CN107288595B - Evaluation method for water injection utilization rate - Google Patents
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- 238000002347 injection Methods 0.000 title claims abstract description 200
- 239000007924 injection Substances 0.000 title claims abstract description 200
- 238000011156 evaluation Methods 0.000 title claims abstract description 116
- 238000004519 manufacturing process Methods 0.000 claims abstract description 115
- 238000000034 method Methods 0.000 claims abstract description 45
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Abstract
A method for evaluating the utilization rate of water flooding comprises the following steps: determining an evaluation index, namely determining a water injection utilization rate evaluation index of the injection-production well group to be analyzed according to the obtained production dynamic data of the injection-production well group to be analyzed, wherein the water injection utilization rate evaluation index comprises an injected water pressurization index and an injected water displacement index; and a water injection utilization rate evaluation step, namely determining the water injection utilization rate of the injection-production well group to be analyzed according to the water injection utilization rate evaluation index and the water injection utilization rate evaluation standard of the injection-production well group to be analyzed. The method solves the problems that the evaluation index in the prior art cannot reflect the loss of the injected water of the fracture-cavity oil reservoir, the existing evaluation standard cannot reflect the large difference of the water drive characteristics and the large types of the reservoirs, can more accurately evaluate the utilization condition of the injected water of the fracture-cavity oil reservoir and the water injection development adjustment potential, and can clearly adjust the direction for water injection measures.
Description
Technical Field
The invention relates to the technical field of oil-gas exploration and development, in particular to a method for evaluating water injection utilization rate.
Background
The fracture-cave carbonate reservoir is an important field for increasing oil and gas storage and increasing production in China. The Tahe oil field Ordovician reservoir is used as the largest fracture-cavity type reservoir which is put into development in China, and the exploratory reserve reaches 13 hundred million tons. In 2005, the Tahe oil field gradually entered the water flooding development stage, but as the water flooding development proceeded, the water flooding effect gradually worsened. To implement the adjustment of the water flooding development technical policy, the current water flooding effect must be evaluated, and the water flooding utilization rate is an important aspect of the evaluation of the water flooding development effect.
Disclosure of Invention
In order to solve the above problems, the present invention provides a method for evaluating a water injection utilization rate, the method comprising:
determining an evaluation index, namely determining a water injection utilization rate evaluation index of the injection-production well group to be analyzed according to the obtained production dynamic data of the injection-production well group to be analyzed, wherein the water injection utilization rate evaluation index comprises an injected water pressurization index and an injected water displacement index;
and a water injection utilization rate evaluation step, namely determining the water injection utilization rate of the injection and production well group to be analyzed according to the water injection utilization rate evaluation index and the water injection utilization rate evaluation standard of the injection and production well group to be analyzed.
According to one embodiment of the invention, the step of determining the water flooding utilization rate evaluation criterion comprises:
acquiring the type of a reservoir of the injection-production well group to be analyzed, and respectively determining water injection utilization rate evaluation indexes of other injection-production well groups according to production dynamic data of the other injection-production well groups belonging to the type of the reservoir;
and determining the water injection utilization rate evaluation standard of the injection and production well group to be analyzed according to the water injection utilization rate evaluation indexes of the injection and production well groups belonging to the type of the reservoir body.
According to one embodiment of the invention, the water injection utilization rate evaluation criterion of the injection and production well group to be analyzed is an average value of water injection utilization rate evaluation indexes of the injection and production well groups belonging to the reservoir type.
According to one embodiment of the invention, the injection water pressurization index is calculated according to the following expression:
wherein f ispIndicating injection water pressurization index, N geological reserve, BoiRepresents the volume coefficient, C, of the crude oil under the original conditionstRepresenting the combined compression factor, peAnd psRespectively representing the reservoir pressure at the end of the evaluation and at the beginning of the evaluation, WiIndicating the amount of water injected.
According to one embodiment of the invention, the flooding index is calculated according to the following expression:
wherein f isdRepresents the flooding index of injected water, NpIndicating cumulative oil production, BoDenotes the volume factor, W, of the crude oiliIndicating the amount of water injected.
According to an embodiment of the present invention, when the water flooding utilization evaluation index of the injection-production well group to be analyzed is lower than the water flooding utilization evaluation standard, the method further comprises:
and analyzing the problem reasons, namely determining influence parameters according to the production dynamic data of the injection and production well group to be analyzed, and determining the reasons that the water injection utilization rate evaluation index of the injection and production well group to be analyzed is lower than the water injection utilization rate evaluation standard according to the influence parameters.
According to an embodiment of the invention, the influencing parameters comprise an injection water loss index and an injection water channeling index, wherein,
calculating the leakage index of the injected water according to the leakage amount of the injected water and the amount of the injected water;
and/or calculating the injection water loss index according to the accumulated water yield and the injection water yield.
According to one embodiment of the invention, the injection water leakage is calculated according to the following expression:
Wieak＝Wi-NpBo-Wp-NBoiCt(pe-ps)
wherein, WleakDenotes the amount of leakage of injected water, WiIndicates the amount of injected water, N indicatesGeological reserve, BoiRepresents the volume coefficient, C, of the crude oil under the original conditionstRepresenting the combined compression factor, peAnd psRespectively representing the reservoir pressure at the end of the evaluation and at the beginning of the evaluation, NpIndicating cumulative oil production, BoDenotes the volume factor, W, of the crude oilpIndicating cumulative water production.
According to one embodiment of the invention, the injection water loss index is calculated according to the following expression:
wherein f istDenotes the loss index of injected water, WleakDenotes the amount of leakage of injected water, WiIndicating the amount of water injected.
According to one embodiment of the present invention, the injection water breakthrough index is calculated according to the following expression:
wherein f iscDenotes the water loss by injection index, WpRepresents the cumulative water production, WiIndicating the amount of water injected.
The fracture-cavity oil reservoir water injection utilization rate evaluation method provided by the invention establishes a water injection utilization rate evaluation index system by using 4 evaluation indexes of an injected water leakage index, an injected water channeling index, a pressurization index and an oil displacement index, determines an evaluation standard according to different reservoir body types, and evaluates the water injection utilization condition. The method solves the problems that the evaluation index in the prior art cannot reflect the loss of the injected water of the fracture-cavity oil reservoir, the existing evaluation standard cannot reflect the large difference of the water drive characteristics and the large types of the reservoirs, can more accurately evaluate the utilization condition of the injected water of the fracture-cavity oil reservoir and the water injection development adjustment potential, and can clearly adjust the direction for water injection measures.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required in the description of the embodiments or the prior art:
FIG. 1 is a flow diagram of a water injection utilization evaluation method according to one embodiment of the invention;
FIG. 2 is a flow chart of a waterflood utilization evaluation method according to another embodiment of the present invention;
fig. 3 is a schematic diagram of a fracture-cavity reservoir flooding process in accordance with one embodiment of the present invention.
Detailed Description
The following detailed description of the embodiments of the present invention will be provided with reference to the drawings and examples, so that how to apply the technical means to solve the technical problems and achieve the technical effects can be fully understood and implemented. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the following description, for purposes of explanation, numerous specific details are set forth in order to provide a thorough understanding of the embodiments of the invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced without some of these specific details or with other methods described herein.
Additionally, the steps illustrated in the flow charts of the figures may be performed in a computer system such as a set of computer-executable instructions and, although a logical order is illustrated in the flow charts, in some cases, the steps illustrated or described may be performed in an order different than here.
At present, the evaluation of the water injection utilization rate of the fracture-cavity type oil reservoir mainly extends to a clastic rock oil reservoir method. The basic flow of evaluating the water injection utilization rate mainly comprises the following steps: calculating an evaluation index; determining an evaluation standard; and comparing the calculation result with a standard, evaluating the quality of the effect and the like. The key points of the process are two: the first is evaluation index, and the second is evaluation standard.
In the aspect of evaluating indexes, the water storage rate and the water consumption rate are main indexes for measuring the water injection utilization rate of the oil field at present. In the existing method, the following expressions are mostly adopted to respectively calculate the water storage rate RwAnd water consumption rate:
wherein, WiIndicates the cumulative water injection amount, WpRepresents cumulative water production, NpIndicating cumulative oil production.
In the aspect of evaluation standard, part of researchers introduce a dimensionless injection curve and a dimensionless extraction curve based on the stage water storage rate, return to a relational expression of the stage water storage rate and the extraction degree under different water drive recovery rates and draw a relational standard chart for the stage water storage rate and the extraction degree, and can evaluate the development adjustment effect by utilizing the chart.
In addition, in the aspect of evaluation criteria, some researchers introduce related empirical formulas of relative permeability of oil and water from the definition of water storage rate and water consumption rate, and derive empirical formulas for drawing theoretical curves of accumulated water storage rate, stage water consumption rate and accumulated water consumption rate. Therefore, actual production data are marked on a theoretical curve chart drawn by using the empirical formulas, so that the water injection utilization rate of the water injection oil field (or block) is evaluated.
However, the existing water injection utilization rate evaluation method has a plurality of defects. Firstly, the evaluation index of the existing method cannot reflect the problem of the loss of injected water of the fracture-cavity oil reservoir. Because the reservoir body structure of the fracture-cavity type oil reservoir is complex and part of the fracture-cavity body is not closed, the injected water can overflow. That is, for a fracture-cavity reservoir, a portion of the injected water enters the subsurface, which is lost, neither displacing the crude oil nor producing it from the well, and the current guidelines do not take this into account.
Secondly, the characteristics of multiple types of reservoirs and large water drive characteristic difference of the fracture-cavity oil reservoir cannot be reflected by evaluating the water injection utilization rate by using the established standard (or chart) by adopting the existing method. Due to the fact that fracture-cavity oil reservoirs are multiple in types, fluid flow characteristics and water flooding characteristics of different types of reservoirs are obviously different, and water injection effect and water injection development and adjustment potential are difficult to accurately evaluate by adopting standards (or plates) established in the prior art.
Aiming at the defects of the existing method, the invention provides a novel method for evaluating the water injection utilization rate, and the evaluation indexes adopted in the evaluation of the water injection utilization rate comprise an injected water supercharging index and an injected water displacement index. In order to more clearly illustrate the principles, implementation procedures and advantages of the water injection utilization rate evaluation method provided by the present invention, the water injection utilization rate evaluation method provided by the present invention is further described below with reference to different embodiments.
The first embodiment is as follows:
fig. 1 shows a flowchart of a water injection utilization rate evaluation method provided in this embodiment.
As shown in fig. 1, the method for evaluating water injection utilization rate provided by this embodiment first obtains the reservoir type of the injection-production well group to be analyzed in step S101.
In practical applications, the reservoir types of the injection-production well group may include: a solution-cavity type, a fracture-cavity type, a crack-cavity type and a crack type. Fluid flow characteristics and water flooding characteristics vary widely among different types of reservoirs. For example, for a cavern-type reservoir, the utilization rate of injected water is theoretically high; in the case of fractured reservoirs, the injected water is theoretically low in utilization rate because the injected water easily flows along the fractures.
After the reservoir type of the injection-production well group to be analyzed is determined, the method obtains production dynamic data of each injection-production well group in the reservoir type to which the injection-production well group to be analyzed belongs in step S102, and calculates water injection utilization rate evaluation indexes of each injection-production well group in the reservoir type of the injection-production well group to be analyzed according to the production dynamic data obtained in step S102 in step S103.
The main purpose of the evaluation of the utilization rate of the injected water is to find out the problems existing in the water injection process so as to find the potential of water flooding. According to the above description, the existing water injection utilization rate evaluation method mainly uses two indexes, namely the water storage rate and the water consumption rate, to evaluate the water injection utilization rate, and the method will take the fracture-cavity type injection and production well group with low water injection utilization rate as the target of the water flooding, which is obviously incorrect.
Therefore, the method provided by the embodiment adopts the injection water supercharging index and the injection water oil displacement index as the water injection utilization rate evaluation indexes. Specifically, in this embodiment, the production dynamic data of each injection-production well group acquired in step S102 preferably includes: geological reserve N, crude oil volume coefficient B under original conditionoiAnd the comprehensive compression coefficient CtThe reservoir pressure p at the end of the evaluationeAnd evaluating the reservoir pressure p at the beginningsCumulative oil production NpCrude oil volume coefficient BoAnd the amount of injected water Wi。
In this embodiment, the injection water pressure increase index is a ratio of water amount for increasing formation pressure to injected water amount, and may be determined according to geological reserve N and crude oil volume coefficient B under original conditionsoiAnd the comprehensive compression coefficient CtThe reservoir pressure p at the end of the evaluationeAnd evaluating the reservoir pressure p at the beginningsAnd the amount of injected water WiAnd (4) calculating.
Specifically, in the present embodiment, the injection water pressure increase index f is calculated according to the following expressionp：
The flooding index refers to the ratio of the amount of water used for flooding to the amount of water injected, and can be determined according to the cumulative oil production NpCrude oil volume coefficient BoAnd injecting waterQuantity WiAnd (4) calculating.
Specifically, in this embodiment, the injection flooding index f is calculated according to the following expressiond：
After obtaining the evaluation indexes of the water injection utilization rate of each injection and production well group in the reservoir type to which the injection and production well group to be analyzed belongs, the method determines the evaluation standard of the water injection utilization rate of the injection and production well group to be analyzed by using the evaluation indexes of the water injection utilization rate in step S104. In this embodiment, the water injection utilization rate evaluation criterion of the injection-production well group to be analyzed is an average value of water injection utilization rate evaluation indexes of each injection-production well group in the reservoir type to which the injection-production well group to be analyzed belongs. The water injection utilization rate evaluation method provided by the embodiment evaluates the water injection utilization rate according to the reservoir body classification, and is more suitable for fracture-cavity oil reservoirs.
It should be noted that in other embodiments of the present invention, other reasonable manners may be adopted to determine the evaluation criterion of water injection utilization rate of the injection-production well group to be analyzed, and the present invention is not limited thereto. For example, in an embodiment of the present invention, the water injection utilization rate evaluation criterion of the injection-production well group to be analyzed may also be a median of water injection utilization rate evaluation indexes of each injection-production well group in the reservoir type to which the injection-production well group to be analyzed belongs; in another embodiment of the present invention, the evaluation criterion of water injection utilization rate of the injection-production well group to be analyzed may be pre-configured according to the type of the reservoir of the injection-production well group to be analyzed and the historical empirical data.
After obtaining the water injection utilization rate evaluation index and the water injection utilization rate evaluation standard of the injection-production well group to be analyzed, the method determines the water injection utilization rate of the injection-production well group to be analyzed according to the water injection utilization rate evaluation index and the water injection utilization rate evaluation standard of the injection-production well group to be analyzed in step S105. Specifically, in this embodiment, if the evaluation index of the water injection utilization rate of the injection-production well group to be analyzed is higher than the evaluation criterion of the water injection utilization rate to determine the water injection utilization rate of the injection-production well group to be analyzed, it indicates that the water injection utilization rate of the injection-production well group to be analyzed is high, and the water injection effect is good; otherwise, the water injection utilization rate of the injection-production well group to be analyzed is low, and the water injection effect is poor.
Example two:
fig. 2 shows a flowchart of the water injection utilization rate evaluation method provided by this embodiment.
As shown in fig. 2, in the method provided in this embodiment, the water injection utilization rate evaluation index and the water injection utilization rate evaluation criterion of the injection-production well group to be analyzed are determined in steps S201 to S204, and the principle and the implementation process of the method are the same as those of steps S101 to S105 in the first embodiment, and therefore are not described herein again.
In step S205, the method determines whether the water injection utilization rate evaluation index of the injection-production well group to be analyzed is greater than the corresponding water injection utilization rate evaluation criterion. If the water injection rate is larger than the preset water injection rate, the water injection utilization rate of the injection-production well group to be analyzed is high, and the effect is good; otherwise, in step S206, it is determined that the injection-production well group to be analyzed has a low water injection utilization rate and a poor water injection effect.
If the water injection utilization rate of the injection-production well group to be analyzed is low and the water injection effect is poor, it is indicated that the water injection process of the injection-production well group to be analyzed has obvious problems, and a corresponding coping strategy needs to be formulated and adopted. Therefore, in step S207, the method provided in this embodiment determines an influence parameter according to the production dynamic data of the injection-production well group to be analyzed, and determines a reason why the evaluation index of the water injection utilization rate of the injection-production well group to be analyzed is lower than the evaluation criterion of the water injection utilization rate according to the influence parameter.
Specifically, in this embodiment, the influence parameters for determining the reason why the water injection utilization rate evaluation index is lower than the water injection utilization rate evaluation criterion include an injected water loss index and an injected water loss index. The injection water loss index is the ratio of the amount of water lost to the amount of water injected, and the injection water loss index is the ratio of the amount of water produced through the oil well to the amount of water injected.
In this embodiment, the injection water loss index and the injection water channeling index may be calculated according to the following expressions:
wherein f istDenotes the index of loss of injected water, fcIndicating the injection water loss index. WleakRepresents the amount of injected water loss, which can be calculated according to the following expression:
Wleak＝Wi-NpBo-Wp-NBoiCt(pe-ps) (7)
in this embodiment, in step S208, the water injection loss index f is determined according to the water injection loss indextAnd injection water loss index fcWhen the reason that the evaluation index of the water injection utilization rate of the injection-production well group to be analyzed is lower than the evaluation standard of the water injection utilization rate is determined, firstly, the average value of the injection water loss indexes and the average value of the injection water loss indexes of all the injection-production well groups in the reservoir body are respectively calculated according to the injection water loss index and the injection water channeling index of each injection-production well group in the reservoir body type to which the injection-production well group to be analyzed belongs, and then the injection water loss indexes f of the injection-production well group to be analyzed are respectively calculatedtAnd injection water loss index fcAnd comparing the average value with the corresponding average value, and determining the reason why the evaluation index of the water injection utilization rate of the injection-production well group to be analyzed is lower than the evaluation standard of the water injection utilization rate according to the comparison result.
In the embodiment, for the injection and production well group with poor effect, the reason of the problem of water injection is determined according to the injection water leakage index and the injection water channeling index, so that a corresponding policy is formulated. For example, for an injection and production well group with a large injection water loss index, the main problem is that the injection and production wells are adjusted when the injection water is lost into the stratum; for the injection and production well group with large injection water channeling index, the main problem is that water channeling occurs, and water shutoff measures are required.
As can be seen from the above description, the method for evaluating the injection water utilization rate provided by the embodiment also considers the problem of injection water loss during the injection process of the fracture-cavity oil reservoir on the basis of the method provided by the first embodiment, and can evaluate the injection water utilization rate more accurately.
As shown in fig. 3, there are four directions for the fracture-cavity reservoir injected water to enter the reservoir: first, leakage through the fracture into the formation; and the second is the loss produced by the oil well, the third is the increase of the formation pressure, and the fourth is the displacement of crude oil. In the evaluation process of the prior art, only the injection amount and the extraction amount of injected water are considered, and the leakage of part of the injected water into a stratum is not considered, so that the injected water has no oil displacement effect or pressurization effect. The method considers the four aspects, so that the utilization rate of the injected water is more accurately evaluated.
In order to verify the practicability of the method provided by the embodiment, the method is used for evaluating the water injection utilization rate of different injection and production well groups.
Taking a certain injection and production well group as an example, in the evaluation stage, the injected water amount is 100 ten thousand square, the accumulated water yield is 5 ten thousand square, the accumulated oil yield is 15 ten thousand square, the volume coefficient of crude oil is 1, the formation pressure is kept unchanged, and the water leakage amount is 80 ten thousand square.
By utilizing the prior art, the water storage rate can be calculated to be 95%. By using the method provided by the embodiment, the injection water loss index is 80%, the injection water loss index is 5%, the injection water pressurization index is 0, and the injection water displacement index is 15% can be calculated respectively.
For the existing method, the calculated water storage rate is 95%, so that the conclusion that the utilization rate of injected water is high can be drawn. In fact, most of the injected water of the injection-production well group is lost, and the effective water storage rate for achieving the oil displacement or pressurization effect is only 15%. Therefore, the method provided by the invention can be used for evaluating the utilization rate of the injected water more accurately.
In addition, taking a certain fracture unit of a tower river oil field fracture-cavity type oil reservoir as an example, the unit develops three reservoir body types (including a karst-cavity type, a fracture-hole type and a fracture type) which comprise 12 injection and production well groups in total.
In evaluating waterflood utilization, the 12 injection and production well groups are first classified into 3 categories based on the differences in reservoir type.
The injection water loss index, the channeling index, the supercharging index and the oil displacement index of each unit can be respectively calculated by using the expressions (3) to (7). The calculation results are shown in table 1:
TABLE 1
The average levels of the various parameters for the different types of reservoirs can be calculated from the data shown in table 1. The results are shown in Table 2:
TABLE 2
It can be found by comparing table 1 and table 2 that the water flooding utilization ratio of 5 well groups is poor, wherein the number of the karst cave type is 1, the number of the crack-hole type is 2, and the number of the crack type is 2. Meanwhile, the evaluation indexes are compared, the reasons with the undesirable effect can be analyzed, and the policy adjustment direction is made according to the reasons. The results are shown in Table 3:
TABLE 3
Therefore, if the existing standard is adopted, the water injection utilization rate of the crack type injection-production well group is low, and the crack type injection-production well group is the main direction for next adjustment. In fact, the theoretical water injection utilization rate of the crack type injection-production well group is low, the effect of the injection-production well group 11 oil displacement index of 20% is good, and adjustment is not needed. And the oil displacement index of the karst cave type injection-production well group 7 is 30 percent, which is higher than that of the crack type injection-production well group, but is obviously lower than that of other karst cave type injection-production well groups, and has adjustment potential. Therefore, the method is more suitable for fracture-cavity oil reservoirs.
From the above description, it can be seen that the present invention relates to a fracture-cavity type oil reservoir water injection utilization rate evaluation method. The method comprises the steps of establishing a water injection utilization rate evaluation index system by using 4 evaluation indexes of an injected water leakage index, an injected water channeling index, a pressurization index and an oil displacement index, determining evaluation standards according to different reservoir body types, and evaluating the water injection utilization condition. The method solves the problems that the evaluation index in the prior art cannot reflect the loss of the injected water of the fracture-cavity oil reservoir, the existing evaluation standard cannot reflect the large difference of the water drive characteristics and the large types of the reservoirs, can more accurately evaluate the utilization condition of the injected water of the fracture-cavity oil reservoir and the water injection development adjustment potential, and can clearly adjust the direction for water injection measures.
It is to be understood that the disclosed embodiments of the invention are not limited to the particular process steps disclosed herein, but rather, are extended to equivalents thereof as would be understood by those of ordinary skill in the relevant art. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting.
Reference in the specification to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Thus, the appearances of the phrase "one embodiment" or "an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment.
While the above examples are illustrative of the principles of the present invention in one or more applications, it will be apparent to those of ordinary skill in the art that various changes in form, usage and details of implementation can be made without departing from the principles and concepts of the invention. Accordingly, the invention is defined by the appended claims.
Claims (1)
1. A method for evaluating the utilization rate of water flooding, which is characterized by comprising the following steps:
determining an evaluation index, namely determining a water injection utilization rate evaluation index of the injection-production well group to be analyzed according to the obtained production dynamic data of the injection-production well group to be analyzed, wherein the water injection utilization rate evaluation index comprises an injected water pressurization index and an injected water displacement index;
a water injection utilization rate evaluation step, namely determining the water injection utilization rate of the injection and production well group to be analyzed according to the water injection utilization rate evaluation index and the water injection utilization rate evaluation standard of the injection and production well group to be analyzed;
when the water injection utilization rate evaluation index of the injection-production well group to be analyzed is lower than the water injection utilization rate evaluation standard, the method further comprises the following steps:
a problem cause analysis step, namely determining influence parameters according to the production dynamic data of the injection and production well group to be analyzed, determining reasons that the water injection utilization rate evaluation indexes of the injection and production well group to be analyzed are lower than the water injection utilization rate evaluation standard according to the influence parameters, and making countermeasures according to the reasons;
wherein the influencing parameters comprise an injected water loss index and an injected water channeling index, wherein,
calculating the leakage index of the injected water according to the leakage amount of the injected water and the amount of the injected water;
and/or, calculating the injection water loss index according to the accumulated water yield and the injection water yield;
wherein the step of determining the evaluation criterion of the water injection utilization rate comprises the following steps:
acquiring the type of a reservoir of the injection-production well group to be analyzed, and respectively determining water injection utilization rate evaluation indexes of other injection-production well groups according to production dynamic data of the other injection-production well groups belonging to the type of the reservoir;
determining the water injection utilization rate evaluation standard of the injection-production well group to be analyzed according to the water injection utilization rate evaluation indexes of the injection-production well groups belonging to the type of the reservoir body;
the water injection utilization rate evaluation standard of the injection-production well group to be analyzed is the average value of water injection utilization rate evaluation indexes of all the injection-production well groups belonging to the reservoir type;
wherein the injection water pressurization index is calculated according to the following expression:
wherein f ispIndicating injection water pressurization index, N geological reserve, BoiRepresentation sourceCrude oil volume coefficient under initial conditions, CtRepresenting the combined compression factor, peAnd psRespectively representing the reservoir pressure at the end of the evaluation and at the beginning of the evaluation, WiRepresents the amount of injected water;
wherein the injection flooding index is calculated according to the following expression:
wherein f isdRepresents the flooding index of injected water, NpIndicating cumulative oil production, BoDenotes the volume factor, W, of the crude oiliRepresents the amount of injected water;
wherein the injection water leakage amount is calculated according to the following expression:
Wleak＝Wi-NpBo-Wp-NBoiCt(pe-ps)
wherein, WleakDenotes the amount of leakage of injected water, WiRepresenting the amount of water injected, N the geological reserve, BoiRepresents the volume coefficient, C, of the crude oil under the original conditionstRepresenting the combined compression factor, peAnd psRespectively representing the reservoir pressure at the end of the evaluation and at the beginning of the evaluation, NpIndicating cumulative oil production, BoDenotes the volume factor, W, of the crude oilpRepresents the cumulative water production;
wherein the injection water loss index is calculated according to the following expression:
wherein f istDenotes the loss index of injected water, WleakDenotes the amount of leakage of injected water, WiRepresents the amount of injected water;
wherein the injection water breakthrough index is calculated according to the following expression:
wherein f iscDenotes the water loss by injection index, WpRepresents the cumulative water production, WiIndicating the amount of water injected.
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