CN113090236A - Carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model - Google Patents

Carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model Download PDF

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CN113090236A
CN113090236A CN202110397630.7A CN202110397630A CN113090236A CN 113090236 A CN113090236 A CN 113090236A CN 202110397630 A CN202110397630 A CN 202110397630A CN 113090236 A CN113090236 A CN 113090236A
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water
oil
reservoir
karst
volume
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乐平
刘东晨
陈小凡
郭忠良
唐潮
陈文刚
丰妍
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Southwest Petroleum University
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
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    • E21B47/06—Measuring temperature or pressure

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Abstract

The invention provides a carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model, when a certain water quantity N is injected into a reservoirWThe functional model of pressure and cumulative injection is:
Figure DDA0003019151060000011
the model can calculate the mutual oil-water supply and exchange condition of two sets of karst cave reservoirs in the water injection oil replacement process. The initial conditions of the improved new model are more consistent with the real conditions of the discrete multi-reservoir bodies of the carbonate reservoir, the change of the water storage rate in the oil-replacing process by water injection is closer to the actual conditions of a mine field, the type of the reservoir bodies can be preliminarily judged by utilizing the theoretical model, the volumes of two sets of karst cave reservoir bodies and the volumes of crude oil and formation water can be more accurately determined, and the oil-water exchange condition between the two sets of karst cave reservoir bodies in the multi-round oil-replacing process by water injection is analyzed.

Description

Carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model
The application is a divisional application with the application date of 2017, 11.01 and 201710019917.X and the name of the invention of carbonate reservoir double-cavern reservoir water injection indication curve explanation model, and is applied to the southwest university of petroleum.
Technical Field
The invention relates to the technical field of oil reservoir geology and development, in particular to a carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model.
Background
At present, the traditional theoretical research of water injection indication curves mostly focuses on a linear indication curve model with the injection pressure linearly increasing along with the accumulated injection amount, and the actual water injection indication curves in the field often have the condition of slope reduction after curve turning, which represents that the well water injection waves and actively uses two or more sets of reservoirs, and the intensive research of the connotation meaning represented by the indication curves is necessary.
Disclosure of Invention
The invention aims to overcome the defects in the prior art and provides a carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model.
A carbonate rock oil reservoir double-karst-cave reservoir body water injection indication curve interpretation model is characterized in that when the oil reservoir is injected with a certain water quantity NWThe functional model of pressure and cumulative injection is:
Figure BDA0003019151040000011
wherein the content of the first and second substances,
N1crude oil volume of cavern 1, m3；
N2Crude oil volume of cavern 2, m3；
NW0The cumulative injection quantity m when water waves are injected into the second set of reservoir bodies in the process of replacing oil by water injection3；
BwIs the volume coefficient, decimal, of water;
Boithe volume coefficient and decimal of the crude oil under the original pressure;
R1the volume ratio of water to oil of the karst cave 1 is small;
Cois the compression factor of crude oil, MPa-1；
p0The formation pressure before oil is replaced by water injection is MPa;
Cwis the compressibility factor of formation water, MPa-1。
Through the change of the slope of the water injection indication curve of a plurality of turns (more than 3 turns) and the oil production and water production data between the water injection turns counted by the production data, the equation can be solved to calculate: volume N of cavernous reservoir 1, 21、N2And water-to-oil volume ratio R1And R2。
Further, according to the carbonate reservoir double-cavern reservoir water injection indication curve interpretation model, when the elastic energy of water in the cavern is not considered, namely the volume coefficient of the water is considered to be constant 1, the function model of the pressure and the accumulated injection amount is simplified as follows:
Figure BDA0003019151040000021
the method takes a double-karst-cave reservoir body model as a research target, and the influence of two sets of karst-cave reservoir bodies on the water injection indication curve form is successively used in the research of the water injection process. The new model can be used for calculating the proportion of the respective volume of the two sets of karst cave reservoirs so as to calculate the respective corresponding volume, and in addition, the new model can consider the influence of the elastic energy of the water phase on the water injection indication curve form, so that the new model is suitable for calculating the oil-water volume of the reservoirs under the following two conditions: the initial conditions in the two sets of karst cave reservoirs are pure oil or oil-water coexistence, wherein the oil-water coexistence comprises the condition that any one or both of the karst cave reservoirs are oil-water coexistence; and the water storage rate in any karst cave reservoir body gradually changes in the later water injection oil replacement process. Therefore, the model can calculate the mutual oil-water supply and exchange condition of the two karst cave reservoirs in the water injection and oil replacement process. The initial conditions of the improved new model are more consistent with the real conditions of the discrete multi-reservoir bodies of the carbonate reservoir, the change of the water storage rate in the oil-replacing process by water injection is closer to the actual conditions of a mine field, the type of the reservoir bodies can be preliminarily judged by utilizing the theoretical model, the volumes of two sets of karst cave reservoir bodies and the volumes of crude oil and formation water can be more accurately determined, and the oil-water exchange condition between the two sets of karst cave reservoir bodies in the multi-round oil-replacing process by water injection is analyzed.
Drawings
FIG. 1 waterflooding indicating curve for a double cavern reservoir (different second cavern volume N)2)；
FIG. 2 waterflooding indicating curve for a double cavern reservoir (different first cavern volume N)1)。
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the technical solutions of the present invention are described below clearly and completely, and it is obvious that the described embodiments are some, not all embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
For the double-cave model, the fracture between the two caves is assumed to only play a role in diversion, the caves are the main reservoir bodies, and the reservoir performance of the fracture is neglected. Suppose the original volumes of caverns 1 and 2 are Vp1，Vp2. The volume of the crude oil in the karst cave 1 is Voi1Volume of formation water is Vwi1Volume of crude oil in karst cave 2 is Voi2Volume of formation water is Vwi2And respectively defining the original water-oil volume ratio in each karst cave as follows:
R1＝Vwi1/Voi1 (1)
R2＝Vwi2/Voi2 (2)
then:
Vp1＝Voi1+Vwi1 (3)
Vp2＝Voi2+Vwi2 (4)
Vp1is the initial total volume of the cavern 1, m3；
Vp2Is the initial total volume of the cavern 2, m3；
Injecting a certain amount of water (N) into the reservoirW) When N is presentWIn a range less than NW0Previously, the injected water merely swept the reservoir 1, only if the cumulative injection volume exceeded NW0I.e., to provide sufficient pressure differential, water is injected to communicate with the second set of reservoir caverns 2. Based on the above assumptions, when the cumulative injection amount is less than NW0The pressure and the accumulated injection amount change of the oil reservoir are the same as those of a single karst cave model, namely:
Figure BDA0003019151040000031
NW0the cumulative injection quantity m when water waves are injected into the second set of reservoir bodies in the process of replacing oil by water injection3；
BwIs the volume coefficient, decimal, of water;
Boithe volume coefficient and decimal of the crude oil under the original pressure;
R1the volume ratio of water to oil of the karst cave 1 is small;
Cwis the compressibility factor of formation water, MPa-1；
p0The formation pressure before oil is replaced by water injection is MPa;
Cois the compression factor of crude oil, MPa-1；
N1Is cavern 1 crude oil volume, m3；
When the volume of injected water is more than NW0The method comprises the following steps: when the pressure differential exceeds the minimum pressure differential at which the fracture communicates with the caverns of the second set of reservoir systems, it is assumed thatPressure is redistributed at the communication time of the karst caves 1 and 2, and pressure balance is achieved in a short time.
Figure BDA0003019151040000041
NW0The cumulative injection quantity m when water waves are injected into the second set of reservoir bodies in the process of replacing oil by water injection3；
R2The volume ratio of water to oil of the karst cave 2 is small;
N2crude oil volume of cavern 2, m3；
Through the change of the slope of the water injection indication curve of a plurality of turns (more than 3 turns) and the oil production and water production data between the water injection turns counted by the production data, the equation can be solved to calculate: volume N of cavernous reservoir 1, 21、N2And water-to-oil volume ratio R1And R2。
Apparently communicating the second set of cavern reservoirs, pressure as a function of cumulative injection, slope from
Figure BDA0003019151040000042
Become into
Figure BDA0003019151040000043
The slope becomes smaller and the curve becomes flatter, i.e. a pressure pattern of the broken line occurs.
For the above formula (6), when the elastic energy of water in the cavern is not considered, i.e. the volume coefficient of water is considered to be constant 1, the above formula can be further simplified as follows:
Figure BDA0003019151040000044
thus, the fill pressure expression can be simplified as a piecewise function as follows:
Figure BDA0003019151040000045
water filling indication curve form analysis
Taking the two-hole model as an example, when the first cavern reservoir in communication with the well has equal volume and the second cavern reservoir has unequal volume, the effect on the slope of the second segment of the indicator curve is shown in FIG. 1:
when the original conditions of the karst cave 1 are the same, the accumulated injection amount does not exceed the value at the inflection point of the karst cave, the indication curves are the same, and when the accumulated injection amount exceeds Nw0And if the oil reservoir volume of the karst cave 2 is larger, the elastic energy of the second part of the karst cave is larger, the injected water is injected more easily in the second stage, and the slope of the straight line is reduced more obviously.
When the volumes of the second volumetric reservoirs in communication with the well are equal and the volumes of the first cavern reservoirs are not equal, the effect on the indicative curve morphology is schematically shown in fig. 2, where the initial conditions of a given cavern 2 are the same, and when the cumulative injection of each curve results in a cavern pressure not exceeding pLIn the process, obviously, the larger the reservoir volume of the karst cave 1 is, the larger the elastic energy is, the smaller the linear slope of the first stage is, the same reservoir pressure is increased, and more water needs to be injected, so that N isW01<NW02<NW03. When the accumulated water injection exceeds the corresponding accumulated injection amount at the position of the respective inflection point pressure, the karst caves 1 and 2 simultaneously exert respective elastic energy, so the slope is reduced, although the property of the second karst cave is assumed to be the same, the slope of the second-stage karst cave is influenced by the common action of the elastic energy of the karst caves 1 and 2, so the slope of the second-stage exponential curve is still satisfied to be smaller when the reservoir volume of the karst cave 1 is larger.
The application is applicable to the calculation of the oil-water volume of the reservoir under the following two conditions: the initial conditions in the two sets of karst cave reservoirs are pure oil or oil-water coexistence, wherein the oil-water coexistence comprises the condition that any one or both of the karst cave reservoirs are oil-water coexistence; and the water storage rate in any karst cave reservoir body gradually changes in the later water injection oil replacement process. Therefore, the model can calculate the mutual oil-water supply and exchange condition of the two karst cave reservoirs in the water injection and oil replacement process. The initial conditions of the improved new model are more consistent with the real conditions of the discrete multi-reservoir bodies of the carbonate reservoir, the change of the water storage rate in the oil-replacing process by water injection is closer to the actual conditions of a mine field, the type of the reservoir bodies can be preliminarily judged by utilizing the theoretical model, the volumes of two sets of karst cave reservoir bodies and the volumes of crude oil and formation water can be more accurately determined, and the oil-water exchange condition between the two sets of karst cave reservoir bodies in the multi-round oil-replacing process by water injection is analyzed.
Finally, it should be noted that: the above examples are only intended to illustrate the technical solution of the present invention, but not to limit it; although the present invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; and such modifications or substitutions do not depart from the spirit and scope of the corresponding technical solutions of the embodiments of the present invention.

Claims (2)

1. A carbonate rock oil reservoir double-karst-cave reservoir body water injection indication curve interpretation model is disclosed, wherein a certain water quantity N is injected into an oil reservoirWWhen the amount of injected water is more than Nw0When the injected water is communicated with the karst cave 2 from the karst cave 1, the pressure is redistributed and pressure balance is achieved in a short time on the assumption that the karst caves 1 and 2 are communicated, and the method is characterized in that when the injected water quantity N of the oil reservoir is Nw＞Nw0Then, the function model of the pressure and the accumulated injection amount is as follows;
Figure FDA0003019151030000011
wherein the content of the first and second substances,
N1crude oil volume of cavern 1, m3；
N2Crude oil volume of cavern 2, m3；
NW0The cumulative injection amount m when water wave reaches the karst cave 2 in the process of replacing oil by water injection3；
BwIs the volume coefficient, decimal, of water;
Boiis original pressure originalVolume factor, decimal fraction of oil;
R1the volume ratio of water to oil of the karst cave 1 is small;
Cois the compression factor of crude oil, MPa-1；
p0The formation pressure before oil is replaced by water injection is MPa;
Cwis the compressibility factor of formation water, MPa-1；
Through the change of the slope of the water injection indication curve of more than 3 times and the oil production and water production data of each water injection time counted by the production data, the equation is solved to calculate: crude oil volume N of karst cave 1, 21、N2And water-to-oil volume ratio R1And R2。
2. The method for establishing the carbonate reservoir double-karst-cave reservoir water injection indication curve interpretation model is characterized by comprising the following steps of:
assuming that the cracks between the two karst caves only play a role in diversion, the karst caves are main reservoir bodies, and the reservoir performance of the cracks is neglected;
suppose the original volumes of caverns 1 and 2 are Vp1，Vp2(ii) a The volume of the crude oil in the karst cave 1 is Voi1Volume of formation water is Vwi1Volume of crude oil in karst cave 2 is Voi2Volume of formation water is Vwi2And respectively defining the original water-oil volume ratio in each karst cave as follows:
R1 original＝Vwi1/Voi1 (1)
R2 original＝Vwi2/Voi2 (2)
R1 originalThe original water-oil volume ratio of the karst cave 1;
R2 originalThe original water-oil volume ratio of the karst cave 2;
then:
Vp1＝Voi1+Vwi1 (3)
Vp2＝Voi2+Vwi2 (4)
Vp1is the original volume of the cavern 1,m3；
Vp2is the original volume of the cavern 2, m3；
When the oil reservoir injects a certain water quantity NW, when the injected water quantity is more than Nw0And (3) communicating the water to the karst cave 2 from the karst cave 1, and assuming that the communication time of the karst caves 1 and 2 is constant, the pressure is redistributed, and the pressure is balanced in a short time to obtain a function model of the pressure and the accumulated injection amount.
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