CN111287739B - Residual oil distribution prediction method based on stratum crude oil viscosity - Google Patents
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- 239000003921 oil Substances 0.000 title claims abstract description 73
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- 239000012530 fluid Substances 0.000 claims abstract description 15
- 238000011084 recovery Methods 0.000 claims abstract description 13
- 238000009412 basement excavation Methods 0.000 claims abstract description 5
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- 230000015572 biosynthetic process Effects 0.000 claims description 11
- 238000004364 calculation method Methods 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 11
- 239000003129 oil well Substances 0.000 claims description 9
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
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Abstract
The invention discloses a residual oil distribution prediction method based on stratum crude oil viscosity, which comprises the following steps: step 1), determining a parameter combination mainly based on fluid viscosity for each stratum in a target block; the parameter combination comprises the viscosity of crude oil and at least one of the other eight parameters; calculating to obtain all parameter values in the parameter combination; step 2), normalizing parameters in the parameter combination to obtain a normalized parameter combination V, respectively calculating entropy values of all the parameters in the parameter combination, and further calculating to obtain weights W of all the parameters; step 3), obtaining a comprehensive index I of the corresponding stratum according to the parameters determined in the parameter combination in the step 1) and the weight of each parameter obtained in the step 2) by the following formula; and 4) selecting a stratum with the comprehensive index of 0.5-0.75 as a potential layer, predicting an effective residual oil reserve enrichment area, and carrying out recovery excavation of residual oil.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas exploration and development, in particular to a residual oil distribution prediction method based on stratum crude oil viscosity.
Background
The exploration and development of oil and gas resources mainly surrounds two main subjects of improving the oil and gas exploration rate and the exploration benefit and improving the oil and gas recovery rate and the development benefit. With the increasing decrease of petroleum resources, the continuous running of energy prices and the increase of exploration difficulty and cost promote the development of heavy oil and extra heavy oil reservoirs and supplement petroleum reserves. Numerous oilfield development practices have shown that general crude oil recovery is only about 30%, and two-thirds of the remaining oil reservoirs remain underground, while heavy oil and extra heavy oil recovery is only about 10%. Heavy oil, extra heavy oil development is becoming more urgent and important in fluid analysis and enhanced recovery. As development objects become more complex, research on the distribution of residual oil must be advanced to a high-level, refined direction.
At present, the development of residual oil monitoring and mining technologies is emphasized at home and abroad, but the formation and distribution of residual oil are not deep enough, and particularly the distribution of residual oil with low recovery ratio for heavy oil and extra heavy oil development is not deep enough. To clarify the complex distribution characteristics of residual oil in heavy oil and extra heavy oil reservoirs, the reservoir description must develop to the direction of refinement and quantification, and by adopting a new technology and improving a conventional method, a geological model capable of reflecting underground objective conditions and finely describing the heterogeneous characteristics of the reservoirs is established, so that the effective development of the heavy oil and extra heavy oil reservoirs is realized.
The research of the distribution of the residual oil is very difficult, and the prediction of the distribution of the residual oil by only one discipline has very large limitation, and only the application of multidisciplinary theory, method and technology can accurately predict the distribution of the residual oil. The multidisciplinary comprehensive research requires that information such as geology, geophysics, reservoir physics, fluid seepage mechanics and the like are adopted to the maximum extent, and the formation conditions, distribution rules and control factors of the residual oil are researched. The prior art can not meet the actual requirements.
Disclosure of Invention
Aiming at the problems in the prior art, the invention provides a residual oil distribution prediction method based on the viscosity of stratum crude oil, which has reasonable design, definite index and accurate prediction and can be used for predicting the residual oil distribution in heavy oil and extra heavy oil stratum.
The invention is realized by the following technical scheme:
a residual oil distribution prediction method based on the viscosity of crude oil in a stratum comprises the following steps:
step 1), determining a parameter combination mainly based on fluid viscosity for each stratum in a target block; the parameter combination comprises crude oil viscosity, and at least one of the eight parameters including porosity, permeability, water saturation, sedimentary microphase, effective thickness to total thickness ratio of sandstone reservoir, permeability variation coefficient, permeability kick-in coefficient and permeability level difference is calculated; calculating to obtain all parameter values in the parameter combination;
step 2), normalizing parameters in the parameter combination to obtain a normalized parameter combination V, respectively calculating entropy values of all the parameters in the parameter combination, and further calculating to obtain weights W of all the parameters;
step 3), obtaining a comprehensive index I of the corresponding stratum according to the parameters determined in the parameter combination in the step 1) and the weight of each parameter obtained in the step 2) by the following formula;
I＝WV T
and 4) selecting a stratum with the comprehensive index of 0.5-0.75 as a potential layer, predicting an effective residual oil reserve enrichment area, and carrying out recovery excavation of residual oil.
Preferably, after the potential layer is obtained in the step 4), determining parameter combinations mainly based on fluid viscosity for each oil well in the potential layer; repeating steps 1) to 4), selecting a potential oil well, predicting as an effective residual oil reserve enrichment oil well, and carrying out recovery excavation of residual oil.
Preferably, when the selected calculation parameters comprise discontinuously-changed deposition microphase, carrying out the following quantitative assignment on the deposition microphase, and assigning a composite beach-and-dam value of 1; the value of the curved river channel is 0.8; the value of the breach fan is 0.6; the flooding plains are assigned 0.2; assigning a value of 0.1 to the split bay; the microphase value between river channels is 0.
Preferably, in step 2), the step of normalizing the parameters in the parameter combination is as follows,
writing different parameters in the same matrix is represented as follows:
wherein, when the parameter combination corresponds to the stratum, P jLi A j-th parameter representing an i-th stratum, and n represents the number of stratum; when the parameter combination corresponds to the oil well, P jLi A j-th parameter replaced with an i-th well; n represents the number of oil wells; l1 represents a response parameter of the first well;
carrying out normalization treatment on parameters which are inversely related to the characteristic oil content in the parameter combination, wherein the parameters comprise water saturation, crude oil viscosity, permeability level difference, permeability variation coefficient and permeability burst coefficient;
normalizing parameters positively correlated to the characteristic oil content in the parameter combination, including porosity, permeability and effective thickness/total thickness, by the following formula;
finally, the deposition microphase of the numerical value between 0 and 1 which is positively correlated with the characteristic oiliness in the parameter combination and 8 normalized parameter combinations are combined to obtain the following normalized result, namely normalized parameter combination V,
further, in the normalization process, for parameters of permeability, resistivity and crude oil viscosity on a logarithmic scale, calculation of taking the logarithm of each term in two normalization formulas and then performing normalization is required.
Further, calculating entropy values of the parameters according to the normalized results:
still further, the entropy value of each parameter is calculated according to the normalized result, the weight W of each parameter is calculated,
preferably, in step 4), the recovery of the remaining oil is not considered when the overall index is greater than 0.75; and when the comprehensive index is smaller than 0.5, the mining of the residual oil is considered as a secondary potential layer.
Compared with the prior art, the invention has the following beneficial technical effects:
according to the invention, the crude oil viscosity parameter is introduced into the residual oil distribution evaluation, 9 parameters which can reflect the property of reservoir fluid (crude oil viscosity and water saturation) and the parameters which reflect the quality and geometric form of the reservoir (porosity, permeability, effective thickness/total thickness and deposition micro-equality) are selected, the residual oil distribution comprehensive index of the reservoir is obtained based on the entropy weight method, and a good application effect is obtained in practical application. Among the 8 horizontal wells which are drilled at present, the production results of 7 wells are consistent with the calculation results of the invention, and the coincidence rate reaches 87.5%.
Drawings
Fig. 1 shows the overall index of the remaining oil distribution of different small layers of JN-4 blocks of a country according to the examples of the present invention.
Fig. 2 is a graph of the overall index of the distribution of remaining oil in a single sand layer of JN-4 block E2 and the simulated remaining oil in a reservoir according to an embodiment of the present invention.
Detailed Description
The invention will now be described in further detail with reference to specific examples, which are intended to illustrate, but not to limit, the invention.
In the invention, 9 parameters which mainly comprise the viscosity of crude oil and have an indication effect on the oil content of a reservoir are firstly optimized according to the property of extra heavy oil, and then the comprehensive index is calculated according to the 9 parameters. The 9 parameters are fluid viscosity, porosity, permeability, water saturation, sedimentary microphase, sandstone reservoir effective thickness to total thickness ratio, permeability variation coefficient, permeability kick-in coefficient and permeability level difference, wherein other parameters besides fluid viscosity can be selected, increased or decreased according to practical conditions, and P is used for each 1 -P 9 To represent the 9 parameters in turn. The calculation of the 9 parameters adopts a common calculation method in industry, wherein the deposition microphase is not a continuously-changing numerical value, and the quantitative assignment needs to be carried out on the deposition microphase: the physical properties of the composite beach dam in all micro phases are best, the sand body is thickest, and the value is 1; the sediment of the curved-flow river channel is mainly the sand body with medium sorting, the bottom is thick layer and medium grain, the sand rock with medium-bad sorting is assigned to 0.8; the lithology of the sea-ear fan sediment is mainly fine grain-extremely fine grain sandstone, and the lithology is 0.6; the lithology characteristics of the inundation plain are between the filling deposition of the braided river channel and the deposition of the diversion bay, mainly mud rock, and are assigned to be 0.2; the fine sandstone deposited in the diversion bay is complex, and the bottom is usually formed into siltstone or extremely fine sandstone layer, namely thin-layer mudstone or thick-layer mudstone upwards, which is 0.1; little sand is deposited in the microphase between the river channels, and the value is 0.
The calculation method of the comprehensive indication parameter comprises the following steps:
I＝WV T (1)
wherein W is a weighted term and V is a parameter term, wherein the expression mode of V is as follows.
Writing different parameters of different horizons in the same matrix is represented as follows:
p in the above jLi The j-th parameter representing the i-th formation, thus representing the residual oil distribution of the different formations, where P is the distribution in the plane to be considered jLi The corresponding data of the ith well is replaced; n represents the number of formations or wells. L1 represents a response parameter of the first well.
Since each indicated parameter has different scales and possibly different oil contents characterized by the sizes, different methods are needed to normalize the parameters:
of the above two formulas, formula (3) is applicable to parameters that are inversely related to characterizing oil content, such as water saturation, crude oil viscosity, permeability level difference, permeability variation coefficient, and permeability breakthrough coefficient; formula (4) applies to parameters that are positively correlated with characterizing oil content, such as porosity, permeability and effective thickness/total thickness.
If the parameters are logarithmic for permeability, resistivity and crude oil viscosity, the logarithm is taken for each of the formulas (3) and (4) and then calculated.
And parameters representing oil content in positive correlation, wherein the deposition microphase belongs to a value between 0 and 1 of positive correlation, and normalization is not needed.
The results of combining the deposition microphase and normalizing the parameters in formula (2) using formulas (3) and (4) are as follows:
calculating entropy values of the parameters according to the normalized results:
and from this the weight W is calculated:
the residual oil comprehensive index can be obtained by taking the results of the formulas (5) and (7) into the formula (1).
The calculation result shows that: the effective residual oil reserves are mainly enriched in the area with the comprehensive index of 0.5-0.75, when the comprehensive index is more than 0.75, the physical properties of the reservoir are better, the thickness of the sand body is large, the oil content is better, the water flooding is easy, the water washing degree is higher, and the saturation of the residual oil is reduced; in the region where the combination index is less than 0.5, the physical properties of the reservoir and the fluid are poor, the thickness of the oil layer is thin, and the recovery of the residual oil is unfavorable and can be disregarded although the saturation of the residual oil is relatively high. Only the region with the comprehensive index of 0.5-0.75 has better permeability, and the flooding degree is not high, so that the method is a main target for further mining of residual oil. Thus, the distribution of the integrated index over a plane can be used to predict the remaining oil-rich zone.
The method of the present invention will be further described with reference to well data of JN-4 block of a country.
The remaining oil distribution of the total of 7 small layers A, B, C, C2, E1, E2 and E3 is analyzed by calculating according to the data of the 18 wells with nuclear magnetic resonance data in the block.
(1) The values of the various parameters (porosity, permeability coefficient of variation, permeability snap-in coefficient, permeability level difference, water saturation, effective thickness/total sand thickness, sedimentary microphases and fluid viscosity) in each small layer were first calculated, where the different sedimentary microphases were quantified as follows because the sedimentary microphases were not continuously varying values: the physical properties of the composite beach dam in all micro phases are best, the sand body is thickest, and the value is 1; the sediment of the curved-flow river channel is mainly the sand body with medium sorting, the bottom is thick layer and medium grain, the sand rock with medium-bad sorting is assigned to 0.8; the lithology of the sea-ear fan sediment is mainly fine grain-extremely fine grain sandstone, and the lithology is 0.6; the lithology characteristics of the inundation plain are between the filling deposition of the braided river channel and the deposition of the diversion bay, mainly mud rock, and are assigned to be 0.2; the fine sandstone deposited in the diversion bay is complex, and the bottom is usually formed into siltstone or extremely fine sandstone layer, namely thin-layer mudstone or thick-layer mudstone upwards, which is 0.1; little sand is deposited in the microphase between the river channels, and the value is 0.
(2) The calculation is carried out by using the formulas (1) to (7), and the comprehensive index calculation weight list in the block is obtained as follows:
table 1 JN-4 weight for each index parameter of the reservoir
The calculated composite index is shown in figure 1. There is a large difference between the dominant and non-dominant small layers, A, B and C1 small layers have a lower overall index, E1 small layers have a higher overall index, and C2, E2 and E3 small layers are of moderate extent. The physical properties of the E1 small layer are good, the water washing degree is high, and the saturation of residual oil is reduced; the small layers C2, E2 and E3 are relatively rich areas of residual oil, and belong to main digging targets; A. the movable residual oil of the layers B and C1 is relatively low, and belongs to a secondary diving object.
(3) Data of various parameters of different wells inside different small layers are obtained. Taking E2 single sand layer as an example, obtaining each parameter value, and calculating the residual oil distribution in each small layer by using the formulas (1) - (7), wherein P in the formula (2) jLi Parameter data representing different wells. The comprehensive index of the reservoir residual oil distribution and the saturation distribution of the reservoir simulated residual oil are shown in figure 2。
Claims (8)
1. The residual oil distribution prediction method based on the formation crude oil viscosity is characterized by comprising the following steps of:
step 1), determining a parameter combination mainly based on fluid viscosity for each stratum in a target block; the parameter combination comprises crude oil viscosity, and at least one of the eight parameters including porosity, permeability, water saturation, sedimentary microphase, effective thickness to total thickness ratio of sandstone reservoir, permeability variation coefficient, permeability kick-in coefficient and permeability level difference is calculated; calculating to obtain all parameter values in the parameter combination;
step 2), normalizing parameters in the parameter combination to obtain a normalized parameter combination V, respectively calculating entropy values of all the parameters in the parameter combination, and further calculating to obtain weights W of all the parameters;
step 3), obtaining a comprehensive index I of the corresponding stratum according to the parameters determined in the parameter combination in the step 1) and the weight of each parameter obtained in the step 2) by the following formula;
I＝WV T
and 4) selecting a stratum with the comprehensive index of 0.5-0.75 as a potential layer, predicting an effective residual oil reserve enrichment area, and carrying out recovery excavation of residual oil.
2. The method for predicting the distribution of remaining oil based on the viscosity of formation fluid according to claim 1, wherein after the potential layer is obtained in step 4), determining a combination of parameters based on the viscosity of the fluid for each well in the potential layer; repeating steps 1) to 4), selecting a potential oil well, predicting as an effective residual oil reserve enrichment oil well, and carrying out recovery excavation of residual oil.
3. The method for predicting the distribution of residual oil based on the viscosity of formation fluid according to claim 1 or 2, wherein when the selected calculation parameters comprise deposition microphases which discontinuously change, the following quantitative assignment is carried out on the deposition microphases, and the complex beach-dam assignment is 1; the value of the curved river channel is 0.8; the value of the breach fan is 0.6; the flooding plains are assigned 0.2; assigning a value of 0.1 to the split bay; the microphase value between river channels is 0.
4. The method for predicting the distribution of residual oil based on the viscosity of formation fluid according to claim 1 or 2, wherein in the step 2), the step of normalizing the parameters in the parameter combination is as follows,
writing different parameters in the same matrix is represented as follows:
wherein, when the parameter combination corresponds to the stratum, P jLi A j-th parameter representing an i-th stratum, and n represents the number of stratum; when the parameter combination corresponds to the oil well, P jLi A j-th parameter replaced with an i-th well; n represents the number of oil wells; l1 represents a response parameter of the first well;
carrying out normalization treatment on parameters which are inversely related to the characteristic oil content in the parameter combination, wherein the parameters comprise water saturation, crude oil viscosity, permeability level difference, permeability variation coefficient and permeability burst coefficient;
normalizing parameters positively correlated to the characteristic oil content in the parameter combination, including porosity, permeability and effective thickness/total thickness, by the following formula;
finally, the deposition microphase of the numerical value between 0 and 1 which is positively correlated with the characteristic oiliness in the parameter combination and 8 normalized parameter combinations are combined to obtain the following normalized result, namely normalized parameter combination V,
5. the method for predicting the distribution of residual oil based on the viscosity of crude oil in a stratum according to claim 4, wherein in the normalization process, for parameters with logarithmic scales of permeability and viscosity of crude oil, calculation is required for taking the logarithm of each term in two normalization formulas and then normalizing.
6. The method for predicting the distribution of residual oil based on the viscosity of crude oil in a stratum as claimed in claim 4, wherein the entropy value of each parameter is calculated according to the normalized result:
7. the method for predicting residual oil distribution based on formation crude oil viscosity according to claim 6, wherein entropy values of the respective parameters are calculated based on the normalized result, weights W of the respective parameters are calculated,
8. the method for predicting the distribution of residual oil based on the viscosity of crude oil in a formation as set forth in claim 1, wherein in the step 4), when the integrated index is greater than 0.75, the recovery of residual oil is not considered; and when the comprehensive index is smaller than 0.5, the mining of the residual oil is considered as a secondary potential layer.
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