CN110792436B - Method and device for determining carbonate reservoir type - Google Patents
Method and device for determining carbonate reservoir type Download PDFInfo
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- CN110792436B CN110792436B CN201810873711.8A CN201810873711A CN110792436B CN 110792436 B CN110792436 B CN 110792436B CN 201810873711 A CN201810873711 A CN 201810873711A CN 110792436 B CN110792436 B CN 110792436B
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 47
- 238000000034 method Methods 0.000 title claims abstract description 40
- 239000002253 acid Substances 0.000 claims abstract description 233
- 239000007788 liquid Substances 0.000 claims abstract description 58
- 238000004519 manufacturing process Methods 0.000 claims abstract description 29
- 230000033558 biomineral tissue development Effects 0.000 claims description 48
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 47
- 239000008398 formation water Substances 0.000 claims description 24
- 238000002347 injection Methods 0.000 claims description 22
- 239000007924 injection Substances 0.000 claims description 22
- 238000009826 distribution Methods 0.000 claims description 17
- 230000015654 memory Effects 0.000 claims description 13
- 238000004590 computer program Methods 0.000 claims description 9
- 238000003860 storage Methods 0.000 claims description 6
- 239000003921 oil Substances 0.000 description 23
- 239000000243 solution Substances 0.000 description 22
- 230000018109 developmental process Effects 0.000 description 9
- 239000012530 fluid Substances 0.000 description 8
- 230000015572 biosynthetic process Effects 0.000 description 7
- 230000008569 process Effects 0.000 description 7
- 238000010586 diagram Methods 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- 239000002352 surface water Substances 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 4
- 230000002706 hydrostatic effect Effects 0.000 description 4
- 230000001965 increasing effect Effects 0.000 description 4
- 230000004048 modification Effects 0.000 description 4
- 238000012986 modification Methods 0.000 description 4
- 239000011148 porous material Substances 0.000 description 4
- 230000006835 compression Effects 0.000 description 3
- 238000007906 compression Methods 0.000 description 3
- 238000010306 acid treatment Methods 0.000 description 2
- 239000002131 composite material Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 230000001133 acceleration Effects 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005530 etching Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The invention provides a method and a device for determining carbonate reservoir types, wherein a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing are obtained, and a bottom hole pressure difference is determined according to the first bottom hole pressure value and the second bottom hole pressure value; acquiring parameters of a first acid liquid injected into a reservoir to be detected and parameters of a second acid liquid discharged from the reservoir to be detected after acid fracturing; and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing. The reservoir type determined by the method provides data reference and theoretical basis for subsequent carbonate oil and gas development.
Description
Technical Field
The invention relates to the field of oil and gas field development, in particular to a method and a device for determining carbonate reservoir type.
Background
From the global perspective, carbonate reservoir reservoirs are widely distributed and have huge reserves. It has now been found that reserves of carbonate reservoirs account for about 50% of the total reserve, with yields accounting for about 60%. The acid fracturing modification technology has long become one of the leading technologies for increasing and stabilizing the yield of the carbonate oil and gas reservoir development well. With the continuous development of the acid fracturing technology, the technology develops from the initial common acid fracturing to the current deep acid fracturing, the acid fracturing modification process mainly comprises clean self-diverting acid fracturing, composite acid fracturing, ultra-large repeated acid fracturing, hydraulic jet segmented acid fracturing, network fracture acid fracturing and the like, the processes are widely applied at home and abroad, the yield increasing effect is ideal, and an important guarantee is provided for the production increase of oil fields on the basis of storage.
The acid fracturing technology is to use acid liquor as fracturing fluid under the condition of higher than the fracture pressure of stratum to perform fracturing without adding proppant. The wall surface of the crack is corroded into an uneven surface by the corrosion action of the acid liquor in the acid fracturing process, so that the wall surface of the crack cannot be completely closed after the pump is stopped to relieve pressure. Therefore, the composite material has higher flow conductivity and obvious effect on recovering and improving the production capacity of an oil well.
With the increasing application of acid fracturing modification of carbonate rocks, the accurate judgment of the type of the carbonate rock reservoir according to the acid fracturing process is a premise of improving the yield, the determination of the type of the carbonate rock reservoir is not regularly known at present, and the mining efficiency of the carbonate rock is greatly reduced.
Disclosure of Invention
The invention provides a method and a device for determining carbonate reservoir types, which provide data reference and theoretical basis for carbonate oil and gas development.
A first aspect of the invention provides a method of determining a carbonate reservoir type, comprising:
acquiring a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing, and determining a bottom hole pressure difference according to the first bottom hole pressure value and the second bottom hole pressure value;
acquiring a first acid liquid parameter injected into a reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing;
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing.
In a possible implementation manner, the acquiring parameters of the first acid solution injected into the reservoir to be detected and the parameters of the second acid solution discharged from the reservoir to be detected after acid fracturing includes:
and acquiring the acid liquor injection amount and the first mineralization degree of the first acid liquor injected into the reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of the second acid liquor discharged from the reservoir to be detected after acid fracturing.
In a possible implementation manner, before determining the reservoir type of the reservoir to be detected according to the bottom-hole pressure difference, the first acid liquid parameter, the second acid liquid parameter, and the post-acid fracturing production condition, the method further includes:
determining the acid liquor flowback rate of the reservoir to be detected according to the acid liquor injection amount of the first acid liquor and the acid liquor discharge amount of the second acid liquor; and
determining the stratum water distribution condition of the reservoir to be detected according to the first mineralization degree, the second mineralization degree and the stratum water mineralization degree;
determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing, wherein the determining comprises the following steps:
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
In one possible implementation, the reservoir types include a large slotted body oil layer, a large slotted body oil-water layer, a small slotted body oil-water layer, a water layer, and a dry layer.
A second aspect of the invention provides an apparatus for determining a carbonate reservoir type, comprising:
the acquisition module is used for acquiring a first bottom hole pressure value of the reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing;
a determination module for determining a bottom hole pressure differential based on the first bottom hole pressure value and the second bottom hole pressure value;
the acquisition module is also used for acquiring parameters of a first acid liquid injected into the reservoir to be detected and parameters of a second acid liquid discharged from the reservoir to be detected after acid fracturing;
the determining module is further used for determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing.
In a possible implementation manner, the obtaining module is specifically configured to:
and acquiring the acid liquor injection amount and the first mineralization degree of the first acid liquor injected into the reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of the second acid liquor discharged from the reservoir to be detected after acid fracturing.
In a possible implementation manner, the determining module is further configured to:
determining the acid liquor flowback rate of the reservoir to be detected according to the acid liquor injection amount of the first acid liquor and the acid liquor discharge amount of the second acid liquor; and
determining the stratum water distribution condition of the reservoir to be detected according to the first mineralization degree, the second mineralization degree and the stratum water mineralization degree;
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
In one possible implementation, the reservoir types include a large slotted body oil layer, a large slotted body oil-water layer, a small slotted body oil-water layer, a water layer, and a dry layer.
A third aspect of the invention provides an apparatus for determining a carbonate reservoir type, comprising:
a memory;
a processor; and
a computer program;
wherein the computer program is stored in the memory and configured to be executed by the processor to implement the method according to any one of the first aspect of the invention.
A fourth aspect of the invention provides a computer readable storage medium having stored thereon a computer program for execution by a processor to perform the method according to any one of the first aspect of the invention.
According to the method and the device for determining the carbonate reservoir type, provided by the embodiment of the invention, the bottom hole pressure difference is determined according to the first bottom hole pressure value and the second bottom hole pressure value by acquiring the first bottom hole pressure value of the reservoir to be detected before acid fracturing and the second bottom hole pressure value after acid fracturing; acquiring a first acid liquid parameter injected into a reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing; and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing. The reservoir type determined by the method provides data reference and theoretical basis for subsequent carbonate oil and gas development.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the embodiments or the description of the prior art will be briefly described below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and those skilled in the art can obtain other drawings based on the drawings without inventive labor.
FIG. 1 is a schematic flow diagram of a method for determining carbonate reservoir type according to an embodiment of the present invention;
FIG. 2 is a schematic flow diagram of a method for determining carbonate reservoir type according to another embodiment of the present invention;
fig. 3 is a schematic structural diagram of a carbonate reservoir type determination device provided by the present invention;
fig. 4 is a hardware configuration diagram of a carbonate reservoir type determining apparatus provided in the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but 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.
The terms "comprising" and "having," and any variations thereof, in the description and claims of this invention are intended to cover non-exclusive inclusions. For example, a process, method, system, article, or apparatus that comprises a list of steps or elements is not limited to only those steps or elements listed, but may alternatively include other steps or elements not listed, or inherent to such process, method, article, or apparatus.
The terms "first," "second," and the like in the description and claims of the present invention and in the preceding drawings are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments of the invention described herein are capable of operation in other sequences than those illustrated or described herein.
Reference throughout this specification to "one embodiment" or "another embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the present application. Thus, the appearances of the phrases "in one embodiment" or "in this embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment. It should be noted that the embodiments and features of the embodiments may be combined with each other without conflict.
Acid fracturing is an effective production increase measure for modifying carbonate reservoirs. In the process of acidizing and fracturing, when the pad fluid or the acid treatment fluid is constructed at the injection displacement which is more than the acceptable injection displacement of the stratum, the pressure near the borehole is increased, and when the pressure is higher than the fracture pressure of the stratum, the stratum is pressed open, and the pad fluid or the acid treatment fluid enters the fracture; if a certain pressure is continuously kept, the fracture continuously extends, acid rock reaction occurs along with the injection of the acid liquor, and the acid liquor unevenly etches the wall surface of the stratum fracture. If the design is proper, after the construction pressure on the ground is removed, the crack can not be closed under the formation pressure, and the uneven etched channel with certain flow conductivity enables formation fluid to flow into the bottom of the well more easily. If non-uniform etching is not formed, the cracks will close after the pump is stopped, so that the flow conductivity of the cracks is small.
The method for determining the type of the carbonate reservoir determines the type of the reservoir at present according to the formation pressure difference before and after acid fracturing, flowback characteristics and production conditions, so that data reference and theoretical basis are provided for subsequent carbonate oil and gas development.
The method for determining the type of carbonate reservoir provided by the present invention is described in detail below with reference to specific examples.
Fig. 1 is a schematic flow chart of a method for determining a carbonate reservoir type according to an embodiment of the present invention, and as shown in fig. 1, the method for determining a carbonate reservoir type according to the embodiment includes the following steps:
s101, acquiring a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing;
in this embodiment, before injecting acid solution into a reservoir to be detected, an original reservoir pressure value at the bottom of the reservoir, that is, a first bottom-hole pressure value, is detected. And after injecting acid liquor, when the ground construction pressure is removed, detecting the reservoir pressure value after the pump is stopped at the bottom of the reservoir, namely a second bottom hole pressure value. In theory, any ingress of ambient fluid will cause a change in formation pressure, and therefore, the second bottomhole pressure value is typically greater than the first bottomhole pressure value.
S102, determining a bottom hole pressure difference according to the first bottom hole pressure value and the second bottom hole pressure value;
introducing a bottom hole pressure difference delta P, wherein the calculation formula is shown as a formula I:
ΔP＝P-P o formula one
Wherein P is a second bottom hole pressure value, P o Is a first bottom hole pressure value.
The second bottom hole pressure value is the wellhead pressure value P when the pump is stopped Stopping the pump The pressure value P of a wellbore hydrostatic column filled with acid liquid Hydrostatic column As shown in equation two:
P＝P stopping the pump +P Hydrostatic column Formula II
P Hydrostatic column Equation three of ρ gh
Wherein rho is the density of the acid solution, g is the gravity acceleration, and h is the depth of the shaft.
Assuming that the injection amount of acid liquor injected into the reservoir to be detected is V Note that And can be represented by formula four:
V note that ＝V o ×C o ×ΔP+V p ×C p ×ΔP+V w ×C w X Δ P formula four
Wherein, V o Is the volume of crude oil in the formation, m 3 ；C o Is the compression factor of crude oil, MPa -1 ；V p Is the pore volume, m 3 ；C p Is the pore compressibility, MPa -1 ；V w To confine the volume of water, m 3 ；C w Is the formation water compression coefficient, MPa -1 。
Δ P = V Note that /((V o +V p +V w )×C t ) Formula five
Wherein, C t Is a comprehensive compression coefficient, MPa -1 ，C t Can be represented by the formula six:
C t ＝C o +(C p +S wc *C w )/(1-S wc ) Formula six
Wherein S is wc Is water saturation (%). The compressive coefficient C of a certain oil reservoir t Is constant, about n 10 -4 MPa -1 . Thus, it can be derived: under the condition of the same injection amount, the larger the formation crude oil volume and the pore volume are, the larger the size of the fracture hole is, the smaller the bottom hole pressure difference is, namely the second bottom hole pressure value is approximately close to the first bottom hole pressure value, and the acid fracturing effect is the moreGood; the smaller the formation crude oil volume and the pore volume, the smaller the size of the fracture hole, the larger the pressure difference at the bottom of the well and the poorer the acid fracturing effect.
S103, acquiring a first acid liquid parameter injected into a reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing;
the first acid liquid parameter comprises the injection amount of the first acid liquid and the first mineralization degree of the first acid liquid, and the second acid liquid parameter comprises the discharge amount of the second acid liquid and the second mineralization degree of the second acid liquid.
In this embodiment, the first acid solution is an initial acid solution injected into the reservoir to be detected, the acid solution is configured by using surface water, and the water density of the surface water is generally less than or equal to 1.04g/cm 3 And the surface water has a mineralization degree smaller than 3000mg/L.
The water density of the formation water in the reservoir is typically 1.14g/cm 3 The water density of the formation water is different according to different well depths of different oil fields, but is larger than that of the surface water.
The mineralization degree of the formation water in the reservoir is larger than that of the surface water, for example, the well depth of a Tarim oil field is 5000-8000 m, the mineralization degree of the formation water is larger than 50000mg/L, the mineralization degrees of the formation water of different oil fields are different according to the well depth, but are larger than that of the formation water, and the quantity level is ten thousand milligrams per liter.
According to different types of reservoirs, the second mineralization degree and the water density of the second acid liquid discharged after acid fracturing are changed to different degrees, and the following conditions can be existed:
the degree of mineralization of the second acid solution is close to the degree of mineralization of the first acid solution, as the case may be;
in another possible case, the mineralization degree of the second acid solution is between the mineralization degree of the first acid solution and the mineralization degree of the formation water;
in yet another possible scenario, the second acid solution has a mineralization close to the mineralization of the formation water.
As one skilled in the art will appreciate, the higher the degree of mineralization, the greater the density of water.
Thus, the presence or absence of formation water in the reservoir can be determined based on the second degree of mineralization of the second acid fluid.
S104, determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing.
In this embodiment, the production conditions after acid fracturing include the oil-producing time and the water-producing time after acid fracturing.
And determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference determined in the step S102 and the first acid liquid parameter and the second acid liquid parameter determined in the step S103 and by combining the oil production time and the water production time after acid fracturing.
Specifically, the reservoir types comprise a large slotted hole body oil layer, a large slotted hole body oil-water layer, a small slotted hole body oil-water layer, a water layer and a dry layer.
According to the method for determining the carbonate reservoir type, provided by the embodiment of the invention, the bottom hole pressure difference is determined according to the first bottom hole pressure value and the second bottom hole pressure value by acquiring the first bottom hole pressure value of the reservoir to be detected before acid fracturing and the second bottom hole pressure value after acid fracturing; acquiring a first acid liquid parameter injected into a reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing; and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing. The reservoir type determined by the method provides data reference and theoretical basis for subsequent carbonate oil and gas development.
Fig. 2 is a schematic flow chart of a method for determining a carbonate reservoir type according to another embodiment of the present invention, and as shown in fig. 2, the method for determining a carbonate reservoir type according to this embodiment includes the following steps:
s201, acquiring a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing;
s202, determining a bottom hole pressure difference according to the first bottom hole pressure value and the second bottom hole pressure value;
s201 and S202 of this embodiment are the same as S101 and S102 of the above embodiment, and for details, reference is made to the above embodiment, which is not described again in this embodiment.
S203, acquiring the acid liquor injection amount and the first mineralization degree of a first acid liquor injected into the reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of a second acid liquor discharged from the reservoir to be detected after acid fracturing;
s204, determining the acid liquid flowback rate of the reservoir to be detected according to the acid liquid injection amount of the first acid liquid and the acid liquid discharge amount of the second acid liquid;
in this embodiment, the acid solution injection amount of the first acid solution is V Note that The acid liquor discharge amount of the second acid liquor is V Row board And determining the acid liquor flowback rate K of the reservoir to be detected according to a formula seven:
K＝V row board /V Note that Formula seven
It should be noted that the reservoir type cannot be accurately judged only according to the value of the K value, and the reservoir type needs to be comprehensively judged by combining the bottom hole pressure difference, the formation water distribution condition and the production condition after acid fracturing.
S205, determining the stratum water distribution condition of the reservoir to be detected according to the first mineralization degree, the second mineralization degree and the stratum water mineralization degree;
in this embodiment, when the second salinity is close to the first salinity, it may be determined that the reservoir to be detected does not contain formation water;
when the second mineralization degree is close to the mineralization degree of the formation water, determining that a large amount of formation water exists in the reservoir to be detected;
when the second salinity is intervened between the first salinity and the salinity of the formation water, the existence of a small amount of formation water in the reservoir to be detected can be determined.
S206, determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
In this embodiment, the production conditions after acid fracturing include the oil-producing time and the water-producing time after acid fracturing.
And determining the reservoir type of the reservoir to be detected by combining the oil production time and the water production time after acid fracturing according to the bottom hole pressure difference determined in the step S202, the acid liquor flowback rate determined in the step S204 and the formation water distribution condition determined in the step S205.
Specifically, the reservoir types comprise a large slotted hole body oil layer, a large slotted hole body oil-water layer, a small slotted hole body oil-water layer, a water layer and a dry layer.
S206 is described in detail below with reference to a specific example.
The injection amount of the acid liquor injected into a certain reservoir to be detected is 500m 3 Detecting a first bottom hole pressure value before acid fracturing and a second bottom hole pressure value after acid fracturing, and determining a bottom hole pressure difference delta P; detecting the acid liquor discharge amount after acid fracturing, and determining the acid liquor flowback rate K; determining the stratum water distribution condition of the reservoir to be detected according to the second mineralization degree of the liquid except the oil liquid after acid fracturing; and determining the length of oil-meeting time and the length of water-meeting time according to the production condition after acid fracturing, and finally determining the reservoir type of the reservoir to be detected.
Table 1 is a reservoir type determination table.
TABLE 1
According to the method for determining the carbonate reservoir type, provided by the embodiment of the invention, the bottom hole pressure difference is determined according to the first bottom hole pressure value and the second bottom hole pressure value by acquiring the first bottom hole pressure value of the reservoir to be detected before acid fracturing and the second bottom hole pressure value after acid fracturing; acquiring the acid liquor injection amount and the first mineralization of first acid liquor injected into a reservoir to be detected, the acid liquor discharge amount and the second mineralization of second acid liquor discharged from the reservoir to be detected after acid fracturing, and determining the acid liquor flowback rate of the reservoir to be detected according to the acid liquor injection amount of the first acid liquor and the acid liquor discharge amount of the second acid liquor; determining the stratum water distribution condition of the reservoir to be detected according to the first salinity, the second salinity and the stratum water salinity; and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing. The reservoir type determined by the method provides data reference and theoretical basis for subsequent carbonate oil and gas development.
Fig. 3 is a schematic structural diagram of the device for determining a carbonate reservoir type according to the present invention, and as shown in fig. 3, the device 30 for determining a carbonate reservoir type according to the present embodiment includes:
the acquisition module 31 is used for acquiring a first bottom hole pressure value of the reservoir to be detected before acid fracturing and a second bottom hole pressure value of the reservoir to be detected after acid fracturing;
a determination module 32 for determining a bottom hole pressure difference from the first bottom hole pressure value and the second bottom hole pressure value;
the acquisition module 31 is further configured to acquire a first acid liquid parameter injected into the reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing;
the determining module 32 is further configured to determine the reservoir type of the reservoir to be detected according to the bottom-hole pressure difference, the first acid liquid parameter, the second acid liquid parameter, and the production condition after acid fracturing. The determining device for the carbonate reservoir type comprises an obtaining module and a determining module, wherein the obtaining module is used for obtaining a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing, and obtaining a first acid liquid parameter injected into the reservoir to be detected and a second acid liquid parameter discharged from the reservoir to be detected after acid fracturing; the determining module is used for determining a bottom hole pressure difference according to the first bottom hole pressure value and the second bottom hole pressure value, and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the first acid liquid parameter, the second acid liquid parameter and the production condition after acid fracturing. The reservoir type determined by the determining device provides data reference and theoretical basis for carbonate oil and gas development.
In a possible implementation manner, the obtaining module 31 is specifically configured to:
and acquiring the acid liquor injection amount and the first mineralization degree of the first acid liquor injected into the reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of the second acid liquor discharged from the reservoir to be detected after acid fracturing.
In a possible implementation manner, the determining module 32 is further configured to:
determining the acid liquor flowback rate of the reservoir to be detected according to the acid liquor injection amount of the first acid liquor and the acid liquor discharge amount of the second acid liquor; and
determining the stratum water distribution condition of the reservoir to be detected according to the first salinity, the second salinity and the stratum water salinity;
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
In one possible implementation, the reservoir types include a large slotted body oil layer, a large slotted body oil-water layer, a small slotted body oil-water layer, a water layer, and a dry layer.
The device for determining the type of the carbonate reservoir provided by this embodiment may implement the technical solutions of the method embodiments described above, and the implementation principle and technical effects are similar, and are not described herein again.
Fig. 4 is a hardware configuration diagram of the apparatus for determining a carbonate reservoir type according to the present invention, and as shown in fig. 4, the apparatus 40 for determining a carbonate reservoir type according to the present embodiment includes:
a memory 41;
a processor 42; and
a computer program;
wherein the computer program is stored in the memory 41 and configured to be executed by the processor 42 to implement the technical solution of any one of the foregoing method embodiments, and the implementation principle and technical effect are similar, which are not described herein again.
Alternatively, the memory 41 may be separate or integrated with the processor 42.
When the memory 41 is a device separate from the processor 42, the carbonate reservoir type determining apparatus 40 further includes:
a bus 43 for connecting the memory 41 and the processor 42.
Embodiments of the present invention also provide a computer readable storage medium having stored thereon a computer program for execution by processor 42 to carry out the steps as performed by the apparatus for determining a carbonate reservoir type in the above method embodiment.
The storage medium may be a magnetic Disk, an optical Disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a Flash Memory (Flash Memory), a Hard Disk (Hard Disk Drive, abbreviated as HDD), a Solid State Drive (SSD), or the like; the storage medium may also comprise a combination of memories of the kind described above.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and these modifications or substitutions do not depart from the spirit of the corresponding technical solutions of the embodiments of the present invention.
Claims (6)
1. A method of determining a carbonate reservoir type, comprising:
acquiring a first bottom hole pressure value of a reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing, and determining a bottom hole pressure difference according to the first bottom hole pressure value and the second bottom hole pressure value;
acquiring the acid liquor injection amount and the first mineralization degree of a first acid liquor injected into a reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of a second acid liquor discharged from the reservoir to be detected after acid fracturing;
determining the acid liquor flowback rate of the reservoir to be detected according to the acid liquor injection amount of the first acid liquor and the acid liquor discharge amount of the second acid liquor; and
determining the stratum water distribution condition of the reservoir to be detected according to the first mineralization degree, the second mineralization degree and the stratum water mineralization degree;
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
2. The method of claim 1,
the reservoir types comprise a large-scale fracture-cavity body oil layer, a large-scale fracture-cavity body oil-water layer, a small-scale fracture-cavity body oil-water layer, a water layer and a dry layer.
3. An apparatus for determining a carbonate reservoir type, comprising:
the acquisition module is used for acquiring a first bottom hole pressure value of the reservoir to be detected before acid fracturing and a second bottom hole pressure value after acid fracturing;
a determination module for determining a bottom hole pressure differential based on the first bottom hole pressure value and the second bottom hole pressure value;
the acquisition module is further used for acquiring the acid liquor injection amount and the first mineralization degree of the first acid liquor injected into the reservoir to be detected, and the acid liquor discharge amount and the second mineralization degree of the second acid liquor discharged from the reservoir to be detected after acid fracturing;
the determining module is further configured to determine an acid liquid flow back rate of the reservoir to be detected according to the acid liquid injection amount of the first acid liquid and the acid liquid discharge amount of the second acid liquid; and
determining the stratum water distribution condition of the reservoir to be detected according to the first mineralization degree, the second mineralization degree and the stratum water mineralization degree;
and determining the reservoir type of the reservoir to be detected according to the bottom hole pressure difference, the acid liquor flowback rate, the formation water distribution condition and the production condition after acid fracturing.
4. The apparatus of claim 3,
the reservoir types comprise a large-scale fracture-cavity body oil layer, a large-scale fracture-cavity body oil-water layer, a small-scale fracture-cavity body oil-water layer, a water layer and a dry layer.
5. An apparatus for determining a carbonate reservoir type, comprising:
a memory;
a processor; and
a computer program;
wherein the computer program is stored in the memory and configured to be executed by the processor to implement the method of claim 1 or 2.
6. A computer-readable storage medium, on which a computer program is stored which is executed by a processor to implement the method according to claim 1 or 2.
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