CN114460278A - Crude oil volume coefficient measuring device and measuring method thereof - Google Patents
Crude oil volume coefficient measuring device and measuring method thereof Download PDFInfo
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- CN114460278A CN114460278A CN202111039456.5A CN202111039456A CN114460278A CN 114460278 A CN114460278 A CN 114460278A CN 202111039456 A CN202111039456 A CN 202111039456A CN 114460278 A CN114460278 A CN 114460278A
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- 239000010779 crude oil Substances 0.000 title claims abstract description 110
- 238000000034 method Methods 0.000 title claims abstract description 23
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- 238000006073 displacement reaction Methods 0.000 claims abstract description 44
- 238000012360 testing method Methods 0.000 claims abstract description 39
- 230000035699 permeability Effects 0.000 claims abstract description 20
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- 239000011521 glass Substances 0.000 claims description 58
- 239000003921 oil Substances 0.000 claims description 25
- 238000002360 preparation method Methods 0.000 claims description 18
- 238000007789 sealing Methods 0.000 claims description 14
- 238000010438 heat treatment Methods 0.000 claims description 12
- 238000005086 pumping Methods 0.000 claims description 9
- 239000006004 Quartz sand Substances 0.000 claims description 6
- 238000001704 evaporation Methods 0.000 claims description 3
- 230000008020 evaporation Effects 0.000 claims description 3
- 238000002474 experimental method Methods 0.000 claims description 3
- 239000000126 substance Substances 0.000 claims description 3
- WLRMANUAADYWEA-NWASOUNVSA-N (S)-timolol maleate Chemical compound OC(=O)\C=C/C(O)=O.CC(C)(C)NC[C@H](O)COC1=NSN=C1N1CCOCC1 WLRMANUAADYWEA-NWASOUNVSA-N 0.000 claims description 2
- 238000001035 drying Methods 0.000 claims description 2
- 239000007789 gas Substances 0.000 description 6
- 238000004364 calculation method Methods 0.000 description 3
- 235000017166 Bambusa arundinacea Nutrition 0.000 description 2
- 235000017491 Bambusa tulda Nutrition 0.000 description 2
- 241001330002 Bambuseae Species 0.000 description 2
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- 239000011425 bamboo Substances 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000011056 performance test Methods 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
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- 230000009286 beneficial effect Effects 0.000 description 1
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- 239000003345 natural gas Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/26—Oils; viscous liquids; paints; inks
- G01N33/28—Oils, i.e. hydrocarbon liquids
- G01N33/2823—Oils, i.e. hydrocarbon liquids raw oil, drilling fluid or polyphasic mixtures
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
- G01D21/00—Measuring or testing not otherwise provided for
- G01D21/02—Measuring two or more variables by means not covered by a single other subclass
Abstract
The invention provides a crude oil volume coefficient measuring device and a measuring method thereof, wherein inlets of a high-permeability reservoir simulation assembly and a low-permeability reservoir simulation assembly are communicated with an outlet of a sample matching device, an inlet of the sample matching device is communicated with an outlet of a high-pressure displacement pump, the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with a temperature sensor, the sample matching device, the high-permeability reservoir simulation assembly, the low-permeability reservoir simulation assembly, a pressure sensor and the temperature sensor are arranged in a stratum, an oven is also arranged in the stratum, signal output ends of the pressure sensor and the temperature sensor are connected with a signal input end of a collector, and outlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with an inlet of a double-cylinder gas meter through a gas pipeline. The invention can simultaneously test and consider the volume coefficient of the crude oil of the stratum under the conditions of high permeability and low permeability of the porous medium of the reservoir, and the volume coefficient of the crude oil of the stratum under the condition of the tested porous medium of the reservoir is closer to the volume coefficient of the crude oil in the real reservoir.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas, in particular to a crude oil volume coefficient measuring device and a crude oil volume coefficient measuring method.
Background
The volume coefficient of crude oil is very important in the calculation of the reserves by a volumetric method, and the geometric difference of the reserve calculation results is brought by the small difference of the volume coefficient.
At present, the disclosed experimental determination method for the volume coefficient of crude oil is experimentally tested in a conventional PVT test unit without considering the environment of a reservoir porous medium, and the formation crude oil is in the porous medium of the reservoir, so that the volume coefficient of the conventional formation crude oil is deviated from the volume coefficient of the crude oil under the real reservoir condition.
Disclosure of Invention
The invention overcomes the defects in the prior art, the existing experimental determination method for the volume coefficient of the crude oil is to carry out experimental test in a conventional PVT test unit without considering the environment of the porous medium of the reservoir, the volume coefficient of the formation crude oil obtained by adopting the method for testing has deviation with the volume coefficient of the crude oil under the real reservoir condition, and provides a crude oil volume coefficient determination device and a determination method thereof.
The purpose of the invention is realized by the following technical scheme.
A device for measuring the volume coefficient of crude oil comprises a high-pressure displacement pump, a sample proportioning device, a high-permeability reservoir simulation assembly, a low-permeability reservoir simulation assembly, a double-cylinder gas meter, a pressure sensor, an oven and a collector,
the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are communicated in parallel, inlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are communicated with an outlet of the sample preparation device through a first pipeline, a four-way valve is arranged on the first pipeline, four ports of the four-way valve are respectively connected with the outlet of the sample preparation device, the inlet of the high-permeability reservoir simulation assembly, the inlet of the low-permeability reservoir simulation assembly and the pressure sensor, the inlet of the sample preparation device is communicated with the outlet of the high-pressure displacement pump through a second pipeline, the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with the temperature sensor, the sample preparation device, the high-permeability reservoir simulation assembly, the low-permeability reservoir simulation assembly, the pressure sensor and the temperature sensor are arranged in the stratum, and the drying oven for heating is also arranged in the stratum, the signal output ends of the pressure sensor and the temperature sensor are connected with the signal input end of the collector, the outlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with the inlet of the test tube through a gas pipeline, and the outlet of the test tube is connected with the inlet of the double-cylinder gas meter.
The high-permeability reservoir simulation assembly is composed of a first sand filling pipe and a first glass cylinder, an inlet of the first sand filling pipe is connected with a port of the four-way valve through a third pipeline, an outlet of the first sand filling pipe is connected with an inlet of the first glass cylinder in series through a fourth pipeline, and an outlet of the first glass cylinder is communicated with an inlet of the first test tube through a fifth pipeline.
The hypotonic reservoir simulation assembly is composed of a second sand filling pipe and a second glass cylinder, an inlet of the second sand filling pipe is connected with a port of the four-way valve through a sixth pipeline, an outlet of the second sand filling pipe is connected with an inlet of the second glass cylinder in series through a seventh pipeline, and an outlet of the second glass cylinder is communicated with an inlet of the second test tube through an eighth pipeline.
The temperature sensor is respectively connected with the first glass cylinder and the second glass cylinder through temperature measuring pipelines.
The first sand filling pipe and the second sand filling pipe are filled with quartz sand with different meshes.
The first glass cylinder and the second glass cylinder are both high-temperature and high-pressure glass cylinders.
The collector adopts a computer host with an acquisition card.
Valves are arranged on the first pipeline, the second pipeline, the third pipeline, the fourth pipeline, the fifth pipeline, the sixth pipeline, the seventh pipeline and the eighth pipeline.
A method for measuring the volume coefficient of crude oil comprises the following steps:
filling quartz sand with different meshes into the first sand filling pipe and the second sand filling pipe respectively, and connecting the first sand filling pipe and the second sand filling pipe in series with the first glass cylinder and the second glass cylinder respectively to form a high-permeability reservoir simulation assembly and a low-permeability reservoir simulation assembly;
carrying out independent sealing test on the hypertonic reservoir simulation assembly and the hypotonic reservoir simulation assembly, and after the test is finished, carrying out vacuumizing operation on the hypertonic reservoir simulation assembly and the hypotonic reservoir simulation assembly;
heating the stratum to the temperature required by the experiment by using an oven;
step 4, injecting formation crude oil into the high-permeability reservoir simulation assembly:
pumping the formation crude oil in the sample preparation device into a high-permeability reservoir simulation assembly formed by connecting a first sand filling pipe and a first glass cylinder in series by using a high-pressure displacement pump, starting a pressure sensor to monitor the pressure in the high-permeability reservoir simulation assembly when the pump is slowly pumped until the pressure displayed by the pressure sensor is stabilized to the formation pressure
transferring the formation crude oil in the sample preparation device into a low-permeability reservoir simulation assembly formed by connecting a second sand filling pipe and a second glass cylinder in series by using a high-pressure displacement pump, starting a pressure sensor to monitor the pressure in the low-permeability reservoir simulation assembly when the pump is slowly pumped until the pressure displayed by the pressure sensor is stabilized to the formation pressure
closing the inlet and outlet valves of the hypotonic reservoir simulation assembly, opening the inlet valve of the hypertonic reservoir simulation assembly, enabling the pump position of the high-pressure displacement pump to return to zero, and enabling a part of crude oil in the formation in the first glass cylinder after passing through the first sand filling pipe to have constant pressure
Flashing to the ground standard condition, and allowing the pressure in the hypertonic reservoir simulation assembly to be stabilized
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
closing the inlet and outlet valves of the high-permeability reservoir simulation assembly, opening the inlet valve of the low-permeability reservoir simulation assembly, and after the pump position of the high-pressure displacement pump is reset to zero, similarly waiting for the pressure in the low-permeability reservoir simulation assembly to be stabilized to be
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
Step 8, calculating volume coefficient under multi-pressure high-permeability condition:
sequentially controlling the pressure of the simulation assembly of the high permeability reservoir to
Hypertonic reservoir simulation groupUnder each pressure test condition, the pump inlet amount of the high-pressure displacement pump is sequentially
Controlling the volume of ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
sequentially controlling the pressure of the simulation assembly of the low permeability reservoir to
Under each pressure test condition of the hypotonic reservoir simulation assembly, the pumping-in amount of the high-pressure displacement pump is sequentially
The volume of the ground flash oil is
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
finally obtaining the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device;
the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 3, 4 … n-th pressure point:
further, the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 4, 5 … n pressure points:
wherein the content of the first and second substances,
considering the volume coefficient of stratum crude oil under the temperature and pressure of stratum when porous medium is high-permeability,
considering the volume coefficient of stratum crude oil at the (i + 1) th pressure point above the formation temperature and the saturation pressure when the porous medium is hypertonic;
when porous medium hypotonicity is considered, the volume coefficient of the crude oil of the stratum under the temperature and the pressure of the stratum is considered;
the volume coefficient of the formation crude oil at the (i + 1) th pressure point above the formation temperature and the saturation pressure is considered when the porous medium is hypotonic.
In step 1, the maximum pressure born by the first sand filling pipe and the second sand filling pipe is 70 MPa.
In the step 2, the sealing test and the vacuumizing operation are carried out on the hypertonic reservoir simulation assembly and the hypotonic reservoir simulation assembly, and the specific steps are as follows:
heating the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly to 150 ℃, and pumping N into the sand filling pipe, the glass cylinder, the pipeline connected between the sand filling pipe and the glass cylinder and the pipeline connected between the pressure sensors by using a high-pressure displacement pump2Sealing performance test is carried out on the sealing device to ensure that the sealing performance is good, and then the outlet valve is opened to discharge N2And the sand filling pipe, the glass cylinder and the pipelines are pumped by a vacuum pump until the vacuum state is reached.
The invention has the beneficial effects that: the device is stable and reliable, reasonable in structure and simple and convenient to operate, and the volume coefficient of the formation crude oil under the high-temperature and high-pressure environment of the reservoir porous medium can be accurately measured and considered by using the device;
the invention can simultaneously test and consider the volume coefficient of the crude oil of the stratum under the conditions of high permeability and low permeability of the porous medium of the reservoir, and the volume coefficient of the crude oil of the stratum under the condition of the tested porous medium of the reservoir is closer to the volume coefficient of the crude oil in the real reservoir;
the invention considers the influence of the adsorption effect of the porous medium on the volume coefficient of the crude oil in the stratum, considers the characteristics of large specific area and adsorption effect of the porous medium, considers the condition of the porous medium, is closer to the volume coefficient of the crude oil in the stratum under the real reservoir condition, and more favorably guides the reserve calculation and production practice.
Drawings
FIG. 1 is a schematic view showing the structure of a crude oil volume coefficient measuring apparatus according to the present invention;
in the figure: 1 is first sand pack pipe, 2 is the second sand pack pipe, 3 is the valve, 4 is a glass section of thick bamboo, 5 is pressure sensor, 6 is temperature sensor, 7 is first test tube, 8 is double-cylinder gasometer, 9 is the high-pressure displacement pump, 10 is the collector, 11 is the joining in marriage the appearance ware, 12 is the oven, 13 is a second glass section of thick bamboo, 14 is the second test tube.
For a person skilled in the art, other relevant figures can be obtained from the above figures without inventive effort.
Detailed Description
The technical solution of the present invention is further illustrated by the following specific examples.
Example one
A crude oil volume coefficient measuring device comprises a high-pressure displacement pump 9, a sample matching device 11, a high-permeability reservoir simulation component, a low-permeability reservoir simulation component, a double-cylinder gas meter 8, a pressure sensor 5, an oven 12 and a collector 10,
the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are in a parallel connection and communicated structure, inlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are communicated with an outlet of a sample preparation device 11 through a first pipeline, a four-way valve is arranged on the first pipeline, four ports of the four-way valve are respectively connected with the outlet of the sample preparation device 11, the inlet of the high-permeability reservoir simulation assembly, the inlet of the low-permeability reservoir simulation assembly and a pressure sensor 5, the inlet of the sample preparation device 11 is communicated with an outlet of a high-pressure displacement pump 9 through a second pipeline, the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are both connected with a temperature sensor 6, the sample preparation device 11, the high-permeability reservoir simulation assembly, the low-permeability reservoir simulation assembly, the pressure sensor 5 and the temperature sensor 6 are all arranged in a stratum, an oven 12 for heating is also arranged in the stratum, and signal output ends of the pressure sensor 5 and the temperature sensor 6 are connected with a signal input end of a collector 10, the outlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with the inlet of the test tube through a gas pipeline, and the outlet of the test tube is connected with the inlet of the double-cylinder gas meter 8.
Example two
On the basis of the first embodiment, the high-permeability reservoir simulation assembly is composed of a first sand filling pipe 1 and a first glass tube 4, the inlet of the first sand filling pipe 1 is connected with the port of the four-way valve through a third pipeline, the outlet of the first sand filling pipe 1 is connected with the inlet of the first glass tube 4 in series through a fourth pipeline, and the outlet of the first glass tube 4 is communicated with the inlet of the first test tube 7 through a fifth pipeline.
The hypotonic reservoir simulation assembly is composed of a second sand filling pipe 2 and a second glass tube 13, the inlet of the second sand filling pipe 2 is connected with the port of the four-way valve through a sixth pipeline, the outlet of the second sand filling pipe 2 is connected with the inlet of the second glass tube 13 in series through a seventh pipeline, and the outlet of the second glass tube 13 is communicated with the inlet of the second test tube 14 through an eighth pipeline.
The temperature sensor 6 is respectively connected with the first glass cylinder 4 and the second glass cylinder 13 through temperature measuring pipelines.
EXAMPLE III
On the basis of the second embodiment, the first sand-filled pipe 1 and the second sand-filled pipe 2 are filled with quartz sand with different meshes.
The first glass cylinder 4 and the second glass cylinder 13 are both high-temperature high-pressure glass cylinders.
The collector 10 uses a computer host with an acquisition card.
All be provided with valve 3 on first pipeline, second pipeline, third pipeline, fourth pipeline, fifth pipeline, sixth pipeline, seventh pipeline and the eighth pipeline.
Example four
A method for measuring the volume coefficient of crude oil comprises the following steps:
the method comprises the steps that quartz sand with different meshes is filled in a first sand filling pipe 1 and a second sand filling pipe 2 respectively, and the first sand filling pipe and the second sand filling pipe are connected with a first glass cylinder 4 and a second glass cylinder 13 in series respectively, so that a high-permeability reservoir simulation assembly and a low-permeability reservoir simulation assembly are formed, wherein the maximum pressure borne by the first sand filling pipe and the second sand filling pipe is 70 MPa;
the method comprises the following steps of carrying out independent sealing test on a high-permeability reservoir simulation assembly and a low-permeability reservoir simulation assembly, and carrying out vacuumizing operation on the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly after the test is finished, wherein the method comprises the following specific steps: heating the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly to 150 ℃, and pumping N into the sand filling pipe, the glass cylinder, the pipeline connected between the sand filling pipe and the glass cylinder and the pipeline connected between the pressure sensors by using a high-pressure displacement pump2Sealing performance test is carried out on the sealing device to ensure that the sealing performance is good, and then the outlet valve is opened to discharge N2The sand filling pipe, the glass cylinder and the pipelines are pumped by a vacuum pump until the vacuum state is reached;
heating the formation to a temperature required for the experiment by using an oven 12;
step 4, injecting formation crude oil into the high-permeability reservoir simulation assembly:
pumping the formation crude oil in the sample preparation device into a high-permeability reservoir simulation assembly formed by connecting a first sand filling pipe 1 and a first glass cylinder 4 in series by using a high-pressure displacement pump 9, starting a pressure sensor 5 to monitor the pressure in the high-permeability reservoir simulation assembly when the pump is slowly pumped until the pressure displayed by the pressure sensor 5 is stabilized to the formation pressure
the formation crude oil in the sample proportioning device is transferred into a second sand filling pipe 2 by a high-pressure displacement pump 9In the hypotonic reservoir simulation assembly formed by connecting the second glass cylinders 13 in series, when the pump is slowly fed, the pressure sensor 5 is opened to monitor the pressure in the hypotonic reservoir simulation assembly until the pressure displayed by the pressure sensor 5 is stabilized to the formation pressure
closing the inlet and outlet valves of the hypotonic reservoir simulation assembly, opening the inlet valve of the hypertonic reservoir simulation assembly, returning the pump position of the high-pressure displacement pump 9 to zero, and keeping a part of the formation crude oil in the first glass cylinder 4 after passing through the first sand filling pipe 1 at a constant pressure
Flashing to the ground standard condition, and allowing the pressure in the hypertonic reservoir simulation assembly to be stabilized
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
closing the inlet and outlet valves of the high-permeability reservoir simulation assembly, opening the inlet valve of the low-permeability reservoir simulation assembly, and after the pump position of the high-pressure displacement pump 9 returns to zero, similarly waiting for the pressure in the low-permeability reservoir simulation assembly to be stabilized as
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
Step 8, calculating volume coefficient under multi-pressure high-permeability condition:
sequentially controlling the pressure of the simulation assembly of the high permeability reservoir to
Under each pressure test condition of the high-permeability reservoir simulation assembly, the pump inlet amount of the high-pressure displacement pump 9 is sequentially
Controlling the volume of ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
sequentially controlling the pressure of the simulation assembly of the low permeability reservoir to
Under each pressure test condition of the hypotonic reservoir simulation assembly, the pump inlet amount of the high-pressure displacement pump 9 is sequentially
The volume of the ground flash oil is
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
finally obtaining the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device;
the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 3, 4 … n-th pressure point:
further, the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 4, 5 … n pressure points:
wherein the content of the first and second substances,
considering the volume coefficient of stratum crude oil under the temperature and pressure of stratum when porous medium is high-permeability,
considering the volume coefficient of stratum crude oil at the (i + 1) th pressure point above the formation temperature and the saturation pressure when the porous medium is hypertonic;
when porous medium hypotonicity is considered, the volume coefficient of the crude oil of the stratum under the temperature and the pressure of the stratum is considered;
the volume coefficient of the formation crude oil at the (i + 1) th pressure point above the formation temperature and the saturation pressure is considered when the porous medium is hypotonic.
EXAMPLE five
First, N was pumped at 150 ℃ by the high-pressure displacement pump 92Carrying out leak detection and pressure test on the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly, raising the pressure to 60Mpa, stabilizing for 4 hours, stabilizing the pump pressure and ensuring good sealing property; opening the outlet valve to discharge N2And a vacuum pump is used for evacuating the sand filling pipe, the high-temperature high-pressure glass cylinder system and each pipeline which are connected in series to a vacuum state;
then, heating the system to the formation temperature of 101.65 ℃ through an oven 12, turning on a high-pressure displacement pump, transferring a certain amount of uniformly stirred formation crude oil in a sample preparation device 11 into a high-permeability reservoir simulation assembly, turning on a pressure sensor when the pump feeding is slow, monitoring the pressure in a sand filling pipe by using a collector 10, and controlling the pumping pressure of a high-pressure displacement pump 9 to stabilize the pressure of the high-permeability system to the formation pressure of 38.87 MPa; similarly, transferring the crude oil of the stratum into a low-permeability reservoir simulation assembly, and controlling the pumping pressure of a high-pressure displacement pump to stabilize the pressure of a low-permeability system to be 38.87MPa of the stratum pressure;
then, closing an inlet valve and an outlet valve of the hypotonic reservoir simulation assembly, opening an inlet valve of the hypertonic reservoir simulation assembly, opening an outlet valve of a hypertonic system after the pump position of the high-pressure displacement pump is reset to zero, flashing a part of formation crude oil in the high-temperature high-pressure glass cylinder 4 after the sand filling pipe is subjected to constant pressure of 38.87MPa to the ground standard condition (0.1MPa, 20 ℃), and recording the pump feeding amount of the high-pressure displacement pump to be 11.7162ml when the pressure in the hypertonic system is stabilized to be 38.87 MPa;
calculating the volume of the ground flash oil to be 10ml by utilizing the mass and the density of the ground flash oil, and further calculating the volume coefficient of the stratum crude oil under the high-permeability condition to be 1.1716 when the pressure is 38.87 MPa; closing an inlet and outlet valve of a high-permeability reservoir simulation assembly, opening an inlet valve of a low-permeability reservoir simulation assembly, after the pump position of a high-pressure displacement pump is reset to zero, similarly, when the pressure in the low-permeability reservoir simulation assembly is stabilized to be 38.87MPa, recording the pumping amount of the high-pressure displacement pump to be 11.7048ml, calculating the volume of ground flash oil to be 10ml by utilizing the mass and the density of the ground flash oil, and further calculating the volume coefficient of the stratum crude oil under the low-permeability condition to be 1.1705 when the pressure is 38.87 MPa;
and then, repeating the steps, and sequentially controlling the pressure of the hypertonic reservoir simulation assembly to be 35MPa, 30MPa, 25MPa, 20MPa and 15 MPa. Under the test condition of the high-permeability reservoir simulation component, the pumping volumes of the high-pressure displacement pumps are 11.7514ml, 11.8168ml, 11.8909ml, 11.9744ml and 12.0686ml in sequence, and the volume of ground flash oil is controlled to be 10 ml; further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
And repeating the steps, and sequentially controlling the pressures of the hypotonic reservoir simulation components to be 35MPa, 30MPa, 25MPa, 20MPa and 15 MPa. Under the test condition of the hypertonic reservoir simulation component, the pump-in amount of the displacement pump is 11.7404ml, 11.8058ml, 11.8801ml, 11.9628ml and 12.0573ml in sequence, and the volume of ground flash oil is controlled to be 10 ml; further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
The volume coefficients of the formation crude oil are calculated by using the formulas (1) to (4) when a porous medium high-permeability model and a low-permeability model are considered, and the volume coefficients are shown in the following table 1:
TABLE 1 comparison of volume coefficients of formation crude oil in models considering porous medium high permeability and low permeability
Spatially relative terms, such as "upper," "lower," "left," "right," and the like, may be used in the embodiments for ease of description to describe one element or feature's relationship to another element or feature as illustrated in the figures. It will be understood that the spatial terms are intended to encompass different orientations of the device in use or operation in addition to the orientation depicted in the figures. For example, if the device in the figures is turned over, elements described as "below" other elements or features would then be oriented "above" the other elements or features. Thus, the exemplary term "lower" can encompass both an upper and a lower orientation. The device may be otherwise oriented (rotated 90 degrees or at other orientations) and the spatially relative descriptors used herein interpreted accordingly.
Moreover, relational terms such as "first" and "second," and the like, may be used solely to distinguish one element from another element having the same name, without necessarily requiring or implying any actual such relationship or order between such elements.
The present invention has been described in detail, but the above description is only a preferred embodiment of the present invention, and is not to be construed as limiting the scope of the present invention. All equivalent changes and modifications made within the scope of the present invention shall fall within the scope of the present invention.
Claims (10)
1. A crude oil volume coefficient measuring device is characterized in that: comprises a high-pressure displacement pump, a sample matching device, a high-permeability reservoir simulation component, a low-permeability reservoir simulation component, a double-cylinder gas meter, a pressure sensor, an oven and a collector,
the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are communicated in parallel, inlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are communicated with an outlet of the sample preparation device through a first pipeline, a four-way valve is arranged on the first pipeline, four ports of the four-way valve are respectively connected with the outlet of the sample preparation device, the inlet of the high-permeability reservoir simulation assembly, the inlet of the low-permeability reservoir simulation assembly and the pressure sensor, the inlet of the sample preparation device is communicated with the outlet of the high-pressure displacement pump through a second pipeline, the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with the temperature sensor, the sample preparation device, the high-permeability reservoir simulation assembly, the low-permeability reservoir simulation assembly, the pressure sensor and the temperature sensor are arranged in the stratum, and the drying oven for heating is also arranged in the stratum, the signal output ends of the pressure sensor and the temperature sensor are connected with the signal input end of the collector, the outlets of the high-permeability reservoir simulation assembly and the low-permeability reservoir simulation assembly are connected with the inlet of the test tube through a gas pipeline, and the outlet of the test tube is connected with the inlet of the double-cylinder gas meter.
2. The apparatus for determining a volumetric coefficient of crude oil according to claim 1, wherein: the high-permeability reservoir simulation assembly is composed of a first sand filling pipe and a first glass cylinder, an inlet of the first sand filling pipe is connected with a port of the four-way valve through a third pipeline, an outlet of the first sand filling pipe is connected with an inlet of the first glass cylinder in series through a fourth pipeline, and an outlet of the first glass cylinder is communicated with an inlet of the first test tube through a fifth pipeline.
3. The apparatus for determining a volumetric coefficient of crude oil according to claim 2, wherein: the hypotonic reservoir simulation assembly is composed of a second sand filling pipe and a second glass cylinder, an inlet of the second sand filling pipe is connected with a port of the four-way valve through a sixth pipeline, an outlet of the second sand filling pipe is connected with an inlet of the second glass cylinder in series through a seventh pipeline, and an outlet of the second glass cylinder is communicated with an inlet of the second test tube through an eighth pipeline.
4. The apparatus for determining a volumetric coefficient of crude oil according to claim 3, wherein: the temperature sensor is respectively connected with the first glass cylinder and the second glass cylinder through temperature measuring pipelines.
5. The apparatus for determining a volumetric coefficient of crude oil according to claim 3, wherein: the first sand filling pipe and the second sand filling pipe are filled with quartz sand with different meshes.
6. The apparatus for determining a volumetric coefficient of crude oil according to claim 3, wherein: the first glass cylinder and the second glass cylinder are both high-temperature and high-pressure glass cylinders.
7. The apparatus for determining a volumetric coefficient of crude oil according to claim 1, wherein: the collector adopts a computer host with an acquisition card.
8. The apparatus for determining a volumetric coefficient of crude oil according to claim 3, wherein: valves are arranged on the first pipeline, the second pipeline, the third pipeline, the fourth pipeline, the fifth pipeline, the sixth pipeline, the seventh pipeline and the eighth pipeline.
9. A method for measuring the volume coefficient of crude oil is characterized by comprising the following steps: the method comprises the following steps:
step 1, establishing a simulation component:
filling quartz sand with different meshes into the first sand filling pipe and the second sand filling pipe respectively, and connecting the first sand filling pipe and the second sand filling pipe in series with the first glass cylinder and the second glass cylinder respectively to form a high-permeability reservoir simulation assembly and a low-permeability reservoir simulation assembly;
step 2, sealing test and vacuumizing:
carrying out independent sealing test on the hypertonic reservoir simulation assembly and the hypotonic reservoir simulation assembly, and after the test is finished, carrying out vacuumizing operation on the hypertonic reservoir simulation assembly and the hypotonic reservoir simulation assembly;
step 3, heating the stratum:
heating the stratum to the temperature required by the experiment by using an oven;
step 4, injecting formation crude oil into the high-permeability reservoir simulation assembly:
pumping the crude oil in the formation in the sample preparation device into a high-permeability reservoir simulation assembly formed by connecting a first sand filling pipe and a first glass cylinder in series by using a high-pressure displacement pump, and starting a pressure sensor to monitor the pressure in the high-permeability reservoir simulation assembly when the pump is slowly fedForce until the pressure indicated by the pressure sensor stabilizes at formation pressure
Step 5, injecting formation crude oil into the hypotonic reservoir simulation assembly:
transferring the formation crude oil in the sample preparation device into a low-permeability reservoir simulation assembly formed by connecting a second sand filling pipe and a second glass cylinder in series by using a high-pressure displacement pump, starting a pressure sensor to monitor the pressure in the low-permeability reservoir simulation assembly when the pump is slowly pumped until the pressure displayed by the pressure sensor is stabilized to the formation pressure
Step 6, calculating the volume coefficient under the high-permeability condition of the pressure:
closing the inlet and outlet valves of the hypotonic reservoir simulation assembly, opening the inlet valve of the hypertonic reservoir simulation assembly, enabling the pump position of the high-pressure displacement pump to return to zero, and enabling a part of crude oil in the formation in the first glass cylinder after passing through the first sand filling pipe to have constant pressure
Flashing to the ground standard condition, and allowing the pressure in the hypertonic reservoir simulation assembly to be stabilized
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
Step 7, calculating the volume coefficient under the hypotonic condition of the pressure:
closing the inlet and outlet valves of the high-permeability reservoir simulation assembly, opening the inlet valve of the low-permeability reservoir simulation assembly, and after the pump position of the high-pressure displacement pump is reset to zero, similarly waiting for the pressure in the low-permeability reservoir simulation assembly to be stabilized to be
Time recording high pressure displacement pump intake
Calculating the volume of the ground flash oil according to the mass and the density of the ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
Step 8, calculating volume coefficient under multi-pressure high-permeability condition:
sequentially controlling the pressure of the simulation assembly of the high permeability reservoir to
Under each pressure test condition of the high-permeability reservoir simulation assembly, the pumping-in amount of the high-pressure displacement pump is sequentially
Controlling the volume of ground flash oil
Further calculating the pressure as
Volume coefficient of time-formation crude oil under high permeability condition
Step 9, calculating volume coefficient under multi-pressure hypotonic condition:
sequentially controlling the pressure of the simulation assembly of the low permeability reservoir to
Under each pressure test condition of the hypotonic reservoir simulation assembly, the pumping-in amount of the high-pressure displacement pump is sequentially
The volume of the ground flash oil is
Further calculating the pressure as
Volume coefficient of time-formation crude oil under low-permeability condition
Step 10, obtaining a volume coefficient:
finally obtaining the crude oil volume coefficient of the formation crude oil in a crude oil volume coefficient measuring device;
the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 3, 4 … n-th pressure point:
wherein the content of the first and second substances,
considering the volume coefficient of stratum crude oil under the temperature and pressure of stratum when porous medium is high-permeability,
considering the volume coefficient of stratum crude oil at the (i + 1) th pressure point above the formation temperature and saturation pressure when the porous medium is hypertonic;
when porous medium hypotonicity is considered, the volume coefficient of the crude oil of the stratum under the temperature and the pressure of the stratum is considered;
the volume coefficient of the formation crude oil at the (i + 1) th pressure point above the formation temperature and the saturation pressure is considered when the porous medium is hypotonic.
10. The method for determining the volume factor of crude oil according to claim 9, wherein: the volume coefficient of the formation crude oil in the crude oil volume coefficient measuring device is calculated by the following method:
volume coefficient of 1 st pressure point:
volume factor of 2, 4, 5 … n pressure points:
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Application publication date: 20220510 |