Method and system for determining condensate content in a gas condensate reservoir

Abstract

The application provides a method and system for determining condensate oil content in a condensate gas reservoir. The method for determining condensate oil content in the condensate gas reservoir comprises the following steps: determining condensate oil reserves according to ground cumulative condensate oil collection amount, condensate oil original geological reserves and formation released condensate oil quality; determining condensate gas volume coefficient, condensate gas reservoir pore volume, condensate gas reservoir saturation parameter and condensate gas reservoir water vapor content; determining condensate oil content according to condensate oil reserves, condensate gas volume coefficient, condensate gas reservoir pore volume, condensate gas reservoir saturation parameter and condensate gas reservoir water vapor content. The application can conveniently and quickly determine condensate oil content in the condensate gas reservoir, and provides technical support for development of the condensate gas reservoir.

Description

Technical Field

[0001] This invention relates to the field of petroleum extraction technology, and more specifically, to a method and system for determining the condensate oil content in condensate gas reservoirs. Background Technology

[0002] During the circulating gas injection development of condensate gas reservoirs with edge and bottom water, as formation pressure decreases, reverse condensation occurs within the reservoir. Primary formation water gradually evaporates and mixes with the condensate gas, significantly altering the compressibility of the reservoir rocks. Simultaneously, edge and bottom water intrudes into the gas reservoir due to the pressure difference. Accurately predicting the condensate oil content of condensate gas reservoirs is crucial for assessing reservoir reserves, analyzing production dynamics, and developing adjustment plans. Currently, the main method for obtaining condensate oil content in condensate gas reservoirs is laboratory measurement, which requires sampling of formation fluids and involves a lengthy research period. Summary of the Invention

[0003] The main objective of this invention is to provide a method and system for determining the condensate oil content in condensate gas reservoirs, so as to conveniently and quickly determine the condensate oil content in condensate gas reservoirs and provide technical support for the development of condensate gas reservoirs.

[0004] To achieve the above objectives, embodiments of the present invention provide a method for determining the condensate oil content in a condensate gas reservoir, comprising:

[0005] The condensate reserves are determined based on the cumulative surface condensate oil collection, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0006] Determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameters of condensate gas reservoir, and the water vapor content of condensate gas reservoir;

[0007] The condensate oil content is determined based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0008] This invention also provides a system for determining the condensate oil content in condensate gas reservoirs, comprising:

[0009] Condensate oil reserve unit is used to determine condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0010] The parameter determination unit is used to determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameter of condensate gas reservoir, and the water vapor content of condensate gas reservoir.

[0011] The condensate oil content determination unit is used to determine the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0012] This invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and running on the processor. When the processor executes the computer program, it implements the steps of the method for determining the condensate oil content in the condensate gas reservoir.

[0013] This invention also provides a computer-readable storage medium storing a computer program thereon, which, when executed by a processor, implements the steps of the method for determining the condensate oil content in the condensate gas reservoir.

[0014] The method and system for determining the condensate oil content in condensate gas reservoirs according to embodiments of the present invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, the condensate oil content is determined based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This method can conveniently and quickly determine the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs. Attached Figure Description

[0015] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0016] Figure 1 This is a flowchart of the method for determining the condensate oil content in condensate gas reservoirs in this embodiment of the invention;

[0017] Figure 2 This is a schematic diagram of the changes in cumulative water infiltration and formation pressure over development time in an embodiment of the present invention;

[0018] Figure 3 This is a schematic diagram of the condensate oil content variation curve of the residual condensate gas in the formation in an embodiment of the present invention;

[0019] Figure 4 This is a structural block diagram of the system for determining the condensate oil content in condensate gas reservoirs in an embodiment of the present invention;

[0020] Figure 5 This is a structural block diagram of the computer device in an embodiment of the present invention. Detailed Implementation

[0021] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0022] Those skilled in the art will recognize that embodiments of the present invention can be implemented as a system, apparatus, device, method, or computer program product. Therefore, this disclosure can be specifically implemented in the following forms: entirely hardware, entirely software (including firmware, resident software, microcode, etc.), or a combination of hardware and software.

[0023] Given that current methods for obtaining condensate oil content in condensate gas reservoirs mainly rely on laboratory measurements, which involve lengthy research cycles, this invention provides a method for determining condensate oil content in condensate gas reservoirs. Taking into account factors such as gas reverse condensation, primary water evaporation, reservoir rock expansion, and edge / bottom water intrusion, a calculation model for condensate oil content in condensate gas reservoirs is established based on the principle of material balance. Combined with formation fluid properties and production dynamics data, this model can conveniently and quickly calculate the condensate oil content in residual condensate gas under different formation pressures, providing technical support for the development of condensate gas reservoirs. The invention will be described in detail below with reference to the accompanying drawings.

[0024] Figure 1 This is a flowchart illustrating the method for determining the condensate oil content in a condensate gas reservoir according to an embodiment of the present invention. Figure 1 As shown, the methods for determining the condensate oil content in condensate gas reservoirs include:

[0025] S101: Determine the condensate reserves based on the cumulative surface condensate oil collection, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0026] In practical implementation, based on the material balance principle of condensate oil, we have:

[0027] N o =N oL +N oG +N op ;

[0028] Therefore, we can conclude that:

[0029] N oG =N oL +N op -N o ;

[0030] Where, N oG N represents the condensate oil reserves (in the remaining condensate gas of the formation), in tons (t); oLThe mass of condensate oil precipitated from the formation is expressed in tons (t); N op The cumulative condensate oil collected at the surface is expressed in tons (t); N o The original geological reserves of condensate oil are expressed in tons (t).

[0031] In one embodiment, it is assumed that edge and bottom water exists in the condensate gas reservoir, the adsorption of condensate gas on the formation rocks is ignored, the original formation pressure is higher than the dew point pressure of the condensate gas, and under the initial conditions, only condensate gas and bound water exist in the gas reservoir. The formation pressure is instantaneously balanced, and the gas-water interface advances uniformly. Under these conditions, the original geological reserves of condensate oil can be determined by the following formula:

[0032] N o =GC oi ×10 -6 ;

[0033] Where, N o G represents the original geological reserves of condensate oil, in tons (t); G represents the original geological reserves of condensate gas reservoir, in cubic meters (m³). 3 );C oi The content of condensate oil in the gas under the original conditions, in g / m³ 3 .

[0034] In one embodiment, the method further includes: obtaining the condensate surface density and condensate volume factor; and determining the mass of condensate oil precipitated from the formation based on the pore volume of the condensate gas reservoir, the condensate saturation, the condensate surface density, and the condensate volume factor.

[0035] For example, when the formation pressure drops to p, the mass of condensate oil precipitated in the formation is:

[0036]

[0037] Where, N oL The mass of condensate oil precipitated from the formation is expressed in tons (t); V G This refers to the pore volume of a condensate gas reservoir under formation pressure p, in meters (m³). 3 S oc The saturation of condensate oil in the formation can be obtained through indoor isochoric depletion experiments or gas-liquid equilibrium calculations; ρ oc This refers to the surface density of condensate oil, in t / m³. 3 B o This is the volume factor of condensate oil, in cubic meters. 3 / m 3 .

[0038] S102: Determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameters of condensate gas reservoir, and the water vapor content of condensate gas reservoir.

[0039] Among them, the saturation parameter of condensate gas reservoir includes the water saturation increment ΔS (caused by external water intrusion within the gas reservoir). w Condensate oil saturation S oc and (within condensate gas reservoirs) bound water saturation S wc .

[0040] In one embodiment, determining the water saturation increment includes:

[0041] Obtain the cumulative water leaching volume, cumulative water production, initial condensate gas reservoir pore volume, and formation water volume factor; determine the water saturation increment based on the cumulative water leaching volume, cumulative water production, formation water volume factor, and initial condensate gas reservoir pore volume.

[0042] During the development of condensate gas reservoirs, a decrease in formation pressure can lead to the intrusion of edge and bottom water into the reservoir. This increase in water saturation ΔS caused by external water intrusion is significant. w It can be represented as:

[0043]

[0044] Where, ΔS w W represents the increase in water saturation. e Cumulative water immersion volume, in meters (m). 3 W can be obtained using the Fetkovitch method. p Cumulative water production, in m³ 3 B w V is the volume factor of formation water under formation pressure p; Gi The initial condensate gas reservoir pore volume is p, which is the initial formation pressure. i The pore volume of the condensate gas reservoir is given in m³. 3 .

[0045] Figure 2 This is a schematic diagram illustrating the changes in cumulative water immersion and formation pressure over development time in an embodiment of the present invention. Figure 2 As shown, Figure 2 The horizontal axis represents development time, in years; Figure 2 The vertical axis represents cumulative water infiltration and formation pressure; the unit of cumulative water infiltration is 10. 2 m 3 The unit of formation pressure is MPa. Figure 2 As can be seen, as the formation pressure decreases, the cumulative water leaching increases, leading to a continuous increase in water saturation within the condensate gas reservoir.

[0046] In one embodiment, determining the volume factor of the condensate gas includes:

[0047] Obtain the current gas deviation factor, current formation temperature, and current formation pressure; determine the condensate volume factor based on the current gas deviation factor, current formation temperature, and current formation pressure.

[0048] In practice, the volume factor of the condensate gas can be determined using the following formula:

[0049]

[0050] Among them, B g p is the volume coefficient of the condensate gas. sc Pressure under standard conditions, unit is MPa; T sc Temperature under standard conditions, in Kelvin (K); Z sc Z is the deviation factor of the gas phase under standard conditions; T is the current gas deviation factor; T is the current formation temperature (current reservoir temperature) in K; p is the current formation pressure in MPa.

[0051] In one embodiment, the gas deviation factor can be solved using relevant empirical formulas of the DPR method:

[0052]

[0053]

[0054] p pr =p / p pc ;

[0055] T pr =T / T pc ;

[0056] p pc =[46.7-32.1(γ)] g -0.5)]×0.09869;

[0057] T pc =171(γ) g -0.5)+182;

[0058] Where, ρ R p represents the relative density of the gas. pr To simulate the pressure; T pr For comparison temperature; p pc The pressure is the pseudocritical pressure, in MPa; T pc The quasi-critical temperature is expressed in Kelvin; γ g ρ represents the relative density of the gas.

[0059] When using the above formula to determine the gas deviation factor, since ρ R It is also a function of Z, so an iterative calculation method is needed to solve it.

[0060] In one embodiment, determining the pore volume of a condensate gas reservoir includes:

[0061] Obtain the original geological reserves, cumulative natural gas volume, and cumulative injected gas volume of the condensate gas reservoir; determine the pore volume of the condensate gas reservoir based on the original geological reserves, cumulative natural gas volume, cumulative injected gas volume, condensate gas volume coefficient, condensate gas reservoir saturation parameters, and condensate gas reservoir water vapor content.

[0062] During the development of condensate gas reservoirs through circulating gas injection, condensate oil will continuously precipitate when the formation pressure falls below the dew point pressure of the condensate gas. Simultaneously, as the formation pressure decreases, the primary formation water also begins to evaporate, and dissolved gases in the formation water will escape. Considering the influence of these factors, the pore volume V of the condensate gas reservoir when the formation pressure drops to p is... G for:

[0063]

[0064] Among them, G p The cumulative extracted natural gas volume (cumulative natural gas volume), in m³. 3 G i The cumulative injected gas volume is expressed in m³. 3 B g y is the volume coefficient of condensate gas; w To determine the water vapor content in condensate gas reservoirs, the relationship between water vapor content and pressure can be established through formation condensate gas saturation water content experiments. A fitting formula for water vapor content can then be established using a multiple regression method to obtain the y-value. w S oc ΔS represents the saturation of condensate oil in the formation. w S represents the increase in water saturation within the gas reservoir caused by external water intrusion. wc This refers to the bound water saturation (within a condensate gas reservoir).

[0065] S103: Determine the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0066] In practice, the condensate oil reserves in the remaining condensate gas in the formation can be expressed by the following formula:

[0067]

[0068] Therefore, the condensate oil content C can be obtained using the following formula. o :

[0069]

[0070] Among them, C o The condensate oil content (of the remaining condensate gas in the formation) is expressed in g / m³. 3 .

[0071] In one embodiment, the condensate oil reserves N will be determined. oG Formula for determining the original geological reserves N of condensate oil o Formulas for determining the mass N of condensate oil precipitated from formations oL Substituting the formula into the mass balance equation, we get:

[0072]

[0073] Therefore, the condensate oil content C o This can be further expressed as:

[0074]

[0075] The pore volume V of the condensate gas reservoir will be determined. G The formula and determination of the volume factor B of condensate gas g Substituting the formula into the above condensate oil content C o From the expression, we can further obtain:

[0076]

[0077] Figure 1 The method for determining the condensate oil content in the condensate gas reservoir shown can be implemented by a computer. Figure 1 As shown in the flowchart, the method for determining the condensate oil content in condensate gas reservoirs in this embodiment of the invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, it determines the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This method can conveniently and quickly determine the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs.

[0078] The specific process of this invention embodiment is as follows:

[0079] 1. Obtain the current gas deviation factor, current formation temperature, and current formation pressure; determine the condensate volume factor based on the current gas deviation factor, current formation temperature, and current formation pressure.

[0080] 2. Obtain the cumulative water leaching volume, cumulative water production, initial condensate gas reservoir pore volume, and formation water volume factor; determine the water saturation increment based on the cumulative water leaching volume, cumulative water production, formation water volume factor, and initial condensate gas reservoir pore volume.

[0081] 3. Determine the water vapor content, condensate oil saturation, and bound water saturation of the condensate gas reservoir.

[0082] 4. Obtain the original geological reserves, cumulative natural gas volume, and cumulative injected gas volume of the condensate gas reservoir; determine the pore volume of the condensate gas reservoir based on the original geological reserves, cumulative natural gas volume, cumulative injected gas volume, condensate gas volume coefficient, water saturation increment, condensate oil saturation, bound water saturation, and water vapor content of the condensate gas reservoir.

[0083] 5. Obtain the surface density and volume factor of condensate oil; determine the mass of condensate oil precipitated from the formation based on the pore volume of the condensate gas reservoir, condensate oil saturation, surface density of condensate oil, and volume factor of condensate oil.

[0084] 6. Determine the condensate oil reserves based on the cumulative surface condensate oil collection, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0085] 7. Determine the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the increase in water saturation, the condensate oil saturation, the bound water saturation, and the water vapor content of the condensate gas reservoir.

[0086] One specific embodiment of the present invention is as follows:

[0087] The original geological reserves G of a certain edge-water condensate gas reservoir are 14.6 × 10⁻⁶. 8 m 3 The central burial depth is 4280m, and the initial formation pressure is p. i The initial formation pressure is 43.98 MPa, the formation temperature T is 142℃, the condensate gas dew point pressure is 38 MPa, the initial gas deviation factor is 1.162, the water vapor content per unit volume of gas phase under the initial formation pressure is 0.168%, and the bound water saturation S in the condensate gas reservoir is... wc The coefficient of performance is 0.12, and the compressibility coefficient of the reservoir rock is 3.32 × 10⁻⁶. -4 MPa -1 Table 1 shows the production dynamics data and fluid properties of the condensate gas reservoir. As shown in Table 1, the water vapor content (y) is... w It is obtained through interpolation of indoor experimental data, while the current gas deviation factor Z is solved using relevant empirical formulas of the DPR method, and the formation condensate oil saturation S oc It was obtained based on an indoor isovolumetric decay experiment.

[0088] Table 1

[0089]

[0090]

[0091] Figure 3This is a schematic diagram of the condensate oil content variation curve of residual condensate gas in the formation in an embodiment of the present invention. Figure 3 As shown, Figure 3 The horizontal axis represents formation pressure in MPa; the vertical axis represents condensate oil content in g / m³. 3 The condensate oil content in the remaining condensate gas of a condensate gas reservoir under different formation pressure conditions can be calculated using the formula for determining condensate oil content. Figure 3 It can be seen that when the formation pressure is higher than the dew point pressure (38 MPa), the condensate oil content of the remaining condensate gas in the formation remains unchanged (400 g / m³). 3 When the formation pressure is lower than the dew point pressure, the condensate oil content of the remaining condensate gas in the formation decreases as the formation pressure decreases. This is mainly due to the precipitation of condensate oil in the formation. This precipitated condensate oil adheres to the surface of the formation rocks. Because the condensate oil has a low saturation level, it fails to reach the critical flow saturation, and therefore a large amount of condensate oil is lost in the formation and cannot be extracted to the surface.

[0092] In summary, the method for determining the condensate oil content in condensate gas reservoirs according to the embodiments of the present invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, it determines the condensate oil content based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This method can conveniently and quickly determine the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs.

[0093] Based on the same inventive concept, this invention also provides a system for determining the condensate oil content in condensate gas reservoirs. Since the principle of this system in solving the problem is similar to the method for determining the condensate oil content in condensate gas reservoirs, the implementation of this system can refer to the implementation of the method, and the repeated parts will not be described again.

[0094] Figure 4 This is a structural block diagram of the system for determining the condensate oil content in a condensate gas reservoir, as described in an embodiment of the present invention. Figure 4 As shown, the system for determining the condensate oil content in condensate gas reservoirs includes:

[0095] Condensate oil reserve unit is used to determine condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0096] The parameter determination unit is used to determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameter of condensate gas reservoir, and the water vapor content of condensate gas reservoir.

[0097] The condensate oil content determination unit is used to determine the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0098] In one embodiment, the parameter determination unit is specifically used for:

[0099] Obtain the current gas deviation factor, current formation temperature, and current formation pressure;

[0100] The volume factor of condensate gas is determined based on the current gas deviation factor, current formation temperature, and current formation pressure.

[0101] In one embodiment, the parameter determination unit is specifically used for:

[0102] To obtain the original geological reserves, cumulative natural gas volume, and cumulative injected gas volume of condensate gas reservoirs;

[0103] The pore volume of a condensate gas reservoir is determined based on its original geological reserves, cumulative natural gas volume, cumulative injected gas volume, condensate gas volume factor, condensate gas reservoir saturation parameters, and condensate gas reservoir water vapor content.

[0104] In one embodiment, the saturation parameter of the condensate gas reservoir includes the water saturation increment;

[0105] The parameter determination unit is specifically used for:

[0106] Obtain the cumulative water leaching volume, cumulative water production, initial condensate gas reservoir pore volume, and formation water volume factor;

[0107] The increment of water saturation is determined based on the cumulative water leaching, cumulative water production, formation water volume factor, and initial condensate gas reservoir pore volume.

[0108] In one embodiment, the condensate gas reservoir saturation parameter also includes condensate oil saturation;

[0109] The system for determining condensate oil content in condensate gas reservoirs also includes:

[0110] The acquisition unit is used to acquire the surface density and volume factor of condensate oil.

[0111] The condensate oil quality determination unit is used to determine the quality of condensate oil precipitated from the formation based on the pore volume of the condensate gas reservoir, the condensate oil saturation, the condensate oil surface density, and the condensate oil volume coefficient.

[0112] In summary, the condensate oil content determination system in condensate gas reservoirs according to this invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, it determines the condensate oil content based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This system can conveniently and quickly determine the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs.

[0113] This invention also provides a specific implementation of a computer device capable of performing all the steps in the method for determining the condensate oil content in condensate gas reservoirs described in the above embodiments. Figure 5 This is a structural block diagram of the computer device in an embodiment of the present invention, see below. Figure 5 The computer equipment specifically includes the following:

[0114] Processor 501 and memory 502.

[0115] The processor 501 is used to call the computer program in the memory 502. When the processor executes the computer program, it implements all the steps in the method for determining the condensate oil content in the condensate gas reservoir in the above embodiments. For example, when the processor executes the computer program, it implements the following steps:

[0116] The condensate reserves are determined based on the cumulative surface condensate oil collection, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0117] Determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameters of condensate gas reservoir, and the water vapor content of condensate gas reservoir;

[0118] The condensate oil content is determined based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0119] In summary, the computer equipment in this embodiment of the invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, it determines the condensate oil content based on the condensate oil reserves, the volume coefficient of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This allows for convenient and quick determination of the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs.

[0120] This invention also provides a computer-readable storage medium capable of implementing all steps of the method for determining the condensate oil content in a condensate gas reservoir as described in the above embodiments. The computer-readable storage medium stores a computer program that, when executed by a processor, implements all steps of the method for determining the condensate oil content in a condensate gas reservoir as described in the above embodiments. For example, when the processor executes the computer program, it implements the following steps:

[0121] The condensate reserves are determined based on the cumulative surface condensate oil collection, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation.

[0122] Determine the volume factor of condensate gas, the pore volume of condensate gas reservoir, the saturation parameters of condensate gas reservoir, and the water vapor content of condensate gas reservoir;

[0123] The condensate oil content is determined based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir.

[0124] In summary, the computer-readable storage medium of this invention first determines the condensate oil reserves based on the cumulative condensate oil collection volume at the surface, the original geological reserves of condensate oil, and the quality of condensate oil precipitated from the formation. Then, it determines the condensate oil content based on the condensate oil reserves, the volume factor of condensate gas, the pore volume of the condensate gas reservoir, the saturation parameters of the condensate gas reservoir, and the water vapor content of the condensate gas reservoir. This allows for convenient and rapid determination of the condensate oil content in condensate gas reservoirs, providing technical support for the development of condensate gas reservoirs.

[0125] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above descriptions are merely specific embodiments of the present invention and are not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

[0126] Those skilled in the art will also understand that the various illustrative logical blocks, units, and steps listed in the embodiments of the present invention can be implemented by electronic hardware, computer software, or a combination of both. To clearly demonstrate the interchangeability of hardware and software, the functions of the various illustrative components, units, and steps described above have been generally described. Whether such functionality is implemented through hardware or software depends on the specific application and the overall system design requirements. Those skilled in the art can implement the described functions using various methods for each specific application, but such implementation should not be construed as exceeding the scope of protection of the embodiments of the present invention.

[0127] The various illustrative logic blocks, units, or devices described in the embodiments of this invention can be implemented or operate the described functions using a general-purpose processor, digital signal processor, application-specific integrated circuit (ASIC), field-programmable gate array or other programmable logic device, discrete gate or transistor logic, discrete hardware components, or any combination thereof. The general-purpose processor can be a microprocessor; alternatively, it can be any conventional processor, controller, microcontroller, or state machine. The processor can also be implemented using a combination of computing devices, such as a digital signal processor and a microprocessor, multiple microprocessors, one or more microprocessors combined with a digital signal processor core, or any other similar configuration.

[0128] The steps of the methods or algorithms described in the embodiments of this invention can be directly embedded in hardware, a software module executed by a processor, or a combination of both. The software module can be stored in RAM, flash memory, ROM, EPROM, EEPROM, registers, hard disk, removable disk, CD-ROM, or any other form of storage medium in the art. Exemplarily, the storage medium can be connected to the processor so that the processor can read information from and write information to the storage medium. Optionally, the storage medium can also be integrated into the processor. The processor and storage medium can be housed in an ASIC, which can be housed in a user terminal. Optionally, the processor and storage medium can also be housed in different components of the user terminal.

[0129] In one or more exemplary designs, the functions described in the embodiments of the present invention can be implemented in hardware, software, firmware, or any combination of these three. If implemented in software, these functions can be stored on a computer-readable medium or transmitted on a computer-readable medium in the form of one or more instructions or code. Computer-readable media include computer storage media and communication media that facilitate the transfer of computer programs from one place to another. Storage media can be any available media that can be accessed by a general-purpose or special-purpose computer. For example, such computer-readable media can include, but is not limited to, RAM, ROM, EEPROM, CD-ROM or other optical disk storage, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to carry or store program code in the form of instructions or data structures and other forms that can be read by a general-purpose or special-purpose computer, or a general-purpose or special-purpose processor. Furthermore, any connection can be suitably defined as a computer-readable medium, for example, if the software is transmitted from a website, server or other remote resource via a coaxial cable, fiber optic cable, twisted pair, digital subscriber line (DSL) or wirelessly, such as infrared, wireless and microwave, it is also included in the defined computer-readable medium. The disks and discs mentioned include compressed disks, laser discs, optical discs, DVDs, floppy disks, and Blu-ray discs. Disks typically copy data magnetically, while disks typically copy data optically using lasers. Combinations of the above can also be contained in computer-readable media.

Claims

1. A method of determining condensate content in a gas condensate reservoir, characterized by, Comprising: determining a condensate oil reserve based on a cumulative condensate oil production amount on the ground, a condensate oil original geological reserve, and a formation condensate oil quality; determining a condensate gas volume factor, a condensate gas reservoir pore volume, a condensate gas reservoir saturation parameter, and a condensate gas reservoir water vapor content; determining a condensate oil content based on the condensate oil reserve, the condensate gas volume factor, the condensate gas reservoir pore volume, the condensate gas reservoir saturation parameter, and the condensate gas reservoir water vapor content; the condensate gas reservoir saturation parameter comprises a water saturation increment, a condensate oil saturation, and a bound water saturation; a process of determining an expression of the condensate oil content comprises: The formula for determining the condensate reserves N oG The formula for determining the condensate original geological reserves N o The formula for determining the formation condensate mass N oL The formula is brought into the material balance equation to obtain: The formula for determining the condensate gas reservoir pore volume V G The formula for determining the volume coefficient B g of the condensate gas is brought into the above expression, and the expression for the condensate oil content is obtained as follows: wherein the condensate reserves N are determined oG The formula is: determining the condensate original geological reserves N o The formula is: N o = GC oi x 10 -6 determining a quality N of the condensate that is released from the formation oL The formula is: the material balance equation is: N o = N oL + N oG + N op determining the condensate gas reservoir pore volume V G The formula is: determining a bulk coefficient B of the condensate gas g The formula is: In the above equation, C o is the condensate content, G is the original geological reserves of the gas condensate reservoir, C oi is the condensate content in the gas under the original condition, G p is the cumulative volume of the natural gas produced, G i is the cumulative volume of the injected gas, B g is the volume factor of the condensate gas, p sc is the pressure under the standard condition, T sc is the temperature under the standard condition, Z sc is the deviation factor of the gas phase under the standard condition, Z is the current gas deviation factor, T is the current formation temperature, p is the current formation pressure, y w is the water vapor content of the gas condensate reservoir, V G is the pore volume of the gas condensate reservoir, p oc is the surface density of the condensate oil, B o is the volume factor of the condensate oil, S oc is the condensate oil saturation, AS w is the water saturation increment, S wc is the irreducible water saturation, N o is the original geological reserves of the condensate oil, N oG is the condensate oil reserves, N oL is the formation released condensate oil mass, N op is the surface cumulative condensate oil production.

2. The method for determining the condensate content in a gas condensate reservoir according to claim 1, characterized in that, determining the condensate gas volume factor comprises: obtaining a current gas deviation factor, a current formation temperature, and a current formation pressure; determining the condensate gas volume factor based on the current gas deviation factor, the current formation temperature, and the current formation pressure.

3. The method for determining the condensate content in a gas condensate reservoir according to claim 1, characterized in that, determining the condensate gas reservoir pore volume comprises: obtaining a condensate gas reservoir original geological reserve, a cumulative natural gas volume, and a cumulative injected gas volume; determining the condensate gas reservoir pore volume based on the condensate gas reservoir original geological reserve, the cumulative natural gas volume, the cumulative injected gas volume, the condensate gas volume factor, the condensate gas reservoir saturation parameter, and the condensate gas reservoir water vapor content.

4. The method for determining the condensate content in a gas condensate reservoir according to claim 1, characterized in that, the condensate gas reservoir saturation parameter comprises a water saturation increment; determining the water saturation increment comprises: obtaining a cumulative water influx, a cumulative water production, an initial condensate gas reservoir pore volume, and a formation water volume factor; determining the water saturation increment based on the cumulative water influx, the cumulative water production, the formation water volume factor, and the initial condensate gas reservoir pore volume.

5. The method for determining the condensate content in a gas condensate reservoir according to claim 4, characterized in that, the condensate gas reservoir saturation parameter further comprises a condensate oil saturation; the condensate oil content determination method in the condensate gas reservoir further comprises: obtaining a condensate oil ground density and a condensate oil volume factor; determining the formation condensate oil quality based on the condensate gas reservoir pore volume, the condensate oil saturation, the condensate oil ground density, and the condensate oil volume factor.

6. A system for determining condensate content in a gas condensate reservoir, characterized by, Comprising: a condensate oil reserve unit configured to determine a condensate oil reserve based on a cumulative condensate oil production amount on the ground, a condensate oil original geological reserve, and a formation condensate oil quality; a parameter determination unit configured to determine a condensate gas volume factor, a condensate gas reservoir pore volume, a condensate gas reservoir saturation parameter, and a condensate gas reservoir water vapor content; a condensate oil content determination unit configured to determine a condensate oil content based on the condensate oil reserve, the condensate gas volume factor, the condensate gas reservoir pore volume, the condensate gas reservoir saturation parameter, and the condensate gas reservoir water vapor content; the condensate gas reservoir saturation parameter comprises a water saturation increment, a condensate oil saturation, and a bound water saturation; a process of determining an expression of the condensate oil content comprises: The formula for determining the condensate reserves N oG The formula for determining the condensate original geological reserves N o The formula for determining the formation condensate mass N oL The formula is brought into the material balance equation to obtain: The formula for determining the condensate gas reservoir pore volume V G The formula for determining the volume coefficient B g of the condensate gas is brought into the above expression, and the expression for the condensate oil content is obtained as follows: wherein the condensate reserves N are determined oG The formula is: determining the condensate original geological reserves N o The formula is: N o = GC oi x 10 -6 determining a quality N of the condensate that is being released from the formation oL The formula is: the material balance equation is: N o = N oL + N oG + N op determining the condensate gas reservoir pore volume V G The formula is: determining a bulk coefficient B of the condensate gas g The formula is: In the above equation, C o is the condensate content, G is the original geological reserves of the gas condensate reservoir, C oi is the condensate content in the gas under the original condition, G p is the cumulative volume of the natural gas produced, G i is the cumulative volume of the injected gas, B g is the volume factor of the condensate gas, p sc is the pressure under the standard condition, T sc is the temperature under the standard condition, Z sc is the deviation factor of the gas phase under the standard condition, Z is the current gas deviation factor, T is the current formation temperature, p is the current formation pressure, y w is the water vapor content of the gas condensate reservoir, V G is the pore volume of the gas condensate reservoir, p oc is the surface density of the condensate oil, B o is the volume factor of the condensate oil, S oc is the condensate oil saturation, ΔS w is the water saturation increment, S wc is the irreducible water saturation, N o is the original geological reserves of the condensate oil, N oG is the condensate oil reserves, N oL is the formation released condensate oil mass, N op is the surface cumulative condensate oil production.

7. A condensate content determination system in a gas condensate reservoir as defined in claim 6, wherein, the parameter determination unit is specifically configured to: obtain a current gas deviation factor, a current formation temperature, and a current formation pressure; determine the condensate gas volume factor based on the current gas deviation factor, the current formation temperature, and the current formation pressure.

8. The condensate content determination system in a gas condensate reservoir of claim 6, wherein, the parameter determination unit is specifically configured to: obtaining an initial geological reserve of the condensate gas reservoir, a cumulative natural gas volume, and a cumulative injected gas volume; determining a condensate gas reservoir pore volume according to the initial geological reserve of the condensate gas reservoir, the cumulative natural gas volume, the cumulative injected gas volume, a volume coefficient of the condensate gas, a saturation parameter of the condensate gas reservoir, and a water vapor content of the condensate gas reservoir.

9. The condensate content determination system in a gas condensate reservoir of claim 6, wherein, The saturation parameter of the condensate gas reservoir comprises a water saturation increment; The parameter determination unit is specifically configured to: obtain a cumulative water influx, a cumulative water production, an initial condensate gas reservoir pore volume, and a volume coefficient of formation water; determine the water saturation increment according to the cumulative water influx, the cumulative water production, the volume coefficient of the formation water, and the initial condensate gas reservoir pore volume.

10. A condensate content determination system in a gas condensate reservoir according to claim 9, characterized in that, The saturation parameter of the condensate gas reservoir further comprises a condensate oil saturation; The condensate oil content determination system in the condensate gas reservoir further comprises: an obtaining unit configured to obtain a condensate oil surface density and a condensate oil volume coefficient; a condensate oil quality determination unit configured to determine a quality of the condensate oil produced from the formation according to the condensate gas reservoir pore volume, the condensate oil saturation, the condensate oil surface density, and the condensate oil volume coefficient.

11. A computer device comprising a memory, a processor, and a computer program stored on the memory and running on the processor, characterized in that, The processor executes the computer program to implement the steps of the condensate oil content determination method in the condensate gas reservoir according to any one of claims 1 to 4.

12. A computer readable storage medium having stored thereon a computer program, characterized in that, The computer program is executed by the processor to implement the steps of the condensate oil content determination method in the condensate gas reservoir according to any one of claims 1 to 5.

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