CN114002128A - Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid - Google Patents
Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid Download PDFInfo
- Publication number
- CN114002128A CN114002128A CN202111346794.3A CN202111346794A CN114002128A CN 114002128 A CN114002128 A CN 114002128A CN 202111346794 A CN202111346794 A CN 202111346794A CN 114002128 A CN114002128 A CN 114002128A
- Authority
- CN
- China
- Prior art keywords
- fracturing fluid
- mineralization
- fluid
- shale
- fracturing
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 191
- 230000033558 biomineral tissue development Effects 0.000 title claims abstract description 98
- 238000002474 experimental method Methods 0.000 title claims abstract description 10
- 230000035699 permeability Effects 0.000 claims abstract description 25
- 238000000034 method Methods 0.000 claims abstract description 17
- 230000006378 damage Effects 0.000 claims abstract description 11
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 8
- 238000011144 upstream manufacturing Methods 0.000 claims description 14
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 12
- 239000011148 porous material Substances 0.000 claims description 4
- 230000032683 aging Effects 0.000 claims description 3
- 238000005553 drilling Methods 0.000 claims description 3
- 238000001035 drying Methods 0.000 claims description 3
- 238000011156 evaluation Methods 0.000 claims description 3
- 238000011065 in-situ storage Methods 0.000 claims description 3
- 238000012545 processing Methods 0.000 claims description 3
- 239000011435 rock Substances 0.000 claims description 3
- 230000035882 stress Effects 0.000 claims description 3
- 230000000704 physical effect Effects 0.000 claims description 2
- 230000008569 process Effects 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 16
- 239000012071 phase Substances 0.000 description 8
- 239000000243 solution Substances 0.000 description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 230000009467 reduction Effects 0.000 description 4
- 238000006073 displacement reaction Methods 0.000 description 3
- ZRALSGWEFCBTJO-UHFFFAOYSA-N Guanidine Chemical compound NC(N)=N ZRALSGWEFCBTJO-UHFFFAOYSA-N 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 229910001873 dinitrogen Inorganic materials 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- CHJJGSNFBQVOTG-UHFFFAOYSA-N N-methyl-guanidine Natural products CNC(N)=N CHJJGSNFBQVOTG-UHFFFAOYSA-N 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000003113 dilution method Methods 0.000 description 1
- SWSQBOPZIKWTGO-UHFFFAOYSA-N dimethylaminoamidine Natural products CN(C)C(N)=N SWSQBOPZIKWTGO-UHFFFAOYSA-N 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 229910052749 magnesium Inorganic materials 0.000 description 1
- 239000011777 magnesium Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 230000001737 promoting effect Effects 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 230000001954 sterilising effect Effects 0.000 description 1
- 238000004659 sterilization and disinfection Methods 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Chemical & Material Sciences (AREA)
- General Health & Medical Sciences (AREA)
- Immunology (AREA)
- Dispersion Chemistry (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- Fluid Mechanics (AREA)
- General Physics & Mathematics (AREA)
- Health & Medical Sciences (AREA)
- Pathology (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
Abstract
The invention relates to an experimental method for rapidly optimizing the mineralization degree of a fracturing fluid of a shale reservoir, which is characterized in that the mineralization degree of the fracturing fluid corresponding to the mineralization degree just higher than 30% is the optimal mineralization degree of the fracturing fluid by calculating the damage rates of the shale gas-phase permeability when a fracturing fluid return fluid mineralization degree solution, an 3/4 fracturing fluid return fluid mineralization degree solution, a 1/2 fracturing fluid return fluid mineralization degree solution and a 1/4 fracturing fluid return fluid mineralization degree solution are pressurized and saturated on the basis of the shale gas-phase permeability of the initial mineralization degree of the fracturing fluid. The method better simulates the transportation process of gas in the shale after the fracturing fluid with different degrees of mineralization enters the shale reservoir, the degree of mineralization of the optimized fracturing fluid is more accurate, the operation is simple, convenient and quick, the optimal degree of mineralization of the fracturing fluid required by the fracturing of the shale reservoir can be quickly evaluated, and theoretical basis and guidance are provided for the degree of mineralization selection of the fracturing fluid configuration of the shale reservoir on site.
Description
Technical Field
The invention relates to an experimental method for quickly optimizing the mineralization degree of a shale reservoir fracturing fluid in the fields of petroleum, geology and mining.
Background
The staged hydraulic fracturing technology of the horizontal well is a key technology for commercial exploitation of shale gas, the length of the horizontal section of the shale gas well is 1500m, and the dosage of the fracturing fluid used in fracturing construction is 30000m3The above. The water for preparing the fracturing fluid is required to be clear and transparent, has no impurities and has the pH value of 6.5-7.5. River water is usually used as a base fluid to prepare the fracturing fluid on site, and the mineralization degree of the prepared fracturing fluid is usually below 300 mg/L. The flowback rate of the fracturing fluid entering the shale reservoir is usually between 30% and 50%, the flowback rate of the fracturing fluid of the normal-pressure shale reservoir is greater than that of the fracturing fluid of the high-pressure and abnormally high-pressure shale reservoir, and the flowback rate can reach more than 90%. The shale fracturing fluid flowback fluid has the characteristics of complex components (mainly guanidine gum and high polymer, and sulfate reducing bacteria, sulfide, iron, magnesium, calcium and the like) and high treatment difficulty, and in order to save treatment cost and reduce the harm of the fracturing fluid flowback fluid to the environment, the shale fracturing fluid flowback fluid is usually reinjected and is used as a base fluid to prepare the fracturing fluid after simple sterilization and solid phase removal treatment.
The low-mineralization fracturing fluid enters the shale reservoir, so that more micro cracks can be generated, and meanwhile, the flowback rate of the fracturing fluid is lower, so that the treatment cost of the fracturing fluid is reduced. The method for reducing the mineralization degree of the fracturing fluid adopted on site is a dilution method, the clear fracturing fluid and the fracturing fluid flowback fluid are mixed according to different proportions, so that the purpose of reducing the mineralization degree of the fracturing fluid is achieved, and scientific theoretical guidance is not formed for how much the mineralization degree of the fracturing fluid is reduced, and the yield of a shale gas well can be ensured, and the treatment cost of the fracturing fluid flowback fluid can be reduced. Therefore, a set of experimental evaluation method which is simple and convenient to operate and can quickly and preferably select the mineralization degree of the fracturing fluid suitable for a specific reservoir stratum is urgently needed.
Disclosure of Invention
The technical problem to be solved by the invention is as follows: in order to overcome the defects in the prior art, the invention provides an experimental method for quickly optimizing the mineralization degree of the fracturing fluid of the shale reservoir, so as to quickly obtain the mineralization degree of the optimal fracturing fluid which is provided by comprehensively considering factors such as the fracturing fluid crack promoting effect, the flowback fluid treatment cost and the like.
The technical scheme adopted by the invention for solving the technical problems is as follows: an experimental method for rapidly optimizing the mineralization degree of a shale reservoir fracturing fluid comprises the following steps:
s1, drilling five shale samples with similar components and physical properties on the same full-diameter core along bedding, processing the shale samples into a plunger shape with the diameter of 25mm and the length of 50mm, drying the five shale samples for 24 hours at 65 ℃, and vacuumizing for 4 hours for later use;
s2, mixing the fracturing fluid flowback fluid with fracturing fluid prepared by taking river water as base fluid according to different proportions to prepare fracturing fluid with different mineralization degrees by taking the fracturing fluid flowback fluid as the base fluid;
s3, placing the shale sample in the prepared fracturing fluid for vacuumizing and pressurizing saturation, wherein the vacuumizing time is 4h, and the pressurizing saturation pressure is the median saturation pressure of the shale sample;
s4, placing the shale sample in a core holder, aging for 24h under in-situ effective stress, and then evaluating the permeability of the shale sample in fracturing fluids with different mineralization degrees through a pressure attenuation method;
and S5, calculating the shale gas phase permeability damage rate when the fracturing fluid flow-back fluid mineralization solution, 3/4 fracturing fluid flow-back fluid mineralization solution, 1/2 fracturing fluid flow-back fluid mineralization solution and 1/4 fracturing fluid flow-back fluid mineralization solution are pressurized and saturated by taking the initial fracturing fluid mineralization shale gas phase permeability as a reference, wherein the shale gas phase permeability damage rate is the optimal fracturing fluid mineralization rate, and the corresponding fracturing fluid mineralization rate with the permeability damage rate of just more than 30% is the optimal fracturing fluid mineralization rate.
Preferably, in the step S2, the configured mineralization degrees of the fracturing fluid are 1:0, 3:1, 1:3 and 0:1 in total, which correspond to five shale samples, respectively, and the mineralization degrees corresponding to the five proportions sequentially include a mineralization degree of a fracturing fluid flow-back fluid, a mineralization degree of a 3/4 fracturing fluid flow-back fluid, a mineralization degree of a 1/2 fracturing fluid flow-back fluid, a mineralization degree of a 1/4 fracturing fluid flow-back fluid and a mineralization degree of a fracturing fluid configured with river water.
Specifically, in step S4, the pressure attenuation method evaluation includes the steps of:
(1) recording the pressure attenuation curve of the upstream end of the rock core in real time, and obtaining the ratio F of the residual gas to the total gas volumeR，FRCan be calculated from equation 1:
wherein, Pci-initial pressure of the upstream end chamber in Pa;
Pc-the pressure at the upstream end of the sample at time t, in Pa;
Psi-initial pressure of the sample, in Pa;
a, the ratio of the pore volume of the core to the volume of the chamber at the upstream end;
(2) drawing a straight line ln (F)R) F + mt, wherein f is the intercept of the straight line in the y direction, m is the intercept of the straight line, t is the time of pressure decay in the unit of s, and the shale gas-phase permeability damage rate I after the fracturing fluid is saturated under pressure under different mineralization degrees is calculated according to the formula 2D；
In the formula, m0Ln (F) after pressurized saturation of fracturing fluid with river water as baseR) Slope from time t, miAnd (3) the slope of a straight line after the fracturing fluid flow-back fluid with different mineralization degrees is pressurized and saturated, wherein i is 1,2,3 and 4 respectively correspond to the mineralization degrees of the fracturing fluid flow-back fluid, 3/4, 1/2 and 1/4.
The invention has the beneficial effects that:
(1) the permeability of the shale base block is extremely low, the permeability cannot be accurately measured by a conventional steady state method, the method is simple, convenient and quick to operate, and the optimal mineralization degree of the fracturing fluid required by the fracturing of the shale reservoir can be quickly evaluated.
(2) The method well simulates the transportation process of gas in the shale after the fracturing fluid with different mineralization degrees enters the shale reservoir, and the optimized fracturing fluid mineralization degree is more accurate and more in line with the field reality.
(3) The method provides a new idea and a new method for optimizing the mineralization degree of the fracturing fluid, and provides theoretical basis and guidance for the selection of the mineralization degree of the fracturing fluid preparation of the shale reservoir on site.
Drawings
The invention is further illustrated with reference to the following figures and examples.
FIG. 1 is a schematic diagram of the experimental apparatus according to the present invention.
In the figure: 1. the device comprises a nitrogen cylinder, a pressure reducing valve, a six-way valve, a core holder, a confining pressure pump, a micro container, a shale sample, a core plug, a pressure sensor and a computer, wherein the pressure reducing valve is 2, the six-way valve is 3, the core holder is 4, the confining pressure pump is 5, the micro container is 6, the shale sample is 7, the core plug is 8, the pressure sensor is 9, and the computer is 10.
Detailed Description
The present invention will now be described in further detail with reference to the accompanying drawings. These drawings are simplified schematic views illustrating only the basic structure of the present invention in a schematic manner, and thus show only the constitution related to the present invention.
As shown in fig. 1, the experimental device for rapidly optimizing the mineralization degree of the shale reservoir fracturing fluid is composed of an air source system, five sets of core displacement systems and a data acquisition system, wherein the air source system, the core displacement systems and the data acquisition system are connected through a steel metal pipeline, the wall thickness of the metal pipeline is 2mm, and the pressure resistance is 90 MPa.
The air source system comprises: the device consists of a nitrogen gas bottle 1, a pressure reducing valve 2 and a six-way valve 3, wherein the six-way valve 3 is provided with six air ports, and the nitrogen gas bottle 1 is communicated with one air port of the six-way valve 3 through the pressure reducing valve 2.
The core displacement system comprises: the device is provided with five core holders 4, a confining pressure pump 5 and a micro container 6, a shale sample 7 is arranged in the core holders 4, a core plug 8 is arranged at the rear end of the shale sample 7, the other five air ports of the six-way valve 3 are correspondingly connected with the five core holders 4 through pipelines, the micro container 6 is arranged on the pipeline at the front end of the core holder 4, and the confining pressure pump 5 is connected with the pipeline on the side wall of the core holder 4.
A data acquisition system: the pressure sensor 9 and the computer 10 are connected by a line, and the pressure sensor 9 is connected to a pipe on the front side of the micro-container 6.
An experimental method for rapidly optimizing the mineralization degree of a shale reservoir fracturing fluid by adopting the experimental device comprises the following steps:
(1) drilling five shale samples 7 on a full-diameter rock core with a non-developed crack along bedding, processing the five shale samples 7 into a plunger shape with the diameter of 25mm and the length of 50mm, drying the shale samples 7 at 65 ℃ for 24h, and vacuumizing for 4h for later use;
(2) mixing the fracturing fluid flowback fluid with fracturing fluid prepared by taking river water as base fluid according to different proportions to prepare fracturing fluid with different mineralization degrees by taking the fracturing fluid flowback fluid as the base fluid, wherein the prepared proportions are 1:0 and 3: 1; 1:1, 1:3 and 0:1, which respectively correspond to five shale samples 7, and the corresponding mineralization degrees of the shale samples are the mineralization degree of a fracturing fluid flowback fluid, the mineralization degree of an 3/4 fracturing fluid flowback fluid, the mineralization degree of a 1/2 fracturing fluid flowback fluid, the mineralization degree of a 1/4 fracturing fluid flowback fluid and the mineralization degree of a fracturing fluid prepared by river water.
(3) And respectively vacuumizing and pressurizing the five shale samples 7 in the fracturing fluid with the corresponding configuration proportion for saturation for 4h, wherein the pressurizing saturation pressure is the saturation median pressure of the shale samples 7, and the saturation pressure is 20 MPa.
(4) Respectively placing five shale samples 7 in respective core holders 4, pressurizing the core holders 4 through a confining pressure pump 5, and respectively placing the mineralization degrees of fracturing fluid flowback fluid, 3/4 fracturing fluid flowback fluid, 1/2 fracturing fluid flowback fluid, 1/4 fracturing fluid flowback fluid and the mineralization degrees of fracturing fluid configured by river water in the five core holders 4; the method comprises the steps of aging for 24 hours under the in-situ effective stress of 25MPa, and then evaluating the permeability of five shale samples 7 after pressurization saturation in fracturing fluids with different mineralization degrees by adopting a pressure attenuation method.
(5) Opening the nitrogen cylinder 1, the six-way valve 3 and a valve on a pipeline to enable the gas pressure at the inlet end of the core holder 4 to reach 2MPa, then closing the valve, transmitting signals through the pressure sensor 9, and recording the pressure attenuation curve at the upstream end of the shale sample 7 by the computer 10 in real time.
The ratio F of the residual gas to the total gas volume at the time t of the pressure decay process is calculated by the following formulaR
In the formula, Pci-initial pressure of the upstream end chamber, Pa;
Pc-the pressure, Pa, at the upstream end of the sample at time t;
Psi-initial pressure of the sample, Pa;
a is the ratio of the core pore volume to the upstream end chamber volume.
The core pore volume can be calculated according to the porosity and the apparent volume of the core, and the upstream end chamber volume is the sum of the upstream end pipeline of the core and the volume of the micro container 6.
(6) Drawing a straight line ln (F)R) F + mt, where f is the intercept of the straight line in the y-direction, dimensionless; m is the intercept of a straight line, and is dimensionless; t is the time of pressure decay, s, the intercept of a straight line is obtained, and the shale gas phase permeability reduction rate I after the fracturing fluid is pressurized and saturated under different mineralization degrees is calculated according to the following formulaD。
In the formula, m0After shale pressurized saturation of fracturing fluid prepared with river water as base fluid (F)R) The slope from time t, dimensionless; m isiAnd (3) the slope of a straight line after the fracturing fluid flow-back fluid with different mineralization degrees is pressurized and saturated, and the slope is dimensionless, wherein i is 1,2,3 and 4 respectively correspond to the mineralization degrees of the fracturing fluid flow-back fluid, 3/4 the mineralization degree of the fracturing fluid flow-back fluid, 1/2 the mineralization degree of the fracturing fluid flow-back fluid and 1/4 the mineralization degree of the fracturing fluid flow-back fluid.
And calculating the shale gas phase permeability reduction rate when the fracturing fluid flow-back fluid mineralization solution, the 3/4 fracturing fluid flow-back fluid mineralization solution, the 1/2 fracturing fluid flow-back fluid mineralization solution and the 1/4 fracturing fluid flow-back fluid mineralization solution are subjected to pressurization saturation by taking the shale gas phase permeability of the initial fracturing fluid mineralization as a reference, wherein the shale gas phase permeability reduction rate is the optimal fracturing fluid mineralization rate, and the corresponding fracturing fluid mineralization rate with the permeability reduction rate of just more than 30 percent is the optimal fracturing fluid mineralization rate.
According to the invention, the permeability is not required to be tested independently, the permeability change characteristic (namely the permeability damage degree) can be obtained only according to the pressure change curve, and the operation process is quick, simple and convenient.
In light of the foregoing description of the preferred embodiment of the present invention, many modifications and variations will be apparent to those skilled in the art without departing from the spirit and scope of the invention. The technical scope of the present invention is not limited to the content of the specification, and must be determined according to the scope of the claims.
Claims (3)
1. An experimental method for rapidly optimizing the mineralization degree of a shale reservoir fracturing fluid is characterized by comprising the following steps: comprises the following steps:
s1, drilling five shale samples with similar components and physical properties on the same full-diameter core along bedding, processing the shale samples into a plunger shape with the diameter of 25mm and the length of 50mm, drying the five shale samples for 24 hours at 65 ℃, and vacuumizing for 4 hours for later use;
s2, mixing the fracturing fluid flowback fluid with fracturing fluid prepared by taking river water as base fluid according to different proportions to prepare fracturing fluid with different mineralization degrees by taking the fracturing fluid flowback fluid as the base fluid;
s3, placing the shale sample in the prepared fracturing fluid for vacuumizing and pressurizing saturation, wherein the vacuumizing time is 4h, and the pressurizing saturation pressure is the median saturation pressure of the shale sample;
s4, placing the shale sample in a core holder, aging for 24h under in-situ effective stress, and then evaluating the permeability of the shale sample in fracturing fluids with different mineralization degrees through a pressure attenuation method;
and S5, calculating the shale gas phase permeability damage rate when the fracturing fluid flow-back fluid mineralization solution, 3/4 fracturing fluid flow-back fluid mineralization solution, 1/2 fracturing fluid flow-back fluid mineralization solution and 1/4 fracturing fluid flow-back fluid mineralization solution are pressurized and saturated by taking the initial fracturing fluid mineralization shale gas phase permeability as a reference, wherein the shale gas phase permeability damage rate is the optimal fracturing fluid mineralization rate, and the corresponding fracturing fluid mineralization rate with the permeability damage rate of just more than 30% is the optimal fracturing fluid mineralization rate.
2. The experimental method for rapidly optimizing the mineralization degree of the shale reservoir fracturing fluid, as set forth in claim 1, is characterized in that: in step S2, the prepared fracturing fluid has mineralization ratios of 1:0, 3:1, 1:3 and 0:1, which correspond to five shale samples, respectively, and the mineralization ratios corresponding to the five ratios are the mineralization ratio of the fracturing fluid flow-back fluid, the mineralization ratio of the 3/4 fracturing fluid flow-back fluid, the mineralization ratio of the 1/2 fracturing fluid flow-back fluid, the mineralization ratio of the 1/4 fracturing fluid flow-back fluid and the mineralization ratio of the fracturing fluid prepared from river water.
3. The experimental method for rapidly optimizing the mineralization degree of the shale reservoir fracturing fluid, as set forth in claim 1, is characterized in that: in step S4, the pressure attenuation method evaluation includes the steps of:
(1) recording the pressure attenuation curve of the upstream end of the rock core in real time, and obtaining the ratio F of the residual gas to the total gas volumeR，FRCan be calculated from equation 1:
wherein, Pci-initial pressure of the upstream end chamber in Pa;
Pc-the pressure at the upstream end of the sample at time t, in Pa;
Psi-initial pressure of the sample, in Pa;
a, the ratio of the pore volume of the core to the volume of the chamber at the upstream end;
(2) drawing a straight line ln (F)R) Where f is the intercept of the line in the y-direction, m is the intercept of the line, and t is the time of pressure decay, in units of s, according to the commonFormula 2, calculating the shale gas-phase permeability damage rate I after fracturing fluid pressurization saturation under different mineralization degreesD；
In the formula, m0Ln (F) after pressurized saturation of fracturing fluid with river water as baseR) Slope from time t, miAnd (3) the slope of a straight line after the fracturing fluid flow-back fluid with different mineralization degrees is pressurized and saturated, wherein i is 1,2,3 and 4 respectively correspond to the mineralization degrees of the fracturing fluid flow-back fluid, 3/4, 1/2 and 1/4.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111346794.3A CN114002128A (en) | 2021-11-15 | 2021-11-15 | Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111346794.3A CN114002128A (en) | 2021-11-15 | 2021-11-15 | Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN114002128A true CN114002128A (en) | 2022-02-01 |
Family
ID=79929138
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111346794.3A Pending CN114002128A (en) | 2021-11-15 | 2021-11-15 | Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114002128A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN115059460A (en) * | 2022-07-14 | 2022-09-16 | 重庆大学 | Method for reducing self-water-absorbing capacity of hydraulic fracturing shale reservoir |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101487831A (en) * | 2009-02-06 | 2009-07-22 | 西南石油大学 | Method for fast confirming compact rock core damage |
| CN106153518A (en) * | 2016-06-22 | 2016-11-23 | 西南石油大学 | Compact sandstone gas reservoir fracturing liquid damage experimental evaluation method |
| CN206399784U (en) * | 2017-01-10 | 2017-08-11 | 中国石油大学(华东) | One kind vibration auxiliary imbibition experimental provision |
| CN108152330A (en) * | 2017-11-14 | 2018-06-12 | 中国石油天然气股份有限公司 | Measure experimental system and method that infiltration voltage influences shale |
| CN109115822A (en) * | 2018-08-20 | 2019-01-01 | 西安石油大学 | Salinity is evaluated to the method for shale gas reservoir self-priming leading edge migration capacity |
| CN113218832A (en) * | 2020-02-04 | 2021-08-06 | 中国石油天然气股份有限公司 | Shale osmotic pressure simulation generation device, measurement experiment system and method |
| CN113605873A (en) * | 2021-07-30 | 2021-11-05 | 中国石油大学(华东) | Method and system for determining optimal mineralization degree of fracturing fluid for inhibiting pulverized coal retention in fracturing |
-
2021
- 2021-11-15 CN CN202111346794.3A patent/CN114002128A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101487831A (en) * | 2009-02-06 | 2009-07-22 | 西南石油大学 | Method for fast confirming compact rock core damage |
| CN106153518A (en) * | 2016-06-22 | 2016-11-23 | 西南石油大学 | Compact sandstone gas reservoir fracturing liquid damage experimental evaluation method |
| CN206399784U (en) * | 2017-01-10 | 2017-08-11 | 中国石油大学(华东) | One kind vibration auxiliary imbibition experimental provision |
| CN108152330A (en) * | 2017-11-14 | 2018-06-12 | 中国石油天然气股份有限公司 | Measure experimental system and method that infiltration voltage influences shale |
| CN109115822A (en) * | 2018-08-20 | 2019-01-01 | 西安石油大学 | Salinity is evaluated to the method for shale gas reservoir self-priming leading edge migration capacity |
| CN113218832A (en) * | 2020-02-04 | 2021-08-06 | 中国石油天然气股份有限公司 | Shale osmotic pressure simulation generation device, measurement experiment system and method |
| CN113605873A (en) * | 2021-07-30 | 2021-11-05 | 中国石油大学(华东) | Method and system for determining optimal mineralization degree of fracturing fluid for inhibiting pulverized coal retention in fracturing |
Non-Patent Citations (5)
| Title |
|---|
| CHEN M, BAI J, KANG Y, ET AL: "Redistribution of fracturing fluid in shales and its impact on gas transport capacity", JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING, vol. 86, 9 December 2020 (2020-12-09), pages 1 - 11, XP086433879, DOI: 10.1016/j.jngse.2020.103747 * |
| 何泽轩;: "压裂液矿化度对致密储层渗吸作用的影响", 云南化工, no. 07 * |
| 康毅力;张晓磊;游利军;杜新龙;: "压力衰减法在大牛地致密储层流体敏感性评价中的应用", 钻井液与完井液, vol. 30, no. 06, 30 November 2013 (2013-11-30) * |
| 游利军;王飞;康毅力;方朝合;陈强;: "页岩气藏水相损害评价与尺度性", 天然气地球科学, vol. 27, no. 11, 10 November 2016 (2016-11-10) * |
| 黄波;李猛;战永平;李杨;李海鹏;: "滩坝砂储层压裂液伤害及敏感性评价研究", 内蒙古石油化工, no. 22, pages 150 - 153 * |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN115059460A (en) * | 2022-07-14 | 2022-09-16 | 重庆大学 | Method for reducing self-water-absorbing capacity of hydraulic fracturing shale reservoir |
| CN115059460B (en) * | 2022-07-14 | 2024-05-03 | 重庆大学 | Method for reducing self-water absorption of hydraulically fractured shale reservoir |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN110296921B (en) | Testing device and testing method for shale gas permeability under reservoir conditions in steady state method | |
| CN105910971B (en) | The simultaneous measuring method of rich organic matter compact rock core gas permeability and diffusion coefficient | |
| CN106525690B (en) | Method for measuring gas-water relative permeability curve by tight sandstone steady-state method | |
| CN111257202A (en) | Shale fracturing fluid forced imbibition and flowback experimental method under condition of containing adsorbed gas | |
| CN101968423B (en) | Low-permeability reservoir bed starting pressure testing method | |
| CN104502224B (en) | Saturation water Coal Under rock isothermal desorption curve determination device and method | |
| CN106596380B (en) | Shale staged fracturing horizontal well fracturing fluid flowback capability evaluation method and device | |
| EP3391025A1 (en) | Method and device for determining gas permeability of a subsurface formation | |
| Lyu et al. | Effects of testing method, lithology and fluid-rock interactions on shale permeability: a review of laboratory measurements | |
| CN109470617A (en) | A kind of quick experimental evaluation method of Fractured compact sandstone gas layer fluid speed | |
| CN105137039B (en) | Damage evaluation method for multi-scalemass transfer capability of coal rock reservoir gas | |
| CN110261274B (en) | Evaluation method for static contribution rate of spontaneous imbibition effect on water flooding oil displacement efficiency | |
| CN106198338A (en) | Shale reservoir fracturing crack stress sensitive system safety testing device and the method using it | |
| CN103926184B (en) | Rock core gas surveys porosity detection method and detection device thereof | |
| CN104594885A (en) | Measuring test device and method for seepage law of shale gas in microfractures | |
| CN110242290B (en) | Shale core bedding crack flow simulation evaluation device and method | |
| CN108956854B (en) | Device for evaluating plugging performance of temporary plugging steering fluid and testing method thereof | |
| CN114002128A (en) | Experimental method for quickly optimizing mineralization degree of shale reservoir fracturing fluid | |
| Wang et al. | Seepage law and permeability calculation of coal gas based on Klinkenberg effect | |
| CN103994958B (en) | A kind of for measuring the measurement apparatus of ultra-low penetration rock core gas permeability and utilizing the measuring method of this device | |
| Roychaudhuri et al. | Shale-fluid interactions during forced lmbibition and flow-back | |
| Lu et al. | Gas flow characteristics in shale fractures after supercritical CO2 soaking | |
| Galeczka et al. | A novel high pressure column flow reactor for experimental studies of CO2 mineral storage | |
| CN112304842B (en) | Shale oil CO2/N2Alternating displacement injection quantity simulation analysis method | |
| Su et al. | The discovery and control of slug flow in coalbed methane reservoir |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |