CN109372478B - Experimental method and device for determining immiscible gas flooding oil exploitation mode - Google Patents
Experimental method and device for determining immiscible gas flooding oil exploitation mode Download PDFInfo
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- CN109372478B CN109372478B CN201811572964.8A CN201811572964A CN109372478B CN 109372478 B CN109372478 B CN 109372478B CN 201811572964 A CN201811572964 A CN 201811572964A CN 109372478 B CN109372478 B CN 109372478B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- G—PHYSICS
- G09—EDUCATION; CRYPTOGRAPHY; DISPLAY; ADVERTISING; SEALS
- G09B—EDUCATIONAL OR DEMONSTRATION APPLIANCES; APPLIANCES FOR TEACHING, OR COMMUNICATING WITH, THE BLIND, DEAF OR MUTE; MODELS; PLANETARIA; GLOBES; MAPS; DIAGRAMS
- G09B25/00—Models for purposes not provided for in G09B23/00, e.g. full-sized devices for demonstration purposes
- G09B25/06—Models for purposes not provided for in G09B23/00, e.g. full-sized devices for demonstration purposes for surveying; for geography, e.g. relief models
Abstract
The invention provides an experimental method and device for determining a non-miscible gas flooding oil exploitation mode. The experimental method is used for simulating the physical process of the immiscible gas flooding oil extraction of the inclined oil reservoir, and comprises the following steps: designing an experimental device, and assembling the experimental device; preparing simulated formation water and simulated experiment oil, and selecting simulated experiment gravel; testing the porosity and the permeability of the simulation experiment gravel; respectively carrying out a gas-water displacement experiment and a non-miscible gas-oil displacement experiment by adopting an experimental device; and observing the oil-water change of the gas drive oil flat glass model, recording the displacement time, simultaneously measuring the mass and the volume of the liquid extracted at each moment, calculating the final extraction degree of each group, and preferably selecting the optimal immiscible gas drive oil extraction mode. The simulation of different oil reservoir inclination angles is realized by arranging the rotatable plate glass model; the permeability of the simulation experiment gravel is tested by adopting a vertical linear stable seepage model test method, and the technical problem that the permeability of a filling medium in a flat glass model is difficult to test is solved.
Description
Technical Field
The invention relates to the technical field of oil and gas exploitation, in particular to an experimental method and device for determining an immiscible gas flooding oil exploitation mode.
Background
The inclined oil reservoir is a special reservoir in the field of oil-gas exploration and development, the oil reservoir and a conventional oil reservoir have obvious difference in space structure, the flowing rule of fluid in the oil reservoir is different from that of the conventional oil reservoir, a set of mature development mode does not exist at present aiming at the development of the oil reservoir, and the research on the development mode of the inclined oil reservoir is mostly in an indoor experiment stage or a pilot experiment stage of a mine field. At the present stage, the knowledge of the inclined oil reservoir is more limited to the theoretical research of the oil reservoir fluid seepage under certain assumed conditions, and the evaluation knowledge of the overall oil reservoir development system by indoor experiments is lacked. The pilot experiment development of the mine field is usually limited by the geological and ground conditions of the oil reservoir, and the experimental result can only be suitable for the oil reservoir of a specific block; the main purpose of the research through the indoor experiment is to clarify the oil-water migration rule in the displacement process, clarify the migration channel and the oil-water distribution condition, and further provide the mining mode suitable for the inclined oil reservoir, so that the extraction degree of the inclined oil reservoir is greatly improved. Therefore, laboratory experimental research is particularly important.
At present, natural cores are mainly adopted for indoor experimental research and development of oil reservoirs, and can accurately reflect the real conditions of the oil reservoir reservoirs, but the method is limited in that the displacement scale of the natural cores is small, and the displacement process is invisible; another common mode is to use an artificial cylindrical quartz sand core physical model, which can set simulation dimensions and model parameters according to requirements and has a wider research range, but the model is the same as a natural core, the displacement process is invisible, and the real-time oil-water change process of the displacement process cannot be observed; based on the invisible shortcomings, researchers began to use glass etched microscopic physical models, which have the following advantages: the model displacement process is visual, can carry out data acquisition, image analysis and processing, and can be repeatedly used for multiple times; the disadvantages are that: because the physical model is manufactured by adopting the photoetching technology, the physical model has smaller geometric dimension, is in a plane two-dimensional form, can not simulate the real pore seepage structure of an oil reservoir, has lower accuracy of an experimental result, and has higher manufacturing cost, difficulty and requirements on manufacturing equipment. The three conventional indoor simulation oil reservoir development modes at present have certain defects. Especially for inclined oil reservoirs, a non-miscible gas flooding exploitation method is generally adopted. The three measures are not applicable any more, the physical models of the natural rock core and the artificial cylindrical quartz sandstone core can not realize the purpose of simulating the inclined oil reservoir, and the oil reservoir displacement process is invisible; the glass etching microscopic physical model belongs to a two-dimensional model, and although the visualization of the displacement process is realized, the error of the three-dimensional pore seepage structure for simulating the reservoir by adopting the glass etching is too large and is inconsistent with the actual geological condition, the glass etching microscopic physical model cannot bear high-pressure gas injection, and the glass sheet is easy to break. Therefore, it is urgently needed to develop an experimental device and an experimental method which can accurately simulate an inclined oil reservoir, realize visual displacement and research on an immiscible gas oil displacement mode.
Disclosure of Invention
The invention aims to solve the technical problems that inclined oil reservoirs cannot be accurately simulated, visual displacement can be realized, and the experimental device and the experimental method for researching the immiscible gas displacement mode can be realized in the prior art, and provides the experimental method and the experimental device for determining the immiscible gas displacement oil exploitation mode.
The invention is realized by the following technical scheme: an experimental method for determining an unmiscible gas flooding oil exploitation mode comprises the following steps:
step S1: designing an experimental device, and assembling the experimental device, wherein the experimental device comprises a flat glass model, an injection system, a measurement system and a camera device, threaded holes for simulating a gas injection well and a liquid production well are formed in the flat glass model, and the flat glass model is connected with a support through a bearing; the injection system is connected with a threaded hole of the simulated gas injection well through a gas injection pipeline, the measurement system is connected with a threaded hole of the simulated liquid production well through a liquid outlet pipeline, and the camera equipment is arranged above the flat glass model and used for shooting an immiscible gas-drive oil experiment process at time intervals;
step S2: preparing simulated formation water and simulated experiment oil, and selecting simulated experiment gravel;
step S3: testing the porosity of the simulated experimental gravel and the permeability of the simulated experimental gravel;
step S4: respectively carrying out a gas-drive water experiment and a non-miscible gas-drive oil experiment by adopting the experimental device;
step S5: observing the change of the gas drive front edge position, the gas dominant seepage channel, the gas seepage main direction, the drive sweeping position and the gas swept range, recording the displacement time, simultaneously measuring the mass and the volume of the liquid extracted at each moment, calculating the gas drive recovery speed and the change of the recovery degree, and calculating the final recovery degree of each group of experiments, preferably selecting the optimal immiscible gas drive oil recovery mode.
In a preferred embodiment of the invention, the simulated formation water is prepared from distilled water and NaCl, the mineralization degree of the simulated formation water is 2.5g/L, and the viscosity of the simulated formation water is 1mPa & s; the simulated test oil is prepared from common white oil and kerosene, and the viscosity of the simulated test oil is 5mPa & s; the mesh number of the simulation experiment gravel is 80-120 meshes.
In a preferred embodiment of the present invention, the method for testing the porosity of the simulated experimental gravel comprises: adding a certain amount of simulation experiment gravel into the vector cylinder, and measuring the volume of the simulation experiment gravel to be V1Then dripping with a glue headAdding a proper volume of water into the measuring cylinder by a pipe, wherein the volume of the added water is V2The cylinder is left for one day and the remaining volume in the cylinder is measured as V3And calculating the porosity of the simulation experiment gravel by using the calculation formula of the porosity of the simulation experiment gravel
And repeatedly measuring three groups of experimental data, and finally taking the arithmetic mean value as the porosity value of the simulated experimental gravel.
In a preferred embodiment of the present invention, the testing of the simulated experimental gravel permeability adopts a vertical linear stable seepage model testing method, which includes the following steps: selecting a glass tube, and measuring the inner diameter of the glass tube by using a vernier caliper for calculating the area of a cross section; selecting a proper screen mesh for plugging the glass tube, and filling the simulation experiment gravel with a certain height into the glass tube; measuring the height of the filled simulated experimental gravel by using a ruler; and fourthly, controlling the height of the pressure head by injecting liquid into the glass tube to form vertical linear stable seepage, calculating the permeability value of the simulated experiment gravel, repeatedly measuring three groups of experiment data, and finally taking the arithmetic mean value as the permeability value of the simulated experiment gravel.
In a preferred embodiment of the present invention, the injection liquid is distilled water; the calculation formula of the simulation experiment gravel permeability is as follows:
wherein: k is the liquid permeability, mum2(ii) a Q is the flow of the liquid, cm3S; l is the height of the filling gravel in cm; a is the area of the cross section in cm2(ii) a Rho is the density of the injected liquid, kg/cm3(ii) a g is the acceleration of gravity, m/s2(ii) a Mu is the viscosity of the injection liquid, mPa & s; h is the head height, m.
In a preferred embodiment of the invention, the gas flooding experiment comprises three groups of experiments, the gas flooding experiment adopts a continuous gas injection mode, and in the three groups of experiments, the first experiment and the second experiment adopt the same gas injection speed and the same gas injection position and adopt different oil reservoir dip angles for comparing the influence of different oil reservoir dip angles on the displacement effect; the first experiment and the third experiment adopt the same oil deposit inclination angle and the same gas injection position and different gas injection speeds for comparing the influence of different gas injection speeds on the displacement effect.
In a preferred embodiment of the invention, the immiscible gas flooding experiment comprises three groups of experiments, the immiscible gas flooding experiment adopts a continuous gas injection mode, and in the three groups of experiments, experiment four and experiment five adopt the same gas injection speed and the same gas injection position, and adopt different reservoir dip angles for comparing the influence of different reservoir dip angles on the displacement effect; experiment four and experiment six adopt the same oil deposit inclination, the same gas injection position, adopt different gas injection speed for contrast different gas injection speed to the influence of displacement effect.
In a preferred embodiment of the present invention, the reservoir dip angle is set in the range of 15 ° to 60 °; the gas injection speed is controlled to be 2.5cm3/s～10cm3S; the gas injection position is selected at a high position, and the liquid extraction position is selected at a low position.
An experimental device for determining an experimental method of a non-miscible gas drive oil exploitation mode comprises a flat glass model, an injection system, a measurement system and a camera device;
the plate glass model is made of two pieces of transparent glass with the size of 100cm multiplied by 100cm, the simulation experiment gravel is filled in the plate glass model, threaded holes for simulating a gas injection well and a liquid production well are formed in the plate glass model, the threaded holes are arranged at equal intervals of 5 multiplied by 5, the plate glass model is sealed by epoxy resin glue, and the plate glass model is connected with a support through a bearing;
the injection system comprises an air storage tank and an injection pipeline; the measuring system comprises a liquid outlet pipeline, a measuring cylinder and an electronic balance; the camera shooting equipment is a high-definition camera;
the injection system is connected with a threaded hole of the simulated gas injection well through the injection pipeline, the measurement system is connected with a threaded hole of the simulated liquid production well through the liquid outlet pipeline, the tail end of the liquid outlet pipeline is arranged in the measuring cylinder, and the measuring cylinder is arranged on the electronic balance; the camera equipment is used for shooting the unmixed-phase gas flooding oil experiment process at time intervals.
In a preferred embodiment of the present invention, the flat glass model is made of organic glass material; the flat glass model is designed to rotate 360 degrees around the bearing and is used for simulating different inclined oil reservoirs.
The advantages of the invention at least include: firstly, an indoor experimental method for determining a non-miscible gas drive oil exploitation mode is provided, the visualization of an experimental process is realized, and the method can be used for observing the change of the position of a gas drive front edge, a gas dominant seepage channel, a gas seepage main direction, a sweeping position and a gas sweep range; simulation of different oil reservoir inclination angles is realized by arranging a rotatable plate glass model, and reference is provided for optimization of an inclined oil reservoir gas injection exploitation mode; and thirdly, testing the permeability of the gravel in the simulation experiment by adopting a vertical linear stable seepage model test method, wherein the method is based on Darcy's law deformation improvement, and compared with the conventional gas detection and liquid detection, the method is simpler and more convenient, and solves the technical problem that the permeability of the filling medium in the flat glass model is difficult to test.
Drawings
FIG. 1 is a flow chart of an experimental laboratory method for determining immiscible gas flooding oil recovery mode provided by the present invention;
FIG. 2 is a schematic diagram of an experimental apparatus for determining immiscible gas flooding oil recovery mode according to the present invention;
FIG. 3 is a schematic view of an experimental apparatus for measuring permeability according to the present invention;
FIG. 4 is a schematic view of the observation of the displacement front during the gas flooding experiment
FIG. 5 is a diagram of the relationship between the dip angle and the production degree of different strata in a gas flooding water experiment
FIG. 6 is a graph showing the relationship between the gas injection speed and the extraction degree in the gas flooding water experiment
FIG. 7 is a graph of the extent of production versus injection volume factor for both gas flooding and gas flooding
FIG. 8 is a graph of the extent of production versus injection volume factor for both gas flooding and gas flooding
Wherein: the method comprises the following steps of 1-plate glass model, 2-injection system, 3-measurement system, 4-camera equipment, 5-threaded hole, 6-air storage tank, 7-injection pipeline, 8-liquid outlet pipeline, 9-measuring cylinder, 10-electronic balance, 11-bearing and 12-support.
Detailed Description
The technical scheme of the invention is described in detail in the following with reference to the accompanying drawings. In the actual experimental process, the designer of the invention carries out the experiment according to the following steps:
fig. 1 is a flowchart of an indoor experimental method for determining an immiscible gas flooding oil exploitation mode according to the present invention. The specific operation is shown in the following examples.
Designing an experimental device and assembling the experimental device. Filling simulation experiment gravels in the plate glass model, and sealing the plate glass model 1 by using epoxy resin glue; in order to fully saturate the gravel in the model with the solution, the model filled with gravel is placed in the solution for one day; connecting a gas storage tank 6 of the injection system with a threaded hole 5 of the simulated gas injection well through the injection pipeline 7; connecting the measuring system with a threaded hole 5 of the simulated liquid production well through the liquid outlet pipeline 8; the tail end of the liquid outlet pipeline 8 is arranged in the measuring cylinder 9, and the measuring cylinder 9 is arranged on an electronic balance 10; the flat glass model 1 was saturated with distilled water and evacuated for use.
The sheet glass model is designed to rotate 360 ° around the bearing 11, and this feature can be used to simulate the formation dip, the model design being shown in figure 2. When soaking plexiglas in the respective fluid, the internal gravel can be sufficiently saturated with fluid, while the position of the gas injection and production wells can be freely chosen, for example: the top threaded hole 3 may be used for top gas injection and the bottom threaded hole 23 may represent a production well.
And (4) configuring simulated formation water and simulated experiment oil, and selecting simulated experiment gravel. In consideration of the fact that the simulated experimental oil is large in viscosity and poor in fluidity, mineralized water is selected to replace crude oil in the early stage of an experiment, and in order to simulate the mineralization degree of formation water, a proper amount of NaCl is added into distilled water to prepare a solution with the mineralization degree of 2.5g/L, wherein the viscosity of the solution is 1mPa & s. And in the later stage of the experiment, common white oil and kerosene are selected to prepare experiment simulation oil, and the viscosity is 5 mPas. The injection gas used may be one of air, carbon dioxide, nitrogen. The mesh number of gravel selected for the experiment is 80-120 meshes.
And testing the porosity and the permeability of the simulation experiment gravel. A certain amount of simulation experiment gravel is added into the vector cylinder, and the volume of the simulation experiment gravel is V1Then adding a proper volume of water into the vector cylinder by using a rubber head dropper, wherein the volume of the water is V2The cylinder is left for one day and the volume V remaining in the cylinder is observed3Reduced volume of V1+V2-V3The porosity of the simulated experimental gravel is phi.
Three sets of experimental data were measured and the arithmetic mean was taken at last. Table 1 shows the porosity experimental data.
Table 1 simulation experiment gravel porosity experimental data
| Group of | 1 | 2 | 3 |
| V1+V2-V3(cm3) | 3.3 | 4.5 | 3.8 |
| V1(cm3) | 12 | 16 | 13 |
| φ | 0.275 | 0.281 | 0.292 |
The measured simulated experimental grit had an average porosity of 0.282.
And measuring the permeability by adopting a vertical linear stable seepage model test method and a downward seepage mode with a pressure head height h. The measurement method is shown in FIG. 3.
Modifying the darcy formula according to the test equipment:
wherein: k is the liquid permeability, mum2(ii) a Q is the flow of the liquid, cm3S; l is the height of the filling gravel in cm; a is the area of the cross section in cm2(ii) a Rho is the density of the injected liquid, kg/cm3(ii) a g is the acceleration of gravity, m/s2(ii) a Mu is the viscosity of the injection liquid, mPa & s; h is the head height, m.
The experimental steps are as follows:
selecting a glass tube, and measuring the inner diameter of the glass tube by using a vernier caliper for calculating the area of a cross section;
selecting a proper screen mesh for plugging the glass tube, and filling the simulation experiment gravel with a certain height into the glass tube;
measuring the height of the filled simulated experimental gravel by using a ruler;
and fourthly, controlling the height of the pressure head by injecting liquid into the glass tube to form vertical linear stable seepage, calculating the permeability value of the simulated experiment gravel, repeatedly measuring three groups of experiment data, and finally taking the arithmetic mean value as the permeability value of the simulated experiment gravel.
Three sets of experimental data were measured and the arithmetic mean was taken at last. Table 2 shows the experimental data measured:
table 2 simulation experiment gravel permeability data
| Group of | 1 | 2 | 3 |
| q cm3 | 0.20 | 0.21 | 0.20 |
| t s | 51 | 51 | 50 |
| Q cm3/s | 0.0039 | 0.0041 | 0.004 |
| Kμm2 | 0.301 | 0.317 | 0.307 |
The measured simulation experiment gravel average permeability is 0.308 mu m2。
And respectively carrying out a gas flooding water experiment and a non-miscible gas flooding oil experiment. The gas flooding water comprises a first experiment, a second experiment and a third experiment, wherein the first experiment: the dip angle of the oil reservoir is 30 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 5.0cm3S; experiment two: the dip angle of the oil reservoir is 45 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 5.0cm3S; experiment three: the dip angle of the oil reservoir is 30 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 7.7cm3And s. The injection pressure is controlled in the experimental process, the pressure change is noticed all the time, and the experimental device is prevented from being damaged due to overlarge pressure.
The immiscible gas flooding oil comprises experiment four, experiment five and experiment six, wherein experiment four: the dip angle of the oil reservoir is 30 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 5.0cm3S; experiment five: the dip angle of the oil reservoir is 45 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 5.0cm3S; experiment six: the dip angle of the oil reservoir is 30 degrees, the oil reservoir is injected with gas from the top 3 wells independently, the bottom 23 wells are liquid production wells, and the gas injection speed is 7.7cm3And s. The injection pressure is controlled in the experimental process, the pressure change is noticed all the time, and the experimental device is prevented from being damaged by overlarge pressure。
The data of the three groups of gas flooding experiments are shown in the table 3-table 5.
TABLE 3 gas flooding Water inclination 30 degree gas injection velocity 5.0cm3Data/s
TABLE 4 gas flooding Water Dip 45 deg. gas injection velocity 5.0cm3Data/s
| t(s) | 0 | 17 | 51 | 89 | 122 | 169 | 204 |
| ER(％) | 0 | 0.284 | 1.135 | 2.043 | 2.752 | 3.801 | 4.482 |
| t(s) | 248 | 282 | 329 | 365 | 416 | 469 | 524 |
| ER(％) | 5.504 | 6.27 | 7.206 | 7.943 | 8.936 | 9.929 | 11.007 |
| t(s) | 581 | 642 | 706 | 774 | 846 | 943 | 1025 |
| ER(％) | 12.113 | 13.135 | 14.213 | 15.262 | 16.312 | 17.447 | 19.035 |
| t(s) | 1112 | 1205 | 1306 | 1414 | 1532 | 1659 | 1800 |
| ER(％) | 20.142 | 21.305 | 22.468 | 23.603 | 24.738 | 25.929 | 27.092 |
| t(s) | 1955 | 2129 | 2323 | 2544 | 2796 | 3091 | 3446 |
| ER(％) | 28.17 | 29.504 | 30.95 | 32.426 | 33.844 | 35.348 | 36.823 |
| t(s) | 3874 | 4400 | 5110 | 6162 | 7045 | ||
| ER(％) | 38.326 | 39.773 | 41.191 | 42.667 | 43.83 |
TABLE 5 gas flooding Water inclination 30 degree gas injection velocity 7.7cm3Data/s
| t(s) | 0 | 15 | 45 | 70 | 97 | 133 | 170 |
| ER(％) | 0 | 0.255 | 1.305 | 2.014 | 2.723 | 3.773 | 4.709 |
| t(s) | 207 | 245 | 285 | 327 | 372 | 418 | 466 |
| ER(％) | 5.73 | 6.723 | 7.66 | 8.652 | 9.702 | 10.723 | 11.801 |
| t(s) | 518 | 574 | 632 | 696 | 784 | 856 | 934 |
| ER(％) | 12.596 | 13.504 | 14.27 | 15.092 | 16 | 17.078 | 18.27 |
| t(s) | 1018 | 1108 | 1206 | 1313 | 1430 | 1560 | 1704 |
| ER(％) | 19.149 | 20.113 | 20.993 | 21.986 | 22.894 | 23.801 | 24.681 |
| t(s) | 1874 | 2044 | 2250 | 2485 | 2761 | 3090 | 3492 |
| ER(％) | 25.589 | 26.468 | 27.348 | 28.227 | 29.106 | 30.043 | 30.95 |
| t(s) | 3978 | 4625 | 5562 | 6745 | |||
| ER(％) | 31.887 | 32.709 | 33.617 | 34.582 |
FIG. 4 is a schematic view of the observation of the displacement front during the gas flooding experiment. The main direction of gas seepage basically is along the gas injection well and production well line, and the direction points to the production well, because the sand pack is even, the gas drives the front edge and is basically the arc propulsion, and it is very fast to inject into the well to the position direction of production well, and both sides impel the speed slower.
Fig. 5 shows the relationship between different formation dip angles and the extraction degree in a gas flooding water experiment, and simulates a 30-degree formation dip angle and a 45-degree formation dip angle, and the relationship between the extraction degree and the injection volume multiple can be seen through comparison in a high-injection low-extraction and continuous gas injection mode: when the injection volume multiple is 94, the production degree under the condition of simulating continuous gas injection (high injection and low production) at the formation inclination angle of 45 degrees is 3.8 percent higher than that under the condition of simulating continuous gas injection (high injection and low production) at the formation inclination angle of 30 degrees. This is mainly due to the fact that the density of air is much lower than that of water, the larger the formation dip angle is, the more favorable the gas is to gather at the top, the obvious effect of water-gas gravity separation is, and the production degree is larger. The experiment in this group shows that: the oil reservoir with a certain stratum inclination angle is beneficial to gas drive, and the larger the stratum inclination angle is, the more beneficial the gas forms a gas cap on the top, and the better the displacement effect is.
FIG. 6 is a graph showing the relationship between different gas injection speeds and the extraction degree in a gas flooding water experiment, which simulates a formation dip angle of 30 degrees and gas injection speeds of 5.0cm3/s、7.7cm3In the case of/s, the degree of production is related to the multiple of the injection volume, as can be seen by comparison: under higher gas injection speed, the recovery rate of earlier stage is higher, but final extraction degree is lower, this is because under higher gas injection speed, gas is the faster breakthrough, forms the gas channeling, is unfavorable for the displacement of reservoir oil, and extraction degree reduces. Therefore, for the oil field developed by gas injection, the reasonable gas injection speed can be determined according to the physical property characteristics of the reservoir of the oil field and by combining the constraint of economic limit yield.
Three sets of immiscible gas flooding experimental data are shown in tables 6-8.
TABLE 6 gas flooding oil Dip 30 degree gas injectionSpeed 5.0cm3Data/s
| pv number (f) | 0 | 0.4 | 1.13 | 1.6 | 2.21 | 2.96 | 3.53 |
| ER(％) | 0 | 0.19 | 0.63 | 0.89 | 1.19 | 1.63 | 1.91 |
| pv number (f) | 4.11 | 4.68 | 5.27 | 5.87 | 6.49 | 7.12 | 7.77 |
| ER(％) | 2.23 | 2.54 | 2.85 | 3.13 | 3.44 | 3.77 | 4.08 |
| pv number (f) | 8.44 | 9.12 | 9.81 | 10.56 | 11.32 | 12.11 | 12.91 |
| ER(％) | 4.43 | 4.77 | 5.11 | 5.45 | 5.82 | 6.13 | 6.49 |
| pv number (f) | 13.76 | 14.92 | 15.83 | 16.79 | 17.79 | 18.84 | 19.93 |
| ER(％) | 6.84 | 7.21 | 7.77 | 8.15 | 8.52 | 8.9 | 9.31 |
| pv number (f) | 21.09 | 22.29 | 23.57 | 24.93 | 26.37 | 27.92 | 29.59 |
| ER(％) | 9.69 | 10.08 | 10.49 | 10.87 | 11.27 | 11.67 | 12.04 |
| pv number (f) | 31.36 | 33.28 | 35.37 | 37.67 | 40.17 | 42.96 | 46.09 |
| ER(％) | 12.43 | 12.82 | 13.21 | 13.61 | 14.01 | 14.4 | 14.81 |
| pv number (f) | 49.67 | 53.79 | 58.45 | 64.03 | 70.93 | 80.12 | 91.73 |
| ER(％) | 15.22 | 15.62 | 16.03 | 16.45 | 16.83 | 17.26 | 17.67 |
TABLE 7 gas flooding oil inclination angle 45 degree gas injection speed 5.0cm3Data/s
| pv number (f) | 0.32 | 0.93 | 1.28 | 1.77 | 2.4 | 2.85 | 3.31 |
| ER(％) | 0.2 | 0.64 | 0.9 | 1.2 | 1.64 | 1.92 | 2.24 |
| pv number (f) | 3.76 | 4.23 | 4.71 | 5.21 | 5.72 | 6.25 | 6.8 |
| ER(％) | 2.56 | 2.87 | 3.15 | 3.46 | 3.79 | 4.1 | 4.45 |
| pv number (f) | 7.36 | 7.93 | 8.56 | 9.2 | 9.87 | 10.55 | 11.28 |
| ER(％) | 4.79 | 5.14 | 5.48 | 5.85 | 6.16 | 6.52 | 6.87 |
| pv number (f) | 12.32 | 13.11 | 13.95 | 14.83 | 15.76 | 16.73 | 17.77 |
| ER(％) | 7.25 | 7.81 | 8.2 | 8.57 | 8.95 | 9.36 | 9.75 |
| pv number (f) | 18.85 | 20.01 | 21.25 | 22.57 | 24 | 25.55 | 27.2 |
| ER(％) | 10.14 | 10.56 | 10.94 | 11.34 | 11.75 | 12.13 | 12.54 |
| pv number (f) | 29 | 30.97 | 33.15 | 35.53 | 38.2 | 41.21 | 44.67 |
| ER(％) | 13.05 | 13.55 | 14.07 | 14.59 | 15.1 | 15.63 | 16.15 |
| pv number (f) | 48.67 | 53.21 | 58.67 | 65.45 | 74.52 | 86.01 | |
| ER(％) | 16.68 | 17.21 | 17.75 | 18.26 | 18.81 | 19.34 |
TABLE 8 gas flooding oil inclination angle 30 degree gas injection speed 7.7cm3Data/s
| Pv number (f) | 0.41 | 1.13 | 1.54 | 2.18 | 2.92 | 3.49 | 4.07 |
| ER(％) | 0.19 | 0.63 | 0.89 | 1.19 | 1.63 | 1.91 | 2.23 |
| pv number (f) | 4.64 | 5.24 | 5.85 | 6.51 | 7.17 | 7.86 | 8.58 |
| ER(％) | 2.54 | 2.85 | 3.14 | 3.45 | 3.77 | 4.08 | 4.43 |
| pv number (f) | 9.32 | 10.08 | 10.92 | 11.79 | 12.69 | 13.61 | 14.62 |
| ER(％) | 4.77 | 5.07 | 5.34 | 5.64 | 5.88 | 6.16 | 6.44 |
| pv number (f) | 16.1 | 17.19 | 18.36 | 19.59 | 20.9 | 22.28 | 23.76 |
| ER(％) | 6.76 | 7.24 | 7.56 | 7.84 | 8.15 | 8.48 | 8.79 |
| pv number (f) | 25.3 | 26.96 | 28.75 | 30.66 | 32.73 | 34.99 | 37.41 |
| ER(％) | 9.1 | 9.44 | 9.74 | 10.07 | 10.4 | 10.69 | 11 |
| pv number (f) | 40.06 | 42.98 | 46.2 | 49.75 | 53.74 | 58.25 | 63.45 |
| ER(％) | 11.32 | 11.63 | 11.96 | 12.28 | 12.6 | 12.93 | 13.26 |
| pv number (f) | 69.48 | 76.36 | 84.64 | 94.97 | 108.81 | 126.38 | |
| ER(％) | 13.59 | 13.92 | 14.25 | 14.56 | 14.91 | 15.24 |
Through experimental data and observation of phenomena, the front edge of gas flooding oil is also propelled in an arc shape, the propulsion of the connecting line direction between the gas injection well and the production well is faster, the main direction of gas seepage basically follows the connecting line direction of the gas injection well and the production well, but the propulsion speed of the front edge of gas flooding oil is obviously slower than that of gas flooding water.
FIG. 7 shows that the dip angle of the formation is 30 degrees and the gas injection speed is 5.0cm for gas flooding and gas flooding oil3/s、7.7cm3In/s, the extent of production is related to the multiple of the injection volume. It can be seen that for the gas flooding, the larger the gas injection speed is, the lower the later extraction degree is, because the too high gas injection speed makes the gas flooding front edge break through too early, and the extraction degree is reduced; under different gas injection speeds, the extraction degree is lower than the water-driving efficiency because the viscosity of the experimental simulated oil is greater than that of water, the seepage resistance is large, and simultaneously, because the density of the experimental simulated oil is less than that of water, the density ratio of oil to gas is less than that of water, and the effect of gravity differentiation is relatively weak.
FIG. 8 shows gas injection for both gas flooding and gas floodingSpeed of 5.0cm3And/s, the relationship between the production degree and the injection volume multiple when the stratum inclination angle is respectively 30 degrees and 45 degrees. It can be seen that for gas flooding, the larger the formation dip angle is, the higher the production degree is, because the larger the formation dip angle is, the more obvious the gravity differentiation effect is; under different stratum inclination angles, the extraction degree is lower than the water-driving efficiency, and the experiment simulation oil viscosity is higher than the viscosity of water, the seepage resistance is large, and meanwhile, the experiment simulation oil density is lower than the density of water, and the effect of the gravity differentiation effect is weak.
According to the experimental results, when the non-miscible gas flooding is carried out on the inclined reservoir, a gas injection mode of slow speed and mild gas injection is adopted as much as possible, so that the gas drive front edge is prevented from being broken through too early due to overlarge gas injection speed, and the extraction degree is prevented from being reduced; the development modes of high-position gas injection and low-position oil extraction are selected, and the gravity differentiation effect caused by the formation dip angle is fully utilized to improve the extraction degree.
In the description of the present invention, it should be noted that the terms "center", "upper", "lower", "left", "right", "vertical", "horizontal", "inner", "outer", etc. indicate orientations or positional relationships based on the orientations or positional relationships shown in the drawings, and are only used for simplifying the description of the present invention, but do not indicate or imply that the device or element referred to must have a specific orientation, be constructed in a specific orientation, and be operated, and thus, should not be construed as limiting the present invention.
In the description of the present invention, it should be noted that unless otherwise explicitly stated or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, and may be, for example, a fixed connection, a detachable connection, an integral connection, a mechanical connection, an electrical connection, a direct connection, an indirect connection via an intermediate medium, and a communication between two elements. The specific meanings of the above terms in the present invention can be understood in specific cases to those skilled in the art.
The above description is only an exemplary embodiment of the present invention, and is not intended to limit the scope of the present invention. Any equivalent changes and modifications that can be made by one skilled in the art without departing from the spirit and principles of the invention should fall within the protection scope of the invention.
Claims (8)
1. An experimental method for determining a non-miscible gas flooding oil exploitation mode is characterized by comprising the following steps of:
step S1: designing an experimental device, and assembling the experimental device, wherein the experimental device comprises a flat glass model, an injection system, a measurement system and a camera device, threaded holes for simulating a gas injection well and a liquid production well are formed in the flat glass model, and the flat glass model is connected with a support through a bearing; the injection system is connected with a threaded hole of the simulated gas injection well through an injection pipeline, the measurement system is connected with a threaded hole of the simulated liquid production well through a liquid outlet pipeline, and the camera equipment is arranged above the flat glass model and used for shooting an immiscible gas-drive oil experiment process at time intervals;
step S2: preparing simulated formation water and simulated experiment oil, and selecting simulated experiment gravel;
step S3: testing the porosity of the simulated experimental gravel and the permeability of the simulated experimental gravel;
the test of the simulation experiment gravel permeability adopts a vertical linear stable seepage model test method, which comprises the following steps: selecting a glass tube, and measuring the inner diameter of the glass tube by using a vernier caliper for calculating the area of a cross section; selecting a proper screen mesh for plugging the glass tube, and filling the simulation experiment gravel with a certain height into the glass tube; measuring the height of the filled simulated experimental gravel by using a ruler; fourthly, controlling the height of a pressure head by injecting liquid into the glass tube to form vertical linear stable seepage, calculating the permeability value of the simulated experiment gravel, repeatedly measuring three groups of experiment data, and finally taking the arithmetic mean value as the permeability value of the simulated experiment gravel; the injected liquid is distilled water; the calculation formula of the simulation experiment gravel permeability is as follows:
wherein: k is the liquid permeability, m2(ii) a Q is the flow of the liquid, cm3S; the height of the L position filling gravel is cm; a is the area of the cross section in cm2(ii) a Rho is the density of the injected liquid, kg/cm3(ii) a g is the acceleration of gravity, m/s2(ii) a Mu is the viscosity of the injection liquid, mPa & s; h is the height of the pressure head, m;
step S4: respectively carrying out a gas-drive water experiment and a non-miscible gas-drive oil experiment by adopting the experimental device;
step S5: observing the change of the gas drive front edge position, the gas dominant seepage channel, the gas seepage main direction, the drive sweeping position and the gas swept range, recording the displacement time, simultaneously measuring the mass and the volume of the liquid extracted at each moment, calculating the gas drive recovery speed and the change of the recovery degree, and calculating the final recovery degree of each group of experiments, preferably selecting the optimal immiscible gas drive oil recovery mode.
2. The experimental method for determining the immiscible gas flooding oil exploitation method according to claim 1, wherein the simulated formation water is prepared from distilled water and NaCl, the mineralization degree of the simulated formation water is 2.5g/L, and the viscosity of the simulated formation water is 1 mPa-s; the simulated test oil is prepared from common white oil and kerosene, and the viscosity of the simulated test oil is 5mPa & s; the mesh number of the simulation experiment gravel is 80-120 meshes.
3. The experimental method for determining an unmixed gas drive oil recovery pattern according to claim 2, wherein the test method for simulating the porosity of the experimental gravel comprises: adding a certain amount of simulation experiment gravel into the vector cylinder, and measuring the volume of the simulation experiment gravel to be V1Then adding a proper volume of water into the measuring cylinder by using a rubber head dropper, wherein the volume of the added water is V2The cylinder is left for one day and the remaining volume in the cylinder is measured as V3Calculating the aboveThe porosity of the simulation experiment gravel is calculated according to the formula
And repeatedly measuring three groups of experimental data, and finally taking the arithmetic mean value as the porosity value of the simulated experimental gravel.
4. The experimental method for determining immiscible gas flooding oil exploitation according to claim 3, wherein the gas flooding water experiment comprises three groups of experiments, the gas flooding water experiment adopts continuous gas injection, and of the three groups of experiments, experiment one and experiment two adopt the same gas injection speed and the same gas injection position and adopt different reservoir dip angles for comparing the influence of different reservoir dip angles on the displacement effect; the first experiment and the third experiment adopt the same oil deposit inclination angle and the same gas injection position and different gas injection speeds for comparing the influence of different gas injection speeds on the displacement effect.
5. The experimental method for determining the immiscible gas flooding oil exploitation method according to claim 4, wherein the immiscible gas flooding experiments comprise three groups of experiments, the immiscible gas flooding experiments all adopt a continuous gas injection mode, and in the three groups of experiments, the fourth experiment and the fifth experiment adopt the same gas injection speed and the same gas injection position and adopt different reservoir dip angles for comparing the influence of different reservoir dip angles on the displacement effect; experiment four and experiment six adopt the same oil deposit inclination, the same gas injection position, adopt different gas injection speed for contrast different gas injection speed to the influence of displacement effect.
6. The experimental method for determining an immiscible gas flooding oil recovery mode according to claim 5, characterized in that the reservoir dip angle is set in the range of 15 ° to 60 °; the gas injection speed is controlled to be 2.5cm3/s～10cm3S; the gas injection position is selected at a high position, and the liquid extraction position is selected at a low position.
7. An experimental device for the experimental method for determining the immiscible gas flooding oil exploitation manner according to any one of claims 1 to 6, which is characterized by comprising a plate glass model, an injection system, a measurement system and a camera device; the plate glass model is made of two pieces of transparent glass with the size of 100cm multiplied by 100cm, the simulation experiment gravel is filled in the plate glass model, threaded holes for simulating a gas injection well and a liquid production well are formed in the plate glass model, the threaded holes are arranged at equal intervals of 5 multiplied by 5, the plate glass model is sealed by epoxy resin glue, and the plate glass model is connected with a support through a bearing; the injection system comprises an air storage tank and an injection pipeline; the measuring system comprises a liquid outlet pipeline, a measuring cylinder and an electronic balance; the camera shooting equipment is a high-definition camera; the injection system is connected with a threaded hole of the simulated gas injection well through the injection pipeline, the measurement system is connected with a threaded hole of the simulated liquid production well through the liquid outlet pipeline, the tail end of the liquid outlet pipeline is arranged in the measuring cylinder, and the measuring cylinder is arranged on the electronic balance; the camera equipment is arranged above the plate glass model and used for shooting the experimental process of the non-miscible gas flooding oil at time intervals.
8. The experimental device of claim 7, wherein the flat glass model is made of organic glass material; the flat glass model is designed to rotate 360 degrees around the bearing and is used for simulating different inclined oil reservoirs.
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| CN111878075B (en) * | 2020-09-14 | 2022-02-11 | 西南石油大学 | Method for testing regional extraction degree of gas-water co-injection of inclined reservoir |
| CN114458261A (en) * | 2022-02-17 | 2022-05-10 | 中国石油大学(华东) | Visual physical simulation experiment device for carbon dioxide flooding well pattern displacement of heterogeneous oil reservoir |
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