CN114607367B - Method and device for correcting core parameters of oil layer burned by fire - Google Patents
Method and device for correcting core parameters of oil layer burned by fire Download PDFInfo
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- CN114607367B CN114607367B CN202011393708.XA CN202011393708A CN114607367B CN 114607367 B CN114607367 B CN 114607367B CN 202011393708 A CN202011393708 A CN 202011393708A CN 114607367 B CN114607367 B CN 114607367B
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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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
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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
- E21B47/00—Survey of boreholes or wells
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Abstract
本发明提供了一种火烧油层岩心参数校正方法及装置，该方法包括：对比岩心样品的岩心自然伽马曲线和测井自然伽马曲线，确定岩心样品的埋藏深度；分析获得岩心样品的储层微观特征和储层宏观特征；判断岩心样品所处的燃烧区带；基于异常值剔除后的参数数据，绘制岩心样品在覆压下的孔隙度校正图版和渗透率校正图版，获得校正的孔隙度数据和校正的渗透率数据；基于校正的孔隙度数据和含油饱和度数据，绘制第一含油饱和度校正图版，获得第一校正的含油饱和度数据；基于核磁共振含油饱和度数据和第一校正的含油饱和度数据，绘制第二含油饱和度校正图版，获得第二校正的含油饱和度数据。本发明可以对火烧油层的岩心参数进行校正，准确度高。
The present invention provides a method and device for correcting core parameters of a fire-burned oil layer, the method comprising: comparing the core natural gamma curve and the well logging natural gamma curve of the core sample to determine the burial depth of the core sample; analyzing and obtaining the reservoir microscopic characteristics and reservoir macroscopic characteristics of the core sample; judging the combustion zone where the core sample is located; drawing the porosity correction plate and the permeability correction plate of the core sample under overburden pressure based on the parameter data after the outliers are eliminated, and obtaining the corrected porosity data and the corrected permeability data; drawing the first oil saturation correction plate based on the corrected porosity data and oil saturation data, and obtaining the first corrected oil saturation data; drawing the second oil saturation correction plate based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data, and obtaining the second corrected oil saturation data. The present invention can correct the core parameters of the fire-burned oil layer with high accuracy.
Description
Technical Field
The invention relates to the technical field of core testing, in particular to a method and a device for correcting in-situ combustion core parameters.
Background
In-situ combustion is an advanced development technique for injecting air into an underground oil reservoir through an injection well, manually igniting the oil reservoir to generate heat, and displacing crude oil to a production well. Several zones of burnt zone, combustion zone, coking zone, steam zone, oil-rich zone, tail gas zone and residual oil zone are formed between injection well and production well. The in-situ combustion has the advantages of high recovery ratio, low cost, low energy consumption and wide application range. The reservoir change and the residual oil saturation difference of a plurality of zones are large, the conventional core parameter correction is an effective method for quantifying the reservoir change and the residual oil distribution, but the test result under the ground condition is influenced by factors such as core properties, freezing, compaction and the like, and the accuracy of the conventional core parameter correction method is not high.
Thus, there is currently a lack of an effective correction method for core parameters of in-situ combustion.
Disclosure of Invention
The embodiment of the invention provides a method for correcting in-situ combustion core parameters, which is used for correcting the in-situ combustion core parameters and has high accuracy, and the method comprises the following steps:
Comparing the natural gamma curve of the core with the natural gamma curve of the logging to determine the burial depth of the core sample;
Analyzing and obtaining reservoir microscopic features of the core sample;
analyzing and obtaining reservoir macro-features of the core sample;
judging a combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir;
removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data;
Drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
and drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data.
The embodiment of the invention provides a core parameter correction device for in-situ combustion, which is used for correcting the core parameter of the in-situ combustion, and has high accuracy, and the device comprises:
The buried depth determining module is used for comparing the core natural gamma curve of the core sample with the logging natural gamma curve to determine the buried depth of the core sample;
the reservoir microscopic feature analysis module is used for analyzing and obtaining reservoir microscopic features of the core sample;
the reservoir macro-feature analysis module is used for analyzing and obtaining reservoir macro-features of the core sample;
The combustion zone judging module is used for judging the combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir;
the abnormal value removing module is used for removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
The first correction module is used for drawing a porosity correction plate and a permeability correction plate of the core sample under the covering pressure based on the parameter data after the outlier is removed, so as to obtain corrected porosity data and corrected permeability data;
the second correction module is used for drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
And the third correction module is used for drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data.
The embodiment of the invention also provides computer equipment, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the method for correcting the in-situ combustion core parameters is realized when the processor executes the computer program.
The embodiment of the invention also provides a computer readable storage medium, wherein the computer readable storage medium stores a computer program for executing the in-situ combustion core parameter correction method.
In the embodiment of the invention, a core natural gamma curve of a core sample is compared with a logging natural gamma curve, and the burial depth of the core sample is determined; analyzing and obtaining reservoir microscopic features of the core sample; analyzing and obtaining reservoir macro-features of the core sample; judging a combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir; removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data; drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data; drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data; and drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data. In the process, according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, abnormal values of parameter data of the core sample are removed, so that accuracy of the parameter data of the core sample acquired in the earlier stage is high, and then the parameter data are corrected in a mode of drawing a porosity correction chart and a permeability correction chart under the overpressure; by drawing the first oil saturation correction plate and the second oil saturation correction plate, the oil saturation data is corrected, and the overall correction accuracy is high.
Drawings
In order to more clearly illustrate the embodiments of the invention or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art. In the drawings:
FIG. 1 is a flow chart of a method for correcting in-situ core parameters in an embodiment of the invention;
FIG. 2 is a detailed flow chart of a method for correcting in-situ core parameters in an embodiment of the invention;
FIG. 3 is a graph showing a comparison of a core natural gamma curve of a core sample and a log natural gamma curve in an embodiment of the present invention;
FIG. 4 is a schematic diagram of original pore structure change data of a core sample according to an embodiment of the present invention;
FIGS. 5 and 6 are schematic diagrams of a porosity correction plate and a permeability correction plate, respectively, of a core sample under overburden pressure in accordance with an embodiment of the present invention;
FIG. 7 is a schematic illustration of a first oil saturation correction plate, in accordance with an embodiment of the present invention;
FIG. 8 is a schematic illustration of a second oil saturation correction chart of an embodiment of the present invention;
FIG. 9 is a block remaining oil potential evaluation schematic diagram in an embodiment of the invention;
FIG. 10 is a schematic illustration of in-situ control in an embodiment of the present invention;
FIG. 11 is a schematic diagram of a core parameter calibration device for in-situ combustion in an embodiment of the present invention;
FIG. 12 is another schematic view of an in-situ core parameter correcting device according to an embodiment of the invention;
Fig. 13 is a schematic diagram of a computer device in an embodiment of the invention.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention will be described in further detail with reference to the accompanying drawings. The exemplary embodiments of the present invention and their descriptions herein are for the purpose of explaining the present invention, but are not to be construed as limiting the invention.
In the description of the present specification, the terms "comprising," "including," "having," "containing," and the like are open-ended terms, meaning including, but not limited to. The description of the reference terms "one embodiment," "a particular embodiment," "some embodiments," "for example," etc., means that a particular feature, structure, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the application. In this specification, schematic representations of the above terms do not necessarily refer to the same embodiments or examples. Furthermore, the particular features, structures, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples. The order of steps involved in the embodiments is illustrative of the practice of the application, and is not limited and may be suitably modified as desired.
Fig. 1 is a flowchart of a method for correcting in-situ core parameters according to an embodiment of the present invention, as shown in fig. 1, the method includes:
Step 101, comparing a core natural gamma curve of a core sample with a logging natural gamma curve to determine the burial depth of the core sample;
102, analyzing and obtaining reservoir microscopic features of a core sample;
step 103, analyzing and obtaining reservoir macro-features of the core sample;
104, judging a combustion zone where the core sample is located according to the burial depth, the reservoir macro-feature and the reservoir micro-feature of the core sample;
Step 105, eliminating abnormal values of parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
Step 106, drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data;
Step 107, drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
And step 108, drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data, and obtaining second corrected oil saturation data.
According to the embodiment of the invention, abnormal values of parameter data of a core sample are removed according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, so that the accuracy of the parameter data of the core sample acquired in the earlier stage is high, and then the porosity data and the permeability data are corrected by drawing a porosity correction chart and a permeability correction chart under the overpressure; by drawing the first oil saturation correction plate and the second oil saturation correction plate, the oil saturation data is corrected, and the overall correction accuracy is high. In particular embodiments, core parameters include, but are not limited to, permeability, porosity, and oil saturation, and other core parameter (e.g., water saturation) correction methods for correcting for permeability, porosity, and oil saturation are contemplated by embodiments of the present invention.
In an embodiment, the method further comprises:
And obtaining a core natural gamma curve of the core sample, wherein the core natural gamma curve is obtained by scanning the core sample.
In the above embodiment, since the core sample is taken out and then tested on the ground, the natural gamma curve of the core sample is obtained by scanning the core sample, and the natural gamma curve of the core sample is different from the natural gamma curve of the core sample in the coring well (the well from which the core sample is taken out), so that in step 101, the depth of burial of the core sample needs to be determined by comparing the natural gamma curve of the core sample with the natural gamma curve of the well, and thus the determined depth of burial is more accurate.
In one embodiment, analyzing reservoir microfeatures of an obtained core sample includes:
Obtaining scanning electron microscope data of a core sample, wherein the scanning electron microscope data is obtained by performing electron microscope scanning on the core sample processed into microscopic rock slices;
and analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data.
In the above embodiments, the reservoir microfeatures include raw pore structure change data formed for reservoir parameter changes and saturation changes.
In an embodiment, analyzing reservoir macrofeatures of an obtained core sample includes:
And comparing logging data of the coring well where the core sample is positioned with logging data of the production well developed at different stages, and analyzing reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data.
In the above embodiment, there must be many production wells around the coring well, and these production wells may be developed at different stages (i.e. at different times), and many logging data, and by comparing, the electrical change rule data of the core sample may be obtained. During analysis, oil deposit engineering research and on-site monitoring data can be combined.
In step 104, the combustion zone where the core sample is located is determined according to the depth of burial of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir, and when determining specifically, the combustion zone where the in-situ combustion zone is located is determined by the layering section according to the depth of burial of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir, where the in-situ combustion zone is located, on the basis of the results of indoor physical simulation study (e.g. physical simulation of the core), comprehensive dynamic oil reservoir engineering study (e.g. rule of adjacent wells) and on-site monitoring.
In step 105, abnormal values are removed from the parameter data of the core sample according to the reservoir microscopic features, the reservoir macroscopic features and the combustion zone of the core sample, wherein the parameter data refer to the assay analysis data of the core parameter, and after the abnormal values are removed, the parameter data of the core sample which can show the actual conditions of the development target layer can be screened.
In an embodiment, drawing a porosity correction plate and a permeability correction plate of the core sample under the over-pressure based on the parameter data after outlier rejection includes:
obtaining formation pressure under different burial depths in an in-situ combustion layer through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure;
Obtaining the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures;
And drawing a porosity correction chart and a permeability correction chart of the core sample under the overburden pressure according to the relation between the buried depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data.
In the above embodiment, formation pressure acts as an intermediary to determine the relationship of the depth of burial to the porosity and permeability data. In the drawn porosity correction plate, the abscissa is the buried depth, and the ordinate is the porosity correction rate; in the drawn permeability correction plate, the abscissa is the buried depth, and the ordinate is the permeability correction rate. Correction rate= (parameter value before correction-parameter value after correction)/parameter value before correction×100%.
In one embodiment, after drawing the porosity correction plate and the permeability correction plate of the core sample under the overpressure, further comprising:
Removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data;
Drawing a first oil saturation correction plate based on the corrected porosity data and oil saturation data to obtain first corrected oil saturation data, comprising:
and drawing a first oil saturation correction chart based on the recalibrated porosity data and the oil saturation data to obtain first corrected oil saturation data.
In the embodiment, the correction porosity data and the correction permeability data are more accurate by eliminating errors caused by the thick oil loose core under the overburden pressure. The error is formed by the expansion of the rock sample pores caused by the influence of the temperature and pressure reduction of the thick oil loose core on the ground.
In addition, when the first oil saturation correction chart is drawn, the porosity cumulative correction rate is taken as an abscissa, and the oil saturation is taken as an ordinate. After the first corrected oil saturation data is obtained, to further correct the oil saturation, a second oil saturation correction plate is drawn based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data. The second oil saturation correction plate takes the nuclear magnetic resonance oil saturation as an abscissa and takes the oil saturation correction rate as an ordinate. Nuclear magnetic resonance oil saturation is obtained by performing nuclear magnetic resonance on a core sample to obtain saturation measurement.
Through the steps 101-108, the corrected porosity data, the corrected permeability data and the second corrected oil saturation data are obtained, and compared with the data before correction, the accuracy of the data is greatly improved. The corrected parameter data can evaluate the potential of remaining oil of well groups and blocks, and guide the programming and regulation of in-situ combustion scheme.
Based on the above embodiments, the present invention proposes the following embodiment to illustrate the detailed flow of the in-situ core parameter correcting method, and fig. 2 is a detailed flow chart of the in-situ core parameter correcting method in the embodiment of the present invention, as shown in fig. 2, including:
Step 201, obtaining a core natural gamma curve of a core sample, wherein the core natural gamma curve is obtained by scanning the core sample;
Step 202, comparing a core natural gamma curve of a core sample with a logging natural gamma curve to determine the burial depth of the core sample;
step 203, obtaining scanning electron microscope data of a core sample, wherein the scanning electron microscope data is obtained by performing electron microscope scanning on the core sample processed into microscopic rock slices;
Step 204, analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data;
Step 205, comparing the logging data of the coring well where the core sample is located with the logging data of the production well developed at different stages, and analyzing the reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data;
step 206, judging a combustion zone where the core sample is located according to the burial depth, the reservoir macro-feature and the reservoir micro-feature of the core sample;
Step 207, eliminating abnormal values of parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
Step 208, obtaining formation pressure under different burial depths in the in-situ combustion through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure;
Step 209, obtaining the relationship between the formation pressure and the porosity data and the relationship between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures;
Step 210, drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure according to the relation between the burial depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data;
Step 211, removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data;
step 212, drawing a first oil saturation correction chart based on the re-corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
and step 213, drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data.
Of course, it is to be understood that other variations of the above detailed procedures are also possible, and all related variations should fall within the protection scope of the present invention.
A specific example is given below to illustrate a specific application of the method for correcting in-situ core parameters in an embodiment of the present invention.
Taking the structure of a D broken block area in the middle section of a concave west slope of the broken western section of the Liaohe as an example, the target layer is an oil layer of four upper sections Du Gutai of the ancient system sand river street group sand of the new world. The block is put into development in 1986, steam throughput, steam flooding and hot water flooding pilot tests are carried out successively, a fire flooding test is carried out in 2005 in 6, and core samples are taken from an in-situ combustion layer and core parameters are corrected after the fire flooding test.
Firstly, a core natural gamma curve of a core sample is obtained, and fig. 3 is a comparison chart of the core natural gamma curve of the core sample and a logging natural gamma curve in an embodiment of the present invention, from which the burial depth of the core sample can be determined. In this example, three core samples were taken, and the burial depths were 810m, 830m, and 860m, respectively.
Then, scanning a core sample processed into a microscopic rock slice by using an electron microscope to obtain scanning electron microscope data of the core sample, and analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data, and fig. 4 is a schematic diagram of the original pore structure change data of the core sample in the embodiment of the invention, wherein (a) in fig. 4 is an original stratum, and the original pore structure mainly contacts with a dotted line; in fig. 4 (b) is a non-dominant force layer, the original pore structure is mainly dotted contact and is partially free; in fig. 4, (c) is the primary force layer, and the original pore structure is free particles and floating.
And comparing logging data of the coring well where the core sample is positioned with logging data of the production well developed at different stages, and analyzing reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data.
And judging the combustion zone of the core sample according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir. Table 1 is a schematic representation of the division of the combustion zone in the examples of the present invention.
TABLE 1
| Sample of | Depth of burial/m | Combustion zone |
| Core sample 1 | 810 | Burnt zone |
| Core sample 2 | 830 | Steam zone |
| Core sample 3 | 860 | Residual oil zone |
And removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data.
Obtaining formation pressure under different burial depths in an in-situ combustion layer through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure; obtaining the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures; and drawing a porosity correction chart and a permeability correction chart of the core sample under the overburden pressure according to the relation between the buried depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data. Fig. 5 and 6 are schematic diagrams of a porosity correction plate and a permeability correction plate, respectively, of a core sample under overburden pressure in accordance with an embodiment of the present invention. Table 2 is a schematic representation of the correction rate value tables corresponding to fig. 5 and 6.
TABLE 2
Then, removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data; drawing a first oil saturation correction chart based on the recalibrated porosity data and the oil saturation data to obtain first corrected oil saturation data; fig. 7 is a schematic diagram of a first oil saturation correction chart according to an embodiment of the present invention, a second oil saturation correction chart is drawn based on nmr oil saturation data and the first corrected oil saturation data, and second corrected oil saturation data is obtained, and fig. 8 is a schematic diagram of the second oil saturation correction chart according to an embodiment of the present invention.
Through the steps, correction of physical parameters (permeability and porosity) and oily parameters (oil saturation) is realized, accuracy is high, and subsequently, the method can be used for evaluating the potential of the well group and the block residual oil, guiding programming and regulation of an in-situ combustion scheme, fig. 9 is a schematic diagram of evaluation of the block residual oil potential in the embodiment of the invention, table 3 is a potential evaluation result corresponding to fig. 9, in fig. 9, a single well is S46-039, according to the corrected physical parameters and the corrected oily parameters, the position of the core sample 1 can be evaluated to be in a burnt zone, the potential evaluation result is that the core sample is used, namely, the residual oil saturation is low, and cost can be saved by adopting modes of monolayer reduction of gas injection quantity and the like; the position of the core sample 2 is in a steam area, and the potential evaluation result is that partial use is performed, so that the current gas injection intensity is maintained; the position of the core sample 3 is in a residual oil area, the potential evaluation result is that the core sample is not used, and the core sample is a key potential area of lower regulation and control, and the combustion state of the in-situ combustion is improved by adopting modes of increasing gas filling quantity and the like. FIG. 10 is a schematic illustration of in-situ control of combustion in an embodiment of the present invention, for example, single well S46-039 in FIG. 10, with a firing line advance distance of 20.5m-62.3m during control.
TABLE 3 Table 3
| Sample of | Depth of burial/m | Combustion zone | Evaluation of potential |
| Core sample 1 | 810 | Burnt zone | Has been used for |
| Core sample 2 | 830 | Steam zone | For part of |
| Core sample 3 | 860 | Residual oil zone | Not to use |
In summary, in the method provided by the embodiment of the invention, the core natural gamma curve of the core sample is compared with the logging natural gamma curve, and the burial depth of the core sample is determined; analyzing and obtaining reservoir microscopic features of the core sample; analyzing and obtaining reservoir macro-features of the core sample; judging a combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir; removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data; drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data; drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data; and drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data. In the process, according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, abnormal values of parameter data of the core sample are removed, so that accuracy of the parameter data of the core sample acquired in the earlier stage is high, and then the parameter data are corrected in a mode of drawing a porosity correction chart and a permeability correction chart under the overpressure; by drawing the first oil saturation correction plate and the second oil saturation correction plate, the oil saturation data is corrected, and the overall correction accuracy is high.
The embodiment of the invention also provides a device for correcting the in-situ combustion core parameters, the principle of which is similar to that of the in-situ combustion core parameter correction method, and the description is omitted here.
Fig. 11 is a schematic diagram of an in-situ core parameter correcting apparatus according to an embodiment of the present invention, as shown in fig. 11, including:
The burial depth determining module 1101 is configured to compare a core natural gamma curve of the core sample with a logging natural gamma curve, and determine the burial depth of the core sample;
the reservoir microscopic feature analysis module 1102 is configured to analyze reservoir microscopic features of the obtained core sample;
the reservoir macro-feature analysis module 1103 is configured to analyze reservoir macro-features of the obtained core sample;
the combustion zone judging module 1104 is used for judging the combustion zone where the core sample is located according to the burial depth, the reservoir macro-feature and the reservoir micro-feature of the core sample;
The outlier removing module 1105 is configured to perform outlier removing on parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and a combustion zone where the reservoir microscopic features and the combustion zone are located, where the parameter data includes permeability data, porosity data and oil saturation data;
The first correction module 1106 is configured to draw a porosity correction plate and a permeability correction plate of the core sample under the covering pressure based on the parameter data after the outlier rejection, so as to obtain corrected porosity data and corrected permeability data;
a second correction module 1107, configured to draw a first oil saturation correction chart based on the corrected porosity data and the oil saturation data, and obtain first corrected oil saturation data;
A third correction module 1108 is configured to draw a second oil saturation correction chart based on the nmr oil saturation data and the first corrected oil saturation data, and obtain second corrected oil saturation data.
Fig. 12 is another schematic diagram of an apparatus for correcting in-situ core parameters according to an embodiment of the present invention, and in an embodiment, the apparatus further includes a curve obtaining module 1109 configured to: and obtaining a core natural gamma curve of the core sample, wherein the core natural gamma curve is obtained by scanning the core sample.
In one embodiment, the reservoir microfeature analysis module is specifically configured to:
Obtaining scanning electron microscope data of a core sample, wherein the scanning electron microscope data is obtained by performing electron microscope scanning on the core sample processed into microscopic rock slices;
and analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data.
In one embodiment, the reservoir macrofeature analysis module is specifically configured to:
And comparing logging data of the coring well where the core sample is positioned with logging data of the production well developed at different stages, and analyzing reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data.
In one embodiment, the first correction module is specifically configured to:
obtaining formation pressure under different burial depths in an in-situ combustion layer through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure;
Obtaining the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures;
And drawing a porosity correction chart and a permeability correction chart of the core sample under the overburden pressure according to the relation between the buried depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data.
In an embodiment, the apparatus further comprises a fourth correction module 1110 for: removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data;
the second correction module is specifically configured to:
and drawing a first oil saturation correction chart based on the recalibrated porosity data and the oil saturation data to obtain first corrected oil saturation data.
In summary, in the device provided by the embodiment of the invention, the core natural gamma curve of the core sample is compared with the logging natural gamma curve, and the burial depth of the core sample is determined; analyzing and obtaining reservoir microscopic features of the core sample; analyzing and obtaining reservoir macro-features of the core sample; judging a combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir; removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data; drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data; drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data; and drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data. In the process, according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, abnormal values of parameter data of the core sample are removed, so that accuracy of the parameter data of the core sample acquired in the earlier stage is high, and then the parameter data are corrected in a mode of drawing a porosity correction chart and a permeability correction chart under the overpressure; by drawing the first oil saturation correction plate and the second oil saturation correction plate, the oil saturation data is corrected, and the overall correction accuracy is high.
An embodiment of the present application further provides a computer device, and fig. 13 is a schematic diagram of the computer device in the embodiment of the present application, where the computer device can implement all the steps in the in-situ combustion core parameter correction method in the foregoing embodiment, and the computer device specifically includes the following contents:
A processor 1301, a memory 1302, a communication interface (Communications Interface) 1303, and a communication bus 1304;
Wherein, the processor 1301, the memory 1302, and the communication interface 1303 complete communication with each other through the communication bus 1304; the communication interface 1303 is configured to implement information transmission among related devices such as a server device, a detection device, and a user device;
the processor 1301 is configured to invoke a computer program in the memory 1302, which when executed implements all the steps in the in-situ core parameter correction method in the above embodiment.
The embodiment of the present application also provides a computer readable storage medium, which can implement all the steps in the in-situ core parameter correcting method in the above embodiment, and the computer readable storage medium stores a computer program, and when the computer program is executed by a processor, the computer program implements all the steps in the in-situ core parameter correcting method in the above embodiment.
It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the invention, and is not meant to limit the scope of the invention, but to limit the invention to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the invention are intended to be included within the scope of the invention.
Claims (10)
1. A method for correcting in-situ core parameters, comprising:
Comparing the natural gamma curve of the core with the natural gamma curve of the logging to determine the burial depth of the core sample;
Analyzing and obtaining reservoir microscopic features of the core sample;
analyzing and obtaining reservoir macro-features of the core sample;
judging a combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir;
removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after the outlier rejection to obtain corrected porosity data and corrected permeability data;
Drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
Drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data;
Drawing a porosity correction plate and a permeability correction plate of the core sample under the overpressure based on the parameter data after outlier rejection, comprising: obtaining formation pressure under different burial depths in an in-situ combustion layer through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure; obtaining the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures; drawing a porosity correction chart and a permeability correction chart of the core sample under the overburden pressure according to the relation between the buried depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data;
After drawing the porosity correction plate and permeability correction plate of the core sample under the overburden pressure, further comprising: removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data;
drawing a first oil saturation correction plate based on the corrected porosity data and oil saturation data to obtain first corrected oil saturation data, comprising: and drawing a first oil saturation correction chart based on the recalibrated porosity data and the oil saturation data to obtain first corrected oil saturation data.
2. The in-situ core parameter correcting method as defined in claim 1, further comprising:
And obtaining a core natural gamma curve of the core sample, wherein the core natural gamma curve is obtained by scanning the core sample.
3. The in-situ core parameter calibration method as recited in claim 1, wherein analyzing reservoir microfeatures of the obtained core sample comprises:
Obtaining scanning electron microscope data of a core sample, wherein the scanning electron microscope data is obtained by performing electron microscope scanning on the core sample processed into microscopic rock slices;
and analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data.
4. The in-situ core parameter correction method as defined in claim 1, wherein analyzing reservoir macrofeatures of the obtained core sample comprises:
And comparing logging data of the coring well where the core sample is positioned with logging data of the production well developed at different stages, and analyzing reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data.
5. A device for correcting core parameters of in-situ combustion, comprising:
The buried depth determining module is used for comparing the core natural gamma curve of the core sample with the logging natural gamma curve to determine the buried depth of the core sample;
the reservoir microscopic feature analysis module is used for analyzing and obtaining reservoir microscopic features of the core sample;
the reservoir macro-feature analysis module is used for analyzing and obtaining reservoir macro-features of the core sample;
The combustion zone judging module is used for judging the combustion zone where the core sample is located according to the burial depth of the core sample, the macroscopic features of the reservoir and the microscopic features of the reservoir;
the abnormal value removing module is used for removing abnormal values from parameter data of the core sample according to reservoir microscopic features, reservoir macroscopic features and combustion zones of the core sample, wherein the parameter data comprise permeability data, porosity data and oil saturation data;
The first correction module is used for drawing a porosity correction plate and a permeability correction plate of the core sample under the covering pressure based on the parameter data after the outlier is removed, so as to obtain corrected porosity data and corrected permeability data;
the second correction module is used for drawing a first oil saturation correction chart based on the corrected porosity data and the oil saturation data to obtain first corrected oil saturation data;
the third correction module is used for drawing a second oil saturation correction chart based on the nuclear magnetic resonance oil saturation data and the first corrected oil saturation data to obtain second corrected oil saturation data;
The first correction module is specifically configured to: obtaining formation pressure under different burial depths in an in-situ combustion layer through RFT formation testing, and obtaining the relation between the burial depths and the formation pressure; obtaining the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data according to the porosity data and the permeability data corresponding to different formation pressures; drawing a porosity correction chart and a permeability correction chart of the core sample under the overburden pressure according to the relation between the buried depth and the formation pressure, the relation between the formation pressure and the porosity data and the relation between the formation pressure and the permeability data;
A fourth correction module for: removing errors caused by the thick oil loose core under the overpressure from the porosity correction plate and the permeability correction plate respectively to obtain re-corrected porosity data and re-corrected permeability data;
the second correction module is specifically configured to: and drawing a first oil saturation correction chart based on the recalibrated porosity data and the oil saturation data to obtain first corrected oil saturation data.
6. The in-situ core parameter correcting apparatus as recited in claim 5, further comprising a curve acquisition module for: and obtaining a core natural gamma curve of the core sample, wherein the core natural gamma curve is obtained by scanning the core sample.
7. The in-situ core parameter correcting apparatus as recited in claim 5, wherein the reservoir microfeature analysis module is configured to:
Obtaining scanning electron microscope data of a core sample, wherein the scanning electron microscope data is obtained by performing electron microscope scanning on the core sample processed into microscopic rock slices;
and analyzing reservoir microscopic features of the core sample according to the scanning electron microscope data, wherein the reservoir microscopic features comprise original pore structure change data.
8. The in-situ core parameter correcting apparatus as recited in claim 5, wherein the reservoir macrofeature analysis module is configured to:
And comparing logging data of the coring well where the core sample is positioned with logging data of the production well developed at different stages, and analyzing reservoir macro-features of the core sample, wherein the reservoir macro-features comprise electrical change rule data.
9. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the method of any of claims 1 to 4 when executing the computer program.
10. A computer readable storage medium, characterized in that the computer readable storage medium stores a computer program for executing the method of any one of claims 1 to 4.
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