CN106677764B - Method for calculating pressure difference in production of stress sensitivity gas reservoir test - Google Patents
Method for calculating pressure difference in production of stress sensitivity gas reservoir test Download PDFInfo
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Abstract
The invention provides a method for calculating the production pressure difference of a stress sensitivity gas reservoir test, which comprises the following steps: based on the well-logging information, the logging information is transmitted to the well,obtaining the reservoir thickness h and the borehole radius r of the test layerwReservoir temperature T; obtaining the effective liquid supply radius r of the test layer according to the adjacent well dataeGas viscosity mu, natural gas mean deviation factor Z; obtaining the initial permeability K of the test layer0Reservoir original pressure peAnd a stress sensitivity coefficient β; establishing a minimum bottom hole pressure pwThe invention establishes a stress sensitivity gas reservoir test production pressure difference calculation model based on productivity response, can accurately obtain the minimum bottom hole pressure of various stress sensitivity gas reservoirs, particularly low-hole seepage gas reservoirs, thereby accurately obtaining the allowed maximum test production pressure difference, providing scientific basis for selecting the production pressure difference in the operations such as gas reservoir production test and the like, reducing the operation time, reducing the operation cost and having good economic and technical values.
Description
Technical Field
The invention relates to the field of natural gas development, in particular to a method for calculating the production pressure difference of a stress sensitivity gas reservoir test.
Background
With the increasing demand for natural gas and the development of oil and gas exploration, the exploration and development of natural gas reservoirs are beginning to develop towards medium and low porosity. The medium-low pore gas reservoir and even the high pore gas reservoir have strong stress sensitivity, the flow characteristics of the natural gas reservoir can be changed by the rock characteristics, and therefore, the influence of the change of the flow characteristics on the production pressure difference needs to be considered in the testing process. At present, during reservoir well completion testing, the testing production pressure difference is mainly determined according to factors such as sand production, well wall stability, flowback or pipe column safety and the like, and the productivity problem during testing is rarely considered. However, in the case of a formation with high stress sensitivity, when the production pressure difference is increased to a certain extent, the productivity (i.e. the daily average gas yield of the gas reservoir) tends to be stable, and the production pressure difference is continuously increased, so that the productivity cannot be greatly increased; meanwhile, if the production pressure difference is too large, a series of hazards such as particle movement, formation sand production, reverse condensation, early water production and the like can be caused. Therefore, it is important how to determine the maximum production pressure differential to improve the economics of gas reservoir development and to ensure successful testing.
Disclosure of Invention
In view of the above-mentioned shortcomings of the prior art, it is an object of the present invention to provide a stress sensitive gas reservoir test differential production pressure calculation method that determines a maximum differential production pressure based on capacity response.
In order to achieve the aim, the invention provides a method for calculating the production pressure difference of a stress sensitivity gas reservoir test, which comprises the following steps:
s1, obtaining the reservoir thickness h and the borehole radius r of the test layer according to the logging informationwAnd a reservoir temperature T;
s2, obtaining the effective liquid supply radius r of the test layer according to the adjacent well dataeGas viscosity μ, and natural gas mean deviation factor Z;
s3, obtaining the initial permeability K of the test layer0；
S4, acquiring reservoir original pressure p of the tested layere；
S5, obtaining the stress sensitivity coefficient beta of the test layer;
s6, establishing a minimum bottom hole pressure pwTo solve the minimum bottom hole pressure pw；
The minimum bottom hole pressure pwThe exponential model of (a) is:
the minimum bottom hole pressure pwThe power function model of (1) is:
in the formula, m is a production pressure difference productivity coefficient;
s7, establishing a model of the production pressure difference delta p during gas reservoir testing: Δ p ═ pe-pwAnd solving the production pressure difference delta p.
Further, in the step S3, the initial permeability K0Obtained by logging data or by test reports or by laboratory tests.
Preferably, in the step S4, the reservoir original pressure PeTo test the measured formation pressure at the location of the interval.
Further, in the step S4, the reservoir original pressure PeObtained from well log data or by the eaton method or by an effective stress model.
Preferably, in the step S5, the stress sensitivity coefficient β is obtained by a laboratory test.
As mentioned above, the method for calculating the production pressure difference in the stress sensitivity gas reservoir test has the following beneficial effects:
the invention establishes a stress sensitivity gas reservoir test production pressure difference calculation model based on productivity response, can accurately obtain the minimum bottom hole pressure of various stress sensitivity gas reservoirs, particularly low-hole permeability gas reservoirs, thereby accurately obtaining the allowed maximum test production pressure difference, providing scientific basis for the selection of the production pressure difference in the operations such as gas reservoir production test and the like, reducing the operation time and the operation cost and having good economic and technical values.
Drawings
FIG. 1 is a flow chart of the present invention.
FIG. 2 is a graph of actual differential pressure versus actual gas production capacity in one embodiment.
Detailed Description
The following description of the embodiments of the present invention is provided for illustrative purposes, and other advantages and effects of the present invention will become apparent to those skilled in the art from the present disclosure.
It should be understood that the structures, ratios, sizes, and the like shown in the drawings and described in the specification are only used for matching with the disclosure of the specification, so as to be understood and read by those skilled in the art, and are not used to limit the conditions under which the present invention can be implemented, so that the present invention has no technical significance, and any structural modification, ratio relationship change, or size adjustment should still fall within the scope of the present invention without affecting the efficacy and the achievable purpose of the present invention. In addition, the terms "upper", "lower", "left", "right", "middle" and "one" used in the present specification are for clarity of description, and are not intended to limit the scope of the present invention, and the relative relationship between the terms and the terms is not to be construed as a scope of the present invention.
As shown in fig. 1, the present application provides a method for calculating a pressure difference in production of a stress-sensitive gas reservoir test, comprising the following steps:
s1, obtaining the reservoir thickness h (unit m) and the borehole radius r of the gas reservoir test layer according to the logging informationw(in cm), and reservoir temperature T (in K);
s2, obtaining the effective liquid supply radius r of the gas reservoir test layer according to the adjacent well informatione(in cm), gas viscosity μ (in Mpa · s), and natural gas mean deviation factor Z;
s3, obtaining the initial permeability K of the gas reservoir test layer0(Unit 10)-3μm2)；
S4, acquiring reservoir original pressure p of the gas reservoir test layere(in MPa), reservoir original pressure peThe formation pressure at the well site is also tested for the gas reservoir;
s5, obtaining the stress sensitivity coefficient beta of the gas reservoir test layer;
s6, establishing a minimum bottom hole pressure pwTo solve the minimum bottom hole pressure pw(in MPa);
the minimum bottom hole pressure pwThe exponential model of (a) is:
the minimum bottom hole pressure pwThe power function model of (1) is:
in the above formula, m is the productivity coefficient of differential pressure production, and Q is the minimum bottom hole pressure pwCapacity equation of (2);
s7, establishing a model of the production pressure difference delta p during gas reservoir testing: Δ p ═ pe-pwAnd solving the production pressure difference delta p.
In the above steps, the logging data is the original data of the test well, mainly including acoustic time difference, well diameter, density, electron rate, etc., the reservoir thickness h, and the well radius rwAnd the reservoir temperature T can be obtained directly from the log data. The adjacent well data refers to original data and test reports of wells near the test well, and the effective liquid supply radius reThe gas viscosity, mu, and the natural gas mean deviation factor, Z, can all be obtained directly from the adjacent well data. In this application, the reservoir original pressure PeInitial permeability K0And the acquisition of the stress sensitivity coefficient beta belong to the prior art. Preferably, the reservoir original pressure PeThe method can be obtained according to logging data, can also be obtained through an Eton method or can be obtained through an effective stress model, such as traditional method discussion for detecting the formation pore pressure through logging data published in journal of Petroleum exploration and development, volume 8, month 8, 2003, volume 30, and the traditional method discloses a method for obtaining the formation pore pressure (namely the reservoir original pressure in the application) through the logging data. When the tested well section position of the gas reservoir has the actually measured stratum pressure, the original reservoir pressure PePreferably, measured formation pressure is used. The initial permeability K0The permeability can be obtained through well logging data, test reports or indoor tests, such as ultralow permeability core gas logging permeability test error analysis published in journal, journal of university of western's petroleum (nature science edition), vol 24, 2009, 24, which discloses a method for calculating permeability. The stress sensitivity coefficient beta is obtained by regression of laboratory test data, such as the gas reservoir numerical simulation study considering stress sensitivity influence in 2007 university of Master's academic paper at southwest of Petroleum, section 3.3.3.2 of which discloses calculating the stress sensitivity constant b (i.e., the stress sensitivity system in the present application)Number β).
In addition, it is known that with the bottom hole pressure pwThe production pressure difference delta p is gradually reduced and increased, and the productivity Q of the gas reservoir is gradually increased; however, when the bottom hole pressure pwIf the gas reservoir is reduced to a certain extent and then reduced, the capacity Q of the gas reservoir tends to a fixed value. Thus, the productivity Q of the gas reservoir and the bottom hole pressure p tend to be constant before the productivity Q of the gas reservoir approaches a fixed valuewIs in inverse relation between the productivity Q and the bottom hole pressure pwThe tangent ratio of the relation curve is the production pressure difference productivity coefficient m, and the production pressure difference productivity coefficient m is different for different gas reservoirs. The method considers the change rate of the productivity in the stress sensitivity gas reservoir testing process, when the change rate of the productivity is too small, the testing production pressure difference is increased, the productivity cannot be greatly improved, and the development cost of the gas reservoir is increased and the testing failure is caused when the production pressure difference is too large; the present application establishes a minimum bottom hole pressure p based on productivity responsewTo obtain a minimum bottom hole pressure pwAnd finally obtaining the maximum production pressure difference delta p, wherein the production pressure difference delta p can also ensure that the gas reservoir development has better economy on the premise of ensuring the successful test.
The method can be suitable for various stress sensitivity gas reservoirs, such as high-pore gas reservoirs, ultralow-pore gas reservoirs, medium-low-pore gas reservoirs, matrix sandstone gas reservoirs, fractured sandstone gas reservoirs, carbonate gas reservoirs, coal bed gas reservoirs and the like, and can also be used for common gas reservoirs. In order to verify that the production pressure difference Δ p determined by the application is based on capacity response, the production pressure difference and the corresponding capacity of the gas reservoir are recorded in the actual gas reservoir development process, and fig. 2 is a relation graph between the production pressure difference and the capacity obtained after the gas reservoir is actually developed; the maximum production pressure difference delta p of the gas reservoir obtained by applying the model established in the application is 32.9MPa, as can be seen from figure 2, the yield change is gradually reduced along with the increase of the production pressure difference, when the production pressure difference of the gas reservoir is less than 32.9MPa, the change rate of the gas yield is large, and the gas yield can be greatly improved by improving the production pressure difference; when the production pressure difference of the gas reservoir is greater than 32.9MPa, the change rate of the gas yield is very small, and the influence effect on the gas yield is small by increasing the production pressure difference. In conclusion, the method can accurately obtain the minimum bottom hole pressure of various stress-sensitive gas reservoirs, particularly low-hole permeability gas reservoirs, so that the maximum production pressure difference allowed in gas reservoir testing can be accurately obtained, scientific basis is provided for selection of the production pressure difference in operations such as gas reservoir production testing and the like, and the maximum test production pressure difference is determined based on capacity response, so that related scientific basis is provided for economic and effective development of the whole gas reservoir. Therefore, the invention effectively overcomes various defects in the prior art and has high industrial utilization value.
The foregoing embodiments are merely illustrative of the principles and utilities of the present invention and are not intended to limit the invention. Any person skilled in the art can modify or change the above-mentioned embodiments without departing from the spirit and scope of the present invention. Accordingly, it is intended that all equivalent modifications or changes which can be made by those skilled in the art without departing from the spirit and technical spirit of the present invention be covered by the claims of the present invention.
Claims (5)
1. A method for calculating the pressure difference in production of a stress-sensitive gas reservoir test is characterized by comprising the following steps:
s1, obtaining the reservoir thickness h and the borehole radius r of the test layer according to the logging informationwAnd a reservoir temperature T;
s2, obtaining the effective liquid supply radius r of the test layer according to the adjacent well dataeGas viscosity μ, and natural gas mean deviation factor Z;
s3, obtaining the initial permeability K of the test layer0；
S4, acquiring reservoir original pressure p of the tested layere；
S5, obtaining the stress sensitivity coefficient beta of the test layer;
s6, establishing a minimum bottom hole pressure pwTo solve the minimum bottom hole pressure pw；
The minimum bottom hole pressure pwThe exponential model of (a) is:
the minimum bottom hole pressure pwThe power function model of (1) is:
in the formula, m is a production pressure difference productivity coefficient;
s7, establishing a model of the maximum production pressure difference delta p allowed in the gas reservoir test: Δ p ═ pe-pwThe maximum allowable differential production pressure Δ p is solved.
2. The method for calculating the production pressure difference of the stress-sensitive gas reservoir test according to claim 1, wherein the method comprises the following steps: in the step S3, the initial permeability K0Obtained by logging data or by test reports or by laboratory tests.
3. The method for calculating the production pressure difference of the stress-sensitive gas reservoir test according to claim 1, wherein the method comprises the following steps: in the step S4, the reservoir original pressure PeTo test the measured formation pressure at the location of the interval.
4. The method for calculating the production pressure difference of the stress-sensitive gas reservoir test according to claim 1, wherein the method comprises the following steps: in the step S4, the reservoir original pressure PeObtained from well log data or by the eaton method or by an effective stress model.
5. The method for calculating the production pressure difference of the stress-sensitive gas reservoir test according to claim 1, wherein the method comprises the following steps: in step S5, the stress sensitivity coefficient β is obtained by an indoor test.
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