Evaluation method and equipment for shale in-situ conversion recoverable oil and gas resource quantity and favorable area

Abstract

The invention provides a shale in-situ conversion recoverable oil and gas resource quantity and favorable area evaluation method and equipment, and belongs to the field of shale oil and gas exploration and development. The evaluation method comprises the following steps: according to thermal simulation experiment data of a shale sample, taking influence of total organic carbon content, vitrinite reflectivity, retention oil and gas quantity, crude oil density, fluid pressure and organic matter type on oil and gas ratio in produced oil and gas as control factors, and establishing a unit mass shale in-situ conversion produced oil and gas quantity prediction model; determining an oil recovery equivalent lower limit value and an oil recovery equivalent lower limit value of rock per unit mass; determining a favorable interval according to the lower limit value of the oil recovery equivalent and the oil and gas output amount of the rock per unit mass; determining the quantity abundance of recoverable oil and gas resources according to the favorable interval; and determining a favorable area according to the abundance and the lower limit value of the recoverable oil and gas resource quantity. According to the method provided by the invention, a universal evaluation basis can be provided for evaluating the quantity of exploitable oil and gas resources developed by in-situ conversion of immature-medium and low-maturity shale and selecting areas.

Description

Technical Field

[0001] This invention relates to the field of shale oil and gas exploration and development, specifically to a method for evaluating the recoverable oil and gas resources from in-situ shale conversion, a method for evaluating favorable development areas from in-situ shale conversion, a device for evaluating the recoverable oil and gas resources from in-situ shale conversion, a device for evaluating favorable development areas from in-situ shale conversion, an electronic device, and a computer-readable storage medium. Background Technology

[0002] Immature to low-maturity shale oil and gas resources are abundant and represent a strategic area for future oil and gas exploration and development. However, due to the low degree of thermal evolution in immature to low-maturity shale, the proportion of convertible organic matter in the shale that can be converted into oil and gas is low, with most existing in a solid state. Organic pores are underdeveloped, and the gas-oil ratio is low, making large-scale development impossible with existing horizontal well volumetric fracturing technology. In-situ conversion technology is an effective technique for the efficient exploitation of oil and gas in immature to low-maturity shale. The recoverable oil and gas resources from in-situ conversion in immature to low-maturity shale are fundamental to development; therefore, accurate evaluation of the recoverable oil and gas resources from in-situ conversion in immature to low-maturity shale is crucial for selecting favorable areas.

[0003] Laboratory thermal simulation is the most common and important method for assessing the recoverable oil and gas resources from in-situ conversion of immature to low-maturity shale. In laboratory simulation experiments, the samples are heated relatively uniformly, and all convertible organic matter in the shale can be completely converted during the thermal simulation experiment to evaluate the recoverable oil and gas reserves from in-situ conversion. However, there are significant differences between in-situ shale conversion in the field and laboratory in-situ conversion heating. When evaluating the recoverable resources from in-situ shale conversion, the following influencing factors should be considered:

[0004] (1) The influence of shale organic matter abundance or total organic carbon content, thermal evolution degree or vitrinite reflectance on the amount of oil and gas produced by in-situ conversion of shale;

[0005] (2) During the in-situ conversion and heating of shale underground, the temperature of shale gradually decreases from the heating well to the production well due to factors such as the heterogeneity of rock minerals and composition and differences in heat conduction. Even if the shale lithology is relatively homogeneous, the amount of hydrocarbon generated per unit mass of shale varies due to different temperatures at different locations, and the amount of oil and gas produced also varies. Therefore, it is necessary to consider the influence of heating temperature or the corresponding organic matter vitrinite reflectance on the produced oil and gas.

[0006] (3) Due to the different degrees of thermal evolution of shale in in-situ transformation, there are convertible solid organic matter and oil and gas that have been generated and retained in the shale. These organic matter contribute to the amount of oil and gas produced during the in-situ transformation process.

[0007] (4) Differences in burial depth and / or in-situ conversion development conditions result in differences in fluid pressure in shale in-situ conversion strata, which affects the amount of oil and gas produced.

[0008] (5) The properties and / or density of the retained oil have an impact on the amount of oil and gas produced by in-situ conversion;

[0009] (6) The type of organic matter has an impact on the oil-to-gas ratio (or gas-to-oil ratio) in the produced oil and gas.

[0010] Therefore, to accurately assess the recoverable oil and gas resources in shale in-situ conversion, it is necessary to consider controlling factors such as shale organic matter abundance, organic matter type, thermal evolution degree, amount of retained oil and gas and density of retained oil, and fluid pressure during in-situ conversion. This will facilitate the establishment of a more accurate evaluation method for recoverable oil and gas resources in shale in-situ conversion, and provide technical support for the selection, evaluation, and development of in-situ conversion areas for immature to low-maturity shale.

[0011] However, existing technologies for evaluating the amount of oil and gas produced and / or the recoverable oil and gas resources from in-situ shale conversion mainly consider the influence of factors such as the total organic carbon content of shale, vitrinite reflectance, heating rate, and temperature. For example, Chinese patent document filed on July 15, 2020, with application number 202010678399.4, proposes a method and apparatus for predicting the recoverable oil and gas resources from in-situ shale conversion. This prediction method uses the total organic carbon content of shale and vitrinite reflectance to establish a predictive model for recoverable oil and gas resources. Chinese patent document filed on March 2, 2018, with application number 201810174445.X, proposes a method and apparatus for determining the amount of oil and gas produced from in-situ shale oil conversion. This determination method uses the total organic carbon content of shale, vitrinite reflectance, and HC parameters to establish an evaluation model for the amount of oil and gas produced from in-situ conversion. These evaluation methods are applicable to assessing the amount of oil and gas produced (or recoverable oil and gas resources) from the in-situ conversion of shale in the target layer in the study area, but they are not universally applicable. If these evaluation methods are extended to the amount of oil and gas produced (or recoverable oil and gas resources) from the in-situ conversion of shale in non-thermal simulation experimental study areas, their evaluation accuracy will be limited. Furthermore, these evaluation methods do not consider factors such as the amount of oil and gas retained during the in-situ conversion process, the properties of retained oil (such as crude oil density), fluid pressure, and the type of organic matter on the oil-to-gas ratio (or gas-to-oil ratio) in the produced oil and gas, which will also limit the evaluation accuracy.

[0012] In summary, it is necessary to provide a method for evaluating recoverable oil and gas resources in shale in-situ conversion that simultaneously considers factors such as total organic carbon content of shale, degree of thermal evolution or vitrinite reflectivity, amount of retained oil and gas, properties of retained oil (such as crude oil density), fluid pressure, and the influence of organic matter type on the oil-to-gas ratio or gas-to-oil ratio in the produced oil and gas. Summary of the Invention

[0013] To address the technical problem that existing methods for evaluating recoverable oil and gas reserves from shale in-situ conversion consider few control factors, thus limiting the accuracy of such evaluations, this invention provides a method for evaluating recoverable oil and gas reserves from shale in-situ conversion. This method enables the establishment of a universally applicable evaluation model for recoverable oil and gas reserves from shale in-situ conversion, suitable for accurate evaluation in areas where in-situ conversion thermal simulation experiments have been conducted or not. Furthermore, this invention also provides a method for evaluating favorable development zones in shale in-situ conversion. This method can identify favorable sections for shale in-situ conversion, providing technical support for shale in-situ conversion development.

[0014] To achieve the above objectives, the first aspect of the present invention provides a method for evaluating the recoverable oil and gas resources from in-situ shale conversion. This method includes the following steps: acquiring thermal simulation experimental data of shale in-situ conversion under different fluid pressure conditions, thermal simulation experimental data of crude oil in-situ conversion under different hydrocarbon expulsion pressure conditions, and Fischer analysis experimental data of shale under different degrees of thermal evolution. The thermal simulation experimental data of shale in-situ conversion includes: total organic carbon content, vitrinite reflectance, thermal simulation produced oil and gas volume, and retained oil and gas volume. The thermal simulation experimental data of crude oil in-situ conversion includes: crude oil density, the proportion of produced oil to the original thermal simulation oil volume, and the gas produced per unit mass of thermal simulation oil. The Fischer analysis experimental data of shale includes: the amount of oil and gas generated per unit of total organic carbon content. Based on shale in-situ conversion thermal simulation experimental data under different fluid pressure conditions and shale Fischer analysis experimental data under different thermal evolution degrees, a prediction model for shale in-situ conversion oil and gas production is constructed; based on shale in-situ conversion thermal simulation experimental data under predetermined fluid pressure conditions, a prediction model for retained oil and gas production is constructed; based on crude oil in-situ conversion thermal simulation experimental data under different hydrocarbon expulsion pressure conditions, a prediction model for crude oil in-situ conversion oil and gas production is constructed; based on the shale in-situ conversion oil and gas production prediction model, the retained oil and gas production prediction model, and the crude oil in-situ conversion oil and gas production prediction model, a prediction model for shale in-situ conversion oil and gas production per unit mass is constructed; based on the shale in-situ conversion oil and gas production prediction model per unit mass, the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated are determined.

[0015] In an exemplary embodiment of the present invention, the construction of a shale in-situ conversion oil and gas production prediction model based on shale in-situ conversion thermal simulation experimental data under different fluid pressure conditions and shale Fischer analysis experimental data under different thermal evolution degrees may include: constructing a cumulative oil and gas production prediction model based on shale in-situ conversion thermal simulation experimental data under predetermined fluid pressure conditions; constructing a fluid pressure correction model for oil and gas production based on shale in-situ conversion thermal simulation experimental data under different fluid pressure conditions; constructing a generated oil and gas production prediction model based on shale Fischer analysis experimental data under different thermal evolution degrees; and constructing a shale in-situ conversion oil and gas production prediction model based on the cumulative oil and gas production prediction model, the fluid pressure correction model for oil and gas production, and the generated oil and gas production prediction model.

[0016] In an exemplary embodiment of the present invention, the construction of a cumulative oil and gas production prediction model based on shale in-situ conversion thermal simulation experimental data under predetermined fluid pressure conditions may include: using total organic carbon content and vitrinite reflectance as dual independent variables, and the cumulative oil and gas production from shale in-situ conversion under predetermined fluid pressure conditions as the dependent variable, and obtaining the cumulative oil and gas production prediction model by fitting.

[0017] In an exemplary embodiment of the present invention, the cumulative oil and gas production prediction model may include: a calculation expression for the cumulative oil production from in-situ shale conversion and a calculation expression for the cumulative gas production from in-situ shale conversion;

[0018] The following formula can be used to fit the cumulative oil production calculation expression of shale in-situ conversion:

[0019]

[0020] The following formula can be used to fit the cumulative gas production calculation expression of shale in-situ conversion:

[0021]

[0022] Among them, Q po The cumulative oil production from in-situ shale conversion before correction, in mg / g rock; Q pg The cumulative gas production from in-situ shale conversion before correction is ml / g rock; TOC is total organic carbon content, wt%; R oα is the vitrinite reflectance, %; a1 is the first empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a2 is the second empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a3 is the third empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a4 is the fourth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a5 is the fifth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a6 is the sixth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a7 is the seventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a8 is the eighth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a9 is the ninth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 10 a is the tenth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 11 This is the eleventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a 12 a is the twelfth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 13 This is the thirteenth empirical coefficient of the cumulative oil and gas production prediction model, and it is dimensionless.

[0023] In an exemplary embodiment of the present invention, the step of constructing a fluid pressure correction model for the amount of oil and gas produced based on shale in-situ conversion thermal simulation experimental data under different fluid pressure conditions may include: calculating the ratio of the thermally simulated oil and gas production under different fluid pressure conditions to the thermally simulated oil and gas production under predetermined fluid pressure conditions, and determining the ratio as the fluid pressure correction coefficient for the amount of oil and gas produced under different fluid pressure conditions; using different fluid pressures as independent variables and the fluid pressure correction coefficient for the amount of oil and gas produced under different fluid pressure conditions as dependent variables, and obtaining the fluid pressure correction model for the amount of oil and gas produced by fitting.

[0024] In an exemplary embodiment of the present invention, the fluid pressure correction model for the amount of oil and gas produced may include: a correction expression for the amount of oil produced by fluid pressure and a correction expression for the amount of gas produced by fluid pressure;

[0025] The corrected expression for fluid pressure on oil production can be obtained by fitting the following formula:

[0026]

[0027] The corrected expression for fluid pressure versus output gas volume can be obtained by fitting the following formula:

[0028] PR gas =c3P1+c4,

[0029] Among them, PR oil The fluid pressure correction factor for oil production is dimensionless; PR gasc1 is the fluid pressure correction coefficient for the produced gas volume, dimensionless; P1 is the fluid pressure, MPa; c1 is the first empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c2 is the second empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c3 is the third empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c4 is the fourth empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless.

[0030] In an exemplary embodiment of the present invention, the construction of a prediction model for the amount of oil and gas generated based on shale Fischer analysis experimental data under different thermal evolution degrees may include: using vitrinite reflectance as the independent variable and the amount of oil and gas generated per unit of total organic carbon content as the dependent variable, and obtaining the prediction model for the amount of oil and gas generated through fitting.

[0031] In an exemplary embodiment of the present invention, the oil and gas generation prediction model may include: an oil generation calculation expression and a gas generation calculation expression;

[0032] The formula for calculating the amount of oil produced can be fitted using the following formula:

[0033]

[0034] The formula for calculating the generated gas volume can be obtained by fitting the following formula:

[0035]

[0036] Among them, Q FAOT Q represents the amount of oil produced per unit of total organic carbon, expressed in mg / g TOC. FAGT The amount of gas generated per unit of total organic carbon content, ml / g.TOC; R o d1 is the vitrinite reflectance, %; d2 is the first empirical coefficient of the oil and gas generation prediction model, dimensionless; d3 is the third empirical coefficient of the oil and gas generation prediction model, dimensionless; d4 is the fourth empirical coefficient of the oil and gas generation prediction model, dimensionless; d5 is the fifth empirical coefficient of the oil and gas generation prediction model, dimensionless; d6 is the sixth empirical coefficient of the oil and gas generation prediction model, dimensionless.

[0037] In an exemplary embodiment of the present invention, the shale in-situ conversion oil and gas production prediction model may include: a correction expression for the cumulative oil production from shale in-situ conversion and a correction expression for the cumulative gas production from shale in-situ conversion;

[0038] A corrected expression for the cumulative oil production from in-situ shale conversion can be constructed using the following formula:

[0039]

[0040] A corrected expression for the cumulative gas production from in-situ shale conversion can be constructed using the following formula:

[0041]

[0042] Among them, Q poc For the corrected cumulative oil production from in-situ shale conversion, mg / g rock; PR oil The fluid pressure correction factor for oil production is dimensionless. To evaluate the amount of oil produced per unit of total organic carbon (TOC) in shale samples from the target layer, the value is expressed as mg / g.TOC. The amount of oil produced per unit of total organic carbon (TOC) of shale samples used in the in-situ shale conversion heat simulation experiment, in mg / g.TOC; Q po The cumulative oil production from in-situ shale conversion before correction, in mg / g rock; Q pgc The revised cumulative gas production from in-situ shale conversion, in ml / g rock; PR gas The fluid pressure correction factor for the output gas volume is dimensionless. To evaluate the amount of gas generated per unit of total organic carbon (TOC) in shale samples from the target layer, expressed as ml / g.TOC; The amount of gas generated per unit of total organic carbon (TOC) of shale samples used in the shale in-situ conversion heat simulation experiment, in ml / g.TOC; Q pg The cumulative gas production from in-situ shale conversion before correction is expressed in ml / g.rock.

[0043] In an exemplary embodiment of the present invention, the crude oil in-situ conversion oil and gas production prediction model may include: an expression for calculating the proportion of oil produced to the original oil consumption in the thermal simulation and an expression for calculating the gas production per unit mass of thermal simulation oil.

[0044] The crude oil in-situ conversion heat simulation experimental data based on different hydrocarbon expulsion pressure conditions, used to construct a predictive model for crude oil and gas production from in-situ conversion, may include:

[0045] Using hydrocarbon discharge pressure and crude oil density as the two independent variables and the proportion of produced oil to the original oil consumption in the thermal simulation as the dependent variable, the expression for calculating the proportion of produced oil to the original oil consumption in the thermal simulation is obtained by fitting.

[0046] Using hydrocarbon discharge pressure and crude oil density as the two independent variables and the gas production per unit mass of thermally simulated oil as the dependent variable, a calculation expression for the gas production per unit mass of thermally simulated oil was obtained through fitting.

[0047] In an exemplary embodiment of the present invention, the expression for calculating the proportion of produced oil to the original oil consumption in the heat simulation can be obtained by fitting the following formula:

[0048]

[0049] The following formula can be used to fit and obtain the expression for calculating the gas output per unit mass of thermal simulation oil:

[0050]

[0051] Among them, R oil RQ represents the percentage of oil produced relative to the original oil consumption in the thermal simulation. gas P1 represents the gas production per unit mass of thermal simulation oil, in ml / g.oil; P2 represents the hydrocarbon discharge pressure, in MPa; ρ o Crude oil density for thermal simulation, g / cm³ 3 f1 is the first empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f2 is the second empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f3 is the third empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f4 is the fourth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f5 is the fifth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f6 is the sixth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless.

[0052] In an exemplary embodiment of the present invention, constructing a prediction model for the amount of retained oil and gas based on shale in-situ conversion heat simulation experimental data under predetermined fluid pressure conditions may include:

[0053] Using total organic carbon content and vitrinite reflectance as the two independent variables, and the amount of retained oil and gas under predetermined fluid pressure conditions as the dependent variable, a prediction model for the amount of retained oil and gas was obtained through fitting.

[0054] In an exemplary embodiment of the present invention, the prediction model for retained oil and gas volume may include: a calculation expression for retained oil volume in shale and a calculation expression for retained gas volume in shale;

[0055] The following formula can be used to fit the expression for calculating shale oil retention:

[0056]

[0057] The following formula can be used to fit the expression for calculating shale gas retention:

[0058]

[0059] Among them, Q ro Q represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. rgThe value represents the amount of gas trapped per unit mass of shale, in ml / g rock; TOC represents the total organic carbon content, in wt%; R o ρ is the vitrinite reflectance, %; b1 is the first empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b2 is the second empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b3 is the third empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b4 is the fourth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b5 is the fifth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b6 is the sixth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b7 is the seventh empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b8 is the eighth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b9 is the ninth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b 10 The tenth empirical coefficient of the residual oil and gas volume prediction model is dimensionless.

[0060] In an exemplary embodiment of the present invention, the prediction model for oil and gas production per unit mass of shale in-situ conversion may include: an expression for calculating oil production per unit mass of shale in-situ conversion and an expression for calculating gas production per unit mass of shale in-situ conversion;

[0061] The following formula can be used to construct an expression for calculating the oil yield per unit mass of shale in-situ conversion:

[0062] Q oil =Q poc +Q ro ×R oil ,

[0063] The following formula can be used to construct an expression for calculating the gas production per unit mass of shale in-situ conversion:

[0064] Q gas =Q pgc +Q ro ×RQ gas +Q rg ,

[0065] Among them, Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. poc For the corrected cumulative oil production from in-situ conversion, mg / g rock; Q ro R represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. oil The fraction representing the proportion of oil produced to the original oil consumption in the thermal simulation; Q gas Q represents the in-situ gas production per unit mass of shale through conversion, expressed in ml / g rock. pgc The corrected cumulative in-situ conversion gas yield, ml / g rock; RQ gasQ represents the gas production per unit mass of thermal simulation oil, expressed in ml / g.oil. rg The amount of gas trapped per unit mass of shale is expressed in ml / g rock.

[0066] The second aspect of this invention provides a method for evaluating favorable areas for in-situ shale conversion and development. The evaluation method includes the following steps: determining the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer using the evaluation method described above; determining the lower limit of recoverable oil equivalent per unit mass of shale based on shale in-situ conversion and development parameter values; the shale in-situ conversion and development parameter values ​​include: the average fixed investment, average operating cost, average taxes and fees, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commercialization rate of the development well group or development unit during the in-situ conversion production cycle; comparing the lower limit of recoverable oil equivalent per unit mass of shale with the recoverable oil and gas resources per unit mass of shale in-situ conversion; and identifying areas where the recoverable oil equivalent per unit mass of shale is greater than the lower limit of recoverable oil equivalent per unit mass of shale as favorable zones for in-situ conversion and development.

[0067] In another exemplary embodiment of the present invention, determining the lower limit of recoverable oil equivalent per unit mass of shale based on shale in-situ conversion and development parameter values ​​may include: determining the economic lower limit of recoverable oil equivalent for development well groups or development units based on shale in-situ conversion and development parameter values; and determining the lower limit of recoverable oil equivalent per unit mass of shale based on the effective heated shale volume, shale density, and economic lower limit of recoverable oil equivalent for development well groups or development units.

[0068] In another exemplary embodiment of the present invention, the economic lower limit of recoverable oil equivalent for a development well group or development unit can be determined according to the following formula:

[0069]

[0070] The lower limit of recoverable oil equivalent per unit mass of shale can be determined using the following formula:

[0071]

[0072] Among them, EUR_BOE cutoff The economic lower limit of recoverable oil equivalent for a development well group or development unit, 10 4 t; Capex is the lower bound of the rate of return on investment for a development well group or development unit in year i, expressed as a fraction. i $Opex is the average fixed investment for a development well group or development unit in year i. i $Dct represents the average operating cost of a development well group or development unit in year i.i $;SC represents the average abandonment cost of a development well group or development unit in year i. i $Rf represents the average sunk cost of a development well group or development unit in year i. i $; CR is the average reclamation cost for a development well group or development unit in year i. oil_i P represents the average commercialization rate of oil produced by a development well group or development unit in year i, expressed as a fraction. oil_i The average selling price of oil produced by a development well group or development unit in year i, $ / 10 4 t; Tax oil_i The average tax rate per unit of oil produced by a development well group or development unit in year i, $ / 10 4 t; CR gas_i P represents the average, fractional, rate of commercialization of natural gas produced by a development well group or development unit in year i. gas_i The average selling price of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; Tax gas_i The average tax rate per unit of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; n represents the production time of a development well group or development unit, in years; Q BOE_cutoff The recoverable oil equivalent per unit mass of shale is the lower limit, mg / g rock; V rock The effective heated shale volume controlled by a development well group or development unit, in m 3 ;ρ rock To effectively heat shale density, g / cm³ 3 .

[0073] In another exemplary embodiment of the present invention, the evaluation method may further include the following steps: determining the abundance of recoverable oil and gas resources based on favorable in-situ conversion development intervals and recoverable oil and gas resources per unit mass of shale; comparing the economic lower limit of recoverable oil equivalent of development well groups or development units with the abundance of recoverable oil and gas resources; and determining the area where the abundance of recoverable oil and gas resources is greater than or equal to the economic lower limit of recoverable oil equivalent of development well groups or development units as favorable areas for in-situ shale conversion development.

[0074] In another exemplary embodiment of the present invention, the abundance of recoverable oil and gas resources can be determined according to the following formula:

[0075] AOR=10 -7 O oil ×H shale ×ρ shale ,

[0076] AGR=10-8 O gas ×H shale ×ρ shale ,

[0077] Where AOR represents recoverable oil resource abundance, 10 4 t / km 2 AGR represents recoverable gas resource abundance, 10 8 m 3 / km 2 Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. gas The in-situ gas production from shale conversion per unit mass, expressed as ml / g rock; H shale The shale depth of the favorable in-situ transformation zone is in km; ρ shale Shale density in favorable in-situ transformation zones, g / cm³ 3 .

[0078] A third aspect of this invention provides an evaluation device for the recoverable oil and gas resources generated from in-situ shale conversion. The evaluation device includes: an acquisition module for acquiring in-situ thermal simulation experimental data of shale conversion under different fluid pressure conditions, in-situ thermal simulation experimental data of crude oil conversion under different hydrocarbon expulsion pressure conditions, and Fischer analysis experimental data of shale under different thermal evolution degrees; the shale in-situ thermal simulation experimental data includes: total organic carbon content, vitrinite reflectance, thermal simulation produced oil and gas volume, and retained oil and gas volume; the crude oil in-situ thermal simulation experimental data includes: crude oil density, the proportion of produced oil to the original thermal simulation oil volume, and the produced gas volume per unit mass of thermal simulation oil; the shale Fischer analysis experimental data includes: the generated oil and gas volume per unit of total organic carbon content; and a first construction module for acquiring in-situ shale conversion data under different fluid pressure conditions. The system employs three main modules: a first module to construct a predictive model for the amount of oil and gas produced from shale in-situ conversion, and a second module to construct a predictive model for the amount of oil and gas retained in shale based on in-situ conversion heat simulation data under predetermined fluid pressure conditions. A third module is used to construct a predictive model for the amount of oil and gas produced from crude oil in-situ conversion based on in-situ conversion heat simulation data under different hydrocarbon expulsion pressure conditions. A fourth module is used to construct a predictive model for the amount of oil and gas produced per unit mass of shale in-situ conversion, based on the shale in-situ conversion oil and gas production prediction model, the retained oil and gas production prediction model, and the crude oil in-situ conversion oil and gas production prediction model. A final determination module is used to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated, based on the predictive model for the amount of oil and gas produced per unit mass of shale in-situ conversion.

[0079] A fourth aspect of the present invention provides an evaluation device for favorable areas of shale in-situ conversion development. The evaluation device includes: a second determining module for determining the recoverable oil and gas resources per unit mass of shale in-situ converted using the evaluation method for recoverable oil and gas resources of shale in-situ converted as described above; a third determining module for determining a lower limit of recoverable oil equivalent per unit mass of shale based on shale in-situ conversion development parameter values, wherein the shale in-situ conversion development parameter values ​​include: the average fixed investment, average operating cost, average taxes and fees, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commercialization rate of the development well group or development unit during the in-situ conversion production cycle; a comparison module for comparing the lower limit of recoverable oil equivalent per unit mass of shale with the recoverable oil and gas resources per unit mass of shale in-situ converted; and a fourth determining module for determining areas where the recoverable oil equivalent per unit mass of shale is greater than the lower limit of recoverable oil equivalent per unit mass of shale as favorable in-situ conversion development zones.

[0080] The fifth aspect of the present invention provides an electronic device comprising a processor and a memory, the memory storing at least one computer program, the at least one computer program being loaded and executed by one or more processors to cause the processors to perform the evaluation method for recoverable oil and gas resources in shale in-situ conversion as described above, or the evaluation method for favorable development areas of shale in-situ conversion as described above.

[0081] The sixth aspect of the present invention provides a computer-readable storage medium storing at least one piece of program code, which is loaded and executed by a processor to enable a computer to perform the evaluation method for recoverable oil and gas resources in shale in-situ conversion as described above, or the evaluation method for favorable development areas of shale in-situ conversion as described above.

[0082] The present invention has at least the following technical effects through the technical solution provided by the present invention:

[0083] (1) The evaluation method for recoverable oil and gas resources in shale in situ conversion of the present invention comprehensively considers the influence of total organic carbon content, vitrinite reflectance, amount of retained oil and gas, properties of retained oil (or crude oil density), fluid pressure, and organic matter type on the oil-gas ratio (or gas-oil ratio) in the produced oil and gas, and establishes an evaluation model for recoverable oil and gas resources in shale in situ conversion, which can effectively improve the prediction accuracy of recoverable oil and gas resources in shale in situ conversion;

[0084] (2) The method for evaluating recoverable oil and gas resources in shale in-situ conversion of the present invention has universality and can be applied to the accurate evaluation of recoverable resources in shale in-situ conversion in areas where in-situ conversion thermal simulation experiments have been carried out or not.

[0085] (3) The evaluation method of the favorable area for in-situ conversion and development of shale in this invention can quickly determine the favorable development section of the target layer to be evaluated, and can provide technical support for in-situ conversion and development of shale.

[0086] Other features and advantages of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0087] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0088] Figure 1 A flowchart illustrating the method for evaluating recoverable oil and gas resources from in-situ shale conversion provided in this embodiment of the invention;

[0089] Figure 2 This is a schematic diagram of the process for constructing a shale in-situ conversion oil and gas production prediction model provided in an embodiment of the present invention;

[0090] Figure 3 A schematic diagram of the curve of oil and gas production as a function of fluid pressure, provided for an embodiment of the present invention;

[0091] Figure 4 A flowchart illustrating an evaluation method for favorable areas of in-situ shale conversion and development provided in an embodiment of the present invention;

[0092] Figure 5 A flowchart illustrating another method for evaluating favorable areas for in-situ shale conversion and development, provided in an embodiment of the present invention;

[0093] Figure 6 A flowchart illustrating a method for evaluating recoverable oil and gas resources and favorable development areas in in-situ shale conversion, provided as an embodiment of the present invention.

[0094] Figure 7 A recoverable oil equivalent abundance distribution map of the immature to low-maturity shale at the bottom of the second member of the Nenjiang Formation in the Songliao Basin, provided for an embodiment of the present invention.

[0095] Figure 8 A map showing the distribution of favorable areas for the immature to low-maturity shale at the bottom of the second member of the Nenjiang Formation in the Songliao Basin, provided in an embodiment of the present invention.

[0096] Figure 9 This is a schematic diagram of the structure of the shale in-situ conversion recoverable oil and gas resource evaluation device provided in an embodiment of the present invention;

[0097] Figure 10 This is a schematic diagram of the structure of the evaluation device for favorable areas of in-situ shale conversion and development provided in an embodiment of the present invention;

[0098] Figure 11 This is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention.

[0099] Explanation of reference numerals in the attached figures

[0100] 101-Acquisition module, 102-First construction module, 103-Second construction module, 104-Third construction module, 105-Fourth construction module, 106-First determination module, 201-Second determination module, 202-Third determination module, 203-Comparison module, 204-Fourth determination module, 301-Processor, 302-Memory. Detailed Implementation

[0101] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0102] It should be noted that, in the absence of conflict, the embodiments of the present invention and the features in the embodiments may be combined with each other.

[0103] In this invention, terms such as "first" and "second" are used merely for ease of description and distinction, and should not be construed as indicating or implying relative importance.

[0104] In the description of this invention, it should also be noted that, unless otherwise explicitly specified and limited, the terms "installation," "connection," etc., should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integrated connection; they can refer to a direct connection or an indirect connection; they can refer to a wired connection or a wireless connection. Those skilled in the art can understand the specific meaning of the above terms in this invention according to the specific circumstances.

[0105] In existing technologies, after conducting shale thermal simulation experiments, an evaluation model for in-situ conversion of oil and gas production can be established using parameters such as total organic carbon content, vitrinite reflectance, and heating rate of shale. This model can then be used to obtain the in-situ conversion oil and gas production (or recoverable oil and gas resources) of the target shale layer in the study area. While these methods can obtain recoverable oil and gas resources from in-situ shale conversion, the evaluation results are only applicable to shale samples corresponding to the thermal simulation experiments and lack universality. For study areas where thermal simulation experiments have not been conducted, the evaluation models for in-situ conversion of oil and gas production obtained by the above methods are not suitable for calculating the recoverable oil and gas resources from in-situ shale conversion in non-thermal simulation experiment study areas. Furthermore, the above methods do not consider the influence of control factors such as the amount of retained oil and gas, the properties of retained oil (such as crude oil density), fluid pressure, and organic matter type on the oil-to-gas ratio or gas-to-oil ratio in the produced oil and gas, thus limiting the accuracy of recoverable oil and gas resource evaluation.

[0106] To address the limitation on the accuracy of recoverable oil and gas resource assessment in existing shale in-situ conversion methods due to the limited number of control factors considered, this invention provides a method for evaluating recoverable oil and gas resources in shale in-situ conversion. This method simultaneously considers factors such as total organic carbon content, thermal evolution degree (or vitrinite reflectance), amount of retained oil and gas, properties of retained oil (e.g., crude oil density), fluid pressure, and the influence of organic matter type on the oil-to-gas ratio or gas-to-oil ratio in the produced oil and gas, establishing a universally applicable evaluation model for recoverable oil and gas resources in shale in-situ conversion. Furthermore, this invention also provides a method for evaluating favorable development areas in shale in-situ conversion. Based on the results obtained from the shale in-situ conversion recoverable oil and gas resource assessment model, this method proposes a shale in-situ conversion site selection technique, providing technical support for shale in-situ conversion development. Compared to existing methods for evaluating recoverable oil and gas resources in shale in-situ conversion, this invention improves the accuracy of predicting recoverable oil and gas resources in shale in-situ conversion. In practice, the above method can be executed by an electronic device, which can be a server, terminal, or other device with processing capabilities.

[0107] The technical solution of the present invention will now be described in detail with reference to the accompanying drawings and embodiments. The following specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments.

[0108] like Figure 1 As shown in the figure, this invention provides a method for evaluating the recoverable oil and gas resources from in-situ shale conversion. The evaluation method includes the following steps:

[0109] Step S101: Obtain shale in-situ conversion heat simulation experimental data under different fluid pressure conditions, crude oil in-situ conversion heat simulation experimental data under different hydrocarbon expulsion pressure conditions, and shale Fischer analysis experimental data under different thermal evolution degrees.

[0110] It should be noted here that the shale in-situ transformation thermal simulation experiment refers to an experiment used to simulate the in-situ transformation process of shale under high temperature and high pressure conditions underground. In this experiment, a high-temperature and high-pressure reactor or an experimental device simulating underground rock layers is typically used to simulate geological conditions. At the start of the thermal simulation experiment, the shale sample is placed under high temperature and high pressure conditions, and an appropriate catalyst or activator is added. Then, by heating the sample and applying pressure, the temperature and pressure conditions in the underground rock are simulated. Under such conditions, the organic matter in the shale may undergo pyrolysis, cracking, and transformation, producing hydrocarbons and other hydrocarbons. In this embodiment, the data from the shale in-situ transformation thermal simulation experiment should at least include the total organic carbon content, vitrinite reflectance, thermally simulated oil and gas production (including thermally simulated oil and gas production), and retained oil and gas production (including retained oil and gas production).

[0111] In-situ crude oil conversion thermal simulation experiment refers to an experiment used to evaluate the contribution of residual oil in shale to the production of oil and gas from in-situ shale conversion. In this experiment, after all convertible organic matter in the shale sample has been converted, crude oil is usually mixed with the sample residue in a certain proportion, and then the sample residue is heated and pressure is applied. In this embodiment, the data from the crude oil in-situ conversion thermal simulation experiment should at least include the crude oil density, the proportion of produced oil to the original amount of oil used in the thermal simulation, and the amount of gas produced per unit mass of thermal simulation oil.

[0112] The Fischer assay for shale oil is a method used to assess the potential yield and quality of shale oil. In this assay, shale samples are heated to high temperatures, typically between 500°C and 600°C, under anaerobic conditions. During this process, the organic matter in the shale decomposes, releasing gaseous and liquid products. By collecting and analyzing these released gaseous and liquid products, the hydrocarbon content, hydrocarbon composition, calorific value, and other key parameters of the shale can be assessed. In this embodiment, the Fischer assay data should include at least the amount of oil and gas generated per unit of total organic carbon content.

[0113] Step S102: Based on the experimental data of shale in-situ conversion thermal simulation under different fluid pressure conditions and the experimental data of shale Fischer analysis under different thermal evolution degrees, a prediction model for the amount of oil and gas produced by shale in-situ conversion is constructed.

[0114] Step S103: Based on the experimental data of shale in-situ conversion heat simulation under predetermined fluid pressure conditions, construct a prediction model for the amount of retained oil and gas.

[0115] Step S104: Based on the experimental data of in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions, construct a prediction model for the amount of oil and gas produced by in-situ conversion of crude oil.

[0116] Step S105: Based on the shale in-situ conversion oil and gas production prediction model, the retained oil and gas production prediction model, and the crude oil in-situ conversion oil and gas production prediction model, construct a unit mass shale in-situ conversion oil and gas production prediction model.

[0117] Step S106: Based on the prediction model of oil and gas production per unit mass of shale in-situ conversion, determine the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated.

[0118] Thus, by analyzing various experimental data from shale samples, a model for evaluating the recoverable oil and gas resources from in-situ shale conversion can be constructed (i.e., the prediction model for the amount of oil and gas produced per unit mass of shale from in-situ conversion obtained in step 6) under the premise of considering factors such as the total organic carbon content of shale, the degree of thermal evolution (or vitrinite reflectance), the amount of retained oil and gas, the properties of retained oil (such as crude oil density), fluid pressure, and the influence of organic matter type on the oil-to-gas ratio or gas-to-oil ratio in the produced oil and gas. This model can be applied to the recoverable oil and gas resources from in-situ conversion of shale in the development area where the shale sample is located, as well as to the recoverable oil and gas resources from in-situ conversion of shale in development areas with similar lithology to the shale sample but where thermal simulation experiments have not yet been conducted.

[0119] Furthermore, in one possible implementation, such as Figure 2 As shown, in step S102, the process of constructing a prediction model for the amount of oil and gas produced by the in-situ conversion of shale based on experimental data of in-situ thermal simulation of shale under different fluid pressure conditions and experimental data of shale Fischer analysis under different thermal evolution degrees may include, but is not limited to, the following sub-steps S1021 to S1024.

[0120] In step S1021, based on the experimental data of shale in-situ conversion heat simulation under predetermined fluid pressure conditions, a prediction model for cumulative oil and gas production is constructed.

[0121] Specifically, under predetermined fluid pressure conditions, in-situ thermal simulation experiments of shale transformation at different thermal simulation temperatures are conducted on different shale samples to obtain the simulated oil and gas production of different shale samples at different thermal simulation temperatures. By analyzing the variation patterns among the total organic carbon content, vitrinite reflectance, and simulated oil and gas production of different shale samples, a cumulative oil and gas production prediction model can be constructed.

[0122] In step S1022, based on the experimental data of shale in-situ conversion heat simulation under different fluid pressure conditions, a fluid pressure correction model for the amount of oil and gas produced is constructed.

[0123] Specifically, changes in fluid pressure have a significant controlling effect on the amount of oil and gas produced from in-situ shale conversion, such as... Figure 3 As shown, under the same conditions, the oil production decreases and the gas production increases with increasing fluid pressure. Therefore, the influence of fluid pressure must be considered when evaluating the oil and gas production from the in-situ conversion of shale solid organic matter.

[0124] Based on this, by conducting in-situ thermal simulation experiments on different shale samples at the same thermal simulation temperature under different fluid pressure conditions, the simulated oil and gas production of different shale samples under different fluid pressures can be obtained. By analyzing the variation law between different fluid pressures and the simulated oil and gas production, a fluid pressure correction model for the oil and gas production can be constructed.

[0125] In step S1023, a prediction model for oil and gas production is constructed based on experimental data from shale Fischer analysis under different thermal evolution conditions.

[0126] Specifically, since the degree of thermal evolution or vitrinite reflectance has a certain impact on the amount of hydrocarbons generated from in-situ conversion of shale, Fischer analysis experiments on shale samples under different degrees of thermal evolution can be conducted to obtain the amount of hydrocarbons generated per unit of total organic carbon under different degrees of thermal evolution. By analyzing the variation patterns between the vitrinite reflectance of shale samples and the amount of hydrocarbons generated per unit of total organic carbon, a hydrocarbon generation prediction model can be constructed.

[0127] In step S1024, based on the cumulative oil and gas production prediction model, the fluid pressure correction model for oil and gas production, and the oil and gas generation prediction model, a shale in-situ conversion oil and gas production prediction model is constructed.

[0128] Furthermore, in one possible implementation, the specific process of constructing a cumulative oil and gas production prediction model based on shale in-situ conversion heat simulation experimental data under predetermined fluid pressure conditions in step S1021 may include:

[0129] Sub-step S10212: Based on the thermal simulation experimental data of shale in-situ conversion under predetermined fluid pressure conditions, the thermal simulation oil and gas production of each shale sample is determined as the cumulative oil and gas production of shale in-situ conversion.

[0130] In sub-step S10212, a prediction model for the cumulative oil and gas production is obtained by fitting a model with total organic carbon content and vitrinite reflectance as the two independent variables and the cumulative oil and gas production from in-situ shale conversion under predetermined fluid pressure conditions as the dependent variable.

[0131] Here, the cumulative oil and gas production prediction model can include: the calculation expression for the cumulative oil production from in-situ shale conversion and the calculation expression for the cumulative gas production from in-situ shale conversion.

[0132] For example, in practical implementation, during the shale in-situ conversion heat simulation experiment, besides most of the oil collected in a sealed collector immersed in a 5°C constant temperature water bath, a portion of the simulated oil produced by the shale in-situ conversion heat also adheres to the hydrocarbon discharge pipeline. The weight of the oil in the collector (G1) can be quantified by the change in the weight of the collector before and after the experiment. The method for collecting and quantifying the oil adhering to the hydrocarbon discharge pipeline is as follows: First, the hydrocarbon discharge pipeline is flushed with 15 ml of dichloromethane. The crude oil contained in the flushing fluid is quantified using the internal standard method, with the internal standard being C at a concentration of 0.205 mg / ml. 24 H 49 D; then, the total oil content (G2) in the collected liquid is obtained by comparing the peak areas in the chromatogram of the collected liquid with the internal standard area. Based on this, the total weight G of the thermally simulated oil produced at a certain temperature point is calculated. i It is equal to the sum of G1 and G2.

[0133] As for the gases generated during the shale in-situ conversion heat simulation experiment, they can be collected using a vacuum bag, and the gas volume can be measured by displacing the entire bag. Gas composition analysis can be performed on a Wasson-Agilent 7890 gas chromatograph, which contains one flame ionization detector and two thermal conductivity detectors, and can detect hydrocarbon gases as well as H2S, CO2, H2, O2, and N2 in a single analysis.

[0134] Therefore, based on the experimental data of shale in-situ conversion thermal simulation under predetermined fluid pressure conditions, the cumulative oil production calculation expression of shale in-situ conversion can be obtained by fitting the following formula (1).

[0135]

[0136] The cumulative gas production calculation expression of shale in-situ conversion can be obtained by fitting the following formula (2).

[0137]

[0138] Among them, Q po The cumulative oil production from in-situ shale conversion before correction (i.e., the oil production from the thermal simulation experiment of in-situ shale conversion), mg / g rock; Q pg The cumulative gas production from in-situ shale conversion before correction (i.e., the gas production from the shale in-situ conversion thermal simulation experiment), ml / g.rock; TOC is the total organic carbon content, wt%; R oα is the vitrinite reflectance, %; a1 is the first empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a2 is the second empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a3 is the third empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a4 is the fourth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a5 is the fifth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a6 is the sixth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a7 is the seventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a8 is the eighth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a9 is the ninth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 10 a is the tenth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 11 This is the eleventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a 12 a is the twelfth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 13 This is the thirteenth empirical coefficient of the cumulative oil and gas production prediction model, and it is dimensionless.

[0139] Furthermore, in one possible implementation, step S1022, the specific implementation process of constructing a fluid pressure correction model for oil and gas production based on shale in-situ conversion heat simulation experimental data under different fluid pressure conditions, may include:

[0140] Sub-step S10221: Calculate the ratio of the thermally simulated oil and gas production under different fluid pressure conditions to the thermally simulated oil and gas production under predetermined fluid pressure conditions, and determine the ratio as the fluid pressure correction coefficient for the oil and gas production under different fluid pressure conditions.

[0141] Sub-step S10222: Using different fluid pressures as independent variables and the fluid pressure correction coefficient for the amount of oil and gas produced under different fluid pressure conditions as dependent variables, a fluid pressure correction model for the amount of oil and gas produced is obtained by fitting.

[0142] Here, the fluid pressure correction model for the amount of oil and gas produced can include: a correction expression for the amount of oil produced by fluid pressure and a correction expression for the amount of gas produced by fluid pressure.

[0143] For example, in practical implementation, using the same batch of crushed shale samples, under the same heating rate and final heating temperature, data on oil and gas production corresponding to thermal simulation experiments with fluid pressures of 0 Psi, 100 Psi, 250 Psi, 500 Psi, and 725 Psi were obtained. The ratio of oil production under the 0 Psi, 100 Psi, 250 Psi, and 500 Psi fluid pressure conditions to that under the 725 Psi fluid pressure condition (i.e., PR) was calculated.oil The fluid pressure correction coefficient PR for the oil production rate is obtained by regressing the fluid pressure with the corresponding fluid pressure. oil Similarly, the ratio of the produced gas volume under fluid pressure conditions of 0 Psi, 100 Psi, 250 Psi, and 500 Psi to the produced gas volume under fluid pressure condition of 725 Psi (i.e., PR) gas The fluid pressure correction coefficient PR for the output gas volume is obtained by regressing the output gas volume with the corresponding fluid pressure. gas .

[0144] Therefore, based on the experimental data of shale in-situ conversion heat simulation under different fluid pressure conditions, the correction expression of fluid pressure on oil production can be obtained by fitting the following formula (3).

[0145]

[0146] The corrected expression for fluid pressure on the output gas volume can be obtained by fitting the following formula (4).

[0147] PR gas =c3P1+c4 (4)

[0148] Among them, PR oil The fluid pressure correction factor for oil production is dimensionless; PR gas c1 is the fluid pressure correction coefficient for the produced gas volume, dimensionless; P1 is the fluid pressure, MPa; c1 is the first empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c2 is the second empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c3 is the third empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c4 is the fourth empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless.

[0149] Furthermore, in one possible implementation, in step S1023, the specific implementation process of constructing a prediction model for the amount of oil and gas generated based on shale Fischer analysis experimental data under different thermal evolution degrees may include: using vitrinite reflectance as the independent variable and the amount of oil and gas generated per unit of total organic carbon content as the dependent variable, and obtaining the prediction model for the amount of oil and gas generated through fitting.

[0150] Here, the oil and gas production prediction model can include: an expression for calculating oil production and an expression for calculating gas production.

[0151] For example, in specific implementation, based on the shale Fischer analysis experimental data under different thermal evolution degrees, the formula (5) can be used to fit the expression for calculating the amount of oil generated.

[0152]

[0153] The formula for calculating the generated gas volume can be obtained by fitting the following formula (6).

[0154]

[0155] Among them, Q FAOT Q represents the amount of oil produced per unit of total organic carbon, expressed in mg / g TOC. FAG T The amount of gas generated per unit of total organic carbon content, ml / g.TOC; R o d1 is the vitrinite reflectance, %; d2 is the first empirical coefficient of the oil and gas generation prediction model, dimensionless; d3 is the third empirical coefficient of the oil and gas generation prediction model, dimensionless; d4 is the fourth empirical coefficient of the oil and gas generation prediction model, dimensionless; d5 is the fifth empirical coefficient of the oil and gas generation prediction model, dimensionless; d6 is the sixth empirical coefficient of the oil and gas generation prediction model, dimensionless.

[0156] Furthermore, in one possible implementation, the shale in-situ conversion oil and gas production prediction model constructed in step S1024 may include: a correction expression for the cumulative oil production from shale in-situ conversion and a correction expression for the cumulative gas production from shale in-situ conversion.

[0157] In practice, the correction expression for the cumulative oil production from in-situ shale conversion can be constructed according to the following formula (7).

[0158]

[0159] A corrected expression for the cumulative gas production from in-situ shale conversion can be constructed according to the following formula (8).

[0160]

[0161] Among them, Q poc For the corrected cumulative oil production from in-situ shale conversion, mg / g rock; PR oil The fluid pressure correction factor for oil production is dimensionless. To evaluate the amount of oil produced per unit of total organic carbon (TOC) in shale samples from the target layer, the value is expressed as mg / g.TOC. The amount of oil produced per unit of total organic carbon (TOC) of shale samples used in the in-situ shale conversion heat simulation experiment, in mg / g.TOC; Q po The cumulative oil production from in-situ shale conversion before correction, in mg / g rock; Q pgc The revised cumulative gas production from in-situ shale conversion, in ml / g rock; PR gas The fluid pressure correction factor for the output gas volume is dimensionless. To evaluate the amount of gas generated per unit of total organic carbon (TOC) in shale samples from the target layer, expressed as ml / g.TOC; The amount of gas generated per unit of total organic carbon (TOC) of shale samples used in the shale in-situ conversion heat simulation experiment, in ml / g.TOC; Q pg The cumulative gas production from in-situ shale conversion before correction is expressed in ml / g.rock.

[0162] Furthermore, in one possible implementation, step S103, the specific implementation process of constructing a prediction model for the amount of retained oil and gas based on the experimental data of shale in-situ conversion heat under predetermined fluid pressure conditions, may include: using total organic carbon content and vitrinite reflectance as dual independent variables, and the amount of retained oil and gas under predetermined fluid pressure conditions as the dependent variable, to obtain a prediction model for the amount of retained oil and gas through fitting.

[0163] Here, the prediction model for retained oil and gas volume can include: the calculation expression for retained oil volume in shale and the calculation expression for retained gas volume in shale.

[0164] For example, in a practical implementation, during the in-situ thermal simulation experiment of shale conversion, the amount of oil and gas retained in the rock samples at different thermal simulation temperatures can be collected to obtain the amount of oil and gas retained in the shale.

[0165] Therefore, based on the experimental data of shale in-situ conversion heat simulation under predetermined fluid pressure conditions, the formula for calculating the amount of oil retained in shale can be obtained by fitting the following formula (9).

[0166]

[0167] The formula for calculating the amount of gas retained in shale can be obtained by fitting the following formula (10).

[0168]

[0169] Among them, Q ro Q represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. rg The value represents the amount of gas trapped per unit mass of shale, in ml / g rock; TOC represents the total organic carbon content, in wt%; R oρ is the vitrinite reflectance, %; b1 is the first empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b2 is the second empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b3 is the third empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b4 is the fourth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b5 is the fifth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b6 is the sixth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b7 is the seventh empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b8 is the eighth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b9 is the ninth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b 10 The tenth empirical coefficient of the residual oil and gas volume prediction model is dimensionless.

[0170] Furthermore, in one possible implementation, the crude oil in-situ conversion oil and gas production prediction model may include: an expression for calculating the proportion of produced oil to the original oil consumption in the thermal simulation and an expression for calculating the gas production per unit mass of thermal simulation oil.

[0171] Based on this, in step S104, the process of constructing a prediction model for the amount of oil and gas produced by the in-situ conversion of crude oil based on the experimental data of the in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions may include, but is not limited to, the following sub-steps S1041 to S1042.

[0172] In step S1041, with hydrocarbon discharge pressure and crude oil density as the two independent variables and the proportion of produced oil to the original oil consumption in the thermal simulation as the dependent variable, the expression for calculating the proportion of produced oil to the original oil consumption in the thermal simulation is obtained through fitting.

[0173] In step S1042, with hydrocarbon discharge pressure and crude oil density as the two independent variables and the gas production per unit mass of thermal simulation oil as the dependent variable, the gas production per unit mass of thermal simulation oil is obtained by fitting.

[0174] For example, in specific implementation, based on the experimental data of crude oil in-situ conversion heat simulation under different hydrocarbon discharge pressure conditions, the following formula (11) can be used to fit and obtain the calculation expression of the proportion of produced oil to the original oil consumption in the heat simulation.

[0175]

[0176] The gas production calculation expression for a unit mass of thermal simulation oil can be obtained by fitting the following formula (12).

[0177]

[0178] Among them, R oil RQ represents the percentage of oil produced relative to the original oil consumption in the thermal simulation. gasP1 represents the gas production per unit mass of thermal simulation oil, in ml / g.oil; P2 represents the hydrocarbon discharge pressure, in MPa; ρ o Crude oil density for thermal simulation, g / cm³ 3 f1 is the first empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f2 is the second empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f3 is the third empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f4 is the fourth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f5 is the fifth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f6 is the sixth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless.

[0179] It should be noted that the present invention is not limited to this. In addition to the fitting method, other methods such as neural network model, support vector regression model, linear regression model, ridge regression model or Lasso regression model can also be used to construct the cumulative oil and gas production prediction model, the fluid pressure correction model for oil and gas production, the oil and gas generation prediction model, the stagnant oil and gas production prediction model and the crude oil in-situ conversion oil and gas production prediction model in the embodiments of the present invention.

[0180] Furthermore, in one possible implementation, in step S105, the prediction model for oil and gas production per unit mass of shale in-situ conversion includes: an expression for calculating oil production per unit mass of shale in-situ conversion and an expression for calculating gas production per unit mass of shale in-situ conversion.

[0181] The following formula (13) can be used to construct an expression for calculating the oil production per unit mass of shale in-situ conversion.

[0182] Q oil =Q poc +Q ro ×R oil (13)

[0183] The following formula (14) can be used to construct an expression for calculating the gas production per unit mass of shale in-situ conversion.

[0184] Q gas =Q pgc +Q ro ×RQ gas +Q rg (14)

[0185] Among them, Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. poc For the corrected cumulative oil production from in-situ conversion, mg / g rock; Q roR represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. oil The percentage of oil produced relative to the original oil consumption in the thermal simulation, also known as the percentage of oil produced per unit mass of retained oil in the in-situ conversion, is expressed as a fraction; Q. gas Q represents the in-situ gas production per unit mass of shale through conversion, expressed in ml / g rock. pgc The corrected cumulative in-situ conversion gas yield, ml / g rock; RQ gas Q represents the gas production per unit mass of thermal simulation oil, also known as the gas production per unit mass of retained oil in in-situ conversion, expressed in ml / g.oil; rg The amount of gas trapped per unit mass of shale is expressed in ml / g rock.

[0186] like Figure 4 As shown, this embodiment of the invention also provides an evaluation method for favorable areas for in-situ conversion and development of shale, which includes the following steps:

[0187] Step S201: Use the shale in-situ conversion oil and gas production prediction model to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated.

[0188] Here, the prediction model for oil and gas production from in-situ shale conversion can be constructed using the evaluation method for recoverable oil and gas resources from in-situ shale conversion in the above embodiments. The specific implementation process will not be elaborated here.

[0189] Step S202: Based on the in-situ conversion and development parameter values ​​of shale, determine the lower limit of recoverable oil equivalent per unit mass of shale.

[0190] Among them, the shale in-situ conversion development parameter values ​​should include at least the following: the average fixed investment, average operating cost, average taxes and fees, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commodity rate of the development well group or development unit during the in-situ conversion production cycle.

[0191] Step S203: Compare the lower limit of recoverable oil equivalent per unit mass of shale with the recoverable oil and gas resources generated in situ from per unit mass of shale.

[0192] Step S204: The area where the recoverable oil equivalent per unit mass of shale in-situ conversion is greater than the lower limit of the recoverable oil equivalent per unit mass of shale is identified as a favorable zone for in-situ conversion development.

[0193] Furthermore, in one possible implementation, in step S202, the process of determining the lower limit of recoverable oil equivalent per unit mass of shale based on the in-situ conversion and development parameter values ​​of shale may include, but is not limited to, the following sub-steps S2021 to S2022.

[0194] Step S2021: Based on the in-situ conversion and development parameter values ​​of shale, determine the economic lower limit of recoverable oil equivalent for development well groups or development units.

[0195] In step S2022, based on the effective heated shale volume, shale density, and economic lower limit of recoverable oil equivalent of the development well group or development unit, the lower limit of recoverable oil equivalent per unit mass of shale is determined.

[0196] For example, in specific implementation, the economic lower limit of recoverable oil equivalent of development well groups or development units can be determined according to the following formula (15).

[0197]

[0198] The lower limit of recoverable oil equivalent per unit mass of shale can be determined according to the following formula (16).

[0199]

[0200] Among them, EUR_BOE cutoff The economic lower limit of recoverable oil equivalent for a development well group or development unit, 10 4 t; Capex is the lower bound of the rate of return on investment for a development well group or development unit in year i, expressed as a fraction. i $Opex is the average fixed investment for a development well group or development unit in year i. i $Dct represents the average operating cost of a development well group or development unit in year i. i $;SC represents the average abandonment cost of a development well group or development unit in year i. i $Rf represents the average sunk cost of a development well group or development unit in year i. i $; CR is the average reclamation cost for a development well group or development unit in year i. oil_i P represents the average commercialization rate of oil produced by a development well group or development unit in year i, expressed as a fraction. oil_i The average selling price of oil produced by a development well group or development unit in year i, $ / 10 4 t; Tax oil_i The average tax rate per unit of oil produced by a development well group or development unit in year i, $ / 10 4 t; CR gas_i P represents the average, fractional, rate of commercialization of natural gas produced by a development well group or development unit in year i. gas_i The average selling price of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; Tax gas_iThe average tax rate per unit of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; n represents the production time of a development well group or development unit, in years; Q BOE_cutoff The recoverable oil equivalent per unit mass of shale is the lower limit, mg / g rock; V rock The effective heated shale volume controlled by a development well group or development unit, in m 3 ;ρ rock To effectively heat shale density, g / cm³ 3 .

[0201] This invention also provides another method for evaluating favorable areas for in-situ shale conversion and development. This evaluation method, in addition to the process of dividing favorable strata for in-situ conversion and development based on the lower limit of recoverable oil equivalent per unit mass of shale, also includes the process of dividing favorable areas for in-situ shale conversion and development.

[0202] Specifically, such as Figure 5 As shown, another method for evaluating favorable areas for in-situ shale conversion and development may include the following steps:

[0203] Step S301: Use the shale in-situ conversion oil and gas production prediction model to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated.

[0204] Step S302: Based on the in-situ conversion and development parameter values ​​of shale, determine the lower limit of recoverable oil equivalent per unit mass of shale.

[0205] Step S303: Compare the lower limit of recoverable oil equivalent per unit mass of shale with the recoverable oil and gas resources generated in situ from per unit mass of shale.

[0206] Step S304: The area where the recoverable oil equivalent per unit mass of shale in-situ conversion is greater than the lower limit of the recoverable oil equivalent per unit mass of shale is identified as a favorable zone for in-situ conversion development.

[0207] It should be noted that the process of determining the favorable strata for in-situ conversion and development in steps S301 to S304 is the same as the concept of the evaluation method for favorable shale in-situ conversion and development areas in the above embodiments, and the specific implementation process will not be repeated here.

[0208] Step S305: Based on the favorable strata for in-situ conversion development and the recoverable oil and gas resources per unit mass of shale in-situ conversion, determine the abundance of recoverable oil and gas resources.

[0209] For example, in specific implementation, the abundance of recoverable oil resources can be determined according to the following formula (17), and the abundance of recoverable gas resources can be determined according to the following formula (18).

[0210] AOR=10 -7 Ooil ×H shale ×ρ shale (17)

[0211] AGR=10 -8 O gas ×H shale ×ρ shale (18)

[0212] Where AOR represents recoverable oil resource abundance, 10 4 t / km 2 AGR represents recoverable gas resource abundance, 10 8 m 3 / km 2 Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. gas The in-situ gas production from shale conversion per unit mass, expressed as ml / g rock; H shale The shale depth of the favorable in-situ transformation zone is in km; ρ shale Shale density in favorable in-situ transformation zones, g / cm³ 3 .

[0213] Step S306: Compare the economic lower limit of recoverable oil equivalent of the development well group or development unit with the abundance of recoverable oil and gas resources.

[0214] Step S307: Areas with recoverable oil and gas resource abundance greater than or equal to the economic lower limit of recoverable oil equivalent of development well groups or development units are identified as favorable areas for in-situ shale conversion and development.

[0215] To better understand the exemplary embodiments of the present invention described above, they will be further described below in conjunction with specific examples and accompanying drawings.

[0216] Taking nine shale samples from the Chang 73 Formation of the Triassic System in the Ordos Basin and five shale samples from the Nenjiang Formation of the Cretaceous System in the Songliao Basin as examples, the original geochemical parameter values ​​of each shale sample are shown in Tables 1 and 2.

[0217] Table 1. Original geochemical parameters of the Triassic Yanchang Formation Chang 73 shale sample from the Ordos Basin.

[0218]

[0219] Table 2. Original geochemical parameters of Cretaceous Nenjiang Formation shale samples from the Songliao Basin.

[0220]

[0221] Based on the aforementioned shale samples, after conducting in-situ shale conversion heat simulation experiments, crude oil in-situ conversion heat simulation experiments, and shale Fischer analysis experiments, a prediction model for the amount of oil and gas produced per unit mass of shale in-situ conversion was constructed. The specific process for predicting the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated is as follows (e.g. Figure 6 (As shown).

[0222] Step S401: Using shale in-situ conversion heat simulation experimental data, and taking total organic carbon content and vitrinite reflectance as influencing factors, establish a prediction model for cumulative oil and gas production and a prediction model for retained oil and gas production, respectively.

[0223] Specifically, 108 in-situ conversion heat simulation experiments were first conducted on 9 shale samples from the Triassic Yanchang Formation (Chang 73) in the Ordos Basin, and 60 in-situ conversion heat simulation experiments were conducted on 5 shale samples from the Cretaceous Nenjiang Formation in the Songliao Basin, to obtain the simulated oil and gas production and retained oil and gas volume, respectively.

[0224] When conducting in-situ conversion heat simulation experiments on shale to produce oil and gas, the preset fluid pressure was 5 MPa (725 Psi) and the hydrocarbon expulsion pressure was 7 MPa (1015 Psi). The temperature was increased at a rate of 20 °C / d to the preset temperature before each set temperature point (the temperature before the first temperature point was 200 °C). Then, the sample was heated to the preset temperature at a rate of 5 °C / d and held at the preset temperature for 10 hours. Among them, the preset temperatures for the in-situ heat transformation simulation experiments of 9 shale samples from the Chang 73 Formation of the Triassic System in the Ordos Basin were 250℃, 300℃, 320℃, 335℃, 350℃, 360℃, 390℃, 440℃, 500℃, 540℃, and 580℃, respectively; and the preset temperatures for the in-situ heat transformation simulation experiments of 5 shale samples from the Nenjiang Formation of the Cretaceous System in the Songliao Basin were 215℃, 235℃, 285℃, 305℃, 320℃, 335℃, 345℃, 375℃, 385℃, 485℃, 525℃, and 565℃, respectively.

[0225] The inventors discovered through research that the maximum oil and gas production rates produced in in-situ conversion thermal simulation experiments with different heating rates are roughly equivalent. Therefore, it can be considered that the cumulative oil and gas production from shale in-situ conversion is basically unaffected by the heating rate. Thus, in this embodiment, the influence of the heating rate is not considered in the cumulative oil and gas production prediction model.

[0226] Using 108 sets of in-situ conversion heat simulation experimental data from 9 shale samples of the Chang 73 section of the Triassic Yanchang Formation in the Ordos Basin, the cumulative hydrocarbon production prediction model obtained through fitting is as follows:

[0227]

[0228]

[0229] Using 108 sets of in-situ conversion heat simulation experimental data from 9 shale samples of the Chang 73 section of the Triassic Yanchang Formation in the Ordos Basin, the predicted model for retained hydrocarbon volume obtained through fitting is as follows:

[0230]

[0231]

[0232] Step S402: Using experimental data from shale in-situ conversion heat simulation under different fluid pressure conditions, and taking fluid pressure as an influencing factor, establish a fluid pressure correction model for the amount of oil and gas produced.

[0233] Specifically, we first conducted in-situ shale conversion heat simulation experiments under different fluid pressure conditions on shale samples to obtain fluid pressure correction coefficients under different fluid pressure conditions.

[0234] When conducting thermal simulations of the effect of fluid pressure on the production of oil and gas from in-situ transformed shale, five fluid pressures were preset: 0 MPa (0 Psi), 0.7 MPa (100 Psi), 1.7 MPa (250 Psi), 3.5 MPa (500 Psi), and 5 MPa (725 Psi). The samples were heated to 200 °C at a rate of 20 °C / d, and then heated to the preset temperature of 425 °C at a rate of 5 °C / d. After reaching the preset temperature, the samples were held at that temperature for 10 h. The original geochemical parameters of the shale samples are shown in Table 3, and the simulated oil and gas production under different pressure conditions are shown in Table 4.

[0235] Table 3 Geochemical parameters of shale samples

[0236]

[0237] Table 4. Simulated oil and gas production under different fluid pressure conditions using in-situ heat conversion.

[0238]

[0239] Using in-situ shale conversion heat simulation experimental data under different fluid pressure conditions, the fluid pressure correction model for oil and gas production obtained by fitting is as follows:

[0240]

[0241] PR gas =0.1144P1+0.428.

[0242] Step S403: Using Fischer analysis experimental data of shale with different thermal evolution degrees, and taking vitrinite reflectance as an influencing factor, establish a prediction model for the amount of oil and gas generated.

[0243] Using Fischer analysis data of shale samples at different thermal evolution stages, the hydrocarbon generation prediction model obtained through fitting is as follows:

[0244]

[0245]

[0246] Step S404: Using experimental data from in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions, and taking hydrocarbon expulsion pressure and crude oil density as influencing factors, establish a prediction model for the amount of oil and gas produced from in-situ conversion of crude oil.

[0247] To address the contribution of shale oil residing in shale to the production of oil and gas from in-situ conversion, a calorimetric simulation of oil and gas production from crude oil in-situ conversion was conducted. First, the shale sample was heated to 800℃ and held at that temperature for 48 hours to convert all convertible organic matter in the shale. The cooled sample residue was then extracted with dichloromethane. The extracted residue sample was held at 80℃ for 48 hours and then cooled. Crude oil was mixed with the sample residue at a mass of 5 wt%. A heating rate of 5℃ / d and hydrocarbon expulsion pressures of 2 MPa (290 Psi), 5 MPa (725 Psi), and 10 MPa (1450 Psi) were set for the calorimetric simulation of oil and gas production from crude oil in-situ conversion. The proportion of produced oil to the original oil used in the calorimetric simulation and the amount of gas produced per unit mass of simulated oil were obtained.

[0248] Using experimental data from in-situ crude oil conversion heat simulation under different hydrocarbon expulsion pressures on shale samples, a prediction model for crude oil and gas production from in-situ conversion was obtained through fitting:

[0249]

[0250]

[0251] Step S405: Based on the fluid pressure correction model for the produced oil and gas volume and the oil and gas generation prediction model, the cumulative oil and gas production prediction model is corrected to establish a shale in-situ conversion oil and gas production prediction model.

[0252] The constructed prediction model for oil and gas production from in-situ shale conversion is as follows:

[0253]

[0254]

[0255] Step S406: Based on the shale in-situ conversion oil and gas production prediction model, the retained oil and gas production prediction model, and the crude oil in-situ conversion oil and gas production prediction model, establish a prediction model for the production of oil and gas per unit mass of shale in-situ conversion.

[0256] The final prediction model for the amount of oil and gas produced per unit mass of shale in-situ conversion is as follows:

[0257]

[0258]

[0259] By performing steps S401 to S406 above, a prediction model for the amount of oil and gas produced by in-situ conversion of shale per unit mass can be constructed. Using this prediction model, the recoverable oil and gas resources per unit mass of shale in-situ conversion of the target layer to be evaluated can be calculated, thereby realizing the evaluation of recoverable oil and gas resources in in-situ conversion and development of immature to medium-low maturity shale.

[0260] After determining the recoverable oil and gas resources per unit mass of shale in-situ conversion in the target layer to be evaluated, shale in-situ conversion site selection can be carried out to identify favorable areas for in-situ conversion development. Specifically, the specific process for further determining favorable areas for shale in-situ development based on the oil and gas production prediction model per unit mass of shale in-situ conversion is as follows (e.g.) Figure 6 (As shown).

[0261] Step S407: Use the in-situ conversion oil and gas production prediction model of shale per unit mass to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion of the target layer to be evaluated.

[0262] Step S408: Based on the in-situ conversion and development parameter values ​​of shale, determine the economic lower limit of recoverable oil equivalent and the lower limit of recoverable oil equivalent per unit mass of shale for the development well group or development unit.

[0263] For the specific calculation process of the economic lower limit of recoverable oil equivalent and the lower limit of recoverable oil equivalent per unit mass of shale, please refer to the above formulas (15) and (16).

[0264] Step S409: Based on the lower limit of recoverable oil equivalent per unit mass of shale and the recoverable oil and gas resources per unit mass of shale in-situ conversion, determine the favorable strata for in-situ conversion.

[0265] In shale in-situ conversion development, heaters are used to heat the favorable strata as a whole. When profitable mining is achieved, the average recoverable oil equivalent per unit mass of rock in the heated strata must be greater than its economic lower limit. This method is used to determine the favorable strata for in-situ conversion.

[0266] Step S410: Determine the abundance of recoverable oil and gas resources based on the favorable strata for in-situ conversion development and the recoverable oil and gas resources per unit mass of shale in-situ conversion.

[0267] In this example, according to 1425m 3 The calorific value of natural gas is equivalent to that of 1 ton of crude oil, which can be used to calculate the recoverable oil equivalent abundance.

[0268] For the specific calculation process of recoverable oil and gas resource abundance, please refer to the above formulas (17) and (18).

[0269] Step S411: Determine favorable areas for in-situ shale conversion and development based on the economic lower limit of recoverable oil equivalent and the abundance of recoverable oil and gas resources of the development well group or development unit.

[0270] Areas with recoverable oil and gas resource abundance greater than or equal to the economic lower limit of recoverable oil equivalent of development well groups or development units can be identified as favorable areas for in-situ shale conversion and development.

[0271] After constructing a prediction model for the amount of oil and gas produced by in-situ conversion of shale per unit mass by performing steps S401 to S406, the selection of development areas for in-situ conversion of immature to low-maturity shale can be realized by performing steps S407 to S411.

[0272] For example, Figure 7 To utilize the evaluation method for favorable shale in-situ development areas in this example, a recoverable oil equivalent resource abundance distribution map was calculated based on the parameters of the immature to low-maturity shale at the bottom of the second member of the Nenjiang Formation in the Songliao Basin. Figure 8 This is a map showing the distribution of favorable areas for in-situ transformation of immature to low-maturity shale at the bottom of the second member of the Nenjiang Formation in the Songliao Basin.

[0273] Combination Figure 7 and Figure 8 It can be seen that the lower limit of recoverable oil equivalent resource abundance (i.e., the lower limit of recoverable oil equivalent economic abundance) is 100×10 4 t / km 2 and 70×10 4 t / km 2 Using these two lower limits and Figure 7 By comparing the recoverable oil equivalent resource abundance (i.e., recoverable oil and gas resource abundance) at different locations within the development well group, it is possible to classify and obtain... Figure 8 The Songliao Basin contains Class I and Class II favorable areas for in-situ transformation of immature to low-maturity shale at the bottom of the Nenjiang Formation II.

[0274] Furthermore, the implementation environment of this embodiment includes at least one terminal and one server, and the method is executed on the terminal or the server respectively. The terminal and the server can establish a communication connection to achieve interactive information transmission.

[0275] The terminal can be any electronic product that can interact with the user through one or more methods such as keyboard, touchpad, touch screen, voice interaction, etc., such as PC (Personal Computer), PPC (Pocket Personal Computer), tablet computer, etc.

[0276] A server can be a single server, a server cluster consisting of multiple servers, or a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, CDN (Content Delivery Network), and big data and artificial intelligence platforms.

[0277] like Figure 9 As shown, this embodiment of the invention also provides an evaluation device for the recoverable oil and gas resources of shale in-situ conversion. The evaluation device includes an acquisition module 101, a first construction module 102, a second construction module 103, a third construction module 104, a fourth construction module 105, and a first determination module 106.

[0278] The acquisition module 101 is used to acquire shale in-situ conversion heat simulation experimental data under different fluid pressure conditions, crude oil in-situ conversion heat simulation experimental data under different hydrocarbon expulsion pressure conditions, and shale Fischer analysis experimental data under different thermal evolution degrees.

[0279] The data from the shale in-situ conversion thermal simulation experiment include: total organic carbon content, vitrinite reflectance, thermal simulation oil and gas production, and retained oil and gas volume; the data from the crude oil in-situ conversion thermal simulation experiment include: crude oil density, the proportion of produced oil to the original oil consumption in the thermal simulation, and the gas production per unit mass of thermal simulation oil; the shale Fischer analysis experimental data include: the amount of oil and gas generated per unit of total organic carbon content.

[0280] The first construction module 102 is used to construct a prediction model for the amount of oil and gas produced from the in-situ conversion of shale based on experimental data of in-situ thermal simulation of shale under different fluid pressure conditions and experimental data of shale Fischer analysis under different thermal evolution degrees.

[0281] The second construction module 103 is used to construct a prediction model for the amount of oil and gas produced from the in-situ conversion of shale based on experimental data of in-situ thermal simulation of shale under different fluid pressure conditions and experimental data of shale Fischer analysis under different thermal evolution degrees.

[0282] The third construction module 104 is used to construct a prediction model for the amount of oil and gas produced by the in-situ conversion of crude oil based on experimental data of in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions.

[0283] The fourth construction module 105 is used to construct a prediction model for the amount of oil and gas produced by in-situ shale conversion based on the prediction models for oil and gas production from in-situ shale conversion, the prediction model for oil and gas retention, and the prediction model for oil and gas production from in-situ crude oil conversion.

[0284] The first determining module 106 is used to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion based on a prediction model for oil and gas production per unit mass of shale in-situ conversion.

[0285] like Figure 10 As shown, this embodiment of the invention also provides an evaluation device for favorable areas for in-situ conversion and development of shale. The evaluation device includes a second determination module 201, a third determination module 202, a comparison module 203, and a fourth determination module 204.

[0286] The second determining module 201 is used to determine the recoverable oil and gas resources per unit mass of shale in-situ converted from the target layer to be evaluated. It should be noted that the specific implementation process of the second determining module belongs to the same concept as the evaluation method for recoverable oil and gas resources in-situ converted from shale provided in the above embodiments. Its specific implementation process is detailed in the method embodiments and will not be repeated here.

[0287] The third determining module 202 is used to determine the lower limit of recoverable oil equivalent per unit mass of shale based on the in-situ conversion and development parameter values ​​of shale.

[0288] Among them, the shale in-situ conversion development parameters include: the average fixed investment, average operating cost, average taxes and fees, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commodity rate of the development well group or development unit during the in-situ conversion production cycle.

[0289] Comparison module 203 is used to compare the lower limit of recoverable oil equivalent per unit mass of shale and the recoverable oil and gas resources per unit mass of shale converted in situ.

[0290] The fourth determination module 204 is used to determine areas where the recoverable oil equivalent per unit mass of shale in situ conversion is greater than the lower limit of the recoverable oil equivalent per unit mass of shale as favorable strata for in situ conversion development.

[0291] It should be noted that the above-described device is only illustrated by the division of the functional modules described above. In practical applications, the functions can be assigned to different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete all or part of the functions described above. Furthermore, the device and method provided in the above embodiments belong to the same concept, and their specific implementation process can be found in the method embodiments, which will not be repeated here.

[0292] like Figure 11As shown, this embodiment of the invention also provides an electronic device, which includes a processor 301 and a memory 302. The memory stores at least one computer program, which is loaded and executed by one or more of the processors to enable the processors to implement the method for evaluating recoverable oil and gas resources in shale in-situ conversion in the above embodiments, or the method for evaluating favorable development areas of shale in-situ conversion in the above embodiments.

[0293] Of course, the electronic device may also have wired or wireless network interfaces, keyboards, and input / output interfaces for input and output. The electronic device may also include other components for implementing the various functions of the device, which will not be elaborated here.

[0294] This invention also provides a computer-readable storage medium storing at least one piece of program code, which is loaded and executed by a processor to enable a computer to implement the method for evaluating recoverable oil and gas resources from in-situ shale conversion in the above embodiments, or the method for evaluating favorable development areas from in-situ shale conversion in the above embodiments.

[0295] Optionally, the computer-readable storage medium may be a read-only memory (ROM), a random access memory (RAM), a compact disc read-only memory (CD-ROM), a magnetic tape, a floppy disk, or an optical disc data storage device, etc. Those skilled in the art will understand that all or part of the steps in the methods of the above embodiments can be implemented by a program instructing related hardware. This program is stored in a storage medium and includes several instructions to cause a microcontroller, chip, or processor to execute all or part of the steps of the methods described in each embodiment of this application. The aforementioned storage medium includes various media capable of storing program code, such as a USB flash drive, a portable hard drive, a read-only memory (ROM), a random access memory (RAM), a magnetic disk, or an optical disc.

[0296] The preferred embodiments of the present invention have been described in detail above with reference to the accompanying drawings. However, the present invention is not limited to the specific details of the above embodiments. Within the scope of the technical concept of the present invention, various simple modifications can be made to the technical solution of the present invention, and these simple modifications all fall within the protection scope of the present invention.

[0297] It should also be noted that the various specific technical features described in the above specific embodiments can be combined in any suitable manner without contradiction. In order to avoid unnecessary repetition, the present invention will not describe the various possible combinations separately.

[0298] Furthermore, various different embodiments of the present invention can be combined in any way, as long as they do not violate the spirit of the present invention, they should also be regarded as the content disclosed by the present invention.

Claims

1. A method for evaluating recoverable oil and gas resources from in-situ shale conversion, characterized in that, The evaluation methods include: Data on in-situ thermal transformation of shale under different fluid pressure conditions, data on in-situ thermal transformation of crude oil under different hydrocarbon expulsion pressure conditions, and Fischer analysis data on shale under different thermal evolution degrees were obtained. The in-situ thermal transformation data of shale included: total organic carbon content, vitrinite reflectance, simulated oil and gas production, and retained oil and gas volume. The in-situ thermal transformation data of crude oil included: crude oil density, the proportion of produced oil to the original oil used in the thermal simulation, and the gas production per unit mass of simulated oil. The Fischer analysis data of shale included: the amount of oil and gas generated per unit of total organic carbon content. Based on experimental data of in-situ thermal simulation of shale under different fluid pressure conditions and experimental data of shale Fischer analysis under different thermal evolution degrees, a prediction model for oil and gas production from in-situ shale conversion is constructed. Based on the experimental data of shale in-situ conversion heat simulation under predetermined fluid pressure conditions, a prediction model for the amount of retained oil and gas is constructed. Based on the experimental data of in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions, a prediction model for the amount of oil and gas produced by in-situ conversion of crude oil is constructed. Based on the prediction models for oil and gas production from shale in-situ conversion, retained oil and gas production, and crude oil in-situ conversion, a prediction model for oil and gas production per unit mass of shale in-situ conversion is constructed. Based on the prediction model of oil and gas production per unit mass of shale in-situ conversion, the recoverable oil and gas resources per unit mass of shale in-situ conversion of the target layer to be evaluated are determined.

2. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 1, characterized in that, Based on experimental data from in-situ thermal simulations of shale conversion under different fluid pressure conditions and Fischer analysis data of shale under different degrees of thermal evolution, a predictive model for oil and gas production from in-situ shale conversion is constructed, including: Based on the experimental data of shale in-situ conversion heat simulation under predetermined fluid pressure conditions, a prediction model for cumulative oil and gas production is constructed. Based on the experimental data of shale in-situ conversion heat simulation under different fluid pressure conditions, a fluid pressure correction model for the production of oil and gas is constructed. Based on Fischer analysis experimental data of shale under different thermal evolution conditions, a prediction model for generated oil and gas volume is constructed. Based on the cumulative oil and gas production prediction model, the fluid pressure correction model for oil and gas production, and the oil and gas generation prediction model, a prediction model for oil and gas production from in-situ shale conversion is constructed.

3. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 2, characterized in that, The cumulative oil and gas production prediction model is constructed based on the shale in-situ conversion heat simulation experimental data under predetermined fluid pressure conditions, including: Using total organic carbon content and vitrinite reflectance as the two independent variables, and the cumulative oil and gas production from in-situ shale conversion under predetermined fluid pressure conditions as the dependent variable, a prediction model for cumulative oil and gas production was obtained through fitting.

4. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 3, characterized in that, The cumulative oil and gas production prediction model includes: a calculation expression for the cumulative oil production from in-situ shale conversion and a calculation expression for the cumulative gas production from in-situ shale conversion; The following formula was used to fit the expression for calculating the cumulative oil production from in-situ shale conversion: The following formula was used to fit the cumulative gas production calculation expression for in-situ shale conversion: Among them, Q po The cumulative oil production from in-situ shale conversion before correction, in mg / g rock; Q pg The cumulative gas production from in-situ shale conversion before correction is ml / g rock; TOC is total organic carbon content, wt%; R o α is the vitrinite reflectance, %; a1 is the first empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a2 is the second empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a3 is the third empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a4 is the fourth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a5 is the fifth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a6 is the sixth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a7 is the seventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a8 is the eighth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a9 is the ninth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 10 a is the tenth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 11 This is the eleventh empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; a 12 a is the twelfth empirical coefficient of the cumulative oil and gas production prediction model, dimensionless; 13 This is the thirteenth empirical coefficient of the cumulative oil and gas production prediction model, and it is dimensionless.

5. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 2, characterized in that, The fluid pressure correction model for oil and gas production is constructed based on shale in-situ conversion heat simulation experimental data under different fluid pressure conditions, including: Calculate the ratio of the thermally simulated oil and gas production under different fluid pressure conditions to the thermally simulated oil and gas production under a predetermined fluid pressure condition, and determine this ratio as the fluid pressure correction coefficient for the oil and gas production under different fluid pressure conditions. Using different fluid pressures as independent variables and the fluid pressure correction coefficient for the amount of oil and gas produced under different fluid pressure conditions as dependent variables, a fluid pressure correction model for the amount of oil and gas produced is obtained by fitting.

6. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 5, characterized in that, The fluid pressure correction model for the oil and gas production includes: a correction expression for the oil production by fluid pressure and a correction expression for the gas production by fluid pressure. The corrected expression for fluid pressure versus oil production rate is obtained by fitting the following formula: The corrected expression for fluid pressure versus output gas volume is obtained by fitting the following formula: PR gas =c3P1+c4, Among them, PR oil The fluid pressure correction factor for oil production is dimensionless; PR gas c1 is the fluid pressure correction coefficient for the produced gas volume, dimensionless; P2 is the fluid pressure, MPa; c3 is the first empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c4 is the second empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c5 is the third empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless; c6 is the fourth empirical coefficient of the fluid pressure correction model for the produced oil and gas volume, dimensionless.

7. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 2, characterized in that, The oil and gas volume prediction model is constructed based on shale Fischer analysis experimental data under different thermal evolution degrees, including: Using vitrinite reflectance as the independent variable and the amount of oil and gas generated per unit of total organic carbon content as the dependent variable, a prediction model for the amount of oil and gas generated was obtained through fitting.

8. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 7, characterized in that, The oil and gas generation prediction model includes: an oil generation calculation expression and a gas generation calculation expression; The following formula was used to fit the expression for calculating the amount of oil produced: The formula for calculating the generated gas volume is obtained by fitting the following formula: Among them, Q FAOT Q represents the amount of oil produced per unit of total organic carbon, expressed in mg / g TOC. FAGT The amount of gas generated per unit of total organic carbon content, ml / g.TOC; R o d1 is the vitrinite reflectance, %; d2 is the first empirical coefficient of the oil and gas generation prediction model, dimensionless; d3 is the third empirical coefficient of the oil and gas generation prediction model, dimensionless; d4 is the fourth empirical coefficient of the oil and gas generation prediction model, dimensionless; d5 is the fifth empirical coefficient of the oil and gas generation prediction model, dimensionless; d6 is the sixth empirical coefficient of the oil and gas generation prediction model, dimensionless.

9. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 2, characterized in that, The shale in-situ conversion oil and gas production prediction model includes: a correction expression for the cumulative oil production from shale in-situ conversion and a correction expression for the cumulative gas production from shale in-situ conversion; The following formula is used to construct a corrected expression for the cumulative oil production from in-situ shale conversion: The following formula is used to construct a corrected expression for the cumulative gas production from in-situ shale conversion: Among them, Q poc For the corrected cumulative oil production from in-situ shale conversion, mg / g rock; PR oil The fluid pressure correction factor for oil production is dimensionless. To evaluate the amount of oil produced per unit of total organic carbon (TOC) in shale samples from the target layer, the value is expressed as mg / g.TOC. The amount of oil produced per unit of total organic carbon (TOC) of shale samples used in the in-situ shale conversion heat simulation experiment, in mg / g.TOC; Q po The cumulative oil production from in-situ shale conversion before correction, in mg / g rock; Q pgc The revised cumulative gas production from in-situ shale conversion, in ml / g rock; PR gas The fluid pressure correction factor for the output gas volume is dimensionless. To evaluate the amount of gas generated per unit of total organic carbon (TOC) in shale samples from the target layer, expressed as ml / g.TOC; The amount of gas generated per unit of total organic carbon (TOC) of shale samples used in the shale in-situ conversion heat simulation experiment, in ml / g.TOC; Q pg The cumulative gas production from in-situ shale conversion before correction is expressed in ml / g.rock.

10. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 1, characterized in that, The model for predicting the amount of retained oil and gas is constructed based on the shale in-situ conversion heat simulation experimental data under predetermined fluid pressure conditions, including: Using total organic carbon content and vitrinite reflectance as the two independent variables, and the amount of retained oil and gas under predetermined fluid pressure conditions as the dependent variable, a prediction model for the amount of retained oil and gas was obtained through fitting.

11. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 10, characterized in that, The prediction model for retained oil and gas includes: an expression for calculating the amount of retained oil in shale and an expression for calculating the amount of retained gas in shale. The following formula was used to fit the expression for calculating shale oil retention: The following formula was used to fit the expression for calculating shale gas retention: Among them, Q ro Q represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. rg The value represents the amount of gas trapped per unit mass of shale, in ml / g rock; TOC represents the total organic carbon content, in wt%; R o ρ is the vitrinite reflectance, %; b1 is the first empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b2 is the second empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b3 is the third empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b4 is the fourth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b5 is the fifth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b6 is the sixth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b7 is the seventh empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b8 is the eighth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b9 is the ninth empirical coefficient of the residual oil and gas volume prediction model, dimensionless; b 10 The tenth empirical coefficient of the residual oil and gas volume prediction model is dimensionless.

12. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 1, characterized in that, The crude oil in-situ conversion oil and gas production prediction model includes: an expression for calculating the proportion of oil produced to the original oil consumption in the thermal simulation and an expression for calculating the gas production per unit mass of thermal simulation oil. The model for predicting the amount of oil and gas produced from in-situ crude oil conversion is constructed based on experimental data from in-situ crude oil conversion heat simulation under different hydrocarbon expulsion pressure conditions, including: Using hydrocarbon discharge pressure and crude oil density as the two independent variables and the proportion of produced oil to the original oil consumption in the thermal simulation as the dependent variable, the expression for calculating the proportion of produced oil to the original oil consumption in the thermal simulation is obtained by fitting. Using hydrocarbon discharge pressure and crude oil density as the two independent variables and the gas production per unit mass of thermally simulated oil as the dependent variable, a calculation expression for the gas production per unit mass of thermally simulated oil was obtained through fitting.

13. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 12, characterized in that, The following formula was used to fit the expression for calculating the proportion of produced oil to the original oil consumption in the heat simulation: The following formula is used to fit the expression for calculating the gas production per unit mass of thermal simulation oil: Among them, R oil RQ represents the percentage of oil produced relative to the original oil consumption in the thermal simulation. gas P1 represents the gas production per unit mass of thermal simulation oil, in ml / g.oil; P2 represents the hydrocarbon discharge pressure, in MPa; ρ o Crude oil density for thermal simulation, g / cm³ 3 f1 is the first empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f2 is the second empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f3 is the third empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f4 is the fourth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f5 is the fifth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless; f6 is the sixth empirical coefficient of the crude oil in-situ conversion oil and gas production prediction model, dimensionless.

14. The method for evaluating recoverable oil and gas resources from in-situ shale conversion according to claim 1, characterized in that, The prediction model for oil and gas production per unit mass of shale in-situ conversion includes: an expression for calculating oil production per unit mass of shale in-situ conversion and an expression for calculating gas production per unit mass of shale in-situ conversion. The following formula can be used to construct an expression for calculating the oil yield per unit mass of shale in-situ conversion: Q oil =Q poc +Q ro ×R oil , The following formula can be used to construct an expression for calculating the gas production per unit mass of shale in-situ conversion: Q gas =Q pgc +Q ro ×RQ gas +Q rg , Among them, Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. poc For the corrected cumulative oil production from in-situ conversion, mg / g rock; Q ro R represents the amount of oil retained per unit mass of shale, expressed in mg / g rock. oil The fraction representing the proportion of oil produced to the original oil consumption in the thermal simulation; Q gas Q represents the in-situ gas production per unit mass of shale through conversion, expressed in ml / g rock. pgc The corrected cumulative in-situ conversion gas yield, ml / g rock; RQ gas Q represents the gas production per unit mass of thermal simulation oil, expressed in ml / g.oil. rg The amount of gas trapped per unit mass of shale is expressed in ml / g rock.

15. A method for evaluating favorable areas for in-situ conversion and development of shale, characterized in that, The evaluation methods include: The recoverable oil and gas resources per unit mass of the target layer to be evaluated are determined by the evaluation method for the recoverable oil and gas resources of shale in situ conversion according to any one of claims 1 to 14. Based on the in-situ conversion and development parameters of shale, the lower limit of recoverable oil equivalent per unit mass of shale is determined; the in-situ conversion and development parameters of shale include: the average fixed investment, average operating cost, average taxes and fees, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commercialization rate of the development well group or development unit during the in-situ conversion production cycle. Compare the lower limit of recoverable oil equivalent per unit mass of shale and the recoverable oil and gas resources generated in situ from per unit mass of shale; Areas where the recoverable oil equivalent per unit mass of shale in situ conversion is greater than the lower limit of the recoverable oil equivalent per unit mass of shale are identified as favorable strata for in situ conversion development.

16. The evaluation method for favorable areas for in-situ shale conversion and development according to claim 15, characterized in that, The determination of the lower limit of recoverable oil equivalent per unit mass of shale based on shale in-situ conversion and development parameter values ​​includes: Based on the in-situ conversion and development parameters of shale, determine the economic lower limit of recoverable oil equivalent for development well groups or development units; Based on the effective heated shale volume, shale density, and economic lower limit of recoverable oil equivalent of the development well group or development unit, the lower limit of recoverable oil equivalent per unit mass of shale is determined.

17. The evaluation method for favorable areas for in-situ shale conversion and development according to claim 16, characterized in that, The economic lower limit of recoverable oil equivalent for development well groups or development units shall be determined according to the following formula: The lower limit of recoverable oil equivalent per unit mass of shale should be determined using the following formula: Among them, EUR_BOE cutoff The economic lower limit of recoverable oil equivalent for a development well group or development unit, 10 4 t; Capex is the lower bound of the rate of return on investment for a development well group or development unit in year i, expressed as a fraction. i $Opex is the average fixed investment for a development well group or development unit in year i. i $Dct represents the average operating cost of a development well group or development unit in year i. i $;SC represents the average abandonment cost of a development well group or development unit in year i. i $Rf represents the average sunk cost of a development well group or development unit in year i. i $; CR is the average reclamation cost for a development well group or development unit in year i. oil_i P represents the average commercialization rate of oil produced by a development well group or development unit in year i, expressed as a fraction. oil_i The average selling price of oil produced by a development well group or development unit in year i, $ / 10 4 t; Tax oil_i The average tax rate per unit of oil produced by a development well group or development unit in year i, $ / 10 4 t; CR gas_i P represents the average, fractional, rate of commercialization of natural gas produced by a development well group or development unit in year i. gas_i The average selling price of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; Tax gas_i The average tax rate per unit of natural gas produced by a development well group or development unit in year i, $ / 10 4 t; n represents the production time of a development well group or development unit, in years; Q BOE_cutoff The recoverable oil equivalent per unit mass of shale is the lower limit, mg / g rock; V rock The effective heated shale volume controlled by a development well group or development unit, in m 3 ;ρ rock To effectively heat shale density, g / cm³ 3 .

18. The evaluation method for favorable areas for in-situ shale conversion and development according to claim 16, characterized in that, The evaluation method also includes: Based on the favorable strata for in-situ conversion development and the recoverable oil and gas resources per unit mass of shale in-situ conversion, the abundance of recoverable oil and gas resources is determined. Compare the economic lower limit of recoverable oil equivalent with the abundance of recoverable oil and gas resources in development well groups or development units; Areas with recoverable oil and gas resource abundance greater than or equal to the economic lower limit of recoverable oil equivalent of development well groups or development units are identified as favorable areas for in-situ shale conversion and development.

19. The evaluation method for favorable areas for in-situ shale conversion and development according to claim 18, characterized in that, The abundance of recoverable oil and gas resources is determined using the following formula: AOR=10 -7 ABOUT oil ×H shale ×ρ shale , AGR=10 -8 The gas ×H shale ×r shale , Where AOR represents recoverable oil resource abundance, 10 4 t / km 2 AGR represents recoverable gas resource abundance, 10 8 m 3 / km 2 Q oil Q represents the in-situ oil yield from shale conversion per unit mass, expressed in mg / g rock. gas The in-situ gas production from shale conversion per unit mass, expressed as ml / g rock; H shale The shale depth of the favorable in-situ transformation zone is in km; ρ shale Shale density in favorable in-situ transformation zones, g / cm³ 3 .

20. A device for evaluating the recoverable oil and gas resources from in-situ conversion of shale, characterized in that, The evaluation device includes: The acquisition module is used to acquire in-situ thermal simulation experimental data of shale under different fluid pressure conditions, in-situ thermal simulation experimental data of crude oil under different hydrocarbon expulsion pressure conditions, and Fischer analysis experimental data of shale under different thermal evolution degrees. The in-situ thermal simulation experimental data of shale includes: total organic carbon content, vitrinite reflectance, thermal simulation oil and gas production, and retained oil and gas volume. The in-situ thermal simulation experimental data of crude oil includes: crude oil density, the proportion of produced oil to the original oil used in thermal simulation, and the gas production per unit mass of thermal simulation oil. The Fischer analysis experimental data of shale includes: the amount of oil and gas generated per unit of total organic carbon content. The first construction module is used to construct a prediction model for the amount of oil and gas produced by the in-situ conversion of shale based on experimental data of thermal simulation of shale conversion under different fluid pressure conditions and experimental data of shale Fischer analysis under different thermal evolution degrees. The second construction module is used to construct a prediction model for the amount of retained oil and gas based on shale in-situ conversion heat simulation experimental data under predetermined fluid pressure conditions. The third module is used to construct a prediction model for the amount of oil and gas produced by the in-situ conversion of crude oil based on experimental data of in-situ conversion heat simulation of crude oil under different hydrocarbon expulsion pressure conditions. The fourth construction module is used to construct a prediction model for the amount of oil and gas produced by in-situ shale conversion based on the prediction models for oil and gas production from in-situ shale conversion, the prediction model for oil and gas retention, and the prediction model for oil and gas production from in-situ crude oil conversion. The first determination module is used to determine the recoverable oil and gas resources per unit mass of shale in-situ conversion based on a prediction model for oil and gas production per unit mass of shale in-situ conversion.

21. An evaluation device for favorable areas of in-situ shale conversion and development, characterized in that, The evaluation device includes: The second determining module is used to determine the unit mass of recoverable oil and gas resources of the target layer to be evaluated by the evaluation method of recoverable oil and gas resources of shale in situ conversion as described in any one of claims 1 to 14. The third determining module is used to determine the lower limit of recoverable oil equivalent per unit mass of shale based on the in-situ conversion and development parameter values ​​of shale; the in-situ conversion and development parameter values ​​of shale include: the average fixed investment, average operating cost, average tax and fee, average reclamation cost, average abandonment cost, average sunk cost, average oil and gas sales price, and average oil and gas commodity rate of the development well group or development unit during the in-situ conversion production cycle; The comparison module is used to compare the lower limit of recoverable oil equivalent per unit mass of shale and the recoverable oil and gas resources per unit mass of shale converted in situ. The fourth determination module is used to identify areas where the recoverable oil equivalent per unit mass of shale in situ conversion is greater than the lower limit of the recoverable oil equivalent per unit mass of shale as favorable strata for in situ conversion development.

22. An electronic device, characterized in that, The electronic device includes a processor and a memory, wherein the memory stores at least one computer program, which is loaded and executed by one or more processors to enable the processor to perform the evaluation method for recoverable oil and gas resources in shale in-situ conversion as described in any one of claims 1 to 14, or the evaluation method for favorable development areas of shale in-situ conversion as described in any one of claims 15 to 19.

23. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores at least one piece of program code, which is loaded and executed by a processor to enable the computer to perform the evaluation method for recoverable oil and gas resources in shale in-situ conversion as described in any one of claims 1 to 14, or the evaluation method for favorable development areas of shale in-situ conversion as described in any one of claims 15 to 19.

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