CN114165227A - Flow field adjustment feasibility quantitative evaluation method based on reservoir equilibrium displacement - Google Patents
Flow field adjustment feasibility quantitative evaluation method based on reservoir equilibrium displacement Download PDFInfo
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- 239000003129 oil well Substances 0.000 claims description 4
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 abstract description 16
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- 239000003921 oil Substances 0.000 description 52
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
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- E—FIXED CONSTRUCTIONS
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Abstract
The invention belongs to the field of oil and gas field development, and particularly relates to a quantitative evaluation method for flow field adjustment feasibility based on reservoir balanced displacement. The method comprises the following steps: detecting the residual oil condition, the oil reservoir balanced displacement condition, the injection and production current situation and the balanced displacement matching condition of a mine field development unit; and judging the feasibility of the flow field adjustment implemented by the development unit according to the detection result and by combining the evaluation standard of the flow field adjustment feasibility. The quantitative evaluation method for the flow field adjustment feasibility based on the oil reservoir balanced displacement comprehensively considers the contradiction between the oil reservoir material foundation and the development, evaluates the feasibility and the necessity of the flow field adjustment from three dimensions of the residual oil material foundation, the oil reservoir balanced displacement condition, the injection and extraction current situation and the balanced displacement matching, evaluates the feasibility and the necessity comprehensively and objectively, and provides reliable technical support for the evaluation of the oil reservoir flow field adjustment resource potential in the later period of extremely high water content.
Description
Technical Field
The invention belongs to the field of oil and gas field development, and particularly relates to a quantitative evaluation method for flow field adjustment feasibility based on reservoir balanced displacement.
Background
The problem of low efficiency and ineffective circulation of injected water is prominent because the flow field is affected by the cross flow and the cross flow affects the uneven change of the flow field, even a high water consumption zone is developed when the oil reservoir is developed by injecting water for a long time, particularly a middle and high permeability sandstone oil reservoir with strong homogeneity. Not only the utilization rate of injected water is reduced, but also the dynamic heterogeneity in layers, interlamination and planes is aggravated, the zero-excavation difficulty of residual oil distribution is large, the water-oil ratio is sharply increased, and the production cost is greatly increased.
The traditional well pattern adjustment technology for the strata series mainly depends on drilling a new well to control the relative enrichment of residual oil so as to improve the oil reservoir recovery ratio, and cannot meet the requirement of benefit development in an ultrahigh water content development stage. Aiming at the practical problem, oil reservoir engineers provide a flow field adjustment development technology, namely, on the basis of fully utilizing old wells, depending on different water injection amounts and water injection directions of the water injection wells and differential liquid production strength of oil production wells, the high water consumption zone is longitudinally regulated and controlled, the high water consumption zone is horizontally regulated and controlled, and residual oil in the stratum is driven to a destination. The technology is particularly suitable for exploiting old oil fields for years with relatively fixed flow lines to further improve the oil reservoir recovery efficiency.
At present, the research on the flow field adjustment and development technology is mainly focused on two directions. Firstly, the method has more researches on the fluid seepage characteristics and the preferential flow field identification and characterization in the oil reservoir, can visually display the oil reservoir flow field distribution, describes the position and the development condition of a large pore passage, and realizes qualitative and semi-quantitative description of the oil reservoir flow field. For example, chinese patent application CN111209711A discloses a method for identifying a water flooding reservoir optimal flow field based on flow field diagnosis and clustering. And secondly, aiming at more research on how to adjust the flow field in a mine field, various flow field adjusting technical modes such as adjusting a diversion line by a well network, coordinating an injection-production drainage line, comprehensively treating a balanced flow field, performing multi-level fine adjustment on a profile, and performing injection-production coupling adjustment on the flow line are formed. For example, the chinese invention patent CN108049849B discloses a design method for controlling a planar flow field of a water-flooding reservoir; chinese patent application CN111563654A discloses a method for evaluating the suitability of a high water-cut reservoir flow field.
However, there is no relevant research currently on whether the development unit needs to implement flow field adjustment to further improve the reservoir development effect in the reservoir development practice, and on what degree the flow field displacement is unbalanced, the flow field adjustment needs to be performed to effectively improve the reservoir development effect.
The feasibility analysis of the flow field adjustment of the oil reservoir development unit is an important premise of the flow field adjustment, so that the quantitative evaluation method of the flow field adjustment feasibility is significant.
Disclosure of Invention
The invention mainly aims to provide a quantitative evaluation method for flow field adjustment feasibility based on reservoir balanced displacement, provides a quantitative evaluation standard for judging whether a reservoir development unit needs to implement flow field adjustment or not, and fills the blank in the prior art.
In order to achieve the purpose, the invention adopts the following technical scheme:
the invention provides a flow field adjustment feasibility quantitative evaluation method based on reservoir equilibrium displacement, which comprises the following steps:
detecting the residual oil condition, the oil reservoir balanced displacement condition, the injection and production current situation and the balanced displacement matching condition of a mine field development unit;
and judging the feasibility of the flow field adjustment implemented by the mine development unit according to the detection result and by combining the evaluation standard of the flow field adjustment feasibility.
Preferably, the recovery factor enhancement potential and the single well control of the remaining geological reserve are used as indicators of the remaining oil condition. On the one hand, it can be judged whether there is a material basis for development and adjustment by the difference between the current recovery factor and the theoretical recovery factor (recovery factor improvement potential). On the other hand, the single control residual geological reserve is a function of the residual oil saturation, and the residual potential of the oil reservoir can be comprehensively and objectively reflected.
Preferably, the cumulative fluid production intensity variation coefficient and the cumulative oil production intensity variation coefficient are used as the characterization indexes of the reservoir equilibrium displacement condition. The simulated seepage resistance level difference obtained by digital-analog research is generally used for representing the reservoir displacement equilibrium displacement condition. The level difference reflects the saturation difference due to the difference in the cumulative production strength. Therefore, the introduction of a readily available index of the cumulative mining intensity difference at the mine site: and accumulating the variation coefficient of the oil production strength and the variation coefficient of the oil production strength as the judgment indexes of the oil reservoir balanced displacement condition.
Preferably, the similarity between the pressure gradient field and the seepage resistance field (for short, the similarity between the two fields) is used as a characterization index of the matching situation between the current injection-production situation and the balanced displacement.
Further preferably, a Tanimoto coefficient method is adopted to convert the field distribution parameters into two n-dimensional vectors, the similarity of the two vectors is solved, and the similarity of the two fields is represented.
Preferably, the indicators of the evaluation criteria include: the recovery efficiency is improved, the residual geological reserves are controlled by a single well, the variation coefficient of the strength of the produced fluid is accumulated, and the similarity of the two fields is improved.
The recovery efficiency enhancement potential is the difference between the actual recovery efficiency and the theoretical recovery efficiency (indoor experimental oil displacement efficiency). And the single-well control residual geological reserve is the quotient of the residual geological reserve of the development unit and the total well number of the oil well.
Further preferably, when the recovery factor enhancement potential is > 15%, the single well control residual geological reserves is >7 ten thousand tons/port, demonstrating the feasibility of having flow field adjustments from the perspective of the residual oil material base.
Further preferably, when the variation coefficient of the cumulative oil recovery strength is greater than 0.6, and the variation coefficient of the cumulative oil recovery strength is greater than 0.6, the feasibility of flow field adjustment is shown from the perspective of reservoir equilibrium displacement conditions.
Further preferably, the similarity between the two fields is less than 0.6, which indicates that the feasibility of flow field adjustment is provided from the perspective of the current situation of injection and production and the balanced displacement matching.
Preferably, the evaluation criterion of the flow field adjustment feasibility is that the following index requirements are simultaneously met:
the recovery efficiency enhancement potential is more than 15%, and the single well control residual geological reserve is more than 7 ten thousand tons/mouth;
the variation coefficient of the accumulated oil production strength is greater than 0.6, and the variation coefficient of the accumulated oil production strength is greater than 0.6;
the two fields have a similarity of < 0.6.
The invention achieves the following beneficial effects:
the quantitative evaluation method for the flow field adjustment feasibility based on the oil reservoir balanced displacement comprehensively considers the contradiction between the oil reservoir material foundation and the development, evaluates the feasibility and the necessity of the flow field adjustment from three dimensions of the residual oil material foundation, the oil reservoir balanced displacement condition, the injection and extraction current situation and the balanced displacement matching, evaluates the feasibility and the necessity comprehensively and objectively, and provides reliable technical support for the evaluation of the oil reservoir flow field adjustment resource potential in the later period of extremely high water content.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, are included to provide a further understanding of the invention, and are incorporated in and constitute a part of this specification, illustrate exemplary embodiments of the invention and together with the description serve to explain the invention and not to limit the invention.
FIG. 1 is a graph of cumulative fluid production intensity variation coefficient versus increased recoverable reserves per well in accordance with an embodiment of the present invention;
FIG. 2 is a graph of cumulative recovery intensity variation coefficient versus increased recoverable reserves per well in accordance with an embodiment of the present invention;
fig. 3 is a diagram of the similarity of the displacement pressure gradient field and the simulated seepage resistance field and the improvement of the extraction degree in an embodiment of the invention.
Detailed Description
It is to be understood that the following detailed description is exemplary and is intended to provide further explanation of the invention as claimed. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the invention. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of the stated features, steps, operations, and/or combinations thereof, unless the context clearly indicates otherwise.
In order to make the technical solutions of the present invention more clearly understood by those skilled in the art, the technical solutions of the present invention will be described in detail below with reference to specific embodiments.
Embodiment quantitative evaluation method for flow field adjustment feasibility based on reservoir equilibrium displacement
The method comprises the following steps:
(1) and detecting the residual oil condition before and after the flow field is adjusted, the balanced displacement condition of the oil reservoir, the injection and production current situation and the balanced displacement matching condition.
And taking the recovery ratio and the single-well control residual geological reserve as the characterization indexes of the residual oil condition.
And taking the variation coefficient of the cumulative produced fluid strength and the variation coefficient of the cumulative produced oil strength as the characterization indexes of the balanced displacement condition of the oil reservoir.
And taking the similarity of the two fields as a characterization index of the matching condition of the injection and production current situation and the balanced displacement situation. And converting the field distribution parameters into two n-dimensional vectors by adopting a Tanimoto coefficient method, solving the similarity of the two vectors, and representing the similarity of the two fields.
(2) The flow field was adjusted for feasibility evaluation criteria as shown in table 1 below.
TABLE 1 evaluation criteria for flow field adjustment feasibility
Determining evaluation basis of each characterization index: firstly, the evaluation basis of the basic characterization indexes of the substances is determined. The statistical analysis of the data of 16 development units with flow field adjustment in the mine site shows that the distribution interval of the recovery ratio before adjustment is 45.0% -57.6%, and the average value is 49.9%; the theoretical recovery ratio distribution interval obtained by indoor experiments is 65.7% -72.1%, and the average value is 67.3%. Compared with theoretical measurement and calculation, the actual recovery ratio has the recovery ratio enhancement potential distribution interval of 13.5-20.6 percent and the average value of 17.4 percent. Comprehensively considering the minimum improvement potential and the average improvement potential, and taking the recovery efficiency improvement potential more than or equal to 15% as the evaluation basis of the index; before the development unit is adjusted, the single well controls the distribution interval of the residual geological reserves to be 5.0-17.7 ten thousand tons/mouth, and the average value is 9.0 ten thousand tons/mouth. And comprehensively considering the minimum single-well control residual geological reserve and the average single-well control residual geological reserve, and taking the single-well control residual geological reserve of more than or equal to 7 ten thousand tons per mouth as the evaluation basis of the index.
And secondly, determining the evaluation basis of the characterization index of the reservoir equilibrium displacement condition. The statistical analysis of 57 injection and production well groups (corresponding to 132 oil wells) in the mine field shows that the effect of implementing the variable flow line adjustment shows that the larger the variation coefficient of the cumulative liquid production strength and the variation coefficient of the cumulative oil production strength between the oil wells in the injection and production well groups is, the better the effect of increasing the recoverable reserves is after implementing the variable flow line adjustment. When the variation coefficient of the accumulated liquid production strength is less than 0.6, the increasing recoverable reserves of a single well is generally lower than 0.5 ten thousand tons, and when the variation coefficient of the accumulated liquid production strength is greater than 0.6, the increasing recoverable reserves of the single well is distributed between 0.5 and 1.1 ten thousand tons (see figure 1); when the variation coefficient of the cumulative oil production intensity is less than 0.6, the increase recoverable capacity of a single well is generally lower than 0.5 ten thousand tons, and when the variation coefficient of the cumulative oil production intensity is greater than 0.6, the increase recoverable capacity of the single well is distributed between 0.5 and 1.2 ten thousand tons (see figure 2). Therefore, the variation coefficient of the accumulative oil extraction strength is greater than 0.6 and the variation coefficient of the accumulative oil extraction strength is greater than 0.6, which are used as evaluation basis of the balanced displacement condition of the oil reservoir.
And finally, determining the evaluation basis of the current injection-production situation and the characterization index of the balanced displacement matching. Taking an AA development unit as an example, according to a similarity criterion, establishing a similar model reflecting the characteristics of permeability, effective thickness, crude oil viscosity and the like of a typical block with medium and high permeability, and respectively setting 6-injection 3-extraction and 6-injection 6-extraction well patterns with the liquid extraction speed of 10 percent for 2 small layers in the longitudinal direction. Setting 6 groups of different injection-production condition schemes, and simulating to the same production degree of 40%; calculating the similarity of two fields at the moment of the mining degree of 40% under different injection-mining condition schemes by adopting a Tanimoto coefficient method; based on the above, flow field adjustment is performed under the conditions of simulating the similarity of two different fields, and the influence of 10 years of production on the development effect is shown in table 2.
TABLE 2 flow field adjusting effect under different two-field similarity conditions
A relation graph (see figure 3) of the similarity of the two fields and the extraction degree improvement amplitude is drawn, so that the two fields show an obvious negative matching relation, when the similarity of the two fields is greater than 0.6, the two fields are basically matched, and the extraction degree improvement amplitude is not obvious after 10 years; when the similarity of the two fields is less than 0.6, the two fields are not matched, and the extraction degree is improved remarkably after 10 years. Therefore, the similarity of the two fields is less than 0.6, and the evaluation basis of the matching between the current situation of the injection and production and the flow field is used.
(3) And according to the detection result, verifying the mine field adaptability of the evaluation standard by combining the flow field adjustment feasibility evaluation standard.
The oil field development unit BB is adopted, the longitudinal oil-containing small layer is developed, the interlayer heterogeneity is strong, and the average permeability of the reservoir is 2070 mD. By 2017, the calibrated recovery rate is 40.6 percent, which is 20.7 percent lower than the oil displacement efficiency measured by indoor experiments (namely the recovery rate improvement potential is 20.7 percent), the single control residual geological reserve is 12.5 ten thousand tons/mouth, the variation coefficient of the accumulated production fluid strength is 1.36, the variation coefficient of the accumulated production fluid strength is 1.79, and the similarity of two fields is 0.42. According to the evaluation criteria described in this embodiment, the development unit has the feasibility of flow field adjustment.
In 2018, flow field adjustment with a variable flow line as a core is implemented: improving a well pattern by old well stratum changing, transferring and the like; the row-column opposite direction injection-production well pattern is adjusted into a row-column staggered injection-production well pattern, and the injection-production flow line is adjusted by 45 degrees. After the adjustment is carried out, the comprehensive water content is reduced from 95.6 percent to 94.9 percent by 0.7 percent; the daily oil production level is increased from 87.7t/d to 114.8t/d, and is increased by 27.1 t/d; the water drive control degree is improved to 90.7 percent from 72.9 percent, the recovery rate is improved to 43.4 percent from 40.6 percent, and the water drive development effect is obviously improved by 2.8 percent.
Therefore, the flow field adjustment feasibility quantitative evaluation method based on the oil reservoir balanced displacement has feasibility and can be popularized and applied.
The above embodiments are preferred embodiments of the present invention, but the present invention is not limited to the above embodiments, and any other changes, modifications, substitutions, combinations, and simplifications which do not depart from the spirit and principle of the present invention should be construed as equivalents thereof, and all such changes, modifications, substitutions, combinations, and simplifications are intended to be included in the scope of the present invention.
Claims (10)
1. The flow field adjustment feasibility quantitative evaluation method based on reservoir equilibrium displacement is characterized by comprising the following steps of:
detecting the residual oil condition, the oil reservoir balanced displacement condition, the injection and production current situation and the balanced displacement matching condition of a mine field development unit;
and judging the feasibility of the flow field adjustment implemented by the development unit according to the detection result and by combining the evaluation standard of the flow field adjustment feasibility.
2. The method of claim 1, wherein the enhanced recovery potential and single well control of the remaining geological reserve are used as indicators of remaining oil conditions.
3. The method of claim 1, wherein the cumulative fluid production intensity variation coefficient and the cumulative oil production intensity variation coefficient are used as the characterization indexes of the reservoir equilibrium displacement condition.
4. The method according to claim 1, characterized in that the similarity between the pressure gradient field and the seepage resistance field is used as a characterization index of the matching situation between the current situation of injection and production and the balanced displacement.
5. The method of claim 4, wherein a Tanimoto coefficient method is adopted to convert the field distribution parameters into two n-dimensional vectors, and the similarity of the two vectors is solved to represent the similarity of the pressure gradient field and the seepage resistance field.
6. The method of claim 1, wherein the indicators of the evaluation criteria comprise: the recovery efficiency is improved, the residual geological reserves are controlled by a single well, the variation coefficient of the strength of the produced fluid is accumulated, and the similarity between a displacement pressure gradient field and a seepage resistance field is also increased;
the recovery factor enhancing potential is the difference between the actual recovery factor and the theoretical recovery factor;
and the single-well control residual geological reserve is the quotient of the residual geological reserve of the development unit and the total number of the oil wells.
7. The method of claim 6, wherein the single well control residual geological reserves is >7 million tons/port when the recovery factor enhancement potential is > 15%, indicating the feasibility of having flow field adjustments from the perspective of the residual oil material foundation.
8. The method of claim 6, wherein the cumulative recovery strength variation coefficient is >0.6, and the cumulative recovery strength variation coefficient is >0.6, indicating the feasibility of flow field adjustment from the perspective of reservoir equilibrium displacement conditions.
9. The method of claim 6, wherein the similarity between the displacement pressure gradient field and the seepage resistance field is less than 0.6, which indicates that the feasibility of flow field adjustment is provided from the perspective of the current situation of injection and production and the balanced displacement matching.
10. The method according to claim 1 or 6, wherein the evaluation criterion of the flow field adjustment feasibility is that the following index requirements are simultaneously met:
the recovery efficiency enhancement potential is more than 15%, and the single well control residual geological reserve is more than 7 ten thousand tons/mouth;
the variation coefficient of the accumulated oil production strength is greater than 0.6, and the variation coefficient of the accumulated oil production strength is greater than 0.6;
the similarity between the displacement pressure gradient field and the seepage resistance field is less than 0.6.
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