CN110578517A - Method for describing viscosity heterogeneity of heavy oil reservoir numerical simulation underground crude oil - Google Patents
Method for describing viscosity heterogeneity of heavy oil reservoir numerical simulation underground crude oil Download PDFInfo
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- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The invention provides a method for describing viscosity heterogeneity of heavy oil reservoirs in a numerical simulation underground crude oil, which comprises the following steps: step 1, testing the viscosity and the gas-oil ratio of ground degassed crude oil; step 2, calculating the viscosity of the underground crude oil of each well, respectively finding out the maximum value and the minimum value of the viscosity, and carrying out viscosity-temperature test; step 3, defining heavy components and light components through numerical simulation, and inputting viscosity-temperature curves of the two components; step 4, calculating the mole fraction of the heavy component and the mole fraction of the light component of each well; step 5, respectively solving the mole fraction field data of the heavy component and the light component through well point interpolation calculation; and 6, calculating a viscosity distribution field of the underground crude oil in the heavy oil reservoir numerical simulation. The method for describing the viscosity heterogeneity of the underground crude oil of the heavy oil reservoir numerical simulation can be used for finely describing the heterogeneity of the viscosity distribution of the underground crude oil, so that the accuracy of the viscosity distribution description of the underground crude oil in the heavy oil reservoir numerical simulation is improved.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a method for describing the viscosity heterogeneity of heavy oil reservoirs in a numerical simulation underground crude oil.
Background
The thickened oil is different from conventional thin oil, and the most essential characteristic of the thickened oil is that the viscosity of the thickened oil is relatively high, and the thickened oil is considered to have an oil viscosity of more than 50mPa & s. The heavy oil can be classified into common heavy oil, extra heavy oil and super heavy oil according to the viscosity standard. The viscosity of crude oil is one of the important factors that directly affect the production of an oil well. The viscosity is too high, so that the production well cannot produce oil. The chemical composition of crude oil is an internal factor for determining the viscosity, and the content of colloid and asphaltene in the crude oil has a great influence on the viscosity of the crude oil. In addition, the viscosity of crude oil is also affected by reservoir formation factors and reservoir environment, such as cap seal, reservoir depth, reservoir temperature, dissolved gas-oil ratio. The viscosity difference of the thick oil is large due to different environments and various factors.
The distribution difference of the crude oil viscosity brings certain difficulty for the simulation and accurate description of oil reservoir characteristics of heavy oil thermal recovery numerical value and the development of high-efficiency production history fitting. In the traditional thick oil thermal recovery numerical simulation, in order to describe the heterogeneity of viscosity distribution, a plurality of sets of viscosity-temperature curves are defined through viscosity-temperature partitions to approximately describe the difference of the viscosity distribution. Although the method is relatively simple, the description precision of the viscosity heterogeneity is low, and the heterogeneity of the viscosity distribution of the crude oil cannot be well reflected. Therefore, we invented a method for describing the viscosity heterogeneity of heavy oil reservoirs in numerical simulation of underground crude oil, and solve the above technical problems.
Disclosure of Invention
The invention aims to provide a method for describing the heterogeneity of the viscosity of underground crude oil by heavy oil reservoir numerical simulation, which can finely describe the heterogeneity of the viscosity of the underground crude oil in the heavy oil reservoir numerical simulation.
The object of the invention can be achieved by the following technical measures: the method for describing the viscosity heterogeneity of the heavy oil reservoir numerical simulation underground crude oil comprises the following steps: step 1, testing the viscosity and the gas-oil ratio of ground degassed crude oil; step 2, calculating the viscosity of the underground crude oil of each well, respectively finding out the maximum value and the minimum value of the viscosity, and carrying out viscosity-temperature test; step 3, defining heavy components and light components through numerical simulation, and inputting viscosity-temperature curves of the two components; step 4, calculating the mole fraction of the heavy component and the mole fraction of the light component of each well; step 5, respectively solving the mole fraction field data of the heavy component and the light component through well point interpolation calculation; and 6, calculating a viscosity distribution field of the underground crude oil in the heavy oil reservoir numerical simulation.
The object of the invention can also be achieved by the following technical measures:
In step 1, crude oil sampling is performed separately for each well in the numerical simulation study area.
In step 1, the oil sample of each well is tested, and the viscosity and the gas-oil ratio of the ground degassed crude oil are respectively measured.
in step 2, the viscosity value of the underground crude oil of each well is calculated according to the formula (1):
μo＝A×μB (1)
A＝10.7×(5.615Rs+100)-0.515
B＝5.44×(5.615Rs+150)-0.338
In the formula, muoRepresents the viscosity of underground crude oil, mPa & s;
Mu represents the viscosity of the ground degassed crude oil, mPa & s;
Rs-dissolved gas-oil ratio, Nm3/m3。
in step 2, the wells with the maximum value and the minimum value of the viscosity of the underground crude oil are found out, and viscosity-temperature tests are carried out to respectively represent the viscosity-temperature data of the heavy component and the light component.
In step 3, the heavy oil composition of each well is expressed by mixing a heavy component and a light component according to a certain proportion; in the heavy oil reservoir numerical simulation, two components are respectively defined, one is a heavy component, and the other is a light component, and the viscosity temperature data of the tested crude oil in the step 2 is input into the numerical simulation.
In step 3, in the heavy oil reservoir numerical simulation, the linear mixing criterion relation between the mole fraction of the heavy oil components and the component viscosity is as follows:
in the formula,. mu.oRepresents the viscosity of the crude oil underground; mu.soiRepresents the component viscosity; x is the number ofirepresents the mole fraction of the component; n iscRepresenting the number of the components;
The heavy oil component is expressed by 2 components of heavy component and light component, so n in the formulacAt this point, the linear mixing criteria relation may be expressed as:
ln(μo)＝x11n(μo1)+x2ln(μo2) (2)
Wherein x is1+x2＝1。
In step 4, the linear mixing criterion relation between the component mole fraction of the heavy oil and the component viscosity, namely the formula (2), is appropriately transformed into a function relation with the component viscosity as an independent variable and the component mole fraction as a dependent variable, as shown in the formula (3):
In step 4, according to the transformed linear mixing criterion relation (3), the mole fraction values of the heavy component and the light component of each well are respectively calculated.
In step 5, by using a kriging interpolation or an inverse distance weighted average algorithm, well interpolation calculation is performed to respectively obtain the mole fraction field data of the heavy component and the mole fraction field data of the light component.
in step 6, linear mixing criterion relation (2) between the mole fraction of the heavy oil component and the component viscosity is utilized, and according to the mole fractions of the heavy component and the light component, underground crude oil viscosity distribution field data in the oil reservoir numerical simulation can be calculated.
The invention relates to a method for describing the heterogeneity of the viscosity distribution of underground crude oil simulated by heavy oil reservoir numerical values, which comprises the steps of utilizing the linear mixing rule relation between the mole fraction of heavy oil components and the component viscosity, representing the crude oil by two components of heavy components and light components, calculating the mole fraction values of the heavy components and the light components of each well, calculating the mole fractions of the heavy components and the light components at any point position by a well point interpolation method, further calculating the viscosity distribution field of the underground crude oil, and thus finely describing the heterogeneity of the viscosity distribution of the underground crude oil, and further improving the accuracy of the description of the viscosity distribution of the underground crude oil in the heavy oil reservoir numerical simulation. The invention relates to a method for describing heavy oil reservoir numerical simulation underground crude oil viscosity heterogeneity, which fully considers technical and economic factors.
Drawings
FIG. 1 is a flow chart depicting one embodiment of a method of the present invention for numerically modeling the heterogeneity of the viscosity of the subterranean crude oil in a heavy oil reservoir;
FIG. 2 is a field diagram of mole fractions of heavy and light components of heavy oil calculated by well interpolation in an embodiment of the present invention;
Fig. 3 is a graph of the viscosity distribution of the underground crude oil in the numerical simulation of the heavy oil reservoir in accordance with an embodiment of the present invention.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the invention more comprehensible, preferred embodiments accompanied with figures are described in detail below.
as shown in fig. 1, fig. 1 is a flow chart for describing a method for numerically simulating viscosity inhomogeneity of subsurface crude oil for heavy oil reservoirs.
101, sampling crude oil from each production well of a heavy oil reservoir numerical simulation research area, and testing the viscosity of ground degassed crude oil; and (4) respectively sampling the crude oil viscosity of each well of the heavy oil reservoir numerical simulation research block. And (5) respectively carrying out oil sample test on the sampling wells to measure the viscosity and the gas-oil ratio of the ground degassed crude oil.
And 102, calculating the viscosity of the underground crude oil of each well, respectively finding out the wells with the maximum viscosity values and the minimum viscosity values, and carrying out crude oil viscosity temperature test to respectively represent viscosity temperature data of heavy components and light components. And (4) calculating the viscosity value of the underground crude oil of each well according to the formula (1).
μo＝A×μB (1)
A＝10.7×(5.615Rs+100)-0.515
B＝5.44×(5.615Rs+150)-0.338
in the formula, muorepresents the viscosity of underground crude oil, mPa & s;
Mu represents the viscosity of the ground degassed crude oil, mPa & s;
Rs-dissolved gas-oil ratio, Nm3/m3。
103, defining 2 components of the heavy component and the light component, and respectively inputting crude oil viscosity temperature test data representing the heavy component and the light component into the heavy oil reservoir numerical simulation; the thick oil composition of each well is expressed by mixing a heavy component and a light component according to a certain proportion. In the heavy oil reservoir numerical simulation, two components, one being a heavy component and the other being a light component, are respectively defined, and the viscosity temperature data of the test crude oil in step 102 is input into the numerical simulation.
In the heavy oil reservoir numerical simulation, the linear mixing criterion relation between the mole fraction of heavy oil components and the viscosity of the components is as follows:
in the formula,. mu.orepresents the viscosity of the crude oil underground; mu.soiRepresents the component viscosity; x is the number ofiRepresents the mole fraction of the component; n iscRepresents the number of components.
In the method, the heavy oil component can be expressed by 2 components of heavy component and light component, so n in the formulacAt this point, the linear mixing criteria relation may be expressed as:
ln(μo)＝x1 ln(μo1)+x2ln(μo2) (2)
wherein x is1+x2＝1
104, transforming a linear mixing criterion relation between the component mole fraction and the component viscosity, and respectively calculating the mole fraction of the heavy component and the mole fraction of the light component of each well; the linear mixing criteria relationship between the component mole fraction and the component viscosity is suitably transformed into a functional relationship with the component viscosity as an independent variable and the mole fraction as a dependent variable. And respectively calculating the mole fractions of the heavy component and the light component of each well according to the transformed linear mixing criterion relation.
The linear mixing criteria relation (2) between the viscous oil component mole fraction and the component viscosity is suitably transformed into a functional relation with the component viscosity as an independent variable and the component mole fraction as a dependent variable, as shown in formula (3).
and (4) according to the converted linear mixing criterion relation (3), calculating the mole fraction values of the heavy component and the light component of each well respectively.
105, respectively calculating the mole fraction field data of the heavy component and the light component through well point interpolation calculation; and respectively solving the mole fraction field data of the heavy component and the mole fraction field data of the light component by utilizing a Krigin interpolation or an inverse distance weighted average algorithm and through well point interpolation calculation.
and 106, calculating a viscosity distribution field of the underground crude oil in the heavy oil reservoir numerical simulation by using a linear mixing criterion, so that the heterogeneity of the viscosity of the underground crude oil in the reservoir can be described. And calculating the viscosity distribution field of the underground crude oil in the numerical simulation of the heavy oil reservoir by using the linear mixing criterion relation between the component mole fraction and the component viscosity and according to the mole fractions of the heavy component and the light component, so as to describe the non-homogeneity of the viscosity of the underground crude oil in the reservoir.
In one embodiment of the present invention, the method comprises the following steps:
In step 1, crude oil of each production well of the heavy oil reservoir numerical simulation research block is sampled, and the viscosity and the gas-oil ratio of the ground degassed crude oil are tested. In one example, the study block had 48 production wells, each of which was sampled and tested for degassed crude oil viscosity and gas-to-oil ratio. The flow proceeds to step 2.
in step 2, the viscosity of the subsurface crude oil for each well is calculated. In one embodiment, the viscosities of the crude oil in the subsurface of 48 wells can be calculated separately. Subsequently, wells with the highest and lowest viscosity values of the underground crude oil are found, respectively, STS3RP10 and STS3RP13, and crude oil samples from these two wells are subjected to viscometric temperature tests, representing viscometric temperature data for heavy and light fractions, respectively. Table 1 shows the surface oil viscosity and the subsurface oil viscosity for each well in the examples. Table 2 shows viscosity temperature data for heavy and light components of the heavy oil in the examples.
Table 1 table of viscosity values of crude oil on ground and underground crude oil on production well in heavy oil reservoir numerical simulation research area
Table 2 shows viscosity-temperature curves of heavy and light components of heavy oil
the flow proceeds to step 3.
in step 3, the heavy oil composition of each well is expressed by a heavy component and a light component, and is respectively defined in the heavy oil reservoir numerical simulation, and crude oil viscosity temperature test data representing the heavy component and the light component are respectively input into the heavy oil reservoir numerical simulation. The flow proceeds to step 4.
In step 4, the linear mixing rule relation between the component mole fraction and the component viscosity is properly transformed into a functional relation taking the component viscosity as an independent variable and the mole fraction as a dependent variable, and the mole fractions of the heavy component and the light component of each well are respectively calculated according to the transformed linear mixing rule relation. Table 3 shows the mole fractions of heavy and light components for each production well in the examples.
Table 3 table for calculating mole fractions of heavy and light components per well
The flow proceeds to step 5.
and 5, respectively carrying out interpolation calculation on the mole fractions of the heavy component and the light component calculated at each well point by using a kriging interpolation algorithm to obtain a mole fraction field of the heavy component and the mole fraction field of the light component. FIG. 2 is a plot of the interpolated mole fraction fields of the heavy and light fractions in the examples. The flow proceeds to step 6.
And 6, calculating the viscosity distribution field of the underground crude oil by using the linear mixing rule-of-thumb relation between the mole fraction of the heavy oil components and the component viscosity again and using heavy oil reservoir numerical simulation software according to the mole fraction fields of the heavy components and the light components. FIG. 3 is a plot of the subsurface crude oil viscosity distribution field calculated by the software of the example.
Claims (11)
1. the method for describing the viscosity heterogeneity of the heavy oil reservoir numerical simulation underground crude oil is characterized by comprising the following steps of:
step 1, testing the viscosity and the gas-oil ratio of ground degassed crude oil;
Step 2, calculating the viscosity of the underground crude oil of each well, respectively finding out the maximum value and the minimum value of the viscosity, and carrying out viscosity-temperature test;
step 3, defining heavy components and light components through numerical simulation, and inputting viscosity-temperature curves of the two components;
Step 4, calculating the mole fraction of the heavy component and the mole fraction of the light component of each well;
Step 5, respectively solving the mole fraction field data of the heavy component and the light component through well point interpolation calculation;
And 6, calculating a viscosity distribution field of the underground crude oil in the heavy oil reservoir numerical simulation.
2. The method for describing the viscosity heterogeneity of heavy oil reservoirs in numerical simulation of underground crude oil according to claim 1, wherein in step 1, crude oil sampling is performed separately for each well in the numerical simulation study area.
3. The method for describing the viscosity heterogeneity of heavy oil reservoirs in numerical simulation of underground crude oil according to claim 2, wherein in step 1, the oil samples of each well are tested, and the viscosity and gas-oil ratio of the surface degassed crude oil are respectively measured.
4. The method for describing the viscosity heterogeneity of heavy oil reservoirs numerical simulation underground crude oil according to claim 1, wherein in step 2, the viscosity value of underground crude oil of each well is calculated according to formula (1):
μo＝A×μB (1)
A＝10.7×(5.615Rs+100)-0.515
B＝5.44×(5.615Rs+150)-0.338
In the formula, muoRepresents the viscosity of underground crude oil, mPa & s;
Mu represents the viscosity of the ground degassed crude oil, mPa & s;
rs-dissolved gas-oil ratio, Nm3/m3。
5. The method for describing the viscosity heterogeneity of heavy oil reservoirs numerical simulation underground crude oil according to claim 1, wherein in step 2, the wells with the maximum value and the minimum value of the viscosity of the underground crude oil are found, and viscosity temperature tests are carried out to represent the viscosity temperature data of heavy components and light components respectively.
6. The method for describing the viscosity heterogeneity of heavy oil reservoirs numerical simulation underground crude oil according to claim 1, wherein in step 3, the heavy oil composition of each well is expressed by mixing a heavy component and a light component according to a certain proportion; in the heavy oil reservoir numerical simulation, two components are respectively defined, one is a heavy component, and the other is a light component, and the viscosity temperature data of the tested crude oil in the step 2 is input into the numerical simulation.
7. The method for describing the viscosity heterogeneity of heavy oil reservoirs in numerical simulation of underground crude oil according to claim 6, wherein in the step 3, in the numerical simulation of heavy oil reservoirs, the linear mixing criterion relation between the mole fraction of heavy oil components and the viscosity of the components is as follows:
in the formula,. mu.orepresenting viscosity of underground crude oilDegree; mu.soiRepresents the component viscosity; x is the number ofiRepresents the mole fraction of the component; n iscrepresenting the number of the components;
The heavy oil component is expressed by 2 components of heavy component and light component, so n in the formulacat this point, the linear mixing criteria relation may be expressed as:
ln(μo)＝x1ln(μo1)+x2ln(μo2) (2)
Wherein x is1+x2＝1。
8. The method for describing the viscosity heterogeneity of heavy oil reservoirs numerically simulating underground crude oil according to claim 7, wherein in step 4, the linear mixing rule relation (2) between the component molar fraction and the component viscosity of heavy oil is appropriately transformed into a function relation with the component viscosity as an independent variable and the component molar fraction as a dependent variable, as shown in formula (3):
9. the method for describing the viscosity heterogeneity of heavy oil reservoirs in numerical simulation of underground crude oil according to claim 8, wherein in step 4, the mole fraction values of heavy component and light component of each well are calculated respectively according to the transformed linear mixing criterion relation (3).
10. The method for describing the viscosity heterogeneity of heavy oil reservoirs in a numerical simulation underground crude oil is characterized in that in step 5, a kriging interpolation or an inverse distance weighted average algorithm is used for well point interpolation calculation to respectively obtain mole fraction field data of heavy components and mole fraction field data of light components.
11. the method for describing the viscosity heterogeneity of heavy oil reservoirs in the numerical simulation of the underground crude oil according to claim 7, wherein in step 6, the viscosity distribution field data of the underground crude oil in the reservoir numerical simulation can be calculated by using the linear mixing criterion relation (2) between the mole fraction of the heavy oil component and the component viscosity and according to the mole fraction of the heavy component and the light component.
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Application publication date: 20191217 |