CN111398095A - Detection and evaluation method for fluid loss characteristics of fracturing fluid - Google Patents
Detection and evaluation method for fluid loss characteristics of fracturing fluid Download PDFInfo
- Publication number
- CN111398095A CN111398095A CN202010359018.6A CN202010359018A CN111398095A CN 111398095 A CN111398095 A CN 111398095A CN 202010359018 A CN202010359018 A CN 202010359018A CN 111398095 A CN111398095 A CN 111398095A
- Authority
- CN
- China
- Prior art keywords
- fracturing fluid
- micro
- flow field
- fluid
- detection
- 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 116
- 238000001514 detection method Methods 0.000 title claims abstract description 34
- 238000011156 evaluation Methods 0.000 title claims abstract description 21
- 238000010586 diagram Methods 0.000 claims abstract description 21
- 238000003384 imaging method Methods 0.000 claims abstract description 21
- 238000002347 injection Methods 0.000 claims abstract description 18
- 239000007924 injection Substances 0.000 claims abstract description 18
- 239000011148 porous material Substances 0.000 claims abstract description 17
- 238000000034 method Methods 0.000 claims description 19
- 239000011859 microparticle Substances 0.000 claims description 17
- 239000000700 radioactive tracer Substances 0.000 claims description 10
- 238000012545 processing Methods 0.000 claims description 8
- 238000011084 recovery Methods 0.000 claims description 6
- 238000004364 calculation method Methods 0.000 claims description 4
- 229920003229 poly(methyl methacrylate) Polymers 0.000 claims description 4
- 239000004926 polymethyl methacrylate Substances 0.000 claims description 4
- 230000000007 visual effect Effects 0.000 claims description 2
- 239000011435 rock Substances 0.000 abstract description 8
- 239000011159 matrix material Substances 0.000 abstract 2
- 238000011056 performance test Methods 0.000 abstract 1
- 229920000642 polymer Polymers 0.000 description 13
- 239000002245 particle Substances 0.000 description 10
- 239000000243 solution Substances 0.000 description 10
- 238000002474 experimental method Methods 0.000 description 5
- 238000011144 upstream manufacturing Methods 0.000 description 3
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 239000011521 glass Substances 0.000 description 2
- 238000003475 lamination Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- ABBQHOQBGMUPJH-UHFFFAOYSA-M Sodium salicylate Chemical compound [Na+].OC1=CC=CC=C1C([O-])=O ABBQHOQBGMUPJH-UHFFFAOYSA-M 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000002803 fossil fuel Substances 0.000 description 1
- XQSBLCWFZRTIEO-UHFFFAOYSA-N hexadecan-1-amine;hydrobromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[NH3+] XQSBLCWFZRTIEO-UHFFFAOYSA-N 0.000 description 1
- 239000000693 micelle Substances 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229960004025 sodium salicylate Drugs 0.000 description 1
- 230000001052 transient effect Effects 0.000 description 1
- 239000012780 transparent material Substances 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N11/00—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties
- G01N11/02—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties by measuring flow of the material
- G01N11/04—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties by measuring flow of the material through a restricted passage, e.g. tube, aperture
Landscapes
- Physics & Mathematics (AREA)
- Health & Medical Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Indicating Or Recording The Presence, Absence, Or Direction Of Movement (AREA)
Abstract
The invention relates to the field of performance test of fracturing fluid, and discloses a detection and evaluation method for fluid loss characteristics of fracturing fluid, which comprises the following steps: preparing a fracturing fluid and detection equipment, wherein the detection equipment comprises an injection system, a transparent or semitransparent micro model (4) and a flow field imaging system, and a micro channel which is used for simulating the porosity of a matrix and is provided with an inlet (5) and an outlet (6) is arranged in the micro model (4); injecting the fracturing fluid into the microchannel through the inlet (5) using the injection system, while acquiring a flow field map in the microchannel using the flow field imaging system; and evaluating the fluid loss of the fracturing fluid according to the flow field diagram. By the technical scheme, the pores of the rock matrix can be simulated through the micro model, the flowing state of the fracturing fluid in the micro channel is obtained, a flow field diagram is obtained, the flowing characteristic of the fracturing fluid is observed more visually, the fluid loss performance of the fracturing fluid is evaluated, and more accurate fluid loss data is obtained.
Description
Technical Field
The invention relates to performance detection of a fracturing fluid, in particular to a detection and evaluation method for fluid loss characteristics of the fracturing fluid.
Background
With the increase of global demand for fossil fuels, the exploitation potential of unconventional reservoirs such as coal bed gas and shale and tight reservoirs has attracted high attention from the oil-gas world, and therefore, the efficient development of unconventional reservoirs has become an important research field. Hydraulic fracturing is one of the most effective methods to increase the recovery of unconventional oil reservoirs. As an important index for evaluating the performance of the fracturing fluid, the fluid loss of the fracturing fluid is related to the quality of a hydraulic fracturing effect.
At present, a common method for researching the fluid loss is mainly a macroscopic indoor physical simulation experiment, such as simulating an artificial crack by combining two artificial rock cores, establishing a fracturing fluid loss simulation device based on a flat plate model and the like. In the experiment, the filtration rule of the fracturing fluid in the test is researched by mainly utilizing rock cores, sand filling models and the like to simulate the formation macro-fracture morphology. However, the indoor physical model experiment is greatly influenced by factors such as core permeability, porosity, pore throat structure and the like, the experimental result has no repeatability, the accuracy of data is low, and the experimental operation is relatively complicated.
Disclosure of Invention
The invention aims to provide a method for detecting and evaluating the fluid loss characteristics of a fracturing fluid, which aims to solve the problems of complex operation, inconvenience in observing the flow characteristics of the fracturing fluid and the like.
In order to achieve the above object, the present invention provides a method for detecting and evaluating fluid loss characteristics of a fracturing fluid, wherein the method comprises:
preparing fracturing fluid and detection equipment, wherein the detection equipment comprises an injection system, a transparent or semitransparent microscopic model and a flow field imaging system, and a microchannel which is used for simulating cracks and is provided with an inlet and an outlet is arranged in the microscopic model;
injecting the fracturing fluid into the microchannel through the inlet using the injection system while acquiring a flow field map in the microchannel using the flow field imaging system;
and evaluating the fluid loss of the fracturing fluid according to the flow field diagram.
Optionally, in the detection and evaluation method, a visualized micro particle tracer is added to the fracturing fluid and then injected into the micro channel, and the flow field image system is used to obtain a flow field map in the micro channel according to the micro particle tracer.
Optionally, the flow field imaging system includes a microscopic particle image velocimeter, a controller and a computer, and in the detection and evaluation method, the controller controls the microscopic particle image velocimeter to focus and shoot the fluid in the microchannel, and transmits the shot image to the computer for computational processing, so as to obtain the flow field map.
Optionally, the microchannel comprises two throats and a channel between the two throats, the channel having a width greater than the throat width, wherein the flow field pattern comprises a flow field pattern of the channel.
Alternatively, the width of the tunnel is 2 to 16 times the width of the throat, and the tunnel is symmetrical about a central axis in the length direction of the throat.
Alternatively, the tunnel and the throat are the same depth and the flow in the microchannel is viewed in the depth direction using the flow field imaging system.
Alternatively, the micro-mold comprises a first plate portion and a second plate portion connected in a detachable lamination, and the micro-channel is composed of a groove formed on a surface of the first plate portion and/or the second plate portion.
Alternatively, the first plate portion and the second plate portion are made of polymethyl methacrylate, and the first plate portion and the second plate portion are connected by a bolt.
Alternatively, the injection system may include a micro-flow pump, a syringe, and a catheter connectable to the syringe and an inlet of the micro-channel, and in the detection and evaluation method, the syringe containing the fracturing fluid is mounted to the micro-flow pump, and a constant pressure is applied to the syringe by the micro-flow pump to continuously inject the fracturing fluid into the micro-channel.
Optionally, the test device further comprises a recovery vessel connected to the outlet.
By the technical scheme, rock cracks can be simulated through the micro model, the flowing state of the fracturing fluid in the micro channel is obtained, a flow field diagram is obtained, the flowing characteristic of the fracturing fluid is observed more visually, the fluid loss characteristic of the fracturing fluid is evaluated, more accurate fluid loss data is obtained, and the method is simple to operate and convenient for repeated experiments.
Drawings
FIG. 1 is a schematic structural diagram of a detection apparatus according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of the structure of microchannels of a micromodel according to an embodiment of the present invention;
FIG. 3 is a flow field diagram of a polymer fracturing fluid in accordance with an embodiment of the present invention;
fig. 4 is a flow field diagram of a clean fracturing fluid in accordance with an embodiment of the present invention.
Description of the reference numerals
1 micro-flow pump 2 cylinder
3 catheter 4 micro-model
5 inlet 6 outlet
7 throat 8 duct
9 recovery container 10 microscopic particle image velocimeter
11 controller 12 computer
Detailed Description
The following detailed description of embodiments of the invention refers to the accompanying drawings. It should be understood that the detailed description and specific examples, while indicating the present invention, are given by way of illustration and explanation only, not limitation.
The invention provides a detection and evaluation method for fluid loss characteristics of fracturing fluid, wherein the detection and evaluation method comprises the following steps:
preparing a fracturing fluid and detection equipment, wherein the detection equipment comprises an injection system, a transparent or semitransparent micro model 4 and a flow field imaging system, and a micro channel which is used for simulating a crack and is provided with an inlet 5 and an outlet 6 is arranged in the micro model 4;
injecting the fracturing fluid into the microchannel through the inlet 5 by using the injection system, and simultaneously acquiring a flow field diagram in the microchannel by using the flow field imaging system;
and evaluating the fluid loss of the fracturing fluid according to the flow field diagram.
The detection and evaluation method for the fluid loss characteristics of the fracturing fluid is used for detecting the fluid loss characteristics of the fracturing fluid, and the detection equipment comprises a micro model 4, an injection system capable of injecting the fracturing fluid into the micro model 4 and a flow field imaging system capable of observing and acquiring a flow field diagram in the micro model 4. Wherein, micro-channels are arranged in the micro-model 4 and used for simulating rock cracks in the stratum, the micro-channels extend to the outside of the micro-model 4 to form an inlet 5 and an outlet 6, the fracturing fluid can be injected from an injection system through the inlet 5, and the fracturing fluid can be discharged through the outlet 6. In addition, the micro-model 4 is a transparent or translucent structure to allow light to transmit to observe the fluid in the micro-channel therein, where the micro-model 4 is a micro-scale micro-channel, and the micro-model 4 may be a macro-scale micro-model.
In the process of injecting the fracturing fluid into the micro-channel through the injection system, the fracturing fluid flows in the micro-channel, the flowing process can simulate the flowing condition of the fracturing fluid in a stratum rock fracture, at the moment, the fluid in the micro-channel is observed through the flow field imaging system, the flowing condition of the fluid is suggested in a mode of shooting pictures and recording videos, and the pictures and the recording videos are further processed to obtain a flow field diagram of the fluid, so that the filtration property of the used fracturing fluid can be analyzed and evaluated according to the flow field diagram.
In the detection and evaluation method, a visual micro particle tracer is added into the fracturing fluid and then injected into the micro channel, and a flow field diagram in the micro channel is obtained according to the micro particle tracer by using the flow field imaging system. The particulate tracer comprises chemically and physically stable particulates that are insoluble in the fracturing fluid and are non-transparent, visible particulates, such as colored particles (and of a different color than the fracturing fluid), that are uniformly dispersed in the fracturing fluid and flow substantially simultaneously as the fracturing fluid flows in the microchannels, thereby clearly indicating and reflecting the flow conditions of the fracturing fluid. The flow field imaging system can obtain the flow state of the micro-particles by shooting pictures and recording videos, and obtains the flow field of the micro-particles through calculation processing, so that the flow field of the fracturing fluid is represented by the flow field of the micro-particles.
The fracturing fluid used in the scheme comprises a polymer fracturing fluid and a clean fracturing fluid, wherein the polymer fracturing fluid is a polymer solution which is prepared by dissolving 800-1200 ten thousand molecular weight polyacrylamide (HPAM) powder (Allantin company, purity 99.9%) in water and has a mass fraction of 0.1-0.3%, the clean fracturing fluid is prepared by fully mixing 10-30 mMol/L hexadecylammonium bromide (CTAB) and 5-15 mMol/L sodium salicylate (NaSal), the fracturing fluid is kept still for 24 hours at room temperature (20 ℃) after preparation to ensure that the solution is uniform, the used microparticle tracer is a Fluoro-Max fluorescent microparticle solution with a particle size of 0.9 mu m and a content of 1%, in the detection and evaluation method, the microparticle tracer can be added into the fracturing fluid for 1 drop, and placed into a water bath ultrasonic analyzer at 40 ℃ for 1 minute so that the microparticle tracer is fully and uniformly dispersed in the fracturing fluid.
Specifically, the flow field imaging system comprises a microscopic particle image velocimeter 10, a controller 11 and a computer 12, wherein in the detection and evaluation method, the controller 11 controls the microscopic particle image velocimeter 10 to focus and shoot the fluid in the microchannel, and the shot image is transmitted to the computer 12 for calculation processing to obtain the flow field image. The flow field imaging system comprises a micro particle image velocimeter 10 (model is mu-PIV), a controller 11 and a computer 12 which are electrically connected with each other, wherein the micro particle image velocimeter 10 can capture the flow state of micro particles (such as the above-mentioned Fluoro-Max red fluorescent particles) in the fracturing fluid and shoot to form a picture and a video, the controller 11 is a MITAS controller and can control the focusing, the imaging field of view and the like of the micro particle image velocimeter 10 and shoot, and the controller 11 can transmit the shooting result to the computer 12 so as to obtain a flow field image by processing the picture and the video through the computer 12. The microscopic particle image velocimeter 10 can take pictures directly and when pictures are taken continuously at small time intervals (e.g. 20ms as described below) the pictures can be combined into a dynamic video recording.
The controller 10 has a rocker arm which can be used to perform a focusing operation to set a focusing point at a target position, for example, at the junction between the tunnel 8 and the throat 7 and the tunnel 8, the exposure time 80000 μ s is selected, a calibration operation is performed using a Scaling module, and a laser of the microscopic particle image velocimeter 10 is turned on to perform photographing to obtain a flow chart (in which the photographing interval is 20ms), the obtained flow chart is subjected to batch Processing on the computer 12 using a Processing module, the Processing range is defined at the tunnel 8 (the calculation area is 800 μm × 800 μm), the flow arrow density is selected to be × 1 and × 2, the injection direction of the solution is set as an x coordinate axis, the direction horizontal to the flow direction is set as a y coordinate axis, and the flow field measured by the experiment is shown in fig. 3 and 4.
Specifically, the microchannel comprises two sections of throats 7 and a duct 8 positioned between the two sections of throats 7, wherein the width of the duct 8 is larger than that of the throat 7, and the flow field diagram comprises a flow field diagram of the duct 8. Referring to fig. 2, a schematic structural diagram of a microchannel is shown, wherein two ends are respectively an inlet 5 and an outlet 6, and the microchannel comprises two throats 7 and a pore canal 8 between the two throats 7, so that the flow width of the fracturing fluid is smaller, and the pore canal 8 has a larger width, and the microchannel structure can be used for simulating a fracture structure in rock, so that the fluid flows approximately in the rock fracture, and similar flow data of the fracturing fluid can be observed. The flow field pattern finally obtained by the method is mainly the flow field pattern of the fluid in the duct 8, and certainly, the method is not limited thereto, and the fluid in the part of the throat 7 connected with the duct 8 can be observed to obtain a corresponding flow field pattern, and particularly the flow pattern in the part of the throat 7 connected with the duct 8 is needed to help obtain the flow field pattern of the duct 8.
Alternatively, the width of the tunnel 8 is 2 to 16 times the width of the throat 7, and the tunnel 8 is symmetrical about the central axis of the length of the throat 7. Both the throat 7 and the tunnel 8 are symmetrical about a central axis in the length direction, and the width of the tunnel 8 is preferably 8 times the width of the throat 7, although other width ratios are possible.
Wherein the tunnel 8 and the throat 7 have the same depth, and the flow in the microchannel is observed in the depth direction using the flow field imaging system. In the microchannel, the length direction, the width direction and the depth direction are perpendicular to each other, wherein the sizes of the channel 8 and the throat 7 in the depth direction are basically the same, but the sizes of the channel 8 and the throat 7 in the width direction are different, and the flow field imaging system observes the fluid in the microchannel in the depth direction, namely the flowing condition of the fracturing fluid is reflected on a plane where the length direction and the width direction are located together, and particularly the influence of the width change of the connecting part of the throat 7 and the channel 8 on the flow field is reflected. Wherein the depth of the duct 8 and the throat 7 may be 100 μm, the length of the duct 8 is 800 μm, the width is 800 μm, and the width of the throat 7 is 100 μm.
Alternatively, the micro-mold 4 includes a first plate portion and a second plate portion connected in a detachable lamination, and the micro-channel is composed of a groove formed on a surface of the first plate portion and/or the second plate portion. The first plate portion and the second plate portion may be transparent or translucent plate members and may be detachably laminated together, and grooves may be formed on surfaces of the two plate portions facing each other to fit the microchannels.
Further, the first plate portion and the second plate portion are made of polymethyl methacrylate, and the first plate portion and the second plate portion are connected by a bolt. Being made of polymethylmethacrylate, which facilitates perforation and bolting, allows the two plate portions to be removed when the microchannel is blocked, and the grooves described above may be etched in only one of the plate portions, conforming to the other plate portion to form the microchannel. Of course, in other embodiments, the first plate portion and the second plate portion may be made of glass.
Specifically, the injection system comprises a micro-flow pump 1, a syringe 2 and a catheter 3, wherein the catheter 3 can be connected to the syringe 2 and an inlet 5 of the micro-channel, in the detection and evaluation method, the syringe 2 filled with the fracturing fluid is mounted on the micro-flow pump 1, and constant pressure is applied to the syringe 2 through the micro-flow pump 1 so as to continuously inject the fracturing fluid into the micro-channel. The cylinder 2 may be made of a transparent material such as glass or plastic for containing the fracturing fluid, and the micro-flow pump 1 may be connected to the cylinder 2 to pressurize it so that the fracturing fluid is injected into the micro-channel through the conduit 3, and the injection flow rate may be set to Q ═ 15ml/hr so that a steady and continuous flow is formed in the micro-channel, for example, the flow rate in the throat 7 is maintained substantially constant.
Furthermore, the detection device comprises a recovery vessel 9 connected to the outlet 6. The recovery tank 9 may collect the fracturing fluid discharged from the outlet 6 for the next use.
The following are specific experimental data of two different fracturing fluids, wherein in the micro model 4, the depth of the pore canal 8 and the throat 7 is 100 μm, the length of the pore canal 8 is 800 μm, the width of the throat 7 is 100 μm, the flow rate Q is 15ml/hr, the flow rate arrow density is selected to be × 1 and × 2, the injection direction of the solution is set to be an x-coordinate axis (x-position), the direction horizontal to the flow direction is set to be a y-coordinate axis (y-position), and the flow field measured by the experiment is shown in fig. 3 and fig. 4.
The fluid loss of the fracturing fluid was evaluated by comparing the flow field diagrams of fig. 3 and 4:
(1) the flow field distribution of the polymer fracturing fluid (HPAM solution) in the channels is shown in figure 3. The flow field of the polymer fracturing fluid is kept stable, the flow mode is symmetrical between the upstream and the downstream of the pore canal 8, and the flow mode is a protruding structure (x is 400 mu m) at the joint of the throat 7 and the pore canal 8 at the upstream and a protruding structure (x is-400 mu m) at the joint of the pore canal 8 and the throat 7 at the downstream; the solution flow is basically concentrated at the center of the channel structure, the main flow area ranges from-125 μm to 125 μm, no obvious flow velocity line can be measured in other areas, the flow velocity (velocity) is very close to 0, and the flow velocity outside the main flow area is very small and can be ignored; the arrows showing the flow velocity lines within the flow field are all along the x-axis, and little flow is observed along the y-axis.
As can be seen from the measured flow field pattern of the polymer fracturing fluid, at a higher injection rate (flow rate Q ═ 15ml/hr), the flow pattern of the polymer solution exhibits a pattern similar to a "stripe" in the cell structure, the solution flows mainly in the middle region of the cell structure, and the streamlines maintain an aggregated morphology; the flow pattern of the polymer fracturing fluid is not greatly influenced by the structures of 'protruding' and 'protruding shrinkage', and the flow speed outside the main flow zone is very low. Thus, the polymer fracturing fluid has a relatively small fluid loss within the porous media.
(2) The flow field distribution of clean fracturing fluid (CTAB + NaSal) in the channels is shown in fig. 4. The flow field of the clean fracturing fluid remains stable, but the flow mode of the clean fracturing fluid is greatly different from that of the polymer fracturing fluid. The flow pattern of the flow field of the clean fracturing fluid is asymmetric up and down in the pore channel structure, after the flow passes through the upstream 'projecting' structure (x is 400 mu m), the flow line does not keep an aggregated state as the flow line of the polymer fracturing fluid, but shows a flow state of diverging flow line, the flow line diverges towards two sides from the connection part of the throat 7 and the pore channel 8, and the flow velocity line arrow comprises velocity components along the x coordinate axis and the y coordinate axis; and converging from two sides of the pore throat structure to the central area again at the position where x is 100 mu m, and finally showing the state of a gathered streamline of the polymer-like fracturing fluid at the connection part of the pore canal 8 and the throat 7 at the downstream of the pore throat structure.
According to the measured clean fracturing fluid flow field diagram, the flow pattern of the clean fracturing fluid flow field diagram shows a flow mode similar to a triangle in the pore throat structure, and the streamline has a form of first divergence and then convergence. This is due to the fact that the wormlike micelles in the clean fracturing fluid have dynamic properties of fracture-rearrangement, and the extensional viscosity drops sharply due to the transient strong tensile effect when passing through the "open" structure, and the streamlines are difficult to maintain an aggregated morphology like that of a polymer fracturing fluid. Thus, clean fracturing fluids have relatively greater fluid loss within the porous media than polymeric fracturing fluids.
The experimental results show that the fluid loss performance of the fracturing fluid can be evaluated by researching the flow pattern in the pore throat structure of the fracturing fluid.
The preferred embodiments of the present invention have been described in detail above with reference to the accompanying drawings, but the present invention is not limited thereto. Within the scope of the technical idea of the invention, numerous simple modifications can be made to the technical solution of the invention, including combinations of the specific features in any suitable way, and the invention will not be further described in relation to the various possible combinations in order to avoid unnecessary repetition. Such simple modifications and combinations should be considered within the scope of the present disclosure as well.
Claims (10)
1. A detection and evaluation method for fluid loss characteristics of fracturing fluid is characterized by comprising the following steps:
preparing a fracturing fluid and detection equipment, wherein the detection equipment comprises an injection system, a transparent or semitransparent micro model (4) and a flow field imaging system, and a micro channel which is used for simulating a crack and is provided with an inlet (5) and an outlet (6) is arranged in the micro model (4);
injecting the fracturing fluid into the microchannel through the inlet (5) using the injection system, while acquiring a flow field map in the microchannel using the flow field imaging system;
and evaluating the fluid loss of the fracturing fluid according to the flow field diagram.
2. The method of claim 1, wherein the method comprises injecting a visual particulate tracer into the fracturing fluid and then injecting the fluid into the microchannel, and wherein the flow field image system is used to obtain a flow field pattern in the microchannel according to the particulate tracer.
3. The detection and evaluation method for the fluid loss characteristics of the fracturing fluid according to claim 2, wherein the flow field imaging system comprises a micro particle image velocimeter (10), a controller (11) and a computer (12), and in the detection and evaluation method, the micro particle image velocimeter (10) is controlled by the controller (11) to focus and shoot the fluid in the micro channel, and the shot image is transmitted to the computer (12) for calculation processing to obtain the flow field image.
4. The method for detecting and evaluating the fluid loss characteristics of the fracturing fluid according to claim 1, wherein the micro-channel comprises two throats (7) and a duct (8) positioned between the two throats (7), the width of the duct (8) is larger than that of the throat (7), and the flow field pattern comprises a flow field pattern of the duct (8).
5. The method for detecting and evaluating the fluid loss characteristics of a fracturing fluid according to claim 4, wherein the width of the duct (8) is 2 to 16 times the width of the throat (7), and the duct (8) is symmetrical about a central axis in the length direction of the throat (7).
6. The method for detecting and evaluating the fluid loss characteristics of the fracturing fluid according to claim 5, wherein the depth of the pore canal (8) and the throat (7) is the same, and the fluid in the micro-channel is observed along the depth direction by using the flow field imaging system.
7. The method for the detection and evaluation of the fluid loss characteristics of a fracturing fluid according to claim 6, wherein the micro-model (4) comprises a first plate portion and a second plate portion which are detachably connected in a stacked manner, and the micro-channel is composed of grooves formed on the surface of the first plate portion and/or the second plate portion.
8. The method for detecting and evaluating the fluid loss characteristics of a fracturing fluid according to claim 7, wherein the first plate portion and the second plate portion are made of polymethyl methacrylate, and the first plate portion and the second plate portion are connected by a bolt.
9. The method for the detection and evaluation of the fluid loss characteristics of a fracturing fluid according to claim 1, wherein the injection system comprises a micro-flow pump (1), a cylinder (2) and a conduit (3), the conduit (3) being connectable to the cylinder (2) and an inlet (5) of the micro-channel, and in the detection and evaluation method, the cylinder (2) containing the fracturing fluid is mounted to the micro-flow pump (1), and a constant pressure is applied to the cylinder (2) by the micro-flow pump (1) to continuously inject the fracturing fluid into the micro-channel.
10. The method for the detection and evaluation of the fluid loss characteristics of a fracturing fluid according to claim 1, wherein the detection device further comprises a recovery tank (9) connected to the outlet (6).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010359018.6A CN111398095A (en) | 2020-04-29 | 2020-04-29 | Detection and evaluation method for fluid loss characteristics of fracturing fluid |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010359018.6A CN111398095A (en) | 2020-04-29 | 2020-04-29 | Detection and evaluation method for fluid loss characteristics of fracturing fluid |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN111398095A true CN111398095A (en) | 2020-07-10 |
Family
ID=71435434
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010359018.6A Pending CN111398095A (en) | 2020-04-29 | 2020-04-29 | Detection and evaluation method for fluid loss characteristics of fracturing fluid |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111398095A (en) |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101899975A (en) * | 2010-08-02 | 2010-12-01 | 成都理工大学 | Experimental evaluation method suitable for coal-bed fracturing fluid flow filtration |
| US20180002596A1 (en) * | 2015-01-16 | 2018-01-04 | Schlumberger Technology Corporation | Subterranean fluids containing suspended polymer bodies |
| CN108287123A (en) * | 2018-02-05 | 2018-07-17 | 中国石油大学(华东) | A kind of measurement CO2The visualization device and method of solid-carrying performance under the conditions of fracturing fluid high pressure dynamic filtration |
| CN109113692A (en) * | 2018-08-23 | 2019-01-01 | 中国石油大学(华东) | The method of process recovery ratio that matrix-crack dual media handles up physical simulating device and evaluation is handled up |
| CN109211912A (en) * | 2018-08-02 | 2019-01-15 | 西南石油大学 | A kind of foam fracturing fluid prop-carrying capacity evaluating apparatus and working method |
| CN110348031A (en) * | 2018-04-08 | 2019-10-18 | 中国石油化工股份有限公司 | The nearly pit shaft crack distorted configurations method for numerical simulation of fractured horizontal well |
| CN110987636A (en) * | 2019-12-03 | 2020-04-10 | 西南石油大学 | Flat plate and experimental device for simulating influence of natural fracture fluid loss on proppant paving |
-
2020
- 2020-04-29 CN CN202010359018.6A patent/CN111398095A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101899975A (en) * | 2010-08-02 | 2010-12-01 | 成都理工大学 | Experimental evaluation method suitable for coal-bed fracturing fluid flow filtration |
| US20180002596A1 (en) * | 2015-01-16 | 2018-01-04 | Schlumberger Technology Corporation | Subterranean fluids containing suspended polymer bodies |
| CN108287123A (en) * | 2018-02-05 | 2018-07-17 | 中国石油大学(华东) | A kind of measurement CO2The visualization device and method of solid-carrying performance under the conditions of fracturing fluid high pressure dynamic filtration |
| CN110348031A (en) * | 2018-04-08 | 2019-10-18 | 中国石油化工股份有限公司 | The nearly pit shaft crack distorted configurations method for numerical simulation of fractured horizontal well |
| CN109211912A (en) * | 2018-08-02 | 2019-01-15 | 西南石油大学 | A kind of foam fracturing fluid prop-carrying capacity evaluating apparatus and working method |
| CN109113692A (en) * | 2018-08-23 | 2019-01-01 | 中国石油大学(华东) | The method of process recovery ratio that matrix-crack dual media handles up physical simulating device and evaluation is handled up |
| CN110987636A (en) * | 2019-12-03 | 2020-04-10 | 西南石油大学 | Flat plate and experimental device for simulating influence of natural fracture fluid loss on proppant paving |
Non-Patent Citations (1)
| Title |
|---|
| YUAN LI.ET AL: "Viscoelastic surfactant fluids filtration in porous media: A pore-scale study", 《AICHE JOURNAL》 * |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN106596336A (en) | Apparatus and method for measuring elastic turbulence characteristics of viscoelastic polymer in porous medium | |
| CN108333093A (en) | Three-dimensional fracture network rock mass two-phase medium seepage flow test device under a kind of stress | |
| CN106812517B (en) | High concentration particle motion state and liquid flow field monitor experimental method simultaneously in crack | |
| CN105092446A (en) | Two-dimensional visual percolation experiment method capable of simulating in-layer heterogeneity | |
| CN105096719A (en) | Anisotropic two-dimensional visual sand filling model in simulation layer and two-dimensional visual seepage experimental device | |
| CN109779593A (en) | A kind of visualization plate crack device of achievable three-dimensional flow field test | |
| Chen et al. | Core-and pore-scale investigation on the migration and plugging of polymer microspheres in a heterogeneous porous media | |
| Meng et al. | Effect of viscosity on oil production by cocurrent and countercurrent imbibition from cores with two ends open | |
| CN110044774A (en) | Emulsify the micro fluidic device and method for improving recovery ratio research in situ for surfactant | |
| CN108287123B (en) | CO under dynamic filtration2Fracturing fluid sand-carrying visual testing device and method | |
| CN110302851A (en) | Experimental system and its experimental method based on microfluidic control and Jamin effect observation | |
| Lu et al. | Flow measurements in microporous media using micro-particle image velocimetry | |
| CN107939363A (en) | Simulate the Visualization Model of fluid flowing and preparation and application in compact oil reservoir crack | |
| Ma et al. | Experimental investigation of proppant flow and transport dynamics through fracture intersections | |
| Chen et al. | Relative permeability measurement of coal microchannels using advanced microchip technology | |
| CN107860694B (en) | Method for measuring migration rule of pre-crosslinked gel particles in rock microscopic pore throats | |
| Turney et al. | A method for three-dimensional interfacial particle image velocimetry (3D-IPIV) of an air–water interface | |
| Li et al. | Investigation on flow characteristic of viscoelasticity fluids in pore-throat structure | |
| CN112727416A (en) | In-situ microemulsion generation and oil displacement efficiency testing device and method | |
| CN111398095A (en) | Detection and evaluation method for fluid loss characteristics of fracturing fluid | |
| Li et al. | Quantitative experimental study on the rule of fluid flow and its influencing factors in hydraulic fractures | |
| CN116625863A (en) | Visual testing device and method for researching interaction influence of grouting and fracture morphology | |
| CN216132663U (en) | Device for testing resistance reduction performance in fracturing fluid gap based on flow field test | |
| CN115615871A (en) | High Reynolds number slickwater fracturing fluid drag reduction mechanism testing device and method | |
| Blonski et al. | Analysis of turbulence in a micro-channel emulsifier |
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 | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20200710 |
|
| RJ01 | Rejection of invention patent application after publication |