RU2803319C1 - Method and device for predicting the amount of oil/gas reserves recoverable using in situ conversion of shale oil - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: predicting recoverable hydrocarbon reserves. The method includes building a predictive model of the amount of recoverable oil and gas as a result of in situ conversion of shale and obtaining a predicted amount of recoverable oil and gas, building a predictive model of the lower limit value of total organic carbon for productive shale and obtaining a lower limit value of total organic carbon for productive shale based on the lower limit value of the amount of recoverable oil per unit mass of rock as a result of in-situ conversion of shale and the measured vitrinite reflectance index, determination of the productive thickness of shale, the interval of productive thickness and the area of distribution of productive shale as a result of in-situ conversion of shale, building a model of the value of the prevalence of recoverable oil reserves and models the values of the prevalence of recoverable gas reserves for the productive capacity interval and obtaining the value of the prevalence of recoverable oil reserves and the value of the prevalence of recoverable gas in the productive capacity interval of the estimated well, building a predictive model for the amount of recoverable oil and gas reserves and obtaining the amount of recoverable oil and gas reserves.

EFFECT: increasing accuracy and efficiency of forecasting the amount of recoverable oil and gas reserves.

26 cl, 3 tbl, 14 dwg

Description

TECHNICAL FIELD

The present invention relates to a method and apparatus for predicting the amount of recoverable oil and gas reserves using shale in situ conversion (ICP) and relates to the technical field of oil and gas exploration and development.

BACKGROUND OF THE ART

Shale is a sedimentary rock with a high total organic carbon (TOC) content and layered bedding. When the maturity of the shale is low, that is, the vitrinite reflectance index (Ro) is less than 1.0%, the pores in the shale are not developed, fluid flow is difficult, and commercial-scale development cannot be achieved using the existing horizontal volumetric fracturing technology. well, but in situ conversion technology can be used to develop shale with low maturity. In-situ conversion technology is a technology that converts unconverted organic matter in shale into oil and gas through a local heating method, and simultaneously recovers the in-situ converted oil and gas as well as the oil and gas trapped in the shale. Shale here is a collective term for medium to low maturity oil shale, that is, oil shale with Ro less than 1.0%, including medium to low maturity oil shale and immature oil shale.

Based on preliminary studies, global recoverable reserves from shale in situ conversion are estimated to be over 1.5 trillion tons, while recoverable reserves from natural gas technology are approximately 1,300 trillion cubic meters; the amount of recoverable reserves from in-situ conversion of shale in China exceeds 80 billion tons, and the amount of recoverable reserves from natural gas exceeds 60 trillion cubic meters; This is more than three times the amount of recoverable reserves from conventional oil and natural gas, representing enormous potential.

In the prior art, there are two schemes for predicting the amount of oil and gas produced by in-situ conversion of shale with medium and low maturity, which can be used as a guide to estimate the amount of recoverable oil and gas reserves, but there is still no technology for predicting the amount of recoverable reserves as a result of in-situ conversion of shale. Firstly, based on the initial hydrogen to carbon ratio (H/C), the initial total organic carbon content (TOC) and the Ro value of the shale, the model of the amount of oil and gas generated from the initial state of the shale and the model of the amount of trapped oil and gas in the c stages are established. different values of Ro; based on the amount of oil and gas generated and the amount of trapped oil and gas, a model of the amount of oil and gas generated is established; the amount of oil and gas reserves produced as a result of in-situ conversion can be estimated by extrapolation. Secondly, based on the initial hydrogen to carbon ratio (H/C), the initial total organic carbon content (TOC) and the Ro value of the shale, the model of the amount of oil and gas generated from the initial state of the shale and the model of the amount of trapped oil and gas in the c stages are established. With different values of Ro, based on the amount of oil and gas generated and the amount of trapped oil and gas, a model of the amount of oil and gas generated is established; The volume of oil and gas reserves produced as a result of in-situ conversion can be estimated by extrapolation.

The existing two schemes for estimating the amount of oil and gas produced from shale oil with a medium and low degree of maturity in the prior art have disadvantages in predicting the amount of recoverable reserves during in-situ conversion by extrapolation: firstly, the initial ratio of hydrogen and carbon (H/ C), initial total organic carbon (TOC) and Ro value of the shale; While the shale itself has undergone a certain degree of thermal evolution and is not in its original state, it is difficult to accurately obtain the original H/C value or the original HI value and the original TOC value of the shale using existing technology, so there is a large error in the amount of oil and gas produced , which is obtained from the original H/C value or the original HI value and the original TOC value. Secondly, the amount of generated oil and gas from the original state of shale and the amount of trapped oil and gas in stages with different Ro values should be determined so as to obtain the amount of generated oil and gas based on the amount of generated oil and gas and the amount of trapped oil and gas; in the case where there is no shale in the original state and thermal modeling experiments are not carried out, the amount of oil and gas generated and the amount of trapped oil and gas cannot be accurately determined, so the amount of oil and gas produced by in-situ conversion cannot be obtained, however, the amount of oil and gas extracted from shale cannot be obtained by extrapolation either.

Therefore, it is impossible to accurately obtain the original H/C value, original HI value, original TOC value, the amount of oil and gas produced and the amount of trapped oil and gas of shale with the thermal evolution of shale to a certain extent using the existing relevant technology, and thus It is impossible to accurately study the amount of oil and gas produced from in-situ shale conversion. At the same time, the technology for estimating recoverable oil and gas reserves during in-situ shale conversion differs significantly from the existing technology, and the technology for predicting recoverable oil and gas reserves during in-situ shale conversion has not yet been developed.

Therefore, the development of a new method and apparatus for predicting the amount of recoverable oil and gas reserves from in-situ shale conversion has become a technical problem that urgently needs to be solved in this field of technology.

SUMMARY OF THE INVENTION

To overcome the disadvantages described above, one object of the present invention is to provide a method for predicting the amount of recoverable oil and gas reserves resulting from in-situ conversion of shale.

Another object of the present invention is to provide a device for predicting the amount of recoverable oil and gas reserves resulting from in-situ conversion of shale.

Another object of the present invention is to provide a computer device.

It is yet another object of the present invention to provide a computer readable storage medium. The present invention can quantitatively predict the amount of recoverable oil and gas reserves resulting from shale in-situ conversion, and improve the accuracy and efficiency of predicting the amount of recoverable oil and gas reserves from shale in-situ conversion.

To achieve the above object, in one aspect, the present invention provides a method for predicting the amount of recoverable oil and gas reserves resulting from in-situ conversion of shale, the method comprising:

obtaining the total organic carbon content and vitrinite reflectance index of the shale to be measured in the area to be assessed;

constructing a predictive model of the amount of oil recoverable from in-situ conversion of shale, and obtaining the amount of recoverable oil from shale to be measured based on the total organic carbon content and vitrinite reflectance index of the shale to be measured using the predictive model of the amount of recoverable oil from in-situ conversion of shale ;

constructing a predictive model of the amount of recoverable gas from shale in-situ conversion, and obtaining the amount of recoverable gas from shale to be measured based on the total organic carbon content and vitrinite reflectance index of the shale to be measured using the predictive model of the amount of recoverable gas from shale in-situ conversion ;

constructing a predictive model of the lower limit value of the total organic carbon content in the producing shale and obtaining a lower limit value of the total organic carbon content in the producing shale based on the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of the shale and the measured vitrinite reflectivity index of the shale, subject to measurement;

determination of the productive thickness of the shale, the productive thickness interval and the distribution area of the productive shale as a result of in-situ conversion of the shale based on the total organic carbon content in the area to be assessed, represented by the log, and the lower limit value of the total organic carbon content of the productive shale;

constructing, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval and, accordingly, obtaining the prevalence of recoverable oil reserves and the prevalence of recoverable gas reserves in the productive capacity range of the well being assessed, based on the amount of recoverable oil per unit mass of rock and the amount of gas recovered per unit mass of rock at the logging point; And

constructing, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves and obtaining the amount of recoverable oil reserves and the amount of recoverable gas reserves based on the forecast model for the amount of recoverable oil reserves and the forecast model for the amount of recoverable gas reserves.

In the method described above, preferably, building a predictive model of the amount of oil recovered as a result of in-situ conversion of shale includes:

building a model of the relationship between oil production and total organic carbon based on oil production data obtained from thermal modeling experiments on many different shale samples, as well as the total organic carbon content and vitrinite reflectance index of shale samples, and then extracting empirical parameters in the model to build a model with vitrinite reflectivity index to obtain a predictive model of the amount of oil recovered from in-situ shale conversion.

In the method described above, a predictive model of the amount of oil recovered from shale in-situ conversion is preferably established according to the following formula:

where Q _po is the measured amount of oil extracted from the shale to be measured, in mg/g⋅rock; Ro is the reflectivity index of the vitrinite shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; a1, a2, a3, a4, a5 and a6 - empirical parameters;

g⋅rock in the unit of mg/g⋅rock the quantity Q _po of oil extracted from the shale to be measured refers to the mass per g of rock.

Moreover, one skilled in the art can obtain specific numerical values of the above empirical parameters a1, a2, a3, a4, a5 and a6 according to the result of a thermal modeling experiment in the area to be evaluated.

In the method described above, preferably, building a predictive model for the amount of gas recovered from in-situ shale conversion involves:

building a model of the relationship between the amount of gas produced and the total organic carbon content based on the amount of gas produced data obtained by performing thermal modeling experiments on many different shale samples, as well as the total organic carbon content and vitrinite reflectance index of the shale samples, and then extracting empirical parameters in the model to build a model with the vitrinite reflectivity index to obtain a predictive model of the amount of gas recovered as a result of in-situ shale conversion.

In the method described above, a predictive model of the amount of gas recovered from shale in-situ conversion is preferably set according to the following formula:

where Q _pg is the measured amount of gas extracted from the shale to be measured, in m ³ /t⋅rock; Ro is the reflectivity index of the vitrinite shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; b1, b2, b3, b4, b5, b6, b7, b8, b9, b10, b11, b12, b13, b14 and b15 - empirical parameters; w1 is 0.5%-1.0%, and w2 is 1.0%-1.4%;

t⋅rock in the unit m ³ /t⋅rock quantity Q _pg of gas extracted from the shale to be measured refers to the mass per ton of rock.

Moreover, one skilled in the art can obtain specific numerical values of the above empirical parameters b1, b2, b3, b4, b5, b6, b7, b8, b9, b10, b11, b12, b13, b14 and b15 according to the result of the thermal experiment. modeling in the assessed area.

In the above method, preferably, the lower limit value of the amount of oil produced per unit mass of rock as a result of in-situ conversion of shale is obtained based on the lower limit value of the total amount of oil produced by any production group of wells in the same development area (same development area refers to a development area with similar geological conditions of in-situ conversion and similar development processes) resulting from in-situ conversion of shale and based on the rock mass of the effective heating area controlled by a group of production wells, according to the following formula:

where Q _{po_limit} is the lower limit value of the amount of oil recovered per unit mass of rock during in-situ conversion of shale, in mg/g⋅rock; Q _{oil_limit} - lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale, in mg; Wt _rock is the mass of rock in the area of effective heating controlled by a group of production wells as a result of in-situ conversion of shale, in the city.

In the method described above, preferably, building a predictive model of the lower limit value of the total organic carbon content of the producing shale includes: based on the predictive model of the amount of oil recoverable as a result of in-situ conversion of the shale and the lower limit value of the amount of oil recoverable per unit mass of rock as a result of in-situ conversion shale, building a predictive model of the lower limit value of the total organic carbon content in productive shale using the following formula:

where TOC _limt is the lower limit value of total organic carbon content in productive shale, wt. %; Q _{po_limt} - lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, in mg/g⋅rock; Ro is the reflectivity index of the vitrinite shale to be measured, in %; c1, c2, c3, c4, c5 and c6 are empirical parameters.

One skilled in the art can obtain specific numerical values of the above empirical parameters c1, c2, c3, c4, c5 and c6 in accordance with the result of a thermal modeling experiment in the area to be evaluated, the development process, development cost and the like.

In the method described above, preferably, the productive thickness of the shale, the productive thickness interval and the distribution areas of the productive shale as a result of in-situ conversion of shale are determined based on the total organic carbon content of the area to be estimated represented by the log and the lower limit value of the total organic carbon content in productive shale according to the following rules:

When the continuous thickness of a shale with total organic carbon content represented by logs greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the depth interval corresponding apparent productive capacity of shale, is the interval of apparent productive capacity; between two adjacent apparent productive thickness intervals, when the continuous thickness of a shale with total organic carbon content represented by logs less than the lower limit value of the total organic carbon content of the productive shale is less than a specified value of 0.5-5 m, the specified value is determined as 2 m , and this interval is converted into the apparent productive capacity of the shale; When the continuous thickness of a shale with total organic carbon content represented by logs less than the lower limit value of the total organic carbon content of the producing shale is greater than the specified value of 0.5-5 m, the specified value is determined as 2 m and this interval is not counted towards the apparent productive capacity of oil shale;

when the apparent productive capacity of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive capacity of the shale, the apparent productive capacity of the shale is the productive capacity of the shale, and the interval corresponding to the upper and lower value of the productive capacity of the shale is the productive capacity interval;

When the apparent productive thickness of the shale is less than or equal to the specified value of 3-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, but the apparent productive thickness of the shale cannot be used as the productive capacity of the shale and therefore cannot be used as a self-producing interval, however, the amount of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m, each productive thickness interval will be considered separately as a separate shale productive thickness interval, i.e. be considered as an independent series of development layers;

obtaining the distribution of the productive capacity of shale in the assessed area by the non-equidistant interpolation method based on the productive capacity of the shale at well points in the assessed area, while the cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km (preferably 2 km), and when the productive capacity of the shale in the assessed area there is more than the established value of 3-15 m of productive capacity, the boundary of the productive capacity of the shale distribution area is taken to be 5 m, and the area where the productive capacity of the shale exceeds 5 m is the productive shale distribution area.

One skilled in the art can calibrate the log data based on core analysis and system well analysis results, and obtain the log data of the area to be evaluated;

the set value can be determined according to the needs of in-situ conversion and geological conditions;

The non-equidistant interpolation method includes three-point method, five-point method, finite element method, Kriging method, linear interpolation method, nonlinear interpolation method, etc.

In the method described above, it is preferable to respectively create a recoverable oil reserve abundance value model and a recoverable gas reserve abundance value model in a shale producing interval, which includes:

constructing, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive shale interval depending on the amount of recoverable oil and the amount of recoverable gas of the rock in the interval of productive capacity per unit area, based on the amount of recoverable oil and gas per unit mass rock, logging spacing, rock density and productive thickness interval.

In the method described above, preferably, the oil reserve abundance value model and the gas reserve abundance value model in the producing shale interval are set, respectively, according to the following formulas:

where AOR is the value of the prevalence of recoverable oil reserves in the productive shale interval of the assessed area, in 10,000 t/km ² ; AGR is the value of the prevalence of recoverable gas reserves in the productive shale interval of the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of extracted oil per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the range of productive thickness of the assessed area, in g/cm ³ ; L _inter is the logging step of the well being evaluated, in m; n is the total number of logging points in the productive thickness interval, n is an integer.

In the method described above, the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at a logging point are preferably obtained in accordance with the following steps:

obtaining the total organic carbon content, rock density value, and measured distance between points represented by the log in a producing shale interval based on the total organic carbon content of the area to be estimated represented by the log, and then obtaining the amount of oil recoverable per unit mass of rock, and the amount of gas recoverable per unit mass of rock of a point represented by the log, in accordance with the predictive model of the amount of oil recoverable from in-situ shale conversion and in accordance with the predictive model of the amount of recoverable gas from shale in-situ conversion based on total organic carbon content, rock density value and the measured value of the distance between logging points in the productive shale interval and the vitrinite reflectivity index of the well location in the target formation.

In the above method, the oil recoverable abundance value and the gas recoverable abundance value for all well locations in the estimated area can be obtained based on the above model of recoverable oil resource abundance value and the above built model of recoverable gas reserve abundance value in the producing shale interval; Then, based on the prevalence values of recoverable oil reserves and the prevalence values of recoverable gas reserves for all well locations in the estimated area, a planar distribution of the prevalence of recoverable oil reserves and the abundance of recoverable gas reserves in the estimated area can be obtained using non-equidistant interpolation methods, such as three-point method, five-point method method, finite element method, Kriging method, linear interpolation method and nonlinear interpolation method; Based on the planar distribution, it is possible to obtain the prevalence of recoverable oil reserves of the j-th grid node in the area of productive shale distribution and the prevalence of recoverable gas reserves of the j-th grid node in the area of productive shale distribution.

In a more preferred embodiment of the present invention, the grid spacing of the non-equidistant interpolation of the three-point method, the five-point method, the finite element method, the Kriging method, the linear interpolation method, the nonlinear interpolation method, and the like. takes a preset value of 0.1-10 km, preferably 2 km.

In the method described above, preferably, based on the value of the prevalence of oil and gas reserves in the grid nodes of the oil shale distribution area and the area of the productive shale distribution area, the forecast model of the amount of recoverable oil reserves and the forecast model of the amount of recoverable gas reserves are set, respectively, according to the following formulas:

where NO is the amount of recoverable oil reserves in the assessed area, in 10,000 tons; NG - the amount of recoverable gas reserves in the assessed area, 100 million cubic meters. m; AOR _j is the value of the prevalence of recoverable oil reserves of the j-th grid node in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves of the j-th grid node in the area of distribution of productive shale, in 100 million m ³ / km ² ; Aj is the area of the j-th grid cell in the area of distribution of productive shale, in km ² ; m is the number of grid cells in the area of productive shale distribution, m is an integer.

In another aspect, the present invention further provides an apparatus for predicting the amount of recoverable oil and gas reserves resulting from in-situ shale conversion, said apparatus comprising:

a data acquisition module used to obtain the total organic carbon content and vitrinite reflectance index of the shale to be measured in the area to be assessed;

Module for building a predictive model of the amount of oil recoverable from shale in-situ conversion, used to build a predictive model of the amount of oil recoverable from in-situ conversion of shale and obtaining the amount of oil recoverable from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of oil recovered as a result of in-situ conversion of shale;

module for building a predictive model of the amount of recoverable gas from shale in-situ conversion, used to build a predictive model of the amount of recoverable gas from in-situ conversion of shale and obtaining the amount of recoverable gas from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of gas recovered as a result of in-situ shale conversion;

module for building a forecast model of the lower limit value of the total organic carbon content in the producing shale, used to build a forecast model of the lower limit value of the total organic carbon content in the producing shale and obtaining a lower limit value of the total organic carbon content in the producing shale based on the lower limit value of the amount of extractable oil per unit mass of rock as a result of in-situ conversion of shale and measured shale vitrinite reflectance index;

module for determining the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of in-situ shale conversion, used to determine the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of in-situ shale conversion based on the total organic carbon content in the area, to be estimated, represented by logging, and the lower limit value of the total organic carbon content of the producing shale;

module for constructing a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval, used to build, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval and, accordingly, obtaining the value the prevalence of recoverable oil reserves and the value of the prevalence of recoverable gas reserves in the productive capacity interval of the estimated well based on the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at the point represented by the logging; And

module for constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves, used to build, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves and obtaining the number of recoverable oil reserves and the amount of recoverable gas reserves based on the forecast models for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves.

In the apparatus described above, preferably, the module for constructing a predictive model of the amount of oil produced by in-situ conversion of shale is specifically used to build a model of the relationship between the amount of oil produced and the total organic carbon content based on the oil production amount data obtained by conducting thermal experiments. modeling on many different shale samples, as well as the total organic carbon content and vitrinite reflectance index of the shale samples, and then extracting the empirical parameters into the model to build a vitrinite reflectance index model to create a predictive model of the amount of oil recoverable from in-situ shale conversion .

In the apparatus described above, preferably, the module for constructing a predictive model of the amount of oil recoverable from in-situ conversion of shale is further used to construct a predictive model of the amount of recoverable oil from in-situ conversion of shale in accordance with the following formula:

where Q _po is the amount of oil extracted from shale to be measured, in mg/g⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; a1, a2, a3, a4, a5 and a6 are empirical parameters.

In the apparatus described above, preferably, the module for constructing a predictive model of the amount of gas produced by in-situ conversion of shale is specifically used to build a model of the relationship between the amount of gas produced and the total organic carbon content based on the gas produced amount data obtained by conducting experiments on thermal modeling on many different shale samples, as well as the total organic carbon content and vitrinite reflectivity index in the shale samples, and then extracting empirical parameters into the model to build a vitrinite reflectivity index model to build a predictive model for the amount of gas recovered due to in-situ oil shale conversion.

In the apparatus described above, preferably, the module for constructing a predictive model of the amount of gas produced by shale in-situ conversion is further used to construct a predictive model of the amount of gas recovered by shale in-situ conversion according to the following formula:

where Q _pg is the amount of gas extracted from the shale to be measured, in m ³ /t⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; b1, b2, b3, b4, b5, b6, b7, b8, b9, b10, b11, b12, b13, b14 and b15 - empirical parameters; w1 is 0.5%-1.0%, and w2 is 1.0%-1.4%.

In the above-described device, preferably, the module for constructing a predictive model of the lower limit value of the total organic carbon content in the productive shale contains a block for obtaining the lower limit value of the amount of recoverable oil per unit mass of rock as a result of in-situ conversion of shale, used to obtain the lower limit value of the amount of recoverable oil per unit mass of rock as a result of in-situ conversion of shale based on the lower limit value of the total amount of oil produced by any production group of wells in the same development area as a result of in-situ conversion of shale and rock mass of the effective heating area controlled by a group of production wells, according to the following formula:

where Q _{po_limt} is the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, in mg/g⋅rock; Q _{oil_limt} - lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale, in mg; Wt _rock is the mass of rock in the area of effective heating, controlled by a group of production wells, as a result of in-situ conversion of shale, in the city.

In the apparatus described above, the module for constructing a prediction model of the lower limit value of total organic carbon content of the producing shale is specifically used to construct a prediction model of the lower limit value of the total organic carbon content of the producing shale based on the prediction model of the amount of oil recoverable from the in-situ conversion of the shale and lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, according to the following formula:

where TOC _limt is the lower limit value of the total organic carbon content in productive shale, in wt. %; Q _{po_limt} - lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, in mg/g⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; c1, c2, c3, c4, c5 and c6 are empirical parameters.

In the apparatus described above, preferably, the module for determining the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale resulting from the in-situ conversion of shale is specifically used to determine the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of the in-situ conversion of shale on based on the total organic carbon content of the area to be assessed as represented by the log and a lower limit value for the total organic carbon content of the producing shale in accordance with the following rules:

When the continuous thickness of a shale with total organic carbon content represented by logs greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the depth interval corresponding apparent productive capacity of shale, is the interval of apparent productive capacity; between two adjacent apparent pay thickness intervals, when the continuous thickness of a shale with logged total organic carbon content less than the lower limit value of the pay shale total organic carbon content is below the specified value of 0.5-5 m, the specified value is defined as 2 m , and this interval is converted into the apparent productive capacity of the shale; When the continuous thickness of a shale with total organic carbon content represented by logs is less than the lower limit value of the total organic carbon content of the producing shale, exceeds the specified value of 0.5-5 m, the specified value is defined as 2 m, and this interval is not counted towards the apparent pay shale power;

when the apparent productive thickness of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive thickness of the shale, the apparent productive thickness of the shale is the productive thickness of the shale, and the interval corresponding to the upper and lower value of the productive thickness of the shale is the productive capacity interval;

When the apparent payable thickness of the shale is less than or equal to the set value of 3-15 m, the set value of 5 m is used as the apparent payload of the shale, however, the apparent payload of the shale cannot be used as the payload of the shale and therefore cannot be used as a self-producing interval , and the amount of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m, each productive thickness interval will be considered separately as a separate shale productive thickness interval, i.e. be considered as an independent series of development layers;

obtaining the distribution of the productive capacity of shale in the assessed area by the non-equidistant interpolation method based on the productive capacity of the shale at well points in the assessed area, while the grid cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km, and when the productive capacity of the shale in the assessed area exceeds The established value is 3-15 m of productive capacity, the value of 5 m is used as the boundary of the distribution area of the productive capacity of shale, and the area where the productive thickness of the shale exceeds 5 m is the distribution area of productive shale.

In the apparatus described above, preferably, a module for constructing a recoverable oil reserve abundance value model and a recoverable gas reserve abundance value model in the production capacity interval is specifically used to, respectively, construct a recoverable oil reserve abundance value model and a recoverable gas reserve abundance value model in the interval productive shale depending on the amount of recoverable oil and the amount of recoverable gas of the rock in the interval of productive capacity per unit area, based on the amount of recoverable oil and gas per unit mass of rock, logging spacing, rock density and interval of productive capacity.

In the apparatus described above, preferably, a module for constructing a model for the occurrence value of recoverable oil reserves and a model for the occurrence value of recoverable gas reserves in the production capacity interval is further used to construct, respectively, a model for the occurrence value of recoverable oil reserves and a model for the occurrence value of recoverable gas reserves in the interval productive shale according to the following formulas:

where AOR is the value of the prevalence of recoverable oil reserves in the productive shale interval of the assessed area, in 10,000 t/km ² ; AGR - the value of the prevalence of recoverable gas reserves in the productive shale interval of the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of extracted oil per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the range of productive thickness of the assessed area, in g/cm ³ ; L _inter is the logging step of the well being evaluated, in m; n is the total number of logging points in the productive thickness interval, n is an integer.

In the device described above, preferably, the module for constructing a model of the prevalence value of recoverable oil reserves and a model of the prevalence value of recoverable gas reserves in the range of productive capacity contains a block for obtaining the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at the point represented by logging used for:

obtaining the total organic carbon content, the rock density value, and the measured distance between points represented by the log in a producing shale interval based on the total organic carbon content of the area to be estimated represented by the log, and then obtaining the amount of recoverable oil per unit mass of rock, and amount of gas recoverable per unit mass of rock at a point represented by the log, through a predictive model of the amount of oil recoverable from in-situ shale conversion and a predictive model of the amount of recoverable gas from shale in-situ conversion based on the total organic carbon content, the rock density value and the measured value of the distance between points represented by logs in the producing shale interval and vitrinite reflectivity index at the well location in the target formation.

In the apparatus described above, preferably, a module for constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves is specifically used for,

based on the prevalence of recoverable oil and gas reserves in the cell nodes of the productive shale distribution area and the area of the productive shale distribution area, creating, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves using the formulas:

where NO is the amount of recoverable oil reserves in the assessed area, in 10,000 tons; NG - the amount of recoverable gas reserves in the assessed area, 100 million cubic meters. m; AOR _j is the value of the prevalence of recoverable oil reserves in the j-th grid cell in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves in the j-th grid cell in the area of distribution of productive shale, in 100 million m ³ / km ² ; A _j is the area of the j-th grid cell in the area of distribution of productive shale, in km ² ; m is the number of grid cells in the area of productive shale distribution, m is an integer.

In yet another aspect, the present invention further provides a computer device comprising a memory, a processor, and computer programs stored in the memory and capable of execution on the processor, wherein the processor, when executing the computer programs, implements the steps of the method described above for predicting the amount of recoverable oil and gas reserves resulting from in-situ oil shale conversion.

In yet another aspect, the present invention further provides a computer-readable storage medium on which computer programs are stored that, when executed by a processor, implement the steps of the above method for predicting the amount of oil and gas recoverable from in-situ conversion of shale.

The technical solution in accordance with the present invention provides the following useful technical results.

Firstly, based on the TOC value and Ro value of the shale to be measured, as well as the pre-built oil recovery quantity prediction model and gas recovery quantity prediction model of the shale in-situ conversion, the oil recovery quantity and gas recovery quantity of the shale to be measured are obtained , which overcomes the disadvantages of the prior art, only by obtaining the original HI or original H/S and original TOC of shale and the amount of oil and gas formed by immature shale and the amount of trapped oil and gas, the amount of recoverable oil and the amount of recoverable gas can be determined, the disadvantage , which is the low accuracy in extracting the original HI or original TOC using shales that have undergone a certain thermal evolution, and the disadvantage that only by obtaining the amount of trapped oil and gas and the amount of generated oil and gas can the amount of produced oil and gas be obtained gas, and the effect of using the current TOC and Ro of shale in the reservoir is achieved to obtain the amount of recoverable oil and the amount of recoverable gas as a result of in-situ conversion. Therefore, the present invention uses a recoverable oil amount prediction model and a recoverable gas amount prediction model of shale in-situ conversion, which not only realizes a quantitative prediction of the amount of oil and gas recoverable from shale in-situ conversion, but also improves the accuracy of predicting the amount of oil and gas recoverable from shale in situ conversion. in-situ conversion of shale.

Secondly, the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale is obtained based on the lower limit value of the total amount of oil produced by any group of production wells in the same development area (the same development area means a development area with similar geological conditions of in-situ conversion and similar development processes) as a result of in-situ conversion of shale and rock mass of the effective heating area controlled by one group of production wells, and accordingly, a predictive model of the lower limit TOC value of the producing shale is obtained to obtain the lower limit TOC value of the producing shale so that The productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale were accurately obtained, which eliminates the disadvantage that the lower limit TOC value of the productive shale cannot be determined in the prior art, as well as the disadvantage that the productive The thickness of the shale, the productive thickness interval and the distribution area of the productive shale cannot be accurately obtained.

Finally, based on the TOC value of the area to be assessed, represented by the logging, the rock density value, the measured pitch value, the analysis and the Ro analysis value (vitrinite reflectivity index at the well location in the target formation) and the productive thickness interval, as well as a pre-built predictive model the amount of recoverable oil and the forecast model of the amount of recoverable gas, the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at the logging point are obtained; based on the previously obtained model for the prevalence of recoverable oil reserves and the model for the prevalence of recoverable gas reserves, the prevalence of recoverable oil reserves and the prevalence of a recoverable gas source are obtained; Based on the distribution area of productive shale in the estimated area and the previously obtained forecast model for the amount of recoverable oil reserves and the forecast model for the amount of recoverable gas reserves, the amount of recoverable oil reserves and the amount of recoverable gas reserves are obtained, which eliminates the disadvantage that for calculating the corresponding parameters The prior art uses average parameter values, and the disadvantage of the actual situation is that the non-linear relationship between the amount of recoverable oil and gas reserves and TOC cannot be reflected using the average parameter, but is achieved by calculating for different contributions to the amount of recoverable oil reserves and gas from various TOC points in the longitudinal direction within the productive shale interval.

Thus, the solution according to the present invention can quantitatively predict the amount of recoverable oil and gas reserves resulting from shale in-situ conversion, and improve the accuracy and efficiency of predicting the amount of recoverable oil and gas reserves from shale in-situ conversion.

BRIEF DESCRIPTION OF THE DRAWINGS

Fig. 1 is a flow diagram of a method for predicting the amount of recoverable oil and gas reserves from in-situ shale conversion proposed in an embodiment of the present invention;

Fig. 2 is a chart of the relationship between thermal simulation temperature and Ro in an embodiment of the present invention;

Fig. 3 is a diagram showing the relationship between the amount of oil produced by thermal simulation and TOC in an embodiment of the present invention;

Fig. 4 is a diagram showing the relationship between the amount of generated gas obtained by thermal simulation and the TOC in an embodiment of the present invention;

Fig. 5 is a chart of the relationship between the maximum gas production amount and the maximum oil production amount obtained by thermal modeling in an embodiment of the present invention;

Fig. 6 is a chart of the relationship between the lower limit value of TOC and Ro when the lower limit value of the amount of oil produced per unit of shale is 14 mg/g in an embodiment of the present invention;

Fig. 7 is a schematic diagram when there is no intermediate layer in a shale producing interval in an embodiment of the present invention;

Fig. 8 is a schematic diagram of the presence of an intermediate layer in a shale reservoir in an embodiment of the present invention;

Fig. 9 is a TOC distribution diagram of shale in the Chang 7 ₃ area of the Ordos Basin in an embodiment of the present invention;

Fig. 10 is a distribution diagram of Ro shale in the Chang 7 ₃ area of the Ordos Basin in an embodiment of the present invention;

Fig. 11 is a chart showing the distribution of shale production capacity in the Chang 7 ₃ area of the Ordos Basin in an embodiment of the present invention;

Fig. 12 is a distribution diagram of the occurrence value of recoverable oil reserves in shale in the Chang 7 ₃ area of the Ordos Basin in an embodiment of the present invention;

Fig. 13 is a distribution diagram of the occurrence value of recoverable gas reserves in shale in the Chang 7 ₃ area of the Ordos Basin in an embodiment of the present invention; And

Fig. 14 is a block diagram of an apparatus for predicting the amount of recoverable oil and gas reserves resulting from in-situ shale conversion according to an embodiment of the present invention.

DETAILED DESCRIPTION

The technical solutions in the embodiments of the present invention are clearly and fully described below with reference to the accompanying drawings in the embodiments of the present invention. It will be appreciated that the described embodiments represent only some, and not all, embodiments of the present invention. All other embodiments obtained without creative effort by one skilled in the art based on embodiments of the present invention fall within the scope of protection of the present invention.

In-situ shale conversion technology for oil and gas development is different from existing technologies and is revolutionary. According to in-situ conversion technology, light oil and natural gas are generated and produced from unconverted organic matter and trapped oil in the reservoir through artificial heating, and in-situ conversion technology is applicable to medium and low maturity immature shale clays. The amount of recoverable oil and gas reserves from shale in-situ conversion is a key factor for in-situ conversion development and controls the benefits of in-situ conversion development. The technology for predicting recoverable oil and gas reserves resulting from in-situ conversion is clearly different from the technology currently being developed for estimating oil and gas reserves that have been generated and stored in the reservoir. Predicting the amount of recoverable oil and gas reserves from in situ conversion requires an entirely new way of thinking and estimation to meet the needs of assessing site selection for in situ conversion, exploration and development.

To overcome the lack of technology for predicting the amount of recoverable oil and gas reserves from shale in-situ conversion in the prior art, a solution for predicting the amount of recoverable oil and gas reserves from shale in-situ conversion comes to the fore. A solution for predicting the amount of recoverable oil and gas reserves from in-situ shale conversion related to embodiments of the present invention is described in detail below.

Fig. 1 is a flow chart of a method for predicting the amount of recoverable oil and gas reserves from in-situ shale conversion proposed in an embodiment of the present invention, wherein from FIG. 1 it can be seen that the method includes the following steps:

101: measurement of total organic carbon content and vitrinite reflectance index of shale;

102: Constructing a predictive model of the amount of oil recoverable from in-situ conversion of shale and obtaining the amount of oil recoverable from the shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale to be measured using the predictive model of the amount of oil recoverable from in-situ conversion of shale ;

103: Constructing a predictive model of the amount of recoverable gas from shale in-situ conversion and obtaining the amount of recoverable gas from the shale to be measured based on the total organic carbon content and vitrinite reflectance index of the shale to be measured using the predictive model of the amount of recoverable gas from in-situ shale conversion ;

104: obtaining a lower limit value of the amount of oil produced per unit mass of rock as a result of in-situ conversion of shale based on the lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale and rock mass of the effective heating area controlled by a group of production wells;

105: Constructing a predictive model of the lower limit value of total organic carbon content in the producing shale and obtaining the lower limit value of the total organic carbon content in the producing shale based on the lower limit value of the amount of oil recoverable per unit mass of rock as a result of in-situ conversion of shale and the vitrinite reflectivity index in slate to be measured;

106: obtaining the productive thickness of the shale, the productive thickness interval and the distribution area of the producing shale as a result of in-situ conversion of the shale based on the total organic carbon content of the area to be estimated represented by the log and the lower limit value of the total organic carbon content of the producing shale;

107: constructing, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval, and obtaining, respectively, the prevalence of recoverable oil reserves and the prevalence of recoverable gas reserves in the productive capacity interval of the estimated well, based on the quantity recoverable oil per unit mass of rock and amount of recoverable gas per unit mass of rock at the logging point; And

108: constructing, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves, and obtaining the amount of recoverable oil reserves and the amount of recoverable gas reserves based on the forecast model for the amount of recoverable oil reserves and the forecast model for the amount of recoverable gas reserves.

The technical solution of the embodiments of the present invention provides the following useful technical results.

Firstly, based on the TOC value and Ro value of the shale to be measured, as well as the pre-constructed oil recovery quantity prediction model and gas recovery quantity prediction model of the in-situ conversion of the shale, the oil recovery quantity and gas recovery quantity of the shale to be measured are obtained, which overcomes the shortcomings of the prior art, only by obtaining the original HI or the original H/C and the original TOC of the shale, and the amount of oil and gas formed by the immature shale, and the amount of trapped oil and gas, the amount of oil to be recovered and the amount of gas to be recovered can be determined, thereby overcoming the disadvantage is that the accuracy is low in extracting the original HI or original TOC using shale that has experienced a certain thermal evolution, and also overcomes the disadvantage that only by obtaining the amount of trapped oil and gas and the amount of generated oil and gas can the amount of produced oil and gas, while achieving the effect of using the current TOC and Ro of shale in the reservoir to obtain the amount of oil recovered and the amount of gas recovered as a result of in-situ conversion. Therefore, the present invention uses a predictive model for the amount of recoverable oil and a predictive model for the amount of recoverable gas from shale in-situ conversion, which not only realizes a quantitative prediction of the amount of oil and gas recoverable from in-situ conversion of shale, but also improves the accuracy of forecasting the amount of recoverable oil and gas as a result of in-situ conversion of shale.

Secondly, the lower limit value of the amount of oil produced per unit mass of rock as a result of in-situ conversion of shale is obtained based on the lower limit value of the total amount of oil produced by any group of production wells in the same development area as a result of in-situ conversion of shale and the rock mass of the area of effective heating controlled one group of production wells, and accordingly establish a prediction model of the lower limit value of the productive shale TOC to obtain a lower limit value of the productive shale TOC, so that the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale are obtained accurately, which eliminates the disadvantage, the disadvantage that the lower limit TOC value of the productive shale cannot be determined in the prior art, and the disadvantage that the productive thickness of the shale, the productive thickness interval and the distribution area of the productive shale cannot be accurately obtained.

Finally, based on the TOC value of the area to be evaluated represented by the logging, the rock density value, the measured interval value, the Ro value obtained from the analysis and evaluation (vitrinite reflectivity index of the well point in the target formation) and the productive thickness interval, and also preliminarily the constructed predictive model of the amount of recoverable oil and the predictive model of the amount of recoverable gas, the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock of the field, obtain logging points; based on a pre-built model of the prevalence value of recoverable oil reserves and the model of the prevalence value of a recoverable gas source, the prevalence value of recoverable oil reserves and the prevalence value of recoverable gas reserves are obtained; Based on the distribution area of productive shale in the estimated area and the pre-built forecast model of the amount of recoverable oil reserves and the forecast model of the amount of recoverable gas reserves, the amount of recoverable oil reserves and the amount of recoverable gas reserves are obtained, which eliminates the disadvantage that for calculating the corresponding parameters The prior art uses average parameter values, and the disadvantage of the actual situation is that the nonlinear relationship between the amount of oil and gas recovered and TOC cannot be reflected using an average parameter, while the calculation is achieved for different contributions of different TOC points to The amount of longitudinally recoverable oil and gas reserves within a producing shale interval.

Thus, the technical solution of an embodiment of the present invention can quantitatively predict the amount of recoverable oil and gas reserves resulting from shale in-situ conversion, and improve the accuracy and efficiency of predicting the amount of recoverable oil and gas reserves from shale in-situ conversion.

With reference to FIG. 2 - Fig. 13, all steps of the method for predicting the amount of recoverable oil and gas reserves resulting from in-situ shale conversion provided in an embodiment of the present invention are described in detail below.

I. Thermal modeling experiments were carried out on shale samples before all models were built.

Several groups of shale samples were collected from the target reservoir of the evaluation area with different TOC values and Ro value less than 0.5%. In this embodiment, these multiple groups of shale samples are shale samples collected from outcrops in the Chang 7 ₃ area of the Ordos Basin, and shale samples with different TOC and Ro less than 0.5% are in a total of 9 groups, marked as No. 1 - No. 9, while each group of shale samples was crushed to shale samples measuring 40-80 mesh, preferably 60 mesh, and completely homogeneously mixed; then each group of homogeneously mixed shale samples was divided into 11 parts, and the mass of each part of the shale samples exceeded 3 kg.

The total organic carbon content (TOC) and vitrinite reflectance index (Ro) of each group of shale samples were measured separately, and the details of the obtained experimental data are presented in Table 1 below.

The TOC of each group of shale samples was measured in accordance with the national standard GB/T 19145-2003 “Determination of total organic carbon content in sedimentary rocks”; Ro was measured according to industry standard SY/T 5124-2012, Method for Determining Vitrinite Reflectance Index in Sedimentary Rock.

All thermal simulation experiments in this embodiment use a semi-open experimental system with a set pressure of 5 MPa and different set temperatures. The thermal modeling experiment specifically includes: loading the shale sample into the reactor and repeatedly compacting the shale sample with a pressure of 20 MPa, weighing the mass of the shale sample in the reactor before modeling, and then evacuating the reactor and introducing He. The thermal simulation experiment used 11 set temperature points, namely 250°C, 300°C, 320°C, 335°C, 350°C, 360°C, 390°C, 440°C, 500°C, 540 °C and 580°C, with these set temperatures covering various stages from the beginning to the end of oil and gas production. For the first set temperature at 250°C, a programmed heating rate of 20°C/day is used until the simulation temperature becomes 200°C; between 200°C and 250°C simulation temperature, a programmed heating rate of 5°C/day is used; for set temperature points two through eleven, a programmed heating rate of 20°C/day is used until the simulation temperature reaches the temperature of one previous set temperature point from the target set temperature point; when the simulation temperature is between the temperature of one previous set temperature point from the target set temperature and the temperature of the target set temperature point, the programmed heating rate of 5°C/day is used; After the simulation temperature reaches the set temperature, the set temperature is kept constant for 10 hours, and so on until the thermal simulation of all set temperature points is completed. The hydrocarbon release pressure is set to 7 MPa, and the amount of oil and gas released during the thermal simulation is used to calculate the amount of oil and gas produced per unit mass of rock.

For each shale sample, thermal simulation experiments were carried out to simulate the oil and gas produced, respectively, at 11 set temperatures. After the completion of the simulation, the amount of oil produced and the amount of gas produced per unit mass of rock at the corresponding set temperature point were obtained based on the ratio of the amount of oil produced and the amount of gas produced obtained during collection to the mass of the shale sample before thermal simulation in the corresponding reactor, while the experimental The data are presented in Table 2. After completing the thermal simulation, the TOC and Ro of the extraction residues were measured at each set temperature point, and the experimental data are presented in Table 3.

The TOC of each group of oil and gas source rock samples was measured in accordance with the national standard GB/T 19145-2003 “Determination of total organic carbon content in sedimentary rocks”; Ro was measured according to industry standard SY/T 5124-2012, Method for Determining Vitrinite Reflectance Index in Sedimentary Rock.

The average value of Ro after thermal simulation of different shale samples at the same set temperature in a thermal simulation experiment was obtained to establish the relationship between pyrolysis simulation temperature and Ro. The amount of oil and gas produced in shale thermal simulation is related to Ro to facilitate the corresponding study of the degree of thermal evolution of shale under stratigraphic conditions, and the simulation temperature is converted into the corresponding Ro value according to the following formula 1):

in formula (1): Ro - vitrinite reflectivity index, %; T - temperature of pyrolysis simulation, °C; x1 and x2 are empirical coefficients and can be equal to 0.13797 and 0.005667, respectively.

In this embodiment, a plot of the relationship between the average Ro value after thermal simulation of different shale samples at the same set temperature and the simulated pyrolysis temperature is shown in FIG. 2.

II. Based on the data obtained from the above thermal modeling experiment, all models are built.

1. According to the oil production quantity data obtained from the above thermal modeling experiment, as well as the TOC and Ro values of shale samples, a model for estimating the oil production quantity from various shale under the corresponding TOC and Ro conditions (quantity prediction model) is preliminarily established recoverable oil as a result of in-situ conversion of shale).

The amount of oil produced from shale is related to the Ro and TOC of the shale. Based on the results of thermal modeling experiments, a model of the relationship between the amount of oil produced and TOC is built. Empirical parameters of the model are extracted to build a model with Ro. Thus, a model for estimating the amount of oil produced is constructed, as shown in the following formula (2) and Fig. 3.

where Q _po is the amount of residual oil per unit mass of shale (to be separated), in mg/g⋅rock; Ro - vitrinite reflectivity index, in%; TOC - organic carbon content, wt. %; a1, a2, a3, a4, a5 and a6 are empirical parameters, with a1 and a6 equal to 0.99892 and 0.01538, respectively; at Ro≤0.76% a2 and a3 are equal to 0.4265 and 0.7516, respectively; when 0.76%<Ro≤1.0%, a2 and a3 are equal to -0.4593 and 1.41, respectively; when Ro>0.98%, a2 and a3 are equal to -4.164 and 5.3161, respectively; at Ro≤0.77% a4 and a5 are equal to 0.068 and 1.1297, respectively; when 0.775%<Ro≤1.06%, a4 and a5 are equal to -2.6881 and 3.2629, respectively, and when Ro>1.06%, a4 and a5 are equal to -3.5488 and 4, respectively, 1449.

2. According to the gas production amount data obtained from the above thermal modeling experiment, as well as the TOC and Ro values of shale samples, a model for estimating the gas production amount of various shale under the corresponding TOC and Ro conditions (recoverable gas quantity prediction model) is preliminarily established as a result of in-situ conversion of shale).

The amount of gas produced from shale is related to the Ro and TOC of the shale. Based on the results of thermal modeling experiments, a model of the relationship between the amount of gas produced and TOC is established. The empirical parameters of the model are extracted to build a model with Ro. Thus, a model for estimating the amount of gas produced is constructed, as shown in the following formula (3) and Fig. 4.

where Q _pg is the amount of residual gas produced per unit mass of shale, in m ³ /t⋅rock; Ro - vitrinite reflectivity index, in%; TOC - organic carbon content, wt. %; b1, b2, b3, b4, b5, b6, b7, b8, b9, b10, b11, b12, b13, b14 and b15 - empirical parameters equal to, respectively, 1.0062, 0.9478, 0.5744, - 0.0997, -1.1745, 3.4118, 2.1756, 1.5235, -2.3651, -0.2334, 2.9012, -2.9174, -0.0967, 0.5035 and - 0.4776.

During a specific implementation, the solution provided by an embodiment of the present invention overcomes the disadvantage of the prior art that only by performing a simulation experiment or providing the original TOC and initial HI or initial H/C shale and obtaining the amount of oil and gas generated and the amount trapped oil and gas, it is possible to obtain the amount of produced oil and gas, and the constructed dependencies of TOC, Ro and the amount of oil and gas produced (predictive model of the amount of oil produced as a result of in-situ conversion of shale and predictive model of the amount of gas produced as a result of in-situ conversion of shale) overcome the disadvantage The prior art is that the amount of oil and gas produced from shale with different TOC and Ro cannot be estimated (predicted), so that the amount of oil produced and the amount of gas produced from shale with different TOC and Ro can be predicted accordingly.

Due to the long time required to model the amount of oil and gas produced as a result of in-situ conversion of shale, for areas without thermal modeling experiment data, formulas (3) and (4) can be used to obtain data on the amount of oil and gas produced in the result of in-situ conversion of shale in the assessed area, which is used to estimate and optimize recoverable oil and gas reserves and the “golden zone”.

III. Based on the above forecast model of the amount of oil produced as a result of in-situ conversion of shale and the forecast model of the amount of gas produced as a result of in-situ conversion of shale, a forecast model of the amount of recoverable oil reserves and a forecast model of the amount of recoverable gas reserves were built.

1. A predictive model has been constructed for the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale.

In the process of in-situ conversion development of shale, in order to develop on an economic scale, the amount of oil recovered and the amount of gas recovered per unit mass of shale must be greater than a certain lower limit value. Since there is a very good linear relationship between the maximum amount of oil recoverable and the maximum amount of gas recoverable, it is only necessary to determine the lower limit value of the recoverable oil. Fig. 5 is a diagram of the maximum recoverable oil and maximum recoverable gas in shale samples obtained from thermal simulation experiments.

When developing in-situ shale conversion on an economic scale, the lower limit value of the extracted oil per unit mass of rock as a result of in-situ conversion of shale is obtained based on the lower limit value of the total amount of oil produced by any group of production wells in the same area of development of in-situ conversion of shale and rock mass of the area of effective heating , controlled by a group of production wells according to the following formula (4):

where Q _{po_limt} is the lower limit value of the amount of oil recovered per unit mass of rock during in-situ conversion of shale, in mg/g⋅rock; Q _{oil_limt} - lower limit value of the total amount of oil produced by one group of production wells, in mg; Wt _rock is a rock massif of an area of effective heating controlled by a group of production wells in the city.

If horizontal wells are used for development, then it is assumed that the group of production wells includes 10 heating and 1 production wells; heating wells are located at a distance of 15 m from each other; horizontal well length 1200 m; the mass of rock in the area of effective heating is 708×104 tons. The lower limit value of the amount of oil produced by one group of production wells is 10×104 tons, and the lower limit value of the amount of oil recovered per unit mass of rock, calculated using the above formula (4), is 14 mg/g⋅rock.

2. A predictive model of the lower limiting TOC value as a result of in-situ conversion of shale was built.

Based on the determination of the lower limit value of the amount of recoverable oil per unit mass of rock, the lower limit value of TOC as a result of in-situ conversion of shale, corresponding to the lower limit value of the amount of recoverable oil per unit mass of rock, is derived from formula (2), and a pre-built predictive model of the lower limit value The TOC resulting from in-situ shale conversion corresponds to formula (5) presented below.

where TOC _limt is the lower limit value of total organic carbon content in productive shale, in wt. %; Q _{po_limt} - lower limit value of the amount of oil recovered per unit mass of rock during in-situ conversion of shale, in mg/g⋅rock; Ro - vitrinite reflectivity index of the shale to be measured, in %;; c1, c2, c3, c4, c5 and c6 are empirical parameters, with c1 and c4 equal to 1.0011 and 0.0154, respectively; when Ro≤0.77% c2 and c3 are equal to 0.068 and 1.1297, respectively; when 0.775%<Ro≤1.06%, c2 and c3 are equal to -2.6881 and 3.2629, respectively; when Ro>1.06%, c2 and c3 are equal to -3.5488 and 4.1449, respectively; when Ro≤0.76% c5 and c6 are equal to 0.4265 and 0.7516, respectively; when 0.76%<Ro≤1.0%, c5 and c6 are equal to -0.4593 and 1.41, respectively; when Ro>0.98% c5 and c6 are equal to -4.164 and 5.3161, respectively.

Fig. 6 is a diagram of the change in the lower limit value of the total organic carbon content in productive shales with Ro, calculated by formula (5), with a lower limit value of the amount of oil recovered per unit mass of rock equal to 14 mg/g⋅rock, with the corresponding lower limit The value of the total organic carbon content of the producing shale can be obtained according to different values of Ro, when Ro is about 0.8%, the corresponding lower limit value of the total organic carbon content of the producing shale is at least about 6%.

3. The productive thickness of the shale, the interval of productive thickness and the productive area of distribution of shale as a result of in-situ conversion of shale were determined.

The productive thickness of the shale, the productive thickness interval and the distribution of the producing shale as a result of in-situ conversion of shale are determined using the lower limit value of the total organic carbon content of the producing shale and the TOC represented by the logging, as well as the vitrinite reflectivity index according to the following rules.

When the continuous thickness of a shale with total organic carbon content represented by logs greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the thickness interval, corresponding to the apparent productive capacity of the shale, is the apparent productive capacity interval; between two adjacent intervals of apparent productive thickness, when the continuous thickness of the shale with the presented logging content of total organic carbon is less than the lower limit value of the content of total organic carbon in the productive shale is less than the established value of 0.5-5 m, the established value is determined as 2 m, and this interval converted into apparent productive capacity of shale; When the continuous thickness of a shale with total organic carbon logs reported is less than the lower limit of total organic carbon in producing shale and is greater than the specified value of 0.5-5 m, the specified value is determined to be 2 m and this interval is not counted towards the apparent productive thickness of the shale.

When the apparent productive thickness of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive thickness of the shale, and the apparent productive thickness of the shale is the productive capacity of the shale, and the interval corresponding to the upper and lower productive thickness of the shale is the productive capacity interval .

When the apparent productive thickness of the shale is less than or equal to the specified value of 3-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, but the apparent productive thickness of the shale cannot be used as the productive capacity of the shale and therefore cannot be used as independently developed interval, and the amount of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m (preferably 3 m), each productive thickness interval is considered separately as a separate shale productive thickness interval, i.e. is considered as an independent series of development layers.

Based on the productive capacity of the shale at well points in the assessment area, the distribution of the productive capacity of the shale in the assessment area is obtained using a non-equidistant interpolation method such as the three-point method, the five-point method, the finite element method, the Kriging method, the linear interpolation method and the nonlinear interpolation method, wherein The cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km (for example, 2 km), when the productive capacity of the shale in the estimated area exceeds the set value of 3-15 m of productive capacity, 5 m is used as the boundary of the distribution area of the shale productive capacity, and the area where the productive thickness of the shale is more than 5 m is the productive area of shale distribution.

Fig. 7 is a schematic diagram when there is no interlayer in the producing shale interval, and FIG. 8 is a schematic diagram of when a layer exists in a producing shale interval.

4. Forecast models of the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale were constructed.

Based on the TOC represented by the logging, the TOC value of the logging point in the producing shale interval, the rock density value and the measured distance value are obtained; Based on the Ro value of the well point in the target formation obtained by analysis and testing, the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock of the logging point are obtained by using the pre-built predictive model of the amount of recoverable oil and the predictive model of the amount of recoverable gas .

The occurrence value of recoverable oil reserves and the abundance value of recoverable gas reserves in the producing shale interval of the evaluated well are respectively obtained in accordance with the models, as shown in the following formulas (6) and (7).

where AOR is the value of the prevalence of recoverable oil reserves in the assessed area, in 10,000 t/km ² ; AGR - the value of the prevalence of recoverable gas reserves in the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of oil recovered per unit mass of rock at the i-th logging point in the productive interval, in mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the productive interval, in m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the productive interval, in g/cm ³ ; L _inter is the logging step of the well being evaluated, in m; n is the total number of logging points in the productive interval, n is an integer.

Based on the oil recoverable abundance value and the gas recoverable abundance value for all well points in the estimated area, the planar distribution of the oil recoverable abundance value and the recoverable gas reserve abundance value in the estimated area can be obtained using non-equidistant interpolation methods such as the three-point method, five-point method, finite element method, Kriging method, linear interpolation method and nonlinear interpolation method, the interpolation cell step uses a preset value of 0.1-10 km, such as 2 km.

Based on the area of the productive shale area in the evaluation area, the amount of recoverable oil reserves and the amount of recoverable gas reserves in the productive shale area of the assessment area are respectively obtained using the models as shown in Formula (8) and Formula (9).

where NO is the volume of recoverable oil reserves in the assessed area, in 10,000 tons; NG - volume of recoverable gas reserves in the assessed area, 100 million cubic meters; AOR _j is the value of the prevalence of recoverable oil reserves of the j-th cell in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves of the j-th network in the area of distribution of productive shale, in 100 million m ³ / km ² ; A _j is the area of the j-th cell in the area of distribution of productive shale, in km ² ; m is the number of grids in the area of productive shale distribution, m is an integer.

Fig. 9 is a TOC distribution diagram with TOC greater than TOC _limt obtained using TOC interpreted by logging shale from the Chang 7 ₃ area of the Ordos Basin. FIG. 9 represents the distribution area that can be developed by in-situ conversion in terms of TOC, and the higher the TOC, the greater the potential for in-situ conversion.

Fig. 10 is a Ro distribution diagram obtained from shale core analysis of the Chang 7 ₃ area of the Ordos Basin. From Fig. 9, we can see the maturity of the shale suitable for production as a result of in-situ conversion and the potential for in-situ conversion of the shale. The lower Ro, the greater the potential for in-situ conversion.

Fig. 11 is a shale yield distribution chart obtained using the method of an embodiment of the present invention for the Chang 7 ₃ shale of the Ordos Basin, where the greater the shale yield, the greater the in situ conversion potential.

Fig. 12 is a distribution chart of the oil reserve abundance value in the area of production shale obtained using the method of an embodiment of the present invention for the Chang 7 ₃ shale of the Ordos Basin, where the larger the oil reserve abundance value, the greater the recoverable oil reserve. due to in-situ conversion per unit area of shale, and the more favorable the development of in-situ conversion.

Fig. 13 is a distribution chart of the recoverable gas reserve abundance value obtained using the method of an embodiment of the present invention for the Chang 7 ₃ shale of the Ordos Basin, where the larger the gas reserve abundance value, the greater the recoverable gas reserve due to in situ conversion at unit area of shale, the more favorable the development of in-situ conversion.

The amount of recoverable oil reserves from the Chang 7 ₃ shale rock of the Ordos Basin obtained using the method of an embodiment of the present invention is 45.2 billion tons, and the amount of recoverable gas reserves is 37 trillion cubic meters.

During a specific implementation, the technical solution of an embodiment of the present invention can quantify the amount of recoverable oil reserves and the amount of recoverable gas reserves as a result of in-situ conversion of shale with different TOC and Ro.

Based on the same concept of the invention, an embodiment of the present invention further provides an apparatus for predicting the amount of recoverable oil and gas reserves from shale in situ conversion, since the principle of the problem solving apparatus is similar to the principle of a method for predicting the amount of recoverable oil and gas reserves from shale in situ conversion, implementation device may refer to the implementation of the method, and the same description will not be repeated. Fig. 14 is a block diagram of an apparatus for predicting the amount of recoverable oil and gas reserves resulting from in-situ shale conversion according to an embodiment of the present invention. As shown in FIG. 14, a device for predicting the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale includes:

a data acquisition module 1 used to obtain the total organic carbon content and the vitrinite reflectance index of the shale to be measured in the area to be assessed;

Module 2 for building a predictive model of the amount of oil recoverable from shale in-situ conversion, used to build a predictive model of the amount of oil recoverable from shale in-situ conversion and obtaining the amount of oil recoverable from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of oil recovered as a result of in-situ conversion of shale;

module 3 for constructing a predictive model of the amount of recoverable gas from shale in-situ conversion, used to build a predictive model of the amount of recoverable gas from in-situ conversion of shale and obtaining the amount of recoverable gas from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of oil recovered as a result of in-situ conversion of shale;

Module 4 for building a lower limit prediction model for shale TOC, used to build a lower limit prediction model for shale TOC, and deriving a lower limit value for shale TOC based on the lower limit. the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale and the measured reflectivity index of shale vitrinite;

module 5 to determine the productive capacity of the shale, the productive capacity interval and the area of productive shale as a result of in-situ conversion of shale, used to determine the productive capacity of the shale, the productive capacity interval and the area of productive shale as a result of in-situ conversion of shale based on the total organic carbon content in the area , subject to estimation, represented by logging, and the lower limit value of the total organic carbon content of the producing shale;

module 6 for constructing a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval, used to build, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval, respectively, obtaining the value the prevalence of recoverable oil reserves and the value of the prevalence of recoverable gas reserves in the productive capacity range of the estimated well based on the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock of the point represented by the logging; And

module 7 for constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves, used to build, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves and obtaining the amount of recoverable oil reserves and the amount of recoverable gas reserves based on a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves.

In one embodiment, the module for building a predictive model of the amount of oil produced from in situ conversion of shale is specifically used to build a model of the relationship between the amount of oil produced and the total organic carbon content based on the oil produced data obtained by performing thermal modeling experiments on many different samples. shale, as well as the total organic carbon content and vitrinite reflectance index in the shale samples, and then extract the empirical parameters into the model to build a vitrinite reflectance index model to establish a predictive model for the amount of oil recoverable from in-situ conversion of shale.

In one embodiment, the module for building a predictive model of the amount of oil recovered from shale in-situ conversion is further used to build a predictive model of the amount of oil recovered from shale in-situ conversion in accordance with the following formula:

where Q _po is the amount of oil extracted from shale to be measured, in mg/g⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; a1, a2, a3, a4, a5 and a6 are empirical parameters.

In one embodiment, the shale in-situ conversion gas recovery predictive model module is specifically used to build a model of the relationship between gas production and total organic carbon based on gas production data obtained from thermal modeling experiments on a variety of different samples. shale, as well as total organic carbon content and vitrinite reflectivity index in shale samples, and then extract the empirical parameters into the model to build a vitrinite reflectivity index model to establish a predictive model for the amount of gas recovered from in-situ conversion of shale.

In one embodiment, the module for building a predictive model of the amount of gas produced during shale in-situ conversion is further used to build a predictive model of the amount of gas recovered during shale in-situ conversion in accordance with the following formula:

where Q _pg is the amount of gas extracted from the shale to be measured, in m ³ /t⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; TOC is the total organic carbon content of the shale to be measured, in wt. %; b1, b2, b3, b4, b5, b6, b7, b8, b9, b10, b11, b12, b13, b14 and b15 - empirical parameters; w1 is 0.5%-1.0%, and w2 is 1.0%-1.4%.

In one embodiment, the module for constructing a predictive model of the lower limit value of the total organic carbon content in productive shale contains a block for obtaining a lower limit value of the amount of oil recoverable per unit mass of rock as a result of in-situ conversion of shale, used to obtain a lower limit value of the amount of oil recoverable per unit mass of rock as a result of in-situ conversion of shale based on the lower limit value of the total amount of oil produced by any group of production wells in the same development area as a result of in-situ conversion of shale and rock mass of the effective heating area controlled by a group of production wells according to the following formula:

where Q _{po_limt} is the lower limit value of the amount of oil recovered per unit mass of rock during in-situ conversion of shale, in mg/g⋅rock; Q _{oil_limt} - lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale, in mg; Wt _rock is the mass of rock in the area of effective heating controlled by a group of production wells as a result of in-situ conversion of shale, in the city.

In one embodiment, the shale TOC lower limit prediction model module is specifically used to build a shale TOC lower limit prediction model based on the shale in-situ conversion oil recovery prediction model and the lower limit value. the amount of oil recovered per unit mass of rock during in-situ conversion of shale using the following formula:

where TOG _limt is the lower limit value of the total organic carbon content in productive shale, in wt. %; Q _{po_limt} - lower limit value of the amount of oil recovered per unit mass of rock during in-situ conversion of shale, in mg/g⋅rock; Ro is the vitrinite reflectivity index of the shale to be measured, in %; c1, c2, c3, c4, c5 and c6 are empirical parameters.

In one embodiment, a module for determining shale production capacity, production capacity interval, and shale production area from shale in situ conversion is specifically used to determine shale production capacity, production capacity interval, and shale production area from shale in situ conversion based on total organic content carbon in the area to be estimated, by means of well logs, and a lower limit value for the total organic carbon content of the producing shale in accordance with the following rules:

When the continuous thickness of a shale with logged total organic carbon content greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the depth interval corresponding to the apparent shale productive capacity, is the interval of apparent productive capacity; between two adjacent intervals of apparent productive thickness, when the continuous thickness of the shale with the presented logging total organic carbon content is less than the lower limit value of the total organic carbon content of the productive shale is less than the established value of 0.5-5 m, the established value is determined as 2 m, and this interval converted into apparent productive capacity of shale; when the continuous thickness of the shale with total organic carbon content logged is less than the lower limit value of the total organic carbon content of the productive shale is greater than the established value of 0.5-5 m, the established value is determined as 2 m, and this interval is not counted towards the apparent productive thickness of the shale;

when the apparent productive capacity of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive capacity of the shale, the apparent productive capacity of the shale is the productive capacity of the shale, and the interval corresponding to the upper and lower values of the productive capacity of the shale is the productive capacity interval;

When the apparent productive thickness of the shale is less than or equal to the specified value of 3-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, however, the apparent productive thickness of the shale cannot be used as the productive capacity of the shale and therefore cannot be used as a self-producing interval, and the volume of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m, each productive thickness interval will be considered separately as a separate shale productive thickness interval, i.e. be considered as an independent series of development layers;

obtaining the distribution of the productive capacity of shale in the assessed area by the non-equidistant interpolation method based on the productive capacity of the shale at well points in the assessed area, while the cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km, and when the productive capacity of the shale in the assessed area exceeds the established the value of 3-15 m of productive thickness, 5 m is used as the boundary of the distribution area of the productive capacity of shale, and the area where the productive thickness of the shale exceeds 5 m is the distribution area of productive shale.

In one embodiment, a module for constructing a recoverable oil reserves abundance value model and a recoverable gas reserves occurrence value model in a pay interval is specifically used to, respectively, construct a recoverable oil reserves occurrence value model and a recoverable gas reserves occurrence value model in a shale pay interval depending on from the amount of recoverable oil and the amount of recoverable gas of the rock in the productive capacity interval per unit area based on the amount of oil and gas recoverable per unit mass of rock, logging spacing, rock density and productive capacity interval.

In one embodiment, the module for constructing a recoverable oil reserves abundance value model and a recoverable gas reserves occurrence value model in a pay interval is further used to respectively build a recoverable oil reserves occurrence value model and a recoverable gas reserves occurrence value model in a shale pay interval using the following formulas:

where AOR is the value of the prevalence of recoverable oil reserves in the interval of productive shale of the assessed area, in 10,000 t/km ² ; AGR - the value of the prevalence of recoverable gas reserves in the interval of productive shale of the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of extracted oil per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, in m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the range of productive thickness of the assessed area, in g/cm ³ ; L _inter is the logging step of the well being evaluated, in m; n is the total number of logging points in the productive thickness interval, n is an integer.

In one embodiment, the module for constructing a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval contains a block for obtaining the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at a logging point, used for:

obtaining the total organic carbon content, rock density value, and measured distance between logging points in a producing shale interval based on the total organic carbon content of the area to be estimated represented by the log, and then obtaining the amount of oil recoverable per unit mass of rock and the amount of gas recoverable per unit mass of rock, logging points based on a predictive model of the amount of oil recoverable from in-situ shale conversion and a predictive model of the amount of gas recovered from in-situ shale conversion based on total organic carbon content, rock density value and measured distance between logging points in the producing shale interval and vitrinite reflectivity index of a well point in the target formation.

In one embodiment, a module for building a predictive model for the amount of recoverable oil reserves and a predictive model for the amount of recoverable gas reserves is specifically used to,

based on the prevalence of recoverable oil and gas reserves in the cell nodes of the area of distribution of productive shale and the area of the area of distribution of productive shale, respectively, constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves using the formulas:

where NO is the amount of recoverable oil reserves in the assessed area, in 10,000 tons; NG - volume of recoverable gas reserves in the assessed area, 100 million cubic meters. m; AOR _j is the value of the prevalence of recoverable oil reserves of the j-th cell in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves of the j-th cell in the area of distribution of productive shale, in 100 million m ³ / km ² ; A _j is the area of the j-th cell in the area of distribution of productive shale, in km ² ; m is the number of grids in the area of productive shale distribution, m is an integer.

What is described above is only a specific embodiment of the present invention and cannot be used to limit the scope of the invention. Therefore, substitution of equivalent components or equivalent changes and modifications within the scope of the patent of the present invention will still fall within the scope of this patent. Moreover, in the present invention, technical features and technical features, technical features and technical aspects, and technical aspects and technical aspects can be freely combined for use.

Claims (127)

1. A method for predicting the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale, including: obtaining the total organic carbon content and vitrinite reflectance index of the shale to be measured in the area to be assessed; constructing a predictive model of the amount of oil recoverable from in-situ conversion of shale, and obtaining the amount of recoverable oil from shale to be measured based on the total organic carbon content and vitrinite reflectance index of the shale to be measured using the predictive model of the amount of recoverable oil from in-situ conversion of shale ; constructing a predictive model of the amount of recoverable gas from shale in-situ conversion, and obtaining the amount of recoverable gas from shale to be measured based on the total organic carbon content and vitrinite reflectance index of the shale to be measured using the predictive model of the amount of recoverable gas from shale in-situ conversion ; constructing a predictive model of the lower limit value of the total organic carbon content in the producing shale and obtaining a lower limit value of the total organic carbon content in the producing shale based on the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of the shale and the measured vitrinite reflectivity index of the shale, subject to measurement; determining the productive thickness of the shale, the productive thickness interval and the distribution area of the producing shale as a result of in-situ conversion of the shale based on the total organic carbon content in the area to be assessed, represented by the log, and the lower limit value of the total organic carbon content of the producing shale; constructing, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval and, accordingly, obtaining the prevalence of recoverable oil reserves and the prevalence of recoverable gas reserves in the productive capacity range of the well being assessed, based on the amount of recoverable oil per unit mass of rock and the amount of gas recovered per unit mass of rock at the logging point; And constructing, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves and obtaining the amount of recoverable oil reserves and the amount of recoverable gas reserves based on the forecast model for the amount of recoverable oil reserves and the forecast model for the amount of recoverable gas reserves. 2. The method according to claim 1, in which when constructing a predictive model of the amount of oil recovered as a result of in-situ conversion of shale, a model of the relationship between the amount of oil produced and the total organic carbon content is established based on data on the amount of oil produced obtained as a result of experiments on thermal modeling on many different shale samples, as well as the total organic carbon content and vitrinite reflectance index of the shale samples, and then extract the empirical parameters in the model to build a vitrinite reflectance index model to obtain a predictive model of the amount of oil recoverable from in-situ shale conversion . 3. The method according to claim 2, in which the predictive model of the amount of oil recovered as a result of in-situ conversion of shale is established in accordance with the following formula: , where Q _po is the measured amount of oil extracted from the shale to be measured, mg/g⋅rock; Ro is the reflectivity index of vitrinite shale to be measured, %; TOC is the total organic carbon content in the shale to be measured, wt.%; a ₁ , a ₂ , a ₃ , a ₄ , a ₅ and a ₆ are empirical parameters. 4. The method according to claim 1, in which when constructing a predictive model of the amount of gas extracted as a result of in-situ conversion of shale, a model of the relationship between the amount of gas produced and the total organic carbon content is established based on data on the amount of gas produced obtained by conducting thermal experiments simulation on many different shale samples, as well as the total organic carbon content and vitrinite reflectivity index of the shale samples, and then extract the empirical parameters in the model to build a vitrinite reflectance index model to obtain a predictive model for the amount of gas recovered from in-situ shale conversion. 5. The method according to claim 4, in which the predictive model of the amount of gas recovered as a result of in-situ conversion of shale is established in accordance with the following formula: , where Q _pg is the measured amount of gas extracted from the shale to be measured, m ³ /t⋅rock; Ro is the reflectivity index of vitrinite shale to be measured, %; TOC is the total organic carbon content in the shale to be measured, wt.%; b ₁ , b ₂ , b ₃ , b ₄ , b ₅ , b ₆ , b ₇ , b ₈ , b ₉ , b ₁₀ , b ₁₁ , b 12, b ₁₃ , b ₁₄ and _{b 15 -} empirical parameters; w ₁ is 0.5-1.0%, aw ₂ is 1.0-1.4%. 6. The method according to claim 1, in which the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale is obtained based on the lower limit value of the total amount of oil produced by any production group of wells in the same development area as a result of in-situ conversion shale and based on the rock mass of the area of effective heating, controlled by a group of production wells, according to the following formula: , where Q _{po_lim t} is the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, mg/g⋅rock; Q _{oil_lim t} - lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale, mg; Wt _rock is the mass of rock in the area of effective heating controlled by a group of production wells as a result of in-situ conversion of shale, g. 7. The method according to claim 1 or 6, in which when constructing a predictive model, the lower limit value of the total organic carbon content in the productive shale is established, based on the predictive model, of the amount of oil recovered as a result of in-situ conversion of shale and the lower limit value of the amount of oil recovered per unit mass rocks as a result of in-situ conversion of shale, a predictive model of the lower limit value of the total organic carbon content in productive shale using the following formula: , where TOC _{lim t} is the lower limit value of total organic carbon content in productive shale, wt. %; Q _{po_lim t} - lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, mg/g⋅rock; Ro is the reflectivity index of vitrinite shale to be measured, %; c ₁ , c ₂ , c ₃ , c ₄ , c ₅ and c ₆ - empirical parameters. 8. The method according to claim 1 or 7, in which the productive thickness of the shale, the productive thickness interval and the distribution area of the productive shale as a result of in-situ conversion of the shale are determined based on the total organic carbon content in the area to be estimated, represented by the logging, and the lower limit value of the content total organic carbon in productive shale according to the following rules: When the continuous thickness of a shale with total organic carbon content represented by logs greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the depth interval corresponding apparent productive capacity of shale, is the interval of apparent productive capacity; between two adjacent apparent productive thickness intervals, when the continuous thickness of a shale with total organic carbon content represented by logs less than the lower limit value of the total organic carbon content of the productive shale is less than the specified value of 0.5-5 m, the specified value is determined as 2 m and this interval is converted into the apparent productive capacity of the shale; When the continuous thickness of a shale with total organic carbon content represented by logs less than the lower limit value of total organic carbon content in the producing shale is greater than the established value of 0.5-5 m, the established value is determined as 2 m and this interval is not counted towards the apparent pay shale power; when the apparent productive capacity of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive capacity of the shale, the apparent productive capacity of the shale is the productive capacity of the shale, and the interval corresponding to the upper and lower value of the productive capacity of the shale is the productive capacity interval; When the apparent productive thickness of the shale is less than or equal to the specified value of 3-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, but the apparent productive thickness of the shale cannot be used as the productive capacity of the shale and therefore cannot be used as a self-producing interval, however, the amount of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m, each productive thickness interval will be considered separately as a separate shale productive thickness interval, i.e. be considered as an independent series of development layers; obtain the distribution of the productive capacity of shale in the assessed area by the non-equidistant interpolation method based on the productive capacity of the shale at well points in the assessed area, while the cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km, and when the productive capacity of the shale in the assessed area is greater than the established values of 3-15 m of productive capacity, the boundary of the productive capacity of the shale distribution area is taken to be 5 m, and the area where the productive capacity of the shale exceeds 5 m is the area of distribution of productive shale. 9. The method according to claim 1, in which, when constructing, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive shale interval, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive shale interval are established, respectively. interval of productive shale depending on the amount of recoverable oil and the amount of recoverable gas of the rock in the interval of productive thickness per unit area, based on the amount of recoverable oil and gas per unit mass of rock, logging spacing, density of the rock and interval of productive thickness. 10. The method according to claim 9, in which the model of the occurrence value of recoverable oil reserves and the model of the occurrence value of recoverable gas reserves in the producing shale interval are set, respectively, according to the following formulas: , where AOR is the value of the prevalence of recoverable oil reserves in the productive shale interval of the assessed area, in 10,000 t/km ² ; AGR - the value of the prevalence of recoverable gas reserves in the productive shale interval of the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of extracted oil per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the productive thickness range of the assessed area, g/cm ³ ; L _inter is the logging step of the well being evaluated, m; n is the total number of logging points in the productive thickness interval, n is an integer. 11. Method according to any one of paragraphs. 1, 9 or 10, wherein the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at a logging point are obtained in accordance with the following steps: obtaining the total organic carbon content, rock density value, and measured distance between points represented by the log in a producing shale interval based on the total organic carbon content of the area to be estimated represented by the log, and then obtaining the amount of oil recoverable per unit mass of rock, and amount of recoverable gas per unit mass of rock of the point represented by the log, in accordance with the predictive model of the amount of oil recoverable from in-situ shale conversion and in accordance with the predictive model of the amount of recoverable gas from shale in-situ conversion based on total organic carbon content, rock density value and the measured value of the distance between logging points in the productive shale interval and the vitrinite reflectivity index of the well location in the target formation. 12. The method according to claim 1, in which, based on the value of the prevalence of recoverable oil and gas reserves in the grid nodes of the area of distribution of productive shale and the area of the area of distribution of productive shale, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves are established, respectively, according to the following formulas: , , where NO is the amount of recoverable oil reserves in the assessed area, in 10,000 tons; NG is the amount of recoverable gas reserves in the assessed area, in 100 million ^m3 ; AOR _j is the value of the prevalence of recoverable oil reserves of the j-th grid node in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves of the j-th grid node in the area of distribution of productive shale, in 100 million m ³ / km ² ; A _j is the area of the j-th grid cell in the area of distribution of productive shale, km ² ; m is the number of grid cells in the area of productive shale distribution, m is an integer. 13. A device for predicting the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale, containing: a data acquisition module used to obtain the total organic carbon content and vitrinite reflectance index of the shale to be measured in the area to be assessed; module for building a predictive model of the amount of oil recoverable from in-situ conversion of shale, used to build a predictive model of the amount of oil recoverable from in-situ conversion of shale and obtaining the amount of oil recoverable from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of oil recovered as a result of in-situ conversion of shale; Module for building a predictive model of the amount of recoverable gas from shale in-situ conversion, used to build a predictive model of the amount of recoverable gas from in-situ conversion of shale and obtaining the amount of recoverable gas from shale to be measured based on the total organic carbon content and the vitrinite reflectance index of the shale , to be measured using a predictive model of the amount of gas recovered as a result of in-situ shale conversion; Module for building a forecast model of the lower limit value of total organic carbon in the producing shale, used to build a forecast model of the lower limit value of the total organic carbon content in the producing shale and obtaining a lower limit value of the total organic carbon content in the producing shale based on the lower limit value of the amount of extractable oil per unit mass of rock as a result of in-situ conversion of shale and measured shale vitrinite reflectance index; module for determining the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of in-situ shale conversion, used to determine the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of the in-situ conversion of shale based on the total organic carbon content in the area, subject to estimation, represented by logging, and the lower limit value of the total organic carbon content of the producing shale; module for constructing a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval, used to build, respectively, a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval and, accordingly, obtaining the value the prevalence of recoverable oil reserves and the prevalence of recoverable gas reserves in the productive capacity interval of the estimated well based on the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at the logging point; And module for constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves, used to build, respectively, a forecast model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves and obtaining the number of recoverable oil reserves and the amount of recoverable gas reserves based on the forecast a model for the amount of recoverable oil reserves and a forecast model for the amount of recoverable gas reserves. 14. The device according to claim 13, in which the module for building a predictive model of the amount of oil produced as a result of in-situ conversion of shale is specifically used to build a model of the relationship between the amount of oil produced and the total organic carbon content based on the data on the amount of oil produced obtained through experiments. by thermal modeling on many different shale samples, as well as the total organic carbon content and vitrinite reflectivity index of the shale samples, and then extracting the empirical parameters into the model to build a vitrinite reflectivity index model to create a predictive model of the amount of oil recoverable from in-situ oil shale conversion. 15. The device according to claim 14, in which the module for building a predictive model of the amount of oil recovered as a result of in-situ conversion of shale is additionally used to build a predictive model of the amount of oil recovered as a result of in-situ conversion of shale in accordance with the following formula: , where Q _po is the amount of oil extracted from shale to be measured, mg/g⋅rock; Ro - vitrinite reflectivity index of the shale to be measured, %; TOC - total organic carbon content in the shale to be measured, wt.%; a ₁ , a ₂ , a ₃ , a ₄ , a ₅ and a ₆ are empirical parameters. 16. The apparatus of claim 13, wherein the module for constructing a predictive model of the amount of gas produced as a result of in-situ conversion of shale is specifically used to build a model of the relationship between the amount of gas produced and the total organic carbon content based on the data on the amount of gas produced obtained by thermal modeling experiments on many different shale samples, as well as the total organic carbon content and vitrinite reflectivity index in the shale samples, and then extracting the empirical parameters into the model to build a model with the vitrinite reflectance index to build a predictive model for the amount of gas recoverable in as a result of in-situ conversion of shale. 17. The device according to claim 16, in which the module for building a predictive model of the amount of gas to be recovered as a result of in-situ conversion of shale is further used to build a predictive model of the amount of gas to be recovered as a result of in-situ conversion of shale in accordance with the following formula: , where Q _pg is the amount of gas extracted from the shale to be measured, m ³ /t⋅rock; Ro - vitrinite reflectivity index of the shale to be measured, %; TOC - total organic carbon content in the shale to be measured, wt.%; b ₁ , b ₂ , b ₃ , b ₄ , b ₅ , b ₆ , b ₇ , b ₈ , b ₉ , b ₁₀ , b ₁₁ , b 12, b ₁₃ , b ₁₄ and _{b 15 -} empirical parameters; w ₁ is 0.5-1.0%, aw ₂ is 1.0-1.4%. 18. The device according to claim 13, in which the module for constructing a predictive model of the lower limit value of the total organic carbon content in productive shale contains a block for obtaining the lower limit value of the amount of extracted oil per unit mass of rock as a result of in-situ conversion of shale, used to obtain the lower limit value the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale based on the lower limit value of the total amount of oil produced by any production group of wells in the same development area as a result of in-situ conversion of shale and rock mass of the effective heating area controlled by a group of production wells, according to following formula: , where Q _{po_lim t} is the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, mg/g⋅rock; Q _{oil_lim t} - lower limit value of the total amount of oil produced by one group of production wells as a result of in-situ conversion of shale, mg; Wt _rock is the mass of rock in the area of effective heating controlled by a group of production wells as a result of in-situ conversion of shale, g. 19. The apparatus of claim 13 or 18, wherein the module for building a lower limit TOC prediction model of a shale reservoir is specifically used to construct a lower limit TOC prediction model for a shale reservoir based on a recoverable oil quantity prediction model as a result of in-situ conversion of shale and the lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, according to the following formula: , where TOC _{lim t} is the lower limit value of the total organic carbon content in productive shale, wt.%; Q _{po_lim t} - lower limit value of the amount of oil recovered per unit mass of rock as a result of in-situ conversion of shale, mg/g⋅rock; Ro - vitrinite reflectivity index of the shale to be measured, %; c ₁ , c ₂ , c ₃ , c ₄ , c ₅ and c ₆ - empirical parameters. 20. The apparatus of claim 13, wherein the module for determining the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of in-situ conversion of shale is specifically used to determine the productive capacity of the shale, the productive capacity interval and the distribution area of the productive shale as a result of in-situ conversion shale based on the total organic carbon content of the area to be assessed as represented by the log and a lower limit value of the total organic carbon content of the producing shale in accordance with the following rules: When the continuous thickness of a shale with total organic carbon content represented by logs greater than the lower limit value of the total organic carbon content of the producing shale exceeds the specified value of 1-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, and the depth interval corresponding apparent productive capacity of shale, is the interval of apparent productive capacity; between two adjacent apparent pay thickness intervals, when the continuous thickness of a shale with logged total organic carbon content less than the lower limit value of the pay shale total organic carbon content is below the specified value of 0.5-5 m, the specified value is defined as 2 m and this interval is converted into the apparent productive capacity of the shale; When the continuous thickness of a shale with log-represented total organic carbon content less than the lower limit of total organic carbon content of the producing shale exceeds the specified value of 0.5-5 m, the specified value is defined as 2 m and this interval is not counted towards the apparent productive thickness slate; when the apparent productive thickness of the shale exceeds the set value of 3-15 m, the set value of 5 m is used as the apparent productive thickness of the shale, the apparent productive thickness of the shale is the productive thickness of the shale, and the interval corresponding to the upper and lower value of the productive thickness of the shale is the productive capacity interval; When the apparent productive thickness of the shale is less than or equal to the specified value of 3-15 m, the specified value of 5 m is used as the apparent productive thickness of the shale, however, the apparent productive thickness of the shale cannot be used as the productive capacity of the shale and therefore cannot be used as a self-producing interval, and the amount of recoverable reserves for this interval is not calculated; When the longitudinal distance between two or more productive thickness intervals exceeds the specified thickness value of 0.5-5 m, each productive thickness interval will be considered separately as a separate shale productive thickness interval, i.e. be considered as an independent series of development layers; obtaining the distribution area of the productive capacity of shale in the assessed area by the non-equidistant interpolation method based on the productive capacity of the shale at well points in the assessed area, while the grid cell step of the non-equidistant interpolation method uses a set value of 0.1-10 km, and when the productive capacity of the shale in the assessed area exceeds the established value of 3-15 m of productive thickness, the value of 5 m is used as the boundary of the distribution area of the productive thickness of shale, and the area where the productive thickness of the shale exceeds 5 m is the distribution area of productive shale. 21. The device according to claim 13, wherein the module for constructing a model of the occurrence value of recoverable oil reserves and the model of the occurrence value of recoverable gas reserves in the production capacity interval is specifically used for, respectively, constructing a model of the occurrence value of oil reserves and a model of the occurrence value of recoverable gas reserves in the productive shale interval, depending on the amount of oil recoverable and the amount of gas recoverable in the rock in the productive capacity interval per unit area, based on the amount of oil and gas recoverable per unit mass of rock, logging spacing, rock density and productive capacity interval. 22. The device according to claim 21, in which the module for constructing a model of the prevalence value of recoverable oil reserves and a model of the prevalence value of recoverable gas reserves in the productive capacity interval is additionally used to build, respectively, a model of the prevalence value of oil reserves and a model of the prevalence value of recoverable gas reserves in the productive shale interval using the following formulas: , , where AOR is the value of the prevalence of recoverable oil reserves in the productive shale interval of the assessed area, in 10,000 t/km ² ; AGR - the value of the prevalence of recoverable gas reserves in the productive shale interval of the assessed area, 100 million m ³ / km ² ; Q _{po_i} is the amount of extracted oil per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, mg/g⋅rock; Q _{pg_i} is the amount of extracted gas per unit mass of rock at the i-th logging point in the range of productive capacity of the assessed area, m ³ /t⋅rock; ρ _i is the value of rock density at the i-th logging point in the productive thickness range of the assessed area, g/cm ³ ; L _inter is the logging step of the well being evaluated, m; n is the total number of logging points in the productive thickness interval, n is an integer. 23. The device according to any one of paragraphs. 13, 21 and 22, in which the module for constructing a model for the prevalence of recoverable oil reserves and a model for the prevalence of recoverable gas reserves in the productive capacity interval contains a block for obtaining the amount of recoverable oil per unit mass of rock and the amount of recoverable gas per unit mass of rock at a logging point, used for obtaining the total organic carbon content, rock density value, and measured distance between logging points in a producing shale interval based on the total organic carbon content of the area to be estimated represented by the log, and then obtaining the amount of oil recoverable per unit mass of rock and the amount of gas recoverable per unit mass of rock at a logging point through a predictive model of the amount of oil recoverable from in-situ shale conversion and a predictive model of the amount of gas recovered from in-situ shale conversion based on total organic carbon content, rock density value and measured distance between logging points in the producing shale interval and vitrinite reflectivity index at the well location in the target formation. 24. The apparatus of claim 13, wherein the module for constructing a forecast model for the amount of recoverable oil reserves and a forecast model for the quantity of recoverable gas reserves is specifically used to create, respectively, a forecast model for the quantity of recoverable oil reserves and a forecast model for the quantity of recoverable gas reserves based on the abundance value recoverable oil and gas reserves in the cell nodes of the area of distribution of productive shale and the area of the area of distribution of productive shale according to the formulas: , , where NO is the amount of recoverable oil reserves in the assessed area, in 10,000 tons; NG - the amount of recoverable gas reserves in the assessed area, 100 million cubic meters. m; AOR _j is the value of the prevalence of recoverable oil reserves in the j-th grid cell in the area of distribution of productive shale, in 10,000 t/km ² ; AGR _j is the value of the prevalence of recoverable gas reserves in the j-th grid cell in the area of distribution of productive shale, in 100 million m ³ / km ² ; A _j is the area of the j-th grid cell in the area of distribution of productive shale, km ² ; m is the number of grid cells in the area of distribution of productive shale, m is an integer. 25. A computer device containing memory, a processor and computer programs that are stored in memory and can be executed by the processor, wherein the processor, when executing said computer programs, implements the steps of a method for predicting the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale according to any one of claims. 1-12. 26. A machine-readable storage medium on which computer programs are stored, which, when executed by a processor, implement the steps of a method for predicting the amount of recoverable oil and gas reserves as a result of in-situ conversion of shale according to any one of paragraphs. 1-12.