CN109339745B - Shale gas reservoir exploitation method based on optimal single well control area - Google Patents
Shale gas reservoir exploitation method based on optimal single well control area Download PDFInfo
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- CN109339745B CN109339745B CN201811430509.4A CN201811430509A CN109339745B CN 109339745 B CN109339745 B CN 109339745B CN 201811430509 A CN201811430509 A CN 201811430509A CN 109339745 B CN109339745 B CN 109339745B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/006—Production of coal-bed methane
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Abstract
A shale gas reservoir exploitation method based on an optimal single well control area comprises the following steps: 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 area 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 further determining the optimal single-well control area by combining the area of the work area and the opportunity cost, and mining the shale gas reservoir 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 based on an optimal single well control area.
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 characteristics, 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 defects and shortcomings of the prior art, it is necessary to research a shale gas reservoir exploitation method based on optimal single well control area.
Disclosure of Invention
The shale gas reservoir exploitation method based on the optimal single-well control area is achieved by obtaining a single-well control area and production yield relation curve through a corresponding relation curve of the shale gas well control area and the single-well accumulated gas production rate and combining an economic model.
Specifically, according to one aspect of the present invention, a shale gas reservoir exploitation method based on an optimal single well control area is provided, 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 fracturesfLength of crack LfFracture conductivity FcPermeability K of the zone in the formationm1And permeability K of the outer zone of the formationm2；
Obtaining formation static parameters including original formation pressure P by using well logging interpretation and static pressure testiFormation porosity phimHorizontal well length DfAnd well control area width xeAnd length ye；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experimentLAnd PL；
B) Length y of fixed control areaeBy varying the width xeChanging 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)jRepresents the net cash flow of the j year irAnnual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, CwellFor the cost of drilling a single well, CfractureCost of fracturing a single cluster of main fractures, nfThe 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 best benefit point S2 to satisfy
dNPV/dS|s＝s2＝NPV/S|s＝s2Or NPV/S-s＝s2＝Max
When S is S2, the benefit obtained by the single well control area is the maximum, namely NPVa is K; when S is lower or higher than S2, opportunity cost P is defined,
P＝K-NPVa
E) measuring the area A of the work area, and when A/S2 is an integer, taking the single-well control area as S2;
when A/S2 is a non-integer, rounding A/S2 to N, determining the corresponding single well control area S2 'as A/N when N wells are uniformly distributed in the work area A, and the corresponding single well control area S2' as A/(N +1) when N +1 wells are uniformly distributed in the work area A,
determining S according to NPVa ═ NPV/S, taking corresponding NPVa 'and NPVa when S2' and S2 'are respectively taken, determining NPVa according to P ═ K-NPVa, taking P' and P when NPVa 'and NPVa' are respectively taken,
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'
F) And setting the single well control area to be S2, and carrying out shale gas reservoir exploitation.
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 graph of individual well control area versus cumulative production at different 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 graph of the single well control area versus net present value at different 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 analysis graph of the determination of the 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 present invention will be described in detail with reference to the accompanying drawings, wherein the detailed description is for the purpose of illustrating the invention in detail, and is not to be construed as limiting the invention, as various changes and modifications can be made therein without departing from the spirit and scope thereof, which are intended to be encompassed within the appended claims.
Example 1
Referring to fig. 1-11, preferably, the present invention provides a shale gas reservoir exploitation method based on optimal single well area control, 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 fracturesfLength of crack LfFracture conductivity FcPermeability K of the zone in the formationm1And permeability K of the outer zone of the formationm2；
Obtaining formation static parameters including original formation pressure P by using well logging interpretation and static pressure testiFormation porosity phimHorizontal well length DfAnd well control area width xeAnd length ye；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experimentLAnd PL；
B) Length y of fixed control areaeBy varying the width xeChanging 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)jRepresents the net cash flow of the j year irAnnual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, CwellFor the cost of drilling a single well, CfractureCost of fracturing a single cluster of main fractures, nfThe 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 best benefit point S2 to satisfy
dNPV/dS|s＝s2＝NPV/S|s＝s2Or NPV/S-s＝s2＝Max
When S is S2, the benefit obtained by the single well control area is the maximum, namely NPVa is K; when S is lower or higher than S2, opportunity cost P is defined,
P＝K-NPVa
E) measuring the area A of the work area, and when A/S2 is an integer, taking the single-well control area as S2;
when A/S2 is a non-integer, rounding A/S2 to N, determining the corresponding single well control area S2 'as A/N when N wells are uniformly distributed in the work area A, and the corresponding single well control area S2' as A/(N +1) when N +1 wells are uniformly distributed in the work area A,
determining S according to NPVa ═ NPV/S, taking corresponding NPVa 'and NPVa when S2' and S2 'are respectively taken, determining NPVa according to P ═ K-NPVa, taking P' and P when NPVa 'and NPVa' are respectively taken,
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'
F) And setting the single well control area to be S2, and carrying out shale gas reservoir exploitation.
Preferably, the control area is the well control area length and width xeThe product of (a).
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.
Gp(t)＝f(Km1,Km2,Lf,Fc,nf；xe,ye；φm,Pi(ii) a A PVT parameter; vL,PL)
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 11, preferably, the invention provides a shale gas reservoir mining method based on an optimal single well control area, and the implementation process is described by taking a certain typical development well in a shale gas production area in the four-Sichuan basin of China as an example. 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 tests and experimental tests, 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 analysisfLength of crack LfFracture conductivity FcPermeability K of the zone in the formationm1And permeability K of the outer zone of the formationm2；
A2) Obtaining static parameters of stratum including original stratum pressure P by analysis through well logging interpretation and static pressure testiFormation porosity phimHorizontal well length DfAnd width x of well control areaeAnd length ye。
A3) Obtaining a gas PVT parameter and a Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical properties and an isothermal adsorption experimentLAnd PL。
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 xeTo change the control area value. Preferably, the ratio between the length of the slit and the area width is set to a constant Ix＝Lf/xe. In the present embodiment, the control area x is sete100-450 m, corresponding crack length LfAnd B), substituting the basic parameters provided in the step A) into the single-well gas production model for calculation, wherein the basic parameters are 80-360 m. 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 differenceThe corresponding relation between the single well control area and the accumulated yield in the production time is that the longer the production period is, the more remarkable the influence of the single well control area on the accumulated yield is.
In step C), an economic model is introduced, wherein the net present value formula is as follows:
here, (CI-CO)jRepresents the net cash flow of the j year irAnnual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment (equipment cost, etc.), CwellFor the cost of drilling a single well, CfractureFor a single cluster (main fracture) fracturing cost, nfThe number of cracks is shown.
In 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/m3The period is 20 years. The different fracture length costs increase exponentially, as in fig. 5.
In step C2), the net present value for a single well is obtained from the cumulative production per well curve provided in step B) in combination with equation (1). FIG. 6 shows the corresponding relationship between net present value and production time for different individual well control areas, and negative values appear in the individual well net present value under the conditions of short production time and small individual 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 versus average unit area benefit (NPVa), 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., marginal effect (curve 3 in fig. 8) is determined.
D＝dNPV/dS (3)
In step D4), a profit-loss balance point S1 (fig. 9) is determined, which is satisfied
NPV|s＝s1(ii) 0 or NPVas＝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 so as to be satisfied
dNPV/dS|s＝s2＝NPV/S|s＝s2Or NPV/S-s＝s2＝Max (5)
S2 is determined as the optimal single well control area.
E) And setting the single well control area to be S2, and carrying out shale gas reservoir exploitation.
Preferably, the obtained benefit of the single well control area is the maximum when S is equal to S2, i.e., NPVa is equal to K, and when S is lower or higher than S2, the actual benefit is lower than this value. 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. The decision process can be effectively guided according to the sensitivity of the P value to the S and the asymmetry of the P value on two sides of the point S2.
Preferably, when the area A of the work area is measured, and the A/S2 is an integer, the single-well control area is S2;
when A/S2 is a non-integer, rounding A/S2 to N, determining the corresponding single well control area S2 'as A/N when N wells are uniformly distributed in the work area A, and the corresponding single well control area S2' as A/(N +1) when N +1 wells are uniformly distributed in the work area A,
determining S according to NPVa ═ NPV/S, taking corresponding NPVa 'and NPVa when S2' and S2 'are respectively taken, determining NPVa according to P ═ K-NPVa, taking P' and P when NPVa 'and NPVa' are respectively taken,
and 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'.
Example 3
Preferably, the present invention provides a shale gas reservoir mining method based on optimal single well control area, the 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 exploitation method based on an optimal single well control area 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 fracturesfLength of crack LfFracture conductivity FcPermeability K of the zone in the formationm1And permeability K of the outer zone of the formationm2；
Obtaining formation static parameters including original formation pressure P by using well logging interpretation and static pressure testiFormation porosity phimHorizontal well length DfAnd well control area width xeAnd length ye；
Obtaining gas PVT parameter and Langmuir isothermal adsorption characteristic parameter V by utilizing high-pressure physical property and isothermal adsorption experimentLAnd PL；
B) Length y of fixed control areaeBy varying the width xeChanging 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)jRepresents the net cash flow of the j year irAnnual interest rate, j is the jth year, n is the production cycle, FC is the fixed total investment, CwellFor the cost of drilling a single well, CfractureCost of fracturing a single cluster of main fractures, nfThe 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 best benefit point S2 to satisfy
dNPV/dS|s＝s2＝NPV/S|s＝s2Or NPV/S-s＝s2＝Max
When S is S2, the benefit obtained by the single well control area is the maximum, namely NPVa is K; when S is lower or higher than S2, opportunity cost P is defined,
P＝K-NPVa
E) measuring the area A of the work area, and when A/S2 is an integer, taking the single-well control area as S2;
when A/S2 is a non-integer, rounding A/S2 to N, determining the corresponding single well control area S2 'as A/N when N wells are uniformly distributed in the work area A, and the corresponding single well control area S2' as A/(N +1) when N +1 wells are uniformly distributed in the work area A,
determining that S is corresponding to NPVa 'and NPVa when S is 2' and S2 'respectively according to NPVa ═ NPV/S, determining that NPVa is P' and P when NPVa 'and NPVa' respectively according to 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';
F) and setting the single well control area to be S2, and carrying out shale gas reservoir exploitation.
2. The method of claim 1, wherein: the single well control area is equal to the product of the well control area length and width.
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