CN114166999A - Oil reservoir type gas storage simulation experiment device and method - Google Patents

Oil reservoir type gas storage simulation experiment device and method Download PDF

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Publication number
CN114166999A
CN114166999A CN202111457167.7A CN202111457167A CN114166999A CN 114166999 A CN114166999 A CN 114166999A CN 202111457167 A CN202111457167 A CN 202111457167A CN 114166999 A CN114166999 A CN 114166999A
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China
Prior art keywords
liquid
core
core model
pressure
reservoir
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CN202111457167.7A
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Chinese (zh)
Inventor
李宜强
齐桓
王文东
陈小龙
刘哲宇
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China University of Petroleum Beijing CUPB
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China University of Petroleum Beijing CUPB
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Priority to CN202111457167.7A priority Critical patent/CN114166999A/en
Publication of CN114166999A publication Critical patent/CN114166999A/en
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    • GPHYSICS
    • G01MEASURING; TESTING
    • G01NINVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00

Abstract

The invention provides a simulation experiment device and a simulation experiment method for an oil reservoir type gas storage, wherein the simulation experiment device for the oil reservoir type gas storage comprises the following steps: the core model is arranged in the core holder, and a confining pressure cavity is formed between the core model and the core holder; the injection system comprises an internal pressure injection unit and a confining pressure injection unit, the monitoring system comprises a temperature monitoring unit, a pressure monitoring unit and a saturation monitoring unit, the control system is connected with the monitoring system, and the rotating frame drives the core holder to rotate in a vertical plane; and the metering unit is used for metering the amount of the medium flowing out of the core model. The oil reservoir type gas storage simulation experiment device and method provided by the invention can systematically realize the experiment of combining oil displacement experiments in various modes with gas storage cooperative development.

Description

Oil reservoir type gas storage simulation experiment device and method
Technical Field
The invention relates to the technical field of oil and gas production of oil and gas fields, in particular to a simulation experiment device and method for an oil reservoir type gas storage.
Background
At present, the technical level of oil and gas field development in China is continuously improved, certain effect is achieved on oil field development, and more problems and challenges are faced at the same time. Under the international background of the shortage of petroleum energy supply in the world, the strategic position of natural gas in national economic development is gradually obvious, natural gas energy in partial oil fields of China is sufficient, if only crude oil is extracted without recovery or reutilization of natural gas, a large amount of natural gas resources are wasted and lost, and the establishment of a gas storage is used for solving the problem of natural gas storage.
The oil-gas field exploitation has modes of continuous gas-gas injection (CGI), gas-water alternating-gas injection (WAG) and gas-assisted gravity drive (GAGD), and in order to avoid the waste of natural gas energy, the development mode of gas-assisted gravity drive is mostly adopted for oil-gas field exploitation, but the gas reservoir construction in China is still in the early theoretical exploration research stage, particularly the research on the oil reservoir type gas reservoir is very little, and the oil reservoir reconstruction gas reservoir needs a large amount of physical simulation experiments for analysis and evaluation. At present, an effective simulation experiment system and method for the system are lacked, and technical support is provided for the analysis and evaluation of an oil displacement technology and the cooperative development of a gas storage reservoir.
Therefore, it is urgently needed to develop an oil reservoir type gas storage simulation experiment device and method, which can systematically realize the oil displacement experiment combining with the gas storage cooperative development experiment in multiple ways to promote the technical level improvement of oil reservoir reconstruction gas storage.
Disclosure of Invention
The invention provides an oil reservoir type gas storage reservoir simulation experiment device and method, which can realize an experiment of simulating gas-assisted gravity displacement of reservoir oil and combining gas storage reservoir cooperative development and provide technical support for analyzing and evaluating a gas-assisted gravity displacement of reservoir oil technology and combining gas storage reservoir cooperative development.
In order to achieve the above object, the present invention provides a reservoir type gas storage simulation experiment apparatus, comprising:
a core model;
the core holder is used for holding the core, the core model is arranged in the core holder, and a confining pressure cavity is formed between the core model and the core holder;
the injection system comprises an internal pressure injection unit and a confining pressure injection unit, the internal pressure injection unit is configured to selectively inject a first liquid, a second liquid and experimental gas into the core model, the confining pressure injection unit is communicated with the confining pressure cavity, and the confining pressure injection unit is configured to inject the first liquid into the confining pressure cavity;
the monitoring system comprises a temperature monitoring unit, a pressure monitoring unit and a saturation monitoring unit, wherein the temperature monitoring unit is used for monitoring the temperature in the confining pressure cavity, the pressure monitoring unit is used for monitoring the pressure in the rock core model, and the saturation monitoring unit is used for monitoring the saturation of the first liquid and the second liquid injected into the rock core model;
the control system is electrically connected with the monitoring system and is used for acquiring pressure data, temperature data and saturation data monitored by the monitoring system and respectively maintaining the pressure data, the temperature data and the saturation data within a preset range;
a rotating frame configured to drive the core holder to rotate in a vertical plane;
and the metering unit is communicated with the interior of the core model and is configured to monitor the respective amounts of the first liquid, the second liquid and the experimental gas flowing out of the interior of the core model.
The oil reservoir type gas storage simulation experiment device provided by the invention can realize various experiments such as horizontal displacement simulation, vertical displacement simulation and the like by driving the core holder to rotate in a vertical plane to a horizontal state, a vertical state or an inclined state at any angle through the rotating frame, and can realize the simulation of oil reservoir reconstruction gas storage, carry out multiple injection-production experiments of the gas storage, truly simulate the operation process of the gas storage, the oil, water and gas quantities produced inside the core model can be conveniently measured by connecting the measuring units, the experiment of oil displacement experiment combined with gas storage reservoir collaborative development of multiple modes can be systematically simulated, the requirement of physical simulation experiment cooperatively built by top gas injection gravity flooding and oil reservoir type gas storage reservoir is met, technical support is provided for analyzing and evaluating gas-assisted gravity oil displacement combined with gas storage reservoir collaborative development, and technical support is provided for the full-period operation of rebuilding the oil reservoir type gas storage reservoir in the later stage of oil reservoir development.
In one possible implementation, the core model includes:
the core comprises a core body, wherein one end of the core body is provided with a first plug, the other end of the core body is provided with a second plug, the first plug is connected with an inlet pipeline, the second plug is connected with an outlet pipeline, the inlet pipeline and the outlet pipeline are both communicated with the core body, a first valve is arranged on the inlet pipeline, and a second valve is arranged on the outlet pipeline;
the sleeve is sleeved on the periphery of the core body.
In one possible embodiment, the internal pressure injection unit includes:
the liquid injection unit comprises two liquid storage elements, a first pump is arranged in each liquid storage element, and the outlet end of the first pump is communicated with the inlet pipeline;
the gas injection unit comprises a gas storage element, a pressurizing element and a flowmeter, the gas storage element is communicated with the inlet end of the pressurizing element, the flowmeter is communicated with the outlet end of the pressurizing element, and the flowmeter is communicated with the inlet pipeline.
In a possible implementation manner, the confining pressure injection unit comprises a second pump, a peripheral pipeline is connected to the outside of the core holder, the second pump is communicated with the confining pressure cavity through the peripheral pipeline, and a third valve is arranged on the peripheral pipeline.
In one possible implementation, the temperature monitoring unit comprises a temperature acquisition probe disposed within the confined chamber;
the pressure monitoring unit comprises a plurality of pressure sensors, and the pressure sensors are distributed on the surface of the rock core body;
the saturation monitoring unit comprises a plurality of saturation monitoring electrodes, and the saturation monitoring electrodes extend into the core body from the surface of the core body.
In a possible implementation manner, the metering unit is detachably connected with the outlet pipeline or the first valve through a connecting pipeline, a back pressure valve is connected to the connecting pipeline, and a third pump is connected to the back pressure valve.
In a possible implementation manner, the core mold further comprises a negative pressure unit, the negative pressure unit is communicated with the inlet pipeline, and the negative pressure unit is used for providing negative pressure for the interior of the core mold.
In one possible implementation, the core holder further comprises a heating device, the heating device is arranged in the core holder, and the heating device is electrically connected with the control system.
The invention also provides a simulation experiment method of the oil reservoir type gas storage, which is applied to the simulation experiment device of the oil reservoir type gas storage and comprises the following steps:
connecting an outlet pipeline with a connecting pipeline, rotating the rock core holder and the rock core model to be in a horizontal state, and injecting a first liquid into the confining pressure cavity;
sequentially injecting the first liquid and the second liquid into the core model in a horizontal state so as to enable the first liquid and the second liquid in the core model to be in a saturated state respectively;
when the core holder and the core model are in a horizontal state, injecting a first displacement medium into the core model, and measuring the amount of the first liquid and the amount of the second liquid flowing out of the core model;
rotating the core holder and the core model injected with the first displacement medium to a vertical state or an inclined state;
blocking the outlet pipeline, and changing the connection state of the connecting pipeline from the connection with the outlet pipeline to the connection with the first valve;
and when the core holder and the core model injected with the first displacement medium rotate to a vertical state or an inclined state, injecting a second displacement medium into the core model, and metering the amount of the first liquid, the amount of the second liquid and the amount of experimental gas flowing out of the core model.
In a possible implementation manner, after the rotating the core holder and the core model injected with the first displacement medium to the vertical state or the inclined state, injecting a second displacement medium into the core model, and metering the amount of the first liquid, the amount of the second liquid and the amount of the experimental gas flowing out of the core model, the method further comprises:
and when the first liquid and the second liquid do not flow out from the core model any more, alternately injecting and releasing the second displacement medium into the core model, maintaining the pressure in the core model within a preset pressure range, and measuring the amount of the experimental gas flowing out from the core model.
In a possible implementation manner, the method further includes, after connecting the outlet pipe and the connection pipe, rotating the core holder and the core model to a horizontal state, and injecting a first liquid into the confining pressure chamber, and before sequentially injecting the first liquid and a second liquid into the core model in the horizontal state so that the first liquid and the second liquid in the core model are respectively in a saturated state, the method further includes:
vacuumizing the interior of the core model;
and in the process of injecting the first liquid and the second liquid, monitoring the temperature in the confining pressure cavity, the pressure in the core model and the respective saturation of the first liquid and the second liquid injected into the core model in real time through a monitoring system.
In one possible implementation manner, after the first liquid and the second liquid are sequentially injected into the core model in the horizontal state, so that the first liquid and the second liquid in the core model are respectively in a saturated state, and before the first displacement medium is injected into the core model and the amount of the first liquid and the amount of the second liquid flowing out of the core model are measured when the core holder and the core model are in the horizontal state, the method further includes:
standing for a preset time; the preset time is greater than 72 hours.
The oil reservoir type gas storage simulation experiment device and the method provided by the invention can realize various experiments such as horizontal displacement simulation, vertical displacement simulation and the like by driving the core holder to rotate in a vertical plane to a horizontal state, a vertical state or an inclined state at any angle through the rotating frame, and can realize the simulation of oil reservoir reconstruction gas storage, carry out multiple injection-production experiments of the gas storage, truly simulate the operation process of the gas storage, the oil, water and gas quantities produced inside the core model can be conveniently measured by connecting the measuring units, the experiment of reservoir collaborative development is combined in the oil displacement experiment of multiple modes can be systematically simulated, the requirement of physical simulation experiment of top gas injection gravity drive and reservoir type reservoir collaborative construction is met, technical support is provided for analysis and evaluation of gas auxiliary gravity oil displacement combined reservoir collaborative development, and improvement of the full-period operation technical level of reservoir type reservoir reconstruction in the later stage of reservoir development is facilitated.
According to the oil reservoir type gas storage simulation experiment device and method provided by the invention, under the condition of truly simulating the formation temperature and pressure, top gas injection development and gas storage construction can be uniformly researched, oil gas production and gas storage construction are organically and uniformly researched, oil and gas are generated to form circulating flow, the amount of media driven out from a core model can be accurately measured, and experiment errors are reduced.
The oil reservoir type gas storage simulation experiment device and the method provided by the invention have the advantages that the functions are comprehensive, the measurement is convenient, the size of the core holder is large, the core holder can rotate at any angle, the state of the whole period of the gradual intervention operation of the top gas injection development and the gas storage can be simulated, and great convenience is provided for the high-temperature and high-pressure physical simulation experiment constructed by the top gas injection development and the oil reservoir type gas storage collaborative development.
The oil reservoir type gas storage simulation experiment device provided by the invention realizes real-time monitoring of the pressure and saturation of different parts of the core model, and is convenient for drawing a pressure field diagram and a saturation field diagram in the model at each stage of the experiment.
According to the oil reservoir type gas storage simulation experiment method provided by the invention, the connection state of the oil reservoir type gas storage simulation experiment device is simply changed, so that the early-stage horizontal water flooding development process, the middle-stage top gas injection gravity flooding development process and the later-stage gas storage building operation process can be simulated, the experiment can be continuously carried out, the oil flooding process and the gas storage collaborative development process can be evaluated by measuring the amount of the medium flowing out of the core model, and the technical support is provided for the gas storage building.
In addition to the technical problems solved by the embodiments of the present invention, the technical features constituting the technical solutions, and the advantages brought by the technical features of the technical solutions, other technical problems that can be solved by the oil reservoir type gas storage simulation experiment apparatus and method provided by the embodiments of the present invention, other technical features included in the technical solutions, and advantages brought by the technical features will be further described in detail in the detailed description.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
Fig. 1 is a schematic structural diagram of a horizontal displacement stage of an oil reservoir type gas storage simulation experiment device provided by an embodiment of the invention;
FIG. 2 is a schematic structural diagram of a vertical displacement stage of an oil reservoir type gas storage simulation experiment apparatus according to an embodiment of the present invention;
fig. 3 is a schematic structural diagram of a gas storage construction phase of the oil reservoir type gas storage simulation experiment apparatus provided in the embodiment of the present invention;
fig. 4 is a schematic structural diagram of a core holder of the reservoir-type gas storage simulation experiment apparatus according to the embodiment of the present invention;
fig. 5 is a left side view of a core holder of the reservoir-type gas storage simulation experiment apparatus according to the embodiment of the present invention;
fig. 6 is a change curve of the extraction degree and the water content and gas content in the horizontal water flooding and top gas injection processes in the first embodiment of the oil reservoir type gas storage simulation experiment method according to the embodiment of the present invention;
fig. 7 is a change curve of reservoir capacity and recovery ratio during multiple rounds of gas injection of a gas reservoir in the first embodiment of the experimental method for simulating an oil reservoir type gas reservoir according to the embodiment of the present invention;
FIG. 8 is a flow chart of a method of an experimental apparatus for simulating an oil reservoir type gas storage according to an embodiment of the present invention;
FIG. 9 is a flow chart of another method of a reservoir-type gas storage simulation experiment apparatus according to an embodiment of the present invention;
fig. 10 is a partial flowchart of a method of an oil reservoir type gas storage simulation experiment apparatus according to an embodiment of the present invention.
Description of reference numerals:
10-a core model;
11-a core body;
111-a first plug;
112-a second plug;
113-an inlet conduit;
114-an outlet conduit;
115-a first valve;
116-a second valve;
12-a sleeve;
121-peripheral pipes;
122-a third valve;
20-a core holder;
21-confining pressure cavity;
30-an injection system;
31-internal pressure injection means;
311-a liquid injection unit;
3111-a liquid storage element;
3112-a first pump;
312-a gas injection unit;
3121-a gas storage element;
3122-a pressurizing element;
3123-a flow meter;
313-a fourth valve;
32-confining pressure injection unit;
321-a second pump;
40-a monitoring system;
41-temperature monitoring unit;
411-temperature acquisition probe;
42-a pressure monitoring unit;
421-a pressure sensor;
422-first outlet;
43-saturation monitoring unit;
431-a saturation monitoring electrode;
432-a second outlet;
50-a control system;
60-a rotating frame;
61-an operating wheel;
70-a metering unit;
71-connecting a pipe;
81-a back pressure valve;
82-a third pump;
90-oil reservoir type gas storage simulation experiment device.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention clearer, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings, and it is obvious that the described embodiments are some, but not all embodiments of the present invention. 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 principle of gas-assisted gravity flooding is to continuously inject gas from an injection well at the top of an oil and gas field by using the density difference between oil and gas and produce from a production well at the lower part of an oil reservoir. The gas-assisted gravity flooding utilizes the super-covering effect of gas to form a secondary gas cap at the top of a reservoir, the secondary gas cap is gradually moved to the bottom of an oil layer to replace the pore space occupied by the crude oil initially, and simultaneously the crude oil is discharged into a horizontal production well under the action of gravity. Gas injection assisted gravity flooding enables a stable displacement front to be achieved, allowing higher recovery than previously possible.
After the oil reservoir is exploited, the whole oil field is observed, the oil reservoir has a perfect injection-production well pattern and detailed exploration and development data, and meanwhile, a large amount of natural gas exists in the oil reservoir, so that a large amount of waste and loss can still be caused if the natural gas is not recovered or reused. Because of the huge demand of natural gas in China, the problem of balance of supply and demand of natural gas can be solved when a gas storage is built. At present, a physical simulation experiment method for top gas injection development and gas storage cooperative construction is still blank in technology.
In view of the above background, the oil reservoir type gas reservoir simulation experiment device and method provided by the invention can perform unified research on top gas injection development and gas reservoir construction under the condition of truly simulating formation temperature and pressure, can realize multiple oil displacement experiments such as horizontal displacement simulation and vertical displacement simulation, can realize simulation of oil reservoir reconstruction of a gas reservoir, perform multiple injection and production experiments of the gas reservoir, truly simulate the operation process of the gas reservoir, provide technical support for analyzing and evaluating gas-assisted gravity displacement and gas reservoir collaborative development, and contribute to improvement of the full-period operation technical level of the oil reservoir type gas reservoir reconstructed at the later stage of development.
The following describes an oil reservoir type gas storage simulation experiment device and method provided by the embodiment of the invention with reference to the accompanying drawings.
Referring to fig. 1 and 4, the present invention provides a reservoir-type gas storage simulation experiment apparatus 90, including: the core-type gas sensor comprises a core model 10, a core holder 20, an injection system 30, a monitoring system 40, a control system 50, a rotating frame 60 and a metering unit 70, wherein the core model 10 is arranged inside the core holder 20, and a confining pressure cavity 21 is formed between the core model 10 and the core holder 20. The core model 10 may be a natural core or an artificial core made of epoxy resin, and the core holder 20 may be a hollow structure for simulating the environment of the formation.
The injection system 30 comprises an internal pressure injection unit 31 and a confining pressure injection unit 32, wherein the internal pressure injection unit 31 is configured to selectively inject a first liquid, a second liquid and experimental gas into the core model 10, the confining pressure injection unit 32 is communicated with the confining pressure cavity 21, and the confining pressure injection unit 32 is configured to inject the first liquid into the confining pressure cavity 21.
The monitoring system 40 comprises a temperature monitoring unit 41, a pressure monitoring unit 42 and a saturation monitoring unit 43, wherein the temperature monitoring unit 41 is used for monitoring the temperature in the confining pressure cavity 21, the pressure monitoring unit 42 is used for monitoring the pressure in the core model 10, and the saturation monitoring unit 43 is used for monitoring the saturation of the first liquid and the second liquid injected into the core model 10; the control system 50 is electrically connected to the monitoring system 40, and the control system 50 is configured to collect pressure data, temperature data, and saturation data monitored by the monitoring system 40, and maintain the pressure data, the temperature data, and the saturation data within a preset range, respectively. The monitoring system 40 can be arranged to ensure that the high-temperature and high-pressure environment of the formation can be really simulated, the pressure and the oil saturation of different parts of the core model 10 can be monitored in real time, and the high-temperature and high-pressure experimental environment can be provided.
The rotating frame 60 is configured to drive the core holder 20 to rotate in a vertical plane; the metering unit 70 is in communication with the interior of the core model 10, and the metering unit 70 is configured to monitor the respective amounts of the first liquid, the second liquid, and the experimental gas flowing out of the interior of the core model 10. The switching of the vertical state, the horizontal state and the inclined state of the core holder 20 can be conveniently realized through the rotating frame 60, and the experiment operation is convenient.
Referring to fig. 1 and 2, the oil reservoir type gas storage simulation experiment device 90 provided by the invention can realize various experiments such as simulation of horizontal displacement, vertical displacement and the like by driving the core holder 20 to rotate in a vertical plane through the rotating frame 60 into a horizontal state, a vertical state or an inclined state at any angle, can realize simulation of oil reservoir reconstruction of a gas storage, can perform multi-round injection and production experiments of the gas storage, can truly simulate the operation process of the gas storage, can conveniently measure the amount of oil, water and gas produced inside the core model 10 by connecting the measuring unit 70, can systematically realize simulation of oil displacement experiments in various modes and experiments of gas storage collaborative development, meets the requirements of top gravity displacement and oil reservoir type gas storage collaborative gas injection construction physical simulation experiments, and provides technical support for analysis and evaluation of gas-assisted gravity and oil storage collaborative development, and technical support is provided for the full-period operation of rebuilding the oil reservoir type gas storage at the later stage of oil reservoir development.
In one possible embodiment, the core model 10 is disposed inside the core holder 20, and may have a holding structure inside the core holder 20, such that the core model 10 is held inside the core holder 20 and the core model 10 is detachable from the inside of the core holder 20.
In a possible implementation mode, the driving core holder 20 is rotatably connected in the rotating frame 60, and in order to facilitate the rotating frame 60 to drive the core holder 20 to rotate in the vertical plane, an operating wheel 61 is arranged on the rotating frame 60, and the rotating frame 60 can drive the core holder 20 to rotate in the vertical plane by rotating the operating wheel 61. For example, after the rotating frame 60 rotates the core holder 20 by 90 ° in the vertical plane, the rotated state of the core holder 20 may be fixed, that is, the core holder 20 and the core model 10 are rotated from the horizontal state to the vertical state and may be fixed in the vertical state, or the core holder 20 and the core model 10 are rotated from the vertical state to the horizontal state and may be fixed in the horizontal state. The structure of the rotating frame 60 is not particularly limited, and the core holder 20 may be driven to rotate in a vertical plane.
In a possible implementation mode, the core model 10 adopts an artificial core with the diameter of 10cm, the thickness of 80cm and the length of 150cm, and because the core size is large, the gravity effect can be effectively simulated, the gravity effect in the displacement process is prominent, and the defects that the pore volume in the core model 10 with a smaller size is smaller, the dead volume of the whole device cannot be ignored, and the metering is inaccurate can be overcome.
Referring to fig. 1 and 4, in a possible implementation mode, the core holder 20 is a closed hollow metal cabin capable of holding the core model 10 and resisting high temperature and high pressure, the core holder 20 can simultaneously bear 50MPa pressure and 150 ℃, the core model 10 of the core holder 20 is loaded inside the core holder 20, and the sealing performance of the whole core holder 20 is ensured in use.
In one possible implementation, the core model 10 includes: the core comprises a core body 11 and a sleeve 12, wherein one end of the core body 11 is provided with a first plug 111, the other end of the core body 11 is provided with a second plug 112, the first plug 111 is connected with an inlet pipeline 113, the second plug 112 is connected with an outlet pipeline 114, the inlet pipeline 113 and the outlet pipeline 114 are both communicated with the core body 11, a first valve 115 is arranged on the inlet pipeline 113, and a second valve 116 is arranged on the outlet pipeline 114. The sleeve 12 is sleeved on the periphery of the core body 11.
The first plug 111 and the second plug 112 are used for fixing the core model 10 in the core holder 20, and the first plug 111 and the second plug 112 also prevent the medium entering the core model 10 from leaking from the two ends of the core body 11.
The two ends of the sleeve 12 are also respectively sleeved on the peripheries of the first plug 111 and the second plug 112, the sleeve 12 is tightly connected with the core body 11 to play a role in preventing leakage, and the sleeve 12 can be made of high-temperature and high-pressure resistant materials, such as rubber, so that the sleeve 12 is ensured to tightly wrap the core body 11 under experimental conditions.
Referring to fig. 1 and 4, in one possible implementation, the internal pressure injection unit 31 includes: liquid injection unit 311 and gas injection unit 312, liquid injection unit 311 includes two liquid storage components 3111, is provided with first pump 3112 in the liquid storage component 3111, and the exit end of first pump 3112 communicates with inlet pipeline 113.
The two fluid reservoirs 3111 are used for storing water and oil, respectively, and supplying water and oil, respectively, and the first pump 3112 is used for transferring the fluid stored in the fluid reservoirs 3111 to the inlet pipe 113 and further into the core mold 10.
In one possible implementation, the first pump 3112 may be a dual cylinder constant velocity constant pressure pump.
In one possible embodiment, the liquid storage element 3111 may be a container provided with a piston, by which movement the liquid is delivered to the inlet duct 113.
Referring to fig. 1 and 2, the gas injection unit 312 includes a gas storage element 3121, a pressurizing element 3122, and a flow meter 3123, the gas storage element 3121 communicates with an inlet end of the pressurizing element 3122, the flow meter 3123 communicates with an outlet end of the pressurizing element 3122, and the flow meter 3123 communicates with the inlet duct 113. The pressurizing element 3122 is used for pressurizing the gas flowing out of the gas storage element 3121 to the pressure required by the experiment, and the flowmeter 3123 is used for measuring the flow rate of the gas conveyed into the core model 10
In one possible implementation, the gas storage element 3121 may be a gas cylinder.
The two liquid storage elements 3111 of the liquid injection unit 311 and the flow meter 3123 of the gas injection unit 312 communicate with the inlet duct 113 through the fourth valve 313. The fourth valve 313 may be a six-way valve, and the liquid stored in the two liquid storage elements 3111 and the gas stored in the gas storage element 3121 may be selectively controlled to enter the inlet duct 113 through the fourth valve 313.
The confining pressure injection unit 32 comprises a second pump 321, a peripheral pipeline 121 is connected to the outside of the core holder 20, the second pump 321 is communicated with the confining pressure cavity 21 through the peripheral pipeline 121, and a third valve 122 is arranged on the peripheral pipeline 121. The confining pressure injection unit 32 can form a high temperature and high pressure condition in the confining pressure chamber 21, the second pump 321 can inject liquid into the confining pressure chamber 21 for simulating the environment of underground water, and the third valve 122 is used for controlling the opening and closing of the peripheral pipeline 121. The second pump 321 may be a constant pressure pump for injecting liquid into the confining pressure chamber 21 to supplement the pressure in the confining pressure chamber 21.
Referring to fig. 1 and 4, the temperature monitoring unit 41 includes a temperature acquisition probe 411, and the temperature acquisition probe 411 is disposed in the confining pressure cavity 21; the pressure monitoring unit 42 comprises a plurality of pressure sensors 421, and the plurality of pressure sensors 421 are distributed on the surface of the core body 11; the saturation monitoring unit 43 includes a plurality of saturation monitoring electrodes 431, and the plurality of saturation monitoring electrodes 431 all extend from the surface of the core body 11 into the core body 11.
The temperature acquisition probe 411 is used for monitoring the temperature of the core model 10; the pressure sensors 421 may be uniformly distributed along the length direction of the core model 10, and monitor the pressures at different positions of the core model 10 to realize multi-point pressure acquisition; the plurality of saturation monitoring electrodes 431 can be uniformly distributed along the length direction of the core model 10, and the saturations of different positions of the core model 10 are monitored, so that multi-point saturation collection is realized.
In a possible implementation manner, grooves are machined in different positions on the surface of the core body 11 by means of electric drills and the like, holes corresponding to the grooves are machined in the sleeve 12, and the saturation monitoring electrode 431 extends into the grooves of the core body 11 through the holes in the sleeve 12, so that the saturation monitoring electrode 431 can monitor the saturation of the first liquid and the second liquid in the core body 11.
In one possible implementation, the control system 50 may include temperature control system software, pressure acquisition software, and saturation monitoring software.
Referring to fig. 4 and 5, the temperature acquisition probe 411 is connected to the temperature control system software of the control system 50 through a wire, so as to transmit the temperature data acquired by the temperature acquisition probe 411 to the temperature control system software of the control system 50, so as to maintain the temperature data within a preset range; the pressure sensors 421 are respectively connected with the pressure acquisition software of the control system 50 through first outgoing lines 422, so that pressure data acquired by the pressure sensors 421 are conveniently transmitted to the pressure acquisition software of the control system 50, and the pressure data are maintained within a preset range; the saturation monitoring electrodes 431 are respectively connected with the saturation monitoring software of the control system 50 through second outgoing lines 432, so that the saturation data acquired by the saturation monitoring electrodes 431 can be conveniently transmitted to the saturation monitoring software of the control system 50, and the saturation data can be maintained in a preset range.
Referring to fig. 2 and 3, in a possible embodiment, the metering unit 70 is detachably connected to the outlet pipe 114 or the first valve 115 through a connecting pipe 71, a back-pressure valve 81 is connected to the connecting pipe 71, and a third pump 82 is connected to the back-pressure valve 81. The medium from the outlet pipe 114 is fed into the metering unit 70 through the connecting pipe 71 for real-time metering.
The back pressure valve 81 is used for ensuring that the pressure of the core model 10 cannot be relieved from the connecting pipeline 71, the third pump 82 can be a constant pressure pump, and the third pump 82 needs to be controlled to reduce the pressure at a constant speed through a manual or programmed means, so that the effect of constant-speed gas production is achieved, and the gas production process of the operation of the gas storage is ensured to be carried out at a constant speed and stably.
It will be readily appreciated that in simulating horizontal flooding and simulating top injection development, the metering unit 70 is connected to the outlet pipe 114 by the connecting pipe 71. When gas production and gas injection are carried out at the same end of the simulated gas storage, the metering unit 70 is connected with the first valve 115 through the connecting pipeline 71.
In a possible embodiment, the metering unit 70 is an oil, gas and water three-phase separation metering device, and can respectively meter the volumes of oil, gas and water.
In a possible implementation manner, the reservoir-type gas storage simulation experiment apparatus 90 provided by the present invention further includes a negative pressure unit, the negative pressure unit is communicated with the inlet pipe 113, and the negative pressure unit is configured to provide negative pressure to the inside of the core model 10. The negative pressure unit is arranged to help collect accurate experimental data, and the phenomenon that air mixed in the core model 10 influences the collection result of gas is avoided.
In one possible embodiment, the negative pressure unit may be in communication with the interior of the core model 10 by accessing the fourth valve 313. The negative pressure unit may be a negative pressure pump.
In a possible implementation manner, the reservoir-type gas storage simulation experiment device 90 provided by the invention further comprises a heating device, wherein the heating device is arranged in the core holder 20 and is electrically connected with the control system 50.
In a possible embodiment, the heating device may be a heater for heating the liquid injected in the confining pressure chamber 21 to simulate a high-temperature groundwater environment. The control system 50 controls the operation of the heating device according to the temperature data acquired by the temperature acquisition probe 411. For example, if the temperature data collected by the temperature collecting probe 411 is lower than the experimental standard temperature, the control system 50 controls the heating device to start heating, and if the temperature data collected by the temperature collecting probe 411 reaches the experimental standard temperature, the control system 50 controls the heating device to stop heating, thereby implementing thermostatic control.
In a possible embodiment, the liquid injected in the confining pressure cavity 21 can be water or oil.
According to the oil reservoir type gas storage simulation experiment device provided by the invention, under the condition of truly simulating the formation temperature and pressure, top gas injection development and gas storage construction can be uniformly researched, oil gas production and gas storage construction are organically and uniformly researched, oil and gas are generated to form circulating flow, a medium driven out from the core model 10 can be accurately measured, and experiment errors are reduced.
The oil reservoir type gas storage simulation experiment device provided by the invention has comprehensive functions, is convenient to measure, has a large core holder 20, can rotate at any angle, can simulate the state of the whole period of top gas injection development and gradual intervention operation of a gas storage, and provides great convenience for high-temperature and high-pressure physical simulation experiments constructed by top gas injection development and oil reservoir type gas storage collaborative development.
The oil reservoir type gas storage simulation experiment device provided by the invention can effectively simulate gravity and calculate the storage capacity, and overcomes the defects that the traditional sand filling model is not resistant to scouring and cannot simulate the physical properties of a real compact reservoir.
The oil reservoir type gas storage simulation experiment device provided by the invention realizes real-time monitoring of the pressure and saturation of different parts of the core model 10, and is convenient for drawing a pressure field diagram and a saturation field diagram in the model at each stage of the experiment.
Referring to fig. 1 and 8, the present invention further provides a reservoir type gas storage simulation experiment method, which is applied to the reservoir type gas storage simulation experiment apparatus 90, and includes:
s10, connecting an outlet pipeline and a connecting pipeline, rotating the core holder and the core model to be in a horizontal state, and injecting a first liquid into the confining pressure cavity;
s20, sequentially injecting a first liquid and a second liquid into the core model in the horizontal state so as to enable the first liquid and the second liquid in the core model to be in a saturated state respectively;
s30, when the core holder and the core model are in a horizontal state, injecting a first displacement medium into the core model, and measuring the amount of a first liquid and the amount of a second liquid flowing out of the core model;
s40, rotating the core holder and the core model injected with the first displacement medium to a vertical state or an inclined state;
s50, blocking the outlet pipeline, and changing the connection state of the connecting pipeline from the connection with the outlet pipeline to the connection with the first valve;
and S60, when the core holder and the core model injected with the first displacement medium rotate to a vertical state or an inclined state, injecting a second displacement medium into the core model, and measuring the amount of the first liquid, the amount of the second liquid and the amount of the experimental gas flowing out of the core model.
According to the oil reservoir type gas storage simulation experiment method provided by the invention, the connection state of the oil reservoir type gas storage simulation experiment device 90 is simply changed, so that the early-stage horizontal water flooding development process, the middle-stage top gas injection gravity flooding development process and the later-stage oil reservoir reconstruction gas storage process can be simulated, the experiment can be continuously carried out, the oil flooding process and the gas storage collaborative development process can be evaluated by measuring the amount of the medium flowing out of the core model 10, and the technical support is provided for the gas storage construction.
The steps S10 and S20 are experimental condition preparation stages for establishing experimental conditions for simulating early-stage horizontal flooding by connecting the outlet pipe 114 with the connecting pipe 71 and rotating the core holder 20 and the core model 10 to a horizontal state so that the inlet pipe 113 and the outlet pipe 114 are substantially in a horizontal position.
And injecting a first liquid into the confining pressure cavity 21, wherein the pressure in the confining pressure cavity 21 is greater than the pressure at the injection end of the core model 10. For simulating a real formation environment, the first liquid is injected into the confining pressure cavity 21 by opening the third valve 122 and injecting the first liquid into the confining pressure cavity 21 through the second pump 321. The first liquid injected into the confining pressure cavity 21 can be oil or water, and the pressure in the confining pressure cavity 21 is kept to be 2 MPa-4 MPa higher than the pressure at the injection end of the core model 10. For example, the pressure at the injection end of the core model 10 may be 29MPa to 57MPa, and the pressure in the corresponding confining pressure chamber 21 may be 33MPa to 59MPa, so that the pressure in the confining pressure chamber 21 may be higher than the pressure at the injection end of the core model 10 by 2MPa to 4 MPa.
In one possible embodiment, a first fluid is injected into the core model 10 in a horizontal state, such that the first fluid in the core model 10 is saturated. The first liquid may be water, and the fourth valve 313 may be controlled to supply water to the liquid storage element 3111 of the two liquid storage elements 3111 storing water into the core model 10, so that the core model 10 becomes water saturated.
In one possible embodiment, a second fluid is injected into the core model 10 in a horizontal state, such that the second fluid in the core model 10 is saturated. The second liquid may be oil, and the fourth valve 313 may be controlled to supply oil to the two liquid storage elements 3111, in which the oil is stored, into the core model 10. The core model 10 is brought into an oil-saturated state on the basis of the water-saturated state.
In a possible implementation, the first liquid may be water, the second liquid may be oil, and the first liquid is injected into the confining pressure cavity 21 to simulate the environment in which groundwater exists. And simulating the states of stored water and oil in the stratum.
In step S30, a development process of horizontal flooding in the early stage of reservoir exploitation is simulated, and the first displacement medium may be a first liquid or an experimental gas. The horizontal water flooding experiment may be implemented by controlling the fourth valve 313 so that the two liquid storage elements 3111, in which water is stored, supply water into the core model 10, and drive out water and oil stored in the core model 10 through the water supply, and the water and oil stored in the core model 10 are driven out and then enter the connecting pipe 71 from the outlet pipe 114, and finally flow into the metering unit 70.
In one possible implementation, a first displacement medium is injected into the core model 10 and the amount of the first liquid and the amount of the second liquid flowing out of the interior of the core model 10 are measured; in this step, the medium flowing out of the core model 10 includes: the first fluid and the second fluid injected into the core model 10 in step S20, where the first displacement medium is the same as the first fluid injected into the core model 10 in step S20.
The core holder 20 and the core model 10 shown in fig. 1 are in a horizontal state, and the core holder 20 and the core model 10 shown in fig. 2 are rotated in a vertical state.
And S40 and S50, establishing experimental conditions for the top gas injection gravity drive development in the middle stage of reservoir exploitation. It is to be understood that step S50 may be executed first, and step S40 may be executed. Referring to fig. 3, the connection relationship of the reservoir-type gas storage simulation experiment device 90 is changed through step S50, and the connection pipeline 71 is changed from being connected with the outlet pipeline 114 to being connected with the first valve 115, so that the connection route between the core model 10 and the metering unit 70 is changed, and the effect of simultaneous injection and production is achieved.
Step S60 is a process of simulating a top gas injection development process and a process of reconstructing a reservoir from an oil reservoir, and the measurement unit 70 is an oil, water, gas, and three-phase separation measurement device, and is configured to measure the amount of the first liquid, the amount of the second liquid, and the amount of the experimental gas flowing out of the core model 10, which may be volume measurements of each liquid. The second displacement medium may be the first liquid or the test gas.
Referring to fig. 2 and 9, in a possible implementation manner, when the core holder 20 and the core model 10 injected with the first displacement medium are rotated to a vertical state or an inclined state, the second displacement medium is injected into the core model 10, and the amount of the first liquid, the amount of the second liquid and the amount of the experimental gas flowing out of the core model 10 are measured, the experimental method for simulating the reservoir type gas reservoir further includes:
and S70, when the first liquid and the second liquid do not flow out from the core model, alternately injecting and releasing a second displacement medium into the core model, so that the pressure in the core model is maintained within a preset pressure range, and the amount of the experimental gas flowing out from the core model is measured.
Step S70 is to simulate an operation process of the reservoir reconstruction gas storage, and when the first liquid and the second liquid do not flow out from the core model 10, it means that water and oil inside the core model 10 are completely displaced, the reservoir has been reconstructed into the gas storage, and the second displacement medium may be an experimental gas. For example, the predetermined pressure may be in the range of 19MPa to 37MPa, and for example, the predetermined pressure may be 19MPa, 25MPa, 30MPa or 37 MPa. By closing the first valve 115, the top gas production process is prepared after the pressure in the core model 10 is stabilized, and the gas production process of the operation of the gas storage is simulated.
In a possible implementation manner, referring to fig. 1 and 10, after the step S10 of connecting the outlet pipe and the connecting pipe, rotating the core holder and the core model to a horizontal state, and injecting the first liquid into the confining pressure cavity, and before the step S20 of sequentially injecting the first liquid and the second liquid into the core model in the horizontal state so as to make the first liquid and the second liquid in the core model respectively in a saturated state, the reservoir-type gas reservoir simulation experiment method provided by the present invention further includes:
s11, vacuumizing the interior of the core model;
and S12, in the process of injecting the first liquid and the second liquid, monitoring the temperature in the confining pressure cavity, the pressure in the core model and the respective saturation of the first liquid and the second liquid injected into the core model in real time through a monitoring system.
The step S11 is to evacuate the interior of the core model 10 for exhausting the air in the core model 10, so as to avoid the air in the core model 10 from affecting the accuracy of the experimental result, and may be to evacuate the interior of the core model 10 by starting the negative pressure unit. The negative pressure unit may be a vacuum pump.
In step S12, the monitoring system 40 is activated to monitor the temperature in the confining pressure chamber 21, the pressure in the core model 10, and the saturation of the injected medium in the core model 10 in real time. In step S12, the temperature in the confining pressure cavity 21 needs to be maintained and controlled to be the same as the actual reservoir temperature, and the pressure in the core model 10 needs to be maintained to be the same as the actual reservoir pressure.
Typically, the actual reservoir temperature is 50 ℃ to 200 ℃ and the actual reservoir pressure is 19MPa to 37 MPa. For example, the actual reservoir temperature is 89 ℃, and thus the temperature in the confining pressure cavity 21 is controlled to be maintained at 89 ℃; the actual reservoir pressure was 25MPa, thus the pressure in the controlled core model 10 was 25 MPa.
In a possible implementation manner, after injecting a first displacement medium into the core model and measuring the amount of the first liquid and the amount of the second liquid flowing out of the core model when the core holder and the core model are in a horizontal state and before rotating the core holder and the core model injected with the first displacement medium to a vertical state or an inclined state at step S40, the method further includes:
and injecting a second displacement medium into the core model 10, and measuring the amount of the first liquid, the amount of the second liquid and the amount of the experimental gas flowing out of the core model 10.
Here, an experimental procedure for horizontal gas flooding was performed after simulating horizontal water flooding. The respective volumes of the media flowing out of the core model 10 during the displacement process are measured by the measuring unit 70. The fourth valve 313 may be controlled to stop providing liquid for both the liquid storage elements 3111 and allow the gas stored in the gas storage element 3121 to flow out, the experimental gas stored in the gas storage element 3121 enters the pressurizing element 3122 and is pressurized, and then is provided into the core model 10 after being measured by the flow meter 3123, the flow meter 3123 is used for measuring the flow rate of the gas provided into the core model 10, and the gas injection speed can be adjusted according to experimental requirements by setting the flow meter 3123.
In one possible implementation, the second displacement medium may be a test gas for simulating oil recovery in a horizontal gas injection development.
In step S60, a second displacement medium is injected into the core model 10, and the amount of the first liquid, the amount of the second liquid, and the amount of the experimental gas flowing out of the core model 10 are measured, where the fourth valve 313 is controlled to stop supplying liquid to both of the two liquid storage elements 3111 and to flow out the gas stored in the gas storage element 3121, the gas stored in the gas storage element 3121 enters the pressurizing element 3122 and is then pressurized, and then is supplied into the core model 10 after being measured by the flow meter 3123, and the flow meter 3123 is used to measure the flow rate of the gas supplied into the core model 10.
In step S50, the outlet conduit 114 is blocked, possibly by closing the second valve 116, so that the outlet conduit 114 is blocked, so that in step S60 a second displacement medium is injected into the core model 10 through the inlet conduit 113, the medium stored in the core model 10 is expelled and flows from the connecting conduit 71 into the metering unit 70.
In a possible implementation manner, after the step S20 of sequentially injecting the first liquid and the second liquid into the core model 10 in a horizontal state to make the first liquid and the second liquid in the core model 10 respectively in a saturated state, and before the step S30 of injecting the first displacement medium into the core model 10 and measuring the amount of the first liquid and the amount of the second liquid flowing out of the core model 10 when the core holder 20 and the core model 10 are in a horizontal state, the reservoir simulation experiment method provided by the present invention further includes: s21, standing for a preset time; wherein the preset time is more than 72 hours. And standing for a preset time, wherein the main purpose is to ensure that the core model 10 containing water is aged after being fully contacted with oil, so that the adsorption balance state is achieved.
It should be noted that, during the gas production process, the second pump 321 connected to the third valve 122 needs to be controlled or programmed at a constant speed to reduce the pressure, so as to ensure that the gas production process of the gas storage operation is performed at a constant speed and stably. Meanwhile, the pressure of the second pump 321 is controlled to be higher than the pressure of the connecting pipeline 71 by 2MPa to 3MPa in an artificial or programmed mode.
And finally, by arranging the measurement results of the measurement unit 70, comparing the oil production amount and the gas production amount in the development process of each round, drawing a pressure field diagram and a pressure change process inside the core model 10, drawing a saturation field diagram inside the core model 10, and analyzing the oil and water migration rule inside the core model 10. And various types of experiments can be continuously carried out subsequently, such as experiments of changing the displacement angle, changing the temperature and the pressure, changing the type of injected gas, changing the used first displacement medium and second displacement medium and the like.
In order to illustrate that the oil reservoir type gas storage simulation experiment method provided by the invention can provide technical support for analysis and evaluation of a gas-assisted gravity displacement technology in combination with gas storage cooperative development, the results of the first embodiment are listed below.
Example one
In this embodiment, according to the above oil reservoir type gas storage simulation experiment method, an indoor physical simulation experiment is performed on the whole oil reservoir development process, and on the basis of the early development of the oil reservoir, a multi-round injection-production process for reconstructing the gas storage at a later stage is simulated.
The core body 11 of the core model 10 adopts a natural full-diameter core with the diameter of 10cm and the length of 89cm, the gas logging permeability of the natural core is 96.35 millidarcy, m Darcy, md for short, and the porosity is 18.2%.
The experimental temperature of this embodiment is 92 ℃, the upper limit pressure collected by the pressure sensor 421 during the experiment is 37MPa, and the lower limit pressure is 19MPa respectively.
After the step S10 and the step S20 are executed, the step S30 is executed, the development process of the oil reservoir exploitation early-stage horizontal oil displacement is simulated, the water content of the core model 10 is driven to 90% in the development process of the early-stage horizontal oil displacement, the step S40, the step S50 and the step S60 are sequentially executed, the top gas injection gravity drive development mode is started, until the oil is not discharged, the time is considered to be the time for building the gas storage at this time, the first valve 115 is intermittently opened, and the gas storage building operation process of multiple rounds of gas injection and gas production of top injection and top recovery is carried out.
In the experimental process, the step S30 is executed to simulate horizontal oil displacement in the early stage of reservoir exploitation, the step S60 is executed to simulate the top gas injection gravity flooding mode, and the extraction degree, the water content and the gas content change curves of the horizontal water flooding and top gas injection processes shown in fig. 6 are drawn by comparing the extraction degree, the water content and the gas content change curves of the step S30 and the step S60.
As can be seen from fig. 6, the abscissa PV represents the pore volume of the core model 10, the left ordinate represents the degree of extraction, and the right ordinate represents the water content and gas content. The extent of production represents the ratio of the amount of oil produced to the original oil volume within the core model 10.
When the PV value is 0-0.7, the method is a horizontal water flooding exploitation mode at the early stage of oil reservoir exploitation, the exploitation degree of the exploited oil mass is in an increased state, and horizontal water injection can continuously obtain oil;
when the PV value reaches 0.7, the water content in the horizontal flooding is close to 100 percent, which means that the oil can not be continuously produced almost by horizontal water injection, and at the moment, the horizontal water injection is stopped and the top gas injection gravity flooding mode is adopted for production;
when the PV value is 0.7-1.5, the development mode is a top gas injection gravity drive mode, gas injected from the top drives out water in the core model 10, and oil in the core model 10 is also driven out, wherein when the PV value is 0.9-1.0, the extraction degree is in a fast rising state, which means that the top gas injection gravity drive mode can continue to extract oil which cannot be driven out in the water drive process; when the PV value is 1.0-1.2, the production degree is increased and slowed down, which means that the capacity of improving the recovery ratio of the top gas injection gravity flooding is reduced; when the PV value reaches 1.2, the gas content of the produced fluid reaches 100 percent, which means that the produced fluid is completely gas and oil can not be produced any more, and the time is considered to be the time for building the gas storage.
Fig. 7 is a graph showing the change in the reservoir volume and the recovery factor when the gas reservoir undergoes 12 gas injections, the abscissa shows the operation time, the time when the operation time is 0 is the time when the PV value is 1.5 in fig. 6, the reservoir volume is 180L, and the pressure inside the core model 10 is 33 MPa. Considering that the pressure interval of the operation of the gas storage is 19-37 MPa, gas is continuously injected into the core model 10 until the pressure inside the core model 10 reaches 37MPa, the gas injection into the core model 10 is stopped, at the moment, the storage capacity is 205L, standing is carried out for 2 hours, gas production is started until the pressure inside the core model 10 reaches a stable and balanced state, the gas production is finished until the pressure inside the core model 10 is 19MPa, the gas production is finished, at the moment, the storage capacity is 108L, and the first gas production is finished.
And after the first gas production is finished, stabilizing for 2h, continuously injecting gas into the gas storage to increase the pressure inside the core model 10 to 37MPa from 19MPa, stabilizing for 2h, starting the second gas production to reduce the pressure inside the core model 10 to 19MPa from 37MPa, stopping gas production, and after stabilizing for 2h, continuously injecting gas into the gas storage to reciprocate to realize multiple rounds of gas production and gas injection.
The total operation process of the gas storage can be divided into two stages from the storage capacity change and the process of each round of operation: wherein the operation time interval is 0-90 h, and residual oil in the core model 10 can be brought out in the gas production process as a storage and production linkage stage, so that the oil production rate can be improved; after the operation time interval is 90 hours, the oil residual in the core model 10 is not brought out in a pure gas reservoir operation stage, and the oil extraction rate is not increased.
The storage and production linkage stage not only meets the peak regulation requirement of the gas storage, ensures that gas is produced on time, but also ensures that residual oil is carried out along with gas injection and gas production in the linkage stage, and increases the ultimate enhanced recovery ratio level of the oil field. The method has better consistency with the field reality on the whole, and the reliability of the experimental method is shown.
Through analyzing the experimental result, the oil reservoir type gas storage simulation experimental method provided by the invention visually shows two stages in the operation process of the gas storage, and can help guide and adjust the production system and production parameters in the actual production process.
The oil reservoir type gas storage simulation experiment method provided by the invention can be realized on the same oil reservoir type gas storage simulation experiment device 90 by simulating three processes of early development, development mode conversion and full life cycle of later-stage reconstruction of an oil reservoir, and only the connection mode of pipelines needs to be changed in the experiment process, so that the operation steps of the experiment are greatly simplified, and a large amount of manpower and material resources are saved.
According to the oil reservoir type gas storage simulation experiment method provided by the invention, high-temperature and high-pressure experiment environments can be provided by changing the core models 10 with different lengths and different types, and a simulation experiment can be performed by changing the rotation angles of the core models 10 and the core holders 20 in the experiment process.
It should be noted that the numerical values and numerical ranges referred to in this application are approximate values, and there may be some error due to the manufacturing process, and the error may be considered to be negligible by those skilled in the art.
In the description of the present invention, it is to be understood that the terms "center", "length", "width", "thickness", "top", "bottom", "upper", "lower", "left", "right", "front", "rear", "vertical", "horizontal", "inner", "outer", "axial", "circumferential", and the like, are used to indicate an orientation or positional relationship based on that shown in the drawings, merely to facilitate the description of the invention and to simplify the description, and do not indicate or imply that the position or element referred to must have a particular orientation, be of particular construction and operation, and thus, are not to be construed as limiting the invention.
Furthermore, the terms "first", "second" and "first" are used for descriptive purposes only and are not to be construed as indicating or implying relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of the present invention, "a plurality" means at least two, e.g., two, three, etc., unless specifically limited otherwise.
In the present invention, unless otherwise expressly specified or limited, the terms "mounted," "connected," "secured," and the like are to be construed broadly and can, for example, be fixedly connected, detachably connected, or integral; may be mechanically coupled, may be electrically coupled or may be in communication with each other; either directly or indirectly through intervening media, such as through internal communication or through an interaction between two elements. The specific meanings of the above terms in the present invention can be understood by those skilled in the art according to specific situations.
In the present invention, unless otherwise expressly stated or limited, "above" or "below" a first feature means that the first and second features are in direct contact, or that the first and second features are not in direct contact but are in contact with each other via another feature therebetween. Also, the first feature being "on," "above" and "over" the second feature includes the first feature being directly on and obliquely above the second feature, or merely indicating that the first feature is at a higher level than the second feature. A first feature being "under," "below," and "beneath" a second feature includes the first feature being directly under and obliquely below the second feature, or simply meaning that the first feature is at a lesser elevation than the second feature.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and the modifications or the substitutions do not make the essence of the corresponding technical solutions depart from the scope of the technical solutions of the embodiments of the present invention.

Claims (12)

1. The utility model provides an oil reservoir type gas storage reservoir simulation experiment device which characterized in that includes:
a core model (10);
the core holder (20), the core model (10) is arranged inside the core holder (20), and a confining pressure cavity (21) is formed between the core model (10) and the core holder (20);
an injection system (30), wherein the injection system (30) comprises an internal pressure injection unit (31) and a confining pressure injection unit (32), the internal pressure injection unit (31) is configured to selectively inject a first liquid, a second liquid and an experimental gas into the core model (10), the confining pressure injection unit (32) is communicated with the confining pressure cavity (21), and the confining pressure injection unit (32) is configured to inject the first liquid into the confining pressure cavity (21);
the monitoring system (40) comprises a temperature monitoring unit (41), a pressure monitoring unit (42) and a saturation monitoring unit (43), wherein the temperature monitoring unit (41) is used for monitoring the temperature in the confining pressure cavity (21), the pressure monitoring unit (42) is used for monitoring the pressure in the core model (10), and the saturation monitoring unit (43) is used for monitoring the saturation of the first liquid and the second liquid injected into the core model (10);
the control system (50) is electrically connected with the monitoring system (40), and the control system (50) is used for acquiring pressure data, temperature data and saturation data monitored by the monitoring system (40) and respectively maintaining the pressure data, the temperature data and the saturation data within preset ranges;
a rotating frame (60), the rotating frame (60) configured to drive the core holder (20) to rotate in a vertical plane;
a metering unit (70), the metering unit (70) being in communication with an interior of the core model (10), and the metering unit (70) being configured to monitor respective amounts of the first liquid, the second liquid, and the experimental gas flowing out of the interior of the core model (10).
2. The reservoir-type gas reservoir simulation experiment device of claim 1, wherein the core model (10) comprises:
the core comprises a core body (11), wherein one end of the core body (11) is provided with a first plug (111), the other end of the core body (11) is provided with a second plug (112), the first plug (111) is connected with an inlet pipeline (113), the second plug (112) is connected with an outlet pipeline (114), the inlet pipeline (113) and the outlet pipeline (114) are both communicated with the core body (11), a first valve (115) is arranged on the inlet pipeline (113), and a second valve (116) is arranged on the outlet pipeline (114);
the sleeve (12), sleeve (12) cover is established on the periphery of rock core body (11).
3. The reservoir-type gas reservoir simulation experiment device of claim 2, wherein the internal pressure injection unit (31) comprises:
a liquid injection unit (311), the liquid injection unit (311) comprising two liquid storage elements (3111), a first pump (3112) being arranged in the liquid storage element (3111), an outlet end of the first pump (3112) being in communication with the inlet pipe (113);
a gas injection unit (312), the gas injection unit (312) comprising a gas storage element (3121), a pressurizing element (3122), and a flow meter (3123), the gas storage element (3121) communicating with an inlet end of the pressurizing element (3122), the flow meter (3123) communicating with an outlet end of the pressurizing element (3122), and the flow meter (3123) communicating with the inlet duct (113).
4. The reservoir-type gas storage simulation experiment device as claimed in claim 1, wherein the confining pressure injection unit (32) comprises a second pump (321), a peripheral pipeline (121) is connected to the outside of the core holder (20), the second pump (321) is communicated with the confining pressure cavity (21) through the peripheral pipeline (121), and a third valve (122) is arranged on the peripheral pipeline (121).
5. The reservoir type gas storage simulation experiment device of claim 2,
the temperature monitoring unit (41) comprises a temperature acquisition probe (411), and the temperature acquisition probe (411) is arranged in the confining pressure cavity (21);
the pressure monitoring unit (42) comprises a plurality of pressure sensors (421), and the pressure sensors (421) are distributed on the surface of the core body (11);
the saturation monitoring unit (43) comprises a plurality of saturation monitoring electrodes (431), and the saturation monitoring electrodes (431) extend into the core body (11) from the surface of the core body (11).
6. The reservoir type gas storage simulation experiment device according to claim 2, wherein the metering unit (70) is detachably connected with the outlet pipeline (114) or the first valve (115) through a connecting pipeline (71), a back pressure valve (81) is connected to the connecting pipeline (71), and the back pressure valve (81) is connected with a third pump (82).
7. The reservoir-type gas reservoir simulation experiment device of claim 2, further comprising a negative pressure unit, wherein the negative pressure unit is communicated with the inlet pipeline (113), and is used for providing negative pressure for the interior of the core model (10).
8. The reservoir-type gas reservoir simulation experiment device as set forth in any one of claims 1 to 6, further comprising a heating device, wherein the heating device is disposed in the core holder 20 and is electrically connected to the control system 50.
9. A reservoir-type gas reservoir simulation experiment method applied to the reservoir-type gas reservoir simulation experiment apparatus (90) according to any one of claims 1 to 8, comprising:
connecting an outlet pipeline (114) with a connecting pipeline (71), rotating the core holder (20) and the core model (10) to be in a horizontal state, and injecting a first liquid into the confining pressure cavity (21);
sequentially injecting the first liquid and the second liquid into the core model (10) in a horizontal state so as to enable the first liquid and the second liquid in the core model (10) to be in a saturated state respectively;
when the core holder (20) and the core model (10) are in a horizontal state, injecting a first displacement medium into the core model (10), and measuring the amount of the first liquid and the amount of the second liquid flowing out of the core model (10);
rotating the core holder (20) and the core model (10) injected with the first displacement medium to a vertical state or an inclined state;
blocking the outlet pipe (114) and changing the connection state of the connecting pipe (71) from the connection with the outlet pipe (114) to the connection with the first valve (115);
and when the core holder (20) and the core model (10) injected with the first displacement medium rotate to a vertical state or an inclined state, injecting a second displacement medium into the core model (10), and metering the amount of the first liquid, the amount of the second liquid and the amount of experimental gas flowing out of the core model (10).
10. The reservoir-type gas reservoir simulation experiment method as claimed in claim 9, wherein after the core holder (20) and the core model (10) injected with the first displacement medium are rotated to a vertical state or an inclined state, a second displacement medium is injected into the core model (10), and the amount of the first liquid, the amount of the second liquid and the amount of the experiment gas flowing out of the core model (10) are measured, the method further comprises:
and when the first liquid and the second liquid do not flow out from the core model (10), alternately injecting and releasing the second displacement medium into the core model (10), so that the pressure in the core model (10) is maintained within a preset pressure range, and the amount of the experimental gas flowing out from the core model (10) is measured.
11. The reservoir-type gas reservoir simulation experiment method according to claim 9, wherein the outlet pipe (114) is connected with the connecting pipe (71), the core holder (20) and the core model (10) are rotated to be in a horizontal state, after a first liquid is injected into a confining pressure cavity (21), and before the first liquid and a second liquid are sequentially injected into the core model (10) in the horizontal state, so that the first liquid and the second liquid in the core model (10) are respectively in a saturated state, the method further comprises:
vacuumizing the interior of the core model (10);
in the process of injecting the first liquid and the second liquid, monitoring the temperature in the confining pressure cavity (21), the pressure in the core model (10) and the respective saturation of the first liquid and the second liquid injected into the core model (10) in real time through a monitoring system (40).
12. The reservoir-type gas reservoir simulation experiment method as claimed in claim 11, wherein after the first liquid and the second liquid are sequentially injected into the core model (10) in a horizontal state, so that the first liquid and the second liquid in the core model (10) are respectively in a saturated state, and before the core holder (20) and the core model (10) are in a horizontal state, a first displacement medium is injected into the core model (10), and the amount of the first liquid and the amount of the second liquid flowing out of the core model (10) are measured, the method further comprises:
standing for a preset time; the preset time is greater than 72 hours.
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