CN112966422A - Flow simulation method suitable for shale gas reservoir thermal recovery - Google Patents

Flow simulation method suitable for shale gas reservoir thermal recovery Download PDF

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CN112966422A
CN112966422A CN202110289489.9A CN202110289489A CN112966422A CN 112966422 A CN112966422 A CN 112966422A CN 202110289489 A CN202110289489 A CN 202110289489A CN 112966422 A CN112966422 A CN 112966422A
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朱光普
姚军
钟俊杰
张磊
孙海
张凯
杨永飞
严侠
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China University of Petroleum East China
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Abstract

The invention relates to a flow simulation method suitable for shale gas reservoir thermal recovery, which comprises the following steps: establishing a gas reservoir geometric model according to the development scale of the shale gas reservoir mine, the distribution condition of cracks after hydraulic fracturing, the size of a reservoir transformation area obtained through micro earthquake and the distribution of micro cracks; describing artificial cracks through a discrete crack model; establishing a shale gas reservoir dual-medium fracturing horizontal well seepage field model based on the reservoir modified area and the reservoir non-modified area; taking the artificial cracks as a constant-temperature heat source, and establishing a shale gas reservoir thermal field model; and coupling the seepage field model and the thermal force field model, subdividing the geometric model based on the Delaunay triangular mesh, and solving the geometric model to realize the numerical simulation of the thermal development of the complex fractured shale gas reservoir. The invention establishes a shale gas reservoir composite gas reservoir segmented pressure horizontal well thermal development model and provides guidance for shale gas reservoir thermal exploitation potential evaluation and future mine field development.

Description

Flow simulation method suitable for shale gas reservoir thermal recovery
Technical Field
The invention relates to the field of unconventional oil and gas field development, in particular to a flow simulation method suitable for shale gas reservoir thermal recovery.
Background
With the improvement of oil and gas reservoir exploitation technology and the increase of oil and gas resource demand, unconventional oil and gas resources are increasingly concerned and valued, and become powerful supplements of important strategic resources gradually. Shale gas has the characteristics of wide distribution range, large resource quantity, long stable production period and the like, and becomes a hot spot of current oil and gas exploration and development. The shale gas reservoir has the advantages of nano-scale pore diameter, various occurrence modes, extremely low porosity and permeability, and belongs to a typical compact porous medium. Compared with the conventional gas reservoir, the shale gas reservoir migration mechanism is complex, and the flow mode presents nonlinearity. The staged fracturing horizontal well technology provides a foundation for commercial development of shale gas reservoirs. At present, staged fracturing of a horizontal well is a main development mode, fractured artificial fractures and natural fractures jointly form a complex fracture network, and the fracture system is directly related to the gas well productivity and the ultimate recovery ratio. In the actual development process, because the shale gas reservoir is poor in bedrock permeability, low in adsorbed gas abundance, small in brittle mineral content, small in fracturing scale, limited in ground production condition and poor in development effect, other yield-increasing measures are required to be taken for the gas reservoir, and the gas recovery rate is improved.
Thermal recovery is a relatively mature technology for increasing the recovery rate, is suitable for very complicated geological-physical conditions, is particularly suitable for high-viscosity crude oil, and is a high-potential method for a thick oil field. In recent years, thermal recovery has been increasingly applied to unconventional oil and gas resource recovery. The Mobil corporation proposes an electric crack technology, a conductive material is injected into an artificial crack, the artificial crack is electrically heated, the crack temperature can reach 400 ℃, kerogen of oil shale is promoted to be decomposed into oil gas, the viscosity of the shale gas is reduced, and the purpose of increasing the yield is achieved. At present, the electric cracking technology is applied to the exploitation test of the shale oil deposit in the mine field. The shale gas reservoir framework surface has a large amount of adsorbed gas, the formation temperature is raised, the adsorbed gas can be promoted to be desorbed from the framework surface from the aspect of mechanism, and the purpose of increasing yield is achieved, but the technologies such as electric cracking and the like are not applied to the actual development of the shale gas reservoir, the actual development effect is unknown, the productivity evaluation research is necessary, the potential of the heating artificial cracking technology on the shale gas reservoir development is researched, and the guidance is provided for the thermal development of the shale gas reservoir in the future.
Disclosure of Invention
The invention aims to establish a thermal development model considering a shale gas reservoir nonlinear seepage mechanism, which is used for researching the influence of thermal exploitation based on heating artificial cracks on the adsorption and energy production of the shale gas reservoir and providing guidance for economic and effective thermal development of the shale gas reservoir in the future.
In order to achieve the purpose, the invention provides the following scheme:
a flow simulation method suitable for shale gas reservoir thermal recovery comprises the following steps:
s1, establishing a gas reservoir geometric model according to the development scale of the shale gas reservoir mine, the distribution condition of cracks after hydraulic fracturing, the size of a reservoir transformation area obtained through micro earthquake and the distribution of micro cracks;
s2, describing the artificial crack through a discrete crack model; establishing a shale gas reservoir dual-medium fracturing horizontal well seepage field model based on the reservoir modified area and the reservoir non-modified area;
s3, taking the artificial cracks as a constant-temperature heat source, and establishing a shale gas reservoir thermal field model;
and S4, coupling the seepage field model and the thermal force field model through pressure and temperature variables, carrying out mesh subdivision on the geometric model based on a Delaunay triangular mesh, carrying out local mesh encryption on the artificial fracture, further solving the geometric model, and realizing the numerical simulation of the thermal development of the complex fractured shale gas reservoir.
Preferably, in the step S2, the high-speed non-darcy effect is considered in the artificial fracture, the non-darcy flow process is described by the Forchheimer equation of the secondary flow term, the modified zone is described based on a dual medium model, and the unmodified zone of the reservoir is described based on a single-hole medium model.
Preferably, in the step S2, the artificial fractures and the natural fractures in the horizontal well and the alteration area are pressure-continuous boundaries.
Preferably, the reservoir reconstruction area is composed of bedrock and natural fractures, a thermal force field between the bedrock and the natural fractures is calculated by adopting quasi-steady-state channeling, and the pressure of the natural fracture system of the reservoir reconstruction area is equal to the pressure of the junction of the artificial fractures.
Preferably, the quasi-steady-state cross flow calculation method is as follows:
Figure BDA0002981885410000031
wherein k ismDenotes the permeability of the bedrock in m2(ii) a Alpha is the cross-flow coefficient and has the unit of m-2，ρgIs the gas density in kg/m3，pmRepresenting the gas pressure in the bedrock in kg/m3, pfIs the fracture pressure.
Preferably, the matrix contains adsorbed gas and free gas, and the gas reservoir temperature in the matrix is calculated by adopting an isothermal adsorption model due to the adsorption and desorption effect in the matrix.
Preferably, the non-isothermal adsorption model is as follows:
Figure BDA0002981885410000032
wherein, VLIs the volume of Langmuir in m3/kg；ρsIs shale core density with unit of kg/m3，VstdIs the molar volume in the standard case in m3/mol。
The invention has the beneficial effects that:
(1) in the process of building the thermal development model, the complex migration mechanism and the nonlinear seepage mechanism in the shale gas reservoir are considered, and the model solving result is ensured to be in line with the actual condition of a mine field.
(2) The invention establishes a shale gas reservoir composite gas reservoir segmented pressure horizontal well thermal development model and provides guidance for shale gas reservoir thermal exploitation potential evaluation and future mine field development.
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In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings without inventive exercise.
FIG. 1 is a flow chart of a shale gas reservoir thermal development simulation method of the present invention;
FIG. 2 is a schematic diagram of a complex fractured shale gas reservoir physical model according to the 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.
In order to make the aforementioned objects, features and advantages of the present invention comprehensible, embodiments accompanied with figures are described in further detail below.
A flow simulation method suitable for shale gas reservoir thermal recovery is disclosed, and the flow is as shown in the attached figure 1, and the flow simulation method specifically comprises the following steps:
step one, establishing a shale gas reservoir composite gas reservoir geometric model as shown in figure 2 according to the development scale of a shale gas reservoir mine field, the distribution condition of cracks after hydraulic fracturing, the size of a reservoir transformation area obtained by micro earthquake and the distribution of micro cracks.
Step two: the flow conductivity of the artificial crack is high, the gas flow speed is high, the gas flow deviates from Darcy flow due to the action of inertia force, and therefore the high-speed non-Darcy effect needs to be considered. The non-darcy flow is described using the fochheimer equation, which considers the secondary flow term, as shown in equation (1).
Figure BDA0002981885410000051
Wherein p isaIs the artificial fracture pressure in Pa; k is a radical ofaIs the permeability of the artificial crack in m2Mu is gas viscosity in Pa.s, beta is Forchheimer coefficient, rho is gas density in kg/m3，vaThe flow rate of gas in the artificial fracture is expressed in m/s.
The viscosity of the gas is described by using Lee formula in consideration of real gas effect, as shown in formula (2).
Figure BDA0002981885410000052
Wherein μ is the gas viscosity, MgIs the molar mass of the gas in kg/mol; t is the gas reservoir temperature, the unit is K, K, X and Y are intermediate variables, and no specific physical significance is realized.
The Mohmoud formula calculates the compression factor Z at the corresponding pressure and temperature, as shown in formula (3).
Figure BDA0002981885410000061
Wherein T isrAnd PrRespectively corresponding temperature and corresponding pressure.
The continuity equation of the artificial fracture system is:
Figure BDA0002981885410000062
wherein phi isaThe porosity of the crack is generally 1; p is a radical ofaIs the artificial fracture pressure in Pa; q. q.saThe unit is kg/s for the source and sink items of the artificial crack; rhoaThe gas density in the artificial fracture is expressed in kg/m3；μaThe gas viscosity in the artificial crack is expressed in Pa.s; k is a radical ofaIs the permeability of the artificial crack in m2；CagThe gas compression coefficient in Pa in the artificial crack is shown-1。
The artificial fractures and the horizontal wells and the natural fractures in the reservoir reconstruction zone adopt continuous pressure boundary conditions.
Step three: the reservoir transformation area is mainly composed of bedrock and natural fractures, adsorbed gas and free gas exist in the bedrock, and the free gas mainly exists in the natural fractures. Adsorption desorption, Knudsen diffusion and viscous flow are considered within the bedrock. In the process of thermal development, the gas reservoir temperature is continuously changed, and the Langmuir isothermal adsorption formula is not applicable any more, so that the non-isothermal adsorption model is adopted to calculate the gas reservoir temperature qads：
Figure BDA0002981885410000063
Wherein, VLIs the volume of Langmuir in m3/kg；MgIs the molar mass of the gas; rhosIs shale core density with unit of kg/m3；VstdIs the molar volume in the standard case in m3/mol；pmExpressed as bedrock pressure in kg/m3And K (T) represents an intermediate function related to temperature.
Shale gas reservoir is denser, pore radius is smaller, collision between gas molecules and a wall surface is dominant, and mass flow between the gas molecules is expressed by Knudsen diffusion:
Figure BDA0002981885410000071
wherein N iskThe mass flow rate caused by Knudsen diffusion is expressed in kg/(m)2·s)；CmIs the molar concentration of the gas in mol/m3；DkmIs the diffusion coefficient of the bedrock in m2S; r is ideal gas fraction, R is 8.314 J.K-1·mol-1；pmIs the bedrock pressure in Pa.
Quasi-steady state channeling is adopted between bedrock and natural fractures:
Figure BDA0002981885410000072
wherein k ismDenotes the permeability of the bedrock in m2(ii) a Alpha is the cross-flow coefficient and has the unit of m-2；ρgIs the gas density in kg/m3；pmRepresenting the gas pressure in the bedrock in kg/m 3; p is a radical offIs the fracture pressure.
Then the continuous equation for the real gas is considered as:
Figure BDA0002981885410000073
during shale gas reservoir development, the reduction of formation pressure is considered to be large for the pores of the reservoir, so in addition to consideration of Knudsen diffusion in a natural fracture system, stress sensitivity effect must be considered, as shown in formula 9:
Figure BDA0002981885410000081
wherein k isf0Is the intrinsic permeability of the natural fracture in m2；piAnd pfRespectively the initial pressure of the stratum and the pressure of the natural fracture, and the unit is Pa; gamma is the stress sensitivity coefficient.
The continuity equation for a natural fracture system is:
Figure BDA0002981885410000082
wherein, FfRepresenting the mass flow of gas within the natural fracture; rhofThe density of gas in natural fracture in kg/m3；kfPermeability of natural fractures in m2；pfIs the pressure of the gas in the natural fracture in Pa; mu.sfThe viscosity of the gas in the natural fracture is expressed in Pa & s; dkfIs the diffusion coefficient of the gas in the natural fracture.
The pressure of a natural fracture system and the pressure of an artificial fracture system are considered to be the same by the inner boundary, and the pressure of bedrock and the pressure of an unmodified area of a reservoir are considered to be the same by the outer boundary.
Step four: the bedrock of the non-modified region of the reservoir is the same as the bedrock system in the modified region of the reservoir, viscous flow, Knudsen diffusion and adsorption mechanisms are considered in the bedrock, the pressure of the inner boundary of the bedrock system is equal to the pressure of the bedrock in the dual-medium system everywhere, and the outer boundary is a closed boundary. The mathematical model of the unmodified zone of the reservoir is shown in equation (8) above.
Step five: the temperature of the artificial crack is basically kept unchanged due to the continuous propagation of heat in the heating process of the artificial crack, and the artificial crack can be used as a constant-temperature heat source. Heat transfer in the formation may be described by heat diffusion equations. The way heat propagates in different media varies. In the bedrock framework, heat is mainly transferred in a heat conduction manner, as shown in formula 11:
Figure BDA0002981885410000091
wherein phi ismIs bedrock porosity; rhosThe density of the matrix is expressed in kg/m3；TmThe temperature of the matrix is expressed in K.
Heat is transferred in the pores of the bedrock by gas in both heat conduction and heat convection, as shown in equation 12:
Figure BDA0002981885410000092
wherein, TgIndicating the gas temperature, taking into account the local heat balance, Tm＝TgT, in K; c. Cm，cgRespectively represents the specific heat capacity of the bedrock framework and the gas, and the unit is J.kg-1·K-1；Km，KgRespectively represents the heat conductivity coefficients of the matrix skeleton and the gas, and the unit is W.m-1·K-1；vm，vfRespectively represents the flow velocity of gas in bedrock and natural fracture and has the unit of m & s-1；qmRepresenting the gas flow in the bedrock.
Coupling a seepage field model and a thermal force field model through pressure and temperature variables, meshing the geometric model based on a Delaunay triangular mesh, carrying out local mesh encryption on artificial cracks, solving the model by using a Galerkin finite element and a Newton iteration method, and realizing the numerical simulation of the thermal development of the complex fractured shale gas reservoir.
In the process of building the thermal development model, the complex migration mechanism and the nonlinear seepage mechanism in the shale gas reservoir are considered, and the model solving result is ensured to be in line with the actual condition of a mine field. The invention establishes a shale gas reservoir composite gas reservoir segmented pressure horizontal well thermal development model and provides guidance for shale gas reservoir thermal exploitation potential evaluation and future mine field development.
The above-described embodiments are merely illustrative of the preferred embodiments of the present invention, and do not limit the scope of the present invention, and various modifications and improvements of the technical solutions of the present invention can be made by those skilled in the art without departing from the spirit of the present invention, and the technical solutions of the present invention are within the scope of the present invention defined by the claims.

Claims (7)

1. A flow simulation method suitable for shale gas reservoir thermal recovery is characterized by comprising the following steps:
s1, establishing a gas reservoir geometric model according to the development scale of the shale gas reservoir mine, the distribution condition of cracks after hydraulic fracturing, the size of a reservoir transformation area obtained through micro earthquake and the distribution of micro cracks;
s2, describing the artificial crack through a discrete crack model; establishing a shale gas reservoir dual-medium fracturing horizontal well seepage field model based on the reservoir modified area and the reservoir non-modified area;
s3, taking the artificial cracks as a constant-temperature heat source, and establishing a shale gas reservoir thermal field model;
and S4, coupling the seepage field model and the thermal force field model through pressure and temperature variables, carrying out mesh subdivision on the geometric model based on a Delaunay triangular mesh, carrying out local mesh encryption on the artificial fracture, further solving the geometric model, and realizing the numerical simulation of the thermal development of the complex fractured shale gas reservoir.
2. The flow simulation method for shale gas reservoir thermal recovery as claimed in claim 1, wherein in step S2, the high speed non-darcy effect is considered in the artificial fracture, the non-darcy flow process is described by a Forchheimer equation of a quadratic flow term, the modified zone is described based on a dual media model, and the unmodified zone of the reservoir is described based on a single-hole media model.
3. The flow simulation method for shale gas reservoir thermal recovery as claimed in claim 1, wherein in step S2, the artificial fractures are pressure continuous boundaries with horizontal wells and natural fractures in the reservoir reconstruction zone.
4. The flow simulation method suitable for shale gas reservoir thermal recovery as claimed in claim 3, wherein the reservoir reconstruction zone is composed of bedrock and natural fractures, the thermal force field between the bedrock and the natural fractures is calculated by adopting quasi-steady state channeling, and the natural fracture system pressure of the reservoir reconstruction zone is equal to the artificial fracture junction pressure.
5. The flow simulation method for shale gas reservoir thermal recovery as set forth in claim 4, wherein said quasi-steady state cross flow calculation method is:
Figure FDA0002981885400000021
wherein k ismDenotes the permeability of the bedrock in m2(ii) a Alpha is the cross-flow coefficient and has the unit of m-2，ρgIs the gas density in kg/m3，pmRepresenting the gas pressure in the bedrock in kg/m3, pfIs the fracture pressure.
6. The flow simulation method for shale gas reservoir thermal recovery as claimed in claim 4, wherein adsorbed gas and free gas exist in the bedrock, and due to adsorption and desorption effects in the bedrock, the gas reservoir temperature in the bedrock is calculated by using an isothermal adsorption model.
7. The flow simulation method for shale gas reservoir thermal recovery of claim 6, wherein the non-isothermal adsorption model is as follows:
Figure FDA0002981885400000022
wherein, VLIs the volume of Langmuir in m3/kg；ρsIs shale core density with unit of kg/m3，VstdIs the molar volume in the standard case in m3/mol。
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CN113642272A (en) * 2021-09-15 2021-11-12 西南石油大学 Shale oil and gas reservoir seepage-horizontal wellbore flow coupling model building method
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CN114201934B (en) * 2021-12-15 2022-08-26 中国石油大学(华东) Method for evaluating temperature field when low-frequency electric field heats shale oil reservoir
CN115270663A (en) * 2022-09-27 2022-11-01 中国石油大学(华东) Method and system for describing unsteady flow channeling between shale matrix and natural fracture

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