CN118008229A - Method for determining front dynamic position of thickened oil steam injection thermal oil extraction gas interface - Google Patents
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Abstract
The invention discloses a method for determining the dynamic position of the front edge of a thick oil steam injection thermal oil extraction gas interface, which comprises the following steps: obtaining basic parameters, thermodynamic parameters, well position parameters and daily steam injection quantity of a target oil reservoir; sequentially calculating the dynamic positions of the front edge of the oil-gas interface of the steam vertical movement stage, the front stage of the transverse movement of the steam after encountering the impermeable layer in the stratum, the rear stage of the transverse movement of the steam after encountering the impermeable layer in the stratum, the second vertical movement stage of the steam, the front stage of the transverse movement of the steam along the cover layer, the rear stage of the transverse movement of the steam along the cover layer and the front edge of the oil-gas interface of the steam downward movement stage; and according to the calculation results of each stage, obtaining the dynamic position change result of the front edge of the oil-gas interface in the whole process of steam movement in the reservoir. The method can accurately determine the front dynamic position of the thick oil steam injection thermal oil extraction gas interface, and provides technical support for efficient development of the thick oil reservoir in the oilfield site.
Description
Technical Field
The invention relates to the technical field of petroleum exploration and development, in particular to a method for determining the front edge dynamic position of a thickened oil steam injection thermal oil extraction gas interface.
Background
The thickened oil and asphalt in the crude oil resources found in the world occupy about 70%, play an important role in the replacement of crude oil reserves meeting the world future energy demands, and how to efficiently and reasonably guide the thickened oil exploitation is a difficult problem to be solved at present.
The fourth biggest heavy oil country is the fourth biggest heavy oil country, the heavy oil resources are quite abundant and widely distributed, and the heavy oil resources are distributed in more than 70 oil fields of 12 basins, wherein the Tahe oil field, liaohe oil field, the victory oil field and the original oil field are main heavy oil production bases of the country. The burial depth of the thick oil reservoir in China is generally more than 800m and less than 2000m. Although shallow in burying, the thick oil has high viscosity and is difficult to flow at normal temperature, and meanwhile, the geological conditions of China are complex, and some impermeable rock stratum exists in the stratum, so that the thick oil is more difficult to extract. In order to extract the abundant resources, china uses a series of thermal recovery technologies for extracting the thick oil in Canada, wherein the steam injection thermal recovery technology is the most effective technology for extracting the thick oil, particularly for extracting shallow and ultra-high viscosity oil reservoirs, and the injected hot steam releases latent heat to heat the crude oil and reduce the viscosity of the crude oil, so that the extraction of the thick oil is realized, and the method has the characteristics of high oil-gas ratio, high oil extraction rate and high recovery ratio.
However, steam injection thermal recovery requires a large amount of energy, and therefore, a more reasonable development scheme must be established for the development mode of heavy oil thermal recovery. The dynamic position of the front edge of the hydrocarbon interface refers to the position of the steam at the junction with cold oil in the stratum expansion process, and under the geological condition containing an impermeable stratum, the steam mainly has five stages in the stratum, namely a vertical movement stage of the steam, a transverse movement stage (divided into a front stage and a rear stage) after the steam meets the impermeable layer in the stratum, a second vertical movement stage of the steam, a transverse movement stage (divided into a front stage and a rear stage) of the steam along the cover layer, and a downward movement stage of the steam. The front dynamic position of the oil-gas interface is an important index for the design of a heavy oil reservoir development scheme, can help developers to determine the current reservoir exploitation progress, assists the developers to design reasonable steam injection amount, avoids resource waste and saves development cost. Therefore, a method for determining the front dynamic position of the thick oil steam injection thermal oil production gas interface is needed, and technical support is provided for efficient development of thick oil reservoirs in oil fields.
Disclosure of Invention
Aiming at the problems, the invention aims to provide a method for determining the front edge dynamic position of a thick oil steam injection thermal oil extraction gas interface.
The technical scheme of the invention is as follows:
a method for determining the dynamic position of the front edge of a thick oil steam injection thermal oil extraction gas interface comprises the following steps:
s1: obtaining basic parameters, thermodynamic parameters, well position parameters and daily steam injection quantity of a target oil reservoir;
S2: calculating the dynamic position of the front edge of the oil-gas interface in the vertical movement stage of steam;
S3: calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum;
S4: calculating the dynamic position of the front edge of the oil-gas interface in the later stage of transverse movement after the steam encounters the impermeable layer in the stratum;
S5: calculating the dynamic position of the front edge of the oil-gas interface in the second vertical movement stage of steam;
S6: calculating the dynamic position of the front edge of the oil-gas interface at the early stage of the transverse movement of the steam along the cover layer;
S7: calculating the dynamic position of the front edge of the oil-gas interface at the later stage of the transverse movement of the steam along the cover layer;
S8: calculating the dynamic position of the front edge of the oil-gas interface in the downward movement stage of steam;
S9: and (3) obtaining a dynamic position change result of the steam at the front edge of the oil-gas interface in the whole reservoir moving process according to the calculation results of the steps S2-S8.
Preferably, in step S1, the basic parameters include reservoir thickness, porosity, effective permeability of the reservoir, initial oil saturation, residual oil saturation, irreducible water saturation, rock density, crude oil density, water density, crude oil viscosity, and density of the impermeable layer;
The thermodynamic parameters comprise the specific heat capacity of rock, the specific heat capacity of crude oil, the specific heat capacity of water, the heat conductivity coefficient of a cover layer, the heat conductivity coefficient of an impermeable layer, the specific heat capacity of the cover layer, the dryness of steam, the initial reservoir temperature, the steam temperature, the latent heat of steam and the thermal diffusivity;
The well location parameters include horizontal leg length, production well depth, steam injection well depth, drainage boundary, well spacing, production well to overburden distance, production well to impermeable layer distance.
Preferably, in step S2, when calculating the dynamic position of the front edge of the oil-gas interface in the steam vertical movement stage, the distance of the steam vertical movement is calculated by the following formula:
wherein: h 1 is the vertical movement distance of the steam in the vertical movement stage of the steam, and m; q in is the rate of latent heat release by steam per unit horizontal well length, J/(m·d); t is time, d; beta is a constant and dimensionless; The latent heat released for steam is used to heat the rock matrix, crude oil and bound water at a heat loss rate, J/m 4;
in step S3, when calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the lateral movement after the steam encounters the impermeable layer in the stratum, the distance of the lateral movement of the steam is calculated by the following formula:
Wherein: x 1 is the distance of the lateral movement of the vapor at the early stage of the lateral movement after the vapor encounters the impermeable layer in the formation, m; psi is the specific heat of constant pressure, J/(m 3·℃);Ts) is the steam temperature, DEG C, T r is the initial reservoir temperature, DEG C, q L1 is the total heat loss consumed by steam movement per unit horizontal well length in the early stage of lateral movement after the steam encounters an impermeable layer in the formation, J/(m.d), gamma () is the gamma function, tau is the integral over time, d, erfc is the error function;
In step S4, when calculating the dynamic position of the front edge of the oil-gas interface in the later stage of the lateral movement after the steam encounters the impermeable layer in the stratum, the distance of the lateral movement of the steam is calculated by the following formula:
Wherein: x 2 is the distance of the lateral movement of the steam at the later stage of the lateral movement after the steam encounters the impermeable layer in the formation, m; q 1 is the amount of latent heat released by steam per unit horizontal well length in time t at the later stage of lateral movement after the steam encounters an impermeable layer in the formation, J/m; ζ 1 is an intermediate parameter; The average moving speed of the steam in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum is m/d; t 1 is the total time that the steam has elapsed during the early stages of lateral movement after encountering an impermeable layer in the formation, d; h d is the distance from the production well to the impermeable layer, m; lambda d is the thermal conductivity of the impermeable layer, J/(m.d. ℃ C.); ρ d is the density of the impermeable layer, kg/m 3;cd is the specific heat capacity of the impermeable layer, J/(kg·deg.C);
In step S5, when calculating the dynamic position of the front edge of the oil-gas interface in the second vertical movement stage of steam, the vertical movement distance of steam is calculated by the following formula:
Wherein: h 2 is the distance of the steam vertical movement in the second vertical movement stage of the steam, and m; q L3 is the total heat loss consumed by steam movement per unit horizontal well length in the second vertical movement stage of steam, J/(m·d); t 2 is the total time that the vapor undergoes in the early and late stages of lateral movement after encountering an impermeable layer in the formation, d;
in step S6, when calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the steam lateral movement along the cover layer, the distance of the steam lateral movement is calculated by the following formula:
Wherein: x 3 is the distance that the vapor moves laterally along the cap layer during the early stage of the lateral movement of the vapor, m; h is the production well to cap distance, m; q L4 is the total heat loss consumed by steam movement per unit horizontal well length at the early stage of steam movement across the cap layer, J/(m·d);
in step S7, when calculating the dynamic position of the steam along the front edge of the oil-gas interface in the later stage of the lateral movement of the cover layer, the distance of the lateral movement of the steam is calculated by the following formula:
wherein: x 4 is the distance that the vapor moves laterally along the vapor at the later stage of the lateral movement of the cap layer, m; q 2 is the amount of latent heat released by steam per unit horizontal well length in the later stage of the steam traverse along the overburden, J/m; ζ 2 is an intermediate parameter; The average moving speed of the steam in the earlier stage of the steam moving transversely along the cover layer is m/d; t 3 is the total time that the vapor has elapsed during the early stages of its lateral movement along the cap layer, d; lambda cap is the thermal conductivity of the cap layer, J/(m.d. ℃ C.); ρ cap is the density of the cap layer, kg/m 3;ccap is the specific heat capacity of the cap layer, J/(kg·deg.C);
in step S8, when calculating the dynamic position of the front edge of the oil-gas interface in the steam downward movement stage, the distance of the steam downward movement is calculated by the following formula:
Wherein: y is the distance of downward movement of steam in the downward movement stage of steam, and m; q is the oil yield per unit horizontal well length in the steam downward moving stage, and m 3/(m.d); phi is porosity, dimensionless; Δs o is the change in oil saturation, dimensionless; w c is the width of the impermeable layer, m;
In the steps S2-S8, the dynamic position of the front edge of the oil-gas interface of the steam movement in each step can be obtained by calculating the steam movement distances at different moments.
Preferably, the rate of latent heat released by steam per unit length of horizontal well is calculated by the following formula:
Wherein: lambda is the dryness of the steam,%; q s is the steam injection rate, kg/d; h s is the latent heat of steam, J/kg; l is the horizontal segment length, m.
Preferably, the rate of heat loss of the latent heat released by the steam for heating the rock matrix, crude oil and bound water is calculated by the following formula:
ΔSo＝Soi-Sor (13)
Wherein: ρ o is the crude oil density, kg/m 3;Ar is the heat absorption rate of the rock skeleton per unit horizontal well length, J/(m.kg); a o is the heat absorption rate of crude oil in unit horizontal well length, J/(m.kg); a wc is the heat absorption rate of water bound by the length of a unit horizontal well, J/(m.kg); ρ r is the rock density, kg/m 3;cr is the specific heat capacity of the rock, J/(kg·deg.C); s oi is the initial oil saturation, dimensionless; s or is the saturation of residual oil, and is dimensionless; c o is the specific heat capacity of the crude oil, J/(kg. Deg.C); ρ w is water density, kg/m 3;Swc is irreducible water saturation, dimensionless; c w is the specific heat capacity of water, J/(kg. Deg.C.).
Preferably, the constant pressure specific heat is calculated by the following formula:
ψ＝(1-φ)ρrcr+φ(Soρoco+Swρwcw) (16)
Wherein: s o is the saturation of crude oil, and is dimensionless; s w is the saturation of water, dimensionless.
Preferably, the total heat loss per unit horizontal well length of steam movement consumed at the early stages of lateral movement after the steam encounters an impermeable layer in the formation is calculated by:
qL1＝qa1+qd1 (17)
Wherein: q a1 is the rate of heat loss around the steam per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); q d1 is the latent heat of steam absorbed by the impermeable layer per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); x is distance, m;
The total heat loss consumed by the steam shift per unit horizontal well length for the second vertical shift stage of steam is calculated by:
Wherein: An average velocity, m/d, for the vapor to bypass the impermeable layer;
The total heat loss consumed by steam movement per unit horizontal well length of the earlier stage of steam movement along the overburden is calculated by:
qL4＝qa3+qb1 (22)
Wherein: q a3 is the rate of heat loss around the steam per unit horizontal well length at the early stage of steam lateral movement along the overburden, J/(m·d); q b1 is the latent heat of steam absorbed by the cap layer per unit horizontal well length of the earlier stage of steam movement along the cap layer, J/(m·d).
Preferably, the amount of latent heat released by steam per unit horizontal well length at time t in the later stage of lateral movement after the steam encounters an impermeable layer in the formation is calculated by:
Wherein: The average steam injection rate of steam in the t time of the later stage of transverse movement after the steam encounters an impermeable layer in the stratum is kg/d; q s,i is the steam injection rate on the ith day of steam, kg/d;
The amount of latent heat released by steam per unit horizontal well length during the t time of the later stage of its lateral movement along the overburden is calculated by:
Wherein: the average steam injection rate of steam, kg/d, is the time t during which the steam moves laterally along the cover layer in the later stage.
Preferably, the average rate of movement of the vapor at the early stages of lateral movement after the vapor encounters the impermeable layer in the formation is calculated by:
The average vapor movement velocity of the vapor during the early stages of its lateral movement along the cover layer is calculated by the following equation:
preferably, the unit horizontal well length oil production for the steam down shift stage is calculated by:
Wherein: k is the effective permeability of the oil reservoir, D; g is gravity acceleration, m/s 2; alpha is the thermal diffusivity of the overburden rock, m 2/d; m is a constant, dimensionless; mu is the viscosity of crude oil and m 2/d.
The beneficial effects of the invention are as follows:
The method can accurately determine the front dynamic position of the thick oil steam injection thermal oil extraction gas interface, can help developers to determine the current oil reservoir exploitation progress, assists the developers to design reasonable steam injection amount, avoids resource waste, saves development cost and provides technical support for efficient development of thick oil reservoirs in oil fields.
Drawings
In order to more clearly illustrate the embodiments of the invention or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, it being obvious that the drawings in the description below are only some embodiments of the invention, and that other drawings can be obtained according to these drawings without inventive faculty for a person skilled in the art.
FIG. 1 is a schematic diagram of a target heavy oil reservoir profile and well position information according to one embodiment;
FIG. 2 is a schematic diagram of the dynamic position of the front of the hydrocarbon interface during a vertical vapor translation stage according to one embodiment;
FIG. 3 is a schematic representation of the dynamic position of the hydrocarbon interface front at a pre-lateral stage of movement of steam after encountering an impermeable layer in a formation, in accordance with one embodiment;
FIG. 4 is a schematic representation of the dynamic position of the hydrocarbon interface front at a later stage of lateral movement after steam encounters an impermeable layer in a formation in accordance with one embodiment;
FIG. 5 is a schematic diagram of dynamic position of the front of the hydrocarbon interface during the second vertical movement stage of steam in accordance with one embodiment;
FIG. 6 is a schematic diagram of the dynamic position of the hydrocarbon interface front at a pre-stage of steam movement along the cover layer in accordance with one embodiment;
FIG. 7 is a schematic diagram of the dynamic position of the hydrocarbon interface front at a later stage of steam movement along the cover layer in accordance with one embodiment;
FIG. 8 is a schematic diagram of the dynamic position of the front of the hydrocarbon interface during a vapor down shift stage in accordance with one embodiment;
FIG. 9 is a schematic diagram of the dynamic position of the front of the hydrocarbon interface during the movement of the reservoir with steam in accordance with one embodiment.
Detailed Description
The application will be further described with reference to the drawings and examples. It should be noted that, without conflict, the embodiments of the present application and the technical features of the embodiments may be combined with each other. It is noted that all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs unless otherwise indicated. The use of the terms "comprising" or "includes" and the like in this disclosure is intended to cover a member or article listed after that term and equivalents thereof without precluding other members or articles.
The invention provides a method for determining the dynamic position of the front edge of a thick oil steam injection thermal oil extraction gas interface, which comprises the following steps:
s1: and acquiring basic parameters, thermodynamic parameters, well position parameters and daily steam injection quantity of the target oil reservoir.
In a specific embodiment, the base parameters include reservoir thickness, porosity, effective permeability of the reservoir, initial oil saturation, residual oil saturation, irreducible water saturation, rock density, crude oil density, water density, crude oil viscosity, and density of the impermeable layer;
The thermodynamic parameters comprise the specific heat capacity of rock, the specific heat capacity of crude oil, the specific heat capacity of water, the heat conductivity coefficient of a cover layer, the heat conductivity coefficient of an impermeable layer, the specific heat capacity of the cover layer, the dryness of steam, the initial reservoir temperature, the steam temperature, the latent heat of steam and the thermal diffusivity;
The well location parameters include horizontal leg length, production well depth, steam injection well depth, drainage boundary, well spacing, production well to overburden distance, production well to impermeable layer distance.
S2: and calculating the dynamic position of the front edge of the oil-gas interface in the vertical movement stage of the steam.
In a specific embodiment, when calculating the dynamic position of the front edge of the oil-gas interface in the steam vertical movement stage, the distance of the steam vertical movement is calculated by the following formula:
wherein: h 1 is the vertical movement distance of the steam in the vertical movement stage of the steam, and m; q in is the rate of latent heat release by steam per unit horizontal well length, J/(m·d); t is time, d; beta is a constant and dimensionless; The latent heat released for steam is used to heat the rock matrix, crude oil and bound water at a heat loss rate, J/m 4;
and calculating the steam moving distances at different moments to obtain the dynamic position of the front edge of the oil-gas interface in the steam vertical moving stage.
In a specific embodiment, the constant β in formula (1) takes a value of 0.7.
S3: the dynamic position of the oil-gas interface front at the early stage of lateral movement after the steam encounters the impermeable layer in the formation is calculated.
In a specific embodiment, the distance that the steam moves laterally is calculated by calculating the dynamic position of the hydrocarbon interface front at the early stage of lateral movement after the steam encounters the impermeable layer in the formation by:
Wherein: x 1 is the distance of the lateral movement of the vapor at the early stage of the lateral movement after the vapor encounters the impermeable layer in the formation, m; psi is the specific heat of constant pressure, J/(m 3·℃);Ts) is the steam temperature, DEG C, T r is the initial reservoir temperature, DEG C, q L1 is the total heat loss consumed by steam movement per unit horizontal well length in the early stage of lateral movement after the steam encounters an impermeable layer in the formation, J/(m.d), gamma () is the gamma function, tau is the integral over time, d, erfc is the error function;
and calculating the steam moving distance at different moments to obtain the dynamic position of the front edge of the oil-gas interface in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum.
S4: the dynamic position of the oil-gas interface front at the later stage of lateral movement after the steam encounters the impermeable layer in the formation is calculated.
In a specific embodiment, the distance that the steam moves laterally is calculated by calculating the dynamic position of the hydrocarbon interface front at the later stage of lateral movement after the steam encounters the impermeable layer in the formation by:
Wherein: x 2 is the distance of the lateral movement of the steam at the later stage of the lateral movement after the steam encounters the impermeable layer in the formation, m; q 1 is the amount of latent heat released by steam per unit horizontal well length in time t at the later stage of lateral movement after the steam encounters an impermeable layer in the formation, J/m; ζ 1 is an intermediate parameter; The average moving speed of the steam in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum is m/d; t 1 is the total time that the steam has elapsed during the early stages of lateral movement after encountering an impermeable layer in the formation, d; h d is the distance from the production well to the impermeable layer, m; lambda d is the thermal conductivity of the impermeable layer, J/(m.d. ℃ C.); ρ d is the density of the impermeable layer, kg/m 3;cd is the specific heat capacity of the impermeable layer, J/(kg·deg.C);
and calculating the steam moving distance at different moments to obtain the dynamic position of the front edge of the oil-gas interface in the later stage of the transverse movement after the steam encounters the impermeable layer in the stratum.
S5: and calculating the dynamic position of the front edge of the oil-gas interface in the second vertical movement stage of the steam.
In a specific embodiment, when calculating the dynamic position of the leading edge of the oil-gas interface in the second vertical movement stage of steam, the vertical movement distance of steam is calculated by the following formula:
Wherein: h 2 is the distance of the steam vertical movement in the second vertical movement stage of the steam, and m; q L3 is the total heat loss consumed by steam movement per unit horizontal well length in the second vertical movement stage of steam, J/(m·d); t 2 is the total time that the vapor undergoes in the early and late stages of lateral movement after encountering an impermeable layer in the formation, d;
and calculating the steam moving distances at different moments to obtain the dynamic position of the front edge of the oil-gas interface in the second vertical steam moving stage.
S6: the dynamic position of the front of the hydrocarbon interface at the early stage of the steam movement along the cover layer is calculated.
In a specific embodiment, the distance that the steam moves laterally is calculated by calculating the dynamic position of the leading edge of the hydrocarbon interface at a previous stage of the steam moving laterally along the cap layer by:
Wherein: x 3 is the distance that the vapor moves laterally along the cap layer during the early stage of the lateral movement of the vapor, m; h is the production well to cap distance, m; q L4 is the total heat loss consumed by steam movement per unit horizontal well length at the early stage of steam movement across the cap layer, J/(m·d);
And calculating the steam moving distances at different moments to obtain the dynamic position of the front edge of the oil-gas interface of the steam at the earlier stage of the lateral movement of the reservoir.
S7: the dynamic position of the front of the hydrocarbon interface at the later stage of the steam movement along the cover layer is calculated.
In a specific embodiment, when calculating the dynamic position of the vapor along the hydrocarbon interface front at the later stage of lateral movement of the cap layer, the distance of lateral movement of the vapor is calculated by:
wherein: x 4 is the distance that the vapor moves laterally along the vapor at the later stage of the lateral movement of the cap layer, m; q 2 is the amount of latent heat released by steam per unit horizontal well length in the later stage of the steam traverse along the overburden, J/m; ζ 2 is an intermediate parameter; The average moving speed of the steam in the earlier stage of the steam moving transversely along the cover layer is m/d; t 3 is the total time that the vapor has elapsed during the early stages of its lateral movement along the cap layer, d; lambda cap is the thermal conductivity of the cap layer, J/(m.d. ℃ C.); ρ cap is the density of the cap layer, kg/m 3;ccap is the specific heat capacity of the cap layer, J/(kg·deg.C);
And calculating the steam moving distances at different moments to obtain the dynamic position of the front edge of the oil-gas interface of the steam at the later stage of the lateral movement of the reservoir.
S8: and calculating the dynamic position of the front edge of the oil-gas interface in the steam downward movement stage.
In a specific embodiment, when calculating the dynamic position of the leading edge of the hydrocarbon interface during the steam down movement phase, the distance that the steam moves down is calculated by:
Wherein: y is the distance of downward movement of steam in the downward movement stage of steam, and m; q is the oil yield per unit horizontal well length in the steam downward moving stage, and m 3/(m.d); phi is porosity, dimensionless; Δs o is the change in oil saturation, dimensionless; w c is the width of the impermeable layer, m;
And calculating the steam moving distances at different moments to obtain the dynamic position of the front edge of the oil-gas interface in the steam downward moving stage.
S9: and (3) obtaining a dynamic position change result of the steam at the front edge of the oil-gas interface in the whole reservoir moving process according to the calculation results of the steps S2-S8.
In a specific embodiment, the rate of latent heat released by steam per unit length of horizontal well is calculated by:
Wherein: lambda is the dryness of the steam,%; q s is the steam injection rate, kg/d; h s is the latent heat of steam, J/kg; l is the horizontal segment length, m.
In a specific embodiment, the rate of heat loss of the latent heat released by the steam for heating the rock matrix, crude oil and bound water is calculated by the following formula:
ΔSo＝Soi-Sor (13)
Wherein: ρ o is the crude oil density, kg/m 3;Ar is the heat absorption rate of the rock skeleton per unit horizontal well length, J/(m.kg); a o is the heat absorption rate of crude oil in unit horizontal well length, J/(m.kg); a wc is the heat absorption rate of water bound by the length of a unit horizontal well, J/(m.kg); ρ r is the rock density, kg/m 3;cr is the specific heat capacity of the rock, J/(kg·deg.C); s oi is the initial oil saturation, dimensionless; s or is the saturation of residual oil, and is dimensionless; c o is the specific heat capacity of the crude oil, J/(kg. Deg.C); ρ w is water density, kg/m 3;Swc is irreducible water saturation, dimensionless; c w is the specific heat capacity of water, J/(kg. Deg.C.).
In a specific embodiment, the specific heat at constant pressure is calculated by the following formula:
ψ＝(1-φ)ρrcr+φ(Soρoco+Swρwcw) (16)
Wherein: s o is the saturation of crude oil, and is dimensionless; s w is the saturation of water, dimensionless.
In a specific embodiment, the total heat loss per unit horizontal well length of steam movement consumed at the early stages of lateral movement after the steam encounters an impermeable layer in the formation is calculated by:
qL1＝qa1+qd1 (17)
Wherein: q a1 is the rate of heat loss around the steam per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); q d1 is the latent heat of steam absorbed by the impermeable layer per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); x is distance, m;
The total heat loss consumed by the steam shift per unit horizontal well length for the second vertical shift stage of steam is calculated by:
Wherein: An average velocity, m/d, for the vapor to bypass the impermeable layer;
The total heat loss consumed by steam movement per unit horizontal well length of the earlier stage of steam movement along the overburden is calculated by:
qL4＝qa3+qb1 (22)
Wherein: q a3 is the rate of heat loss around the steam per unit horizontal well length at the early stage of steam lateral movement along the overburden, J/(m·d); q b1 is the latent heat of steam absorbed by the cap layer per unit horizontal well length of the earlier stage of steam movement along the cap layer, J/(m·d).
In a specific embodiment, the amount of latent heat released by steam per unit horizontal well length at time t of the later stage of lateral movement after the steam encounters an impermeable layer in the formation is calculated by:
Wherein: The average steam injection rate of steam in the t time of the later stage of transverse movement after the steam encounters an impermeable layer in the stratum is kg/d; q s,i is the steam injection rate on the ith day of steam, kg/d;
The amount of latent heat released by steam per unit horizontal well length during the t time of the later stage of its lateral movement along the overburden is calculated by:
Wherein: the average steam injection rate of steam, kg/d, is the time t during which the steam moves laterally along the cover layer in the later stage.
In a specific embodiment, the average rate of movement of steam during the early stages of lateral movement after the steam encounters an impermeable layer in the formation is calculated by:
The average vapor movement velocity of the vapor during the early stages of its lateral movement along the cover layer is calculated by the following equation:
in a specific embodiment, the unit horizontal well length oil production for the steam down shift stage is calculated by:
/>
Wherein: k is the effective permeability of the oil reservoir, D; g is gravity acceleration, m/s 2; alpha is the thermal diffusivity of the overburden rock, m 2/d; m is a constant, dimensionless; mu is the viscosity of crude oil and m 2/d.
In a specific embodiment, the constant m in equation (31) takes a value of 4.
It should be noted that, the formulas (10) - (31) are calculation formulas of the preferred parameters of the present invention, and other methods of obtaining the corresponding physical parameters in the prior art may be applicable to the present invention.
In a specific embodiment, taking a certain heavy oil reservoir as an example, the method for determining the front dynamic position of the heavy oil steam-injection thermal oil production gas interface specifically comprises the following steps:
(1) Obtaining basic parameters, thermodynamic parameters, well position parameters and daily steam injection quantity of a target oil reservoir;
in this embodiment, the profile of the target oil reservoir and the well position information are shown in fig. 1, and the obtained parameter results are shown in tables 1 to 3:
TABLE 1 basic parameters and thermodynamic parameters of target reservoirs
TABLE 2 well site parameters
| Length of horizontal segment L | 377(m) | Well spacing H j | 5.4(m) |
| Production well depth H p | 195.2(m) | Distance H of production well to overburden | 31.8(m) |
| Well depth H of steam injection well i | 189.8(m) | Distance H of production well to impermeable layer d | 11.5(m) |
| Drainage boundary W | 50(m) | - | - |
In table 2, the well depth of the production well, the well depth of the steam injection well, the drainage boundary and the well spacing are all parameters required for introducing the well structure, and the parameters are not used in calculating the dynamic position of the front edge of the hydrocarbon interface. In addition, the production well to cap distance is the same parameter as the reservoir thickness, but two different expressions.
TABLE 3 daily steam injection
| Time (d) | 2016/7/10 | 2016/7/11 | 2016/7/12 | … | 2023/12/18 | 2023/12/19 | 2023/12/20 |
| Steam injection rate q s (kg/d) | 47.2 | 47.2 | 47.2 | … | 138 | 120 | 138 |
In this embodiment, the steam vertical movement stage is S 1, and the vertical movement distance h 1; the earlier stage of the transverse movement of the steam after encountering the impermeable layer in the stratum is S 2 -1, and the distance of the transverse movement is x 1; the later stage of the transverse movement of the steam after encountering the impermeable layer in the stratum is S 2 -2, and the distance of the transverse movement is x 2; the second vertical movement stage of the steam is recorded as S 3, and the vertical movement distance is h 2; the earlier stage of the lateral movement of the vapor along the cap layer is S 4 -1, the distance of lateral movement is x 3; the later stage of the lateral movement of the vapor along the cap layer is S 4 -2, the distance of lateral movement is x 4; the downward moving stage of the steam is S 5, and the downward moving distance is y; t 1 is the total time elapsed during stage S 2 -1; t 2 is the total time elapsed for the two phases S 2 -1 and S 2 -2; t 3 is the total time elapsed during stage S 4 -1, and t 1、t2、t3 is provided by on-site combined temperature monitoring data or numerical simulation, and the results are shown in Table 4:
TABLE 4 stage time
| Total time t 1 (d) elapsed during stage S 2 -1 | Total time t 2 (d) elapsed for two phases S 2 -1 and S 2 -2 | Total time t 3 (d) elapsed during stage S 4 -1 |
| 137 | 525 | 468 |
(2) Calculating the dynamic position of the front edge of the oil-gas interface in the stage S 1;
1) calculating the rock matrix heat absorption rate per unit horizontal well length according to formulas (12) - (13):
ΔSo＝Soi-Sor＝0.749-0.30＝0.449 (32)
2) Calculating the heat absorption rate of crude oil per unit horizontal well length according to formula (14):
3) Calculating the constrained water heat absorption rate per unit horizontal well length according to formula (15):
4) The rate of heat loss of the latent heat released by the steam for heating the rock matrix, crude oil and bound water is calculated according to equation (11):
5) Calculating a rate at which latent heat of steam release per unit horizontal well length is obtained according to formula (10);
6) And (3) calculating according to the formula (1) to obtain the vertical moving distances of the steam at different moments in the S 1 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 1 stage shown in FIG. 2.
(3) Calculating the dynamic position of the front edge of the oil-gas interface in the S 2 -1 stage;
1) Calculating a rate at which latent heat of steam release per unit horizontal well length is obtained according to formula (10);
2) Calculating according to the formula (16) to obtain constant-pressure specific heat;
3) Calculating according to the formula (18) to obtain the heat loss rate around the steam of the unit horizontal well length in the S 2 -1 stage;
4) Obtaining the latent heat of steam absorbed by the impermeable layer of the unit horizontal well length in the S 2 -1 stage according to the formula (19);
5) Calculating according to the formula (17) to obtain total heat loss consumed by steam movement per unit horizontal well length in the S 2 -1 stage;
6) And (3) calculating according to the formula (2) to obtain the distances of the steam transverse movement at different moments in the S 2 -1 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 2 -1 stage shown in figure 3.
(4) Calculating the dynamic position of the front edge of the oil-gas interface in the S 2 -2 stage;
1) Calculating according to a formula (26) to obtain the average steam injection rate of steam in the t time of the S 2 -2 stage;
2) Calculating and obtaining the amount of the latent heat released by steam in unit horizontal well length in the t time of the S 2 -2 stage according to the formula (25);
3) Calculating according to the formula (29) to obtain the average moving speed of the steam in the S 2 -1 stage;
4) And (3) calculating according to formulas (3) - (4) to obtain the distances of the steam transverse movement at different moments in the S 2 -2 stage, and drawing to obtain the dynamic position change diagram of the oil-gas interface front edge in the S 2 -2 stage shown in figure 4.
(5) Calculating the dynamic position of the front edge of the oil-gas interface in the stage S 3;
1) Calculating a rate at which latent heat of steam release per unit horizontal well length is obtained according to formula (10);
2) Calculating an average rate of vapor bypassing the impermeable layer according to equation (21);
3) Calculating and obtaining total heat loss consumed by steam movement per unit horizontal well length in the S 3 stage according to a formula (20);
4) And (3) calculating according to the formula (5) to obtain the vertical moving distances of the steam at different moments in the S 3 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 3 stage shown in FIG. 5.
(6) Calculating the dynamic position of the front edge of the oil-gas interface in the S 4 -1 stage;
1) Calculating a rate at which latent heat of steam release per unit horizontal well length is obtained according to formula (10);
2) Calculating according to the formula (23) to obtain the heat loss rate around the steam of the unit horizontal well length in the S 4 -1 stage;
3) Obtaining the latent heat of steam absorbed by the cover layer of unit horizontal well length in the S 4 -1 stage according to the calculation of the formula (24);
4) Calculating and obtaining total heat loss consumed by steam movement per unit horizontal well length in the S 4 -1 stage according to the formula (22);
5) And (3) calculating according to the formula (6) to obtain the distances of the steam transverse movement at different moments in the S 4 -1 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 4 -1 stage shown in FIG. 6.
(7) Calculating the dynamic position of the front edge of the oil-gas interface in the S 4 -2 stage;
1) Calculating according to a formula (28) to obtain the average steam injection rate of steam in the t time of the S 4 -2 stage;
2) Calculating and obtaining the amount of the latent heat released by steam in unit horizontal well length in the t time of the S 4 -2 stage according to the formula (27);
3) Calculating according to the formula (30) to obtain the average moving speed of the steam in the S 4 -1 stage;
4) And (3) calculating according to the formula (7) to obtain the distances of the steam transverse movement at different moments in the S 4 -2 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 4 -2 stage shown in FIG. 7.
(8) Calculating the dynamic position of the front edge of the oil-gas interface in the stage S 5;
1) Calculating according to the formula (31) to obtain the unit horizontal well length oil yield in the S 5 stage;
2) And (3) calculating according to the formula (9) to obtain the downward moving distances of the steam at different moments in the S 5 stage, and drawing to obtain the dynamic position change diagram of the front edge of the oil-gas interface in the S 5 stage shown in FIG. 8.
(9) And (3) according to the calculation results of the steps (2) - (8), obtaining a dynamic position change diagram of the front edge of the oil-gas interface of the steam in the whole reservoir moving process as shown in fig. 9.
In conclusion, the method can accurately determine the front dynamic position of the thick oil steam injection thermal oil extraction gas interface. Compared with the prior art, the invention has obvious progress.
The present invention is not limited to the above-mentioned embodiments, but is intended to be limited to the following embodiments, and any modifications, equivalents and modifications can be made to the above-mentioned embodiments without departing from the scope of the invention.
Claims (10)
1. A method for determining the dynamic position of the front edge of a thickened oil steam injection thermal oil extraction gas interface is characterized by comprising the following steps:
s1: obtaining basic parameters, thermodynamic parameters, well position parameters and daily steam injection quantity of a target oil reservoir;
S2: calculating the dynamic position of the front edge of the oil-gas interface in the vertical movement stage of steam;
S3: calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum;
S4: calculating the dynamic position of the front edge of the oil-gas interface in the later stage of transverse movement after the steam encounters the impermeable layer in the stratum;
S5: calculating the dynamic position of the front edge of the oil-gas interface in the second vertical movement stage of steam;
S6: calculating the dynamic position of the front edge of the oil-gas interface at the early stage of the transverse movement of the steam along the cover layer;
S7: calculating the dynamic position of the front edge of the oil-gas interface at the later stage of the transverse movement of the steam along the cover layer;
S8: calculating the dynamic position of the front edge of the oil-gas interface in the downward movement stage of steam;
S9: and (3) obtaining a dynamic position change result of the steam at the front edge of the oil-gas interface in the whole reservoir moving process according to the calculation results of the steps S2-S8.
2. The method of determining the dynamic position of the front edge of a thick oil steam injection thermal gas interface according to claim 1, wherein in step S1, the basic parameters include reservoir thickness, porosity, effective permeability of the reservoir, initial oil saturation, residual oil saturation, irreducible water saturation, rock density, crude oil density, water density, crude oil viscosity, and density of impermeable layer;
The thermodynamic parameters comprise the specific heat capacity of rock, the specific heat capacity of crude oil, the specific heat capacity of water, the heat conductivity coefficient of a cover layer, the heat conductivity coefficient of an impermeable layer, the specific heat capacity of the cover layer, the dryness of steam, the initial reservoir temperature, the steam temperature, the latent heat of steam and the thermal diffusivity;
The well location parameters include horizontal leg length, production well depth, steam injection well depth, drainage boundary, well spacing, production well to overburden distance, production well to impermeable layer distance.
3. The method for determining the dynamic position of the front edge of the gas interface of the thick oil steam injection thermal recovery according to claim 1, wherein in step S2, when calculating the dynamic position of the front edge of the gas-oil interface in the vertical movement stage of the steam, the vertical movement distance of the steam is calculated by the following formula:
wherein: h 1 is the vertical movement distance of the steam in the vertical movement stage of the steam, and m; q in is the rate of latent heat release by steam per unit horizontal well length, J/(m·d); t is time, d; beta is a constant and dimensionless; The latent heat released for steam is used to heat the rock matrix, crude oil and bound water at a heat loss rate, J/m 4;
in step S3, when calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the lateral movement after the steam encounters the impermeable layer in the stratum, the distance of the lateral movement of the steam is calculated by the following formula:
Wherein: x 1 is the distance of the lateral movement of the vapor at the early stage of the lateral movement after the vapor encounters the impermeable layer in the formation, m; psi is specific heat at constant pressure, J/(m 3·℃);Ts) is steam temperature, DEG C, T r is initial reservoir temperature, DEG C, q L1 is total heat loss consumed by steam movement per unit horizontal well length in the early stage of lateral movement after the steam encounters an impermeable layer in the formation,
J/(m.d); f () is a gamma function; τ is the integral over time, d; erfc is the error function;
In step S4, when calculating the dynamic position of the front edge of the oil-gas interface in the later stage of the lateral movement after the steam encounters the impermeable layer in the stratum, the distance of the lateral movement of the steam is calculated by the following formula:
Wherein: x 2 is the distance of the lateral movement of the steam at the later stage of the lateral movement after the steam encounters the impermeable layer in the formation, m; q 1 is the amount of latent heat released by steam per unit horizontal well length in time t at the later stage of lateral movement after the steam encounters an impermeable layer in the formation, J/m; ζ 1 is an intermediate parameter; The average moving speed of the steam in the early stage of the transverse movement after the steam encounters the impermeable layer in the stratum is m/d; t 1 is the total time that the steam has elapsed during the early stages of lateral movement after encountering an impermeable layer in the formation, d; h d is the distance from the production well to the impermeable layer, m; lambda d is the thermal conductivity of the impermeable layer, J/(m.d. ℃ C.); ρ d is the density of the impermeable layer, kg/m 3;cd is the specific heat capacity of the impermeable layer, J/(kg·deg.C);
In step S5, when calculating the dynamic position of the front edge of the oil-gas interface in the second vertical movement stage of steam, the vertical movement distance of steam is calculated by the following formula:
Wherein: h 2 is the distance of the steam vertical movement in the second vertical movement stage of the steam, and m; q L3 is the total heat loss consumed by steam movement per unit horizontal well length in the second vertical movement stage of steam, J/(m·d); t 2 is the total time that the vapor undergoes in the early and late stages of lateral movement after encountering an impermeable layer in the formation, d;
in step S6, when calculating the dynamic position of the front edge of the oil-gas interface in the early stage of the steam lateral movement along the cover layer, the distance of the steam lateral movement is calculated by the following formula:
Wherein: x 3 is the distance that the vapor moves laterally along the cap layer during the early stage of the lateral movement of the vapor, m; h is the production well to cap distance, m; q L4 is the total heat loss consumed by steam movement per unit horizontal well length at the early stage of steam movement across the cap layer, J/(m·d);
in step S7, when calculating the dynamic position of the steam along the front edge of the oil-gas interface in the later stage of the lateral movement of the cover layer, the distance of the lateral movement of the steam is calculated by the following formula:
wherein: x 4 is the distance that the vapor moves laterally along the vapor at the later stage of the lateral movement of the cap layer, m; q 2 is the amount of latent heat released by steam per unit horizontal well length in the later stage of the steam traverse along the overburden, J/m; ζ 2 is an intermediate parameter; The average moving speed of the steam in the earlier stage of the steam moving transversely along the cover layer is m/d; t 3 is the total time that the vapor has elapsed during the early stages of its lateral movement along the cap layer, d; lambda cap is the thermal conductivity of the cap layer, J/(m.d. ℃ C.); ρ cap is the density of the cap layer, kg/m 3;ccap is the specific heat capacity of the cap layer, J/(kg·deg.C);
in step S8, when calculating the dynamic position of the front edge of the oil-gas interface in the steam downward movement stage, the distance of the steam downward movement is calculated by the following formula:
Wherein: y is the distance of downward movement of steam in the downward movement stage of steam, and m; q is the oil yield per unit horizontal well length in the steam downward moving stage, and m 3/(m.d); phi is porosity, dimensionless; Δs o is the change in oil saturation, dimensionless; w c is the width of the impermeable layer, m;
In the steps S2-S8, the dynamic position of the front edge of the oil-gas interface of the steam movement in each step can be obtained by calculating the steam movement distances at different moments.
4. A method of determining the dynamic position of the front of a thickened oil vapor thermal recovery gas interface as claimed in claim 3 wherein the rate of latent heat released by vapor per unit length of horizontal well is calculated by:
Wherein: lambda is the dryness of the steam,%; q s is the steam injection rate, kg/d; h s is the latent heat of steam, J/kg; l is the horizontal segment length, m.
5. A method of determining the dynamic position of the front edge of a thick oil steam-injected thermal oil production gas interface as claimed in claim 3, wherein the rate of heat loss of the latent heat released by steam for heating the rock skeleton, crude oil and bound water is calculated by the following equation:
ΔSo＝Soi-Sor (13)
Wherein: ρ o is the crude oil density, kg/m 3;Ar is the heat absorption rate of the rock skeleton per unit horizontal well length, J/(m.kg); a o is the heat absorption rate of crude oil in unit horizontal well length, J/(m.kg); a wc is the heat absorption rate of water bound by the length of a unit horizontal well, J/(m.kg); ρ r is the rock density, kg/m 3;cr is the specific heat capacity of the rock, J/(kg·deg.C); s oi is the initial oil saturation, dimensionless; s or is the saturation of residual oil, and is dimensionless; c o is the specific heat capacity of the crude oil, J/(kg. Deg.C); ρ w is water density, kg/m 3;Swc is irreducible water saturation, dimensionless; c w is the specific heat capacity of water, J/(kg. Deg.C.).
6. The method for determining the dynamic position of the front edge of the thick oil steam injection thermal oil production gas interface according to claim 3, wherein the constant pressure specific heat is calculated by the following formula:
ψ＝(1-φ)ρrcr+φ(Soρoco+Swρwcw) (16)
Wherein: ρ r is the rock density, kg/m 3;cr is the specific heat capacity of the rock, J/(kg·deg.C); s o is the saturation of crude oil, and is dimensionless; ρ o is the crude oil density, kg/m 3;co is the specific heat capacity of the crude oil, J/(kg·deg.C); s w is the saturation of water, dimensionless; ρ w is water density, kg/m 3;cw is specific heat capacity of water, J/(kg·deg.C).
7. A method of determining the dynamic position of the front of a thick oil steam-injected thermal recovery gas interface as defined in claim 3, wherein the total heat loss per horizontal well length steam movement at the early stage of lateral movement after the steam encounters the impermeable layer in the formation is calculated by:
qL1＝qa1+qd1 (17)
Wherein: q a1 is the rate of heat loss around the steam per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); q d1 is the latent heat of steam absorbed by the impermeable layer per unit horizontal well length at the early stage of lateral movement after the steam encounters the impermeable layer in the formation, J/(m·d); x is distance, m;
The total heat loss consumed by the steam shift per unit horizontal well length for the second vertical shift stage of steam is calculated by:
Wherein: An average velocity, m/d, for the vapor to bypass the impermeable layer;
The total heat loss consumed by steam movement per unit horizontal well length of the earlier stage of steam movement along the overburden is calculated by:
qL4＝qa3+qb1 (22)
Wherein: q a3 is the rate of heat loss around the steam per unit horizontal well length at the early stage of steam lateral movement along the overburden, J/(m·d); q b1 is the latent heat of steam absorbed by the cap layer per unit horizontal well length of the earlier stage of steam movement along the cap layer, J/(m·d).
8. A method of determining the dynamic position of the front edge of a thick oil steam-injected thermal recovery gas interface as defined in claim 3, wherein the amount of latent heat released by steam per horizontal well length at time t in the later stage of lateral movement after the steam encounters the impermeable layer in the formation is calculated by:
Wherein: lambda is the dryness of the steam,%; The average steam injection rate of steam in the t time of the later stage of transverse movement after the steam encounters an impermeable layer in the stratum is kg/d; q s,i is the steam injection rate on the ith day of steam, kg/d;
The amount of latent heat released by steam per unit horizontal well length during the t time of the later stage of its lateral movement along the overburden is calculated by:
Wherein: l is the length of the horizontal segment, m; the average steam injection rate of steam, kg/d, is the time t during which the steam moves laterally along the cover layer in the later stage.
9. A method of determining the dynamic position of the front of a thick oil steam-injected thermal recovery gas interface as defined in claim 3, wherein the average rate of movement of steam during the early stages of lateral movement of the steam after encountering an impermeable layer in the formation is calculated by:
The average vapor movement velocity of the vapor during the early stages of its lateral movement along the cover layer is calculated by the following equation:
10. a method of determining the dynamic position of the front edge of a thickened oil steam injection thermal oil recovery gas interface as claimed in claim 3, wherein the unit horizontal well length oil production during the steam down shift stage is calculated by the following equation:
Wherein: k is the effective permeability of the oil reservoir, D; g is gravity acceleration, m/s 2; alpha is the thermal diffusivity of the overburden rock, m 2/d; m is a constant, dimensionless; mu is the viscosity of crude oil and m 2/d.
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