Method and device for determining lithology space-time distribution characteristics of coal measure gas

Abstract

The invention relates to the technical field of unconventional resource development, in particular to a method and a device for determining lithology space-time distribution characteristics of coal measure gas, and the corresponding method comprises the following steps: building a sequence stratigraphic framework of a target work area according to rock debris logging data and logging data of the target work area; determining dominant storage lithology corresponding to each coal series gas; according to the sequence stratigraphic framework and the advantage storage lithology corresponding to each type of coal measure gas, establishing a well connection section and a lithology plane graph; and according to the well connection profile and the lithologic plan, determining the lithologic spatial-temporal distribution characteristics of the coal-series gas. The effective determination method of the lithology space-time distribution rule is formed on the basis of combination of the sequence strata, the rock core and the logging, rock core constraint, logging lithology correction and high-precision sequence strata isochronous framework constraint, and then the lithology space-time distribution rule of coal bed gas, coal series shale gas and coal series tight sandstone gas evaluation is determined.

Description

Technical Field

[0001] This disclosure relates to the field of petroleum exploration and development technology, particularly to the field of unconventional resource exploration and development technology, specifically to a method, apparatus, equipment, storage medium, and computer program for determining the lithological spatiotemporal distribution characteristics of coalbed methane. Background Technology

[0002] Coal-bearing gas refers to various types of natural gas found in coal-bearing strata, including coalbed methane, coal-bearing shale gas, coal-bearing tight sandstone gas, and coal-bearing limestone gas. Among these, coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas are commonly referred to as the "three gases" of coal-bearing strata. Coal-bearing strata are widely distributed and thick, and coal-bearing gas resources account for more than 60% of the total geological resources of natural gas, making them an important and hot area for unconventional natural gas exploration. With the continuous deepening of coal-bearing gas exploration and development, the focus has gradually shifted from the exploration and development of single coal-bearing tight sandstone gas and coalbed methane to the joint exploration and development of the "three gases" of coal-bearing strata. The spatiotemporal distribution pattern of lithology is the core evaluation element of the "three gases" of coal-bearing strata. Previous studies mainly focused on the spatiotemporal distribution of lithology in coal-bearing tight sandstone gas, emphasizing the spatiotemporal distribution patterns of coal seams and sandstone, while often weakening or ignoring the distribution of other lithologies besides coal seams and sandstone, or conducting general analyses of other lithologies. However, focusing on the lithological classification and comparison of tight sandstone and coal seams is insufficient to meet the requirements of evaluating the spatial and temporal distribution and combination of lithology for the "three gases" in coal-bearing systems. Summary of the Invention

[0003] This disclosure provides a lithological spatiotemporal distribution analysis method for coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas based on sequence stratigraphy, core analysis, and well logging. By utilizing the constraints of core analysis, lithological correction of well logging, and constraints of high-precision sequence stratigraphy isochronous framework, an effective analysis and evaluation of the spatiotemporal distribution law of lithology is formed, thereby realizing the effective implementation of the spatiotemporal distribution law of lithology in the evaluation of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas.

[0004] Firstly, this disclosure provides a method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas, including:

[0005] A sequence stratigraphic framework for the target work area is established based on cuttings logging data and well logging data of the target work area.

[0006] Determine the dominant reservoir lithology for each type of coal-bearing gas;

[0007] Based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas, well-connected profiles and lithological plan maps were established.

[0008] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view.

[0009] In some embodiments of this disclosure, the coalbed methane includes: coalbed methane, coalbed shale gas, and coalbed tight sandstone gas;

[0010] The sequence stratigraphic framework is a fourth-order sequence.

[0011] In some embodiments of this disclosure, the dominant lithology for storing coalbed methane is coal;

[0012] The dominant lithology for storing coal-bearing tight sandstone gas is medium-coarse clastic rock.

[0013] The dominant lithology for storing coal-bearing shale gas is carbonaceous shale.

[0014] In some embodiments of this disclosure, determining the dominant reservoir lithology corresponding to each type of coal-bearing gas includes:

[0015] The carbonaceous shale was identified using the well logging data and the geochemical data of the target work area.

[0016] In some embodiments of this disclosure, the carbonaceous shale is determined using the well logging data and the geochemical data of the target work area, including:

[0017] The formation corresponding to the coal is determined using the well logging data.

[0018] In strata other than the strata corresponding to the coal, the carbonaceous shale is determined based on the pre-established mapping relationship between the well logging data and the geochemical data.

[0019] In some embodiments of this disclosure, the geochemical data is total organic carbon;

[0020] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view, including:

[0021] Based on the well profile and the lithology plan, the dominant storage lithology corresponding to the coal-bearing gas is divided into single lithology and composite lithology.

[0022] Based on the well profile and the lithological plan view, determine the spatiotemporal distribution characteristics of the single lithology and the spatiotemporal distribution characteristics of the composite lithology.

[0023] Secondly, this disclosure provides a device for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas, comprising:

[0024] The sequence stratigraphic framework establishment module is used to establish the sequence stratigraphic framework of the target work area based on cuttings logging data and well logging data of the target work area.

[0025] The dominant reservoir lithology determination module is used to determine the dominant reservoir lithology corresponding to each type of coal-bearing gas.

[0026] The map creation module is used to create well-connected profiles and lithological plan maps based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas.

[0027] The lithological spatiotemporal distribution characteristic determination module is used to determine the lithological spatiotemporal distribution characteristics of the coal-bearing gas based on the well profile and the lithological plan view.

[0028] In some embodiments of this disclosure, the coalbed methane includes: coalbed methane, coalbed shale gas, and coalbed tight sandstone gas;

[0029] The sequence stratigraphic framework is a fourth-order sequence.

[0030] In some embodiments of this disclosure, the dominant lithology for storing coalbed methane is coal;

[0031] The dominant lithology for storing coal-bearing tight sandstone gas is medium-coarse clastic rock.

[0032] The dominant lithology for storing coal-bearing shale gas is carbonaceous shale.

[0033] In some embodiments of this disclosure, the dominant storage lithology determination module includes:

[0034] The carbonaceous shale identification unit is used to identify the carbonaceous shale using the well logging data and the geochemical data of the target work area.

[0035] In some embodiments of this disclosure, the carbonaceous shale determining unit includes:

[0036] A coal-bearing strata determination unit is used to determine the strata corresponding to the coal using the well logging data.

[0037] The carbonaceous shale identification subunit is used to identify the carbonaceous shale in strata other than the coal-bearing strata, based on a pre-established mapping relationship between the well logging data and the geochemical data.

[0038] In some embodiments of this disclosure, the geochemical data is total organic carbon;

[0039] The lithological spatiotemporal distribution characteristic determination module includes:

[0040] The lithological classification unit is used to classify the dominant storage lithology corresponding to the coalbed methane into single lithology and composite lithology based on the well profile and the lithological plan.

[0041] The spatiotemporal distribution characteristic determination unit is used to determine the spatiotemporal distribution characteristics of the single lithology and the spatiotemporal distribution characteristics of the composite lithology based on the well profile and the lithology plan view.

[0042] Thirdly, this disclosure provides a computer device including a memory, a processor, and a computer program stored in the memory, wherein the processor executes the computer program to implement the steps of the method described in the foregoing aspects.

[0043] Fourthly, this disclosure provides a computer-readable storage medium having a computer program stored thereon that, when executed by a processor, implements the steps of the methods described in the above aspects.

[0044] Fifthly, this disclosure provides a computer program product, including a computer program / instructions that, when executed by a processor, implement the steps of the methods described in the foregoing aspects.

[0045] This disclosure provides a method, apparatus, equipment, storage medium, and computer program for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas. The corresponding method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas includes: first, establishing a sequence stratigraphic framework for the target work area based on cuttings logging data and well logging data; determining the dominant storage lithology corresponding to each type of coal-bearing gas; next, establishing a series of well profiles and lithological plan views based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas; and finally, determining the lithological spatiotemporal distribution characteristics of coal-bearing gas based on the series of well profiles and lithological plan views.

[0046] The corresponding device for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas includes: a sequence stratigraphic framework establishment module, used to establish the sequence stratigraphic framework of the target work area based on cuttings logging data and well logging data; a dominant storage lithology determination module, used to determine the dominant storage lithology corresponding to each type of coal-bearing gas; a map establishment module, used to establish well-connected profiles and lithological plan maps based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas; and a lithological spatiotemporal distribution characteristic determination module, used to determine the lithological spatiotemporal distribution characteristics of coal-bearing gas based on the well-connected profiles and lithological plan maps.

[0047] In summary, the method for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in this disclosure effectively reveals and evaluates the lithological spatiotemporal distribution patterns of coalbed methane, coalbed shale gas, and coalbed tight sandstone gas, thus providing a better reference for their exploration and development. Attached Figure Description

[0048] The present disclosure will be described in more detail below based on embodiments and with reference to the accompanying drawings:

[0049] Figure 1 This is a flowchart illustrating a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, provided in an embodiment of this disclosure.

[0050] Figure 2This is a flowchart illustrating step 200 of a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, as provided in an embodiment of this disclosure.

[0051] Figure 3 This is a flowchart illustrating step 201 of a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in an embodiment of this disclosure.

[0052] Figure 4 This is a flowchart illustrating step 400 of a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in an embodiment of this disclosure.

[0053] Figure 5 A flowchart illustrating a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, provided as an application example of this disclosure.

[0054] Figure 6 A lithological comparison diagram of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas provided for application examples in this disclosure.

[0055] Figure 7 Lithological planar distribution maps of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas provided for application examples in this disclosure.

[0056] Figure 8 The lithological planar combination distribution map of coalbed methane, coal-bearing shale gas and coal-bearing tight sandstone gas provided for the application examples of this disclosure.

[0057] Figure 9 A block diagram of a device for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in an embodiment of this disclosure.

[0058] In the accompanying drawings, the same parts are referred to by the same reference numerals, and the drawings are not drawn to scale. Detailed Implementation

[0059] To enable those skilled in the art to better understand the technical solutions of this disclosure, and to fully understand and implement the process of how this disclosure applies technical means to solve technical problems and achieve corresponding technical effects, the technical solutions in the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this disclosure, not all embodiments. The embodiments of this disclosure and the various features within them can be combined with each other without conflict, and the resulting technical solutions are all within the protection scope of this disclosure. All other embodiments obtained by those skilled in the art based on the embodiments of this disclosure without creative effort should fall within the protection scope of this disclosure.

[0060] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0061] It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases the steps shown or described may be executed in a different order than that shown here.

[0062] In existing technologies, the evaluation of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas is often based on drilling data. The evaluation process often focuses on the vertical combination sequence of lithology, and is generally classified into types such as coal, shale, sandstone, and carbonaceous shale. On this basis, coalbed methane, tight sandstone gas, and coal-bearing sandstone gas are further classified according to lithological type. However, the analysis of the lithological profile distribution and planar distribution patterns related to coal-bearing gas is limited, and no well-guided classification method has been formed.

[0063] Meanwhile, studies on the spatiotemporal distribution patterns of rocks are often conducted under the constraints of stratigraphic units, which often leads to time inhomogeneity and thus affects the effective regularity of revealing the spatiotemporal distribution patterns of lithology.

[0064] Furthermore, the lithological classification based on drilling cuttings logging data has certain accuracy issues, especially in the identification of carbonaceous shale (mudstone) and coal seams, where there is often confusion in identification. At the same time, there is also the problem of carbonaceous shale (mudstone) not being identified, which often affects the evaluation of coal-bearing shale gas.

[0065] Example 1

[0066] Based on this, the present disclosure provides a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane. Figure 1 This is a flowchart illustrating a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, provided in an embodiment of this disclosure. Figure 1 As shown, a method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas includes:

[0067] Step 100: Establish the sequence stratigraphic framework of the target work area based on the cuttings logging data and well logging data of the target work area;

[0068] Step 200: Determine the dominant reservoir lithology for each type of coal-bearing gas;

[0069] Step 300: Establish well-connected profiles and lithological plan views based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas;

[0070] Step 400: Determine the lithological spatiotemporal distribution characteristics of the coalbed methane based on the well profile and the lithological plan view.

[0071] This disclosure provides a method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas, comprising: first, establishing a sequence stratigraphic framework for the target work area based on cuttings logging data and well logging data; determining the dominant storage lithology corresponding to each type of coal-bearing gas; then, establishing a series of well profiles and lithological plan views based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas; and finally, determining the lithological spatiotemporal distribution characteristics of coal-bearing gas based on the series of well profiles and lithological plan views.

[0072] In summary, the method for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in this disclosure utilizes core constraints, well logging lithology correction, and high-precision sequence stratigraphy isochronous framework constraints to form an effective analysis and evaluation of the spatiotemporal distribution law of lithology, thereby effectively realizing the evaluation of the spatiotemporal distribution law of coalbed methane, coalbed shale gas, and coalbed tight sandstone gas.

[0073] Example 2

[0074] In step 100, high-precision sequence stratigraphy division and correlation were carried out using the classic Vail sequence stratigraphy principle and under the joint constraints of cuttings logging data and well logging data.

[0075] Vail sequence stratigraphy, based on the concept of sequence stratigraphy, emphasizes the control of global sea-level change (i.e., relative sea-level change) on sedimentation and stratigraphic formation. The following are some key points of the principles of Vail sequence stratigraphy:

[0076] Sequence stratigraphy: Composed of several successive sedimentary system tracts, it represents a complete sedimentary cycle, with its boundaries determined by unconformities or their isochronous surfaces. Sequence stratigraphy represents a complete process from marine transgression to marine regression.

[0077] Systems tracts: The basic building blocks within a sequence, each systems tract representing a specific sedimentary environment and process.

[0078] Common system tracts include lowstand system tracts, transgressive system tracts, and highstand system tracts.

[0079] Relative sea-level changes: The rise and fall of the relative sea level is the main factor driving sedimentary processes and strata formation. Sea-level rise (marine transgression) and sea-level fall (marine regression) lead to the migration of sedimentary environments, resulting in the formation of different types of sediments in different locations.

[0080] Unconformities: These represent sedimentary hiatuses or erosion surfaces and are important markers for identifying and dividing sequence stratigraphy. These unconformities can be global or local, reflecting the effects of relative sea-level changes.

[0081] The coal-bearing gas in step 200 includes: coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas, specifically:

[0082] Coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas are three closely related unconventional natural gas resources, with different formation mechanisms, reservoir conditions, and extraction methods. The following is a brief introduction to these three gas resources:

[0083] Coalbed methane is natural gas found in coal seams, and its main component is methane (CH4). It is an organic gas produced during the coalification process, with some of it adsorbed in the pores of the coal and some existing in a free state in the fissures and pores of the coal seam.

[0084] Coalbed methane is mainly adsorbed on the surface of micropores in coal seams, and its storage capacity is closely related to the type, rank, pore structure, and moisture content of the coal. Coalbed methane is found in shallow to medium-deep coal seams.

[0085] Coalbed methane extraction involves reducing the pressure in the coal seam or removing moisture to release the gas adsorbed in the coal seam, which is then collected through the wellhead.

[0086] Coal-bearing shale gas is natural gas found in coal-bearing shale. Shale gas is mainly formed during the sedimentation and diagenesis of shale through hydrocarbon generation, and the gas exists in both adsorbed and free states.

[0087] Coal-series shale gas is mainly found in organic-rich shale layers. The gas is adsorbed on the surface of organic matter or clay minerals in the shale, and may also exist in microfractures and pores within the shale. Coal-series shale gas reservoirs are often characterized by low porosity and low permeability. Extraction of coal-series shale gas generally employs horizontal wells and hydraulic fracturing techniques. Artificial fractures are used to increase the permeability of the reservoir, allowing the gas to flow into the wellbore for collection.

[0088] Coal-associated tight sandstone gas is natural gas contained in coal-associated tight sandstone layers. Tight sandstone gas forms in sandstone layers within coal-associated sedimentary basins and is primarily composed of free gas.

[0089] Coal-series tight sandstone gas reservoirs are characterized by low porosity and low permeability. The sandstone has a fine grain size and complex pore structure, with gas existing primarily in a free state within micropores and microfractures. The extraction of coal-series tight sandstone gas also requires enhancement measures such as hydraulic fracturing to improve reservoir permeability, thereby enabling the effective flow and collection of natural gas.

[0090] Coalbed methane mainly originates from coal seams, and the gas is mainly in the adsorbed state; coal-bearing shale gas is mainly found in the shale layers of coal-bearing sediments, and the gas is mainly in the adsorbed and free states; coal-bearing tight sandstone gas is found in tight sandstone layers, and the gas is mainly in the free state.

[0091] For the well-connected profile in step 300, under the constraints of the sequence stratigraphic framework, the dominant storage lithology corresponding to each coal-bearing gas is connected by linking the stratigraphic profiles of multiple wells to show the comparison and continuity of the strata between different well locations, so as to intuitively show the strata thickness, sediment type, lithological changes and the location of unconformities between each well.

[0092] The lithological plan view in step 300 shows the spatial distribution of dominant reservoir lithologies corresponding to a specific geological period or a particular coal-bearing gas. It reflects the lateral variation of lithology within a geological region.

[0093] Example 3

[0094] Based on the above embodiments, the coal-bearing gas includes: coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas;

[0095] The sequence stratigraphic framework is a fourth-order sequence (quasi-sequence group).

[0096] In sequence stratigraphy, the fourth-order sequence (also known as a subsequence) is a classification method for stratigraphic units, primarily used to describe the spatiotemporal distribution and evolution of sedimentary rocks. The construction of the fourth-order sequence is based on the sequence and further divided into multiple levels to allow for more detailed analysis of sedimentary environments and processes.

[0097] The composition of the fourth-level hierarchy:

[0098] Sequence stratigraphy is the largest stratigraphic unit, reflecting changes in sedimentary environments within a specific geological period. Sequence stratigraphy consists of sedimentary rock layers formed by alternating sedimentary environments, and is influenced by sea-level changes and tectonic activity.

[0099] Parasequence sets are subdivisions within a sequence, corresponding to specific sedimentary events or processes. They can reflect different sedimentary environments and conditions, helping researchers understand more detailed sedimentary features.

[0100] Systematic domains: These are units that are further subdivided within each hierarchical sequence, including:

[0101] Lowstand Systems Tract (LST): Formed when the relative sea level is lowest, mainly consisting of sandstone deposits.

[0102] Transgressive Systems Tract (TST): Formed during a period of relative sea-level rise, it is mainly composed of mudstone, shale, and carbonates.

[0103] Highstand Systems Tract (HST): Formed by sedimentation at relatively high sea levels, mainly consisting of coal seams and sandstone.

[0104] Sedimentary unit: refers to a stratigraphic unit formed by physical and biological processes within the same sedimentary environment. The division of sedimentary units helps to analyze sedimentary characteristics, sediment genesis, and their changes in more detail.

[0105] Understandably, by analyzing the fourth-order sequence, we can better reconstruct the paleoenvironment and paleoclimate of the target work area, in order to better understand the origin and evolution of coal-bearing gas.

[0106] Based on the above embodiments, the dominant storage lithology for coalbed methane is coal; the dominant storage lithology for coal-bearing tight sandstone gas is medium-coarse clastic rock; and the dominant storage lithology for coal-bearing shale gas is carbonaceous shale.

[0107] Specifically, the lithologies related to coal-bearing tight sandstone gas are classified as medium-coarse clastic rocks (including fine sandstone, medium sandstone, coarse sandstone, gravelly sandstone, and conglomerate), the lithologies related to coal-bearing shale gas are classified as carbonaceous shale (mudstone), and coal related to coalbed methane is classified as a separate category. In addition, other lithologies are classified as auxiliary lithologies, including limestone, silty mudstone, mudstone, and argillaceous siltstone.

[0108] The fine sandstone associated with coal-bearing tight sandstone gas has a diameter between 0.0625 and 0.25 mm. It has fine grains, a relatively dense texture, relatively high porosity, and contains a large amount of clay minerals.

[0109] The medium-sized sandstones associated with coal-bearing tight sandstone gas have a diameter between 0.25 and 0.5 mm. They are relatively coarse-grained, more permeable than fine sandstones, and have a looser texture. Their color is yellow, brown, or gray.

[0110] The coarse sandstone associated with coal-bearing tight sandstone gas has a diameter between 0.5 and 2 mm. It has relatively large grains, is more loosely packed than fine and medium sandstone, and contains more coarse particles. It exhibits a variety of colors, often appearing gray or brown.

[0111] The gravelly sandstone associated with coal-bearing tight sandstone gas is mainly composed of sand grains, but contains gravel particles with a diameter greater than 2 mm. It is a mixture of larger gravel and sand grains, with high density and strength. It exhibits significant color variation and contains a variety of mineral components.

[0112] The conglomerate lithology associated with coal-bearing tight sandstone gas mainly consists of gravels larger than 2 mm in diameter, interspersed with smaller sand grains. The grains are relatively large and varied in shape, exhibiting strong cohesion, and are often formed with strong water flow. They come in a variety of colors, generally gray, brown, or red.

[0113] Carbonaceous shale is a sedimentary rock rich in organic matter, mainly composed of clay minerals and fine sediments. It is characterized by a relatively high content of organic carbon (typically exceeding 6%).

[0114] Carbonaceous shale is mainly composed of clay minerals (such as illite and montmorillonite), and may also contain quartz, feldspar, and other minerals. It is rich in organic carbon, which originates from the deposition of plant remains and microorganisms, forming the organic matter in the shale.

[0115] Carbonaceous shale is black or dark gray, and the color varies depending on the organic matter content and mineral composition.

[0116] Carbonaceous shale forms in low-energy environments, such as still water environments like lakes, swamps, or ocean bottoms, where sediments accumulate under anaerobic conditions, inhibiting the decomposition of organic matter.

[0117] Limestone, silty mudstone, mudstone, and argillaceous siltstone are common sedimentary rock types with different compositions and characteristics. The following is a detailed description of each type of rock:

[0118] The auxiliary lithologies include: limestone, silty mudstone, mudstone, and argillaceous siltstone, specifically:

[0119] Limestone, primarily composed of calcium carbonate (CaCO3), is formed from biological sediments (such as corals and shells) or chemical precipitation. It is light gray, white, or pale yellow. It is crystalline or granular, has high hardness, and good compressive strength.

[0120] Silty mudstone, mainly composed of clay minerals and silt (particle size between 0.0625 and 0.25 mm), containing small amounts of organic matter and other minerals. It is gray, brown, or green in color. It is relatively fine-grained, quite hard, and exhibits good bedding.

[0121] Mudstone is mainly composed of clay minerals and a small amount of silt, with a high water content. It comes in various colors, commonly gray, brown, and black. It is relatively fine-grained, loosely textured, and exhibits good stratification.

[0122] Muddy siltstone is mainly composed of sand grains and clay. The sand grains range in diameter from 0.0625 to 2 mm, while the clay content is relatively high. It is light gray, yellowish-brown, or red. It has a relatively hard texture and possesses a certain degree of permeability and porosity.

[0123] Example 4

[0124] Based on the above embodiments, see Figure 2 Step 200 includes:

[0125] Step 201: Identify the carbonaceous shale using the well logging data and the geochemical data of the target work area.

[0126] Based on the above embodiments, the geochemical data refers to total organic carbon; see also Figure 3 Step 201 includes:

[0127] Step 2011: Determine the formation corresponding to the coal using the well logging data;

[0128] Distinguishing between coal seams and carbonaceous shale is the key to lithological classification. Coal seams are first identified by logging responses based on the "three highs and one low" (high neutron gamma value, high sonic transit time, high density porosity, and low neutron porosity).

[0129] The logging response of coal seams exhibiting "three highs and one low" (high neutron gamma value, high sonic transit time, high density porosity, and low neutron porosity) is an important indicator of coal seam geological characteristics. The following is a detailed explanation of each parameter and its significance in coal seams:

[0130] Gamma logging is primarily used to measure the content of radioactive materials in formations, particularly potassium, uranium, and thorium. Coal seams typically have a high organic matter content, which usually results in higher gamma values.

[0131] Acoustic transit time refers to the time it takes for sound waves to travel through rock strata, and is used to assess the elastic properties of rocks. Coal seams generally have higher acoustic transit times, indicating a lower elastic modulus, which is related to the looseness and porosity of coal. Compared to other rocks, the higher acoustic transit time in coal seams is due to the influence of internal fractures and organic matter.

[0132] Neutron porosity logging is primarily used to assess the fluid content in formations, particularly the presence of water and oil / gas. Coal seams typically exhibit low neutron porosity due to the organic matter structure and pore properties of coal. Relatively low neutron porosity indicates lower water content and potentially higher gas content (such as methane) within the coal seam.

[0133] Step 2012: In strata other than the strata corresponding to the coal, determine the carbonaceous shale based on the pre-established mapping relationship between the well logging data and the geochemical data.

[0134] Based on coal seam identification, a TOC calculation formula was established by correlating measured total organic carbon (TOC) with well logging curves. After removing coal seams, lithologies with TOC greater than 6% were classified as carbonaceous shale. The relationship between TOC and well logging data is as follows:

[0135] TOC = 1.30153 * lg LLD (deep lateral) + 0.05082 * AC (acoustic transit time) - 16.50689

[0136] Based on the above embodiments, well-connected profiles and lithological plans are established according to the sequence stratigraphic framework and the dominant reservoir lithology corresponding to each type of coal-bearing gas, including:

[0137] Through lithological verification, vertical lithological regularity analysis was conducted, and well-connected profile comparison analysis of medium-coarse clastic rocks, carbonaceous shale (mudstone), limestone, silty mudstone, mudstone, and argillaceous siltstone was carried out under the constraints of a fourth-level high-precision sequence stratigraphy framework. The lithological planar mapping also fully considered the lithological mapping within a 20m range of the top and bottom plates. Based on this, the lithological planar distribution was divided and characterized under the constraints of the sequence stratigraphy framework.

[0138] Based on the above embodiments, see Figure 4 Step 400 includes:

[0139] Step 401: Based on the well profile and the lithology plan, the dominant storage lithology corresponding to the coalbed methane is divided into single lithology and composite lithology.

[0140] Step 402: Determine the spatiotemporal distribution characteristics of the single lithology and the composite lithology based on the well profile and the lithology plan view.

[0141] In steps 401 and 402, under the constraints of a high-precision sequence stratigraphic framework, the lithological assemblages of key strata are divided. The lithological assemblages are divided into single lithology and composite lithology based on the number of lithological assemblages, and different types of secondary lithological assemblages are further divided for the main lithology of single lithology and composite lithology.

[0142] In summary, to address the difficulty of accurately and precisely evaluating the spatiotemporal distribution patterns of coal-bearing gas lithologies using existing methods, this disclosure provides a method for determining the spatiotemporal distribution characteristics of coal-bearing gas lithologies based on a combination of sequence stratigraphy, core analysis, and well logging. This method includes: first, establishing a sequence stratigraphic framework for the target work area based on cuttings logging data and well logging data; determining the dominant storage lithology corresponding to each type of coal-bearing gas; next, establishing a series of well profiles and lithology plans based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas; and finally, determining the spatiotemporal distribution characteristics of coal-bearing gas lithologies based on the series of well profiles and lithology plans.

[0143] Effective evaluation of the spatiotemporal distribution patterns of lithology is one of the core tasks in the joint exploration and evaluation of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas. Addressing the issues of evaluation effectiveness and accuracy in the exploration and development of these three gas types, this disclosure provides a method based on high-precision isochronous stratigraphic framework division and isochronous constraints, combined core and well logging lithology correction, and optimized combinations of lithology types. This method enables targeted joint evaluation of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas, thereby more effectively supporting the joint evaluation and exploration deployment of these three gas types.

[0144] The method provided in this disclosure avoids the single-focus lithological analysis of shale gas and tight sandstone gas, and forms a new method for studying the lithological types and spatiotemporal distribution laws of coalbed methane, coal-bearing shale gas and coal-bearing tight sandstone gas, thus expanding the research connotation of the spatiotemporal distribution laws of lithology under the coexistence of multiple lithologies.

[0145] In summary, this disclosure provides a rapid and effective lithological analysis and evaluation method for coalbed methane, coal-bearing shale gas, and tight sandstone gas, and this method takes lithological analysis into account. This method is an effective tool for the exploration and development of coalbed methane, coal-bearing shale gas, and tight sandstone gas, facilitating more accurate and effective analysis of the spatiotemporal lithological configuration of these gases. It also effectively guides the evaluation and selection of sweet spots for these gases and provides effective guidance for fracturing and engineering, effectively promoting the integrated exploration-development-engineering of coalbed methane, coal-bearing shale gas, and tight sandstone gas.

[0146] Example 5

[0147] To further illustrate the solution, based on the above embodiments, this embodiment takes gas reservoir A as an example, see [link to example]. Figure 5 This paper provides an application example to further explain a method for determining the lithological spatiotemporal distribution characteristics of coalbed methane.

[0148] The method and technology of this invention are applicable to the fields of exploration and development of coalbed methane, coal-bearing shale gas, coal-bearing tight sandstone gas, and even unconventional resources, and are of great significance to exploration, development and engineering.

[0149] Effective evaluation of the spatiotemporal distribution patterns of lithology is one of the core tasks in the joint exploration and evaluation of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas. A new approach and method for spatiotemporal dynamic lithology evaluation is based on the comprehensive discrimination and analysis of lithological classification and spatiotemporal distribution patterns of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas, rather than a single coal-bearing tight sandstone gas, coal-bearing shale gas, or coalbed methane. It establishes isochronous stratigraphic lithology correlation based on sequence stratigraphic framework constraints, employs reasonable lithology discrimination methods, and classifies different types of unconventional lithological combinations, fully considering the characteristics of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas.

[0150] This disclosure addresses the issues of evaluation effectiveness and accuracy in the exploration and development of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas. Based on lithology identification, lithology classification, and the spatiotemporal distribution of lithological combinations under an isochronous framework, it effectively supports the integrated evaluation of exploration, development, and engineering for coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas.

[0151] In the application examples disclosed herein, a method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas includes the establishment of a high-precision sequence stratigraphic framework, lithological type classification, lithological verification of coal seams and carbonaceous shale (mudstone), and analysis of the spatiotemporal distribution patterns of lithological assemblages under an isochronous framework. Specifically:

[0152] S1: Establish a high-precision isochronous stratigraphic framework.

[0153] Specifically, based on the principles and analytical methods of classical Vail sequence stratigraphy, this disclosure presents a high-precision sequence stratigraphic division and correlation under the combined constraints of cuttings logging and well logging. The stratigraphic framework is divided to the quasi-sequence group (fourth-order sequence).

[0154] For sequence stratigraphy, the first step is to identify the sequence boundaries and the marine or lacustrine flooding surfaces, and then divide the systems tracts and quasi-sequence groups based on these boundaries.

[0155] High-precision sequence stratigraphy first requires determining a single-well stratigraphy scheme. Based on this, multiple wells need to be subjected to high-precision sequence stratigraphy. Generally, the well-to-well correlation method is used to compare sequence stratigraphy to ensure the consistency of the sequence stratigraphy.

[0156] S2: Classify lithological types.

[0157] Taking into full account the relevant lithologies of coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas, lithology classification was performed based on different natural gas reservoir types, including coal-bearing tight sandstone gas, coal-bearing shale gas, and coalbed methane. Specifically, the classification was based on the reservoir types (coalbed methane, coal-bearing shale gas, and coalbed methane). On this basis, further analysis was conducted on the lithologies included in each major category. This further classification was mainly based on sedimentary rock classification methods, primarily according to rock structure (rock grain size) and inclusions (focusing on organic matter in this study).

[0158] Specifically, the lithologies related to coal-bearing tight sandstone gas are classified as medium-coarse clastic rocks (including fine sandstone, medium sandstone, coarse sandstone, gravelly sandstone, and conglomerate), the lithologies related to coal-bearing shale gas are classified as carbonaceous shale (mudstone), and coal related to coalbed methane is classified as a separate category. In addition, other lithologies are classified as auxiliary lithologies, including limestone, silty mudstone, mudstone, and argillaceous siltstone.

[0159] S3: Identify carbonaceous shale and coal seams.

[0160] Distinguishing between coal seams and carbonaceous shale is a key aspect of lithological classification. The classification process begins with identifying coal seams based on their logging responses to three highs and one low (high neutron gamma value, high sonic transit time, high density porosity, and low neutron porosity). Based on this identification, a TOC logging calculation formula is established by correlating measured TOC with logging curves. After removing coal seams, lithologies with a TOC greater than 6% are classified as carbonaceous shale.

[0161] S4: Determine the spatiotemporal distribution patterns of lithology.

[0162] Through lithological verification, vertical lithological regularity analysis was conducted (the vertical lithology within the formation studied in each well varies and exhibits regular vertical lithological variations). Furthermore, under the constraint of a fourth-order high-precision sequence stratigraphic framework, a well-to-well profile comparative analysis was carried out for medium-coarse clastic rocks, carbonaceous shale (mudstone), limestone, silty mudstone, mudstone, and argillaceous siltstone. Figure 6 Specifically, by using cross-sections of multiple wells in the east-west and north-south directions, lithology is compared laterally to clarify the spatiotemporal distribution patterns of different lithofacies in the lateral and even vertical directions.

[0163] In addition, the lithological plan mapping also fully considers the lithological mapping within a 20m range of the top and bottom lithological plates. Figure 7 Based on this, and under the constraints of the sequence stratigraphic framework, the planar distribution of lithology is divided and characterized.

[0164] S5: Classify lithological assemblages.

[0165] Under the constraints of a high-precision sequence stratigraphic framework, lithological assemblages of key strata are classified, including single lithology and complex lithology based on the number of lithological assemblages. Furthermore, different types of secondary lithological assemblages are classified based on the main lithology of both single and complex lithologies. Figure 8 ).

[0166] As described above, the application example of this disclosure provides a method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas. First, a sequence stratigraphic framework for the target work area is established based on cuttings logging data and well logging data. The dominant storage lithology corresponding to each type of coal-bearing gas is determined. Next, a series of well profiles and lithological plan views are established based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas. Finally, the lithological spatiotemporal distribution characteristics of coal-bearing gas are determined based on the series of well profiles and lithological plan views.

[0167] The method provided in this disclosure has been used to evaluate sweet spots for coalbed methane, coal-bearing shale gas, and coal-bearing tight sandstone gas in reservoir A. Specifically, unconventional gas sweet spots in coal-bearing strata of groups b and c were evaluated sequentially to reveal the spatiotemporal distribution patterns of various lithological combinations, ultimately obtaining a planar distribution map of coal-bearing gas.

[0168] The results show that areas dominated by a single lithology are mainly for exploration of tight sandstone gas, coalbed methane, or shale gas, while areas with complex lithology are mainly for joint exploration and mining of multiple types of unconventional gas. The method for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas provided in this disclosure effectively guides the exploration, evaluation, and deployment of unconventional coal-bearing gas.

[0169] Example 6

[0170] Based on the same inventive concept, this application also provides a device for determining the lithological spatiotemporal distribution characteristics of coalbed methane, which can be used to implement the method described in the above embodiments, as shown in the following embodiments. Since the principle of the device for determining the lithological spatiotemporal distribution characteristics of coalbed methane is similar to that of the method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, the implementation of the device can refer to the implementation of the method for determining the lithological spatiotemporal distribution characteristics of coalbed methane, and repeated details will not be elaborated further. As used below, the terms "unit" or "module" can refer to a combination of software and / or hardware that performs a predetermined function. Although the system described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated.

[0171] The embodiments of the present invention provide a specific implementation of a device for determining the lithological spatiotemporal distribution characteristics of coalbed methane, which enables the determination of the lithological spatiotemporal distribution characteristics of coalbed methane. See also... Figure 9 A device for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas includes:

[0172] Sequence stratigraphic framework establishment module 10 is used to establish the sequence stratigraphic framework of the target work area based on cuttings logging data and well logging data of the target work area.

[0173] The dominant storage lithology determination module 20 is used to determine the dominant storage lithology corresponding to each type of coal-bearing gas.

[0174] Map creation module 30 is used to create well-connected profiles and lithological plan maps based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas.

[0175] The lithological spatiotemporal distribution characteristic determination module 40 is used to determine the lithological spatiotemporal distribution characteristics of the coal-bearing gas based on the well profile and the lithological plan view.

[0176] In some embodiments of this disclosure, the coalbed methane includes: coalbed methane, coalbed shale gas, and coalbed tight sandstone gas;

[0177] The sequence stratigraphic framework is a fourth-order sequence.

[0178] In some embodiments of this disclosure, the dominant lithology for storing coalbed methane is coal;

[0179] The dominant lithology for storing coal-bearing tight sandstone gas is medium-coarse clastic rock.

[0180] The dominant lithology for storing coal-bearing shale gas is carbonaceous shale.

[0181] In some embodiments of this disclosure, the dominant storage lithology determination module includes:

[0182] The carbonaceous shale identification unit is used to identify the carbonaceous shale using the well logging data and the geochemical data of the target work area.

[0183] In some embodiments of this disclosure, the carbonaceous shale determining unit includes:

[0184] A coal formation determination unit is used to determine the formation corresponding to the coal using the well logging data.

[0185] The carbonaceous shale identification subunit is used to identify the carbonaceous shale in strata other than the coal-bearing strata, based on a pre-established mapping relationship between the well logging data and the geochemical data.

[0186] In some embodiments of this disclosure, the geochemical data is total organic carbon;

[0187] The lithological spatiotemporal distribution characteristic determination module includes:

[0188] The lithological classification unit is used to classify the dominant storage lithology corresponding to the coalbed methane into single lithology and composite lithology based on the well profile and the lithological plan.

[0189] The spatiotemporal distribution characteristic determination unit is used to determine the spatiotemporal distribution characteristics of the single lithology and the spatiotemporal distribution characteristics of the composite lithology based on the well profile and the lithology plan view.

[0190] This disclosure provides a device for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas, comprising: a sequence stratigraphic framework establishment module for establishing a sequence stratigraphic framework of a target working area based on cuttings logging data and well logging data; a dominant storage lithology determination module for determining the dominant storage lithology corresponding to each type of coal-bearing gas; a map establishment module for establishing well-connected profiles and lithological plan maps based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas; and a lithological spatiotemporal distribution characteristic determination module for determining the lithological spatiotemporal distribution characteristics of coal-bearing gas based on the well-connected profiles and lithological plan maps.

[0191] In summary, the device for determining the lithological spatiotemporal distribution characteristics of coalbed methane provided in this disclosure utilizes core constraints, well logging lithology correction, and high-precision sequence stratigraphy isochronous framework constraints to form an effective analysis and evaluation of the spatiotemporal distribution law of lithology, thereby effectively realizing the evaluation of the spatiotemporal distribution law of coalbed methane, coalbed shale gas, and coalbed tight sandstone gas.

[0192] Example 7

[0193] Based on the above embodiments, this embodiment provides a computer device, including a memory, a processor, and a computer program stored in the memory, wherein the processor executes the computer program to implement the steps of the method described in the above embodiments.

[0194] In some embodiments of this example, a computer-readable storage medium is provided, on which a computer program is stored. When executed by a processor, the computer program implements the steps of the method described in the above embodiments, specifically including the following:

[0195] A sequence stratigraphic framework for the target work area is established based on cuttings logging data and well logging data of the target work area.

[0196] Determine the dominant reservoir lithology for each type of coal-bearing gas;

[0197] Based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas, well-connected profiles and lithological plan maps were established.

[0198] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view.

[0199] In some embodiments of this disclosure, the coalbed methane includes: coalbed methane, coalbed shale gas, and coalbed tight sandstone gas;

[0200] The sequence stratigraphic framework is a fourth-order sequence.

[0201] In some embodiments of this disclosure, the dominant lithology for storing coalbed methane is coal;

[0202] The dominant lithology for storing coal-bearing tight sandstone gas is medium-coarse clastic rock.

[0203] The dominant lithology for storing coal-bearing shale gas is carbonaceous shale.

[0204] In some embodiments of this disclosure, determining the dominant reservoir lithology corresponding to each type of coal-bearing gas includes:

[0205] The carbonaceous shale was identified using the well logging data and the geochemical data of the target work area.

[0206] In some embodiments of this disclosure, the carbonaceous shale is determined using the well logging data and the geochemical data of the target work area, including:

[0207] The formation corresponding to the coal is determined using the well logging data.

[0208] In strata other than the strata corresponding to the coal, the carbonaceous shale is determined based on the pre-established mapping relationship between the well logging data and the geochemical data.

[0209] In some embodiments of this disclosure, the geochemical data is total organic carbon;

[0210] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view, including:

[0211] Based on the well profile and the lithology plan, the dominant storage lithology corresponding to the coal-bearing gas is divided into single lithology and composite lithology.

[0212] Based on the well profile and the lithological plan view, determine the spatiotemporal distribution characteristics of the single lithology and the spatiotemporal distribution characteristics of the composite lithology.

[0213] In some embodiments of this example, a computer program product is provided, including a computer program / instructions. When executed by a processor, the computer program implements the steps of the method described in the above embodiments, specifically including the following:

[0214] A sequence stratigraphic framework for the target work area is established based on cuttings logging data and well logging data of the target work area.

[0215] Determine the dominant reservoir lithology for each type of coal-bearing gas;

[0216] Based on the sequence stratigraphic framework and the dominant storage lithology corresponding to each type of coal-bearing gas, well-connected profiles and lithological plan maps were established.

[0217] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view.

[0218] In some embodiments of this disclosure, the coalbed methane includes: coalbed methane, coalbed shale gas, and coalbed tight sandstone gas;

[0219] The sequence stratigraphic framework is a fourth-order sequence.

[0220] In some embodiments of this disclosure, the dominant lithology for storing coalbed methane is coal;

[0221] The dominant lithology for storing coal-bearing tight sandstone gas is medium-coarse clastic rock.

[0222] The dominant lithology for storing coal-bearing shale gas is carbonaceous shale.

[0223] In some embodiments of this disclosure, determining the dominant reservoir lithology corresponding to each type of coal-bearing gas includes:

[0224] The carbonaceous shale was identified using the well logging data and the geochemical data of the target work area.

[0225] In some embodiments of this disclosure, the carbonaceous shale is determined using the well logging data and the geochemical data of the target work area, including:

[0226] The formation corresponding to the coal is determined using the well logging data.

[0227] In strata other than the strata corresponding to the coal, the carbonaceous shale is determined based on the pre-established mapping relationship between the well logging data and the geochemical data.

[0228] In some embodiments of this disclosure, the geochemical data is total organic carbon;

[0229] The lithological spatiotemporal distribution characteristics of the coal-bearing gas are determined based on the well profile and the lithological plan view, including:

[0230] Based on the well profile and the lithology plan, the dominant storage lithology corresponding to the coal-bearing gas is divided into single lithology and composite lithology.

[0231] Based on the well profile and the lithological plan view, determine the spatiotemporal distribution characteristics of the single lithology and the spatiotemporal distribution characteristics of the composite lithology.

[0232] The processor may include, but is not limited to, one or more processors or microprocessors. Each processor may be implemented as an Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor, or other electronic component, for executing the methods in the above embodiments.

[0233] Computer-readable storage media can be implemented by any type of volatile or non-volatile storage device or a combination thereof. Computer-readable storage media may include, but are not limited to, random access memory (RAM), read-only memory (ROM), flash memory, EPROM memory, EEPROM memory, registers, and computer storage media (e.g., hard disks, floppy disks, solid-state drives, removable disks, CD-ROMs, DVD-ROMs, Blu-ray discs, etc.).

[0234] Computer-readable storage media may also store at least one computer-executable program / instruction, such as computer-readable instructions. Computer-readable storage media include, but are not limited to, volatile memory and / or non-volatile memory. Volatile memory may include, for example, random access memory (RAM) and / or cache memory. Computer-readable storage media may include, for example, read-only memory (ROM), hard disk, flash memory, etc. For example, a non-transitory computer-readable storage medium may be connected to a computing device such as a computer, and then, when the computing device executes the computer-readable instructions stored on the computer-readable storage medium, the various methods described above can be performed.

[0235] In addition, the computer device may include (but is not limited to) a data bus, an input / output (I / O) bus, a display, and input / output devices (e.g., keyboard, mouse, speakers, etc.).

[0236] The processor can communicate with external devices via the I / O bus through wired or wireless networks.

[0237] In one embodiment, the at least one computer-executable instruction may also be compiled into or comprise a software product / computer program product, wherein one or more computer-executable instructions are executed by a processor to perform the steps of the various functions and / or methods in the embodiments described herein.

[0238] In the embodiments provided in this disclosure, it should be understood that the disclosed apparatus and methods can also be implemented in other ways. The apparatus embodiments described above are merely illustrative; for example, the flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods, and computer program products according to various embodiments of this disclosure. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than those marked in the drawings. For example, two consecutive blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in a block diagram and / or flowchart, and combinations of blocks in block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or action, or using a combination of dedicated hardware and computer instructions.

[0239] It should be noted that, in this disclosure, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitation, an element limited by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0240] While the embodiments disclosed herein are as described above, the foregoing content is merely for the purpose of facilitating understanding of this disclosure and is not intended to limit this disclosure. Any person skilled in the art to which this disclosure pertains may make any modifications and changes in form and detail of the implementation without departing from the spirit and scope of this disclosure; however, the scope of patent protection of this disclosure shall still be determined by the scope defined in the appended claims.

Claims

1. A method for determining the lithological spatiotemporal distribution characteristics of coal measures gas, characterized in that, The method comprises the following steps: establishing a sequence stratigraphic framework of the target work area according to the cutting logging data and the logging data of the target work area; determining the dominant storage lithology corresponding to each coal measure gas; establishing a well-to-well profile and a lithology plan according to the sequence stratigraphic framework and the dominant storage lithology corresponding to each coal measure gas; determining the lithology spatiotemporal distribution characteristics of the coal measure gas according to the well-to-well profile and the lithology plan.

2. The method according to claim 1, wherein, The coal measure gas comprises coalbed methane, coal measure shale gas and coal measure tight sandstone gas. The sequence stratigraphic framework is a fourth-order sequence.

3. The method according to claim 2, characterized in that, The dominant storage lithology of the coalbed methane is coal. The dominant storage lithology of the coal measure tight sandstone gas is medium-coarse clastic rock. The dominant storage lithology of the coal measure shale gas is carbonaceous shale.

4. The method according to claim 3, characterized in that, The method for determining the dominant storage lithology corresponding to each coal measure gas comprises the following steps: determining the carbonaceous shale according to the logging data and geochemical data of the target work area.

5. The method according to claim 4, characterized in that, The method for determining the carbonaceous shale according to the logging data and geochemical data of the target work area comprises the following steps: determining the formation corresponding to the coal according to the logging data; determining the carbonaceous shale according to a pre-established mapping relationship between the logging data and the geochemical data in the formation other than the formation corresponding to the coal.

6. The method according to claim 4, wherein, The geochemical data is total organic carbon. The method for determining the lithology spatiotemporal distribution characteristics of the coal measure gas according to the well-to-well profile and the lithology plan comprises the following steps: dividing the dominant storage lithology corresponding to the coal measure gas into single lithology and composite lithology according to the well-to-well profile and the lithology plan; determining the lithology spatiotemporal distribution characteristics of the single lithology and the lithology spatiotemporal distribution characteristics of the composite lithology according to the well-to-well profile and the lithology plan.

7. A device for determining the lithological spatiotemporal distribution characteristics of coal measures gas, characterized in that, The method comprises the following steps: a sequence stratigraphic framework establishing module, configured to establish a sequence stratigraphic framework of a target work area according to cutting logging data and logging data of the target work area; a dominant storage lithology determining module, configured to determine the dominant storage lithology corresponding to each coal measure gas; a drawing establishing module, configured to establish a well-to-well profile and a lithology plan according to the sequence stratigraphic framework and the dominant storage lithology corresponding to each coal measure gas; a lithology spatiotemporal distribution characteristics determining module, configured to determine the lithology spatiotemporal distribution characteristics of the coal measure gas according to the well-to-well profile and the lithology plan.

8. A computer device comprising a memory, a processor, and a computer program stored on the memory, wherein the computer program comprises instructions that, when executed by the processor, cause the processor to perform the method of any one of claims 1-7. The processor executes the computer program to implement the steps of the method for determining the lithology spatiotemporal distribution characteristics of the coal measure gas according to any one of claims 1 to 6.

9. A computer-readable storage medium having stored thereon a computer program, characterized in that, The computer program is executed by the processor to implement the steps of the method for determining the lithology spatiotemporal distribution characteristics of the coal measure gas according to any one of claims 1 to 6.

10. A computer program product comprising computer programs / instructions, characterized in that, The computer program is executed by the processor to implement the steps of the method for determining the lithology spatiotemporal distribution characteristics of the coal measure gas according to any one of claims 1 to 6.

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