CN111983192B - Method for quantitatively determining large-amount dissipation depth of syncline background shale gas - Google Patents
Method for quantitatively determining large-amount dissipation depth of syncline background shale gas Download PDFInfo
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- CN111983192B CN111983192B CN202010860519.2A CN202010860519A CN111983192B CN 111983192 B CN111983192 B CN 111983192B CN 202010860519 A CN202010860519 A CN 202010860519A CN 111983192 B CN111983192 B CN 111983192B
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- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
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- G—PHYSICS
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- G01N7/00—Analysing materials by measuring the pressure or volume of a gas or vapour
- G01N7/02—Analysing materials by measuring the pressure or volume of a gas or vapour by absorption, adsorption, or combustion of components and measurement of the change in pressure or volume of the remainder
- G01N7/04—Analysing materials by measuring the pressure or volume of a gas or vapour by absorption, adsorption, or combustion of components and measurement of the change in pressure or volume of the remainder by absorption or adsorption alone
Abstract
The invention discloses a method for quantitatively determining the large-amount escape depth of syncline background shale gas, which comprises the following steps of: taking a plurality of cores of parallel bedding planes of the syncline stratum; obtaining a first parallel layer permeability change rule under different burial depths only considering the action of the overburden pressure by using an overburden permeability experiment; the quantitative relation between the reduction degree of the permeability of the parallel layer and the adsorbed gas quantity is determined by utilizing the permeability experiment before and after natural gas adsorption and the isothermal adsorption experiment, the change rule II of the permeability of the parallel layer under the combined action of the overburden pressure and the adsorbed gas is obtained by combining the overburden permeability experiment, and the burial depth of the shale gas during large-scale dissipation is determined according to the change rule I and the change rule II. The method utilizes experiments and theoretical analysis to clearly determine the escape depth of a large amount of syncline background shale gas, and is more accurate and scientific than the conventional method for determining the upper limit of the drilling burial depth of the favorable area only by experience.
Description
Technical Field
The invention relates to the technical field of shale gas exploitation, in particular to a quantitative determination method for the large-amount dissipation depth of syncline background shale gas.
Background
The Sichuan basin and the periphery thereof are the main sea-phase shale gas producing areas in China, and because of complicated structure movement, a plurality of shale layers exist in the residual syncline. The permeability of the parallel layer direction is far higher than that of the vertical layer direction, the parallel layer is a main seepage channel of the shale gas, how to find out the depth of the shale gas which starts to dissipate greatly towards the inclined background, and further determine the upper limit of the burial depth of the favorable area, which is an important problem to be solved urgently. The previous people do not deeply study, and the drilling burial depth of the inclined background favorable area is determined only by experience, so that the method is inaccurate and does not develop theoretical research.
Disclosure of Invention
In view of the above problems, the present invention aims to provide a quantitative determination method for the depth of a large amount of shale gas escaping to an inclined background.
The technical scheme of the invention is as follows:
a method for quantitatively determining the large dissipation depth of syncline background shale gas comprises the following steps:
taking a plurality of cores of parallel bedding planes of the syncline stratum;
testing the permeability of the rock core flowing through the parallel bedding surface direction under different confining pressure conditions by using natural gas, and obtaining a first parallel bedding surface permeability change rule under different burial depths only considering the action of an overlying pressure according to a first quantitative relation between confining pressure and burial depth;
placing the rock core under different natural gas osmotic pressures, measuring the permeability before and after natural gas adsorption, and calculating the permeability reduction degree before and after natural gas adsorption under different methane osmotic pressures to obtain a quantitative relation II between the permeability reduction degree and the natural gas osmotic pressure;
grinding the rock core to perform an isothermal adsorption experiment to obtain a third quantitative relation between the adsorption gas amount and the natural gas osmotic pressure;
combining the quantitative relation II with the quantitative relation three-phase to obtain a quantitative relation IV between the permeability reduction degree and the adsorption gas amount;
according to an adsorption gas quantity quantitative calculation formula, combining the quantitative relation IV to obtain a quantitative relation V between the permeability reduction degree and the burial depth only considering the adsorption effect;
substituting the quantitative relation five into the permeability value of the parallel bedding surface only considering the action of the overlying pressure to obtain a second change rule of the permeability of the parallel bedding surface under the combined action of the overlying pressure and the adsorbed gas;
and calculating corresponding burial depth I and burial depth II according to the overburden pressure corresponding to the permeability mutation point in the change rule I and the change rule II, wherein the large dissipation depth of the shale gas is between the burial depth I and the burial depth II.
Preferably, the natural gas is any one or combination of more of methane, ethane, propane, butane and nitrogen.
Preferably, the quantitative relation is specifically:
H＝P×1000/9.81 (1)
in the formula: h is the stratum buried depth m; p is confining pressure, MPa.
Preferably, the permeability decrease degree is calculated by the following method:
D＝(K1-K2)/K1 (2)
in the formula: d is the permeability reduction degree in the direction parallel to the layer surface, and is dimensionless; k1Permeability, mD, parallel to the bedding plane direction before the shale adsorbs the natural gas; k2For shale to absorbPermeability parallel to the bedding plane direction after attaching natural gas, mD.
Preferably, the core is ground to 20-40 mesh.
Preferably, the formula for quantitatively calculating the amount of adsorbed gas is specifically as follows:
T＝0.02×H+15 (4)
p＝1×9.81×H/1000 (5)
in the formula: v is the amount of adsorbed gas, m3T; TOC is total organic carbon content, and is dimensionless; t is the formation temperature, DEG C; p is the formation pressure, MPa; e is a natural index and is dimensionless.
Preferably, the point of the permeability mutation is a point at which the difference in permeability changes by an order of magnitude.
Compared with the prior art, the invention has the following advantages:
the quantitative relation between the permeability reduction degree of the parallel layer and the adsorption gas quantity is determined by utilizing permeability experiments before and after natural gas adsorption and isothermal adsorption experiments; by combining the overburden permeability experiment, the burial depth of shale gas in a large amount of loss caused by permeability change of a parallel layer under the combined action of overburden pressure and adsorbed gas is found out, and the obtained result is more accurate and scientific than the result of determining the burial depth upper limit of drilling in a favorable area only by experience in the past.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a schematic representation of the relationship between overburden pressure and permeability for example 1 considering only overburden pressure;
FIG. 2 is a graph showing the relationship between the amount of adsorbed gas and the decrease in permeability in example 1;
FIG. 3 is a graph showing the relationship between overburden pressure and permeability in example 1 under consideration of both overburden pressure and sorbate gas.
Detailed Description
The invention is further illustrated with reference to the following figures and examples. It should be noted that, in the present application, the embodiments and the technical features of the embodiments may be combined with each other without conflict. Unless defined otherwise, technical or scientific terms used in the present disclosure should have the ordinary meaning as understood by those of ordinary skill in the art to which the present disclosure belongs. The use of the terms "comprising" or "including" and the like in the present disclosure is intended to mean that the elements or items listed before the term cover the elements or items listed after the term and their equivalents, but not to exclude other elements or items.
Example 1
A method for quantitatively determining the large dissipation depth of syncline background shale gas comprises the following steps:
s1: selecting Longmaxi organic-rich shale with Penge 1 wells of 2141.94m and 2153.32m as a target stratum, and drilling a plurality of rock cores on parallel bedding surfaces of an syncline stratum, wherein the rock cores are in a column shape, the diameter of the rock core is 25mm, and the length of the rock core is 50 mm.
S2: an AP-608 overpressure permeability tester is used, methane is used as a measuring medium, 9 pressure points (3.5MPa, 5MPa, 10MPa, 15MPa, 20MPa, 25MPa, 30MPa, 35MPa and 40MPa) are selected under overpressure, the permeability in the direction of parallel layers is tested, the experimental result of the overpressure permeability is shown in figure 1, in the figure, 1A is Pengpe 1 well Longmaxi group 2141.94m, and in the figure, 1B is Pengpe 1 well Longmaxi group 2153.32 m.
S3: testing the permeability of the rock core in parallel layer directions before and after methane adsorption under different osmotic pressures (0MPa, 0.5MPa, 0.8MPa, 1MPa, 1.5MPa, 3MPa, 5MPa, 7MPa, 9MPa and 11MPa) by using a triaxial gas seepage device and taking methane as a measuring medium; simultaneously, a triaxial gas seepage device is utilized to carry out an isothermal adsorption experiment on a sample, so that the content of adsorbed gas corresponding to different osmotic pressures is obtained, the two experimental results are combined, and the permeability parallel to the layer direction before and after methane adsorption under the condition of different adsorbed gas contents is obtained, wherein the results are shown in table 1 and figure 2.
TABLE 1 penetration test results of parallel bedding directions before and after methane adsorption
As can be seen from table 1 and fig. 2, the permeability of the shale sample before and after methane adsorption is significantly different, and the permeability decreases with increasing osmotic pressure. According to fig. 2, it can be found that the quantitative relationship between the permeability amplitude in the direction of the parallel layer and the amount of the adsorbed gas is four:
D＝0.3338V (6)
s4: according to equation (2), the permeability of shale in the direction parallel to the bedding plane after adsorbing methane can be expressed as:
K2＝K1×(1-D) (7)
the formula (6) may be substituted for the formula (7):
K2＝K1×(1-0.3338V) (8)
the formula (3) may be substituted for the formula (8):
combining formula (9), calculating the parallel-bedding-direction permeability of the shale after absorbing methane according to the parallel-bedding-direction permeability, the burial depth and the TOC content before the shale absorbs methane in step S3, and the result is shown in table 2 and fig. 3, wherein the circular data point in fig. 3 is the permeability of the shale before absorbing methane (only considering the case of overburden pressure); the diamond data points are the permeability of the shale after methane adsorption (considered under the combined action of both overburden pressure and adsorbed gas).
TABLE 2 calculation of permeability in parallel to the bedding plane after methane adsorption
From table 2, the difference in permeability values obtained are shown in table 3:
TABLE 3 calculation of permeability differences
As can be seen from fig. 1 and table 3, in the process that the overburden pressure of the penpage 1-well roman group rich in organic shale is increased from 3.5MPa to 40MPa, the permeability in the direction parallel to the bedding plane is greatly reduced by 2 orders of magnitude, which shows that under the conditions that the burial depth is gradually increased and the overburden pressure is gradually increased, the permeability is obviously reduced, and the self-sealing capability of the shale is obviously enhanced. Further analysis shows that when the pressure is greater than 15MPa, the permeability difference starts to change in order of magnitude, which indicates that when the pressure reaches 15MPa, the permeability of the shale in the direction parallel to the bedding surface is suddenly changed, and the corresponding burial depth is 1529m according to the quantitative relation I between confining pressure and burial depth shown in the formula (1).
As can be seen from fig. 3 and tables 2 to 3, when the combined action of overburden pressure and adsorbed gas is considered, the permeability difference starts to change by orders of magnitude when the pressure is greater than 10MPa, which indicates that when the combined action of overburden pressure and adsorbed gas is considered, when the pressure reaches 10MPa, the permeability of the shale in the direction parallel to the layer surface changes suddenly, and the corresponding burial depth is 1019m according to formula (1).
The large-amount dissipation depth of the shale gas is between the first burial depth under the condition that only the overlying pressure is considered and the second burial depth under the combined action of the overlying pressure and the adsorbed gas, namely the large-amount dissipation depth of the shale gas is 1019-1529 m. In the negative construction mode, the drilling depth is at least deeper than 1019-1529 m, and the larger the drilling depth is, the higher the formation pressure coefficient is, and the larger the gas production rate of the shale gas well is.
According to the result, the pressure point can be selected within the range of 10MPa-15MPa, and then the experiment is carried out by adopting the method, so that the buried depth result is more accurate.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (6)
1. A method for quantitatively determining the large amount of dissipation depth of syncline background shale gas is characterized by comprising the following steps:
taking a plurality of cores of parallel bedding planes of the syncline stratum;
testing the permeability of the rock core flowing through the parallel bedding surface direction under different confining pressure conditions by using natural gas, and obtaining a first parallel bedding surface permeability change rule under different burial depths only considering the action of an overlying pressure according to a first quantitative relation between confining pressure and burial depth; the quantitative relationship is specifically as follows:
H＝P×1000/9.81 (1)
in the formula: h is the stratum buried depth m; p is confining pressure, MPa;
placing the rock core under different natural gas osmotic pressures, measuring the permeability before and after natural gas adsorption, and calculating the permeability reduction degree before and after natural gas adsorption under different methane osmotic pressures to obtain a quantitative relation II between the permeability reduction degree and the natural gas osmotic pressure;
grinding the rock core to perform an isothermal adsorption experiment to obtain a third quantitative relation between the adsorption gas amount and the natural gas osmotic pressure;
combining the quantitative relation II with the quantitative relation three-phase to obtain a quantitative relation IV between the permeability reduction degree and the adsorption gas amount;
according to an adsorption gas quantity quantitative calculation formula, combining the quantitative relation IV to obtain a quantitative relation V between the permeability reduction degree and the burial depth only considering the adsorption effect; the quantitative calculation formula of the adsorption gas amount is specifically as follows:
in the formula: v is the amount of adsorbed gas, m3T; TOC is total organic carbon content, and is dimensionless; t is the formation temperature, DEG C; p is the formation pressure, MPa; e is a natural index and is dimensionless;
substituting the quantitative relation five into the permeability value of the parallel bedding surface only considering the action of the overlying pressure to obtain a second change rule of the permeability of the parallel bedding surface under the combined action of the overlying pressure and the adsorbed gas;
calculating a first burial depth according to the overburden pressure corresponding to the permeability mutation point in the first change rule and in combination with the first quantitative relation;
calculating the second buried depth by combining the first quantitative relation according to the overlying pressure corresponding to the permeability mutation point in the second change rule;
the shale gas escapes to a great depth, namely between the first burial depth and the second burial depth.
2. The method for quantitatively determining the large amount of dissipation depth of the syncline background shale gas as claimed in claim 1, wherein the natural gas is any one or more of methane, ethane, propane, butane and nitrogen.
3. The method for quantitatively determining the large amount of dissipation depth of the syncline background shale gas as claimed in claim 1, wherein the permeability reduction degree is calculated as follows:
D＝(K1-K2)/K1 (2)
in the formula: d is the permeability reduction degree in the direction parallel to the layer surface, and is dimensionless; k1Permeability, mD, parallel to the bedding plane direction before the shale adsorbs the natural gas; k2The permeability, mD, of the shale in the direction parallel to the layer surface after adsorbing natural gas.
4. The method for quantitatively determining the large amount of escaping depth of the syncline background shale gas as claimed in claim 1, wherein the core is ground to 20-40 mesh.
5. The method for quantitatively determining the large amount of dissipation depth of the syncline background shale gas as claimed in claim 1, wherein the calculation formula of the formation temperature is as follows:
T＝0.02×H+15 (4)
the calculation formula of the formation pressure is as follows:
p＝1×9.81×H/1000 (5)。
6. the method for quantitatively determining the large quantity dissipation depth of the syncline background shale gas according to any one of claims 1 to 5, wherein the point of the permeability mutation is a point of magnitude-order change of a permeability difference.
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