CN109657299B - Shale gas reservoir mining method - Google Patents
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Abstract
A shale gas reservoir mining method, comprising the steps of: and exploiting the shale gas reservoir by using the staged fracturing horizontal well, enabling gas to flow into the cracks from the stratum and flow into the horizontal shaft from the cracks, and calculating the corresponding relation between the gas production rate and the accumulated yield of the single well and the time by using a full life cycle dynamic simulation method. The single well control area is changed through the well control area width xe, and the corresponding relation between different single well control areas and the single well accumulated gas production is determined. And combining the single well accumulated yield curve with the net present value NPV model to obtain corresponding relation curves of different single well control areas and production benefit relations. And obtaining the optimal single well control area by using a graphical method according to the production benefit relation curve. And carrying out shale gas reservoir exploitation according to the optimal single well control area.
Description
Technical Field
The invention relates to the field of shale gas reservoir development, in particular to a shale gas reservoir mining method.
Background
The shale gas reservoir is a continuous gas reservoir, is basically characterized by large distribution area and insignificant change of local geological conditions, and is generally influenced by regional environment and geological conditions. Aiming at the characteristic, the development working mode of the shale gas reservoir is integrally proved, the development technology is broken through, and the step-by-step implementation is carried out. Once the development technology is broken through, the basic conditions of benefit development are provided, the investment of each well is basically determined, and the decision of the operator is how to step and implement the problem. More specifically, it is the question of how to allocate the control area of each well so that the reserve per unit area on average is utilised to the maximum extent and to the maximum benefit.
Therefore, in order to solve the deficiencies and drawbacks of the prior art, it is necessary to develop a shale gas reservoir mining method.
Disclosure of Invention
The invention has been made in view of at least one of the above problems, and an exploitation method of shale gas reservoir is obtained by obtaining a curve relating a single well control area to a production yield through a curve relating a shale gas well control area to a single well cumulative gas production rate in combination with an economic model.
Specifically, according to an aspect of the present invention, there is provided a shale gas reservoir mining method, characterized by comprising the steps of:
a) Obtaining dynamic parameters of stratum fractures by well testing and productivity testing, wherein the dynamic parameters comprise the number n of fractures f Length of crack L f Fracture conductivity F c Permeability K of the zone in the formation m1 And permeability K of the outer zone of the formation m2 ；
Obtaining formation static parameters including original formation pressure P by using well logging interpretation and static pressure test i Formation porosity
Horizontal well length D f And well control area width x e And length y e ；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experiment L And P L ；
B) Length y of fixed control area e By varying the width x e Changing the control area value, determining the corresponding relation between the accumulated gas production and the production time under different single well control areas by combining the parameters measured in the step A) through a single well gas production model, and obtaining a single well control area-accumulated gas production relation curve;
c) Obtaining the corresponding relation between the net present value NPV and the production time under different single well control areas through an economic model, wherein
Wherein, (CI-CO) j Represents the net cash flow of the j year i r Annual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, C well For the cost of drilling a single well, C fracture Cost of fracturing a single cluster of main fractures, n f The number of cracks is shown;
d) Further obtaining a relation curve of the single well control area and the net present value NPV and a relation curve of the single well control area and the average unit area benefit NPVa;
NPVa＝NPV/S
determining a relation curve of the single well control area and the incremental benefit D,
D＝dNPV/dS
determining the optimum benefit point S2 to satisfy
dNPV/dS| s＝s2 ＝NPV/S| s＝s2 Or NPV/S- s＝s2 ＝Max
When S = S2, the single well control area obtains the maximum benefit, namely NPVa = K;
e) Measuring the area A of a work area, setting the single well control area as S2, setting N = INT (A/S2), uniformly arranging N wells in the area A of the work area and setting the single well control area as S2, carrying out shale gas reservoir exploitation, and carrying out residual area S in the area A of the work area Surplus Reserved for future mining, S Surplus ≥0。
Compared with the prior art, the invention has the beneficial effects that:
according to the method, the corresponding relation between the net present value NPV and the production time under different single well control areas is obtained through an economic model, further, a relation curve between the single well control area and the net present value NPV and a relation curve between the single well control area and the average unit area benefit NPVa are obtained, and an optimal benefit point S2, namely the optimal single well control area, is determined, so that a basis is provided for shale gas reservoir exploitation.
Drawings
FIG. 1 is a flow chart of shale gas optimal single well control area determination according to a preferred embodiment of the present invention.
FIG. 2 is a staged fracturing horizontal well production dynamic physical model at single well control area in accordance with a preferred embodiment of the present invention.
FIG. 3 is a graph of cumulative production versus time for different individual well control areas in accordance with a preferred embodiment of the present invention.
FIG. 4 is a plot of individual well control area versus cumulative production at various production times in accordance with a preferred embodiment of the present invention.
FIG. 5 is a graph of the composite cost of a single fracture for different fracture lengths according to a preferred embodiment of the invention.
FIG. 6 is a net present value versus time plot for different individual well control areas in accordance with a preferred embodiment of the present invention.
FIG. 7 is a plot of individual well control area versus net present value at various production times in accordance with a preferred embodiment of the present invention.
FIG. 8 is a graph of single well control area versus production benefit in accordance with a preferred embodiment of the present invention.
Fig. 9 is an analytical diagram for determining an optimal control area for a single well in accordance with a preferred embodiment of the present invention.
FIG. 10 is an example of a well spacing to single well control area, pattern density conversion table in accordance with a preferred embodiment of the present invention.
FIG. 11 is an exemplary data table of the basic parameters of a typical well in accordance with a preferred embodiment of the present invention.
FIG. 12 is a schematic illustration of opportunity costs in accordance with a preferred embodiment of the present invention.
Detailed Description
The best mode for carrying out the invention will now be described in detail by way of preferred embodiments with reference to the accompanying drawings, wherein the detailed description is intended to illustrate the invention in detail without limiting the invention thereto, and various changes and modifications can be made without departing from the spirit and scope of the invention as defined by the appended claims.
Example 1
Referring to fig. 1-12, preferably, the present invention provides a shale gas reservoir mining method, which is characterized by comprising the following steps:
a) Obtaining dynamic parameters of stratum fractures by well testing and productivity testing, wherein the dynamic parameters comprise the number n of fractures f Length of crack L f Fracture conductivity F c Permeability K of the zone in the formation m1 And permeability K of the outer zone of the formation m2 ；
Using well logging solutionsObtaining static parameters of stratum including original stratum pressure P by releasing and static pressure test i Porosity of formation
Horizontal well length D f And well control area width x e And length y e ；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by using high-pressure physical property and isothermal adsorption experiment L And P L ；
B) Length y of fixed control area e By varying the width x e Changing the control area value, determining the corresponding relation between the accumulated gas production and the production time under different single well control areas by combining the parameters measured in the step A) through a single well gas production model, and obtaining a single well control area-accumulated gas production relation curve;
c) Obtaining the corresponding relation between the net present value NPV and the production time under different single well control areas through an economic model, wherein
Wherein, (CI-CO) j Represents the net cash flow of the j year, i r Annual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, C well For cost of single well drilling, C fracture Cost of fracturing for a single cluster of main fractures, n f The number of cracks is shown;
d) Further obtaining a relation curve of the single-well control area and the net present value NPV, and a relation curve of the single-well control area and the average unit area benefit NPVa;
NPVa＝NPV/S
determining a relation curve of the single well control area and the incremental benefit D,
D＝dNPV/dS
determining the optimum benefit point S2 to satisfy
dNPV/dS| s＝s2 ＝NPV/S| s＝s2 Or NPV/S- s＝s2 ＝Max
When S = S2, the benefit obtained by controlling the area of the single well is the maximum, namely NPVa = K;
e) Measuring the area A of a work area, setting the single well control area as S2, setting N = INT (A/S2), uniformly arranging N wells in the area A of the work area and setting the single well control area as S2, carrying out shale gas reservoir exploitation, and carrying out residual area S in the area A of the work area Surplus Reserved for future mining, S Surplus ≥0。
Preferably, N = INT (a/S2) is set to be, specifically, a rounding of (a/S2), for example, a =100, S2=0.45, (a/S2) =222.22, and then N = INT (a/S2) =222. That is, in the work area range of 100 square meters, 222 gas wells with the single well control area of 0.45 square meters are uniformly arranged, and S Surplus And =0.1 square meter, the remaining 0.1 square area is reserved.
Preferably, referring to fig. 1-12, the present invention also provides a shale gas reservoir mining method, which is characterized by the following steps:
a) Obtaining formation fracture dynamic parameters including fracture number n by well testing and productivity testing f Length of crack L f Fracture conductivity F e Permeability K of the zone in the formation m1 And permeability K of outer zone of the formation m2 ；
Obtaining static parameters of stratum including original stratum pressure P by utilizing well logging interpretation and static pressure test i Porosity of formation
Horizontal well length D f And well control area width x e And length y e ；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experiment L And P L ；
B) Length y of fixed control area e By varying the width x e Changing the control area value, determining the corresponding relation between the accumulated gas production and the production time under different single well control areas by combining the parameters measured in the step A) through a single well gas production model, and obtaining a single well control area-accumulated gas production relation curve；
C) Obtaining the corresponding relation between the net present value NPV and the production time under different single well control areas through an economic model, wherein
Wherein, (CI-CO) j Represents the net cash flow of the j year i r Annual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, C well For cost of single well drilling, C fracture Cost of fracturing a single cluster of main fractures, n f The number of cracks is shown;
d) Further obtaining a relation curve of the single well control area and the net present value NPV and a relation curve of the single well control area and the average unit area benefit NPVa;
NPVa＝NPV/S
determining a relation curve of the single well control area and the incremental benefit D,
D＝dNPV/dS
determining the optimum benefit point S2 to satisfy
dNPV/dS| s＝s2 ＝NPV/S| s＝s2 Or NPV/S- s＝s2 ＝Max
When S = S2, the benefit obtained by controlling the area of the single well is the maximum, namely NPVa = K; when S is lower or higher than S2, defining opportunity cost P,
P＝K-NPVa
e) Measuring the area A of the work area, and when A/S2 is an integer, taking S2 as the single-well control area;
when A/S2 is a non-integer, rounding the A/S2 to N, determining the corresponding single well control area S2'= A/N when N wells are uniformly distributed in the work area A, and the corresponding single well control area S2' = A/(N + 1) when N +1 wells are uniformly distributed in the work area A,
determining that the S is corresponding to the S2 'and the S2' according to the NPVa = NPV/S, determining that the NPVa is corresponding to the P 'and the P' respectively according to the P = K-NPVa,
when P ' is less than or equal to P ', the single well control area S2 is S2', otherwise, the single well control area S2 is S2 ″, and
f) And setting the single well control area as S2, and performing shale gas reservoir exploitation.
Preferably, the control area is the product of the well control area length and the width xe.
Preferably, the single well gas production model is specifically: according to the physical model shown in FIG. 2, a full-life-cycle gas well production dynamic mathematical model is constructed, and the parameters/basic parameters measured in the step A) are substituted into the mathematical model f (), so that the corresponding relation between the gas well cumulative yield G and the time t can be obtained.
G p (t)＝f(K m1 ，K m2 ，L f ，F c ，n f ；x e ，y e ；φ m ，P i (ii) a A PVT parameter; v L ，P L )
Advantageously, the method obtains the corresponding relation between the net present value NPV and the production time under different single well control areas through an economic model, further obtains a relation curve between the single well control area and the net present value NPV and a relation curve between the single well control area and the average unit area benefit NPVa, and determines the optimal benefit point S2, namely the optimal single well control area, thereby providing a basis for shale gas reservoir exploitation.
Example 2
Referring to fig. 1 to 12, preferably, the present invention provides a shale gas reservoir mining method, which takes a typical development well of a shale gas production area in the four-Sichuan basin of china as an example to illustrate an implementation process. Specifically, the method comprises the following steps:
in the step A), the corresponding static geological parameters of the well are obtained by utilizing mine field test and experimental test, and the corresponding dynamic engineering parameters of the well are obtained by utilizing fracturing construction and dynamic monitoring, and the method specifically comprises the following steps:
a1 Dynamic data are obtained by well testing and productivity testing, and relevant stratum and fracture dynamic parameters including the number n of fractures are obtained through analysis f Length of crack L f Fracture conductivity F c Permeability K of the zone in the formation m1 And permeability K of the outer zone of the formation m2 ；
A2 By interpretation of well logs, hydrostatic testing, obtaining the formation by analysisStatic parameters, including virgin formation pressure P i Formation porosity
Horizontal well length D f And width x of well control area e And length y e 。
A3 Utilizing high pressure physical properties and isothermal adsorption experiments to obtain gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V L And P L 。
The above dynamic and static data are summarized in fig. 11.
In step B), the control area length is fixed, by varying the control area width x e To change the control area value. Preferably, the ratio between the length and the area width of the slit is set here to a constant I x ＝L f /x e . In the present embodiment, the control area x is set e = 100-450 m, corresponding crack length L f And = 80-360 m, and calculating by substituting the basic parameters provided in the step A) into the single-well gas production model. Fig. 3 reflects the corresponding relation of the accumulated yield and the production time under different single well control areas, and the larger the single well control area is, the higher the accumulated yield is. Fig. 4 reflects the corresponding relationship between the single well control area and the cumulative production at different production times, and the longer the production cycle is, the more significant the single well control area influences the cumulative production.
In step C), an economic model is introduced, wherein the net present value formula is as follows:
here, (CI-CO) j Represents the net cash flow of the j year, i r Annual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment (equipment cost, etc.), C well For cost of single well drilling, C fracture For a single cluster (main fracture) fracturing cost, n f The number of cracks is shown.
In the step C1), the comprehensive cost (except fracturing) of a single well is 4000 ten thousand yuan, the annual rate is 10 percent, and the gas price is 1.2 yuan/m 3 The period is 20 years. The different fracture length costs increase exponentially as shown in figure 5.
In step C2), the net present value for a single well is obtained from the cumulative production curve for a single well provided in step B) in combination with equation (1). FIG. 6 shows the corresponding relationship between net present value and production time for different single well control areas, and the net present value of a single well appears negative under the conditions of short production time and small single well control area. FIG. 7 shows the relationship between the single well control area and the single well net present value at different periods.
In step D), the optimal single well control area is determined.
In step D1), a single well control area versus production benefit curve (curve 1 in fig. 8) is obtained.
In step D2), a single well control area to average unit area benefit (NPVa) curve, i.e. scale effect (curve 2 in fig. 8) is determined.
NPVa＝NPV/S (2)
In step D3), a single well control area versus incremental benefit (D) curve, i.e. the marginal effect, is determined (curve 3 in fig. 8).
D＝dNPV/dS (3)
In step D4), a profit-loss balance point S1 (fig. 9) is determined so as to satisfy
NPV| s＝s1 (= 0 or NPVa s＝s1 ＝0 (4)
This is the lowest limit for single well control area below which single well production gains will not be placed against.
In step D5), the best effort point S2 (fig. 9) is determined such that it is satisfied
dNPV/dS| s＝s2 ＝NPV/S| s＝s2 Or NPV/S- s＝s2 ＝Max (5)
And determining S2 as the optimal single-well control area.
E) And setting the single well control area as S2, and performing shale gas reservoir exploitation.
Preferably, the single well control area achieves the greatest benefit when S = S2, i.e., NPVa = K, and the actual benefit is below this value when S is lower or higher than S2. Referring to FIG. 12, an opportunity cost P is determined, defined
P＝K-NPVa (6)
P may measure the size of the opportunity cost. Meaning that the benefit is lost when the S value deviates from the optimum value. The likelihood is that more benefit can be gained if there is an opportunity to make up for insufficient area or to use excess area for new wells. The difference between this better benefit and the actual benefit is the probable opportunity loss. For continuous reservoirs, such opportunities are realistic or necessary. According to the sensitivity of the P value to the S and the asymmetry of the P value on two sides of the S2 point, the decision process can be effectively guided. Preferably, when the area A of the work area is measured, and A/S2 is an integer, the single-well control area is S2;
when the A/S2 is a non-integer, rounding the A/S2 to N, determining that the single well control area S2'= A/N corresponding to N wells uniformly distributed in the work area A, and the single well control area S2' = A/(N + 1) corresponding to N +1 wells uniformly distributed in the work area A,
determining that the S is corresponding to the S2 'and the S2' according to the NPVa = NPV/S, determining that the NPVa is corresponding to the P 'and the P' respectively according to the P = K-NPVa,
and when P ' is less than or equal to P ', taking S2' as the single well control area S2', or taking S2' as the single well control area S2.
Example 3
Preferably, the present invention provides a shale gas reservoir mining method, comprising the steps of:
step A), exploiting the shale gas reservoir by using a staged fracturing horizontal well according to the physical model in the figure 2, wherein gas flows into a fracture from a stratum and flows into a horizontal shaft from the fracture. And calculating the corresponding relation between the gas production rate of the single well, the accumulated production and the time by using a full life cycle dynamic simulation method.
And step B), the single-well control area is changed through the well control area width xe, and the corresponding relation between different single-well control areas and the single-well accumulated gas production is determined. The conversion relationship between the well control area width (i.e., the corresponding well spacing) and the single well control area and well pattern density is summarized in fig. 10.
And C), combining the single well accumulated yield curve with the net present value NPV model to obtain corresponding relation curves of different single well control area and production benefit relations. And fracturing costs corresponding to different single well control areas in the net present value model are different.
And D), obtaining the optimal single-well control area and/or the corresponding optimal technical parameters by using a graphical method according to the production benefit relation curve.
In conclusion, the beneficial effects of the invention are as follows:
according to the method, the corresponding relation between the net present value NPV and the production time under different single well control areas is obtained through an economic model, further, a relation curve between the single well control area and the net present value NPV and a relation curve between the single well control area and the average unit area benefit NPVa are obtained, and an optimal benefit point S2, namely the optimal single well control area, is determined, so that a basis is provided for shale gas reservoir exploitation.
The present invention is not limited to the specific embodiments described above. It will be understood that various changes and modifications may be made without departing from the spirit and scope of the invention, which should be considered as within the scope of the invention.
Claims (2)
1. A shale gas reservoir mining method is characterized by comprising the following steps:
a) Obtaining formation fracture dynamic parameters including fracture number n by well testing and productivity testing f Length of crack L f Fracture conductivity F c Permeability K of the zone in the formation m1 And permeability K of outer zone of the formation m2 ；
Obtaining formation static parameters including original formation pressure P by using well logging interpretation and static pressure test i Formation porosity
Horizontal well length D f And well control area width x e And length y e ；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experiment L And P L ；
B) Length y of fixed control area e By varying the width x e Changing the control area value, determining the corresponding relation between the accumulated gas production and the production time under different single well control areas by combining the parameters measured in the step A) through a single well gas production model, and obtaining a single well control area-accumulated gas production relation curve;
c) Obtaining the corresponding relation between the net present value NPV and the production time under different single well control areas through an economic model, wherein
Wherein, (CI-CO) j Represents the net cash flow of the j year i r Annual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, C well For the cost of drilling a single well, C fracture Cost of fracturing a single cluster of main fractures, n f The number of cracks is shown;
d) Further obtaining a relation curve of the single well control area and the net present value NPV and a relation curve of the single well control area and the average unit area benefit NPVa;
NPVa＝NPV/S
determining the relation curve of the single well control area and the incremental benefit D,
D＝dNPV/dS
determining the optimum benefit point S2 to satisfy
dNPV/dS| s＝s2 ＝NPV/S| s＝s2 Or NPV/S- s＝s2 ＝Max
When S = S2, the single well control area obtains the maximum benefit, namely NPVa = K; max and K are the maximum value of the average unit area benefit;
e) Measuring the area A of a work area, setting the single well control area as S2, setting N = INT (A/S2), uniformly arranging N wells in the area A of the work area and setting the single well control area as S2, carrying out shale gas reservoir exploitation, and measuring the residual area S in the area A of the work area Surplus Reserved for future mining, S Surplus ≥0。
2. The method of claim 1, wherein: the single well control area is equal to the product of the length and width of the well control area.
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