Shale bed free hydrocarbon determination method and device, storage medium and electronic equipment

Abstract

The invention discloses a shale bed free hydrocarbon determination method and device, a storage medium and electronic equipment. The method comprises the steps that an organic carbon parameter and a maturity parameter in a shale bed are determined, the organic carbon parameter is used for representing a content index of organic matter in the shale bed, and the maturity parameter is used for representing a degree index of conversion of the organic matter into hydrocarbons; and determining free hydrocarbon parameters in the shale bed based on the organic carbon parameters and the maturity parameters. The method and the device solve the technical problem that the accuracy of determining the parameters of the free hydrocarbon in the shale bed is not ideal in the prior art.

Description

Technical Field

[0001] The present invention relates to the field of geological exploration technology, and in particular to a method, device, storage medium and electronic equipment for determining free hydrocarbons in a shale layer. Background Art

[0002] The shale oil and gas field has gradually become an important field for oil and gas replacement. Free hydrocarbon S1 is a hydrocarbon that has been generated in the rock but still remains in the rock and exists in a free state. Its size directly affects the production of the reservoir and is an important indicator for directly evaluating the oil production capacity. Accurately obtaining the S1 content is the key to evaluating shale oil and gas reservoirs. In related technologies, the organic carbon parameter TOC (Total Organic Carbon) is used for calculation. Generally, in the evaluation of shale oil, the more organic carbon content, the greater the maturity, and the greater the reactive oil and gas content S1. However, in related technologies, in high-maturity areas, the conversion of organic matter is mainly based on the light hydrocarbon indicator parameter S0 (free hydrocarbon S0 refers to the content of organic matter that can be dissolved in the solvent in the formation). In fact, the S1 content will be relatively reduced. The use of the organic carbon parameter TOC to determine the free hydrocarbon parameter S1 results in unsatisfactory accuracy of the free hydrocarbon parameter S1, making it difficult to accurately evaluate the oil and gas content in the shale reservoir.

[0003] To address the above-mentioned problems, no effective solution has been proposed yet. Summary of the invention

[0004] The embodiments of the present invention provide a method, device, storage medium and electronic device for determining free hydrocarbons in a shale layer, so as to at least solve the technical problem of unsatisfactory accuracy in determining free hydrocarbon parameters in a shale layer existing in the related art.

[0005] According to one aspect of an embodiment of the present invention, a method for determining free hydrocarbons in a shale layer is provided, comprising: determining an organic carbon parameter and a maturity parameter in a shale layer, wherein the organic carbon parameter is used to characterize an index of a content of organic matter in the shale layer, and the maturity parameter is used to characterize an index of a degree of conversion of the organic matter into hydrocarbons; based on the organic carbon parameter and the maturity parameter, determining the free hydrocarbon parameter in the shale layer.

[0006] Optionally, determining the free hydrocarbon parameter in the shale layer based on the organic carbon parameter and the maturity parameter includes: determining a target proportion coefficient based on the maturity parameter; and determining the free hydrocarbon parameter based on the target proportion coefficient and the organic carbon parameter.

[0007] Optionally, determining the free hydrocarbon parameter based on the target proportion coefficient and the organic carbon parameter includes: obtaining a first regional coefficient of the region where the shale layer is located; and obtaining the target proportion coefficient based on the maturity parameter in the following manner:

[0008] S1 / TOC=∫(Ro)+g

[0009] Among them, S1 is the free hydrocarbon parameter, TOC is the organic carbon parameter, S1 / TOC is the target ratio coefficient, Ro is the maturity, and g is the first regional coefficient.

[0010] Optionally, determining the organic carbon parameters in the shale layer includes: acquiring core data of the shale layer; and performing regression analysis based on the core data to determine the organic carbon parameters.

[0011] Optionally, the core data includes sonic time difference, resistivity, compensated density, and compensated neutrons, and the regression analysis based on the core data to determine the organic carbon parameters includes: performing regression analysis based on the sonic time difference, the resistivity, the compensated density, and the compensated neutrons to determine the second regional coefficient corresponding to the sonic time difference, the third regional coefficient corresponding to the resistivity, the fourth regional coefficient corresponding to the compensated density, and the fifth regional coefficient corresponding to the compensated neutrons; determining the organic carbon parameters based on the sonic time difference, the second regional coefficient, the resistivity, the third regional coefficient, the compensated density, the fourth regional coefficient, the compensated neutrons, and the fifth regional coefficient.

[0012] Optionally, determining the maturity parameters in the shale layer includes: acquiring core data of the shale layer; determining the well temperature gradient of the shale layer based on the core data, wherein the well temperature gradient represents the rate at which the crust temperature in the shale layer changes with depth; and determining the maturity parameters based on the well temperature gradient and the detection depth.

[0013] Optionally, the determining the maturity parameter based on the well temperature gradient and the detection depth includes: obtaining the maturity parameter based on the well temperature gradient and the detection depth in the following manner;

[0014] Ro=f*e i*depth×td

[0015] Among them, Ro is the maturity, f is the predetermined sixth region coefficient, i is the predetermined seventh region coefficient, depth is the detection depth, and td is the well temperature gradient.

[0016] According to another aspect of an embodiment of the present invention, a device for determining free hydrocarbons in a shale layer is provided, comprising: a parameter acquisition module, used to determine an organic carbon parameter and a maturity parameter in a shale layer, wherein the organic carbon parameter is used to characterize an index of a content of organic matter in the shale layer, and the maturity parameter is used to characterize an index of a degree of conversion of the organic matter into hydrocarbons; and a calculation module, used to determine the free hydrocarbon parameter in the shale layer based on the organic carbon parameter and the maturity parameter.

[0017] According to another aspect of an embodiment of the present invention, a non-volatile storage medium is provided, wherein the non-volatile storage medium stores a plurality of instructions, wherein the instructions are suitable for being loaded by a processor and executed by any one of the methods for determining free hydrocarbons in a shale layer.

[0018] According to another aspect of an embodiment of the present invention, there is provided an electronic device, comprising: one or more processors and a memory, wherein the memory is used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement any one of the methods for determining free hydrocarbons in a shale layer.

[0019] In the embodiment of the present invention, the organic carbon parameter and maturity parameter in the shale layer are determined by combining the change of maturity parameter, wherein the organic carbon parameter is used to characterize the content index of organic matter in the shale layer, and the maturity parameter is used to characterize the degree index of the conversion of the organic matter into hydrocarbons; based on the organic carbon parameter and the maturity parameter, the free hydrocarbon parameter in the shale layer is determined. The purpose of using the maturity parameter in the shale layer in combination with the organic carbon parameter to improve the accuracy of the assessment of the oil generation capacity in the shale layer is achieved, and the technical effect of improving the accuracy of the free hydrocarbon parameter is achieved, thereby solving the technical problem of unsatisfactory accuracy of determining the free hydrocarbon parameter in the shale layer existing in the related art. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] The drawings described herein are used to provide a further understanding of the present invention and constitute a part of this application. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute an improper limitation of the present invention. In the drawings:

[0021] Figure 1 is a flow chart of an optional method for determining free hydrocarbons in a shale layer provided according to an embodiment of the present invention;

[0022] Figure 2 is a maturity parameter variation diagram of an optional method for determining free hydrocarbons in a shale layer provided according to an embodiment of the present invention;

[0023] Figure 3 is a schematic diagram of proportion changes of an optional method for determining free hydrocarbons in a shale layer provided according to an embodiment of the present invention;

[0024] Figure 4 is a schematic diagram of an algorithm for determining free hydrocarbons in a shale layer according to an optional method provided in an embodiment of the present invention;

[0025] Figure 5 is a schematic diagram of actual measurement verification of an optional method for determining free hydrocarbons in a shale layer provided according to an embodiment of the present invention;

[0026] Figure 6 It is a schematic diagram of an optional shale layer free hydrocarbon determination device provided according to an embodiment of the present invention. DETAILED DESCRIPTION

[0027] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0028] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0029] For the convenience of description, some nouns or terms involved in the embodiments of the present application are explained below:

[0030] Shale layers are of great significance in geology and oil exploration. Since shale layers contain a large amount of organic matter, they can form oil and natural gas after pyrolysis and compaction. Therefore, shale layers are considered to be an important unconventional energy resource. In recent years, with the development of horizontal drilling and hydraulic fracturing technology, the development capacity of shale oil and gas has been improved.

[0031] Organic carbon parameter, organic carbon parameter TOC content of high shale layers generally means rich in organic matter, often has higher shale gas production, and has higher hydrocarbon storage potential, because organic matter can be converted into oil and natural gas under appropriate temperature and pressure conditions.

[0032] Maturity parameters, maturity parameters can be used to evaluate the oil and gas generation potential in shale, that is, the ability of organic matter to produce oil and gas at different maturity levels. Based on maturity parameters, the amount and quality of oil and gas resources in shale layers can be predicted and evaluated. Maturity parameters in shale layers usually include kerogen type and kerogen reflectivity. Kerogen (Cheese root) refers to huge rocks formed deep underground, usually formed by long-term erosion and dissolution of dissolved rock layers such as salt rock or gypsum. Kerogen type refers to the source and composition of kerogen, which can be used to infer the type and content of organic matter in shale. Kerogen reflectivity is an indicator to measure the degree of kerogen pyrolysis and the degree of formation of pyrolysis products.

[0033] Free hydrocarbon parameter, the free hydrocarbon parameter S1 in the shale layer refers to the content of free hydrocarbons that can be extracted from the shale sample. Free hydrocarbons refer to hydrocarbon substances that can be volatilized from rocks at normal temperature and pressure. S1 is the first stage of free hydrocarbons and indicates the quality of volatile oil extracted from rocks. The determination of free hydrocarbon S1 can be used to evaluate the amount of combustible hydrocarbon resources in shale and the abundance and maturity of organic matter in rocks.

[0034] Generally speaking, the higher the organic carbon content, the higher the maturity, the more oil and gas content converted from organic matter by default, and the higher the free hydrocarbon S1. In related technologies, free hydrocarbons are obtained by using organic carbon, but because organic carbon includes carbon that cannot be extracted with organic solvents and cannot be pyrolyzed to generate hydrocarbons, the organic carbon content does not absolutely reflect the potential of the source rock.

[0035] In response to the above problems, an embodiment of the present invention provides an embodiment of a method for determining free hydrocarbons in a shale formation. It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and although a logical order is shown in the flowchart, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0036] Figure 1 is a flow chart of a method for determining free hydrocarbons in a shale layer according to an embodiment of the present invention. Figure 1 As shown, the method comprises the following steps:

[0037] Step S102, determining an organic carbon parameter and a maturity parameter in the shale layer, wherein the organic carbon parameter is used to characterize an index of the content of organic matter in the shale layer, and the maturity parameter is used to characterize an index of the degree of conversion of organic matter into hydrocarbons;

[0038] It can be understood that the ratio of free hydrocarbons to organic carbon becomes more complicated with the change of maturity. Calculating free bodies based on organic carbon and maturity can effectively improve the accuracy of free hydrocarbons and is conducive to the accurate evaluation of oil generation capacity.

[0039] In an optional embodiment, determining the organic carbon parameters in the shale layer includes: obtaining core data of the shale layer; and performing regression analysis based on the core data to determine the organic carbon parameters.

[0040] It can be understood that the core data of the shale layer refers to the relevant data of the shale rock samples obtained through core drilling. Core drilling is a geological exploration technology that uses a drill bit to drill underground to obtain core samples of underground rocks. These core samples can provide detailed information on the physical properties, chemical composition, pore structure, rock composition and rock structure of the rock. Through the core data obtained based on the core samples, regression analysis can be performed to determine the organic carbon parameters.

[0041] In an optional embodiment, the core data includes sonic time difference, resistivity, compensated density, and compensated neutrons, and regression analysis is performed based on the core data to determine the organic carbon parameters, including: performing regression analysis based on the sonic time difference, resistivity, compensated density, and compensated neutrons to determine the second area coefficient corresponding to the sonic time difference, the third area coefficient corresponding to the resistivity, the fourth area coefficient corresponding to the compensated density, and the fifth area coefficient corresponding to the compensated neutrons; determining the organic carbon parameters based on the sonic time difference, the second area coefficient, resistivity, the third area coefficient, the compensated density, the fourth area coefficient, the compensated neutrons, and the fifth area coefficient.

[0042] It can be understood that the above core data can be multiple, and the acoustic time difference (Acoustic Time Difference), resistivity (Resistivity), compensated density (Compensated Density) and compensated neutron (Compensated Neutron) in the core data are used to describe the physical properties and composition of the rock, and can be associated with the organic carbon parameters in the rock formation to provide information about the content and type of organic matter in the rock. Specifically, the acoustic time difference measurement can provide information about the density of the rock, while organic matter usually has a lower density, and an increase in the acoustic time difference is usually associated with an increase in the organic matter content. Organic matter usually has a higher resistivity, while the resistivity of the rock itself is usually low, and an increase in resistivity is usually associated with an increase in the organic matter content. Compensated density measurement can provide information about the density of the rock, while organic matter usually has a lower density, and a decrease in compensated density is usually associated with an increase in the organic matter content. Organic matter usually has a lower neutron absorption capacity, and an increase in compensated neutrons is usually associated with a decrease in the organic matter content. In order to analyze the correlation between the above parameters included in the core data and the organic carbon content, it is necessary to use regression analysis to determine the second regional coefficient corresponding to the acoustic time difference, the third regional coefficient corresponding to the resistivity, the fourth regional coefficient corresponding to the compensated density, and the fifth regional coefficient corresponding to the compensated neutron, so as to characterize the organic carbon parameters.

[0043] Optionally, acoustic time difference measurement can be obtained in a variety of ways, for example: using the speed and time of sound wave propagation to calculate the density of the formation. By measuring the speed of sound waves propagating in the rock and the time difference when they reach different receivers, the density of the formation can be calculated, thereby understanding the physical properties of the rock.

[0044] Alternatively, resistivity measurements can be obtained in a variety of ways, for example, by applying an electric current in the rock and measuring the electric field strength to determine the resistivity properties of the rock. Different types of rock have different resistivities, and resistivity measurements can be used to identify and distinguish different rock types.

[0045] Optionally, the compensated density can be obtained in a variety of ways, for example, by estimating the density of the formation by measuring the attenuation of the rock to the radiation. The compensated density measurement can correct the effect of the pore space in the rock on the density measurement, thereby providing more accurate density data.

[0046] Alternatively, compensated neutron measurements can be obtained in a variety of ways, for example: compensated neutron measurements can be used to identify radioactive elements in rocks, thereby providing information about the composition and properties of the rocks.

[0047] In an optional embodiment, determining maturity parameters in a shale layer includes: obtaining core data of the shale layer; determining a well temperature gradient of the shale layer based on the core data, wherein the well temperature gradient represents the rate at which crustal temperature in the shale layer changes with depth; and determining maturity parameters based on the well temperature gradient and the detection depth.

[0048] It can be understood that in order to detect the formation conditions in the shale layer, the logging method can be used to obtain parameters, and the collected core data can be used to obtain the rate at which the crustal temperature of the shale layer changes with depth in the logging direction. Compared with the use of a single depth to obtain maturity in related technologies, the introduction of well temperature gradient is conducive to dealing with abnormal geothermal gradient areas and is conducive to the accurate acquisition of maturity parameters.

[0049] In an optional embodiment, determining the maturity parameter based on the well temperature gradient and the detection depth includes: obtaining the maturity parameter based on the well temperature gradient and the detection depth by the following method;

[0050] Ro=f*e i*depth×td

[0051] Among them, Ro is maturity, f is the predetermined sixth region coefficient, i is the predetermined seventh region coefficient, depth is the detection depth, and td is the well temperature gradient.

[0052] It is understandable that the maturity parameter is usually expressed as Ro, which usually has a certain temporal relationship with temperature and time. For areas with non-constant geothermal gradients, the previous method of calculating Ro only by depth has limitations, such as Figure 2 As shown in the figure, multiple logging data are given. It can be seen that with the increase of vertical depth in the logging, the changes in maturity parameters are not the same, and all show nonlinear changes. Based on the core analysis vitrinite reflectance data (vitrinite reflectance can reflect the highest temperature experienced by organic matter and is a good maturity indicator), the well temperature gradient curve is used to simulate the geothermal gradient, and the specific mathematical expression of the maturity parameter Ro is established. In this way, the maturity parameters of various depth formations can be determined by changing the detection depth.

[0053] Step S104, determining the free hydrocarbon parameters in the shale layer based on the organic carbon parameters and the maturity parameters.

[0054] It can be understood that the proportional relationship between free hydrocarbon parameters and organic carbon parameters becomes complicated with the change of maturity. By calculating the free hydrocarbon parameters, the calculation accuracy of the free hydrocarbon parameters can be improved in the evaluation of reservoirs with a large maturity range, thereby accurately evaluating the oil and gas content of shale reservoirs.

[0055] In an optional embodiment, based on the organic carbon parameter and the maturity parameter, the free hydrocarbon parameter in the shale layer is determined, including: determining a target proportion coefficient based on the maturity parameter; and determining the free hydrocarbon parameter based on the target proportion coefficient and the organic carbon parameter.

[0056] It can be understood that the target proportional coefficient between the free hydrocarbon parameter and the organic carbon parameter is related to the maturity parameter of the shale layer. As the maturity increases, the hydrocarbon compounds in the organic matter will be gradually released. As the maturity increases, the organic matter in the rock formation is heated and compacted, and the hydrocarbon compounds in the organic matter will gradually be converted into free hydrocarbons. Therefore, the maturity parameter can characterize the correlation ratio between the free hydrocarbon parameter and the organic carbon parameter.

[0057] In an optional embodiment, based on the target proportion coefficient and the organic carbon parameter, determining the free hydrocarbon parameter includes: obtaining a first regional coefficient of the region where the shale layer is located; based on the maturity parameter, obtaining the target proportion coefficient by the following method:

[0058] S1 / TOC=∫(Ro)+g

[0059] Among them, S1 is the free hydrocarbon parameter, TOC is the organic carbon parameter, S1 / TOC is the target ratio coefficient, Ro is the maturity, and g is the first area coefficient.

[0060] It can be understood that the first regional coefficient is an empirical coefficient for the region and is dimensionless. By integrating the maturity and adding the first regional coefficient, the target proportional coefficient can be obtained. Figure 3 As shown in the figure, for shale mainly composed of light oil, after the maturity parameter reaches a certain critical value, the oil and gas are mainly represented by the light component representative parameter S0, the free hydrocarbon representative parameter S1 value decreases, and S1 shows an inverted "V" shape change with increasing maturity.

[0061] In an optional embodiment, after determining the free hydrocarbon parameters in the shale layer based on the organic carbon parameter and the maturity parameter, the method further includes: measuring the free hydrocarbons in the shale layer to determine the measured parameters; when the deviation value between the free hydrocarbon parameter and the measured parameter is greater than a predetermined deviation range, determining a first significance coefficient corresponding to the organic carbon parameter and a second significance coefficient corresponding to the maturity parameter, wherein the first significance coefficient is used to represent the influence of the organic carbon parameter on the deviation value, and the second significance coefficient is used to represent the influence of the maturity parameter on the deviation value; when the first significance coefficient is greater than a first predetermined value, correcting the organic carbon parameter to obtain a corrected organic carbon parameter; determining the free hydrocarbon parameter based on the corrected organic carbon parameter and maturity parameter; when the second significance coefficient is greater than a second predetermined value, correcting the maturity parameter to obtain a corrected maturity parameter; determining the free hydrocarbon parameter based on the organic carbon parameter and the corrected maturity parameter.

[0062] It can be understood that in order to determine the applicability of the method for obtaining free hydrocarbon parameters, the free hydrocarbon can be measured in the shale layer. When the deviation between the free hydrocarbon parameter and the measured parameter is greater than the predetermined deviation range, it is considered that the parameter needs to be adjusted. In order to determine what kind of adjustment should be made, the first significance coefficient and the second significance coefficient can be determined respectively. The larger the significance coefficient, the greater the impact on the deviation. The corresponding organic carbon parameter or maturity parameter can be adjusted accordingly. In the above manner, parameter correction can be achieved in one step to provide the accuracy of the free hydrocarbon parameter.

[0063] Through the above step S102, the organic carbon parameter and maturity parameter in the shale layer are determined, wherein the organic carbon parameter is used to characterize the content index of organic matter in the shale layer, and the maturity parameter is used to characterize the degree index of the conversion of organic matter into hydrocarbons; step S104, based on the organic carbon parameter and the maturity parameter, the free hydrocarbon parameter in the shale layer is determined. The purpose of improving the accuracy of evaluating the oil generation capacity in the shale layer by combining the maturity parameter in the shale layer with the organic carbon parameter can be achieved, and the technical effect of improving the accuracy of the free hydrocarbon parameter is achieved, thereby solving the technical problem of unsatisfactory accuracy of determining the free hydrocarbon parameter in the shale layer existing in the related art.

[0064] Based on the above embodiments and optional embodiments, the present invention proposes an optional implementation mode, which is specifically the following steps: Figure 4 As shown, in order to determine the free hydrocarbon parameter S1 in the shale layer, firstly, the correlation between the organic carbon parameter TOC and the free hydrocarbon parameter S1 is established based on the core data obtained from the formation, and then the relationship with the maturity parameter Ro is determined to obtain the free hydrocarbon parameter S1, as described in detail below.

[0065] Step S401, determining the organic carbon parameter TOC based on the core data, firstly obtaining the acoustic time difference, resistivity, compensated density, compensated neutron and other data based on the core data, performing multivariate regression analysis on the acoustic time difference, resistivity, compensated density, compensated neutron curves, and respectively obtaining the second regional coefficient a corresponding to the acoustic time difference, the third regional coefficient b corresponding to the resistivity, the fourth regional coefficient c corresponding to the compensated density, and the fifth regional coefficient d corresponding to the compensated neutron. After determining the above-mentioned multiple regional coefficients, the required organic carbon parameter TOC can be determined, and the above-mentioned regional coefficients are dimensionless.

[0066] TOC=a*log(RT)+b*AC+c*DEN+d*CNL

[0067] Where RT is the resistivity, which can be further called deep lateral resistivity, in Ω·m (ohm per meter), AC is the acoustic time difference, in μs / ft (microseconds per foot), and DEN is the compensated density, in g / cm3 (g / cubic centimeter), CNL is compensated neutron, the unit is % (percent).

[0068] Step S402, based on the core data, the maturity parameter Ro is determined. Ro usually has a certain time relationship with temperature and time. For the non-constant geothermal gradient area, the previous method of calculating Ro only by depth has limitations. Based on the core analysis of vitrinite reflectance (vitrinite reflectance can reflect the highest temperature experienced by organic matter and is a good maturity indicator) data, the geothermal gradient is simulated by the well temperature gradient curve in the well logging method, and the following mathematical expression can be used:

[0069] Ro=f*e i*depth×td

[0070] Among them, f is the predetermined sixth regional coefficient, i is the predetermined seventh regional coefficient, the above two regional coefficients are dimensionless, depth is the detection depth, the unit is m (meter), td is the well temperature gradient, the unit is ℃ / Km (degrees Celsius per kilometer).

[0071] Step S403, through the above two-step processing, the organic carbon parameter TOC and the maturity parameter Ro are obtained. Generally, under the same maturity and type conditions, the greater the organic matter abundance (high organic carbon content) of the source rock, the more oil and gas it produces. However, since organic carbon includes carbon that cannot be extracted with organic solvents and cannot be pyrolyzed to generate hydrocarbons, the content of organic carbon does not absolutely reflect the potential of the source rock, and the hydrocarbon production potential is an important indicator for directly evaluating its oil production ability. Among the traditional geochemical indicators, the free hydrocarbon parameter S1 can more directly reflect the amount of oil, so the free hydrocarbon parameter S1 content is used to quantitatively evaluate the oil and gas content of shale.

[0072] Core analysis was performed on each well to determine the target ratio coefficients of free hydrocarbon S1 and organic carbon parameter TOC. The correlation analysis of the target ratio coefficient and maturity parameter Ro was performed to establish the correlation model between S1 / TOC (i.e., target ratio coefficient) and Ro:

[0073] S1 / TOC=∫(Ro)+g

[0074] S1=(∫(Ro)+g)×TOC

[0075] Where g is the first region coefficient and is dimensionless.

[0076] Step S404: In order to verify the accuracy of the above free hydrocarbon parameters, the reservoir well data is processed to obtain measured data, such as Figure 5As shown, from left to right, the first track is a lithology logging curve track, including natural gamma and borehole diameter curves, the second track is a depth track, the third track is an electrical track, including deep and shallow lateral resistivity curves, the fourth track is a three-porosity logging curve track, including compensated density, compensated neutron, acoustic time difference, and density compensation value curves, the fifth track is a lithology track, which is a lithology scanning logging curve, the sixth track is an oil-bearing track, which represents the measured parameters of free hydrocarbons and the free hydrocarbon parameter curve obtained from step S401 to step S403, the seventh track is a source rock characteristic track, which is the measured organic carbon parameter TOC and the organic carbon parameter TOC curve obtained from step S401, and the measured maturity parameter Ro and the maturity parameter Ro curve obtained from step S402. By comparing the measured free hydrocarbon parameters with the free hydrocarbon parameter curves obtained from step S401 to step S403, the results are generally consistent.

[0077] The optional implementation method described above achieves at least the following effects: This implementation method introduces neutron and density curves that reflect changes in reservoir physical properties, and the calculation of organic carbon content is more accurate. In the method of obtaining maturity at a single depth in related technologies, the change in well temperature gradient is introduced to replace the change in geothermal gradient, and the maturity of the geothermal gradient abnormal area is accurately obtained. It also takes into account that the relationship between the ratio of free hydrocarbons and organic carbon becomes more complicated with the change in maturity, and a mathematical expression for calculating free hydrocarbons is given. In the evaluation of reservoirs with a large range of maturity changes, the calculation accuracy of free hydrocarbons can be improved, and the oil and gas content of shale reservoirs can be accurately evaluated.

[0078] It should be noted that the steps shown in the flowcharts of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and that, although a logical order is shown in the flowcharts, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0079] In this embodiment, a shale layer free hydrocarbon determination device is also provided, which is used to implement the above-mentioned embodiments and preferred embodiments, and the descriptions that have been made will not be repeated. As used below, the terms "module" and "device" can implement a combination of software and / or hardware for a predetermined function. Although the devices described in the following embodiments are preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceivable.

[0080] According to an embodiment of the present invention, there is also provided an embodiment of a device for implementing a method for determining free hydrocarbons in a shale layer. Figure 6 is a schematic diagram of a device for determining free hydrocarbons in a shale layer according to an embodiment of the present invention. Figure 6 As shown, the above-mentioned shale layer free hydrocarbon determination device includes: a parameter acquisition module 602 and a calculation module 604. The device is described below.

[0081] The parameter acquisition module 602 is used to determine the organic carbon parameter and maturity parameter in the shale layer, wherein the organic carbon parameter is used to characterize the content index of organic matter in the shale layer, and the maturity parameter is used to characterize the degree index of the conversion of organic matter into hydrocarbons;

[0082] The calculation module 604 is connected to the parameter acquisition module 602 and is used to determine the free hydrocarbon parameters in the shale layer based on the organic carbon parameters and the maturity parameters.

[0083] In a shale layer free hydrocarbon determination device provided by an embodiment of the present invention, a parameter acquisition module 602 is used to determine the organic carbon parameter and maturity parameter in the shale layer, wherein the organic carbon parameter is used to characterize the content index of organic matter in the shale layer, and the maturity parameter is used to characterize the degree index of the conversion of organic matter into hydrocarbons; a calculation module 604 is connected to the parameter acquisition module 602, and is used to determine the free hydrocarbon parameter in the shale layer based on the organic carbon parameter and the maturity parameter. The purpose of using the maturity parameter in the shale layer in combination with the organic carbon parameter to improve the accuracy of the assessment of the oil generation capacity in the shale layer is achieved, and the technical effect of improving the accuracy of the free hydrocarbon parameter is achieved, thereby solving the technical problem of unsatisfactory accuracy of determining the free hydrocarbon parameter in the shale layer existing in the related art.

[0084] As an optional embodiment, the shale layer free hydrocarbon determination device provided in the embodiment of the present invention is also used to determine the target proportion coefficient based on the maturity parameter; and determine the free hydrocarbon parameter based on the target proportion coefficient and the organic carbon parameter.

[0085] As an optional embodiment, the shale layer free hydrocarbon determination device provided in the embodiment of the present invention is also used to obtain a first regional coefficient of the region where the shale layer is located; based on the maturity parameter, the target proportional coefficient is obtained in the following manner:

[0086] S1 / TOC=∫(Ro)+g

[0087] Among them, S1 is the free hydrocarbon parameter, TOC is the organic carbon parameter, S1 / TOC is the target ratio coefficient, Ro is the maturity, and g is the first area coefficient.

[0088] As an optional embodiment, the shale layer free hydrocarbon determination device provided in the embodiment of the present invention is also used to obtain core data of the shale layer; and to perform regression analysis based on the core data to determine organic carbon parameters.

[0089] As an optional embodiment, the shale layer free hydrocarbon determination device provided in the embodiment of the present invention is also used to perform regression analysis based on the acoustic wave time difference, resistivity, compensated density, and compensated neutrons to determine the second area coefficient corresponding to the acoustic wave time difference, the third area coefficient corresponding to the resistivity, the fourth area coefficient corresponding to the compensated density, and the fifth area coefficient corresponding to the compensated neutrons; and determine the organic carbon parameters based on the acoustic wave time difference, the second area coefficient, resistivity, the third area coefficient, the compensated density, the fourth area coefficient, the compensated neutrons, and the fifth area coefficient.

[0090] As an optional embodiment, the embodiment of the present invention provides a shale layer free hydrocarbon determination device, which is also used to obtain core data of the shale layer; based on the core data, determine the well temperature gradient of the shale layer, wherein the well temperature gradient represents the rate at which the crust temperature in the shale layer changes with depth; based on the well temperature gradient and the detection depth, determine the maturity parameter.

[0091] As an optional embodiment, the shale layer free hydrocarbon determination device provided in the embodiment of the present invention is also used to obtain maturity parameters based on the well temperature gradient and the detection depth in the following manner;

[0092] Ro=f*e i*depth×td

[0093] Among them, Ro is maturity, f is the predetermined sixth region coefficient, i is the predetermined seventh region coefficient, depth is the detection depth, and td is the well temperature gradient.

[0094] It should be noted that the above modules can be implemented by software or hardware. For example, for the latter, it can be implemented in the following ways: the above modules can be located in the same processor; or the above modules can be located in different processors in any combination.

[0095] It should be noted that the parameter acquisition module 602 and the calculation module 604 correspond to steps S102 to S104 in the embodiment, and the examples and application scenarios implemented by the modules and the corresponding steps are the same, but are not limited to the contents disclosed in the embodiment. It should be noted that the modules as part of the device can be run in a computer terminal.

[0096] It should be noted that the optional or preferred implementation of this embodiment can refer to the relevant description in the embodiment, which will not be repeated here.

[0097] The above-mentioned shale layer free hydrocarbon determination device may also include a processor and a memory. The parameter acquisition module 602, the calculation module 604, etc. are all stored in the memory as program units, and the processor executes the above-mentioned program units stored in the memory to realize corresponding functions.

[0098] The processor includes a kernel, which retrieves the corresponding program unit from the memory. There can be one or more kernels. The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one storage chip.

[0099] An embodiment of the present invention provides a non-volatile storage medium on which a program is stored. When the program is executed by a processor, a method for determining free hydrocarbons in a shale layer is implemented.

[0100] An embodiment of the present invention provides an electronic device, which includes a processor, a memory, and a program stored in the memory and can be run on the processor. When the processor executes the program, the following steps are implemented: determining organic carbon parameters and maturity parameters in the shale layer, wherein the organic carbon parameter is used to characterize the content index of organic matter in the shale layer, and the maturity parameter is used to characterize the degree index of the conversion of organic matter into hydrocarbons; based on the organic carbon parameter and the maturity parameter, determining the free hydrocarbon parameter in the shale layer. The device in this article can be a server, a PC, etc.

[0101] The present invention also provides a computer program product, which, when executed on a data processing device, is suitable for executing a program that initializes the following method steps: determining organic carbon parameters and maturity parameters in a shale layer, wherein the organic carbon parameters are used to characterize the content index of organic matter in the shale layer, and the maturity parameters are used to characterize the degree of conversion of organic matter into hydrocarbons; based on the organic carbon parameters and the maturity parameters, determining free hydrocarbon parameters in the shale layer.

[0102] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0103] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0104] These computer program instructions may also be stored in a computer readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture including an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0105] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0106] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0107] The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory in the form of read-only memory (ROM) or flash RAM. The memory is an example of a computer-readable medium.

[0108] Computer readable media include permanent and non-permanent, removable and non-removable media that can be implemented by any method or technology to store information. Information can be computer readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disk read-only memory (CD-ROM), digital versatile disk (DVD) or other optical storage, magnetic cassettes, magnetic tape disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include temporary computer readable media (transitory media), such as modulated data signals and carrier waves.

[0109] It should also be noted that the terms "include", "comprises" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, commodity or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, commodity or device. In the absence of more restrictions, the elements defined by the sentence "comprises a ..." do not exclude the existence of other identical elements in the process, method, commodity or device including the elements.

[0110] It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as methods, systems or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program codes.

[0111] The above are only embodiments of the present invention and are not intended to limit the present invention. For those skilled in the art, the present invention may have various modifications and variations. Any modification, equivalent substitution, improvement, etc. made within the spirit and principle of the present invention should be included in the scope of the claims of the present invention.

Claims

1. A method for determining free hydrocarbons in a shale layer, characterized in that: include: Determining an organic carbon parameter and a maturity parameter in a shale layer, wherein the organic carbon parameter is used to characterize an index of the content of organic matter in the shale layer, and the maturity parameter is used to characterize an index of the degree of conversion of the organic matter into hydrocarbons; Based on the organic carbon parameter and the maturity parameter, a free hydrocarbon parameter in the shale formation is determined.

2. The method according to claim 1, characterized in that The step of determining the free hydrocarbon parameter in the shale layer based on the organic carbon parameter and the maturity parameter includes: Based on the maturity parameter, determining a target proportionality factor; The free hydrocarbon parameter is determined based on the target proportionality factor and the organic carbon parameter.

3. The method according to claim 2, characterized in that The step of determining the free hydrocarbon parameter based on the target proportional coefficient and the organic carbon parameter comprises: Obtaining a first regional coefficient of the region where the shale layer is located; Based on the maturity parameter, the target proportionality coefficient is obtained in the following manner: S1 / TOC=∫(Ro)+g Among them, S1 is the free hydrocarbon parameter, TOC is the organic carbon parameter, S1 / TOC is the target ratio coefficient, Ro is the maturity, and g is the first regional coefficient.

4. The method according to claim 1, characterized in that: The method of determining the organic carbon parameters in the shale layer comprises: Acquiring core data of the shale layer; Regression analysis is performed based on the core data to determine the organic carbon parameters.

5. The method according to claim 4, characterized in that The core data includes acoustic wave time difference, resistivity, compensated density, and compensated neutron, and the regression analysis based on the core data to determine the organic carbon parameter includes: Performing regression analysis based on the acoustic time difference, the resistivity, the compensated density, and the compensated neutron to determine a second regional coefficient corresponding to the acoustic time difference, a third regional coefficient corresponding to the resistivity, a fourth regional coefficient corresponding to the compensated density, and a fifth regional coefficient corresponding to the compensated neutron; The organic carbon parameter is determined based on the acoustic wave delay, the second regional coefficient, the resistivity, the third regional coefficient, the compensated density, the fourth regional coefficient, the compensated neutron, and the fifth regional coefficient.

6. The method according to claim 1, characterized in that Determining the maturity parameter in the shale formation includes: Acquiring core data of the shale layer; Determining a well temperature gradient of the shale layer based on the core data, wherein the well temperature gradient represents a rate at which the crust temperature in the shale layer changes with depth; The maturity parameter is determined based on the well temperature gradient and the detection depth.

7. The method according to claim 6, characterized in that The determining of the maturity parameter based on the well temperature gradient and the detection depth includes: Based on the well temperature gradient and the detection depth, the maturity parameter is obtained in the following manner; Ro=f*e i*depth×td Among them, Ro is the maturity, f is the predetermined sixth region coefficient, i is the predetermined seventh region coefficient, depth is the detection depth, and td is the well temperature gradient.

8. A device for determining free hydrocarbons in shale layers, characterized in that: include: A parameter acquisition module, used to determine an organic carbon parameter and a maturity parameter in the shale layer, wherein the organic carbon parameter is used to characterize an index of the content of organic matter in the shale layer, and the maturity parameter is used to characterize an index of the degree of conversion of the organic matter into hydrocarbons; A calculation module is used to determine the free hydrocarbon parameter in the shale layer based on the organic carbon parameter and the maturity parameter.

9. A non-volatile storage medium, characterized in that: The non-volatile storage medium stores a plurality of instructions, and the instructions are suitable for being loaded by a processor and executed by the method for determining free hydrocarbons in a shale layer as claimed in any one of claims 1 to 8.

10. An electronic device, characterized in that: include: One or more processors and a memory, wherein the memory is used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement the shale layer free hydrocarbon determination method as described in any one of claims 1 to 8.

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