CN115163015A - Method and device for regulating and controlling later-period yield of super-thick oil steam flooding and electronic equipment - Google Patents
Method and device for regulating and controlling later-period yield of super-thick oil steam flooding and electronic equipment Download PDFInfo
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- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
Abstract
The invention discloses a method for regulating and controlling the later-stage yield of super heavy oil steam flooding, which comprises the following steps: obtaining a wellbore heat loss calculation parameter and a bottom hole fluid actual measurement pressure of a production well; determining the bottom hole effluent temperature of the production well according to the wellbore heat loss calculation parameters; determining the corresponding bottom hole saturated steam temperature according to the measured bottom hole fluid pressure; determining a saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature; and regulating and controlling the later-period yield of the super-heavy oil steam flooding according to the saturated temperature difference. The regulation and control method can obviously improve the steam flooding efficiency and ensure the stability of the later-stage yield of the super-heavy oil steam flooding.
Description
Technical Field
The application relates to the technical field of steam flooding super-heavy oil exploitation, in particular to a method and a device for regulating and controlling super-heavy oil steam flooding yield and electronic equipment.
Background
The technology of super heavy oil (the viscosity of ground degassed crude oil at 50 ℃ is more than 50000mpa.s) is the next step of the steam huff and puff later period of primary oil recovery. However, because the crude oil viscosity of the super heavy oil reservoir in the original state is higher and far exceeds the steam flooding screening standard (< 10000 mpa.s), the technology is always in the indoor research and field test stage. In recent years, with the continuous decrease of petroleum exploration resources and the continuous deterioration of the quality of exploited oil reservoirs, researchers have increased the research strength on ultra-heavy oil steam flooding, and the success of field tests on ultra-heavy oil steam flooding (> 50000mpa.s (millipascal seconds, viscosity unit)) is achieved, so that the reservoir engineering design method is mastered. Meanwhile, the method realizes breakthrough on the later-stage regulation and control method of the super-thick oil steam flooding, realizes stable yield, stable water content and 0.03-0.06 oil-steam ratio improvement by regulating and controlling the later-stage yield of the super-thick oil steam flooding by utilizing the flow saturation temperature difference limit, and improves the economy of the super-thick oil steam flooding.
Some current prior arts provide methods for exploiting ultra-heavy oil reservoirs by steam flooding, for example, CN102278103A discloses a method for enhancing deep ultra-heavy oil reservoir recovery by gravity drainage assisted steam flooding, in which method the deep massive ultra-heavy oil reservoir recovery is enhanced by exploiting gravity drainage assisted steam flooding. CN101852074A discloses a mining method and a system for a layered super heavy oil reservoir, according to the characteristics of a multi-layer oil reservoir, a plurality of bottom wells are adopted for steam huff and puff, a plurality of branch wells are sidedly drilled in a main shaft to deeply enter each oil layer of the oil reservoir, the whole mining range is subjected to three-dimensional comprehensive heating, as large as possible steam swept areas are formed under the cooperation of a central steam injection well, the mobility of super heavy oil is improved, the oil-water mobility ratio is improved, and the problems that the layered super heavy oil is high in viscosity, difficult to drive and small in steam sweeping range are solved.
However, in the later development period of the super heavy oil, the problems of low steam flooding efficiency, low annual oil production of well groups, low oil production speed and the like occur. The prior art is lack of a regulation and control scheme for the later-stage output of the super-thick oil steam flooding so as to improve the steam flooding efficiency of the super-thick oil steam flooding in the later stage.
Disclosure of Invention
The invention provides a method and a device for regulating and controlling the later-stage yield of an ultra-thick oil steam flooding and electronic equipment, which are used for improving the later-stage steam flooding efficiency of the ultra-thick oil steam flooding and ensuring the later-stage yield.
In order to solve the technical problem, a first aspect of the embodiments of the present invention provides a method for regulating and controlling a late-stage yield of an ultra-thick oil steam flooding, including:
obtaining a wellbore heat loss calculation parameter and a bottom hole fluid actual measurement pressure of a production well;
determining the bottom hole effluent liquid temperature of a production well according to the heat loss calculation parameters of the shaft;
determining the corresponding bottom hole saturated steam temperature according to the measured pressure of the bottom hole fluid;
determining a saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature;
and regulating and controlling the later-stage yield of the super-heavy oil steam flooding according to the flow saturation temperature difference.
Optionally, the adjusting and controlling the later-stage yield of the super heavy oil steam flooding according to the saturated temperature difference comprises:
if the flow saturation temperature difference is lower than 30 ℃, adjusting the thrust of a liquid outlet pump of the production well and/or adjusting the extraction-injection ratio of steam flooding so that the flow saturation temperature difference is not lower than 30 ℃.
Optionally, the wellbore heat loss calculation parameters include a wellbore size parameter, a wellbore heat transfer parameter, and an injected steam parameter;
the size parameters of the shaft comprise the length of the shaft and at least one of the inner diameter of an oil pipe, the outer diameter of the oil pipe, the outer diameter of a heat insulation oil pipe, the inner diameter of a casing, the outer diameter of the casing and the outer diameter of a cement sheath;
the wellbore heat conduction parameter comprises at least one of formation heat diffusion coefficient, formation heat conductivity coefficient, cement sheath heat conductivity coefficient and heat insulation oil pipe heat conductivity coefficient;
the injected steam parameters include steam ground temperature and steam ground dryness.
Optionally, before the determining a bottom-hole effluent temperature of the production well according to the calculated parameter of the heat loss of the wellbore, the control method further includes:
obtaining a range of injection steam rates and a range of injection steam pressures;
determining a bottom hole steam quality data set at different injection steam rates and different injection steam pressures based on the injection steam rate range, the injection steam pressure range, and the wellbore heat loss calculation parameters;
determining a target injection steam rate and a target injection steam pressure from the downhole steam quality dataset.
Optionally, the determining a bottom-hole effluent temperature of the production well according to the wellbore heat loss calculation parameter includes:
determining a total conductivity coefficient of the shaft according to the size parameter of the shaft and the heat conduction parameter of the shaft;
determining wellbore heat loss based on the wellbore size parameter, the wellbore total conductivity coefficient, and the steam surface temperature;
determining a theoretical bottom-hole steam quality of the steam injection well according to the steam ground quality, the heat loss of the shaft and the target steam injection rate;
and when the difference value between the actually measured bottom-hole steam dryness and the theoretical bottom-hole steam dryness is smaller than a set value, determining the bottom-hole effluent temperature according to the heat loss of the shaft, or determining the bottom-hole effluent temperature according to the total conductivity coefficient of the shaft.
Optionally, the determining the bottom hole effluent temperature according to the wellbore heat loss comprises:
obtaining the temperature of a wellhead effluent of a production well;
and determining a bottom-hole effluent calculated temperature according to the wellhead effluent temperature, the heat loss of the mineshaft and the length of the mineshaft, and taking the bottom-hole effluent calculated temperature as the bottom-hole effluent temperature.
Optionally, the determining the bottom hole flowing liquid temperature according to the total conductivity of the wellbore comprises:
obtaining the liquid production amount, the liquid water content, the air cavity pressure and the wellhead effluent temperature of the production well in unit time;
and determining the calculation temperature of the bottom-hole effluent according to the total conductivity coefficient of the shaft, the temperature of the top-hole effluent, the liquid production amount per unit time, the water content of the liquid and the pressure of the air cavity, and taking the calculation temperature of the bottom-hole effluent as the temperature of the bottom-hole effluent.
Optionally, the calculating the temperature of the bottom hole effluent as the temperature of the bottom hole effluent comprises:
obtaining the measured temperature of the bottom-hole effluent;
and when the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid tend to be consistent, taking the calculated temperature of the bottom-hole effluent liquid as the temperature of the bottom-hole effluent liquid.
Based on the same inventive concept, a second aspect of the embodiments of the present invention provides a device for regulating and controlling the late-stage yield of super heavy oil steam flooding, including:
the acquisition module is used for acquiring a wellbore heat loss calculation parameter of a production well and a bottom hole fluid actual measurement pressure;
the first determination module is used for determining the bottom hole effluent liquid temperature of the production well according to the heat loss calculation parameters of the shaft;
the second determination module is used for determining the corresponding bottom hole saturated steam temperature according to the measured pressure of the bottom hole fluid;
the third determination module is used for determining the flow saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature;
and the regulation and control module is used for regulating and controlling the later-period yield of the super-thick oil steam flooding according to the saturated temperature difference.
Based on the same inventive concept, a third aspect of the embodiments of the present invention provides an electronic device, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor, and the processor implements the steps of the regulation method according to any one of the first aspects when executing the computer program.
Through one or more technical schemes of the invention, the invention has the following beneficial effects or advantages:
the invention provides a method for regulating and controlling the later-period output of a super-heavy oil steam flooding, which is characterized in that the bottom-hole effluent liquid temperature and the bottom-hole saturated steam temperature of a production well are respectively determined, then the flow saturation temperature difference of the production well is determined based on the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature, a reasonable flow saturation temperature difference control limit can be established through the flow saturation temperature difference, and steam breakthrough is prevented; the flow saturation temperature difference is utilized to dynamically regulate and control the super-heavy oil steam flooding yield, the water content can be kept unchanged and the oil-steam ratio can be improved while the steam injection amount of a well group is effectively reduced, so that the steam flooding efficiency is obviously improved, and the stability of the later yield of the super-heavy oil steam flooding is ensured.
The foregoing description is only an overview of the technical solutions of the present invention, and the embodiments of the present invention are described below in order to make the technical means of the present invention more clearly understood and to make the above and other objects, features, and advantages of the present invention more clearly understandable.
Drawings
Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Also, like reference numerals are used to refer to like parts throughout the drawings.
In the drawings:
FIG. 1 is a flow chart of a method for controlling the late-stage production of an ultra-thick oil steam flooding according to an embodiment of the invention;
FIG. 2 shows a schematic representation of a wellbore configuration according to one embodiment of the invention;
FIG. 3 illustrates a wellhead steam quality profile for a steam flooding block at different injection steam pressures, in accordance with one embodiment of the present invention;
FIG. 4 illustrates a steam quality profile at different injected steam rates according to one embodiment of the present invention;
FIG. 5 illustrates a variation of injection steam pressure at different injection steam rates according to an embodiment of the present invention;
FIG. 6 shows a table of downhole effluent temperature data at different depths in accordance with an embodiment of the present invention;
FIG. 7 is a schematic diagram of a device for controlling the late stage production of an ultra-thick oil steam flooding according to an embodiment of the invention;
FIG. 8 shows a schematic diagram of an electronic device according to one embodiment of the invention.
Detailed Description
In order to make the present application more clearly understood by those skilled in the art to which the present application pertains, the following detailed description of the present application is made with reference to the accompanying drawings by way of specific embodiments. Throughout the specification, unless otherwise specifically noted, terms used herein should be understood as having meanings as commonly used in the art. Accordingly, unless defined otherwise, 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 invention belongs. If there is a conflict, the present specification will control. Unless otherwise specifically indicated, various devices and the like used in the present invention may be commercially available or may be prepared by existing methods.
In the middle and later stages of the development of the ultra-thick oil steam flooding, the water content of the oil production of the well group is more than 85%, the oil-steam ratio is less than 0.12, and the daily oil production of the well group is obviously reduced by more than 10%. In order to improve the steam flooding efficiency at this stage and ensure the oil production of the later well group, in an optional embodiment, as shown in fig. 1, a method for regulating and controlling the later yield of the super heavy oil steam flooding is provided, which includes steps S1 to S5, specifically as follows:
s1: obtaining a wellbore heat loss calculation parameter and a bottom hole fluid actual measurement pressure of a production well;
specifically, the measured downhole fluid pressure is the fluid pressure of downhole production fluid measured and updated at regular intervals on the production well, such as on a daily basis.
And the calculation parameter of the heat loss of the shaft is a calculation parameter required when the heat loss of the shaft is calculated. Wellbore heat loss calculation parameters may be classified by type into wellbore size parameters, wellbore heat transfer parameters, and steam injection parameters. The schematic of the cross section of the wellbore in this embodiment is shown in fig. 2, and the related wellbore heat loss calculation parameters are shown in table 1:
table 1: wellbore heat loss calculation parameters
In some optional embodiments, prior to calculating a bottom hole effluent temperature of the production well, the conditioning method provided in this embodiment may further comprise:
obtaining an injection steam rate range and an injection steam pressure range; determining a bottom hole steam quality data set at different injection steam rates and different injection steam pressures based on the injection steam rate range, the injection steam pressure range, and the wellbore heat loss calculation parameters; determining a target injection steam rate and a target injection steam pressure from the downhole steam quality dataset.
Specifically, the steam quality at the bottom of the well is X j Can be calculated using the following formula:
in the above formula:
X i : steam ground dryness or wellhead steam dryness,%;
M s : rate of injected steam, m 3 D or t/d;
C s : the vaporization latent heat of the wellhead steam is constant, kcal/kg;
and Qs: the rate of heat loss.
The wet steam inevitably has pressure loss and heat loss during the whole flowing process from the steam injection station to the bottom of the well. The heat loss of the well bore is the heat loss of the fluid in the well bore per unit time and unit length. Because unstable heat flow exists under the condition of the steam injection well casing, the calculation formula of the heat loss rate Qs of the steam in the well casing obtained by combining the heat transfer theory is as follows:
in the above formula:
U to : total conductivity of the wellbore, W.m/deg.C;
T s : steam ground temperature, deg.C;
K e : formation thermal conductivity, W.m/deg.C;
b: the temperature of the earth surface (constant temperature layer) is DEG C;
a: geothermal gradient, DEG C/m;
l: wellbore (total) length, m;
The calculation formula of the total conductivity coefficient of the well bore is as follows:
in the above formula:
h c : heat transfer coefficient of heat conduction and natural convection of annular gas, W.m/° C;
h r : the radiation heat transfer coefficient of the annular gas, W.m/DEG C;
K cem : cement sheath thermal conductivity, W.m/deg.C;
K ins : the thermal conductivity of the heat-insulating oil pipe is W.m/DEG C;
r to : the outer radius of the oil pipe, m;
r co : the outer radius of the sleeve, m;
r i : the outer radius of the heat insulation oil pipe, m;
r h : wellbore radius, m.
An example of a downhole steam quality data set is shown in table 1. In table 1, the steam quality of the wellbore at a depth of 998 meters is the steam quality of the bottom hole in this example.
TABLE 2 statistical table of steam quality variation under different injection steam rates and injection steam pressures
As can be seen from table 1, at the same wellhead steam quality and injection steam pressure, the steam quality at the zone of interest 998m increases as the injection steam velocity increases. Moreover, under different steam injection pressures, the steam quality at the well mouth is also different, as shown in fig. 3; meanwhile, the dryness of the steam is reduced along with the increase of the depth, and the smaller the steam injection rate is, the larger the reduction amplitude is; the steam quality of the horizontal section is basically kept constant, the steam quality at the annular space is reduced sharply, and the slope is larger when the steam injection rate is smaller, as shown in fig. 4. For the injection steam pressure, if the injection steam velocity is smaller, the pressure is firstly stable (or slightly increased), the friction resistance in the steam injection pipe column is overcome to reduce, and the pressure at the annular space is kept stable, as shown in fig. 5.
The optimization conditions and the oil reservoir production requirements are comprehensively considered, the target injection steam pressure can be determined to be 3-6 MPa, and the target injection steam rate is 90-120 t/d.
S2: determining the bottom hole effluent temperature of the production well according to the wellbore heat loss calculation parameters;
specifically, an alternative determination method includes steps S21 to S24, which are specifically as follows:
s21: determining a total conductivity coefficient of the shaft by adopting a formula (3) according to the size parameter of the shaft and the heat conduction parameter of the shaft;
s22: determining wellbore heat loss using equation (2) based on the wellbore size parameter, the wellbore total conductivity, and the steam surface temperature;
s23: determining a theoretical bottom-hole steam quality of the steam injection well according to the steam ground quality, the heat loss of the shaft and the target steam injection rate;
wherein, the detailed calculation and derivation processes of the total wellbore conductivity coefficient, the wellbore heat loss and the bottom-hole steam dryness of the S21-S23 can refer to a Master academic thesis: "Sun Nengtao. Steam flooding whole-course heat loss and steam injection parameters are preferably studied, daqing Petroleum institute, 2007", pages 19 to 27, which is not described much in this embodiment.
S24: and when the difference value between the actually measured bottom hole steam quality and the theoretical bottom hole steam quality is smaller than a set value, determining the bottom hole effluent liquid temperature according to the heat loss of the shaft, or determining the bottom hole effluent liquid temperature according to the total conduction coefficient of the shaft.
Specifically, when the difference value between the actually measured bottom-hole steam dryness and the theoretical bottom-hole steam dryness is smaller than a set value, namely the actually measured bottom-hole steam dryness and the theoretical bottom-hole steam dryness tend to be consistent, the calculation of the theoretical bottom-hole steam dryness in the process is accurate, and meanwhile, the calculation of the heat loss of the shaft and the total conduction coefficient of the shaft is also accurate, so that the calculation precision in the subsequent calculation of the temperature of the bottom-hole effluent liquid is ensured. If the measured bottom-hole steam quality is inconsistent with the theoretical bottom-hole steam quality, the heat conduction parameter of the shaft is required to be adjusted to recalculate the heat conduction parameter of the shaft, the heat loss of the shaft and the theoretical bottom-hole steam quality in sequence.
The reason for adopting the heat loss of the shaft to calculate the temperature of the bottom-hole effluent liquid is that the cost for acquiring the temperature of the bottom-hole effluent liquid at the bottom of the shaft is very high, only a few wells can be provided with an acquisition sensor of the temperature of the bottom-hole effluent liquid in a block generally, and data cannot be acquired at any time. This embodiment therefore uses the loss of wellbore heat to calculate the bottom hole effluent temperature.
In determining the bottom hole effluent temperature from wellbore heat loss, two approaches may be used:
scheme I,
Obtaining the temperature of a wellhead effluent of a production well; and determining a bottom-hole effluent calculated temperature according to the wellhead effluent temperature, the heat loss of the mineshaft and the length of the mineshaft, and taking the bottom-hole effluent calculated temperature as the bottom-hole effluent temperature.
In particular, the wellhead effluent temperature is readily measurable and the wellbore heat loss Qs, while representing the heat loss per unit time and length of the wellbore for steam, may also reflect the heat loss of the fluid in the wellbore. Thus, the wellhead effluent temperature, combined with the heat loss of the effluent in the wellbore, can be used to calculate the bottom hole effluent temperature.
Scheme II,
Obtaining the liquid production amount, the liquid water content, the air cavity pressure and the wellhead effluent temperature of the production well in unit time; and determining the calculation temperature of the bottom-hole effluent according to the total conductivity coefficient of the shaft, the temperature of the wellhead effluent, the liquid production amount in unit time, the water content of the liquid and the pressure of the air cavity, and taking the calculation temperature of the bottom-hole effluent as the temperature of the bottom-hole effluent.
The total wellbore conductivity coefficient is calculated in step S21, and the values and values of some parameters used in the calculation process are shown in table 3:
table 3: example of parameters calculated for bottom hole effluent temperature of production well
The method for calculating the temperature of the bottom-hole effluent in the second scheme belongs to the prior art, and can apply a Master academic thesis: the calculation process of the "steam flooding whole-course heat loss and steam injection parameter optimization research of sun Yongtao, daqing Petroleum institute, 2007" iterative algorithm of wellbore temperature and pressure in steam injection process on page 27 "is not described much in this embodiment.
FIG. 6 shows exemplary data calculated for downhole flow rate variation at different depths. In FIG. 6, length is wellbore depth, fluid Temp is effluent temperature, case Temp is Casing temperature, fluid Press is effluent pressure, and Steam Vap is Steam content.
In some alternative embodiments, for wells that are conditionally collecting measured temperature of bottom hole effluent, it may be verified whether the bottom hole effluent calculated temperature is accurate, as follows:
obtaining the measured temperature of the bottom-hole effluent liquid; and when the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid tend to be consistent, taking the calculated temperature of the bottom-hole effluent liquid as the temperature of the bottom-hole effluent liquid.
Specifically, the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid tend to be consistent, namely when the measured temperature of the bottom-hole effluent liquid is equal to the calculated temperature of the bottom-hole effluent liquid or the absolute value of the difference between the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid is smaller than a set value, the calculated temperature of the bottom-hole effluent liquid is consistent with the measured temperature, the calculated temperature of the bottom-hole effluent liquid can be used for calculating the flow saturation temperature difference, and all parameters can be applied to research on the steam flooding production of the super-heavy oil at the current stage in the block. If the calculated temperature does not match the measured temperature, the total conductivity coefficient U of the shaft is recalculated after the heat conduction parameter of the shaft is adjusted to And then, repeating the steps to determine the calculated temperature of the bottom-hole effluent liquid for repeated correction until the calculated temperature of the bottom-hole effluent liquid is consistent with the measured temperature data of the bottom-hole effluent liquid of the measured well in the block, which indicates that all parameters in the calculation process have correct values.
S3: determining the corresponding bottom hole saturated steam temperature according to the measured bottom hole fluid pressure;
specifically, the temperature of the saturated steam at the bottom of the well can be determined according to the measured pressure of the fluid at the bottom of the well and the corresponding relation between the saturated water and the saturated steam.
S4: determining a saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature;
specifically, the flow saturation temperature difference can be obtained by subtracting the temperature of the bottom outflow liquid from the temperature of the bottom saturation steam.
S5: and regulating and controlling the later-period yield of the super-heavy oil steam flooding according to the saturated temperature difference.
Specifically, after the flow saturation temperature difference is obtained, the flow saturation temperature difference limit of the super-heavy oil steam flooding can be determined through repeated tests and verification. Taking a certain steam flooding of a certain oil field as an example, in order to prevent steam breakthrough, the well group adopts the scheme of reducing the liquid discharge amount, increasing the sinking degree, improving the production flow pressure and improving the saturation temperature. When the water content of the well group is more than 88 percent, the saturated temperature difference of the control flow is 10-20 ℃, at the moment, the water content does not rise any more, but the daily oil production of the well group is reduced by 13 percent; regulating the flow saturation temperature difference limit to be 20-30 ℃, reducing the water content by 1-3 percent, increasing the oil-gas ratio by 0.01-0.02, and reducing the daily oil production of a well group by 8-10 percent compared with the daily oil production before regulation, wherein the effect is still not ideal; when the flow saturation temperature difference is adjusted to be more than 30 ℃, the water content is reduced to be less than 85%, the daily oil production of the well group is equal to that before adjustment, the oil-gas ratio is 0.08-0.1 higher than that before adjustment, the injection-production ratio is stabilized to be about 1.2, and the purposes of oil stabilization, gas reduction and cost control are achieved, so that the flow saturation temperature difference is determined to be 30 ℃ by later-stage regulation and control of the super-thick oil steam flooding.
Therefore, in order to adjust the later yield of the ultra-thick oil steam flooding, the saturation temperature of the flow needs to be controlled to be more than 30 ℃, and the method mainly comprises two ways: 1. adjusting the sprint of the liquid outlet pump of the production well according to the flow saturation temperature difference; 2. and adjusting the extraction-injection ratio of the steam flooding according to the flow saturation temperature difference.
For the first time, the spurs are adjusted, the bottom hole flow pressure of the production well is changed by adjusting the liquid supply capacity, when the bottom hole pressure is AMPa, the saturated steam temperature of the corresponding saturated pressure is B ℃, the theoretical liquid column height of the production well is Cm at the moment, the target layer well depth Dm is Dm, the theoretical value of the working fluid level is D-C = Em, but the actual working fluid level is Fm, the actual liquid column height is D-F = Gm at the moment, the spurs are required to be adjusted to enable the working fluid level F to be close to the theoretical value E at the moment, even if the liquid column height G is close to the theoretical value C, and the purpose of adjusting the bottom hole flow pressure of the production well is achieved.
Taking a certain block as an example, when the bottom hole pressure is 2.3MPa, the bottom hole saturated steam temperature of the corresponding saturated pressure is 220 ℃, the theoretical liquid column height of the production well is 300m, the target layer well depth is 950m, the theoretical value of the working fluid level is 950-300=650m, but the actual working fluid level is 700-750 m, which indicates that the actual liquid column height is 200-250 m, and the impulse needs to be adjusted to make the working fluid level approach the theoretical value: the 300m liquid column height is close to the theoretical value. The block is produced by adopting a 57# screw pump, the pump efficiency is 65 percent, the discharge capacity is 66t/d, the liquid production amount of a production well = the maximum discharge capacity of the pump multiplied by the pump efficiency, when the sprint is 4.5-5.5, the flow saturation temperature difference is 10-20 ℃, when the sprint is 3.5-4.5, the flow saturation temperature difference is 20-30 ℃, and when the sprint is 2.5-3.5, the flow saturation temperature difference is more than 30 ℃, so that the bottom hole flowing pressure of the production well can reach a reasonable value by adjusting the sprint to 2.5-3.5, and the later-stage yield of the ultra-thick oil steam flooding is improved.
And for the second step, the injection ratio is adjusted, and the injection ratio can be changed by adjusting the steam injection quantity or the steam injection rate, so that the flow saturation temperature difference reaches a reasonable value. And determining the reasonable well group steam injection amount according to the production-injection ratio, increasing the well group steam injection amount to improve the injection heat, releasing more heat by more latent heat of vaporization in the oil reservoir, raising the temperature and reducing the viscosity, improving the flow saturation temperature difference value, and improving the later-stage yield of the super-heavy oil steam drive. However, in the later period of the ultra-thick oil steam flooding, attention needs to be paid to channeling prevention, and the development effect cannot be pursued simply to increase the steam injection amount.
It should be noted that the sprint and injection ratio can be adjusted individually or in combination, which is not limited in this respect.
Generally speaking, the embodiment provides a method for regulating and controlling the later-period yield of the super-heavy oil steam flooding, which comprises the steps of respectively determining the temperature of bottom-hole effluent liquid of a production well and the temperature of bottom-hole saturated steam, then determining the flow saturation temperature difference of the production well based on the temperature of the bottom-hole saturated steam and the temperature of the bottom-hole effluent liquid, and establishing a reasonable flow saturation temperature difference control limit through the flow saturation temperature difference to prevent steam breakthrough; the flow saturation temperature difference is utilized to dynamically regulate and control the super-heavy oil steam flooding yield, the water content can be kept unchanged and the oil-steam ratio can be improved while the steam injection amount of a well group is effectively reduced, so that the steam flooding efficiency is obviously improved, and the stability of the later yield of the super-heavy oil steam flooding is ensured.
Based on the same inventive concept of the previous embodiment, in another alternative embodiment, as shown in fig. 7, there is provided a device for controlling the late production of super heavy oil steam flooding, comprising:
the acquisition module 10 is used for acquiring the heat loss calculation parameters of a shaft of the production well and the actually measured pressure of bottom fluid;
the first determining module 20 is used for determining the bottom hole effluent liquid temperature of a production well according to the calculated parameters of the heat loss of the shaft;
the second determination module 30 is configured to determine a corresponding bottom hole saturated steam temperature according to the measured bottom hole fluid pressure;
a third determination module 40, configured to determine a saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent temperature;
and the regulation and control module 50 is used for regulating and controlling the later-period yield of the super-thick oil steam flooding according to the saturated temperature difference.
Optionally, the regulation module 50 is configured to:
if the flow saturation temperature difference is lower than 30 ℃, adjusting the thrust of a liquid outlet pump of the production well and/or adjusting the extraction-injection ratio of steam flooding so that the flow saturation temperature difference is not lower than 30 ℃.
Optionally, the obtaining module 10 is configured to:
obtaining an injection steam rate range and an injection steam pressure range;
the first determining module 20 is configured to:
determining a bottom hole steam quality data set at different injection steam rates and different injection steam pressures based on the injection steam rate range, the injection steam pressure range, and the wellbore heat loss calculation parameters; determining a target injection steam rate and a target injection steam pressure from the downhole steam quality dataset.
Optionally, the first determining module 20 is configured to:
determining a total conductivity coefficient of the shaft according to the size parameter of the shaft and the heat conduction parameter of the shaft;
determining wellbore heat loss based on the wellbore size parameter, the wellbore total conductivity coefficient, and the steam surface temperature;
determining a theoretical bottom-hole steam quality of the steam injection well according to the steam ground quality, the heat loss of the shaft and the target steam injection rate;
and when the difference value between the actually measured bottom-hole steam dryness and the theoretical bottom-hole steam dryness is smaller than a set value, determining the bottom-hole effluent temperature according to the heat loss of the shaft, or determining the bottom-hole effluent temperature according to the total conductivity coefficient of the shaft.
Optionally, the first determining module 20 is configured to:
obtaining the temperature of a wellhead effluent of a production well;
and determining a bottom-hole effluent calculated temperature according to the wellhead effluent temperature, the heat loss of the mineshaft and the length of the mineshaft, and taking the bottom-hole effluent calculated temperature as the bottom-hole effluent temperature.
Optionally, the first determining module 20 is configured to:
obtaining the liquid production amount per unit time, the liquid water content, the air cavity pressure and the wellhead effluent temperature of the production well;
and determining the calculation temperature of the bottom-hole effluent according to the total conductivity coefficient of the shaft, the temperature of the top-hole effluent, the liquid production amount per unit time, the water content of the liquid and the pressure of the air cavity, and taking the calculation temperature of the bottom-hole effluent as the temperature of the bottom-hole effluent.
Optionally, the first determining module 20 is configured to:
obtaining the measured temperature of the bottom-hole effluent;
and when the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid tend to be consistent, taking the calculated temperature of the bottom-hole effluent liquid as the temperature of the bottom-hole effluent liquid.
Based on the same inventive concept of the previous embodiment, in yet another alternative embodiment, as shown in fig. 8, there is provided an electronic device 800 comprising a processor 820 and a memory 810, the memory 810 being coupled to the processor 820, the memory 810 storing a computer program 811, the computer program 811, when executed by the processor 820, causing the electronic device 800 to perform the steps of the regulation method of the previous embodiment.
The electronic device 800 may be a server, a desktop computer, a notebook computer, a tablet computer, a smart phone, and the like, without limitation.
Through one or more embodiments of the present invention, the present invention has the following advantageous effects or advantages:
the embodiment provides a method, a device and electronic equipment for regulating and controlling the later-period output of a super-heavy oil steam flooding, wherein the regulation and control method comprises the steps of respectively determining the temperature of a bottom-hole effluent liquid of a production well and the temperature of bottom-hole saturated steam, then determining the flow saturation temperature difference of the production well based on the temperature of the bottom-hole saturated steam and the temperature of the bottom-hole effluent liquid, and establishing a reasonable flow saturation temperature difference control limit through the flow saturation temperature difference to prevent steam from breaking through; the flow saturation temperature difference is utilized to dynamically regulate and control the super-heavy oil steam flooding yield, the water content can be kept unchanged and the oil-steam ratio can be improved while the steam injection amount of a well group is effectively reduced, so that the steam flooding efficiency is obviously improved, and the stability of the later yield of the super-heavy oil steam flooding is ensured.
While the preferred embodiments of the present application have been described, additional variations and modifications in those embodiments may occur to those skilled in the art once they learn of the basic inventive concepts. Therefore, it is intended that the appended claims be interpreted as including the preferred embodiment and all changes and modifications that fall within the scope of the present application.
It will be apparent to those skilled in the art that various changes and modifications may be made in the present application without departing from the spirit and scope of the application. Thus, if such modifications and variations of the present application fall within the scope of the claims of the present application and their equivalents, the present application is intended to include such modifications and variations as well.
Claims (10)
1. The method for regulating and controlling the later-period yield of the super heavy oil steam flooding is characterized by comprising the following steps of:
obtaining a wellbore heat loss calculation parameter and a bottom hole fluid actual measurement pressure of a production well;
determining the bottom hole effluent liquid temperature of a production well according to the heat loss calculation parameters of the shaft;
determining the corresponding bottom hole saturated steam temperature according to the measured pressure of the bottom hole fluid;
determining a saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature;
and regulating and controlling the later-period yield of the super-heavy oil steam flooding according to the saturated temperature difference.
2. The method for controlling the late stage production of the ultra-heavy oil steam flooding according to the saturation temperature difference as claimed in claim 1, wherein the controlling the late stage production of the ultra-heavy oil steam flooding comprises:
if the flow saturation temperature difference is lower than 30 ℃, adjusting the thrust of a liquid outlet pump of the production well and/or adjusting the extraction-injection ratio of steam flooding so that the flow saturation temperature difference is not lower than 30 ℃.
3. The method of conditioning of claim 1, wherein the wellbore heat loss calculation parameters comprise a wellbore size parameter, a wellbore heat transfer parameter, and an injected steam parameter;
the size parameter of the shaft comprises the length of the shaft and at least one of the inner diameter of an oil pipe, the outer diameter of the oil pipe, the outer diameter of a heat insulation oil pipe, the inner diameter of a casing, the outer diameter of the casing and the outer diameter of a cement sheath;
the wellbore heat conduction parameter comprises at least one of formation heat diffusion coefficient, formation heat conductivity coefficient, cement sheath heat conductivity coefficient and heat insulation oil pipe heat conductivity coefficient;
the injected steam parameters include steam ground temperature and steam ground dryness.
4. A method of conditioning as recited in claim 3, wherein prior to said determining a bottom hole effluent temperature of a production well based on said calculating a parameter based on heat loss from said wellbore, said method further comprises:
obtaining a range of injection steam rates and a range of injection steam pressures;
determining a bottom hole steam quality data set at different injection steam rates and different injection steam pressures based on the injection steam rate range, the injection steam pressure range, and the wellbore heat loss calculation parameters;
determining a target injection steam rate and a target injection steam pressure from the downhole steam quality dataset.
5. A control method as recited in claim 4 wherein said determining a bottom hole effluent temperature of a production well based on said wellbore heat loss calculation parameter comprises:
determining a total conductivity coefficient of the shaft according to the size parameter of the shaft and the heat conduction parameter of the shaft;
determining wellbore heat loss based on the wellbore size parameter, the wellbore total conductivity coefficient, and the steam surface temperature;
determining a theoretical bottom-hole steam quality of the steam injection well according to the steam ground quality, the heat loss of the shaft and the target steam injection rate;
and when the difference value between the actually measured bottom-hole steam dryness and the theoretical bottom-hole steam dryness is smaller than a set value, determining the bottom-hole effluent temperature according to the heat loss of the shaft, or determining the bottom-hole effluent temperature according to the total conductivity coefficient of the shaft.
6. A control method as described in claim 5 wherein said determining the bottom hole effluent temperature from the wellbore heat loss comprises:
obtaining the temperature of a wellhead effluent of a production well;
and determining a bottom-hole effluent calculated temperature according to the wellhead effluent temperature, the heat loss of the mineshaft and the length of the mineshaft, and taking the bottom-hole effluent calculated temperature as the bottom-hole effluent temperature.
7. A control method as described in claim 5 wherein said determining the bottom hole effluent temperature from the total wellbore conductivity comprises:
obtaining the liquid production amount, the liquid water content, the air cavity pressure and the wellhead effluent temperature of the production well in unit time;
and determining the calculation temperature of the bottom-hole effluent according to the total conductivity coefficient of the shaft, the temperature of the wellhead effluent, the liquid production amount in unit time, the water content of the liquid and the pressure of the air cavity, and taking the calculation temperature of the bottom-hole effluent as the temperature of the bottom-hole effluent.
8. A control method as claimed in claim 6 or 7, wherein said calculating the bottom hole effluent temperature as the bottom hole effluent temperature comprises:
obtaining the measured temperature of the bottom-hole effluent liquid;
and when the measured temperature of the bottom-hole effluent liquid and the calculated temperature of the bottom-hole effluent liquid tend to be consistent, taking the calculated temperature of the bottom-hole effluent liquid as the temperature of the bottom-hole effluent liquid.
9. The utility model provides a regulation and control device of super viscous crude steam flooding later stage output which characterized in that, regulation and control device includes:
the acquisition module is used for acquiring a wellbore heat loss calculation parameter of a production well and a bottom hole fluid actual measurement pressure;
the first determination module is used for determining the bottom hole effluent liquid temperature of the production well according to the heat loss calculation parameters of the shaft;
the second determination module is used for determining the corresponding bottom hole saturated steam temperature according to the measured pressure of the bottom hole fluid;
the third determination module is used for determining the flow saturation temperature difference of the production well according to the bottom-hole saturated steam temperature and the bottom-hole effluent liquid temperature;
and the regulation and control module is used for regulating and controlling the later-period yield of the super-thick oil steam flooding according to the saturated temperature difference.
10. An electronic device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the steps of the regulation method according to any one of claims 1 to 8 are implemented when the computer program is executed by the processor.
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