CN112324420A - Prediction method and system for well control geological reserves - Google Patents

Prediction method and system for well control geological reserves Download PDF

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CN112324420A
CN112324420A CN201910693152.7A CN201910693152A CN112324420A CN 112324420 A CN112324420 A CN 112324420A CN 201910693152 A CN201910693152 A CN 201910693152A CN 112324420 A CN112324420 A CN 112324420A
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CN112324420B (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
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    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
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Abstract

The invention provides a prediction method and a prediction system for well control geological reserves. The well control geological reserve prediction method comprises the following steps: the following iterative process is performed: calculating the normalized yield of each moment; calculating the material balance simulated 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, further effectively guide the development process of the natural gas and improve the natural gas recovery ratio.

Description

Prediction method and system for well control geological reserves
Technical Field
The invention relates to the field of natural gas development, in particular to a prediction method and a prediction system for well control geological reserves.
Background
The shale gas reservoir is a special gas reservoir type with coexisting free gas and adsorbed gas, and the industrial capacity 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 an effective utilization range (mainly consistent with a volume transformation area) in the shale gas reservoir, and comprise two parts of free gas reserves and adsorbed gas reserves. Geological reserves are usually evaluated by three methods, namely volumetric methods, material balance methods and yield subtraction methods. Volumetric and material balance methods are used to predict the original geological reserves of natural gas, while yield diminishing laws are used to predict recoverable reserves of natural gas. Since volumetric methods rely on detailed knowledge of reservoir properties (which are generally unknown, such as shale gas available area, height, etc.), the estimated reserves may be very inaccurate. The yield subtraction method uses dynamic data of a gas reservoir, but only predicts the recoverable natural gas reserves under the existing operating conditions, if the operating conditions change, the natural gas yield and the recoverable reserves can change, and the original natural gas geological reserves can be difficult to determine by the yield subtraction method. The traditional material balance equation needs to acquire the average formation pressure of a gas reservoir or keep the gas well producing at a constant yield so as to predict more accurate geological reserves.
Disclosure of Invention
The embodiment of the invention mainly aims to provide a prediction method and a prediction system for well control geological reserves, which are used for accurately predicting the well control geological reserves, do not influence the continuous production of gas wells, save time and cost, further effectively guide the development process of natural gas and improve the recovery ratio of the natural gas.
In order to achieve the above object, an embodiment of the present invention provides a method for predicting well control geological reserves, including:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance simulated 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 production rate at each moment, the well control geological reserve initial value, 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 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
The embodiment of the invention also provides a prediction system of well control geological reserves, which comprises the following steps:
the system comprises a first acquisition module, a second acquisition module and a third acquisition module, wherein the first acquisition module is used for acquiring a well control geological reserve initial value, gas viscosity at the 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 at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
an iteration module, the iteration module comprising:
the gas pseudo-pressure unit is used for 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;
the bottom-hole gas pseudo-pressure unit is used for calculating bottom-hole gas pseudo-pressure according to gas viscosity under the formation pressure at the moment, deviation factors of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom pressure;
the normalized yield unit is used for calculating the normalized yield of each moment according to the gas well yield of each moment, the gas pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
the material balance simulated time unit is used for calculating the material balance simulated 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 production rate at each moment, the initial value of well control geological reserve, 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 at each moment;
a coordinate point unit for generating a plurality of reciprocal coordinate points according to a reciprocal of the normalized yield at each time and a material balance pseudo-time at each time;
the slope unit is used for fitting the reciprocal coordinate points to obtain the slope of a fitting curve;
the well control geological reserve unit is used for calculating the well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
the judging unit is used for judging whether the absolute value of the difference between the predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not;
the well control geological reserve prediction value unit is used 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 reserve to replace the initial value of the well control geological reserve and continuously executing iterative processing.
The embodiment of the present invention further provides a computer device, which includes a memory, a processor, and a computer program stored in the memory and capable of running on the processor, and when the processor executes the computer program, the following steps are implemented:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance simulated 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 production rate at each moment, the well control geological reserve initial value, 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 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
An embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored, where the computer program, when executed by a processor, implements the following steps:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance simulated 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 production rate at each moment, the well control geological reserve initial value, 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 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
The prediction method and the system for the well control geological reserves of the embodiment of the invention execute the following iterative processing: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained based on these drawings without creative efforts.
FIG. 1 is a flow chart of a method of predicting well-controlled geological reserves in one embodiment of the present invention;
FIG. 2 is a flow chart of a method of predicting well controlled geological reserves in another embodiment of the present invention;
FIG. 3 is a flowchart of S105 according to an embodiment of the present invention;
FIG. 4 is a flowchart of S107 according to an embodiment of the present invention;
FIG. 5 is a schematic representation of mean formation pressure and pseudo-time of material balance over production time for a first iteration in an embodiment of the present invention;
FIG. 6 is a diagram illustrating a fitting under a first iteration according to an embodiment of the present invention;
FIG. 7 is a diagram illustrating a comparison of a final iteration to a first iteration in accordance with an embodiment of the present invention;
FIG. 8 is a schematic diagram of well control geological reserves at different iterations in an embodiment of the present invention;
FIG. 9 is a block diagram of a system for predicting well-controlled geological reserves, in accordance with an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
As will be appreciated by one skilled in the art, embodiments of the present invention may be embodied as a system, apparatus, device, method, or computer program product. Accordingly, the present disclosure may be embodied in the form of: entirely hardware, entirely software (including firmware, resident software, micro-code, etc.), or a combination of hardware and software.
In view of the fact that the prior art is difficult to accurately predict well control geological reserves and affects gas well production, the embodiment of the invention provides a prediction method of the well control geological reserves, which is used for accurately predicting the well control geological reserves, does not affect continuous production of gas wells, saves time and cost, further effectively guides the development process of natural gas and improves the natural gas recovery ratio. The present invention will be described in detail below with reference to the accompanying drawings.
FIG. 1 is a flow chart of a method of predicting well controlled geological reserves in an embodiment of the present invention. As shown in fig. 1, the method for predicting well control geological reserves comprises:
s101: acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments.
When only one well exists in the gas reservoir, the data is single-well data. When multiple wells are present in the reservoir, the data is an average of the multiple wells.
The following iterative process is performed:
s102: and 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.
In one embodiment, the gas pseudo-pressure at the initial time can be calculated by the following formula:
Figure BDA0002148503310000061
wherein, m [ p (t)0)]Simulating the pressure of the gas at the initial moment; mu.sg[p(t0)]Gas viscosity at formation pressure at the initial moment, Zg[p(t0)]Is a deviation factor of the formation pressure at the initial moment, p (t)0) Is the formation pressure at the initial moment in megapascals (MPa), xi is the formation pressure, mug(xi) is the gas viscosity at formation pressure xi, Zg(xi) is a deviation factor of formation pressure xi. The gas viscosity was obtained by a room gas high pressure physical property test and has a unit of Pa · s (Pa · s).
S103: and calculating the pseudo-pressure of the gas at the bottom of the well 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.
In one embodiment, the bottom hole gas pseudo pressure may be calculated by the following equation:
Figure BDA0002148503310000062
wherein, m (p)w) For bottom-hole gas pseudo-pressure, pwIn megapascals (MPa) for bottom hole pressure.
S104: and calculating the normalized yield of each moment according to the gas well yield of each moment, the gas pseudo-pressure of the initial moment and the bottom hole gas pseudo-pressure.
In one embodiment, the normalized production at each time can be calculated by the following equation:
Figure BDA0002148503310000071
wherein Q (tj) is the normalized yield at time j, qg(tj) gas well production at time j, mp (t)0)]At an initial momentPseudo pressure of gas, m (p)w) The bottom hole gas pressure is simulated. The unit of gas pseudo pressure is megapascals (MPa), and the unit of gas well yield is cubic meter per day (m)3/d)，
S105: and 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 production at each moment, the well control geological reserve initial value, 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 at each moment.
S106: a plurality of reciprocal coordinate points is generated based on the reciprocal of the normalized yield at each time instant and the material balance pseudo-time at each time instant.
S107: and fitting a plurality of reciprocal coordinate points to obtain the slope of the fitting curve.
S108: and calculating the well control geological reserves 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not.
S110: and when the well control geological reserve is smaller than the preset first precision, finishing iteration and taking the well control geological reserve as a predicted well control geological reserve value.
S111: and when the accuracy is larger than or equal to the preset first accuracy, replacing the initial value of the well control geological reserve by the well control geological reserve, and continuously executing iterative processing.
The execution subject of the prediction method of well-controlled geological reserves shown in fig. 1 may be a computer. As can be seen from the flow shown in fig. 1, the prediction method for well control geological reserves according to the embodiment of the present invention performs the following iterative process: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
FIG. 2 is a flow chart of a method of predicting well controlled geological reserves in another embodiment of the present invention. As shown in fig. 2, before performing S101, the method may further include:
s201: and acquiring the gas compression coefficient, 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 at the initial moment.
S202: and calculating a corrected gas deviation coefficient of the formation pressure at the initial time according to the deviation factor of the formation pressure at the initial time, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor at the standard state pressure, the Langmuir pressure and the formation pressure at the initial time.
In one embodiment, the corrected gas deviation factor for the formation pressure at the initial time may be calculated by the following equation:
Figure BDA0002148503310000081
wherein,
Figure BDA0002148503310000082
correction of gas deviation coefficient, Z, for formation pressure at initial timeg[p(t0)]Is a deviation factor, V, of the formation pressure at the initial momentLLangmuir volume, T formation temperature, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs gas bias at standard state pressureDifference factor, pLLangmuir pressure, p (t)0) The formation pressure at the initial time.
S203: and calculating a corrected gas compressibility at the formation pressure at the initial time according to the gas compressibility at the formation pressure at the initial time, 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 at the formation pressure at the initial time and the formation pressure at the initial time.
In one embodiment, the corrected gas compressibility at the formation pressure at the initial time may be calculated by the following equation:
Figure BDA0002148503310000083
wherein, ct[p(t0)]Corrected gas compressibility at formation pressure at the initial moment, cg[p(t0)]Is the gas compressibility at formation pressure at the initial moment, VLLangmuir volume, T formation temperature, pLIs Langmuir pressure, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs a gas deviation factor, Z, at standard state pressureg[p(t0)]Is a deviation factor of the formation pressure at the initial moment, p (t)0) The formation pressure at the initial time. The compression factor of the gas and the compression factor of the corrected gas are both in units of one part per megapascal (MPa)-1)。
Fig. 3 is a flowchart of S105 according to 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 production at each moment and the initial value of the well control geological reserve.
Wherein calculating the average formation pressure at each time 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 production at each moment and the initial value of the well control geological reserve; and calculating the average formation pressure at each moment according to the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment.
In one embodiment, the quotient of the corrected gas deviation factor for the average formation pressure at each time and the average formation pressure at each time may be calculated by the following equation:
Figure BDA0002148503310000091
wherein,
Figure BDA0002148503310000092
is the quotient of the corrected gas deviation factor, p, of the average formation pressure at time j and the average formation pressure at time javg(tj) Is the average formation pressure at time j,
Figure BDA0002148503310000093
corrected gas deviation coefficient, p (t), for mean formation pressure at time j0) Is the formation pressure at the initial time of day,
Figure BDA0002148503310000094
corrected gas deviation coefficient, G, for formation pressure at initial timep(tj) Cumulative gas production at time j, G0Is the initial value of well control geological reserves and has the unit of cubic meter (m)3). Cumulative gas production is also in units of cubic meters (m)3)。
S302: and obtaining the gas viscosity under the average formation pressure at each moment and the corrected gas compression coefficient under 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 compressibility 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 compressibility at the average formation pressure at each moment.
In one embodiment, the material balance pseudo-time at each time can be calculated by the following formula:
Figure BDA0002148503310000095
wherein, tmba(tj) The time is simulated for the material balance at time j in days (d), μg[p(t0)]Gas viscosity at formation pressure at the initial moment, ct[p(t0)]Corrected gas compressibility at formation pressure at the initial time, qg(tj) Gas well production at time j, qg(τ) gas well production at time τ, μg[pavg(τ)]Is the gas viscosity at the mean formation pressure at time τ ct[pavg(τ)]The corrected gas compressibility at the average formation pressure at time τ and time tj is time j.
Before performing S303, the method 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, Langmuir pressure, a standard state pressure, a formation effective porosity, a standard state temperature and a gas deviation factor under the standard state pressure; a corrected gas compressibility at the average formation pressure at each time is calculated based on the gas compressibility at the average formation pressure at each time, the langmuir volume, the formation temperature, the langmuir pressure, the standard-case pressure, the effective formation porosity, the standard-case temperature, the gas deviation factor at the standard-case pressure, the deviation factor for the average formation pressure at each time, and the average formation pressure at each time.
In one embodiment, the corrected gas compressibility at the average formation pressure at each time may be calculated by the following equation:
Figure BDA0002148503310000101
wherein, ct[pavg(τ)]Corrected gas compressibility at mean formation pressure at time τ, cg[pavg(τ)]Is the gas compressibility at the mean formation pressure at time τLLangmuir volume, T formation temperature, pLIs Langmuir pressure, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs a gas deviation factor, Z, at standard state pressureg[pavg(τ)]Deviation factor, p, of mean formation pressure at time τavg(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 sequencing the multiple reciprocal coordinate points from small to large according to the magnitude of the material balance simulated time.
S402: and using the maximum material balance simulation time as a fixed point, searching a plurality of data points in a preset number forwards, and fitting to obtain the slope of the first initial fitting curve.
The following iterative process is performed:
s403: and continuously searching a plurality of data points of a preset number 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 a second preset precision.
S405: and when the initial fitting curve is smaller than the second preset precision, finishing the iteration and taking the slope of the second initial fitting curve as the slope of the fitting curve.
S406: and when the second preset precision is greater 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 continuously executing iterative processing.
The specific process of the embodiment of the invention is as follows:
1. the formation pressure at the initial time, the deviation factor of the formation pressure at the initial time, the gas compressibility at 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, the gas deviation factor at the standard-state pressure, and the langmuir pressure are obtained.
Wherein, the Langmuir pressure is measured by an indoor desorption adsorption experiment, and the unit is megapascal (MPa); standard state pressure units are megapascals (MPa); the temperature of the formation is 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; langmuir volume was measured by room desorption adsorption experiments and is reported in cubic meters per ton (m)3T); the effective porosity of the stratum is obtained through well logging interpretation.
2. And calculating a corrected gas deviation coefficient of the formation pressure at the initial time according to the deviation factor of the formation pressure at the initial time, the Langmuir volume, the formation temperature, the standard state pressure, the effective porosity of the formation, the standard state temperature, the gas deviation factor at the standard state pressure, the Langmuir pressure and the formation pressure at the initial time.
3. And calculating a corrected gas compressibility at the formation pressure at the initial time according to the gas compressibility at the formation pressure at the initial time, 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 at the formation pressure at the initial time and the formation pressure at the initial time.
4. And acquiring an initial value of well control geological reserves, the gas viscosity at the formation pressure at the initial moment, the bottom hole pressure, the accumulated gas production at each moment and the gas well yield at each moment. In one embodiment, the initial value of the well control geological reserve is 34.26 x 103m3. The following iterative process is performed:
5. and 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. And calculating the pseudo-pressure of the gas at the bottom of the well 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. And calculating the normalized yield of each moment according to the gas well yield of each moment, the gas pseudo-pressure of the initial moment and the bottom hole gas pseudo-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 production at each moment and the initial value of the well control geological reserve.
7. And obtaining the gas viscosity under the average formation pressure at each moment and the corrected gas compression coefficient under the average formation pressure at each moment according to the average formation pressure at each moment. Taking the example of obtaining the corrected gas compressibility at the average formation pressure at each time, the method includes: 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; a corrected gas compressibility at the average formation pressure at each time is calculated based on the gas compressibility at the average formation pressure at each time, the langmuir volume, the formation temperature, the langmuir pressure, the standard-case pressure, the effective formation porosity, the standard-case temperature, the gas deviation factor at the standard-case pressure, the deviation factor for the average formation pressure at each time, and the average formation pressure at each time.
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 compressibility 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 compressibility at the average formation pressure at each moment.
FIG. 5 is a graphical representation of mean formation pressure and pseudo-time of material balance over production time for a first iteration in an embodiment of the present invention. As shown in FIG. 5, the abscissa is time of production in days (day), the left ordinate is average formation pressure in Mega pascals (MPa), and the right ordinate is material balance pseudo-time in days (day).
9. A plurality of reciprocal coordinate points is generated based on the reciprocal of the normalized yield at each time instant and the material balance pseudo-time at each time instant.
10. And sequencing the multiple reciprocal coordinate points from small to large according to the magnitude of the material balance simulated time. And using the maximum material balance simulation time as a fixed point, searching a plurality of data points in a preset number forwards, and fitting to obtain the slope of the first initial fitting curve.
FIG. 6 is a diagram illustrating a fitting under a first iteration in an embodiment of the present invention. As shown in FIG. 6, the abscissa is the simulated time for material balance in days (day) and the ordinate is the reciprocal of the normalized yield in megapascals day/kilosquare (MPa day/10)3m3). The iterative result shows that the gas reservoir enters into a quasi-steady state production stage in about 290 days, data in 291 days to 589 days are selected for linear regression analysis, and the Slope is 4.8667 multiplied by 10-4MPa/103m3Degree of fitting R2Fitted curve of 0.92.
11. The following iterative process is performed: and continuously searching a plurality of data points of a preset number 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 or not; and when the second preset precision is smaller than the second preset precision, finishing the iteration, taking the slope of the second initial fitting curve as the slope of the fitting curve, otherwise, taking the slope of the second initial fitting curve as the slope of the first initial fitting curve, and continuously executing the iteration processing.
FIG. 7 is a diagram illustrating a comparison of the final iteration and the initial iteration in accordance with an embodiment of the present invention. As shown in FIG. 7, the abscissa is the simulated time for material balance in days (day) and the ordinate is the reciprocal of the normalized yield in megapascals day/kilosquare (MPa day/10)3m3)。
12. And calculating the well control geological reserves 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not. And when the well control geological reserve is smaller than the preset first precision, finishing iteration and taking the well control geological reserve as a predicted well control geological reserve value. And when the accuracy is larger than or equal to the preset first accuracy, replacing the initial value of the well control geological reserve with the well control geological reserve, continuously executing iterative processing, and returning to the step 5.
FIG. 8 is a schematic diagram of well control geological reserves at different iterations in an embodiment of the present invention. As shown in fig. 8, the abscissa is the number of iterations and the ordinate is the well control geological reserve in units of thousand squares. At iteration 9, the final accurate well control geological reserve obtained is about 90.11 × 103m3。
In summary, the prediction method of well control geological reserves of the embodiment of the present invention performs the following iterative processing: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
Based on the same invention concept, the embodiment of the invention also provides a well control geological reserve prediction system, and as the problem solving principle of the system is similar to the well control geological reserve prediction method, the implementation of the system can refer to the implementation of the method, and repeated parts are not described again.
FIG. 9 is a block diagram of a system for predicting well-controlled geological reserves, in accordance with an embodiment of the present invention. As shown in fig. 9, a system for predicting well-controlled geological reserves comprises:
the system comprises a first acquisition module, a second acquisition module and a third acquisition module, wherein the first acquisition module is used for acquiring a well control geological reserve initial value, gas viscosity at the 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 at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
an iteration module, the iteration module comprising:
the gas pseudo-pressure unit is used for 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;
the bottom-hole gas pseudo-pressure unit is used for calculating bottom-hole gas pseudo-pressure according to gas viscosity under the formation pressure at the moment, deviation factors of the formation pressure at the initial moment, the formation pressure at the initial moment and the bottom pressure;
the normalized yield unit is used for calculating the normalized yield of each moment according to the gas well yield of each moment, the gas pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
the material balance simulated time unit is used for calculating the material balance simulated 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 production rate at each moment, the initial value of well control geological reserve, 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 at each moment;
a coordinate point unit for generating a plurality of reciprocal coordinate points according to a reciprocal of the normalized yield at each time and a material balance pseudo-time at each time;
the slope unit is used for fitting the reciprocal coordinate points to obtain the slope of a fitting curve;
the well control geological reserve unit is used for calculating the well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
the judging unit is used for judging whether the absolute value of the difference between the predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not;
the well control geological reserve prediction value unit is used 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 reserve to replace the initial value of the well control geological reserve and continuously executing iterative processing.
In one embodiment, fitting a plurality of reciprocal coordinate points to obtain a slope of a fitted straight line comprises:
sequencing the multiple reciprocal coordinate points from small to large according to the magnitude of the material balance simulation time;
using the maximum material balance simulation time as a fixed point, searching a plurality of data points in a preset number forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative process is performed:
continuously searching a plurality of data points in a preset number 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 or not; and when the second preset precision is smaller than the second preset precision, finishing the iteration, taking the slope of the second initial fitting curve as the slope of the fitting curve, otherwise, taking the slope of the second initial fitting curve as the slope of the first initial fitting curve, and continuously executing the iteration processing.
In one embodiment, the method further comprises the following steps:
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 under the formation 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;
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, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the formation effective 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.
In one embodiment, 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 production at each moment and the initial value of the well control geological reserve;
according to the average formation pressure at each moment, 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;
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 compressibility 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 compressibility at the average formation pressure at each moment.
In one embodiment, the method further comprises the following steps:
a third obtaining module, configured to obtain a gas compression coefficient at an average formation pressure at each time, a deviation factor of the average formation pressure at each time, 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 at the standard-state pressure;
and the second corrected gas compressibility module is used for calculating the corrected gas compressibility at the average formation pressure at each moment according to the gas compressibility at the average formation pressure at each moment, the Langmuir volume, the formation temperature, the Langmuir pressure, the standard state pressure, the formation effective porosity, the standard state temperature, the gas deviation factor at the standard state pressure, the deviation factor at the average formation pressure at each moment and the average formation pressure at each moment.
In one embodiment, the 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 production at each moment and the initial value of the well control geological reserve;
and calculating the average formation pressure at each moment according to the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment.
In summary, the prediction system of well control geological reserves of the embodiment of the present invention performs the following iterative process: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
The embodiment of the present invention further provides a computer device, which includes a memory, a processor, and a computer program stored in the memory and capable of running on the processor, and when the processor executes the computer program, the following steps are implemented:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance simulated 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 production rate at each moment, the well control geological reserve initial value, 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 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
To sum up, the computer device of the embodiment of the present invention performs the following iterative process: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
An embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored, where the computer program, when executed by a processor, implements the following steps:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance simulated 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 production rate at each moment, the well control geological reserve initial value, 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 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 simulation 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
To sum up, the computer-readable storage medium of an embodiment of the present invention performs the following iterative process: calculating the normalized yield of 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 of each moment and the material balance simulation time of each moment, then fitting the reciprocal coordinate points to obtain the slope of a fitting curve, calculating the well control geological reserve according to the slope, and finally judging whether the absolute value of the difference between the predicted value of the well control geological reserve and the initial value of the well control geological reserve is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing. The method can accurately predict the well control geological reserves, does not influence the continuous production of the gas well, saves time and cost, further effectively guides the development process of the natural gas, and improves the natural gas recovery ratio.
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.

Claims (20)

1. A method of predicting well-controlled geological reserves, comprising:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance quasi-time of each moment according to the formation pressure of the initial moment, the corrected gas deviation coefficient of the formation pressure of the initial moment, the accumulated gas production rate of each moment, the initial value of the well control geological reserve, the gas viscosity of the formation pressure of the initial moment, the corrected gas compression coefficient of the formation pressure of 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 simulation time at each moment;
fitting the 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
2. The method of predicting a well-controlled geological reserve of claim 1, wherein fitting the plurality of reciprocal coordinate points to obtain a slope of a fitted straight line comprises:
sequencing the reciprocal coordinate points from small to large according to the magnitude of the substance balance simulated time;
using the maximum material balance simulation time as a fixed point, searching a plurality of data points in a preset number forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative process is performed:
continuously searching a plurality of data points in a preset number 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 or not; and when the second preset precision is smaller than the second preset precision, finishing iteration, taking the slope of the second initial fitting curve as the slope of the fitting curve, and otherwise, taking the slope of the second initial fitting curve as the slope of the first initial fitting curve, and continuously executing iteration processing.
3. The method of predicting a well-controlled geological reserve of claim 1, further comprising:
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 under the formation pressure at an initial moment;
calculating a corrected gas deviation factor for the formation pressure at the initial time based on the deviation factor for 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, the gas deviation factor for the standard-state pressure, the langmuir pressure, and the formation pressure at the initial time;
and calculating a corrected gas compressibility at the formation pressure at the initial time based on the gas compressibility at the formation pressure at the initial time, the langmuir volume, the formation temperature, the langmuir pressure, the standard-state pressure, the formation effective porosity, the standard-state temperature, the gas deviation factor at the standard-state pressure, the deviation factor at the formation pressure at the initial time, and the formation pressure at the initial time.
4. The method of predicting a well-controlled geological reserve of claim 1, wherein calculating a material balance pseudo-time for each time instant 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 production at each moment and the initial value of the well control geological reserve;
according to the average formation pressure at each moment, 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;
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 compressibility 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 compressibility at the average formation pressure at each moment.
5. The method of predicting a well-controlled geological reservoir 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, Langmuir pressure, a standard state pressure, a formation effective porosity, a standard state temperature and a gas deviation factor under the standard state pressure;
calculating a corrected gas compressibility at the average formation pressure for each time based on the gas compressibility at the average formation pressure for each time, the langmuir volume, the formation temperature, the langmuir pressure, the standard-case pressure, the formation effective porosity, the standard-case temperature, the gas deviation factor at the standard-case pressure, the deviation factor for the average formation pressure for each time, and the average formation pressure for each time.
6. The method of predicting a well-controlled geological reservoir of claim 4, wherein calculating the average formation pressure at each time 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 production at each moment and the initial value of the well control geological reserve;
and calculating the average formation pressure at each moment according to the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment.
7. The method of predicting a well-controlled geological reservoir of claim 1,
calculating the gas pseudo-pressure at the initial moment by the following formula:
Figure FDA0002148503300000031
wherein, m [ p (t)0)]For the initial time of the gas pseudo-pressure, mug[p(t0)]Gas viscosity at formation pressure at the initial moment, Zg[p(t0)]Is a deviation factor of the formation pressure at the initial moment, p (t)0) Is the formation pressure at the initial moment, xi is the formation pressure, mug(xi) is the gas viscosity at formation pressure xi, Zg(xi) is a deviation factor of formation pressure xi;
calculating the bottom hole gas pseudo pressure by the following formula:
Figure FDA0002148503300000032
wherein, m (p)w) For bottom-hole gas pseudo-pressure, pwIs the bottom hole pressure.
8. A method of predicting well-controlled geological reserves according to claim 1, characterized by calculating the normalized production at each moment in time by the formula:
Figure FDA0002148503300000033
wherein Q (tj) is the normalized yield at time j, qg(tj) gas well production at time j, mp (t)0)]Pseudo pressure of gas at the initial moment, m (p)w) The bottom hole gas pressure is simulated.
9. A method of predicting a well-controlled geological reservoir as defined in claim 3, wherein the corrected gas deviation factor for formation pressure at said initial time is calculated by the formula:
Figure FDA0002148503300000041
wherein,
Figure FDA0002148503300000042
correction of gas deviation coefficient, Z, for formation pressure at initial timeg[p(t0)]Is a deviation factor, V, of the formation pressure at the initial momentLLangmuir volume, T formation temperature, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs a gas deviation factor at standard state pressure, pLLangmuir pressure, p (t)0) Is the formation pressure at the initial time;
calculating a corrected gas compressibility at the formation pressure at the initial time by the following equation:
Figure FDA0002148503300000043
wherein, ct[p(t0)]Corrected gas compressibility at formation pressure at the initial moment, cg[p(t0)]Is the gas compressibility at formation pressure at the initial moment, VLLangmuir volume, T formation temperature, pLIs Langmuir pressure, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs a gas deviation factor, Z, at standard state pressureg[p(t0)]Is a deviation factor of the formation pressure at the initial moment, p (t)0) The formation pressure at the initial time.
10. A method of predicting a well-controlled geological reservoir as defined in claim 4, wherein the pseudo-time to material balance at each time is calculated by the formula:
Figure FDA0002148503300000044
wherein, tmba(tj) For the material equilibrium at time jg[p(t0)]Gas viscosity at formation pressure at the initial moment, ct[p(t0)]Corrected gas compressibility at formation pressure at the initial time, qg(tj) Gas well production at time j, qg(τ) gas well production at time τ, μg[pavg(τ)]Is the gas viscosity at the mean formation pressure at time τ ct[pavg(τ)]The corrected gas compressibility at the average formation pressure at time τ and time tj is time j.
11. The method of predicting a well-controlled geological reservoir of claim 5,
the corrected gas compressibility at the average formation pressure at each time is calculated by the following equation:
Figure FDA0002148503300000045
wherein, ct[pavg(τ)]Mean formation pressure at time τCorrected gas compression factor of cg[pavg(τ)]Is the gas compressibility at the mean formation pressure at time τLLangmuir volume, T formation temperature, pLIs Langmuir pressure, pscIs the standard state pressure, phi is the effective formation porosity, TscIs a standard state temperature, ZscIs a gas deviation factor, Z, at standard state pressureg[pavg(τ)]Deviation factor, p, of mean formation pressure at time τavg(τ) is the average formation pressure at time τ.
12. A method of predicting a well controlled geological reservoir as defined in claim 6, wherein the quotient of the mean formation pressure at each time and the corrected gas deviation factor for the mean formation pressure at each time is calculated by the formula:
Figure FDA0002148503300000051
wherein,
Figure FDA0002148503300000052
is the quotient of the corrected gas deviation factor, p, of the average formation pressure at time j and the average formation pressure at time javg(tj) Is the average formation pressure at time j,
Figure FDA0002148503300000053
corrected gas deviation coefficient, p (t), for mean formation pressure at time j0) Is the formation pressure at the initial time of day,
Figure FDA0002148503300000054
corrected gas deviation coefficient, G, for formation pressure at initial timep(tj) Cumulative gas production at time j, G0And the initial value of the well control geological reserves is obtained.
13. A system for predicting well-controlled geological reserves, comprising:
the system comprises a first acquisition module, a second acquisition module and a third acquisition module, wherein the first acquisition module is used for acquiring a well control geological reserve initial value, gas viscosity at the 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 at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
an iteration module, the iteration module comprising:
the gas pseudo-pressure unit is used for 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;
the bottom-hole gas pseudo-pressure unit is used for calculating 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;
the normalized yield unit is used for calculating the normalized yield of each moment according to the gas well yield of each moment, the gas pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
the material balance simulated time unit is used for calculating material balance simulated 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 production rate at each moment, the initial well control geological reserve value, 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 a reciprocal of the normalized yield at each time and a material balance pseudo-time at each time;
the slope unit is used for fitting the reciprocal coordinate points to obtain the slope of a fitting curve;
the well control geological reserve unit is used for calculating the well control geological reserve according to the slope and the corrected gas compression coefficient under the formation pressure at the initial moment;
the judging unit is used for judging whether the absolute value of the difference between the predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not;
the well control geological reserve prediction value unit is used for taking the well control geological reserve as a well control geological reserve prediction value;
and the replacing unit is used for replacing the well control geological reserve with the well control geological reserve initial value and continuously executing iterative processing.
14. The system of claim 13, wherein fitting the plurality of reciprocal coordinate points to obtain a slope of a fitted straight line comprises:
sequencing the reciprocal coordinate points from small to large according to the magnitude of the substance balance simulated time;
using the maximum material balance simulation time as a fixed point, searching a plurality of data points in a preset number forwards and fitting to obtain the slope of a first initial fitting curve;
the following iterative process is performed:
continuously searching a plurality of data points in a preset number 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 or not; and when the second preset precision is smaller than the second preset precision, finishing iteration, taking the slope of the second initial fitting curve as the slope of the fitting curve, and otherwise, taking the slope of the second initial fitting curve as the slope of the first initial fitting curve, and continuously executing iteration processing.
15. The system for predicting well-controlled geological reserves 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 under the formation pressure at the initial moment;
a corrected gas deviation factor module to calculate a corrected gas deviation factor for the formation pressure at the initial time based on the deviation factor for the formation pressure at the initial time, the langmuir volume, the formation temperature, the standard-case pressure, the effective formation porosity, the standard-case temperature, the gas deviation factor at the standard-case pressure, the langmuir pressure, and the formation pressure at the initial time;
a first modified gas compressibility module configured to calculate a modified gas compressibility at the formation pressure at the initial time based on the gas compressibility at the formation pressure at the initial time, 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 at the formation pressure at the initial time, and the formation pressure at the initial time.
16. The system of claim 13, wherein 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 production at each moment and the initial value of the well control geological reserve;
according to the average formation pressure at each moment, 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;
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 compressibility 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 compressibility at the average formation pressure at each moment.
17. The system for predicting well-controlled geological reserves of claim 16, further comprising:
a third obtaining module, configured to obtain a gas compression coefficient at an average formation pressure at each time, a deviation factor of the average formation pressure at each time, 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 at the standard-state pressure;
a second modified gas compressibility module to calculate a modified gas compressibility at the average formation pressure for each time based on the gas compressibility at the average formation pressure for each time, 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 for the average formation pressure for each time, and the average formation pressure for each time.
18. The system of claim 16, wherein the 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 production at each moment and the initial value of the well control geological reserve;
and calculating the average formation pressure at each moment according to the quotient of the average formation pressure at each moment and the corrected gas deviation coefficient of the average formation pressure at each moment.
19. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor when executing the computer program implements the steps of:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance quasi-time of each moment according to the formation pressure of the initial moment, the corrected gas deviation coefficient of the formation pressure of the initial moment, the accumulated gas production rate of each moment, the initial value of the well control geological reserve, the gas viscosity of the formation pressure of the initial moment, the corrected gas compression coefficient of the formation pressure of 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 simulation time at each moment;
fitting the 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
20. A computer-readable storage medium, on which a computer program is stored, which, when being executed by a processor, carries out the steps of:
acquiring a well control geological reserve initial value, gas viscosity at the 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 production at each moment and a corrected gas compression coefficient at the formation pressure at the initial moment; the number of the moments is multiple, and the moments comprise initial moments;
the following iterative process 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 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 pseudo-pressure of the initial moment and the bottom gas pseudo-pressure;
calculating the material balance quasi-time of each moment according to the formation pressure of the initial moment, the corrected gas deviation coefficient of the formation pressure of the initial moment, the accumulated gas production rate of each moment, the initial value of the well control geological reserve, the gas viscosity of the formation pressure of the initial moment, the corrected gas compression coefficient of the formation pressure of 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 simulation time at each moment;
fitting the 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 predicted well control geological reserve value and the initial well control geological reserve value is smaller than a preset first precision or not; and when the well control geological reserve is smaller than the preset first precision, finishing iteration, taking the well control geological reserve as a predicted well control geological reserve value, or replacing the initial well control geological reserve value with the well control geological reserve value, and continuously executing iteration processing.
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CN106484933A (en) * 2015-08-31 2017-03-08 中国石油化工股份有限公司 A kind of method and system for determining shale gas well well control dynamic holdup
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