CN109001097B - Visual fracturing fluid spontaneous imbibition research device and method - Google Patents
Visual fracturing fluid spontaneous imbibition research device and method Download PDFInfo
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- CN109001097B CN109001097B CN201810878659.5A CN201810878659A CN109001097B CN 109001097 B CN109001097 B CN 109001097B CN 201810878659 A CN201810878659 A CN 201810878659A CN 109001097 B CN109001097 B CN 109001097B
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- 239000012530 fluid Substances 0.000 title claims abstract description 183
- 238000000034 method Methods 0.000 title claims abstract description 71
- 238000005213 imbibition Methods 0.000 title claims abstract description 65
- 230000002269 spontaneous effect Effects 0.000 title claims abstract description 56
- 238000011160 research Methods 0.000 title claims abstract description 29
- 230000000007 visual effect Effects 0.000 title claims abstract description 20
- 230000003287 optical effect Effects 0.000 claims abstract description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 79
- 229920006395 saturated elastomer Polymers 0.000 claims description 45
- 238000006073 displacement reaction Methods 0.000 claims description 23
- 229920001971 elastomer Polymers 0.000 claims description 16
- 239000005060 rubber Substances 0.000 claims description 16
- 239000003350 kerosene Substances 0.000 claims description 11
- MCPLVIGCWWTHFH-UHFFFAOYSA-L methyl blue Chemical compound [Na+].[Na+].C1=CC(S(=O)(=O)[O-])=CC=C1NC1=CC=C(C(=C2C=CC(C=C2)=[NH+]C=2C=CC(=CC=2)S([O-])(=O)=O)C=2C=CC(NC=3C=CC(=CC=3)S([O-])(=O)=O)=CC=2)C=C1 MCPLVIGCWWTHFH-UHFFFAOYSA-L 0.000 claims description 7
- 238000010276 construction Methods 0.000 claims description 4
- 238000004043 dyeing Methods 0.000 claims description 2
- XOSXWYQMOYSSKB-LDKJGXKFSA-L water blue Chemical compound CC1=CC(/C(\C(C=C2)=CC=C2NC(C=C2)=CC=C2S([O-])(=O)=O)=C(\C=C2)/C=C/C\2=N\C(C=C2)=CC=C2S([O-])(=O)=O)=CC(S(O)(=O)=O)=C1N.[Na+].[Na+] XOSXWYQMOYSSKB-LDKJGXKFSA-L 0.000 claims description 2
- 230000032683 aging Effects 0.000 claims 1
- 238000004088 simulation Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 114
- 239000011148 porous material Substances 0.000 description 12
- 239000007789 gas Substances 0.000 description 10
- 239000007788 liquid Substances 0.000 description 9
- 239000010779 crude oil Substances 0.000 description 7
- 239000011435 rock Substances 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 5
- 230000014759 maintenance of location Effects 0.000 description 4
- 239000003086 colorant Substances 0.000 description 3
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- 238000002474 experimental method Methods 0.000 description 2
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 241000282414 Homo sapiens Species 0.000 description 1
- 239000005062 Polybutadiene Substances 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- FFBHFFJDDLITSX-UHFFFAOYSA-N benzyl N-[2-hydroxy-4-(3-oxomorpholin-4-yl)phenyl]carbamate Chemical compound OC1=C(NC(=O)OCC2=CC=CC=C2)C=CC(=C1)N1CCOCC1=O FFBHFFJDDLITSX-UHFFFAOYSA-N 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
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- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000007689 inspection Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 238000000399 optical microscopy Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000000049 pigment Substances 0.000 description 1
- 229920002857 polybutadiene Polymers 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011002 quantification Methods 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 238000011179 visual inspection Methods 0.000 description 1
- 238000012800 visualization Methods 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
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- 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
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/84—Systems specially adapted for particular applications
- G01N21/85—Investigating moving fluids or granular solids
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/84—Systems specially adapted for particular applications
- G01N2021/8405—Application to two-phase or mixed materials, e.g. gas dissolved in liquids
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- Physics & Mathematics (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Dispersion Chemistry (AREA)
- Investigating Or Analysing Materials By Optical Means (AREA)
- Investigating Or Analyzing Non-Biological Materials By The Use Of Chemical Means (AREA)
Abstract
The invention relates to a visual fracturing fluid spontaneous imbibition research device and method, wherein the device comprises a booster pump, a first burette, a second burette, a core sheet and a vacuum pump; the inlet end of the core slice is connected with one end of the first burette, and the outlet end of the core slice is connected with one end of the second burette; when the core slice is vacuumized, the other end of the second buret is connected with a vacuum pump; when the core slice is driven forward, the other end of the first burette is connected with the pressurizing pump; when the core slice is reversely driven, the other end of the second buret is connected with the pressurizing pump, the device can simulate the whole hydraulic fracturing process to study the spontaneous imbibition of the fracturing fluid, and the spontaneous imbibition phenomenon can be observed and recorded by naked eyes and optical microscope equipment during simulation, so that the characteristic of the spontaneous imbibition of the fracturing fluid can be obtained qualitatively and quantitatively finally.
Description
Technical Field
The invention relates to the technical field of oil and gas reservoir development, in particular to a visual fracturing fluid spontaneous imbibition research device and method.
Background
Along with the increase of the dependence degree of human beings on resources such as petroleum, natural gas and the like, the unconventional oil gas exploitation gradually becomes a main task of oil gas exploitation in countries around the world in recent decades. In general, unconventional oil and gas resources have the characteristics of large resource amount and large exploitation difficulty, and in order to form industrial oil and gas flows, the unconventional oil and gas resources must be subjected to yield increasing operation different from the conventional oil and gas resources. Hydraulic fracturing operations are one of the important means of producing unconventional hydrocarbon resources.
After hydraulic fracturing is usually carried out, the fracturing fluid needs to be quickly reversely discharged to prevent the fracturing fluid from damaging a reservoir, and oil gas is brought out after the fracturing fluid is reversely discharged, so that a fracturing well can be rapidly put into production. But the situation in the field is exactly opposite to the above knowledge: after fracturing some tight sandstone reservoirs, the reverse drainage rate of fracturing fluids of many wells is extremely low, but the yield is very high, and the reverse drainage rate of fracturing fluids of few wells is high, but the yield of single wells is relatively low.
Imbibition refers to the process by which a porous medium spontaneously imbibes some wetting fluid, and since the kinetics of imbibition are primarily due to capillary forces, spontaneous imbibition occurs mostly in tight reservoirs. Thus, the fracturing fluid in the tight reservoir which is not reversely discharged is imbibed to displace the crude oil, thereby causing the above phenomena on site.
Most of the existing spontaneous imbibition research methods are methods for researching spontaneous imbibition of water into core-displaced crude oil, and in recent years, many experimental methods take surfactants, various chemical reagents and stratum conditions into consideration. However, there are few research methods capable of completely displaying the whole spontaneous imbibition process and researching the spontaneous imbibition phenomenon of the fracturing fluid in the hydraulic fracturing process.
Disclosure of Invention
Aiming at the defects existing in the existing spontaneous imbibition research method, such as incapability of visually observing the whole imbibition process for researchers and almost no research method for researching imbibition of fracturing fluid, the invention provides a visual device and a method for researching spontaneous imbibition of fracturing fluid. The invention aims to study spontaneous imbibition of the fracturing fluid, and enable researchers to intuitively observe the spontaneous imbibition phenomenon, and finally obtain the spontaneous imbibition of the fracturing fluid qualitatively or quantitatively.
In order to achieve the above purpose, the present invention adopts the following technical scheme:
a visual fracturing fluid spontaneous imbibition research device comprises a booster pump, a first burette, a second burette, a core slice and a vacuum pump; the inlet end of the core slice is connected with one end of the first burette, and the outlet end of the core slice is connected with one end of the second burette;
when the core slice is vacuumized, the other end of the second buret is connected with a vacuum pump;
when the core slice is driven forward, the other end of the first burette is connected with the pressurizing pump;
when the core slice is driven reversely, the other end of the second buret is connected with the pressurizing pump.
Preferably, the forward driving means that the core sheet is driven by pressurizing the core sheet at the inlet end of the core sheet; the reverse driving means that the outlet end of the rock core sheet is used for pressurizing and driving the rock core sheet, and in the method, vacuumizing, saturated water, saturated oil and fracturing fluid displacement are all in a forward driving mode; the oil back-drive fracturing fluid is in a back-drive mode.
Preferably, the core sheet comprises a core sheet, and the core sheet is arranged in the center of the viewing area of the optical microscope.
Preferably, the inlet end of the core slice is connected with the first burette through a rubber hose.
Preferably, the outlet end of the core slice is connected with the second burette through a rubber hose.
Preferably, the first burette is connected with the pressurizing pump through a rubber hose.
Preferably, the rubber hose is a butadiene rubber hose.
The visual fracturing fluid spontaneous imbibition research method is carried out by the device and comprises the following steps of:
(1) Vacuumizing: filling water in the first buret, and emptying the second buret; stopping a passage between the first buret and the inlet end of the core slice, and vacuumizing the core slice through a vacuum pump;
(2) Saturated water: after the vacuum pumping is finished, the passage between the second buret and the vacuum pump is cut off; conducting a passage between the first burette 3 and the inlet end of the core sheet; saturating the core of the core sheet with water, and ending the saturated water when the color of the core is not obviously changed;
(3) Saturated oil: replacing the first burette with a burette containing oil, and replacing the second burette with an empty burette; pressurizing a burette containing oil by a pressurizing pump to enable the oil to enter a core slice; ending saturated oil when the oil is discharged from an empty burette connected with the outlet end of the core sheet and the color of the core is unchanged;
(4) Displacement of oil by fracturing fluid: replacing a burette connected with the inlet end of the core sheet with a burette containing fracturing fluid, and replacing the burette connected with the outlet end of the core sheet with an empty burette; pressurizing a burette containing fracturing fluid by a pressurizing pump to enable the fracturing fluid to enter a core slice; when the fracturing fluid is discharged from an empty burette connected with the outlet end of the core sheet and the color of the core is unchanged, the oil displacement of the fracturing fluid is finished;
(5) Oil back-drive fracturing fluid: replacing a burette connected with the outlet end of the core sheet with a burette containing oil, and replacing the burette connected with the inlet end of the core sheet with an empty burette; pressurizing a buret containing oil by a pressurizing pump to reversely drive the oil into the fracturing fluid in the core sheet; ending the oil back-driving fracturing fluid when the empty buret connected with the inlet end of the core slice produces oil and the color of the core is unchanged; observing the spontaneous imbibition phenomenon in the process of oil back-driving fracturing fluid;
(6) And calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid.
Preferably, in the step (6), the process of calculating the percentage of the residual fracturing fluid of the core that is spontaneously imbibed by the fracturing fluid is as follows:
calculating the retention of the fracturing fluid in the core sheet through scales of burets at two ends of the core sheet;
subtracting the water quantity in the first buret after the saturated water is ended from the water quantity in the first buret when the saturated water starts in the step (2), and subtracting the water quantity in the second buret after the saturated water is ended to obtain the water quantity L1 entering the core slice;
subtracting the oil quantity in the buret connected with the outlet end after the saturated oil is finished from the oil quantity in the buret containing the oil at the beginning of the saturated oil in the step (3), so as to obtain the oil quantity O1 entering the core sheet;
subtracting the water quantity in the burette connected with the outlet end in the step (3) from the water quantity L1 entering the core sheet in the step (2) to obtain the water quantity L2 in the core sheet after the saturated oil is finished;
subtracting the water quantity in the buret connected with the outlet end after the completion of fracturing oil displacement from the fracturing fluid quantity of the buret containing the fracturing fluid at the beginning of the fracturing fluid oil displacement in the step (4), and adding the water quantity L2 in the core sheet after the completion of saturated oil to obtain the fracturing fluid quantity F1 remained in the core sheet;
subtracting the oil quantity of the buret connected with the outlet end in the step (4) from the oil quantity O1 entering the core sheet in the step (3) to obtain the oil quantity O2 in the core sheet after the oil displacement of the fracturing fluid is finished;
the oil quantity in the buret connected with the outlet end at the beginning of the oil back-driving fracturing fluid in the step (5) is reduced, the oil quantity in the buret connected with the inlet end after the oil back-driving fracturing fluid is ended, and the oil quantity O2 in the core sheet after the step (4) is ended is added, so that the oil quantity O3 in the core sheet after the oil back-driving fracturing fluid is ended is obtained;
the fracturing fluid quantity F1 entering the core sheet after the step (4) is finished is subtracted by the fracturing fluid quantity F2 in the buret connected with the inlet end in the step (5) to obtain the fracturing fluid quantity F2 in the core sheet after the oil back-drive fracturing fluid is finished, and the percentage of the residual fracturing fluid of the core after spontaneous imbibition of the fracturing fluid is
Preferably, in the step (1), the water in the first burette is a sample prepared according to the water property of the stratum of the target layer, and methyl blue is added into the water to make the water blue;
in the step (4), the fracturing fluid is a sample prepared by a hydraulic fracturing construction fracturing fluid formula, and methyl blue is added into the fracturing fluid to make the fracturing fluid blue;
in the step (5), the oil adopts kerosene, and oil-soluble red dyeing is added into the kerosene to make the kerosene red.
Preferably, in the step (6), the process of calculating the percentage of the residual fracturing fluid of the core that is spontaneously imbibed by the fracturing fluid is as follows:
step 6.1, shooting a core slice in the operation process of the steps (1) to (5) through an optical microscope from the beginning of vacuumizing in the step (1) to the end of oil back-driving fracturing fluid in the step (5), shooting a full view after each step of shooting in the steps (2) to (5), and sending the shot image to an electronic computer through the optical microscope;
step 6.2, the electronic computer is used for describing the oil-water color in the image through different thresholds, so as to obtain a chromatogram of the full-view image;
step 6.3, analyzing the residual water quantity by the electronic computer according to the chromatogram to obtain a blue area F in the oil displacement process of the fracturing fluid in the step 4 1 ' blue area F of the oil counter-flooding fracturing fluid process of step (5) 2 ' and calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid as follows
Preferably, in the step (1), the time of vacuumizing is 5-10 hours;
in the step (2), the time of core saturation of the core sheet is 2-3 hours;
in the step (3), the pressurizing pump pressurizes the burette containing the oil for 5-8 hours;
in the step (4), the pressurizing pump pressurizes a burette containing the fracturing fluid for 5-8 hours;
in the step (5), the pressurizing time of the burette with the oil in the pressurizing pump is 5-8 hours.
Preferably, in the step (3), the pressure of the pressurizing pump pressurizing the burette containing the oil is 0.02 to 0.20MPa;
in the step (4), the pressurizing pump pressurizes a burette containing the fracturing fluid at a pressure of 0.02-0.20 MPa;
in the step (5), the pressurizing pump pressurizes the burette containing the oil at a pressure of 0.02 to 0.20MPa.
Preferably, from step (3) to step (5), after each step is finished, the core sheet is left for 6-12 hours, and the core sheet is aged.
The beneficial effects of the invention are:
according to the visual fracturing fluid spontaneous imbibition research device, the first buret and the second buret are respectively connected to the inlet end and the outlet end of the core sheet, and when the core sheet is vacuumized, the other end of the second buret is connected with the vacuum pump; when the core slice is driven forward, the other end of the first burette is connected with the pressurizing pump; when the core slice is driven reversely, the other end of the second buret is connected with the pressurizing pump; therefore, the occurrence of the phenomenon of fluid flow and imbibition can be visually seen in the research process, the defect that the prior art cannot directly observe is overcome, in addition, the spontaneous imbibition of the rock core can be quantitatively measured through the buret, and finally, the condition of spontaneous imbibition of the fracturing fluid can be qualitatively or even quantitatively obtained, so that the influence of the spontaneous imbibition of the fracturing fluid on production is obtained.
Further, the full-view image of the rock core slice can be photographed in real time through the optical microscope, the full-view image is analyzed and processed by the electronic computer, a chromatogram of the full-view image is obtained, and the electronic computer obtains areas of corresponding colors according to thresholds of different colors, so that the imbibition residual quantity and the imbibition residual fracturing fluid percentage of the fracturing fluid are obtained; the invention can visually see the occurrence of fluid flow and imbibition phenomenon by recording and analyzing through the optical microscope and the computer. In addition, the amount of the fracturing fluid finally remained in the core slice can be quantitatively calculated through an electronic computer, so that the influence of spontaneous imbibition of the fracturing fluid on production is obtained.
According to the visual fracturing fluid spontaneous imbibition research method, when the fracturing fluid spontaneous imbibition is researched, the fact that the fracturing fluid cannot be singly taken out to carry out imbibition experiments is considered, and the whole variable flowing process of stratum fluid during hydraulic fracturing is simulated is designed, so that four main steps of saturated water, saturated oil, fracturing fluid displacement and oil back-drive fracturing fluid are designed, the four main steps are respectively represented that original stratum pores are occupied by stratum water first, stratum pores are occupied by crude oil after oil generation until the fracturing fluid displaces crude oil to occupy pores during subsequent fracturing construction operation, and finally four processes of crude oil back-drive the fracturing fluid during production are considered, and the whole process from water to pore occupation until oil well oil production is simulated by a complete system, so that the research is closer to reality and more comprehensive.
Drawings
FIG. 1 is an overall schematic diagram of one embodiment of a visual fracturing fluid spontaneous imbibition research device of the invention;
FIG. 2 is a schematic illustration of a core sheet of the present invention;
FIG. 3 is a schematic flow chart of the research method of the present invention;
FIG. 4 is a full view taken with an optical microscope of the present invention;
FIG. 5 is a computer-derived chromatogram of the present invention.
Icon description: 1-booster pump, 2-rubber hose, 3-first burette, 3-1-second burette, 4-core slice, 5-vacuum pump, 6-optical microscope, 7-electronic computer, A-inlet end; b-outlet end.
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 will be clearly and completely described below with reference to the accompanying drawings. It will be apparent that the described embodiments are only some, but not all, embodiments of the invention. All other embodiments, which can be made by one of ordinary skill in the art without undue burden from the invention, are within the scope of the invention.
Referring to fig. 1 and 2, the visual fracturing fluid spontaneous imbibition research device comprises a booster pump 1, a first burette 3, a second burette 3-1, a core sheet 4 and a vacuum pump 5; the inlet end A of the core slice 4 is connected with one end of the first burette 3, and the outlet end B of the core slice 4 is connected with one end of the second burette 3-1;
referring to fig. 3, when the core sheet 4 is vacuumized, the other end of the second burette 3-1 is connected to the vacuum pump 5;
when the core slice 4 is driven forward, the other end of the first buret 3 is connected with the booster pump 1;
when the core sheet 4 is driven reversely, the other end of the second burette 3-1 is connected with the pressurizing pump 1.
Referring to fig. 3, in the present invention, forward driving means that the core sheet 4 is driven by pressurizing the core sheet 4 at the inlet end a of the core sheet 4; the reverse driving means that the outlet end B of the core slice 4 pressurizes and drives the core slice 4, and in the method, vacuumizing, saturated water, saturated oil and fracturing fluid displacement are all in a forward driving mode; the oil back-drive fracturing fluid is in a back-drive mode.
As shown in fig. 1, as a preferred embodiment of the present invention, the visual fracturing fluid spontaneous imbibition research device of the present invention further comprises an observation assembly, wherein the observation assembly comprises an optical microscope 6 and an electronic computer 7, the optical microscope 6 is connected with the electronic computer 7, and the core sheet 4 is arranged at the viewing center of the optical microscope 6. The optical microscope 6 of the present invention can be connected to an electronic computer 7 for subsequent experimental recording and data processing. The optical microscope 6 has the characteristics of being compatible with a computer system and software. The computer software described above is software that can distinguish between image pigments, including but not limited to Photoshop software and Nikon Nis-Elements Documentation software.
Referring to fig. 1, as a preferred embodiment of the present invention, the inlet end a of the core sheet 4 is connected to the first burette 3 through a rubber hose 2. The outlet end B of the core slice 4 is connected with the second burette 3-1 through a rubber hose 2. The first burette 3 is connected to the pressurizing pump 1 via a rubber hose 2.
As a preferred embodiment of the invention, the rubber hoses 2 at the two ends of the core slice are made of materials which are resistant to high pressure and are not easy to deform.
The visual fracturing fluid spontaneous imbibition research method disclosed by the invention comprises the following steps in sequence:
and (3) preparing a basic experimental material: as shown in fig. 2, after the core is obtained, the core is made into a core sheet 4, and a certain length of high-pressure-resistant rubber hose 2 which is not easy to deform is respectively connected to an inlet end a and an outlet end B of the core sheet 4. Preparing a stratum water sample according to the stratum water property of the target layer, and adding methyl blue into the stratum water sample to enable the stratum water sample to be blue; preparing a fracturing fluid sample according to a fracturing fluid formula for on-site fracturing construction, and adding methyl blue into the fracturing fluid sample to enable the fracturing fluid sample to be blue; adding oil-soluble red into kerosene by taking a kerosene sample as stratum oil to enable the kerosene to be red;
(2) Vacuumizing: as shown in step 1 of fig. 2, an inlet end a of the core sheet 4 is connected to a burette filled with water, an outlet end B of the core sheet 4 is connected to an empty burette and a vacuum pump 5, and the tightness of the connected overall structure is checked. After the inspection, if the tightness is good, the core sheet 4 is placed at the center of the view of the optical microscope 6, the optical microscope 6 is opened and connected with the electronic computer 7, and the connection condition of the system is inspected. Finally, clamping the rubber hose 2 at the joint of the core slice 4 and the burette filled with water by using a sealing clamp, opening a vacuum pump 5, and vacuumizing the core slice 4 for 5-10 hours;
(3) Saturated water: after the vacuum is drawn, the rubber hose 2 at the junction of the core sheet 4 and the vacuum pump 5 is clamped by a sealing clamp, and the vacuum pump 5 is turned off and removed, as shown in step 2 in fig. 2. And then opening the rubber hose 2 at the joint of the core sheet 4 and the burette (namely the burette connected with the inlet end A) to saturate the core with water, and ending the saturated water when the color of the core has no obvious change. Typically saturated water for 2-3 hours, and the core flakes are allowed to age for 6-12 hours after saturation is complete. The process simulates the process that water fills the rock pores under the original stratum condition;
(4) Saturated oil: as shown in step 3 of fig. 2, the burette connected to the inlet end a of the core sheet 4 is replaced with a burette containing oil, and the burette connected to the outlet end B is replaced with an empty burette. Then, the burette with the oil at the inlet end A of the core sheet 4 is connected with the pressurizing pump 1 and gradually pressurized, so that the oil in the burette connected with the inlet end A gradually enters the core sheet 4. And (3) ending the saturated oil after the oil is discharged from the air burette connected with the outlet end B for a period of time and when the color of the core is not obviously changed. The oil outlet period and the color of the core is changed in a nameless way means that: the liquid from the empty burette connected with the outlet end B is always the liquid in the burette at the pressurized inlet end, and the red area and the blue area in the core sheet 4 are not changed any more. Typically saturated oil for 5-8 hours, and the core flakes are allowed to age for 6-12 hours after saturation is complete. The process simulates the process of the formation to produce oil-gas and then oil-displacement water so as to occupy pores;
(5) Displacement of oil by fracturing fluid: at this time, as shown in step 4 of fig. 2, the burette connected to the inlet end a of the core sheet 4 is replaced with a burette containing the fracturing fluid, the burette connected to the outlet end is replaced with an empty burette, and the fracturing fluid in the burette connected to the inlet end a is pressurized to make the fracturing fluid enter the core sheet 4. And when the burette connected with the outlet end B outputs the fracturing fluid for a period of time and the color of the core is not obviously changed, the oil displacement of the fracturing fluid is finished. And (3) normally displacing oil for 5-8 hours, and placing the core slice for 6-12 hours after the completion of displacing oil of the fracturing fluid to age the core slice. The process simulates the process that fracturing fluid enters the stratum pores to drive away crude oil in the development process;
(6) Oil back-drive fracturing fluid: as shown in step 5 in fig. 2, the burette connected to the outlet end B is replaced with a burette containing oil, the burette connected to the inlet end a is replaced with an empty burette, the burette containing oil connected to the outlet end B is connected to the booster pump 1, and the booster pump 1 reversely pressurizes the oil in the burette containing oil connected to the outlet end B. And when the oil is discharged from the air burette connected with the inlet end A for a period of time and the color of the core is unchanged for a long time, the oil back-driving fracturing fluid is finished. The core slice is placed for 6-12 hours to age after the back driving is completed. The process simulates the process of entering the well bore by the oil after hydraulic fracturing;
the step (4) - (6) of gradually pressurizing the fracturing fluid sample or kerosene is performed by pressurizing the fracturing fluid sample or kerosene by the pressurizing pump 1 at a small constant pressure and then gradually pressurizing the fracturing fluid sample or kerosene. The pressure is not lower than 0.02MPa at the lowest and not more than 0.20MPa at the lowest. The pressure pressurization time of each stage is 1-2 hours.
(7) In the experimental process, the spontaneous imbibition phenomenon is observed and the data is recorded, specifically as follows:
by visual inspection: the blue liquid or the red liquid can be obviously seen by naked eyes to enter the core slice 4 to occupy a certain space, and a small amount of color change is still caused after the core slice is generally stable until no color change is finally caused;
observation by optical microscopy: the method is also a main observation mode, the optical microscope 6 can be used for amplifying local observation, water or oil or fracturing fluid can be clearly observed to occupy and remove the core pores, and the phenomenon that the fracturing fluid enters the micro pores to drive out spontaneous imbibition of oil can be observed more easily when the fracturing fluid enters the core sheet 4. Meanwhile, the optical microscope 6 is connected with the electronic computer 7, and the optical microscope 6 can shoot or record the whole experimental research process for subsequent analysis and calculation.
(8) Calculating treatment data to obtain the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid, wherein the step is divided into the following two conditions:
(a) Manual metering method: according to the method, the retention of the fracturing fluid in the core sheet 4 is calculated through scales of burettes at two ends of the core sheet 4:
(1) subtracting the water quantity in the first buret after the saturated water is ended from the water quantity in the first buret when the saturated water starts in the step (3), and subtracting the water quantity in the second buret after the saturated water is ended to obtain the water quantity L1 entering the core slice;
(2) subtracting the oil quantity in the buret connected with the outlet end after the saturated oil is finished from the oil quantity in the buret containing the oil at the beginning of the saturated oil in the step (4), so as to obtain the oil quantity O1 entering the core sheet;
(3) subtracting the water quantity in the burette connected with the outlet end in the step (4) from the water quantity L1 entering the core sheet in the step (3) to obtain the water quantity L2 in the core sheet after the saturated oil is finished;
(4) subtracting the water quantity in the buret connected with the outlet end after the completion of fracturing oil displacement from the fracturing fluid quantity of the buret containing the fracturing fluid at the beginning of the fracturing fluid oil displacement in the step (5), and adding the water quantity L2 in the core sheet after the completion of saturated oil to obtain the fracturing fluid quantity F1 remained in the core sheet;
(5) subtracting the oil quantity of the buret connected with the outlet end in the step (5) from the oil quantity O1 entering the core sheet in the step (4) to obtain the oil quantity O2 in the core sheet after the oil displacement of the fracturing fluid is finished;
(6) the oil quantity in the buret connected with the outlet end at the beginning of the oil back-driving fracturing fluid in the step (6) is reduced, the oil quantity in the buret connected with the inlet end after the oil back-driving fracturing fluid is ended, and the oil quantity O2 in the core sheet after the step (5) is ended is added, so that the oil quantity O3 in the core sheet after the oil back-driving fracturing fluid is ended is obtained;
(7) the fracturing fluid quantity F1 entering the core sheet after the step (5) is finished is subtracted by the fracturing fluid quantity F2 in the buret connected with the inlet end in the step (6) to obtain the fracturing fluid quantity F2 in the core sheet after the oil back-drive fracturing fluid is finished, and the percentage of the residual fracturing fluid of the core after spontaneous imbibition of the fracturing fluid is(b) Chromatograms method: referring to fig. 4 and 5, the method records the whole spontaneous imbibition process of the fracturing fluid through an optical microscope 6 and an electronic computer 7, and determines the spontaneous imbibition retention of the fracturing fluid by using a different chromatic aberration of the core sheet 4, namely Lan Seou fields for the fracturing fluid (the saturated region of the fracturing fluid shown in fig. 5), red fields for oil (the saturated region of the oil shown in fig. 5) and green fields for unoccupied empty pores (the unsaturated region shown in fig. 5). The method has the characteristics of rapidness and accuracy, and the process is as follows:
(1) starting vacuumizing in the step (2), opening the optical microscope 6 and computer software in the electronic computer 7 to start recording the whole experimental process, and shooting the full-view image of the core sheet 4 after each step from the step (3) to the step (6) is finished, as shown in fig. 4;
(2) importing the full-view images of the core sheet 4 in the step (5) and the step (6) into computer software, and describing the oil-water color by the computer software through different thresholds because different colors have different thresholds, so as to obtain a chromatogram of the full-view image, as shown in fig. 5;
(3) analyzing the residual water quantity by an electronic computer according to the chromatogram to obtain the fracturing fluid in the step (5)Blue area F of oil displacement process 1 ' blue area F of the oil counter-flooding fracturing fluid process of step (6) 2 '. And the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid is calculated by a computer
The research steps adopted by the invention can completely simulate the whole hydraulic fracturing process, display the seepage and suction conditions of the fracturing fluid of the local stratum, and realize the whole-course visualization and quantification. Simulating a process that water fills rock pores under the condition of an original stratum, simulating a process that oil displacement water occupies the pores after oil gas is generated by the stratum, simulating a process that fracturing fluid enters the stratum to drive away crude oil in the development process, and simulating a process that oil enters a shaft after hydraulic fracturing in the step (6); the core slice 4 is adopted for research instead of a whole core, so that the whole process is visible and the spontaneous imbibition phenomenon is observable; by adopting the buret with the metering function and the optical microscope, the liquid amount of the core slice can be effectively metered and discharged, so that the seepage and retention percentage of the fracturing liquid can be calculated.
In the invention, the step (2) is performed for at least 5 hours, and if the core is compact, the step (2) is recommended to be performed for 10 hours.
In the step (3), when the color of the core sheet does not change obviously, the method means that: the formation water sample dyed with methyl blue completely enters the core sheet which is vacuumized, and the blue area of the core sheet is not increased any more.
The step (4) to the step (6) of discharging liquid from the hollow burette end for a period of time means that: the liquid discharged from the empty burette connected with the outlet end B is always the liquid in the burette at the pressurized inlet end, and the oil and water quantity in the core slice reach balance; the core color does not change obviously means that: the red area and the blue area in the core slice are relatively stable. Satisfying the two conditions can be regarded as the end of the step.
After each of the steps (3) to (6) is completed, the core sheet is recommended to be placed for 6-12 hours, so that the core sheet is aged, and the real stratum condition can be simulated more.
In summary, the visual fracturing fluid spontaneous imbibition research device and method provided by the invention aim to research spontaneous imbibition of the fracturing fluid, and can simulate the whole hydraulic fracturing process, so that researchers can intuitively observe the spontaneous imbibition phenomenon through naked eyes and optical microscope equipment, and finally obtain the spontaneous imbibition situation of the fracturing fluid qualitatively and quantitatively.
Claims (2)
1. The visual fracturing fluid spontaneous imbibition research method is characterized by being carried out by a visual fracturing fluid spontaneous imbibition research device, wherein the visual fracturing fluid spontaneous imbibition research device comprises a booster pump (1), a first burette (3), a second burette (3-1), a core sheet (4), a vacuum pump (5) and an observation component; the inlet end (A) of the core sheet (4) is connected with one end of the first burette (3), and the outlet end (B) of the core sheet (4) is connected with one end of the second burette (3-1);
when the core slice (4) is vacuumized, the other end of the second burette (3-1) is connected with a vacuum pump (5);
when the core slice (4) is driven in the forward direction, the other end of the first burette (3) is connected with the pressurizing pump (1);
when the core slice (4) is driven reversely, the other end of the second burette (3-1) is connected with the pressurizing pump (1);
the observation assembly comprises an optical microscope (6) and an electronic computer (7), the optical microscope (6) is connected with the electronic computer (7), and the core sheet (4) is arranged at the center of the visual field of the optical microscope (6);
the visual fracturing fluid spontaneous imbibition research method comprises the following steps:
(1) Vacuumizing: filling water in the first burette (3), and emptying the second burette (3-1); the passage between the first burette (3) and the inlet end (A) of the core slice (4) is cut off, and the core slice (4) is vacuumized through a vacuum pump (5);
(2) Saturated water: after the vacuum is pumped, the passage between the second burette (3-1) and the vacuum pump (5) is cut off; conducting a passage between the first burette (3) and an inlet end (a) of the core sheet (4); saturated water is filled in the core of the core sheet (4), and when the color of the core is not obviously changed, the saturated water is ended;
(3) Saturated oil: replacing the first burette (3) with a burette containing oil, and replacing the second burette (3-1) with an empty burette; pressurizing a burette containing oil by a pressurizing pump (1) to enable the oil to enter a core slice (4); ending saturated oil when the empty burette connected with the outlet end (B) of the core sheet (4) produces oil and the color of the core is unchanged;
(4) Displacement of oil by fracturing fluid: replacing a burette connected with an inlet end (A) of the core sheet (4) with a burette containing fracturing fluid, and replacing a burette connected with an outlet end (B) of the core sheet (4) with an empty burette; pressurizing a burette containing fracturing fluid by a pressurizing pump (1) to enable the fracturing fluid to enter a core sheet (4); when the fracturing fluid is discharged from an empty burette connected with the outlet end (B) of the core sheet (4) and the color of the core is unchanged, the oil displacement of the fracturing fluid is finished;
(5) Oil back-drive fracturing fluid: replacing a burette connected with an outlet end (B) of the core sheet (4) with a burette containing oil, and replacing a burette connected with an inlet end (A) of the core sheet (4) with an empty burette; pressurizing a buret containing oil by a pressurizing pump (1) to reversely drive the fracturing fluid in the core sheet (4) by the oil; ending the oil back-driving fracturing fluid when the empty buret connected with the inlet end (A) of the core sheet (4) produces oil and the color of the core is unchanged; observing the spontaneous imbibition phenomenon in the process of oil back-driving fracturing fluid;
(6) Calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid;
in the step (6), the process of calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid is as follows:
subtracting the water quantity in the first buret (3) after the saturated water is ended from the water quantity in the first buret (3) when the saturated water starts in the step (2), and subtracting the water quantity in the second buret (3-1) after the saturated water is ended to obtain the water quantity L1 entering the core slice (4);
subtracting the oil quantity in the buret connected with the outlet end (B) after the saturated oil is finished from the oil quantity in the buret containing the oil at the beginning of the saturated oil in the step (3), so as to obtain the oil quantity O1 entering the core slice;
subtracting the water quantity in the burette connected with the outlet end (B) in the step (3) from the water quantity L1 entering the core sheet (4) in the step (2) to obtain the water quantity L2 in the core sheet (4) after the saturated oil is finished;
subtracting the water quantity in the buret connected with the outlet end (B) after the completion of fracturing oil displacement from the fracturing fluid quantity of the buret containing the fracturing fluid at the beginning of the fracturing fluid oil displacement in the step (4), and adding the water quantity L2 in the core sheet (4) after the completion of saturated oil to obtain the fracturing fluid quantity F1 remained in the core sheet (4);
subtracting the oil quantity of the burette connected with the outlet end (B) in the step (4) from the oil quantity O1 entering the core sheet in the step (3) to obtain the oil quantity O2 in the core sheet (4) after the oil displacement of the fracturing fluid is finished;
the oil quantity in the buret connected with the outlet end (B) at the beginning of the oil back-driving fracturing fluid in the step (5) is reduced, the oil quantity in the buret connected with the inlet end (A) after the oil back-driving fracturing fluid is ended, and the oil quantity O2 in the core sheet (4) after the step (4) is ended is added to obtain the oil quantity O3 in the core sheet (4) after the oil back-driving fracturing fluid is ended;
after the step (4) is finished, the fracturing fluid quantity F1 entering the core sheet (4) is subtracted by the fracturing fluid quantity F2 in the buret connected with the inlet end A in the step (5) to obtain the fracturing fluid quantity F2 in the core sheet (4) after the oil back-drive fracturing fluid is finished, and the percentage of the residual fracturing fluid of the core is spontaneously imbibed by the fracturing fluid；
In the step (1), water in a first burette (3) is a sample prepared according to the water property of a stratum of a target layer, and methyl blue is added into the water to make the water blue;
in the step (4), the fracturing fluid is a sample prepared by a hydraulic fracturing construction fracturing fluid formula, and methyl blue is added into the fracturing fluid to make the fracturing fluid blue;
in the step (5), kerosene is adopted as the oil, and oil-soluble red dyeing is added into the kerosene to make the oil red;
in the step (6), the process of calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid is as follows:
step 6.1, shooting a core sheet (4) in the operation process of the steps (1) to (5) through an optical microscope (6) from the beginning of vacuumizing in the step (1) to the end of oil back-driving fracturing fluid in the step (5), shooting the full view after each step of the steps (2) to (5) is finished, and sending the shot image to an electronic computer (7) through the optical microscope (6);
step 6.2, the electronic computer (7) is used for describing the oil-water color in the image through different thresholds, so as to obtain a chromatogram of the full-view image;
step 6.3, the electronic computer (7) analyzes the residual water according to the chromatogram to obtain the blue area in the oil displacement process of the fracturing fluid in the step 4Blue area of the process of driving the fracturing fluid reversely with the oil in the step (5)>And calculating the percentage of the residual fracturing fluid of the spontaneous imbibition core of the fracturing fluid to be +.>；
In the step (1), vacuumizing time is 5-10 hours;
in the step (2), the time of core saturated water of the core sheet (4) is 2-3 hours;
in the step (3), the pressurizing pump (1) pressurizes the burette containing the oil for 5-8 hours;
in the step (4), the pressurizing pump (1) pressurizes a burette containing the fracturing fluid for 5-8 hours;
in the step (5), the pressurizing time of a buret containing oil of the pressurizing pump (1) is 5-8 hours;
in the step (3), the pressurizing pump (1) pressurizes a burette containing oil at a pressure of 0.02-0.20 MPa;
in the step (4), the pressurizing pump (1) pressurizes a burette containing the fracturing fluid at a pressure of 0.02-0.20 MPa;
in the step (5), the pressurizing pump (1) pressurizes a burette containing oil at a pressure of 0.02-0.20 MPa;
and (3) after each step is finished, placing the core sheet (4) for 6-12 hours, and aging the core sheet (4).
2. The visual fracturing fluid spontaneous imbibition research method according to claim 1, characterized in that the inlet end (a) of the core sheet (4) is connected with the first burette (3) through a rubber hose (2); the outlet end (B) of the core slice (4) is connected with the second burette (3-1) through a rubber hose (2); the first burette (3) is connected with the pressurizing pump (1) through a rubber hose (2).
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| US11092586B1 (en) | 2020-05-22 | 2021-08-17 | Imperative Chemical Partners Inc. | Evaluating spontaneous hydraulic fracturing fluid imbibition and oil displacement method and apparatus |
| CN114166763A (en) * | 2021-11-18 | 2022-03-11 | 西安石油大学 | Method for measuring imbibition retention of tight sandstone reservoir |
| CN114215504A (en) * | 2022-01-08 | 2022-03-22 | 西安石油大学 | Visual simulation device and method for liquid retention after large-scale fracturing |
| CN115184118A (en) * | 2022-08-15 | 2022-10-14 | 西南石油大学 | Preparation method and preparation system of slice rock sample and core imbibition mechanism research method |
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