CN110807541B - Selection method of gas reservoir development well type - Google Patents
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Abstract
The invention discloses a method for selecting a well type for gas reservoir development, and belongs to the field of gas reservoir development. Determining a well type to be selected of a target gas reservoir, carrying out capacity prediction analysis on the well type to be selected including at least one of a vertical well, a horizontal well, an inclined well and a branch well, and testing the development effect of the well type to be selected in actual production to obtain a test result; and further determining the preferred well type according to the analysis result and the test result. And judging whether the economic benefit meets the requirement according to the obtained preferred well type, and finally selecting the actual gas reservoir exploitation well type from the preferred well types meeting the requirement. Through the steps, various factors are integrated by means of capacity prediction, actual development effect, economic benefit prediction and the like of the well type to be selected, the development well type most suitable for the target gas reservoir is finally determined step by step, the development well type with the best economic benefit suitable for the target gas reservoir can be accurately obtained through the steps, and the gas reservoir development efficiency is improved.
Description
Technical Field
The invention relates to the field of gas reservoir development, in particular to a method for selecting a well type of gas reservoir development.
Background
In the process of gas reservoir development, the selection of the development well type will affect the production amount of natural gas in the gas reservoir and the economic benefit finally obtained by the gas reservoir, so that before the gas reservoir development is carried out, the development well type more suitable for the gas reservoir needs to be determined.
In the existing selection process of the exploitation well type of the gas reservoir to be exploited, the exploitation well type suitable for the gas reservoir is generally determined by combining the exploitation well type with the geological characteristics of the gas reservoir to be exploited or according to the single-well productivity or the gas reservoir recovery ratio of the exploitation well type.
However, the well type of the gas reservoir obtained by the above method is only considered in a single way, so that the probability of obtaining the well type with the best economic benefit suitable for the gas reservoir is low, and the development efficiency of the gas reservoir is influenced finally.
Disclosure of Invention
The embodiment of the invention provides a method for selecting a well type for developing a gas reservoir, which can improve the development efficiency of the gas reservoir. The technical scheme is as follows:
the embodiment of the invention provides a method for selecting a gas reservoir development well type, which comprises the following steps:
determining a well type to be selected of a target gas reservoir, wherein the well type to be selected comprises at least one of a vertical well, a horizontal well, an inclined well and a branch well;
carrying out capacity prediction analysis on at least part of the well types to be selected to obtain an analysis result;
putting the well type to be selected into actual production for development effect test to obtain a test result;
determining a preferred well type according to the analysis result and the test result;
judging whether the economic benefit of the preferred well type meets the requirement;
and selecting the actual gas reservoir exploitation well type from the preferable well types meeting the requirements.
Optionally, the determining the candidate well type of the target gas reservoir includes:
and determining the well type to be selected of the target gas reservoir according to the geological characteristics of the target gas reservoir, wherein the geological characteristics of the target gas reservoir comprise reservoir physical properties, reservoir spreading characteristics, fracture-cave development degree, fluid properties and gas-water relationship.
Optionally, the performing capacity prediction analysis on at least part of the candidate well patterns comprises:
and performing predictive analysis on the productivity of the well type to be selected by respectively using an analytical analysis method and a numerical simulation method.
Optionally, the performing predictive analysis on the productivity of the well type to be selected by an analytical analysis method includes:
respectively calculating the productivity of each well type to be selected;
and calculating the productivity ratio among different well types to be selected according to the productivity of each well type to be selected, and drawing a relation graph of the productivity ratio among the different well types to be selected, the reservoir permeability of the target gas reservoir and the horizontal section length of the development well.
Optionally, when the well type to be selected comprises a vertical well, calculating the productivity of the vertical well by the following method:
wherein q is V For vertical well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eV Radius of drainage of vertical well, r w Is the well radius, e is the natural constant, S is the skin coefficient, μ is the natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, gamma g And h is the reservoir thickness, and beta' is the horizontal turbulence factor.
Optionally, when the well type to be selected comprises a deviated well, calculating the productivity of the deviated well by the following formula:
wherein q is S For inclined shaft productivity, p e Is the formation pressure, p w Is bottom hole flow pressure, mu is natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, h is the reservoir thickness, r eS Is the drainage radius of the inclined shaft, r w Is the well radius, S θ Is the pseudo-epidermal coefficient.
Optionally, when the well type to be selected comprises a horizontal well, calculating the productivity of the horizontal well by the following method:
wherein q is H For horizontal well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eH Radius of drainage of horizontal well, r w Is the well radius, e is the natural constant, S is the skin coefficient, L H Length of horizontal segment, h reservoir thickness, μ natural gas viscosity, k h The permeability in the horizontal direction, Z is a natural gas deviation factor, T is the formation temperature, a is a major semiaxis of an ellipsoid flow field of the horizontal well, beta is an anisotropy coefficient, delta is an eccentricity, pi is a circumferential rate, and gamma is g Beta 'is the turbulence coefficient in the horizontal direction, and beta' is the turbulence coefficient in the vertical direction.
Optionally, the method further comprises: the predicting and analyzing the productivity of the well type to be selected by the numerical simulation method comprises the following steps:
and respectively establishing single-well geological models of the development wells in one-to-one correspondence with the well types to be selected, and performing prediction analysis on the yields of the development wells in one-to-one correspondence with the well types to be selected.
Optionally, the determining whether the economic benefit of the preferred well type is satisfactory comprises:
and judging whether the economic benefit of the preferred well type meets the requirement according to the result of the following formula:
wherein p is t For the expected recovery period of investment, I t For the investment of the t year (new drilling investment + ground construction investment), C o For the t year natural gas production operating cost, R e For operating fee rate of rise, I for discount rate, Q t The natural gas yield in the t year, and the AIC is a reference value for judging whether the economic benefit meets the requirement after the t year;
and when t is less than or equal to the designated year, if the AIC is less than the selling price of the natural gas, the economic benefit of the preferred well type meets the requirement, and if the AIC is greater than or equal to the selling price of the natural gas, the economic benefit of the preferred well type does not meet the requirement.
The technical scheme provided by the embodiment of the invention has the following beneficial effects: determining a well type to be selected of a target gas reservoir, carrying out capacity prediction analysis on the well type to be selected including at least one of a vertical well, a horizontal well, an inclined well and a branch well, and testing the development effect of the well type to be selected in actual production to obtain a test result; and further determining the preferred well type according to the analysis result and the test result. And judging whether the economic benefit meets the requirement according to the obtained preferred well type, and finally selecting the actual gas reservoir exploitation well type from the preferred well types meeting the requirement. Through the steps, various factors are integrated by means of capacity prediction, actual development effect, economic benefit prediction and the like of the well type to be selected, the development well type most suitable for the target gas reservoir is finally determined step by step, the development well type with the best economic benefit suitable for the target gas reservoir can be accurately obtained through the steps, and the gas reservoir development efficiency is improved.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow chart of a method for selecting a well type for a gas reservoir development well according to an embodiment of the present invention;
FIG. 2 is a flow chart of another method for selecting a well type for a gas reservoir development well according to an embodiment of the present invention;
FIG. 3 is a reservoir map of a GM block lamp four gas reservoir provided by an embodiment of the present invention;
FIG. 4 is a schematic diagram illustrating the loss of drilling fluid during the drilling of a borehole provided by an embodiment of the present invention;
FIG. 5 is a histogram of water saturation distribution for a reservoir provided by an embodiment of the present invention;
FIG. 6 is a schematic diagram illustrating the variation of the capacity ratio of a deviated well relative to a horizontal well according to an embodiment of the present invention;
FIG. 7 is a schematic diagram illustrating the variation of the capacity ratio of a deviated well relative to a horizontal well according to another embodiment of the present invention;
FIG. 8 is a histogram of the vertical permeability distribution of the reservoir for a GM-Block four-gas reservoir lamp provided by an embodiment of the present invention;
figure 9 is a graph of the results of actual drilling tests on GM block lamp four gas reservoirs provided by embodiments of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
Fig. 1 is a flow chart of a method for selecting a well type of a gas reservoir development well according to an embodiment of the present invention. As shown in fig. 1, the method includes:
s11: determining a well type to be selected of the target gas reservoir, wherein the well type to be selected comprises at least one of a vertical well, a horizontal well, an inclined well and a branch well.
Step S11 may include: determining the well type to be selected of the target gas reservoir according to the geological characteristics of the target gas reservoir, wherein the geological characteristics of the target gas reservoir include but are not limited to reservoir physical properties, reservoir spreading characteristics, fracture-cave development degree, fluid properties and gas-water relationship. The well type to be selected of the target gas reservoir is determined by combining the geological characteristics of the target gas reservoir, the selection range of the well type to be selected of the target gas reservoir can be narrowed, and the efficiency of the process of determining the well type to be selected is improved.
Optionally, the candidate well type of the target gas reservoir may also be determined according to the reservoir water saturation.
For further understanding of the present invention, the following examples are given for further explanation of the present invention, and the following description should be construed as being in no way limiting.
Specifically, before the target gas reservoir is actually developed, a small number of exploratory wells can be arranged in the target gas reservoir, and logging and well testing work is performed through the exploratory wells, so that relevant data such as reservoir physical properties, reservoir spreading characteristics, fracture-cave development degree, fluid properties, gas-water relationship and the like in the target gas reservoir are obtained. The exploratory well can be a vertical well, a horizontal well, an inclined well or a branch well.
In one embodiment of the invention, the target gas reservoir is a deep carbonate gas reservoir, the development span of the reservoirs of the deep carbonate gas reservoir is large, the reservoirs are overlapped and have strong heterogeneity through logging and well testing, and the inclined wells can give consideration to the longitudinal reservoirs, so that the inclined wells can be adopted for the types to be selected, and the yield of the deep carbonate gas reservoir can be improved.
And when the target gas reservoir is a deep carbonate gas reservoir, if the deep carbonate gas reservoir comprises a large number of reservoir layers mainly comprising cracks and holes through well logging and well testing, the well type to be selected of the deep carbonate gas reservoir can be an inclined well or a horizontal well. The inclined well and the horizontal well are easy to drill a reservoir stratum mainly comprising cracks and holes, and the yield of the deep carbonate gas reservoir is improved. And for the gas reservoir with less cracks or holes in the reservoir, a branch well or a vertical well can be selected as a well type to be selected.
S12: and carrying out capacity prediction analysis on at least part of the well types to be selected to obtain an analysis result.
The step S12 may include: and respectively carrying out prediction analysis on the productivity of the well type to be selected by an analytical analysis method and a numerical simulation method. And respectively carrying out prediction analysis on the productivity of the well type to be selected by an analytical analysis method and a numerical simulation method. The well type productivity of the development well can be accurately obtained, and the method is easy to operate.
The predicting and analyzing the productivity of the well type to be selected by the analytic analysis method comprises the following steps:
respectively calculating the productivity of each well type to be selected; and calculating the productivity ratio among different well types to be selected according to the productivity of each well type to be selected, and drawing a relation graph of the productivity ratio among the different well types to be selected, the reservoir permeability of the target gas reservoir and the length of the horizontal section of the development well.
The productivity of each well type to be selected can be calculated, the productivity height relation among different well types can be simply and directly obtained, and workers can conveniently select the well type to be selected with higher productivity. And obtaining a relation graph of the productivity ratio among different well types to be selected, the reservoir permeability of the target gas reservoir and the horizontal segment length of the development well, wherein the relation graph can be used for facilitating workers to more intuitively obtain the productivity relation between the development well type and different geological characteristic regions of the target gas reservoir, so that the development benefit is higher, and the development well type is suitable for the target gas reservoir.
When the well type to be selected comprises a vertical well, the productivity of the vertical well can be calculated in the following way:
wherein q is V For vertical well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eV Radius of drainage of vertical well, r w Is the well radius, e is the natural constant, S is the skin coefficient, μ is the natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, γ g Is the relative density of natural gas, h is the reservoir thickness, and β' is the horizontal turbulence factor.
The formula is a productivity calculation formula of the straight well obtained after the high-speed Darcy in the near well area and the threshold pressure effect in the far well area are considered, and the obtained productivity of the straight well is accurate.
The derivation process of the formula (1) is as follows:
firstly, establishing a vertical well productivity relational expression obtained by considering the near well area high-speed Darcy and the far well area threshold pressure effect:
and (3) combining the formula (4) with the formulas (2) and (3) to transform to obtain the formula (1).
Optionally, when the candidate well type comprises a deviated well, calculating the productivity of the deviated well by:
wherein q is S For inclined shaft productivity, p e Is the formation pressure, p w Is bottom hole flow pressure, mu is natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, h is the reservoir thickness, r eS Is the drainage radius of the inclined shaft, r w Is the well radius, S θ Is the pseudo-epidermal coefficient.
The formula is a productivity calculation formula of the inclined shaft obtained after the high-speed Darcy in the near well region and the threshold pressure effect in the far well region are considered, and the obtained productivity of the inclined shaft is more accurate.
S in the formula (5) θ The calculation method is as follows:
wherein L is S Is the length of the well section of the inclined well, theta is the inclined angle of the inclined well, r w Is the well radius, k h Permeability in the horizontal direction, k v Is the vertical direction permeability.
Optionally, when the well type to be selected comprises a horizontal well, calculating the productivity of the horizontal well by the following method:
wherein q is H For horizontal well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eH Radius of drainage of horizontal well, r w Is the well radius, e is the natural constant, S is the skin coefficient, L H Length of horizontal segment, h reservoir thickness, μ natural gas viscosity, k h The permeability in the horizontal direction, Z is a natural gas deviation factor, T is the formation temperature, a is a major semiaxis of an ellipsoid flow field of the horizontal well, beta is an anisotropy coefficient, delta is an eccentricity, pi is a circumferential rate, and gamma is g Beta 'is the turbulence coefficient in the horizontal direction, and beta' is the turbulence coefficient in the vertical direction.
The formula is a productivity calculation formula of the horizontal well obtained after the high-speed Darcy in the near well region and the threshold pressure effect in the far well region are considered, and the obtained productivity of the horizontal well is accurate.
The derivation process of equation (10) is as follows:
firstly, establishing a horizontal well productivity relational expression obtained by considering the near well region high-speed Darcy and the far well region threshold pressure effect:
the equations (13), (14) and (15) are transformed by combining the equations (11) and (12) to obtain the equation (10).
According to the formulas (1), (5) and (10), the productivity ratios between horizontal wells and vertical wells, between inclined wells and vertical wells and between horizontal wells and inclined wells can be obtained, and the calculation formulas are respectively as follows:
the method comprises the following steps of obtaining a horizontal well and a vertical well, and obtaining a horizontal well and a vertical well, wherein HRV is the productivity ratio of the horizontal well to the vertical well, SRV is the productivity ratio of the inclined well to the vertical well, and HRS is the productivity ratio of the horizontal well to the inclined well.
And (3) drawing a relation graph of the productivity ratio among different well types to be selected, the reservoir permeability of the target gas reservoir and the length of the horizontal section of the development well according to the formulas (15) to (17) so as to be analyzed by workers. Illustratively, a plot of the capacity ratio between different candidate well types versus the reservoir permeability of the target gas reservoir and the horizontal section length of the development well may be plotted using commercial software such as Excel, OriginLab, SigmaPlot, and the like.
Further, the predicting and analyzing the productivity of the well type to be selected by a numerical simulation method comprises the following steps:
and respectively establishing single-well geological models of the development wells in one-to-one correspondence with the well types to be selected, and simulating and contrastively analyzing the development effects of the development wells in one-to-one correspondence with the well types to be selected.
By establishing the single-well geological model, the productivity of the development wells corresponding to the well types to be selected one by one can be obtained more accurately by performing predictive analysis on the productivity of the development wells corresponding to the well types to be selected one by one.
S13: and putting the well type to be selected into actual production for development effect test to obtain a test result.
In step S13, if the candidate well type includes a slant well, slant wells with different well angles may be put into actual production for development effect testing.
Illustratively, the target gas reservoir is a deep carbonate gas reservoir, and in the process of carrying out development effect test on development wells corresponding to the well types to be selected one by one, 7 inclined wells (comprising 1 horizontal well) with the well inclination angle of more than 60 degrees are obtained, and the test non-resistance flow rate exceeds 100 multiplied by 10 4 m 3 D, the well angle is 3 inclined wells with the angle of 35-60 degrees, the test has no resistance flow of 50 multiplied by 10 4 m 3 /d～100×10 4 m 3 Between/d and 3 vertical wells, the unimpeded flow of single well test is less than 50 multiplied by 10 4 m 3 /d。
Therefore, the horizontal well and the inclined well with the well inclination angle larger than 60 degrees have higher productivity and better development effect.
S14: and determining the preferred well type according to the analysis result and the test result.
Based on the analysis result in the step S12 and the test result in the step S13, a well type having a better predicted capacity and an actual development effect can be selected as a preferred well type.
According to the analysis result of the deep carbonate gas reservoir in the step S12 and the test result in the step S13, the predicted productivity and the actual development effect of the inclined shaft are good, and the inclined shaft can be used as the preferred shaft type.
S15: and judging whether the economic benefit of the preferred well type meets the requirement.
And judging whether the economic benefit of the preferred well type meets the requirement according to the result of the following formula:
wherein p is t For the expected recovery period of investment, I t For the investment of the t year (new drilling investment + ground construction investment), C o For the t year natural gas production operating cost, R e For increasing operating costsRate, I is the discount rate, Q t The AIC is a reference value for whether the economic benefit is satisfactory after the t year.
And when t is less than or equal to the designated year, if the AIC is less than the selling price of the natural gas, the economic benefit of the preferred well type meets the requirement, and if the AIC is greater than or equal to the selling price of the natural gas, the economic benefit of the preferred well type does not meet the requirement.
Wherein, according to the gas field development management outline, the specified age limit can be 20 years.
S16: and selecting the actual gas reservoir exploitation well type from the preferable well types meeting the requirements.
From the results of steps S11 to S15, an actual gas reservoir development well pattern can be selected among the preferred well patterns. If there are at least two desirable preferred well patterns, then of the at least two desirable preferred well patterns, the preferred well pattern with the shorter economic benefit cycle is selected as the actual reservoir development well pattern.
It is noted here that the economic life is the age of the well pattern required when the AIC equals the sales price of natural gas.
Determining a well type to be selected of a target gas reservoir, carrying out capacity prediction analysis on the well type to be selected including at least one of a vertical well, a horizontal well, an inclined well and a branch well, and testing the development effect of the well type to be selected in actual production to obtain a test result; and further determining the preferred well type according to the analysis result and the test result. And judging whether the economic benefit meets the requirement according to the obtained preferred well type, and finally selecting the actual gas reservoir exploitation well type from the preferred well types meeting the requirement. Through the steps, various factors are integrated by means of capacity prediction, actual development effect, economic benefit prediction and the like of the well type to be selected, the development well type most suitable for the target gas reservoir is finally determined step by step, the development well type with the best economic benefit suitable for the target gas reservoir can be accurately obtained through the steps, and the gas reservoir development efficiency is improved.
And through an analytical analysis method and a numerical simulation method, geological factors such as the reservoir thickness of the gas reservoir, the anisotropy of the reservoir and the like are comprehensively considered, quantitative analysis of development effects of different well types is developed, and a solid technical support is provided for developing optimization of well types of the gas reservoir. And the geological characteristics of the gas reservoir are integrated, and then results such as an analytical analysis method, a numerical simulation method, real drilling analysis, economic evaluation and the like are developed, so that the optimized well type is comprehensively ensured to be more reliable.
Fig. 2 is a flow chart of another method for selecting a well type of a gas reservoir development well according to an embodiment of the invention. The invention will be further described below in connection with a GM sector light four gas reservoir of the mithra basin to which the method provided in fig. 2 is applied, but the following discussion is not limiting of the invention. As shown in fig. 2, the method includes:
s21: determining a well type to be selected of the target gas reservoir, wherein the well type to be selected comprises at least one of a vertical well, a horizontal well, an inclined well and a branch well.
Fig. 3 is a reservoir distribution diagram of a GM block light four gas reservoir according to an embodiment of the present invention, where a horizontal gray block portion in fig. 3 is a reservoir 1, and in conjunction with fig. 3, the thickness of the reservoir 1 in the GM block light four gas reservoir is relatively large, the monolayer thickness of the reservoir 1 is generally about 1m to 15m, the reservoir 1 in the GM block light four gas reservoir is distributed within a range of 90m to 247m from the top of the GM block light four gas reservoir, and the reservoir 1 in the GM block light four gas reservoir is relatively concentrated in a region at a depth of 130m from the top of the GM block light four gas reservoir. The cumulative thickness of reservoir 1 in the GM block light four gas reservoir is 17.6m to 153.2m, and the average thickness value of reservoir 1 in the GM block light four gas reservoir is 74.8 m.
GMX1, GMX5, GMX8, GMX6, GM3 and GM12 in FIG. 3 are exploratory wells arranged in a GM block lamp four-gas reservoir and are used for carrying out well logging and well testing work. In the process of developing the exploratory wells, the number of the reservoir layers 1 drilled by each exploratory well is 2-15.
Therefore, the reservoirs in the GM block lamp four gas reservoir are dispersed, the span of the reservoirs in the horizontal direction is large, and the reservoirs are stacked more. From the view of the longitudinal spreading of the reservoir and the physical properties of the reservoir, the four sections of the lamp adopt the inclined wells, so that the effective utilization of the reserves of each longitudinal layer is facilitated.
FIG. 4 is a schematic diagram of the drilling fluid loss experienced during exploratory well development provided by an embodiment of the present invention, as shown in FIG. 4 at GMX1In the development process of multiple exploratory wells such as GMX5, GMX8, GMX6, GM3 and GM12, serious drilling fluid leakage situations occur in gas reservoirs, wherein the drilling fluid leakage quantity of the GMH2 exploratory well exceeds 10000m 3 And the situation that a large number of reservoir layers mainly comprising cracks and holes exist in the GM block lamp four gas reservoir is shown, and in the logging process, the reservoir layers in the GM block lamp four gas reservoir are commonly developed to have holes, holes and cracks. Therefore, the candidate well type of the GM block light four gas reservoir may be a slant well or a horizontal well. The inclined well and the horizontal well are easy to drill a reservoir mainly comprising cracks and holes, and the productivity of the deep carbonate rock gas reservoir is improved.
Fig. 5 is a water saturation distribution histogram of a reservoir according to an embodiment of the present invention, as shown in fig. 5, the water saturation of the reservoir of the GM-tile light four gas reservoir is mainly between 2.17% and 75.93%, the average value is 22.26%, the water saturation of the reservoir is usually higher than 40%, and the water saturation of the reservoir is lower than 40%, so the water saturation of the reservoir of the GM-tile light four gas reservoir is lower. The reservoir is suitable for development with deviated or horizontal wells only from the point of view of the reservoir's water saturation. When the reservoir has high water saturation, then vertical well development is usually employed.
S22: and carrying out capacity prediction analysis on at least part of the well types to be selected to obtain an analysis result.
And performing capacity prediction analysis on the inclined wells and the horizontal wells based on the candidate well type of the GM block lamp four-gas reservoir in the step S21, wherein the candidate well type can be the structure of the inclined wells and the horizontal wells. The method comprises the steps of respectively calculating the yield of each horizontal well and each inclined well by an analytical analysis method, and specifically calculating by adopting formulas (5) - (10) and formula (17); and calculating the productivity ratio between the horizontal well and the inclined well, and drawing a relational graph of the productivity ratio between the horizontal well and the inclined well, the reservoir permeability of the target gas reservoir and the length of the horizontal section of the development well. The graphs of the productivity ratio between the horizontal well and the inclined well in the GM block light four gas reservoir, the reservoir permeability of the target gas reservoir, and the horizontal section length of the development well are shown in fig. 6 and 7.
Fig. 6 is a schematic diagram illustrating a variation of the productivity ratio of a deviated well relative to a horizontal well according to an embodiment of the present invention, as shown in fig. 6, when the reservoir thickness of a deep carbonate gas reservoir is 50 m. Fig. 7 is a schematic diagram of the variation of the productivity ratio of the inclined wells to the horizontal wells according to another embodiment of the present invention, wherein the thickness of the deep carbonate reservoir is 150 m. In fig. 6 and 7, the ordinate is the productivity ratio of the inclined well relative to the horizontal well, the abscissa is the length of the development well, and Kv is the permeability of natural gas in the vertical direction, i.e., the vertical permeability. The top and bottom arrangement order of the left edge line in fig. 6 and 7 coincides with the arrangement order of the Kv value on the right side.
With reference to fig. 6 and 7, the higher the vertical permeability of the natural gas in the reservoir, the lower the productivity ratio of the inclined wells to the horizontal wells, and the lower the vertical permeability of the natural gas in the reservoir, the higher the productivity ratio of the inclined wells to the horizontal wells.
As can be seen from fig. 6 and 7, the productivity ratio of the deviated well to the horizontal well increases as the thickness of the reservoir increases.
And as the length of the drilled well is increased, the productivity ratio of the inclined well to the horizontal well tends to become smaller, but generally, the length of the horizontal section is within 1000m, and the inclined well has certain advantages. Therefore, when the length of the development well is within 1000m, the inclined well can be selected as the preferable well type.
According to fig. 6 and 7, the higher the vertical permeability of the natural gas in the reservoir of the GM zone light four gas reservoir, the lower the yield ratio of the deviated well to the horizontal well, and the lower the vertical permeability of the natural gas in the reservoir, the higher the yield ratio of the deviated well to the horizontal well.
Since it is complicated to perform predictive analysis of the branch well productivity by the analytical analysis method, it is not usually performed to perform predictive analysis of the branch well productivity by this method. That is, when the candidate well type includes a branch well and other candidate well types, the productivity prediction analysis is performed on the other candidate well types except the branch well only by using the analytic analysis method, and when the candidate well type does not include the branch well type, the productivity prediction analysis may be performed on all the candidate well types by using the analytic analysis method.
Fig. 8 is a vertical permeability distribution histogram of a reservoir of a GM block light four gas reservoir according to an embodiment of the present invention, the permeability data in fig. 8 is obtained from well logging and well testing, and the average permeability of the reservoir in the GM block light four gas reservoir is 0.48mD according to fig. 8. Combining the results obtained by the analysis method and the graph of fig. 8, the development span of the four gas reservoir reservoirs of the GM block lamp is large, the reservoirs are overlapped with each other and have strong heterogeneity, the number of drilling reservoirs in the exploration process of the exploratory well is 2-15, the vertical average permeability of the reservoirs is 0.48mD, effective exploitation of reserves of each longitudinal layer is difficult to achieve by adopting a horizontal well, and the initial productivity of exploitation by adopting an inclined well can reach 2-3 times of that of the horizontal well (the length of the horizontal well is less than 1000 m); in addition, the inclined shaft has advantages in the aspects of controlling the gas reservoir reserves, fully exerting the capacity in the longitudinal direction, implementing measures such as acid fracturing and the like. To ensure that the capacity of all reservoirs is exploited, the preferred well pattern for GM block light four gas reservoirs may be considered to be a slant well. However, when the well length is greater than 1000m, it is also possible to give priority to the use of horizontal wells as the preferred well type.
Meanwhile, the productivity of the well types to be selected of the GM block lamp four-gas reservoir can be predicted and analyzed through a numerical simulation method, single-well geological models of the development wells corresponding to the well types to be selected of the GM block lamp four-gas reservoir one to one are respectively established, and the development effects of the development wells corresponding to the well types to be selected of the GM block lamp four-gas reservoir one to one are simulated and contrastively analyzed.
The single well models of different candidate well types can be divided into 7 layers in the vertical direction, the buried depth of each single well model of different candidate well types can be 5046-5192 m, and an interlayer exists between reservoir layers where the single well models of the GM block lamp four-gas reservoir are located.
The results of the predicted productivity of each candidate well type of the GM block light four gas reservoir can be referred to table 1, and the candidate well types of the GM block light four gas reservoir mainly include 4 well types, namely a vertical well, an inclined well, a horizontal well and a branch well.
TABLE 1
As shown in table 1, the GM block light four gas reservoir was simulated using vertical wells, inclined wells (30 °, 40 °, 50 °, 60 °, 70 °), horizontal wells (800, 1000m in length), and multilateral wells at 8 years of stable yield.
Referring to table 1, the gas production capacity of the vertical well is 6.84 × 10 under the condition that the interlayer between the reservoirs of the GM block lamp four gas reservoir does not develop 8 m 3 The stable production period is 13 multiplied by 10 4 m 3 Per d, the gas production capacity of a vertical well is only 6.14X 10 under the condition of interlayer development between reservoirs of GM block lamp four gas reservoirs 8 m 3 The stable delivery period is 11 multiplied by 10 4 m 3 /d。
The accumulative gas production of the horizontal well is increased along with the increase of the length of the horizontal section of the horizontal well, and the horizontal well with the horizontal section length of 1000m is higher in terms of production allocation and accumulative gas production in the steady production period relative to the horizontal well with the horizontal section length of 800 m. Whether a plurality of effective reservoirs can be communicated among a plurality of reservoirs in the longitudinal direction of the gas reservoir is the key for influencing the steady-production-period production allocation and the accumulated gas production rate of the horizontal well. Longitudinal communication in table 1 refers to the availability of effective communication between the various reservoirs of the gas reservoir along the longitudinal direction.
As can be seen from Table 1, as the inclination angle of the inclined shaft increases, the cumulative yield and the steady production period production allocation of the inclined shaft increase, but the increasing amplitude of the cumulative yield and the steady production period production allocation of the inclined shaft gradually becomes slower. The gas production rate of the inclined shaft with the inclination angle of 60 degrees is 0.67 multiplied by 10 higher than that of the inclined shaft with the inclination angle of 50 degrees 8 m 3 The gas production rate of the inclined well with the inclination angle of 70 degrees is 0.38 multiplied by 10 higher than that of the inclined well with the inclination angle of 60 degrees 8 m 3 . Therefore, in the process of carrying out prediction analysis on the productivity of the well type to be selected by a numerical simulation method, the inclined wells with different well angles can be calculated, and the inclined well with the well angle with the larger yield is selected as the preferred well type. In the actual development process, the strong heterogeneous characteristics of the reservoir and the development and distribution conditions of the reservoir also need to be considered, so the well type of the inclined shaft and the track of the inclined shaft need to be optimized according to different reservoir distribution characteristics and the direction of the maximum main stress in the reservoir.
The production effect of the inclined branch well is the best, but the drilling period and the cost are the highest.
As can be seen from table 1, the production of the lateral wells is relatively high, followed by the slant wells, horizontal wells, and vertical wells. However, the drilling cost and the drilling period of the branch well are obviously higher than those of other three well types, and the calculated 35-year cumulative yield is only 2 multiplied by 10 higher than that of a highly-deviated well 8 m 3 . Therefore, the inclined shaft development adopted at the moment has better development benefit.
As shown in table 1, in the prediction analysis of the productivity of the well type to be selected by the numerical simulation method, the inclined wells with different well angles can be calculated, and the inclined well with the well angle with the larger yield is selected as the preferred well type.
S23: and putting the well type to be selected into actual production for development effect test to obtain a test result.
FIG. 9 is a graph of the actual drilling test results of the GM block lamp four gas reservoir provided by the embodiment of the present invention, as shown in FIG. 9, during the actual testing of the GM block lamp four gas reservoir, 7 deviated wells (including 1 horizontal well) with a well angle greater than 60 degrees are obtained, and the test clear flow rates all exceed 100 × 10 4 m 3 D, the well angle is 3 inclined shafts of 35 degrees to 60 degrees, and the test has no resistance flow of 50 multiplied by 10 4 m 3 /d～100×10 4 m 3 Between/d and 3 vertical wells, the unimpeded flow of single well test is less than 50 multiplied by 10 4 m 3 /d。
S24: and determining the preferred well type according to the analysis result and the test result.
Based on the analysis results and the test results in the step S22 and the step S23, the GM block lamp has the advantages that the development span of four gas reservoir layers of the GM block lamp is large, the reservoir layers are overlapped with each other and have strong heterogeneity, the number of drilling reservoir layers of exploration wells in the development process is 2-15, the vertical average permeability of the reservoir layers is 0.48mD in combination with the graph 8, the horizontal well is difficult to consider the effective development of the reserves of each longitudinal layer, and the initial capacity of the inclined well can reach 2-3 times of that of the horizontal well (the length of the horizontal section is less than 1000 m); in addition, the inclined shaft has advantages in the aspects of controlling the gas reservoir reserves, fully exerting the capacity in the longitudinal direction, implementing measures such as acid fracturing and the like. To ensure that the capacity of all reservoirs is exploited, the preferred well type for GM block light four gas reservoirs may consider the use of slant wells. However, when the well length is greater than 1000m, it is also possible to give priority to the use of horizontal wells as the preferred well type.
Meanwhile, according to the test result of actual drilling, the production effect of the GM block lamp four gas reservoirs obtained by adopting the inclined wells is better. The slant wells may therefore be used as the preferred well pattern for the GM block light four gas reservoir.
S25: and judging whether the economic benefit of the preferred well type meets the requirement.
Based on the result of the step S24, the preferred well type of the GM block lamp four gas reservoir is a horizontal well or a slant well, and whether the economic benefit of the horizontal well and the slant well meets the requirement or not can be determined according to the result of the formula (18). The results of the calculation of the GM sector lamp four gas reservoir are shown in table 2.
TABLE 2
| Well type | Inclined shaft (70 degree) | Horizontal well (800m) |
| Rate of |
90 | 90 |
| Gas price, Yuan/10 3 m 3 | Step gas price | Step gas price |
| |
10 | 10 |
| Accumulated gas production, 10 8 m 3 | 2.87 | 3.46 |
| Period of economic benefit, YEAR | 5.8 | 11.5 |
After the AIC of the slant wells is calculated by the formula (18), the economic benefit results are shown in table 2, when the inclination angle of the slant wells is 70 degrees, the economic benefit period is 5.8 years, and the economic benefit period of the horizontal wells is 11.5 years and is less than 20 years, in this embodiment of the invention, the economic benefits of the slant wells and the horizontal wells with inclination angles of 70 degrees are both satisfactory.
S26: and selecting the actual gas reservoir exploitation well type from the preferable well types meeting the requirements.
Based on the results in table 2 of step S25, the preferred well types for the GM-bank light four gas reservoir are slant wells and horizontal wells, and the economic benefits of both slant wells and horizontal wells with a slant angle of 70 ° are satisfactory. However, because the well type with a smaller economic benefit period can obtain a larger benefit, the yield of the inclined well with the inclined angle of 70 degrees in the economic benefit period of 5.8 years is better than that of the horizontal well with the economic benefit period of 11.5 years, so the inclined well with the inclined angle of 70 degrees can be selected as the actual development well type of the GM block lamp four-gas reservoir.
In conclusion, longitudinal reservoirs of the reservoir of the four gas reservoirs of the GM block lamp are dispersed, have large span, are mutually overlapped and have strong heterogeneity, the well type development is mainly based on inclined wells, the drilling thickness of the reservoir and the single well yield are improved, the reserves of each longitudinal layer are used, and the well type and the well track are optimized according to different reservoir distribution characteristics and the direction of the maximum principal stress; a local high-quality reservoir or a fracture-cave centralized development area can adopt a horizontal well to improve the yield of a single well, and simultaneously, a mixed well type development mode mainly based on inclined well development, namely inclined wells, vertical wells and horizontal wells is finally formed by utilizing a part of vertical wells (exploratory wells to development wells).
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (3)
1. A method for selecting a gas reservoir development pattern, the method comprising:
determining a well type to be selected of a target gas reservoir, wherein the well type to be selected comprises at least one of a vertical well, a horizontal well, an inclined well and a branch well;
carrying out capacity prediction analysis on at least part of the well types to be selected to obtain an analysis result;
putting the well type to be selected into actual production for development effect test to obtain a test result;
determining a preferred well type according to the analysis result and the test result;
judging whether the economic benefit of the preferred well type meets the requirement;
selecting an actual gas reservoir exploitation well type from the preferable well types meeting the requirements;
the capacity prediction analysis of at least part of the well patterns to be selected comprises the following steps:
respectively carrying out predictive analysis on the productivity of the well type to be selected by an analytical analysis method and a numerical simulation method;
the predictive analysis of the productivity of the well type to be selected by the analytical analysis method comprises the following steps:
respectively calculating the productivity of each well type to be selected, calculating the productivity ratio among different well types to be selected according to the productivity of each well type to be selected, and drawing a relation graph of the productivity ratio among different well types to be selected, the reservoir permeability of the target gas reservoir and the horizontal section length of the development well;
the predicting and analyzing the productivity of the well type to be selected by the numerical simulation method comprises the following steps:
respectively establishing single-well geological models of the development wells in one-to-one correspondence with the to-be-selected well types, and performing prediction analysis on the productivity of the development wells in one-to-one correspondence with the to-be-selected well types;
when the well type to be selected comprises a vertical well, calculating the productivity of the vertical well by the following method:
wherein q is V For vertical well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eV Radius of drainage of vertical well, r w Is the well radius, e is the natural constant, S is the skin coefficient, μ is the natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, gamma g The natural gas relative density, h is the reservoir thickness, and beta' is the turbulence coefficient in the horizontal direction;
when the well type to be selected comprises a slant well, calculating the productivity of the slant well by the following formula:
wherein q is S For inclined shaft productivity, p e Is the formation pressure, p w Is bottom hole flow pressure, mu is natural gas viscosity, k h Is the horizontal permeability, Z is the natural gas deviation factor, T is the formation temperature, h is the reservoir thickness, r eS Is the drainage radius of the inclined shaft, r w Radius of the well，S θ Is the pseudo-epidermal coefficient;
when the well to be selected comprises a horizontal well, calculating the productivity of the horizontal well in the following mode:
wherein q is H For horizontal well productivity, p e Is the formation pressure, p w In order to realize the flow pressure at the bottom of the well,
is the mean pressure, λ is the critical pressure gradient, r eH Radius of drainage of horizontal well, r w Is the well radius, e is the natural constant, S is the skin coefficient, L H Length of horizontal segment, h reservoir thickness, μ natural gas viscosity, k h The permeability in the horizontal direction, Z is a natural gas deviation factor, T is the formation temperature, a is a major semiaxis of an ellipsoid flow field of the horizontal well, beta is an anisotropy coefficient, delta is an eccentricity, pi is a circumferential rate, and gamma is g Beta 'is the turbulence coefficient in the horizontal direction, and beta' is the turbulence coefficient in the vertical direction, for the relative density of natural gas.
2. The method of claim 1, wherein determining the candidate well type for the target gas reservoir comprises:
and determining the well type to be selected of the target gas reservoir according to the geological characteristics of the target gas reservoir, wherein the geological characteristics of the target gas reservoir comprise reservoir physical properties, reservoir spreading characteristics, fracture-cave development degree, fluid properties and gas-water relationship.
3. The method of claim 1, wherein said determining whether the economic benefit of the preferred well type is satisfactory comprises:
and judging whether the economic benefit of the preferred well type meets the requirement according to the result of the following formula:
wherein p is t For the expected recovery period of investment, I t Investment for year t, C o For the t year natural gas production operating cost, R e For operating fee rate of rise, I for discount rate, Q t The natural gas yield in the t year, and the AIC is a reference value for judging whether the economic benefit meets the requirement after the t year;
and when t is less than or equal to the designated year, if the AIC is less than the selling price of the natural gas, the economic benefit of the preferred well type meets the requirement, and if the AIC is greater than or equal to the selling price of the natural gas, the economic benefit of the preferred well type does not meet the requirement.
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