CN117328852A - Method, terminal and medium for determining favorable region of shale gas in sea-land transition phase - Google Patents
Method, terminal and medium for determining favorable region of shale gas in sea-land transition phase Download PDFInfo
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- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
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Abstract
The invention provides a method, a terminal and a medium for determining a favorable region of sea-land transition phase shale gas, wherein a plurality of basic parameter sets of each first region are firstly obtained; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters; then, for each first area, calculating the combination parameters corresponding to the basic parameter sets; calculating the favorability parameters of the first areas according to the combination parameters of the first areas; finally, the favorable region of the area to be mined is determined from the first areas according to the favorable parameters of the first areas. The basic parameters are classified and combined to calculate the combination parameters, and then the overall favorable parameters are calculated according to the combination parameters, so that the compensatory property among the key parameters can be fully considered, and the accuracy of the determination of the favorable region in the shale gas is improved.
Description
Technical Field
The invention belongs to the technical field of oil and gas exploration and development, and particularly relates to a method, a terminal and a medium for determining a favorable region of a sea-land transition phase shale gas.
Background
Shale gas is an unconventional natural gas resource that is resident in shale and has become an important component of the energy supply as an independent mineral seed. The sea-land transition phase shale gas is used as a strategic successor field of shale gas industrial development, has the characteristics of large resource potential, wide distribution range, large vertical thickness, occurrence of other types of natural gas accompaniment and the like, but simultaneously has the characteristics of frequent change of sea-land transition phase stratum deposition environment, frequent interbedded sandstone, shale, limestone, coal and the like, large shale thickness change, high clay mineral content and the like. Thus, there is a need for advantageous layering and advantageous zoning of the land-sea transition phase shale gas.
Currently, common methods for advantageous formation and advantageous zone determination of shale gas include: geological analysis, shale gas geological condition analogy, geophysical interpretation, key parameter equivalent coil determination and the like. The above-described methods generally rely on several key parameters, ignoring compensatory properties between certain key parameters, such as adequately high TOC (total organic carbon ) content formations where shale thickness requirements are suitably reduced. Thus, the prior art methods are inaccurate in determining the beneficial zone in shale gas.
Disclosure of Invention
In view of the above, the invention provides a method, a terminal and a medium for determining a favorable region of a sea-land transition phase shale gas, which aim to solve the problem of inaccurate determination of the favorable region in the shale gas in the prior art.
The first aspect of the embodiment of the invention provides a method for determining a favorable region of a sea-land transitional phase shale gas, which comprises the following steps:
acquiring a plurality of basic parameter sets of each first area; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters;
for each first region, calculating a combination parameter corresponding to each basic parameter set;
calculating the favorability parameters of the first areas according to the combination parameters of the first areas;
based on the benefit parameters of each first zone, a benefit zone of the zone to be mined is determined from within each first zone.
A second aspect of the embodiment of the present invention provides a device for determining a favorable region of a sea-land transition phase shale gas, including:
the acquisition module is used for acquiring a plurality of basic parameter sets of each first area; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters;
the combination module is used for calculating combination parameters corresponding to each basic parameter set for each first area;
The calculation module is used for calculating the favorability parameters of the first areas according to the combination parameters of the first areas;
and the determining module is used for determining the favorable region of the to-be-mined area from the first areas according to the favorable parameters of the first areas.
A third aspect of an embodiment of the present invention provides a terminal comprising a memory, a processor and a computer program stored in the memory and executable on the processor, the processor implementing the steps of the method for determining a land-sea transition phase shale gas vantage point as above in the first aspect when executing the computer program.
A fourth aspect of an embodiment of the present invention provides a computer readable storage medium storing a computer program which when executed by a processor performs the steps of the method for determining a land-sea transition phase shale gas vantage point of the first aspect above.
The method, the terminal and the medium for determining the favorable region of the sea-land transition phase shale gas provided by the embodiment of the invention firstly acquire a plurality of basic parameter sets of each first region; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters; then, for each first area, calculating the combination parameters corresponding to the basic parameter sets; calculating the favorability parameters of the first areas according to the combination parameters of the first areas; finally, the favorable region of the area to be mined is determined from the first areas according to the favorable parameters of the first areas. The basic parameters are classified and combined to calculate the combination parameters, and then the overall favorable parameters are calculated according to the combination parameters, so that the compensatory property among the key parameters can be fully considered, and the accuracy of the determination of the favorable region in the shale gas is improved.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings that are needed in the embodiments or the description of the prior art will be briefly described below, it being obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is an application scene diagram of a method for determining a favorable region of a shale gas in a sea-land transition phase, which is provided by the embodiment of the invention;
FIG. 2 is a flow chart of an implementation of a method for determining a favorable region of a shale gas in a sea-land transition phase provided by an embodiment of the invention;
FIG. 3 is a schematic structural view of a device for determining a favorable region of a shale gas in a sea-land transition phase, which is provided by the embodiment of the invention;
fig. 4 is a schematic structural diagram of a terminal according to an embodiment of the present invention.
Detailed Description
In the following description, for purposes of explanation and not limitation, specific details are set forth such as the particular system architecture, techniques, etc., in order to provide a thorough understanding of the embodiments of the present invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced in other embodiments that depart from these specific details. In other instances, detailed descriptions of well-known systems, devices, circuits, and methods are omitted so as not to obscure the description of the present invention with unnecessary detail.
Fig. 1 is an application scene diagram of a method for determining a favorable region of a shale gas in a sea-land transition phase, which is provided by the embodiment of the invention. As shown in fig. 1, in some embodiments, the wearable electrocardiograph monitor includes a data acquisition system 11 and a terminal 12.
The data acquisition system is used for acquiring data measured by a test sample laboratory, an earthquake, a well logging, a well testing and the like, and sending the data to the terminal 12, the terminal 12 determines an advantageous region according to the received data, and related personnel can check the advantageous region in the to-be-mined region on the terminal 12 so as to make a mining plan.
The shale gas beneficial zone determination method in the prior art generally has the following disadvantages:
(1) The existing sea-phase shale gas (slope-land canopy phase) stratum and land-phase shale gas (half-deep lake phase) stratum which are broken through have the characteristics of single lithology, stable distribution, large shale thickness and the like, while the sea-land transition phase stratum has the characteristics of lithology change, frequent interbedded sand-mud coal ash, uneven shale thickness distribution and the like, and the existing shale gas selecting method lacks applicability to the development geological characteristics of the sea-land transition phase shale gas;
(2) The existing method for selecting the favorable layers and the favorable regions of the shale gas is focused on the acquisition of a plurality of key parameters (such as thickness, TOC content, burial depth, gas content and the like) and the determination of the favorable regions, so that the compensatory property among certain key parameters is ignored, for example, the requirement on the thickness of the shale can be properly reduced when the TOC content of a stratum is large enough;
(3) The prior method has less consideration on geological units of which the geological boundary can be naturally divided on the layer section and the area of the area to be determined, and further lacks the comparison of different geological units;
(4) The lack of clear constraint in the aspects of the acquisition method, the approach, the quantity and the like of the data and the parameters leads to various uncertainties in the aspects of the credibility, the comparability, the reproducibility and the like of the determination results of the favorable region;
(5) The existing method lacks classification and layering of basic parameters, and does not consider the same aspect that a certain parameter possibly reflects the determination of the beneficial region of shale gas at the same time;
(6) The existing method is mainly based on the acquired knowledge about successfully developed sea and land shale gas, and lacks specific consideration on the specificity of the sea-land transition phase shale gas, and has obvious defects in the aspects of parameter selection and processing, method use and favorable region determination.
In view of this, the present invention is improved on the basis of conventional methods. Fig. 2 is a flowchart of an implementation of a method for determining a favorable region of a shale gas in a sea-land transition phase provided by an embodiment of the invention. As shown in fig. 2, the land-sea transition phase shale gas vantage point determination method is applied to the terminal 12 shown in fig. 1, and the method includes:
S210, acquiring a plurality of basic parameter sets of each first area; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters.
In the embodiment of the invention, the first area (interval) of the area to be mined is divided on the basis of comprehensively considering two factors of geology and engineering. For interval division, factors such as deposition gyration, lithology combination change, special lithology distribution of magma rock and the like, non-integration interface, coal content of stratum, engineering fracturing thickness and the like are fully considered, main factors of basic interval division are selected, and other factors are considered to comprehensively divide each interval unit. The first area division of the area to be mined needs to consider factors such as fault limit, construction form, outcrop pinch, magma invasion limit, depth range, surface river, basic fracturing construction unit range condition and the like, and meanwhile, the requirement of introducing development planning can be considered according to actual conditions.
In the embodiment of the invention, the division of the basic parameter sets can be expert division, shale exploitation data of each region can also be obtained, correlation analysis is carried out on each basic parameter in the data, and the basic parameters with the correlation larger than the preset correlation degree are divided into a group, wherein the same basic parameters can be simultaneously in different basic parameter sets.
In some embodiments, the plurality of base parameter sets is five base parameter sets; the first set of base parameters includes total organic carbon content and shale thickness; the second set of base parameters includes porosity and permeability; the third basic parameter set comprises gas content and a running-sucking ratio; the fourth set of base parameters includes brittle mineral content and mechanical parameters; the fifth set of base parameters includes reservoir pressure gradient and gas saturation; accordingly, S210 may include: determining the total organic carbon content, the porosity, the permeability, the gas content, the free-flowing ratio, the brittle mineral content, the mechanical parameters and the gas saturation of each first region according to the test result of the shale sample of each first region; shale thickness and reservoir pressure gradients for each first zone are obtained from well test data for each first zone.
In an embodiment of the invention, formation thickness data is obtained from drilling and logging data, and reservoir pressure gradient data is obtained from well testing data. And obtaining TOC content, porosity, permeability, mineral content, mechanical parameters and gas saturation of the shale sample by an experimental test method according to related experimental test standards.
In the embodiment of the invention, on the basis of acquiring the basic parameter data, the basic parameters are required to be subjected to statistical analysis, and the statistical parameters comprise quantity, average value, maximum value, minimum value, median and the like. To ensure reliability of the evaluation results, more than 30 data volumes are ensured for each parameter, and samples are sampled in the vertical and plane directions with enough representativeness and representativeness, and the distribution of the samples accords with the basic rule of geological sample collection. The statistical parameter maxima and minima are used for the construction of the subsequent combined parameters.
Taking TOC content as an example, the average TOC content is calculated as follows:
wherein, TOC i The TOC content was measured in%. To ensure the material basis of shale gas enrichment, the method is to averageThe content gives a constraint of 0.5%. For the whole block, most basic parameters should meet the constraint requirement of the lower limit value, if most parameters meet the constraint of the lower limit value, the whole area is considered to be less favorable, and more favorable shale gas intervals or blocks are difficult to be optimized.
In the embodiment of the invention, the air content Q is obtained by the following formula:
QQ desorption of +Q Loss of +Q Residual of (2)
Wherein Q is Desorption of 、Q Loss of And Q Residual of The desorption gas amount, the loss gas amount and the residual gas amount are respectively m 3 And/t. The desorption gas amount and the residual gas amount can be directly measured according to the shale gas content test related standard, and the loss gas amount can be obtained according to the standard of the loss gas amount estimation method.
The loss gas quantity is calculated by the following formula:
wherein t and t 0 The desorption time and the loss time are respectively given in minutes.
The adsorption gas quantity Q can be obtained by combining isothermal adsorption experimental results of received basal shale samples with actual stratum conditions Adsorption of ：
Wherein Q is Adsorption max [m 3 /t]And P L [MPa]The maximum adsorption gas amount and the Langmuir pressure are respectively obtained through isothermal adsorption experimental data fitting. The middle brackets are the units of each parameter; p is the reservoir pressure in MPa under the actual formation conditions. Isothermal adsorption experimental temperature conditions were set to the actual formation reservoir temperature.
In an embodiment of the invention, the reservoir pressure P, the reservoir temperature T, the shale rock density rho and the gas saturation S are obtained g The free air quantity Q under standard conditions (temperature 0 ℃ and pressure 101.325 kPa) can be further obtained through theoretical calculation Free form [m 3 /t]：
Wherein P is the reservoir pressure under the actual stratum condition, and the unit is MPa; t is the reservoir temperature under actual formation conditions in degrees celsius; z is Z 1 And Z 2 The compression factors of the gas under standard conditions and reservoir conditions are dimensionless; s is S g Is the saturation of gas, the unit is; ρ is shale rock density in t/m 3 (or g/cm) 3 )。
According to the obtained adsorption gas quantity Q Adsorption of And the free air quantity Q Free form Value, suction ratio (R Free form / Adsorption of ) (dimensionless) can be calculated by the following formula:
in an embodiment of the invention, the compressibility parameter brittle mineral content is specifically the rock mineral brittleness index BI Mi Specifically, the method can be calculated by the following formula:
wherein W is quartz, carbonate rock amount and clay content, and the units are% respectively.
The mechanical parameter is specifically rock mechanical brittleness index BI Me Specifically, the method can be calculated by the following formula:
wherein E is Brit Normalized elastic modulus, mu Brit Is the normalized poisson ratio. E. E (E) min And E is max Respectively as samplesYoung's modulus, minimum Young's modulus and maximum Young's modulus, all in GPa; u, u min And u max The poisson ratio, the minimum poisson ratio and the maximum poisson ratio of the sample are dimensionless parameters respectively.
The reservoir pressure gradient G [ MPa/100m ] is calculated as follows:
in the above, H 1 And H 0 The depth of the buried zone and the wind oxidation zone from the ground surface is 100m respectively; p (P) 1 And P 0 Respectively the burial depths are H 1 And H 0 The pressure at the two positions is MPa.
Saturation of gas S g [％]The calculation formula is as follows:
S g ＝100-S w (12)
wherein S is w The core is irreducible water saturation in%.
Meanwhile, in order to meet the condition that more favorable layers or blocks exist in the unit, the invention constrains the lower limit value of the average value of the basic parameters, and the specific constraint criteria are shown in table 1.
TABLE 1 lower limit of the mean value of the basic parameters
S220, for each first area, calculating the combination parameters corresponding to the basic parameter sets.
In some embodiments, S220 may include: calculating basic combination parameters of resources according to the total organic carbon content and the shale thickness; calculating reservoir physical property combination parameters according to the porosity and the permeability; calculating a gas-containing combination parameter according to the gas content and the air-sucking ratio; calculating a compressibility combination parameter according to the content of the brittle minerals and the mechanical parameters; based on the reservoir pressure gradient and the gas saturation, a partitionability combination parameter is calculated.
Optionally, the resource basic combination parameters are:
wherein k is 1 TOC for resource-based composition parameters i The total organic carbon content of the ith test sample corresponding to the first region is expressed in units; TOC (total organic carbon) max And TOC min The maximum value and the minimum value of the total organic carbon content of all the test samples corresponding to the first area are given in units; h i The unit of the shale thickness is m, which is the ith measuring point of the first area; h max And H min The unit of the maximum value and the minimum value of the shale thickness of all the layers in the first area is m; m is m 1 The number of the test samples corresponding to the total organic carbon content is dimensionless, n 1 The number of measuring points is the shale thickness, and is dimensionless;
optionally, the reservoir physical property combination parameters are:
wherein k is 2 Is a combination parameter of physical properties of the reservoir,the unit is the ith measured porosity value in the first region;and->The unit is the maximum value and the minimum value of the porosities of all the test samples in the first area; k (K) i The ith measured permeability in nD in the first zone; k (K) max And K min The unit of the maximum value and the minimum value of the shale thickness of all the intervals is nD; m is m 2 For the number of the test samples corresponding to the porosity, the sample is dimensionless and n 2 The number of the test samples corresponding to the permeability is dimensionless;
Optionally, the gas-containing combination parameters are:
wherein k is 3 As a gas-containing combination parameter, Q i For the gas content value of the ith test sample in the first zone, the unit is m 3 /t；Q max And Q min The unit of the maximum value and the minimum value of the air content of all the test samples in the first area is m 3 /t；R Free/adsorbed i The ith measured running-sucking ratio in the first area is dimensionless; r is R Free/adsorption max And R is Free/adsorb min The maximum value and the minimum value of the upstream suction ratio in the first area are dimensionless parameters; m is m 3 The number of the test samples corresponding to the gas content is dimensionless, n 3 The number of the test samples corresponding to the sucking ratio is dimensionless.
Optionally, the compressibility combination parameters are:
wherein k is 4 As a compressibility combination parameter, BI Mi i is the rock mineral brittleness index of the ith test sample in the first zone in m 3 /t；BI Mimax And BI (BI) Mimin The units of the maximum value and the minimum value of the rock mineral brittleness index of all the test samples in the first area are m 3 /t；BI Me i is the rock mechanical brittleness index of the ith measuring point in the first area, and is dimensionless; BI (BI) Me max and BI Me min is the maximum value and the minimum value of the mechanical brittleness index in the first area, and both are dimensionless parameters; m is m 4 For the number of test samples corresponding to the rock mineral brittleness index, n 4 The number of the test samples corresponding to the rock mechanical brittleness index is dimensionless;
optionally, the acquirability combination parameters are:
wherein k is 5 G as a combination of the acquirability parameters i The reservoir pressure gradient is the ith measuring point in the first area, and the unit is MPa/100m; g max And G min The unit of the maximum value and the minimum value of all reservoir pressure gradient data in the first area is MPa/100m; s is S gi The gas saturation in units of the ith test sample in the first zone; s is S gmax And S is gmin The maximum value and the minimum value of the saturation of the gas in the first area are given by the units; m is m 5 The number of measuring points for the reservoir pressure gradient is dimensionless; n is n 5 The number of the test samples corresponding to the gas saturation value is dimensionless.
S230, calculating the advantage parameters of the first areas according to the combination parameters of the first areas.
Specifically, S230 may include:
wherein k is an advantage parameter, mu is the number of combined parameters, k i Is the i-th combination parameter. Alternatively, μmay be 1/5.
Specifically, S230 may further include:
wherein k is an advantage parameter, mu is the number of combined parameters, k i For the i-th combination parameter,
wherein, if the same basic parameter exists between two basic parameter sets, lambda for the two basic parameter sets i It is also possible to reduce, for example, a/b/c, where a is the correlation between two base parameter sets after removal of the same base parameter, b is the number of the same base parameters, and c is the two base parametersThe number average of the basic parameters of the array.
S240, determining the favorable region of the to-be-mined area from the first areas according to the favorable parameters of the first areas.
In some embodiments, S240 may include: determining the favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region and a first preset threshold value;
the method further comprises the steps of:
determining a more favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region, the first preset threshold value and the second preset threshold value;
determining a less favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region, the second preset threshold and the third preset threshold;
and determining unfavorable areas of the areas to be mined from the first areas according to the favorable parameters of the first areas and a third preset threshold value.
In the embodiment of the present invention, the first preset threshold may be 0.25, the second preset threshold may be 0.5, and the third preset threshold is 0.75.
In summary, the beneficial effects of the invention are as follows:
(1) The method has strong pertinence and applicability to favorable intervals and favorable areas of the shale gas in the sea-land transition phase, and overcomes the inaccuracy of favorable interval selection of the prior shale gas;
(2) The method and the way for acquiring different basic parameters are clarified, so that the determination results of the favorable intervals/favorable areas of the shale gas in the sea-land transition phases of different areas, times and layers have strong comparability;
(3) Based on the basic parameters, the thought of evaluating by adopting the combined parameters is provided, and the limitation of single basic parameter calculation is overcome;
(4) The combination parameters are used as the basis for calculation, so that the comparison of various basic aspects affecting the shale gas advantage can be realized;
(5) By dividing geological units, the contrast evaluation of different units is realized, and meanwhile, a relatively clear basis and a relatively clear direction can be provided for the optimization and development layout of the next well position;
(6) The method is not only suitable for the shale gas of the sea-land transition phase, but also has strong applicability to the shale gas of the sea phase and the land phase, and has wider application range and field than the prior method;
(7) The lower limit value of the average value of the basic parameters is restrained, and a combined parameter calculation method is adopted, so that the calculation result can ensure that the favorable interval or favorable region of shale gas is optimized on the premise of having resource potential;
(8) The implementation of the invention is mainly based on objective actual measurement experimental data or geological data, and the calculation process is based on objective statistics or calculated data results, so that the calculation results are less influenced by subjective factors;
(9) The invention determines the basic step flow of the favorable layer selection and favorable region selection of the shale gas of the sea-land transition phase, so that the development of the favorable layer selection and region selection work is more standard, feasible and reasonable.
It should be understood that the sequence number of each step in the foregoing embodiment does not mean that the execution sequence of each process should be determined by the function and the internal logic, and should not limit the implementation process of the embodiment of the present invention.
Fig. 3 is a schematic structural diagram of a device for determining a favorable region of a shale gas in a sea-land transition phase, which is provided by the embodiment of the invention. As shown in fig. 3, in some embodiments, the spill tracing device 3 based on the remote sensing image and the spectrum image includes:
an obtaining module 310, configured to obtain a plurality of basic parameter sets of each first area; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters;
a combination module 320, configured to calculate, for each first area, a combination parameter corresponding to each base parameter set;
A calculation module 330, configured to calculate an advantage parameter of each first region according to the combined parameter of each first region;
a determining module 340 is configured to determine a favorable zone of the to-be-mined area from within each first zone according to the favorable parameters of each first zone.
Optionally, the computing module 330 is configured to:
wherein k is an advantage parameter, mu is the number of combined parameters, k i Is the i-th combination parameter.
Optionally, the plurality of base parameter sets is five base parameter sets; the first set of base parameters includes total organic carbon content and shale thickness; the second set of base parameters includes porosity and permeability; the third basic parameter set comprises gas content and a running-sucking ratio; the fourth set of base parameters includes brittle mineral content and mechanical parameters; the fifth set of base parameters includes reservoir pressure gradient and gas saturation; an acquisition module 310, configured to: determining the total organic carbon content, the porosity, the permeability, the gas content, the free-flowing ratio, the brittle mineral content, the mechanical parameters and the gas saturation of each first region according to the test result of the shale sample of each first region; shale thickness and reservoir pressure gradients for each first zone are obtained from well test data for each first zone.
Optionally, the combination module 320 is configured to: calculating basic combination parameters of resources according to the total organic carbon content and the shale thickness; calculating reservoir physical property combination parameters according to the porosity and the permeability; calculating a gas-containing combination parameter according to the gas content and the air-sucking ratio; calculating a compressibility combination parameter according to the content of the brittle minerals and the mechanical parameters; based on the reservoir pressure gradient and the gas saturation, a partitionability combination parameter is calculated.
Optionally, the resource basic combination parameters are:
wherein k is 1 TOC for resource-based composition parameters i The ith corresponding to the first areaThe total organic carbon content of the test sample is in units of; TOC (total organic carbon) max And TOC min The maximum value and the minimum value of the total organic carbon content of all the test samples corresponding to the first area are given in units; h i The unit of the shale thickness is m, which is the ith measuring point of the first area; h max And H min The unit of the maximum value and the minimum value of the shale thickness of all the layers in the first area is m; m is m 1 The number of the test samples corresponding to the total organic carbon content is dimensionless, n 1 The number of measuring points is the shale thickness, and is dimensionless;
the physical property combination parameters of the reservoir are as follows:
wherein k is 2 Is a combination parameter of physical properties of the reservoir,the unit is the ith measured porosity value in the first region; And->The unit is the maximum value and the minimum value of the porosities of all the test samples in the first area; k (K) i The ith measured permeability in nD in the first zone; k (K) max And K min The unit of the maximum value and the minimum value of the shale thickness of all the intervals is nD; m is m 2 For the number of the test samples corresponding to the porosity, the sample is dimensionless and n 2 The number of the test samples corresponding to the permeability is dimensionless;
the gas-containing combination parameters were:
wherein k is 3 As a gas-containing combination parameter, Q i Gas content for the ith test sample in the first zoneMagnitude in m 3 /t；Q max And Q min The unit of the maximum value and the minimum value of the air content of all the test samples in the first area is m 3 /t；R Free/adsorbed i The ith measured running-sucking ratio in the first area is dimensionless; r is R Free/adsorption max And R is Free/adsorb min The maximum value and the minimum value of the upstream suction ratio in the first area are dimensionless parameters; m is m 3 The number of the test samples corresponding to the gas content is dimensionless, n 3 The number of the test samples corresponding to the sucking ratio is dimensionless.
Optionally, the compressibility combination parameters are:
wherein k is 4 As a compressibility combination parameter, BI Mi i is the rock mineral brittleness index of the ith test sample in the first zone in m 3 /t；BI Mimax And BI (BI) Mimin The units of the maximum value and the minimum value of the rock mineral brittleness index of all the test samples in the first area are m 3 /t；BI Me i is the rock mechanical brittleness index of the ith measuring point in the first area, and is dimensionless; BI (BI) Me max and BI Me min is the maximum value and the minimum value of the mechanical brittleness index in the first area, and both are dimensionless parameters; m is m 4 For the number of test samples corresponding to the rock mineral brittleness index, n 4 The number of the test samples corresponding to the rock mechanical brittleness index is dimensionless;
the combination parameters of the acquirability are as follows:
wherein k is 5 G as a combination of the acquirability parameters i The reservoir pressure gradient is the ith measuring point in the first area, and the unit is MPa/100m; g max And G min The unit of the maximum value and the minimum value of all reservoir pressure gradient data in the first area is MPa/100m; s is S gi The gas saturation in units of the ith test sample in the first zone; s is S gmax And S is gmin The maximum value and the minimum value of the saturation of the gas in the first area are given by the units; m is m 5 The number of measuring points for the reservoir pressure gradient is dimensionless; n is n 5 The number of the test samples corresponding to the gas saturation value is dimensionless.
Optionally, the computing module 330 is configured to:
wherein k is an advantage parameter, mu is the number of combined parameters, k i For the i-th combination parameter,
optionally, the determining module 340 is configured to: determining the favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region and a first preset threshold value;
optionally, the determining module 340 is further configured to determine, according to the benefit parameter of each first area, the first preset threshold value, and the second preset threshold value, a more beneficial area of the to-be-mined area from each first area; determining a less favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region, the second preset threshold and the third preset threshold; and determining unfavorable areas of the areas to be mined from the first areas according to the favorable parameters of the first areas and a third preset threshold value.
The device for determining the favorable region of the sea-land transition phase shale gas provided by the embodiment can be used for executing the method embodiment, and the implementation principle and the technical effect are similar, and the embodiment is not repeated here.
Fig. 4 is a schematic structural diagram of a terminal according to an embodiment of the present invention. As shown in fig. 4, a terminal 4 according to an embodiment of the present invention is provided, and the terminal 4 according to the embodiment includes: a processor 40, a memory 41 and a computer program 42 stored in the memory 41 and executable on the processor 40. The processor 40, when executing the computer program 42, performs the steps described above in various embodiments of methods for determining the beneficial zone of a sea-land transition phase shale gas, such as the steps shown in fig. 2. Alternatively, the processor 40, when executing the computer program 42, performs the functions of the modules/units of the system embodiments described above, e.g., the functions of the modules shown in fig. 4.
By way of example, the computer program 42 may be partitioned into one or more modules/units, which are stored in the memory 41 and executed by the processor 40 to complete the present invention. One or more of the modules/units may be a series of computer program instruction segments capable of performing a specific function for describing the execution of the computer program 42 in the terminal 4.
The terminal 4 may be a terminal or a server, and the terminal may be a mobile phone, an MCU, an ECU, an industrial personal computer, etc., which are not limited herein, and the server may be a physical server, a cloud server, etc., which are not limited herein. The terminal 4 may include, but is not limited to, a processor 40, a memory 41. It will be appreciated by those skilled in the art that fig. 4 is merely an example of the terminal 4 and is not intended to limit the terminal 4, and may include more or fewer components than shown, or may combine certain components, or different components, e.g., the terminal may further include an input-output device, a network access device, a bus, etc.
The processor 40 may be a central processing unit (Central Processing Unit, CPU), other general purpose processors, digital signal processors (Digital Signal Processor, DSP), application specific integrated circuits (Application Specific Integrated Circuit, ASIC), field-programmable gate arrays (Field-Programmable Gate Array, FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, or the like. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like.
The memory 41 may be an internal storage unit of the terminal 4, such as a hard disk or a memory of the terminal 4. The memory 41 may also be an external storage device of the terminal 4, such as a plug-in hard disk provided on the terminal 4, a Smart Media Card (SMC), a Secure Digital (SD) Card, a Flash memory Card (Flash Card), or the like. Further, the memory 41 may also include both an internal storage unit and an external storage device of the terminal 4. The memory 41 is used to store computer programs and other programs and data required by the terminal. The memory 41 may also be used to temporarily store data that has been output or is to be output.
The embodiment of the invention provides a computer readable storage medium, wherein the computer readable storage medium stores a computer program, and the computer program realizes the steps in the embodiment of the method for determining the beneficial region of the sea-land transition phase shale gas when being executed by a processor.
The computer readable storage medium stores a computer program 42, the computer program 42 comprising program instructions which, when executed by the processor 40, implement all or part of the processes of the above described embodiments, or may be implemented by means of hardware associated with the instructions of the computer program 42, the computer program 42 being stored in a computer readable storage medium, the computer program 42, when executed by the processor 40, implementing the steps of the above described embodiments of the method. The computer program 42 comprises computer program code, which may be in the form of source code, object code, executable files, or in some intermediate form, among others. The computer readable medium may include: any entity or device capable of carrying computer program code, a recording medium, a U disk, a removable hard disk, a magnetic disk, an optical disk, a computer Memory, a Read-Only Memory (ROM), a random access Memory (RAM, random Access Memory), an electrical carrier signal, a telecommunications signal, a software distribution medium, and so forth.
The computer readable storage medium may be an internal storage unit of the terminal of any of the foregoing embodiments, such as a hard disk or a memory of the terminal. The computer readable storage medium may also be an external storage device of the terminal, such as a plug-in hard disk, a Smart Media Card (SMC), a Secure Digital (SD) Card, a Flash memory Card (Flash Card) or the like, which are provided on the terminal. Further, the computer-readable storage medium may also include both an internal storage unit of the terminal and an external storage device. The computer-readable storage medium is used to store a computer program and other programs and data required for the terminal. The computer-readable storage medium may also be used to temporarily store data that has been output or is to be output.
It should be understood that the sequence number of each step in the foregoing embodiment does not mean that the execution sequence of each process should be determined by the function and the internal logic, and should not limit the implementation process of the embodiment of the present invention.
It will be apparent to those skilled in the art that, for convenience and brevity of description, only the above-described division of the functional units and modules is illustrated, and in practical application, the above-described functional distribution may be performed by different functional units and modules according to needs, i.e. the internal structure of the apparatus is divided into different functional units or modules to perform all or part of the above-described functions. The functional units and modules in the embodiment may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit, where the integrated units may be implemented in a form of hardware or a form of a software functional unit. In addition, specific names of the functional units and modules are only for convenience of distinguishing from each other, and are not used for limiting the protection scope of the present application. The specific working process of the units and modules in the above system may refer to the corresponding process in the foregoing method embodiment, which is not described herein again.
In the foregoing embodiments, the descriptions of the embodiments are emphasized, and in part, not described or illustrated in any particular embodiment, reference is made to the related descriptions of other embodiments.
Those of ordinary skill in the art will appreciate that the various illustrative elements and algorithm steps described in connection with the embodiments disclosed herein may be implemented as electronic hardware, or combinations of computer software and electronic hardware. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the solution. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present invention.
In the embodiments provided in the present invention, it should be understood that the disclosed apparatus/terminal and method may be implemented in other manners. For example, the apparatus/terminal embodiments described above are merely illustrative, e.g., the division of modules or units is merely a logical functional division, and there may be additional divisions when actually implemented, e.g., multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. Alternatively, the coupling or direct coupling or communication connection shown or discussed may be an indirect coupling or communication connection via interfaces, devices or units, which may be in electrical, mechanical or other forms.
The units described as separate units may or may not be physically separate, and units shown as units may or may not be physical units, may be located in one place, or may be distributed over a plurality of network units. Some or all of the units may be selected according to actual needs to achieve the purpose of the solution of this embodiment.
In addition, each functional unit in the embodiments of the present invention may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit. The integrated units may be implemented in hardware or in software functional units.
The integrated modules/units, if implemented in the form of software functional units and sold or used as stand-alone products, may be stored in a computer readable storage medium. Based on such understanding, the present invention may implement all or part of the flow of the method of the above embodiment, or may be implemented by a computer program to instruct related hardware, and the computer program may be stored in a computer readable storage medium, where the computer program, when executed by a processor, may implement the steps of each of the method embodiments described above. Wherein the computer program comprises computer program code, which may be in the form of source code, object code, executable files or in some intermediate form, etc. The computer readable medium may include: any entity or device capable of carrying computer program code, a recording medium, a U disk, a removable hard disk, a magnetic disk, an optical disk, a computer Memory, a Read-Only Memory (ROM), a random access Memory (RAM, random Access Memory), an electrical carrier signal, a telecommunications signal, a software distribution medium, and so forth.
The above embodiments are only for illustrating the technical solution of the present invention, and are not limiting; although the invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit and scope of the technical solutions of the embodiments of the present invention, and are intended to be included in the scope of the present invention.
Claims (10)
1. A method for determining a favorable region of a sea-land transition phase shale gas, which is characterized by comprising the following steps:
acquiring a plurality of basic parameter sets of each first area; wherein the zone to be mined comprises a plurality of first zones; each base parameter set includes at least two base parameters;
for each first region, calculating a combination parameter corresponding to each basic parameter set;
calculating the favorability parameters of the first areas according to the combination parameters of the first areas;
the zone of interest of the zone to be mined is determined from within each first zone based on the parameters of interest of each first zone.
2. The method for determining the favorable region of the sea-land transition phase shale gas according to claim 1, wherein the calculating the favorable parameters of each first region according to the combined parameters of each first region comprises:
wherein k is the favorability parameter, mu is the number of combined parameters, k i Is the i-th combination parameter.
3. The method for determining the favorable region of the sea-land transition phase shale gas according to claim 2, wherein the plurality of basic parameter sets are five basic parameter sets; the first set of base parameters includes total organic carbon content and shale thickness; the second set of base parameters includes porosity and permeability; the third basic parameter set comprises gas content and a running-sucking ratio; the fourth set of base parameters includes brittle mineral content and mechanical parameters; the fifth set of base parameters includes reservoir pressure gradient and gas saturation;
the acquiring a plurality of basic parameter sets of each first area includes:
determining the total organic carbon content, the porosity, the permeability, the gas content, the free-flowing ratio, the brittle mineral content, the mechanical parameters and the gas saturation of each first region according to the test result of the shale sample of each first region;
shale thickness and reservoir pressure gradients for each first zone are obtained from well test data for each first zone.
4. A method of determining a land-sea transition phase shale gas vantage point as claimed in claim 3, wherein for each first zone, calculating a respective set of combined parameters for each set of base parameters comprises:
calculating basic combination parameters of resources according to the total organic carbon content and the shale thickness;
calculating reservoir physical property combination parameters according to the porosity and the permeability;
calculating a gas-containing combination parameter according to the gas content and the air-sucking ratio;
calculating a compressibility combination parameter according to the brittle mineral content and the mechanical parameter;
and calculating the combination parameter of the producibility according to the reservoir pressure gradient and the gas saturation.
5. The method for determining the favorable region of the sea-land transition phase shale gas according to claim 4, wherein the resource base combination parameters are as follows:
wherein k is 1 TOC for resource-based composition parameters i The total organic carbon content of the ith test sample corresponding to the first region is expressed in units; TOC (total organic carbon) max And TOC min The maximum value and the minimum value of the total organic carbon content of all the test samples corresponding to the first area are given in units; h i The unit of the shale thickness is m, which is the ith measuring point of the first area; h max And H min The unit of the maximum value and the minimum value of the shale thickness of all the layers in the first area is m; m is m 1 The number of the test samples corresponding to the total organic carbon content is dimensionless, n 1 The number of measuring points is the shale thickness, and is dimensionless;
the reservoir physical property combination parameters are as follows:
wherein k is 2 Is a combination parameter of physical properties of the reservoir,the unit is the ith measured porosity value in the first region; />And->The unit is the maximum value and the minimum value of the porosities of all the test samples in the first area; k (K) i The ith measured permeability in nD in the first zone; k (K) max And K min The unit of the maximum value and the minimum value of the shale thickness of all the intervals is nD; m is m 2 For the number of the test samples corresponding to the porosity, the sample is dimensionless and n 2 The number of the test samples corresponding to the permeability is dimensionless;
the gas-containing combination parameters are as follows:
wherein k is 3 As a gas-containing combination parameter, Q i For the gas content value of the ith test sample in the first zone, the unit is m 3 /t；Q max And Q min The unit of the maximum value and the minimum value of the air content of all the test samples in the first area is m 3 /t；R Free/adsorbed i The ith measured running-sucking ratio in the first area is dimensionless; r is R Free/adsorption max And R is Free/adsorb min The maximum value and the minimum value of the upstream suction ratio in the first area are dimensionless parameters; m is m 3 The number of the test samples corresponding to the gas content is dimensionless, n 3 The number of the test samples corresponding to the sucking ratio is dimensionless.
6. The method for determining the favorable region of the sea-land transition phase shale gas according to claim 4, wherein the compressibility combination parameters are as follows:
wherein k is 4 As a compressibility combination parameter, BI Mi i is the rock mineral brittleness index of the ith test sample in the first zone in m 3 /t；BI Mimax And BI (BI) Mimin The units of the maximum value and the minimum value of the rock mineral brittleness index of all the test samples in the first area are m 3 /t；BI Me i is the rock mechanical brittleness index of the ith measuring point in the first area, and is dimensionless; BI (BI) Me max and BI Me min is the maximum value and the minimum value of the mechanical brittleness index in the first area, and both are dimensionless parameters; m is m 4 For the number of test samples corresponding to the rock mineral brittleness index, n 4 The number of the test samples corresponding to the rock mechanical brittleness index is dimensionless;
the acquirability combination parameters are as follows:
wherein k is 5 G as a combination of the acquirability parameters i The reservoir pressure gradient is the ith measuring point in the first area, and the unit is MPa/100m; g max And G min The unit of the maximum value and the minimum value of all reservoir pressure gradient data in the first area is MPa/100m; s is S gi The gas saturation in units of the ith test sample in the first zone; s is S gmax And S is gmin The maximum value and the minimum value of the saturation of the gas in the first area are given by the units; m is m 5 The number of measuring points for the reservoir pressure gradient is dimensionless; n is n 5 The number of the test samples corresponding to the gas saturation value is dimensionless.
7. The method for determining the favorable region of the sea-land transition phase shale gas according to claim 1, wherein the calculating the favorable parameters of each first region according to the combined parameters of each first region comprises:
wherein k is the favorability parameter, mu is the number of combined parameters, k i For the i-th combination parameter,
8. the method of determining a favorable zone of a sea-land transition phase shale gas according to any of claims 1-7, wherein determining the favorable zone of the area to be mined from within each first area according to the favorable parameters of each first area comprises:
determining the favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region and a first preset threshold value;
The method further comprises the steps of:
determining a more favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region, a first preset threshold value and a second preset threshold value;
determining a less favorable region of the to-be-mined region from each first region according to the favorable parameters of each first region, the second preset threshold and the third preset threshold;
and determining unfavorable areas of the to-be-mined areas from the first areas according to the favorable parameters of the first areas and a third preset threshold value.
9. A terminal comprising a memory, a processor and a computer program stored in the memory and executable on the processor, characterized in that the processor, when executing the computer program, implements the steps of the sea-land transition phase shale gas vantage point determination method of any of claims 1 to 7.
10. A computer readable storage medium, characterized in that it stores a computer program which, when executed by a processor, implements the steps of the sea-land transition phase shale gas vantage point determination method of any of claims 1 to 7 above.
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