) communicated with the cold trap collection unit (110) and used for trapping light hydrocarbons in said primarily separated components and performing separation to obtain secondarily separated components to be measured; a gas metering unit (300) communicated with the light hydrocarbon trapping unit (113) and used for measuring and calculating the volume of gas; and a central control unit (120) for controlling the testing device. Further provided is a testing method for measuring oil, gas and water contents in a rock.

Description

Testing device and method for detecting oil, gas and water content in rocks

[0001] Cross-references to related art

[0002] This application claims the benefit of Chinese patent application 202210806887.8, filed on July 8, 2022, entitled “Device for detecting oil, gas and water content in rocks and its application,” the entire contents of which are incorporated herein by reference. Technical Field

[0003] The present invention belongs to the technical field of oil and gas exploration and development, and in particular relates to a testing device and method for detecting the oil, gas and water contents in rocks. Background Art

[0004] Rocks are the carriers of oil, gas, and water. Accurately determining the content and composition of these oil, gas, and water is crucial for both oil and gas exploration and development, as well as environmental protection. Accurately determining the content and composition of these oil, gas, and water in rocks provides direct evidence for evaluating their oil and gas potential and their mobility, guiding the selection of oil and gas field formations and the formulation of development plans. In the field of environmental protection, the content and composition of oil, gas, and water in soils can provide a scientific basis for environmental governance decisions.

[0005] Methods for analyzing oil content in rocks are primarily categorized into solvent extraction and pyrolysis. Solvent extraction involves either powder or plug (block) extraction. Pyrolysis also involves both powder and block gas elution. For both solvent extraction and pyrolysis, the powder sample method is the most widely used, with corresponding national and industry standards established. For example, SY / T 5118 defines the method for "Determination of Chloroform-Based Bitumen in Rocks" and GB / T 18602 defines the method for "Pyrolysis Analysis of Rocks." Solvent extraction primarily utilizes a Soxhlet extractor, while rock pyrolysis primarily utilizes various pyrolyzers, such as the French ROCK-EVAL, the American HAWK, and domestic oil-producing rock evaluation instruments. Oil content testing of bulk rock samples is rare. The oil washing experiments that have been conducted primarily analyze the porosity of bulk rock samples, and the quantitative results of oil washing can directly indicate the oil content of the rock. For example, the core oil washer disclosed in CN104668233A uses a solvent to dissolve and extract soluble organic matter in the rock. The eluent is distilled and cooled, and then the solvent is repeatedly recycled. After the solvent evaporates, the rock can be weighed to obtain the oil content.

[0006] With the increasing demand for shale gas exploration and development, the analysis methods for rock gas content have developed rapidly, resulting in a large number of shale gas content analysis technologies and devices. A more representative example is CN10468076A, which discloses a shale gas content testing device and testing method. The main principle is to use a combined crushing tool in a closed chamber to crush and degas the core sample, so as to achieve the purpose of quickly obtaining the rock gas content. Another example is CN104155206A, which discloses a rock gas content measuring device and a method for measuring the rock gas content using the same. The main principle is to use a heating method to desorb the gas in the rock, and use a drainage gas collection method to automatically measure the gas volume. Gas analysis in soil mostly uses thermal desorption capture technology and molecular sieve cold capture technology.

[0007] There are many methods for analyzing the moisture content of substances. Analyzing the moisture content of rocks or soil primarily falls into two categories: distillation and electrical measurement. Distillation is widely used. For example, CN2061146866U discloses a soil moisture measurement device that uses a combination of multiple drying cycles and an electronic scale to determine the moisture content. CN207586066U also discloses a core moisture meter that uses a retort to heat the core. The resulting gas and liquid are then collected through a cooling system and separated into oil and water to measure the water content. Electrical measurement methods are also widely used in soil moisture determination, but are rarely used in rock moisture determination. Representative applications include: CN109459333A discloses a portable soil moisture and bulk density measurement device and method. The principle is to utilize the different propagation speeds of electromagnetic waves in different media. By placing UWB sensors on both sides of the object to be measured, the electromagnetic waves released by the UWB sensors pass through the soil, and the moisture content in the soil is linearly related to the data measured by the UWB sensors. CN211856430U discloses a soil moisture tester. The principle of this instrument is to insert two probes into the soil to measure the internal conductivity and thus obtain soil moisture information.

[0008] The above analysis demonstrates that while numerous analytical devices and methods exist for determining rock oil, gas, and water content, these are relatively independent. Determining the oil, gas, and water content of rock samples requires separate testing using multiple, separate experimental devices. Due to the volatile nature of gas, light hydrocarbons, and water, coupled with sample heterogeneity, combining multiple methods can lead to inconsistent analytical results, increasing uncertainty in geological interpretation.

[0009] Summary of the Invention

[0010] In response to the above-mentioned technical problems, the present invention aims to provide a testing device and method for detecting the oil, gas and water content in rocks.

[0011] To this end, according to a first aspect of the present invention, a testing device for detecting the oil, gas and water content in rocks is provided, comprising: a heating and desorption unit, which includes a sample chamber for placing a rock sample to be tested, a crushing mechanism arranged in the sample chamber, and a heating mechanism, wherein the heating and desorption unit can perform closed crushing and heating on the rock sample to achieve gas analysis and desorption analysis of the oil and water contained therein, thereby obtaining the components to be tested; a cold trap collection unit connected to the sample chamber, for capturing the oil and water in the components to be tested, and capable of separating them to obtain primary separated components to be tested; a light hydrocarbon capture unit connected to the cold trap collection unit, for capturing the light hydrocarbons in the primary separated components to be tested, and capable of separating them to obtain secondary separated components to be tested; a gas metering unit connected to the light hydrocarbon capture unit, for measuring and calculating the gas volume; and a central control unit for controlling the testing device.

[0012] In one embodiment, the gas metering unit includes a liquid storage tank, at least one metering tube connected to the liquid storage tank, a magnetostrictive component disposed inside the metering tube, and a magnetostrictive detection component. The magnetostrictive component is configured to generate a magnetostrictive effect and twist when gas is introduced into the metering tube and the liquid level in the metering tube changes. The magnetostrictive detection component is configured to generate a starting pulse and a corresponding return pulse based on the twisting of the magnetostrictive component, thereby calculating the liquid displacement and, thereby, the gas volume.

[0013] In one embodiment, the magnetostrictive assembly includes: a measuring rod, which is vertically arranged inside the metering tube; a magnetostrictive wire, which is arranged inside the measuring rod, and a rotating magnetic field is generated when the starting pulse generated by the magnetostrictive detection assembly moves along the magnetostrictive wire; and a movable magnetic floating ring, which is sleeved on the outside of the measuring rod and can move according to changes in the liquid level, and is used to generate a magnetostrictive effect when encountering the rotating magnetic field.

[0014] In one embodiment, a pressure sensor and a temperature sensor are further provided inside the metering tube.

[0015] In one embodiment, the sample chamber is configured to include a can body and a crushable can cover, wherein the crushable can cover is sealedly connected to the can body via a first sealing filler.

[0016] In one embodiment, the crushing mechanism includes a primary crushing unit connected to the crushing tank cover and a secondary crushing unit arranged in the tank body and at the bottom. The primary crushing unit can impact and crush the rock sample to obtain a gravel sample, and the secondary crushing unit can grind and crush the gravel sample.

[0017] In one embodiment, the primary crushing unit includes a push rod, a weight connected to the lower end of the push rod, an energy storage element arranged on the push rod, and a drive assembly, wherein the upper end of the push rod extends outward through the crushing tank cover and is connected to the drive assembly, wherein the weight can be lifted by the handle and the energy storage element can be released after storing energy, so that the weight can generate impact force to crush the rock sample.

[0018] In one embodiment, the push rod forms a dynamic seal with the crushing tank cover through a dynamic sealing assembly, the dynamic sealing assembly includes a sealing fixing seat and a pneumatic sealing ring installed on the sealing fixing seat, the sealing fixing seat passes through the central area of ​​the crushing tank cover, and the push rod forms a dynamic seal with the crushing tank cover through the pneumatic sealing ring.

[0019] In one embodiment, the secondary crushing unit includes a vibrating plate, grinding balls disposed on the vibrating plate, and an electromagnetic vibrator for driving the vibrating plate. The vibrating plate can work together with the grinding balls to grind and crush the gravel sample.

[0020] In one embodiment, a heat insulation plate is further fixed in the tank body, the heat insulation plate is connected to the bottom of the crushing tank cover through a fixing rod, the push rod passes through the heat insulation plate, and a dynamic seal is formed between the push rod and the heat insulation plate through a second sealing filler.

[0021] In one embodiment, the cold trap collection unit includes: a cold trap collection mechanism for collecting oil and water in the components to be tested; and a low-temperature cold trap for providing a low-temperature environment for the cold trap collection mechanism, wherein the cold trap collection mechanism is arranged inside the low-temperature cold trap.

[0022] In one embodiment, the cold trap capture mechanism includes a first capture tube and a sealing cover for sealing the first capture tube, the sealing cover is provided with an air inlet and an air outlet, the air inlet is connected to the sample chamber, and the air outlet is connected to the light hydrocarbon capture unit.

[0023] In one embodiment, the air inlet is provided with an injection cannula, which extends to the interior of the first collecting tube and close to the bottom, and is used to pass the component to be tested into the bottom of the collecting tube. The ratio of the length of the injection cannula extending into the interior of the first collecting tube to the length of the first collecting tube is 1:1.5-1:1.2.

[0024] In one embodiment, the first collecting tube is connected to the sample chamber via a temperature-controllable heating auxiliary heating line, and the inner wall of the auxiliary heating line is subjected to a passivation anti-adsorption treatment.

[0025] In one embodiment, the invention further comprises a gas delivery unit communicated with the sample chamber, for delivering the components to be detected remaining in the sample chamber into the cold trap collection unit and the light hydrocarbon capture unit.

[0026] In one embodiment, the gas delivery unit is connected to the sample chamber through a first gas pipeline, the cold trap collection unit is connected to the gas metering unit through a second gas pipeline, the light hydrocarbon capture unit is connected to the second gas pipeline, and a flow meter is provided between the light hydrocarbon capture unit and the gas metering unit for use with the gas delivery unit to control the flow of the carrier gas in the testing device.

[0027] In one embodiment, the light hydrocarbon capture unit includes a second capture tube filled with adsorption material.

[0028] In one embodiment, the invention further comprises a cold air delivery unit connected to the sample chamber, for delivering cold air into the sample chamber.

[0029] According to a second aspect of the present invention, there is provided a testing method for detecting the oil, gas and water content in rocks, comprising the following steps:

[0030] Step 1: Provide the test device as described above;

[0031] Step 2: Weigh the weight of the first collecting tube in the cold trap collection unit and the second collecting tube in the light hydrocarbon collecting unit respectively;

[0032] Step 3: controlling the heating and desorption unit and the cold trap collection unit to corresponding first predetermined temperatures through the central control unit to form a gas metering and oil-water capture test environment;

[0033] Step 4: placing the rock to be tested into the sample chamber;

[0034] Step 5: Recording the volume of gas collected by the gas metering unit until the volume of gas in the gas metering unit no longer increases, wherein the volume is recorded at predetermined intervals, and after the predetermined time, the heating and desorption unit is heated in stages;

[0035] Step six: adjusting the carrier gas flow rate in the test device to a predetermined flow rate, and controlling the heating desorption unit and the cold trap collection unit to a corresponding second predetermined temperature through the central control unit (120) to form an oil-water capture test environment;

[0036] Step 7: Reweigh the first collecting tube and the second collecting tube, and perform calculation and analysis to obtain the oil, gas and water contents in the rock to be tested.

[0037] In one embodiment, in step three, the predetermined temperature of the heating desorption unit is 60°C-110°C, and the predetermined temperature of the cold trap collection unit is -20°C-10°C. In step six, the predetermined flow rate is 10-30 mL / min, the predetermined temperature of the heating desorption unit is 60°C-350°C, and the predetermined temperature of the cold trap collection unit is -20°C-10°C.

[0038] In one embodiment, in step five, each time the heating desorption unit is heated, the temperature is maintained constant until the volume of the gas in the gas metering unit no longer increases, and then the carrier gas is transported into the sample chamber through the gas delivery unit to deliver the components to be detected remaining in the sample chamber into the cold trap collection unit and the light hydrocarbon capture unit.

[0039] Compared with the prior art, the advantages of this application are:

[0040] The testing device for detecting the oil, gas, and water content in rock, according to the present invention, uses a sequentially connected cold trap collection unit, a light hydrocarbon capture unit, and a gas metering unit to capture the components to be tested. This allows simultaneous oil, gas, and water measurements on full-diameter core samples of a certain thickness at the drilling site, thereby simultaneously determining the oil, gas, and water content in the rock. Furthermore, the device can be combined with the rock gas analysis curve to recover lost gas volume. This testing device eliminates the loss of gas, light hydrocarbons, and water during the experiment, improving work efficiency while overcoming the poor data matching issues associated with existing methods. This provides scientific data for evaluating rock oil and gas content and mobility. BRIEF DESCRIPTION OF THE DRAWINGS

[0041] The present invention will be described below with reference to the accompanying drawings.

[0042] FIG1 schematically shows the structure of a testing device for detecting the oil, gas and water contents in rocks according to the present invention.

[0043] FIG. 2 schematically shows the structure of a heating and desorption unit in a sample chamber of the testing device shown in FIG. 1 .

[0044] FIG3 schematically shows the structure of the crushed can cover in the heating and desorption unit shown in FIG2 .

[0045] FIG. 4 schematically shows the structure of the first collecting tube in the testing device shown in FIG. 1 .

[0046] FIG5 is a schematic diagram of the scale lines and the sealing cover on the first collecting tube shown in FIG4 .

[0047] FIG6 schematically shows the structure of the gas metering unit in the testing device shown in FIG1 .

[0048] In this application, all drawings are schematic drawings, which are only used to illustrate the principles of the present invention and are not drawn to scale. DETAILED DESCRIPTION

[0049] The present invention is described below with reference to the accompanying drawings. It should be noted that these descriptions are only provided for illustrating the principles of the present invention and are not intended to limit the scope of the present invention.

[0050] Figure 1 schematically shows the structure of a testing device 100 for oil, gas and water content in rocks according to the present invention. As shown in Figure 1, the testing device 100 includes a central control unit 120, and a heating and desorption unit 400, a cold trap collection unit 110, a light hydrocarbon capture unit 113, and a gas metering unit 300 connected in sequence. The heating and desorption unit 400 is used to heat the rock sample 106 to obtain the components to be tested. The cold trap collection unit 110 is used to capture the oil and water in the components to be tested, and separate them to obtain the primary separated components to be tested. The light hydrocarbon capture unit 113 is used to capture the light hydrocarbons in the primary separated components to be tested, and separate them to obtain the secondary separated components to be tested. The gas metering unit 300 is used to measure the amount of gas in the secondary separated components to be tested. The central control unit 120 is used to control the opening and closing of the testing device 100.

[0051] The light hydrocarbons referred to in the present invention are: 14 of hydrocarbon components.

[0052] According to the present invention, as shown in Figures 1 and 2, the heating and desorption unit 400 includes a sample chamber 105 for placing a rock sample 106, a crushing mechanism disposed within the sample chamber 105, and a heating mechanism 121. The heating and desorption unit 400 is capable of performing closed crushing and heating on the rock sample 106 to achieve gas desorption and desorption analysis of the contained oil and water, thereby obtaining the components to be tested.

[0053] As shown in Figure 2, the sample chamber 105 comprises a can body 4 and a crushing can lid 2. The crushing can lid 2 and the can body 4 are sealed by a first sealing filler. This creates a sealed environment within the can body 4. Preferably, an outer annular groove is provided at the bottom end of the crushing can lid 2. The first sealing filler is embedded in the outer annular groove to seal the crushing can lid 2 and the can body 4. Furthermore, preferably, the first sealing filler can be, for example, an O-ring.

[0054] The crushing mechanism includes a primary crushing unit connected to the crushing tank cover 2 and a secondary crushing unit arranged at the bottom of the tank body 4. The primary crushing unit can impact-crush the rock sample 106 to obtain a gravel sample, and the secondary crushing unit can grind and crush the gravel sample to achieve secondary crushing of the rock to be crushed.

[0055] According to one embodiment of the present invention, as shown in FIG2 , the primary crushing unit includes a push rod 8, a weight 7 connected to the lower end of the push rod 8, an energy storage element 5 provided on the push rod 8, and a drive assembly 1. The weight 7 is provided inside the tank body 4, and the weight 7 is provided in a conical cylindrical form and has a certain weight. The primary crushing unit can move up and down so that the weight 7 can hammer the rock to be crushed. The upper end of the push rod 8 extends outward through the crushing tank cover 2 and is connected to the drive assembly 1. At the same time, the push rod 8 is slidingly sealed and fitted with the crushing tank cover 2. The drive assembly 1 can lift the weight 7 and store energy in the energy storage element 5, thereby releasing the weight 7, so that the weight 7 can generate an impact force under the action of its own gravity and the energy storage element 5 to crush the rock sample 106.

[0056] The energy storage element 5 is preferably a weight spring sleeved on the push rod 8. The bottom end of the weight spring is fixed to the weight 7, and the top end of the weight spring 5 is in contact with a heat shield 9 (see below).

[0057] The driving assembly 1 is a manual driving assembly, for example, it can be a handle. When working, the staff can operate the handle 1 to drive the push rod 8 to move. Of course, the driving assembly 1 can also be an electric driving assembly. For example, the electric driving assembly includes a wire rope connected to the handle and a motor, a fixed pulley, and a winding roller for driving the wire rope to move. The wire rope is wound on the fixed pulley, and one end of the wire rope is connected to the winding roller. The winding roller is driven by the motor, and then the motor can drive the wire rope to rise, so that the energy storage element 5 and the weight gain potential energy. Then the motor stops, and the potential energy of the weight and the energy storage element 5 is converted into kinetic energy of the weight, which impacts the rock core and breaks the rock core.

[0058] In one embodiment, as shown in Figure 3, a dynamic seal is formed between the push rod 8 and the crushing tank cover 2 via a dynamic seal assembly. The dynamic seal assembly includes a seal holder 15 and a pneumatic seal ring 16 mounted on the seal holder 15. The seal holder 15 extends through the center of the crushing tank cover 2, and the push rod 8 forms a dynamic seal with the crushing tank cover 2 via the pneumatic seal ring 16. Specifically, a groove is defined at the center of the upper end surface of the crushing tank cover 2, into which the seal holder 15 is inserted. The pneumatic seal ring 16 is disposed within the seal holder 15 and forms a sliding seal with the push rod 8. Thus, the dynamic seal assembly ensures a tight seal between the crushing tank cover 2 and the push rod 8.

[0059] According to one embodiment of the present invention, the secondary crushing unit includes a vibrating plate disposed at the bottom end of the tank body 4, a plurality of grinding balls 6 disposed on the vibrating plate, and an electromagnetic vibrator for driving the vibrating plate. The grinding balls 6 are capable of moving under the action of the electromagnetic vibrator to grind and crush the gravel sample. The grinding balls 6 are preferably magnets. When the electromagnetic vibrator inputs a set of alternating current signals, the coil inside the electromagnetic vibrator generates a corresponding alternating magnetic field, while the polarity of the magnet remains fixed. Therefore, under the action of the alternating magnetic field, the permanent magnets of the grinding balls 6 will undergo violent movement, moving up, down, left, and right, thereby grinding the rock to be crushed.

[0060] Since the gas desorption process in the shale rock is carried out in a heated environment in the tank body 4, and if the tank body is directly set up, there will be a situation where hot gas exchanges heat with the outside world, causing some hot gas to condense on the inner wall of the tank structure when it is cold, reducing the accuracy of subsequent gas collection. Therefore, a heat insulation board 9 is also provided inside the tank body 4. As shown in Figure 2, the heat insulation board 9 is fixedly installed in the tank body 4. The heat insulation board 9 is connected to the lower end of the crushing tank cover 2 through a fixing rod 10 and is spaced apart from the crushing tank cover 2. A through hole is provided in the middle of the heat insulation board 9, and a push rod 8 passes through the through hole. A second sealing filler is provided between the push rod 8 and the heat insulation board 9 to form a dynamic seal. A stepped groove is provided inside the tank body 4, and the heat insulation board 9 is clamped and arranged above the stepped groove and is sealed with the inner wall of the tank body 4 through a third sealing filler. In one embodiment, the second sealing filler and the third sealing filler can be, for example, graphite soft filler.

[0061] Preferably, the bottom end of the crushing tank cover 2 is provided with three circular grooves, each of which houses a heat shield fixing rod 10. These rods 10 are used to secure the heat shield 9. The heat shield 9 provides both sealing and thermal insulation. Furthermore, in addition to the inherent sealing function of the tank body 4, the heat shield 9 provides a secondary seal for the tank structure, significantly enhancing the measurement of rock desorption products.

[0062] In one embodiment, the tank body 4 is cylindrical, which facilitates the placement of the heating mechanism 121 around the periphery of the tank body 4. Preferably, the heating mechanism 121 is arranged in a wrapped manner around the periphery of the tank body 4. The heating mechanism 121 can be, for example, a ceramic heating plate arranged around the periphery of the tank body 4. Preferably, the heating assembly can use three ceramic heating plates, one wrapped around the side, one placed at the bottom, and one placed at the top, to provide overall heating and accurate temperature control.

[0063] According to the present invention, as shown in FIG2 , the side wall of the tank body 4 is provided with an air inlet 42 and an exhaust hole 43 extending therethrough. Specifically, the air inlet 42 and the exhaust hole 43 are relatively arranged on the side of the tank body 4. The line connecting the air inlet 42 and the exhaust hole 43 passes through the axial center position. In the embodiment shown in FIG2 , two air inlet holes 42 are provided at intervals along the height direction of the tank body 4, and the upper air inlet 42 is correspondingly located below the heat insulation board 9 and close to the heat insulation board 9, while the lower air inlet 42 is close to the bottom of the tube body 4. At the same time, two exhaust holes 43 are provided at intervals along the height direction of the tank body 4, and are distributed relative to the two air inlet holes 42.

[0064] The air inlet 42 is connected to the purge system, through which the oil, gas, and water desorbed from the rock in the tank body 4 can be purged and transported. The exhaust hole 43 is connected to the oil-water cold trap collection system, the light hydrocarbon capture system, and the gas metering and collection system, thereby collecting the oil, gas, and water desorbed from the rock. In this way, the oil, gas, and water in the sample chamber 105 can be blown out without dead angles and transported to the oil-water cold trap collection system, the light hydrocarbon capture system, and the gas metering and collection system, which is conducive to improving the accuracy of the test results. The sample chamber 105 can be directly loaded with a full-diameter core sample of a certain thickness at the drilling site. Under the experimental temperature conditions, there is no gas leakage, and there is no dead volume for the carrier gas to enter and flow out.

[0065] In one embodiment, anti-blocking filters (not shown) are provided at the air inlet 42 and the air outlet 43, respectively, to filter dust. An air inlet pipe is connected to the air inlet 42, and an exhaust pipe is connected to the exhaust 43. The air inlet pipe allows nitrogen to flow in, and the exhaust pipe allows oil, gas, and water to be discharged. A one-way valve is provided on each of the air inlet and exhaust pipes to prevent gas from desorbing rock from entering the air inlet pipe and prevent gas from entering the exhaust pipe and flowing back into the tank 4.

[0066] Preferably, the diameter of the grinding ball 6 is larger than the inner diameter of the air inlet hole 42 and the exhaust hole 43, and the setting position of the air inlet hole 42 and the exhaust hole 43 is higher than the position of the grinding ball 6, thereby preventing the grinding ball 6 from clogging the air inlet hole 42 and the exhaust hole 43.

[0067] The specific working process of the heating and desorption unit 400 is briefly described below:

[0068] First, the rock to be crushed is loaded into tank 4 and sealed. The process for loading the rock into tank 4 is as follows: The crushing tank cover 2 is opened and the rock to be crushed is placed inside tank 4. Then, the crushing tank cover 2 is placed on top of tank 4, creating a primary seal between the crushing tank cover 2 and tank 4. Furthermore, a heat shield 9 is enclosed within tank 4, providing a secondary seal. This creates a two-stage seal within tank 4, effectively preventing oil, gas, and water desorption products from the core from escaping from tank 4 and affecting detection accuracy when the core is subsequently heated.

[0069] The crushing mechanism then hammers the rock to be crushed, breaking the core. The specific process is as follows: the motor drives the wire rope upward, causing the weight spring and weight to gain potential energy. The motor then stops, and the potential energy of the weight and weight spring is converted into kinetic energy by the weight, which impacts the rock core, breaking it. Alternatively, by operating handle 1, which drives push rod 8 up and down, the weight impacts the rock core, breaking it.

[0070] Afterwards, when the crushing mechanism hammers the rock to be crushed, the grinding balls cooperate with the heavy hammer 7 to further crush the rock core. When the heavy hammer 7 hammers the rock to be crushed, an extrusion force is generated between the rock to be crushed and the grinding balls. Then, when the heavy hammer 7 hammers the rock to be crushed, under the action of the vibrating disk, small pieces of gravel are scattered around and large pieces of gravel move toward the center. At the same time, the grinding balls continuously hammer the gravel to grind it.

[0071] Afterwards, the electromagnetic vibrator drives the grinding balls to grind the broken rock core, achieving the purpose of secondary crushing of the rock core, grinding the gravel to 60-100 mesh, and realizing integrated crushing.

[0072] Afterwards, the exhaust port 43 is opened, the tank structure is heated by the ceramic heating plate, and the core desorbed gas is collected by the gas metering and collection system. During this process, the desorbed gas generated inside the tank 4 enters the gas metering and collection system, where it is collected and measured.

[0073] Then, the inlet 42 and the outlet 43 are opened, and an inert gas is introduced into the tank structure through the inlet 42. The inert gas sweeps the core desorption products into the oil-water cold trap collection system for oil and water collection. The inert gas in the present invention can be nitrogen, which does not mix with oil or water.

[0074] Since the heavy hammer 7 will cause rocks to scatter when hammering the rocks to be crushed, the heat insulation plate 9 provided in the present invention can block the rocks and prevent the splashing rocks from damaging the crushing tank cover 2.

[0075] According to the present invention, as shown in Figure 1, the cold trap collection unit 110 includes a cold trap capturing mechanism 109 and a low-temperature cold trap 110a. The cold trap capturing mechanism 109 is arranged inside the low-temperature cold trap 110a. The cold trap capturing mechanism 109 is used to capture oil and water in the components to be tested, and the low-temperature cold trap 110a is used to provide a low-temperature environment for the cold trap capturing mechanism 109.

[0076] In the present invention, there is no particular limitation on the low-temperature cold trap 110 a , as long as the low-temperature cold trap 110 a can provide a low-temperature environment for the cold trap capturing mechanism 109 . Preferably, the low-temperature cold trap 110 a is selected from an electric refrigeration cold trap.

[0077] Preferably, as shown in Figures 4 and 5 , the cold trap capture mechanism 109 includes a first capture tube 201, a sealing cap 203 that seals the first capture tube 201, an air inlet 205 and an air outlet 204 provided on the sealing cap 203, and an injection cannula 202 connected to the air inlet 205 and extending into the interior of the first capture tube 201. A sealing ring 206 is provided between the sealing cap 203 and the first capture tube 201, thereby sealing the first capture tube 201. The air inlet 205 is used to communicate with the sample chamber 105, and the air outlet 204 is used to communicate with the light hydrocarbon capture unit 113.

[0078] According to the present invention, the injection cannula 202 extends into the interior of the first collecting tube 201 and near the bottom, and is used to pass the components to be tested into the bottom of the first collecting tube 201. The ratio of the length of the injection cannula 202 extending into the interior of the first collecting tube 201 to the length of the first collecting tube 201 is 1:1.5-1:1.2.

[0079] In the present invention, by regulating the ratio of the distance that the injection cannula 202 extends into the interior of the first collecting tube 201 to the length of the first collecting tube 201, the residence time of the component to be detected in the first collecting tube 201 can be increased. At the same time, it can be prevented that the component to be detected that enters later will enter the component to be detected in the first collecting tube 201 before the component to be detected, and it can be prevented that the airflow carries condensed water and oil out of the first collecting tube 201, resulting in detection errors.

[0080] According to the present invention, the light hydrocarbon capture unit 113 includes a second capture pipe 113 a , and the second capture pipe 113 a is filled with adsorption material.

[0081] In the present invention, there is no special limitation on the second collecting tube 113a. The second collecting tube 113a is filled with adsorption material, which only allows inorganic gases and gaseous hydrocarbons to pass through at room temperature, and captures light hydrocarbons with carbon numbers above C5. Under high temperature conditions, the light hydrocarbons captured in the collecting tube can be desorbed, and the collecting tube can be activated and reused.

[0082] According to the present invention, the testing device 100 further includes a gas delivery unit 101. The gas delivery unit 101 is connected to the thermal desorption unit 400 and is used to deliver the residual components to be detected in the testing device 100 to the cold trap collection unit 110 and the light hydrocarbon capture unit 113. It should be noted that the gas delivery unit 101 herein is the purge system connected to the gas inlet 42 described above. For example, the gas delivery unit 101 can be connected to the sample chamber 105 via a first gas line 103.

[0083] The gas in the gas delivery unit 101 is nitrogen, helium or the like. The present invention does not impose any particular limitation on the gas used here, as long as it does not interfere with the detection of the corresponding substance in the component to be detected.

[0084] During the detection process, a certain amount of components to be detected will remain in the test device 100. The gas is delivered to the device through the gas delivery unit 101, which can serve as a carrier gas to purge the thermal desorption products into the subsequent cold trap capture unit 110, light hydrocarbon capture unit 113, etc., and can further improve the detection accuracy of the test device 100.

[0085] According to the present invention, the testing device 100 further includes a flow meter 115, which is disposed between the light hydrocarbon capture unit 113 and the gas metering unit 300. The flow meter 115 cooperates with the gas delivery unit 101 to control the flow rate of the carrier gas within the testing device 100. As shown in FIG1 , the cold trap collection unit 110 and the gas metering unit 300 are connected via a second gas pipeline 111, to which the light hydrocarbon capture unit 113 is connected. The flow meter 115 is disposed between the light hydrocarbon capture unit 113 and the gas metering unit 300 via a connecting pipe.

[0086] Preferably, the flow meter 115 is selected from a float flow meter.

[0087] According to the present invention, the testing device 100 further includes a cold air delivery unit 122. The cold air delivery unit 122 is in communication with the sample chamber 105 of the heating-desorption unit 400 and is configured to deliver cold air to the heating-desorption unit 400. By delivering cold air to the heating-desorption unit via the cold air delivery unit 122, the temperature in the sample chamber 105 can be reduced in a relatively short period of time, facilitating the testing of the next sample and improving testing efficiency.

[0088] According to the present invention, the pipeline connecting the heating and desorption unit 400 and the cold trap collection unit 110 is the auxiliary heating line 108. Specifically, as shown in Figure 1, the first collection tube 201 is connected to the sample chamber 105 via the auxiliary heating line 108. Preferably, the inner wall of the auxiliary heating line 108 has been passivated and treated to prevent adsorption. By setting the pipeline between the heating and desorption unit 400 and the cold trap collection unit 110 as the auxiliary heating line 108, it is possible to prevent the residue of the detected component in the pipeline, thereby improving the accuracy of the detection.

[0089] According to the present invention, the central control unit 120 is respectively connected to the heating desorption unit 400, the cold trap collection unit 110 and the gas metering unit 300 through the central control line 119, and is used to control the signals of the heating desorption unit 400, the cold trap collection unit 440 and the gas metering unit 300.

[0090] As shown in Figure 6, the gas metering unit 300 includes a liquid storage tank 301, at least one metering tube 309 connected to the liquid storage tank 301, a magnetostrictive assembly disposed within the metering tube 309, and a magnetostrictive detection assembly. The magnetostrictive assembly is designed to produce a magnetostrictive effect and twist when gas is introduced into the metering tube 309 and the liquid level within the tube 309 changes. The magnetostrictive detection assembly generates a starting pulse and, based on the twisting of the magnetostrictive assembly, generates a corresponding return pulse, thereby calculating the liquid displacement and, therefore, the gas volume.

[0091] The magnetostrictive assembly includes a measuring rod 312, a magnetostrictive wire, and a movable magnetic ring 311. The measuring rod 312 is vertically positioned within the metering tube 309. The magnetostrictive wire is positioned within the measuring rod 312. The starting pulse generated by the magnetostrictive detection assembly travels along the magnetostrictive wire, generating a rotating magnetic field. The movable magnetic ring 311 is sleeved around the measuring rod 312 and moves according to changes in the liquid level, generating a magnetostrictive effect when it encounters the rotating magnetic field.

[0092] According to the present invention, at least one metering tube 309 is provided, each of which is in communication with the liquid storage tank 301, capable of supplying liquid 310 through the liquid storage tank 301 or returning liquid to the liquid storage tank 301. As shown in FIG6 , a metering tube base 308 is provided at the bottom of the metering tube 309, and a sealing cover 318 is provided at the top of the metering tube 309. The sealing cover 318 effectively seals the metering tube 309 to prevent the gas inside the metering tube 309 from escaping.

[0093] Liquid storage tank 301 is used to hold liquid. When metering tube 309 is draining and collecting gas, the liquid in metering tube 309 returns to liquid storage tank 301. Before metering tube 309 needs to drain and collect gas again, liquid can be added to metering tube 309 through liquid storage tank 301 to facilitate the next drain and collection operation.

[0094] Specifically, a liquid inlet pipe 302 and a liquid return pipe 305 are connected between the liquid storage tank 301 and the metering pipe 309. A liquid inlet pump 303 and a liquid inlet valve 304 are provided on the liquid inlet pipe 302. A proportional one-way speed regulating valve 306 and a liquid return pump 307 are provided on the liquid return pipe 305. The controlled ends of the liquid inlet pump 303, the liquid inlet valve 304, the proportional one-way speed regulating valve 306 and the liquid return pump 307 are respectively connected to the output end of the central control unit 120.

[0095] When liquid needs to be added, the central control unit 120 controls the liquid inlet valve 304 to open, starts the liquid inlet pump 303, and controls the proportional one-way speed regulating valve 306 to close, so that the liquid inlet pump 303 pumps the liquid in the liquid storage tank 301 into the metering pipe 309. When the metering pipe 309 is performing a drainage and gas collection operation, the central control unit 120 controls the liquid inlet valve 304 to close and controls the proportional one-way speed regulating valve 306 to open, so that the liquid in the metering pipe 309 can flow back to the liquid storage tank 301.

[0096] The air intake assembly is disposed on the metering tube 309 and can input gas into the metering tube 309. The controlled end of the air intake assembly is connected to the output end of the central control unit 120. The air intake assembly includes an air intake line 313 and an air intake valve 314.

[0097] Because the gas generated during the desorption process of shale contains a certain amount of water, passing the water-containing gas into the metering tube 309 for gas metering will affect the gas metering accuracy. However, the present invention connects one end of the air inlet line 313 to the top of the metering tube 309 and the other end to the oil-water separation device. The heating desorption unit 400 is used to heat the shale, so that the gas in the shale is desorbed, and the desorbed gas enters the metering tube 309 for metering. Because the present invention separates oil and water through the oil-water separation device before collecting the gas desorbed from the shale, it ensures that the desorbed water does not affect the gas collection process, thereby ensuring the accuracy of gas detection. It should be noted that the oil-water separation device here includes a cold trap collection unit 110 and a light hydrocarbon capture unit 113. The cold trap collection unit 110 and the light hydrocarbon capture unit 113 are used to separate oil and water to ensure that the gas entering the metering tube 309 does not contain water.

[0098] The air intake valve 314 is provided on the air intake line 313 for controlling the on-off of the air intake line 313 . The controlled end of the air intake valve 314 is connected to the output end of the central control unit 120 .

[0099] The exhaust assembly is provided on the metering tube 309 and can discharge the gas in the metering tube 309. The controlled end of the exhaust assembly is connected to the output end of the central control unit 120. The exhaust assembly includes an exhaust pipe 320 and a purge valve 319.

[0100] One end of the exhaust pipe 320 is connected to the top end of the metering pipe 309, and the other end is connected to the outside atmosphere.

[0101] The air release valve 319 is provided on the exhaust pipe 320 for controlling the on-off of the exhaust pipe 320 . The controlled end of the air release valve 319 is connected to the output end of the central control unit 120 .

[0102] The magnetostrictive component is disposed inside the metering tube 309 and is used to generate a magnetostrictive effect and twist when the air inlet component introduces gas into the metering tube 309 and the liquid level in the metering tube 309 changes.

[0103] The magnetostrictive assembly includes a measuring rod 312, a magnetostrictive wire, and a movable magnetic ring 311. The measuring rod 312 is vertically positioned within the measuring tube 309 and is made of non-magnetic stainless steel, reliably protecting the magnetostrictive wire. The magnetostrictive wire, also known as a waveguide, is positioned within the measuring rod 312. The starting pulse generated by the magnetostrictive detection assembly generates a rotating magnetic field as it travels along the magnetostrictive wire. The movable magnetic ring 311 is positioned around the measuring rod 312 and moves according to changes in the liquid level, generating the magnetostrictive effect when it encounters the rotating magnetic field.

[0104] The magnetostrictive detection assembly generates a starting pulse during operation and a corresponding return pulse based on the twisting of the magnetostrictive assembly, calculating the liquid displacement and, consequently, the gas volume. The output of the magnetostrictive detection assembly is connected to the input of the central control unit 120, transmitting its signal to the central control unit 120 for easier monitoring.

[0105] The magnetic detection component in the present invention is an electronic compartment 317, which contains an electronic circuit and an energy pickup mechanism. The electronic circuit can generate pulses, and the energy pickup mechanism can receive the torsional signal of the magnetic detection component and convert it into a corresponding return pulse.

[0106] A pressure sensor 315 is further provided inside the metering tube 309 . The pressure sensor 315 is used to detect the pressure condition inside the metering tube 109 . The output end of the pressure sensor 315 is connected to the input end of the central control unit 120 .

[0107] A temperature sensor 316 is further provided inside the metering tube 309 . The temperature sensor 316 is used to detect the temperature condition inside the metering tube 309 . The output end of the temperature sensor 316 is connected to the input end of the central control unit 120 .

[0108] The air intake valve 314 , the air release valve 319 , the pressure sensor 315 , the temperature sensor 316 , the liquid inlet valve 304 , the liquid inlet pump 303 , the proportional one-way speed regulating valve 306 , and the liquid withdrawal pump 307 in the present invention are respectively connected to the central control unit 120 via the central control line 321 .

[0109] The working process of the gas metering unit 300 of the present invention is as follows:

[0110] First, several metering tubes 309 are connected to the liquid storage tank 301 in sequence, and the air inlet line 313 in each metering tube 309 is connected to the heating desorption unit 400 and the air outlet end of the oil-water separation device, so that multiple metering tubes 309 can measure gas at the same time and improve the gas metering speed.

[0111] Then, the liquid inlet valves 304 on the metering tubes 309 are opened, and the central control unit 120 controls the liquid inlet pump 303 to pump the liquid in the liquid storage tank 301 into the metering tubes 309 , and then closes the liquid inlet valves 304 .

[0112] Afterwards, each air inlet valve 314 is opened and each air release valve 319 is closed. The shale desorbs gas in the heating desorption unit 400. The desorbed gas is separated from oil and water by the oil-water separation device to remove the oil and water contained in the gas. Then the gas enters each metering pipe 309, and the desorbed gas is collected through each metering pipe 309.

[0113] Afterwards, the gas enters the metering tube 309 and pushes the liquid in the metering tube 309 downward, and the liquid in the metering tube 309 returns to the liquid storage tank 301 through the liquid withdrawal pipe 305 at the bottom. As the liquid in the metering tube 309 moves downward, the movable magnetic floating ring 311 moves downward with the liquid level.

[0114] A starting pulse is generated by the electronic circuit in the electronic compartment. When this starting pulse is transmitted in the waveguide wire, a rotating magnetic field is simultaneously generated that moves along the direction of the waveguide wire. When this magnetic field meets the permanent magnetic field in the mobile magnetic levitation ring 311, a magnetostrictive effect is generated, causing the waveguide wire to twist. This twisting is sensed by the energy pickup mechanism installed in the electronic compartment and converted into a corresponding return pulse. The time difference between the starting pulse and the return pulse is calculated by the electronic circuit of the electronic compartment (similar to the radar ranging principle), and the measured displacement can be accurately measured. The electronic compartment feeds back the liquid displacement information to the central control unit 120, and the gas volume is calculated by the central control unit 120.

[0115] During the drainage gas collection and metering process, the pressure sensor 315 can detect the pressure condition in the metering tube 309 and feed the pressure information back to the central control unit 120. The temperature sensor 316 can detect the temperature condition in the metering tube 309 and feed the temperature information back to the central control unit 120. Furthermore, the present invention can also detect the pressure and temperature of the desorbed gas when implementing drainage gas collection and metering, and detect the changes in the pressure and temperature of the gas in the metering tube 309.

[0116] After the drainage and gas collection metering is completed, the air release valve 319 is opened to discharge the gas. Then, the central control unit 120 controls the liquid inlet pump 303 to pump the liquid in the liquid storage tank 301 into each metering pipe 309 again for the next test.

[0117] The present invention also provides a testing method for detecting the oil, gas and water content in rocks, which uses the above-mentioned testing device 100. The testing method is described in detail below with reference to Figures 1, 2 and 3.

[0118] First, a testing device 100 is provided, the weight of the first collecting tube 201 is weighed as m1, the weight of the second collecting tube 113a is weighed as m2, and the weighed first collecting tube 201 and second collecting tube 113a are installed in their original positions in the testing device 100.

[0119] Afterwards, the test device 100 is tested for air tightness. Specifically, gas is supplied to the device through the gas delivery unit 101, and the air tightness of the test device 100 is checked by adjusting the pressure regulating valve 102, the first valve 104, the second valve 107, the third valve 112, the fourth valve 114, the fifth valve 116, and the sixth valve 118 to ensure that there is no leakage at 0.3 MPa.

[0120] Afterwards, by adjusting the pressure regulating valve 102 and cooperating with the gas metering unit 300, when the carrier gas flow rate is adjusted to a predetermined flow rate, for example, when the carrier gas flow rate is a value between 10-30 mL / min, the gas delivery unit 101 is closed to stop inputting gas into the testing device 100.

[0121] Afterwards, the temperature of the heating mechanism 121 is set to a first predetermined temperature, for example, the actual temperature of the drilling mud circulation, such as 60°C-110°C. According to the drilling site data, the temperature of the auxiliary heating pipeline 108 is set to a value between 260°C and 300°C, and the temperature of the low-temperature cold trap 110a of the cold trap collection unit 110 is set to a value between -20°C and 10°C. Thus, the heating and desorption unit 400 and the cold trap collection unit 110 are controlled to the corresponding first predetermined temperature to form a gas metering and oil-water capture test environment.

[0122] The first valve 104 and the second valve 107 are closed, and the rock sample 106 is placed in the sample chamber 105. It should be noted that for the rock sample 106 that needs to be crushed, the rock sample 106 can be hammered by a crushing mechanism to crush the rock sample 106.

[0123] The central control unit 120 controls the test device 100 to open through the central control line 119. At this time, the first valve 104, the fourth valve 114 and the sixth valve 118 are in the closed state; the second valve 107, the third valve 112 and the fifth valve 116 are in the open state, and the cold trap collection unit 110, the first capture pipe 201 and the gas metering unit 300 start working.

[0124] At regular intervals, such as a value between 1 and 3 minutes, the opening and closing of fifth valve 116 are adjusted, and the volume of gas collected in gas metering unit 300 is recorded. When gas metering unit 300 needs to be vented, fifth valve 116 is closed and sixth valve 118 is opened to vent gas. The exhausted gas can then be analyzed to detect its composition.

[0125] After heating mechanism 121 has operated for a period of time, for example, 1-3 hours, the temperature of heating mechanism 121 is raised to 110°C and maintained at this temperature for 5-8 hours, until the volume of gas in gas metering unit 300 no longer increases. The fifth valve 116 and the sixth valve 118 are then closed, stopping gas metering. The first valve 104 and the fourth valve 114 are opened, and carrier gas is simultaneously delivered to the device via gas delivery unit 101.

[0126] Heating mechanism 121 is heated to 300°C and maintained for 1-3 hours. Heating mechanism 121 is then deactivated, the heating mechanism on auxiliary heating line 108 is turned off, and gas delivery unit 101 stops delivering carrier gas to the device. First valve 104, second valve 107, third valve 112, and fourth valve 114 are closed.

[0127] The central control unit 120 adjusts the carrier gas flow rate within the test apparatus 100 to a predetermined flow rate, and controls the heating and desorption unit 400 and the cold trap collection unit 110 to corresponding second predetermined temperatures to create an oil-water capture test environment. For example, the carrier gas flow rate is controlled to a predetermined flow rate of 10-30 mL / min, the heating and desorption unit 400 is controlled to a predetermined temperature of 60°C-350°C, and the cold trap collection unit 110 is controlled to a predetermined temperature of -20°C-10°C.

[0128] The cooling air is delivered to the device by the cooling air delivery unit 122 to cool the sample chamber 105 .

[0129] The second collecting tube 113a is removed and weighed to obtain a weight of m3, where m3-m2 is the weight of the light hydrocarbons in the rock. Alternatively, the light hydrocarbon components can be quantitatively analyzed using a thermal desorption chromatograph.

[0130] The first collecting tube 201 is removed and weighed to obtain a weight of m4. m4-m1 is the oil and water content in the rock.

[0131] A solvent (e.g., ethylene dichloride) is added to first collection tube 201. After shaking to separate the layers, the volume of the water layer is measured to obtain the water content, and the oil content is obtained by subtraction. To prevent the liquid from spilling, first collection tube 201 is sealed with a sealing cap 207.

[0132] Similarly, the oil-containing liquid in the first collecting tube 201 can be extracted and the infrared method can be used to perform quantitative analysis on the oil content to obtain oil content information, and the water content information can be obtained by using the subtraction method.

[0133] The gas content information is the gas volume obtained in the gas metering unit 300 plus the lost gas volume. The lost gas volume is obtained according to the rock gas desorption curve according to the method specified in the industry standard SY / T 6940-2020 "Method for Determination of Shale Gas Content".

[0134] The total oil content in the rock is the sum of the light hydrocarbon content in the second collecting tube 113 a and the oil content in the cold trap collecting mechanism 109 .

[0135] After the sample chamber 105 cools down, the rock sample 106 is taken out and the next sample is tested.

[0136] After the rock sample 106 to be tested is heated by the heating mechanism 121 in the sample chamber 105, the components to be tested in the rock sample are released into the testing device 100. The components to be tested flow through the cold trap collection unit 110, the light hydrocarbon capture unit 113, and the gas metering unit 300 in sequence. The water and oil components in the components to be tested are captured by the cold trap collection unit 110, the light hydrocarbon components in the components to be tested are captured by the light hydrocarbon capture unit 113, and the gas components in the components to be tested are measured by the gas metering unit 300. The testing device 100 provided by the present invention can test a full-diameter core sample of a certain thickness at the drilling site and obtain the oil, gas, and water content in the rock at one time; further combined with the rock gas analysis curve, the lost gas volume can be recovered. The testing device 100 does not lose any components during the experiment, which not only improves work efficiency, but also overcomes the problem of poor matching of test data in existing methods, providing scientific data for the evaluation of rock oil and gas content and mobility.

[0137] In the description of the present invention, it should be understood that the terms "first" and "second" are used for descriptive purposes only and should not be understood to indicate or imply relative importance or implicitly specify the number of the technical features indicated. Therefore, a feature specified as "first" or "second" may explicitly or implicitly include one or more of the features. In the description of the present invention, "plurality" means two or more, unless otherwise specifically defined.

[0138] In addition, in the description of this specification, reference to the terms "one embodiment," "some embodiments," "examples," "specific examples," or "some examples" means that the specific features, structures, materials, or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present invention. In this specification, the schematic representation of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials, or characteristics described can be combined in any appropriate manner in any one or more embodiments or examples.

[0139] Finally, it should be noted that the above description is only a preferred embodiment of the present invention and does not constitute any limitation to the present invention. Although the present invention has been described in detail with reference to the aforementioned embodiments, it is still possible for those skilled in the art to modify the technical solutions described in the aforementioned embodiments or to replace some of the technical features therein with equivalents. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included in the scope of protection of the present invention.

Claims

1. A testing device for detecting the oil, gas and water content in rocks, comprising: A heating and desorption unit (400) comprises a sample chamber (105) for placing a rock sample (106) to be tested, a crushing mechanism arranged in the sample chamber (105), and a heating mechanism (121). The heating and desorption unit (400) is capable of performing closed crushing and heating on the rock sample (106) to achieve gas analysis and desorption analysis of contained oil and water, thereby obtaining components to be tested; A cold trap collection unit (110) communicated with the sample chamber (105) is used to capture oil and water in the components to be tested and to separate them to obtain primary separated components to be tested; A light hydrocarbon capture unit (113) in communication with the cold trap collection unit (110) is used to capture light hydrocarbons in the primary separation components to be detected and to separate them into secondary separation components to be detected; A gas metering unit (300) in communication with the light hydrocarbon capture unit (113) for measuring and calculating the gas volume; as well as A central control unit (120) for controlling the testing device.

2. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: The gas metering unit (300) comprises a liquid storage tank (301), at least one metering tube (309) connected to the liquid storage tank (301), a magnetostrictive component arranged inside the metering tube (309), and a magnetostrictive detection component. The magnetostrictive component is used to generate a magnetostrictive effect and twist when gas is introduced into the metering tube (309) and the liquid level in the metering tube (309) changes. The magnetostrictive detection component is used to generate a starting pulse and can generate a corresponding return pulse according to the twisting of the magnetostrictive component to calculate the liquid displacement and thus calculate the gas volume.

3. The testing device for detecting the oil, gas and water content in rocks according to claim 2, characterized in that: The magnetostrictive component comprises: a measuring rod (312) vertically disposed inside the metering tube (309); A magnetostrictive wire is arranged inside the measuring rod (312), and a rotating magnetic field is generated when the starting pulse generated by the magnetostrictive detection component moves along the magnetostrictive wire; The movable magnetic floating ring (311) is sleeved on the outside of the measuring rod (312) and can move according to the change of the liquid level, and is used to generate a magnetostrictive effect when encountering a rotating magnetic field.

4. The testing device for detecting the oil, gas and water content in rocks according to claim 2 or 3, characterized in that: A pressure sensor (315) and a temperature sensor (316) are also provided inside the metering tube (309).

5. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: The sample chamber (105) is constructed to include a can body (4) and a crushing can cover (2), wherein the crushing can cover (2) and the can body (4) are sealed via a first sealing filler.

6. The testing device for detecting the oil, gas and water content in rocks according to claim 5, characterized in that: The crushing mechanism comprises a primary crushing unit connected to the crushing tank cover (2) and a secondary crushing unit arranged in the tank body (4) and at the bottom. The primary crushing unit is capable of impact crushing the rock sample (106) to obtain a crushed stone sample, and the secondary crushing unit is capable of grinding and crushing the crushed stone sample.

7. The testing device for detecting the oil, gas and water content in rocks according to claim 6, characterized in that: The primary crushing unit comprises a push rod (8), a weight (7) connected to the lower end of the push rod (8), an energy storage element (5) arranged on the push rod (8), and a drive assembly (1). The upper end of the push rod (8) extends outward through the crushing tank cover (2) and is connected to the drive assembly (1). The driving assembly (1) can lift the heavy hammer (7) and store energy in the energy storage element (5), thereby releasing the heavy hammer (7) to generate an impact force to crush the rock sample (106).

8. The testing device for detecting the oil, gas and water content in rocks according to claim 7, characterized in that: The push rod (8) forms a dynamic seal with the crushing tank cover (2) through a dynamic seal assembly. The dynamic sealing assembly comprises a sealing fixing seat (15) and a pneumatic sealing ring (16) mounted on the sealing fixing seat, wherein the sealing fixing seat (15) passes through the central area of ​​the crushing tank cover (2), and the push rod (8) forms a dynamic seal with the crushing tank cover (2) through the pneumatic sealing ring (16).

9. The testing device for detecting the oil, gas and water content in rocks according to claim 6, characterized in that: The secondary crushing unit comprises a vibrating plate, grinding balls (6) arranged on the vibrating plate, and an electromagnetic vibrator for driving the vibrating plate. The vibrating plate can work together with the grinding balls (6) to grind and crush the gravel sample.

10. The testing device for detecting the oil, gas and water content in rocks according to claim 7 or 8, characterized in that: A heat insulation plate (9) is also fixed in the tank body (4), and the heat insulation plate (9) is connected to the bottom of the crushing tank cover (2) through a fixing rod (10). The push rod (8) passes through the heat insulation plate (9), and a dynamic seal is formed between the push rod (8) and the heat insulation plate (9) through a second sealing filler.

11. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: The cold trap collection unit (110) comprises: A cold trap collecting mechanism (109) for collecting oil and water in the components to be detected; and A low-temperature cold trap (110a) is used to provide a low-temperature environment for the cold trap capturing mechanism (109), wherein the cold trap capturing mechanism (109) is arranged inside the low-temperature cold trap (110a).

12. The testing device for detecting the oil, gas and water content in rocks according to claim 1 or 11, characterized in that: The cold trap capture mechanism (109) includes a first capture tube (201) and a sealing cover (203) that covers the first capture tube (201), and the sealing cover (203) is provided with an air inlet (205) and an air outlet (204), wherein the air inlet (205) is communicated with the sample chamber (105), and the air outlet (204) is communicated with the light hydrocarbon capture unit (113).

13. The testing device for detecting the oil, gas and water content in rocks according to claim 12, characterized in that: The air inlet (205) is provided with an injection cannula (202), which extends to the interior of the first collecting tube (201) and close to the bottom, and is used to pass the component to be detected into the bottom of the collecting tube (201). The ratio of the length of the injection cannula (202) extending into the interior of the first collecting tube (201) to the length of the first collecting tube (201) is 1:1.5-1:1.

2.

14. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: The first collecting tube (201) is connected to the sample chamber (105) via a temperature-controllable heating auxiliary heating line (108), and the inner wall of the auxiliary heating line (108) is subjected to a passivation anti-adsorption treatment.

15. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: It also includes a gas delivery unit (101) in communication with the sample chamber (105) for delivering the components to be detected remaining in the sample chamber (105) into the cold trap collection unit (110) and the light hydrocarbon capture unit (113).

16. The testing device for detecting the oil, gas and water content in rocks according to claim 15, characterized in that: The gas delivery unit (101) is connected to the sample chamber (105) via a first gas pipeline (103), the cold trap collection unit (110) is connected to the gas metering unit (300) via a second gas pipeline (111), the light hydrocarbon capture unit (113) is connected to the second gas pipeline (111), and a flow meter (115) is provided between the light hydrocarbon capture unit (113) and the gas metering unit for use in conjunction with the gas delivery unit (101) to control the flow of the carrier gas in the testing device.

17. The testing device for detecting the oil, gas and water content in rocks according to claim 1 or 16, characterized in that: The light hydrocarbon capture unit (113) comprises a second capture tube (113a), and the second capture tube (113a) is filled with adsorption material.

18. The testing device for detecting the oil, gas and water content in rocks according to claim 1, characterized in that: It also includes a cold air delivery unit communicated with the sample chamber (105) and used for delivering cold air into the sample chamber (105).

19. A test method for determining the oil, gas, and water content in rock, comprising the following steps: Step 1: providing a testing device according to any one of claims 1 to 18; Step 2: Weighing the weight of the first collecting tube (201) in the cold trap collection unit (110) and the second collecting tube (113a) in the light hydrocarbon collecting unit (113); Step 3: controlling the heating and desorption unit (400) and the cold trap collection unit (110) to corresponding first predetermined temperatures through the central control unit (120) to form a gas metering and oil-water capture test environment; Step 4: placing the rock to be tested into the sample chamber (105); Step 5: Recording the volume of gas collected by the gas metering unit (300) until the volume of gas in the gas metering unit (300) no longer increases, wherein the volume is recorded once at predetermined intervals, and after the predetermined time, the heating and desorption unit is heated in stages; Step six: adjusting the carrier gas flow rate in the test device to a predetermined flow rate, and controlling the heating desorption unit and the cold trap collection unit to a corresponding second predetermined temperature through the central control unit (120) to form an oil-water capture test environment; Step 7: Re-weigh the weight of the first collecting tube (201) and the second collecting tube (113a), and perform calculation and analysis to obtain the content of oil, gas and water in the rock to be tested.

20. The testing method for detecting the oil, gas and water content in rocks according to claim 19, characterized in that: In the step three, the predetermined temperature of the heating desorption unit is 60°C-110°C, and the predetermined temperature of the cold trap collection unit (110) is -20°C-10°C. In the step six, the predetermined flow rate is 10-30 mL / min, the predetermined temperature of the heating desorption unit is 60°C-350°C, and the predetermined temperature of the cold trap collection unit is -20°C-10°C.

21. The testing method for detecting the oil, gas and water content in rocks according to claim 20, characterized in that: In the step five, each time the heating desorption unit is heated, the temperature is maintained constant until the volume of the gas in the gas metering unit (300) no longer increases, and then the carrier gas is transported into the sample chamber (105) through the gas transport unit (101) to transport the remaining components to be detected in the sample chamber (105) into the cold trap collection unit (110) and the light hydrocarbon capture unit (113).