CN114352242A - Heavy oil reservoir exploitation method - Google Patents
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Abstract
The invention discloses a heavy oil reservoir exploitation method, wherein the method comprises the following steps: calculating the target splitting number of each of the m jetted oil layers according to a well logging interpretation result table of the current well; calculating the total water storage information of the current well by adopting a material balance method; splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain respective split water storage information of the m oil layers; determining i steam flooding oil layers and j fire flooding oil layers from the m oil layers according to respective splitting water storage information of the m oil layers; combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode; and combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding manner. By adopting the invention, the technical problem of poor mining effect caused by singly adopting steam flooding in the prior art can be solved.
Description
Technical Field
The invention relates to the technical field of oil exploitation, in particular to a heavy oil reservoir exploitation method.
Background
In the field of thick oil exploitation, steam flooding and fire flooding are currently the most widely applied technologies for replacing thick oil after huff and puff development. However, in practical application, the heat utilization rate of conventional steam drive development is low, a steam cavity is difficult to form, and the steam drive development effect is poor due to factors such as longitudinal development of an oil layer, steam overload and formation water storage. In the fireflood technology, certain technical risks also exist due to the complex mechanism and the difficulty in operating and controlling the live wire.
Therefore, it is necessary to provide a more suitable recovery scheme for heavy oil reservoirs after stimulation.
Disclosure of Invention
The embodiment of the application provides a heavy oil reservoir exploitation method, and solves the technical problems that in the prior art, exploitation effect is poor due to independent adoption of steam flooding and the like.
In one aspect, the present application provides a heavy oil reservoir exploitation method according to an embodiment of the present application, the method including:
calculating the target splitting number of each of the m jetted oil layers according to a well logging interpretation result table of the current well, wherein m is a positive integer;
calculating the total water storage information of the current well by adopting a material balance method;
splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain respective split water storage information of the m oil layers;
according to the respective splitting water storage information of the m oil layers, i steam flooding oil layers and j fire flooding oil layers are determined from the m oil layers, wherein i and j are natural numbers less than or equal to m;
combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode;
and combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding manner.
Optionally, the calculating, according to the logging interpretation result table of the current well, the target splitting numbers of the m jetted oil layers includes:
calculating the respective initial splitting coefficients of m oil layers in the current well according to a logging interpretation result table of the current well;
correcting the initial splitting numbers of the m oil layers according to the test results of the current well at different times to obtain the target splitting numbers of the m oil layers;
wherein the well log interpretation result table includes at least the thickness and permeability of each of the m reservoirs.
Optionally, the initial splitting coefficient of the ith reservoir is:
where Kh is the initial splitting coefficient, KiPermeability of the i-th reservoir, hiIs the thickness of the ith oil layerAnd i is a positive integer less than or equal to m.
Optionally, the split water spot information includes a reservoir water volume and/or a water spot pore volume factor PV.
Optionally, the determining i steam flooding oil layers and j fire flooding oil layers from the m oil layers according to the respective splitting water storage information of the m oil layers includes:
determining i oil layers meeting preset conditions in the m oil layers as the i steam flooding oil layers;
determining oil layers except the i steam flooding oil layers in the m oil layers as the j fire flooding oil layers;
wherein the preset condition is related to at least the split trap information.
Optionally, the preset first condition comprises at least one of: the thickness of the steam oil drive layer exceeds a first threshold value, the water storage amount of the steam oil drive layer is smaller than a second threshold value, the water storage PV of the steam oil drive layer is smaller than a third threshold value, the permeability level difference between the steam oil drive layer and a previous adjacent oil layer is smaller than a fourth threshold value, and the combined thickness corresponding to the i steam oil drive layers exceeds a fifth threshold value.
Optionally, the combining the i steam flooding oil layers and exploiting the heavy oil reservoir in a steam flooding manner further includes:
and when an oil layer with the span exceeding a preset first span exists in the i steam flooding oil layers, the heavy oil reservoir is exploited by adopting a mode of injecting high-temperature steam in a grading manner.
Optionally, the combining the j fire flooding oil layers and exploiting the heavy oil reservoir in a fire flooding manner further includes:
and when an oil layer with the span exceeding a preset second span exists in the j fire flooding oil layers, exploiting the heavy oil reservoir by adopting a mode of staged ignition and air injection.
Optionally, the steam flooding injection-production parameters adopted by the steam flooding include: the steam injection rate is 1.6-1.8 t/(d.ha.m), the extraction-injection ratio is 1.0-1.2, and the dryness of bottom-hole steam is more than or equal to 50%.
Optionally, the steam flooding injection-production parameters adopted by the steam flooding include: the steam injection rate is 1.6 t/(d.ha.m), the extraction-injection ratio is 1.0-2.0, and the dryness of bottom-hole steam is 50%.
Optionally, the fireflood injection-production parameters adopted by the fireflood include: an electric ignition mode is adopted, the ignition temperature is above 400 ℃, and the discharge injection ratio is 0.6-1.0.
One or more technical solutions provided in the embodiments of the present application have at least the following technical effects or advantages: according to a current well logging interpretation result table, calculating respective target splitting numbers of m oil layers; calculating the total water storage information of the current well by adopting a material balance method; splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain respective split water storage information of the m oil layers; according to the respective splitting water storage information of the m oil layers, i steam flooding oil layers and j fire flooding oil layers are determined from the m oil layers, wherein i and j are natural numbers less than or equal to m; combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode; and combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding manner. In the scheme, the steam flooding and fire flooding combined development scheme is adopted, so that the exploitation efficiency and the exploitation effect of heavy oil reservoir exploitation are improved, and the recovery ratio is further improved.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on the drawings without creative efforts.
Fig. 1 is a schematic flow chart of a heavy oil reservoir exploitation method according to an embodiment of the present disclosure.
FIG. 2 is a schematic diagram of a log interpretation result table provided in an embodiment of the present application.
FIG. 3 is a graphical representation of the split coefficient versus percent imbibition for each of the oil zones provided in the examples herein.
Fig. 4 is a schematic diagram of water storage PV of each oil layer provided in the embodiments of the present application.
Fig. 5 is a schematic cross-sectional view of a steam flooding and fire flooding combined development provided by an embodiment of the present application.
FIG. 6 is a schematic plan view of a steam flooding and fire flooding combined development system according to an embodiment of the present disclosure.
Reference numerals:
1-oil layer; 2-an interlayer; 3-steam injection well; 4-air injection well; 5, a production well; 6-perforation section; 7-steam front; 8-combustion front; 9-the included angle between the front edge of the steam cavity and the stratum.
Detailed Description
The applicant has also found in the course of the present application that: steam flooding is one of the more widely applied successor techniques after steam huff and puff development. It usually uses a central well as steam injection well and peripheral wells as production wells, and continuously injects steam to displace crude oil. The steam flooding is generally applied to heavy oil reservoirs with crude oil viscosity of less than (<)200000mPa s, burial depth of less than 1600m, thickness of 7-60m and net total ratio of more than (>)0.4, is typically applied to 40 blocks of steam flooding pilot test areas, the production degree reaches 63.5%, and the expected recovery ratio can reach 65%.
However, because the layered heavy oil reservoir is influenced by the difference of physical properties between layers and the steam overlap, the high-permeability layer and the upper oil layer are better used, and the steam 7 is continuously pushed along the high-permeability layer after the development of the steam drive, so that the longitudinal use degree of the steam drive is lower. On the other hand, the water storage amount and the water saturation of the high permeability layer, the upper oil layer and the water body invasion layer are higher, the specific heat capacity of water in a standard state is 4.187kJ/kg. ℃, the water is a substance with the highest specific heat capacity in all elements and compounds, and injected steam heat is absorbed by a large amount of stratum stored water after the development of steam flooding is carried out, so that the heat efficiency is low, and the development effect of the steam flooding is greatly influenced. The production degree of 20 well groups in a typical block such as 40 flush steam flooding side water areas is only 49.5 percent.
The fireflood development is an in-situ modification technology, and compared with steam injection thermal recovery, the fireflood injection medium is air, the crude oil is ignited and heated under the stratum condition, and the crude oil and the air generate a high-temperature oxidation reaction to form a combustion front which is continuously pushed forward to a production well. The fire flooding technology is generally applied to heavy oil reservoirs with crude oil viscosity of less than 10000mPa & s, buried depth of 150 & lt- & gt 2000m, thickness of more than 6m, permeability of more than 30mD and oil saturation of more than 35%. The production degree of a typical application block Du 66 fireflood pilot test area reaches 55.8%, and the expected recovery rate can reach 60%.
Because the fireflood has the characteristics of large heat release, high displacement efficiency (the residual oil of a burned rock core is less than 2 percent) and the like, the water stored in the stratum can be effectively heated, a steam zone and a hot water zone are formed to continuously heat the crude oil, and the mobility of the thickened oil under the stratum condition is enhanced, so that the recovery ratio can be further improved in oil reservoirs with high water storage capacity in the stratum such as a bottom water oil reservoir, a water body invasion layer and the like. The method has a good effect in the implementation of fire flooding projects of the brocade 91 block edge bottom water oil reservoir, and the recovery ratio is estimated to be 61.9%.
Therefore, after the heavy oil reservoir is subjected to steam huff and puff, steam drive development is carried out, the problems that the steam drive is uneven in longitudinal utilization due to high-permeability steam absorption, the steam drive is low in heat efficiency due to high-stratum water storage and the like are caused. In order to solve the problems, the application provides a heavy oil reservoir exploitation method, which has the following general idea:
calculating the target splitting number of each of the m jetted oil layers according to a well logging interpretation result table of the current well, wherein m is a positive integer;
calculating the total water storage information of the current well by adopting a material balance method;
splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain respective split water storage information of the m oil layers;
according to the respective splitting water storage information of the m oil layers, i steam flooding oil layers and j fire flooding oil layers are determined from the m oil layers, wherein i and j are natural numbers less than or equal to m;
combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode;
and combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding manner.
In order to better understand the technical solution, the technical solution will be described in detail with reference to the drawings and the specific embodiments.
First, it is stated that the term "and/or" appearing herein is merely one type of associative relationship that describes an associated object, meaning that three types of relationships may exist, e.g., a and/or B may mean: a exists alone, A and B exist simultaneously, and B exists alone. In addition, the character "/" herein generally indicates that the former and latter related objects are in an "or" relationship.
Fig. 1 is a schematic flow chart of a heavy oil reservoir recovery method according to an embodiment of the present disclosure. The method as shown in fig. 1 comprises the following implementation steps:
s101, calculating target splitting numbers of the jetted m oil layers according to a logging interpretation result table of the current well, wherein m is a positive integer.
The well logging interpretation result table is generated by a system in a self-defined mode, and can include but is not limited to oil layer information of m oil layers in a heavy oil reservoir, m is a positive integer determined by the system according to actual conditions, and the oil layer information includes but is not limited to information such as saturation, permeability, thickness and porosity. Referring to FIG. 2, a schematic diagram of a possible well log interpretation results table is shown. The well logging interpretation result table shown in fig. 2 includes 6 oil layers, and each oil layer has its own thickness, porosity and permeability.
In a specific embodiment, the method can perform geological coefficient statistics and calculation on each oil layer according to a logging interpretation result table to obtain a dimensionless formation coefficient of a perforated well section, and then determine the respective target splitting number of each oil layer. Specifically, the method can obtain the test results of the steam absorption, the liquid production and the well temperature at different time, establish the corresponding relation between the dimensionless formation coefficient and the gas absorption/liquid production percentage according to the test results and the well logging interpretation result table, and then correct the dimensionless formation coefficient by using the test results to obtain the final target splitting coefficient.
In another specific embodiment, the initial splitting coefficients of m oil layers in the current well can be obtained by calculation according to a logging interpretation result table of the current well, and the initial splitting coefficient of the ith oil layer is taken as an example and is obtained by calculation by using the following formula (1):
where Kh is the initial splitting coefficient of the ith oil layer, KiPermeability of the i-th reservoir, hiAnd i is the thickness of the ith oil layer and is a positive integer less than or equal to m.
Further, the method and the device can obtain the test results of steam absorption and liquid production profiles of the production wells in different time and different areas, and correct the respective initial splitting numbers of the m oil layers in the current well according to the test results and different time to form the respective target splitting numbers of the m oil layers in different time.
For example, fig. 3 shows a comparison of the number of possible initial splitting of the reservoir versus the percentage of vapor absorption. As shown in fig. 3, the initial split coefficient and the steam absorption percentage of each of the 6 oil layers are shown in the depth direction.
And S102, calculating the total water storage information of the current well by adopting a material balance method.
The method can be used for calculating the total water storage information of the current well by adopting a material balance method according to the data of liquid production, oil production, steam injection and pressure measurement over the years, wherein the total water storage information comprises but is not limited to the total water storage amount and the volume multiple of the total water storage pore (also called as water storage PV).
S103, splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain the respective split water storage information of the m oil layers.
This application can be according to the respective target split system number of m oil reservoirs, will totally deposit water information split to m oil reservoirs in to obtain the respective split system of m oil reservoirs and deposit water information. The split water spot information includes the reservoir water volume and/or the water spot PV.
In a specific embodiment, the method can also judge the water outlet time of the current well according to the dynamic change of the current well; and judging a water layer position by combining the oil layer development condition, the oil-water distribution and the current well perforation, and further determining a water flooded layer and a non-water flooded layer in the m oil layers. Further, aiming at the flooding layer, splitting can be carried out according to the initial splitting number Kh of the flooding layer; aiming at the non-water flooded layer, the method can split according to the corrected target splitting number, so that the respective water storage amount and/or water storage PV of the m oil layers are obtained through calculation. For example, see FIG. 4 for a schematic illustration of a possible trapped PV column for each oil layer. As shown in FIG. 4, the respective trapped PV values for the 6 oil layers are given, as shown in detail.
S104, according to the respective splitting water storage information of the m oil layers, i steam flooding oil layers and j fire flooding oil layers are determined from the m oil layers, wherein i and j are natural numbers smaller than or equal to m.
In a specific embodiment, the present application may determine i oil layers satisfying a preset condition among the m oil layers as i steam flooding oil layers, and determine the remaining other oil layers as j fire flooding oil layers. The preset condition is set by the system in a self-defining way, and for example, the preset condition can include but is not limited to any one or more of the following items: the thickness of the steam oil drive layer exceeds a first threshold value, the water storage amount of the steam oil drive layer is smaller than a second threshold value, the water storage PV of the steam oil drive layer is smaller than a third threshold value, the permeability level difference between the steam oil drive layer and a previous adjacent oil layer is smaller than a fourth threshold value, and the combined thickness corresponding to the i steam oil drive layers exceeds a fifth threshold value.
In practical application, in order to ensure longitudinal utilization, the oil layers with the combined thickness exceeding 15m, the single-layer thickness exceeding 1m, the permeability level difference being less than 4 and the water storage amount or water storage PV being small (for example, less than a preset threshold value of 0.15) are selected from m oil layers to serve as i steam drive oil layers. Accordingly, the remaining oil layer not used, the high water storage rate, or the oil layer of the high water storage PV is determined as j oil layers for fireflooding.
And S105, combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode.
This application can drive the oil reservoir to i steam and make up to adopt the steam to drive the mode and develop, can full play steam drive latent heat of vaporization like this, improve the heat utilization efficiency. If the oil layer span existing in the i steam flooding oil layers is large (for example, exceeds the preset first span), the method can be developed by adopting a mode of injecting high-temperature steam in a grading mode. The span referred to in this application may refer to the degree of step jump between two adjacent said steam flooding zones.
And S106, combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding mode.
This application can be made up j fire flooding oil reservoir to adopt the fire flooding mode to develop. If the reservoir span among the j fire flooding reservoirs is large (for example, exceeds a preset second span), the method for injecting air by adopting staged ignition can be considered to be developed.
In practical application, this application can be with the higher water layer of depositing of surplus (i.e. j fire flooding oil reservoir) according to certain thickness, the poor development of permeability carries out the fireflood, utilizes the burning to produce the heat and heats the stratum and deposit water, improves swept volume and displacement efficiency, and the effective heating top interlayer of heat after the fireflood development, has realized preheating in advance to the vapour drive position for vapour drives the development start fast, with instant effect, displacement leading edge is relatively even. When the oil-containing well section is too long, under the process permission condition, graded ignition and gas injection can be considered, and longitudinal multilayer uniform fireflood is realized.
In an optional embodiment, the injection and production parameters (also called as operation parameters) corresponding to the steam flooding and the fire flooding can be reasonably optimized, so that oil reservoirs can be uniformly used, and the efficient operation of the steam flooding and the fire flooding development is ensured. For example, the steam flooding injection and production parameters adopted by the steam flooding include: the steam injection rate is 1.6-1.8 t/(d.ha.m), the extraction-injection ratio is 1.0-2.0, and the dryness of bottom-hole steam is more than or equal to 50%. The fire flooding injection and production parameters adopted by the fire flooding comprise: an electric ignition mode is adopted, the ignition temperature is above 400 ℃, the discharge-injection ratio is 0.6-1.0, and the initial gas injection strength is 400-3/(d.m), monthly gas injection intensity of 50-70m3/(d.m), maximum gas injection Strength 1800-2000m3/(d · m), etc.
In practical application, the steam repelling high water storage layer is operated according to the steam injection rate of 1.6 t/d.ha.m per unit volume and the bottom hole dryness of 50 percent, and the injection and extraction ratio is controlled to be 1.1-1.2; the method comprises the steps of screening steam-repellent injection layers, recombining fire flooding development, calculating ventilation strength, combining pressure change between injection and production wells after steam flooding, designing initial gas injection speed and monthly incremental gas injection speed, ensuring that the pressure of a steam-drive layer section and the pressure of a fire-drive layer section are consistent as far as possible on the basis of ensuring that an oil layer is ignited to be fully combusted and the temperature of a combustion front edge is advanced, and avoiding the phenomenon that steam/gas channeling and the like occur in advance due to the fact that the pressure difference between layers is too large and a certain mode and a certain layer are advanced too fast.
Referring to fig. 5 and 6 together, a cross-section and a plan well pattern of a steam flooding and a fire flooding composite development are shown, respectively. As in fig. 5, the reference numerals 1 to 9 each denote the following meanings: 1-oil layer, 2-interlayer, 3-steam injection well, 4-air injection well, 5-production well, 6-perforation section, 7-steam front, 8-combustion front, and 9-steam cavity front and stratum included angle.
For example, referring to the example shown in FIG. 4, as in FIG. 4, 2 small layers (i.e., oil layer 2) are affected by throughput, and the water spot PV is relatively high, mainly the throughput injection-production water spot; 5. the 6 small layers are affected by the intrusion of edge water, the water is mainly invaded, and the calculated water storage PV is higher than the upper layer for huff and puff. For the thickness, physical property, use and water storage difference of oil layers at different longitudinal layers, the combination of 1, 3 and 4 small layers with concentrated thickness, small permeability grade difference and less water storage is preferably developed by steam drive. When the span of 1, 3 small oil layers is large, two-stage steam injection can be considered to ensure longitudinal power utilization and reduce heat loss. The steam flooding is operated according to the steam injection rate of 1.6 t/d.ha.m per unit volume, the dryness of the bottom of the well is ensured to be about 50 percent, and the extraction-injection ratio is 1.1-1.2.
Accordingly, the present application can also combine the 2, 5, 6 small layers with high water storage according to the thickness of the oil layer, the physical properties, and the difference screening. When the 2, 5 small-layer well sections are too long, stratified ignition, air injection and the like can be considered under the permission of process conditions.
Due to the difference of the fluidity between the injected medium (steam and air) and the displaced material (thick oil), the displacement front edge and the oil layer form a phi angle, and the larger the difference of the fluidity is, the smaller the phi angle is, and the more uneven the displacement front edge is. After ignition is successful, the fireflood releases a large amount of heat, the top interlayer is effectively heated under the action of gas overlap, the heat is transferred to the adjacent steam drive layer section through the interlayer, the viscosity of crude oil at the lower part in the steam drive layer is reduced, the fluidity is improved, the steam displacement resistance is reduced, and the front edge form is more uniform.
The fire flooding development calculates the initial gas injection speed according to a ventilation intensity formula, on the basis of meeting the propelling speed of the combustion front edge at 4cm/d, the monthly increasing gas injection intensity is not too high, the synchronous propelling of the fire flooding front edge and the steam flooding front edge is ensured, and premature steam/gas channeling is avoided. Please refer to table 1 to give the scheme of the present application, and compare the statistical table with the production situation developed by steam flooding and fire flooding alone.
TABLE 1
As can be seen from the above Table 1, the development of heat loss by adopting steam flooding alone is large, the production time is short, the economic production time is only 7.7 years, the stage production degree is 13.6%, and the stage oil-to-steam ratio is 0.143. The extraction degree is improved to 18.3% in the stage of separately adopting the fireflood, the oil-gas ratio is 0.16 according to the conversion of the steam and air price, the economic production time is 9.6 years, and the development economy is improved. The mining method adopts the steam flooding and fire flooding combined development, increases the water storage PV as the basis of the layer combination, combines the steam flooding and fire flooding selective layers, has the economic and effective production time of about 14.3 years through reasonable design and fine field operation management, has the stage mining degree of 25.0 percent and the stage oil-gas ratio of 0.127, and improves the mining degrees by 11.4 percent and 6.7 percent respectively compared with the mining degrees of the steam flooding and fire flooding stages.
Through implementing this application, effectively solved the problem that steam drive development vertically used inequality, thermal efficiency low, vertical dual mode is compound, adopts steam drive mode displacement to deposit the water layer lowly, and the vertical degree of using of water layer improvement oil reservoir is deposited to fire drive displacement height, and effectively utilizes the stratum to deposit water and carry out secondary heating and improved the thermal efficiency and the fire drive ripples and the volume of steam drive. Reasonable reservoir engineering design and injection-production parameter operation can ensure that the interlayer pressure is used in two effective modes, the total displacement front edge is uniformly and stably propelled, and the recovery ratio of the heavy oil reservoir after huff and puff development is improved.
While preferred embodiments of the present invention 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 preferred embodiments and all such alterations and modifications as fall within the scope of the invention.
It will be apparent to those skilled in the art that various changes and modifications may be made in the present invention without departing from the spirit and scope of the invention. Thus, if such modifications and variations of the present invention fall within the scope of the claims of the present invention and their equivalents, the present invention is also intended to include such modifications and variations.
Claims (11)
1. A heavy oil reservoir recovery method, comprising:
calculating the target splitting number of each of the m jetted oil layers according to a well logging interpretation result table of the current well, wherein m is a positive integer;
calculating the total water storage information of the current well by adopting a material balance method;
splitting the total water storage information according to the respective target splitting number of the m oil layers to obtain respective split water storage information of the m oil layers;
according to the respective splitting water storage information of the m oil layers, i steam flooding oil layers and j fire flooding oil layers are determined from the m oil layers, wherein i and j are natural numbers less than or equal to m;
combining the i steam flooding oil layers, and exploiting the heavy oil reservoir in a steam flooding mode;
and combining the j fire flooding oil layers, and exploiting the heavy oil reservoir in a fire flooding manner.
2. The method of claim 1, wherein calculating the target split numbers of the m jetted oil layers according to the well logging interpretation result table of the current well comprises:
calculating the respective initial splitting coefficients of m oil layers in the current well according to a logging interpretation result table of the current well;
correcting the initial splitting numbers of the m oil layers according to the test results of the current well at different times to obtain the target splitting numbers of the m oil layers;
wherein the well log interpretation result table includes at least the thickness and permeability of each of the m reservoirs.
3. The method of claim 2, wherein the initial split coefficient for the ith reservoir is:
where Kh is the initial splitting coefficient, KiPermeability of the i-th reservoir, hiAnd i is the thickness of the ith oil layer and is a positive integer less than or equal to m.
4. The method of claim 1, wherein the split water spot information comprises a reservoir water spot and/or a water spot pore volume factor PV.
5. The method of claim 4, wherein the determining i steam flooding zones and j fire flooding zones from the m zones based on respective split water information of the m zones comprises:
determining i oil layers meeting preset conditions in the m oil layers as the i steam flooding oil layers;
determining oil layers except the i steam flooding oil layers in the m oil layers as the j fire flooding oil layers;
wherein the preset condition is related to at least the split trap information.
6. The method of claim 5, wherein the preset first condition comprises at least one of: the thickness of the steam oil drive layer exceeds a first threshold value, the water storage amount of the steam oil drive layer is smaller than a second threshold value, the water storage PV of the steam oil drive layer is smaller than a third threshold value, the permeability level difference between the steam oil drive layer and a previous adjacent oil layer is smaller than a fourth threshold value, and the combined thickness corresponding to the i steam oil drive layers exceeds a fifth threshold value.
7. The method of claim 1, wherein the combining the i steam flooding oil layers and the heavy oil reservoir production by steam flooding further comprises:
and when an oil layer with the span exceeding a preset first span exists in the i steam flooding oil layers, the heavy oil reservoir is exploited by adopting a mode of injecting high-temperature steam in a grading manner.
8. The method of claim 1, wherein the combining the j fire flooding oil layers and the fire flooding heavy oil reservoir exploitation further comprises:
and when an oil layer with the span exceeding a preset second span exists in the j fire flooding oil layers, exploiting the heavy oil reservoir by adopting a mode of staged ignition and air injection.
9. The method of claim 1, wherein the steam flooding parameters include: the steam injection rate is 1.6-1.8 t/(d.ha.m), the extraction-injection ratio is 1.0-1.2, and the dryness of bottom-hole steam is more than or equal to 50%.
10. The method of claim 9, wherein the steam flooding parameters include: the steam injection rate is 1.6 t/(d.ha.m), the extraction-injection ratio is 1.0-2.0, and the dryness of bottom-hole steam is 50%.
11. The method of claim 1, wherein the fireflood injection production parameters employed by the fireflood include: an electric ignition mode is adopted, the ignition temperature is above 400 ℃, and the discharge injection ratio is 0.6-1.0.
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