CN112324420B - Well control geological reserve prediction method and system - Google Patents

Well control geological reserve prediction method and system Download PDF

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CN112324420B
CN112324420B CN201910693152.7A CN201910693152A CN112324420B CN 112324420 B CN112324420 B CN 112324420B CN 201910693152 A CN201910693152 A CN 201910693152A CN 112324420 B CN112324420 B CN 112324420B
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gas
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formation pressure
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CN112324420A (en
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王军磊
贾爱林
位云生
袁贺
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Petrochina Co Ltd
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
    • Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping

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  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
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  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

The invention provides a well control geological reserve prediction method and system. The well control geological reserve prediction method comprises the following steps: the following iterative processing is performed: calculating the normalized yield at each moment; calculating the material balance simulation time at each moment according to the initial value of the well control geological reserve; generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment; fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve; calculating well control geological reserves according to the slope; judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict well control geological reserves, further effectively guide the development process of natural gas and improve the recovery ratio of the natural gas.

Description

Well control geological reserve prediction method and system
Technical Field
The invention relates to the field of natural gas exploitation, in particular to a well control geological reserve prediction method and system.
Background
Shale gas reservoirs are a special gas reservoir type in which free gas and adsorption gas coexist, and industrial productivity is obtained by forming an artificial gas reservoir through volume transformation. The shale gas reservoir well control geological reserves refer to original geological reserves corresponding to the effective utilization range (mainly consistent with the volume transformation area) in the shale gas reservoir, and the original geological reserves comprise free gas reserves and adsorbed gas reserves. Three methods are commonly used for geologic reservoir evaluation, namely volumetric, mass balance, and yield progressive. Volumetric and mass balance methods are used to predict natural gas primary geological reserves, while yield-decreasing rules are used to predict natural gas recoverable reserves. Since the volumetric method relies on detailed knowledge of reservoir characteristics (typically unknown, such as shale gas effective area, elevation, etc.), the estimated reserves may be very inaccurate. The production incremental method uses gas reservoir dynamic data, but only predicts the recoverable natural gas reserves under existing operating conditions, and if the operating conditions change, changes in natural gas production and recoverable reserves are caused, which makes it difficult to determine the original natural gas geological reserves using the production incremental method. Conventional material balance equations require the acquisition of average formation pressure of the reservoir, or the maintenance of constant production in the well, to predict more accurate geologic reserves.
Disclosure of Invention
The embodiment of the invention mainly aims to provide a well control geological reserve prediction method and a well control geological reserve prediction system, so that the well control geological reserve is accurately predicted, continuous production of a gas well is not affected, time and cost are saved, the development process of natural gas is further effectively guided, and the natural gas recovery ratio is improved.
In order to achieve the above object, an embodiment of the present invention provides a method for predicting well control geological reserves, including:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating the bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
Calculating the normalized yield of each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity under the formation pressure at the initial moment, the corrected gas compression coefficient under the formation pressure at the initial moment and the gas well yield of each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing.
The embodiment of the invention also provides a well control geological reserve prediction system, which comprises the following steps:
the first acquisition module is used for acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at the initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the iteration module, the iteration module includes:
the gas quasi-pressure unit is used for calculating the gas quasi-pressure at the initial moment according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
the bottom hole gas pseudo-pressure unit is used for calculating the bottom hole gas pseudo-pressure according to the gas viscosity under the formation pressure at the moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
the normalized output unit is used for calculating the normalized output at each moment according to the gas well output at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
The material balance simulation time unit is used for calculating the material balance simulation time at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield at each moment;
a coordinate point unit for generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
the slope unit is used for fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
the well control geological reserve unit is used for calculating well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
a judging unit for judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision;
a well control geological reserve prediction value unit for taking the well control geological reserve as a well control geological reserve prediction value;
and the replacing unit is used for enabling the well control geological reserves to replace the initial values of the well control geological reserves and continuously executing the iterative processing.
The embodiment of the invention also provides a computer device, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor realizes the following steps when executing the computer program:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating the bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
Calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity under the formation pressure at the initial moment, the corrected gas compression coefficient under the formation pressure at the initial moment and the gas well yield of each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing.
The embodiment of the invention also provides a computer readable storage medium, on which a computer program is stored, which when being executed by a processor, realizes the following steps:
Acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating the bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity under the formation pressure at the initial moment, the corrected gas compression coefficient under the formation pressure at the initial moment and the gas well yield of each moment;
Generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing.
The well control geological reserve prediction method and system of the embodiment of the invention execute the following iterative processing: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings that are needed in the description of the embodiments will be briefly described below, it being obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a flow chart of a method of predicting well control geological reserves in accordance with one embodiment of the present invention;
FIG. 2 is a flow chart of a method of predicting well control geological reserves in accordance with another embodiment of the present invention;
FIG. 3 is a flowchart of S105 in an embodiment of the present invention;
FIG. 4 is a flowchart of S107 in an embodiment of the invention;
FIG. 5 is a graphical representation of average formation pressure and material balance fit time over production time for a first iteration in an embodiment of the present invention;
FIG. 6 is a schematic representation of a fit at a first iteration in an embodiment of the present invention;
FIG. 7 is a diagram of a comparison of a final iteration versus a first iteration of an embodiment of the present invention;
FIG. 8 is a schematic of well control geological reserves at different iteration numbers in an embodiment of the present invention;
FIG. 9 is a block diagram of a well control geological reserve prediction system in accordance with an embodiment of the present invention.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Those skilled in the art will appreciate that embodiments of the invention may be implemented as a system, apparatus, device, method, or computer program product. Accordingly, the present disclosure may be embodied in the following forms, namely: complete hardware, complete software (including firmware, resident software, micro-code, etc.), or a combination of hardware and software.
In view of the difficulty in accurately predicting well control geological reserves and influencing gas well production in the prior art, the embodiment of the invention provides a well control geological reserve prediction method for accurately predicting the well control geological reserves, so that the continuous production of the gas well is not influenced, the time and the cost are saved, the development process of natural gas is further effectively guided, and the natural gas recovery ratio is improved. The present invention will be described in detail with reference to the accompanying drawings.
FIG. 1 is a flow chart of a method of predicting well control geological reserves in accordance with one embodiment of the present invention. As shown in fig. 1, the well control geological reserve prediction method includes:
s101: acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; wherein the number of moments is a plurality of, and the moments include initial moments.
When there is only one well in the gas reservoir, the data is single well data. When there are multiple wells in the gas reservoir, the data is an average of the multiple wells.
The following iterative processing is performed:
s102: and calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment.
In one embodiment, the gas partial pressure at the initial time may be calculated by the following formula:
wherein m [ p (t) 0 )]Simulating pressure for gas at initial moment; mu (mu) g [p(t 0 )]For the gas viscosity at formation pressure at the initial moment, Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial time, p (t 0 ) Is the formation pressure at the initial moment, the unit is megapascal (MPa), and the unit is the formation pressure, and the unit is the formation pressure g (ζ) is the gas viscosity at formation pressure ζ, Z g (ζ) is a deviation factor of formation pressure ζ. The gas viscosity was obtained by an indoor gas high-pressure physical property test and was expressed in Pa.s.
S103: and calculating the bottom hole gas pseudo pressure according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure.
In one embodiment, the bottom hole gas pressure may be calculated by the following formula:
wherein m (p) w ) Pseudo pressure for bottom hole gas, p w Is the bottom hole pressure in megapascals (MPa).
S104: and calculating the normalized yield at each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the bottom hole gas quasi-pressure.
In one embodiment, the normalized yield for each instant can be calculated by the following formula:
wherein Q (tj) is normalized yield at the j-th moment, Q g (tj) is the production of the gas well at the j-th moment, m [ p (t) 0 )]For the initial moment, the gas is under pressure, m (p w ) The pressure is simulated for the downhole gas. The gas pseudo-pressure unit is megapascals (MPa), and the gas well yield unit is cubic meters per day (m) 3 /d)，
S105: and calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield of each moment.
S106: and generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment.
S107: and fitting a plurality of reciprocal coordinate points to obtain the slope of the fitted curve.
S108: well control geological reserves are calculated according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment.
S109: and judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision.
S110: and when the accuracy is smaller than the preset first accuracy, ending the iteration, and taking the well control geological reserves as well control geological reserves predicted values.
S111: and when the first precision is greater than or equal to the preset first precision, replacing the well control geological reserve with the well control geological reserve initial value, and continuing to execute the iterative processing.
The main body of execution of the well control geological reserve prediction method shown in fig. 1 may be a computer. As can be seen from the flow chart shown in fig. 1, the well control geological reserve prediction method according to the embodiment of the invention performs the following iterative process: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
FIG. 2 is a flow chart of a method of predicting well control geological reserves in accordance with another embodiment of the present invention. As shown in fig. 2, before S101 is performed, it may further include:
S201: and acquiring a gas compression coefficient, a Langmuir volume, a formation temperature, a standard state pressure, an effective formation porosity, a standard state temperature, a gas deviation factor and a Langmuir pressure at the standard state pressure at the initial moment.
S202: and calculating a correction gas deviation coefficient of the formation pressure at the initial moment according to the deviation factor of the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the Langmuir pressure and the formation pressure at the initial moment.
In one embodiment, the corrected gas deviation coefficient for the formation pressure at the initial time may be calculated by the following formula:
wherein,,correction gas deviation coefficient for formation pressure at initial time, Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial moment, V L Is Langmuir volume, T is formation temperature, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor at standard state pressure, p L Is Langmuir pressure, p (t) 0 ) Is the formation pressure at the initial time.
S203: and calculating the corrected gas compression coefficient under the formation pressure at the initial time according to the gas compression coefficient under the formation pressure at the initial time, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the formation pressure at the initial time and the formation pressure at the initial time.
In one embodiment, the corrected gas compression factor at formation pressure at the initial time may be calculated by the following equation:
wherein c t [p(t 0 )]C is the corrected gas compression coefficient at the formation pressure at the initial time g [p(t 0 )]Stratum being the initial momentCompression coefficient of gas under pressure, V L Is Langmuir volume, T is formation temperature, p L Is Langmuir pressure, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor under standard state pressure, Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial time, p (t 0 ) Is the formation pressure at the initial time. The units of the gas compression coefficient and the corrected gas compression coefficient are each one megapascal (MPa) -1 )。
Fig. 3 is a flowchart of S105 in an embodiment of the present invention. As shown in fig. 3, S105 includes:
S301: and calculating the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve.
Wherein calculating the average formation pressure at each time instant comprises: calculating the quotient of the average formation pressure at each moment and the correction gas deviation coefficient of the average formation pressure at each moment according to the formation pressure at the initial moment, the correction gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of well control geological reserves; the average formation pressure at each time is calculated from the quotient of the average formation pressure at each time and the corrected gas deviation coefficient of the average formation pressure at each time.
In one embodiment, the quotient of the corrected gas deviation coefficient of the average formation pressure at each time and the average formation pressure at each time may be calculated by the following formula:
wherein,,a quotient, p, of the corrected gas deviation coefficient of the average formation pressure at the j-th moment and the average formation pressure at the j-th moment avg (t j ) Is the average formation pressure at time j +.>A corrected gas deviation coefficient for the average formation pressure at the j-th time, p (t 0 ) For the formation pressure at the initial moment +.>G is a corrected gas deviation coefficient of formation pressure at the initial time p (t j ) For the accumulated gas yield at the j th moment, G 0 For well control geological reserves initial values, the unit is cubic meters (m 3 ). The cumulative gas production is also in cubic meters (m 3 )。
S302: and obtaining the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment according to the average formation pressure at each moment.
S303: and calculating the material balance simulation time at each moment according to the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, the gas well yield at each moment, the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment.
In one embodiment, the material balance pseudo-time for each instant can be calculated by the following formula:
wherein t is mba (t j ) The time is calculated for the material balance at the j-th moment, and the unit is day (d) and mu g [p(t 0 )]C is the gas viscosity at formation pressure at the initial time t [p(t 0 )]For the corrected gas compression coefficient, q, at formation pressure at the initial time g (t j ) For gas well production at time j, q g Gas well production at time τ, [ mu ] is (τ) g [p avg (τ)]Is the τThe gas viscosity at the mean formation pressure at time, c t [p avg (τ)]The corrected gas compression coefficient at the average formation pressure at time τ, tj is the jth time.
Before performing S303, it may further include: acquiring a gas compression coefficient under the average formation pressure at each moment, a deviation factor of the average formation pressure at each moment, a Langmuir volume, a formation temperature, a Langmuir pressure, a standard state pressure, a formation effective porosity, a standard state temperature and a gas deviation factor under the standard state pressure; and calculating the corrected gas compression coefficient under the average formation pressure at each moment according to the gas compression coefficient under the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the average formation pressure at each moment and the average formation pressure at each moment.
In one embodiment, the corrected gas compression factor at the average formation pressure at each time may be calculated by the following equation:
wherein c t [p avg (τ)]C is the corrected gas compression coefficient at the average formation pressure at time τ g [p avg (τ)]Is the gas compression coefficient at the average formation pressure at time tau, V L Is Langmuir volume, T is formation temperature, p L Is Langmuir pressure, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor under standard state pressure, Z g [p avg (τ)]Is the deviation factor of the average formation pressure at the tau point, p avg And (τ) is the average formation pressure at time τ.
Fig. 4 is a flowchart of S107 in an embodiment of the present invention. As shown in fig. 4, S107 includes:
s401: and ordering the plurality of reciprocal coordinate points in order from small to large according to the size of the material balance quasi-time.
S402: and taking the maximum material balance fitting time as a fixed point, searching a plurality of data points with preset quantity forwards, and fitting to obtain the slope of the first initial fitting curve.
The following iterative processing is performed:
s403: and continuing to search a plurality of data points with preset quantity forwards and fitting to obtain the slope of the second initial fitting curve.
S404: and judging whether the absolute value of the difference between the slope of the second initial fitting curve and the slope of the first initial fitting curve is smaller than the second preset precision.
S405: and when the initial fitting curve is smaller than the second preset precision, ending the iteration, and taking the slope of the second initial fitting curve as the slope of the fitting curve.
S406: and when the first initial fitting curve is larger than or equal to the second preset precision, taking the slope of the second initial fitting curve as the slope of the first initial fitting curve, and continuing to execute iterative processing.
The specific flow of the embodiment of the invention is as follows:
1. and acquiring the formation pressure at the initial moment, a deviation factor of the formation pressure at the initial moment, a gas compression coefficient under the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure and the Langmuir pressure.
Wherein the Langmuir pressure is measured through an indoor desorption adsorption experiment, and the unit is megapascal (MPa); standard state pressure units are megapascals (MPa); formation temperature in kelvin (K); the standard state temperature unit is Kelvin (K), and the deviation factor of the formation pressure at the initial moment is obtained through an indoor gas high-pressure physical property experiment; the langmuir volume was measured by an indoor desorption adsorption experiment in cubic meters per ton (m 3 T); the effective porosity of the formation is interpreted by logging.
2. And calculating a correction gas deviation coefficient of the formation pressure at the initial moment according to the deviation factor of the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the Langmuir pressure and the formation pressure at the initial moment.
3. And calculating the corrected gas compression coefficient under the formation pressure at the initial time according to the gas compression coefficient under the formation pressure at the initial time, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the formation pressure at the initial time and the formation pressure at the initial time.
4. The initial value of well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the bottom hole pressure, the cumulative gas production at each moment and the gas well production at each moment are obtained. In one embodiment, the well control geological reserve initial value is 34.26X10 3 m 3 . The following iterative processing is performed:
5. and calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment. And calculating the bottom hole gas pseudo pressure according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure. And calculating the normalized yield at each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the bottom hole gas quasi-pressure.
6. And calculating the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve.
7. And obtaining the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment according to the average formation pressure at each moment. Taking as an example the corrected gas compression factor at the average formation pressure at each instant, comprising: acquiring a gas compression coefficient under the average formation pressure at each moment and a deviation factor of the average formation pressure at each moment; and calculating the corrected gas compression coefficient under the average formation pressure at each moment according to the gas compression coefficient under the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the average formation pressure at each moment and the average formation pressure at each moment.
8. And calculating the material balance simulation time at each moment according to the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, the gas well yield at each moment, the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment.
FIG. 5 is a graphical representation of average formation pressure and material balance fit time over production time for a first iteration in an embodiment of the present invention. As shown in FIG. 5, the abscissa represents production time in days (day), the left ordinate represents average formation pressure in megapascals (MPa), and the right ordinate represents material balance pseudo-time in days (day).
9. And generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment.
10. And ordering the plurality of reciprocal coordinate points in order from small to large according to the size of the material balance quasi-time. And taking the maximum material balance fitting time as a fixed point, searching a plurality of data points with preset quantity forwards, and fitting to obtain the slope of the first initial fitting curve.
Fig. 6 is a schematic representation of a fit at a first iteration in an embodiment of the invention. As shown in FIG. 6, the abscissa represents the material balance pseudo-time in days (day), and the ordinate represents the reciprocal of the normalized yield in megaPascals day/kilosquare (MPa day/10) 3 m 3 ). The iteration result shows that the gas reservoir enters a quasi-steady-state production stage about 290 days, and data within 291 days to 589 days are selected for linear regression analysis Slope slope= 4.8667 ×10 is obtained -4 MPa/10 3 m 3 Degree of fit R 2 Fitting curve=0.92.
11. The following iterative processing is performed: and continuing to search a plurality of data points with preset quantity forwards and fitting to obtain the slope of the second initial fitting curve. Judging whether the absolute value of the difference between the slope of the second initial fitting curve and the slope of the first initial fitting curve is smaller than a second preset precision; and when the first initial fitting curve is smaller than the second preset precision, ending the iteration, taking the slope of the first initial fitting curve as the slope of the fitting curve, otherwise, taking the slope of the first initial fitting curve as the slope of the first initial fitting curve, and continuing to execute the iteration processing.
FIG. 7 is a diagram of a comparison of a final iteration versus a first iteration fit in an embodiment of the present invention. As shown in FIG. 7, the abscissa represents the material balance pseudo-time in days (day), the ordinate represents the reciprocal of the normalized yield in megaPascals day/kilosquare (MPa day/10) 3 m 3 )。
12. Well control geological reserves are calculated according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment.
13. And judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision. And when the accuracy is smaller than the preset first accuracy, ending the iteration, and taking the well control geological reserves as well control geological reserves predicted values. And when the accuracy is greater than or equal to the preset first accuracy, replacing the initial value of the well control geological reserve with the well control geological reserve, continuing to execute iterative processing, and returning to the step 5.
FIG. 8 is a schematic of well control geological reserves at different iteration numbers in an embodiment of the present invention. As shown in fig. 8, the abscissa represents the number of iterations, and the ordinate represents well control geological reserves in thousand square units. At iteration 9, the final accurate well control geological reserve was approximately 90.11X10 3 m 3 。
In summary, the well control geological reserve prediction method according to the embodiment of the present invention performs the following iterative processing: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
Based on the same inventive concept, the embodiment of the invention also provides a well control geological reserve prediction system, and because the principle of solving the problem of the system is similar to that of a well control geological reserve prediction method, the implementation of the system can refer to the implementation of the method, and the repetition is omitted.
FIG. 9 is a block diagram of a well control geological reserve prediction system in accordance with an embodiment of the present invention. As shown in fig. 9, the well control geological reserve prediction system includes:
the first acquisition module is used for acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at the initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the iteration module, the iteration module includes:
the gas quasi-pressure unit is used for calculating the gas quasi-pressure at the initial moment according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
The bottom hole gas pseudo-pressure unit is used for calculating the bottom hole gas pseudo-pressure according to the gas viscosity under the formation pressure at the moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
the normalized output unit is used for calculating the normalized output at each moment according to the gas well output at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
the material balance simulation time unit is used for calculating the material balance simulation time at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield at each moment;
a coordinate point unit for generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
the slope unit is used for fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
the well control geological reserve unit is used for calculating well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
A judging unit for judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision;
a well control geological reserve prediction value unit for taking the well control geological reserve as a well control geological reserve prediction value;
and the replacing unit is used for enabling the well control geological reserves to replace the initial values of the well control geological reserves and continuously executing the iterative processing.
In one embodiment, fitting a plurality of reciprocal coordinate points to obtain a slope of a fitted line includes:
sequencing a plurality of reciprocal coordinate points according to the size of the material balance simulation time in order from small to large;
taking the maximum material balance fitting time as a fixed point, searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative processing is performed:
continuously searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a second initial fitting curve;
judging whether the absolute value of the difference between the slope of the second initial fitting curve and the slope of the first initial fitting curve is smaller than a second preset precision; and when the first initial fitting curve is smaller than the second preset precision, ending the iteration, taking the slope of the first initial fitting curve as the slope of the fitting curve, otherwise, taking the slope of the first initial fitting curve as the slope of the first initial fitting curve, and continuing to execute the iteration processing.
In one embodiment, the method further comprises:
the second acquisition module is used for acquiring a gas compression coefficient, a Langmuir volume, a formation temperature, a standard state pressure, a formation effective porosity, a standard state temperature, a gas deviation factor and a Langmuir pressure at the standard state pressure at the initial moment;
the corrected gas deviation coefficient module is used for calculating a corrected gas deviation coefficient of the formation pressure at the initial moment according to the deviation factor of the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the Langmuir pressure and the formation pressure at the initial moment;
the first corrected gas compression coefficient module is used for calculating the corrected gas compression coefficient under the formation pressure at the initial moment according to the gas compression coefficient under the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment.
In one of these embodiments, the slope unit is specifically configured to:
calculating the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of well control geological reserves;
obtaining the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment according to the average formation pressure at each moment;
and calculating the material balance simulation time at each moment according to the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, the gas well yield at each moment, the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment.
In one embodiment, the method further comprises:
the third acquisition module is used for acquiring the gas compression coefficient under the average formation pressure at each moment, the deviation factor of the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature and the gas deviation factor under the standard state pressure;
And the second correction gas compression coefficient module is used for calculating the correction gas compression coefficient under the average formation pressure at each moment according to the gas compression coefficient under the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the average formation pressure at each moment and the average formation pressure at each moment.
In one of these embodiments, the slope unit is specifically configured to:
calculating the quotient of the average formation pressure at each moment and the correction gas deviation coefficient of the average formation pressure at each moment according to the formation pressure at the initial moment, the correction gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of well control geological reserves;
the average formation pressure at each time is calculated from the quotient of the average formation pressure at each time and the corrected gas deviation coefficient of the average formation pressure at each time.
In summary, the well control geological reserve prediction system of the embodiment of the invention executes the following iterative processing: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
The embodiment of the invention also provides a computer device, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor realizes the following steps when executing the computer program:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating the bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
Calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity under the formation pressure at the initial moment, the corrected gas compression coefficient under the formation pressure at the initial moment and the gas well yield of each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing.
In summary, the computer device of the embodiment of the present invention performs the following iterative processing: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
The embodiment of the invention also provides a computer readable storage medium, which stores a computer program, and the computer program realizes the following steps when being executed by a processor:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating the bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield at each moment, the gas quasi-pressure at the initial moment and the well bottom gas quasi-pressure;
Calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield of each moment, the initial value of well control geological reserves, the gas viscosity under the formation pressure at the initial moment, the corrected gas compression coefficient under the formation pressure at the initial moment and the gas well yield of each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting a plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing.
In summary, the computer-readable storage medium of the embodiment of the present invention performs the iterative processing of: calculating the normalized yield at each moment according to the initial value of the well control geological reserve, generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance fit time at each moment, fitting the reciprocal coordinate points to obtain the slope of a fitted curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the well control geological reserve and the initial value of the well control geological reserve is smaller than the preset first precision; and when the first precision is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, otherwise, enabling the well control geological reserve to replace a well control geological reserve initial value, and continuing to execute the iteration processing. The method can accurately predict the well control geological reserve, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of natural gas and improves the recovery ratio of the natural gas.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the invention, and is not meant to limit the scope of the invention, but to limit the invention to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the invention are intended to be included within the scope of the invention.

Claims (20)

1. A method of predicting well control geological reserves, comprising:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; wherein the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
Calculating a bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield of each moment, the gas quasi-pressure of the initial moment and the bottom hole gas quasi-pressure;
calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of the well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield at each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting the plurality of reciprocal coordinate points to obtain the slope of a fitted curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision; and when the well control geological reserve is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, and if not, enabling the well control geological reserve to replace the well control geological reserve initial value, and continuing to execute the iteration processing.
2. The method of predicting well control geological reserves of claim 1, wherein fitting the plurality of reciprocal coordinate points to obtain the slope of the fitted line comprises:
sequencing the plurality of reciprocal coordinate points according to the material balance fit time in order from small to large;
taking the maximum material balance fitting time as a fixed point, searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative processing is performed:
continuously searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a second initial fitting curve;
judging whether the absolute value of the difference between the slope of the second initial fitting curve and the slope of the first initial fitting curve is smaller than a second preset precision; and when the first initial fitting curve is smaller than the second preset precision, ending the iteration, taking the slope of the first initial fitting curve as the slope of the fitting curve, otherwise taking the slope of the first initial fitting curve as the slope of the first initial fitting curve, and continuing to execute the iteration processing.
3. The method of predicting well control geological reserves of claim 1, further comprising:
Acquiring a gas compression coefficient, a Langmuir volume, a formation temperature, a standard state pressure, effective porosity of the formation, a standard state temperature, a gas deviation factor and a Langmuir pressure at the standard state pressure at the initial moment;
calculating a correction gas deviation coefficient of the formation pressure at the initial moment according to the deviation factor of the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the standard state pressure, the effective formation porosity, the standard state temperature, the gas deviation factor under the standard state pressure, the Langmuir pressure and the formation pressure at the initial moment;
and calculating a correction gas compression coefficient under the formation pressure at the initial moment according to the gas compression coefficient under the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective formation porosity, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment.
4. The method of predicting well control geological reserves of claim 1, wherein calculating the material balance fit time for each moment comprises:
calculating the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve;
obtaining the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment according to the average formation pressure at each moment;
and calculating the material balance simulation time of each moment according to the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, the gas well yield at each moment, the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment.
5. The method of predicting well control geological reserves of claim 4, further comprising:
acquiring a gas compression coefficient under the average formation pressure at each moment, a deviation factor of the average formation pressure at each moment, a Langmuir volume, a formation temperature, a Langmuir pressure, a standard state pressure, a formation effective porosity, a standard state temperature and a gas deviation factor under the standard state pressure;
And calculating a corrected gas compression coefficient at the average formation pressure at each moment according to the gas compression coefficient at the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective formation porosity, the standard state temperature, the gas deviation factor at the standard state pressure, the deviation factor of the average formation pressure at each moment and the average formation pressure at each moment.
6. The method of predicting well control geological reserves of claim 4, wherein calculating the average formation pressure for each time instant comprises:
calculating the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve;
the average formation pressure at each time is calculated from the quotient of the average formation pressure at each time and the corrected gas deviation coefficient of the average formation pressure at each time.
7. The method of predicting well control geological reserves of claim 1,
The gas partial pressure at the initial time is calculated by the following formula:
wherein m [ p (t) 0 )]For initial time gas pseudo-pressure, mu g [p(t 0 )]Is the viscosity of the gas at formation pressure at the initial time，Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial time, p (t 0 ) Is the formation pressure at the initial moment, and xi is the formation pressure and mu g (ζ) is the gas viscosity at formation pressure ζ, Z g (ζ) is a deviation factor of formation pressure ζ;
calculating the bottom hole gas pseudo pressure by the following formula:
wherein m (p) w ) Pseudo pressure for bottom hole gas, p w Is the bottom hole pressure.
8. The method of predicting well control geological reserves of claim 1, wherein the normalized production for each time instant is calculated by the formula:
wherein Q (tj) is normalized yield at the j-th moment, Q g (tj) is the production of the gas well at the j-th moment, m [ p (t) 0 )]For the initial moment, the gas is under pressure, m (p w ) The pressure is simulated for the downhole gas.
9. A method of predicting well control geological reserves as claimed in claim 3, wherein the corrected gas deviation coefficient of formation pressure at said initial time is calculated by the formula:
wherein,,correction gas deviation coefficient for formation pressure at initial time, Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial moment, V L Is Langmuir volume, T is formation temperature, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor at standard state pressure, p L Is Langmuir pressure, p (t) 0 ) The formation pressure at the initial time;
calculating a corrected gas compression coefficient at the formation pressure at the initial time by the following formula:
wherein c t [p(t 0 )]C is the corrected gas compression coefficient at the formation pressure at the initial time g [p(t 0 )]Is the gas compression coefficient at the formation pressure at the initial time, V L Is Langmuir volume, T is formation temperature, p L Is Langmuir pressure, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor under standard state pressure, Z g [p(t 0 )]Is the deviation factor of the formation pressure at the initial time, p (t 0 ) Is the formation pressure at the initial time.
10. The method of predicting well control geological reserves of claim 4, wherein the material balance fit time for each moment is calculated by the formula:
wherein t is mba (t j ) Time, mu for substance balance at j-th moment g [p(t 0 )]C is the gas viscosity at formation pressure at the initial time t [p(t 0 )]For correction gas at formation pressure at initial time Compression coefficient, q g (t j ) For gas well production at time j, q g Gas well production at time τ, [ mu ] is (τ) g [p avg (τ)]C is the gas viscosity at the average formation pressure at time τ t [p avg (τ)]The corrected gas compression coefficient at the average formation pressure at time τ, tj is the jth time.
11. The method of predicting well control geological reserves of claim 5,
the corrected gas compression factor at the average formation pressure at each time is calculated by the following formula:
wherein c t [p avg (τ)]C is the corrected gas compression coefficient at the average formation pressure at time τ g [p avg (τ)]Is the gas compression coefficient at the average formation pressure at time tau, V L Is Langmuir volume, T is formation temperature, p L Is Langmuir pressure, p sc Is the standard state pressure, phi is the effective porosity of the stratum, T sc At standard state temperature, Z sc Is the gas deviation factor under standard state pressure, Z g [p avg (τ)]Is the deviation factor of the average formation pressure at the tau point, p avg And (τ) is the average formation pressure at time τ.
12. The method of predicting well control geological reserves of claim 6, wherein the quotient ofthe corrected gas deviation coefficient of the average formation pressure at each time instant and the average formation pressure at each time instant is calculated by the formula:
Wherein,,a quotient, p, of the corrected gas deviation coefficient of the average formation pressure at the j-th moment and the average formation pressure at the j-th moment avg (t j ) Is the average formation pressure at time j +.>A corrected gas deviation coefficient for the average formation pressure at the j-th time, p (t 0 ) For the formation pressure at the initial moment +.>G is a corrected gas deviation coefficient of formation pressure at the initial time p (t j ) For the accumulated gas yield at the j th moment, G 0 Initial value for well control geological reserves.
13. A system for predicting well control geological reserves, comprising:
the first acquisition module is used for acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at the initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; wherein the number of the moments is a plurality of, and the moments comprise initial moments;
an iteration module, the iteration module comprising:
the gas quasi-pressure unit is used for calculating the gas quasi-pressure at the initial moment according to the gas viscosity at the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
A bottom hole gas pseudo-pressure unit for calculating a bottom hole gas pseudo-pressure according to the gas viscosity at the formation pressure at the initial time, the deviation factor of the formation pressure at the initial time, the formation pressure at the initial time and the bottom hole pressure;
the normalized output unit is used for calculating the normalized output at each moment according to the gas well output at each moment, the gas quasi-pressure at the initial moment and the bottom hole gas quasi-pressure;
a material balance simulation time unit, configured to calculate a material balance simulation time at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of the well control geological reserve, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, and the gas well yield at each moment;
a coordinate point unit for generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
the slope unit is used for fitting the plurality of reciprocal coordinate points to obtain the slope of a fitting curve;
A well control geological reserve unit for calculating a well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
a judging unit for judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision;
a well control geological reserve prediction value unit for taking the well control geological reserve as a well control geological reserve prediction value;
and the replacing unit is used for enabling the well control geological reserves to replace the initial values of the well control geological reserves and continuously executing iterative processing.
14. The well control geological reserve prediction system of claim 13, wherein fitting said plurality of reciprocal coordinate points to obtain a slope of a fitted line comprises:
sequencing the plurality of reciprocal coordinate points according to the material balance fit time in order from small to large;
taking the maximum material balance fitting time as a fixed point, searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative processing is performed:
continuously searching a plurality of data points with preset quantity forwards and fitting to obtain the slope of a second initial fitting curve;
Judging whether the absolute value of the difference between the slope of the second initial fitting curve and the slope of the first initial fitting curve is smaller than a second preset precision; and when the first initial fitting curve is smaller than the second preset precision, ending the iteration, taking the slope of the first initial fitting curve as the slope of the fitting curve, otherwise taking the slope of the first initial fitting curve as the slope of the first initial fitting curve, and continuing to execute the iteration processing.
15. The well control geological reserve prediction system of claim 13, further comprising:
the second acquisition module is used for acquiring a gas compression coefficient, a Langmuir volume, a formation temperature, a standard state pressure, a formation effective porosity, a standard state temperature, a gas deviation factor and a Langmuir pressure at the standard state pressure at the initial moment;
a corrected gas deviation coefficient module, configured to calculate a corrected gas deviation coefficient of the formation pressure at the initial time according to a deviation factor of the formation pressure at the initial time, the langmuir volume, the formation temperature, the standard state pressure, the effective formation porosity, the standard state temperature, a gas deviation factor at the standard state pressure, the langmuir pressure, and the formation pressure at the initial time;
And the first corrected gas compression coefficient module is used for calculating the corrected gas compression coefficient under the formation pressure at the initial moment according to the gas compression coefficient under the formation pressure at the initial moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective formation porosity, the standard state temperature, the gas deviation factor under the standard state pressure, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment.
16. The well control geological reserve prediction system of claim 13, wherein said slope unit is specifically configured to:
calculating the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve;
obtaining the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment according to the average formation pressure at each moment;
and calculating the material balance simulation time of each moment according to the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment, the gas well yield at each moment, the gas viscosity at the average formation pressure at each moment and the corrected gas compression coefficient at the average formation pressure at each moment.
17. The well control geological reserve prediction system of claim 16, further comprising:
the third acquisition module is used for acquiring the gas compression coefficient under the average formation pressure at each moment, the deviation factor of the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective porosity of the formation, the standard state temperature and the gas deviation factor under the standard state pressure;
and the second corrected gas compression coefficient module is used for calculating the corrected gas compression coefficient at the average formation pressure at each moment according to the gas compression coefficient at the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the effective formation porosity, the standard state temperature, the gas deviation factor at the standard state pressure, the deviation factor of the average formation pressure at each moment and the average formation pressure at each moment.
18. The well control geological reserve prediction system of claim 16, wherein said slope unit is specifically configured to:
calculating the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment and the initial value of the well control geological reserve;
The average formation pressure at each time is calculated from the quotient of the average formation pressure at each time and the corrected gas deviation coefficient of the average formation pressure at each time.
19. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the following steps when executing the computer program:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; wherein the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating a bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
Calculating the normalized yield of each moment according to the gas well yield of each moment, the gas quasi-pressure of the initial moment and the bottom hole gas quasi-pressure;
calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of the well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield at each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting the plurality of reciprocal coordinate points to obtain the slope of a fitted curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision; and when the well control geological reserve is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, and if not, enabling the well control geological reserve to replace the well control geological reserve initial value, and continuing to execute the iteration processing.
20. A computer readable storage medium having stored thereon a computer program, characterized in that the computer program when executed by a processor realizes the steps of:
acquiring an initial value of well control geological reserves, gas viscosity under formation pressure at an initial moment, a deviation factor of the formation pressure at the initial moment, bottom hole pressure, gas well yield at each moment, a corrected gas deviation coefficient of the formation pressure at the initial moment, accumulated gas yield at each moment and a corrected gas compression coefficient under the formation pressure at the initial moment; wherein the number of the moments is a plurality of, and the moments comprise initial moments;
the following iterative processing is performed:
calculating the gas pseudo pressure at the initial moment according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment and the formation pressure at the initial moment;
calculating a bottom hole gas pseudo pressure according to the gas viscosity under the formation pressure at the initial moment, the deviation factor of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom hole pressure;
calculating the normalized yield of each moment according to the gas well yield of each moment, the gas quasi-pressure of the initial moment and the bottom hole gas quasi-pressure;
Calculating the material balance simulation time of each moment according to the formation pressure at the initial moment, the corrected gas deviation coefficient of the formation pressure at the initial moment, the accumulated gas yield at each moment, the initial value of the well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the corrected gas compression coefficient at the formation pressure at the initial moment and the gas well yield at each moment;
generating a plurality of reciprocal coordinate points according to the reciprocal of the normalized yield at each moment and the material balance quasi-time at each moment;
fitting the plurality of reciprocal coordinate points to obtain the slope of a fitted curve;
calculating well control geological reserves according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
judging whether the absolute value of the difference between the well control geological reserve and the well control geological reserve initial value is smaller than a preset first precision; and when the well control geological reserve is smaller than the preset first precision, ending the iteration, taking the well control geological reserve as a well control geological reserve predicted value, and if not, enabling the well control geological reserve to replace the well control geological reserve initial value, and continuing to execute the iteration processing.
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