CN110688742A - Method for quantitatively characterizing dynamic change formed by extraction degree in water-flooding oil reservoir development stage - Google Patents
Method for quantitatively characterizing dynamic change formed by extraction degree in water-flooding oil reservoir development stage Download PDFInfo
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Abstract
The invention discloses a dynamic change quantitative characterization method for the extraction degree composition in the water-flooding oil reservoir development stage, which decomposes the stage extraction degree by five parameters of the stage oil displacement efficiency, the plane sweep coefficient, the longitudinal sweep coefficient, the water-drive reserve control degree and the water-drive reserve utilization degree to obtain the change curves of different parameters along with the water content. Dynamic decomposition research is formed by the stage recovery degree: firstly, characteristic parameters of yield increasing measures with different action mechanisms can be deeply analyzed, and by comparing the change conditions of all parameters in the extraction degrees of the stages before and after the measures, compared with the conventional general evaluation method, the method has the advantages that the evaluation parameters are more detailed and more targeted; secondly, the main development contradiction of oil reservoirs in different water-containing stages is determined.
Description
Technical Field
The invention belongs to the technical field of reservoir engineering in oil and gas field development, and particularly relates to a method for quantitatively characterizing dynamic change of extraction degree in a reservoir water-flooding development stage.
Background
At present, the water injection development mode of maintaining the pressure of an oil layer by oil field water injection is widely adopted at home and abroad. The stage production degree refers to the percentage of the accumulated oil production or gas production of the oil and gas field in the floor mass reserves. For water-flooding oil reservoirs, the relationship between the stage extraction degree and the comprehensive water content is generally used for researching the water drive characteristics and the predicted recovery ratio of the oil reservoir. Without a decomposition study of the composition of the stage production degree. In different stages of oil field development, to improve the development effect, plan adjustment or stimulation measures are usually performed, including injection-production adjustment, fine zonal injection, well pattern encryption, profile control and water shutoff, or enhanced oil recovery techniques related to tertiary oil recovery, and the like. When the effect evaluation of the production increasing measures is carried out, parameters such as increasing oil, decreasing and decreasing, maintaining the level of formation pressure, stage extraction degree and the like are usually used for evaluation, but because the yield increasing mechanisms of different technologies are different, such as the main purpose of well pattern encryption adjustment, plane sweep coefficients are improved, the improvement degree of the plane sweep coefficients and the contribution of the plane sweep coefficients to the stage extraction degree are more emphasized during the effect evaluation. However, the existing method for evaluating the effect of the yield increasing measure is too simple and general, and cannot realize the directional evaluation of the measure effect, so that the adaptability of the technology in an oil reservoir is not sufficient, so that the analysis needs to be carried out from the angle of the change of the stage extraction degree, and the change rules of the oil displacement efficiency, the stage sweep coefficient, the stage plane sweep coefficient and the stage longitudinal sweep coefficient before and after the measure, the effect of the directional evaluation measure and the adaptability of the technology are compared.
Disclosure of Invention
Aiming at the problem that the adaptability of the technology in the oil reservoir is not deeply known due to the fact that the effect evaluation method of different yield increasing measures for water-flooding oil reservoir development is too simple and general and directional evaluation of the effect of the measures cannot be achieved at present, the method for quantitatively characterizing the dynamic change formed by the extraction degree in the oil reservoir water-flooding development stage is provided, and a method for deeply knowing the adaptability of different technologies is provided.
In order to achieve the purpose, the invention provides a quantitative characterization method for forming the stage mining degree dynamically changing along with the water content by combining actual oil deposit production dynamic data, water absorption profile test data and water displacement relative permeability data, and the stage mining degree is decomposed into five parameters of stage oil displacement efficiency, plane sweep coefficient, longitudinal sweep coefficient, water drive reserve control degree and water drive reserve utilization degree, so as to obtain the change curves of different parameters along with the water content.
The method comprises the following steps:
step 1, calculating a stage extraction degree according to the ratio of the accumulated oil and the geological reserves of a target oil reservoir, a block or a measure well group to obtain a stage extraction degree-water ratio relation;
step 2, carrying out normalization calculation on a phase permeability curve according to different core water flooding relative permeability curves of a target oil reservoir or a block to obtain a relative permeability curve representing the target block, calculating water contents under different water saturations according to the phase permeability curve of the block and a flow rate equation, and then calculating water contents under different water saturations according to the water saturations SwIrreducible water saturation SwiResidual oil saturation SorCalculating the stage oil displacement efficiency to obtain a stage oil displacement efficiency-water content curve;
step 3, calculating a stage sweep coefficient according to the stage extraction degree-water content curve obtained in the step 1 and the stage oil displacement efficiency-water content curve obtained in the step 2 to obtain a stage sweep coefficient-water content curve;
step 4, calculating the water drive reserves control degrees of different water content stages to obtain stage water drive reserve control degree-water content curves;
step 5, calculating the utilization degree of stage water drive reserves under different water contents to obtain a stage water drive reserve control degree-water content curve;
step 6, calculating a stage longitudinal sweep coefficient according to the stage water drive reserve control degree obtained in the step 4 and the stage water drive reserve utilization degree obtained in the step 5 to obtain a stage longitudinal sweep coefficient-water ratio curve;
and 7, calculating a stage plane sweep coefficient according to the stage sweep coefficient obtained in the step 3 and the stage longitudinal sweep coefficient obtained in the step 6 to obtain a stage plane sweep coefficient-water content curve.
Further, step 2 comprises the following steps:
s1, carrying out normalization calculation on the relative permeability curve of the facies permeability curve according to different core water flooding relative permeability curves of the target oil reservoir or the block to obtain the relative permeability curve representing the block;
s2, calculating the water content under different water saturation according to the phase permeability curve of the block and the flow rate equation, and then calculating the water content under different water saturation according to the water saturation SwIrreducible water saturation SwiResidual oil saturation SorCalculating the stage oil displacement efficiency to obtain a stage oil displacement efficiency-water content curve;
efficiency of staged oil displacement
The calculation formula of (2) is as follows:
further, in step 3, the stage sweep coefficient is equal to the stage production degree divided by the stage flooding efficiency.
Further, in step 4, the stage water drive reserve control degree is equal to the accumulated thickness of the perforation intervals at different water content stages divided by the accumulated thickness of the oil reservoir.
Further, in step 5, the water drive reserve in the stage is divided by the accumulated water absorption thickness explained by all water absorption profile tests of the blocks in the stage with different water contents by the accumulated oil layer thickness.
Further, in step 6, the stage longitudinal sweep coefficient is equal to the stage water drive reserve control degree obtained in step 4 multiplied by the stage water drive reserve utilization degree determined in step 5.
Further, in step 7, the stage plane sweep coefficient is equal to the stage sweep coefficient obtained in step 3 divided by the stage longitudinal sweep coefficient determined in step 6.
Through the process, the stage production degree can be decomposed into the stage oil displacement efficiency, the plane sweep coefficient, the longitudinal sweep coefficient, the water drive reserve control degree and the water drive reserve utilization degree, and the change curves of different parameters along with the water content are obtained. And (4) directionally evaluating the effect of the measures by comparing the change conditions of the parameters before and after the measures.
Compared with the prior art, the method has at least the following beneficial technical effects that the quantitative characterization method for the stage extraction degree formed by combining the actual oil deposit production dynamic data, the water absorption profile test data and the water flooding relative permeability data and changing along with the dynamic change of the water content is provided, and the change condition formed by the stage extraction degree is characterized by the change curves of 5 parameters of the stage oil flooding efficiency, the plane sweep coefficient, the longitudinal sweep coefficient, the water flooding reserve control degree and the water flooding reserve utilization degree along with the water content. Dynamic decomposition research is formed by the stage recovery degree: firstly, characteristic parameters of yield increasing measures with different action mechanisms can be deeply analyzed, and by comparing the change conditions of all parameters in the extraction degrees of the stages before and after the measures, compared with the conventional general evaluation method, the method has the advantages that the evaluation parameters are more detailed and more targeted; secondly, the main development contradiction of oil reservoirs in different water-containing stages is determined, if the plane sweep coefficient is low, the measure direction in the later stage is mainly to improve the plane sweep coefficient; if the water drive reserve control degree is low, the later measures are mainly implemented by filling holes to improve the water drive reserve control degree. By comparing the change degree formed by the extraction degrees of the front and rear stages of the measures, the contribution rate of different parameters to the accumulated oil increment of the measures can be more accurately evaluated, the adaptability of the technology to different development contradictory oil reservoirs can be more clearly judged, the accurate matching of different technologies and development contradictory is realized, the effects of different measures are directionally evaluated, and a quantitative basis is provided for more deeply knowing the adaptability of different technologies. Meanwhile, according to the size of each parameter in different water-containing stages, the main contradiction of different development stages and the main direction for improving the development effect are determined.
Drawings
FIG. 1 is a flow chart of the phase extraction level composition decomposition.
Detailed Description
The present invention will be described in detail below with reference to the accompanying drawings and specific embodiments.
In the description of the present invention, it is to be understood that the terms "center", "longitudinal", "lateral", "up", "down", "front", "back", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", and the like, indicate orientations or positional relationships based on those shown in the drawings, and are used only for convenience in describing the present invention and for simplicity in description, and do not indicate or imply that the referenced devices or elements must have a particular orientation, be constructed and operated in a particular orientation, and thus, are not to be construed as limiting the present invention. Furthermore, the terms "first", "second" and "first" are used for descriptive purposes only and are not to be construed as indicating or implying relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of the present invention, "a plurality" means two or more unless otherwise specified. In the description of the present invention, it should be noted that, unless otherwise explicitly specified or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, e.g., as meaning either a fixed connection, a removable connection, or an integral connection; can be mechanically or electrically connected; they may be connected directly or indirectly through intervening media, or they may be interconnected 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.
Referring to fig. 1, a quantitative characterization method for forming dynamic change along with water content according to stage extraction degree formed by combining actual oil reservoir production dynamic data, water absorption profile test data and water displacement relative permeability data decomposes the stage extraction degree by 5 parameters of stage oil displacement efficiency, plane sweep coefficient, longitudinal sweep coefficient, water drive reserve control degree and water drive reserve utilization degree to obtain change curves of different parameters along with the water content, and the calculation method of different dynamic change curves comprises the following steps:
(1) and (3) calculating a stage extraction degree-water content curve: calculating the stage extraction degree according to the actual production dynamic data of the target oil reservoir, block or measure well group by the ratio of the accumulated oil and the geological reserves to obtain a stage extraction degree-water ratio relation;
(2) calculating a curve of oil displacement efficiency-water content in a stage: and selecting different core water flooding relative permeability curves representing the target oil deposit and the block, and performing normalization calculation on the relative permeability curves to obtain the relative permeability curve representing the block. Calculating the water content under different water saturation according to the phase permeability curve of the block and the flow rate equation, and then calculating the water content according to the water saturation SwIrreducible water saturation SwiResidual oil saturation SorCalculating the stage oil displacement efficiency to obtain a stage oil displacement efficiency-water content curve which can represent the average oil displacement efficiency in different water-containing stages-water injection swept areas;
the calculation formula of the stage oil displacement efficiency is as follows:
in the above formula: swThe water saturation; swiTo restrict water saturation, SorIn order to be the residual oil saturation degree,for stage flooding efficiency (water saturation of S)wDisplacement efficiency at the time of flooding), η is the displacement efficiency at the end of flooding (maximum water cut)Oil displacement efficiency of saturation).
(3) Calculating a stage sweep coefficient-water content curve: calculating a stage sweep coefficient according to the stage extraction degree-water content curve obtained in the step (1) and the stage oil displacement efficiency-water content curve obtained in the step (2) under the same water content to obtain a stage sweep coefficient-water content curve;
the stage sweep coefficient is stage extraction degree/stage oil displacement efficiency;
(4) and (3) counting a water drive reserve control degree-water content curve in the stage: calculating the water drive reserves control degrees of different water content stages to obtain stage water drive reserve control degree-water content curves;
and controlling the stage water flooding reserve degree, namely, using the accumulated perforation interval thickness/accumulated oil reservoir layer thickness of different water content stages.
(5) And (3) counting a water drive reserve utilization degree-water content curve in the stage: calculating the utilization degree of stage water drive reserves under different water contents to obtain a stage water drive reserve control degree-water content curve;
accumulated water absorption thickness/accumulated oil layer thickness explained by all water absorption profile test of blocks in stage with different water content
(6) Calculating a longitudinal sweep coefficient-water content curve at a stage: calculating a stage longitudinal sweep coefficient to obtain a stage longitudinal sweep coefficient-water content curve;
stage water drive reserve usage degree determined by stage water drive reserve control degree x (5) obtained by stage longitudinal sweep coefficient (4)
(7) Determining a stage plane wave spread coefficient-water content curve: and calculating the stage plane wave spread coefficient to obtain a stage plane wave spread coefficient-water content curve.
And (3) determining the stage longitudinal wave spread coefficient by the stage plane wave spread coefficient/(6) obtained by calculation.
Through the process, the stage production degree can be decomposed into the stage oil displacement efficiency, the plane sweep coefficient, the longitudinal sweep coefficient, the water drive reserve control degree and the water drive reserve utilization degree, and the change curve of the five parameters along with the water content is obtained.
The stage extraction degree is stage oil displacement efficiency multiplied by stage swept volume;
step swept volume is the step plane swept volume multiplied by the step longitudinal swept volume;
the stage longitudinal swept volume is stage water drive reserve utilization degree multiplied by stage water drive reserve control degree;
step water drive reserve consumption degree is equal to step accumulated perforation interval thickness/step accumulated oil layer thickness;
and controlling the stage water flooding reserve, namely stage accumulated water absorption interval thickness/stage accumulated perforation interval thickness.
When the stage oil displacement efficiency is low, the injection medium is recommended to be changed to improve the oil displacement efficiency, and the method specifically comprises the steps of injecting a surfactant and injecting gas (CO)2、N2Or natural gas, etc.);
when the plane sweep coefficient is low, the plane sweep coefficient is improved by the measures of injection-production adjustment, well pattern encryption and the like;
when the longitudinal sweep efficiency is low, the longitudinal sweep efficiency is improved by the modes of profile control of a water injection well, water shutoff of an oil well, water injection by layers, mining by layers and the like;
when the water drive reserve control degree is low, the perforation thickness is improved by selecting a layer and repairing holes, and the water drive reserve control degree is improved;
when the water drive reserve utilization degree is low, the water absorption thickness is improved through profile control of a water injection well and stratified water injection, and the water drive reserve utilization degree is improved.
By utilizing the change curve of the water content along with the water content, the main development contradiction of oil reservoirs in different water-containing stages and the adjustment direction of development policies can be clarified, the effects of different yield increasing measures can be directionally evaluated, and the pertinence of evaluation is improved.
The above-mentioned contents are only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited thereby, and any modification made on the basis of the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (8)
1. A method for quantitatively characterizing dynamic change formed by extraction degrees at a water injection oil reservoir development stage is characterized in that the extraction degrees at the stages are decomposed into five parameters of oil displacement efficiency, plane sweep coefficient, longitudinal sweep coefficient, water drive reserve control degree and water drive reserve utilization degree at the stages, and variation curves of different parameters along with water content are obtained.
2. The method for quantitatively characterizing the mining degree composition dynamic change in the waterflooding reservoir stage according to claim 1, which is characterized by comprising the following steps:
step 1, calculating a stage extraction degree according to the ratio of the accumulated oil and the geological reserves of a target oil reservoir, a block or a measure well group to obtain a stage extraction degree-water ratio relation;
step 2, carrying out normalization calculation on a phase permeability curve according to different core water flooding relative permeability curves of a target oil reservoir or a block to obtain a relative permeability curve representing the target block, calculating water contents under different water saturations according to the phase permeability curve of the block and a flow rate equation, and then calculating water contents under different water saturations according to the water saturations SwIrreducible water saturation SwiResidual oil saturation SorCalculating the stage oil displacement efficiency to obtain a stage oil displacement efficiency-water content curve;
step 3, calculating a stage sweep coefficient according to the stage extraction degree-water content curve obtained in the step 1 and the stage oil displacement efficiency-water content curve obtained in the step 2 to obtain a stage sweep coefficient-water content curve;
step 4, calculating the water drive reserves control degrees of different water content stages to obtain stage water drive reserve control degree-water content curves;
step 5, calculating the utilization degree of stage water drive reserves under different water contents to obtain a stage water drive reserve control degree-water content curve;
step 6, calculating a stage longitudinal sweep coefficient according to the stage water drive reserve control degree obtained in the step 4 and the stage water drive reserve utilization degree obtained in the step 5 to obtain a stage longitudinal sweep coefficient-water ratio curve;
and 7, calculating a stage plane sweep coefficient according to the stage sweep coefficient obtained in the step 3 and the stage longitudinal sweep coefficient obtained in the step 6 to obtain a stage plane sweep coefficient-water content curve.
3. The method for quantitatively characterizing the mining degree composition dynamic change in the waterflooding reservoir stage according to claim 2, wherein the step 2 comprises the following steps:
s1, carrying out normalization calculation on the relative permeability curve of the facies permeability curve according to different core water flooding relative permeability curves of the target oil reservoir or the block to obtain the relative permeability curve representing the block;
s2, calculating the water content under different water saturation according to the phase permeability curve of the block and the flow rate equation, and then calculating the water content under different water saturation according to the water saturation SwIrreducible water saturation SwiResidual oil saturation SorCalculating the stage oil displacement efficiency to obtain a stage oil displacement efficiency-water content curve;
efficiency of staged oil displacement
The calculation formula of (2) is as follows:
4. the method for quantitatively characterizing the formation of dynamic changes of the stage production degree of a water-flooding oil reservoir according to claim 2, wherein in the step 3, the stage sweep coefficient is equal to the stage production degree divided by the stage oil displacement efficiency.
5. The method for quantitatively characterizing the extraction degree of a water-flooding oil reservoir stage as a dynamic change according to claim 2, wherein in the step 4, the stage water-flooding reserve control degree is equal to the accumulated perforation interval thickness of different water content stages divided by the accumulated oil reservoir layer thickness.
6. The method for quantitatively characterizing the extraction degree composition dynamic change of the waterflood development reservoir stage as claimed in claim 2, wherein in step 5, the stage water drive reserve uses the accumulated water absorption thickness of all water absorption profile test interpretations of the blocks with the degree equal to that of the different water content stages to divide the accumulated oil layer thickness.
7. The method for quantitatively characterizing the extraction degree composition dynamic change of the waterflood reservoir stage according to claim 2, wherein in the step 6, the stage longitudinal sweep coefficient is equal to the stage water drive reserve control degree obtained in the step 4 multiplied by the stage water drive reserve utilization degree determined in the step 5.
8. The method for quantitatively characterizing the formation of dynamic changes of the stage extraction degree of a water-flooding oil reservoir according to claim 2, wherein in the step 7, the stage plane sweep coefficient is equal to the stage sweep coefficient obtained in the step 3 divided by the stage longitudinal sweep coefficient determined in the step 6.
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| CN116861714B (en) * | 2023-09-05 | 2023-11-24 | 西南石油大学 | Method for determining water flooding sweep degree of fracture-cavity oil reservoir |
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