CN113866069A - Shale core permeability experiment device and method - Google Patents
Shale core permeability experiment device and method Download PDFInfo
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- 230000035699 permeability Effects 0.000 title claims abstract description 84
- 238000000034 method Methods 0.000 title claims abstract description 36
- 238000002474 experimental method Methods 0.000 title claims abstract description 24
- 238000002347 injection Methods 0.000 claims abstract description 63
- 239000007924 injection Substances 0.000 claims abstract description 63
- 238000011144 upstream manufacturing Methods 0.000 claims abstract description 42
- 230000006835 compression Effects 0.000 claims abstract description 5
- 238000007906 compression Methods 0.000 claims abstract description 5
- 239000003079 shale oil Substances 0.000 claims description 25
- 238000003860 storage Methods 0.000 claims description 8
- 239000011435 rock Substances 0.000 claims description 7
- 238000009826 distribution Methods 0.000 claims description 2
- 230000010354 integration Effects 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 6
- 238000005259 measurement Methods 0.000 abstract description 6
- 239000003208 petroleum Substances 0.000 abstract description 3
- 238000012360 testing method Methods 0.000 description 15
- 239000012530 fluid Substances 0.000 description 10
- 238000010586 diagram Methods 0.000 description 5
- 238000001802 infusion Methods 0.000 description 5
- 230000003247 decreasing effect Effects 0.000 description 4
- 238000002360 preparation method Methods 0.000 description 4
- 238000005086 pumping Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 230000001052 transient effect Effects 0.000 description 3
- 238000013461 design Methods 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 239000002655 kraft paper Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000005325 percolation Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000013517 stratification Methods 0.000 description 1
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- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/0806—Details, e.g. sample holders, mounting samples for testing
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
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Abstract
The invention discloses a shale core permeability experimental device and method, relating to the technical field of petroleum exploration and development; the device comprises an injection pump, a receiving pump and a core holder; the injection pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, the receiving pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, and the pipelines are respectively provided with valves; one end of the core holder is connected with a confining pressure pump through a pipeline and a valve, temperature and pressure meters are respectively arranged on the injection pump, the receiving pump, the core holder and the confining pressure pump, and a differential pressure meter is connected between the upstream end and the downstream end of the core holder through a pipeline. The experimental method based on the experimental device can realize rapid and automatic measurement of the oil permeability of the high-permeability to ultra-low-permeability shale core sample and the permeability of the shale core sample under different confining pressure conditions, and calculates the fracture compression coefficient of the shale core sample.
Description
Technical Field
The invention relates to the technical field of petroleum exploration and development, in particular to a shale core permeability experimental device and method.
Background
The shale oil is used as an important petroleum succedaneum resource in China, and has important strategic and practical significance in developing the shale oil. At present, the difficulty of the development of domestic shale oil lies in the development of pure shale type shale oil, the lithology of a shale oil reservoir layer is mainly shale, and the shale or the siltstone or the carbonate rock with a very thin layer is sandwiched, the biggest characteristic of the shale oil reservoir layer is that a shale gap develops, and a large amount of oil exists in the shale gap in a free state. Because the initial and long-term yield of the shale oil is determined by the oil content in the shale cracks and the mobility of the oil, the research on the flow of the shale oil in the shale cracks has important significance for predicting the yield of the shale oil and boosting the development of the shale oil benefit.
At present, gas measurement methods are mostly adopted for testing the shale permeability, for example, permeability experiments of shale gas shale are carried out by using methane. The pulse attenuation method is generally adopted for testing the permeability of a hypotonic sample, however, the shale has a natural fracture system and the permeability of a hydraulic fracturing fracture needs to be researched in shale oil and gas development, so that the value span of the permeability of a shale core can reach 8 orders of magnitude or more. If the permeability of different samples from high permeability to ultra-low permeability needs to be tested, the experimental device needs to be provided with a plurality of sets of cylinders with different volumes, and the system is complex. Meanwhile, because shale oil has large difference between fluid property and gas property, the existence of the Kraft effect causes the difference of the gas permeability and the oil permeability to reach orders of magnitude. Furthermore, the shale oil is very complex in composition and difficult to correct with gas permeability results to oil permeability results, and therefore, a real shale oil sample needs to be used.
At present, experimental research on the permeability of oil in shale is difficult to carry out, so that experimental equipment is needed to meet the requirement of testing the permeability of shale samples with different high and low permeability by using oil.
Disclosure of Invention
The invention aims to provide a shale core permeability experiment device and method, which are used for solving the problems in the prior art and can realize rapid and automatic measurement of oil permeability of a high-permeability to ultra-low permeability shale core sample.
In order to achieve the purpose, the invention provides the following scheme:
the invention provides a shale core permeability experimental device which comprises an injection pump, a receiving pump and a core holder, wherein the injection pump is connected with the receiving pump; the injection pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, the receiving pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, and the pipelines are respectively provided with valves; one end of the rock core holder is communicated withThe pipeline and the valve are connected with a confining pressure pump, the injection pump, the receiving pump, the core holder and the confining pressure pump are respectively provided with a temperature and pressure gauge, and a differential pressure gauge is connected between the upstream end and the downstream end of the core holder through a pipeline; the core holder can only apply confining pressure or axial pressure, the design of the core holder is not the key point of the invention, and the mature core holder design can be used. The confining pressure is controlled by a pump, which can be set for constant confining pressure control or for constant effective stress control depending on the fluid pressure. And a differential pressure sensor is used for directly and accurately measuring the differential pressure at two ends of the rock core. The experimental device can realize rapid and automatic measurement of the high-permeability to ultra-low permeability shale core sample (10)-13To 10-21) The permeability of the shale core under the pressure increasing and reducing conditions and the permeability of the shale core sample under different confining pressure conditions can be measured, and the fracture compression coefficient of the shale core sample is calculated. At the same time, the mobility of the oil in the shale, i.e. the ratio of permeability to viscosity, can be determined. Cores also include other dense rocks besides shale.
Optionally, the pipelines include a first pipeline, a second pipeline, a third pipeline, a fourth pipeline, and a fifth pipeline, and the valves include a first valve, a second valve, a third valve, a fourth valve, a fifth valve, a sixth valve, a seventh valve, an eighth valve, a ninth valve, and a tenth valve; one end of the first pipeline and one end of the second pipeline are connected with the injection pump after being converged, the other end of the first pipeline and one end of the fourth pipeline are connected with the upstream end of the core holder after being converged, the other end of the second pipeline is connected with the downstream end of the core holder after being converged with one end of the third pipeline, the other end of the third pipeline is connected with the receiving pump after being converged with the other end of the fourth pipeline, and the two ends of the fifth pipeline are respectively connected with the upstream end of the core holder and the confining pressure pump; the injection pump is connected with an oil storage tank through a first valve, and the joint position of the first pipeline and the second pipeline is connected with the injection pump through a second valve and an external vacuumizing device; the receiving pump is connected with an oil storage tank through a sixth valve, the junction position of the third pipeline and the fourth pipeline is connected with the receiving pump through a fifth valve and an external vacuumizing device, and the junction position of the second pipeline and the third pipeline is connected with the external vacuumizing device through a ninth valve; the first pipeline is provided with a third valve, the second pipeline is provided with an eighth valve, the third pipeline is provided with a tenth valve, and the fourth pipeline is provided with a fourth valve.
Optionally, the infusion pump and the receiving pump have the same structure, are high-precision metering pumps, comprise an automatic control system, can set constant-pressure control and provide precise metering volume, and have the precision of 0.001 ml or below.
The invention also provides an experimental method for the permeability of the shale core, which comprises the step of mainly measuring the permeability range of the shale core to be about 10-13m2To 10-16m2The steady state method of (a), the steady state method comprising the steps of:
the injection pump enters the pump for injection, and the shale oil flows through the core sample and enters the receiving pump; the control mode adopts a constant pressure injection mode or a constant speed injection mode; when the constant pressure injection mode is adopted, the receiving pump is also in the constant pressure mode, and the speeds of the injection pump and the receiving pump are constant; when the constant-speed injection mode is adopted, the receiving pump is in the constant-speed mode, and the pressure difference between two ends of the equal core is constant; at this time, the permeability is calculated by darcy's law as follows
Wherein Q is the volume flow rate, obtained by the relationship between the change in pump volume and the change in time; k is the permeability; a is the cross-sectional area of the sample; Δ P is the real-time pressure difference upstream and downstream; μ is the viscosity of the oil; l is the length of the sample.
Optionally, the core permeability range of the main measurement is about 10-15m2To 10-20m2The pulse attenuation method of (1), the pulse attenuation method testing device generally has two constant volume oil storage tanks, and compared with the constant volume upstream and downstream oil storage tanks, the device has the advantages ofSo as to accurately set the pressures of the upstream and downstream by the injection pump and the receiving pump of the upstream and downstream, and at the same time, freely adjust the volumes of the upstream and downstream pumps so as to more conveniently measure samples with different permeabilities, the pulse attenuation method comprises the following steps:
accurately setting the pressure of the upstream end and the downstream end of the core holder through an injection pump and a receiving pump, simultaneously increasing the pressure through the injection pump and the receiving pump to saturate the sample with oil, then increasing the pressure of the upstream end of the core holder through the injection pump, keeping the volumes of the injection pump and the receiving pump constant, obtaining an attenuation curve of the pressure difference by recording the pressure difference of the upstream end and the downstream end of the core holder, and calculating the permeability through the following formula:
ΔP＝ΔP0e-at equation 2
Wherein, V1Is the volume of the upstream injection pump end, V2Is the volume of the downstream receiving pump end, Δ P is the real-time differential pressure change between upstream and downstream, Δ P0Is the initial pressure differential, k is the permeability, A is the cross-sectional area of the sample, μ is the viscosity of the oil, β is the compressibility of the oil, and L is the length of the sample.
Optionally, the method further comprises a quasi-steady state method, wherein the quasi-steady state method comprises the following steps:
the injection pump injects oil into a sample in the core holder at a constant speed, the receiving pump keeps the volume unchanged, the change condition of the downstream pressure of the core holder is always monitored, when the downstream pressure of the core holder begins to change, time and pressure difference are recorded, the flow of the oil in the sample at the moment is considered to reach a quasi-steady state, namely, the pressure distribution in the sample meets the following relation:
the pressure versus position in the sample obtained after integration is:
when the pressure P at the downstream end2At the start of the change-over time,
considered as the starting pressure gradient;
therefore, the flow rate is first calculated by the following equation, the volume compression caused by shale oil pressure rise needs to be subtracted:
where β is the compressibility of the shale oil. Then, the permeability was calculated using the following formula
The fluids used in the experiments may be light oil or condensate (liquid). The sample used for the experiment may be shale or tight sandstone. In the case of ultra-low permeability core samples (e.g., less than 10)-20m2) For example, a shale sample perpendicular to the bedding direction, a stub sample may be prepared for faster permeability determination.
In the calculation of the above three methods, the mobility parameter (i.e. the ratio of permeability to viscosity) of the oil is obtained first, and when the viscosity of the oil sample is known, the permeability of the sample can be obtained.
In the experimental process of the three methods, the confining pressure and the fluid pressure of the oil can be changed to test the permeability, and the relation between the oil permeability and the fluid pressure and the stress borne by the sample is obtained. The fracture compressibility of the shale core sample may be calculated by the following equation:
where k is the permeability at stress σ, k0Is a stress of σ0Permeability of (2), CfIs the core fracture compressibility.
Compared with the prior art, the invention has the following technical effects:
the invention uses a differential pressure sensor to directly measure the pressure difference at two ends of the sample, and can improve the measuring precision of the permeability. Hypertonic, mid-to-low and extra-low permeability shale core samples can be tested using three different measurement modes, respectively. The start-up pressure gradient of a hypotonic sample was studied by establishing a non-linear change in flow velocity versus differential pressure through a series of injection experiments starting from a low flow rate. The relation between the permeability and the fluid pressure and the confining pressure can be obtained by changing the fluid pressure and the confining pressure in the experimental process, and the compression coefficient of the core fracture is calculated.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed in the embodiments 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 to obtain other drawings without creative efforts.
FIG. 1 is a schematic structural diagram of a shale core permeability experimental apparatus according to the present invention;
FIG. 2 is a schematic diagram of the possible variations in pumping volume and flow rate during a steady state process experiment in accordance with the present invention;
FIG. 3 is a schematic diagram of possible changes in pressure upstream and downstream of a core holder during a transient experimental procedure in accordance with the present disclosure;
FIG. 4 is a schematic diagram of possible variations in pressure differential between upstream and downstream of a core holder during a transient experimental procedure in accordance with the present disclosure;
FIG. 5 is a schematic diagram of possible changes in pump pressures for an injection pump upstream and a receiver pump downstream of a core holder during a pseudo-steady state process experiment in accordance with the present invention;
wherein, 1 is a first valve, 2 is a second valve, 3 is a third valve, 4 is a fourth valve, 5 is a fifth valve, 6 is a sixth valve, 7 is a seventh valve, 8 is an eighth valve, 9 is a ninth valve, 10 is a tenth valve, 11 is a first pipeline, 12 is a second pipeline, 13 is a third pipeline, 14 is a fourth pipeline, 15 is a fifth pipeline, 16 is a differential pressure gauge, 17 is a temperature and pressure gauge, 18 is an injection pump, 19 is a confining pressure pump, 20 is a core holder, and 21 is a receiving pump.
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 given herein without making any creative effort, shall fall within the protection scope of the present invention.
The invention aims to provide a shale core permeability experiment device and method, which are used for solving the problems in the prior art and can realize rapid and automatic measurement of oil permeability of a high-permeability to ultra-low permeability shale core sample.
In order to make the aforementioned objects, features and advantages of the present invention comprehensible, embodiments accompanied with figures are described in further detail below.
Example one
At present, a gas measuring method is mainly adopted for measuring the permeability of the shale core. Meanwhile, as the components of shale oil are complex and the shale oil components of different wells are greatly different, the permeability of the shale core needs to be directly measured by oil so as to better predict the yield of the shale oil. In this example, a cylindrical shale sample is used for illustration; the specific experimental procedure is as follows.
1. Shale rock core permeability experimental apparatus assembly connection
As shown in fig. 1, the shale core permeability experimental apparatus includes an injection pump 18, a receiving pump 21 and a core holder 20; the injection pump 18 is respectively connected with the upstream and the downstream of the core holder 20 through pipelines, the receiving pump 21 is respectively connected with the upstream and the downstream of the core holder 20 through pipelines, and the pipelines are respectively provided with valves; one end of the core holder 20 is connected with a confining pressure pump 19 through a pipeline and a valve, the injection pump 18, the receiving pump 21, the core holder 20 and the confining pressure pump 19 are respectively provided with a temperature and pressure gauge 17, and a differential pressure gauge 16 is connected between the upstream end and the downstream end of the core holder 20 through a pipeline.
Specifically, the pipelines include a first pipeline 11, a second pipeline 12, a third pipeline 13, a fourth pipeline 14, and a fifth pipeline 15, and the valves include a first valve 1, a second valve 2, a third valve 3, a fourth valve 4, a fifth valve 5, a sixth valve 6, a seventh valve 7, an eighth valve 8, a ninth valve 9, and a tenth valve 10; one end of a first pipeline 11 and one end of a second pipeline 12 are connected with an injection pump 18 after being converged and connected, the other end of the first pipeline 11 is connected with the upstream end of a core holder 20 after being converged and connected with one end of a fourth pipeline 14, the other end of the second pipeline 12 is connected with the downstream end of the core holder 20 after being converged and connected with one end of a third pipeline 13, the other end of the third pipeline 13 is connected with a receiving pump 21 after being converged and connected with the other end of the fourth pipeline 14, and the two ends of a fifth pipeline 15 are respectively connected with the upstream end of the core holder 20 and a confining pressure pump 19; the injection pump 18 is connected with an oil storage tank through a first valve 1, and the joint position of the first pipeline 11 and the second pipeline 12 and the injection pump 18 are connected with an external vacuum-pumping device through a second valve 2; the receiving pump 21 is connected with an oil storage tank through a sixth valve 6, the joint position of the third pipeline 13 and the fourth pipeline 14 and the receiving pump 21 are connected with an external vacuum-pumping device through a fifth valve 5, and the joint position of the second pipeline 12 and the third pipeline 13 is connected with the external vacuum-pumping device through a ninth valve 9; a third valve 3 is arranged on the first pipeline 11, an eighth valve 8 is arranged on the second pipeline 12, a tenth valve 10 is arranged on the third pipeline 13, and a fourth valve 4 is arranged on the fourth pipeline 14.
2. Preparation and installation of samples
The cylindrical shale sample is prepared using a wire cutting apparatus to ensure that the sample is minimally affected by the preparation process. Depending on the direction of the percolation studied, samples can be prepared either parallel to the shale bedding direction or perpendicular to the bedding direction. The cylindrical sample has a diameter of 5 cm and a length of 10 cm, but may have other standard dimensions. The sample need not be of a standard size in length, however, particularly hypotonic samples allow for the preparation of shorter length samples that are loaded into the core holder 20 by using additional pads to encase the sample in a gum cover.
3. System preparation
After the sample is installed, all valves are first closed. The system temperature is set to a target temperature. The seventh valve 7 is opened, confining pressure is applied to the core holder 20, and the ninth valve 9 is opened to vacuumize the sample.
The first valve 1 and the second valve 2 are opened and the oil sample is fed to the injection pump 18 through the first valve 1 and the line.
The fifth valve 5 and the sixth valve 6 are opened and the oil sample is fed to the receiving pump 21 through the sixth valve 6 and the pipeline.
And after the temperature of the system reaches the set temperature and the sample is vacuumized to reach the target vacuum degree, closing all the valves.
4. Oil saturation of samples
The third valve 3 and the tenth valve 10 are opened and the pressure of the injection pump 18 and the receiving pump 21 are controlled at the same pressure level and slightly above one atmosphere so that the shale oil enters the shale core and fully saturates the fracture system of the core. The pressure of the injection pump 18 and the receiver pump 21 is raised to a first test pressure, such as 1MPa, and when the pump volume no longer changes, the oil in the fracture system of the core is considered to be saturated and the target test pressure is reached.
5. Steady state method sample permeability test
The pressure of the infusion pump 18 is increased, for example to 1.2MPa, the pressure of the receiving pump 21 is decreased, for example to 0.8MPa, and the fixed pressure is maintained by the pump control, and the upstream and downstream pressures, the differential pressure across the sample and the volumes of the infusion pump 18 and receiving pump 21 are recorded, as shown in figure 2. When the speeds of the injection pump 18 and the receiving pump 21 both reach a steady state, the oil mobility and the oil permeability of the shale are calculated using equation 1. When the next permeability test is performed, the injection pump 18 and the receiving pump 21 are exchanged, i.e. after the oil has mostly flowed to the receiving pump 21, the flow direction of the experiment can flow from the receiving pump 21 to the injection pump 18. At this time, the third valve 3 and the tenth valve 10 are closed, the pressure of the receiving pump 21 is increased to, for example, 1.2MPa, the pressure of the injection pump 18 is decreased to, for example, 0.8MPa, the fourth valve 4 and the eighth valve 8 are opened, and the above steps are repeated.
The confining pressure and the fluid pressure of the oil are changed, and the oil permeability under different confining pressure, oil pressure and effective stress conditions can be obtained by repeating the above experimental steps. The temperature of the system can also be varied and the above test repeated to obtain the effect of temperature on permeability.
After a series of experiments, the third valve 3 and the tenth valve 10 or the fourth valve 4 and the eighth valve 8 are opened, and the pressures of the injection pump 18 and the receiving pump 21 are reduced to 1 atmosphere, at this time, the pressure in the core holder 20 is also reduced to 1 atmosphere, and the confining pressure is reduced to 1 atmosphere. And closing the third valve 3, the fourth valve 4, the seventh valve 7, the eighth valve 8 and the tenth valve 10, taking out the rock core, and finishing the experiment.
6. Transient method sample permeability test
If the permeability of the sample is low, for example at 10-16m2To 10-18m2Within this range, after the sample is mounted and the temperature reaches the target temperature, the experiment is prepared using the methods of steps 3 and 4.
Increasing the pressure of the injection pump 18, for example to 1.2MPa, and decreasing the pressure of the receiving pump 21, for example to 0.8MPa, then stopping the constant pressure control mode of the pumps, keeping the volumes of the injection pump 18 and the receiving pump 21 constant, at this time, recording the pressure upstream and downstream of the sample in the core holder 20 and the pressure difference across the sample, as shown in fig. 3 and 4, and when the pressure difference upstream and downstream is decreased to 20% of its initial pressure difference, calculating the oil permeability of the shale using equation 2 and equation 3. When the pressure difference changes rapidly, the confining pressure can be changed after the test is finished to perform the next permeability test, so that the relation between the permeability and the confining pressure is researched; when the pressure difference changes particularly slowly, i.e. the permeability is particularly low, the ambient pressure can be varied simultaneously during the depressurization process to obtain the permeability under different ambient pressure conditions, in order to save test time.
7. Pseudo-steady state method sample permeability test
If the permeability of the sample is extremely low, for example, the permeability of the sample in the vertical direction of stratification may be at 10-18m2The experiment was then prepared as described above in steps 3 and 4 using a short shale sample plus pad installation into the core holder at this point.
At this point the infusion pump 18 is turned off so that it no longer changes volume, and the infusion pump 18 upstream uses a constant flow rate mode, but a very small flow rate, e.g., 0.001 ml per minute. The upstream pressure, the differential pressure across and downstream of the sample, and the downstream pressure change are recorded, as in fig. 5, and as the downstream pressure begins to change, the flow rate is calculated by equation 6. And the permeability was calculated by equation 1. Experiments can be carried out under different confining pressure and fluid pressure conditions to obtain shale oil permeability as a function of confining pressure and fluid pressure.
In the description of the present invention, it should be noted that the terms "center", "top", "bottom", "left", "right", "vertical", "horizontal", "inner", "outer", and the like indicate orientations or positional relationships based on those shown in the drawings, and are only for convenience of description and simplicity of description, and do not indicate or imply that the device or element being referred to must have a particular orientation, be constructed in a particular orientation, and be operated, and thus, should not be construed as limiting the present invention. Furthermore, the terms "first" and "second" are used for descriptive purposes only and are not to be construed as indicating or implying relative importance.
The principle and the implementation mode of the invention are explained by applying a specific example, and the description of the embodiment is only used for helping to understand the method and the core idea of the invention; meanwhile, for a person skilled in the art, according to the idea of the present invention, the specific embodiments and the application range may be changed. In view of the above, the present disclosure should not be construed as limiting the invention.
Claims (6)
1. The utility model provides a shale rock core permeability experimental apparatus which characterized in that: the device comprises an injection pump, a receiving pump and a core holder; the injection pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, the receiving pump is respectively connected with the upstream end and the downstream end of the core holder through pipelines, and the pipelines are respectively provided with valves; one end of the core holder is connected with a confining pressure pump through a pipeline and a valve, temperature and pressure meters are respectively arranged on the injection pump, the receiving pump, the core holder and the confining pressure pump, and a differential pressure meter is connected between the upstream end and the downstream end of the core holder through a pipeline.
2. The shale core permeability experimental apparatus of claim 1, wherein: the pipelines comprise a first pipeline, a second pipeline, a third pipeline, a fourth pipeline and a fifth pipeline, and the valves comprise a first valve, a second valve, a third valve, a fourth valve, a fifth valve, a sixth valve, a seventh valve, an eighth valve, a ninth valve and a tenth valve; one end of the first pipeline and one end of the second pipeline are connected with the injection pump after being converged, the other end of the first pipeline and one end of the fourth pipeline are connected with the upstream end of the core holder after being converged, the other end of the second pipeline is connected with the downstream end of the core holder after being converged with one end of the third pipeline, the other end of the third pipeline is connected with the receiving pump after being converged with the other end of the fourth pipeline, and the two ends of the fifth pipeline are respectively connected with the upstream end of the core holder and the confining pressure pump; the injection pump is connected with an oil storage tank through a first valve, and the joint position of the first pipeline and the second pipeline is connected with the injection pump through a second valve and an external vacuumizing device; the receiving pump is connected with an oil storage tank through a sixth valve, the junction position of the third pipeline and the fourth pipeline is connected with the receiving pump through a fifth valve and an external vacuumizing device, and the junction position of the second pipeline and the third pipeline is connected with the external vacuumizing device through a ninth valve; the first pipeline is provided with a third valve, the second pipeline is provided with an eighth valve, the third pipeline is provided with a tenth valve, and the fourth pipeline is provided with a fourth valve.
3. The shale core permeability experimental apparatus of claim 1, wherein: the injection pump and the receiving pump have the same structure and are both high-precision metering pumps.
4. A shale core permeability experiment method is characterized by comprising the following steps: including a steady state process comprising the steps of:
the injection pump enters the pump for injection, and the shale oil flows through the core sample and enters the receiving pump; the control mode adopts a constant pressure injection mode or a constant speed injection mode; when the constant pressure injection mode is adopted, the receiving pump is also in the constant pressure mode, and the speeds of the injection pump and the receiving pump are constant; when the constant-speed injection mode is adopted, the receiving pump is in the constant-speed mode, and the pressure difference between two ends of the equal core is constant; at this time, the permeability is calculated by darcy's law as follows
Wherein Q is the volume flow rate, obtained by the relationship between the change in pump volume and the change in time; k is the permeability; a is the cross-sectional area of the sample; Δ P is the real-time pressure difference upstream and downstream; μ is the viscosity of the oil; l is the length of the sample.
5. The shale core permeability experimental method of claim 4, wherein: the method also comprises a pulse attenuation method, wherein the pulse attenuation method comprises the following steps:
accurately setting the pressure of the upstream end and the downstream end of the core holder through an injection pump and a receiving pump, simultaneously increasing the pressure through the injection pump and the receiving pump to saturate the sample with oil, then increasing the pressure of the upstream end of the core holder through the injection pump, keeping the volumes of the injection pump and the receiving pump constant, obtaining an attenuation curve of the pressure difference by recording the pressure difference of the upstream end and the downstream end of the core holder, and calculating the permeability through the following formula:
ΔP＝ΔP0e-αt
wherein, V1Is the volume of the upstream injection pump end, V2Is the volume of the downstream receiving pump end, Δ P is the real-time differential pressure change between upstream and downstream, Δ P0Is the initial pressure differential, k is the permeability, A is the cross-sectional area of the sample, μ is the viscosity of the oil, β is the compressibility of the oil, and L is the length of the sample.
6. The shale core permeability experimental method of claim 4, wherein: the method also comprises a quasi-steady state method, wherein the quasi-steady state method comprises the following steps:
the injection pump injects oil into a sample in the core holder at a constant speed, the receiving pump keeps the volume unchanged, the change condition of the downstream pressure of the core holder is always monitored, when the downstream pressure of the core holder begins to change, time and pressure difference are recorded, the flow of the oil in the sample at the moment is considered to reach a quasi-steady state, namely, the pressure distribution in the sample meets the following relation:
the pressure versus position in the sample obtained after integration is:
when the pressure P at the downstream end2At the start of the change-over time,
considered as the starting pressure gradient;
therefore, the flow rate is first calculated by the following equation, the volume compression caused by shale oil pressure rise needs to be subtracted:
where β is the compressibility of the shale oil. Then, the permeability was calculated using the following formula
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