Simulation device and simulation method for whole sequence of oil and gas reservoir forming process in whole oil and gas system

Abstract

The application provides a simulation device and simulation method for a full-oil-gas-system full-sequence oil-gas reservoir forming process, relates to the technical field of oil-gas reservoir forming, and comprises a fixed frame, a visual model, an angle adjusting frame, a pressurizing device and a drainage device. The visual model is placed on the fixed frame, the visual model has a cavity for placing a stratum sample, and the angle adjusting frame is placed below the visual model to simulate different geological environments or experimental conditions. The stratum model is completely saturated with stratum water through a displacement method to simulate the stratum water. Basic physical parameters of the stratum model in the saturated stratum water state are determined. A simulation experiment is carried out through a filling pressure and liquid addition, and experimental data are recorded. The experimental data are analyzed to obtain pressure and liquid output data of oil and gas in initial migration and secondary migration, and high-definition photos of the process and distribution characteristics of oil and gas migration and accumulation, so that the process of underground oil and gas migration and accumulation is accurately displayed.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil and gas accumulation, in particular to a simulation device and method for the whole sequence of oil and gas accumulation process in the whole oil and gas system. BACKGROUND

[0002] The whole oil and gas system theory is an oil and gas enrichment theory proposed in recent years based on the exploration of deep and ultra-deep oil and gas. At present, the whole sequence of oil and gas accumulation process has been reconstructed in theory, however, there is still a lack of experimental devices to simulate such whole sequence of oil and gas accumulation process. Oil and gas migration and accumulation is a complex process controlled by multiple geological conditions, and it is a crucial part of petroleum geology to study the basic processes such as conventional and unconventional oil and gas generation, migration and accumulation, and to understand the conditions, influencing processes and dynamic mechanisms of oil and gas accumulation. For many years, oil and gas accumulation physical simulation experiment technology has developed rapidly and has been widely used in oil and gas accumulation research, which realizes the intuitive reflection of oil and gas migration and accumulation process and the simulation of oil and gas dominant migration path under laboratory conditions.

[0003] Although the simulation method is constantly developing, the device is constantly improving, and the elements are constantly increasing, there are still many problems: ①The oil and gas reservoir properties are single, it is difficult to realize the change of reservoir properties, and there is a lack of reduction of the whole sequence of oil and gas accumulation geological process; ②The subtle phenomena of oil and gas charging and migration are not obvious, and it is difficult to observe; ③The observation surface is single, and it is difficult to measure parameters. The above problems affect the applicability of oil and gas accumulation physical simulation and the comprehensive understanding of the process and mechanism of oil and gas charging, migration and accumulation. SUMMARY

[0004] In view of the above problems, the present design solves the partial defects of the traditional two-dimensional physical simulation method, and designs a simulation method for the whole sequence of oil and gas accumulation process in the whole oil and gas system, which includes:

[0005] Step one, connecting and debugging the simulation device for the whole sequence of oil and gas accumulation process in the whole oil and gas system;

[0006] Step two, preparing a solution for simulation experiment;

[0007] Step three, building a formation model;

[0008] Step four, saturating the formation model with formation water by displacement method;

[0009] Step five, measuring the basic physical property parameters of the formation model in the state of saturated formation water;

[0010] Step six, performing simulation experiment by charging pressure and liquid addition, and recording experimental data;

[0011] Step seven, analyze the experimental data to obtain the pressure, liquid volume data of oil and gas in the first migration and secondary migration, and high-definition photos of the process and distribution characteristics of oil and gas migration and accumulation.

[0012] In the preferred embodiment, in step two, the preparation process of the simulation experiment solution is as follows: saturated sodium chloride solution is prepared as formation water; calcium chloride solution is prepared for standby; red oil-soluble dye is used to dye kerosene to prepare red tracer oil phase; blue oil-soluble dye is used to dye kerosene to prepare blue tracer oil phase.

[0013] In the preferred embodiment, in step three, quartz sand with mesh numbers of 110 and 200 is selected respectively, and sodium carbonate powder is selected, and then they are mixed in proportion to obtain conventional formation material, transition formation material and unconventional formation material.

[0014] Conventional reservoir material: 110 mesh quartz sand: 200 mesh quartz sand = 4:1;

[0015] Transition reservoir material: 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:7:2;

[0016] Unconventional reservoir material: 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:8:1;

[0017] The three kinds of reservoir materials are layered from bottom to top in the cavity of the formation sample in a volume ratio of 1:1:1, and are oscillated and compacted to simulate the compaction state of the formation under the action of pressure for a long time.

[0018] In the preferred embodiment, in step four, the saturated sodium chloride solution prepared in step two is slowly injected into the formation model to make the formation model fully saturated. During the injection process, the water absorption of the formation model is closely observed to ensure that the saturated sodium chloride solution is uniformly distributed in the pores of the formation model, and until there is a stable water flow out of the outlet section and no obvious bubbles.

[0019] In the preferred embodiment, step six includes:

[0020] The air compressor is started, the output pressure is adjusted, valves two and three are closed, valve one is opened, the red tracer oil phase is slowly injected from inlet one into the formation model through the liquid feeding pump, the migration path and accumulation of the red tracer oil phase in the formation model are observed and recorded in real time through the high-definition camera, and the distribution change and migration speed of the red tracer oil phase are recorded.

[0021] Valve one is closed, the pressure of the air compressor is adjusted, valve three is opened, and the prepared calcium chloride solution is quickly injected into the formation model through the liquid feeding pump, so that the calcium chloride solution reacts with sodium carbonate to cause densification; after the injection is completed, valve three is closed, and the formation model is placed to allow the densification reaction to proceed fully;

[0022] Close the valve three, adjust the air compressor pressure, open the valve two, through the liquid filling control blue tracer oil phase from the import two to the formation model slow injection, through the high-definition camera real-time observation and record the blue tracer oil phase in the densification after the migration characteristics of the reservoir, the accumulation process, and the conventional reservoir oil and gas migration and accumulation process are compared.

[0023] In the preferred embodiment, the step seven, the collected pressure, liquid discharge data and high-definition photos are analyzed, including: pressure change curve, liquid discharge and time relationship, oil phase distribution characteristics in different reservoirs, analysis of the control effect of formation porosity and pressure factors on oil and gas accumulation.

[0024] In the preferred embodiment, the step one, the visualization model is fixed on the fixed frame, the angle adjusting frame is connected and arranged, the pressurizing device is connected, the connection is ensured to be tight and leak-free, the drainage device is connected with the visualization model through the pipe valve, and the high-definition camera is focused on the observation surface of the visualization model.

[0025] The application also provides a simulation device for the whole sequence of oil and gas accumulation process of the whole oil and gas system, which is used for realizing the simulation method, and the simulation device comprises a fixed frame, a visualization model, an angle adjusting frame, a pressurizing device and a drainage device.

[0026] The visualization model is placed on the fixed frame, the visualization model has a cavity for placing a formation sample, and the angle adjusting frame is placed below the visualization model to simulate different geological environments or experimental conditions.

[0027] The pressurizing device is arranged on the import side of the visualization model, and comprises an air compressor, a liquid filling device, a pressure sensor and a pipe valve, the air compressor provides compressed air to simulate the pressure environment of the underground oil and gas reservoir, the liquid filling device is used for storing and adding liquid required for simulation experiments, the pressure sensor is used for detecting the pressure change in the pipeline, and the import valve is used for controlling the on-off of the liquid or gas.

[0028] The drainage device comprises a measuring cylinder and a liquid outlet valve, the measuring cylinder is used for measuring the volume of the liquid flowing out of the visualization model, and the liquid outlet valve is used for discharging the liquid.

[0029] Compared with the prior art, the application has the following beneficial effects:

[0030] In view of the single observation surface in the traditional two-dimensional physical simulation experiment, the oil and gas charging theme model is designed as a semi-transparent visualization device, so that the whole process of oil and gas migration and accumulation can be observed. BRIEF DESCRIPTION OF DRAWINGS

[0031] Figure 1 It is a three-dimensional schematic diagram of the simulation device of the application.

[0032] Figure 2 It is a schematic diagram of the structure of each part of the simulation device of the application.

[0033] REFERENCE NUMERALS

[0034] 1: visualization model; 2: angle adjusting frame; 3: fixed frame; 4: air compressor; 5: liquid filling; 6: liquid inlet valve; 7: pressure sensor; 8: liquid outlet valve; 9: measuring cylinder. DETAILED DESCRIPTION

[0035] The application will be described in detail below with specific embodiments. The following embodiments will help those skilled in the art to further understand the application, but do not limit the application in any form. It should be pointed out that, for those skilled in the art, without departing from the concept of the application, a number of changes and improvements can be made. These all belong to the protection scope of the application.

[0036] Example 1

[0037] The embodiment provides a simulation device for the whole sequence of oil and gas accumulation process in a whole oil and gas system, which comprises a fixed frame, a visualization model, an angle adjusting frame, a pressurizing device and a drainage device.

[0038] The visualization model for oil and gas migration simulation is placed on the fixed frame, the visualization model has a cavity for placing a stratum sample, three inlets and two outlets are respectively arranged on both sides of the cavity, and filter screens are arranged on the inlets and outlets to prevent experimental materials for simulating the stratum from entering the pipeline and causing blockage.

[0039] An angle adjusting frame is placed below the visualization model to simulate different geological environments or experimental conditions.

[0040] The pressurizing device is arranged at the inlet side of the visualization model of the oil and gas migration simulation, and the pressurizing device comprises an air compressor, a liquid filling cylinder (or a gas cylinder), a pressure sensor and a liquid inlet valve. The air compressor provides compressed air for driving the liquid in the liquid filling cylinder, or provides a specific air pressure condition during the experiment, so as to simulate the pressure environment of the underground oil and gas reservoir and the like; the liquid filling cylinder is used for storing and adding the liquid required for the simulation experiment, such as formation water, simulated oil and the like; the pressure sensor is used for detecting the pressure change in the pipeline, so as to provide pressure data for the experiment; and the liquid inlet valve is used for controlling the on-off of the liquid or gas, so as to accurately control the flow of the fluid during the experiment, and ensure the preparation and reliability of the experiment.

[0041] The drainage device comprises a measuring cylinder and a liquid outlet valve, the measuring cylinder is used for measuring the volume of the liquid flowing out of the visualization model, so as to obtain the related data such as liquid production during the experiment; and the liquid outlet valve is used for draining the liquid.

[0042] Embodiment 2

[0043] The embodiment provides a simulation method for the whole sequence of oil and gas reservoir forming processes in a whole oil and gas system.

[0044] Step 1, connect and debug the simulation device in embodiment 1.

[0045] Fix the visualization model on the fixed frame, and connect the angle adjusting frame.

[0046] Connect the pressurizing device such as the air compressor, the liquid filling cylinder (or the gas cylinder), the pressure sensor, the liquid inlet valve and the like, ensure that the connection between the parts is tight and has no leakage, and correctly connect the drainage device and the main body of the visualization model through the pipe valve.

[0047] Comprehensively check the whole experimental device, start the air compressor to test the pressure output thereof, check the sealing property of the liquid filling cylinder, debug the pressure sensor to ensure that the pressure data is accurately displayed, test the opening and closing functions of the pipe valve, and ensure that each equipment can normally operate.

[0048] Focus the high-definition camera on the observation surface of the visualization model, and calibrate the light source to avoid reflection.

[0049] Step 2, prepare the solution for the simulation experiment.

[0050] Prepare a saturated sodium chloride solution as formation water; prepare a 1 mol / L calcium chloride solution for standby; use a red oil-soluble dye to dye kerosene to prepare a red tracer oil phase; and use a blue oil-soluble dye to dye kerosene to prepare a blue tracer oil phase.

[0051] Step 3, build a formation model.

[0052] The sodium carbonate particles are ground into fine powder. Select 110 mesh and 200 mesh quartz sand respectively, and then select sodium carbonate powder. Mix them evenly according to the proportion to obtain conventional formation material, transition formation material and unconventional formation material.

[0053] Conventional reservoir material, 110 mesh quartz sand: 200 mesh quartz sand = 4:1;

[0054] Transition reservoir material, 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:7:2;

[0055] Unconventional reservoir material: 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:8:1.

[0056] The three different proportions of reservoir material are layered from bottom to top in the cavity of the formation sample at a volume ratio of 1:1:1. The filled mixed material is oscillation compacted, and a suitable counterweight is applied on the top to simulate the compaction state of the formation under long-term pressure, so that the model is closer to the actual formation structure.

[0057] Step four, completely saturate the formation model by displacement method to simulate formation water.

[0058] Slowly inject the saturated sodium chloride solution (formation water) prepared in step two into the visualized model of oil and gas migration and accumulation through the liquid filling and liquid inlet valve, so that the formation model of the visualized model is fully saturated. During the injection process, the water absorption of the formation model is closely observed to ensure that the saturated sodium chloride solution (formation water) is evenly distributed in the pores of the formation model until there is a stable water flow at the outlet section and no obvious bubbles.

[0059] Step five, determine the basic physical property parameters of the formation model under the condition of saturated formation water.

[0060] After the formation model is saturated with formation water, close all inlet and outlet valves, and record the initial pressure data of the formation model displayed by the pressure display.

[0061] Step six, carry out simulation experiment by filling pressure and liquid injection, and record experimental data.

[0062] Start the air compressor and adjust the output pressure to 0.10 Mpa. Close valves two and three, and open valve one. Control the slow injection of red tracer oil phase from inlet one into the formation model through the liquid filling device to simulate the preferential migration and accumulation of oil and gas in the conventional reservoir. Observe and record the migration path, accumulation condition, distribution change and migration speed of the red tracer oil phase in the formation model in real time through the high-definition camera. Record: the filling pressure is 0.10 Mpa, the filling time is 40 min, and the outlet one liquid volume is 60 ml.

[0063] Close valve one, adjust the air compressor pressure to 0.60Mpa, open valve three. Through the liquid filling control, inject the prepared 1mol / L calcium chloride solution from the inlet three into the model quickly, so that the calcium chloride solution and sodium carbonate occur densification reaction. Record: the filling pressure is 0.60Mpa, the filling time is 10min, and the total liquid volume of outlet one and two is 450g (solid-liquid mixture). After the injection is completed, close valve three, and stand the model for 10min to ensure that the densification reaction is fully carried out.

[0064] Close valve three, adjust the air compressor pressure to 0.60Mpa, open valve two. Through the liquid filling control, inject the blue tracer oil phase from the inlet two into the formation model slowly. Through the high-definition camera, observe and record the migration characteristics and aggregation process of the blue tracer oil phase in the reservoir after densification, and compare with the conventional reservoir oil and gas migration and aggregation process. Record: the filling pressure is 0.60Mpa, the filling time is 50min, and the liquid volume of outlet one is 50ml.

[0065] Step seven, process the recorded experimental data to obtain the pressure, liquid volume data of oil and gas in the primary migration and secondary migration, and high-definition photos of the process and distribution characteristics of oil and gas migration and aggregation.

[0066] Arrange and analyze the collected pressure, liquid volume and high-definition photos and other related data. Including but not limited to: pressure change curve, liquid volume and time relationship, oil phase distribution characteristics in different reservoirs, etc. Through the analysis, the control effect of key factors such as formation porosity and pressure on oil and gas migration and accumulation is revealed.

[0067] Finally, disassemble the visualization model, and take out the sand body samples of the conventional reservoir, transition reservoir and unconventional reservoir regions respectively. Clean, dry and other processes are carried out on the sand body samples to prepare cast thin sections. Use a polarizing microscope to observe the pore structure, throat size and distribution, and densification product distribution characteristics.

[0068] The sand body matching scheme of the simulated formation in different experimental groups is shown in Table 1, and the rock formation with different porosities is simulated;

[0069] The filling pressure and corresponding liquid volume in the experimental process of different experimental groups are shown in Table 2, and the liquid volume under different pressures is simulated.

[0070] Table 1 Formation sand body matching scheme

[0071]

[0072] Table 2 Filling pressure, liquid volume and oil phase aggregation area

[0073]

[0074] The specific embodiments of the present application are described above. It needs to be understood that the present application is not limited to the specific embodiments described above, and various changes or modifications can be made by those skilled in the art within the scope of the claims, which do not affect the essential content of the present application. The embodiments of the present application and the features in the embodiments can be combined with each other arbitrarily without conflict.

Claims

1. A simulation method for the entire hydrocarbon accumulation process of a complete hydrocarbon system, characterized in that, include: Step 1: Connect and debug the simulation device for the entire oil and gas system's full sequence of hydrocarbon accumulation processes; Step 2: Prepare the solution for the simulation experiment; Step 3: Construct a stratigraphic model; Select quartz sand with mesh sizes of 110 mesh and 200 mesh respectively, and select sodium carbonate powder, and mix them thoroughly according to the proportions to obtain conventional stratigraphic materials, transitional stratigraphic materials and unconventional stratigraphic materials; Conventional reservoir materials: 110-mesh quartz sand : 200-mesh quartz sand = 4:1; Transitional reservoir material: 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:7:2; Unconventional reservoir material: 110 mesh quartz sand: 200 mesh quartz sand: sodium carbonate powder = 11:8:1; Three types of reservoir materials were loaded into the cavity of the formation sample from bottom to top in a 1:1:1 volume ratio and then subjected to oscillatory compaction to simulate the compaction state of the formation under long-term pressure. Step 4: Use the displacement method to fully saturate the formation model to simulate formation water; Step 5: Determine the basic physical properties of the formation model under saturated formation water conditions; Step Six: Conduct a simulation experiment by adjusting the filling pressure and adding liquid, and record the experimental data, including: Turn on the air compressor, adjust the output pressure, close valves two and three, open valve one, and slowly inject the red tracer oil phase from inlet one into the formation model by controlling the liquid injection tank. Observe and record the migration path and accumulation of the red tracer oil phase in the formation model in real time through a high-definition camera, and record the distribution changes and migration speed of the red tracer oil phase. Close valve one, adjust the air compressor pressure, open valve three, and rapidly inject the prepared calcium chloride solution into the formation model through inlet three using the liquid injection tank, so that the calcium chloride solution reacts with sodium carbonate to form a densification reaction; after injection, close valve three and let the formation model stand still to allow the densification reaction to proceed fully. Close valve three, adjust the air compressor pressure, and open valve two; control the slow injection of the blue tracer oil phase from the inlet two-dimensional formation model by adding liquid tank, and observe and record the migration characteristics and accumulation process of the blue tracer oil phase in the densified reservoir in real time by high-definition camera, and compare it with the conventional reservoir oil and gas migration and accumulation process. Step 7: Analyze the experimental data to obtain the pressure and liquid output data of oil and gas during the primary and secondary migrations, as well as the process of oil and gas accumulation. Use a polarizing microscope to observe the pore structure, throat size and distribution, and distribution characteristics of densification products.

2. The simulation method for the entire hydrocarbon accumulation process of a complete oil and gas system according to claim 1, characterized in that, In step two, the preparation process of the solution for the simulation experiment is as follows: prepare a saturated sodium chloride solution as formation water; prepare a calcium chloride solution for later use; use a red oil-soluble dye to dye kerosene to prepare a red tracer oil phase; use a blue oil-soluble dye to dye kerosene to prepare a blue tracer oil phase.

3. The simulation method for the entire hydrocarbon accumulation process of a complete oil and gas system according to claim 2, characterized in that, In step four, the saturated sodium chloride solution prepared in step two is slowly injected into the formation model to fully saturate it. During the injection process, the water absorption of the formation model is closely observed to ensure that the saturated sodium chloride solution is evenly distributed in the pores of the formation model until a stable water flow is discharged from the outlet section without obvious bubbles.

4. The simulation method for the entire hydrocarbon accumulation process of a complete oil and gas system according to claim 1, characterized in that, In step seven, the collected pressure, liquid output data, and high-resolution images are analyzed, including: pressure change curves, the relationship between liquid output and time, the distribution characteristics of oil phases in different reservoirs, and the control effect of formation porosity and pressure factors on oil and gas migration and accumulation.

5. The simulation method for the entire hydrocarbon accumulation process of a complete oil and gas system according to claim 1, characterized in that, In step one, the visualization model is fixed on the fixed frame, the angle adjustment bracket is connected, and the pressurization device is connected to ensure a tight and leak-free connection. The drainage device is connected to the visualization model through pipes and valves, and the high-definition camera is focused on the observation surface of the visualization model.

6. A simulation device for the entire hydrocarbon accumulation process of a complete oil and gas system, characterized in that, For implementing the simulation method as described in any one of claims 1-5, the simulation device includes: a fixed frame, a visualization model, an angle adjustment frame, a pressurization device, and a drainage device; The visualization model is placed on a fixed frame. The visualization model has a cavity for placing stratum samples. An angle adjustment frame is placed below the visualization model to simulate different geological environments or experimental conditions. A pressurization device, located on the inlet side of the visualization model, includes an air compressor, a liquid filling tank, a pressure sensor, and pipe valves. The air compressor provides compressed air to simulate the pressure environment of an underground oil and gas reservoir. The liquid filling tank is used to store and add liquids required for the simulation experiment. The pressure sensor is used to detect pressure changes in the pipeline, and the liquid inlet valve is used to control the flow of liquid or gas. A drainage device includes a graduated cylinder for measuring the volume of liquid flowing out of a visualization model and a discharge valve for discharging the liquid.

Images