CN114076991B - Characterization method of macroscopic heterogeneity of reservoir - Google Patents
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Abstract
The invention relates to a characterization method of reservoir macroscopic heterogeneity, which belongs to the technical field of geological exploration and development of oil and gas reservoirs, and not only considers three key parameters of reservoir thickness in the range of stratum thickness of each well in the longitudinal direction, reservoir thickness in the range of reservoir span and interlayer number between reservoirs, which influence reservoir heterogeneity difference, but also establishes normalized characterization parameters of single well phase change indexes and interlayer number at different positions on a plane, and simultaneously forms characterization parameters expressing that three phase change indexes comprehensively influence reservoir heterogeneity. By fully utilizing geological information of logging, related information such as reservoir sections and interlayer sections is obtained, macroscopic heterogeneity characteristics of the reservoir are depicted, the problem that the conventional method cannot accurately represent the macroscopic heterogeneity of the sandstone reservoir through single characterization parameters is effectively solved, comprehensive evaluation of the macroscopic heterogeneity of the sandstone reservoir is realized, reliability is high, and practical guiding significance is provided for oil and gas reservoir distribution and exploration, development and dynamic evaluation and research.
Description
Technical Field
The invention belongs to the technical field of geology of oil and gas reservoir exploration and development, and particularly relates to a characterization method of reservoir macroscopic heterogeneity.
Background
Reservoir heterogeneity refers to the fact that reservoirs are affected by the deposition environment, diagenetic and structural effects during formation, with non-uniform changes in spatial distribution and internal properties, which are the primary factors affecting subsurface oil, gas, water movement and oil and gas recovery. Currently, the general classification method of reservoir heterogeneity is to divide reservoir heterogeneity of clastic rock into four categories of interbedded, intrastratal, planar and pore heterogeneity; reservoir heterogeneity is classified into macroscopic and microscopic heterogeneities according to the reservoir description scale, while macroscopic reservoir heterogeneity is described, characterized mainly by heterogeneous parameters, reservoir parameters, their distribution, etc., but these characterization methods describe reservoir heterogeneity from only one side.
For example, chinese patent publication No. CN10561676B proposes a method for characterizing reservoir heterogeneity by establishing a study zone construction model and a three-dimensional model of reservoir permeability, and determining permeability heterogeneity parameters for a desired interval to characterize reservoir heterogeneity. The disadvantage of such methods is that, due to the complex factors affecting reservoir heterogeneity, the reservoir heterogeneity is represented by a single parameter, which may make the characterization of macroscopic heterogeneity inaccurate, and may easily lead to inaccurate subsequent reservoir distribution prediction and exploration, development and evaluation, thereby causing serious economic loss. Therefore, the method accurately and comprehensively characterizes the macroscopic heterogeneity of the reservoir, and has great significance for the dynamic evaluation and research of the distribution of the oil and gas reservoirs and the exploration and development.
Disclosure of Invention
The invention aims to provide a characterization method of reservoir macro-heterogeneity, which is used for solving the problem that the conventional method cannot accurately characterize the reservoir macro-heterogeneity.
Based on the above purpose, the technical scheme of the method for characterizing the macroscopic heterogeneity of the reservoir is as follows:
(1) According to the logging curves of the single well objective layers of the research area, the stratum thickness of the single well objective layers, the thickness of the reservoir sections, the number of the interlayer sections, the maximum number of the interlayer sections in all wells in the whole area, and the top boundary depth of the uppermost reservoir section and the bottom boundary depth of the lowermost reservoir section of each single well are obtained;
(2) According to the ratio of the reservoir thickness and the stratum thickness of each single well target layer, calculating to obtain the reservoir-to-ground ratio of each single well; the thickness of the reservoir layer of each single-well target layer is the sum of the thicknesses of all reservoir sections of each single-well target layer;
according to the difference between the bottom boundary depth of the lowest reservoir section and the top boundary depth of the uppermost reservoir section, calculating to obtain the reservoir span of each single-well target layer;
(3) Calculating to obtain a first phase change index of each single well according to the ratio of the reservoir thickness and the reservoir span of each single well target layer; and calculating according to the first phase change indexes of the single wells to obtain second phase change indexes, wherein the calculation formula is as follows:
D＝0.5+(C-Cmin)/(2*(Cmax-Cmin))
wherein D is a second phase change index, C is a first phase change index, cmax is the maximum value of the first phase change index C of the whole region, cmin is the minimum value of the first phase change index C of the whole region;
and calculating a third phase change index according to the number of the interval sections of each single well and the maximum value of the number of the interval sections in all wells in the whole area, wherein the calculation formula is as follows:
E＝1-N/(2*Nmax)
wherein E is a third phase change index, N is the number of interval layers, and Nmax is the maximum value of the number of interval layers in all wells in the whole area;
(4) According to the storage-to-earth ratio of each single well, combining the second phase change index and the third phase change index of each single well, calculating the macroscopic heterogeneity index of each single well reservoir, wherein the calculation formula is as follows:
F＝A*(D+E)/2
wherein F is a macroscopic heterogeneity index, and the value range is (0, 1); a is the storage-to-ground ratio, D is the second phase change index, and E is the third phase change index.
The beneficial effects of the technical scheme are as follows:
the characterization method of the invention considers three key parameters of the reservoir thickness ratio (A) in the stratum thickness range of each well in the longitudinal direction, the reservoir thickness ratio (C) in the reservoir span range and the interval layer number (N) of the reservoir, and establishes the single-well phase change index C and the normalized characterization parameters (D, E) of the interval layer number N in different positions on a plane, and simultaneously forms the characterization parameters (F) for expressing the three phase change indexes A, D, E and comprehensively influencing the reservoir heterogeneity. By fully utilizing geological information of logging, related information such as reservoir sections and interlayer sections is obtained, macroscopic heterogeneity characteristics of the reservoir are depicted, the problem that the conventional method cannot accurately represent the macroscopic heterogeneity of the sandstone reservoir through single characterization parameters is effectively solved, comprehensive evaluation of the macroscopic heterogeneity of the sandstone reservoir is realized, reliability is high, and practical guiding significance is provided for oil and gas reservoir distribution and exploration, development and dynamic evaluation and research.
Further, to obtain macroscopic inhomogeneities of the whole body of the investigation region, the method further comprises the steps of:
according to the macro-heterogeneity index of each single well reservoir in the research area, a histogram of the reservoir macro-heterogeneity index in the research area is established by taking the macro-heterogeneity index as a horizontal axis and the number of single wells as a vertical axis, a normal distribution curve of the macro-heterogeneity index of the reservoir in the research area is determined according to the histogram, and the overall heterogeneity of the reservoir in the research area is predicted according to the peak value of the normal distribution curve.
In order to obtain parameters such as stratum thickness, reservoir section thickness and the like, the logging curve comprises a natural gamma curve, a natural potential curve and an acoustic time difference curve.
To determine the storage-to-earth ratio of each individual well, the storage-to-earth ratio of each individual well is calculated as follows:
A＝th r /th s
wherein A is the storage-to-ground ratio, th r To the reservoir thickness th s Is the formation thickness.
In order to determine the reservoir span of each single well destination, the reservoir span of each single well destination is calculated as follows:
B＝h l -h t
wherein B is the reservoir span of the target layer, h l Depth of bottom boundary of reservoir at the lowest part of the layer，h t Is the uppermost reservoir top boundary depth.
To determine the first phase change index, the first phase change index is calculated as follows:
C＝th r /B
wherein C is a first phase transition index, th r For reservoir thickness, B is the reservoir span of the layer of interest.
Drawings
FIG. 1 is a flow chart of a method for characterizing reservoir macro-heterogeneity in an embodiment of the invention;
FIG. 2 is a diagram of a Shan Jingtu embodiment of the present invention identifying reservoir segments from barrier segments;
FIG. 3 is a graph of a macroscopic heterogeneity index histogram and a normal distribution of a reservoir in a research area in accordance with an embodiment of the present invention.
Detailed Description
The following describes the embodiments of the present invention further with reference to the drawings.
The embodiment provides a characterization method of macroscopic heterogeneity of a reservoir, the arrangement flow is shown in fig. 1, and the following describes a specific implementation process of the characterization method by taking a sandstone reservoir of 1 section of a lower stone box group box in a certain area as an example:
specific conditions of the reservoir include: the range of the research area is 200km 2 59 holes are formed in the drilling hole of the section 1 of the under-target-layer stone box group box in the research area; the target layer deposition phase of the research area is a braided river. The specific implementation steps of the characterization method of the invention are as follows:
s101) identifying reservoir sections and interlayer sections, and counting stratum thickness of each single well, thickness of the reservoir sections, thickness of the interlayer sections, number of interlayer sections (N) and maximum value (Nmax) of interlayer numbers of all wells in the whole area.
Specifically, the reservoir section and the interval section are identified according to the logging curve of the target layer of the single well box 1 section in the research area 59, namely, the upper limit value of the GR curve (natural gamma curve) and the lower limit value of the AC curve (sonic time difference curve), as shown in fig. 2.
The natural gamma, natural potential and acoustic time difference curve in the logging curve are utilized, the physical characteristics of the region are combined, the GR value is not more than 70API, the AC value is not less than 220 mu s/m as a reservoir section, and the calculated thickness of the reservoir section is 0.5m; GR value is larger than 70API, AC value is smaller than 220 mu s/m, and thickness of the interlayer is 1m according to geological knowledge of the research area. The formation thickness, the thickness of the reservoir section, the thickness and the number (N) of the interlayer sections, the maximum value (Nmax) of the number of the interlayer in all wells in the whole area and the top and bottom boundary depth data of the reservoir section in the target layer of the single well box 1 section of the research area 59 are counted. As shown in FIG. 2, the formation thickness of a single well is 62.7m, 5 co-developed reservoir segments are a1, a2, a3, a4, a5, a6 and a7 respectively, the reservoir thickness (i.e. the sum of all reservoir segment thicknesses) is 36.2 m, the number of the interlayer segments is 4, the interlayer thickness is 15.3m, g1, g2, g3 and g4 respectively, the top boundary depth of the uppermost reservoir segment is 2661.8m, and the bottom boundary depth of the lowermost reservoir segment is 2716.0m. And counting 59 wells in the whole area to obtain 5 maximum interlayer numbers.
S102) calculating the storage-to-earth ratio of each single well and the storage span of a target layer, wherein the calculation formula is as follows:
A＝th r /th s (1)
B＝h l -h t (2)
wherein A is the storage-to-ground ratio, th r To the reservoir thickness th s For formation thickness, B is the reservoir span of the interval of interest, h l Is the depth of the bottom boundary of the reservoir at the lowest part in the layer, h t Is the uppermost reservoir top boundary depth.
In the step, taking the deposition difference of each well in the longitudinal direction into consideration, and representing the ratio of the thickness of a reservoir layer in the stratum thickness range of each well by establishing a formula of a reservoir-to-ground ratio A; the reservoir span also has certain difference due to the difference of interlayer distribution in the development range of the reservoir, and a calculation formula of the reservoir span B is established.
According to the above formula, the storage-to-earth ratio A and the storage span B of the whole zone 59 single-well box 1 section destination layer are calculated, and the storage-to-earth ratio of the well is 0.58 and the storage span is 54.2m by taking the well shown in FIG. 2 as an example.
S103) determining the phase change index C, D, E of each single well according to the reservoir thickness, the reservoir span, the number of interlayer segments and the maximum number of interlayers, which are obtained in the steps, wherein the calculation formula is as follows:
C＝th r /B (3)
D＝0.5+(C-Cmin)/(2*(Cmax-Cmin)) (4)
E＝1-N/(2*Nmax) (5)
in th r For reservoir thickness, cmax is the maximum value of the phase change index C of the whole zone, cmin is the minimum value of the phase change index C of the whole zone, N is the number of interval layers, and Nmax is the maximum value of the number of all well intervals of the whole zone.
In the step, in order to further characterize the ratio of the reservoir thickness within the span range of the reservoir, a calculation formula of a phase change index C is established; the interval layer number (N) of the reservoir is also a key parameter for influencing the reservoir heterogeneity difference, the problem of large macroscopic heterogeneity difference of the reservoir of the river sand bodies at different positions of the river on the plane is comprehensively considered, and a calculation formula of the normalized characterization parameters phase change indexes D and E of the phase change index C and the interval layer number N is established.
Taking the well shown in fig. 2 as an example, the phase change index C of the well is 0.67, the maximum value of the phase change index C of the whole 59 single wells is 1.00, and the minimum value is 0.17, so the phase change index D of the well is 0.80; the phase change index E of the well was calculated to be 0.7.
S104) establishing a characterization formula according to the single well storage-to-land ratio and the phase change index D, E obtained in the steps, and calculating a macroscopic heterogeneity index F of each single well storage layer, wherein the characterization formula of the index is as follows:
F＝A*(D+E)/2 (6)
wherein F is a macroscopic heterogeneity index, the range of index values is (0, 1), a larger value of F represents a weaker macroscopic heterogeneity of the reservoir, and a smaller value of F represents a stronger macroscopic heterogeneity of the reservoir; a is the storage-to-earth ratio of a single well, and D, E is the phase change index of the single well.
In the step, by comprehensively considering the deposition difference in the single-well target interval and the reservoir interval, the characterization parameter (F) expressing three phase change indexes A, D, E and comprehensively influencing the reservoir heterogeneity is formed, and the accuracy and the comprehensiveness of the single-well reservoir heterogeneity are improved.
Taking the single well as shown in fig. 2 as an example, the macroscopic heterogeneity index F of the well reservoir has a value of 0.43; and calculating the macroscopic heterogeneity index of each single well reservoir in the whole region, wherein the maximum value of the macroscopic heterogeneity index of each single well reservoir in the whole region is 0.66, the minimum value of the macroscopic heterogeneity index of each single well reservoir in the whole region is 0.03, and the average value of the macroscopic heterogeneity index of each single well reservoir in the whole region is 0.25.
S105) establishing a normal distribution curve graph of the reservoir macro-heterogeneity index of the whole area (namely a research area) according to the calculated macro-heterogeneity index of each single well reservoir in the whole area, wherein in the figure 3, a histogram of the reservoir macro-heterogeneity index in the research area is established according to the macro-heterogeneity index of each single well reservoir in the research area by taking the macro-heterogeneity index as a horizontal axis and the number of single wells as a vertical axis, and a normal distribution curve of the reservoir macro-heterogeneity index in the research area is determined according to the histogram, and the overall heterogeneity of the reservoir in the research area is predicted according to the peak value of the normal distribution curve, and the overall stronger reservoir macro-heterogeneity in the research area can be obtained due to the fact that the main peak value of the normal distribution curve of the reservoir macro-heterogeneity index in the research area is 0.25.
In this embodiment, if the overall evaluation of the macro-heterogeneity of the reservoir in the investigation region is not considered, step S105 is not required, and only the macro-heterogeneity index of each single-well reservoir may be obtained.
In this embodiment, the steps S101 to S105 are only one execution order for implementing the characterization method of the present invention, that is, the step sequence in the steps S101 to S105 is not unique, for example, the step S101 is used to obtain each parameter used in the subsequent step, and as other embodiments, it is not necessary to obtain all the required parameters at one time, but when there is an obtaining requirement in the subsequent step, the required parameters are obtained in the step immediately; as another example, the reservoir ratio and the reservoir span in step S102 may be performed in two steps, respectively, so step S102 may also be split; etc. Therefore, in this embodiment, there is no execution sequence of the partial steps.
However, there is indeed a sequence of some of the steps in this embodiment, for example, for the same single well, the step of calculating the reservoir span must be performed before calculating the phase change index C; for another example, before calculating the phase change index D, the phase change index C must be calculated; etc. Based on the above considerations, the present embodiment does not strictly limit the sequence of steps of the method of the present invention.
The characterization method of the invention considers three key parameters of the reservoir thickness ratio (A) in the stratum thickness range of each well in the longitudinal direction, the reservoir thickness ratio (C) in the reservoir span range and the interval layer number (N) of the reservoir, and establishes the single-well phase change index C and the normalized characterization parameters (D, E) of the interval layer number N in different positions on a plane, and simultaneously forms the characterization parameters (F) for expressing the three phase change indexes A, D, E and comprehensively influencing the reservoir heterogeneity. By fully utilizing the geological information of the logging, the reservoir and the interlayer are identified, the macroscopic heterogeneity characteristics of the reservoir are depicted, the problem that the macroscopic heterogeneity of the sandstone reservoir cannot be accurately represented by a single characterization parameter in the conventional method is effectively solved, the comprehensive evaluation of the macroscopic heterogeneity of the sandstone reservoir is realized, the reliability is higher, and the method has practical guiding significance for the distribution of the oil and gas reservoirs and the dynamic evaluation and research of exploration and development.
Finally, it should be noted that: the above embodiments are only for illustrating the technical aspects of the present invention and not for limiting the same, and although the present invention has been described in detail with reference to the above embodiments, it should be understood by those of ordinary skill in the art that: modifications and equivalents may be made to the specific embodiments of the invention without departing from the spirit and scope of the invention, which is intended to be covered by the claims.
Claims (6)
1. A method for characterizing macroscopic heterogeneity of a reservoir, comprising the steps of:
(1) According to the logging curves of the single well objective layers of the research area, the stratum thickness of the single well objective layers, the thickness of the reservoir sections, the number of the interlayer sections, the maximum number of the interlayer sections in all wells in the whole area, and the top boundary depth of the uppermost reservoir section and the bottom boundary depth of the lowermost reservoir section of each single well are obtained;
(2) According to the ratio of the reservoir thickness and the stratum thickness of each single well target layer, calculating to obtain the reservoir-to-ground ratio of each single well; the thickness of the reservoir layer of each single-well target layer is the sum of the thicknesses of all reservoir sections of each single-well target layer;
according to the difference between the bottom boundary depth of the lowest reservoir section and the top boundary depth of the uppermost reservoir section, calculating to obtain the reservoir span of each single-well target layer;
(3) Calculating to obtain a first phase change index of each single well according to the ratio of the reservoir thickness and the reservoir span of each single well target layer; and calculating according to the first phase change indexes of the single wells to obtain second phase change indexes, wherein the calculation formula is as follows:
D＝0.5+(C-Cmin)/(2*(Cmax-Cmin))
wherein D is a second phase change index, C is a first phase change index, cmax is the maximum value of the first phase change index C of the whole region, cmin is the minimum value of the first phase change index C of the whole region;
and calculating a third phase change index according to the number of the interval sections of each single well and the maximum value of the number of the interval sections in all wells in the whole area, wherein the calculation formula is as follows:
E＝1-N/(2*Nmax)
wherein E is a third phase change index, N is the number of interval layers, and Nmax is the maximum value of the number of interval layers in all wells in the whole area;
(4) According to the storage-to-earth ratio of each single well, combining the second phase change index and the third phase change index of each single well, calculating the macroscopic heterogeneity index of each single well reservoir, wherein the calculation formula is as follows:
F＝A*(D+E)/2
wherein F is a macroscopic heterogeneity index, and the value range is (0, 1); a is the storage-to-ground ratio, D is the second phase change index, and E is the third phase change index.
2. The method of characterizing reservoir macro-heterogeneity according to claim 1, further comprising the steps of:
according to the macro-heterogeneity index of each single well reservoir, taking the macro-heterogeneity index as a horizontal axis and the number of single wells as a vertical axis, establishing a histogram of the reservoir macro-heterogeneity index in a research area, determining a normal distribution curve of the macro-heterogeneity index of the reservoir in the research area according to the histogram, and predicting the overall heterogeneity of the reservoir in the research area according to the peak value of the normal distribution curve.
3. The method of claim 1, wherein the well log curves comprise natural gamma curves, natural potential curves, and sonic moveout curves.
4. The method of claim 1, wherein the reservoir ratio calculation for each individual well is as follows:
A＝th r /th s
wherein A is the storage-to-ground ratio, th r To the reservoir thickness th s Is the formation thickness.
5. The method of claim 1, wherein the reservoir span of each single well target layer is calculated as:
B＝h l -h t
wherein B is the reservoir span of the target layer, h l Is the depth of the bottom boundary of the reservoir at the lowest part in the layer, h t Is the uppermost reservoir top boundary depth.
6. The method of claim 5, wherein the first phase change index is calculated as follows:
C＝th r /B
wherein C is a first phase transition index, th r For reservoir thickness, B is the reservoir span of the layer of interest.
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