CN115964842A - A method and system for determining the amount of natural gas hydrate resources - Google Patents

Abstract

The invention provides a method and a system for determining natural gas hydrate resource amount. The method comprises the following steps: obtaining the thickness and the area of a sedimentary rock stratum of a natural gas hydrate stability zone of a target area, the volume factor of the natural gas hydrate, the thickness and the area of the sedimentary rock stratum where a conventional oil and gas resource is located and the volume factor of the natural gas; acquiring the proportion of gaseous hydrocarbons in a target area; determining the proportion of the natural gas hydrate in the conventional oil and gas resources in a target region based on the thickness and the area of the sedimentary rock formation of the natural gas hydrate stability zone, the volume factor of the natural gas hydrate, the thickness and the area of the sedimentary rock formation where the conventional oil and gas resources are located, the volume factor of the natural gas and the proportion of gaseous hydrocarbon; acquiring the conventional petroleum and natural gas resource quantity and the conventional heavy oil and asphalt resource quantity of a target area; and determining the natural gas hydrate resource amount of the target region based on the conventional petroleum and natural gas resource amount, the conventional heavy oil and asphalt resource amount and the ratio of the natural gas hydrate in the conventional oil gas resource of the target region.

Description

A method and system for determining the amount of natural gas hydrate resources

technical field

The invention relates to the technical field of natural gas hydrate exploration, in particular to a method and system for determining the amount of natural gas hydrate resources.

Background technique

Natural gas hydrate (NGH) is considered to be a new resource to replace traditional oil and gas resources in the future. Its global resource potential assessment has always been a matter of concern. Due to the uncertainty of the gas hydrate stable zone (GHSZ) and other resource assessment parameters, the global gas hydrate resource assessment research progress is slow, which has become an urgent problem to be solved. Based on different research areas and evaluation methods, predecessors have made at least 29 sets of published evaluation results on global gas hydrate resources, and the difference between the estimated results is as high as 10,000 times. In order to further reduce the uncertainty of global gas hydrate resource assessment, previous scholars have successively proposed different methods, from the analysis of the main controlling factors of the distribution of hydrate stable zones, to accurate observation models and function calculations to reduce the Great progress has been made in assessing the uncertainties in global hydrate resource assessments.

From 1973 to 1981, based on very few real data and imaginary parameters, some scholars believed that the maximum global gas hydrate resource was estimated to exceed 1.67×10 ¹⁸ m ³ , and scholars were very optimistic about the resource potential of gas hydrate. manner. In 1982, some scholars began to study the resources of gas hydrate in the global marine environment, and determined that hydrates would not exist in areas with a water depth less than 500m, which reduced the analogy of the global gas hydrate resources to the original half. In 1991, some scholars began to apply geological survey and geological exploration to the prediction of favorable areas of gas hydrate in the marine environment. The seabed simulated reflector (BSR), which represents the anomaly reflected in the seismic section between the gas hydrate-bearing formation in the seafloor formation and the underlying gas hydrate-free formation, is used to determine the existence area of gas hydrate, which makes the global The analogy result of natural gas hydrate resources was reduced to 1/4 of the original result again. In 1999, some scholars revealed that the degradation of organic matter in sedimentary strata is the source of gas in natural gas hydrate reservoirs, and gas and water form a "cage-like "The structure of solid combustible ice remains stable only under specific high-pressure and low-temperature conditions, which limits the gas hydrate stable zone to the hydrate stable zone (GHSZ) in the earth's poles, plateau permafrost and deep-sea sedimentary basins, making the global The evaluation results of natural gas hydrate resources were further reduced to 1/3 of the original. From 2009 to 2016, some scholars proposed the recoverable hydrate resources, limiting the hydrates accumulated in high-porosity and high-permeability formations as recoverable resources Further assessment shows that recoverable resources only account for less than 18% of the total global hydrate resources. In recent years, with the advancement of physical simulation experiments and field test production, the technical recovery rate of natural gas hydrate has been determined to be 15% to 70%, with an average of 30%, and the global recoverable resources of natural gas hydrate have been further reduced to the original 1/3 of.

In the above assessment, it can be found that as time goes by, the progress of scientific and technological research and the improvement of methods seem to lead to the gradual reduction of the assessment results of NGH potential resources. When evaluating NGH resources, due to its distribution characteristics of high pressure and low temperature, it is inevitable to determine the area and thickness of the GHSZ, as well as the porosity, permeability and hydrate saturation of the GHSZ rock formation. In general, previous studies were based on measured or simulated data in a certain area, and calculated the potential resources of gas hydrate in the area through the data of GHSZ rock formation volume, porosity, permeability, and hydrate saturation in the study area. The global natural gas hydrate potential resources can be estimated by field data extrapolation method or model function calculation method. However, the variability of the above-mentioned data leads to inaccurate assessment results, and there are huge differences among the assessment results, and it is difficult to improve the accuracy of the assessment results with the existing technical level and exploration level. In addition, previous studies considered all hydrates in the GHSZ as potential resources, but did not distinguish the dispersed hydrates in mudstone from the enriched hydrate resources in high porosity and permeability reservoirs, resulting in an overestimated evaluation result.

With the current level of technology and exploration, it is basically impossible to accurately evaluate the global gas hydrate resources. Some scholars have found in their research that organic matter degradation gas in formations below the GHSZ is an important source of gas in hydrates in the GHSZ, which reflects that deep source rocks in oil-gas-rich basins can migrate to the hydrate stable zone after gas is discharged. Gas hydrates form "cage" hydrates with water, and 1/3 of the 13 hydrate exploration wells in the world have confirmed that the gas in the hydrates comes from the degradation of organic matter in deep source rocks, proving that natural gas hydrates, like conventional oil and gas resources, are the A special category in oil and gas systems. Since natural gas hydrate has many characteristics in common with conventional oil and gas resources, for example, both are formed in the free dynamic field, driven by buoyancy as the driving force for migration and accumulation, and the hydrocarbons in the two resources are derived from hydrocarbon sources. The degradation of organic matter in rocks and the basic characteristics of high porosity and high permeability in reservoirs make the evaluation of gas hydrate resources comparable to the evaluation methods and ideas of conventional oil and gas resources. Based on this, the present invention proposes a method for evaluating natural gas hydrate resource amount based on conventional oil and gas resource analogy.

Contents of the invention

In order to solve the problem of difficult and low-precision evaluation of natural gas hydrate resources and provide important technical support for the evaluation of hydrate resource potential and energy prospects, the purpose of the present invention is to provide a method and system capable of determining natural gas hydrate resources.

In order to achieve the above object, the present invention provides technical solutions in the following four aspects.

In a first aspect, the present invention provides a method for determining the amount of natural gas hydrate resources, wherein the method includes:

Obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area;

Obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the natural gas volume factor; wherein, the conventional oil and gas resources refer to oil and gas resources generated by organic matter, distributed in a free dynamic field, and using buoyancy as the driving force for migration;

Obtain the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Determine the target based on the thickness and area of the sedimentary rock layer in the gas hydrate stable zone in the target area, the gas hydrate volume factor, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, the natural gas volume factor, and the proportion of gaseous hydrocarbons in the target area. The proportion of regional gas hydrate in conventional oil and gas resources;

Acquire conventional oil and gas resources and conventional heavy oil and asphalt resources in the target area; wherein, the conventional oil and gas resources refer to those produced by organic matter, distributed in the free power field, and buoyant as the driving force, without Biodegradable oil and natural gas resources, conventional heavy oil and bitumen resources refer to biodegraded heavy oil and bitumen resources that are generated from organic matter, distributed in the free dynamic field, and driven by buoyancy;

Based on the amount of conventional oil and gas resources, conventional heavy oil and bitumen resources, and the proportion of gas hydrate in conventional oil and gas resources in the target area, determine the amount of gas hydrate resources in the target area.

According to a preferred implementation of the first aspect, wherein obtaining the proportion of gaseous hydrocarbons in the target area includes:

Obtain the ratio of the amount of gas generated by source rocks with organic matter type III in the target area to the total amount of hydrocarbons generated in the biochemical gas generation stage (Ro<0.5%), which is the first ratio; obtain the proven conventional oil and gas in the target area The ratio of gas volume to total hydrocarbon volume in the reservoir is the second ratio;

The weighted average value of the ratio of gaseous hydrocarbons to total hydrocarbons generated by source rocks of type I, type II and type III organic matter in the free dynamic field of the target area in the biological gas generation stage and thermal gas generation stage is the second Three ratios;

Determine the proportion of gaseous hydrocarbons in the target area based on the first ratio, the second ratio, and the third ratio; wherein, the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio;

Preferably, the third ratio is used as the initial value of the proportion of gaseous hydrocarbons in the target area, and the initial value of the proportion of gaseous hydrocarbons in the target area is corrected by using the first ratio and the second ratio to obtain the proportion of gaseous hydrocarbons in the target area; wherein, when the target area When the initial value of the proportion of gaseous hydrocarbons is less than or equal to the first ratio and greater than or equal to the second ratio, the proportion of gaseous hydrocarbons in the target area is the initial value of the proportion of gaseous hydrocarbons in the target area; when the initial value of the proportion of gaseous hydrocarbons in the target area is greater than the first ratio , the proportion of gaseous hydrocarbons in the target area is the first ratio; when the initial value of the proportion of gaseous hydrocarbons in the target area is less than the second ratio, the proportion of gaseous hydrocarbons in the target area is the second ratio.

According to a preferred implementation of the first aspect, wherein the proportion of natural gas hydrate in conventional oil and gas resources is determined by the following formula:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; B _gh is the volume factor of gas hydrate, which represents the ratio of the volume of methane hydrate under standard surface conditions to the volume of gas hydrate under reservoir conditions , the unit is dimensionless; B _g is the natural gas volume factor, which means the ratio of the natural gas volume under the standard surface condition to the natural gas volume under the reservoir condition, the unit is dimensionless; A _GHSZ is the area of the sedimentary rock in the gas hydrate stable zone, the unit is 10 ⁶ km ² ; H _GHSZ is the thickness of the sedimentary rock in the gas hydrate stable zone, unit m; A _conv is the area of the sedimentary rock where the conventional oil and gas resources are located, and the unit is 10 ⁶ km ² ; H _conv is the sedimentary rock where the conventional oil and gas resources are located thickness, in m; g is the proportion of gaseous hydrocarbons, in %.

According to a preferred embodiment of the first aspect, wherein, the natural gas hydrate resource amount determination model is used to determine the natural gas hydrate resource amount; wherein, the natural gas hydrate resource amount determination model is the natural gas hydrate resource amount relative to the natural gas hydrate in conventional oil and gas resources The calculation model of the proportion of conventional oil and natural gas resources, conventional heavy oil and bitumen resources;

Preferably, the gas hydrate resource determination model is:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), unit: 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), unit: 10 ¹² m ³ .

In the second aspect, the present invention provides a system for determining the amount of natural gas hydrate resources, wherein the system includes:

Gas hydrate parameter acquisition module: used to obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area;

Oil and gas resource parameter acquisition module: used to obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor; wherein, the conventional oil and gas resources refer to those generated by organic matter, distributed in the free dynamic field, and buoyant Oil and gas resources for the movement of power;

The proportion acquisition module of gaseous hydrocarbons: used to obtain the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Natural gas hydrate proportion acquisition module: used for the thickness and area of the sedimentary rock layer and the natural gas hydrate volume factor based on the gas hydrate stable zone in the target area, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor, and the proportion of gaseous hydrocarbons in the target area to determine the proportion of gas hydrate in the conventional oil and gas resources in the target area;

Conventional energy quantity acquisition module: used to obtain conventional oil and gas resources and conventional heavy oil and bitumen resources in the target area; wherein, the conventional oil and gas resources refer to those generated by organic matter, distributed in the free dynamic field, and buoyant For the transportation of dynamic, non-biodegradable oil and gas resources, conventional heavy oil and bitumen resources refer to the biodegraded heavy oil produced by organic matter, distributed in the free dynamic field, and driven by buoyancy. Quality oil and bitumen resources;

Natural gas hydrate resources acquisition module: used to determine the natural gas hydrate resources in the target area based on the conventional oil and natural gas resources, conventional heavy oil and bitumen resources, and the proportion of natural gas hydrate in conventional oil and gas resources in the target area.

According to a preferred implementation of the second aspect, wherein the gaseous hydrocarbon proportion acquisition module includes:

The first ratio acquisition sub-module: used to obtain the ratio of the amount of gas generated by the source rock with type III organic matter in the target area during the biochemical gas generation stage (Ro<0.5%) to the total amount of hydrocarbon generated is the first ratio;

The second ratio acquisition sub-module: used to obtain the ratio of the gas amount to the total hydrocarbon amount in the proven conventional oil and gas reservoirs in the target area is the second ratio;

The third ratio acquisition sub-module: used to obtain the gaseous hydrocarbons and total hydrocarbons generated by source rocks with organic matter types of type I, type II and type III in the free dynamic field of the target area in the biological gas generation stage and thermal gas generation stage The weighted average of the ratios is the third ratio;

The sub-module for determining the proportion of gaseous hydrocarbons: used to determine the proportion of gaseous hydrocarbons in the target area based on the first ratio, the second ratio and the third ratio; wherein, the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio;

Preferably, the sub-module for determining the proportion of gaseous hydrocarbons is used to use the third ratio as the initial value of the proportion of gaseous hydrocarbons in the target area, and use the first and second ratios to correct the initial value of the proportion of gaseous hydrocarbons in the target area to obtain the gaseous hydrocarbons in the target area. Proportion of hydrocarbons; Wherein, when the initial value of the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio, the proportion of gaseous hydrocarbons in the target area is the initial value of the proportion of gaseous hydrocarbons in the target area; when the proportion of gaseous hydrocarbons in the target area When the initial ratio is greater than the first ratio, the ratio of gaseous hydrocarbons in the target area is the first ratio; when the initial ratio of gaseous hydrocarbons in the target area is smaller than the second ratio, the ratio of gaseous hydrocarbons in the target area is the second ratio.

According to a preferred implementation of the second aspect, wherein the gas hydrate proportion acquisition module determines the proportion of natural gas hydrate in conventional oil and gas resources through the following formula:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; B _gh is the volume factor of gas hydrate, which represents the ratio of the volume of methane hydrate under standard surface conditions to the volume of gas hydrate under reservoir conditions , the unit is dimensionless; B _g is the natural gas volume factor, which means the ratio of the natural gas volume under the standard surface condition to the natural gas volume under the reservoir condition, the unit is dimensionless; A _GHSZ is the area of the sedimentary rock in the gas hydrate stable zone, the unit is 10 ⁶ km ² ; H _GHSZ is the thickness of the sedimentary rock in the gas hydrate stable zone, unit m; A _conv is the area of the sedimentary rock where the conventional oil and gas resources are located, and the unit is 10 ⁶ km ² ; H _conv is the sedimentary rock where the conventional oil and gas resources are located thickness, in m; g is the proportion of gaseous hydrocarbons, in %.

According to the preferred implementation of the second aspect, wherein, the natural gas hydrate resource amount acquisition module determines the natural gas hydrate resource amount using a natural gas hydrate resource amount determination model; wherein, the natural gas hydrate resource amount determination model is the natural gas hydrate resource amount relative to natural gas Calculation models for the proportion of hydrates in conventional oil and gas resources, the amount of conventional oil and gas resources, and the amount of conventional heavy oil and bitumen resources;

Preferably, the gas hydrate resource determination model is:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ .

In a third aspect, the present invention provides an electronic device, including a processor, a memory, and a computer program stored on the memory and operable on the processor. When the processor executes the program, the steps of the method for determining the natural gas hydrate resource amount are implemented.

In a fourth aspect, the present invention provides a computer-readable storage medium, on which a computer program is stored, and when the computer program is executed by a processor, the steps of the method for determining natural gas hydrate resources are implemented.

The technical solution provided by the present invention effectively solves the problem of evaluating natural gas hydrate resources, solves the problem of low reliability of natural gas hydrate resource evaluation caused by low exploration degree, low exploration technology, and lack of exploration data in the past, and can be more Obtaining the amount of natural gas hydrate resources objectively and more accurately has great guiding significance for the research on the resource potential and energy prospects of natural gas hydrates.

Description of drawings

Fig. 1 is a flowchart of a method for determining the amount of natural gas hydrate resources in an embodiment.

Fig. 2 is a frame diagram of a system for determining natural gas hydrate resources in an embodiment.

FIG. 3 is a statistical diagram of the area A _GHSZ distribution of sedimentary rock layers in the global gas hydrate stable zone in Example 1. FIG.

FIG. 4 is a statistical diagram of the distribution of the thickness H _GHSZ of sedimentary rock layers in the global gas hydrate stability zone in Example 1.

Fig. 5 is a statistical diagram of the distribution g of the proportion of gaseous hydrocarbons of natural gas hydrate in the world in Example 1.

Fig. 6 is a graph showing the gas to total hydrocarbon ratio of different organic matter types of source rocks in the biochemical gas generation stage (Ro<0.5%) in Example 1.

Fig. 7 is a diagram of the ratio of gas to total hydrocarbons in the world's proven conventional oil and gas reservoirs in Example 1.

Fig. 8 is a graph showing the ratios of gaseous hydrocarbons and total hydrocarbons in the amount of hydrocarbons generated by source rocks with Type I, Type II and Type III kerogens in the biogas generation and thermal gas generation stages in the free dynamic field.

Detailed ways

In order to make the purpose, technical solutions and advantages of the embodiments of the present invention more clear, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Apparently, the described embodiments are some, not all, embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by persons of ordinary skill in the art without making creative efforts belong to the protection scope of the present invention.

The inventor incorporated natural gas hydrate resources into the global oil and gas system, conducted unified analysis and research, established a unified model and mass balance equation between the amount of NGH resources and conventional oil and gas resources, comprehensively compared conventional oil and gas evaluation parameters and 29 groups of predecessors Based on the evaluation results of natural gas hydrate, a method for evaluating the amount of natural gas hydrate resources based on the analogy of conventional oil and gas resources is proposed to solve the problem of difficult and low-precision evaluation of global natural gas hydrate resources, and to evaluate the potential of hydrate resources and energy prospects. Provide new ideas. The technical solutions provided by the present invention are explained below by listing some specific embodiments.

Referring to Fig. 1, a specific embodiment of the present invention provides a method for determining the amount of natural gas hydrate resources, wherein the method includes:

Step S1: Obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor in the gas hydrate stable zone in the target area;

Step S2: Obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor; wherein, the conventional oil and gas resources refer to those produced by organic matter, distributed within the free dynamic field, and using buoyancy as the driving force for migration oil and gas resources;

Step S3: Obtain the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Step S4: Based on the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area, the thickness and area of the sedimentary rock layer and the natural gas volume factor where the conventional oil and gas resources in the target area are located, and the proportion of gaseous hydrocarbons in the target area , to determine the proportion of gas hydrate in conventional oil and gas resources in the target area;

Step S5: Obtain the amount of conventional oil and natural gas resources and the amount of conventional heavy oil and asphalt resources in the target area; wherein, the conventional oil and natural gas resources refer to those produced by organic matter, distributed in the free dynamic field, and driven by buoyancy , Oil and natural gas resources without biodegradation, conventional heavy oil and bitumen resources refer to biodegraded heavy oil and bitumen resources that are generated from organic matter, distributed in the free dynamic field, and driven by buoyancy ;

Step S6: Based on the amount of conventional oil and natural gas resources in the target area, the amount of conventional heavy oil and asphalt resources, and the proportion of gas hydrate in conventional oil and gas resources, determine the amount of natural gas hydrate resources in the target area.

The above method of natural gas hydrate resources solves the disadvantages of insufficient geological theory and large errors in evaluation methods in the past, and achieves predictions with geological basis and high reliability; predictions with advanced technology and high accuracy; predictions with new ideas, It is highly innovative; moreover, this method only uses the commonly used evaluation parameters in conventional oil and gas evaluation to obtain data, and the operation process is simple and quick. In general, this method has the following advantages: (1) sufficient geological basis and high reliability; (2) distinct technical characteristics and high accuracy; (3) complete and clear thinking and strong innovation; (4) simple data Easy to get, strong maneuverability.

In one embodiment, step S3, obtaining the proportion of gaseous hydrocarbons in the target area includes:

Step S31: Obtain the ratio of the amount of gas generated in the biochemical gas generation stage (Ro<0.5%) of source rocks with type III organic matter in the target area to the total amount of hydrocarbons generated, which is the first ratio; the first ratio is the parameter gas state A possible upper limit for the hydrocarbon fraction;

Step S32: Obtain the ratio of the gas volume to the total hydrocarbon volume in the proven conventional oil and gas reservoirs in the target area, which is the second ratio; the second ratio is the possible lower limit of the parameter gaseous hydrocarbon ratio;

Step S33: Obtain the weighted average of the ratios of gaseous hydrocarbons and total hydrocarbons produced by source rocks with organic matter types I, II and III in the free dynamic field of the target area in the biological gas generation stage and thermal gas generation stage is the third ratio;

Step S34: Determine the proportion of gaseous hydrocarbons in the target area based on the first ratio, the second ratio and the third ratio; wherein, the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio;

For example, the third ratio is used as the initial value of the proportion of gaseous hydrocarbons in the target area, and the initial value of the proportion of gaseous hydrocarbons in the target area is corrected by using the first and second ratios to obtain the proportion of gaseous hydrocarbons in the target area; where, when the gaseous hydrocarbons in the target area When the initial value of the proportion of hydrocarbons is less than or equal to the first ratio and greater than or equal to the second ratio, the proportion of gaseous hydrocarbons in the target area is the initial value of the proportion of gaseous hydrocarbons in the target area; when the initial value of the proportion of gaseous hydrocarbons in the target area is greater than the first ratio, The proportion of gaseous hydrocarbons in the target area is the first ratio; when the initial value of the proportion of gaseous hydrocarbons in the target area is less than the second ratio, the proportion of gaseous hydrocarbons in the target area is the second ratio;

For example, the ratio of gaseous hydrocarbons to total hydrocarbons generated by source rocks with type I organic matter in the biogas generation stage in the free dynamic field of the target area, and the ratio of total hydrocarbons generated by source rocks with type I organic matter in the The ratio of gaseous hydrocarbons generated to total hydrocarbons generated, the ratio of gaseous hydrocarbons generated to total hydrocarbons generated by source rocks with type II organic matter in the biogas generation stage, and the source rocks with type II organic matter The ratio of gaseous hydrocarbons to total hydrocarbons generated in the biogas generation stage, the ratio of gaseous hydrocarbons to total hydrocarbons generated in the biogas generation stage of source rocks with type III organic matter, and the ratio of source rocks with type III organic matter in thermal The ratio of the gaseous hydrocarbons generated in the gas generation stage to the total hydrocarbons generated is a weighted average of the above ratios to obtain the third ratio.

In one embodiment, in step S4, the proportion of natural gas hydrate in conventional oil and gas resources is determined by the following formula:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; B _gh is the volume factor of gas hydrate, which represents the ratio of the volume of methane hydrate under standard surface conditions to the volume of gas hydrate under reservoir conditions , the unit is dimensionless; B _g is the natural gas volume factor, which means the ratio of the natural gas volume under the standard surface condition to the natural gas volume under the reservoir condition, the unit is dimensionless; A _GHSZ is the area of the sedimentary rock in the gas hydrate stable zone, the unit is 10 ⁶ km ² ; H _GHSZ is the thickness of the sedimentary rock in the gas hydrate stable zone, in m; A _conv is the area of the sedimentary rock where the conventional oil and gas resources are located, and the unit is 10 ⁶ km ² ; H _conv is the sedimentary rock where the conventional oil and gas resources are located thickness, in m; g is the proportion of gaseous hydrocarbons, in %.

In one embodiment, in step S6, the natural gas hydrate resource determination model is used to determine the natural gas hydrate resource amount; wherein, the natural gas hydrate resource amount determination model is the natural gas hydrate resource amount relative to the proportion of natural gas hydrate in conventional oil and gas resources , Calculation models of conventional oil and gas resources, conventional heavy oil and asphalt resources;

Further, the determination model of natural gas hydrate resources is:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ ;

Among them, the above-mentioned natural gas hydrate resource determination model is preferably established in the following way:

Like other oil and gas resources, the hydrocarbons of gas hydrates come from the degradation of deep organic matter, and gas hydrate resources are included in the oil and gas system; the oil and gas system includes all source rocks on the surface and the related hydrocarbon migration and accumulation process, and the oil and gas system The types of oil and gas resources included include conventional oil and gas resources, unconventional oil and gas resources and shale oil and gas resources; according to the principle of mass balance, the total oil and gas generated by conventional oil and gas resources, unconventional oil and gas resources, shale oil and gas resources and source rocks in the oil and gas system are established Related models for resources:

Q _C + Q _U + Q _S ≤ Q _P

In the formula, Q _C is the amount of conventional oil and gas resources; Q _U is the amount of unconventional oil and gas resources; Q _S is the amount of shale oil and gas resources; Q _P is the total amount of generated oil and gas resources;

Gas hydrate has the same characteristics as conventional oil and gas resources, conventional heavy oil and bitumen resources in terms of hydrocarbon source, migration and accumulation dynamics and process, and reservoir characteristics. In addition, gas hydrate Only stored in the stable zone of high pressure and low temperature, natural gas hydrate can be considered as a special conventional oil and gas resource accumulated in high pressure and low temperature reservoirs; based on this, the establishment of natural gas hydrate resources, conventional oil and gas resources and conventional Related models of heavy oil and bitumen resources:

Q _C ＝Q _C1 +Q _C2 +Q _C3 ≤Q _EC

In the formula, Q _C1 is the amount of natural gas hydrate resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is the amount of conventional oil and gas Quality oil and bitumen resources (in gas equivalent), unit 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent ), unit, 10 ¹² m ³ ; Q _C is conventional oil and gas resources (in gas equivalent), unit 10 ¹² m ³ ;

Based on the related models of gas hydrate resources, conventional oil and gas resources, and conventional heavy oil and bitumen resources, a unified model and mass balance equation between gas hydrate resources and conventional oil and gas resources are established:

Q _C1 ＝Q _C -Q _C2 -Q _C3 ＝f×Q _C

In the formula, Q _C1 is the amount of natural gas hydrate resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is the amount of conventional oil and gas Quality oil and bitumen resources (in gas equivalent), unit 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent ), the unit is 10 ¹² m ³ ; Q _C is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; f is the proportion of gas hydrate in conventional oil and gas resources, the unit is %;

Based on the unified model and mass balance equation between gas hydrate resources and conventional oil and gas resources, the determination model of gas hydrate resources is established as follows:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ ;

In short, the above-mentioned gas hydrate resource determination model is based on the oil and gas system, and three types of conventional oil and gas resources (gas hydrate resources , conventional oil and natural gas resources, conventional heavy oil and asphalt resources) for unified analysis and model construction, based on the principle of material balance; the above-mentioned gas hydrate resource determination model can reflect the natural gas hydrate resource and conventional oil and natural gas resources , The mass balance relationship between conventional heavy oil and bitumen resources can realize the reliable evaluation of the gas hydrate resources in the target area (including the global regional gas hydrate resources).

In one embodiment, in step S5, obtaining conventional oil and natural gas resources and conventional heavy oil and asphalt resources in the target area is achieved by the following methods:

Based on expert assessments in the field of petroleum geology and exploration and data from world authoritative petroleum institutions, determine the amount of conventional oil and gas resources, conventional heavy oil and asphalt resources in the target area.

In one embodiment, in step S1, obtaining the thickness and area of the sedimentary rock layer in the gas hydrate stable zone in the target area and the volume factor of the gas hydrate are achieved in the following manner:

According to the published evaluation results of gas hydrate resources in the target area, the thickness and area of the sedimentary rock layer and the volume factor of gas hydrate in the gas hydrate stable zone of the target area are determined through mathematical statistical analysis methods.

In one embodiment, in step S2, obtaining the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the volume factor of natural gas are achieved by the following methods:

According to the authoritative data of the oil and gas industry in the target area, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the natural gas volume factor are determined through mathematical statistical analysis methods.

The embodiment of the present invention also provides a specific implementation of a system for determining the amount of natural gas hydrate resources, and the system is used to implement the above-mentioned embodiment of the method for determining the amount of natural gas hydrate resources. Referring to Figure 2, the system includes:

Gas hydrate parameter acquisition module 21: used to obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area;

Oil and gas resource parameter acquisition module 22: used to obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the natural gas volume factor; wherein, the conventional oil and gas resources refer to those generated by organic matter, distributed within the free dynamic field, and Oil and gas resources with buoyancy as the driving force;

Gaseous hydrocarbon proportion acquisition module 23: used to acquire the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Gas hydrate proportion acquisition module 24: used for the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor , and the proportion of gaseous hydrocarbons in the target area to determine the proportion of gas hydrate in the conventional oil and gas resources in the target area;

Conventional energy quantity acquisition module 25: used to obtain conventional oil and gas resources and conventional heavy oil and asphalt resources in the target area; wherein, the conventional oil and gas resources refer to those generated by organic matter, distributed within the free power field, and Buoyancy refers to non-biodegraded petroleum and natural gas resources that are driven by buoyancy. Conventional heavy oil and asphalt resources refer to the biodegraded resources that are generated from organic matter, distributed in the free dynamic field, and powered by buoyancy. Heavy oil and bitumen resources;

Natural gas hydrate resource acquisition module 26: used to determine the natural gas hydrate resource in the target area based on the conventional oil and gas resources, conventional heavy oil and bitumen resources, and the proportion of natural gas hydrate in conventional oil and gas resources in the target area .

In one embodiment, the gaseous hydrocarbon proportion acquisition module 23 includes:

The first ratio acquisition sub-module 231: used to obtain the ratio of the amount of gas generated by the source rock with organic matter type III in the target area during the biochemical gas generation stage (Ro<0.5%) to the total amount of hydrocarbon generated is the first ratio ; The first ratio is a possible upper limit of the proportion of parameter gaseous hydrocarbons;

The second ratio acquisition sub-module 232: used to obtain the ratio of the gas amount to the total hydrocarbon amount in the proven conventional oil and gas reservoirs in the target area is the second ratio; the second ratio is the possible lower limit of the parameter gaseous hydrocarbon ratio;

The third ratio acquisition sub-module 233: used to acquire the gaseous hydrocarbons and the total gaseous hydrocarbons produced in the biological gas generation stage and thermal gas generation stage of source rocks with organic matter types of type I, type II and type III in the free dynamic field of the target area The weighted average of the ratio of hydrocarbons is the third ratio;

The proportion determination sub-module 234 of gaseous hydrocarbons: used to determine the proportion of gaseous hydrocarbons in the target area based on the first ratio, the second ratio and the third ratio; wherein, the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio ;

Further, the sub-module 234 for determining the proportion of gaseous hydrocarbons is specifically used to use the third ratio as the initial value of the proportion of gaseous hydrocarbons in the target area, and use the first and second ratios to correct the initial value of the proportion of gaseous hydrocarbons in the target area to obtain the target The proportion of gaseous hydrocarbons in the region; when the initial value of the proportion of gaseous hydrocarbons in the target area is less than or equal to the first ratio and greater than or equal to the second ratio, the proportion of gaseous hydrocarbons in the target area is the initial value of the proportion of gaseous hydrocarbons in the target area; When the initial value of the proportion of gaseous hydrocarbons is greater than the first ratio, the proportion of gaseous hydrocarbons in the target area is the first ratio; when the initial value of the proportion of gaseous hydrocarbons in the target area is less than the second ratio, the proportion of gaseous hydrocarbons in the target area is the second ratio .

In one embodiment, the natural gas hydrate proportion acquisition module 24 determines the proportion of natural gas hydrate in conventional oil and gas resources by the following formula:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; B _gh is the volume factor of gas hydrate, which represents the ratio of the volume of methane hydrate under standard surface conditions to the volume of gas hydrate under reservoir conditions , the unit is dimensionless; B _g is the natural gas volume factor, which means the ratio of the natural gas volume under the standard surface condition to the natural gas volume under the reservoir condition, the unit is dimensionless; A _GHSZ is the area of the sedimentary rock in the gas hydrate stable zone, the unit is 10 ⁶ km ² ; H _GHSZ is the thickness of the sedimentary rock in the gas hydrate stable zone, unit m; A _conv is the area of the sedimentary rock where the conventional oil and gas resources are located, and the unit is 10 ⁶ km ² ; H _conv is the sedimentary rock where the conventional oil and gas resources are located thickness, in m; g is the proportion of gaseous hydrocarbons, in %.

In one embodiment, the natural gas hydrate resource amount acquisition module 26 uses the natural gas hydrate resource amount determination model to determine the natural gas hydrate resource amount; wherein, the natural gas hydrate resource amount determination model is the natural gas hydrate resource amount relative to the natural gas hydrate Calculation models for the proportion of oil and gas resources, the amount of conventional oil and gas resources, and the amount of conventional heavy oil and bitumen resources;

Further, the determination model of natural gas hydrate resources is:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ ;

Among them, the above-mentioned natural gas hydrate resource determination model is preferably established in the following way:

Like other oil and gas resources, the hydrocarbons of gas hydrates come from the degradation of deep organic matter, and gas hydrate resources are included in the oil and gas system; the oil and gas system includes all source rocks on the surface and the related hydrocarbon migration and accumulation process, and the oil and gas system The types of oil and gas resources included include conventional oil and gas resources, unconventional oil and gas resources and shale oil and gas resources; according to the principle of mass balance, the total oil and gas generated by conventional oil and gas resources, unconventional oil and gas resources, shale oil and gas resources and source rocks in the oil and gas system are established Related models for resources:

Q _C + Q _U + Q _S ≤ Q _P

In the formula, Q _C is conventional oil and gas resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _U is unconventional oil and gas resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _S is shale oil and gas The amount of resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _P is the total generated oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ;

Gas hydrate has the same characteristics as conventional oil and gas resources, conventional heavy oil and bitumen resources in terms of hydrocarbon source, migration and accumulation dynamics and process, and reservoir characteristics. In addition, gas hydrate Only stored in the stable zone of high pressure and low temperature, natural gas hydrate can be considered as a special conventional oil and gas resource accumulated in high pressure and low temperature reservoirs; based on this, the establishment of natural gas hydrate resources, conventional oil and gas resources and conventional Related models of heavy oil and bitumen resources:

Q _C ＝Q _C1 +Q _C2 +Q _C3 ≤Q _EC

In the formula, Q _C1 is natural gas hydrate resources (in gas equivalent), unit: 10 ¹² m ³ ; Q _C2 is conventional oil and natural gas resources (in gas equivalent), unit is 10 ¹² m; Q _C3 is conventional heavy Quality oil and bitumen resources (in gas equivalent), unit 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent ), the unit is 10 ¹² m ³ ; Q _C is conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ;

Based on the related models of gas hydrate resources, conventional oil and gas resources, and conventional heavy oil and bitumen resources, a unified model and mass balance equation between gas hydrate resources and conventional oil and gas resources are established:

Q _C1 ＝Q _C -Q _C2 -Q _C3 ＝f×Q _C

In the formula, Q _C1 is natural gas hydrate resources (in gas equivalent), unit: ×10 ¹² m ³ ; Q _C2 is conventional oil and natural gas resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C3 is Conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent). Equivalent), the unit is 10 ¹² m ³ ; Q _C is the amount of conventional oil and gas resources, the unit is 10 ¹² m ³ ; f is the proportion of gas hydrate in conventional oil and gas resources, the unit is %;

Based on the unified model and mass balance equation between gas hydrate resources and conventional oil and gas resources, the determination model of gas hydrate resources is established as follows:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ ;

In short, the above-mentioned gas hydrate resource determination model is based on the oil and gas system, and three types of conventional oil and gas resources (gas hydrate resources , conventional oil and natural gas resources, conventional heavy oil and asphalt resources) for unified analysis and model construction, based on the principle of material balance; the above-mentioned gas hydrate resource determination model can reflect the natural gas hydrate resource and conventional oil and natural gas resources , The mass balance relationship between conventional heavy oil and bitumen resources can realize the reliable evaluation of the gas hydrate resources in the target area (including the global regional gas hydrate resources).

In one embodiment, the conventional energy quantity acquisition module 25 acquires conventional oil and gas resources and conventional heavy oil and asphalt resources in the target area in the following manner:

Based on expert assessments in the field of petroleum geology and exploration and data from world authoritative petroleum institutions, determine the amount of conventional oil and gas resources, conventional heavy oil and asphalt resources in the target area.

In one embodiment, the gas hydrate parameter acquisition module 21 acquires the thickness and area of the sedimentary rock layer and the gas hydrate volume factor in the gas hydrate stable zone of the target area in the following manner:

According to the published evaluation results of gas hydrate resources in the target area, the thickness and area of the sedimentary rock layer and the volume factor of gas hydrate in the gas hydrate stable zone of the target area are determined through mathematical statistical analysis methods.

In one embodiment, the oil and gas resource parameter acquisition module 22 acquires the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the natural gas volume factor in the following manner:

According to the authoritative data of the oil and gas industry in the target area, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located and the natural gas volume factor are determined through mathematical statistical analysis methods.

Embodiments of the present invention also provide a specific implementation of an electronic device that can implement all the steps in the method for determining the amount of natural gas hydrate resources in the above embodiments. The electronic device specifically includes the following content:

Processor, memory, communication interface and bus;

Among them, the processor, the memory, and the communication interface complete the communication with each other through the bus; the communication interface is used to realize the information transmission between the server-side device and the client device and other related devices; the processor is used to call the computer program in the memory, and the processor When the computer program is executed, all the steps in the method for determining the amount of natural gas hydrate resources in the above embodiments are realized. For example, when the processor executes the computer program, the following steps are realized:

Step S1: Obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor in the gas hydrate stable zone in the target area;

Step S2: Obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor; wherein, the conventional oil and gas resources refer to those produced by organic matter, distributed within the free dynamic field, and using buoyancy as the driving force for migration oil and gas resources;

Step S3: Obtain the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Step S4: Based on the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area, the thickness and area of the sedimentary rock layer and the natural gas volume factor where the conventional oil and gas resources in the target area are located, and the proportion of gaseous hydrocarbons in the target area , to determine the proportion of gas hydrate in conventional oil and gas resources in the target area;

Step S5: Obtain the amount of conventional oil and natural gas resources and the amount of conventional heavy oil and asphalt resources in the target area; wherein, the conventional oil and natural gas resources refer to those produced by organic matter, distributed in the free dynamic field, and driven by buoyancy , Oil and natural gas resources without biodegradation, conventional heavy oil and bitumen resources refer to biodegraded heavy oil and bitumen resources that are generated from organic matter, distributed in the free dynamic field, and driven by buoyancy ;

Step S6: Based on the amount of conventional oil and natural gas resources in the target area, the amount of conventional heavy oil and asphalt resources, and the proportion of gas hydrate in conventional oil and gas resources, determine the amount of natural gas hydrate resources in the target area.

Embodiments of the present invention also provide a computer-readable storage medium capable of implementing all the steps in the method for determining the amount of natural gas hydrate resources in the above-mentioned embodiments. A computer program is stored on the computer-readable storage medium, and the computer program is processed When the processor is executed, all the steps of the method for determining the amount of natural gas hydrate resources in the above embodiments are realized. For example, when the processor executes the computer program, the following steps are realized:

Step S1: Obtain the thickness and area of the sedimentary rock layer and the gas hydrate volume factor in the gas hydrate stable zone in the target area;

Step S2: Obtain the thickness and area of the sedimentary rock layer where the conventional oil and gas resources in the target area are located, and the natural gas volume factor; wherein, the conventional oil and gas resources refer to those produced by organic matter, distributed within the free dynamic field, and using buoyancy as the driving force for migration oil and gas resources;

Step S3: Obtain the proportion of gaseous hydrocarbons in the target area; wherein, the proportion of gaseous hydrocarbons refers to the proportion of gaseous hydrocarbons in the discharged hydrocarbons;

Step S4: Based on the thickness and area of the sedimentary rock layer and the gas hydrate volume factor of the gas hydrate stable zone in the target area, the thickness and area of the sedimentary rock layer and the natural gas volume factor where the conventional oil and gas resources in the target area are located, and the proportion of gaseous hydrocarbons in the target area , to determine the proportion of gas hydrate in conventional oil and gas resources in the target area;

Step S5: Obtain the amount of conventional oil and natural gas resources and the amount of conventional heavy oil and asphalt resources in the target area; wherein, the conventional oil and natural gas resources refer to those produced by organic matter, distributed in the free dynamic field, and driven by buoyancy , Oil and natural gas resources without biodegradation, conventional heavy oil and bitumen resources refer to biodegraded heavy oil and bitumen resources that are generated from organic matter, distributed in the free dynamic field, and driven by buoyancy ;

Step S6: Based on the amount of conventional oil and natural gas resources in the target area, the amount of conventional heavy oil and asphalt resources, and the proportion of gas hydrate in conventional oil and gas resources, determine the amount of natural gas hydrate resources in the target area.

Example 1

The following takes the whole world as the target area, and uses the method for determining the natural gas hydrate resource amount provided by the present invention to determine the global natural gas hydrate resource amount, so as to illustrate the method for determining the natural gas hydrate resource amount provided by the present invention.

In this example, starting from the perspective of cutting-edge geological theory, the current global natural gas hydrate resource evaluation is difficult and the accuracy is low, especially the global natural gas hydrate The problem of low reliability of resource assessment is comprehensively analyzed using previous research results and key parameters, based on the principle of mass balance, including natural gas hydrate resources into the global oil and gas system, establishing a corresponding unified model and mass balance equation, and finally determining the global natural gas hydration level. material resources.

The method adopted in this embodiment specifically includes the following steps:

1. The model for determining the amount of natural gas hydrate resources; specifically including:

1.1. Like other oil and gas resources, natural gas hydrates are the same as other oil and gas resources. The hydrocarbons are derived from the degradation of deep organic matter, and natural gas hydrate resources are included in the oil and gas system; the global oil and gas system includes all source rocks on the surface and related hydrocarbon migration and accumulation processes. The types of oil and gas resources included in the global oil and gas system include conventional oil and gas resources, unconventional oil and gas resources, and shale oil and gas resources; according to the principle of mass balance, conventional oil and gas resources are established (conventional oil and gas resources refer to those generated by organic matter and distributed in free dynamic fields. , oil and gas resources with buoyancy as the driving force), unconventional oil and gas resources, shale oil and gas resources, and related models of oil and gas resources generated by source rocks in oil and gas systems:

Q _C + Q _U + Q _S ≤ Q _P

In the formula, Q _C is conventional oil and gas resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _U is unconventional oil and gas resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _S is shale oil and gas The amount of resources (in gas equivalent), the unit is 10 ¹² m ³ , Q _P is the total generated oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ;

1.2. Natural gas hydrate has the same characteristics as conventional oil and gas resources, conventional heavy oil and bitumen resources in terms of hydrocarbon source, migration and accumulation dynamics and process, and reservoir characteristics. In addition, natural gas Hydrates are only stored in the stable zone of high pressure and low temperature, so natural gas hydrate can be considered as a special conventional oil and gas resource accumulated in high pressure and low temperature reservoirs; based on this, the establishment of natural gas hydrate resources, conventional oil and gas resources (Conventional oil and natural gas resources refer to oil and natural gas resources that are generated from organic matter, distributed in a free dynamic field, driven by buoyancy, and not biodegraded) and conventional heavy oil and bitumen resources (conventional heavy oil and Bitumen resources refer to the relevant models of biodegraded heavy oil and bitumen resources generated by organic matter, distributed in the free dynamic field, and driven by buoyancy:

Q _C ＝Q _C1 +Q _C2 +Q _C3 ≤Q _EC

In the formula, Q _C1 is the amount of natural gas hydrate resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is the amount of conventional oil and gas Quality oil and bitumen resources (in gas equivalent), unit 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent ), the unit is 10 ¹² m ³ ; Q _C is conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ;

1.3. Based on the relevant models of natural gas hydrate resources, conventional oil and natural gas resources, conventional heavy oil and asphalt resources, a unified model and mass balance equation between natural gas hydrate resources and conventional oil and gas resources are established:

Q _C1 ＝Q _C -Q _C2 -Q _C3 ＝f×Q _C

In the formula, Q _C1 is the amount of natural gas hydrate resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is the amount of conventional oil and gas Quality oil and bitumen resources (in gas equivalent), unit 10 ¹² m ³ ; Q _EC is the amount of hydrocarbon resources discharged from source rocks above the lower limit of buoyancy accumulation and within the free dynamic field (in gas equivalent ), the unit is 10 ¹² m ³ ; Q _C is the amount of conventional oil and gas resources (in gas equivalent), the unit is 10 ¹² m ³ ; f is the proportion of gas hydrate in conventional oil and gas resources, the unit is %;

1.4. Based on the unified model and mass balance equation between natural gas hydrate resources and conventional oil and gas resources, the gas hydrate resource determination model is established as follows:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; Q _C1 is the amount of gas hydrate resources (in gas equivalent), unit is 10 ¹² m ³ ; Q _C2 is the amount of conventional oil and gas resources ( In gas equivalent), the unit is 10 ¹² m ³ ; Q _C3 is conventional heavy oil and bitumen resources (in gas equivalent), the unit is 10 ¹² m ³ .

2. Obtain the thickness and area of the sedimentary rock layer and the volume factor of natural gas hydrate in the global gas hydrate stable zone, and obtain the thickness and area of the sedimentary rock layer and the natural gas volume factor where the global conventional oil and gas resources are located;

In this example, 29 sets of published evaluation results of global natural gas hydrate resources and authoritative data of the global oil and gas industry were selected, and by means of mathematical statistical analysis methods, the requirements for the evaluation of natural gas hydrate resources based on conventional oil and gas resources were obtained. The key parameters, including the parameters reflecting the volume of sedimentary rocks in the gas hydrate stable zone, are the area A _GHSZ of the sedimentary rocks in the gas hydrate stable zone, the thickness H _GHSZ and the gas hydrate volume factor B _gh data, reflecting the free dynamic field, conventional oil and gas Parameters of the volume of sedimentary rocks in the reservoir For the area A _conv , thickness H _conv and natural gas volume factor B _g of the sedimentary rocks where the conventional oil and gas resources are located, please refer to Table 1, Figure 3, and Figure 4 for details.

3. Obtain the proportion of gaseous hydrocarbons; specifically include:

3.1. Obtain the ratio of the amount of gas generated by the source rock with the global organic matter type III in the biochemical gas generation stage (Ro<0.5%) to the total amount of hydrocarbon generated, which is the first ratio;

The gas to total hydrocarbon ratios of different organic matter types of source rocks at the biochemical gas generation stage (Ro<0.5%) are shown in Figure 6;

3.2. Obtain the ratio of the gas volume to the total hydrocarbon volume in the world's proven conventional oil and gas reservoirs, which is the second ratio;

The ratio of gas to total hydrocarbon in the world's proven conventional oil and gas reservoirs is shown in Figure 7;

3.3. Obtain the weighted average value of the ratio of gaseous hydrocarbons to total hydrocarbons generated by source rocks of type I, type II and type III organic matter in the global free dynamic field in the biological gas generation stage and thermal gas generation stage is The third ratio; specifically:

In the free dynamic field, the ratio of gaseous hydrocarbons generated by source rocks with type I organic matter to the total hydrocarbons generated in the biological gas generation stage, the ratio of gaseous hydrocarbons generated by source rocks with type I organic matter in the stage of thermal gas generation to Ratio of total hydrocarbons generated, ratio of gaseous hydrocarbons generated by source rocks with type II organic matter to total hydrocarbons generated in the biological gas generation stage, gaseous hydrocarbons generated by source rocks with type II organic matter in the stage of thermal gas generation Ratio to total hydrocarbons generated, ratio of gaseous hydrocarbons to total hydrocarbons generated by type III organic matter source rocks in the biogas generation stage, gaseous hydrocarbons generated by type III organic matter source rocks in thermogenetic gas generation stage The ratio of hydrocarbons to the total hydrocarbons generated, the above-mentioned ratios are weighted and averaged to obtain the third ratio;

The ratio of gaseous hydrocarbons to total hydrocarbons generated by source rocks with type I, type II and type III kerogens in the biogas generation stage and thermal gas generation stage in the free dynamic field is shown in Fig. 8;

Step S34: Determine the proportion g of gaseous hydrocarbons based on the first ratio, the second ratio and the third ratio; specifically:

Taking the third ratio as the initial value of the proportion of gaseous hydrocarbons, and using the first ratio and the second ratio to correct the initial value of the proportion of gaseous hydrocarbons to obtain the proportion of gaseous hydrocarbons g; wherein, when the initial value of the proportion of gaseous hydrocarbons is less than or equal to the first When the ratio is greater than or equal to the second ratio, the proportion of gaseous hydrocarbons g is the initial value of the proportion of gaseous hydrocarbons; when the initial value of the proportion of gaseous hydrocarbons is greater than the first ratio, the proportion of gaseous hydrocarbons g is the first ratio; when the proportion of gaseous hydrocarbons When the initial value of the proportion is less than the second ratio, the proportion g of gaseous hydrocarbons is the second ratio;

The global gaseous hydrocarbon proportion g distribution is shown in Fig. 5.

Table 1

parameter minimum value The optimal value maximum value <![CDATA[A_GHSZ(10⁶km²)]]> 5.0 50-30 150 <![CDATA[H_GHSZ(m)]]> 10 500-400 1200 <![CDATA[A_conv(10⁶km²)]]> 162 180 240 <![CDATA[H_conv(m)]]> 300 2600-3500 7000 <![CDATA[B_gh]]> 160 164 168 <![CDATA[B_g]]> 35 210 360 g 0.379 0.715-0.67 0.907

4. Based on the thickness and area of the sedimentary rock layer in the gas hydrate stable zone and the volume factor of natural gas hydrate, the thickness and area of the sedimentary rock layer where the conventional oil and gas resources are located, and the natural gas volume factor, the gas hydrate in the conventional oil and gas resource is determined by the following formula Proportion in:

In the formula, f is the proportion of gas hydrate in conventional oil and gas resources, unit %; B _gh is the volume factor of gas hydrate, which represents the ratio of the volume of methane hydrate under standard surface conditions to the volume of gas hydrate under reservoir conditions , the unit is dimensionless; B _g is the natural gas volume factor, which means the ratio of the natural gas volume under the standard surface condition to the natural gas volume under the reservoir condition, the unit is dimensionless; A _GHSZ is the area of the sedimentary rock in the gas hydrate stable zone, the unit is 10 ⁶ km ² ; H _GHSZ is the thickness of the sedimentary rock in the gas hydrate stable zone, unit m; A _conv is the area of the sedimentary rock where the conventional oil and gas resources are located, and the unit is 10 ⁶ km ² ; H _conv is the sedimentary rock where the conventional oil and gas resources are located thickness, in m; g is the proportion of gaseous hydrocarbons, in %.

5. Obtain conventional oil and natural gas resources and conventional heavy oil and asphalt resources; specifically:

Based on expert assessments in the field of petroleum geology and exploration and data from world authoritative petroleum institutions, the Q _C2 data of global conventional oil and gas resources and the Q _C3 data of conventional heavy oil and bitumen resources are determined.

6. Based on the amount of conventional oil and natural gas resources, the amount of conventional heavy oil and asphalt resources, and the proportion of natural gas hydrate in conventional oil and gas resources, the global natural gas hydrate resource amount is determined through the natural gas hydrate resource amount determination model.

In this example, the optimum value f of the proportion of natural gas hydrate in conventional oil and gas resources is 0.01-0.03; the global conventional oil resources are 1983.3×10 ⁹ m ³ , and the global conventional natural gas resources are 672.1×10 ¹² m ^3. The sum of the above two is the global conventional oil and gas resources Q _C2 ; the global conventional heavy oil and asphaltene resources Q _C3 is 1438.0×10 ¹² m ³ . The optimal value of the global natural gas hydrate resources finally determined is 84×10 ¹² m ³ , the average value is 179×10 ¹² m ³ , and the final result is 84-179×10 ¹² m ³ .

The method for determining the amount of natural gas hydrate resources provided in this example starts from cutting-edge geological theories and incorporates natural gas hydrate resources into the global oil and gas system to construct a unified model and mass balance equation, and to find out the difference between natural gas hydrate resources and conventional oil and gas resources. In terms of similarities in resource types, by analogy with conventional oil and gas resource evaluation methods, reliable evaluation of global natural gas hydrate resources is carried out. Through this method, the disadvantages of insufficient geological theory and large errors in evaluation methods in the past have been solved, and the prediction has geological basis and high reliability; the prediction has advanced technology and high accuracy; the prediction has a new idea and is highly innovative; and This method only uses commonly used evaluation parameters in conventional oil and gas evaluation, and integrates previous evaluation results and parameters of hydrates. The data type is simple and easy to obtain, and the operation process is simple and fast. In general, the method has the following advantages after being verified by practical application: (1) The geological basis is sufficient and the reliability is high; (2) The technical characteristics are clear and the accuracy is high; (3) The thinking is complete and clear, and the innovation is strong ; (4) The information is simple and easy to obtain, and the operability is strong.

The above descriptions are only preferred embodiments of the present invention, and are not intended to limit the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included in the protection of the present invention. within range.

Claims (10)

1. A method of determining an amount of a natural gas hydrate resource, wherein the method comprises:

obtaining the thickness and the area of a sedimentary rock stratum of a natural gas hydrate stability zone of a target area and a natural gas hydrate volume factor;

obtaining the thickness and the area of a sedimentary rock stratum where the conventional oil and gas resources of a target area are located and a natural gas volume factor; the conventional oil-gas resource is generated by organic matters, distributed in a free power field and taking buoyancy as migration power;

acquiring the gaseous hydrocarbon ratio of a target area; wherein the gaseous hydrocarbon ratio refers to the ratio of gaseous hydrocarbons in the discharged hydrocarbon;

determining the proportion of the target region natural gas hydrates in the conventional oil and gas resources based on the thickness and the area of the sedimentary rock formations of the target region natural gas hydrate stability zone, the volume factor of the natural gas hydrates, the thickness and the area of the sedimentary rock formations where the target region conventional oil and gas resources are located, the volume factor of the natural gas and the proportion of the target region gaseous hydrocarbons;

acquiring the conventional petroleum and natural gas resource quantity and the conventional heavy oil and asphalt resource quantity of a target area; the conventional petroleum and natural gas resources are petroleum and natural gas resources which are generated by organic matters, distributed in a free power field, taking buoyancy as migration power and are not biodegraded, and the conventional heavy oil and asphalt resources are heavy oil and asphalt resources which are generated by organic matters, distributed in the free power field, taking buoyancy as migration power and are biodegraded;

and determining the natural gas hydrate resource amount of the target region based on the conventional petroleum and natural gas resource amount, the conventional heavy oil and asphalt resource amount and the ratio of the natural gas hydrate in the conventional oil gas resource of the target region.

2. The method of claim 1, wherein obtaining a target zone gaseous hydrocarbon fraction comprises:

acquiring a first ratio of the gas quantity generated by the hydrocarbon source rock with the organic matter type III in the biochemical gas generation stage to the total hydrocarbon quantity generated by the hydrocarbon source rock in the target area; acquiring a second ratio which is the ratio of the gas quantity to the total hydrocarbon quantity in the conventional petroleum and natural gas reservoir which is proved to be in the target area;

acquiring a weighted average value of ratios of gaseous hydrocarbons and total hydrocarbons generated by hydrocarbon source rocks of which the organic matter types are I type, II type and III type in a free power field of a target area in a biological gas generation stage and a thermal gas generation stage, wherein the weighted average value is a third ratio;

determining the gaseous hydrocarbon ratio of the target area based on the first ratio, the second ratio and the third ratio; wherein the ratio of the gaseous hydrocarbons in the target area is less than or equal to a first ratio and greater than or equal to a second ratio;

preferably, the third ratio is used as an initial value of the gaseous hydrocarbon ratio of the target area, and the initial value of the gaseous hydrocarbon ratio of the target area is corrected by using the first ratio and the second ratio to obtain the gaseous hydrocarbon ratio of the target area; when the initial value of the gaseous hydrocarbon proportion of the target area is less than or equal to a first ratio and is greater than or equal to a second ratio, the initial value of the gaseous hydrocarbon proportion of the target area is the initial value of the gaseous hydrocarbon proportion of the target area; when the initial value of the gaseous hydrocarbon proportion of the target area is greater than the first ratio, the gaseous hydrocarbon proportion of the target area is the first ratio; and when the initial value of the gaseous hydrocarbon proportion of the target area is smaller than the second ratio, the gaseous hydrocarbon proportion of the target area is the second ratio.

3. The method of claim 1, wherein the natural gas hydrate is determined in the conventional oil and gas resource by the following formula:

in the formula, f is the proportion of natural gas hydrate in conventional oil gas resources, and the unit percent; b _gh Is a natural gas hydrate volume factor with unit dimensionless; b is _g Is a natural gas volume factor, and the unit is dimensionless; a. The _GHSZ Area of sedimentary rock formation of gas hydrate stability zone, singlyBit 10 ⁶ km ² ；H _GHSZ The thickness of the sedimentary rock formation in m, which is the natural gas hydrate stability zone; a. The _conv The unit of the area of the sedimentary rock stratum where the conventional oil and gas resources are located is 10 ⁶ km ² ；H _conv The thickness of the sedimentary rock stratum where the conventional oil and gas resources are located is m; g is the proportion of gaseous hydrocarbon in unit percent.

4. The method of claim 1, wherein the natural gas hydrate resource amount is determined using a natural gas hydrate resource amount determination model; the natural gas hydrate resource quantity determination model is a calculation model of the natural gas hydrate resource quantity related to the proportion of the natural gas hydrate in conventional oil and gas resources, the conventional petroleum and natural gas resource quantity and the conventional heavy oil and asphalt resource quantity;

preferably, the natural gas hydrate resource amount determination model is:

in the formula, f is the proportion of natural gas hydrate in conventional oil gas resources, and the unit percent; q _C1 Is the natural gas hydrate resource amount with the unit of 10 ¹² m ³ ；Q _C2 The unit is 10 for the conventional petroleum and natural gas resource quantity ¹² m ³ ；Q _C3 Is the resource quantity of conventional heavy oil and asphalt, and has a unit of 10 ¹² m ³ 。

5. A system for determining an amount of a natural gas hydrate resource, wherein the system comprises:

a natural gas hydrate parameter acquisition module: the method is used for obtaining the thickness and the area of a sedimentary rock stratum of a natural gas hydrate stability zone of a target area and a natural gas hydrate volume factor;

an oil and gas resource parameter acquisition module: the method is used for obtaining the thickness and the area of a sedimentary rock stratum where the conventional oil and gas resources of a target area are located and the natural gas volume factor; the conventional oil gas resource is generated by organic matters, distributed in a free power field and taking buoyancy as migration power;

the gaseous hydrocarbon proportion obtaining module: the method is used for acquiring the gaseous hydrocarbon ratio of a target area; wherein the gaseous hydrocarbon ratio refers to the ratio of gaseous hydrocarbons in the discharged hydrocarbon;

the natural gas hydrate proportion obtaining module: the method comprises the steps of determining the occupation ratio of natural gas hydrates in a target region in conventional oil and gas resources based on the thickness and the area of a sedimentary rock stratum of a natural gas hydrate stability zone of the target region, the volume factor of the natural gas hydrates, the thickness and the area of the sedimentary rock stratum where the conventional oil and gas resources of the target region are located, the volume factor of the natural gas and the occupation ratio of gaseous hydrocarbons of the target region;

the conventional energy quantity acquisition module: the method is used for acquiring the conventional petroleum and natural gas resource quantity and the conventional heavy oil and asphalt resource quantity of a target area; the conventional petroleum and natural gas resources are petroleum and natural gas resources which are generated by organic matters, distributed in a free power field, taking buoyancy as migration power and are not biodegraded, and the conventional heavy oil and asphalt resources are heavy oil and asphalt resources which are generated by organic matters, distributed in the free power field, taking buoyancy as migration power and are biodegraded;

the natural gas hydrate resource quantity acquisition module: the method is used for determining the natural gas hydrate resource amount of the target area based on the conventional petroleum and natural gas resource amount, the conventional heavy oil and asphalt resource amount and the ratio of natural gas hydrate in the conventional oil gas resource of the target area.

6. The system of claim 5, wherein the gaseous hydrocarbon fraction obtaining module comprises:

a first ratio acquisition submodule: the method is used for obtaining the ratio of the gas quantity generated by the hydrocarbon source rock with the organic matter type III in the biochemical gas generation stage to the total hydrocarbon quantity generated in the target area, namely the first ratio;

a second ratio acquisition submodule: the second ratio is used for acquiring the ratio of the gas quantity to the total hydrocarbon quantity in the conventional petroleum and natural gas reservoir which is already detected in the target area;

a third ratio acquisition submodule: the weighted average value of the ratios of the gaseous hydrocarbons generated by the hydrocarbon source rocks of which the organic matter types are I type, II type and III type in the free power field of the target area in the biological gas generation stage and the thermal gas generation stage to the total hydrocarbons generated is a third ratio;

a gaseous hydrocarbon ratio determination submodule: determining a target zone gaseous hydrocarbon fraction based on the first ratio, the second ratio, and the third ratio; wherein the ratio of the gaseous hydrocarbons in the target area is less than or equal to a first ratio and greater than or equal to a second ratio;

preferably, the gaseous hydrocarbon ratio determination submodule is used for taking the third ratio as an initial gaseous hydrocarbon ratio value of the target area, and correcting the initial gaseous hydrocarbon ratio value of the target area by using the first ratio and the second ratio to obtain the gaseous hydrocarbon ratio of the target area; when the initial value of the gaseous hydrocarbon proportion of the target area is less than or equal to a first ratio and is greater than or equal to a second ratio, the initial value of the gaseous hydrocarbon proportion of the target area is the initial value of the gaseous hydrocarbon proportion of the target area; when the initial value of the gaseous hydrocarbon proportion of the target area is greater than the first ratio, the gaseous hydrocarbon proportion of the target area is the first ratio; and when the initial value of the gaseous hydrocarbon proportion of the target area is smaller than the second ratio, the gaseous hydrocarbon proportion of the target area is the second ratio.

7. The system of claim 5, wherein the natural gas hydrate fraction acquisition module determines the natural gas hydrate fraction in the conventional oil and gas resource by the following formula:

in the formula, f is the proportion of natural gas hydrate in conventional oil gas resources, and the unit percent; b is _gh Is a natural gas hydrate volume factor with unit dimensionless; b is _g Is a natural gas volume factor, and the unit is dimensionless; a. The _GHSZ Area of sedimentary rock formation as gas hydrate stability zone, unit 10 ⁶ km ² ；H _GHSZ The thickness of the sedimentary rock formation in m, which is the natural gas hydrate stability zone; a. The _conv Sedimentary rock for conventional oil and gas resourcesArea of layer, unit 10 ⁶ km ² ；H _conv The thickness of the sedimentary rock stratum where the conventional oil and gas resources are located is m; g is the proportion of gaseous hydrocarbon in unit percent.

8. The system of claim 5, wherein the natural gas hydrate resource amount acquisition module determines the natural gas hydrate resource amount using a natural gas hydrate resource amount determination model; the natural gas hydrate resource quantity determination model is a calculation model of the natural gas hydrate resource quantity related to the proportion of the natural gas hydrate in conventional oil and gas resources, the conventional petroleum and natural gas resource quantity and the conventional heavy oil and asphalt resource quantity;

preferably, the natural gas hydrate resource amount determination model is as follows:

in the formula, f is the proportion of natural gas hydrate in conventional oil gas resources, and the unit percent; q _C1 Is the natural gas hydrate resource amount with the unit of 10 ¹² m ³ ；Q _C2 The unit is 10 for the conventional petroleum and natural gas resource quantity ¹² m ³ ；Q _C3 The unit is 10 for the amount of conventional heavy oil and asphalt resources ¹² m ³ 。

9. An electronic device comprising a processor, a memory, and a computer program stored on the memory and executable on the processor, the processor when executing the program implementing the steps of determining a natural gas hydrate resource quantity method according to any one of claims 1-4.

10. A computer readable storage medium having stored thereon a computer program which, when executed by a processor, carries out the steps of any of claims 1-4 of determining a natural gas hydrate resource quantity method.

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